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HomeMy WebLinkAbout206-055 STATE OF ALASKA AKA OIL AND GAS CONSERVATION COM SION .. REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other:Scale Inhibitor Treatment ❑., 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory ❑ 206-055 3.Address: Stratigraphic Q Service ❑ 6.API Number: P.O. Box 100360,Anchorage,AK 99510 50-103-20531-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380077, 384211 CRU CD4-320 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): None Colville River Field/Alpine Oil Pool 11.Present Well Condition Summary: Total Depth measured 14471 feet Plugs measured None feet true vertical 7019 feet Junk measured None feet Effective Depth measured 14471 feet Packer measured 7487 feet true vertical 7019 feet true vertical 6877 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 16" 114' 114' Surface 2472' 9.625" 2509' 2378' Intermediate Production 8111' 7" 8145' 6991' Liner 6534' 4.5" 14462' 7019' RECEIVED Perforation depth Measured Depth: Slotted Liner 8122'- 14420' SCAN E FEBJAN 14 2C11 True Vertical Depth: 6991' 7017' , Tubing(size,grade,measured and true vertical depth) 4.5", L-80, 7926' MD and 6985'TVD AOGCC Packers and SSSV(type,measured and true vertical depth) Packer: Baker Premier Packer, 7487' MD and 6877'TVD SSSV: Camco WRDP-2, 2048'MD and 1959'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 8145'-14471' Treatment descriptions including volumes used and final pressure: Please see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 452 4972 4190 1656 1074 Subsequent to operation: Well has not been tested since squeeze job (Temporarily Shut-In for Gas Handling) 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work. Daily Report of Well Operations Q Exploratory❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. 'Sundry Number or N/A if C.O.Exempt: N/A Contact Kerry Freedman Email Kerry.C.Freedman(a�cop.com Printed Name Kerry Freedman A Title Principal Production Engineer Signature 7/l.LLJfl4s._-.. Phone 265-6579 Date i/13 lit v1 - 1/72 /1 I te ` I Form 10-404 Revised 5/2015 /�4/(6 RBDMSJ'I AN 1 4 2016 Submit Original Only • • CD4-320 Scale Inhibition Treatment 12/17/15—12/18/15 Aqueous Scale Inhibitor Squeeze Job pumped from 11:00 on 12/17/15 to 06:45 on 12/18/15. LRS= Little Red Services ACF=Alpine Central Facility - Initial pressure TBG/IA/OA—1113/1300/675 - ACF pumped 30 bbls produced water for a tubing flush at 2.25—3.19 bpm,TBG/IA/OA- 1024/1320/687 - LRS pumped 23 bbls WAW5206 at .3 bpm while ACF pumped 207.5 bbls produced water at 2.46 —2.84 bpm,TBG/IA/OA-409/1447/760 - LRS pumped 34.6 bbls SCW4004 scale inhibitor at.45 bpm while ACF pumped 196 bbls produced water at 2.49 bpm,TBG/IA/OA—369/1454/765 - ACF pumped 2247 bbls produced water overflush at 2—2.5 bpm,TBG/IA/OA-418/1533/798 Interval treated: 8145'—14471' WNS1111 CD4-320 ' COnOCOPh1II1 0"1169 Well Attributes Max Angle&MD TD a, Aaska I Wellbore API/UWI Field Name Well Status Mel(") MD IRKS) Act Btm(ftKB) tsxxa-+mops , 501032053100 NANUQ KUPARUK PROD 92.16 11,364.87 14,471.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(R) Rig Release Date "' SSSV:WRDP Last WO: 43.82 6/30/2006 Well Coofp:-CD4-320,225/20139:40:26 AM Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:WRDP C/O haggea 2/25/2013 HANGER.32 ,e Casing Strings ,a $( Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String.. String Top Thrd �r CONDUCTOR 16 15.250 37.0 114.0 114.0 65.00 H-40 Insulated 44" Cuing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt..String...String Top Thrd SURFACE 95/8 8.835 36.9 2,509.0 2,378.3 40.00 L-80 BTCM Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt..String...String Top Thrd INTERMEDIATE 7 6.276 34.6 8,145.1 26.00 L-80 Buttress Thread Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd LINER 41/2 3.958 7,928.5 14,462.1 12.60 L-80 SLHT Liner Details CONDUCTOR Top Depth Insulated 44",—� (ND) Top Incl Need... 37-114 Top(ftKB) (ftKB) I) Item Description Comment ID(In) 7,928.5 SLEEVE BAKER'HR'LINER SETTING SLEEVE 4.420 7,941.5 NIPPLE BAKER'RS'PACKOFF SEAL NIPPLE 4.250 7,944.5 HANGER BAKER'DG'FLEX LOCK HANGER 4.400 wnDP,z,o4a 7,954.3 XO Reducing CROSSOVER 5"x 4 5" 4.500 NIPPLE.2.048 m` Tubing Strings ` Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)... String Wt...String.. String Top Thrd TUBING 41/2 3.958 31.6 7,925.6 12.60 L-80 IBTM i --' Completion Details Top Depth (ND) Top Incl Nomi... Top(ftKB) (ftKB) 11 Item Description Comment ID(in) 31.6 31.6 -0.06 HANGER FMC TUBING HANGER 4.500 2,048.2 1,959.3 23.01 NIPPLE BAL-O NIPPLE ID 3.812" 3.812 S 37.2,509 ( 7,486.6 PACKER BAKER PREMIER PACKER 3.875 '-_-- ' 7,547.3 NIPPLE HES 3(N'NIPPLE 3.725 7,915.4 WLEG WIRELINE ENTRY GUIDE 4.000 GAS LIFT, __^ 3,622 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top Depth (ND) Top Incl Top(ftKB) (RKB) (°) Description Comment Run Date ID(in) 2,048.2 1,959.3 23.01 WRDP 3.81"DB LOCK w/WRDP-2(HVS-268) 2/20/2013 2.125 Perforations&Slots GAS LIFT. Shot 6,089 Top(ND) She(TVD) Dens Top(ftKB)Btm(ftKB) (SKS) (ftKB) Zone Date (sh... Type Comment 8,122.0 8,438.0 7/26/2006 32.0 SLOTS Alternating solid/slotted pipe- 0.125'k2.5"@ 4 circumferential adjacent rows,3"centers staggered 18 deg,3'non-slotted ends GAS LIFT, 7,37s la 8,603.0 11,251.0 7/26/2006 32.0 SLOTS 11,411.0 14,420.0 7/26/2006 32.0 SLOTS Notes:General&Safety End Date Annotation 7/29/2006 NOTE:TREE:FMC GEN 5-5000 psi-TREE CAP CONNECTION:7"OTIS PACKER,7,487failiggil 12/4/2009 NOTE:View Schematic w/Alaska Schematic9.0 ili NIPPLE,7,547 110 WLEG,7915 NTERMEDIATE, - 35-8,145� SLOTS. Mandrel Details 8,122-8,438 Top Depth Top Port (ND) Incl OD Valve Latch Size TRO Run N...Top(ftKB) (ftKB) (°) Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 3,622.3 3,405.7 18.81 CAMCO KBG-2 1 GAS LIFT GLV BK 0.188 2,010.0 3/6/2007 2 6,089.4 CAMCO KBG-2 1 GAS LIFT GLV BK-5 0.250 2,229.0 3/6/2007 SLOTS, 3 7,375.3 CAMCO KBG-2 1 GAS LIFT OV BK 0.250 0.0 8/3/2011 8,603-11,251 SLOTS. 11,411-14,420 —,--. r LINER, 7.929-14462 TO(CD4-320). 14.471 • • Image Projeet Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~Q ~ - (~ ~S Well History File Identifier Organizing (done) ~j Two-sided III II'I II II ~I (II III ^ Rescan Needed 'I I II'I (I ~~ II II ~ III RE CAN DIGI AL DATA OVERSIZED (Scannable) Color Items: Diskettes, No. ~ ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: ^ Other: NOTES: OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: BY: Maria Date: /s/ ~ Y ~ r Project Proofing III IIIIII (III) II III BY: Maria Date: U ~ /s/ ~, Scanning Preparation ~_ x 30 = a +~5 =TOTAL PAGES_~`S (Count does not include cover sheet) BY: Maria Date: ~ /~9~D~ /s/ Production Scanning Stage 7 Page Count from Scanned File: _~~ (Count does include cover eet) V Scanning is complete at this point unless rescanning is required. Page Count Matches Number in Scanning Preparation: YES _ BY: Maria Date: ~/~Q ©~ Stage 1 If NO in stage 1, page(s) discrepanci//es were found: YES BY: Maria Date: NO /s/ NO ~ F "iiiumuu~iui ReScanned BY: Maria Date: /s/ Comments about this file: a~a~,.~~e~k,a uiumiiiinmu 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA ' - ALA" OIL AND GAS CONSERVATION COMIIISION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon i — Repair w ell 1 — Rug Perforations f Perforate i . Other jr Scale Inhibition P ull Tubing I - Treatment Alter Casing (—' 9 C Stimulate - F rac J�' Waiver Time Extension ("" Change Approved Program EEOperat. Shutdow n r — Stimulate - Other fl Re -enter Suspended Well °" 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. • Development f . Exploratory r _ 206 -055 • 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic ( Service E 50 103 - 20531 - 00 • 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 380077, 384211 CD4 -320 ' 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none Colville River Field / Nanuq- Kuparuk Oil Pool • 11. Present Well Condition Summary: Total Depth measured 14471 • feet Plugs (measured) none true vertical 7019 feet Junk (measured) none Effective Depth measured 14471 feet Packer (measured) 7487 true vertical 7019 feet (true vertical) 6877 Casing Length Size MD TVD Burst Collapse CONDUCTOR INE 77 16 114 114 SURFACE 2472 9.625 2509 2378 INTERMEDIATE 8110 7 8145 6992 a 1, 4; t. . LINER 6534 4.5 14462 7018 1 i Perforation depth: Measured depth: slots 8122 -8438, 8603 - 11251, 11411 -14420 True Vertical Depth: 6991 -6995, 6996 -7006, 7001 -7017 JUN 2D� SCANNED Tubing (size, grade, MD, and TVD) 4.5, L - 80, 7926 MD, 6984 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER PREMIER PACKER @ 7487 MD and 6877 TVD NIPPLE - BAL -O NIPPLE @ 2048' MD and 1959 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 8145 - 14471 Treatment descriptions including volumes used and final pressure: see attached summary 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation 639 3282 5789 -- 332 Subsequent to operation 792 4816 6604 -- 366 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory ( Development I: . Service 1 — Stratigraphic E 16. Well Status after work: Oil (✓ . Gas E WDSPL F Daily Report of Well Operations XXX GSTOR I VVINJ 1 WAG r GINJ f SUSP r SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Garrett McKee (a. 265 -6549 Email Garrett.L.McKee(a)cop.com Printed Name Garrett McKee Title WNS Engineer Signature Phone: 265 6549 Date 0/Z0/ 3 krLY BDMS J UN - 7 20 Form 10 -404 Revised 10/2012 Submit Original Only • CD4 -320 Scale Inhibition Treatment: 5/13/2013 Initial pressure TBG /IA /OA- 200/1827/927; Facility pumped 50 bbls PW preflush; LRS pumped 6.5 bbls WAW5206 (273 gal) at 0.4 bpm while facility pumped 59 bbls SW at 4 bpm, VAC/1709/901; LRS pumped 65.6 bbls SCW4004 (2751 gal) at 0.65 bpm while facility pumped 371 bbls of PW at 4 bpm VAC/1642/886; facility pumped 2245 bbls of PW over - displacement. Final pressures: VAC/1642/886. Intervals treated: 8145' — 14471' WNS CD4 -320 COnOCOPhillipS W Well Attributes Max Angle & MD TD Abska,Inc. Wellbore API/UWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) 501032053100 NANUO KUPARUK PROD 92.16 11364.87 14,471.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date • - Well Confp: - CD4 -320: 2/25/2013940'.26AM SSSV: WRDP Last WO: 43.82 6/30/2006 Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason. WRDP C/O haggea 2/25 /2013 Casing Strings HANGER, 32 Casing Description String 0... String ID ... Top (ftKB) Set Depth f... Set Depth (TVD) String Wt... String String To Thrd 9 P 9 9 P( ) P ( P ( I ��� 9 9 �� 9 P CONDUCTOR 16 15.250 37.0 114.0 114.0 65.00 H-40 Mk Insulated 44" Casing Description String 0... String ID ... Top (ftKB) Set Depth f ) t pion 9 P (.•. Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.835 36.9 2,509.0 2,378.3 40.00 L - 80 BTCM 1 " Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd INTERMEDIATE 7 6.276 34.6 8,145.1 26.00 L - 80 Buttress Thread ' . Casing Description String 0... String ID... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd LINER 41/2 3.958 7,928.5 14,462.1 12.60 L -80 SLHT Liner Details CONDUCTOR Top Depth Insulated 44•, (TVD) Top Inc! Noml... 37 -114 -- -- -- Top (ftKB) (ftKB) C item Description Comment ID (in) - - 7,928.5 SLEEVE BAKER 'HR' LINER SETTING SLEEVE 4.420 7,941.5 NIPPLE BAKER 'RS' PACKOFF SEAL NIPPLE 4250 7,944.5 HANGER BAKER 'DC' FLEX LOCK HANGER 4.400 MI WRDP, 2,04e 7,954.3 XO Reducing CROSSOVER 5" x 4.5" 4.500 NIPPLE. 2,048 O I. Tubing Strings Tubing Description String 0... String ID ... Top (NHS) Set Depth (f... Set Depth (TVD) ... String WL.. String ... String Top Thrd TUBING I 41/2 I 3.958 I 31.6 I 7,925.6 12.60 L -80 IBTM S Completion Details Top Depth . (TVD) Top Inc! Noml,.. Top (ftKB) (ftKB) ( °) Item Description Comment ID (!n) 31.6 31.6 -0.06 HANGER FMC TUBING HANGER 4.500 2,048.2 1,959.3 23.01 NIPPLE BAL-0 NIPPLE ID 3.812" 3.812 SURFACE, 7,486.6 PACKER BAKER PREMIER PACKER 3.875 7,547.3 NIPPLE HES 'XN' NIPPLE 3.725 �,. 7,915.4 WLEG WIRELINE ENTRY GUIDE 4.000 GAS LIFT. 3.622 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Inc] Top (ftKB) (0613) (°) Description Comment Run Date ID (in) 2,048.2 1,959.3 23.01 WRDP 3.81" DB LOCK w/ WRDP-2 (HVS -268) 2/20/2013 2.125 Perforations & Slots GAS LIFT, Shot 6009 Top (TVD) Btm(TVD) Dens AM Top (ftKB) Btm (RIO) (BBB) (ftKB) Zone Date Wt... Type Comment 8,122.0 8,438.0 7/26/2006 32.0 SLOTS Altemating solid/slotted pipe - 0.125 "x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non - slotted ends GAS LIFT. c 7,375 a 8,603.0 11,251.0 7/26/2006 32.0 SLOTS _._ 11,411.0 14,420.0 7/26/2006 32.0 SLOTS Notes: General & Safety End Date Annotation 7/29/2006 NOTE: TREE: FMC GEN 5 - 5000 psi - TREE CAP CONNECTION: 7" OTIS PACKER. 7,487 - -- -- 12/4/2009 NOTE: View Schematic w/ Alaska Schematic9.0 alk NIPPLE. 7,547 ilir WLEG, 7,915 j.. 1 NTERMEDIATE, 35-8,145 SLOTS, M andrel D etails 8,122 -8,438 T op De Top Port (TVD) Inc' OD Valve Latch Size TRO Run N... Top (ftKB) OMB) ( °) Make Model (in) Sery Type Type (in) (Psi) Run Date Com... 1 3,622.3 3,405.7 18.81 CAMCO KBG -2 1 GAS LIFT GLV BK 0.188 2,010.0 3/6/2007 2 6,089.4 CAMCO KBG -2 1 GAS LIFT GLV BK -5 0250 2,229.0 3/6/2007 stors i 3 7,375.3 CAMCO KBG -2 1 GAS LIFT OV BK 0250 0.0 8/3/2011 8,603 - 11.251 SLOTS, 11,411 - 14,420 LINER. 7,929 - 14,482l TD (CD4 -320). 14,471 RECEIVED STATE OF ALASKA AL. OIL AND GAS CONSERVATION COMOION JUN 1 4 2012 REPORT OF SUNDRY WELL OPERATIONS ("�f� 1. Operations Performed: Abandon r Repair well r Plug FFrforations r Perforate r Oth� ition Alter Casing r Pull Tubing r Stimulate - Frac r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p' Exploratory r - 4 206 -055 3. Address: 6. API Number:.., P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service r 00 50- 103- 20531 -00 O 7. Property Designfion (Lease Number): 8. Well Name and Number: v ADL 380077, 384211 CD4 -320 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): . ]V AN—K__ Oil "NM IrIr1 none Colville River Field / Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 14471 feet Plugs (measured) none true vertical 7019 feet Junk (measured) none Effective Depth measured 14471 feet Packer (measured) 7487 true vertical 7019 feet (true vertucal) 6877 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114 114 SURFACE 2472 9.625 2509 2378 INTERMEDIATE 8110 7 8145 6992 LINER 6534 4.5 14462 7018 Perforation depth: Measured depth: 8122'- 8438', 8603'- 11251', 11411'- 14420' True Vertical Depth: 6991'- 6995', 6996'- 7006', 7001' -7017' g�a i .�c'S�+r JUL. 2 z* ZOIL Tubing (size, grade, MD, and TVD) 4.5, L - 80, 7926 MD, 6984 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER PREMIER PACKER @ 7487 MD and 6877 TVD SSSV - DB SSSV @ 2048 MD and 1959 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 8122'- 8437', 8603'- 11251', 11411'- 14420' Treatment descriptions including volumes used and final pressure: See attachment 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 647 3882 4216 -- 384 Subsequent to operation 487 3224 3181 -- 696 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development ]►. . Service r Stratigraphic r 16. Well Status after work: r Oil 17 Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact David Neville @ 265 -6402 Printed Name David Neville Title Alpine Production Engineer Signature Phone: 265 -6402 Date ‘ A 3,7 z RBDMS JUN 15 �r��" 2012 crrlil . ;1 A i i' Gr i r z, Form 10 -404 Revised 11/2011 1;e I� Z3l�7/ Submit Original Only 3 WNS CD4 -320 ConocoPhillips 111 Well Attributes • Max Angle & MD TD • Alaska. 111c, Wel!bore APIIUWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) ca,u<roops 501032053100 NANUQ KUPARUK PROD 92.16 11164.87 14,471.0 Comment 829 (ppm) Date Annotation End Date KB (ft) Rig Release Date "' SSSV: WRDP Last WO: 4182 6/30/2006 Well Coolie - CD4-320, 8/13/2011 68688 AM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag. Rev Reason: RESET WRDP, GLV C/O ninam 8/13/2011 HANGER,32 ' Casing Strings _ Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.250 37.0 114.0 114.0 65.00 H -40 I r Insulated 44" Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 9 5/8 8.835 36.9 2,509.0 2,378.3 40.00 L - 80 BTCM Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd INTERMEDIATE 7 6.276 34.6 8,145.1 26.00 L - 80 Buttress Thread Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd LINER 41/2 3.958 7,928.5 14,462.1 12.60 L -80 SLHT Liner Details CONDUCTOR Top Depth Insulated 44•, (TVD) Top Intl Nomi... 37 -114 Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) 7,928.5 SLEEVE BAKER 'HR' LINER SETTING SLEEVE 4.420 7,941.5 NIPPLE BAKER 'RS' PACKOFF SEAL NIPPLE 4.250 7,944.5 HANGER BAKER 'DG' FLEX LOCK HANGER 4.400 WRDP, 2.048 = 7,954.3 XO Reducing CROSSOVER 5x4.5" 4.500 NIPPLE, 2,048 ^' I I Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 4 1/2 3.958 31.6 7,925.6 1260 L -80 IBTM Completion Details Top Depth 0 Top (ftKB) (TVD) Top Inc! Noml... (ftKB) (°) Item Description Comment ID (!n) 31.6 31.6 -0.06 HANGER FMC TUBING HANGER 4 2,048.2 1,959.3 23.01 NIPPLE BAL -O NIPPLE ID 3.812" 3.812 SURFACE, .I 37 - 2809 7,486.6 PACKER BAKER PREMIER PACKER 3.875 7,547.3 NIPPLE HES'XN' NIPPLE 3.725 _.. 7,915.4 WLEG WIRELINE ENTRY GUIDE 4.000 GAS LIFT, I c_ 3.622 Other In Hole ireline retrievable plugs, valves, pumps, fish, etc.) _ Top Depth -- -- (TVD) Top Inc! Top (ftKB) (ftKB) ( °) Description Comment Run Date ID (in) 2,048 1,959.3 23.01 WRDP 3.81" DB LOCK w/ WRDP -2 (HSS- 199) 8/3/2011 2.125 IMI Perforations & Slots GAS LIFT, ._ Shot 6,089 Top(TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ft00) Zone Date (eh.- Type Comment 8,122 8,438 7/26/2006 32.0 SLOTS Alternating solid/slotted pipe - 0.125 "x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non - slotted ends GAS LIFT, 1 __ 7,375 8,603 11,251 7/26/2006 32.0 SLOTS 11,411 14,420 7/26/2006 32.0 SLOTS Notes: General & Safety End Date Annotation 7/29/2006 NOTE: TREE: FMC GEN 5 - 5000 psi - TREE CAP CONNECTION: 7" OTIS PACKER, 7,487 -- - 1 12/4/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 NIPPLE. 7,547 al WLEG, 7,915 J F 1 NTERMEDIATE, , 35 -8,145 SLOTS, Mandrel Details 8,122 - 8,438 - - - - -- Top Depth Top Port (TVD) Intl OD Valve Latch Size TRO Run 6 Stn Top (ftKB( (ftKB) (°) Make Model (in) Sery Type Type (!n) (psi) Run Date Com... 1 3,622.3 3,405.7 18.81 CAMCO KBG-2 1 GAS LIFT GLV BK 0.188 2,010.0 3/6/2007 2 6,089.4 CAMCO KBG-2 1 GAS LIFT GLV BK -5 0.250 2,229.0 3/6/2007 SLOTS. 3 7,375.3 CAMCO KBG -2 1 GAS LIFT OV BK 0.250 0.0 8/3/2011 _____,,i 8803 11,251 1 1 SLOTS, 11,411- 14.420 LINER, 7,929 - 14,462 TD (C04 -320), 14,471 • • Scale Inhibition Treatment: CD4 -320 5/15/2012: Initial pressure TBG/IA/OA — Not given; Facility pumped 50 bbls SW preflush at 4 bpm; LRS pumped 5.5 bbls WAW5206 (231 gal) at 0.4 bpm while facility pumped 50 bbls of SW at 4 bpm, 300/1244/855; LRS pumped 55 bbls SCW4004 (2310 gal) at 0.65 bpm while facility pumped 312 bbls of SW at 4.3 bpm , 0/1241/872; facility pumped 1792 bbls of SW over - displacement at 4.3 bpm. STATE OF ALASKA ' ALASKA • AND GAS CONSERVATION COMMISSO REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Rug Perforations r Stimulate r Other se�.�t 1 b i# Alter Casing r Pull Tubing r Perforate New Fool r Waiver r Time Extension r Change Approved Program r Operat. Shutdown r Perforate r Re -enter Suspended Well 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r - 206 - 055 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 50 - 103 - 2 0531 - 'r" Oa 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 380077, 384211 • CD4 -320 9. Field /Pool(s): • Colville River Field / Alpine Oil Pool 10. Present Well Condition Summary: Total Depth measured 14471 feet Plugs (measured) None true vertical 7019 feet Junk (measured) None Effective Depth measured 14471 feet Packer (measured) 7487 true vertical 7019 feet (true vertucal) 6877 Casing Length Size MD TVD Burst Collapse CONDUCTOR IN 77 16 114 114 SURFACE 2472 9.625 2509 2378 INTERMEDIATE 8110 7 8145 6992 LINER 6534 4.5 14462 018 \ , Lti RECEIVED' Perforation depth: Measured depth: 8122'- 8438', 8603'- 11251', 11411'- 14420' AUG , 2011 True Vertical Depth: 6991'- 6995', 6996'- 7006', 7001' -7017' Meeks CM & G8: Cola. Gummi Tubing (size, grade, MD, and TVD) 4.5, L -80, 7926 MD, 6984 TVD Anchorage Packers & SSSV (type, MD, and TVD) PACKER - BAKER PREMIER PACKER @ 7487 MD and 6877 TVD SSSV - CAMCO WRDP -2 @ 2048 MD and 1959 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 8122'- 14420' Treatment descriptions including volumes used and final pressure: see attached summary 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 505 1605 5908 -- 680 Subsequent to operation 311 1014 6012 -- 358 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory f Development S7 r Service r Stratigraphic r 15. Well Status after work: ,, Oil tv Gas lfl WDSPL E Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG fl 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Jack Walker @ 265 -6268 Printed Name Jack Walker Title Principal Production Engineer Signature (2---01--------- Phone: 265 -6268 Date_1,6%. sit R8DMS AUG 2 3 t'f1 "- 9 %2 3•« Form 10 -404 Revised 10/2010 Submit Original Only /.4€ Za3 /( I; • WNS III CD4 -320 , }li i t Max Ate & MD TD ! . Well �1AL es- Angle � � ',#• � WNiboe APWWI Field Name Well Status Intl ( °) ND (ftKB) Act Btm (896) „ ' 501032053100 NANUQ KUPARUK ( PROD 92.16 11,36487 14.4/1.0 Comment H28 (ppm) Date Annotation End Date KB (ft) Rig Release Date SSSV: WRDP Last WO' 43.82 6/30/2006 , a :::sgig .._,_ Annotation Depth (ftKB) End Date Annotatron Last Mod ... End Dafe Last Tag: L _ _ _ _ Rev Reason- RESET WRDP_ 1 Imosbor 1 10/29/2010 WINGER, 32 4' Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ..'String Wt... String ... String Top Thrd ziO. CONDUCTOR 16 15.250 37.0 114.0 114.0 65.00 11-40 1 4 Insulated 44" Casing Description String 0.., String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.835 36.9 2,509.0 2,378.3 40.00 L BTCM ': Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd INTERMEDIATE 7 6.276 34.6 8,145.1 26.00 L Buttress Thread Casing Description String 0... Siring ID . Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd LINER 41/2 3.958 7,928.5 14,462.1 12.60 L-80 SLHT Ow ,Agssearier Details __ - - -- - - — -- -- _ CONDUCTOR Top Depth m. Insulated 44' (ND) Top Inc! N . 37 -114 Top KB (ftKB) ( ") Item Desal• Inc Comment ID (in) 7,928.5 SLEEVE BAKER 'FIR' LINER SETTING SLEEVE 4 420 7,941.5 NIPPLE BAKER 'RS' PACKOFF SEAL NIPPLE 4.250 7,944. HANGER BAKER 'DO FLEX LOCK HANGER 4.400 WRDP, 2,tu8� _ 7,954.3 I XO Reducing CROSSOVER 5x4 5" 4.500 NIPPLE, 2,048 Tubing Description g Strin O -__ -- - -� _ -- Tubing Strings ° g g ._ String ID ... Top (ftKB) Set Depth (f.. Set Depth (TVD) ... String Wt... String .. String Top Thrd TUBING 41/2 3.958 I 31.6 7,925.6 12.60 L-80 I IBTM Completion Details Top Depth (WD) Top Inc! Nomi... (^ Top(ftKB4 (ftKB) (°I _ Item Description Comment ID (in) 31.6 31.6 -0.06 HANGER FMC TUBING HANGER 4.500 2,048.2 1,959.3 23.01 NIPPLE BAL-0 NIPPLE ID 3.812" 3.812 SURFACE, J , ,,,,, 37 - 2,509 7 PACKER BAKER PREMIER PACKER 3.875 7,547.3 NIPPLE HES'XN' NIPPLE 3.725 7,915.4 WLEG WIRELINE ENTRY GUIDE 4.000 GAS LIFT,__ _ — 3,622 _Oth In Hole irehne_ retrievable plugs valves, pumps fish, etc.) Top Depth (ND) Top Intl : .,,, Top (ft(B) (ftKB) ("1 Description Comment Run Date ID (in) 2,0482 1,959.3 23.01 WRDP CAMCO 3 812" WRDP -2 (HRS 279) 10/16/2010 2.125 lir Perforations & Slots GAS LIFT, Shot 6,089 Top (TVD) Btm (TVD) Dens '' Top (MB) Btm (8K6) (ftKB) (ftKB) Zone Date (sh.. Type Comment ' 8,122.0 8,438.0 7/26/2006 32.0 SLOTS Alternating solid /slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered _ 18 deg, 3' non - slotted ends GAS LIFT,_ ,375 8,603.0 11,251.0 7/26/2006 32.0 SLOTS Alternating solid /slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non - slotted ends . 11,411.0 14,420.0 7/26/2006 32.0 SLOTS Alternating solid/slotted pipe - PACKER, 7487 - - - 0.125 "x2.5" @ 4 circumferential _ -T--- adjacent rows, 3" centers staggered 18 deg, 3' non - slotted ends Notes: General & Safety NIPPLE, 7,547 — -_ End Date Annotation f 7/29/2006 NOTE: TREE: FMC GEN 5 - 5000 psi - TREE CAP CONNECTION: 7" OTIS 12/4/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 WLEG, 7,915 _ . i 4 1?!N4F NTERMEDIATE, 358,145 r - - �' , C F SLOTS. - .. "^ aa�a _..i :: a.- 1 " " --* t - L-� itck ri�^"�„ ' ,'.,e," .. ' i.' . ' " A ai... , '�,r�-� i ,: a.. �� ... c,. • 8,122 -8,438 - _ Top Depth Top Port (TVD) Intl OD Valve Latch Size TRO Run Stn Top (Mal) (ftKB) (") Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 3,622.3 3,405.7 18.81 CAMCO KBG-2 1 GAS LIFT GLV BK 0.188 2,010.0 3/6/2007 2 6,089.4 CAMCO KBG -2 1 GAS LIFT GLV BK -5 0.250 2,229.0 3/6/2007 SLOTS, -' 3 7,375.3 CAMCO KBG-2 1 GAS LIFT OV BEK 0.438 0.0 3/6/2007 6,603 11,251 it i J L SLOTS, '°' 11,411 - 14,420 ;.,.� LINER,. 7,929-14,462 TD (CD4 -320), 14,471 • CD4 -320 8/1/2011: Scale Inhibition Treatment / Initial pressure TBG /IA/OA — 250/1600/900; facility pumped 50 bbls SW preflush; LRS pumped 5.5 bbls WAW5206 (231 gal) at 0.5 bpm and facility pumped 50 bbls SW, 180/1550/850; LRS pumped 55 bbls SCW4004 (2310 gal) at 0.65 bpm and facility pumped 312 bbls SW, 40/1450/850; facility pumped 2248 bbls SW over - displacement STATE OF ALASKA ALASKA•AND GAS CONSERVATION COMMIS ' REPORT OF SUNDRY WELL OPERATI 1. Operations Performed: Abandon r Repair w ell r Plug Perforations r Stimulate 17 Other r Alter Casing r Pull Tubing r Perforate New Pool fl Waiver r Time Extension Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r` Exploratory r ' 206 -055 3. Address: 6. API Number: Stratigraphic r Service P. O. Box 100360, Anchorage, Alaska 99510 ' 50 00 7. Property Designation Number): 8. Well Name and Number: ADL 380077, 384211 •• CD4 - 320 9. Field /Pool(s): Colville River Field / Nanuq- Kuparuk Oil Pool 10. Present Well Condition Summary: Total Depth measured 14471 feet Plugs (measured) None true vertical 7019 feet Junk (measured) None Effective Depth measured 14471 feet Packer (measured) 7487 true vertical 7019 feet (true vertucal) 6877 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114 114 SURFACE 2472 9.625" 2509 2378 INTERMEDIATE 8110 7 8145 6992 LINER 6534 4.5" 14462 7018 StAONED APR 0 I 2011 Perforation depth: Measured depth: slotted liner 8121'- 8438', 8603'- 11251', 11411'- 14420' MAR 3 0 2011 True Vertical Depth: 6991'- 6995', 6996'- 7006', 7001' -7017' Atoka O'd et Gas Cons. Commission Tubing (size, grade, MD, and TVD) 4.5, L -80, 7926 MD, 6984 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER PREMIER PACKER @ 7487 MD and 6877 TVD NIPPLE - BAL-0 NIPPLE @ 2048 MD and 1959 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 8121' -8438' Treatment descriptions including volumes used and final pressure: refer to attached summary 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 1015 3425 5509 -- 370 Subsequent to operation 989 3133 5472 -- 365 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development /r • Service r Stratigraphic 15. Well Status after work: , Oil Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WIND r WAG r GINJ r SUSP r SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Tim Schneider (a) 265 -6859 Printed Name Tim Schneider Title Staff Production Engineer Signature ': Phone: 265 -6859 Date -3— 2 5`— t( RBDMS MAR 3 0 2011 7L 3.31.7/ Form 10-404 Revised 10/2010 , 0 4 Submit Original Only CD4 -320 Well Work Summary DATE SUMMARY 3/6/11 Initial pressure TBG /IA /OA- V11650/930; Facility pumped 50 bbl PW pr sh at 5800 bwpd; LRS Pumped 116 gallons WAW -5206 at 0.45 bpm into 25 bbl PW at 5800 bwpd (4.5 bpm), VAC/1625/930; LRS pumped 1155 gallons SCW4004 at 0.7 bpm into 156 bbl PW at 5800 bwpd (4.7 bpm), VAC/1625/930; Facility pumped 2240 bbl PW overflush at 5800 bwpd. Shut -in 12 hours. Returned to Production. 1.-- • 111 • CD4 -320 • • ConlocoPhillps $ ,,{ Well Attributes Max Angle & MD TO / Wel!bore API /UWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) - 5010320531// NANUQ KUPARUK PROD _92.16 1136487 14,4710 Comment : . H2S (ppm) Date Annotation lEnd Date KB - Grd (ft) Rig Release Date ASSN: io 11P Depth OMB) I End Date Rev Reason RESET WRDP 43 SL 6/n D ate A ( I Last Mod ._ End Date . Sdrfrye- XOlV31 P Imosbor /29/2010 HANGER, 32 Casing_Strings __.. y e Casing Description String 0... String ID ... Top (HKB) Set Depth (f... Set Depth (ND) .. .String Wt... String ... String Top Thrd ";, CONDUCTOR 16 15.250 37.0 114.0 114.0 65.00 H-40 1 Insulated 44" Casing ...__....__ - ,. Description String 0... String ID ... Top MKS) Set Depth (f... Set Depth (TVD) • String Wt... String ... String Top Thrd SURFACE 9 5/8 8.835 36.9 2,509.0 2,378.3 40.00 L -80 BTCM I „ : Casing Description String 0... String ID ... Top (HKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 1 INTERMEDIATE 7 6.276 34.6 8,145.1 26 00 L Buttress Thread ' Coning String 0... String ID ... Top MKS) Set D pth (f... Set Depth (NO) .. String Wt... String .. String Top Thai I LINER 4 1/2 3.958 7,928 5 14 462 1 12.60 L-80 SLHT , Liner Details CONDUCTOR Top Depth Insulated 44 °,- (ND) Top lnel Nceni... 31 -114 Iliinf. Top(ftKB) ( MI ( °) Itwn Description Comment ID(in) 7,928.5 SLEEVE BAKER 'HR' LINER SETTING SLEEVE 4.420 7,941.5 - -- NIPPLE BAKER 'RS' PACKOFF SEAL NIPPLE 4.250 lik _ 7,944.5 HANGER BAKER 'DG FLEX LOCK HANGER 4.400 WRDP, 2 ,04 7,954.3 XO Reducing CROSSOVER 5x4.5” 4.500 NIPPLE, 2,848 8 I r I Tubing_Strings °° Tubing Description String 0... String ID ... [Top (ftKB) ISet Depth (t... Set Depth (ND) . String Wt... String ... String Top Thrd TUBING 41/2 3.958 I 31.6 7,925.6 12.60 L -80 IBTM Completion Details ) Top Depth (ND) Top Incl Nomi... ll 4 1 Top (N(B( (fIKB) ( °) Item Description Comment ID (in) 31.6 31 -6 - -- -0.06 HANGER FMC TUBING HANGER 4.500 l 2,048.2 1,959.3 23.01 NIPPLE BAL -O NIPPLE ID 3.812" _ 3.812 SURFACE, _ ■ 7,486.6 PACKER BAKER PREMIER PACKER 3.875 37-2,509 7,547.3 NIPPLE HES'XN' NIPPLE 3.725 3 7,915.4 WLEG 1 WIRELINE ENTRY GUIDE 4.000 GAS LIFT I _. 3'622 , Other In Hole (Wireline retrievable plugs valves, pumps, fish, etc.) Top Depth (TVD) Top Inc] Top(ftKB) (ftKB) ( °) Description Comment Run Date ID(in) 2,048.2 1,959 3 23 01 WRDP ICAMCO 3.812" WRDP -2 (HRS-279) 10/16/2010 2.125 i Perforations & Slots GAS LIFT. - -- Shot 6,089 r„-,.,,, Top (TVD) Btm (TVD) Dens T - • 11KB Bim fIKB) (ftKB) (ftKB) Zone Date (sh °- Type Comment ...... 8,122.0 8,438.0 7/26/2006 32.0 SLOTS Alternating solid/slotted pipe - 0.125 "x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non - slotted ends GAS LIFT, .---- 7.375 8,603.0 11,251.0 7/26/2006 32.0 SLOTS Alternating solid/slotted pipe - I 0.125 "x2.5" @ 4 circumferential adjacent rows, 3" centers staggered I 18 deg, 3' non - slotted ends L 1 11,411.0 14,420.0 7/26/2006 32.0 SLOTS Alternating solid /slotted pipe - PACKER, 7,487 - -- 4 0.125 "x2.5" @ 4 circumferential - - adjacent rows, 3" centers staggered 18 deg, 3' non - slotted ends I Notes: General & Safety NIPPLE, 7,547 I End Date Annotation 7/29/2006 (.1016: TREE: FMC GEN 5 - 5000 psi - TREE CAP CONNECTION: 7" OTIS 12/4/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 WLEG, 7,915 - . I - - -- if 9 ,..,. i 1 _ ..... .,..___ _ _ __- NTERMEDIATE, " - , ' -y 35 -8.145 � - - - -. _ -_ -_ SLOTS. _.--- -- Mandrel Details 8,122 -8,438 7 Top Depth Top I_.- Port. - - -- (TVO) Inc( OD Valve Latch Size TRO Run Ste Top (HKB) (HKB) (°) Make Model (In) seen Type Type (in) (psi) Run Date Can... A L 1 3,622.3 3,405.7 18.81 CAMCO KBG -2 1 GAS LIFT GLV BK 0.188 2,010.0 3/6/2007 2 6,089.4 CAMCO KBG -2 1 GAS LIFT GLV BK -5 0.250 2,229.0 3/6/2007 SLOTS. 8,603 11,251 - _ _ - — - 3 7 , 375.3 CAMCO KBG2 1 GAS LIFT OV BEK 0.438 0.0 316(2007 j L SLOTS, = . 11,411-14,420 LINR, LINER, 7,929 - 14,482 TD (/04320), 14,471 • ,,.~:. ti ~` - '~~ ~ ~ ~~~ . ,~~. _ ,+ ~, ~,. ~, , `~ .s.i ,~ ~''~~ MICROFILMED .6/30/2010. -DO NOT .PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc STATE OF ALASKA ALASK~L AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS RECEIVED ~Ee ~ $ zoo t operations Performed: Abandon ~ Repair w ell Plug Perforations ~'-' Stimulate 8SI(8 0~ ~~ ~ptt~I11SS10 Alter Casing [~ Pull Tubing ~ Pierforate New Pbol Waiver Time Extensior>At~}I<yf'OQB Change Approved Program ;"° Operat. Shutdown ~"" Perforate j"`"' Re-enter Suspended Well 2. Operator Name: 4. Current Well Status: Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ Exploratory J"'"" 206-055 3. Address: Stratigraphic Service .API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20531-00 7. roperty Designation: ~$. Well Name and Number: ADL 380077, 384211 CD4-320 9. Field/Pool(s): ~ /~~ ~H'l Colville River Field / ru Oil Pool 10. Present Well Condition Summary: Total Depth measured 14471 feet Plugs (measured) None true vertical 7019 feet Junk (measured) None Effective Depth measured 14471' feet Packer (measured) 7487 true vertical 7019' feet (true vertucal) 6877 Casing Length Size MD ND Burst Collapse CONDUCTOR IN 77 16 114 114' SURFACE 2472 9.625 2509 2378' INTERMEDIATE 8110 7 8145 6992' LINER 6534 4.5 14462 7018' Perforation depth: Measured depth: slotted liner from 8121'-8438', 8603'-11251', 11411'-14420' True Vertical Depth: 6991'-6995', 6996'-7006', 7001'-7017' ~.~~~~~k~ F~~ ~- 10,E Tubing (size, grade, MD, and TVD) 4.5, L-80, 7926 MD, 6984 TVD Packers &SSSV (type, MD, and TVD) PACKER -BAKER PREMIER. PACKER @ 7487 MD and 6877 TVD Camco SSSV MD= 2048 TVD=1959 11. Stimulation or cement squeeze summary: Intervals treated (measured): See attachment Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1181 6160 4106 -- 383 Subsequent to operation 1001 5182 4849 -- 363 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run Exploratory Development Service 5. Well Status after work: Oil ~` Gas " WDSPL Daily Report of Well Operations XXX GSTOR WAG ~"` GASINJ `" WINJ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NSA if C.O. Exempt: none contact Tim Schneider ~ 265-6859 Printed Name Tim S h ider Title Alpine Engineer .~~ Phone: 265-6859 Date ~ Signature ~ Form 10-404 Revised 7/2009 r~so~ns ~ ~ ~ ~~'~~ ~~ l ) •/9 •~D ~~~ `Submit Original Only ~, ,;=~~ ~ ,- WNS • CD4-320 _; t~.17110C4J1~'t1~~t~J~ ~ Well Attributes _ Max Angle & MD TD -.t 111 1 'iWellbore APl/UWI 'Field Name Well Status Inc! (°] MD (ftK6) Act Btm (kKB) J ~ 501032053100 NANUO KU('ARUK (PROD 92.16 11,364.87 14,471.0 C ent H25 {ppmj (Data Annotation End Date KB-Grd (ft) Rig Release Date •.. walls 9g.:cDd zo Iz4x -. SSSV WRDP l Last WO: 43.82. 6/30/2006 _- _- SI mali A al A otalion Depth (kKB) End Dale Annott n Last Mod ... !(End Date Last Tag _._~Rev Reason: OC (ALLIES _ _ _ ,. I Imosbor 12/4/2009 _.. Casln Stnn s o _ _p --- P (- J _- e - HANGER.32 ~ ~- ~-- -- " - C 'ng Des ~pt'on String O Sfe g 10 ... T p (ftK6 Set D th (f .. Set D th ND Str n WL.. ~ Str ng String Top Thrd CONDUC I OH 16 'I _.~. 3/ 0 174.0 114 0 65.00 ~, H-40 lnsulatetl 44" ,', Casing Description iString O '.Str g ID _ Top (kKB) Set Depth (f... Set Depth (ND) ... (String Wt... .Strmg String Top Thrd .SURFACE 9 5!8 8.A 5 1 36.9 2 509.0 2,378.3 40.00 i L 80 ~ BTCM Casing Des pt n :String 0... Str g ID ... Top (kKB) Set Depth (f... Sat Depth (ND) ..Strmg Wt... Str g lSt ing Top Thrtl ~~ INl ERMEDIATE 7 I -(i 34.6 8 145.1 26.00 L 80 Buttress Thread Casing Descr ptlon ~'.iStr ng 0... String ID ... Top (ftK6) Sel DepN (f... Sat Depth (ND) ... Strmg Wt... Strmg . St ing Top Thrd ,LINER 41/2 i 3.95& 7,9285 14462.1 12.60 L-80 ~ SLHT ~, ~ ~ - ; .; [ . >.Ia I Liner Details CONDUCTOR ., .. (Top Depth _. _ _. __ _. _. Insula[ed dd'. (NDI Top Inc! N m . 3]-114 Top (ftKBJI~ (ftK6) (°)Item Desn iption Comment ID (inl - 7,9285'1 SLEE'~/F BAKER'HR' LINER SETTING SLEEVE 4420 7,9415 '~ NIPPLE BAKER 'RS'PACKOFF SEAL NIPPLE 4.250 - 7,944.5 HANGEh', BAKER 'DG' FLEX LOCK HANGER 4 400 _-_ 7,954.3, ~ XO CORROSVER 8x4.5" 4.500 WRDP, zo4fl-- _ ,Tubing Strings.. _ _. _ Tubing Descnphon Strmg O .. Str g ID ... Top (ftK6) Set Depth (f... Set Depth (ND) ... String Wt... (Str g .. String Top Thrd NIPPLE. z oae ~, _s 1 UBING 4 V2 ~~ 3 y F',-. I 31.6 7,925.6 12.60 I L 80 IBTM Com letion Details ." .__'. Top Dep[h __ .- ~_ - (ND) Top Inc! Nomi... 1 Top (kK6) (kKB) (°) Item Description Comment _ ID lint I 31.6 31.6 -0.06 HAN(1EF: FMC TUBING HANGER 4.500 2.0482 1,959.3 23.01 NIPPLE BAL-O NIPPLE ID 3.812" w/DUMMY PACKOFF 2.75" ID 2.750 7486.6 iPACKER BAKER PREMIER PACKER 3.875 SURFACE. ~ -- -- 37-2.505 7,547.3 NIPPLE HES'XN' NIPPLE 3.725 - 7,915.41 WLEG WIRELINE ENTRY GUIDE 4.000 . __ _,e Gns uFr, Other In Hole,.(W_ ireline retrlevableplugs, valves, pumps, fish, etc.) 3.622 _. TOP Depth _ _.. - - -._ -_-_ ~'.~ (fVD) Topl 1 Top (ttKB) (ftK6) () Des, ption Comment Run D to ID (in) 2048 1 959.1 ~ 23 01 WRCrt' --- CAMCO WRDP-2 (HSS-128) set 8/28!2007 3/7/2007 2.125 I Perforations 8r Slots snot GAS LIFT. Top (iVD) Bhn rl VOI D s 6.089 Top (HKB)'Btm (kKB) (ftK6) (ftK6) Zone Date (h-~ Type I Comment =jA 8,122 8438 7/2612006 32.0 SLOTS Alternating solidlslottetl pipe - ---~--,,1 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted entls Gns uFr. J ~° 8,603 11,257 7/26/2006 32.0 SLOTS Alternating solidlslotted pipe - ],3]5 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slonetl ends 11,471 14,420 7/26/2006 32.0 SLOTS Alternating solid/slotted pipe - ___ 0.125"x2.5" @ 4 circumferential PACKER, ]pfl] - ~'y I, adjacent rows, 3" centers staggered - ' `-..~ I 18 deg, 3' non-slotted ends Notes: General & Safey , ---- End Date Annotation _ NIPPLE, >.5a] 7/29/2006 (NOTE TREE: FPo1C GEN 5 - 5000 psi -TREE CAP CONNEC PION: 7" OTIS WLEG. 7.915 '' C~ 8,122-8,438 -- ToP Depth ToP Port ~- (ND) Inc! OD Valve Latch Size Stn Top (ftK6) (kKB) (°) Make Motlel Pn) Serv Type Type (in) 1 3,622.3 3,405.7 18.87 CANICO KBG-2 1 GAS LIFT GLV BK 0.78! _ 2 6089.4 CAfoICO F:BG-2 1 GAS LIFT GLV BK-5 0.251 sLOrs, _-- 3 7,375.3 CANICO KBG-2 1 GAS LIFT OV BEK 0431 8.803-11,251 SLOTS, __ '~+ 11,411-14.920 - LINER.- ],929-14.462 \ TD (CD4-320), \... __ _ 14.4]1 CD4-320 Job pumped 1855 on 1/25/2010 by T.Lundstrom. Pumped an aqueous scale squeeze into well. Consisted of preload PW pumped from the facility (No volumes or rates recorded). 35 bbls pre-flush w/PW+5206 (111 gallons) chemical pumped at 4 BPM while the well went on VAC. LRS unit pumped 25 bbls PW+4004 (1375 gal) at 3 BPM, well on VAC. Facility pumped PW overdisplacement (No volumes or rates recorded). Job pumped as planned. Well SI for 12 hours before returning back to production. • STATE OF ALASKA • ~~~~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION tJ~~ ~` ~' lJ~Q REPORT OF SUNDRY WELL OPERATIO~~„ ~,., p ~~.,m ,- ~~,. ~~M~;__:_, 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other t, ~. ie squeeze A11C~ :~~ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ~ Exploratory ^ 206-055 ! ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20531-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 37' CD4-320 8. Property Designation: 10. Field/Pool(s): ~~ ,~~ ~' ~''~ ADL 380077, 384211 • Colville River Field / Nan uk Oil Pool 11. Present Well Condition Summary: Total Depth measured 14471' feet true vertical 7019' feet Plugs (measured) Effective Depth measured 14471' feet Junk (measured) true vertical 7019' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16' 114' 114' SURFACE 2472' 9.625" 2509' 2378' PRODUCTION 8108' 7" 8145' 6992' LINER 6533' 4.5" 14462' 7018' Perforation depth: Measured depth: slotted liner from 8121'-8398', 8603'-11211', 11411'-14380' true vertical depth: 6991'-6995', 6996'-7005', 7001'-7017' ,0 , ~,~ ~ ~ ~ Tubing (size, grade, and measured depth) 4.5", L-80, 7934' MD. Packers & SSSV (type & measured depth) Baker Premier pkr @ ~asT Camco WRDP-2 @ 2048' 12. Stimulation or cement squeeze summary: Intervals treated (measured) see attachment Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 6078 9099 2308 -- 458 Subsequent to operation 5787 10127 2775 -- 463 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oi10 Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Tim Schneider @ 265-6859 Printed Name Tim chneider Title Alpine Staff Engineer ~~ Signature Phone: 265-6859 Date r ~ / G Pre ared b Sharon All u Drake 263-4612 Form 10-404 Revised 04/2006 ~ `i1~~; ~ ~ ~~~~ ~ ~) r"+ t r '~ ~ ,~ ~ Submit Origin Only~/ ,~' 6~~ ~ WSR -Well Service Report Well Service Report Page 1 of 1 Well Job Scope CPAI Rep CD4-320 Scale Inhibition Shirtliffe, Ryan Date Daily Work Unit Number 5/13/2009 32 ni is Final T/I/A 700/1360/980 Final Field: ANUQ KUPARUK Pressures: VAC/1190/925 Pumped an aqueous scale squeeze into well. Consisted of 124 bbl preload, 35 bbl: 2d hr. summary pre-flush w/SW+5206 chemical, 252 bbls SW+4004 followed by and overdisplacement of 868 bbls SW from the manifold.Job pumped as planned. STARTTIM.E O.PE.RATION 03:30 PM Rig in, and have Baker hands take samples from sample pot. Hold safety meeting. 05:00 PM Pressure test and start pumping stage 1 of job. Pump 124 bbls SW into well. Initial pumping pressure 800psi, end stage with well on VAC. Pumping at 5.4 bpm. 06:00 PM Pump 35.6 bbls SW+5306 chemical at 5.4 bpm, 500 psi. Well on vacuum at end of stage. 06:12 PM Pump 251.7 bbls SW+4004 chemical at 5.4 bpm, 450 psi increasing to 500 psi and ending with well on VAC at end of the stage. 07:12 PM Turned well over to operations to pujmp displacement with manifold. Displace well with 878 bbls SW. 09:12 PM LRS pump 35bbls diesel freeze protect. Rig out and return to base. .Fluid Type To Well From Well Non- recoverable ]tiote SEAWATER, SCW- 252 4004 SEAWATER, WAW- 36 5206 SEAWATER 1002 DIESEL 35 http://akapps. conocophillips.net/alaskawelleventquery/worklog. aspx?ID=769A3 CD... 6/4/2009 TUBING (0-7934, OD.4.500, ID:3.958) 'RODUCTION (0-8145, OD:7 000, W (:26.00) Gas Lift MandrelNalve 2 (6089-6090, Gas Lift MandrelNalve 3 (7375-7376, PACKER (7487-7497, OD:5.970) NIP (7547-7548, OD 5.000) SLOTTED LINER (7929-14462, OD:4.500, W C 12.60) Perf (8122-8438) Perf (8603-11251) Perf ;11411-14420) Conc~coPhll~Ps Alaska; Inc. ALPINE CD4-320 March 19, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 ~~"~~ ~ ~~~ Dear Mr. Maunder: ~~ `'~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, 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. The corrosion inhibitor/sealant was pumped March 18~', 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sinc Perry ~~~~~ ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Alpine Field Date 3/19/2009 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # .cement um ed cement date inhibitor sealant date ft bbls ft al CD4-301 B 207-180 SF NA 7" NA 2.55 3/18/2009 CD4-302 207-056 28" NA 28" NA 22.95 3/18/2009 CD4-304 207-132 8" NA 8" NA 1.70 3/18/2009 CD4-05 207-155 SF NA 7" NA 1.70 3/18/2009 CD4-306 207-094 SF NA 5" NA 1.70 3/18/2009 CD4-07 207-118 SF NA 6" NA 0.42 3/18/2009 CD4-208 205-162 SF NA 7" NA 1.27 3/18/2009 CD4-209 206-065 SF NA 6" NA 0.85 3/18/2009 CD4-210 206-077 SF NA 7" NA 1.27 3/18/2009 ` CD4-211 ~ 206-153 9" NA 9" NA 3.82 3/18/2009 CD4-214' 206-145 7" NA 7" NA 2.12 3/18/2009 CD4-215 ~ 206-157 5" NA 5" NA 2.55 3/18/2009 CD4-16 206-131 SF NA 5" NA 2.55 3/18/2009 4-17 206-118 SF NA 11" NA 1.27 3/18/2009 CD4-318A 206-113 7" NA 7" NA 1.70 3/18/2009 CD4-319 205-148 SF NA 7" NA 1.27 3/18/2009 CD4-320 206-055 6" NA 6" NA 0.85 3/18/2009 CD4-321• 206-142 SF NA 8" NA 1.70 3/18/2009 CD4-322 207-101 SF NA 5" NA 1.27 3/18/2009 /~O ~ ~. DATA SUBMITTAL COMPLIANCE REPORT ~~~izoos Permit to Drill 2060550 Well Name/No. COLVILLE RIV NAN-K CD4-320 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20531-00-00 MD 14471 TVD 7019 Completion Date 7/28/2006 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATI ON Types Electric or Other Logs Run: GR/Res, Dens/Neutron (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number -- Name -- - ---__--- -- ----- - Scale Media - - -- No Start _ __ Stop - CH Received Comments pt 14037 LIS Verification Open - 8!22/2006 - - -l I CED C Lis 14037 Induction/Resistivity 2481 8114 Open 8/22/2006 GR, FET, ROP, Res ~pt 14037 LIS Verification 0 0 Open 8/22/2006 P61 ~D C Lis 14037 Induction/Resistivity 2481 7978 Open 8/22/2006 P61 GR, FET, ROP, Res D D Asc Directional Survey 0 14471 Open 8/30/2006 i ~'ED D Asc Directional Survey 0 8019 Open 8/30/2006 PB 1 .Sb C Lis 15022 InductionlResistivity 2481 8155 Open 4/17/2007 LIS Veri, GR, FET, ROP w/Graphics CGM, EMF, PDF -` 1~ C Lis 15022';Induction/Resistivity 2481 8019 Open 4/17!2007 P61 LIS Veri, GR, FET, ROP w/Graphics CGM, EMF, PDF ,,yB~ C Lis 15445 Induction/Resistivity 7900 14471 Open 9/28/2007 LIS Veri, GR, ROP, FET, RES w/PDS and TIF i Graphics tJ,og 15445 Induction/Resistivity 5 Blu 8155 14471 Open 9!28/2007 MD Vision Resisitivity Borehole Final Print 24-Jul- 2006 /Log 15445 Induction/Resistivity 5 Blu 8155 14471 Open 9!28/2007 TVD Vision Resisitivity Borehole Final Print 24-Jul- ~, 2006 Well CoreslSampl es Information: Sample Interval Set Name Start Stop Sent Received Number Comme nts DATA SUBMITTAL COMPLIANCE REPORT ~i7i2oos Permit to Drill 2060550 Well Name/No. COLVILLE RIV NAN-K CD4-320 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20531-00-00 MD 14471 TVD 7019 ADDITIONAL INFORMATION Well Cored? Y Chips Received? Y / N Analysis Y / N Received? Comments: Completion Date 7/28/2006 Completion Status 1-OIL Current Status 1-OIL UIC N Daily History Received? ~ N Formation Tops ~ N Compliance Reviewed By: -- - ~ _ _ Date: ~~_~/_(~-~~~-~ - • 09/19!07 a~` / A 5~1~1G( `° Schlumberger-DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 Attn: Beth Well Job # N0.4420 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine Color Log Description Date BL Prints CD CD4-320" 40013769 OH EDIT MWD/LWD / 07/25106 2 1 CD3-302 40013107 OH EDIT MWD/LWD 03/13/07 1 1 CD3-302PB3 40013107 OH EDIT MWD/LWD 03/08/07 1 1 CD4-322 11837501 SCMT 09/03/07 1 SIGNED: ~ DATE: ~~~~,I' ~ ~)I1(~/ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8367. Thank you. ~~tf'ryc~r~;~!' ~ ~ WELL LOG TRANSiVIITTAL To: State of Alaska April 16, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7t" Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD4-320 &CD4-320 PB 1, AK-MW-4477289 CD4-320 &CD4-320 PB1: LIS & Digital Log Images: 1 CD Rom 50-103-20531-00, 70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNIlVG THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 s '~ ~~j~ Date: C~- c70(v-~S 5~ ~ ~S Odd` Signed: ~S ' . ~°~ ~ ~ ~ 5oa3 • ConocoPhilli s p Casing Detail 9 5/8"Surface Casin_g • ®~ "~ ~.a Well: CD4 - 320 Date: 7/3/2006 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.89 FMC Gen V Hanger 2.18 36.89 Jts 3 to 64 62 Jts 9 5/8" 40# L-80 MBTC Csg 2390.22 39.07 Weatherford Float Collar 1.46 2429.29 Jts 1 to 2 2 Jts 9 5/8" 40# L-80 MBTC Csg 76.10 2430.75 Ray Oil tools (Silver Bullet) 2.15 2506.85 2509.00 TD 12 1/4" Surface Hole 2519.00 12 1/4" Hole @ 2519' MD / 2387' TVD 9 5/8" Shoe @ 2509' MD / 2378 ' TVD RUN TOTAL 38 BOWSPRING CENTRALIZERS - 1 per jt on Jt #1 - #14 (stop ring on Jt #1 8~ 2 ) and over collars on jts# 16, 18, 20, 22, 24, 26, 28, 30, 32, 34, 36, 38, 40, 42, 44, 46, 48, 50, 52, 54, 56, 58,60,62 68 joints in the pipe shed. Run 64 joints Last 4 joints stay out Use Best-o-Life 2000 i e do e MU torque - 8500 ft/Ibs Remarks: Up Wt - 165k Dn Wt - 143k Block Wt - 75k Supervisor: D. Burley / D. Mickey ~ Cement Detail Report CD4-320 Surface Casing Cement Primary Job Type Job Category AFE I RFE Start Date Spud Date End Date DRILLING ORIGINAL DRILLING 10136460 6/30/2006 7/1/2006 7/29/2006 -- - Cement Details _- -- _ - __ _ Description Cementing Start Date Gementing End Date Wellbore Name Surface Casing Cement 7/3/2006 15:15 7/3/2006 17:40 CD4-320 Comment Cement Stages -- -- - - - - - - - Sta e # 1 -- - - - - - __ - - - ---- Description Objective Top (ftKB) Bottom (ftKB) FuIY Return? Gmnt Rtrn (... Top Plug? Btm Plug? Surface Casing Cement 37.0 2,509.0 Yes 94.0 Yes Yes O (start) (bbl/min) Q (end) (bbl/min) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 8 4 7 590.0 1,100.0 Yes 2 0.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment --- _ Cement Fluids & Additives - --- ___ - - - - _ - Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 37.0 2,009.0 344 G 272.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 4.45 20.15 10.70 Additives Additive Type Concentration Conc Unit label Fluid - - - -- Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Glass Volume Pumped (bbl) 2,009.0 2,009.0 238 G 48.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Iblgal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 5.10 1.17 Additives Additive Type Concentration Conc Unit label . Page 1/3 Report Printed: 11/15/2006 Daily Drilling Report CD4-320 A. Report Date: 7/312006 Report Number Days From Spud (days) Depth Start (ftKB) Depth End (ftKB) Depth Progress (ft) Wellbore 4 2.69 2,519.0 2,519.0 0.00 CD4-320 Spud Date Contractor Rig Name/No Field Name Well Type Target Depth (ftKB) 7/1/2006 DOYON 19 NANUO KUPARUK Development 14,471.0 AFE / RFE / Maint.# Total AFE Amount Average ROP (ftlhr} 10136460 6,285,925.00 Last Casing String Next Casing OD (in) Neat Casing Set Depth (ftK6) Surface, 2,509.OftK6 Ops and Depth ~ Morning Report Daily Cost Total Cummulative Cost Testing BOPE 276,987.92 914,616.89 24hr Forecast Daily Mud Cost Cummulative Mud Cost Finish BOP test - MU BHA - RIH -Drill 5,408.92 46,898.89 Last 24hr Summary POOH on TT - LD BHA - RU, Run & cmt 9 5/8" csg - RD riser NU wellhead & BOPE General Remarks Weather .Head Count 50.0 Supervisor - i it!e Donnie Lutrick Rig Supervisor Liz Galiunas Rig Supervisor Time Lo _ - -- _ - -- --- - Start End D..,r Time ~ U ,ice Sta". Depth En_1 Time TimE ihrsl ~~. Phase Trbl Code Trbl Clec~ ftKB` iflKr ~ Comm/Operatlon QP Cc d~ upS, t r; P-N-T 00:00 02:45 2.75 SURFAC DRILL TRIP P 2,459.0 73.0 POOH on TT from 2,459' to 891' -flow ckeck well - static POOH to 73' -stood back hwdp and collars 02:45 05:00 2.25 SURFAC DRILL PULD P 73.0 0.0 Down load MWD - LD MWD collars - XO -stab -float sub -motor and bit -clear tools from rig floor. 05:00 07:30 2.50 SURFAC CASING RURD P 0.0 0.0 Rig up to run casing: Lay down drilling bails - MU fill up tool -pick up casing bails - RU 9 5/8" slips ,elevators and power tongs -ready stabbing board 07:30 07:45 0.25 SURFAC CASING SFTY P 0.0 0.0 Held Prejob safety and Opts meeting with crew 07:45 11:15 3.50 SURFAC CASING RNCS P 0.0 1,735.0 Run 9 5/8" 40# L-80 MBTC csg as follows: Float shoe (Ray Oil Tools silver bullet) 2 jts csg -Float collar (Weatherford) 2 jts. csg (first 4 connections made up w/ BakerLoc -filled pipe & checked floats) 41 jts csg to 1735' (washed down from 510' to 540', tight spot at 525') 11:15 11:30 0.25 SURFAC CASING CIRC P 1,735.0 1,735.0 Stage pumps up to 5.5 bpm - CBU -FCP 320 psi - PUW 132K SOW 120K 11:30 13:00 1.50 SURFAC CASING RNCS P 1,735.0 2,465.0 Continue running 9 5/8" - 40# L-80 MBTC csg f/ 1735' to 2465' - 19 jts (64 jts total ran) - PU FMC csg hanger & landing jt. -Land csg w/ fluted mandle hanger on landing ring w/ float shoe @ 2509' & float collar @ 2429' 13:00 13:30 0.50 SURFAC CEMENT PULD P 2,465.0 2,509.0 LD Frank's fill up tool -Blow down TD - MU cmt head & lines 13:30 15:15 1.75 SURFAC CEMENT CIRC P 2,509.0 2,509.0 Establish circulation -Stage pump up to 7.0 bbl/min - Circulate & condition hole & mud for cmtjob - ICP 360 psi FCP 310 psi (circulated 810 bbls) PJSM Latest BOP Test Data ~~Date ~ - - - - -- - Comment - - -.._ -. - -- Page 1/3 Report Printed: 11/15/2006 r~ Daily Drilling Report CD4-320 . ,~ ,. Report Date: 7/3/2006 ie Log r --- - -- _ -- ----- --- ~ - St< C~d 1 D.~ T ~ - ~ ( ' ` --- T - _ - T,n e Det ti St,i^ 13epth End I ftKB) F N r~ tKC1 ..,a ~~ i P xe ,F :ooe ~ipSuo t,o ~ ~ ) { - Con~ndOpe~diion i Trol Code Trol Class. ( 15:15 17:45 2.50 SURFAC CEMENT DISP P 2,509.0 2,509.0 Cement 9 5/8" csg as follows :Pumped 40 bbls Biozan water w/ nut plug as marker -Pumped 5 bbls water w/ Dowell -Tested lines to 2600 psi -Dropped btm plug - Pumped 50 bbls MudPush @ 10.5 ppg -Mixed & pumped 272 bbls lead slurry (ASL) @ 10.7 ppg Observed nut plug marker @ shakers w/ 253 bbls lead pumped -pumped down surge can) Pumped 48 bbls tail slurry (Class G w/ additives) @ 15.8 ppg -Dropped top plug w/ 20 bbls water f/ Dowell -Switched over to rig pumps & displaced cmt w/ 163.4 bbls 9.8 ppg water base mud -Displaced @ 8.1 bbls/min for first 120 bbls - slowed pump to 6.0 bbls/min for 25 bbls - 4.0 bbls/min for cast 8.4 bbls -Bumped plug w/ 1100 psi (prep bump pressure 590 psi) Check float (held OK) CIP @ 17:40 hrs. -Full circulation throughout job w/ 94 bbls 10.7 ppg cmt returns to surface -reciprocated pipe while circulating & through cement job until last 90 bbls of displacement 17:45 18:30 0.75 SURFAC CEMENT PRTS P 0.0 0.0 Rig up & test 9 5/8" casing to 2500 psi for 30 mins. - Blow down lines - RD 18:30 19:30 1.00 SURFAC CEMENT PULD P 0.0 0.0 RD cmt head - LD landing jt -clear rig floor of tools 19:30 21:30 2.00 SURFAC DRILL PULD P 0.0 0.0 LD surface riser -Remove FMC starting head 21:30 00:00 2.50 SURFAC DRILL OTHR P 0.0 0.0 Install FMC Alpine Gen II wellhead 8~ test seals to 1000 psi - NU BOPE Mud Check Data _ _ - r _ __ _ _ i - ------- ~'~ ~~.e hepth (itn&t ~ Dens ~ibigal) ''dis (sigt) Fv E:ai_ _ -__ ~ - YP Calr 3eI (10s) i im1 ~ +C ~ HTHP Filt Density 7+~rr.; _~: lids, Corr. :::~ i'C>rnt (lUt7100ft') ~v~~, Cft~; iltf 1JL ;'~ ', MCiT IL 1.h`; (rnU30min~ pH (°F} ~ i%) spud 2,519.0 9.80 74 1 6.0 12.000 6.000 14.000 20.000 7.7 __ ~~ 5-- - - - - injection Fluid _. Flwd Source rm~~fease (6b1~ Destination Jo'.e ---- -- Diesel 70.0 CD4-318 freeze perotect CD4-318 Water 150.0 CD4-318 flush CD4-318 Water Based Mud 56.0 CD4-318 f/ CD4-320 ;Drill Strin s: BHA No. 2 - Geo Pilot / Bit Run No. 2 - 8 3/4in, Halliburton Securi DBS , FSF2563 , 10635491 Depth In (ftKB) Depth Out (ftKB) TFA (incl Noz) (ins) Nozzles (132") IADC Bit Dull String Wt (10001bf) WOB (max) (100... W©B (min) (1000... 2,519.0 6,907.0 0.98 16/16/16/16/16 0-0-NO-A-X-I-NO-BHA 68 0 0 Drill Strin g Components J-= ItemBescription GD(in) ID!~nl _ Top ConnSz!'.n, 'fop Thread d,roten(fl) 1 7600 Geo Pilot 6 3!4 4.680 4 1/2 NC 50 25.02 1 NMDC Pony Flex Collar 6 3/4 1.920 4 1/2 NC 50 34.22 1 Stabilizer (Non Mag) ILS 6 3/4 1.900 4 1/2 NC 50 36.42 1 MWD (Dir ~ Logging) 6 3/4 1.900 4 1/2 NC 50 57.52 1 Stabilizer (Non Mag) 6 3/4 1.900 4 1/2 NC 50 59.73 1 MWD (Dir & Logging) H-Cim 6 3/4 1.900 4 1/2 NC 50 66.71 1 MWD (Directional) T-M 6 3/4 1.900 4 1/2 NC 50 76.70 1 Ftoat Sub NM 6 1/2 3.500 4 1/2 NC 50 78.93 3 NMDC 6 3/4 2.813 4 1/2 NC 50 170.89 3 HWDP 5 3.000 4 1!2 NC 50 262.67 1 Drilling Jars -Mechanical 6 1/4 2.250 4 1/2 NC 50 295.36 14 HWDP 5 3.000 4 1/2 NC 50 716.40 1 Drill Pipe 5 4.276 4 1/2 NC 50 747.98 1 Ghost Reamers 8 3/4 2.875 4 1/2 NC 50 753.98 33 Drill Pipe 5 4.276 4 1/2 NC 50 1,800.45 1 Ghost Reamer 8 3/4 2.875 4 1/2 NC 50 1,807.35 2 Drill Pipe 5 4.276 4 1/2 NC 50 1,870.84 XO Sub 6 1/2 2.500 4 XT 39 1,872.20 Page 2/3 Report Printed: 11/15/2006 Daily Drilling Report CD4-320 Drillin Parameters D I u ~ fl r d~.ny Hrs ~ ,ict Drill Q (f3ovr, S_ tart (ftKB) Enn (YJC6j I s ~. rt; Cum Depth (ft) ma (hrs) Int Depth (ft) r T% vvvB Ui,fj RPM (rpr 2,519.0 2,519.0 0.00 0.00 550 20.0 50 --- _- - - -- - Wellbores Report Date: 7/3/2006 ___.. SFP(psi; _ DillTq 1,820.0 7,000.0 Wellbore Name CD4-320 Wellbore API/UWI 501032053100 Section ~i e ,c°~1 I - - - Ad Tip tl1K8! A~~I Btm IftKB:~ Start Oaie_ End Oate COND1 - - -- 44 _ - - 36.0 114.0 2/14!2006 2/15/2006 SURFAC 12 1/4 114.0 2,519.0 7/1/2006 7/2/2006 INTRM1 8 3/4 2,519.0 8,155.0 7/2/2006 7/17/2006 PROD1 --- 6 1/8 -- 8,155.0 14,471.0 7!19/2006 -- _ _ - 7/25/2006 __ Casing Strings Casing Desenpi an ~ 3un D OU i. ~l W. [tns~n) ~ ~, ~, e ~ ! C=,F'~ +rkR`. c[ nrn ant ISurface ~ 3/2006 9 5/8 40.00'~L-30 ! 2509.0 i, Cement Surface Casin Cement -Started 7/3/2006 Type casing Wellbore CD4-320 String SurFace, 2,509.OftKB Cement Evaluation Results Stg No. 1 Description Surface Casing Cement Top (ftKB) 37.0 Bottom (ftKB) 2,509.0 Q (end) (bbl/... 4 P (final) (psi) 590.0 Fluld Amount (sacks] "~~~`__ V (b61) Dansdy (iblga[) ~ Yield (ft'/sack) Est T ap {ftKB) Est Btm (ftKB) Lead Cement _ __ _ _ G G 344 238 272.0 48.0 10.70 1.17 4.45 1.16 37.0 2,009.0 2,009.0 2,009.0 Page 3/3 Report Printed: 11/15/2006 0 0 l1') O ~ tt) l(7 N O O O ~NN6~ c0 ca cOMM ~ MM _-. _ -- •y O 00 O t!~ tf) ~ I.f~ tf'7 ~ ~ ~ lC~ h C d a1 ~ ~ l~C c L O<nLn~ lnNlnM ln~lf) ~ lf)CO Q. ~ ~~ c O O ~ N M ~ to N 0) O a+ d ° ~ o000 oo~no 000 0 0 00 O 0) O ~t I~ O N M N ~ CO ~ ~ i. •fn N M ~ CO t~ N 67 67 07 67 6~ 3 c n 47 •Q a ~~ OWN(') ~ ~CDI~ COOO ~ N d Y Y (n O L Y i+ 0000 0000 000 O 00 d l N C d to ~ ~ ~ ~ ~ ~ ~ Ln ~ ~ O O O m •~ N N N N N N N N N N N N N N ~ ~ O~NM ~~0~ 000)0 ~ O~ ~ O y~ 'C r ~ N N H O •+~ C 0000 0000 000 O 00 CL 03 ~ ~M~ ic">~coo~ OWN M ~~ III V ,Q d ~ ~ ~ r ~ ~ E ~ O ~NM v~nCOI~ 000)0 ~ NM in 7Y ~ ~ ~~ 7 Y O a '--' (n N ~ / ~ ~ , 'N V co ' ~ ~ G. Q ~ 0 Y ~ n. ~ O p d N O Q d N Q N d~ ~ ~ n~N I~ d 00 ~ d O_ J J J n 0. r a ~ ~ ~o p d ~ F I~ oi O co O ° O ° O °p C D o ~~ a ~ d ~, # O 0 ~ O i o S ~ ~ t J ~ ---- C = ~ w = 'L Sr N ~r I~ N J p C ~ ~ ~- ~ ~ ~ r w _ .. .. i+ O ~ ~ . N L a,~WH m~ V O ~ ~ N _ ~ E ~ ~ f- O ' ~"" r ~ 01 Z rn ~ a ~ a ~ ~ y a` Op tT>a ~~ •~o`-o ~ r Q + Q U o ' ~ , ~ oo•~~ ~ ~ °I~°~ O ~ t ~ ~ v Y Q y' U W N ~ ~ ~ ~ J p Cy ~ ~ O >+ Y d O LL. O .C ~ ~ p U to O °v LL ~ ~ c Ci _ ~ , (~ ~ 0 I I N ~ 07I ~ o 0 ~ N O ~ N n~ •in~~~ ~. r+ 0 p1 O ~' J Q J n J J ~ •~ ~ O ~ L, C O c0 O 0 ~ 0 ~ 0 0 00 ~ ~ ~ M a~, ~.. ' ++ ~ N 0 In 0 l!~ ~ ~ ~ O 0 ~ ~ v ~ r` ti ~ N U `n rn C ~ ~ aNi p C .. .. ~ .. ..:.: ~ ~ L L L rn ~ ~ ~ t, p R c U ~ •~ _ (' 7 _ . d N C N N~~ 3 N ~ ~ U ~ ~ ~ ~ ~ O ~II L K c ~ ~ N ? o a~> y a ~ 111 a ~ ~ ~ ~ ~ ~ ~ £ O 'e o a i U .., ~ ~ y ~ F- ai N m Y U vW ~ J ~ Z ~ N ~ ~ m II _ ~ ° w ~ o x if ) f` O r i 7 U ' I ~ I U ~ ~ w T N `7 n ~ j ; '~ ~ i 0 ~ a; - n j o I vo ~ ~ i N J O) Y V 03 m d m 0) m M N 0) ~+ 7 o ~ `~ ~ c +r ao oc ~ a ~y O 0 ~ L W U F- ~ W C LL ~ O N Y Q ~ N J d Q .3 y E d ~ R 7 m ~ H ~ ~ ~ w ~ ~ (7 ~ Z U ~ ~ U ~ 0 0 0 0 0 0 0 0 o ion oo ~ o ion M N N 3bnss3bd • • Cono~oPhilli S Casing Detail 7" Casin_g Well: CD4-320 Date: 7/17/2006 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Lower lock down 34.65 FMC Gen V Hanger 3.33 34.65 Jts 3 to 189 187 Jts 7 " 26# L-80 BTCM Csg 8018.72 37.98 Halliburton Float Collar .99 8056.70 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 85.33 8057.69 Ray Oil Tools Float Shoe 2.06 8143.02 8145.08 TD 8 3/4" Hole 8155.00 8 3/4" Hole TD @ 8155' MD / 6992' TVD 7" Shoe @ 8145.08' MD / 6992' TVD Total Centralizers: 44 Straight blade centralizer one per jt on jts # 1-14 Straight blade centralizer one per jt jts. # 130,131, 132, Straight blade centralizer one per jt on every other joint Starting @ # 134 to # 186 Top Kuparuk - 8030' MD - 6990' TVD 204 joints in shed - 189 total jts. to run Last 15 jts. out Use Run & Seal i e do e Average MU torque 6500 ft/Ibs Remarks: Up Wt - 265k Dn Wt-185k Block Wt - 75k Supervisor: D. Lutrick / L. Hill i ~",,,~ Primary Job Type DRILLING ORIGINAL Cement Details _ Description Production Casing Cement Comment Cement Stages _ - -- IStage # 1 _ Description Objective Production Casing Cement Q (start) (bbl/min) Q (end) (bbl/min) Q (a 4 2 Cement Detail Report CD4-320 Production Casing Cement Job Category AFE / RFE Start Date Spud Date End Date DRILLING 10136460 6/30/2006 7/1/2006 7/29/2006 Cementing Start Date Cementing End Date Wellbore Name 7/18/2006 19:20 7/18/2006 21:24 CD4-320 Top (ftK6) Bottom (ftK6) 6,000.0 8,145.0 Bbl/min) P (final) (psi) P (bump) (psi) F 4 1,200.0 1,670.0 -- - _ _ _ - Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? Yes 0.0 Yes Yes ;ip? Stroke (ft) Rotated? Pipe RPM (rpm) No No !Cement Fluids 8 Additives - -- - ;Fluid __ _ Fluid Type Fluid Description Estimated Top (ftK6) Est Btm (ftK6) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 6,000.0 8,145.0 405 G 89.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 5.09 15.80 11 /15/2006 Daily Drilling Report CD4-320 ... . Report Date: 7/18/2006 Report Number Days From Spud (days) Depth Start (ftKB) Depth End (ftKB) Depth Progress (ft) Wellbore 19 17.69 8,155.0 8,230.0 75.00 CD4-320 Spud Date Contractor Rig Name/No Field Name Well Type Target Depth (ftK6) 7/1/2006 DOYON 19 NANUQ KUPARUK Development 14,471.0 AFE / RFE / Maint.# Total AFE Amount Average ROP (ft/hr) 10136460 6,285,925.00 51.4 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Intermediate, 8,145.1ftK6 Ops and Depth @ Morning Report Daily Cost Total Cummulative Cost MU BHA 323,474.61 3,950,629.20 24hr Forecast Daily Mud Cost Cummulative Mud Cost RIH - S&C DL - CO shoe trk -FIT -Drill 4,795.61 468,172.20 Last 24hr Summary RU & Run 7" csg to 8145' -Circ & condition for cmt job - Cmt 7" csg -Test csg -Set & test pack-off General Remarks Weather Head Count 50/ 45 wc/ SW @ 14 mph 53.0 Suparvisut- - _.. __ _- __ - ----... Title _.. ~.,.. Donnie Lutrick .Rig Supervisor Don Mickey Rig .Supervisor Time Log -- --- - - -_ - - ~~. F-.a -T.in~ ~. ~ Depth Start ~ Depth End 1~,~ i T~i-~c hrsl ?tease Op Code OpSub-Co.-. P-N-T TrbiC~.de ~ 7iblr.lass- r~KR: '~. (ftKB) ( ~nm~Or~ation 00:00 01:15 1.25 INTRM1 WELCTL BOPS T Hole Shale 0.0 0.0 Finish change upper pipe rams to 7". Test 7" rams to Conditions 250-5000 psi. Pull test plug. Install thin wear bushing. 01:15 01:45 0.50 INTRM1 CASING RURD T Hole Shale 0.0 0.0 RU csg equipment. PJSM. Conditions 01:45 05:00 3.25 INTRMI CASING RNCS T Hole Shale 0.0 3,435.0 RIH w/ 80 jts 7" 26# L-80 BTCM csg to 3435'. Conditions 05:00 05:45 0.75 INTRMI CASING CIRC T Hole Shale 3,435.0 3,435.0 Circulate 1 csg volume. Stage pumps to 5 bpm at 430 Conditions psi. 05:45 09:00 3.25 INTRM1 CASING RNCS T Hole Shale 3,435.0 6,993.0 RIH w/ 83 jts 7" 26# L-80 BTCM csg from 3435' to Conditions 6993'. 09:00 10:00 1.00 INTRM1 CASING CIRC T Hole Shale 6,993.0 6,993.0 CBU. Stage pumps up to 4.5 bpm at 540 psi. Conditions 10:00 11:15 1.25 INTRMI CASING RNCS T Hole Shale 6,993.0 7,678.0 RIH w/ 16 jts 7" 26# L-80 BTCM csg from 6993' to Conditions 7678'. Work through tight hole from 7570' to 7668'. 11:15 12:30 1.25 INTRMI CASING RNCS P 7,678.0 8,145.0 RIH w/ 16 jts 7" 26# L-80 BTCM csg from 7678' to 8107'. MU hanger and LJ. Land csg at 8145'. 12:30 13:00 0.50 INTRMI CASING RURD P 8,145.0 8,145.0 RD Franks fill-up tool. RU cement head and lines. 13:00 19:00 6.00 INTRM1 CEMENT CIRC P 8,145.0 8,145.0 Establish Circ @ .5 BPM @ 400 psi -staging pump up to 4.4 BPM - ICP 680 FCP 620 -Circ & attempt to get rate up for cementing -Hole trying to pack -off unable to get rate up to 5 BPM without packing off 19:00 21:30 2.50 INTRMI CEMENT DISP P 8,145.0 8,145.0 PJSM on cmt job -Cemented 7" csg as follows: Pumped 1 bbl water -Tested lines to 4000 psi -Mixed & pumped 40 bbls MudPush @ 12.5 ppg - 4 BPM @ 450 psi -Dropped btm plug - Mixed ~ pumped 89 bbls tail slurry (Class G w/additives) - 15.8 ppg @ 4 BPM @ 400 psi -Dropped top plug w! 20 bbls water f/ Dowell - switched to rig pumps & displaced cmt w/ 10.5 ppg mud @ 4 BPM for 233 bbls -Observed slight packing off - slowed pump to 3.5 BPM next 30 bbls -slowed pump to 2.5 BMP for remained of job - 286 bbls total displacement -Bumped plug w/ 1670 psi -Check floats OK CIP @ 2124 hrs.- Full returns throughout - No pipe movement 21:30 22:30 1.00 INTRMI DRILL OTHR P 8,145.0 8,145.0 RU & test csg to 3500 psi for 30 mins. RD 22:30 23:00 0.50 INTRMI CEMENT PULD P 8,145.0 8,145.0 RD cmt lines & head - LD landing jt. Latest BOP Test Data ~t,at - - - Comment - -- ---- - - - - - - - Page 1/2 Report Printed: 11/15/2006 Daily Drilling Report CD4-320 Report Date: 7/18/2006 _ Time Log - - -- `=',- F ~,~: D.i -_ ~ ~ T•.r~a ~ ~I Der h >Irrt C rl-~ C~ ~-..-__ - - ^ r f iae • i ~: Ph se Up Code OpSub (,~ "-N T 7rbl G~de Tr~l Glass_ { .,:B) 1_ ~.t~:b1 ,vC3pn ~n __ '23:00 00:00 '~~ 1.00 INT RMI DRILL OTHR P 8,145.0 8,145.0 Pull thin wa ll wear bushing -Set & test pack-o ff to 5000 ; I psi - - 'Mud Check Data - - - - T-;,~ __ De ~.h~liKk3. _ I~~n 11 na7j Vis(slgt) PVCaIc{cp) Yf <<I 1~I,100ii i ~~ t al ~s) b6 .St=) Gel (10m) Gel (30m) (Ibf1900ft~) !Ibfl100ft~) MBT(Iblbbl) HTHP Filt {miJ3flmin) _ pli DensrtyTe~,np~ (°F) Solid ~a.~r ( - ~LSND 3.155 0 5 55~ 00 47 14.0 23.000 11 000 13.000 15.000 24.0 6.0 8 ° 125 - - ---- -- .Injection Fluid Fluid Source Fr,.m Lease (b6q Destination Note- . _.. _- - -- Diesel Other --- - - - ----.._ ....._._.. 5.0 130.0 From CD4-320 From CD4-320 Water Based Mud 756.0 CD4-208 From CD4-320 !Drill Strin s: BHA No. 6 - PeriSco /Bit Run No. 6 - 69/bin, Hycalog, RSX513M-62, 213171 Depth In (ftKB) Depth Out (ftK6) TFA (incl Noz) (in') Nozzles (l32") IADC Bit Dull String Wt (70001bf) WOB (max) (700... WOB (min) (7000... 8,155.0 8,503.0 0.38 10/10/10/10/10 ~ ------- 4 ~ 0 0 Drill String Components _ Jr= - - - ItemDescriptr_~n 1 PD Bias Unit 1 PD Control Collar 1 PD Reciever Float Sub 1 Periscope Tool OD pn: I 5 4 15/16 4 11/16 3 1/2 3 1/2 NC 38 NC 38 ~ t;w11 1 Impulse MWD Tool 4 3/4 3 1/2 NC 35 1 VPWD 4 3/4 3 1/2 NC 38 3 Dritl Collar -Flex Non Mag 4 3!4 2.250 3 1/2 NC 38 1 XO Sub 4 3/4 2.250 4 XT-39 3 HWDP 4 2.750 4 XT-39 1 Jars 4 4 XT-39 2 HWDP 4 2.750 4 XT-39 Drilling P -- - - - - -- arameters ,'art `KB ~ - 8.155.0.- ', Wellbores Wellbore Name C na T~.me Sliding Hrs Cum D' '. ( tl ~:; I 3.60 13.95 21.40 46.41 81.21 96.24 188.25 190.89 282.91 314.89 376.26 Fnd tthB ~ ~' (min/ft) Cun D th If.;~ ~ Trme h r~~ Ir • f'~~rt~ (•.; ,.~~ 1 r (I~f) FPM hpro) Sf F !Fvii Dnll T I 8 230.046 ~, 75-00 1.46 75.00 250 8.0 100 1 720.0 5.500-0~ -_ - - - Wellbore API/UWI CD4-320 COND1 44 SURFAC 12 1 /4 INTRMI 8 3/4 PROD1 6 1/8 Survey Data- M~(ftKC~ Ina _;_ ~j ~ 8,219.36 90.96 _ _ I 11 Casing Strings _ Casing D~ ~ p'~?r~ Run Date 501032053100 ,ct Top (ftKB) Act Sint{ftK6) Start Dafe end Daf 36.0 114.0 2114(2006 ___ __. 2/15/2006 114.0 2,519.0 7/1/2006 7/2/2006 2,519.0 8,155.0 7/2/2006 7/17/2006 8,155.0 14,471.0 7/19/2006 7/25/2006 -I? D (ftK L..--- _~ VS ':,j-- ____.. -- NS (ffj - _ ,. _ wl tt. t; --..... -- ULS i- ~__- 1 6 992.69 88.68 309.47 1,024.04 0.3% OJ n; 'sJt nt ~ i :1e ~rel-h r!hNi ~ -- - (;omment lntefineC7idte ~I Cement Production Casin Cement -Started /~ /'17i/ZUUb i 7/18/2006 ~Lb-UU L-dU ~ - b.145.~ - Type casing Wellbore CD4-320 String Intermediate, 8,145.1ftKB Cement Evaluation Results Stg No. 1 Tail Cement Description Production Casing Cement Fluid Class Amount (sacks) G 405 Top (ftKB) 6,000.0 V (b~-, Denstfy (Ib ;, ,i;~. '~. 89.0 15.80 Bottom (ftKB) 8,145.0 ~ Yeld (R'Isack) 1.16 Q (end) (bbt/... P (final) (psi) 2 1,200.0 Est Top (ftKB) _ Est Btm (ftKB) 6,000.0 8,145.0 Page 2/2 Report Printed: 11/15/2006 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD4-320 Rig: Doyon 19 Date: 7/19/2006 Volume I put Pump Rate: Drilling Supervisor: Lutrick /Mickey I Pump used: Cement Unit I ~ i n Barrels I _ Bbls/strk ~ 0.80 Bbl/min ~ Type of Test: Annulus Leak off Test for ~isposa~ Adequacy i ~ Pump ng down annulus. ~ Casin Test Pressure In te rit Test Hole Size: 8-3/4" ~ Casin Shoe Depth Hole Depth Pumpin Shut-in Pumpin Shut-in RKB-CHF: 34.7 Ft 2509.0 Ft-MD 2378.0 Ft-TVD 6000.0 Ft-MD 5700.0 Ft-TVD Bbls psi Min psi Bbls psi Min si Casing Size and Description: '~ 9-5/8" 40#/Ft L-80 BTC ~ 0 0 0 0.00 670 Chan es for Annular Ade uac Test Pressure Int e rit Test 1 0.5 13 0.25 639 Enter outer casing shoe test results in comments Mud Weight: 10.5 ppg 2 1 31 0.50 618 Casing description references outer casing string. Inner casing OD: 7.0 In. 3 1.5 97 1.00 Hole Size is that drilled below outer casing. 4 2 180 1.50 Use estimated TOC for Hole Depth. 5 2.5 308 2.00 Enter inner casing OD at right. Desired PIT EMW: 15.0 ppg 6 3 410 2.50 ,~ Estimates for Test: 556 psi 0.3 bbls 7 3.5 485 3.00 567 ~ ~ 8 4 607 3.50 565 -- - - -- EMW =Leak-off Pressure + Mud Weight = 900 PIT 15 Second 9 4.5 685 4.00 560 0.052 x TVD 0.052 x 237g + 10.5 Shut-in Pressure, psi 10 5 807 4.50 557 EMW at 2509 Ft-MD (2378 Ft-TVD) = 17.8 639 15 5.5 895 5.00 554 laoo - 20 6 900 5.50 547 25 6.5 787 6.00 547 - - 30 7 751 6.50 546 _ - _ _ _ ~ ~ ~ ~ _ 7.5 744 7.00 539 8 745 7.50 539 8 5 727 8 00 539 - . . w 9 727 8.50 539 ~ ~ ~ 9.00 539 ~ soo -- - ~ 9.50 537 w 10.00 ~ -- a - - - ~ ~ 0 0 1 2 3 4 5 6 7 8 9 10 0 5 10 15 20 25 30 Barrels Shut-In time, Minutes ~'~CASING TEST BLEAK-OFF TEST O PIT Point Vol Pum ume ed Vol Bled ume Back Vol Pu ume m ed Vol Bled ume Back s s s s Comments: 9 5/8" shoe LOT @ 17.1 ppg ~.v~tvcu r~i a iuiai w i Summary • ConocoPhillips September 19, 2006 P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 REGEIV'ED Commissioner S E P 1 '~ 2006 State of Alaska Alaska Oil & Gas Conservation Commission Alaska Oil & Gas Cons. Commission 333 West 7th Avenue Suite 100 Anchorage Anchorage, Alaska 99501 Subject: Well Completion Report for CD4-320 (APD 206-055) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the Well Completion Report for the recent drilling operations on the Alpine well CD4-320. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells GCA/skad G. C. Alvord Alpine Drilling Team Leader Drilling & Wells ORIC-INAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 1a. Well Status: Oil O ' Gas Plugged Atrandoned Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1b. Well Class: QIIChOfBge Development ^/ Exploratory f^ Service ^ Stratigraphic Tes10 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: July 28, 2006 ~ 12. Permit to Drill Number: 206-055 / 306-242 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: July 1, 2006 13. API Number: 50-103-20531-00 / 50-103-20531-70 4a. Location of Well (Governmental Section): Surface: 2978' FNL, 438' FEL, Sec. 24, T11 N, R4E, UM 7. Date TD Reached: July 25, 2006 14. Well Name and Number: CD4-320 /CD4-320PB1 At Top Productive Horizon: 2500' FNL, 425' FWL, Sec. 19, T11 N, RSE, UM 8. KB Elevation (ft): 37' RKB 15. Field/Pool(s): Colville River Field Total Depth: 1761' FSL, 1755' FWL, Sec. 30, T11 N, R5E, UM 9. Plug Back Depth (MD + TVD): 14471' MD / 7019' TVD Nanuq-Kuparuk Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 377805' y- 5957437 Zone- 4 10. Total Depth (MD + TVD): 14471' MD / 7019' TVD - 16. Property Designation: . ADL 380077, 384211 TPI: x- 378676 y- 5957900 Zone- 4 Total Depth: x- 379904 • - 5951581 Zone- 4 11. Depth where SSSV set: landing nipple @ 2048' 17. Land Use Permit: ALK 380077 18. Directional Survey: Yes ^/ No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 1400' MD 21. Logs Run: GR/Res/Dens/Neutron 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 65.2# H-40 37' 114' 37' 114' 24" Portland Type III 9.625" 40# L-80 37' 2509' 37' 2378' 12.25" 344 sx AS Lite, 238 sx Class G 7" 26# L-80 37' 8145' 37' 6992' 8.75" 405 sx Class G 4.5" 12.6# L-80 7929' 14462' 6985' 7018' 6.125" slotted liner 23. Pertorations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" 7934' 7486' slotted liner from 8121'-8398' MD, 8603'-11211' MD, 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11411'-14380' MD DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED na 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Flowback to be performed at later time Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (core) not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". COtAtaL~T 0 NONE ~29DM5 SF~ SEP 2 8 2DD6 ~°___ac VERt t1:0 Form 10-407 Revised 12!2003 CONTINUED ON REVERSE ~, ~. ~y(o ~~~~ ~ ~~ ,~9~~~ . ~ ~ ~ ~- G ~E~EIV WELL COMPLETION OR RECOMPLETION REPOR ~6~~hs. commssatt i zs. zs. GEOLOGIC MARKERS FORMATION TESTS ` NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". CD4-320 Nanuq sand 6494' 6157 - Kuparuk Csand 8020' 6990' N/A CD4-320PB1 TD 8019' 6993' 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certiy that the foregoing is true and correct to the best of my knowledge. Contact: Vern Johnson @ 265-6081 Printed Name C. Ivord Title: Alpine Drilling Team Leader Tl I~ ~ O~ D Si t ~ Ph t ure . gna - a e one 2 f,~ ~ G (2 o INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 ,~ Halliburton Company Survey Report Company: ConocoPhillipsAlaskalnc. Date: 8/4/2006 Time 105944 Page:.. 1 Field: Colville River Unit Co-ordinatc(NE} Reference: Wel1_CD4-320, True North ' Site: Alpine CD4 Vertical (TVD) Re ference: CD4-320:56.7 Well: CD4-320 Section (VS) Reference: Well (OAON,O.OOE,158.43Azi) Wellpath: CD4-320 Sur -vcy Calculation Method: Minimum Curvature Db: Oracle Field: Colville River Unit ' North Slope Alaska United States Map System:US State Pl ane Coordin ate System 1927 Map Zone: Alaska, Zone 4 I Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre i. Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Well: CD4-320 Slot Name: - ~ i Alpine CD4 Well Position: +N/-S -94.19 ft Northing: 5957437.90 ft ' Latitude: 70 17 32.039 N +E/-W -368.12 ft Easting : 377805.14 ft ' Longitude: 150 59 21.491 W Position Uncertainty: 0.00 ft ! Wellpath: CD4-320 Drilled From: CD4-320PB1 -~ 501032053100 Tie-on Depth: 4313.09 ft ' Current Datum: CD4-320: Height 56.72 ft Above System Datum: Mean Sea Level Magnetic Data: 7/19/2006 Declination: 23.27 deg Field Strength: 57501 nT Mag Dip Angle: 80.63 deg Vertical Section: Depth From (TVD) +N!-S +E/-W Direction -_-~--_ _-_ ft ft ft deg __ _ _ 3 7.02 ___ -- 0.00 0.00 158+43 -- _ Survey Program for Defi Date: 8/4/2006 nitive Wellpa Validated: th No V ersion: 7 ~ Actual From To Survey Toolcode Tool Name ft ft ', 81.50 802.00 CD4-320P B1 gyro (81.50-802.00) CB-GYRO-SS Camera based gyro sin gle shot ' 889.55 4313.09 CD4-320P 61 (889.5 5-7985.74) (0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4341.00 8113.85 CD4-320 (4341.00-8113.85) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 'L 8150.67 14409.61 CD4-320 Anadrill (8150.67-1440 _ MWD+IFR-AK_CAZ-SC MWD+IFR AK CAZ SCC _ _ _~ Survey J~ID Incl Azim TVD Sys "TVD N/S E/N' MapN MapE Tool ft deg deg ft ft ft ft ft ft 37.02 0.00 0.00 37.02 -19.70 0.00 0.00 5957437.90' 377805.14. TIE LINE 81.50 0.50 114.00 81.50 24.78 -0.08 0.18 5957437.81 377805.31 CB-GYRO-SS I 171.00 0.65 114.00 170.99 114.27 -0.44 1.00 5957437.44 377806.13 CB-GYRO-SS i 261.00 1.00 345.00 260.99 204.27 0.11 1.26 5957437.98 377806.40 CB-GYRO-SS I 351.00 4.70 320.00 350.87 294.15 3.69 -1.31 5957441.61 377803.88 CB-GYRO-SS 441.00 5.00 322.00 440.54 383.82 9.61 -6.10 5957447.60 377799.19 CB-GYRO-SS ~~ 532.00 5.90 322.00 531.13 474.41 16.42 -11.42 5957454.50 377793.99 CB-GYRO-SS '~ 622.00 7.80 321.00 620.48 563.76 24.81 -18.11 5957462.99 377787.43 CB-GYRO-SS 712.00 9.00 324.00 709.52 652.80 35.25 -26.09 5957473.56 377779.62 CB-GYRO-SS 802.00 12.40 338.00 797.95 741.23 49.91 -33.85 5957488.35 377772.10 CB-GYRO-SS 889.55 15.75 346.06 882.87 826.15 70.17 -40.24 5957508.70 377766.04 MWD+IFR-AK-CAZ-SC 934.24 17.65 350.84 925.68 868.96 82.74 -42.78 5957521.32 377763.71 MWD+IFR-AK-CAZ-SC 1029.04 21.03 357.43 1015.13 958.41 113.94 -45.83 5957552.56 377761.16 MWD+IFR-AK-CAZ-SC 1123.86 20.71 0.66 1103.73 1047.01 147.70 -46.40 5957586.32 377761.14 MWD+IFR-AK-CAZ-SC 1219.21 22.59 10.55 1192.38 1135.66 182.58 -42.85 5957621.13 377765.26 MWD+IFR-AK-CAZ-SC 1314.87 22.01 16.36 1280.89 1224.17 217.85 -34.44 5957656.25 377774.24 MWD+IFR-AK-CAZ-SC it 1410.72 22.86 17.66 1369.49 1312.77 252.82 -23.73 5957691.05 377785.52 MWD+IFR-AK-CAZ-SC i 1504.35 22.68 19.85 1455.82 1399.10 287.13 -12.08 5957725.16 377797.72 MWD+IFR-AK-CAZ-SC 1599.49 21.27 13.71 1544.06 1487.34 321.15 -1.76 5957759.01 377808.59 MWD+IFR-AK-CAZ-SC 1694.79 22.26 13.31 1632.57 1575.85 355.51 6.49 5957793.23 377817.40 MWD+IFR-AK-CAZ-SC 1789.60 23.21 13.89 1720.01 1663.29 391.12 15.11 5957828.69 377826.60 MWD+IFR-AK-CAZ-SC 1884.88 21.78 19.37 1808.05 1751.33 426.03 25.48 5957863.42 377837.53 MWD+IFR-AK-CAZ-SC i~ 1980.19 21.95 19.78 1896.50 1839.78 459.48 37.37 5957896.67 377849.97 MWD+IFR-AK-CAZ-SC 2075.26 23.43 17.01 1984.21 1927.49 494.27 48.92 5957931.27 377862.07 MWD+IFR-AK-CAZ-SC 2170.66 24.35 15.38 2071.44 2014.72 531.37 59.68 5957968.19 377873.44 MWD+IFR-AK-CAZ-SC ~ 2263.92 24.94 16.54 2156.20 2099.48 568.76 70.38 5958005.39 377884.74 MWD+IFR-AK-CAZ-SC I 2361.85 24.76 15.13 2245.07 2188.35 608.35 81.61 5958044.79 377896.61 MWD+IFR-AK-CAZ-SC i; Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc: Field: Colville Rive r Unit Site: Alpine CD4 WeIL• CD4-320 Wcllpath: CD4-320 Sur~~ev ><1D Incl Azim TT'D 4~sT<'D ft deg deg ft ft 2457.26 25.28 15.39 2331. 52 2274 .80 2530.65 25.51 15.71 2397. 82 2341 .10 2604.03 25.74 15.66 2463. 98 2407 .26 2695.06 25.37 15.92 2546. 11 2489 .39 2790.06 24.29 16.02 2632. 33 2575 .61 2884.96 23.42 16.88 2719. 12 2662 .40 2980.13 22.99 16.43 2806. 59 2749 .87 3075.49 22.28 17.16 2894. 60 2837 .88 3170.58 21.47 17.48 2982. 85 2926 .13 3265.57 21.32 18.57 3071. 29 3014 .57 3360.98 20.88 19.00 3160. 30 3103 .58 3456.12 20.44 18.84 3249. 32 3192 .60 3551.52 19.65 18.86 3338. 94 3282 .22 3646.49 18.85 18.92 3428. 60 3371 .88 3741.76 18.99 18.39 3518. 73 3462 .01 3837.42 19.18 19.53 3609. 13 3552 .41 3932.68 18.10 20.56 3699. 39 3642 .67 4027.66 16.78 21.08 3790. 00 3733 .28 4124.41 16.53 20.55 3882. 69 3825 .97 4219,55 17.03 21.83 3973. 78 3917 .06 4313.09 17.84 22.48 4063. 03 4006 .31 4341.00 17.56 22.91 4089. 61 4032 .89 4410.01 19.84 25.50 4154. 98 4098 .26 4505.11 22.19 23.44 4243. 75 4187 .03 4600.70 22.20 14.45 4332. 28 4275 .56 4695.69 21.54 7.15 4420. 45 4363 .73 4791.12 19.87 6.07 4509. 71 4452 .99 .4886.55 19.49 5.27 4599. 57 4542 .85 4982.06 20.45 5.48 4689. 34 4632 .62 5076.80 21.04 7.86 4777. 93 4721 .21 5171.98 21.27 8.39 4866. 70 4809 .98 5267.52 17.99 11.20 4956. 68 4899 .96 5362.58 14.85 15.89 5047. 85 4991 .13 5457.72 12.32 26.42 5140. 34 5083 .62 5553.01 9.23 36.20 5233. 94 5177 .22. 5648.69 8.09 56.98 5328. 56 5271 .84 5744.10 8.23 77.60 5423. 02 5366 .30 5839.18 8.43 93.11 5517. 11 5460 .39 Date: 8/4/2006 Time: 10:59:44 Page: 2 Co-ordinate(NE) Reference: WeII:~CD4-320, True North Vertical (TVD)r,Reference: CD4-320:56.7 Section (VS) Reference: Well (O:OON,O.OOE,158.43Azi) Sun~ey Calculation Method: Mininwm Curvature Db: Orade Y/S ft 647.28 677.60 708.15 745.94 784.29 821.10 857.03 892.16 925.99 958.94 991.45 1023.21 1054.15 1083.78 1113.05 1142.62 1171.23 1197.84 1223.76 1249.36 1275.32 1283.15 1303.31 1334.36 1368.41 1403.10 1436.61 1468.59 1501.07 1534.39 1568.40 1600.02 1626.14 1646.97 1662.24 1672.11 1677.23 1678.32 E/W ft 92.23 100.67 109.25 119.93 130.91 141.77 152.52 163.12 173.66 184.39 195.44 206.33 216.89 227.03 236.91 247.07 257.50 267.62 277.47 287.40 297.97 301.25 310.34 324.44 336.13 342.78 346.67 349.85 352.91 356.81 361.67 367.06 373.25 381.11 390.15 400.33 412.63 426.24 IVIapN ft 5958083.54 5958113.72 5958144.12 5958181.73 5958219.89 5958256.52 5958292.26 5958327.22 5958360.86 5958393.63 5958425.96 5958457.53 5958488.30 5958517.75 5958546.85 5958576.26 5958604.69 5958631.12 5958656.88 5958682.32 5958708.10 5958715.87 5958735.88 5958766.69 5958800.55 5958835.12 5958868.57 5958900.49 5958932.90 5958966.16 5959000.08 5959031.61 5959057.62 5959078.31 5959093.44 5959103.14 5959108.06 5959108.92 MapE _ l uol ft 377907.87 MWD+IFR-AK-CAZ-SC i 377916.79 MWD+IFR-AK-CAZ-SC 377925.87 MWD+IFR-AK-CAZ-SC 377937.16 MWD+IFR-AK-CAZ-SC 377948.76 MWD+IFR-AK-CAZ-SC 377960.22 MWD+IFR-AK-CAZ-SC 377971.55 MWD+IFR-AK-CAZ-SC 377982.72 MWD+IFR-AK-CAZ-SC ', 377993.81 MWD+IFR-AK-CAZ-SC ~ 378005.07 MWD+IFR-AK-CAZ-SC 378016.65 MWD+IFR-AK-CAZ-SC 378028.05 MWD+IFR-AK-CAZ-SC 378039.12 MWD+IFR-AK-CAZ-SC 378049.73 MWD+IFR-AK-CAZ-SC 378060.09 MWD+tFR-AK-CAZ-SC ~ 378070.73 MWD+IFR-AK-CAZ-SC 378081.62 MWD+IFR-AK-CAZ-SC 378092.16 MWD+IFR-AK-CAZ-SC 378102.44 MWD+IFR-AK-CAZ-SC ~ 378112.78 MWD+IFR-AK-CAZ-SC i, 378123.77 MWD+IFR-AK-CAZ-SC 378127.17 MWD+IFR-AK-CAZ-SC 378136.60 MWD+IFR-AK-CAZ-SC 378151.19 MWD+IFR-AK-CAZ-SC 378163.43 MWD+IFR-AK-CAZ-SC 378170.64 MWD+IFR-AK-CAZ-SC 378175.08 MWD+IFR-AK-CAZ-SC 378178.78 MWD+IFR-AK-CAZ-SC 378182.36 MWD+IFR-AK-CAZ-SC 378186.81 MWD+IFR-AK-CAZ-SC 378192.22 MWD+IFR-AK-CAZ-SC 378198.13 MWD+IFR-AK-CAZ-SC 378204.74 MWD+IFR-AK-CAZ-SC 378212.93 MWD+IFR-AK-CAZ-SC 378222.22 MWD+IFR-AK-CAZ-SC 378232.56 MWD+IFR-AK-CAZ-SC 378244.94 MWD+IFR-AK-CAZ-SC 378258.56 MWD+IFR-AK-CAZ-SC 378271.37 MWD+IFR-AK-CAZ-SC 378282.30 MWD+IFR-AK-CAZ-SC 378292.20 MWD+IFR-AK-CAZ-SC 378301.62 MWD+IFR-AK-CAZ-SC 378310.41 MWD+IFR-AK-CAZ-SC 378317.81 MWD+IFR-AK-CAZ-SC 378328.94 MWD+IFR-AK-CAZ-SC 378343.98 MWD+IFR-AK-CAZ-SC 378361.16 MWD+IFR-AK-CAZ-SC ~~ 378379.15 MWD+IFR-AK-CAZ-SC li 378397.66 MWD+IFR-AK-CAZ-SC 378415.91 MWD+IFR-AK-CAZ-SC 378435.14 MWD+IFR-AK-CAZ-SC 378457.26 MWD+IFR-AK-CAZ-SC 378481.50 MWD+IFR-AK-CAZ-SC 5935.03 7 .75 115.30 5612. 03 5555. 31 1675.17 439.10 5959105 .57 6030.43 8 .50 132.05 5706. 48 5649. 76 1667.70 450.15 5959097 .92 6125.85 10 .10 144.56 5800. 65 5743. 93 1656.16 460.24 5959086 .22 6221.11 11 .66 149.90 5894. 20 5837. 48 1641.02 469.91 5959070 .93 6315.73 12 .59 155.48 5986. 71 5929. 99 1623.37 478.99 5959053 .13 6397.19 15 .44 158.28 6065. 74 6009. 02 1605.21 486.69 5959034 .85 6493.01 20 .03 155.37 6156. 98 6100. 26 1578.43 498.25 5959007 .89 6588.65 24 .63 153.96 6245. 43 6188. 71 1545.62 513.84 5958974 .83 6683.97 27 .85 155.93 6330. 92 6274. 20 1507.43 531.64 5958936 .36 6779.16 31 .19 157.04 6413. 74 6357. 02 1464.42 550.33 5958893 .06 6874.29 35 .71 159.58 6493. 10 6436. 38 1415.70 569.64 5958844 .03 6969.59 40 .58 162.26 6568. 03 6511. 31 1360.07 588.80 5958788 .11 7063.69 45 .67 161.13 6636. 69 6579. 97 1299.03 609.02 5958726 .75 7159.28 50 .48 160.76 6700. 54 6643. 82 1231.83 632.24 5958659 .19 7255.02 54 .16 160.08 6759. 05 6702. 33 1160.46 657.64 5958587 .41 ~Halliburton Company Survey Report ' Company:- ConocoPhillips Alaska Inc. Date: __ 8/4!2006 Time: 10:59:44 Pagc: 3 Field: Colville Rive r Unit Co-ordinate(NE) Reference: Well: CD4-320, True North Site: Alpine CD4 Vertic al (TVD) Re ference:' CD4-320:56.7 Well: CD4-320 Sectio n (VS) Reference: Well (O.OON,O.OOE,158.43Azi) W'ellpath: CD4-320 Survey Calttdatinn Dlethod: Minimum Curvature Dh: Oracle Survey MD Inc ! Azim TVD Sys"['VD N/5 E/W Sl~p`V 'MapE Tooi ft deg dey ft ft ft ft ft ft 7350. 46 58 .36 160. 25 6812. 05 6755 .33 1085 .82 684.56 5958512. 35 378507.20 MWD+IFR-AK-CAZ-SC I ~ 7445. 99 63 .01 158. 91 6858. 81 6802 .09 1007 .79 713.64 5958433. 87 378535.00 MWD+IFR-AK-CAZ-SC 7541. 59 67 .55 160. 68 6898. 78 6842 .06 926 .31 743.60 5958351. 92 378563.63 MWD+IFR-AK-CAZ-SC 7637. 02 72 .52 162. 89 6931. 35 6874 .63 841 .13 771.60 5958266. 31 378590.24 MWD+IFR-AK-CAZ-SC j 7732. 38 77 .19 165. 95 6956. 27 6899. 55 752. 50 796.28 5958177. 29 378613.48 MWD+IFR-AK-CAZ-SC ' 7827. 95 81 .32 165. 83 6974. 08 6917 .36 661. 45 819.17 5958085. 89 378634.88 MWD+IFR-AK-CAZ-SC 7923. 24 86 .12 167. 38 6984. 50 6927 .78 569. 34 841.10 5957993. 44 378655.31 MWD+IFR-AK-CAZ-SC 7978. 35 86 .84 166. 66 6987. 89 6931 .17 515. 74 853.45 5957939. 66 378666.79 MWD+IFR-AK-CAZ-SC i, 8018. 66 86 .42 166. 39 6990. 26 6933 .54 476. 61 862.83 5957900. 38 378675.53 MWD+IFR-AK-CAZ-SC 8078. 20 90 .29 168. 35 6991. 96 6935 .24 418. 55 875.84 5957842. 12 378687.59 MWD+IFR-AK-CAZ-SC 8113. 85 90 .93 168. 20 6991. 59 6934 .87 383. 64 883.09 5957807. 10 378694.27 MWD+IFR-AK-CAZ-SC 8150. 67 91 .06 168. 33 6990. 95 6934 .23 347 .60 890.57 5957770. 94 378701.17 MWD+IFR-AK-CAZ-SC 8219. 36 90 .96 168. 56 6989. 74 6933 .02 280 .31 904.33 5957703. 45 378713.83 MWD+IFR-AK-CAZ-SC 8313. 97 88 .01 169. 15 6990. 59 6933 .87 187 .50 922.61 5957610. 36 378730.60 MWD+IFR-AK-CAZ-SC 8408. 51 87 .53 166. 58 6994. 26. 6937 .54 95 .15 942.47 5957517. 71 378748.95 MWD+IFR-AK-CAZ-SC 8443. 48 87 .84 166. 08 6995. 68 6938 .96 61. 20 950.73 5957483. 63 378756.65 MWD+IFR-AK-CAZ-SC 8505. 58 89 .31 166. 31 6997. 22 6940. 50 0. 91 965.54 5957423. 12 378770.48 MWD+IFR-AK-CAZ-SC 8597. 53 92 .06 165. 42 6996. 12 6939 .40 -88. 24 987.99 5957333. 62 378791.48 MWD+IFR-AK-CAZ-SC 8695. 45 90 .24 165. 26 6994. 16 6937 .44 -182. 95 1012.77 5957238. 53 378814.71 MWD+IFR-AK-CAZ-SC 8791. 46 90 .55 165. 56 6993. 50 6936 .78 -275. 86 1036.95 5957145. 24 378837.38 MWD+IFR-AK-CAZ-SC 8885. 71 90 .21 164. 24 6992. 87 6936 .15 -366. 85 1061.50 5957053. 87 378860.45 MWD+IFR-AK-CAZ-SC 8981. 26 90 .34 165. 04 6992. 41 6935 .69 -458 .98 1086.81 5956961. 35 378884.25 MWD+IFR-AK-CAZ-SC 9076. 58 90 .07 164. 49 6992. 07 6935 .35 -550 .95 1111.86 5956868. 99 378907.80 MWD+IFR-AK-CAZ-SC ~ 9171. 29 89 .97 163. 68 6992. 04 6935 .32 -642 .03 1137.83 5956777. 51 378932.29 MWD+IFR-AK-CAZ-SC 9267. 50 90 .14 163. 44 6991. 95 6935 .23 -734 .31 1165.06 5956684. 81 378958.01 MWD+IFR-AK-CAZ-SC 9361. 40 90 .00 163. 29 6991. 83 6935. 11 -824. 28 1191.94 5956594. 42 378983.42 MWD+IFR-AK-CAZ-SC 9458. 14 89 .83 162. 37 6991. 97 6935. 25 -916. 71 1220.50 5956501. 55 379010.47 MWD+IFR-AK-CAZ-SC j 9553. 10 89 .96 162. 81 6992. 15 6935 .43 -1007. 32 1248.91 5956410. 50 379037.41 MWD+IFR-AK-CAZ-SC ii 9649. 16 89 .93 165. 77 6992. 24 6935 .52 -1099. 78 1274.92 5956317. 63 379061.90 MWD+IFR-AK-CAZ-SC 9743. 79 89 .62 172. 29 6992. 61 6935 .89 -1192. 63 1292.92 5956224. 51 379078.39 MWD+IFR-AK-CAZ-SC i 9838. 65 89 .83 175. 29 6993. 07 6936 .35 -1286. 92 1303.18 5956130. 07 379087.11 MWD+IFR-AK-CAZ-SC 9935. 58 90 .20 174. 65 6993. 04 6936 .32 -1383. 47 1311.67 5956033. 40 379094.04 MWD+IFR-AK-CAZ-SC 10030. 65 90 .17 173. 48 6992. 74 6936 .02 -1478. 03 1321.50 5955938. 70 379102.33 MWD+IFR-AK-CAZ-SC 10125. 55 90 .10 173. 33 6992. 51 6935 .79 -1572 .30 1332.40 5955844. 27 379111.70 MWD+IFR-AK-CAZ-SC 10221. 83 90 .00 171. 57 6992. 43 6935 .71 -1667 .75 1345.05 5955748. 65 379122.79 MWD+IFR-AK-CAZ-SC 10316. 97 89 .55 169. 91 6992. 80 6936 .08 -1761 .64 1360.36 5955654. 52 379136.57 MWD+IFR-AK-CAZ-SC 10412. 97 89 .55 166. 00 6993. 56 6936. 84 -1855. 51 1380.39 5955560. 35 379155.07 MWD+IFR-AK-CAZ-SC 10506. 89 88 .97 163. 21 6994. 77 6938. 05 -1946. 04 1405.32 5955469. 43 379178.52 MWD+IFR-AK-CAZ-SC 10602. 69 89 .14 162. 64 6996. 35 6939. 63 -2037. 60 1433.45 5955377. 43 379205.15 MWD+IFR-AK-CAZ-SC I 10698. 62 89 .89 164. 19 6997. 16 6940 .44 -2129. 54 1460.82 5955285. 07 379231.03 MWD+IFR-AK-CAZ-SC j ; 10793. 84 88 .87 168. 74 6998. 19 6941 .47 -2222. 08 1483.10 5955192. 19 379251.80 MWD+IFR-AK-CAZ-SC j 10889. 17 88 .49 170. 04 7000. 39 6943 ,67 -2315. 75 1500.65 5955098. 25 379267.82 MWD+IFR-AK-CAZ-SC 10984. 57 88 .52 170. 51 7002. 88 6946 ,16 -2409. 75 1516.76 5955004. 01 379282.40 MWD+IFR-AK-CAZ-SC 11078. 99 89 .11 170. 03 7004. 83 6948 .11 -2502 .79 1532.71 5954910. 73 379296.84 MWD+IFR-AK-CAZ-SC 11172. 92 89 .69 169. 81 7005. 81 6949 .09 -2595 .27 1549.15 5954818. 01 379311.77 MWD+IFR-AK-CAZ-SC I !, 11269. 58 90 .82 171. 80 7005. 38 6948 .66 -2690 .68 1564.60 5954722. 37 379325.66 MWD+IFR-AK-CAZ-SC 11364. 87 92 .16 171. 12 7002. 91 6946 .19 -2784 .88 1578.74 5954627. 96 379338.27 MWD+IFR-AK-CAZ-SC 11459. 70 91. 61 170. 28 6999. 79 6943. 07 -2878. 41 1594.06 5954534. 20 379352.07 i MWD+IFR-AK-CAZ-SC 11553. 39 90 .34 169. 31 6998. 19 6941 .47 -2970. 60 1610.66 5954441. 76 379367.16 MWD+IFR-AK-CAZ-SC 11649. 59 88 .42 167. 25 6999. 23 6942 .51 -3064. 78 1630.19 5954347. 28 379385.16 MWD+IFR-AK-CAZ-SC 11745. 75 88 .66 166. 82 7001. 68 6944 .96 -3158. 46 1651.76 5954253. 27 379405 20 MWD+IFR-AK-CAZ-SC 11842. 46 89 .62 167. 30 7003. 13 6946 .41 -3252. 70 1673.41 5954158. 70 - 379425.32 MWD+IFR-AK-CAZ-SC ,~ Halliburton Company Survey Report Company: ConocoPhillipsAlaska Inc. Date: 8/4/2006 Tine: 10:59:44 Yag_e: 4 Field: Colville River Unit Co-ordioate(NE~ Reference: Well: CD4-320, True North Site: Alpine CD4 Vertical (TVD) Reference: CD4-320:56.7 Well: CD4-320 Sec6oif (VS) Reference: Well (O.OON,O.OOE,158.43Azi) Wellpeth: C04-320 Survey Calculation rilethc,~i: Minimum Curvature Db: Oracle Survey hID lncl ~1zim T~`D Se's"CVD ft deg deg ft ft 11938.24 89.52 166.14 7003. 85 6947.13 12033.90 89.41 164.31 7004. 75 6948.03 12128.62 89.96 163.92 7005. 27 6948.55 12223.25 90.61 166.65 7004. 80 6948.08 12317.82 90.10 167.40 7004. 21 6947.49 12413.91 89.55 165.27 7004. 50 6947.78 12509.44 89.52 164.22 7005. 28 6948.56 12604.47 89.93 164.68 7005. 74 6949.02 12700.20 89.69 164.48 7006. 05 6949.33 12795.56 90.03 163.19 7006. 29 6949.57 12889.44 89.93 162.90 7006. 32 6949.60 12984.56 90.17 164.06 7006. 24 6949.52 13079.07 89.86 165.41 7006. 21 6949.49 13176.24 89.79 167.79 7006. 51 6949 .79 13270.58 89.89 169.15 7006. 77 6950 .05 13366.51 90.85 172.40 7006. 15 6949 .43 13460.25 89.69 173.42 7005. 71 6948 .99 13556.88 89.59 172.29 7006. 32 6949. 60 13652.63 89.11 174.11 7007. 40 6950 .68 13692.80 89.21 173.83 7007. 99 6951 .27 13747.54 89.17 173.84 7008. 77 6952 .05 13842.23 88.90 174.88 7010. 36 6953 .64 13938.37 89.48 175.84 7011. 72 6955 .00 14032.20 87.22 174.90 7014. 42 6957 .70 14126.10 90.65 173.11 7016. 17 6959 .45 14221.91 90.51 171.38 7015. 20 6958 .48 14316.36 89.52 168.10 7015. 17 6958 .45 14409.61 88.18 167.97 7017. 04 6960 .32 14471.00 88.18 167.97 7018. 99. 6962 .27 N/S F!~~~ _MapN MapE Tool......... ft ft ft ft -3345. 91 1695. 41 5954065.15 379445. 80 MWD+IFR-AK-CAZ-SC -3438. 40 1719. 81 5953972.28 379468. 69 MWD+IFR-AK-CAZ-SC -3529. 50 1745. 73 5953880.78 379493. 13 MWD+IFR-AK-CAZ-SC -3621. 02 1769. 77 5953788.89 379515. 67 I MWD+IFR-AK-CAZ-SC -3713. 17 1791. 00 5953696.41 379535. 40 MWD+IFR-AK-CAZ-SC -3806. 54 1813. 70 5953602.70 379556. 57 MWD+IFR-AK-CAZ-SC -3898 .70 1838. 83 5953510.15 379580. 21 MWD+IFR-AK-CAZ-SC -3990 .25 1864. 31 5953418.21 379604. 19 MWD+IFR-AK-CAZ-SC -4082. 53 1889. 76 5953325.53 379628, 13 MWD+IFR-AK-CAZ-SC -4174. 12 1916. 31 5953233.53 379653. 19 MWD+IFR-AK-CAZ-SC -4263. 92 1943. 69 5953143.31 379679. 10 MWD+IFR-AK-CAZ-SC -4355. 11 1970. 73 5953051.69 379704. 66 MWD+IFR-AK-CAZ-SC -4446. 28 1995. 62 5952960.14 379728. 05 MWD+IFR-AK-CAZ-SC i -4540. 80 2018. 13 5952865.27 379749. 03 MWD+IFR-AK-CAZ-SC -4633 .23 2036. 99 5952772.55 379766. 38 MWD+IFR-AK-CAZ-SC -4727 .91 2052. 37 5952677.65 379780. 21 MWD+IFR-AK-CAZ-SC -4820 .93 2063. 94 5952584.46 379790. 27 MWD+IFR-AK-CAZ-SC -4916. 80 2075. 95 5952488.41 379800. 73 MWD+IFR-AK-CAZ-SC -5011. 87 2087. 29 5952393.18 379810. 52 MWD+IFR-AK-CAZ-SC -5051. 81 2091. 51 5952353.18 379814. 09 MWD+IFR-AK-CAZ-SC ~ -5106. 23 2097. 39 5952298.68 379819. 08 MWD+IFR-AK-CAZ-SC -5200. 45 2106. 69 5952204.33 379826. 85 MWD+IFR-AK-CAZ-SC -5296. 26 2114. 47 5952108.41 379833. 07 MWD+IFR-AK-CAZ-SC -5389 .74 2122. 04 5952014.83 379839. 11 MWD+IFR-AK-CAZ-SC -5483 .09 2131. 84 5951921.34 379847. 40 MWD+IFR-AK-CAZ-SC -5578. 02 2144. 77 5951826.22 379858. 78 MWD+IFR-AK-CAZ-SC -5670. 94 2161. 59 5951733.04 379874. 09 MWD+IFR-AK-CAZ-SC -5762. 14 2180. 92 5951641.54 379891. 93 MWD+IFR-AK-CAZ-SC -5822. 16 2193. 71 5951581.34 379903. 74 • PROJECTED to TD Halliburton Company Survey Report Company: ConoCOPhillipsAlaska Inc. __ Date: 8!4/2006 `l'ime: 1'0:18:04 1'a~~c: 1 Field: Colville RiverUnit Co -ordinate(NE) Reference: Welh CD4-320, True North Site: Alpine CD4 Ve rtical (TVD) Re ference: CD4-320:56.7 ~i'ell: CD4-320 Section (dS) Refer ence: Well (O.OON,O.OOE,62.76Azi) Wcllpath: CD4-320P81 Sn rvey Calculatio n Method: Minimum Curvature Db: Oracle r Field: Colville River Unit 'I North Slope Alaska United States Map System:US State Plane Coordin ate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Well: CD4-320 Slot Name: Alpine CD4 Well Position: +N/-S -94.19 ft Northing: 5957437.90 ft Latitude: 70 17 32.039 N +E/-W -368.12 ft Easti ng : 377805.14 ft Longitude: 150 59 21.491 W ! Position Uncertainty: 0.00 ft --- Wellpath: CD4-320PB1 Drilled From: Well Ref. Point 501032053170 Tie-on Depth: 37.02 ft Current Datum: CD4-320: Height 56.72 ft Above System Datum: Mean Sea Level Magnetic Data: 7/19/2006 Declination: 23.27 deg Field Strength: 57501 nT Mag Dip Angl e: 80.63 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 37.02 0.00 0.00 62.76 ~ Survey Program for Definitive Wellpath Date: 5/24/2005 Validated: No Version: 4 I Actual From To Survey Toolcode Tool Name ft ft 81.50 802.00 CD4-320PB1 gyro (81.50-802.00) CB-GYRO-SS Camera based gyro sin gle shot 889.55 7985.74 CD4-320P61 (889.55-7985.74) I' --- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey ___ _ __ SID Intl Azim '1'Vll Sys"I'VD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft __ _ ft ft _ -- ____- 37.02 0.00 0.00 37.02 -19.70 0.00 0.00 5957437.90 377805.14 TIE LINE 81.50 0.50 114.00 81.50 24.78 -0.08 0.18 5957437.81 377805.31 CB-GYRO-SS ~ I 171.00 0.65 114.00 170.99 114.27 -0.44 1.00 5957437.44 377806.13 CB-GYRO-SS 261.00 1.00 345.00 260.99 204.27 0.11 1.26 5957437.98 377806.40 CB-GYRO-SS 351.00 4.70 320.00 350.87 294.15 3.69 -1.31 5957441.61 377803.88 CB-GYRO-SS 441.00 5.00 322.00 440.54 383.82 9.61 -6.10 5957447.60 377799.19 CB-GYRO-SS 532.00 5.90 322.00 531.13 474.41 16.42 -11.42 5957454.50 377793.99 CB-GYRO-SS 622.00 7.80 321.00 620.48 563.76 24.81 -18.11 5957462.99 377787.43 CB-GYRO-SS 712.00 9.00 324.00 709.52 652.80 35.25 -26.09 5957473.56 377779.62 CB-GYRO-SS 802.00 12.40 338.00 797.95 741.23 49.91 -33.85 5957488.35 377772.10 CB-GYRO-SS 889.55 15.75 346.06 882.87 826.15 70.17 -40.24 5957508.70 377766.04 MWD+IFR-AK-CAZ-SC j 934.24 17.65 350.84 925.68 868.96 82.74 -42.78 5957521.32 377763.71 MWD+IFR-AK-CAZ-SC 1029.04 21.03 357.43 1015.13 958.41 113.94 -45.83 5957552.56 377761.16 MWD+IFR-AK-CAZ-SC i 1123.86 20.71 0.66 1103.73 1047.01 147.70 -46.40 5957586.32 377761.14 MWD+IFR-AK-CAZ-SC 1219.21 22.59 10.55 1192.38 1135.66 182.58 -42.85 5957621.13 377765.26 MWD+IFR-AK-CAZ-SC 1314.87 22.01 16.36 1280.89 1224.17 217.85 -34.44 5957656.25 377774.24 MWD+IFR-AK-CAZ-SC 1410.72 22.86 17.66 1369.49 1312.77 252.82 -23.73 5957691.05 377785.52 MWD+IFR-AK-CAZ-SC ~ '~ 1504.35 22.68 19.85 1455.82 1399.10 287.13 -12.08 5957725.16 377797.72 MWD+IFR-AK-CAZ-SC ~~ 1599.49 21.27 13.71 1544.06 1487,34 321.15 -1.76 5957759.01 377808.59 MWD+IFR-AK-CAZ-SC ~~ 1694.79 22.26 13.31 1632.57 1575.85 355.51 6.49 5957793.23 377817.40 MWD+IFR-AK-CAZ-SC ~i 1789.60 23.21 13.89 1720.01 1663.29 391.12 15.11 5957828.69 377826.60 MWD+IFR-AK-CAZ-SC 1884.88 21.78 19.37 1808.05 1751.33 426.03 25.48 5957863.42 377837.53 MWD+IFR-AK-CAZ-SC 1980.19 21.95 19.78 1896.50 1839.78 459.48 37.37 5957896.67 377849.97 MWD+IFR-AK-CAZ-SC 2075.26 23.43 17.01 1984.21 1927.49 494.27 48.92 5957931.27 377862.07 MWD+IFR-AK-CAZ-SC it ~ 2170.66 24.35 15.38 2071.44 2014.72 531.37 59.68 5957968.19 377873.44 MWD+IFR-AK-CAZ-SC i 2263.92 24.94 16.54 2156.20 2099.48 568.76 70.38 5958005.39 377884.74 MWD+IFR-AK-CAZ-SC '~ 2361.85 24.76 15.13 2245.07 2188.35 608.35 81.61 5958044.79 377896.61 MWD+IFR-AK-CAZ-SC 2457.26 25.28 15.39 2331.52 2274.80 647.28 92.23 5958083.54 377907.87 MWD+IFR-AK-CAZ-SC 2530.65 25.51 15.71 2397.82 2341.10 677.60 100.67 5958113.72 377916.79 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report __ Company: ConocoPhillips AlasEca lnc. Date: 3/412006 Time: 10.1804 Pale: Rield: Colville River Unit (~o-or dinatc(NF.) Reference: Well: CD4-320, True North Site: Alpine CD4 ~~crtical (ll'D) Reference; CD4-320 - 56- We1L• CD4-320 Section (VS) Reference: WeII (0-OON,O OOE,62.76Azi) ' ~i~ellpath: CD4-320PB1 Surve y Calculatio n Method: Minirnurt~ Curv ature llb: Oracle Survey 1ID Intl lzim TtiD Sys TVD NiS __ E/1~' R1apN _. 111apE Tool ' ', ft deg de g ft ft ft ft ft ft 2604.03 25.74 15 .66 2463 .98 2407. 26 708 .15 109.25 5958144 .12 377925.87 MWD+IFR-AK-CAZ-SC 2695.06 25.37 15 .92 2546 .11 2489. 39 745 .94 119.93 5958181 .73 377937.16 MWD+IFR-AK-CAZ-SC ~ 2790.06 24.29 16 .02 2632 .33 2575. 61 784 .29 130.91 5958219 .89 377948.76 MWD+IFR-AK-CAZ-SC 2884.96 23.42 16 .88 2719 .12 2662. 40 821 .10 141.77 5958256 .52 377960.22 MWD+IFR-AK-CAZ-SC 2980.13 22.99 16 .43 2806 .59 2749. 87 857 .03 152.52 5958292 .26 377971.55 MWD+IFR-AK-CAZ-SC 3075.49 22.28 17 .16 2894 .60 2837. 88 892 .16 163.12 5958327 .22 377982.72 MWD+IFR-AK-CAZ-SC 3170.58 21.47 17 .48 2982 .85 2926. 13 925 .99 173.66 5958360 .86 377993.81 MWD+IFR-AK-CAZ-SC 3265.57 21.32 18 .57 3071. 29 3014. 57 958 .94 184.39 5958393 .63 378005.07 MWD+IFR-AK-CAZ-SC 3360.98 20.88 19 .00 3160. 30 3103. 58 991 .45 195.44 5958425 .96 378016.65 MWD+IFR-AK-CAZ-SC 3456.12 20.44 18 .84 3249. 32 3192. 60 1023 .21 206.33 5958457 .53 378028.05 MWD+IFR-AK-CAZ-SC 3551.52 19.65 18 .86 3338. 94 3282. 22 1054 .15 216.89 5958488 .30 378039.12 MWD+IFR-AK-CAZ-SC 3646.49 18.85 18 .92 3428 .60 3371. 88 1083 .78 227.03 5958517 .75 378049.73 MWD+IFR-AK-CAZ-SC 3741.76 18.99 18 .39 3518 .73 3462. 01 1113 .05 236.91 5958546 .85 378060.09 MWD+IFR-AK-CAZ-SC 3837.42 19.18 19 .53 3609 .13 3552. 41 1142 .62 247.07 5958576 .26 378070.73 MWD+IFR-AK-CAZ-SC ~ 3932.68 18.10 20 .56 3699 .39 3642. 67 1171 .23 257.50 5958604 .69 378081.62 MWD+IFR-AK-CAZ-SC 4027.66 16.78 21 .08 3790 .00 3733. 28 1197 .84 267.62 5958631 .12 378092.16 MWD+IFR-AK-CAZ-SC 4124.41 16.53 20 .55 3882. 69 3825. 97 1223 .76 277.47 5958656 .88 378102.44 MWD+IFR-AK-CAZ-SC ~~ 4219.55 17.03 21 .83 3973. 78 3917. 06 1249 .36 287.40 5958682 .32 378112.78 MWD+IFR-AK-CAZ-SC 4313.09 17.84 22 .48 4063. 03 4006. 31 1275 .32 297.97 5958708 .10 378123.77 MWD+IFR-AK-CAZ-SC 4410.19 16.86 24 .05 4155. 71 4098. 99 1301 .92 309.40 5958734 .51 378135.63 MWD+IFR-AK-CAZ-SC 4505.03 17.88 24 .73 4246. 22 4189. 50 1327 .70 321.10 5958760 .10 378147.74 MWD+IFR-AK-CAZ-SC 4600.93 19.11 21 .97 4337 .17 4280. 45 1355 .64 333.13 5958787 .83 378160.23 MWD+IFR-AK-CAZ-SC 4695.73 20.63 21 .64 4426. 32 4369. 60 1385 .55 345.09 5958817 .54 378172.67 MWD+IFR-AK-CAZ-SC ~ 4791.06 21.83 19 .47 4515 .18 4458. 46 1417 .87 357.20 5958849 .66 378185.30 MWD+IFR-AK-CAZ-SC 4886.73 22.33 18 .35 4603 .84 4547. 12 1451 .90 368.85 5958883 .48 378197.50 MWD+IFR-AK-CAZ-SC 4983.02 22.07 19 .15 4692. 99 4636. 27 1486 .35 380.54 5958917 .74 378209.75 MWD+IFR-AK-CAZ-SC ~ I 5078.04 20.68 19 .87 4781. 47 4724. 75 1518 .99 392.10 5958950 .19 378221.84 MWD+IFR-AK-CAZ-SC '; 5172.04 19.55 21 .89 4869. 74 4813. 02 1549 .20 403.60 5958980 .20 378233.83 MWD+IFR-AK-CAZ-SC 5267.50 17.89 24 .50 4960. 14 4903. 42 1577 .36 415.64 5959008 .16 378246.32 MWD+IFR-AK-CAZ-SC ', 5362.73 15.94 27 .63 5051. 25 4994. 53 1602 .26 427.77 5959032 .86 378258.86 MWD+IFR-AK-CAZ-SC 5458.02 14.04 33 .62 5143. 30 5086. 58 1623 .48 440.24 5959053 .87 378271.67 MWD+IFR-AK-CAZ-SC 5553.48 12.54 39 .97 5236. 21 5179. 49 1641 .07 453.31 5959071 .24 378285.02 MWD+IFR-AK-CAZ-SC 5648.92 11.65 49 .34 5329. 54 5272. 82 1655 .29 467.28 5959085 .23 378299.22 MWD+IFR-AK-CAZ-SC 5744.41 10.54 59 .14 5423. 25 5366. 53 1666 .05 482.09 5959095 .75 378314.20 MWD+IFR-AK-CAZ-SC 5840.02 9.63 67 .34 5517. 38 5460. 66 1673 .62 496.98 5959103 .08 378329,21 MWD+IFR-AK-CAZ-SC 5934.49 8.40 74 .82 5610. 69 5553. 97 1678 .47 510.93 5959107 .70 378343,24 MWD+IFR-AK-CAZ-SC I 6016.21 8.39 91 .30 5691. 55 5634. 83 1679 .90 522.65 5959108 .94 378354.98 MWD+IFR-AK-CAZ-SC 6111.78 11.23 110 .33 5785. 73 5729. 01 1676 .50 538.36 5959105 .29 378370.63 MWD+IFR-AK-CAZ-SC ', 6207.09 13.05 122 .37 5878. 92 5822. 20 1667 .52 556.15 5959096 .01 378388.27 MWD+IFR-AK-CAZ-SC 6302.38 15.88 135 .41 5971. 21 5914. 49 1652 .47 574.40 5959080 .67 378406.27 MWD+IFR-AK-CAZ-SC 6397.69 19.70 138 .82 6061. 94 6005. 22 1631 .08 594.14 5959058 .97 378425.66 MWD+IFR-AK-CAZ-SC 6493.62 23.83 140 .30 6151. 02 6094. 30 1603 .99 617.17 5959031 .51 378448.25 MWD+IFR-AK-CAZ-SC 6589.26 28.28 144. 75 6236. 92 6180. 20 1570 .60 642.61 5958997 .71 378473.13 MWD+IFR-AK-CAZ-SC 6684.52 29.90 150. 03 6320. 18 6263. 46 1531 .60 667.50 5958958 .31 378497.38 MWD+IFR-AK-CAZ-SC 6779.00 32.16 156. 02 6401. 15 6344. 43 1488 .20 689.49 5958914 .57 378518.66 MWD+IFR-AK-CAZ-SC 6874.24 35.09 157. 37 6480. 45 6423. 73 1439 .77 710.33 5958865 .81 378538.71 MWD+IFR-AK-CAZ-SC 6969.63 38.11 160. 76 6557. 03 6500. 31 1386 .65 730.59 5958812 .37 378558.10 MWD+IFR-AK-CAZ-SC '; 7064.73 43.03 163. 86 6629. 25 6572. 53 1327 .73 749.29 5958753 .16 378575.84 MWD+IFR-AK-CAZ-SC 'I 7159.44 48.48 165 .64 6695. 31 6638. 59 1262 .29 767.08 5958687 .45 378592.57 MWD+IFR-AK-CAZ-SC ~, 7254.88 53.28 164 .19 6755. 52 6698. 80 1190 .83 786.37 5958615 .69 378610.70 MWD+IFR-AK-CAZ-SC ' 7350.21 57.59 164 .15 6809. 59 6752. 87 1115 .32 807.78 5958539 .85 378630.87 MWD+IFR-AK-CAZ-SC 7445.46 ~_, 62.88 164. 21 6856. 86 6800. 14 1035 .80 830.32 5958459 .98 378652.11 ---- MWD+IFR-AK-CAZ-SC - Halliburton Company Survey Report Company: ConocoPhillipsAlaska Inc. ~ Field: Colville River Unit Site: Alpine CD4 Wetl: CD4-320 1Vellpath: C04-320PB1 Survcv ~ID lncl Azim T~ I) SvsT'Vil ', ft deg deg ft ft ', ~ 7540. 62 67.30 163.24 6896. 93 6840.21 I, 7636. 17 70.74 163.43 6931. 13 6874.41 7731. 15 75.96 164.23 6958. 34 6901.62 I~ 7826. 82 82.40 164.31 6976. 29 6919.57 ~, 7875. 04 83.99 165.05 6982. 00 6925.28 7921. 91 84.04 164.51 6986. 89 6930.17 7985. 74 87.40 165.14 6991. 65 6934.93 8019. 00 87.40 165.14 6993. 16 __ _ 6936.44 Date: 8/4/2006 lime: 10:18:04 I'~rhe: 3 Co-ordinate(NE) Reference. Well`. CD4-320, True Narth Vertical (TVD) Reference: CD4-320:56.7 Section (VS) Reference: Well (O.OON,O.OOE,62.76Azi) Survey Cateulafion titethod: Minimum Curvature llb: Oracle N!S E/~V - 1~IapN ft ft ft 952 .98 854.51 5958376. 78 867 .52 880.09 5958290. 92 780 .15 905.41 5958203. 16 689 .75 930.87 5958112. 37 643 .57 943.52 5958065 .99 598 .59 955.76 5958020 .82 537 .17 972.42 5957959. 14 505 .05 980.94 5957926. 90 I19apE Tool.. ft 378674.95 MWD+IFR-AK-CAZ-SC 378699.13 MWD+IFR-AK-CAZ-SC 378723.03 MWD+IFR-AK-CAZ-SC 378747.02 MWD+IFR-AK-CAZ-SC 378758.92 MWD+IFR-AK-CAZ-SC 378770.42 MWD+IFR-AK-CAZ-SC 378786.08 MWD+IFR-AK-CAZ-SC 378794.07 PROJECTED to TD Conoc Phili s Time Lo Summa ~~~~~~ ~eU~ 4~~~,n~ 9 rY Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM 06/30/2006 14:00 18:00 4.00 MIRU MOVE MOB P Move pipe shed -motors & pits -skid back floor -remove cellar walls -move ri 18:00 22:00 4.00 MIRU MOVE PSIT P Move sub over well - set sub feet - jackfloor to drilling position -Spot pits, motors & pipe shed -Hook up service lines - Bring on spud mud -Accept rig 2100 hrs. 22:00 00:00 2.00 MIRU DRILL RURD P NU surface riser ,turnbuckles -drain lines 07/01/2006 00:00 01:00 1.00 0 0 SURFA DRILL PULD P Rig up -Move BHA components to rig floor 01:00 02:00 1.00 0 0 SURFA DRILL OTHR P MU 12 1/4" Bit, bs, xo and 1 stand of hwd 02:00 02:15 0.25 0 0 SURFA DRILL SFTY P Held PreSpud Meeting with Rig Team 02:15 03:00 0.75 0 0 SURFA DRILL OTHR P RIH with 12 1/4" Bit to 97' -cleared ice from Conducter -POOH Lay down tools 03:00 04:00 1.00 0 0 SURFA DRILL PULD P PU two 8" flex collars and drilling jars and stand back in derrick 04:00 06:30 2.50 0 0 SURFA DRILL PULD P MU BHA #1: Bit, motor, mwd, stab, ubho sub -initialize tools -scribe ubho MU 8" felx collars 06:30 07:30 1.00 0 114 SURFA DRILL OTHR P RIH tag at 114' -fill hole and check for leaks -pressure test standipe to 3500 si 07:30 12:00 4.50 114 445 SURFA DRILL DDRL P Spud well at 0730 hrs - Drill 12 1/4" hole f/ 114' to 445' MD 445' TVD _ ADT - 1.86 hrs =ART - 1.27 hrs AST - 0.59 hrs WOB 12/17 RPM 50 GPM 450 @ 1000 psi String wt. PU 100 SO 100 Rot 100 Torque on/off btm. - 4000/3000 ft/Ibs Surve in with G ro 12:00 00:00 12.00 445 1,430 SURFA DRILL DDRL P Drill 12 1/4" hole f/ 445' to 1430' MD 1364' TVD ADT - 6.96 hrs = AST - 4.04 hrs ART - 2.92 hrs. WOB 10/20 K RPM 50 GPM 550 @ 1470 psi String wt. PU 115 SO 115 Rot 120 Tor ue on/off btm. - 4500/4500 ft. lbs. - - _...e.A~ _ P~ ~ ~rf .~3~ Time Logs Date From To Dur S. th E. De th Phase Code Subcode T M 07/02/2006 00:00 12:00 12.00 1,430 2,296 SURFA DRILL DDRL _ P Drill 12 1/4" hole f/ 1,430' to 2,296' MD 2,186' TVD ADT - 8.68 hrs = AST - 0.82 hrs ART - 7.89 hrs. WOB 15/20 K RPM 50 GPM 600 @ 2030 psi String wt. PU 140 SO 125 Rot 135 Tor ue on/off btm. - 7000/6000 ft. lbs. 12:00 17:00 5.00 2,296 2,519 SURFA DRILL DDRL P Drill 12 1/4" hole f/ 2,296' to 2,519' MD 2387' TVD ADT - 3.88 hrs = AST - 0.71 hrs ART - 3.17 hrs. WOB 15/25 K RPM 50 GPM 645 @ 2290 psi String wt. PU 145 SO 130 Rot 140 Tor ue on/off btm. - 7000/6000 ft. lbs. 17:00 17:45 0.75 2,519 2,519 SURFA DRILL CIRC P Circ hole clean for wiper trip 17:45 22:00 4.25 2,519 2,519 SURFA DRILL TRIP P Wiper trip w/ pump f/ 2519' to 891' - Pumping @ 650 to 450 GPM - 50 rpm - Hole took good fill -Monitor well @ 891' (static) RIH to TD -Hole in good condition 22:00 00:00 2.00 2,519 2,459 SURFA DRILL CIRC P Break circ &Circ hole clean -Monitor well (static) -fill TT - LD 2 singles - Blow Bowe TD -Pre to POOH on TT 07/03/2006 00:00 02:45 2.75 2,459 73 SURFA DRILL TRIP P POOH on TT from 2,459' to 891' -flow ckeck well -static POOH to 73' -stood back hwdp and collars 02:45 05:00 2.25 73 0 SURFA DRILL PULD P Down load MWD - LD MWD collars - XO -stab -float sub -motor and bit - cleartools from ri floor. 05:00 07:30 2.50 0 0 SURFA CASINC RURD P Rig up to run casing: Lay down drilling bails - MU fill up tool -pick up casing bails - RU 9 5/8" slips ,elevators and ower ton s -read stabbin board 07:30 07:45 0.25 0 0 SURFA CASIN( SFTY P Held Prejob safety and Opts meeting with crew 07:45 11:15 3.50 0 1,735 SURFA CASIN( RNCS P Run 9 5/8" 40# L-80 MBTC csg as follows: Float shoe (Ray Oil Tools silver bullet) 2 jts csg -Float collar (Weatherford) 2 jts. csg (first 4 connections made up w/ BakerLoc - filled pipe & checked floats) 41 jts csg to 1735' (washed down from 510' to 540', ti ht s of at 525' 11:15 11:30 0.25 1,735 1,735 SURFA CASIN( CIRC P Stage pumps up to 5.5 bpm - CBU - FCP 320 si - PUW 132K SOW 120K 11:30 13:00 1.50 1,735 2,465 SURFA CASIN( RNCS P Continue running 9 5/8" - 40# L-80 MBTC csg f/ 1735' to 2465' - 19 jts (64 jts total ran) - PU FMC csg hanger & landing jt. -Land csg w/fluted mandle hanger on landing ring w/ float shoe @ 2509' & float collar 2429' 13:00 13:30 0.50 2,465 2,509 SURFA CEMEf~ PULD P LD Frank's fill up tool -Blow down TD - MU cmt head & lines ~~ s ~~ _ ~~e oaf °f #3 Time Logs Date From To Dur S. th E. De th Phase Code Subcode T M 07/03/2006 13:30 15:15 1.75 2,509 2,509 SURFA CEMEP CIRC P Establish circulation -Stage pump up to 7.0 bbl/min -Circulate & condition hole & mud for cmt job - ICP 360 psi FCP 310 psi (circulated 810 bbls) PJSM 15:15 17:45 2.50 2,509 2,509 SURFA CEMEI~ DISP P Cement 9 5/8" csg as follows Pumped 40 bbls Biozan water w/ nut plug as marker -Pumped 5 bbls water w/ Dowell -Tested lines to 2600 psi - Dropped btm plug - Pumped 50 bbls MudPush @ 10.5 ppg -Mixed & pumped 272 bbls lead slurry (ASL) @ 10.7 ppg (' Observed nut plug marker @ shakers w/ 253 bbls lead pumped - pumped down surge can) Pumped 48 bbls tail slurry (Class G w/ additives) @ 15.8 ppg -Dropped top plug w/ 20 bbls water f/ Dowell -Switched over to rig pumps & displaced cmt w/ 163.4 bbls 9.8 ppg water base mud - Displaced @ 8.1 bbls/min for first 120 bbls -slowed pump to 6.0 bbls/min for 25 bbls - 4.0 bbls/min for last 8.4 bbls - Bumped plug w/ 1100 psi (prep bump pressure 590 psi) Check float (held OK) CIP @ 17:40 hrs. -Full circulation throughout job w/ 94 bbls 10.7 ppg cmt returns to surface -reciprocated pipe while circulating & through cement job until last 90 bbls of dis lacement 17:45 18:30 0.75 0 0 SURFA CEME~ PRTS P Rig up & test 9 5/8" casing to 2500 si for 30 mins. -Blow down lines - RD 18:30 19:30 1.00 0 0 SURFA CEME~ PULD P RD cmt head - LD landing jt -clear rig floor of tools 19:30 21:30 2.00 0 0 SURFA DRILL PULD P LD surface riser -Remove FMC startin head 21:30 00:00 2.50 0 0 SURFA DRILL OTHR P Install FMC Alpine Gen II wellhead & test seals to 1000 si - NU BOPE 07/04/2006 00:00 00:30 0.50 0 0 SURFA WELCT NUND P Finish NU ROPE. riser and flowline 00:30 01:30 1.00 0 0 SURFA DRILL OTHR P Change out saver sub on top drive to 4" XT 01:30 09:00 7.50 0 0 SURFA WELCT BOPE P PJSM -Install test plug -fill stack with water -Test BOPE - Hydrill to 250 & 3500 psi -Test pipe and blind rams, kill & choke lines, choke manifold and floor safety valves to 250 & 5000 psi - ull test lu and install wear bushin 09:00 10:00 1.00 0 0 SURFA DRILL OTHR P PU drilling bails & 4" elevators - PU Geo-S an to ri floor 10:00 13:30 3.50 0 260 SURFA DRILL PULD P MU 8 3/4" BHA -Bit - GeoPilot - MWD- PU NM flex DC's - Up load MWD - RIH to 260' -Pressure test Geo Span skid to 3500 psi -shallow test tools ~~~ 3 ref 1II Time Los Date From To Dur S. th E. De 'th Phase Code Subcode T M _ 07/04/2006 13:30 15:30 2.00 260 2,340 SURFA DRILL TRIP P RIH w/ HWDP & 5" DP f/ 250' to 1870' (PU 8 3/4" ghost reamers) Change running tools to 4" and RIH with 4" drill i e to 2340' 15:30 15:45 0.25 2,340 2,340 SURFA RIGMN SFTY P PJSM -Cut & Slip drilling line 15:45 17:30 1.75 2,340 2,340 SURFA RIGMN SLPC P Cut and slip drilling line -service Top Drive 17:30 22:45 5.25 2,340 2,519 SURFA CEMEI~ DRLG P Washed down and tagged cement @ 2426'. Cleaned out shoe track and rat hole to 2519'. 22:45 23:00 0.25 2,519 2,539 SURFA DRILL DDRL P Drilled 8.75" hole from 2519' to 2539'. ADT .25 hrs. TVD 2405'. 23:00 23:15 0.25 2,539 2,539 SURFA DRILL CIRC P CBU. 23:15 00:00 0.75 2,539 2,539 SURFA DRILL FIT P Rigged up and performed LOT to 17.1 PPG EMW. 07/05/2006 00:00 12:00 12.00 2,539 3,868 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/GP f/ 2539' to 3868' MD 3625' TVD ADT - 7.6 hrs. ECD - 10.9 ppg WOB 10/15 RPM 130 GPM 595 @ 1960 psi String wt. PU 165 SO 125 Rot 145 Tor ue on/off btm. - 8000/7000 ft/Ibs. 12:00 00:00 12.00 3,868 5,188 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/GP f/ 3868' to 5188' MD 4898' TVD ADT - 7.8 hrs. ECD - 10.6 ppg WOB 15/20 RPM 170 GPM 588 @ 2430 psi String wt. PU 195 SO 145 Rot 165 Tor ue on/off btm. - 10000/8500 ft/Ibs. 07/06/2006 00:00 06:00 6.00 5,188 5,965 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/GP f/ 5,188' to 5,965' MD 5,641' TVD ADT - 4.1 hrs. ECD - 10.6 ppg WOB 18/25 RPM 100-170 GPM 500 @ 1870 psi String wt. PU 205 SO 150 Rot 180 Tor ue on/off btm. - 11000/9000 ft/Ibs. 06:00 07:00 1.00 5,965 5,774 INTRM1 DRILL CIRC NP Unable to obtain dogleg required - Circ and condition mud - 600 gpm / 2780 psi / 130 rpm Set back two stands to 5774' -Flow check well, static 07:00 08:00 1.00 5,774 5,297 INTRM1 DRILL TRIP NP POOH from 5774' to 5297' - 550 gpm / 2350 si / 110 r m 08:00 09:45 1.75 5,297 4,344 INTRM1 DRILL TRIP NP Flow check well, static -POOH on trip tank from 5297' to 4344' -pump dry job - blow down to drive 09:45 13:30 3.75 4,344 78 INTRM1 DRILL TRIP NP POOH from 4344' to 1872' -change running tools to 5" -POOH - (LD ghost reamers) set back hwdp and flex collars -Flow checked well at shoe and hwd ,static 13:30 15:15 1.75 78 0 INTRM1 DRILL PULD NP Down load LWD - LD FS, pony flex, GeoPilot and bit -clear tools from rig floor a ~®~~~~ ~~ or '~ ~~ Time Lo s Date From To Dur S. th E. De th Phase Code Subcode T M 07/06/2006 15:15 18:30 3.25 0 _ 263 INTRM1 DRILL PULD NP Picked up Motor BHA. Uploaded MWD. RIH to 263' and tested MWD. 18:30 21:45 3.25 263 5,858 INTRM1 DRILL TRIP NP RIH filling pipe every 20 stands from 263' to 5858'. 21:45 22:15 0.50 5,858 5,965 INTRM1 DRILL REAM NP Broke circulation and precautionary washed from 5858' to 5965'. 22:15 00:00 1.75 5,965 6,010 INTRM1 DRILL DDRL P Driil 8 3/4" hole w/MM f/ 5,965' to 6,010' MD 5,679' TVD ADT - .94 hrs. ART 0 hrs AST .94 hrs. ECD - 10.6 ppg WOB 18/25 RPM 100-170 GPM 500 @ 1870 psi String wt. PU 210 SO 160 Rot 180 Tor ue on/off btm. - Slidin ft/Ibs. 07/07/2006 00:00 12:00 12.00 6,010 6,430 INTRM1 DRILL DDRL P Driil 8 3/4" hole w/MM f/ 6,010' to 6,430' MD 6,092' TVD ADT - 8.76 hrs. ART 1.72 hrs AST 7.04 hrs. ECD - 10.15 ppg WOB 8/12 RPM 70-80 GPM 600 @ 2630 psi String wt. PU 215 SO 160 Rot 185 Tor ue on/off btm. - 8500/7000 ft/Ibs. 12:00 00:00 12.00 6,430 6,907 INTRM1 DRILL DDRL P Driil 8 3/4" hole w/MM f/ 6,430' to 6,907 MD 6,507 TVD ADT - 8.84- hrs. ART 1.57 hrs AST 7.29 hrs. ECD - 10.2 ppg WOB 8/12 RPM 70-80 GPM 600 @ 2630 psi String wt. PU 200 SO 175 Rot 188 Tor ue on/off btm. - 8000/7000 ft/Ibs. 07/08/2006 00:00 12:00 12.00 6,907 7,341 INTRM1 DRILL DDRL P Driil 8 3/4" hole wlMM f/ 6,907' to 7,341' MD 6,806' TVD ADT - 8.18- hrs. ART .81 hrs AST 7.37 hrs. ECD - 10.1 ppg WOB 8/12 RPM 70 GPM 600 @ 2960 psi String wt. PU 208 SO 175 Rot 195 Tor ue on/off btm. - 9000/7500 ft/Ibs. 12:00 00:00 12.00 7,341 7,866 INTRM1 DRILL DDRL P Driil 8 3/4" hole w/MM f/ 7,341' to 7,866' MD 6,980' TVD ADT - 8.48- hrs. ART 2.11 hrs AST 6.37 hrs. ECD - 10.3 ppg WOB 8/12 RPM 70 GPM 600 @ 3610 psi String wt. PU 210 SO 165 Rot 190 Tor ue on/off btm. - 9000/8000 ft/Ibs. 07/09/2006 00:00 04:00 4.00 7,866 8,019 INTRM1 DRILL DDRL P Driil 8 3/4" hole w/MM f/ 7,866' to 8,019' MD 6,992' TVD ADT - 3.03 -hrs. ART 0.64 hrs AST 2.39 hrs. ECD - 10.4 ppg WOB 8/12 RPM 70 GPM 600 @ 3600 psi String wt. PU 210 SO 160 Rot 185 Tor ue on/off btm. - 9500/8000 ft/Ibs. 04:00 05:30 1.50 8,019 8,019 INTRM1 DRILL CIRC P Circ and condition mud - 600 gpm / 3280 psi / 70 rpm Flow check well static. Time Logs s~ 'Date From To Dur th E. De th Phase Code Sub~ ~C7M 07/09/2006 05:30 10:00 4.50 8,019 7,097 INTRM1 DRILL TRIP P Wiper trip from 8,019' to 7,097' - Backreamwith 550 gpm / 2940 psi / 50-80 rpm -work through tight hole / packing off from 7,634' to 7,564' - continue to backream with short tight spots from 7,500' to 7.350' -flow check well, static 10:00 10:45 0.75 7,097 8,019 INTRM1 DRILL TRIP P RIH from 7,097' to 7,956' -worked past tight spot @ 7,600' -Precautionary wash and ream from 7,956' -bit hung up at 7965', work free -wash and ream to 8,019' - 470 gpm / 2490 psi / 70 r m. 10:45 13:45 3.00 8,019 8,019 INTRM1 DRILL CIRC P Circ and condition mud - 588 gpm / 3600 psi / 80 rpm -pumped 40 bbls high vis pill -observed large push of cuttings at BU (small dark shale chips) high vis sweep brought back moderate push of cuttings -increase mud wt. from 10.0 to 10.2 ppg Flow check well, static 13:45 18:30 4.75 8,019 7,092 INTRM 1 DRILL TRIP NP Wiper trip -Wipe hole from 8,019' - 7092'. 500 gpm /80 rpm. Tight hole and packing off @ 7640', 7578', 7530', and 7478'. 18:30 21:00 2.50 7,092 7,612 INTRM1 DRILL WPRT NP RIH from 7092' to 7478'. Tight hole. Made up top drive and reamed from 7478' to 7612' hole ackin off. 21:00 23:00 2.00 7,612 7,383 INTRM1 DRILL WPRT NP Washed and reamed at 7612' to 7622' unable to pass. Oriented to high side and attempted to get down. Hole packing off. Worked pipe up to 7,383' hole free. MW 10.4 PPG. 23:00 00:00 1.00 7,383 7,388 INTRM1 DRILL CIRC NP Circulated and raised MW to 10.8 PPG. 70 RPM 500 GPM PP 2600 PSI. Had MW cut to 9.4 PPG after 1700 Stks. Gas 26 % LEL. 07/10/2006 00:00 00:30 0.50 7,388 7,478 INTRM1 DRILL CIRC NP Circ BU from 7,478' - 450 gpm / 2760 si/60r m-Mud wt. 10.8 00:30 02:45 2.25 7,478 8,019 INTRM1 DRILL REAM NP Wash and ream from 7,478' to 7,765' - 450 gpm / 2770 psi / 70 rpm -RIH from 7,765' to 7,966' -Precautionary wash and ream from 7,966' to 8,019' 02:45 04:30 1.75 8,019 8,019 INTRM1 DRILL CIRC P Circ and condition mud - 450 gpm / 2810 psi / 80 rpm -pumped 40 bbls high vis sweep and circulate hole clean spotted WBS and tube pills to bit. - Flow check well, static 04:30 05:45 1.25 8,019 7,097 INTRM1 DRILL TRIP P POOH from 8,019' to 7,097' spotting ills 3 b m / 600 si 05:45 14:00 8.25 7,097 78 INTRM1 DRILL TRIP P Flow check well. static -POOH on trip tank from 7,097' to 78' -flow checked well at shoe and hwdp, static -worked through tight spot @ 6000' until) clean -stood back hwdp and nm flex collars ~~ _ m - ..,,~m ..~ Page fr o~ 't k~ Time Lo s Date From To Dur th E. De th Phase Code Subcode T M 07/10/2006 14:00 16:15 2.25 78 0 INTRM1 DRILL PULD P Down load LWD - LD LWD collars, stab's, FS, Motor and bit -clear tools from floor 16:15 19:00 2.75 0 0 INTRM1 CASIN( NUND P Changed rams to 7" and tested. Function tested BOP. 19:00 20:45 1.75 0 0 INTRM1 CASIN( RURD P Rigged up to run 7" casing. PJSM. 20:45 00:00 3.25 0 1,840 INTRM1 CASIN( RNCS P Ran 43 Jts. 7" 26# L-80 BTCM casing to 1,840'. 07/11/2006 00:00 01:15 1.25 1,840 3,425 INTRM1 CASIN( RNCS P RIH w/ 7" csg from 1840' to 3425'. 01:15 02:00 0.75 3,425 3,425 INTRM1 CASIN( CIRC P Circ one csg volume at 5 bpm at 400 si. 02:00 06:00 4.00 3,425 6,852 INTRM1 CASIN( RNCS P RIH w/ 7" csg from 3425' to 6852'. 06:00 07:00 1.00 6,852 6,852 INTRM1 CASIN( CIRC P CBU. Stage pumps up to 5 bpm at 670 si. 07:00 07:30 0.50 6,852 7,197 INTRM1 CASIN( RNCS P RIH w/ 7" csg from 6852' to 7197'. 07:30 08:15 0.75 7,197 7,197 INTRM1 CASIN( EQRP T Repair pipe skate. 08:15 09:00 0.75 7,197 7,581 INTRM1 CASIN( RNCS P RIH w/ 7" csg from 7197' to 7581'. 09:00 10:15 1.25 7,581 7,668 INTRM1 CASIN( RNCS NP Work through tight hole from 7581' to 7668'. Hole packing off while trying to circulate. 10:15 11:00 0.75 7,668 7,581 INTRM1 CASIN( RNCS T PJSM. POH LD 2 jts 7" csg. 11:00 17:30 6.50 7,581 7,581 INTRM1 CASIN( CIRC T Broke circulation and ciriculated raising MW to 11.3 PPG @ 3 to 3.5 BPM 480 PSI. Worked through tight s of 7581' unable to ass.. 17:30 17:45 0.25 7,581 7,581 INTRM1 CASIN( SFTY P PJSM with crew on laying down casin . 17:45 00:00 6.25 7,581 5,442 INTRM1 CASIN( OTHR T POOH laying down 50 Jts 7" casing from 7581' to 5442'. 07/12/2006 00:00 05:30 5.50 5,442 2,509 INTRM1 CASIN( OTHR T POH and LD 7" csg from 5442' to 9 5/8" shoe at 2509'. No hole problems. Flow check well. Static. 05:30 11:15 5.75 2,509 0 INTRM1 CASIN( OTHR T Continue POH and LD 7" csg. Back out and LD Baker Lock jts by using a torch to heat couplings. All csg in good condition. No damage to float shoe. 11:15 12:30 1.25 0 0 INTRM1 CASIN( RURD T RD csg equipment and clean rig floor. RD Franks fill u tool. 12:30 14:30 2.00 0 0 INTRM1 CASIN( NUND T Changed rams from 7" to VBR and tested 250/5000 psi. Laid down test lu and installed wear bushin . 14:30 18:00 3.50 0 1,094 INTRM1 CEMEf~ PLUG T Rigged up and ran 35 Jts 3.5" eue tubin with mule shoe to 1094'. 18:00 21:15 3.25 1,094 7,572 INTRM1 CEMEI~ TRIP T RIH from 1094' to 7572' String took wei ht. 21:15 23:15 2.00 7,572 7,572 INTRM1 CEMEf~ OTHR T Worked pipe and tried to wash down could not pass 7572' .Hole packing off and brid ed off. h e ®~®~ .~. e - ~. ~~ ? of 1 Time Lo s Date From To Dur S. th E. D_ epth Phase Code Subcode T M 07/12/2006 23:15 00:00 0.75 7,572 7,570 INTRM1 CEME~ RURD T Rigged up to set plug from 7570' to 7070'. Tested lines to 2500 si. 07/13/2006 00:00 00:15 0.25 7,570 7,570 INTRM1 CEMEr` PLUG T Set plug #1 from 7570' to 7070'. Pump 5 bbls H2O. Test lines to 2500 psi. Pump 15 bbls H2O, 40 bbls (194 sx) 15.8 cement, 3 bbls H2O and rig dis laced with 69 bbls 11.3 mud. 00:15 01:00 0.75 7,570 6,950 INTRM1 CEME~ TRIP T POH to 6950'. 01:00 02:00 1.00 6,950 6,950 INTRM1 CEME~ CIRC T CBU at 465 gpm @ 2140 psi. Spot 20 bbls hi-vis ill. 02:00 03:00 1.00 6,950 6,745 INTRM1 CEME~ TRIP T POH to 6447'. RIH to 6745'. 03:00 03:30 0.50 6,745 6,745 INTRM1 CEMEf~ PLUG T Set plug #2 from 6745' to 6245'. Pump 5 bbls H2O. Test lines to 2500 psi. Pump 15 bbls H2O, 44 bbls (212 sx) 15.8 cement, 3 bbls H2O and rig dis laced with 60 bbls 11.3 mud. 03:30 05:00 1.50 6,745 5,100 INTRM1 CEMEI~ TRIP T POH to 5100'. 05:00 06:00 1.00 5,100 5,100 INTRM1 CEMEI~ CIRC T CBU at 465 gpm @ 1640 psi. Spot 30 bbl hi-vis ill. 06:00 06:15 0.25 5,100 4,710 INTRM1 CEME~ TRIP T POH to 4710'. 06:15 07:00 0.75 4,710 4,710 INTRM1 CEMEf~ CIRC T CBU at 465 gpm @ 1430 psi. 07:00 07:30 0.50 4,710 4,710 INTRM1 CEMEI~ PLUG T Set plug #3 from 4710' to 4210'. Pump 5 bbls H2O. Test lines to 2500 psi. Pump 15 bbls H2O, 44 bbls (247 sx) 17.0 cement, 3 bbls H2O and rig dis laced with 37 bbls 11.3 mud. 07:30 08:00 0.50 4,710 3,948 INTRM1 CEMEI~ TRIP T POH to 3948'. 08:00 09:00 1.00 3,948 3,948 INTRM1 CEMEC` CIRC T Circ and condition mud. Reduce mud wt from 11.3 to 10':5 ppg. Check flow. Static. 09:00 10:15 1.25 3,948 1,094 INTRM1 CEMEf~ TRIP T POH and stand back 4" DP to 1094'. 10:15 12:15 2.00 1,094 0 INTRM1 CEME~ TRIP T PJSM. POH and LD 35 jts of 3 1/2" tb and mule shoe 12:15 14:15 2.00 0 0 INTRM1 CEME~ RURD T Rigged down tubing tongs and re hung rig tongs. Cleared rig floor and picked u BHA com onets. 14:15 17:00 2.75 0 260 INTRM1 CEME~ PULD T Picked up Geopilot BHA and RIH to 260'. Tested tools. 17:00 19:00 2.00 260 2,435 INTRM1 CEMEI~ TRIP T Changed out jars and RIH to 2435'. 19:00 20:00 1.00 2,435 2,435 INTRM1 RIGMN SVRG P Slipped and cut drilling line. 20:00 21:00 1.00 2,435 3,963 INTRM1 CEMEf~ TRIP T RIH from 2435' to 3963'. 21:00 00:00 3.00 3,963 4,296 INTRM1 CEMEI~ OTHR T Washed down from 3963' to 4296'. Cement top @ 4266' Set Geopilot to high side and Drilled cement from 4277' to 4296'. 07/14/2006 00:00 00:45 0.75 4,296 4,341 INTRM1 CEME~ OTHR T Drill cement and formation from 4296' to 4341'. Sidetrack well at 4341'. .._ ~..~~_._..._~-..~~ m ~ e~ _a.__.~ ~ s age ~ o~ f 1~~ Time Logs Date From To Dur S. th E. Death Phase Code Subcode T M 07/14/2006 00:45 09:15 8.50 4,341 5,008 INTRM1 DRILL DDRL T Drill 8 3/4" hole w/ Geopilot f/ 4341' to 5008' MD 4714' TVD ECD - 11.1 / 11.5 ppg WOB 15/20 RPM 140 GPM 600 @ 2610 psi String wt. PU 180 SO 150 Rot 167 Tor ue on/off btm. - 9000/7500 ft/Ibs. 09:15 09:45 0.50 5,008 5,008 INTRM1 RIGMN RGRP T Repair electrical problems with drilling console. 09:45 12:00 2.25 5,008 5,198 INTRM1 DRILL DDRL T Drill 8 3/4" hole w/ Geopilot f/ 5008' to 5198' MD 4893' TVD ADT Last 12 hrs - 7.50 hrs ECD-11.2/11.5 ppg WOB 15/18 RPM 140 GPM 600 2640 psi String wt. PU 180 SO 150 Rot 167 Tor ue on/off btm. - 9000/7500 ft/Ibs. 12:00 12:45 0.75 5,198 5,293 INTRM1 DRILL DDRL T Drill 8 3/4" hole w/Geopilot f/ 5198' to 5293' MD 4984' TVD ADT - .74 hrs ECD-11.2/11.5 ppg WOB 15/18 RPM 140 GPM 600 2640 psi String wt. PU 180 SO 150 Rot 167 Tor ue on/off btm. - 9000/7500 ft/Ibs. 12:45 14:00 1.25 5,293 5,293. INTRM1 RIGMN RGRP T Repaired washout in #2 Pump. 14:00 00:00 10.00 5,293 6,290 INTRM1 DRILL DDRL T Drill 8 3/4" hole w/ Geopilot f/ 5293' to 6290' MD 5960' TVD ADT - 7.92 hrs ECD-11.5/11.7 ppg WOB 20/23 RPM 100 GPM 500 2250 psi String wt. PU 207 SO 160 Rot 178 Tor ue on/off btm. - 11000/9500 ft/Ibs. 07/15/2006 00:00 01:15 1.25 6,290 6,372 INTRM1 DRILL DDRL T Drill 8 3/4" hole w/ Geopilot f/ 6290' to 6372' MD 6042' TVD ADT - 1.01 hrs ECD-11.3/11.6 ppg WOB 12/23 RPM 140 GPM 500 2250 psi String wt. PU 207 SO 160 Rot 185 Torque on/off btm. - 12000/10000 ft/Ibs. Unable to achieve required dog legs from Geopilot. 01:15 02:00 0.75 6,372 6,372 INTRM1 DRILL CIRC T Circ hole clean at 650 gpm - 3360 psi - 140 r ms. Check flow. Static. 02:00 02:45 0.75 6,372 6,372 INTRM1 DRILL TRIP T POH from 6375' to 5920'. Hole not taking proper fill. check flow. Static. RIH to 6372'. 02:45 03:30 0.75 6,372 6,372 INTRM1 DRILL CIRC T CBU at 650 gpm - 3370 psi - 120 rpm. No influx. Check flow. Static. 03:30 05:30 2.00 6,372 5,389 INTRM1 DRILL TRIP T POH w! pump from 6372' to 5389' at 500 gpm - 2100 psi - 110 rpms. Minor dra and ackoff from 5950' to 5675'. ~ ~'~qe ~ ~t .I .. ~ ..~ Time Lo s _ Da e From To Dur th E. De th Phase Code Subcode T M 07/15/2006 05:30 06:00 0.50 5,389 5,389 INTRM1 DRILL CIRC T Circ hole clean at 600 gpm - 120 rpms. 06:00 11:00 5.00 5,389 167 INTRM1 DRILL TRIP T POH on trip tank from 5389' to 167'. Check flow at shoe and at top of BHA. No hole roblems. 11:00 14:30 3.50 167 261 INTRM1 DRILL PULD T Changed out Geopilot BHA to Mud Motor. RIH to 261' shallow tested MWD. 94:30 18:00 3.50 261 6,243 tNTRM1 DRILL TRIP T RIH from 261' to 6243' filling every 20 stands. 18:00 18:30 0.50 6,243 6,372 INTRM1 DRILL REAM T Washed down precautionary from 6243' to 6372'. 18:30 00:00 5.50 6,372 6,621 INTRM1 DRILL DDRL T Drill 8 3/4" hole w/Mud Motor f/ 6372' to 6621' MD 6275' TVD ADT - 3.46 hrs ART .88 hrs AST 2.58 hrs. ECD - 91.3 / 11.6 ppg WOB 8/13 RPM 60 GPM 600 @ 3380 psi String wt. PU 205 SO 165 Rot 185 Tor ue on/off btm. - 10000/8000 ft/Ibs. 07/16/2006 00:00 12:00 12.00 6,621 6,778 INTRM1 DRILL DDRL T Drill 8 3/4" hole w/Mud Motor f/ 6621' to 7287 MD 6778' TVD ADT - 8.63 hrs ART 3.42 hrs AST 5.21 hrs. ECD - 11.26 ppg WOB 8/1.2 RPM 60 GPM 600 @ 3580 psi String wt. PU 210 SO 170 Rot 190 Tor ue on/off btm. - 9500/8000 ft/Ibs. 12:00 00:00 12.00 6,778 7,905 INTRM1 DRILL DDRL T Drill 8 3/4" hole w/Mud Motor f/ 7287' to 7905' MD 6983' TVD ADT - 9.11 hrs ART 3.62 hrs AST 5.49 hrs. ECD - 11.2 ppg WOB 8/12 RPM 60 GPM 600 @ 3950 psi String wt. PU 205 SO 160 Rot 182 Tor ue on/off btm. - 8500/8000 ft/Ibs. 07/17/2006 00:00 05:00 5.00 7,905 8,155 INTRM1 DRILL DDRL T Driil 8 3/4" hole w/Mud Motor f/ 7905' to 8155' MD 6991' TVD ADT - 3.29 hrs ART 2.19 hrs AST 1.10 hrs. ECD - 11.2 ppg WOB 5/8 RPM 60 GPM 575 @ 3880 psi String wt. PU 205 SO 155 Rot 180 Tor ue on/off btm. - 10000/9000 ft/Ibs. 05:00 07:00 2.00 8,155 7,892 INTRM1 DRILL CIRC T Pump sweep. Circulate 3X bottoms up at 600 gpm - 3980 psi - 80 rpms. Set back 1 std eve 30 min. 07:00 08:15 1.25 7,892 7,032 INTRM1 DRILL WPRT T POH w/ pump from 7892' to 7032' at 500 gpm - 2840 psi - 70 rpms. No hole roblems. 08:15 08:45 0.50 7,032 8,081 INTRM1 DRILL WPRT T RIH to 8081'. No hole problems. ~~_ _s~ ~ ~ ~_..~ ~ n ~e ~~ cif t~ E _ o.-. ~. ~ ~. ..~. ~ ~ a ~ m Time Logs --~ _ Date From To Dur ~ th E. De th Phase Code Subcode T~ ~M 07/17/2006 08:45 11:15 2.50 8,081 8,155 INTRM 1 DRILL CIRC T Precautionary wash and ream from 8081' to 8155'. Circulate 3X bottoms up at 600 gpm - 3820 psi - 80 rpms. Stand back 1 std every 30 min to 7892'. RIH to 8155'. 11:15 14:30 3.25 8,155 6,239 INTRM1 DRILL TRIP T POOH pumping @ 3 BPM from 8155' to 6239'. Spotted casing running pills to above HRZ. PP 550 si. 14:30 20:00 5.50 6,239 717 INTRM1 DRILL TRIP T POOH on Trip Tank from 6239' to 717'. 20:00 23:00 3.00 717 0 INTRM1 DRILL PULD T Laid down BHA and cleared floor. 23:00 00:00 1.00 0 0 INTRM1 WELCT NUND T Pulled wear bushing and changing rams. 07/18/2006 00:00 01:15 1.25 0 0 INTRM1 WELCT BOPE T Finish change upper pipe rams to 7". Test 7" rams to 250-5000 psi. Pull test lu .Install thin wear bushin . 01:15 01:45 0.50 0 0 INTRMI CASIN( RURD T RU csg equipment. PJSM. 01:45 05:00 3.25 0 3,435 INTRM1 CASIN( RNCS T RIH w/ 80 jts 7" 26# L-80 BTCM csg to 3435'. 05:00 05:45 0.75 3,435 3,435 INTRM1 CASIN( CIRC T Circulate 1 csg volume. Stage pumps to 5 b mat 430 si. 05:45 09:00 3.25 3,435 6,993 INTRM1 CASIN( RNCS T RIH w/ 83 jts 7" 26# L-80 BTCM csg from 3435' to 6993'. 09:00 10:00 1.00 6,993 6,993 INTRM1 CASIN( CIRC T CBU. Stage pumps up to 4.5 bpm at 540 si. 10:00 11:15 1.25 6,993 7,678 INTRM1 CASIN( RNCS T RIH w/ 16 jts 7" 26# L-80 BTCM csg from 6993' to 7678'. Work through tight hole from 7570' to 7668'. 11:15 12:30 1.25 7,678 8,145 INTRM1 CASIN( RNCS P RIH w/ 16 jts 7" 26# L-80 BTCM csg from 7678' to 8107'. MU hanger and LJ. Land cs at 8145'. 12:30 13:00 0.50 8,145 8,145 INTRMI CASIN( RURD P RD Franks fill-up tool. RU cement head and lines. 13:00 19:00 6.00 8,145 8,145 INTRM1 CEME~ CIRC P Establish circ @ .5 BPM @ 400 psi - staging pump up to 4.4 BPM - ICP 680 FCP 620 - Circ & attempt to get rate up for cementing -Hole trying to pack - off unable to get rate up to 5 BPM without ackin off ~.~~ _~~ ~ ~~ ~ ~ ~ Page .t~ «~ Time Logs Date From To Dur S. th E. De tft Phase Code Subcode T M 07/18/2006 19:00 21:30 2.50 8,145 8,145 INTRM1 CEMEI~ DISP P PJSM on cmt job -Cemented 7" csg as follows: Pumped 1 bbl water - Tested lines to 4000 psi -Mixed & pumped 40 bbls MudPush @ 12.5 ppg - 4 BPM @ 450 psi -Dropped btm plug - Mixed & pumped 89 bbls tail slurry Class G w/additives) - 15.8 ppg @ 4 BPM @ 400 psi -Dropped top plug w/ 20 bbls water f/ Dowell -switched to rig pumps & displaced cmt w/ 10.5 ppg mud @ 4 BPM for 233 bbls - Observed slight packing off -slowed pump to 3.5 BPM next 30 bbls - slowed pump to 2.5 BMP for remained of job - 286 bbls total displacement - Bumped plug w/ 1670 psi -Check floats OK CIP @ 2124 hrs.- Full returns throu hout - No i e movement 21:30 22:30 1.00 8,145 8,145 INTRM1 DRILL OTHR P RU & test csg to 3500 psi for 30 mins. RD 22:30 23:00 0.50 8,145 8,145 INTRM1 CEME~ PULD P RD cmt lines & head - LD landing jt. 23:00 00:00 1.00 8,145 8,145 INTRM1 DRILL OTHR P Pull thin wall wear bushing -Set & test ack-off to 5000 si 07/19/2006 00:00 00:45 0.75 0 0 INTRM1 WELCT EQRP P PJSM. Change rams from 7" to 3 1/2" X 6' variables. Change out top drive saver sub. 00:45 04:30 3.75 0 0 INTRM1 WELCT BOPE P Test all BOPE to 250-5000 psi with annular to 3500 psi. Witness of test was waived by AOGCC rep Chuck Scheve. 04:30 05:00 0.50 0 0 INTRM1 WELCT OTHR P Pull test plug. Install wear bushing. 05:00 05:30 0.50 0 0 INTRM1 DRILL RURD P RU bails and elevators. 05:30 07:00 1.50 0 376 INTRM1 DRILL PULD P MU BHA #6. Shallow test tools at 376'. 07:00 13:00 6.00 376 6,091 INTRM1 DRILL TRIP P PU and RIH with 180 jts 4" DP from pipe shed from 376' to 6091' Fill pipe eve 2000'.. 13:00 14:30 1.50 6,091 7,895 INTRM1 DRILL TRIP P RIH w/ 4" DP ftom derrick from 6091' to 7895'. Break circulation at 5 bpm - 1500 si. 14:30 16:00 1.50 7,895 7,895 INTRM1 RIGMN SVRG P PJSM. Slip and cut drilling line. Service to drive and ri . 16:00 16:30 0.50 7,895 8,020 INTRM1 DRILL OTHR P Wash down f/ 7895' to 8020' -tag top of cmt. 16:30 19:30 3.00 8,020 8,175 INTRM1 CEME~ DRLG P Clean out cmt to 8055' -drill wiper plug & FC @ to 8057' -clean out cmt f/ 8057' to 8144' -Drill FS to 8346' - clean out rat hole to 8155' & drill 20' new hole to 8175' 19:30 20:30 1.00 8,175 8,175 INTRM1 DRILL CIRC P Circulate hole clean for FIT 20:30 21:00 0.50 8,175 8,175 INTRMI DRILL FIT P RU & perform FIT to 12.5 ppg EMW - RD _.._.. ~ ~® a _-. .~. - _ ._ ~ .~~._. ~ '~ ~ ~f '1 _~ ~.._._ Time Logs Date From To Dur S, pth E. Depth Phase Code Subcode T M _ 07/19/2006 21:00 22:30 1.50 8,175 8,175 PROD1 DRILL CIRC P Change well over f/ 10.5 ppg LSND to 9.2 ppg FloPro - 212 gpm @ 1350 psi w/ 50 rpm's -shut down & monitor well static 22:30 00:00 1.50 8,175 8,230 PROD1 DRILL DDRL P Down link to power drive -Drill 6 1/8" hole w/ Schlum. Power drive RS w/ periscope f/ 8175' to 8230' MD 6989' TVD ADT - 1.46 hrs. ECD - 10.4 ppg WOB 6/8 k RPM 100 GPM 250 @ 1720 psi String wt. PU 195 SO 150 Rot 170 Tor ue on/off btm.- 9500/8500 ft. lbs. 07/20/2006 00:00 05:45 5.75 8,230 8,452 PROD1 DRILL DDRL P Drill 6 1/8" hole w/ Schlum. Power drive RS w/ periscope f/ 8230' to 8452' MD 6996' TVD ADT - 4.57 hrs. ECD - 10.4 ppg WOB 6/9 k RPM 120 GPM 244 @ 1650 psi String wt. PU 195 SO 155 Rot 174 Tor ue on/off btm.- 10,500/9500 ft. lbs. 05:45 06:15 0.50 8,452 8,452 PROD1 DRILL CIRC T Circulate at 244 gpm - 1630 psi -120 rpm. Tools not building angle needed to turn well u . Discuss o tions. 06:15 07:15 1.00 8,452 8,503 PROD1 DRILL DDRL P Drill 6 1/8" hole w/ Schlum. Power drive RS w/ periscope f/ 8452' to 8503' MD 6998' TVD ADT - .45 hrs. ECD - 10.4 ppg WOB 6/9 k RPM 170 GPM 270 @ 2020 psi String wt. PU 195 SO 155 Rot 174 Torque on/off btm.- 10,500/9500 ft. lbs. Penetrated lower shale at 8450'. Max do le from Power drive - 1.25 de . 07:15 08:00 0.75 8,503 8,503 PROD1 DRILL CIRC T CBU at 240 gpm - 1630 psi - 110 rpm 08:00 09:30 1.50 8,503 7,610 PROD1 DRILL TRIP T POH w/ pump from 8503' to 7610' at 200 m - 1050 si. 09:30 09:45 0.25 7,610 8,086 PROD1 DRILL TRIP T Monitor well. Had slight flow out annulus. RIH to 8086'. 09:45 10:45 1.00 8,086 8,086 PROD1 DRILL CIRC T CBU at 240 gpm - 1400 psi. No influx. 10:45 11:15 0.50 8,086 7,610 PROD1 DRILL TRIP T POH w/ pump from 8086' to 7610' at 200 m - 1050 si. 11:15 12:30 1.25 7,610 7,610 PROD1 DRILL CIRC T Displace well to 9.6 ppg brine for trip at 220 gpm at 1070 psi. Check flow. Static. 12:30 17:30 5.00 7,610 375 PROD1 DRILL TRIP T POH on trip tank from 7610' to 375' 17:30 20:00 2.50 375 0 PROD1 DRILL PULD T Stand back HWDP & NM flex DC's - Trouble shoot ower drive -break bit 20:00 21:30 1.50 0 375 PROD1 DRILL PULD T MU new bit - MU power drive, periscope, & MWD - RIH w/ NM flex DC's & HWDP to 375' 21:30 00:00 2.50 375 5,138 PROD1 DRILL TRIP T RIH f/ 375 to 5138' -fill pipe every 20 stds. -shallow test tools 946' OK ~ .~~~ ~ .~ ..~ „r ~~ `I f' Time Los ---~ Date From To Dur S. th E. De th Phase Code Subco de T~ M 07/21/2006 00:00 01:00 1.00 5,138 8,086 PROD1 DRILL _ TRIP T RIH from 5138' to 8086'. Fill pipe every 2000'. Check flow. Static. 01:00 02:30 1.50 8,086 8,086 PROD1 DRILL CIRC T Displace 9.6 brine from well with 9.2 flo- ro at 220 m - 1600 si. 02:30 02:45 0.25 8,086 8,374 PROD1 DRILL TRIP T RIH to 8374'. 02:45 04:00 1.25 8,374 8,503 PROD1 DRILL REAM T Wash and ream from 8374' to 8503'. Hole tight and packing off from 8465' to 8490'. Reduce pump rate to 200 gpm. Ream to 8503' with no roblems. 04:00 12:00 8.00 8,503 9,040 PROD1 DRILL DDRL P Drill 6 1/8" hole w/ Schlum. Power drive RS w/ periscope f/ 8503' to 9040' MD 6992' TVD ADT - 5.15 hrs. ECD - 10.52 ppg WOB 5/12 k RPM 130 GPM 240 @ 1970 psi String wt. PU 200 SO 150 Rot 174 Torque on/off btm.- 11,000/10,000 ft. lbs. 12:00 15:30 3.50 9,040 9,421 PROD1 DRILL DDRL P Drill 6 1/8" hole w/ Schlum. PD RS w/ periscope f/ 9040' to 9421' MD 6992' TVD ADT - 2.97 hrs. ECD - WOB 5/8 k RPM 130 GPM 240 @ 200 psi String wt. PU 195 SO 155 Rot. 170 Torque on/off btm. - 11,000/9,000 ft. lbs. 15:30 16:30 1.00 9,421 9,230 PROD1 DRILL CIRC P CBU for wiper trip - 240 gpm @ 1950 psi w/ 130 RPM (stood back 2 stds while circ btms u to 9230' 16:30 18:30 2.00 9,230 8,277 PROD1 DRILL WPRT P POOH w/ pump f/ 9230' to 8277' w/ 210 gpm @ 1480 psi w/ 50 RPM -Had to work throu h shale f/ 8472' to 8450' 18:30 19:30 1.00 8,277 9,325 PROD1 DRILL WPRT P Flow check (static) -RIH f/ 8277' to 9325' -Observed slight drag going throu h shale section 19:30 20:00 0.50 9,325 9,421 PROD1 DRILL WASH P Wash down f/ 9325' to 9421' - 240 gpm @ 1960' w/ 50 RPM - down link to ower drive 20:00 20:30 0.50 9,421 9,473 PROD1 DRILL DDRL P Drill 6 1/8" hole w/ Schlum. PD RS w/ Periscope f/ 9421' to 9473' MD 6992' TVD ADT..37 hrs. ECD - 10.5 ppg WOB 5/8 k RPM 130 GPM 240 @ 1990 psi String wt. PU 195 SO 155. Rot 170 Torque on/off btm. - 11,000/9,000 ft. lbs. Lost 160 psi pump pressure - MWD failure 20:30 21:30 1.00 9,473 9,325 PROD1 DRILL OTHR T Pressure test surface equipment OK - Circ BU -Std back 2 stds to 9325' 21:30 00:00 2.50 9,325 7,610 PROD1 DRILL TRIP T Flow ck. Static -POOH w/ pump f/ 9325' to 7610' -looking for wash out - 210 m 1300 si - ~e ~ m ~ _.~.....~_ ~.~.. _ ~ ~~~e 1~ ~sf ~~ _ Time Logs. Date From To Dur 5~ th E Depth Phase Code Subcode T M 07/22/2006 00:00 02:00 2.00 7,610 5,991 PROD1 DRILL TRIP T Continue POH with pump from 7610' to 5991' at 210 m - 1100 si. 02:00 03:15 1.25 5,991 5,991 PROD1 DRILL CIRC T Dsiplace well to 9.6 brine. Chech flow. Static. 03:15 07:00 3.75 5,991 187 PROD1 DRILL TRIP T POH on trip tank from 5991' to 187'. 07:00 08:45 1.75 187 0 PROD1 DRILL PULD T Screw into jars. Circulate at 250 gpm. No leaks in jars. Screw into MWD tools and circulate at 250 gpm - 850 psi. No response from MWD tool. LD MWD, PeriSco e, PD and bit. 08:45 10:15 1.50 0 377 PROD1 DRILL PULD T MU bit, new PD, Periscope, new MWD, flex collars and HWDP. Shallow test MWD. OK. 10:15 13:30 3.25 377 6,088 PROD1 DRILL TRIP T RIH with 4" DP from 377' to 6088' 13:30 14:30 1.00 6,088 6,088 PROD1 DRILL CIRC T Displace well @ 6088' f/ 9.6 ppg brine to 9.2 ppg FloPro - @ 210 gpm @ 1330 si w/ 75 RPM -Flow ck Static 14:30 16:00 1.50 6,088 8,530 PROD1 DRILL TRIP T Cont. RIH f/ 6088' to 8530' -string takin wt. 16:00 16:30 0.50 8,530 8,565 PROD1 DRILL REAM T Pull back to 8470' - MU TD -Wash down f/ 8470' to 8565' -tight & packing off 8530' 16:30 17:00 0.50 8,565 9,423 PROD1 DRILL TRIP T Cont. RIH f/ 855' to 9423' 17:00 17:30 0.50 9,423 9,473 PROD1 DRILL REAM T Wash down (/ 9423' to 9473' - 240 gpm @ 1990 psi w/ 80 rpm -Down link to PD 17:30 00:00 6.50 9,473 9,996 PROD1 DRILL DDRL P Drill 6 1/8" hole w/ Schlum. PD RS w/ Periscope f/ 9473' to 9996' MD 6993' TVD ADT - 3.74 hrs. ECD - 10.7 ppg WOB 5/8 k RPM 130 GPM 240 @ 2080 psi String wt. PU 200 SO 143 Rot 172 Tor ue on/off btm. - 11,000/9500 ft lbs. 07/23/2006 00:00 12:00 12.00 9,996 11,045 PROD1 DRILL DDRL P Drill 6 1/8" hole w/ Schlum. PD RS w/ Periscope f/ 9996' to 11,045' MD 7004' TVD ADT - 7.62 hrs. ECD - 10.6 ppg WOB 5/8 k RPM 130 GPM 240 @ 2100 psi String wt. PU 205 SO 138 Rot 170 Torque on/off btm. - 11,000/10,00 ft lbs. 12:00 00:00 12.00 11,045 11,903 PROD1 DRILL DDRL P Drill 6 1/8" holew/Schlum PD SR w/Periscope f/ 11,045' to 11,903' MD 7003' TVD ADT - 7.32 hrs. ECD - 10.86 ppg WOB 619 k RPM 130 GPM 245 @ 2300 psi String wt. - PU 212 SO 125 Rot 168 Torque on/off btm. - 12,000/10,500 ft lbs. ~---~-~~ Time Logs ~_ ___ Date From To Dur S~ th E. De th Phase Code Subcode T M' 07/24/2006 00:00 12:00 12.00 11,903 12,930 PROD1 DRILL DDRL P Drill 6 1/8" hole w/Schlum PD RS w/Periscope f/ 11,903' to 12,930' MD 7006' TVD ADT - 8.72 hrs. ECD - 11.1 ppg WOB 6/10 k RPM 130 GPM 245 @ 2400 psi String wt. - PU 210 SO 125 Rot 162 Torque on/off btm. - 12,000/11,000 ft lbs. 12:00 00:00 12.00 12,930 13,660 PROD1 DRILL DDRL P Drill 6 1/8" hole w/ Schlum PD RS w/ Periscope f/ 12,930' to 13,660' MD 7007' TVD ADT - 8.05 hrs. ECD - 11.22 ppg WOB 6/9 k RPM 130 GPM 240 @ 2600 psi String wt. PU 222 SO 114 Rot 167 Torque on/off btm. - 13,500/12,000 ft. lbs. 07/25/2006 00:00 12:00 12.00 13,660 14,110 PROD1 DRILL DDRL P Drill 6 1/8" hole w/ Schlum. PD RS w/ Periscope f/ 13,660' to 14,110' MD 7019' TVD ATD - 7.83 hrs. ECD - 11.15 ppg WOB 6/9 k RPM 130 GPM 240 @ 2530 psi String wt. PU 218 SO 120 Rot 168 Torque on/off btm. - 11,500/11,000 ft. lbs. 12:00 20:00 8.00 14,110 14,471 PROD1 DRILL DDRL P Drill 6 1/8" hole w/Schlum. PD RS w/ Periscope f/ 14,110' to TD of 14,471' MD / 7,017' TD. ATD - 4.82 hrs. ECD - 11.4 ppg WOB 6/10k RPM 130 GPM 237 @ 2680 psi String wt. PU 220 SO 115 Rot 167 Torque on/off btm. - 12,500 / 12,000 ft. I bs. 20:00 22:30 2.50 14,471 14,093 PROD1 DRILL CIRC P CBU 2xs. Increasing MW to 9.4 ppg. Std back 1 every 30 mins (to 14,093' MD). Pump at 207 gpm, 100 rpm, and 2320 si. 22:30 00:00 1.50 14,093 13,427 PROD1 DRILL TRIP P Check flow: static. POOH with pump from 14,093' to 13,427 '. 3 bpm, 1170 psi. PU=215 K, S0=130K at 13,427' MD. 07/26/2006 00:00 07:00 7.00 13,427 8,145 PROD1 DRILL TRIP P Cont. POOH w/ pump f/ 13,427' to 8145' w/ pump @ 3 BPM @ 1120 psi - FCP 920 psi -flow check (static) - Hole took proper fill & no problem ullin the shale sections 07:00 08:15 1.25 8,145 8,145 PROD1 DRILL CIRC P Circulate btms up @ 5 BPM @ 1700 si -Flow Check static dro 2" rabbit 08:15 08:45 0.50 8,145 7,612 PROD1 DRILL TRIP P Cont. POOH w/ pump f/ 8145' to 7612' 3 BPM 860 is -flow ck static 08:45 10:00 1.25 7,612 7,612 PROD1 DRILL CIRC P Change well over f/ 9.4 ppg FloPro to 9.6 ppg brine @ 5 BPM @ 1600 psi - Flow Ck static ~. -° _ ~ I ~~~~~ 7 ~ of 1 L~ ,_~__~_ _ ~ Time Los Date From To Dur tS h E. De th Phase Code Subcode T M 07/26/2006 10:00 14:30 4.50 7,612 377 PROD1 DRILL TRIP P POOH on TT f/ 7612' to 377' -Flow ck static SB HWDP 14:30 15:30 1.00 377 0 PROD1 DRILL PULD P Std back NM flex DC's - LD BHA 15:30 16:30 1.00 0 0 COMPZ CASIN( RUNL P RU to run 4 1/2" liner -Held Pre job meetin with crew on runnin liner 16:30 21:30 5.00 0 6,502 COMPZ CASIN( RUNL P Run 4 1/2" liner as follows: 151 joints of slotted, 13 joints of blank. P/U: 145K, S/O: 125K. 21:30 23:00 1.50 6,502 6,636 COMPZ CASIN( RUNL P C/O elevations. M/U liner hanger, mix Pal Mix. M/U cross over and 1 std of DP to 6636' MD. Establish circulationat 3 b m, 230 si. 23:00 00:00 1.00 6,636 7,584 COMPZ CASIN( RUNL P Continue to RIH with liner from 6636' to 7584' MD. P/U: 155K, S/O: 137K. 07/27/2006 00:00 00:15 0.25 7,584 8,061 COMPZ CASIN( RUNL P Cont. RIH w/ liner f/ 7584' to 8061' 00:15 00:30 0.25 8,061 8,061 COMPZ CASIN< CIRC P Circ DP vol. - PU 165 SO 137 -Torque 5500 5 & 10 RPM 00:30 05:15 4.75 8,061 14,461 COMPZ CASIN( RUNL P Cont. RIH w/ liner on DP f/ 8061' to 14,461' 05:15 06:00 0.75 14,461 14,461 COMPZ CASIN( RUNL P Tag btm - PU to setting depth -Set liner hanger & release f/liner - PU 230 SO 140 06:00 07:00 1.00 COMPZ CASIN< CIRC P Circ btms up @ 7900' @ 5 BPM @ 500 is -Flow ck -Static 07:00 08:15 1.25 COMPZ RIGMN SLPC P Cut & slip drill Iline -Service TD - Monitorwell on TT -Flow ck -static 08:15 12:00 3.75 COMPZ CASIN( TRIP P POOH w/ DP & liner setting tool f/ 7900' to 1818' 12:00 12:30 0.50 COMPZ RIGMN RGRP T repair iron roughneck 12:30 14:00 1.50 COMPZ CASIN( TRIP P Finish POOH w/ DP & liner running tool -Break down tool & LD same 14:00 14:45 0.75 COMPZ CASIN( RURD P Pull wear bushing & RU to run tbg 14:45 15:00 0.25 COMPZ CASIN( SFTY P Held pre job meeting with crew 15:00 21:00 6.00 0 5,862 COMPZ CASIN( RNCS P Run 4 1/2" 12.6 # L-80 IBTM tbg & tools as follows: Baker shear indicating WLEG - 9 jts - XN nipple - 1 jt. -Baker premier Packer - 2 jts. - Camco GLM w/ shear valve - 31 jt - Camco GLM - 36 'ts. 5862' 21:00 22:00 1.00 5,862 5,862 COMPZ CASIN( RNCS P PJSM - RU Camco equipment - PU SSSV -connect lines & test to 5000 si 22:00 00:00 2.00 5,862 6,828 COMPZ CASIN( RNCS P Continue running 4 1/2" completion f/ 5862' to 6828' 07/28/2006 00:00 02:00 2.00 6,828 7,937 COMPZ CASIN( RNCS P Finish running 4 1/2" completion f/ 6828' to 7937' 02:00 03:30 1.50 7,934 7,934 COMPZ CASIN( OTHR P Tag up with locator & observed shear out -Pick up to space out mark- 3' above liner top -Install space out pups & 2 'ts tb above u s ~~ ~~ caf ~ Time Low _ Date Fram To Dur ~>: th E. De th Phase Code Subcode T M 07/28/2006 03:30 06:00 2.50 7,934 7,934 COMPZ CASIN( OTHR P MU tbg hanger -Run controls through hanger & test connections -Land tbg hanger in wellhead w/ tbg tail WLEG)@ 7934.78 - XN @ 7547' - Packer @ 7486' -GLM #1 @ 7375' - GLM #2 @ 6089' -GLM #3 @ 3622' - BAL-O nipple @ 2048' - RILD - LD LJ A -Set TWC - MU LJ B -Test hanger sealls to 5000 si - LD LJ B 06:00 07:45 1.75 7,934 7,934 COMPZ DRILL RURD P PJSM - ND BOPE 07:45 11:30 3.75 7,934 7,934 COMPZ DRILL OTHR P Terminate control lines through wellhead & test to 6000 psi - NU tree & test to 5000 psi - RU FMC lubricator & ull TWC 11:30 12:30 1.00 7,934 7,934 COMPZ DRILL OTHR P RU hard lines to wellhead & squeeze manifold on rig floor -for packer setting o eration 12:30 15:30 3.00 7,934 7,934 COMPZ DRILL CIRC P PJSM with crew on pumping & packer operation -Test lines to 2500 psi w/ Dowell -Pumped 108 bbls 9.6 ppg inhibited brine followed by 160 bbls diesel (tbg vol plus 2000' TVD for annular freeze protection) Shut down - SITP 850 psi - RU lubricator & dropped packer setting ball/rod assembly - Retest lines to 5000 si 15:30 18:15 2.75 7,934 7,934 COMPZ DRILL OTHR P Pressure up on tbg to 4800 psi to set packer & test tbg for 30 mins. -Bleed tbg to 2000 psi -Pressure up annulus to 3500 psi & test for 30 mins. -bleed annulus to) psi -Bleed tbg down to 850 pis -Shut in well -Flush lines with water & blow down with air - RD hardlines & manifold 18:15 19:30 1.25 7,934 7,934 COMPZ DRILL OTHR P RU FMC lubricator & set BPV - RD lubricator -Secure well 19:30 00:00 4.50 7,934 COMPZ DRILL PULD P RU & LD Excess DP f/ derrick via mouse hole for ri move ~. _ ~~ ~ .~.~~ ~~ ~~ 9 of 13~ • • 17-Aug-06 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD4-320 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 4,313.09' MD Window /Kickoff Survey 0.00' MD (if applicable) Projected Survey: 14,471.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carle Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 ,, ~ ~ ~ / , / /~ Date ~v ~ c ct 0 Signed /~c~~-(`fiU~M~OC U~Wwd Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) • • 17-Aug-06 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD4-320PB1 Dear Dear Sir/Madam: Enclosed is one disk with the '`.PTT and *.PDF files. Tie-on Survey: Window /Kickoff Survey Projected Survey: 37.02' MD 0.00' MD (if applicable) 8,019.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 /~~ Date ~ ~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Surrey Manager Attachment(s) ~p~- of S • • WELL LOG TRANSMITTAL To: State of Alaska August 4, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`h Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD4-320 &CD4-320 PB1, AK-MW-4477289 The technical data listed below is being sr~bmitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted CD Rom with verification listing. API#: 50-103-20531-00, 70. c F,~ ~/aa/v,6 ~~~~ AUG 2 2 2006 ~~ 8~ {3as Cons. Commission Atrdror~ ~, ~ ~a ~ ~ ~ _ ,~ .,~ ~' ~ ~~ ~~~ '°~~ FRANK H. MURKOWSKI, GOVERNOR 8 ~~ ~~ ~ ~ ~J 333 W. 7"' AVENUE, SUITE 100 C01~5ERQATI011T COri1rII55I01~ ~ ANCHORAGE, ALASKA 99501-3539 r PHONE (907) 279-1433 FAX (907) 276-7542 Paul Mazzolini Exploratory Team Lead ConocoPhillips Alaska, inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Nanuq Kuparuk Oil Pool, CD4-320 Sundry Number: 306-242 Dear Mr. Mazzolini: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this2~ day of July, 2006 ~-- Encl. ,~~ ~ ~ ~C.~SJ Chairman ~ ~ ~ ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 July 12, 2006 Alaska Oil and Gas Conservation Commission 333 West 7`h Avenue, Suite 100 Anchorage, Alaska 99501 ConocoPhillips DECEIVED JUL 1 3 ZO(~6 Alaska Oil & Gas Cans. Co+nrttissian Anchorage Re: Application for change to Approved Program- Plug back abandonment and sidetrack operations CD4-320 (permit no. 206-055) Dear Sir or Madam: ConocoPhillips Alaska, {nc. hereby applies fora Permit for change to Approved Programs for CD4-320. Drilling operations on CD4-320 began on 07-01-06 with Doyon 19 and the well was drilled to the planned landing point in the Kuparuk reservoir. ' While performing a wiper trip in the 8-3/4" intermediate holes the hole became tight and the mud weight was increased for additional wellbore stability. After weighting up and wiping the section it was felt that the hole was in good enough condition to run casing. The casing string was not able to move past +/- 7600' MD after repeated attempts and added mud weight. The casing string was pulled and laid down in preparation for plugging and sidetrack operations. It is planned to plug the old hole with cement plugs, then sidetrack and drill to a new 7" casing point target in the Kuparuk sand. The 8-3/4" plugged hole will be re-named CD4-320PB1 with API extension -70 and once ~ re-drilled the new hole will become CD4-320. Please find attached the information: 1. Form 10-403 APPLICATION FOR Sundry approval 2. A proposed plug back and drilling program 3. Proposed plug back schematic If you have any questions or require further information, please contact Vern Johnson, 265-6081 or Chip Alvord at 265-6120. Sinc y, ~/~ Z~66 _ ~ rn Joh on Drilling Engineer Attachments cc: CD4-320 Well File /Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1700 Liz Galiunas ATO 1702 Doug Knock ATO 1792 Lanston Chin Kuukpik Corporation k ~ 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^ Waiver L] Other LJ Alter casing ^ Repair well ^ Plug Pertorations ^ Stimulate ~ Time Extension ^ Change approved program ^~ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, inc. Development ~ ~ Exploratory ^ 206-055 ., 3. Address: Stratigraphic ^ Service ^ 6. API Number. P. O. Box 100360, Anchorage, Alaska 99510 50-103-20531-00 7. KB Elevation (ft): 9. Well Name and Number: 55.1 ft BPMSL CD4-320 ° 8. Property Designation: 10. Field/Pools(s): ADL 380077, 384211 / ALK 380077 Nanuq Kuparuk Oil Pool 11. PRESENT WELL CONDIT ION SUMMARY otal Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft)~ Effective Depth TVD (ft): ~ Plugs (measured) Junk (measured): 8079' ~ ~`j9oZ So a q 6 9y'L Casing Length Size MD ND Burst Collapse Structural Conductor 80' 16" 114' 114' Surface 2472 9.625" 2509 2390' Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None None None None Packers and SSSV Type: Packers and SSSV MD (ft): None None 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch ^ Exploratory ^ Development Q Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 7/12/2006 Oil Q Gas ^ Plugged ~ Abandoned ^ 16. Verbal Approval: D~ te~7~ 2/06 WAG ^ GINJ ^ WINJ [] WDSPL ^ ~ Commission Representative: T. Maunder ~~°T~`'"~- ~ ~ C 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact V. Johnson Printed Name p. Mazzolini Exploration Team Lead Signature ~ ,~ y, _7°y1,c~ I~~ Phone 263-4603 Date 'j ~~ (~~Q COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: a `^'~ Plug Integrity U BOP Test U Mechanical Integrity Test U other. ~~.~ Q\~ ~~'~:7t~e Subsequent Form Required: Q.~ Approved by: ' Form 10-403 Revised 7/2005 ~ ~ ~ ~ ~ ~ A f e ~ ~ ! ~~ ,. STATE OF ALASKA ~a-~ ~U~ ~ '~ Z~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALAiaska oit & Gas Cans. Cofnmission Anchorage 20 AAC 25.280 Location Clearance LJ v~`~~~~~CrJ~'~S ~Ov~~~~ ~~~F o~ ~~~ APPROVED BY TONER THE COMMISSION R ~F~ ~u~ ~ ~ 2046 Date: 7• Lo° °~. ~~~ /C.~6 SUBMIT IN DUPLICATE ; CD4-320 Procedure 1. POOH with 7" casing string. 2. Pick up 3-1/2" tubing stinger and run in hole on drillpipe to +/- 8019' MD. 3. Pump +/- 500 ft MD balanced bottom isolation plug (15.8 ppg G) (top Kuparuk Cat 7906' MD, well CD4- 320PB1 TD at 8019' MD) 4. Pick up to 7519' MD and circulate hole clean. 5. Pull out to +/- 7145' MD and spot a +/- 400ft MD hi vis pill 6. Pick up to +/- 6745' MD and pump a +/- 500 ft MD (isolation plug, 15.8 ppg) to isolate the Nanuq interval. 7. Pick up to 6245' MD and circulate hole clean. 8. Pull out to +/- 5100' MD and spot a +/- 400 ft MD hi vis pill 9. Pick up to +/- 4700' MD and pump a +/- 500 ft MD (abandonment plug, 17 ppg) to isolate the Nanuq interval. 10. Pick up to 4200' MD and circulate hole clean. 11. Pull out of hole and lay down tubing stinger. 12. Pick up an 8-3/4" rotary steerable drilling BHA and run in hole. 13. Tag top isolation plug and dress top of plug. 14. Kick off from plug and drill intermediate hole to landing point in the Kuparuk. 15. Wipe the hole and pull out with the drilling BHA. 16. Run and cement 7" casing. 17. BOPE test to 5000 psi. 18. Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.0 ppg EMW. 19. Drill 6-1 /8" horizontal section to well TD (LWD Program: GR/RES/PWD). 20. Circulate the hole clean and pull out of hole. 21. Run lower completion with slotted liner and liner hanger. 22. Run 4-%2, 12.6#, L-80 tubing with SCSSSV, gas lift mandrels, packer and stinger assembly. Sting in, space out and land hanger. 23. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 24. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 25. Circulate tubing to diesel and install freeze protection in the annulus. 26. Drop ball and rod, set packer and test tubing and annulus to 3500 psi / 30 mins. 27. Set BPV and secure well. Move rig off. • Abandonment plug schematic: • Updated 07/12/06 15:00 I~ Wellhead 16" Conductor to 114' 9-5/8" 40 ppf J-80 BTCM Surface Casing 2509' MD / 2378' ND 10.5 ppg drilling mud KOP 4500' MD' ~ ~~'~~",~s~~~'~`'` 500 ft plus#3:500' (Top at+f_4200' MD >€„;l~~f '!! / 3955' ND). 17 ooa 4700' MD ~i iiii~~:i!:~~~~~~~ ;i" ~..~30 bbls ~Hi~Vis. 4 400 ft 5100' MD pin 11.3 ppg mud Top KUparuk Reservoir at ~~ ~ ~ `""` ~~~ `~"~ `" 500 ft plug #1 ' +~- 500' (T~~ +/- 7519' MD +/-7g06 MD / 6985' ND `~ "`~.,~~,,~~..~'~ ~ 16888' ND ).15.8 ooa CD4-320 P61 TD at +/- 8019' MD / 6992' TVD RE: CD4-320 ~ • Subject: RE: CD4-,?0 From: "Johnson, Vcrn" <-~%l'Ill.lohusoi~~u'conocophillips.com> Date: ~1on, "~4 Jul ~Otb 16: ~9:~ ~ -U800 "['o: 7~homas 1~launder °~tom maunder(ci?admin.statc.ak.us~ Tom, The bottom hole location for the heel (7" casing pt) of CD4-320, after plugging back and sidetracking the well is at 5957776',378700' (ASP4 NAD27) This is 181' from the location described in the permit to drill. The location of the final target is the same in the permit as in the current drilling plan. Let me know if you need further information. Vern Johnson -----Original Message----- From: Thomas Maunder [mailto;tom maurderc~admin.state.ak.us] Sent: Monday, July 24, 2006 12:25 PM To: Johnson, Vern Subject: CD4-320 Vern, Would you please respond regarding any changes of the BHL due to plugging back the intermediate hole on this well? Thanks in advance, Tom Maunder, PE AOGCC 1 of 1 7/25/2006 7:20 AM ~ STATE OF ALASKA '~ ~~iosioa OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: iirn rG~~~:~3~adn:in.state.a>i.~~r aoq~" pr~.Ed,oe b~v~ad:~n.state.ak.us bol; leckenstein;~adrni:~.state.a>~.u~~ Contractor: Doyon Rig No.: 19 DATE: 7/19/2006 Rig Rep.: Krupa/Grazulis Rig Phone: 670-4302 Rig Fax: 670-4303 Operator: Conoco Phillips Alaska Op. Phone: 670-4300 Op. Fax: 670-4301 Rep.: Lutrick/Mickey Field/Unit & Well No.: Colville Rv CD4-320 PTD # 2 Operation: Drlg: x Test: Initial: Test Pressure: Rams: 250/5000 MISC. INSPECTIONS: Test Result Location Gen.: P Well Sign Housekeeping: P Drl. Rig PTD On Location P Hazard Sec. Standing Order Posted P BOP STACK: Quantity Size Test Result Annular Preventer 1 13-5/8 P Pipe Rams 1 3-1/2x 6 P Lower Pipe Rams 1 3-1/2x 6 P Blind Rams 1 blinds P Choke Ln. Valves 1 3-1/8 P HCR Valves 2 3-1/8 P Kill Line Valves 1 3-1/8 P Check Valve 0 NA Workover: Weekly: x Annular: 250/3500 Explor.: Bi-Weekly Valves: 250/5000 TEST DATA FLOOR SAFETY VALVES: Test Result Quantity Test Result P Upper Ketty 1 P P Lower Kelly 1 P P Ball Type 1 P Inside BOP 1 P CHOKE MANIFOLD: Quantity Test Result No. Valves 16 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 3050 P Pressure After Closure 1500 P MUD SYSTEM: Visual Test Alarm Test 200 psi Attained 24 sec P Trip Tank P P Full Pressure Attained 3 min 05 sec P Pit Level Indicators P P Blind Switch Covers: All stations P Flow Indicator P P Nitgn. Bottles (avg): 4@ psi 2100 Meth Gas Detector P P H2S Gas Detector P P Test Results Number of Failures: 0 Test Time: 4 Hours Components tested 28 Repair or replaceme nt of equip ment will be made within Immediately days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: dim reo~q~~adn:i:~.stute.ak.us Remarks: Good test 24 HOUR NOTICE GIVEN YES X NO Waived By Chuck Scheve Date 07/17/06 Time 9:OOam Witness Grazulis/Mickey Test start Finish 4 BOP Test (for rigs) BFL 11/09/04 Doyon19 7-19-06 CD4-320.x1s r RE: CD4-320 sidetrack operations • • Subje~~t: RE: CI~4-320 sidetrack operations Fro~r~: "Johnson, Vern" <Vern.Johnson(~~'conocophillips.com> Date.: Thu, l>> .(ul ?006 ll:28:2h -O~UO 'I'o: Thomas l~~launder °~~tom n~aunder(u~admin.state.ak.us> CC: "~~lvord. Chip" ~ ~Chip.Alvord~~i cot~ocophillips.con>>, "Galiunas, Elizabeth C" ~~ Elizabeth.('.Galiunas~~zconocophillips.a~n~=. "Noel, Brian" ~~~Brian.Noel~~i?eoiwcophillips.com=~~ Tom, ~~~-C~~S Thanks for the note. Plug setting operations have progressed as planned with the exception of the setting depth of the bottom plug. As discussed this marning, we were unable to get a 3-112" tubing stinger past +J- 7570' MD (near the same location the 7" casing stopped}. The bottom 500' isolation plug was pumped at that depth, which is above the Kuparuk sand, but below the Nanuq sand, The subsequent isolation plug {for the Nanuq) and kick off plug setting operations went as planned. Let me know if you have any questions or need further information. Vern Johnson 265-6081 -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Thursday, July 13, 2006 7:22 AM To: Johnson, Vern Cc: Alvord, Chip; Galiunas, Elizabeth C; Noel, Brian; Doyon 19 Company Man; Mike Martin; Martin, Michael W; Steve Davies; Dave Roby Subject: Re: CD4-320 sidetrack operations Vern, et al, The plugging plan looks appropriate. With regard to tagging the two deep plugs, that is acceptable provided there are no problems experienced putting them in place. I will look forward to the sundry. Tom Maunder, PE AOGCC Johnson, Vern wrote, On 7/12/2006 2:15 PM: Tom, As discussed this afternoon, we are preparing to plug back and sidetrack CD4-320 with Doyon 19. After drilling 8-3/4" intermediate hole into the Kuparuk reservoir, we experienced problems in the Kalubik shale with the drilling BHA. We attempted to run 7" casing but were not able to get past this section (+/- 7600' MD / 6919' TVD). The decision was made to pull and lay down 7" casing, plug back the old hole and redrill the intermediate hole section into the Kuparuk. See the attached schematic showing the proposed plug back plan. Since we plan to kick off a cement plug with a drilling BHA, it is requested that the plug tagging requirement under 20 ACC 25.112 (g) be waived. We are currently working on a 10-403 form, which we expect to submit this afternoon. Please let me know if you need further information. 7/17/2006 10:12 AM • • ~~ ~~~~ Updated 07/12/06 14:00 ~ Wellhead 16" Conductor to 114' -5/8" 40 ppf J-80 BTCM Surface Casing L 2509' MD / 2378' TVD 11.3 PP9 ii mud I 6245' MD n Top Nanuq Sand +/-6500 MD / 6157 TVD ~~ Pluq #2 : SOO' (Top at +/_ seas' MD Bottom Nanua Sand +/-6645 MD / 6286' TVD ~[IJ~ #~ 500 ft / 5918 TVD). 15.8 ooa. 6745' MD ~ ~ --~- 30 bbls Hi Vis 7145' MD Pill ~ 400 ft 11.3 PP9 Pluq #1 : +/- 500' (Too ~ +/- 7519' MD 16888' TVD ). 15.8 ooa STATE OF ALASKA 11/09!04 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: dim regg~;yadrr:i:~.state.ak.u~• 5aoq~" pr~.Ed;oe h~, v~{~ya. fdy~:~n.s~taryte.iaS l`.us ff~%}' t~Civ~c~ft~Lv~'it'~~t.~tef 2:t!t. ~tC~et~.i2!l. l~i ~.' Contractor: Doyon Rig No.: 19 DATE: 7/4/2006 Rig Rep.: Welsh/Lupton Rig Phone: 670-4302 Rig Fax: 670-4303 Operator: Conoco Phillips Alaska Op. Phone: 670-4300 Op. Fax: 670-4301 Rep.: Burley/Hill Field/Unit & Well No.: Colville Rv CD4-320 PTD # 206-055 Operation: Drlg: x Workover: Explor.: Test: Initial: x Weekly: Bi-Weekly Test Pressure: Rams: 250/5000 Annular: 250/3500 Valves: 250/5000 TEST DATA MISC. INSPECTIONS: Test Result ', Location Gen.: P Well Sign Housekeeping: P Drl. Rig PTD On Location P Hazard Sec. Standing Order Posted P BOP STACK: Quantity Size Annular Preventer 1 13-5/8 P ', Pipe Rams 1 3-1/2x 6 P Lower Pipe Rams 1 3-1/2x 6 P Blind Rams 1 blinds P Choke Ln. Valves 1 3-1/8 P HCR Valves 2 3-1/8 P Kill Line Valves 1 3-1/8 P Check Valve 0 NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P FLOOR SAFETY VALVES: Test Result Quantity Test Resu P Upper Kelly 1 P P Lower Kelly 1 P P Balt Type 1 P Inside BOP 1 P CHOKE MANIFOLD: Quantity Test Resu No. Valves 16 P Manual Chokes 1 P Hydraulic Chokes 1 P Test Result ACCUMULATOR SYSTEM: Time/Pressure Test Resu System Pressure 2900 P Pressure After Closure 1600 P 200 psi Attained 27 sec P Full Pressure Attained 3 min 14 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4@ psi 2000 Test Results Number of Failures: 0 Test Time: 5.5 Hours Components tested 28 Repair or replacement of equipment will be made within Immediately days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Supervises at: ~irn r~:q~„~~adrni:~.state.ak.us• Remarks: Good test 24 HOUR NOTICE GIVEN YES X NO Date 07/02/06 Time 9:OOam Waived By Not waived Test start Finish Witness BOP Test (for rigs) BFL 11/09/04 Doyon19 7-4-06 CD4-320.x1s onocoPhilli S Casing Detail C ~ 9 5/8"Surface Casino 24 fo -O.S~' Well: CD4 - 320 Date: 7/3/2006 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS 89 36 Jts 3 to 64 62 Jts Doyon 19 RKB to Landing Ring FMC Gen V Hanger 9 5/8" 40# L-80 MBTC Csg . 2.18 2390.22 1 46 36.89 39.07 29 2429 Weatherford Float Collar . . Jts 1 to 2 2 Jts 9 5/8" 40# L-80 MBTC Csg Ray Oil tools (Silver Bullet) 76.10 2.15 2430.75 2506.85 00 2509 . TD 12 1/4" Surface Hole 2519.00 12 114" Hole @ 2519' MD / 2387' TVD 9 5/8" Shoe @ 2509' MD / 2378 ' TVD ~ ~~ r~. ca- ' AZ RUN TOTAL 38 BOWSPRING CENTRALIZERS - 1 per jt on Jt #1 - #14 (stop ring on Jt #1 & 2 ) and over collars on jts# 16, 18, 20, 22, 24, 26, 28, 30, 32, 34, 36, 38, 40, 42, 44, 46,.48, 50, 52, 54, 56, 58,60,62 68 joints in the pipe shed. Run 64 joints Last 4 joints stay out Use Best-o-Life 2000 i e do e MU torque -- 8500 ft/lbs Remarks: Up Wt - 165k Dn Wt - 143k Block Wt - 75k Supervisor: D. Burley / D. Mickey Cement Detail Report CD4-320 Surface Casing Cement goo ~.areyv~ y >rimary Job Type DRILLING 10136460 6/30/2006 _ _ DRILLING ORIGINAL ------ -- - -- -- --- Welibore Name ,ement Details __ _ _ _ _ __ _ ----- ------- - -- Cementing Start Date Cementing End Date CD4-320 )escription 7/3/200615:15 7/3/200617:40 Surface Casing Cement Comment - --- ___ _ _ - _ _ __ _ - Cement Stages _ _ - - _ - _ _.- __ _ -- --- --- ------- -_- -- -- - - - - - Full Retum? Cmnt Rtm (••• Top Plug? Btm Plug? Stake #_1- _ _ _ __ _--- - - - ---- - fop (~B) -- -- -- -- Bottom (FtK6) 94.0 Yes Yes Descnptaon Objective 2,509.0 Yes 37.0 Rotated? Pipe RPM (rpm) Surface Casing Cement ) (p ) Reci ~ stroke (ft) O (start) (bbllmin) Q (end) (bbl/min) Q (avg} (bbUmin) P (final si P (bump) (psi) Yes 20.00 No 590.0 1,100.0 8 4 __ .. 7. Death Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment - - - - - - - - - -- - Cement Flu+ds & - Additives - - - - - - -- - - _ -- -- - - - -- - - - V e Pumped bbl olum - -- 1 - ) _. - Fluid ___ - _ - - - - - - Estrmated Top (ftKB) - - Est etm (ftKB) - Amount (sacks) Class G 272.0 Fluid Type Flwd Descnption 37.0 2,009.0 ~ (c ) it Vi Thickening Time (hrs) CmprStr 1 (psi) Lead Cement Mix H2O Ratio (gal/sa... Free Water (%) Density (Iblgal) p y scos Plastic Yield (fYlsack) 10.70 4.45 20.15 Concentration Conc Unit label Additives Type - Additive - _ - - - - - - - - -- -- - -- - - - - - - - - - - - - - Amount (sacks) - - - -Glass - --- Volume Pumped (bbl) Fluid _ - - - - - - -- - Fluid Description - - Estimated Top (ftKB) Est Btm2 0 91 238 G 48.0 Fluid Type 2,009.0 0 Plastic Viscosity (cp) Thickening Time (hrs) Cmprstr 1 (psi) fYlsack) Mix H2O Ratio (galfsa... Free Water (%) Density (Iblgal) 1 17 1 16 5.10 Concentration Conc Unit label Additives Tvoe 7 !-J Y . ._ , Daily Drilling Report ; ' ., CD4-320 f . f « • Report Date: 7/3/2006 Report Number Days From Spud (days) Depth Start (ftK6) Depth End (ftK6) Depth Progress (ft) Wellbore 00 CD4-320 0 4 3.00 . 2,519.0 2,519.0 Ta et De th ftK6 Well Type ~ p Spud Date Contractor Rig Name/No 19 Field Name 14,213.0 NANUQ KUPARUK Development 7/1/2006 DOYON Total AFE Amount Average ROP (ftlhr) AFE / RFE / Maint.# 925.00 285 6 10136460 , , Next Casing OD (in) Next Casing Set Depth (ftK6) Last Casing String 8,220.00 Surface, 2,509.OftK6 7 Daily Cost Total Cummulative Cost Ops and Depth @ Morning Report 276,987.92 914,616.89 Testing BOPE Daily Mud Cost Cummulative Mud Cost 24hr Forecast 5,408.92 46,898.89 Finish BOP test - MU BHA - RIH -Drill Last 24hr Summary POOH on TT - LD BHA - RU, Run & cmt 9 5/8" csg - RD riser NU wellhead & BOPE Head Count General Remarks Weather 50.0 _....- - -- - - - 3upervtsoi Time - _ - - - - - -- - - -- _ --- - - Dave Burley - ail U rNISG( y ~ P Larry Hill - - - - - - - - - - Rig SupeNisor - _ _- - - - --- - - - - I - , - i_Ttme Lo_g - ~. i _ ~ re ~ ~ ~ b~~-Cod ii ' ~ __ _ _ - I ~ Tin °~ 1 De Ptr tart D {. LL. Er.d~ Comm70pe~at~on _ _ _ ' RkB) I _ _ _ _- nr e~ _ e N T~ Tib7fodr ~ ~ ~ 7m llur .t. 1 F'h; ,c Ti ~F _. ~( ~ ..__ 459' to 891' -flow ckeck well - stafic TT from 2 POOH 00:00 02:45 2.75 SURFAC DRILL TRiP , on P 2,459.0 73.0 POOH to 73' -stood back hwdp and collars D 0 0.0 Down load MWD - LD MWD collars - XO -stab -float sub - P 73 02:45 05:00 2.25 SURFAC DRILL PUL . motor and bit -clear tools from rig floor. D 0 0.0 Rig up to run casing: Lay down drilling bails - MU fill up tool - P 0 05:00 07:30 2.50 SURFAC CASING RUR . pick up casing bails - RU 9 5/8" slips ,elevators and power tongs -ready stabbing board 07:30 07:45 0.25 SURFAC CASING SFTY P 0.0 0.0 Held Prejob safety and Opts meeting with crew 9 5/8" 40# L-80 MBTC csg as follows: Float shoe (Ray Oil R 07:45 11:15 3.50 SURFAC CASING RNCS un P 0.0 1,735.0 Tools silver bullet) 2 jts csg -Float collar (Weatherford) 2 jts. csg (first 4 connections made up w/ BakerLoc -filled pipe & checked floats) 41 jts csg to 1735' (washed down from 510' to 540', tight spot at 525') 25 SURFAC 0 CASING CIRC P 1,735.0 1,735.0 Stage pumps up to 5.5 bpm - CBU -FCP 320 psi - PUW 132K . 11:15 11:30 SOW 120K CS 465.0 Continue running 9 5/8" - 40# L-80 MBTC csg f/ 1735' to 2465' - 0 2 735 P 1 11:30 13:00 1.50 SURFAC CASING RN , . , 19 jts (64 jts total ran) - PU FMC csg hanger & landing jt. -Land w/ fluted mandle hanger on landing ring w/ float shoe @ cs g 2509' 8~ float collar @ 2429' 13:00 13:30 0.50 SURFAC CEMENT PULD P 2,465.0 2,5D9.0 LD Frank's fill up tool -Blow down TD - MU cmt head & lines e pump up to 7.0 bbl/min -Circulate n -Sta l ti i 13:30 15:15 1.75 SURFAC CEMENT CIRC g a o rcu P 2,509.0 2,509.0 Establish c 8~ condition hole 8~ mud for cmt job - ICP 360 psi FCP 310 psi (circulated 810 bbls) PJSM Latest BOP Test Data -- ----- -- Gate -._-.. .- -~-- -------- ------------ --~- -- Page 1/3 Report Printed: 715/200 i Daily Drilling Report CD4-320 Report Date: 7l3l2006 ._- - - - , rime Loci _ _ _ _ _- - - -- - - - - --- - ~ ~ J ~ stn ~t- rt I o~rn Fnd , S rt -( Cod { ~ Ili n --- __ t C mm~!)Fxrat m !f'KB (fiK8) ~ iV T - - Tun ~ iuuF ! ~ OF C~xJ I Oc ~ l,oj= P o~tmr i Fr'~~ ~_ ~~ ' _ - ~ -_ - - _. _ - _ ~ l ib t ~dc I -- 0 Cement 9 5/8" csg as follows .Pumped 40 bbls Biozan water 0 2 509 NT DISP P CEME 15.15 17:45 2.50 SURFAC . 2,505. w/ nut plug as marker -Pumped 5 bbls water w/ Dowell - Tested lines to 2600 psi -Dropped btm plug - Pumped 50 bbls MudPush @ 10.5 ppg -Mixed i3< pumped 272 bbls lead slurry (ASL) @ 10.7 ppg (` Observed nut plug marker @ shakers w/ 253 bbls lead pumped -pumped down surge can) Pumped 48 bbls tail slurry (Class G w/ additives) @ 15.8 ppg -Dropped top plug w/ 20 bbls water f/ Dowell -Switched over to rig pumps & displaced cmt w/ 163.4 bbls 9.8 ppg water base mud - Displaced @ 8.1 bbls/min for first 120 bbls -slowed pump to 6.0 bbls/min for 25 bbls - 4.0 bbls/min for last 8.4 bbls - Bumped plug w/ 1100 psi (prep bump pressure 590 psi) Check float (held OK) CIP @ 17:40 hrs. -.Full c #iroughout job w/ 94 bbls 10.7 ppg cmt returns to surface -reciprocated pipe vrhit~ circulating & througfi cerraant job until last 90 bbls of displacement 17:45 18:30 0.75 SURFAC CEMENT PRTS P 0.0 0.0 Rig up & test 9 5/8" casing to 2500 psi for 30 mins. -Blow down lines - RD P 0 0.0 RD cmt head - LD landing jt -clear rig floor of tools 0 18:30 19:30 1.00 SURFAC CEMENT PULD P . 0 LD surface riser -Remove FMC starting head 0 0 0 19:30 21:30 2.00 SURFAC DRILL PULD . . 0 Install FMC Alpine Gen II wellhead & test seals to 1000 psi - 0 0 0 21:30 00:00 2.50 SURFAC DRILL OTHR P . . NU BOPE LMud Check Data -- - ~ - - - - t ~- - ~T ~nr _tt ~n~ S lid ,o ~ - ~ - ~ i~rr{~ Feu - r~, o o c R 1'P (~Ic l 1 ( ns) a;lom) cl-( Cnn) _-- ~ (It Ut UG,.') 7 ILf ~Cr-tt (~Gr11 G'1fl'; ~ MC7 ;lb(obll~ ~ P _- IfP I6`170 ^e ~-'Jept1~[ttP:P) G r~ il~_ ail Vs'~.1-ti FVt -ic ('~pl U -- 2s190 Sao ~4} ibo ~Sput] I ~ . ) ( _ - 7.7 18 OOO 6.000 i 14.000 20.000 27.5 ~ ~ I II ~ ---- - - - - -- - - ~ -- _- - - - In~ectiorrFlutd- --_ i - - - 1-1_~Id .~ur,e - - - _ ti_~r,r»t;nn --- -- - _ N__,F- - - - ~ Faam~Lease(bb1)` _ -_ ~--- - - -. - -~ _. freeze perotect CD4-318 Diesel 70.0 CD4-318 0 CD4-318 (flush CD4-318 150 Water . 0 CD4-318 f/ CD4-320 56 --- Water Based Mud . -- - -- - ~ -- -- _ _ _ _ _ Drill Stringy BHA No 2 - Steerabie! Bit Run N~. 2 - S 3/4in, Nalliburton Sccuri DE3S , FSF25b3 , 1083549.1 n) (1000... ll String Wt (10001b~ WOB (max) (100... WOB (mi C Bit D " 0 u ) (AD Depth In (itK6) Depth Out (ftK6) TFA (incl Noz) (ins) Nozzles (132 68 0 2,519.0 2,539.0 0.98 16/16/16/16/16 --- Drill Strin r g ComQonents _ _ _- -- ItcmDescrfptwn _ __ - T '. O~ Unj I -- ID (n:) - ~7oF Conrj Sz {inj~. - T,~ Threw -- - - ~ ~ m Len (tt) s J 1 _ - - - - - - 7600 Geo Pilot __ - - - - - 6 3/4 4.680 4 1/2 NC 50 25.0 34 22 1 NMDC Pony Flex Collar 6 3/4 1.920 4 1/2 NC 50 42 36 1 Stabilizer (Non Mag) ILS 6 3/4 1.900 4 1/2 NC 50 . 52 57 1 MWD (Dir ~ Logging) 6 3/4 1.900 4 1/2 NC 50 . 73 59 1 Stabilizer (Non Mag) 6 3/4 1.900 4 1/2 NC 50 . 71 66 1 MWD (Dir & Logging) H-Cim 6 314 1.900 4 1/2 NC 50 . 70 76 1 MWD (Directional) T-M 6 3/4 1.900 4 1/2 4 1/2 NC 50 NC 50 . 78.93 1 Float Sub NM 6 1/2 6 314 3.500 2.813 4 1/2 NC 50 170.89 3 NMDC 5 3.000 4 1/2 NC 50 262.67 3 HWDP 6 1/4 250 2 4 1/2 NC 50 295.36 1 Drilling Jars -Mechanical 5 . 3.000 4 1/2 NC 50 716.40 14 HWDP 5 4.276 4 1/2 NC 50 747.98 1 Drill Pipe 8 3/4 2.875 4 1/2 NC 50 753.98 1 Ghost Reamers 5 4.276 4 112 NC 50 1,800.45 33 Drill Pipe 8 3/4 2 875 4 1/2 NC 50 1,807.35 1 Ghost Reamer 5 4.276 4 1/2 NC 50 1 870.84 2 Drill Pipe 6 1/2 2.500 4 XT 39 1,872.2C XO Sub Page 213 Report Printed: 7/5/200E • ~\ s Daily Drilling Report CD4-320 Report Date: 7!312006 -_- Drillin Parameters _ - ~- ~- _ - - rir~ ~ ; d r - - r - - - ~~~ ~,u ~ T o~~~x->- ~ --- -~ ~ I ~I ~ ~~ ~,3 ~,~ n u ~a - (nrs r-,-n ~ Stem (fiKBj ~ End (ftKB) ~ _ _ - _1_ C~ ~ Tlm t ~ I LQeotr ~`Ll ~- aP~ol ~ )E pb7 ~f PM t~Fu~ - _ ~ 1 -- -~ - ---- _- - 50 2G 0 ~~ ~ I SP-F CF~iI - _- 820 OI ' ~ ~ 1,000.01 --,- - - ~ ~ ~ 0.001 S~Oi -- - - - --- - _ - - - - - 2,519-O 0.00 2,519-0, -.. - ~~ - i Wellbores _ _ _ - - _- - - -_ - - - - -- - - - - - - -- Welltwre APIIUWY - -- Welibore Name ~ 100 32053 5 1 - GD4 320 _ - - {in) y ~ ~ brce - e 1 - - - - ~ - -~a sun'jnx_~, A~t'rop (ftK6) _ { - - - - - - - - - 0~ 3r~ na~r ~ - - Cn~ rJ - 6 -~7I15~200 - - ate - - - - , , -- - -' - - - ~ - - COND1 - - -- 36.0 114.0 2/14/2006 ~ 2/200 i 12 1/4 ~ ~ 114.0 2,519.0 7/1/2006 ~ - - - SURFAC - -- - - - _ - - -- Cemen t _ - - - - - - - - - - - - - - - - --- - - - - - - - -- _ Surface Casi~Cement -Started 7/3/2006 Cement Evaluation Results CD4-320 Surface, 2,509.OftKB 1 Surface Casing Cement (Lead Cement (G G 37.0 I 2,509 0 ~-4 ~ 590 0 I ~s~ v 1~1J ~ o-~sity ~IWgaU ~ ~,eia jft 7s -s~j ~+r_~~fiKS1 ~ - =lsrBtingtttcej- _ ~ 344 212.0 10.70 4.45 - - 37.0 2,009.0 238 48.01 1.171 1.16 2,009.0 2,009.0 Page 3/3 Report Printed: 7/5/2001 PRESSURE IN i EGRITY TEST CONOCOPHILLIPS Alaska, Inc. Vell Name: CD4-320 Rig: Doyon 19 Date: 7/3/2006 Volume Input Volume/Str oke Pum Rate: )tilling Supervisor: D. Burley / D. Mickey/L. Hill Pump used: #2 Mud Pump ~ strokes ~ 0.1000 Bbls/strk ~ 8.0 Strk/min ~ Type of Test: Casing Shoe Test LOT/FII" ~ Pumping down annulus and DP. ~ Casin Test Pressure In te tit Test sole Size: 8-3/4" ~ Casin Shoe De th Hole De th Pum in Shu t-in Pum in Shu t-in RKB-CHF: 34.7 Ft 2,509 Ft-MD 2,378 Ft-TVD 2,539 Ft-MD 2,405 Ft-TVD Strks si Min si Strks si Min si Casing Size and Description: 9-5/8" 4o#/Ft L-so BTC ~ 0 0 0 2520 0 0 0 940 Casin Test Pressure Inte tit Tes t 1 160 1 2520 1 90 0.25 820 Mud Weight: 9.8 ppg Mud Weight: 9.7 ppg 2 310 2 2520 2 200 0.5 625 Mud 10 min Gel: 14.0 Lb1100 Ft2 Mud 10 min Gel: 16.0 Lb/100 Ft2 3 450 3 2520 3 340 1 590 Test Pressure: 2 500 psi Rotating Weight: 125,000 Lbs 4 580 4 2520 4 470 1.5 590 ~ Rotating Weight: , 75,000 Lbs Blocks/Top Drive Weight: 75,000 Lbs 5 710 5 2510 5 600 2 590 Blocks/Top Drive Weight: 75,000 Lbs Desired PIT EMW: 18.0 ppg 6 830 6 2510 6 725 2.5 588 Estimates for Test: 1.8 bbls Estimates for Test: 1026 si 0.7 bbls 7 940 7 2510 7 830 3 585 ~ ~- 8 1050 8 2510 8 920 3.5 585 EMW =Leak-off Pressure + Mud Weight = 920 + 9 PIT 15 Second 9 1150 9 2510 9 950 4 582 581 0.052 x TVD 0.052 x 2378 Shut-in Pressure, si 10 1250 10 2510 10 980 4.5 EMW at 2509 Ft-MD 2378 Ft-ND) = 17.1 ~ ~ 820 11 1340 15 2500 11 980 5 t t h Id 12 1450 20 2500 12 950 5 5 0 1 2 Barrels ~a~CASING TEST -'-f'~ LEAK-OFF TEST Lost 20 psi dunng es , e 99.2% of test pressure. 3 0 5 10 15 20 25 30 Shut-In time, Minutes O PIT Point 13 1570 25 2500 6 17 e 580 5 ume • • ConoeoPhilli S Casing Detail 7 Casing Wetl: CD4-320 Date: 7/17/2006 DEPTH ENGTH TOPS Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN L 65 34 Doyon 19 RKB to Lower lock down FMC Gen V Hanger . 3.33 72 8018 34.65 98 37 Jts 3 to 189 187 Jts 7 " 26# L-80 BTCM Csg Halliburton Float Collar . .99 . 8056.70 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg Ray Oil Tools Float Shoe 85.33 2.06 8057.69 8143.02 08 8145 . " 00 8155 Hole TD 8 3/4 . 8 314" Hole TD @ 8155' MD 16992' TVD 7" Shoe @ 8145.08' MD 16992' TVD Total Centralizers: 44 Straight blade centralizer one per jt on jts # 1-14 Straight blade centralizer one per jt jts. # 130,131, 132, Straight blade centralizer one per jt on every other joint Starting @ # 134 to # 186 Top Kuparuk - 8030' MD - 6990' TVD 204 joints in shed - 189 total jts. to run Last 15 jts. out Use Run 8~ Seal i e do e Average MU torque 6500 ft/Ibs Remarks: Up Wt - 265k Dn Wt-185k Block Wt - 75k .Sunervisor_' D_ Lutrick / L. Hill • Cement Detail Report CD4-320 Production Casing Cement Primary Job Type "'"~ "-~"' -' DRILLING ORIGINAL DRILLING 10136460 6/30/200 ---------- ----------- --- -- 'Cement Details'': _ - - - - --- ---- - -- ---- - Description Cementing Start Oate Cementing End Date Wellbore Name CD4-320 Production Casing Cement 7/18/2006 19:20 7/18/2006 21:24 Comment _ - _ _ - - - - - - ---- - - - -- - - --- ~CementSta es --- - -- -- _ _ _ ___ -- -- _ -- --- - -- _ i Stake # 1 _ - - - -- - -_ To ftKB - - --Bottom (ttK6) __ - - -- -Full Return? GmM Rtm (... Top Plug? Btm Plug? Description Objective p ( ) $,145.0 Yes 0.0 Yes Yes Production Casing 6,000.0 Cement Rotated? Pipe RPM (rpm) P (bump) (psi) Recip? Stroke (ft) No Q (start) (bbllmin) O (end) (bbl/min) O (avg) (bbllmin) P (final) (psi) 1,670.0 No 4 2 4 1,200.0 ne~•ti ai~~~ milled Out To (ftK6) Drill Out Diameter (in) CementEluids & Additives -- - - - - - - -- - - - _ _ _ ___ - _ __ Fluid _ _ -_- - - - -- - - - - ----- - - - --- - -'Amount sacks Class - - - - -Volume Pumped (bbl) Flwd Type Flwd Description Estimated Top (ftKB) Est Btm (ftKB) (405) G 89.0 Tail Cement 6,000.0 8,145.0 Mix H2O Ratio allsa... Free Water (%) Density (Iblgal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) .Yield (ft'Isack) (g 15.80 1.16 5.09 Additives T ~e Concentration Conc Unit label 1/1 n s - Daily Drilling Report CD4-320 ...~ ~~ Report Date: 7/18/2006 Report Number Days From Spud (days) Depth Start (ftKB) Depth End (ftK6) Depth Progress (ft) Wellbore 00 CD4-320 0 19 18.00 8,155.0 . g 155.0 Target Depth (ftKB) Well Type Spud Date Contractor Ri NamelNo Field Name g 19 NANUO KUPARUK Develo ment 14,213.0 p 7/1/2006 DOYON Total AFE Amount Average ROP (ft/hr) AFE / RFE / Maint# 925.00 285 6 10136460 , , Next Casing Set Depth (ftK6) Last Casing String Next Casing OD (in) Intermediate, 8,145.1ftK6 Daily Cost Total Cummulative Cost Ops and Depth @ Morning Report 323,474.61 3,950,629.20 MU BHA Daily Mud Cost Cummulative Mud Cost 24hr Forecast 4,795.61 468,172.20 RIH - S&C DL - CO shoe trk -FIT -Drill Last 24hr Summary Run 7" csg to 8145' -Circ & condition for cmt job - Cmt 7" csg -Test csg -Set i~ test pack-off Head Count RU 8 ~ General Remarks Weather 50/ 45 wG SW @ 14 mph - - - 53.0 -- - -- - -- . - - - - - ' - - --- _. Supervisor': --- -- - -- - - -- - - - -- -------- - roe ---- - --- -- -- - -J -- - - - - IRig Supervisor Gcnnie Lu~rirk 1 _ _ Rig Supervisor - - - - ---------- Don P~lickey - - - 1 T{me Lod _ - _~ -- r - ~ Time ! _ - -- - - - - i Dc p!h S ~rt ~D { r tnc~- ~ .3!1 ~ E ld ~ ~~,~ i n - ~r,~~ ~n~~i rind _ ~, i~,. c~~+~ .. ~~~~,h codes P ra-1 ! Tr<i cod. - inr,ej 1-- - 0 0 _ _ (ttr e? OA Finish change upper pipe rams to r .Test 7" rams to 250-5000 00:00 01:15 1.25 INTRMI WELCTL BOPE T Conditions . psi. Pull test plug. Install thin wear bushing. 01:15 01:45 0.50 INTRMI CASING RURD T Hole 0.0 0.0 RU csg equipment. PJSM. Conditions 0 0 0 RIH w/ 80 jts 7" 26# L-80 BTCM csg to 3435'. 435 3 01:45 05:00 3.251NTRM1 CASING RNCS T Conditions . . , T Hole 435.0 3 3,435.0 Circulate 1 csg volume. Stage pumps to 5 bpm at 430 psi. 70 05:45 0.75 INTRMI CASING CIRC Conditions , ' l 0 435 3 . 993.0 RIH w/ 83 jts 7" 26# L-80 BTCM csg from 3435' to 6993 6 05:45 09:00 3.25 INTRMI e CASING RNCS T Ho Conditions . , , 00 INTRMI 1 CASING CIRC T Hole 6,993.0 6,993.0 CBU. Stage pumps up Yo 4.5 bpm at 540 psi. . 09:00 10:00 Conditions from 6993' to 7678'. Work 10:00 11:15 1.25 INTRMI CASING RNCS T Hole 6,993.0 7,678.0 throu h1ti )ht holef om 7560' to 7668 g g Conditions 0 678 7 145.0 RIH w/ 16 jts 7" 26# L-80 BTCM csg from 7678' to 8107'. MU 8 11:15 12:30 1.25 INTRMI CASING RNCS P . , , hanger and LJ. Land csg at 8145'. P 145.0 8 8,145.0 RD Franks fill-up tool. RU cement head and lines. 12:30 13:00 0.50 INTRMI CASING RURD , 0 145 8 145.0 Establish circ @ .5 BPM @ 400 psi -staging pump up to 4.4 8 13:00 19:00 6.00 INTRMI CEMENT CIRC P . , , BPM - ICP 680 FCP 620 -Circ & attempt to get rate up for cementing -Hole trying to pack -off unable to get rate up to 5 BPM without packing off 0 145 8 145.0 PJSM on cmt job -Cemented 7" csg as follows: Pumped 1 bbl 8 19:00 21:30 2.50 INTRMI CEMENT DISP P . , , water -Tested lines to 4000 psi -Mixed & pumped 40 bbls MudPush @ 12.5 ppg - 4 BPM @ 450 psi -Dropped btm plug - Mixed & pumped 89 bbls tail slurry (Class G wladditives) - 15.E ppg @ 4 BPM @ 400 psi -Dropped top plug w/ 20 bbls water f~ Dowell -switched to rig pumps 8: displaced cmt w/ 10.5 ppg mud @ 4 BPM for 233 bbls -Observed slight packing off - slowed pump to 3.5 BPM next 30 bbls -slowed pump to 2.5 BMP for remained of job - 286 bbls total displacement - Bumped plug w/ 1670. psi -Check floats OK CIP @ 2124 hrs.- Full returns throughout - No pipe movement 145 0 8 145.0 RU & test csg to 3500 psi for 30 mins. RD 8 21:30 22:30 1.00 INTRMI DRILL OTHR P . , , 0 RD cmt lines 8~ head - LD landing jt. 145 8 22:30 23:00 0.50 INTRMI CEMENT PULD P 8,145.0 0 145 8 . , 145.0 Pull thin wall wear bushing -Set & test pack-off to 5000 psi 8 23:00 00:00 1.00 INTRMI DRILL OTHR P . , , Latest BOP Test Data __ - -- ----- co~~~~,E~, _- --- -- - - - Date--~ - ~ - -_. - - - _ - _ _ Page 112 Report Printed: 7/19/201 • Daily Drilling Report CD4-320 r: Report Date: 7/18!2006 Mud Check D~ - - - - - - H~ Hr' Fm - ( li3~n} - - - ~, : ~~~ Tens - Botlan. I S ~1 s. C'r _ - YP CaIc ~ ~ ~ G I{i0s) r G i(90m~ ~ ~ Irr L~ Drln~ t ILbl fl if = ~, Hci,`F) ~ ~? j FAH ~ 7 ~pF ~ D-nth [fl P,R1 1 Uers rl~-~a~1 ~ Us siap ~ PV talc (crl ~ _ _ _ _ __ (i `~1'10D`i ' _ - j , r M6T i ) ~ I - (IL,f/70~]fi'1 1 ~ILi/ Doff 6.O~ X40 0 15 00 . - _ ___ ~ ~ 25 8u c _ 0,155.0 ISND - - I n 1 _ 6,992.00 47 I I 14.0 ~ 28.000 I , 0 11.000 13.00 ~ ~ 1 - -- -- - ~ - - - ---- - - L --- - - - - ---- - - ---- - - - - ----~ injection Fluid -- - _ - - -- -- --. F am Le- blj ~ Drttinalio' ~ I-Jote - - - - - - - - - _ _~w_~~_ - ~ __ _ `~~ :r - - -- - - - - - - - 5.0 - - - From CD4-320 Diesel I 130.0 From CD4-320 Other 1 I 756.0 CD4-208 From CD4-320 - - ---- --- Water Based Mud - - - _ _ - - - - - - - - - - - - - - - __ _ _ _ Wellbores _ - - - - --- - - - WellboreAPl/UWI - - - - - - - - - Wellbo~e Name I 50103205310D - __..- -- .- -- GVY_JGQ -- -- -------~-- Sae:{ins - - - -- - - -Aril P;f`Y,L'~.. - - - - - - _ - ActStni(fLK = an Ua.~~ KH~ ~ -- -- ---- _- - -_ - - - -_ ~a u& e -.. -.- -- ---- ---- PRUD1 - - - 36 0 114.0 2/14/2006 2/15/2006 COND1 44 . 0 114 2,519.0 7/1/2006 7/2!2006 SURFAC 12 1/4 . 519 2 8,155.0 7/2/2006 7/17/2006 _ -- - - - INTRMI 8 3/4 _ _ , . _ _ i _ Surve~Data __ - ~- ~ ;- Tvr{yYP;, _ I ~ ,7,-~_ rd~ nj L _ ~ j ~s { io~~hl a ~~'~IYi --- 233 5 4 - - - 16° ~ E9 OO~ 6 ;4a-~3 ~ c~ 8 41 I ~ 69i~26~ t3 c - x,155 00~ I - Casing Stnngs -- DeSG _ -- - R.un Date .~=~- _ _ i v~ (¢srti j tr~dP ~ ,eir~eptn{rir;r~j - - - - -. - - - - '~D ini ~- - - _. nmrnt - - - - - - - am: F _- - - °- - _ -- -- -_ - 18/2006_ ~ ~ ~ - ~ 0,145 1 26.00 L ~0 -- -- ~ I - -- - - intermediate ~~ - - -- - ~ ~ - --- - - - -- --- - --- Cement - -- - -- - -- - - - - -- Production Casin Cement -Started 7118/2006 Cement Evaluation Results Type Wellbore String casing CD4-320 Intermediate, 8,145.1ftK6 Sfn No. Description Top (ftK6) Bottom (ftK6) Q (end) (bbli... P (final) (psi) 6,000.0 8,145.0 2 1 200 0 1 Production Casing Cement _ - - ~ -~ - - Ta~,ount{saac~j j vcy~p -~ 0ensify,,{1bYgal) xielalft°rsack3 ~ _==~.stTop.{K~i --- Estatm{t2r.si- -° -' _rr7~~_ _ 6,000.0 8,145.0 - - - - • - - 405 89.0 15.80 1.16 Tail Cement V Paae 2/2 Report Pnntea: rr~mcvu PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. CD4-320 Rig: Doyon 19 Date: 7/19/2006 Volume Input Pum Rate: all Name: Lutrick /Mickey Pump used: Cement Unit ~ Barrels ~ Bbls/Strk ~ 0.80 Bbl/min ~ filling Supervisor: Type of Test: Annulus Leak Off Test for Disposal Adequacy ~ Pumping down annulus. '~ Casin Test Pressure Inte rit Test 8-3/4" ale Size: ~ Casin Shoe Depth Hole De th ~~ ~~„ ~~nn n Gt_TVr1 Pum in Shut-in Rhls osi Min si Pumpin Shut-in Bbls psi Min si RKB-CHF: 34.7 Ft 2509.0 Ft-MD 2378.0 Ft-TVD 6000.0 Casina Size and Description: 9-s/s" ao#/Ft L-so BTc Chan es for Annular Ade uac Test Pressure Inte Enter outer casing shoe test results in comments Mud Weight: Casing description references outer casing string. Inner casing OD: Hole Size is that drilled below outer casing. Use estimated TOC for Hole Depth. Desired PIT EMW: Enter inner casing OD at right. Estimates for Test: MW =Leak-off Pressure + Mud Weight = 900 + 10.5 0.052 x TVD 0.052 x 2378 EMW at 2509 Ft-MD (2378 Ft-ND) = 17.8 1000 w N 500 W R' a 1,~pP9 7.O In. 15•UIpp9 556 psi 0.3 bbls I' PIT 15 Second Shut-in Pressure, psi 639 ume 7- 8 9 10 15 0 ~.5 0 13 0.00 0.25 670 639 1 31 0.50 618 1.5 97 1.00 597 2 180 1.50 582 2.5 308 2.00 577 3 410 2.50 570 3.5 4 485 607 3.00 3.50 567 565 5.5 6 895 900 5.00 5.50 554 547 6.5 787 6.00 547 7 751 6.50 546 7.5 744 7.00 539 8 745 7.50 539 8.5 727 8.00 539 9 727 8.50 539 9.00 9.50 539 537 Pumped ~~ Bled Back tiu ti\nnwar ~ Summary ° ' z s a 5 s ~ ~ ~~ - Shut-In time, Minutes Barrels ~'~CASING TEST -~~LEAK-OFF TEST O PIT Point RE: CD4-320 Flowback and Testing Subject: RE: CD4->>0 Flowback anti "Cestin~~ From: "Walker, JackA" ~,Tack.A.Walker~u'conocophillips.com=-= Date: stied, 19 Apr 2006 15:06:48..-0800 To: Thomas Maunder atom ~»aundcr(~%admin.state.~ik.us- CC: ".~ohnson, Vern" <Vern..fohnson(t~conocophillips.com~=~, day°e Roby =~~daverot~y(u-:admin.state.ak.us=, "Bennett, Jim C" ~~~fim.C.Benneti~a!conocop}~illips.c~om~~ Tom, ~ ~ "~S S The flowback would be comparable to CD4-319, based on getting watercut & solids to a level compatible in the plant. CD4-320 testing plans are not well defined at this time, so I suggest after getting more definition, we would make a sundry 10-403 application for testing. Jack -----Original Message----- From: Thomas Maunder [mailto:tom maunder~admin.state.ak.us Sent: Wednesday, April 19, 2006 2:38 PM To: Walker, Jack A Cc: Johnson, Vern; dave Roby Subject: CD4-320 Flowback and Testing. Jack, In the application for CD4-320, it is indicated that after drilling the well will be flowed back and tested. Are the plans for this well different than what has been done on the other wells at CD4, in particular CD4-319? Thanks, Tom Maunder, PE AOGCC 1 of 1 4/19/2006 3:13 PM • ~ ~ ~ ' ' g ~ 1-. ~ , ~ ,) t .~ y ~ ~ ~~ ~~ I 1; ~ ~~ is i~~' d ~ . , AL~SSA OIL A1~TD GAS COI~TSERQATIO~T COl-IItIISSI011T Chip Alvord WNS Drilling Team Lead ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360. FRANK H. MURKOWSKI, GOVERNOR 333 W. T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Colville River Field, Nanuq Kuparuk Oil Pool, CRU CD4-320 ConocoPhillips Alaska, Inc. Permit No: 206-055 Surface Location: 2978' FNL, 438' FEL, SEC. 24, T11N, R4E Bottomhole Location: 3088' FNL, 3292' FEL, SEC. 30, T11N, R5E Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you frorri 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 6,~'i607 (pager). DATED this~Oday of April, 2006 cc: Department of Fish 8s Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. .DIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI SIGN PERMIT TO DRILL ~~ 20 AAC 25.005 ~' ~ 1 8 2006 ~ ~., ~,' =" ~OflS. '~,Q{T1tTtISS10t1 ~~: ~.~'tra~e 1 a. Type of Work: Drill Q ~ Re-drill Re-entry ^ 1 b. Current Well Class: Exploratory ^ Development Oil ^ Stratigraphic Test ^ Service ^ Development Gas ~ Multiple Zone^ Single Zone ^ 1 c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 ' 11. Well Name and Number: CD4-320 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 14204' TVD: 7008' ' 12. Field/Pool(s): Colville River Field 4a. Location of Well (Governmental Section): Surface: 2978 FNL, 438 FEL, Sea 24 , T 11 N R 4 E 7. Properly Designation: ADL ADL 380077, 384211 Nanuq Kuparuk Oil Pool Top of Productive Horizon: 2483 FNL, 4404 FEL, Sec. 19 , T 11 N R 5 E ~ 8. Land Use Permit: ALK 380077 13. Approximate Spud Date: 4129/2006 Total Depth: 3088 FNL, 3292 FEL, Sec. 30 , T 11 N R 5 E 9. Acres in Properly: 2560 14. Distance to Nearest Property: 7472 ' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 377805.36 ` y- 5957436.9 Zone- 4 10. KB Elevation (Fleight above GL): 55.1' RKB feet 15. Distance to Nearest Well within Pool: Nanuk 1 , 268.33 ~ 16. Deviated wells: Kickoff depth: 300 ft. Maximum Hole Angle: g0° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3164 psig ~ Surface: 2464 psig ' 18. Casing Program if S ti Setting Depth Quantity of Cement Size ica pec ons Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 62.5# H-40 ~~lelded 77 37 37 114 114° pre-installed 12.26" 9-518" 40# L-8() BTC 2477 37 37 2514 2390 524 sx AS Lite, 230 sx 15.8 G 8.75" 7" 26# L-80 BTCM 8183 37 37 8220 6994 405 sx Class G 4.5"/3.5" L-80 8032 32 32 8064 6987 tubing 6.125 3.5" 9.3 L-80 IBT-M 6141 8063 6968 14204 7008 slotted liner completion 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD ND Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth ND (ft): 20. Attachments: Filing Fee ^/ BOP Sketch^ Drilling Program /^ Time v. Depth Plot ^ Shallow Hazard Analysis Q Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements ^/ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact V, Johnson Printed Name C. Alvord Sr Title WNS Drilling Team Lead Signature '"~ ,l- r'~~~ Phone Date y'/17~0~ (J v. nr~ r, Commission Use Only Permit to Drill Number: ,~,Q (p ~ dS~ API Number: 50- ~Q3 ~ ZQ S31 "~~ Permit Approval Date: + ~ ~ b See cover letter for other requirements Conditions of approval : If box is checked, well may not be~tus~ed to explore for, test, or produce coalbed me ane, ga tes, or gas contained in shales: ~~~lt-~~-v~~`~~ ,~1~1~~~ ~•~i~eti~t~amples req'd: Yes ^ No ~ ud log req'd: Yes ^ No [~ Other: H2S measures: Yes ~ No ~ Dir nal svy req'd: Yes [V~ No ^ ~5 0~ psi 't`°`\~~MU~`.~~Q . ~ ~ ~ yD i © APPROVED BY THE COMMISSION DATE: ,COMMISSIONER Form 10-401 Revised 12/2005 `-~ 1' ~ ~ Submit in Dyplicate r•.- ... ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 April 17, 2006 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD4-320 Dear Sir or Madam: ConocoPhilli s p ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore producer well from the CD4 drilling pad. The intended spud date for this well is 4/29/2006. It is intended that Doyon Rig 19 be used to drill the well. CD4-320 will be drilled to penetrate the Kuparuk reservoir horizontally. After setting 7" intermediate casing, the horizontal section will be drilled and the well completed as a slotted liner producer. The well is planned to be flowed back and tested after post rig well work. The well will then be shut-in awaiting A waiver for the diverter requirement is requested. This will be the 6th well on the Nanuq (CD4) pad and there has been no indication of gas or shallow gas hydrates. - ,, ,._.._.._ _i f~ AC ~-~ y I r~ Please find attached the information required by 20 l9~2G` 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: atS,C 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ~2~25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ~ 25.005 (c) (1). 3. A proposed drilling program. ~b~C 4. A proposed completion diagram. 5. A drilling fluids program summary. ~~C. 6. Pressure information as required by 20 P~C 25.035 (d)(2). 7. Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ~A,,~'25.035 (a) and (b). 2. A description o the drilling fluids handling system. 3. Diagram of riser setup which replaces the diverter, if approved. If you have any questions or require further information, please contact Vern Johnson at 265- 6081 or Chip Alvord at 265-6120. Sin ely, ~- . Vern Johnson Drilling Engineer %~~/~~ • • Attachments cc: CD4-320 Well File /Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1700 Vern Johnson ATO 1702 Jack Walker ATO 1740 Lanston Chin Kuukpik Corporation • • CD4-320 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-1/4" Hole / 9-5/8" Casing Interval Event Risk Level Miti ation Strate Conductor Broach Low Monitor cellar continuous) durin interval. Well Collision Low G o sin le shots, travelin c finder dia rams Gas Hydrates Low Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud tem eratures Running Sands and Gravel Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Abnormal Pressure in Low Increased mud weight Surface Formations >2000' ND Lost Circulation Low Reduced pump rates, mud theology, lost circulation material, use of low densi cement slurries 8-3/4" Hole / 7" Casino Interval Event Risk Level Miti ation Strate Abnormal Pressure in low BOPE drills, Keep mud weight above 9.6 ppg. Surface Formations ~ Check for flow during connections and if needed, >2000' ND increase mud wei ht. Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheol ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted swee s. Abnormal Reservoir low Well control drills, increased mud weight. No Pressure mapped faults occur within 700' of the planned wellbore. Hydrogen Sulfide gas Low HZS drills, detection systems, alarms, standard well control ractices, mud scaven ers 6-1/8" Hole /Horizontal Production Hole Event Risk Level Miti ation Strate Lost circulation moderate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitorin ,wei hted swee s. Abnormal Reservoir Medium BOPE drills, Keep mud weight above 8.8 ppg. / Pressure _ Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud wei ht. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control ractices, mud scaven ers ORIGINAL • Nanua : CD4-320 Procedure 1. Move on Doyon 19. 2. Drill 12-'/," hole to the surface casing point as per the directional plan. 3. Run and cement 9-5/8" surface casing. 4. Install and test BOPE to 5000 psi. 5. Pressure test casing to 2500 psi. 6. Drill out 20' of new hole. Perform leak off test. 7. Pick up and run in hole with 8-3/4" drilling BHA. 8. Drill 8-3/4" hole to intermediate casing point in the reservoir sand. (LWD Program: GR/RES/PWD) 9. Run and cement 7" casing as per program. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. 10. BOPE test to 5000 psi. 11. Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.0 ppg EMW. 12. Drill 6-1/8" horizontal section to well TD (LWD Program: GR/RES/PWD). 16. Circulate the hole clean and pull out of hole. 17. Run lower completion with slotted liner and liner hanger with liner top packer, then run 3-1/2", tubing with SSSV nipple, gas lift mandrels, sliding sleeve and seal assembly. Sting in, space out and land hanger. 18. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 19. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 20. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. 21. Shear circulation valve in GLM. Circulate tubing to diesel and install freeze protection in the annulus. 22. Set BPV and secure well. Move rig off. ORIGINAL • C7 Wel! Proximity Risks: ~ ~~ Directional drilling /collision avoidance information as required by 20 A C 25.050 (b) is provided in following attachments. Nanuq 5 is the closest well. Well separation is 4.6' @ 253' MD. ~ Drilling Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. '~ Lost circulation: Faulting within the Kuparuk reservoir section is considered to be the most likely cause of '~ lost circulation. Standard LCM material is expected to be effective in dealing with lost circulation. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. ~ ~ ~ ~ • • CD4-320 DRILLING FLUID PROGRAM SPUD to 9-5/8"surface casing Intermediate hole to 7" casing point - 8 3/4" Production Hole Section - 6 1/8" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.0-9.3 ppg PV 10 - 25 10 -15 YP 20-60 15-25 25-30 Funnel Viscosity 100 - 200 Initial Gels 4 - 8 10 -15 10 minute gels <18 12 - 20 API Filtrate NC -10 cc / 30 min 4 -12 cc/30 min (drilling) HPHT Fluid Loss at 160 12 - 14 cc/30 min PH 8.5 - 9.0 9.0 - 10.0 9.0 - 9.5 KCL 6 Surtace Hole: A standard high viscosity fresh water /gel spud mud is recommended for the surface interval. Keep to line viscosity at t 200 seGgt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel /polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the reservoir is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section The horizontal production interval will be drilled with a M-I Flo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with t 30PPB calcium carbonate bridging material to minimize formation damage. Flo-Vis Polymer and Dual-Flo starch will be used f ORIGINAL CD4-320 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 (c) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surtace pressure (ASP) during drilling of this well Casing Size in Csg Setting Depth MD/TVD ft Fracture Gradient lbs. / al Pore pressure si ASP Drilling si 16 114 / 114 10.9 52 53 95/8 2514 / 2390 14.5 1081 1563 7" 8220 / 6994 16.0 3164 ~ 2465 N/A 14214 / 7008 16.0 3171 N/A NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surtace pressure at breakdown of the formation casing seat with a gas gradient to the surtace, or 2) formation pore pressure at the next casing point less a gas gradient to the surtace as follows: 1) ASP = [(FG x 0.052) - 0.1 ]D Where: ASP =Anticipated Surface pressure in psi FG =Fracture gradient at the casing seat in Ib/gal 0.052 =Conversion from Ib./gal to psi/ft 0.1 =Gas gradient in psUft D =true Vertical depth of casing seat in ft RKB OR 2) ASP =FPP - (0.1 x D) Where; FPP =Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1 ] D =[(10.9x0.052)-0.1]x114=53 psi OR ASP =FPP - (0.1 x D) = 1081 - (0.1 x 2390') = 830.2 psi 2. Drilling below surtace casing (9 5/8") ASP = [(FG x 0.052) - 0.1] D _ [(14.5 x 0.052) - 0.1] x 2390 = 1640 psi OR ASP =FPP - (0.1 x D) = 3164 - (0.1 x 6994') = 2465 psi '' 3. Drilling below intermediate casing (7") ASP =FPP - (0.1 x D) = 3171 - (0.1 x 7008') = 2470 psi 0^161NAL • L~ CD4 - 320 Nanuq Kuparuk Producer Completion Sperry Sun 16" Insulated Conductor to 114' DireCtiOnal Plan WP05 0 i 4-'/z' 12.6 ppf L-80 IBT Mod. Tubing 03/30/06 ~ 4-'/2' BP61 Landing Nipple for Wireline Retrievable SSSV Crossover 3.5" 9.3ppf L-80 EUE 8rd Mod. X 4.5"12.6 ppf L-80 IBT Mod 9-5/8" 40 ppf L-80 BTCM Surface Casing 2514' MD / 2390' TVD Top of cement 13 ~- ~~~/// 6067' MD 15686' TVD 15 Top Reservoir at +/- Nanuq 6567' MD / 6160' TVD Kuparuk 8081' MD ! 6988' TVD ~ Uoce r Com lep lion: ~Q IYp lIsm 1) Tubing Hanger 32' 32' 2) 4'h'",12.6#/ft, IBT-Mod Tubing 3) 4'/:" BP61 Landing Nipple 2090' 2000' 4) 4 '/z', 12.6#/ft, IBT-Mod Tubing 5) Crossover 3-''/z' 9.3ppf L-80 EUE Mod X 4'/z' 12.6 ppf L-80 IBT Mod 2150' 2054' 6) 3 '/z' 9.3 ppf L-80 EUE Mod (2 Jts) 7) Camco KBMG GLM (2.867" ID) w/ RP shear out valve 3612' 3400' 8) 3-''/z' 9.3#/ft L-80 EUE Mod (Jts) 9) Camco KBMG GLM (2.867" ID) 6081' 5700' 10) 3 '/z' 9.3#/ft L-80 EUE Mod 11) Camco KBMG GLM (2.867" ID) 7410' 6778' 12) 3-'/~' 9.3#/ft L-80 EUE Mod (2 Jt) 13) CMD Sliding Sleeve 2.813" w/ X profile 7480' 6813' 14) 3-''/z' 9.3#/ft L-80 EUE Mod (2 Jt) 15) HES No-Go XN (2.75") @ 63.8 deg 7550' 6845' 16) 3-'/z' 9.3#Jft L-80 EUE Mod 17) Weatherford 7500 psi mPOD2 Gauge and Gauge Carrier ID=3.958", OD=6.145" @ 81.3 deg 7994' 6978' 18) 3 '/z' 9.3#/ft L-80 EUE Mod (2 Jts) 19) BOT Bonded seal assembly w/ half mule shoe 8064' 6987' Stung into tie extension 8' off bottom of ZXP at 8071' Lowe r Completion: Top MD IYQ ltftIIl 20) Baker ZXP Liner top packer 8063' 6986' 21) Baker RS Nipple 8082' 6988' 22) Baker 5" x 7" Flexlock Liner Hanger 8085' 6989' 23) Seal bore extention 8095' 6989' 24) 3 '/z', 9.3#/ft, SLHT Tubing +/- 4 jts 25) 3 '/z' 9.3#Ift SLHT liner w/ blank across shale and slots across sand 26) Baker Shoe w/ packoff bushing 14203' 7008' TD 6-1/8" hole 14213'MD/ ' 7008' TVD 3'/:" 9.3#!ft L-80 EUE Mod Slotted liner Pattern: 8 slots/ft, 2-'/:' x 1/8" slots 7" 26 ppf L-80 BTC Mod Production Casing @ +/-90° 8220' MD, 6994' TVD oRisina~ • C7 9 5/8" Surface Casing run to 2514' MD / 2390' TVD. Cement from 2514' MD to 2014' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2989' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (1795' MD). Lead slurry: (2014'-1795') X 0.3132 ft3/ft X 1.5 (50% excess) = 102.9 ft3 below permafrost 1795' X 0.3132 ft3/ft X 4 (300% excess) = 2248.8ft3 above permafrost Total volume = 102.9 + 2248.8 = 2351.7 ft3 => 525 Sx @ 4.48 ft3/sk System: 524 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.48 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% 5001 accelerator, 50% D124 extender and 9% BWOWI D044 freeze suppressant Tail slurry: 500' X 0.3132 ft3/ft X 1.5 (50% excess) = 234.9 ft3 annular volume 80' X 0.4341 ft3/ft = 34.7 ft3 shoe joint volume Total volume = 234.9 + 34.7 = 269.6 ft3 => 230 Sx @ 1.17 ft3/sk System: 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% 5001 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casing run to 8220' MD /6994' TVD Cement from 8220' MD to 6067+/-' MD (minimum 500' MD above top of Nanuq/Albian 96) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Tail: (8220' -6067) X 0.1503 ft3/ft X 1.4 (40% excess) = 453 ft3 annular vol. 80' X 0.2148 ft3/ft = 17.2 ft3 shoe joint volume Total volume = 453 + 17.2 = 468.2 ft3 => 405 Sx @ 1.16 ft3/sk System: 405 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.16 ft3/sk ' By Weight Of mix Water, all other additiv • ConocoPhillips Alaska ConocoPhillips Alaska Inc. Colville River Unit Alpine CD4 Plan: CD4-320 Plan: CD4-320 Plan: CD4-320wp05 Proposal Report 13 April, 2006 r1 J HALLIBURTON Sperry Qrilling Services Q~!GINAL ~onocornnnps $ E„"`~ °;~" E„gyp„^°;~ " war^.^o M.orod: Rule: ea.ed Colville River Unit Alaska «°~+K~1em ~79a,NnncoNCoNU61 M 1 Alpine CD4 .~,«k. eW 112W5 Plan: CD4-320 MALLIBURTON Ground Level-. 19.00 Plan: CD4-320 Sperry DAIiMy S~fviC~t RKB. Plannetl Doyon 19 (v; 55.30fl (Doyon 19136.3+ 191) NorihinglASP y. 5957436.86 ~n4-~~nwt,n5 C CD4-320wp05 9-5/8" Csg Pt; 2514' MD, 2390' ND Start Sail; 23.07° INC, 1362' MD, 1329' ND Continue Dir; 3° DLS, 82° TFO, 840' MD, 834' ND, Begin Dir; 4° OLS, 152° TFO, 5449' MD, 5090' ND Begin Dir; 3° DLS, 0° TFO, 540' MD, 539' ND Continue Dir; 4° DLS, 0° TFO, 8088' MD, 6988' ND Kick-aff Point; 2.5° DLS, 333° TFO, 300' MD, 300' ND SHL; 2978' FNL & 438' FEL; Sec24-T11 N-R04E ~ 9 5/8" Target (Heel); 8213' MD, 6994' ND 7" - 7" Csa Pt: 8220' MD. 6994' ND. 2483' FNL & 4404' FEL: Sec19-T11 N-ROSE Target (T1); 9994' MD, 6994' ND -4000 C O O cv 2 L Q U_ ~ 5 Q) 7 L 0 r`_en C-30 I C-20 K_7 Base K-2 Albian 97 Albian 96 Top HRZ LCU ruk C -5000 6-1/8" Open Hole Cp4-320wPp5 - Target (T2); 12494' MD, 7004' TVD Target (Toe); 14213' MD, 7008' ND, 3088' FNL & 3292' FEL; Sec30-Tt t N-ROSE -2000 0 2000 4000 6000 West(-)/East(+) (2000 ft/in) SHL; 2978' FNL 8 438' FEL; Sec2a-T11 N-R04E 0 Kick-off Point; 2.5° DLS, 333° TFO, 300' MD, 300' ND 1p Begin Dir; 3° DLS, 0° TFO, 540' MD, 539' ND Continue Dir; 3° DLS, 82° TFO, 840' MD, 834' ND Start Sail; 23.07° INC, 1362' MD. 1329' ND 9-5/8" Csg Pt; 2514' MD, 2390' ND Begin Dir; 4° DLS, 152° TFO, 5449' MD, 5090' ND ?3 7" Csg Pt; 8220' MD, 6994' ND, 2483' FNL 8 4404' FEL; Sec19-T11 N-R05E Continue Dir; 4° DLS, 0° TFO, 8088' MD, 6988' ND Target (Heel); 8213' MD, 6994' ND Target (Toe); 14213' MD, 7008' ND, 3088' FNL 8 3292' FEL; Sec30-T1 t N-R05E Target (T1); 9994' MD, 6994' ND Target (T2); 12494' MD, 7004' ND 6-1/8" Open Hole w~ +o (n _ A O 1 I A 3 0 N M -2500 0 2500 5000 0 7500 10000 U Conoc4Phil~ips Alaska Sperry Drilling Services ~ HALLIBURTON Planning Report -Geographic --- -------____.__ __,____~__ Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska lnc. Project: Colville River Unit :Site: Alpine CD4 `Well: Plan: CD4-320 Wellbore: Plan: CD4-320 Design:: CD4-320wp05 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Sperry Drilling Services Well Plan: CD4-320 Planned Doyon 19 ~ 55.30ft (Doyon 19 (36.3 + 19)) Planned Doyon 19 Q 55.30ft (Doyon 19 (36.3 + 19)) True Minimum Curvature Project Colville River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Plan: CD4-320 Well Position +N/S 0.00 ft Northing: 5,957,436.86 ft ~ Latitude: 70° 17' 32.029" N +E/-W 0.00 ft Easting: 377,805.36 ft Longitude: 150° 59' 21.484" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 19.OOft Wellbore Plan: CD4-320 Magnetics Model Name Sample Date. Declination Dip Angle Field Strength BGGM2005 4/13/2006 23.36 80.62 57,500 Design CD4-320wp05 Audit Notes: Version: Phase: PLAN Tie On Depth: 36.30 Vertical Section: Depth From (TVD) +N/-S +Ef-W Direction (ft) (ft) (ft) (°) 36.30 0.00 0.00 158.43 Pian Summary Measured Vertical. Dogleg Build Turn Depth Inclination Azimuth .Depth +N/.S +E/ W Rats Rate Rate TFO (ft) (°) (°) (ft) (~) (ft) (°f100ft) (°I100ft) (°/100ft) (°) 36.30 0.00 0.00 36.30 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 540.00 6.00 333.00 539.56 11.19 -5.70 2.50 2.50 0.00 333.00 840.00 15.00 333.00 834.23 59.85 -30.49 3.00 3.00 0.00 0.00 1,362.44 23.07 16.04 1,329.98 219.44 -32.92 3.00 1.54 8.24 81.81 5,449.93 23.07 16.04 5,090.71 1,758.52 409.56 0.00 0.00 0.00 0.00 8,088.06 85.00 169.07 6,988.85 624.79 969.53 4.00 2.35 5.80 152.04 8,213.06 90.00 169.07 6,994.30 502.21 993.20 4.00 4.00 0.00 0.00 9,994.03 90.00 169.07 6,994.30 -1,246.46 1,330.88 0.00 0.00 0.00 0.00 10,005.51 89.77 169.07 6,994.32 -1,257.74 1,333.06 2.00 -2.00 0.00 -179.98 12,494.03 89.77 169.07 7,004.30 -3,701.09 1,804.89 0.00 0.00 0.00 0.00 14,213.81 89.96 169.07 7,008.30 -5,389.67 2,130.97 0.01 0.01 0.00 -0.05 4/13/2006 4:31:43PM Page 2 of 8 COMPASS 2003.11 Build 50 ~~~~A~ • • gy ' Sperry Drilling Services p ~{~1"14C©r~'111 i~3 5 Pl i R t hi G HALLIBURTON ~ ann ng epor - eograp c g ~rr ~ p y Drilling Satrvicas Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan: CD4-320 Company: ConocoPhillips Alaska Inc. TVD Reference: Planned Doyon 19 @ 55.30ft (Doyon 19 (36.3 + 19)} Project:. Colville River Unit MD Reference: Planned Doyon 19 @ 55.30ft (Doyon 19 (36.3 + 19)) Sits:. Alpine CD4 North Reference: True Wslt; Plan: CD4-320 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD4-320 Design: CD4-320wp05 Planned Survey CD4-320wp05 Map Map...... MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Fasting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) 1ft) lft) (°l100ft) (ft1 36.30 0.00 0.00 36.30 -19.00 0.00 0.00 5,957,436.86 377,805.36 0.00 0.00 SHL; 2978' FNL & 438 ' FEL; Sec24-T11N-R04E . 100.00 0.00 0.00 100.00 44.70 0.00 0.00 5,957,436.86 377,805.36 0.00 0.00 200.00 0.00 0.00 200.00 144.70 0.00 0.00 5,957,436.86 377,805.36 0.00 0.00 300.00 0.00 0.00 300.00 244.70 0.00 0.00 5,957,436.86 377,805.36 0.00 0.00 Kick-off Point; 2.5° DLS, 333° TFO, 300' MD, 300' TVD _ 400.00 2.50 333.00 399.97 344.67 1.94 -0.99 5,957,438.82 377,804.40 2.50 -2.17 500.00 5.00 333.00 499.75 444.45 7.77 -3.96 5,957,444.70 377,801.52 2.50 -8.68 540.00 6.00 333.00 539.56 484.26 11.19 -5.70 5,957,448.14 377,799.84 2.50 -12.50 Begin Dir; 3° DLS, 0° TFO, 540' M D, 539' TVD 600.00 7.80 333.00 599.12 543.82 17.61 -8.97 5,957,454.61 377,796.67 3.00 -19.67 700.00 10.80 333.00 697.80 642.50 32.01 -16.31 5,957,469.13 377,789.57 3.00 -35.76 800.00 13.80 333.00 795.49 740.19 50.99 -25.98 5,957,488.26 377,780.21 3.00 -56.97 840.00 15.00 333.00 834.23 778.93 59.85 -30.49 5,957,497.19 377,775.84 3.00 -66.87 Continue Dir; 3° DLS, 82° TFO, 840' MD, 834' TVD 900.00 15.36 339.74 892.15 836.85 74.22 -36.77 5,957,511.67 377,769.80 3.00 -82.54 1,000.00 16.37 350.09 988.36 933.06 100.53 -43.78 5,957,538.09 377,763.22 3.00 -109.59 1,100.00 17.83 359.03 1,083.95 1,028.65 129.73 -46.47 5,957,567.32 377,761.00 3.00 -137.73 1,200.00 19.62 6.52 1,178.67 1,123.37 161.72 -44.82 5,957,599.28 377,763.17 3.00 -166.88 1,300.00 21.68 12.72 1,272.25 1,216.95 196.43 -38.85 5,957,633.89 377,769.71 3.00 -196.96 1,362.44 23.07 16.04 1,329.98 1,274.68 219.44 -32.92 5,957,656.79 377,776.00 3.00 -216.18 Start Sail; 23.07° INC, 1362' MD, 1 329' TVD 1,400.00 23.07 16.04 .1,364.54 1,309.24 233.59 -28.86 5,957,670.87 377,780.30 0.00 -227.84 1,500.00 23.07 16.04 1,456.55 1,401.25 271.24 -18.03 5,957,708.33 377,791.73 0.00 -258.87 1,600.00 23.07 16.04 1,548.56 1,493.26 308.89 -7.21 5,957,745.80 377,803.17 0.00 -289.91 1,700.00 23.07 16.04 1,640.56 1,585.26 346.54 3.62 5,957,783.27 377,814.61 0.00 -320.95 1,800.00 23.07 16.04 1,732.57 1,677.27 384.20 14.44 5,957,820.74 377,826.04 0.00 -351.98 1,900.00 23.07 16.04 1,824.57 1,769.27 421.85 25.27 5,957,858.21 377,837.48 0.00 -383.02 2,000.00 23.07 16.04 1,916.58 1,861.28 459.50 36.09 5,957,895.68 377,848.91 0.00 -414.06 2,100.00 23.07 16.04 2,008.58 1,953.28 497.16 46.92 5,957,933.15 377,860.35 0.00 -445.09 2,200.00 23.07 16.04 2,100.59 2,045.29 534.81 57.74 5,957,970.62 377,871.78 0.00 -476.13 2,300.00 23.07 16.04 2,192.59 2,137.29 572.46 68.57 5,958,008.09 377,8$3.22 0.00 -507.17 2,309.46 23.07 16.04 2,201.30 2,146.00 576.03 69.59 5,958,011.63 377,884.30 0.00 -510.10 C-40 2,400.00 23.07 16.04 2,284.60. 2,229.30 610.12 79.40 5,958,045.56 377,894.65 0.00 -538.20 2,500.00 23.07 16.04 2,376.61 2,321.31 647.77 90.22 5,958,083.03 377,906.09 0.00 -569.24 2,514.56 23.07 16.04 2,390.00 2,334.70 653.25 91.80 5,958,088.48 377,907.75 0.00 -573.76 9-518" Csg Pt; 2514' MD, 2390' TV D - 9 5/8" 2,526.84 23.07 16.04 2,401.30 2,346.00 657.88 93.13 5,958,093.08 377,909.15 0.00 -577.57 C-30 2,600.00 23.07 16.04 2,468.61 2,413.31 685.42 101.05 5,958,120.50 377,917.52 0.00 -600.28 2,700.00 23.07 16.04 2,560.62 2,505.32 723.08 111.87 5,958,157.97 377,928.96 0.00 -631.31 2,800.00 23.07 16.04 2,652.62 2,597.32 760.73 122.70 5,958,195.43 377,940.39 0.00 -662.35 2,900.00 23.07 16.04 2,744.63 2,689.33 798.38 133.52 5,958,232.90 377,951.83 0.00 -693.38 2,922.47 23.07 16.04 2,765.30 2,710.00 806.84 135.95 5,958,241.32 377,954.40 0.00 -700.36 C-20 4/13/2006 4:31:43PM Page 3 of 8 COMPASS 2003.11 Build 50 ® ~ ~I ~~L • ~ !~' Sperry Drilling Services ~ ConocoPh~lhps Pl i R rt G hi HALLIBURTON -- ann ng epo - eograp c ~ ~~ ~~„ ~~c~~ ~~ ~ g t)atabase: - EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan: CD4-320 Company: ConocoPhillips Alaska Inc. TVD Reference: Planned Doyon 19 Q 55.30ft (Doyon 19 (36.3 + 19}) Project: Colville River Unit MD Reference: Planned Doyon 19 Q 55.30ft (Doyon 19 (36.3 + 19)) Site: Alpine CD4 North Reference: True Well: Plan: CD4-320 Survey Calculation Method: Minimum Curvature Wellbores Plan: CD4-320 Design: CD4-320wp05 Planned Survey CD4-320wp05 MD Inclination Azimuth TVD SSTV 3,000.00 23.07 16.04 2,836.63 2,781.33 3,100.00 23.07 16.04 2,928.64 2,873.34 3,200.00 23.07 16.04 3,020.65 2,965.35 3,300.00 23.07 16.04 3,112.65 3,057.35 3,400.00 23.07 16.04 3,204.66 3,149.36 3,500.00 23.07 16.04 3,296.66 3,241.36 3,600.00 23.07 16.04 3,388.67 3,333.37 3,700.00 23.07 16.04 3,480.67 3,425.37 3,800.00 23.07 16.04 3,572.68 3,517.38 3,900.00 23.07 16.04 3,664.69 3,609.39 4,000.00 23.07 16.04 3,756.69 3,701.39 4,072.40 23.07 16.04 3,823.30 3,768.00 K-3 4,100.00 23.07 16.04 3,848.70 3,793.40 4,200.00 23.07 16.04 3,940.70 3,885.40 4,300.00 23.07 16.04 4,032.71 3,977.41 4,302.82 23.07 16.04 4,035.30 3,980.00 Basal K-3 4,339.77 23.07 16.04 4,069.30 4,014.00 K-2 4,400.00 23.07 16.04 4,124.71 4,069.41 4,454.98 23.07 16.04 4,175.30 4,120.00 Base K-2 4,500.00 23.07 16.04 4,216.72 4,161.42 4,600.00 23.07 16.04 4,308.72 4,253.42 4,700.00 23.07 16.04 4,400.73 4,345.43 4,800.00 23.07 16.04 4,492.74 4,437.44 4,900.00 23.07 16.04 4,584.74 4,529.44 5,000.00 23.07 16.04 4,676.75 4,621.45 5,100.00 23.07 16.04 4,768.75 4,713.45 5,200.00 23.07 16.04 4,860.76 4,805.46 5,300.00 23.07 16.04 4,952.76 4,897.46 5,400.00 23.07 16.04 5,044.77 4,989.47 5,449.93 23.07 16.04 5,090.71 5,035.41 Begin Dir; 4° DLS, 152° TFO, 5449' MD, 5090' TVD 5,500.00 21.32 18.62 5,137.07 5,081.77 5,600.00 17.97 .25.18 5,231.25 5,175.95 5,700.00 14.94 34.45 5,327.15 5,271.85 5,800.00 12.46 47.76 5,424.33 5,369.03 5,900.00 10.90 66.07 5,522.29 5,466.99 6,000.00 10.68 87.53 5,620.56 5,565.26 6,100.00 11.87 107.19 5,718.66 5,663.36 6,200.00 14.11 122.00 5,816.13 5,760.83 6,218.76 14.62 124.24 5,834.30 5,779.00 Albian 97 6,300.00 17.01 132.35 5,912.47 5,857.17 6,400.00 20.27 139.61 6,007.22 5,951.92 Map Map- +N/-S +Ef-W Northing Fasting DLSEV Vert Section 836.04 144.35 5,958,270.37 377,963.26 0.00 -724.42 873.69 155.17 5,958,307.84 377,974.70 0.00 -755.46 911.34 166.00 5,958,345.31 377,986.13 0.00 -786.49 949.00 176.82 5,958,382.78 377,997.57 0.00 -817.53 986.65 187.65 5,958,420.25 378,009.00 0.00 -848.57 1,024.30 198.47 5,958,457.72 378,020.44 0.00 -879.60 1,061.96 209.30 5,958,495.19 378,031.87 0.00 -910.64 1,099.61 220.13 5,958,532.66 378,043.31 0.00 -941.68 1,137.26 230.95 5,958,570.13 378,054.74 0.00 -972.71 1,174.92 241.78 5,958,607.60 378,066.18 0.00 -1,003.75 1,212.57 252.60 5,958,645.07 378,077.61 0.00 -1,034.79 1,239.83 260.44 5,958,672.19 378,085.89 0.00 -1,057.26 1,250.22 263.43 5,958,682.53 378,089.05 0.00 -1,065.82 1,287.88 274.25 5,958,720.00 378,100.48 0.00 -1,096.86 1,325.53 285.08 5,958,757.47 378,111.92 0.00 -1,127.90 1,326.59 285.38 5,958,758.53 378,112.24 0.00 -1,128.77 1,340.51 289.38 5,958,772.37 378,116.47 0.00 -1,140.24 1,363.18 295.90 5,958,794.94 378,123.35 0.00 -1,158.93 1,383.89 301.86 5,958,815.54 378,129.64 0.00 -1,176.00 1,400.84 306.73 5,958,832.41 378,134.79 0.00 -1,189.97 1,438.49 317.55 5,958,869.88 378,146.22 0.00 -1,221.01 1,476.14 328.38 5,958,907.35 378,157.66 0.00 -1,252.04 1,513.80 339.21 5,958,944.82 378,169.09 0.00 -1,283.08 1,551.45 350.03 5,958,982.29 378,180.53 0.00 -1,314.12 1,589.10 360.86 5,959,019.76 378,191.96 0.00 -1,345.15 1,626.76 371.68 5,959,057.23 378,203.40 0.00 -1,376.19 1,664.41 382.51 5,959,094.70 378,214.83 0.00 -1,407.23 1,702.06 393.33 5,959,132.17 378,226.27 0.00 -1,438.26 1,739.72 404.16 5,959,169.63 378,237.70 0.00 -1,469.30 1,758.52 409.56 5,959,188.34 378,243.41 0.00 -1,484.79 1,776.57 415.18 5,959,206.30 378,249.32 4.00 -1,499.52 1,807.77 427.55 5,959,237.29 378,262.20 4.00 -1,523.98 1,832.37 441.42 5,959,261.66 378,276.46 4.00 -1,541.77 1,850.26 456.71 5,959,279.30 378,292.04 4.00 -1,552.78 1,861.35 473.34 5,959,290.12 378,308.85 4.00 -1,556.98 1,865.58 491.25 5,959,294.06 378,326.82 4.00 -1,554.33 1,862.94 510.33 5,959,291.11 378,345.86 4.00 -1,544.86 1,853.44 530.50 5,959,281.28 378,365.87 4.00 -1,528.61 1,850.89 534.40 5,959,278.67 378,369.72 4.01 -1,524.81 1,837.11 551.66 5,959,264.61 378,386.76 4.00 -1,505.65 1,814.05 573.70 5,959,241.20 378,408.42 4.00 -1,476.10 4/13/2006 4:31:43PM Page 4 of 8 COMPASS 2003.11 Build 50 ~~~~~L . `-' ConocoPhillip~ Alaska Database:- EDM 2003.11 Single User Db Company:. ConocoPhillips Alaska Inc. Project: Colville River Unit "Site:. Alpine CD4 WeIL• Plan: CD4-320 Welibore: Plan: CD4-320 :Design:: CD4-320wp05 Sperry Drilling Services HALLIBURTON Planning Report -Geographic ----.-..-.-_____________.__...._____ Sperry Drilling Services Local Co-ordinate Reference: Well Plan: CD4-320 TVD Reference: Planned Doyon 19 Q 55.30ft (Doyon 19 (36.3 + 19)) MD Reference: Planned Doyon 19 @ 55.30ft (Doyon 19 (36.3 + 19)) North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey CD4-320wp05 Map Map. MD Inclination Azimuth ND SSTVD +NiS +E/.W Northing Fasting DLSEV Vert Section (ft) (°) (°) (ft) lft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 6,500.00 23.76 144.88 6,099.93 6,044.63 1,784.37 596.53 5,959,211.15 378,430.76 4.00 -1,440.10 6,566.59 26.15 147.64 6,160.30 6,105.00 1,761.00 612.10 5,959,187.53 378,445.95 4.00 -1,412.64 Albian 96 6,600.00 27.37 148.85 6,190.13 6,134.83 1,748.20 620.01 5,959,174.61 378,453.65 4.00 -1,397.84 6,700.00 31.08 151.94 6,277.39 6,222.09 1,705.74 644.06 5,959,131.76 378,477.00 4.00 -1,349.50 6,800.00 34.84 154.43 6,361.28 6,305.98 1,657.17 668.53 5,959,082.81 378,500.68 4.00 -1,295.34 6,900.00 38.65 156.49 6,441.40 6,386.10 1,602.74 693.33 5,959,027.99 378,524.59 4.00 -1,235.61 7,000.00 42.48 158.23 6,517.35 6,462.05 1,542.72 718.32 5,958,967.57 378,548.59 4.00 -1,170.60 7,100.00 46.34 159.74 6,588.77 6,533.47 1,477.39 743.38 5,958,901.86 378,572.59 4.00 -1,100.64 7,200.00 50.22 161.06 6,655.30 6,600.00 1,407.08 768.39 5,95$,831.15 378,596.46 4.00 -1,026.05 7,296.04 53.96 162.19 6,714.30 6,659.00 1,335.19 792.26 5,958,758.88 378,619.15 4.00 -950.42 Top HRZ 7,300.00 54.11 162.24 6,716.63 6,661.33 1,332.13 793.24 5,958,755.81 378,620.08 3.97 -947.22 7,400.00 58.01 163.30 6,772.45 6,717.15 1,252.90 .817.79 5,958,676.20 378,643.34 4.00 -864.51 7,500.00 61.92 164.29 6,822.49 6,767.19 1,169.78 841.93 5,958,592.71 378,666.12 4.00 -778.33 7,600.00 65.84 165.20 6,866.51 6,811.21 1,083.18 865.55 5,958,505.74 378,688.32 4.00 -689.11 7,700.00 69.76 166.05 6,904.29 6,848.99 993.50. 888.52 5,958,415.71 378,709.83 4.00 -597.28 7,800.00 73.68 166.87 6,935.65 6,880.35 901.21 910.73 5,958,323.07 378,730.54 4.00 -503.28 7,900.00 77.61 167.65 6,960.44 6,905.14 806.73 932.08 5,958,228.27 378,750.35 4.00 -407.57 8,000.00 81.54 168.41 6,978.53 6,923.23 710.54 952.46 5,958,131.77 378,769.16 4.00 -310.62 8,019.72 82.31 168.56 6,981.30 6,926.00 691.41 956.36 5,958,112.58 378,772.75 4.01 -291.39 8,081..90 84.76 169.02 6,988.30 6,933.00 630.81 968.37 5,958,051.79 378,783.77 4.00 -230.62 Kuparuk C 8,088.06 85.00 169.07 6,988.85 6,933.55 624.79 969.53 5,958,045.75 378,784.83 4.00 -224.59 Continue D ir; 4° DLS , 0° TFO, 8088' MD, 6988' TVD 8,100.00 85.48 169.07 6,989.84 6,934.54 613.10 971.79 5,958,034.03 378,786.90 3.99 -212.90 8,200.00 89.48 169.07 6,994.24 6,938.94 515.03 990.73 5,957,935.67 378,804.24 4.00 -114.73 8,213.06 90.00 169.07 6,994.30 6,939.00 502.21 993.20 5,957,922.82 378,806.51 4.01 -101.90 Target (Hee l); 8213' MD, 6994' TVD -CD4-320wp05 Heel 8,220.00 90.00 169.07 6,994.30 6,939.00 495.39 994.52 5,957,915.98 378,807.71 0.00 -95.07 7" Csg Pt; 8220' MD, 6994' TVD, 2483' FNL 8 4404' FEL; Sec19-T11 N-R05E - 7" - 8,300.00 90.00 169.07 6,994.30 6,939.00 416.84 1,009.69 5,957,837.20 378,821.60 0.00 -16.45 8,400.00 90.00 169.07 6,994.30 6,939.00 318.65 1,028.65 5,957,738.73 378,838.96 0.00 81.83 8,500.00 90.00 169.07 6,994.30 6,939.00 220.47 1,047.61 5,957,640.26 378,856.32 0.00 180.11 8,600.00 90.00 169.07 6,994.30 6,939.00 122.28 1,066.57 5,957,541.78 378,873.68 0.00 278.39 8,700.00 90.00 169.07 6,994.30 6,939.00 24.10 1,085.53 5,957,443.31 378,891.04 0.00 376.67 8,800.00 90.00 169.07 6,994.30 6,939.00 -74.09 1,104.49 5,957,344.84 378,908.40 0.00 474.95 8,900.00 90.00 169.07 6,994.30 6,939.00 -172.28 1,123.45 5,957,246.36 378,925.76 0.00 573.23 9,000.00 90.00 169.07 6,994.30 6,939.00 -270.46 1,142.41 5,957,147.89 378,943.12 0.00 671.51 9,100.00 90.00 169.07 6,994.30 6,939.00 -368.65 1,161.37 5,957,049.42 378,960.48 0.00 769.79 9,200.00 90.00 169.07 6,994.30 6,939.00 -466.83 1,180.33 5,956,950.94 378,977.84 0.00 868.07 9,300.00 90.00 169.07 6,994.30 6,939.00 -565.02 1,199.29 5,956,852.47 378,995.20 0.00 966.36 9,400.00 90.00 169.07 6,994.30 6,939.00 -663.21 1,218.25 5,956,754.00 379,012.56 0.00 1,064.64 9,500.00 90.00 169.07 6,994.30 6,939.00 -761.39 1,237.21 5,956,655.52 379,029.92 0.00 1,162.92 9,600.00 90.00 169.07 6,994.30 6,939.00 -859.58 1,256.17 5,956,557.05 379,047.29 0.00 1,261.20 9,700.00 90.00 169.07 6,994.30 6,939.00 -957.76 1,275.13 5,956,458.58. 379,064.65 0.00 1,359.48 L~ ~?!GINAL ~.' ConocoPhillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska Inc. Project: Colville River Unit Stte: Alpine CD4 Wellc Plan: CD4-320 Wellbor+e: Plan: CD4-320 Design: CD4-320wp05 Sperry Drilling Services HALLIBUFITON Planning Report -Geographic ___w___.._._______~_._________.___._T Sperry Drilling Services Local Co-ordinate Reference: Well Plan: CD4-320 ND Reference: Planned Doyon 19 @ 55.30ft (Doyon 19 (36.3 + 19)) MD Reference: Planned Doyon 19 @ 55.30ft (Doyon 19 (36.3 + 19)) North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey CD4-320wp05 Map Map,> MD Inclination Azimuth TVD SSTVD +N/-S +El-W ' :Northing Easting DLSEV Vert Section (ft} (°) (°) (ft} (ft) (ft) (ft) (ft) (ft} (°l100ft} (ft) 9,800.00 90.00 169.07 6,994.30 6,939.00 -1,055.95 1,294.09 5,956,360.10 379,082.01 0.00 1,457.76 9,900.00 90.00 169.07 6,994.30 6,939.00 -1,154.14 1,313.05 5,956,261.63 379,099.37 0.00 1,556.04 9,994.03 90.00 169.07 6,994.30 6,939.00 -1,246.46 1,330.88 5,956,169.04 379,115.69 0.00 1,648.45 Target (T1); 9994' MD, 6994' TVD -CD4-320wp05 Ti 10,000.00 89.88 169.07 6,994.31 6,939.01 -1,252.32 1,332.01 5,956,163.16 379,116.73 2.00 1,654.32 10,005.51 89.77 169.07 6,994.32 6,939.02 -1,257.74 1,333.06 5,956,157.73 379,117.68 2.00 1,659.74 10,100.00 89.77 169.07 6,994.70 6,939.40 -1,350.51 1,350.97 5,956,064.69 379,134.09 0.00 1,752.60 10,200.00 89.77 169.07 6,995.10 6,939.80 -1,448.69 1,369.93 5,955,966.21 379,151.45 0.00 1,850.88 10,300.00 89.77 169.07 6,995.50 6,940.20 -1,546.88 1,388.89 5,955,867.74 379,168.81 0.00 1,949.16 10,400.00 89.77 169.07 6,995.90 6,940.60 -1,645.06 1,407.85 5,955,769.27 379,186.17 0.00 2,047.44 10,498.62 89.77 169.07 6,996.30 6,941.00 -1,741.90 1,426.55 5,955,672.15 379,203.29 0.00 2,144.36 LCU 10,500.00 89.77 169.07 6,996.31 6,941.01 -1,743.25 1,426.81 5,955,670.80 379,203.53 0.00 2,145.72 10,600.00 89.77 169.07 6,996.71 6,941.41 -1,841.43 1,445.77 5,955,572.32 379,220.89 0.00 2,244.00 10,700.00 89.77 169.07 6,997.11 6,941.81 -1,939.62 1,464.73 5,955,473.85 379,238.25 0.00 2,342.28 10,800.00 89.77 169.07 6,997.51 6,942.21 -2,037.80 1,483.69 5,955,375.38 379,255.61 0.00 2,440.56 10,900.00 89.77 169.07 6,997.91 6,942.61 -2,135.99 1,502.66 5,955,276.91 379,272.97 0.00 2,538.84 11,000.00 89.77 169.07 6,998.31 6,943.01 -2,234.18 1,521.62 5,955,178.44 379,290.33 0.00 2,837.12 11,100.00 89.77 169.07 6,998.71 6,943.41 -2,332.36 1,540.58 5,955,079.96 379,307.69 0.00 2,735.40 11,200.00 89.77 169.07 6,999.11 6,943.81 -2,430.55 1,559.54 5,954,981.49 379,325.05 0.00 2,833.68 11,300.00 89.77 169.07 6,999.51 6,944.21 -2,528.73 1,578.50 5,954,883.02 379,342.41 0.00 2,931.96 11,400.00 89.77 169.07 6,999.91 6,944.61 -2,626.92 1,597.46 5,954,784.55 379,359.77 0.00 3,030.24 11,496.33 89.77 169.07 7,000.30 6,945.00 -2,721.49 1,615.72 5,954,689.69 379,376.49 0.00 3,124.91 11,500.00 89.77 169.07 7,000.31 6,945.01 -2,725.10 1,616.42 5,954,686.07 379,377.13 0.00 3,128.52 11,600.00 89.77 169.07 7,000.72 6,945.42 -2,823.29 1,635.38 5,954,587.60 379,394.49 0.00 3,226.80 11,700.00 89.77 169.07 7,001.12 6,945.82 -2,921.47 1,654.34 5,954,489.13 379,411.85 0.00 3,325.08 11,800.00 89.77 169.07 7,001.52 6,946.22 -3,019.66 1,673.30 5,954,390.66 379,429.21 0.00 3,423.36 11,900.00 89.77 169.07 7,001.92 6,946.62 -3,117.84 1,692.26 5,954,292.18 379,446.57 0.00 3,521.64 12,000.00 89.77 169.07 7,002.32 6,947.02 -3,216.03 1,711.22 5,954,193..71 379,463.93 0.00 3,619.92 12,100.00 89.77 169.07 7,002.72 6,947.42 -3,314.21 1,730.18 5,954,095.24 379,481.29 0.00 3,718.19 12,200.00 89.77 169.07 7,003.12 6,947.82 -3,412.40 1,749.14 5,953,996.77 379,498.66 0.00 3,816.47 12,300.00 89.77 169.07 7,003.52 6,948.22 -3,510.58 1,768.10 5,953,898.30 379,516.02 0.00 3,914.75 12,400.00 89.77 169.07 7,003.92 6,948.62 -3,608.77 1,787.06 5,953,799.82 379,533.38 0.00 4,013.03 12,494.03 89.77 169.07 7,004.30 6,949.00 -3,701.09 1,804.89 5,953,707.23 379,549.70 0.00 4,105.45 Target (T2); 12494' MD, 7004' TVD -CD4-320wp05 T2 12,500.00 89.77 169.07 7,004.32 6,949.02 -3,706.95 1,806.02 5,953,701.35 379,550.74 0.01 4,111.31 12,600.00 89.78 169.07 7,004.71 6,949.41 -3,805.14 1,824.98 5,953,602.88 379,568.10 0.01 4,209.59 12,700.00 89.79 169.07 7,005.08 6,949.78 -3,903.32 1,843.94 5,953,504.41 379,585.46 0.01 4,307.87 12,800.00 89.80 169.07 7,005.44 6,950.14 -4,001.51 1,862.90 5,953,405.93 379,602.82 0.01 4,406.15 12,900.00 89.82 169.07 7,005.77 6,950.47 -4,099.70 1,881.86 5,953,307.46 379,620.18 0.01 4,504.43 13,000.00 89.83 169.07 7,006.08 6,950.78 -4,197.88 1,900.82 5,953,208.99 379,637.54 0.01 4,602.71 13,100.00 89.84 169.07 7,006.37 6,951.07 -4,296.07 1,919.78 5,953,110.52 379,654.90 0.01 4,700.99 13,200.00 89.85 169.07 7,006.64 6,951.34 -4,394.25 1,938.74 5,953,012.04 379,672.26 0.01 4,799.27 13,300.00 89.86 169.07 7,006.90 6,951.60 -4,492.44 1,957.70 5,952,913.57 379,689.62 0.01 4,897.55 13,400.00 89.87 169.07 7,007.13 6,951.83 -4,590.62 1,976.66 5,952,815.10 379,706.98 0.01 4,995.84 13,500.00 89.88 169.07 7,007.34 6,952.04 -4,688.81 1,995.63 5,952,716.62 379,724.34 0.01 5,094.12 13,600.00 89.89 169.07 7,007.54 6,952.24 -4,787.00 2,014.59 5,952,618.15 379,741.70 0.01 5,192.40 \.J ORIGINAL •-' ° • Sperry Drilling Services ~ MALLIBUFiTON ConocaPhill~p~s Planning Report -Geographic Sperry-D~i~ting se~Ges .Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan: CD4-320 Company: ConocoPhillips Alaska Inc. ND Reference: Planned Doyon 19 @ 55.30ft (Doyon 19 (36.3 + 19)) Protect: Colville River Unit MD Reference.: Planned Doyon 19 @ 55.30ft (Doyon 19 (36.3 + 19)) Site:. Alpine CD4 North Reference: True WeIL Plan: CD4-320 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD4-320 Design: CD4-320wp05 Planned Survey CD4-320wp05 AAap Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Fasting DLSEV Vert Section (ft) (°j (°) lft) (ftj (ftl (ft) (ft) {ft) (°I100ft) (ft) 13,700.00 89.91 169.07 7,007.71 6,952.41 -4,885.18 2,033.55 5,952,519.68 379,759.06 0.01 5,290.68 13,800.00 89.92 169.07 7,007.87 6,952.57 -4,983.37 2,052.51 5,952,421.21 379,776.42 0.01 5,388.96 13,900.00 89.93 169.07 7,008.00 6,952.70 -5,081.55 2,071.47 5,952,322.73 379,793.78 0.01 5,487.24 14,000.00 89.94 169.07 7,008.12 6,952.82 -5,179.74 2,090.43 5,952,224.26 379,811.15 0.01 5,585.52 14,100.00 89.95 169.07 7,008.21 6,952.91 -5,277.93 2,109.39 5,952,125.79 379,828.51 0.01 5,683.80 14,200.00 89,96 169.07 7,008.29 6,952.99 -5,376.11 2,128.35 5,952,027.31 379,845.87 0.01 5,782.08 14,213.81 89,96 169.07 7,008.30 ' 6,953.00 -5,389.67 2,130.97 5,952,013.72 379,848.26 0.01 5,795.65 Target (Toe); 14213' MD, 7008' TVD, 3088' FNL 8 3292' FEL; Sec30-T11 N-R05E - 6-1 /8" Open Hole -CD4-320wp05 Toe , Geologic Targets Plan: CD4-320 TVD Target Name +N1-S +E/-W Northing Fasting (ft) . gape ft ft Ift) (ft) 6,994.30 CD4-320wp05 T1 -1,246.46 1,330.88 5,956,169.04 379,115.69 - Point 7,004.30 CD4-320wp05 T2 -3,701.09 1,804.89 5,953,707.23 379,549.70 - Point 7,008.30 CD4-320wp05 Toe -5,389.67 2,130.97 5,952,013.72 379,848.26 - Point 6,994.30 CD4-320wp05 Heel 502.21 993.20 5,957,922.82 378,806.51 - Point Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) ("j (") 2,514.56 2,390.00 9-5/8 12-1 /4 8,220.00 6,994.30 7 8-3/4 14,213.80 7,008.30 6-118 6-118 4/13/2006 4:31:43PM Page 7 of 8 COMPASS 2003.11 Build 50 !~~~... `/ ConocoPhillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska Inc. Rroject: Colville River Unit Site: Alpine CD4 Well:.. Plan: CD4-320 Wellbore: Plan: CD4-320 '.Design: CD4-320wp05 Sperry Drilling Services MALLIBURTON Planning Report -Geographic -~ ---°-- -_- --------~-- $parry Drilling Sarvlces Local Co-ordinate Reference: Well Plan: CD4-320 ND Reference: Planned Doyon 19 Q 55.30ft (Doyon 19 (36.3 + 19)) MD Reference: Planned Doyon 19 @ 55.30ft (Doyon 19 (36.3 + 19)) North Reference: True Survey Calculation Method: Minimum Curvature Prognosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +N/-E +EI-W (ft) (~) (~) Ift) (g) (~) Name- 2,309.46 23.07 16.04 2,201.30 576.03 69.59 C-40 2,526.84 23.07 16.04 2,401.30 657.88 93.13 C-30 2,922.47 23.07 16.04 2,765.30 806.84 135.95 C-20 4,072.40 23.07 16.04 3,823.30 1,239.83 260.44 K-3 4,302.82 23.07 16.04 4,035.30 1,326.59 285.38 Basal K-3 4,339.77 23.07 16.04 4,069.30 1,340.51 289.38 K-2 4,454.98 23.07 16.04 4,175.30 1,383.89 301.86 Base K-2 6,218.76 14.62 124.24 5,834.30 1,850.89 534.40 Albian 97 6,566.59 26.15 147.64 6,160.30 1,761.00 612.10 Albian 96 7,296.04 53.96 162.19 6,714.30 1,335.19 792.26 Top HRZ 8,081.90 84.76 169.02 6,988.30 630.81 968.37 Kuparuk C ' 10,498.62 89.77 169.07 6,996.30 -1,741.90 1,426.55 LCU - 7,029.30 Base Hrz 4/13/2006 4:31:43PM Page 8 of 8 COMPASS 2003.11 Build 50 ~~ ORIGINAL • • ConocoPhillips Alaska ConocoPhillips Alaska Inc. Colville River Unit Alpine CD4 Plan: CD4-320 Plan: CD4-320 CD4-320wp05 Anticollision Report 30 March, 2006 HA~~~I~~~-ron~ Sperry Drilling services '~'t!GINAL • • a 7 3 .C v ~~~~ III I ,9a ~~~#"~' II !III~I ~ €.i~c:L~°`t ~ II IIIII _~q~~. II I III s~ z ~ a ~~ ~O ~ ~ ~ m_{ J ° i c ~ V O ~~ ~ ~ / 'n ;i W i d. w / \ 1 m ~i i ,~ S Z ORIGINAL ~~ ^~ g ~3 ~d 5 ~~ :~ yssasasassssx ~°°a°°° °°°_°4 as~sa.s.sass.a-. osa r., .,va.arae " 388Y±G5~Rq~~& tae Rn~X&~~~R v { "88=~3~ ~~~'e ~ iaa_S ~~9,d3 F,e~ PR85;~F~Y~ ~~~, ~~#a3~~~~ ~~~ *~ssa€aassssss. ~~T~d~b~~~a '~~dBSaa~aR€=~ ?R8883a~B$¢em ~x~~~~~~g~~a# z ~, U U s 0 LL t E Q U g Y • ~ of sss ~~~ s. a~i >Ws~ z zm~~ 0 0 0 N O M M ~~ ConocoPhitGps Alaska Company: ConocoPhillips Alaska Inc. Project: Colville River Unit Reference Site:. Alpine CD4 Site Error: O.OOft Reference Wellc Plan: CD4-320 WeII Error: O.OOft Reference Welibore Plan: CD4-320 Refeirence Design: CD4-320wp05 Sperry Drilling Services Anticollision Report Local Co-ordinate Reference:-- TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output-errors are at Database: Offset TVD Reference: HALLIBURTON Sperry Orilllin8 Services Well Plan: CD4-320 -Slot 20 Planned Doyon 19 Q 55.30ft (Doyon 19 (36.3 + 19)) Planned Doyon 19 Q 55.30ft (Doyon 19 (36.3 + 19)) True Minimum Curvature 1.00 sigma EDM 2003.11 Single User Db Offset Datum srence CD4-320wp05 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refere Interpolation Method: MD Interval 25.OOft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,617.75ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool. Program Date 3/3012006 From. To (ft) (ft) Survey (Welibore) Tool Name Description 36.30 1,000.00 CD4-320wp05 (Plan: CD4-320) CB-GYRO-SS Camera based gyro single shot 1,000.00 14,213.81 CD4-320wp05 (Plan: CD4-320} MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Summary Reference Offset Centre to No-Go Allowable -Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Weli -Welibore - f)esigrr {ft) (ft) (ft) (ft) Alpine CD4 CD4-208 -CD4-208 -CD4-208 495.49 500.00 240.48 10.35 230.12 Pass -Major Risk CD4-208 -CD4-208P61 -CD4-208PB 1 495.49 500.00 240.48 10.35 230.12 Pass -Major Risk CD4-318 -CD4-318 -CD4-318 722.65 725.00 23.02 14.47 8.70 Pass -Major Risk CD4-318 -CD4-318PB1 -CD4-318P61 722.65 725.00 23.02 ~ 14.47 8.70 Pass -Major Risk CD4-319 -CD4-319 -CD4-319 399.54 400.00 17.72 8.10 9.63 Pass -Major Risk Nanuq 3 -Nanuq 3 -Nanuq 3 414.78 400.00 140.97 7.58 133.40 Pass -Major Risk Nanuq 3 /Plan: CD4-227 -Nanuq 3 -Nanuq 3 414.78 400.00 140.97 7.61 133.37 Pass -Major Risk Nanuq 3 /Plan: CD4-227 -Plan: CD4-227 -CD4- < 426.81 425.00 141.20 7.83 133.38 Pass -Major Risk Nanuq 5 -Nanuq 5 -Nanuq 5 252.59 250.00 161.64 4.63 157.01 Pass -Major Risk Nanuq 5 /Plan: CD4-212 -Nanuq 5 -Nanuq 5 252.59 250.00 161.64 4.66 156.98 Pass -Major Risk Nanuq 5 /Plan: CD4-212 -Plan: CD4-212 -CD4- ~ 252.59 250.00 161.64 4.66 156.98 Pass -Major Risk Plan: CD4-206 -Plan: CD4-206 -CD4-206wp05 495.17 500.00 279.70 10.55 269.16 Pass -Major Risk Plan: CD4-207 -Plan: CD4-207 -CD4-207wp04 3,580.17 3,650.00 283.07 67.36 223.50 Pass -Major Risk Plan: CD4-209 -Plan: CD4-209 -CD4-209wp05 495.68 500.00 221.50 10.54 210.95 Pass -Major Risk Plan: CD4-210 -Plan: CD4-210 -CD4-210wp04 447.17 450.00 200.88 9.48 191.40 Pass -Major Risk Plan: CD4-211 -Plan: CD4-211 -CD4-211wp04 1,100.59 1,125.00 186.66 23.78 163.41 Pass -Major Risk Plan: CD4-213 -Plan: CD4-213 -CD4-213wp03 637.91 650.00 133.68 13.77 119.92 Pass -Major Risk Plan: CD4-214 -Plan: CD4-214 -CD4-214wp03 690.31 700.00 124.47 14.87 109.63 Pass -Major Risk Plan: CD4-215 -Plan: CD4-215 -CD4-215wp03 687.71 700.00 85.43 14.85 70.60 Pass -Major Risk Plan: CD4-216 -Plan: CD4-216 -CD4-216wp03 1,319.65 1,325.00 37.07 26.56 11.97 Pass -Major Risk Plan: CD4-217 -Plan: CD4-217 -CD4-217wp02 569.39 575.00 40.39 12.09 28.30 Pass -Major Risk Alpine Satellites Nanuq 1 -Nanuk 1 -Nanuk 1 +e~8,024.52 6,975.00 182.98 105.51 77.72 Pass -Major Risk Nanuq 3 -Nanuq 3 -Nanuq 3 414.78 400.00 140.89 7.58 133.33 Pass -Major Risk Nanuq 5 -Nanuq 5 -Nanuq 5 252.59 250.00 161.64 4.63 157.01 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 3/30/2006 10:56:45AM Page 2 of 2 COMPASS 2003.11 Build 50 .~, W ~ ~ • ~~~ 2q M O O ~ C_ O O LL9 r t w N 10 O W N d 3 0 0 0 0 0 M O O O O O Op.M« CoiwWNlNlpt AbNw lnc Orid con.clion: -p.f] ° leE Ne: IN/A NNE: CdY]M N.w UnX M.pn.NC O.clnolion. I].]4 ° Ar! Mo: tN/A WW cDd-l]h'p05 dp: lp.Xt All No. IN/A ' Np: /N/A Degbp Pa IW It SY°lem (1Y01 R.Inen ca .rN wN.~. l«.n.n Original VS Plane: 158.43 m~.nl w.N rbn:cwem meps.]e n Vlew VS Plane: 158.43 RS] p ss.w N .. s.s>AU.pR 11 unn sr.l..n S.clion IVSI R.ler.nc.. Comments: Plan View _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ O - N n .~ n M n n w M n M n c~ n n n c~ c~ 5960000 5959000 5958000 5957000 5956000 5955000 5954000 (~~ ~j 5953000 V I 5952000 5951000 D 5950000 5949000 5948000 L a 0 ~ 4000 0 V . ~ ~ 5000 N m 6000 T H ~~(~ 8000 9000 ~ ~ ~ ~ ~ o ~ ~ ~ ~ ~ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 v v v v v v] In h h ~ 'n h ~ ~ r7 ~ v e v e v v v v v v v e O O- 4Q ~O h Q M N - N (h Q h ~O ~ 00 P O N CJ O ~ ~O Vertical Section along "View VS Plane" Combo Preview Page 1 of 1 (CD4-320wp05 Toolbox (4_13_2006).xls) 4/13/2006 4:27 PM • • ~O \ / O ~ O y O \ ~ n V 0 ~\ v 00 / L 00 ~ ~ ~ (~ o ~ V a cv ~ Z \ ° N M i 0 0 ~ ~s ~ o ~~ o o °~ ; j; o ~~ / / A T 1 r Q C Z '~ o o ~ (V 7 ~ M ~ ~ ~ ~VUU o3 C ~ c c c M ~ ~ .Saga v \ ~ Z a ~~~ % a = '" rc~A / z; \ `~ M Q ~~ 7 C N ~ / ` ~ Q~ ~ m Z p ~ ,, ~/ rn ~ 7 ~' , - ~ ~ v - ~ o\ % m 's ~ U G J ~' ~~ ~~ ~ `1 V I ~ ORIGINAL Closest in POOL Closest Approach: Reference Well: CD4-320wp05 Plan Offset Well: Nanuk 1 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Incl. Subsea N(+)/S(-) View VS Meas. Incl. Subsea N(+)/S(-) View VS Min. Dist. Depth Angle TRUE Azi. TVD E(+ /W(-) (158.43°) Comments Depth Angle TRUE Azi. ND E(+)/yy(_) (158.43°) Comments POOL Min Distance POOL Min Distance (268.33 ft) in POOL (268.33 ft) in POOL (8220 - 14213.81 MD) (8220 - 14213.81 to Nanuk 1 (6930 - t to CD4-320wp05 P 378807 9 95 31087 6955 TVDss) ~ 6975 0 38 38.66 6935.794 5958142 378953.1 -266.0884 (6930 - 6955 TVDss) 26$.33 8220 90 169.07 6938.871 5957916 . . - . Closest Approach: Reference Well: CD4-320wp05 Plan Offset Well: Nanuq 5 Coords. - Coords. - ,.,~ ASP ASP ~ctr-ctr Meas. Incl. Subsea N(+)/S(-) View VS Meas. Incl. Subsea N(+)/g(_) View VS Dist. Depth Angle TRUE Azi. TVD E(+)/W(-) (158.43°) Comments Depth Angle TRUE Azi. TVD E +)/W(- (158.43° Comments POOL Min Distance POOL Min Distance (2741.85 ft) in POOL (2741.85 ft) in POOL (8220 - 14213.81 MD) (8220 - 14213.81 MD) to Nanuq 5 (6930 - to CD4-320wp05 Plan 2741.85 14213.81 89.96 169.07 6952.886 5952014 379848.7 5795.421 6955 TVDss) 11475 57.71 160.68 6936.45 5949348 380491.7 8516.336 (6930 - 6955 TVDss) Closest Approac h: Reference Well: CD4-320wp05 Plan Offset Well: CD4-319 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Incl. Subsea N(+)/S(-) View VS Meas. Inci. Subsea N(+)/S(-) View VS Min. Dist. Depth Angle TRUE Azi. TVD E(+)/W(-) (158.43°) Comments Depth Angle TRUE Azi. TVD E(+)/W(-) (158.43°) Comments POOL Min Distance POOL Min Distance (5889.23 ft) in POOL (5889.23 ft) in POOL (8220 - 14213.81 MD) (8220 - 14213.81 MD) to CD4-320wp05 Plan to CD4-319 (12005 - (12005 - 18683.23 5ggg,23 10825 89.77 169.07 6942.184 5955351 379260.2 2464.894 18683.23 MD) 14375 90.1 349.86 7094.23 5954333 373461.7 1373.882 MD) POOL Summary1.xls 4/17/2006 2:51 PM • • SHARON K. ALLSUP-DRAKE 1144 CONOCOPHILLIPS ATO 1530 ~2, /1n 700 G ST, oarE ~[/ r~ ` r I . ANCHORAGE AK 9950~1~t ~1 ss-issi/aa~ PAY TO THE ~~y-/ T. v~ µ/ ~.~~ ,~/ JJ /'1/~~~ ~y~~ r ORDER OF r , G 1 `t--/ t ~' n f'~(/L ~ ~C~(J 1..~ ~~ , u ,~ J ,, ~ iL~ p "~-`-~ ~~ "'~ --r'Y S ~ ~ fL~C~ ~RARS LJ ire, JPMOrganChase ~ % Valid Up To 5000 Dollars JPMorgan Chase Bank, N.A. Columbus, OH , `- , _ MEMO ~~ ~ ~ ~Cc --- --- ------- `j~ _M' -- ~~Z~ -- ------- - ---- ~:0441.15 5 L L~: 5 28 74 7 190 79 2 Iii' ~ L44 • • TRANSMITTAL LETTER CHECKLIST WELL NAME ~~~ C~ ~ 32~ PTD# ~y 6 " ~~~ _ Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If Last two digits in permit No. API No. 50- - - API number are , between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Company NameZhas designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1 /25/06 C:\j ody\transmittal_checkl ist WELL PERMIT CHECKLIST Field & Pool COLVILLE RIVER, NANUQ•KUPK OIL -120185 Well Name: COLVILLE RIV UN NANUQ CD4-320 Program DEV Well bore seg ^ PTD#:2060550 Company CONOCOPHILLIPS ALASKA INC Initial ClasslType DEV! PEND GeoArea 890 Unit 50360 On10ff Shore On Annular Disposal ^ Administration 1 Pe[mitfee attached - - - Yes - - - - - - - - 2 Lease number appropriate- - _ - - _ - - - - _ _ _ - . _ _ Yes Surface location in ADL 380077;_ top prod intervaland TD in_ADL_3.84211, _ _ _ .. _ _ - 3 Unique well-name and number - -- ---------- -- ---- - -- --- ,Yes---- --- ---...- -- ---- -- --------------_.- ----- -- ------ ------ - - 4 Well located in_a,defned-pool, _ - - - - - - - - - - - - - Yes Colville.River Unit, Nanuq Oil_Pool, governed by-Conservation Order_No. 563. _ _ _ _ - 5 Well located properdistance-from drilling unit_bour~dary_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _Yes _ . _ - _ _ _ Conservation Ofde[ NQ. 562 has no interwell_spacingrestricti9ns, Wellbore will be_more than 500' from - _ - . _ _ - 6 Well located proper distance. from other wells. _ - . - _ _ - . _ Yes - - - - . an external property line_where_ownership or_landgwnersh~ changes_ _ _ _ _ _ _ __ _ _ _ _ 7 Sufficient acreageayailablein.drillingunit____________________-_ ________-Yes--.. -__ - - -- - - 8 If deviated,iswellboreplat_included---_______-_-___---__-__ ______ _-Yes____ ____________ - - - - - - - 9 Operator only affected party - Yes - - - - - - - - 10 Operator has appropriate-bond'knforce________________________ _________Yes-._- -._--..-........._. 11 Permit can be issued without conservation order Yes Appr Date 12 Pe[mitcan be issued without administrativ_e_appr_oval _ - - - - - _ - - - _ . _ - . -Yes _ _ _ _ - SFD 4118/2006 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strataapthorizedbylnjection0rde[#(put10#in_comments)-(For. NA_____ _______________________________________________________________________ 15 All wells wthin 114_mile area_of review jdentified (For se[v-ice well only)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA. _ . - - .. , _ _ - _ _ . - _ _ _ _ _ _ _ _ . 16 Pre-produced injector_dur_ationofpre-production less_than3mgnths-(Forservicewellonly)-_NA_____ ____________________________________---._--________________-__-_-_.__ ACMP_Finding of Consistency-has been issued-forthis project - - - - NA_ _ Engineering 18 Conductor string_p_rovided - - - - - Yes - - - - - - 19 Surface casing_protectsallknown.USDWs__-_.......-__ ___._...NA.--.- _-No aquifersperAlQ1$A,conclusion3.___________________________________________ 20 CMT_vol.adequate-tocirculate_on conductor&surfcsg_ ____________ _________Yes__-- _-:---__-______________-.-___- ----------------------------------------- 21 CMT_v_ol. adequate_to tie-in long string to surf csg_ N_o_ _ - _ _ - - All_ hydrocarbons will be covered.- Annular disposal may be proposed.- - .. - - .. - - - 22 CMT_will coyer_all known-productive horizons- - - - - - - - - - - - - - No- _ Slotted liner completion planned, _ . _ -------------------------------- 23 Casing designs adequate for C, T,B&-permafrost---- ------------- --- Yes---- ---------------.--.------------------- -----------------------.--.-- 24 Adequate tankage_o_r reserve pit - _ Yes _ Rig is_equippedwith steel_pits.-No reserve_pitplanned, All waste to-approved annulus_ordisposal well(s), _ _ - _ 25 Ifa-re-drill,has_a_1.0-403 for abandonment been approved___ _________ _________ NA_____ __.___.-----_- 26 Adequate wellbore separationproposed_ _ _ _ _ _ _ _ _ _ _ _ _ ___ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes . - - . _ - _ Proximity. analysis performed, Traveling cylinder path calculated: Gyros planned j4surface hole.. - . _ _ - _ - _ - - 27 If diverter required, does it meet regu_lations_ - - - _ . _ _ - - _ NA_ - Diyerter waiver requested. No shallow gas-problems-reported in any wells at Nanuq. - 20AAC 25.035(h)(2). Appr Date 28 Drilling fluid_programschematic-& equip listadequate_ _ - - _ - - _ _ - . _ - -Yes _ Maximum expected formation pressure 8,7_FMW._ MW planned up to 9,8_ppg in8-3/4"-hole apd 6.3 ppg in Kuparu TEM 4119/2006 29 B_OPEs,dotheymeelregulation____________________________ _____,-Yes___ _--__--__-_____________.__--__-_____________ --------------------------- 30 BOPS-press rating appropriate; test to_(put prig in comments)_ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes . - . - . - - MASP calculated at 2464 psi, 3500_psi_appr_opriate_. _CP_AI usually tests to 500Q psi. _ _ _ _ _ _ _ _ . , _ _ _ _ _ _ - _ 31 Choke_manifold complies w1APt_ RP-53 (May 84)_ Yes -- - - ----- - - - - - 32 Work will occur without operation shutdown_--_.-____ __________ _______-Yes__-_ ____---___.____________-_____________________,.-----__-___________ 33 Ispresence_ofH2Sgasprobable ______--__________________ _________ No_____ __.H2ShasnotbeenreportedinanyofthewellsatGD4.______-_________,-----_._-______-__ , 34 Mechanical condition of wells within AOR verified (For_service well only) _ _ - - _ _ - N_A_ _ - - .. . Geology 35 Permit_can be issued wlo hydrogen_sulfiderneasures - . - . - - - - - . - . - - - -Yes H2$ not encountered in offset wells.. Mitigation measures discussed in Drilling Hazards-section__ _ _ _ _ _ _ _ _ _ _ _ 36 Data_presented on_ potential overpressure zones Yes - . - . - - -Expected reseryoirpressure is 8:7.ppg EMW; will be drilled with mud weight of 9.0-9.3 ppg. _ _ - _ _ Appr Date 37 Seismic analysis of shallow gas zones. . _ - - _ - - _ - - .. - - - NA_ Mulkiple wells drilled from this pad._Hydrates or shallow gas are. unlikely, mitigation measures discussed. _ SFD 4!1812006 38 Seabed condition survey_(if off-shore) . - - _ - _ _ _ _ _ - - NA -- 39 Contact name/phone for weekly.p_rogress reports (exploratory only] - - _ _ - - NA_ - - Geologic Engineering Commissioner: Date: Commissioner: Date Co ner Date • • Well History File APPENDIX • Information of detailed nature that is not particularly germane to the Well Pen~nitting Process but is part of the history file. To improve the readability of the Well History file and 10 simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. • • Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Aug 04 09:47:48 2006 Reel Header Service name ............. LISTPE Date ..................... 06/08/04 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number...... 01 Previous Reel Name....... UNKNOWN Comments ................. STS LIS Writing Library Tape Header Service name ............. LISTPE Date ..................... 06/08/04 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number...... 01 Previous Tape Name....... UNKNOWN Comments ................. STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Colville River Nanuq(KUparuk) MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 2 JOB NUMBER: MW0004477289 LOGGING ENGINEER: J. BOBBITT OPERATOR WITNESS: D. BURLY SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD Scientific Technical Services Scientific Technical Services CD4-320 501032053100 ConocoPhillips Alaska, Inc. Sperry Drilling Services 04-AUG-06 MWD RUN 4 MWD RUN 5 MW0004477289 MW0004477289 J. BOBBITT J. BOBBITT D. LUTRICH D. BURLEY 24 11N 4E 2978 438 56.72 19.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.750 9.625 2509.0 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE WAS EFFECTED BY DRILLING OFF OF A ~-o~ ~ /~/a3~ ~ • CEMENT PLUG AT 4341'MD/4089' TVD, WITHIN THE RUN 2 INTERVAL OF THE CD4-320 PB1 WELLBORE. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,4,5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUNS 2,4 ALSO INCLUDED GEOPILOT ROTARY-STEERABLE BHA (GP), AND MWD RUN 2 INCLUDED GAMMA AT BIT (GAB). 6. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT CONOCO-PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR THE DRILLSITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 7. MWD RUNS 1,2,4,5 REPRESENT WELL CD4-320 WITH API#: 50-103-20531-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8155'MD/6992'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/04 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2481.5 8114.0 FET 2490.0 8106.5 RPD 2490.0 8106.5 RPS 2490.0 8106.5 RPM 2490.0 8106.5 RPX 2490.0 8106.5 ROP 2519.5 8155.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH -- BASELINE DEPTH • MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 2 MWD 4 MWD 5 REMARKS: MERGED MAIN PASS. MERGE TOP MERGE BASE 2481.5 4341.0 4341.5 6372.0 6372.0 8155.0 Data Format Specification Record Data Record Type ................ ..0 Data Specification Block Type... ..0 Logging Direction ............... ..Down Optical log depth units......... ..Feet Data Reference Point ............ ..Undefined Frame Spacing ................... ..60 .lIN Max frames per record ........... ..Undefined Absent value .................... ..-999 Depth Units ..................... .. Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel • DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2481.5 8155 5318.25 11348 2481.5 8155 RPD MWD OHMM 0.33 2000 22.9668 11234 2490 8106.5 RPM MWD OHMM 0.38 1743.45 8.86072 11234 2490 8106.5 RPS MWD OHMM 0.33 1535.52 6.73145 11234 2490 8106.5 RPX MWD OHMM 0.45 2000 6.95975 11234 2490 8106.5 FET MWD HOUR 0.16 201.85 1.08493 11234 2490 8106.5 GR MWD API 47.12 433.34 114.529 11266 2481.5 8114 ROP MWD FT/H 0.34 325.85 137.813 11272 2519.5 8155 First Reading For Entire File..........2481.5 Last Reading For Entire File...........8155 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/04 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/04 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD • • Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2481.5 4341.0 FET 2490.0 4341.0 RPX 2490.0 4341.0 RPS 2490.0 4341.0 RPM 2490.0 4341.0 RPD 2490.0 4341.0 ROP 2519.5 4341.0 LOG HEADER DATA DATE LOGGED: 06-JUL-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 4341.0 TOP LOG INTERVAL (FT) 2519.0 BOTTOM LOG INTERVAL (FT) 4341.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 8.4 MAXIMUM ANGLE: 25.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132482 EWR4 ELECTROMAG. RESIS. 4 10505932 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.750 DRILLER'S CASING DEPTH (FT) 2509.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G) 9.60 MUD VISCOSITY (S) 36.0 MUD PH: 9.2 MUD CHLORIDES (PPM): 350 FLUID LOSS (C3) 6.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 4.700 68.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.980 111.0 MUD FILTRATE AT MT: 5.400 68.0 MUD CAKE AT MT: 5.000 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2481.5 4341 3411.25 3720 2481.5 4341 RPD MWD020 OHMM 0.33 2000 18.4824 3703 2490 4341 RPM MWD020 OHMM 0.38 1743.45 8.02677 3703 2490 4341 RPS MWD020 OHMM 0.33 1535.52 5.66286 3703 2490 4341 RPX MWD020 OHMM 0.45 2000 6.85478 3703 2490 4341 FET MWD020 HOUR 0.16 56.08 1.37042 3703 2490 4341 GR MWD020 API 51.77 200.14 117.242 3720 2481.5 4341 ROP MWD020 FT/H 0.34 325.85 191.165 3644 2519.5 4341 First Reading For En tire Fil e.... ......2481.5 Last Reading For Ent ire File ..... ......4341 File Trailer Service name ..... ........ STSLI B.002 Service Sub Level Name... Version Number... ........ 1.0.0 Date of Generation....... 06/08 /04 Maximum Physical Record.. 65535 File Type ........ ........ LO Next File Name... ........ STSLI B.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/04 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 4341.5 6330.5 RPS 4341.5 6330.5 GR 4341.5 6338.0 RPX 4341.5 6330.5 RPM 4341.5 6330.5 RPD 4341.5 6330.5 ROP 4341.5 6372.0 LOG HEADER DATA DATE LOGGED: 15-JUL-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6372.0 TOP LOG INTERVAL (FT) 4341.0 BOTTOM LOG INTERVAL (FT) 6372.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 8.1 MAXIMUM ANGLE: 22.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBE R DGR DUAL GAMMA RAY 132482 EWR4 ELECTROMAG. RESIS. 4 10505932 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.750 DRILLER'S CASING DEPTH (FT) 2509.0 BOREHOLE CONDITIONS . MUD TYPE: Polymer MUD DENSITY (LB/G) 10.50 MUD VISCOSITY (S): 38.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 400 FLUID LOSS (C3) 4.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT) 2.200 70.0 MUD AT MAX CIRCULATING TERMPERATURE : 1.280 125.0 MUD FILTRATE AT MT: 1.900 70.0 MUD CAKE AT MT: 3.200 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .............. ....0 Data Specification Block Type. ....0 Logging Direction ............. ....Down Optical log depth units....... ....Feet Data Reference Point .......... ....Undefined Frame Spacing ................. ....60 .lIN Max frames per record ......... ....Undefin ed Absent value .................. ....-999 Depth Units ................... .... Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4341.5 6372 5356.75 4062 4341.5 6372 RPD MWD040 OHMM 3.6 11.48 5.73855 3979 4341.5 6330.5 RPM MWD040 OHMM 3.38 13.42 5.49147 3979 4341.5 6330.5 RPS MWD040 OHMM 3.45 17.98 5.56609 3979 4341.5 6330.5 RPX MWD040 OHMM 3.45 21.91 5.54856 3979 4341.5 6330.5 FET MWD040 HOUR 0.24 201.85 0.570206 3979 4341.5 6330.5 GR MWD040 API 47.12 148.63 96.826 3994 4341.5 6338 ROP MWD040 FT/H 2.95 215.58 135.181 4062 4341.5 6372 • • First Reading For Entire File..........4341.5 Last Reading For Entire File...........6372 File Trailer Service name .......... ...STSLIB.003 Service Sub Level Name ... Version Number........ ...1.0.0 Date of Generation.... ...06/08/04 Maximum Physical Record..65535 File Type ............. ...LO Next File Name........ ...STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/04 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 6331.0 8106.5 RPX 6331.0 8106.5 RPD 6331.0 8106.5 FET 6331.0 8106.5 RPS 6331.0 8106.5 GR 6338.5 8114.0 ROP 6372.5 8155.0 LOG HEADER DATA DATE LOGGED: 17-JUL-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 8155.0 TOP LOG INTERVAL (FT) 6372.0 BOTTOM LOG INTERVAL (FT) 8155.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 15.4 MAXIMUM ANGLE: 90.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132482 EWR4 ELECTROMAG. RESIS. 4 10505932 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.750 DRILLER'S CASING DEPTH (FT) 2509.0 BOREHOLE CONDITIONS MUD TYPE: Lignosulfanate MUD DENSITY (LB/G) 10.50 MUD VISCOSITY (S) 37.0 MUD PH: 9.2 MUD CHLORIDES (PPM): 400 FLUID LOSS (C3) 3.8 I'' • • RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 2.300 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.100 154.0 MUD FILTRATE AT MT: 1.900 70.0 MUD CAKE AT MT: 3.200 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWDO50 OHMM 4 1 68 4 2 RPM MWDO50 OHMM 4 1 68 8 3 RPS MWDO50 OHMM 4 1 68 12 4 RPX MWDO50 OHMM 4 1 68 16 5 FET MWDO50 HOUR 4 1 68 20 6 GR MWDO50 API 4 1 68 24 7 ROP MWDO50 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6331 8155 7243 3649 6331 8155 RPD MWDO50 OHMM 1.67 2000 46.9413 3552 6331 8106.5 RPM MWDO50 OHMM 1.67 592.59 13.5044 3552 6331 8106.5 RPS MWDO50 OHMM 1.61 141.47 9.15092 3552 6331 8106.5 RPX MWDO50 OHMM 1.66 149.89 8.65001 3552 6331 8106.5 FET MWDO50 HOUR 0.4 19.77 1.3639 3552 6331 8106.5 GR MWDO50 API 51.39 433.34 131.594 3552 6338.5 8114 ROP MWDO50 FT/H 1.8 171.53 86.2914 3566 6372.5 8155 First Reading For Entire File..........6331 Last Reading For Entire File...........8155 File Trailer Service name ........... ..STSLIB.004 Service Sub Level Name. .. Version Number......... ..1.0.0 Date of Generation..... ..06/08/04 Maximum Physical Record ..65535 File Type .............. ..LO Next File Name......... ..STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 06/08/04 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number...... 01 r Next Tape Name........... UNKNOWN Comments ................. STS LIS Writing Library Reel Trailer Service name ............. LISTPE Date ..................... 06/08/04 Origin ................... STS Reel Name ................. UNKNOWN Continuation Number...... 01 Next Reel Name........... UNKNOWN Comments ................. STS LIS Writing Library Physical EOF Physical EOF Scientific Technical Services Scientific Technical Services End Of LIS File • • Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Aug 04 12:53:04 2006 Reel Header Service name .............LISTPE Date .....................06/08/04 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Tape Header Service name .............LISTPE Date .....................06/08/04 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Colville River Nanuq(KUparuk) MWD/MAD LOGS WELL NAME: CD4-320 PB1 API NUMBER: 501032053170 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 04-AUG-06 JOB DATA MWD RUN 2 MWD RUN 3 JOB NUMBER: MW0004477289 MW0004477289 LOGGING ENGINEER: J. BOBBITT J. BOBBITT OPERATOR WITNESS: D. BURLY D. BURLY SURFACE LOCATION SECTION: 24 TOWNSHIP: 11N RANGE: 4E FNL: 2978 FSL: FEL: 438 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 56.72 GROUND LEVEL: 19.70 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.750 9.625 2509.0 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD) . 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIREC TIONAL ONLY - NO DATA ARE 2b~ -osS ~ /yo3~ • • PRESENTED. 4. MWD RUNS 2,3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUN 2 ALSO INCLUDED GEOPILOT ROTARY- STEERABLE BHA (GP) AND GAMMA AT BIT (GAB). 5. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT CONOCO-PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR THE DRILLSITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 6. MWD RUNS 1-3 REPRESENT WELL CD4-320 PB1 WITH API#: 50-103-20531-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8019'MD/6993'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name ........... ..STSLIB.001 Service Sub Level Name. .. Version Number......... ..1.0.0 Date of Generation..... ..06/08/04 Maximum Physical Record ..65535 File Type .............. ..LO Previous File Name..... ..STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2481.5 7978.5 RPD 2490.0 7971.0 FET 2490.0 7971.0 RPS 2490.0 7971.0 RPM 2490.0 7971.0 RPX 2490.0 7971.0 ROP 2519.5 8019.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD BIT RUN NO MERGE TOP MERGE BASE 2 2481.5 5965.0 3 5965.0 8019.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record. Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 2481.5 8019 5250.25 11076 2481.5 8019 RPD MWD OHMM 0.33 2000 17.776 10963 2490 7971 RPM MWD OHMM 0.38 1743.45 7.80851 10963 2490 7971 RPS MWD OHMM 0.33 1535.52 6.53243 10963 2490 7971 RPX MWD OHMM 0.45 2000 6.88121 10963 2490 7971 FET MWD HOUR 0.16 56.08 1.18119 10963 2490 7971 GR MWD API 43.24 401.94 114.241 10995 2481.5 7978.5 ROP MWD FT/H 0.1 361.67 145.331 11000 2519.5 8019 First Reading For Entire File..........2481.5 Last Reading For Entire File...........8019 File Trailer Service name .............STSLIB.001 Service Sub Level Name.,. Version Number...........1.0.0 Date of Generation.....,.06/08/04 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/04 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FZLE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2481.5 5927.5 • FET 2490.0 5919.5 RPX 2490.0 5919.5 RPS 2490.0 5919.5 RPM 2490.0 5919.5 RPD 2490.0 5919.5 ROP 2519.5 5965.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRZLLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 06-JUL-06 Insite 66.37 Memory 5965.0 2519.0 5965.0 8.4 25.7 TOOL NUMBER 132482 10505932 8.750 2509.0 Fresh Water Gel 9.60 36.0 9.2 350 6.8 4.700 68.0 2.980 111.0 5.400 68.0 5.000 68.0 Data Format Specification Record Data Record Type ....... .......... .0 Data Specification Bloc k Type.... .0 Logging Direction ...... .......... .Down Optical log depth units .......... .Feet Data Reference Point ... .......... .Undefined Frame Spacing .......... .......... .60 .lIN Max frames per record .. .......... .Undefined Absent value ........... .......... .-999 Depth Units ............ .......... . Datum Specification Blo ck sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2481.5 5965 4223.25 6968 2481.5 5965 RPD MWD020 OHMM 0.33 2000 12.6703 6860 2490 5919.5 RPM MWD020 OHMM 0.38 1743.45 6.92516 6860 2490 5919.5 RPS MWD020 OHMM 0.33 1535.52 5.68941 6860 2490 5919.5 RPX MWD020 OHMM 0.45 2000 6.34796 6860 2490 5919.5 FET MWD020 HOUR 0.16 56.08 0.91886 6860 2490 5919.5 GR MWD020 API 50.8 200.14 106.656 6893 2481.5 5927.5 ROP MWD020 FT/H 0.34 325.85 192.049 6892 2519.5 5965 First Reading For Entire File..........2481.5 Last Reading For Entire File...........5965 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/04 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/04 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 5920.0 7971.0 RPD 5920.0 7971.0 RPM 5920.0 7971.0 FET 5920.0 7971.0 RPS 5920..0 7971.0 GR 5928.0 7978.5 ROP 5965.5 8019.0 LOG HEADER DATA DATE LOGGED: 09-JUL-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 8019.0 TOP LOG INTERVAL (FT) 5965.0 BOTTOM LOG INTERVAL (FT) 8019.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 8.4 MAXIMUM ANGLE: 87.4 TOOL STRING (TOP TO BOTTOM) ~~ VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: TOOL NUMBER 132482 10505932 8.750 2509.0 Fresh Water Gel 9.70 38.0 9.2 300 3.0 2.400 72.0 1.290 140.0 2.600 72.0 1.100 72.0 Data Format Specification Re cord Data Record Type ......... ..... ....0 Data Specification Block Type. ....0 Logging Direction ........ ..... ....Down Optical log depth units.. ..... ....Feet Data Reference Point ..... ..... ....Undefined Frame Spacing ............ ..... ....60 .lIN Max frames per record .... ..... ....Undefined Absent value ............. ..... ....-999 Depth Units .............. ..... .... Datum Specification Block sub-type...0 Name Service Order Units Si ze Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5920 8019 6969.5 4199 5920 8019 RPD MWD030 OHMM 2.37 2000 26.3125 4103 5920 7971 RPM MWD030 OHMM 2.19 251.99 9.28543 4103 5920 7971 RPS MWD030 OHMM 2.12 112.51 7.94193 4103 5920 7971 RPX MWD030 OHMM 2 151.91 7.77277 4103 5920 7971 FET MWD030 HOUR 0.53 17.62 1.6198 4103 5920 7971 GR MWD030 API 43.24 401.94 126.986 4102 5928 7978.5 ROP MWD030 FT/H 0.1 361.67 66.9518 4108 5965.5 8019 First Reading For Entire File..........5920 Last Reading For Entire File...........8019 File Trailer Service name .............STSLIB.003 Service Sub Level Name... • • Version Number...........1.0.0 Date of Generation.......06/08/04 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/08/04 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................06/08/04 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File