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207-057
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS KCIOCI V CLi FEB 2 6 2020 1. Operations Abandon L1 Plug Perforations Fracture Stimulate LJ 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 ❑� Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. N Development ❑� Exploratory ❑ Stratigraphic ❑ Service ❑ 207-057 3. Address: PO BOX 100360 6. API Number: Anchorage, AK 99510 50-103-20546-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 380075, 387207, 387212, ASRCNPRI CRU CD2 -72 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 21089 feet Plugs measured None feet true vertical 7242 feet Junk measured None feet Effective Depth measured 21089 feet Packer measured 15912 feet true vertical 7242 feet true vertical 7065 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 76' 16" 114' 114' Surface 3280' 10.75" 3318' 2394' Intermediate 16658' 7.625" 16693' 7268' Production Liner 4511' 4.5" 20950' 7251' Perforation depth Measured depth Perf Pups from 16781'- 20900' MD True Vertical depth 7279' - 7253' TVD Tubing (size, grade, measured and true vertical depth) 3.5", L-80,16427- MD, 7229' TVD Packers and SSSV (type, measured and true vertical depth) Packer: Baker S-3 Packer, 15912' MD, 7065' TVD SSSV: Carrico TRMAXX-5E, 2270' MD, 1981' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 16693' - 21089' MD 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: 1 614 1421 753 1223 224 Subsequent to operation: 1809 823 647 1235 217 14. Attachments (required per20 AAc 25.070.25.071, s 25.283) 15. Well Class after work: Daily Report of Well Operations Exploratory ❑ Development E] Service ❑ Stmtigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 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: NIA Authorized Name: Ka lie Plunkett Contact Name: Kaylie Plunkett Authorized Title: Senior Production Engineer Contact Email: Kavlie.B.Plunkettocop.com Authorized Signature: i. Date: Z 2Y 2626 Contact Phone: 265-6450 U Form 10-404 Revised 412017 V7z- 3/41�1-0 RBDMS W FEB 2 71020 Submit Original Only CD2 -72 Scale Inhibition Treatment 1/25/20 —1/26/20 Non -Aqueous Scale Inhibitor Squeeze Job pumped from 1100 hrs on 1/25/20 to 0300 hrs on 1/26/20. - Initial pressure TBG/IA/OA - 840/1226/725 - LRS pumped 193 bbls Diesel/M209/WAW5206 pre -flush at 2.6 — 3.8 bpm, TBG/IA/OA - 16/1142/679 - LRS pumped 237 bbls 70/30 EG/Seawater and SCW720 scale inhibitor main treatment at 2.5 — 4.0 bpm, TBG/IA/OA-0/1100/615 - LRS pumped 2677 bbls Dead Oil/M209 over -flush at 4.0 bpm, TBG/IA/OA-0/1050/602 Interval treated: 16,693'— 21,089' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS FEB i 9 2mg 1. Operations Abandon L Plug Perforations Fracture Stimulate Li Pull Tubing L 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 ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory ❑ Stratigraphic ❑ Service ❑ 207-057 3. Address: PO BOX 100360 6. API Number: Anchorage, AK 99510 50-103-20546-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 380075, 387207, 387212, ASRCNPR1 CRU CD2 -72 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 21089 feet Plugs measured None feet true vertical 7242 feet Junk measured None feet Effective Depth measured 21089 feet Packer measured 15912 feet true vertical 7242 feet true vertical 7065 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 76' 16" 114' 114' Surface 3280' 10.75" 3318' 2394' Intermediate 16658' 7.625" 16693' 7268' Production Liner 4511' 4.5" 20950' 7251' Perforation depth Measured depth Pelf Pups from 16781'- 20900' MD True Vertical depth 7279' - 7253' TVD Tubing (size, grade, measured and true vertical depth) 3.5", L-80, 16427' MD, 7229' TVD Packers and SSSV (type, measured and true vertical depth) Packer: Baker S-3 Packer, 15912' MD, 7065' TVD SSSV: Camco TRMAXX-5E, 2270' MD, 1981' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 16693' - 21089' MD Treatment descriptions including volumes used and final pressure: Please see attached summary 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-McfWater-Bbl Casing Pressure Tubing Pressure Prior to well operation: 573 1463 806 1122 221 Subsequent to ope ation: 512 1411 741 1147 216 14. Attachments (required per 20 AAc 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations ❑� 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. 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: N/A Authorized Name: Ka lie Plunkett Contact Name: Kaylie Plunkett Authorized Title: Senior Production Engineer Contact Email: Kaylie.B.PlunkettGDcoo.com Authorized Signature: /",�.�,,�.a�� Date: 2- 1q- pq Contact Phone: 265-6450 t%rL. 212o/l9 l.i Form 10-404 Revised 4/2017 �W2V�q RBDMS_ FEtl 19 2019 Submit Original Only CD2 -72 Scale Inhibition Treatment 1/20/19 Non -Aqueous Scale Inhibitor Squeeze Job pumped 1/20/19 from 07:30 to 22:30. - Initial pressure TBG/IA/OA - 392/1108/702 - LRS pumped 193 bbls Diesel/M209/WAW5206 pre -flush at 2.0 bpm, TBG/IA/OA - 0/1046/649 - LRS pumped 193 bbls 70/30 EG/Seawater and SCW3001WC scale inhibitor main treatment at 2.0 bpm, TBG/IA/OA— 0/1005/602 - LRS pumped 2677 bbls Dead Oil/M209 over -flush at 2.0-5.0 bpm, TBG/IA/OA-0/989/600 Interval treated: 16,693'— 21,089' STATE OF ALASKA AL OIL AND GAS CONSERVATION COMA ION 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 E Exploratory ❑ 207-057 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O. Box 100360,Anchorage,AK 99510 50-103-20546-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380075, 387207, 387212,ASRCNPRI CRU CD2-72 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 21089 feet Plugs measured None feet true vertical 7242 feet Junk measured None feet Effective Depth measured 21089 feet Packer measured 15912 feet true vertical 7242 feet true vertical 7065 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 76' 16" 114' 114' Surface 3280' 10.75" 3318' 2394' Intermediate 16658' 7.625" 16693' 7268' RECEIVED Production Liner 4511' 4.5" 20950' 7251' Perforation depth Measured Depth: Peri Pups from 16781'-20900$ $$" MAY I 521! MAY 0 2 2017 AOGCC True Vertical Depth:7279'-7253'TVD Tubing(size,grade,measured and true vertical depth) 3.5", L-80, 16427' MD, 7229'TVD Packers and SSSV(type,measured and true vertical depth) Packer: Baker S-3 Packer, 15912' MD, 7065'TVD SSSV: Camco TRMAXX-5E, 2270' MD, 1981'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 16693'-21089' MD 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: 1102 1493 635 1127 220 Subsequent to operation: 1190 1613 618 1129 225 14.Attachments(required per 20 PAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations E Exploratory❑ Development ❑., Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑., Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Kaylie Plunkett Email Kavlie.B.Plunkettancop.com Printed Name '� Kaylie Plunkett Title Production Engineer Signature —X� U Phone 265-6450 Date L('216 — (7 Y j-t- 3/10/1RBDMS MAY - 3 2017 Form 10-404 Revised 5/2015 `4b�7 Submit Original Only • • CD2-72 Scale Inhibition Treatment 3/29/17 Non-Aqueous Scale Inhibitor Squeeze Job pumped 3/29/17 from 08:00 to 21:30. - Initial pressure TBG/IA/OA-420/1121/660 - LRS pumped 290 bbls Diesel/M209/WAW5206 pre-flush at 1.5—2.5 bpm,TBG/IA/OA- 3/1134/615 - LRS pumped 290 bbls 70/30 EG/Seawater and SCW3001WC scale inhibitor main treatment at 2.5 bpm,TBG/IA/OA—3/1131/585 - LRS pumped 2187 bbls Dead Oi1/M209 over-flush at 2.0—4.8 bpm,TBG/IA/OA-0/1207/570 Interval treated: 16,693'—21,089' e P~'ect Well Histo File Co~r Pa e Imag ~ ~"y J XHVZE This page identifies those items that were not scanned during the initial produetion 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. ~~ ~ - ~~ ~ Well History File Identifier Or anizin (done) p Two-sided II I II'I II II II I II III p Rescan Needed (I ( II II II II ~ I II I III 9 9 RESCAN DIGITAL DATA OVERSIZED (Scannable) Color Items: iskettes, No. ~ ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~S~ Pro "ect Proofin J 9 I I I II'I II I~ I II I I I II BY: Maria Date: ~ ~S~ Scanning Preparation ~ x 30 = ~ +_~ = TOTAL PAGES~~ s n o t i n c l u d e c over sheet) n t d o C o u e ( , BY: Maria Date: ~S~ Production Scanning I I I II ~I (I I I I II I I I I) Stage 1 Page Count from Scanned File: ~(Count does include cover heet) ~ ES Number in Scannin Pre aration: __ Page Count Matches 9 P NO BY: Maria Date: ~ ~ ~~ q ~S~ ~ ~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: ~S~ I I I II ~I I) I II II I I III Scanning is complete at this point unless rescanning is required. ReScanned (I I II'I (I I I II) ( I III BY: Maria Date: ~S~ Comments about this file: Quality Checked 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA • ALA• OIL AND GAS CONSERVATION COM•OION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Rug Perforations r Perforate r Other `"` Alter Casing r Pull Tubing r Stimulate - Frac jd Waiver r Time Extension r"° Change Approved Program r Operat. Shutdown r Stimulate - Other r Re -enter Suspended Well I 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 1" Exploratory r "' 207 - 057 _ 3. Address: 6. API Number: e, Alaska 99510 Stratigraphic r Service J-` P. O. Box 100360, Anchorage, ` 50 - 103 - 20546 - Oa 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 380075, 387207, 387212, AStCNPR1 CD2 -72 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): — none Colville River Field / Alpine Oil Pool 1 11. Present Well Condition Summary: Total Depth measured 21089 feet Plugs (measured) None true vertical 7242 feet Junk (measured) None Effective Depth measured 21089 feet Packer (measured) 15912 true vertical 7242 feet (true vertucal) 7065 Casing Length Size MD TVD Burst Collapse CONDUCTOR 76 16 114 114 SURFACE 3280 10.75 3318 2394 INTERMEDIATE 16657 7.625 16693 7268 LINER 4511 4.5 20950 7250 i Z01 R ECE`1V el° Perforation depth: Measured depth: 16781' 20900' D MAY 1.8 MAY 142012 True Vertical Depth: 7279' - 7253' AOCCC Tubing (size, grade, MD, and ND) 3.5, L -80, 16427 MD, 7229 TVD Packers & SSSV (type, MD, and ND) PACKER - BAKER S -3 PACKER @ 15912 MD and 7065 TVD SSSV - CAMCO TRMAXX -5E SSSV @ 2270 MD and 1979 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 16781 - 20900' MD Treatment descriptions including volumes used and final pressure: pumped 174150# of 16/20 carbolite, final pressure= 750psi 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 1736 2629 356 -- 251 Subsequent to operation 2525 3726 807 -- 263 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development 17 •' Service r Stratigraphic r 16. Well Status after work: "Oil 17 Gas r WDSPL rr Daily Report of Well Operations _XXX GSTOR r WINJ r WAG r GINJ r SUSP l 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: 312 -090 Contact Ty Senden 265 -1544 Printed Na Sen•% n Title Staff Wells Engineer Signature ` Phone: 265 -1544 Date 5/11/11.- \ FRBDMS MAY 14 2012 4,fr ,_,,,-__1 z°' Form 10-404 Re ed 11/2 Submit Original Only WNS CD2 -72 L. 1 " C co t] I r11I1ps i ii l e , Well Attributes M ax Angle & MD TD Alaska !ix; Wel!bore APIIUWI Field Name Well Status Inc! 0 MD (ftKB) Act Btm (ftKB( Ls xxrrtwiii,, 501032054600 ALPINE PROD 94.58 18,154.83 21,049.0 Comment H2S (ppm( Date Annotation End Date KB (ft) Rig Release Date "' SSSV: TRDP Last WO: 37.60 6/3/2007 Well Con69: CO2 -72, 4/28/20129.12:15 AM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date , .. - - Last Tag: Rev Reason: GLV C/O ninam 4/28/2012 -- - 985580..52 -- - - - -- . Casing Strings l ir r Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.250 38.0 114.0 114.0 65.00 H Welded • ! ,, Casing Description String 0... String ID ... Top (fg(B) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 103/4 9.950 37.6 3,317.9 2,393.6 45.50 L - 80 A l i CONDUCTOR, Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD(... String Wt... String ... String Top Thrd 38 - 114 / INTERMEDIATE 75/8 6.875 35.1 16,692.6 7,268.3 29.70 L 1 - 1. 4 X Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 12e LINER 41/2 3.958 16,438.8 20950.0 7,250.7 12.60 L -80 IBTM SAFETYVLV, { .- 1 Liner Details 2'270 I Top Depth (TVD) Top Inc! Nomi... Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) SURFACE, a 16,438.8 7,230.4 78.78 TIE BACK TIE BACK SLEEVE 5.070 36 3,318 16,451.8 7,233.1 79.25 NIPPLE RS NIPPLE 4.875 GAS 81001 F 16,455.5 7,233.9 79.39 HANGER BAKER FLEXLOCK LINER HANGER 5.500 16,465.4 7,235.9 79.75 XO 5.5x4.5 4.500 17,291.9 7,316.0 87.95 Swell Packer EASY WELL SWELL PACKER 3.930 1 17,873.8 7,296.7 93.48 Swell Packer EASY WELL SWELL PACKER 3.930 GAS LIFT. 11,911 Tubing Strings -® Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 31/2 2.992 31.8 16,427.0 7,228.3 9.30 L -80 EEUE8rdABM... GAS 15,854 '"- Completion Details Top Depth (TVD) Top Inc! Nomi... PACKER, - Top (ftKB) (MB) r) item Description _ Comment ID (In) 76.972 M 31.8 31.8 -0.03 HANGER FMC TUBING HANGER 4.853 MIN 1 25.7 125.7 0.40 XO-reducing XO 4.5" x 3.5" 3.500 NIPPLE, 15,990 -- 9 WLEG, 16,427 W lY 2,270.3 1,978.5 58.16 SAFETY VLV CAMCO TRMAXX -5E SSSV 2.812 15,912.0 7,065.0 68.58 PACKER BAKER S-3 PACKER 3.870 .1 dif 15,990.4 7,093.4 68.21 NIPPLE HES 'XN' NO GO NIPPLE 2.7501 16,426.5 7,228.3 78.34 WLEG WIRELINE ENTRY GUIDE w/ LOCATOR SUB "UNABLE TO GET 3.500 WLEG INTO TOP OF LINER" Perforations & Slots NTERMEDIATE, Shot 35-16.693 Top (TVD) Btm (TVD) Dens PERFP. Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (.ft- Type Comment 18,781.16,786 16,781 16,786 7,279.3 7,279.9 ALPA, CD2 -72 5/30/2007 1.0 PERFP Six 1/21D holes, 2 sets of 3, 120 deg phase, each offset from the other set PERFP, by 60 deg - same for all Perf Pups in 17,029- 17,033 = INS well. 17,029 17,033 7,303.4 7,303.5 ALPA, CD2 -72 5/30/2007 1.0 PERFP 18,042 18,046 7,285.7 7,285.3 ALPA, CO2 -72 5/30/2007 1.0 PERFP I 18,245 18,250 7,270.1 7,269.7 ALPA, CD2 -72 5/30/2007 1.0 PERFP 18,448 18,453 7,264.0 7,264.0 ALPA, CO2 -72 5/30/2007 1.0 PERFP 18,652 18,657 7,267.5 7,267.5 ALPA, CD2 -72 5/30/2007 1.0 PERFP 16,042 a o e 18,856 18,861 7,268.0 7,268.0 ALPA, CD2 -72 5/30/2007 1.0 PERFP 19,059 19,064 7,265.3 7,265.2 ALPA, CD2 -72 5/30/2007 1.0 PERFP PERFP, 19,261 19,266 7,260.9 7,260.9 ALPA, CD2 -72 5/30/2007 1.0 PERFP 1s.z4s 16,zso 19,465 19,469 7,261.4 7,261.4 ALPA, CD2 -72 5/30/2007 1.0 PERFP 19,670 19,675 7,261.4 7,261.3 ALPA, CD2 -72 5/30/2007 1.0 PERFP P, - - ea 18.44878 F 45a - -- 19,875 19,880 7,253.5 7,254.2 ALPA, CD2 -72 5/30/2007 1.0 PERFP 20,079 20,084 7,264.2 7,264.2 ALPA, CD2 -72 5/30/2007 1.0 PERFP PERFP, 18,652 - 18,857 Ai 20,283 20,287 7,256.7 7,256.7 ALPA, CD2 -72 5/30/2007 1.0 PERFP FRAC, 16,781 20,488 20,492 7,256.1 7256.2 ALPA, CO2 -72 5/30/2007 1.0 PERFP PERFP, 18,856 PERFP, = 20,691 20,696 7,256.3 7,256.3 ALPA, CD2 -72 5/30/2007 1.0 PERFP 20,895 20,900 7,253.0 7,252.8 ALPA, CD2 -72 5/30/2007 1.0 PERFP PERFP. Stimulations & Treatments 79,059 - 18,064 Bottom Min Top Max Btm Top Depth Depth PERFP, Depth Depth (TVD( (TVD( 19,261 - 19,266 I. (ftKB) (ftKB) (ftKB) (ftKB) Type Date Comment 16,781.0 20,900.0 7,279.3 7,252.8 FRAC 4/22/2012 PUMPED 174,150 LBS OF 16/20 CARBOLITE PERFP, Notes; General & Safety 15.465-18,469 End Date Annotation 4/22/2010 NOTE: View Schematic w/ Alaska Schematic9.0 PERFP, 19,670 - 19,875 PERFP, 19,875- 19,880 Mandrel Details PERFP, Top Depth Top Port 20,079 - 20,084 Mil (TVD) Inc' OD Valve Latch Slze TRO Run Stn Top (ftKB) (ftKB) ( °) Make Model (in) Sery Type Type (!n( (psi) Run Date Com... 1 6,000.7 3,386.7 68.55 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,850.0 4272012 20,283 - 20,287 __ - - 2 11,910.5 5,577.9 67.35 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,768.0 4272012 3 15,854.3 7,043.5 67.68 CAMCO KBMG 1 GAS LIFT OV BK 0.250 0.0 4/27/2012 PERFP, 20,488- 20,492 Mil PERFP, 20,691- 20,696 PERFP, 20,895- 20,900 LINER, 16,439- 20,950 TEL 21,049 - CD2 -72 Well Work Summary DATE . SUMMARY '4/19/12 GAUGE TBG TO 2.79" TO 15911KB. SET 2.81" CAT SV @ SAME. ATTE T TO PULL GLV @ 11910' RKB, NO SUCCESS. IN PROGRESS. 4/20/12 PULLED GLV @ 11910' RKB. REPLACED w/ DV. PULLED ORIFICE VLV @ 15854' RKB. READY FOR CIRC OUT, IN PROGRESS. 4/20/12 PUMPED 580 BBLS OF INHIBITED SEWATER DOWN TBG TAKING RETURNS UP IA TO THE PRODUCTION LINE. DSO PUMPED 100 BBLS OF CRUDE DOWN TBG. U -TUBE T TO IA FOR FREEZE PROTECTION. READY FOR SLICKLINE. 4/21/12 SET HES -SPG (S /N: 718H -4391) @ 15854' RKB. MITT TO 3500 psi. * *PASS * *. MITIA TO 3500 psi. * *PASS * *. PULLED CAT SV © 15990' RKB. SET 2.81" FRAC SLEEVE (OAL= 81 "/ MIN ID= 2.23 ") @ 2270' RKB. READY FOR FRAC. 4/22/12 PUMPED ALPINE "A" SAND FRAC. PUMP 174,150# OF 16/20 CARBOLITE BEHIND PIPE, 100% OF FIRST PART OF THE FRAC. SCREENED OUT DURING THE FLUSH OF THE 6 PPG STAGE. DISPLACE WITH 80 BBL OF X- LINKED GEL FOLLOWED BY 40 BBL OF DIESEL. PUMPED A TOTAL OF 120 BBL OF DISPLACEMENT (148 BBL REQUIRED TO TOP OF PERFS) LEAVING ABOUT 1500# OF CARBOLITE IN THE LINER. WELL IS FREEZE PROTECTED DOWN TO 2850'. UNABLE TO PUMP THE SECOND PART OF THE FRAC DESIGNED FOR AN ADDITIONAL 172,000 #. 4/25/12 PULLED 2.81" FRAC SLEEVE a7 2270' RKB. GAUGED TBG TO 2.80" TO 15,990' RKB. PULLED SPG @ 15,854' SLM, LOST TS WHILE POOH. (OAL OF TS LEFT IN HOLE IS 41.25' W APPROX 35' - 40' OF WIRE) IN PROGRESS. 4/26/12 RECOVERED LOST TS @ 15,976' SLM. ATTEMPT SET OV @ 15,854' RKB. IN PROGRESS. 4/27/12 SET OV @ 15,854' RKB. PULLED DVs CA 11,911' & 6000' RKB & REPLACED W/ GLVs. PULLED CATCHER @ 15,990' RKB. READY FOR EXPRO. 4/30/12 SET FRAC SLEEVE @ 2270' RKB ( MAX OD = 2.85" / 80" OAL) READY FOR EXPRO. • • "y, _ { �' ~- U L u J SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION i ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Ty Senden Staff Wells Engineer ConocoPhillips Alaska, Inc. .40 7 0 b 7 P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD2 -72 Sundry Number: 312 -090 st,MANKNAR 1 2 Z Dear Mr. Senden: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday •r weekend. Sinc- ely al I[.v'n , orr n . Q` Com 'ss' ; er DATED this U day of March, 2012. Encl. . • • Fisher, Samantha J (DOA) From: Foerster, Catherine P (DOA) Sent: Thursday, March 08, 2012 11:53 AM To: Fisher, Samantha J (DOA) Subject: Re: CD2 -72 Approve. Sent from my iPhone On Mar 8, 2012, at 12:53 PM, "Fisher, Samantha J (DOA)" <samantha.fisher @alaska.gov> wrote: > Please approve. > Thank you, > Samantha Fisher, Executive Secretary II > Alaska Oil and Gas Conservation Commission > (907)793 -1223 > <S45C- 212030809431.pdf> 1 I', STATE OF ALASKA RECEIVED 44 AA" OIL AND GAS CONSERVATION COMIV410ON APPLICATION FOR SUNDRY APPROVALS Lh; : , 20 AAC 25.280 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair w eAl Ska OilABASAWRiadDagliniStion Suspend r Rug Perforations r" Perforate r Rill Tubing r Aricnorie Extension r Operational Shutdown r Re -enter Susp. Well r Stimulate g7 . Alter casing r" r Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p. . Exploratory r 207 -057 ' 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20546 - 00' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No F7 CD2 -72' 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 380075, 387207, 387212, ASRCNPR1 s Colville River Field / Alpine Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 21089 7242 " 21089' 7242' Casing Length Size MD TVD Burst Collapse CONDUCTOR 76 16 114' 114' SURFACE 3280 10.75 3318' 2394' INTERMEDIATE 16657 7.625 16693' 7268' LINER 4511 4.5 20950' 7250' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 16790' - 20950' 7279' - 7250' 3.5 L - 16427 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER S -3 PACKER MD= 15912 TVD= 7065 SSSV - CAMCO TRMAXX MD =2270 TVD =1979 12. Attachments: Description Summary of Proposal ;✓ 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch '°` Exploratory Development 1-1 ' Service r " 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/16/2012 Oil F.: - Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ty Senden © 265 -1544 Printed Name T Senden ` Title: Staff Wells Engineer Signature \ 1 \ I Phone: 265 -1544 Date 3J2I I-- Commission Use Only Sundry Number:51 Z- dip Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance E Other: , Subsequent Form Required: , 0 a , APPROVED BY Approved by: / COMMISSIONER THE COMMISSION Fo e Date: �r9'� 20."--- - y} r O 0 R 1(31 N Submit in Duplicate d 7f L % \ 1/ C u� 404 „of- • ' • . • Overview: CD2 -72 was completed as an uncemented liner with pre perforated pups placed approximately 400 feet apart along the entire liner. The well has been on production since 2007. Fracture / q stimulation of the Alpine sand is planned to increase production. r 1 Intermediate String: < 5/17/07: Cemented 1st stage 7 5/8" csg as follows: Pumped 5 bbls CW -100 - Test lines to 3700 C psi - Pumped 15 bbls CW -100 @ 3bbls /min @ 180 psi - Mixed & pumped 40 bbls 10.5 Q � ppg MudPush (Problem getting MP up to weight) @ 3 bbls /min @ 260 psi - Dropped btm l A t40 plug - Mixed & pumped 61.1 bbls 15.8. ppg Tail slurry (class G w/ additives) @ 4.5 Q �✓ bbls /min @ 350 psi - Dropped top plug w/ 20 bbls water f /Dowell - switched to rig pumps F \, 1, & displaced cmt w/ 744.3 bbls 10.3 ppg LSND mud @ 7 bbls. /min @ 500 psi for first 720 bbls slowed pumps to 4 bbls /min @ 400 psi for last 24.3 bbls - Bumped plug w/ 900 psi - CIP @ 05:52 hrs. Checked floats Did not hold - Full returns throughout job - Reciprocated pipe for first 720 bbls of displacement - landed pipe when pumps were slowed to 4 bbls /min. 5/23/07: Perform FIT. Max pressure reached 870 psi = 12.5 ppg. Pressure bled to 400 psi. Perform second LOT to verify first test. Max pressure reached is 570 psi. Leveled off to 375 psi. Pre -Frac Wellwork: 1. Set tubing tail plug in nipple at 15,990' MD. 2. Pull orifice valve from GLM #3 at 15,854' MD. 3. Circulate 600 bbls of seawater and 60 bbls of dead crude down the IA taking returns up the production tubing. 4. U -tube tubing and annulus to freeze protect both strings. 5. RIH to GLM #3 at 15,854' MD and set a Spartek SPG programmed to collect data every second. 6. Pressure test IA to 3500 psi. ■ 7. Pull the tubing tail plug from the nipple at 15,990' MD. , 8. Set ISO sleeve across the SSSV at 2270' MD. - Frac Procedure: 1. MIRU fifteen (15) clean insulated frac tanks with a berm surrounding the tanks that holds a single tank volume plus 10 %. Load tanks with seawater from the injection system (approximately 6800 bbls are required for the treatment). 2. Rig up Schlumberger equipment and stab Stinger Tree Saver. 3. Pressure test surface lines to 7500 psi. 4. Pump the 200 bbl Breakdown with Schlumberger's YF125ST fluid system. Bring pumps up to maximum rate ASAP. 5. Pump the following schedule at -20 BPM with a maximum expected pressure of -6500 psi, add breaker as per lab results. Maintain 3500 psi on the IA during the treatment. 1. 300 bbls YF125ST Pad 2. 120 bbls YF125ST w/ 2 ppa 16/20 Carbolite 3. 500 bbls YF125ST w/ 4 ppa 16/20 Carbolite ' 4. 200 bbls YF125ST w/6 ppa 16/20 Carbolite • 5. Drop 18 Bioballs between stages 6. Repeat 5 times 7. Flush with linear fluid and freeze protect Total Sand: -775,000 lbs. 6. Monitor the surface pressure fall -off at the end of the job for 30 min (or until closure is verified) if the well does not screen out. 7. Rig down equipment, (and prep for next well frac after evaluation by Engineering) move off location. 8. FCO if required with slick diesel. • I WNS • CD2 -72 Conoc 'hilIips " Well Attributes Max Angle & MD TD A1a5ka, Inc. Wel!bore API /UWI Field Name Well Status Ind (1 MD (ftKB) Act Btm (ftKB) lrnxoi'P.ahps 501032054600 ALPINE PROD 94.58 18,154.83 21,049.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date ••• Well Conga: - CD2 -72, 422120101:39:13 PM SSSV: TRDP Last WO: 37.60 6/3/2007 Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod By End Date - _ - _ Last Tag: Rev Reason: update to 9.0 Imosbor 4/22/2010 - mWGCR -32 - - - - - - Mt Casing Strings Mr i= 0 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd # CONDUCTOR 16 15.250 38.0 114.0 114.0 65.00 H Welded - Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 103/4 9.950 37.6 3,317.9 2,393.6 45.50 L - 80 CONDUCTOR, Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd 38 INTERMEDIATE 75/8 6.875 35.1 16,692.6 7,268.3 29.70 L - 80 X0 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd r 126 LINER 41/2 3.958 16,438.8 20,950.0 7,250.7 12.60 L -80 IBTM SAFETY VLV, ----I - 1 Liner Details 2,270 1-- Top Depth (ND) Top Ind Nomi... Top (ftKB) (ftKB) (°) Item Description Comment ID (in) SURFACE. + - 16,438.8 7,230.4 78.78 TIE BACK TIE BACK SLEEVE 5.070 38 - 3,318 16,451.8 7,233.1 79.25 NIPPLE RS NIPPLE 4.875 GAS LIFT. L 6001 16,455.5 7,233.9 79.39 HANGER BAKER FLEXLOCK LINER HANGER 5.500 16,465.4 7,235.9 79.75 XO 5.5x4.5 4.500 17,291.9 7,316.0 87.95 Swell Packer EASY WELL SWELL PACKER 3.930 17,873.8 7,296.7 93.48 Swell Packer EASY WELL SWELL PACKER 3.930 GAS LIFT, 11,911 Tubing Strings Tubing Description String 0... String ID ... I 31.8 I 16,427.0 Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt.., String ... String Top Thrd TUBING l 3 1/2 I 2.992 I 7,228.3 I 9.30 I L -80 I EEUE8rdABM... G "75 54 Completion D Top Depth (ND) Top Intl Nord... PACKER. � . Top (ftKB) (ftKB) (1 item Description Comment ID (In) 15,912 31.8 31.8 -0.03 HANGER FMC TUBING HANGER 4.853 NIPPLE, 15,990 125.7 125.7 0.40 XO- reducing X0 4.5" x 3.5" 3.500 WLEG, 16,427 a 2,270.3 1,978.5 58.16 SAFETY VLV CAMCO TRMAXX -53 SSSV 2.812 15,912.0 7,065.0 68.58 PACKER BAKER S-3 PACKER 3.870 4 oll 15,990.4 7,093.4 68.21 NIPPLE HES 'XN' NO GO NIPPLE 2.750 16,426.5 7,228.3 78.34 WLEG WIRELINE ENTRY GUIDE w/ LOCATOR SUB "UNABLE TO GET 3.500 WLEG INTO TOP OF LINER" Perforations & Slots NTERMEDIATE, ■ Shot 35- 16,893 Top (ND) Btm (TVD) Dens PerIPup, MO Top (ftKB) Btm (ftKB) (ftKB) - (ftKB) Zone Date (sh... Type Comment 18,781 - 18,788 16,781 16,786 7,279.3 7,279.9 ALPA, CD2 -72 5/30/2007 1.0 PerfPup Six 1/2"10 holes, 2 sets of 3, 120 deg phase, each offset from the other set PedPep, by 60 deg - same for all Perf Pups in 17,029 - 1],033 this well. 17,029 17,033 7,303.4 7,303.5 ALPA, CD2 -72 5/30/2007 1.0 PerfPup t 18,042 18,046 7,285.7 7,285.3 ALPA, CD2 -72 5/30/2007 1.0 PerfPup 18,245 18,250 7,270.1 7,269.7 ALPA, CD2 -72 5/30/2007 1.0 PerfPup 18,448 18,453 7,264.0 7,264.0 ALPA, CD2 -72 5/30/2007 1.0 PerfPup 18,652 18,657 7,267.5 7,267.5 ALPA, CD2 -72 5/30/2007 1.0 PerfPup PerfPup, 18,856 18,861 7,268.0 7,268.0 ALPA, CD2 -72 5/30/2007 1.0 PerfPup 18,042 - 18,046 19,059 19,064 7,265.3 7,265.2 ALPA, CD2 -72 5/30/2007 1.0 PerfPup PerfPup, 19,261 19,266 7,260.9 7,260.9 ALPA, CD2 -72 5/30/2007 1.0 PerfPup 18,245 - 18,250 19,465 19,469 7,261.4 7,261.4 ALPA, CD2 -72 5/30/2007 1.0 PerfPup 19,670 19,675 7,261.4 7,261.3 ALPA, CD2 -72 5/30/2007 1.0 PerfPup PerfPup. 18,448 - 18,453 19,875 19,880 7,253.5 7,254.2 ALPA, CD2 -72 5/30/2007 1.0 PerfPup 20,079 20,084 7,264.2 7,264.2 ALPA, CD2 -72 5/30/2007 - 1.0 PerfPup Pe,lP8, - 20,283 20,287 7,256.7 7,256.7 ALPA, CD2 -72 5/30/2007 1.0 PerfPup I 18 20,488 20,492 7,256.1 7,256.2 ALPA, CD2 -72 5/30/2007 1.0 PerfPup PerfPup, - 20,691 20,696 7,256.3 7,256.3 ALPA, CD2 -72 5/30/2007 1.0 PerfPup 18,856 - 18,861 -- 20,895 20,900 7,253.0 7,252.8 ALPA, CO2 -72 5/30/2007 1.0 PertPup PerfPup, Notes: General & Safety 19659- 16084 - End Date Annotation 4/22/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.OREV PerlPcp, 19,281 - 19,268 -- PerfPup. 19,485 - 19,469 PerfPup. 19670- 19,875 PerlPup, 19,875- 19,880 PerfPup. 20,079- 20,084 PerIPUp. 20,283. 20,287 PerlPUp, 20,488- 20,492 PerlPUp. Mandrel Details 20,897- 20,898 Top Depth Top Port (ND) Inc! OD Valve Latch Size TRO Run PerlPUp, Stn Top (ftKB) (ftKB) ( °) Make Model (in) Sery Type Type (in) (psi) Run Date Com... 20,895 1 6,000.7 3,386.7 68.55 CAMCO KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 5/30/2007 LINER, 2 11,910.5 5,577,9 67.35 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,628.0 6/6/2007 18 70. 20,950 3 15,854.3 7,043.5 67.68 CAMCO KBMG 1 GAS LIFT OV BK 0.250 0.0 6/6/2007 TD, ~ ~ ,~ k,. ~, ~ r ~" ~' ~~ ~ ~ ~ o ~' >R s 's ;~ ,, ,' +-' - ~ , MICROFILMED 6/30/201 0 DO NOT PLACE ANY NEWMATERIAL UNDERTHIS PAGE. C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number: 207-057 ConocoPhillips Alaska, Inc. Development ^~ Exploratory ^ 7. Well Name: CD2-72 2. Address: 4b. Well Status: Oil ^~ Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20546-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ^ or Final ^~ 308-153 4/28/2008 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 399* 399 totals (bbls): 2008 / 2nd 25630 100 0 25730 28 5/3/2008 6/26/2008 CD2-75, CD2-464, CD2-466 zoos i 3rd 335 100 0 435 2 7/2/2008 7/5/2008 CD2-72* 2008 / 4th 0 ~ 0 0 0 009 / 1 st 0 0 0 0 Total Ending Report is due on the 20th vo~ume 25965 200 399 26564 30 ~bbis~: of the month following the final month of the quarter. Ex: Apri120 for the first quarter July 20 for the second quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , , October 20 for the third quarte r a nd January 20 for the Other(Explain) ^ ry p fOU ~ ~ ~~ ,~~,ji ~ ~~ L~~7 12. Remarks and Approved Substances Description(s): *Injectivit test and freeze rotect volumes onl I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~~ ~~ Date: ~~7 ~~~`1 Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265-6120 ~ ~ ~ L. Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate ~~ Jti~ I DATA SUBMITTAL COMPLIANCE REPORT 6122/2009 Permit to Drill 2070570 Well Name/No. COLVILLE RIV UNIT CD2-72 Operator CONOCOPHILLIPS ALI~SKA I NC API No. 50-103-20546-00-00 MD 21089 ND 7242 Completion Date 6/2l2007 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: (data taken from Logs Portion of Master Well Data Maint • Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / T pe Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED D Asc Directional Survey 54 21089 Open 8/2/2007 pt 15354 LIS Verification 3288 21089 Open 8/23/2007 LIS Veri, GR, FET, ROP D C Lis 15354/Induction/Resistivity 3288 21089 Open 8/23/2007 LIS Veri, GR, FET, ROP og Induction/Resistivity 25 Col 114 21089 Open 5/1/2009 MD ROP, DGR, EWR 28- May-2007 Log Induction/Resistivity 25 Col 114 7242 Open 5/1/2009 ND DGR, EWR 28-May- 2007 D C 17940''Sae-Not~~' ~+1,...~:,,, ~V~,«:wF4a •~~ 0 0 Open 5/1/2009 EWR logs in PDS, EMF and CGM graphics Well Cores/Samples Information: Sample Interval Set ~ Name Start Stop Sent Received Number Comments ADDITIONAL IPFORMA~ION Well Cored? Y/~ Daily History Received? ~ N Chips Received? Y"MI~ Formation Tops ~N Analysis ~,LDI- Received? DATA SUBMITTAL COMPLIANCE REPORT 6/22/2009 Permit to Drill 2070570 Well Name/No. COLVILLE RIV UNIT CD2-72 Operator CONOCOPHILLIPS ALASKA INC MD 21089 TVD 7242 Completion Date 6/2/2007 Completion Status 1-OIL Current Status 1-OIL Comments: _ __ Compliance Reviewed By: Date: API No. 50-103-20546-00-00 UIC N ~ ` ~ ~ • STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS S-~ 1. Operations Performed: . Abandon ^ Repair Well ^ Plug Pertorations ~ Stimulate Q- Other ^ Alter Casing ^ Pull Tubing ^ Pertorate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Pecmit to Drill Number: ConoCOPhiilips AIBSka, InC. Development ~- Exploratory ^ 207-057 /- 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20546-00 ~ 7. KB Elevation (ft): 9. Weli Name and Number: RKB 54' CD2-72_ 8. Property Designation: 10. Field/Pool(s): ADL 380075, 387207, 387212, ASRCNPRI Colville River Field / Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 21089' - feet true vertical 7242' - feet Plugs (measured) Effective Depth measured 21089'- feet Junk (measured) true vertical 7242'- feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 114' 16" 114' 114' SURFACE 3318' 10-3/4" 3318' 2394' INTERMEDIATE 16693' 7.625" 16693' 7268' LINER 4511' 4.5" 20950' 7250' Perforation depth: Measured depth: alternating blank liner and perforated pup joints 16790'-20950' ~~ ~ true vertical depth: 7279'-7250' ~~~~,~ " " ' ' ~~1Ar~ ~ ,~ .~~~g Tubing (size, grade, and measured depth) x 3.5 , L-80, 116 4.5 x 16427 MD. ~IBS~ ~ pl/ ~ G~$ ~ ~" Packers & SSSV (type & measured depth) Baker S-3 pkr 15912' ~Q~,~~~ ~ ~~n11SS~o~ Camco SSSV @ 227T ~ 12. Stimulation or cement squeeze summary: Intervals treated (measured) refer to 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 2077 3813 186 -- 268 Subsequent to operation 2577 5771 920 -- 275 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: OilO~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: none Contact Tim Schneider @ 265-6859 Printed Name Tim S neider rit~e Alpine Staff Engineer Signature , ~ Phone: 265-6859 Date ~~d`' d~ Pre a Sh n Allsu - rake 263-4612 Form 10-404 Revised 04/2006 ~ ~ ~' ~~. M~Y r:~ ~ 20Q4 ~I~ .~~~~' ~ .... ~. SUbmit Original Only ~ ~ r. Co~~co~~illi~~ Al~~ka, Inc. ALPINE CD2-72 WSR - Well Service Report . , x ~ Well Service Report • Page 1 of 1 ~ WeIl ~~,Ic~b Scnpe ~~ CPAI Rep CD2-72 Scale Inhibition Shirtliffe, Ryan Date Daily ~Vork Unit Ntm~ber 4/19/2009 32 Initial & T/IA/OA Initial- Final 1200/1300/700 Fina1 Field: ALPINE Pressures: vac/1200/800 24 t~r Pumped a Non-Aquesous Scale Inhibition Squeeze using 940 bbls crude along Summary ~th 98 bbls MEG carrier fluid. A total of 39 gal M209, 126 ga1 WAW5206, and 616 ga1 SCW3001 WC was used. Initial tbg 1200 psi, Final tbg - vac. STt1.RTTIME OPERAT.tON 06:00 PM Rig up and pressure test lines to 2000 psig. Good. 06:42 PM Pre-treatment of 91 bbls crude/M209 mix at 4.5 bpm. Tbg 1200-600 psig during stage. Pumped stages 1-7 as follows. Pre-flush 2.4 bbls CR/M209/5206 at 4.5 bpm, 600 06:54 PM Psig. Pump 16.1 bbls MEG/3001 at 4.5 bpm and 600 psi. CR/M209/5206 at 4.5 bpm and 600 psig. Pump 79.9 bbls CR/M209 displacement at 4.5 bpm, 500 psig and dro~ 23 bio-balls/stage for the first 6 stages. 09:24 PM Displace the well with 260.5 bbls of CR/M209 fluid at 4.5 bpm. Well on vac. 11:09 PM Ri~ out eauipment and return to base. FiuSd Type Ta Well .From Well ~Ion- recoverable Nflte OIL 940 Crude treated with chemical OTHER 98 MEG with scale inhibitor http://akapps.conocophillips.net/alaskawelleventquery/worklog.aspx?ID=32B4EF0... 4/22/2009 ~ ~ ~ To: State of Alaska ~~dJ~. ~.~~ 'Y'~Ai~~I~~"~°~'A~, Alaska Oil and Gas Conservatior~ ~omm. Attn.: Librarian 333 West 7`h Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD2-72 Apri12~, 2009 AK-MW-5030483 CD2-72 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 50-103-20546-00 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 50-103-20546-00 Digital Log Images: 50-103-20546-00 1 Color Logs 1 Color Logs 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 Bryan.Burinda~halliburton.com Date: ~~~-b~ ~ ~~~~~ , J ~~ ( Signed: ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number: 207-057 ConocoPhillips Alaska, Inc. Development ^~ Exploratory ^ 7. Well Name: CD2-72 2. Address: 4b. Well Status: Oil Q Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20546-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ^ or Continuation ~ or Final ^ 308-153 4/28/2008 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 399" 399 totals (bbls): 2oos / 2nd 25630 100 0 25730 28 5/3/2008 6/26/2008 CD2-75, CD2-464, CD2-466 2008 / 3rd 335 100 0 435 2 7/2/2008 7/5/2008 CD2-72* 2008 / 4th 0 0 0 0 0 2009 / 1 st 0 0 0 0 Total Ending Report is due on the 20th vo~ume 25965 200 399 26564 30 ~bbis~: of the month following the final month of the quarter. Ex: Apri120 for the first quarter July 20 for the second quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , , October 20 for the third quarter, and January 20 for the Other (Explain} ^ fourth quarter. 12. Remarks and Approved Substances Description(s): *In~ectivit test and freeze protect volumes onl I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: O~.I. ~_ t~'~ Date: ~'1 1~~~ Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265-6120 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate ~ ~ ~ • • ConocoPh i I I i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 19, 2008 ~ ~ ~ ~~~~ _ ~AR ~ ~ Z~ -~ ~~aSk~ ~~~ ~t ~~S COR~e C, .::e,,.>~~.: ~e A~c~or~~~ Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~` Avenue, Suite 100 ~~`~/-7 Anchorage, AK 99501 c~ ~ ~ ` / Dear Mr. Maunder: c.~~. - ~~-- 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 16th & 17~', 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. Sincerely, C ~~ Perry Kleiri ConocoPhillips Well Integrity Projects Supervisor ~~ ~ ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off i ~ Report of Sundry Operations (10-404) Alpine Field Date 3/19/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitod sealant date ft bbls ft al CD2-72 207-057 SF NA 6" NA 0.85 3/17/2009 CD2-73 208-196 4'5" NA 4'S" NA 21.25 3/17/2009 CD2-75 208-064 SF NA 8" NA 1.70 3/17/2009 CD2-463 207-107 4' NA 4' NA 14.87 3/17/2009 CD2-464 208-082 6" NA 6" NA 1.70 3/17/2009 CD2-465 208-145 19" NA 19" NA 4.25 3/17/2009 CD2-466 208-095 8.5" NA 8'5" NA 1.70 3/16/2009 CD2-467 208-114 SF NA 6" NA 0.85 3/16/2009 CD2-468 208-180 SF NA 5" NA 1.70 3/17/2009 CD2-469 208-122 SF NA 7" NA 0.85 3/17/2009 CD2-470 208-129 SF NA 8" NA 1.70 3/17/2009 STATE OF ALASKA ALASKA OlL AND GAS CONSERVATION CQMMISSION REPORT UF ANNULAR aISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number: 207-057 ConocoPhillips Alaska, Inc. Development 0 Exploratory ^ 7. Well Name: CD2-72 2. Address: 4b. Well Status: Oil ^~ Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20546-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ~ or Final ^ 308-153 4/28/2008 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wefls: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 399* 399 totals (bbls): 2008 / 2nd 25630 100 0 25730 28 5/3/2008 6/26/2008 CD2-75, CD2-464, CD2-466 2008 / 3rd 335 100 0 435 2 7/2/2008 7/5/2008 CD2-72* 2008 / 4th 0 0 0 0 0 2009 / 1 st Total Ending Report is due on the 20th vo~ume 25965 200 399 26564 30 Ex: of the month following the final month of the quarter ~bbis~: . Apri120 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ October 20 for the thrrd quarter, and January 20 for the Other (Explain) D fourth quarter. 12. Remarks and Approved Substances Description(s): *In~ectivit test and freeze rotect volumes onl I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: /F`/. ~• l'p1 Date: ~~4 ~~ Printed Name: G. C. Alvord Title: Kuparuk Drilling Team leader Phone Number: (907) 265-6120 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number: 207-057 ConocoPhillips Alaska, Inc. Development ^~ Exploratory ^ 7. Well Name: CD2-72 2. Address: 4b. Well Status: Oil ~ Gas WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20546-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ^ or Continuation ^~ or Final ~ 308-153 4/28/2008 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 399" 399 totals (bbls): 2008 / 2nd 25630 100 0 25730 28 5/3/2008 6/26/2008 CD2-75, CD2-464, CD2-466 2oos i 3rd 335 100 0 435 2 7/2/2008 7/5/2008 CD2-72" 2008 / 4th 2009 / 1 st Total Ending Report is due on the 20th vo~ume 25965 200 399 26564 30 ~bbis~: of the month following the final month of the quarter. Ex: Apri120 for the first quarfer July 20 for the second quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): *In~ectivit test and freeze protect volumes onl I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~ '~_( ~c~ Date: (Q~~3~d4' Printed Name: G. C. Alvord Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6120 ' Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number: 207-057 ConocoPhillips Alaska, tnc. Development ^~ Exploratory ^ 7. Well Name: CD2-72 2. Address: 4b. Well Status: Oil ~ Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20546-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ~ or Continuation ^ or Final ~ 308-153 4/28/2008 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 399* 399 totals (bbls): 2008 / 2nd 25630 100 0 25730 28 5/3/2008 6/26/2008 CD2-75, CD2-464, CD2-466 2008 / 3rd 2008 / 4th 2009 / 1 st T°~' E"d'"9 Report is due on the 20th vo~ume 25630 100 399 26129 28 cbbis~: of the month following the fina/ month of the quarter. Ex: April 20 for the first quarter, Ju/y 20 for the second quarter, 11. Attach: Disposal PerFormance Data: Pressure vs. Time ^ Step Rate Test ^ October 20 for the third quarter, and January 20 for fhe Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): *II1~eCtIV1 test and freeze rotect volumes onl I hereby certiy tFiat the foregoin is true and correct to the best of my knowledge. Signature: ~ 1 Date: ~~ (,~( d a Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate ~ ti ~,~.. ~ ~.,x ~ .~~ ` ~~~ ~ ~~ VM ~ f r~~ ~. : r ~' ` ~~~~ ~ ` ~i~ ((L~~u~' ~ ` ~'~- ~ .~ ~ s M ~ ` ~ ~~ ~ ~ s ~~ ~ ; ~ p~ ~ ~ a y .ua ~, ~ ~ ~ ~F ~ ~ ~ -° ~ ~ ~ r P-~l ~ ~ f9 t ~„~ , ~'. ~ !.~ ~ "~ ~t ~ ' L ..., ~t ~ ~ ~ ... ~ i.......:;V 4b..... + ~a~ ~~ d...'a i..,,_.e:I E ~ \.~/ l,..1 1 J ~ T t. ~ CO1~T5ERQA ATIO C ~ Ip~ Chip Aivord Alpine Drilling Lead ConocoPhillips Alaska Inc PO Box 100360 Anchorage, AK 9g510 Re: Colville River Field, Alpine Oil Pool, CD2-72 Sundry Number: 308-153 Dear Mr. Alvord: SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 F~ (907) 276-7542 Enclosed is the approved Application for Sundry Approval relating to annular disposal of drilling wastes in the above-referenced well. Please note that any disposal into the surface/production casing annulus of a well approved for annular disposal must comply with the requirements and limitations of 20 AAC 25.080. 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 thi~~day of April, Encl. Sincerely, an T. Seamount Chair 2008 ~ ~~ ~~ ~ ;~ ~ R~c~iv ~ ~ ~ ~~~ -° STATE OF ALASKA ~~ APR 2 2 2008 •~ ~ ALASKA OIL AND GAS CONSERVATION COMMIS~~ Q~~ & Gas Cons. Commission ANNULAR DISPOSAL APPLICATION Anchora e 20 AAC 25.080 9 1. Operator 3. Permit to Drill Name: 207-Q57 ` ConocoPhiilips Alaska a. aPi Number. 50-1 ~3-20546-Od ' 2. Address 5. Well P.O. Box 100360, Anchorage, Alaska CD2-72 ' 6. Field: Colville River Field • 7. Publicly recorded wells 8. Stratigraphic description: a) All wells within one-quarter mile: a) Interval exposed to open annulus: CD2-4Q4, CD2-11, CD2-Q2, CD2-59, CD2-21, CD2-09, CQ2 Torok and Seabee formation, shale, siltstone and sandstone 33; CD2-18, CD2-23, CD2-'15, CD2-336; CD2-24 ~!, c ~ r (~.~{~ ~~ ~~ ~CJ ~ ~°'~ (~v.C'~~ ~f~~~ ~~~~c~ ~d~ b) Waste receiving zone: b) water wells within one mile: ~~~~5 ~~.~ __ \;_,, ~`~ J ~~o~~ ~ Sand layers below the C30 marker in the Seabee formation None d~~~S~~~ I c) Confinement: i The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Albian Torok Forma6on provide a lower barrier 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1650' MD / 1600' TVD None 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 13. Maximum anticipated pressure at shoe: None densities range from diesel to 12#/gal 1979 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 35,000 bbls. Types of waste may be drilling mud, drilling cuttings, ~eserve pit fluids, cement- contaminated drilling mud, completion fluids, diesel, formation fluids associated with the 16. Estimated start date: act of drilling a well, drill rig wash fluids, cement rinsate, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and other 4-May-48 substances that the commissioner determines on application are wastes associated with the act of drilling a well permited under 20 AAC 25.005. 17. Attachments: Well Schematic (Include MD and ND) ~ Cement Bond Log (if required) ^ FIT Records w/LOT Graph Q Surf. Casing Cementing Data ~ Other ~ previous authorization for new product cleanup fluids for CD1 and CD2 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~it.~ ~- ~ Title: ~~`3'~-~`~' ` Printed Phone Name: Chip Alvord Number: 265-6120 4/22/2008 Commission Use Only Conditions of approval: ~~"@ h~~~ ~ 1~ A~~-~S ~~~~ LOT review nd approval: ~" ~`~~~ "-C~ ~~ c~~r~~~goS~c.~ c pec-e~~~ns o 1~ ~~ C~a-~~S~S~ ~~ ~.~c~~ roval number: ~~~~~ ir d: ~ A t f S b pp sequen orm requ e u C; ~~~ ~~~ ~~F" ~ ~ ~~~~ , OMMISSION ^ Approved by: COnnMissloNER Date: Z~ V O Form 10-403AD Re~~ ~ 4 INSTRUCTIONS ON REVERSE ~' ~~ ~ ~INA~. ,~ ~ ~Z3-~ Submit in Duplicat~~, ,~/~~/~ ~~ ~ ~ ~ ConocoPhillips Alaska, Inc. ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 ~~~~~~~~ ~' ~ ~ ~~ Telephone 907-276-1215 April22~ Zoog RECEIVEC~ APR 2 2 2008 Alaska Oil and Gas Conservation Commission 333 West 7~` Avenue, suite loo Alaska Oil & Gas Cons. Commission Anchorage, Alaska 99501-3539 Al1ChOfe98 Re: Application for Sundrv Approval for Annular Disposal of Drilling Waste on well CD2-72 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD2-72 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended to begin annular disposal operations on CD2-72 approximately May 4, 2008. Please find attached form 10-403AD and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Summary of wells on Pad 4. Plan View of Adjacent Wells 5. Surface Casing Description 6. Surface Casing Cementing Report & Daily Drilling Report during cement job 7. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 8. Intermediate Casing Description 9. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 10. Formation LOT on 10-3/4" x 7-5/8" casing annulus 11. List of wells on CD3 pad and the lateral distance from the surface casing shoe. 12. Information regarding wells within 1/4 mile radius at AOGCC: CD2-404, CD2-1 l, CD2-59, CD2-21, CD2-09, CD2-23, CD2-15, CD2-24 13. Information regarding remaining wells within'/4 mile radius included in sundry package: CD2-33B, CD2-18, CD2-31, CD2-02 14. Copy of previous authorization (CD1 and CD2) for disposal of new product cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations The initial annular LOT (1230 ppg) occurred at a lower equivalent mud weight than the casing shoe test (15.9 ppg LOT). Therefore we conclude that waste will not migrate above the confining zone provided we do not inject with sustained surface pressures that will cause pressures at the surface shoe to be in excess of the shoe FIT/LOT. If you have any questions or require further information, please contact Liz Galiunas at 265-6247; Chip Alvord can also be reached by calling 265-6120. Sincerely O Liz Gali Drilling Engineer cc: CD2-72 Well File Chip Alvord ATO-1577 Sharon Allsup-Drake ATO-1530 ~ ~ Annulus Disposal Transmittal Form - Well CD2-72 AOGCC Reeulations. 20 AAC 25.080 (bl 1 Desi nation of the well or wells to receive drillin wastes: CD2-72 2 T'he depth to the base of freshwater aquifers and permafrost, i There are no USDW aquifers in the Colville River Unit. resent. Estimated base of Permafrost = 1600' TVD RKB 3 A stratigraphic description of the interval exposed to the open The SChrader Bluff formation provides an upper bamer and annulus and other information sufficient to support a marine shales and claystones of the Albian Torok Formation commission finding that the waste will be confined and will provide a lower barrier. Calculated water salinities of the not come to the surface or contaminate freshwater. Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/1. (Ref. AOGCC Conservation Order No. 443, 4 A list of all publicly recorded wells within one-quarter mile See attached map indicating wells within 1/4 mile. There are and all publicly recorded water wells within one mile of the no water wells within 1 mile. well to receive drillin waste. 5 Identify the types and maacimum volume of waste to be Types of waste may be drilling mud, drilling cuttings, reserve disposed of and the estimated density of the waste slurry. pit fluids, cement-contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. Densities range from diesel to 12#/gal. M~imum volume to be pumped is 35,000 bbls. 6 A description of any waste sought to be determined as drilling Cement rinsate, mud plant rinse fluid generated by rinsing waste under (h)(3) of this section. tanks and equipment after producing drilling/completion fluid (see included note from CDl&2 authorization). 7 An estimate of maximum anticipated pressure at the outer Maximum anticipated pressure at the outer casing shoe during casing shoe during annular disposal operations and disposal operations is 1979 psi. See attached calculation calculations showin how this value was determined. a e. 8 Details that show the shoe of the outer casing is set below the See attached: cementing reports, LOT / FIT reports and base of any freshwater aquifer and permafrost, if present, and casing reports. cemented with sufficient cement to provide zone isolation: 9 Details that show the inner and outer casing sh-ings have See attached casing summary sheet and calculation pages. sufficient strength in collapse and burst to withstand antici ated ressure of dis osal o erations: 10 The downhole pressure obtained during a formation integrity See attached LOT/FIT report. test conducted below the outer casin shoe. 11 Identification of the hydrocarbon zones, if any above the N/A de th to which the inner casin is cemented. 12 The duration of the disposal operation, not to exceed 90 days. N/A 13 Whether drilling waste has previously been disposed of in the N/A annular space of the well and, if so, a summary of the dates of the disposal operations, the volumes of waste disposed of, and the wells where the drilling waste was generated. 14 The well(s) where the drilling waste to be disposed of was or CD2-75, CD2-464, CD2-466, CD2-74, CD3-75, CD2-463 will be enerated. 15 If the operator proposes not to comply with a limitation N/A established in (d) of this section, an explanation of why com liance would be im rudent. 16 Any additional data required by the commission to confirm N/A containment of drillin waste. ~ ~ v~~on i.o - ~an ~os 3,043 = ( 2,394 * 0.052 * MWm~ ) + 1500 - ( 0.4337 * 2,394 ) MWmax = 20.73477 ppg Surface Casing Strin Size 10.75 in Weight 45.5 ppf Grade . L 80 pburstl0o/ 3,580 psi pb,u~cssi 3,043 psi Depth of Shoe 2,394 g FIT/I.OT @ Shoe 15.9 ppg or 1,979 psi FIT/LOT for Annulus 12.3 ppg Max Surf. Pressure 1,500 psi Maximum Fluid Densitv avoid Collapse of 2nd Casing String Pcollapse85 %- PHydrostatic + PApplied- PGasGradient - PHeader 4,072 =( 6,969 * 0.052 * MWm~ )+ 1,500 -( 0.0700 * 6,969 )- 1,000 MWmaa = 11.20161 PPg 2nd Casing Strin~ Size 7.625 in Weight 29.7 ppf Grade L 80 P~oit~seioor 4,790 psi Pcollapse85 % 4,072 psi Top of Cement 6,969 ft Gas Gradient 0.07 psi/8 M~ Surf. Pressure 1,500 psi Header Press 1,000 psi Maximum Antici~ated Pressure at Surface Casing Shoe Pm~~toWab~e= Shoe TVD Depth *.052 * Shoe FIT/LOT pmax allowable - ( 2,394 * .052 * 15.9 ) Pmaxallowable- 1~979 p91 This is the value for the Injection Permit "M~imum Anticipated Pressure at Shoe". Pressure Calculations for Annular Disposal (for submital with Annulaz Disposal Application) Assum tp ions Maacimum injection pressuze of 1,500 psi M~imum density ofthe injection fluid is 12.0 ppg Pore pressure at the 9 5/8" casing shoe is 0.434 psi/ft Gas/Fluid Gradient in tubing/casing annulus 0.07 psUft Header Pressure (for wells on gas lift) 1,000 psi Maximum Fluid Densitv to avoid Burst of Surface Casing Pburst85 % - PHydrostatic + PApplied - PFormation Well CD2-72 Date 4/22/2008 ~ SURFACE CASING SHOE SEPARATION FROM CD2-72 CD2-72 x v Surface Casina Shoe ASP 4 Coordinates 369745.64 5975101.63 • ells Details @ AOGCC ermit # ermk Date ource well Ann. Vol. "'* tart Date nd Date is nce from Object well` Surface csg. Shoe X Coord. SurFace csg. Shoe Y Coord. CD2-35" 2786 372312.31 5974017.68 CD2-42 301-140 611l2001 CD2-24, CD2-33, CD2-33A, CD2-15 33992 6/1/200'I 10/10/2001 1749 377098.46 5973992.48 CD2-24 301-186 7/13l2001 CD2-33 (+A&B), CD2-39, CD2-14, CD2-15 33999 7/16/2001 1019/2001 96 370630.11 5974721.81 CD2"-33 8"" included 1283 370155.64 5973886.23 CD2-39 y 301-281 10f9l2001 CD2-15, CD2-47, CD2-44 29945 10/10/2001 9/16I2002 2990 372350.61 5973633.17 CD2-14 301-288 101912007 CD2-45, CD2-47, CD2-32 31073 11/13/2001 3/5/2002 2461 372202.47 5974960.87 CD2-15 301-308 11(6I2001 CD2-50, CD2-25, CD2-44 31652 3/612002 9121/2002 '` ' 1093 370832.00 5974984.02 CD2-47 301-322 12f312001 CD2-34, CD2-26 27349 12/17/2001 1/20/2002 2340 371231.72 5973294.19 CD2-45 301-345 12l13/2001 CD2-49, CD2-17 22991 1/20/2002 2/19/2002 3267 372765.13 5973853.74 CD2-34 302-069 3/4l20~2 CD2-13, CD2-37 22842 10/17/2002 11l28/2002 2161 371803.06 5974439.79 CD2-26 y 302-068 3/M2002 CD2-44, CD2-29, CD2-13 29626 9/7/2002 10/17I2002 2125 371798.52 5974554.55 CD2-49 302-070 3lM2002 CD2-50, CD2-46, CD2-22 27960 4/22/2002 S128/2002 1828 371252.38 5974065.93 CD2-17 302-122 4/10t2002 CD-48, CD2-08 18181 5/29/2002 2/7/2003 2079 371774.00 5974645.00 CD2-32 302-119 413012002 CD2-19, CD2-41, CD2-23 31113 6/14/2002 7l23/2002 1744 371295.61 5974302.38 CD2-50 302-121 4(30(2002 CD2-41, CD2-19, CD2-16, CD2-38 32000 7/24/2002 9/7/2002 2109 371665.21 5974227.65 CD2-25 NA 1950 371594.00 5974479.00 CD2-46 302-273 9/20/2002 CD2-51, CD2-12 318&4 4/15/2003 S119/2003 2103 371694.80 5974310.85 CD2-22 302-274 9l2012002 CD2-08, CD2-36, CD2-51 31253 2/7/2003 3/16/2003 2007 371678.61 5974562.30 CD2-48 y 302-275 912012002 CD2-28, CD2-35a, CD2 45, CD2-08 32000 12/10/2002 Z/4l2003 2329 371631.74 5973736.14 CD2-19 303-083 4128l2003 CD2-58, CD2-52 31337 5/19/2003 6/27/2003 2574 372284.88 5974681.33 CD2-41 y 303-081 4/28/2003 CD2-20, CD2-55,CD2-43 320QD 6127/2003 7/28/2003 2594 371990.58 5973802.52 CD2-23 303-080 4/28/2003 CD2-18, CD2-55, CD2-06 32000 9/4/2003 1l1/2004 i268 371013.17 5975070.46 CD2-16 2733 372460.34 5974790.01 CD2-38 y 303-082 4l28t2003 CD2-40, CD2-30 30011 7/28/2003 9l4/2003 2778 372033.86 5973527.13 CD2-44 2416 372034.57 5974328.53 CD2-29 303249 8I2512003 CD2-06, CD2-30, CD2-27 29036 10/8/2003 11/19/2003 2914 372652.44 5974896.02 CD2-13 y 2992 372658.78 5975785.31 CD2-37 y 2879 371569.79 5972874.47 CD2-28 2423 372139.80 5974728.95 CD2-OS 2953 372655.88 5975603.76 CD2-36 y 303-365 12/1212003 CD2-43, CD2-31, CD2-57 32000 12131/2003 7l9/2004 2622 37184822 5973535.38 CD2-51 303-312 10t2812003 CD2-07, CD2-10 31769 11/19/2003 12/24/2003 3768 373114.02 5973411.81 CD2-12 303-365 12/1212003 CD2-57, CD2-31 32000 5/15/2004 6l14/2004 1370 371071.29 5975445.60 CD2-58 NA 3395 372102.03 5972657.80 CD2-52 NA 3231 372637.61 5973661.63 CD2-20 304-288 7t30l2004 452 1670 371366.14 5975507.11 CD2-55 y 2349 371118.23 5973194.84 CD2-40 y NA 0 1608 370691.67 5973801.44 CD2-30 NA 0 1659 370473.52 5973610.96 CD2-18 inGuded ' 384 369825.76 5974716.05 CD2-06 NA 0 2078 371610.81 5976018.45 CD2-27 304-226 6/23lZOQ4 CD2-53, CD2-05, CD2-09 32000 7/9I2004 8/27/2004 3875 373046.07 5973071.83 CD2-10 304-289 7l3012004 CD2-09, CD2-56 30703 8l27l2004 10/15/2004 2245 371800.58 5976006.36 CD2-07 NA 0 2742 372218.06 5976287.95 CD2-43 1690 370344.04 5973520.68 CD2-57 y 305-238 8117l2005 CD2-01 19181 8/22/2005 9112/2005 3938 372537.05 5972324.37 CD2-31 induded NA 0 655 369824.37 5974451.30 CD2-53 304-361 9J3012004 CD2-56, CD2-54, CD2-02 26072 10/3/2004 8!5/2005 4080 372896.67 5972509.19 CD2-05 0 1459 370258.60 5973735.40 CD2-09 304-362 9/30/2004 418 1273 370318.00 5976239.00 CD2-56 305-307 10/11/2005 CD2-404 11167 5/7/2006 5123/2006 2053 369875.93 5973053.08 CD2-54 NA 0 1755 369991.09 5973363.59 CD2-21 5&# = 370286.77 5975261.48 CD2-59 1056 369650.94 5974049.86 CD2-60 3158 371269.33 5972336.05 CD2-03 1903 371040.60 5976495.42 CD2-02 inGuded 1065 369431.33 5976119.22 CD2-01 inGuded 3492 373114.47 5976019.06 CD2-11 493 370835.25 5975420J6 CD2-72 induded 0 369745.64 5975101.63 CD2-404 y 307-154 5l8/2007 D2-72 6764 5/14/2007 5131I2007 902 370646.55 5975142.76 ` Lateral distance in feet, between surface casing shoes, in the X-Y plane " CD2-35 was drilled from an ice pad in eariy 1998. The 9-5/8" x 7" annulus has not been permitted for annular disposal. "`CD2-33 B was a delineation well with a window milled out of 9-5/8" casing at 3840' MD (3062' TVD), shoe depth shown indicates window depth. It has not been permitted for an~ular disposal. "" As of 5131/2007 Note that this sheet is not the definitive record. ~ CabuWtlon Metliotl: Mlnlmum Curvalure ~y~~ ! Eno1 Syftam: ISCWSA ~1a/~ ~'~.,/iw.V~ ^~~i~~~.i ~~ gWarnl OuM¢thod ERP's Ba eC ~ ~ Geotle~lc DaWm: Norih Amerlwn ~aNm ieB1 Ma9~e~ Motlel: BGGM3007 Ground Le~m1: a.Pb RKB: CD2-72:~54.53ft(GD2-72:} aaorn,~~yrr.s~v: su7a9aa.xa EastinglASP X: 1511282.9U Project: Western North Slope Site: CD2AlpinePad ~jD2_72 We1L• CD2-72 Wellbore: CD2-72 Quarter Mile View CD2-72 _c~'I:0`L Gp21'~' G'~`L'~1 GD2-4D4 GO'L22 _ ~A~°p~ 2 2 .~ c ~ 0 o~ ti + ~ ~ 0 z ~ ~ ~ 0 ~ West(-)/East(+) (700 ft/in) -4200 -3500 -2800 -2100 -1400 -700 0 700 1400 ~ ~ ConocoPhilli $ ~ Casing Detail ~ 10 3/4" Surface Casinq Well: CD2-72 Date: 5/7/2007 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 37.60 FMC Gen V Hanger 2.59 37.60 Jts 3 to 81 79 Jts 10-3/4" 45.5# L-80 MBTC Csg 3191.34 40,19 Halliburton Float Collar 1.15 3231.53 Jts 1 to 2 2 Jts 10-3/4" 45.5# L-80 MBTC Csg 83.46 3232.68 Weatherfard Float Shoe 1.76 3316.14 3317.90 TD 13 1/2" Surface Hole 3328.00 13-1/2" Hole @ 3328' MD / 2397.5' TVD 10-3/4" Shoe @ 3317.90 ' MD / 2393.7' TVD RUN TOTAL 47 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 64,66,68,70,72,74,76,78, & 79 90 joints in the pipe shed, Run 81 joints Last 9 joints stay out Use Best-o-Life 2000 i e do e All joints drifted 9.875" MU torque ~ 9500 ft/Ibs Remarks: PUW - 195K SOW - 140K Block Wt - 75k Supe-visor.~ D. Bu-1ey/D. Mickey Vr i • Cement Detail Report CD2-72 Surface Casing Cement ~ Surface Casing Cement 5/7/2007 14:15 5/7/2007 1720 CD2-72 Comment Cemented 10 3/4" casing as foliows: Pumped 50 bbls of 9.9 ppg mud with nut plug marker followed with 40 bbls of Biozan as pre flush w/ nut plug marker - Switch over to Dowel! - Pumped 10 bbls CW 900 - tested lines to 3000 psi - pumped 10 bbls CW 100 - Dropped btm plug - Mixed & pumped 50 bbis 10.5 ppg MudPUSH II spacer @ 4.8 BPM @ 165 psi - Mixed & pumped 425 bbls 10.7 ppg Lead slurry (ASL) @ 7.0 BPM / 240 - 290 psi - Observed nut plug marker @ shakers w/ 410 bbls lead slurry pumped -(pumped down surge can 425 bbis total) Switched to tail slurry - Mixed 8 pumped 67 bbis 15.8 ppg lead slurry (Class G w/ 2% S1, 0.2%D46,0.3%D65) @ 3.0 BPM @ 220 psi - Dropped top plug w/ 20 bbls fresh water f/ Dowell - Switched to rig pumps & displaced cement w/ 288 bbls 9.9 ppg mud @ 8.2 BPM / 447 to 761 psi slowed pump to 4.2 BPM / 540 psi(for the last 7 bbls of displacement) Bumped plug to 1070 psi - Check floats OK - CIP @ 1720 hrs. - Full circulation throughout job w/ 148 bbls 10.7 ppg cement returns to surtace - reciprocated pipe while cementing and first 152 bbls of mud displacement - hole ge mg s ic y- os - landed casing for remainder of job Description Objective Top (ftK6) Bottom (ftKB) Full Retum? Cmnt Rtrn ... Top Plug? Btm Plug? Surface Casing Cement 36.0 3,318.0 Yes 148.0 Yes Yes Q (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 8 540.0 1,070.0 Yes 25.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftK6) Drill Out Diameter (in) Comment Gement Fluids 8~'Adciitives F![~id , Fluid Type Fluid Description Estimated Top (ftKB) Est Btrn (ftK6) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 0.0 2,818.0 14 G 425.0 Yield (ft%sack) Mix H20 Ratio (gallsa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1(psi) _4,63 10J0 Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 2,818.0 3,318.0 319 G 67.0 Yield (ft /sack) Mix H20 Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1(psi) 1.17 15.80 IAdditive Conc Unit tabel Page 1/1 ~ . Security Level: Development Daily Drilling Report CD2-72 Report Number: 9 tig: DOYON 19 Report Date: 5/7/2007 AFE Type' NeN/ockllD #; Total qFE~rS~p 10170504 11,442,548.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD2-72 Development ALPINE 3.40 9.0 0,00 3,328.0 3,328.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 6,829.98 50,002.89 577,067.98 1,591,501.89 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 4/29/2007 5/4/2007 35.58 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Surface, 3,317.9ftK6 Ops and Depth ~ Morning Report 24hr Forecast PU BHA #2 RIH w/ BHA #2 - C/O shoe track - FIT - Drill 9 7/8" hole Last 24hr Summary Finish POOH & LD BHA - Run 8~ cmt 10 3/4" csg to 3318' - NU wellhead & BOPE Testing BOPE General Remarks Weather Head Count 16/3WC-SW@12mph 47.0 Dave Burley, Rig Supervisor Don Mickey, Rig Supervisor 00:00 01:00 1.00 SURFAC DRILL TRIP P 893.0 73.0 Flow check well, static - POOH from 893' to 73' 01:00 03:15 2.25 SURFAC DRILL PULD P 73.0 0.0 PJSM - LD UBHO, TM HOC, HCIM, DM HOC, NMXO, IBS, FS, Motor and bit - clear tools from rig floor 03:15 0530 2.25 SURFAC CASING RURD P 0.0 0.0 PuII riser donut - Lay down drilling elevators and bails - install fill -up tool, casing bails, elavators, slips, PU sling and tongs 05:30 05:45 0.25 SURFAC CASING SFTY P 0.0 0.0 Hetd PJSM with crew 05:45 08:45 3.00 SURFAC CASING RNCS P 0.0 1,710.0 Ran 10 3/4" 45.5# L-80 BTC csg as follows: FS (Weatherford) 2 jts. FC (Halliburton) 2 jts.( first 4 connections made up w/BakerLoc - filled pipe & checked floats) 38 jts. to 1710' (42 jts. total) PUW 150K SOW 115K 08:45 09:15 0.50 SURFAC CASING CIRC P 1,710.0 1,710.0 CBU - ICP 3.5 bpm / 300 psi - FCP 7.0 bpm /410 psi - PUW 140K SOW 125K 09:15 11:30 2.25 SURFAC CASWG RNCS P 1,710.0 3,318A Continue running 10 3/4"' 45.5# L-80 BTC csg from 1710' to 3277' (81 jts total) MU FMC fluted hanger and land csg w/ FS @ 3318' & FC @ 3232' 11:30 12:00 0.50 SURFAC CEMENT RURD P 3,318.0 3,318.0 Lay down fill-up tool - blow down top drive - RU cement head and lines 12:00 14:15 2.25 SURFAC CEMENT CIRC P 3,318.0 3,318.0 Stage pumps up to 8 bpm - circulate and conditiom mud for cementing - Reciprocated pipe with full returns throughout - FCP= 8 bpm / 320 psi - PUW 190K SOW 143K- Held PJSM with Dowell and rig crew Data I Page 1!3 Report Printed: 4/78/2008I ~ ~ Security Level: Development 14:15 tig: DOYON 19 Daily Drilling Report CD2-72 Report Number: 9 Report pate: 5/7/2007 Gemented 10 3/4" casfng as Tollows: Pumped 50 bbls of 9.9 ppg mud with nut plug marker followed with 40 bbls of Biozan as pre flush w/ nut plug marker - Switch over to Dowell - Pumped 10 bbls CW 100 - tested lines to 3000 psi - pumped 10 bbls CW 100 - Dropped btm plug - Mixed & pumped 50 bbls 10.5 ppg MudPUSH II spacer @ 4.8 BPM @ 165 psi - Mixed & pumped 425 bbls 10.7 ppg Lead slurry (ASL) @ 7.0 BPM / 240 - 290 psi - Observed nut plug marker @ shakers w/ 410 bbls lead slurry pumped - (pumped down surge can 425 bbls total) Switched to tail slurry - Mixed & pumped 67 bbls 15.8 ppg lead slurry (Class G w/ 2% S1, 0.2%D46,0.3%D65) @ 3.0 BPM @ 220 psi - Dropped top plug w! 20 bbls fresh water f/ Dowell - Switched to rig pumps & displaced cement w/ 288 bbls 9.9 ppg mud @ 8.2 BPM / 447 to 761 psi slowed pump to 4.2 BPM / 540 psi(for the last 7 bbls of displacement) Bumped plug to 1070 psi - Check floats OK - CIP @ 1720 hrs. - Full circulation throughout job w/ 148 bbls 10.7 ppg cement returns to surface - reciprocated pipe while cementing and first 152 bbls of mud displacement - hole getting sticky - lost 35K SOW - landed casing for remainder ofjob 17:30 18:00 0.50 SURFAC CASING DHEQ P 3,318.0 3,318.0 RU and test casing to 3000 psi for 30 minutes - bleed off and blow down lines 18:00 19:00 1.00 SURFAC CEMENT RURD P 3,318.0 3,318.0 RD cmt lines & cmt head - LD landing jt. 19:00 20:30 1.50 SURFAC DRILL RURD P 3,318.0 3,318.0 RD surface riser - Remove starting head 20:30 21:15 0.75 SURFAC DRILL OTHR P 3,318.0 3,318.0 Install FMC wellhead with flow line oriented w/ surveyed scribe line on conductor - Tested to 1000 psi for 10 mins. 21:15 22:15 1.00 SURFAC WELCTL NUND P 3,318.0 3,318.0 NU BOPE & flow line 22:15 22:45 0.50 SURFAC WELCTL OTHR P 3,318.0 3,318.0 Install lower test plug & fill BOPE stack w/ water 22:45 00:00 1.25 SURFAC WELCTL BOPE P 3,318.0 3,318.0 Test BOPE - Test Annular to 250 & 3500 psi - Testing pipe rams & choke manifold - choke & kill line valves to 250 8~ 5000 psi Mud G hs~ck Data'i . ~ ~ ~ YP Ga 1c t ~[ (10s} ' Get {10m~ G~i [3 E1€~3 ~ HT HP Fdt ~ Densrty Temp Solids. CrtR. ' ! ~ . "' Ty pB ` Depih ( 8I(~ E~ens ~b/ gai)'- ~s (sJqt) Pl1 G~c(c~t~ (ibfliSl-fk~~ (I ML140tt'j '~,~IbfliDOff') ~; ~16ff10 0ft~} MBT ~bVbbl) ~m Li30m~) ' ~~ " ~ {°F) ', (°~6) Spud Mud 3,328.0 9.90 90 10.0 19.000 20.0 9.1 75.0 ~n'e~~ion Flu itl .'~ ~IUid': ScwYce ~t~m Le ase (bul) Destina# ion !. Nate Other 280.0 CD1-19 fCD2-72 Cmt contam. Mud Water Based Mud 2075.0 CD1-19 f/CD2-72 I Page 2/3 Report Printed: 4/78/2008I ~ ~ Security Level: Development Daily Drilling Report CD2-72 Report Number: 9 tig: DOYON 19 Report Date: 5/7/2007 ~3ri[I ~trin s; BN~4 N~:.! ~ 8" Mud'Motvr 9~5 - 5.3 ' f~3it Run No. 1-'131~~ir-, Hu k~es Christer~sen ' MX-1 ,'S17959Q Depth In (ftK6) Depth Out (ftKB) TFA (incl Noz) (in') Nozzles (/32") IADC Bit Dull String Wt (10001b~ 114.0 3,955.0 0.75 16/16/18/12 4-5-WT-A-E-O-ER-TD 44 Drill Strin Com onents Jts ~ ° 1{erta [Iescripti4~ ; OIT~n) ; , iD ~in} ; Tap ~onn ~z ~in) ; Top 7~ead Cum L$n (ft} Mud Motor 8 5.000 6 5/8 H 90 31.75 Float Sub 8 2.750 6 5/8 H 90 34.33 Integral Blade Stabilizer 8.11 2.813 6 5/8 H 90 39.99 XO Sub 8.05 3.000 6 5/8 H 90 41.99 MWD (Directional) 8 1.920 6 5/8 Reg 51.19 MWD HCIM 7.98 1.920 6 5/8 Reg 59.90 MWD TM 8 1.920 6 5/8 H 90 69.77 Non Mag UBHO Sub 7.88 2.750 6 5/8 H 90 73.14 NMDC 7.67 2.813 6 5/8 H 90 104.11 NMDC 8.11 3.313 6 5/8 H 90 134.90 Drilling Jars - Mechanical 7 3!4 2.750 4 1/2 IF 169.46 24 HWDP 5 3.000 4 1/2 IF 893.01 3,328. 0 3,328.0 3,214.00 31.97 705 30.0 50 2,480.0 T33 130 177 7,000.0 S,W0.0 Wellbore s Wellbore Name Wellbore API/UWI CD2-72 501032054600 i 8ection . Size (inj , Act Top (ftK8) Act BUn (RKB}', Starf Date ' End fla#e : COND1 16 OA 114.0 4/16/2007 4/17/2007 SURFAC 13 1/2 114.0 3,328.0 5/4/2007 5/6/2007 INTRM1 9 7/8 3,328.0 16,707.0 5/8/2007 5/13/2007 PROD1 6 3/4 16,707.0 21,089.0 5/23/2007 5/28/2007 Cement Surface Casin Cement - Started 5/7/2007 Type Wellbore Cemented String Cement Evaluation Results casing CD2-72 Surface, 3,317.9ftKB Stg No. Description Top (ftK6) Bottom (ftKB) Q(e nd) (bbl/... P(final) (psi) Surface Casing Cement 36.0 3,318.0 4 540.0 Fl~nd ~tass -- f+mount {~acks) : 1l ~bbl~ ;.. Den~itq (Ibigal~ ` Y'~eid ( 7sacic~ EsY 7op ~#K6} ,.. Est Btm {ftK$3 ~: , Lead Cement G 514 425.0 10.70 4.63 0.0 2,818.0 Tail Cement G 319 67.0 15.80 1.17 2,818A 3,318.0 Page 3/3 Report Printed: 4/78/2008 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD2-72 Rig: Doyon 19 Date: 5~$~2~n7 volume Input Volume/Stroke Pump Rate: Drilling Supervisor: D. Burley / L. Hili PUtilp US4d; #2 Mud Pump ~ Strokes ~~ 0.1 QOd Bbls/Strk ~ 7.0 Strk/min ~ i Type of Test: OpenholeTest ~OT/FIT ~ Pump ng down annulus and DP. ~ Casin Test Pressure In te ri Test Hole Size: 9-~/$" ~ Casin Shoe De th Hole De th Pum in Shut-in Pumpin Shut-in RKB-CHF: 35.2 Ft 3,31$ Ft-MD 2,394 Ft-ND 3,348 Ft-MD 2,510 Ft-TVD Strks psi Min si Strks si Min si Casinq Size and Description: 10-3/4" 45.5#/Ft L-80 BTC ~ 0 4 0 3010 0 0 0 88Q Casin Test Pressure Int e rit Test 2 13Q 1 2990 2 40 0.25 840 Mud Weight: 9.9 ppg Mud Weight: 9.5 ppg 4 260 2 298Q 4 60 0.5 800 Mud 10 min Gel: 47.0 Lb/100 Ft2 Mud 10 min GeL 63.0 Lb/100 Ft2 6 360 3 298Q 6 150 1 7Q0 Test Pressure: 3,000 psi Rotating Weight: 130,000 Lbs 8 480 4 2980 8 275 1.5 60 Rotating Weight: 75,OOQ Lbs Blocks/Top Drive Weight: 75,OQ0 Lbs 10 6Q0 5 29$Q 1Q 410 2 55 Blocks/Top Drive Weight: 75,000 Lbs Desired PIT EMW: 18.0 ppg 12 72Q 6 2980 12 510 2.5 525 Estimates for Test: 3.6 bbls Estimates for Test: 1058 psi 1.2 bbls 14 815 7 2980 14 610 3 520 • ~ 16 900 8 2970 16 71 d 3.5 520 EMW = Leak-off Pressure + Mud Weight = 800 + 9 5 PIT 15 Second 18 980 9 2970 18 8Q0 4 520 0.052 x TVD 0.052 x 2394 Shut-in Pressure, psi 20 1070' 10 2970 20 840 4.5 510 EMW at 3318 Ft-MD (2394 Ft-TVD) = 15.9 ~1 ~- 840 22 ~ 14a ~ 5 2970 22 sso 5 510 ssoo i d i t t h ld ~4 1240 20 2960 24 91 fl 5 5 510 Lost 50 ps ur ng es , e . 98 3 % of t re est ssure 26 133d 25 2960 26 910 6 50Q . p . 2$ 1420 30 2960 6.5 500 sooo ~`"~'``~` ~ ~ " 30 _ 151 ~ 7 500 ' 32 1 ~20; 7.5 500 zsoo 34 171(}; 8 500 36 1820 8.5 500 w 38' 1930 9 5Q0 a zooo 40 2040 9 5 500 y . ~ 4~ 216Q 10 5p ~ ~soo 44' 2270 a 46' 238q ~' ~oo0 4 2510 ~ ~ 50 2630 soo ~r; 5~ 276Q 54 2890 : ~fi 3010 0 o , 2 3 4 5 s o 5 , 0 1 5 2 o z s 3o ~CA SING TEST Barrels tL EAK-OFF TE ST S hut- O P In tim IT Poin e, M t inute s Volume PUtll ed Vol Bled ume Back Volume PU111 ed Volume Bled Back 5.6 s Bb s . 2.6 s s Comments: Tested Casing after bumping plugs during cementing ops i ConocoPhilli s p Casing Detail 7 5/8" Casinq ! WeIL• CD2-72 Date: 5/17/2007 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Lower lock down 35.15 FMC Gen V Hanger 329 35.15 Jts 197 to 393 197 Jts 7 5/8" 29.7# L-80 BTCM Csg 8347.19 38.44 Tam Port Collar 2.39 8385.63 Jts 3 to 196 194 Jts 7 5/8" 29.7# L-80 BTCM Csg 8218.78 8388.02 Halliburton Float Collar .99 16606.80 Jts 1 to 2 2 Jts 7 5/8" 29.7# L-80 BTCM Csg 82.69 16607.79 Silver Bullet Float Shoe 2.10 16690.48 16692.58 TD 9 7/8" Hole 16707.5$ 9 7/8" Hole TD @ 16,707' MD / 7270' ND 7 5/8" Shoe @ 16,692' MD / 7268' ND Total Centralizers: 59 Straight blade & 14 Bow spring Straight blade centralizer one per jt on jts # 1-20 Straight blade centralizer one per jt jts. # 196, 197, 199 201, 203, 205, 207, 209, 211, 213, 215, 217, 219, 221 Bow spring centralizer one per jt #'s 317, 318, 319, 321, 323, 325, 327, 329, 331, 333, 335, 337, ~39, 341 Straight blade centralizer one per jt on every other joint Fron jt # 343 thru jt # 391 410 joints in shed - 393 total jts. to run L.ast 17 jts. out Use Run & Seal i e do e Average MU torque 8500 ft/Ibs Remarks: llp Wf - ~}Ofl k { : t~n UUf - 155k ' Block Wt - 75k Supeivisor.-D. Lutrick/L. Hill/S. Lapiene ~ • Cement Detail Report CD2-72 Intermediate Casing Cement ~ Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 5l17/2007 03:16 5/17/2007 05:52 CD2-72 _...._ ..,.. ...,~......... ..r i~.~...~ .......~. i..~...~ ..~. ~.`....~~. .~~... ~....... .,r . ..y. ..... ...y. Intermediate Casing Anchor shoe. 15,660.0 16,707.0 No Yes Yes Cement Q (start) (bbl/min) Q (end) (bbl/min) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 7 4 6 400.0 900.0 Yes 18.00 No Depth tagged (ftK6) Tag Method Depth Plug Drilled Out To (ftK8) Drill Out Diameter (in) Comment PJSM on cementing - Cemented 1 st stage 7 5/8" csg as follows: Pumped 5 bbls CW-100 - Test lines to 3700 psi - Pumped 15 bbls CW-100 @ 3bbls/min ~ 180 psi - Mixed 8~ pumped 40 bbls 10.5 ppg MudPush (Problem getting MP up to weight) @ 3 bbls/min @ 260 psi - Dropped btm plug - Mixed & pumped 61.1 bbls 15.8. ppg Tail slurry (class G w/ additives) @ 4.5 bbis/min @ 350 psi - Dropped top plug w/ 20 bbls water f/Dowell - switched to rig pumps 8 displaced cmt w/ 744.3 bbls 10.3 ppg LSND mud @ 7 bbls./min @ 500 psi for first 720 bbis slowed pumps to 4 bbls/min @ 400 psi for last 24.3 bbls - Bumped plug w/ 900 psi - CIP @ 05:52 hrs. Checked floats Did not hold - Full retums throughout job - Reciprocated pipe for first 720 bbls of displacement - landed pipe when pumps were slow~d to 4 bbis/min. Fluid Type Fluid Description Estimated Top (ftK6) Est Btrn (ftKB) Amount (sacks) Class Volume Pumped (bbl) Intermediate Cement 15,660.0 16,693.0 287 G 61.0 Yield (ft'/sack) Mix H20 Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1(psi) 1.17 5.10 15.80 Additives Type Description Objective Top (ftK6) Bottom (ftKB) Full Return? Cmnt Rtrn ... Top Plug? Btm Plug? Port Collar Isolate K 2 7,300.0 8,388.0 Yes No No Q (sWrt) (bbl/min) Q (end) (bbl/min) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 6 2 6 305.0 1,000.0 No No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cemented 2nd stage 7 5/8" csg as follows: Pumped 5 bbls CW-100 - Test lines to 3500 psi - Pumped 15 bbls CW-100 @ 3.1 bbis/min @ 480 psi - Mixed ~ pumped 30 bbls 10.5 ppg MudPush @ 3 bbls/min @ 460 psi -- Mixed & pumped 60.3 bbls 15.8. ppg Tail slurry (class G w/ additives) @ 4 bbis/min @ 550 psi - Dropped Dart w/ 20 bbls water f/Dowell - switched to rig pumps 8~ displaced cmt w/ 65.5 bbls 10.3 ppg LSND mud @ 3.5 bbls./min @ 500 psi Bumped dart w/ 900 psi - CIP @ 15:10 hrs. Attempted to blow out ball. Did not go - Full returns throughout job - Closed port collar. Fluitl Type Fluid Description Estimated Top (ftKB) Est Btrn (ftKB) Amount (sacks) Class Vo-ume Pumpetl (bbl) Intermediate Cement 7,300.0 8,388.0 287 G 60.3 Yield (ft /sack) Mix H20 Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic ~scosity (cp) Thickening Time (hrs) CmprStr 1(psi) 1.17 5.10 Page 1H • i Daily Drilling Report CD2-72 Security Level: Development Report Number: 19 ;ig: DOYON 19 Report Date: 5/17/2007 AFE 7ype ?. .. P1elworktlD #;: Totat AFE+Sup 10170504 11,442,548.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD2-72 Development ALPINE 13.40 19.0 0.00 16,707.0 16,707.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 4,722.88 642,413.47 729,705.88 4,665,618.47 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (daysj Projected Job End Date 4/29/2007 5/4/2007 35.58 Last Casing String Next Casi~g OD (in) Neut Casing Set Depth (ftKB) Intermediate, 16,692.6ftKB Ops and Depth @ Morning Report 24hr Forecast Attempted casing test. No Good. Cement second stage. Lay down 5" DP from derrick. Last 24hr Summary Ran and cemented 1st stage of 7 5/8" casing. WOC. Changed rams and tested. Made up Tam running tool and RIH picking up 4" DP. General Remarks Weather Head Count 20 W@ 5 mph 47A i Larry Hill, Rig Supervisor I Scott Lapiene, Rig Supervisor Rig Supervisor Rig Supervisor 00:00 00:15 0.25 INTRM1 CASING RNCS P 16,654.0 16,693.0 Made up landing jt and landed casing @ 16,693'. 00:15 00:45 0.50 INTRM1 CEMENT RURD P 16,693.0 16,693.0 Rigged up cement head and lines. 00:45 03:15 2.50 INTRM1 CEMENT CIRC P 16,693.0 16,693.0 Broke circulation. Staged pumps up to 7 BPM 580 PSI. Up wt 475 K down 165 K. Circulated 10.3 PPG in and out. 03:15 06:00 2.75 INTRM1 CEMENT DISP P 16,693.0 0,0 PJSM on cementing - Cemented 1st stage 7 5/8" csg as follows: Pumped 5 bbls CW-100 - Test lines to 3700 psi - Pumped 15 bbls CW-100 @ 3bbls/min @ 180 psi - Mixed & pumped 40 bbls 10.5 ppg MudPush (Problem getting MP up to weight) @ 3 bbls/min @ 260 psi - Dropped btm plug - Mixed & pumped 61.1 bbls 15.8. ppg Tail slurry (class G w/ additives) @ 4.5 bbls/min @ 350 psi - Dropped top plug w/ 20 bbls water f/Dowell - switched to rig pumps & displaced cmt w/ 744.3 bbls 10.3 ppg LSND mud @ 7 bbls./min @ 500 psi for first 720 bbls slowed pumps to 4 bbls/min @ 400 psi for last 24.3 bbls - Bumped plug w! 900 psi - CIP @ 05:52 hrs. Checked floats Did not hold - Full returns throughoutjob - Reciprocated pipe for first 720 bbls of displacement - landed pipe when pumps were slowed to 4 bbls/min. 06:00 06:30 0.50 INTRM1 CASING DHEQ P 0.0 0.0 Attempted casing test pressure bled off to 200 psi. Closed rams after plug bump due to flow out the back side. Put 200 psi on casing annulus had 110 psi. Liner ~ Equipment 11:00 12:00 1.00 INTRM1 RIGMNT SVRG P 0.0 0.0 Rig service and dressed Iron roughneck for 4". I Latest BOP Test Data I Page 1/2 Report Printed: 4/18/2008I ~ • Security Level: Development Daily Drilling Report CD2-72 Report Number: 19 tig: DOYON 19 Report Date: 5/17/2007 Time ~ Lo ~s Siatt El~d DuG ~ ~ '~ Time : ~' PePf#~ Start= Depth End - .,; ~ ~ S T~rt~B Time - {hr~) Ph2s2 '~ Qp 'Lnde'~~ , C~p$ub-Cade ~'~ P-~-~ ' :!, Trbl Cod~ Trb1 Class. ~ - ~ftK6} _ ~ftKB~ ', ' _ Oppa~ion '~~ 12:00 13:00 1.00 INTRM1 CEMENT RURD P 0.0 0.0 Laid down cement head and landing joint. Pulled wear bushing. 13:00 14:15 1.25 INTRM1 CASING DHEQ P 0.0 0.0 Set and tested pack off to 5000 psi. 14:15 15:45 1.50 INTRM1 CASING NUND P 0.0 0.0 Set test plug. Changed top rams to VBR and tested. 15:45 16:45 1.00 INTRM1 DRILL PULD P 0.0 0.0 Pulled test plug and set wear bushing. 16:45 18;30 1.75 INTRM1 CEMENT PULD P 0.0 35.0 Made up Baker plug dropping head and laid down. Made up Tam running tool. 18:30 00:00 5.50 INTRM1 CEMENT TRIP P 35.0 3,500.0 RIH with running tool picking up 110 jts 4" DP from pipe shed. Mud Check Data ~ ~. ~ - ~ NPCa k G eF{10s} 'Get {~Om) ~ Gel(3 6mj' , HT NPFUi ~ De.nsity~Tamp Sc~ids CoR ; Tqpe;; ~epth(ftK8} G~ns{lbt gaiy', Ut~~slr,~tj'~, PV CaIc(cp)':; ~(1bH~00 Ef'j (I bry1~tlii~} {tbf1 100fi~~'~, , ~Ibf110 Dft~ M~3T;j lblk+bl) fm1 ./3Qmin) ~ Py ~, (°Fj 1%) -:,' LSND 16,707.0 10 .20 37 10.0 18. 000 10A 12.0 13 .000 25.0 6.4 9.5 80A 5.3 Diesel 70.0 CD2-404 From CD2-72 Water ~ 150.0 CD2-404 From CD2-72 Water Based Mud 860.0 CD2-404 From CD2-72 Wellbores Wellbore Name Welibore API/UWI CD2-72 501032054600 ' Saction = Size {in) ;, Act Tcap (ftK6) Act BVr1 jlIK6) : Start ~aYe , End Da#e : COND1 16 OA 114.0 4/16/2007 4/17/2007 SURFAC 13 1/2 114.0 3,328.0 5!4/2007 5/6/2007 INTRM1 9 7/8 3,328.0 16,707.0 5/8/2007 5/13/2007 PROD1 63/4 16,707.0 21,089.0 5/23/2007 5/28/2007 Cement' Intermediate Casin Cement - Started 5/17/2007 Type Wellbore Cemented String Cement Evaluation Results casing CD2-72 Intermediate, 16,692.6ftKB Stg No. Description Top (ftKB) Bottom (ftK6) Q(end) (bbl/... P(final) (psi) 1 Intermediate Casing Cement 15,660.0 16,707.0 4 400.0 Fluid Iass Amotfrrt (sacks} U(bbtl ; DensrtY (EWyal} , Yield {ft'/sack) Esf Tap ~ftK6} sEst Btrn (ftKB} Intermediate Cement G 287 61.0 15.80 1.17 15,660A 16,693A Stg No. Description Top (ftK6) Bottom (ftKB) Q(end) (bbl/... P(final) (psi) 2 Port Collar 7,300.0 8,388.0 2 305.0 f~uid Gtazs . i Atnourat (s&cks} U(bbi) Det~sit!' (tblgaE) ; Y~eld (ft'ISackj Es~ TPp {ftKB}. : ESt Btm (tfKB} Intermediate Cement G 287 60.3 1.17 7,300.0 8,388A Page 2/2 Report Printed: 4/18/2008 PRESSURE lNTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD2-72 Rig: Doyon 19 Date: ~~~ 912Q~~ Volume Input Pump Rate: Drilling Supervisor: Lutrick/ Hill / Lapiene Pump used: Cement Unit ~ garrels ~ ~ Bbls/Strk ~ ~1.$Q Bbl/min ~ T f T t P i d ype o es : Annulus Leak Off Test for Disposal Adequacy ~ ump ng own annu~us. ~ asing Tes1 ressure In tegrity Test Hole Size: 9-~/s" ~ Casin Shoe Depth Hole Depth Pumping Shut-in Pumping Shut- in RKB-CHF: 34.2 Ft 3318.0 Ft-MD 2394.0 Ft-TVD 6806.Q Ft-MD 3685.Q Ft-TVD Bbls psi Min psi Bbls psi Min psi Casinu Size and Description: 9-5/s~~ 40#/Ft L-80 BTC ~ 0 Q 100 0.00 251 Chan es for Annular Ade uac Tes Pressure Int e rit Tes1 1 0.5 201 0.25 201 Enter outer casing shoe test results in comments Mud Weight: 10.2 ppg 2 1 220 0.50 195 Casing description references outei casing string Inner casing OD 7.6 In. 3 1.5 227 1.00 189 Hole Size is that drilled below outer casing. 4 2 234 1.50 185 Use estimated TOC for Hole Depth 5 2.5 238 2.00 184 Enter inner casing OD at right. Desired PIT EMW: 15.0 ppg 6 3 242 2.50 180 Estimates for Test: 598 psi 0.4 bbls 7 3.5 245 3.00 178 ~ ~ 8 4 249 3.50 176 EMW = Leak-off Pressure + Mud Weight = 25$ P~T 15 Second 9 4.5 253 4:00 175 + 10.2 0.052 x TVD 0.052 x 2394 ~! Shut-in Pressure, psi 10 5 253 4.50 175 EMW at 3318 Ft-MD (2394 Ft-TVD) = 12.3 ~~ 201 15 5.5 256 5.00 175 soo 20 8 r 6 25 5.50 173 I 25 6.00 172 30 6.50 172 7.00 171 7.50 171 ~ ~,~ e ~ 8.00 17Q W 8.50 171 ~ ~ ~ 9.00 17Q cn ~ 9.50 17p ' ' 10.00 169 ~ a \... ~ o -~ - ~ ~ + F--~ ~ ~- ~ ~ ~ i 0 1 2 4 5 6 7 0 5 10 15 20 25 30 Barrels Shut-In time, Minutes Volume ~~CASING TEST f-LEAK-OFF TEST O PIT Point PU11'1 ed fs: 10 3/4" casing shoe PIT = 16.2 ppc Volume Volume volume Bled Back Pumped Bled Back Summary ~ LJ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD2-72, ~ ~- ~~~~~~~~ ~ u~ p~ ,, The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention o£ Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG fortnatted CD Rom with verification listing. API#: 50-103-20546-00. ~- LJ July 17, 2007 AK-MW-5030483 ,;,,4 ,~ ~ ~ ~0~7 -~=~~~'~s? ~ G~~ ~,t~w. C3m~nissian ~~ ~~~r~r~e ~~~--~s~ ~ t53S ~( ~ ~ • ~- Cor~t~C~Ph ~ I I t p5 J u ly 25, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for CD2-72 (APD 207-057) Dear Commissioner: ~~~~~~~~~ ~~~. 2 ~ z~a~ ~~aa~~ ~~P ~ ~~~ ~s~~~. ~;~r~~issio~ ~~; ~ ~~v~~~,; ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Alpine well CD2-72. 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 ~ G. C. Alvord Alpine Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 GCA/skad n ~~°~~V~u ~ STATE OF ALASKA ~ ~ ~ ~ ~ ~ ~~07 ALASKA OIL AND GAS CONSERVATION COMMISSION 4 ~ ,F_ ~°o~s. ~ommiSSic~~ WELL COMPLETION OR RECOMPLETION REPORT°~'~~L~~ ~ ef ...~~~ 1a. Well Status: Oil ~ Gas Plugged Abandoned Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: Development Q Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: June 2, 2007 "' 12. Permit to Drill Number: 207-057 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: May 4, 2007 '` 13. API Number: 50-103-20546-00 4a. Location of Well (Governmental Section): Surface: 2208' FNL, 1984' FEL, Sec. 2, T11 N, R4E, UM 7. Date TD Reached: May 28, 2007 ° 14. Well Name and Number: CD2-72 ~ Top of Productive Horizon: 1464' FNL, 931' FWL, Sec. 33, T12N, R4E, UM 8. KB (ft above MSL): 50' AMSL Ground (ft MSL): 53.9' MSL ' 15. Field/Pool(s): Colville River Field Total Depth: 2187' FSL, 1231' FEL, Sec. 29, T12N, R4E, UM 9. Plug Back Depth (MD + TVD): 21089' MD / 7242' ND Alpine Oil Pool / 4b. Location of Well (State Base Plane Coordinates): Surface: x- 371250 ' y- 5974157 - Zone- 4 10. Total Depth (MD + ND): ~ 21089' MD / 7242' ND ' 16. Property Designation: r aDL 380075, 3s72o7, 3s72~2, ASRCNPR~y T~I: x- 358426 y- 5980413 Zone- 4 Total Depth: x- 356323 ~ - 5984104 r Zone- 4 1 ~. SSSV Depth (MD + TVD): SSSV @ 2271' MD / 1980' ND 17. Land Use Permit: 380075 18. Directional Survey: Yes ^~ No ~ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (ND): 1250' ND 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/ Res 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD pULLED 16" 65# H-40 37' 114' 37' 114' 24" pre-installed 10.75" 45.5# L-80 37' 3318' 37' 2394' 13.5" 5~ a sx ASLite, 319 sx Class G 7.625" 29.7# L-80 37' 16693' 37' 7268' 9.875" 2s5 sx CI G, 2s7 sx CI G 4.5" 12.6# L-80 16439' 20950' 7228' 7250' 6.75" pertorated and blank liner 23. Open to production or injection? Yes ~ No If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET F 4.5" x 3.5" 116' x 16427' 15912' alternating blank liner and perforated pup joint from 16790'-20950' MD ' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 26. PRODUCTION TEST Date First Production June 11, 2007 Method of Operation (Flowing, gas lift, etc.) Gas Lift Oil Date of Test 6/17/2007 Hours Tested 3 hours Production for Test Period --> OIL-BBL 815 GAS-MCF 590 WATER-BBL 14 CHOKE SIZE 75 Bean GASOIL RATIO 988 Flow Tubing press. 471 psi Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL 6111 ~ GAS-MCF 6039 WATER-BBL 108 OIL GRAVITY -API (corr) not available 27. CORE DATA Conventional Core(s) Acquired? Yes No Q Sidewall Cores Acquired? Yes No ~ If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. ~COMPLETION NONE ' ~ ~. tlAT2 Q~ ~ ~ a ~_...n~~».}^,„_,~ f ~1 Form 10-407 Revised 2l2007 CONTINUED ON REVERSE SIDE ~~ ~~~~ ~ ~ ~oor ~~~~ ~ ~ p -~ ~ ~l ~ ~ 7 ~ `~ ~ ~ 28. GEOLOGIC MARKERS (List ail formations and markers encountered): 29. FORMATION TESTS NAME MD ND Well tested? Yes ~/ No If yes, list intervals and formations tested, PerrrlBfrOSt - Top surface surface briefly summarizing test res~lts. Attach separate sheets to this form, if PerrnafrOSt - BOttom 1284' , 1250' needed, and submit detailed test information per 20 AAC 25.071. ~ C-30 3401' 2425' C-20 4352' 2773' K-3 7201' 3833' K-2 7815' 4058' Kuparuk C g398' 4644' Alb 97 10616' 5098' H~ 15553' 6931' K-1 16067' 7122' Kuparuk D 16188' 7164' Miluveach 16510' 7243' Alpine 16755' 7276' N/A Formation at total depth: Alpine 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certity that the foregoing is true and correct to the best of my knowledge. ContaCt: Vefn Johnson @ 265-6081 Printed ivame Chi Alvord ~,r Titie: WNS Drillina Team Lead , _ ZS~n~ Signature ~ ~ •--Q Phone ZG~ _ `c~, -~ ~ Date INSTRUCTIONS Sharon Allsup-Drake General: This form is designed for submitting a complete and correct weil completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 weli sundry report when the downhole well design is changed. 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 and Ground level elevations in feet above mean sea level. 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: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. 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, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 ~ ~ Halliburton Company Survey Report Ca~mpany ~ontt~UF'hi~psAi~sl~8 ~~G. : , ~atie: 611512fl(~7 ~_ . Time 1252~ 1A ,. w. ~ `~ Pa~e: 1 F~id, ~ = 'Gn4tiill~ Riuer~ tin~ ~ , ~~, ~ '~~ ~, ~ Co~-rdina~e~l~t~) R~~en~: ~', Well: Ct32 ~~; 'Fru~ North '~~ ~~ ~ lSite: ` Alpirte'~~~R?;,. ''~: ~'e~tfcal {'I'V~~Ret'erenee: ~ .~'~ G~2 7~~ 5d~.3 : ~~ ''~ Weil: '. C~Z-'P2 Section (Y~~te~et~uCe ;' .1NBtf (t~_kOhi,(i.4ftE,303.U€~AZt} ~fi'ellpat6s CQ~-72 ~urt~ey ~sksiation 1~Iet6od: " Miriitnum Curvatufc;. ' ll6: ~CaCle Field: Colville River Unit L ~ North Slope Alaska ~ United States i Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate S~stem: Well Centre ~ : Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: CD2-72 Slot Name: Alpine West Well Position: +N/-S -491.73 ft Northing: 59741 57.53 ft Latitude: 70 20 15.389 N +E/-W -437.78 ft Easting : 371250.15 ft Loogitude: 151 2 40.869 W Position Uncertainty: 0.00 ft ~ ~ Wellpath: CD2-72 Drilled From: Well Ref. Point 501032054600 Tie-on Depth: 36.73 ft Current Datum: CD2-72: Height 54.33 ft" Above System Datum: Mean Sea Level Magnetic Data: 5/2/2007 Declination: 22.79 deg Field Strength: 57563 nT Mag Dip Angle: 80.70 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg ~ 36J3 0.00 0.00 303.00 ~ ~ ~ Survey Program for Definitive Wellpath Date: 4/3/2007 Validated: No Version: 1 Actual From To Survey T oolcode Tool Name ft ft 80.00 350.00 CD2-72 gyro (80.00-350.00) C B-GYRO-SS I Camera based gyro single shot ~ 434.22 21048.58 CD2-72 (434.22-21048.58) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C Survey ~' - ~ ~ I' M1?,; In~i A~im " ~ 'I'ND Sys'I"4~D ~T/~' ElW - A~attN ~ MapE '~~ ft' deg deg ' ft ft ' ? ft f~ 'fk ft 36.73 0.00 0.00 36.73 -17.60 0.00 0.00 5974157.53 371250.15 ' TIE LINE 80.00 0.25 91.00 80.00 25.67 0.00 0.09 5974157.53 371250.24 CB-GYRO-SS 170.00 0.48 94.00 170.00 115.67 -0.03 0.67 5974157.49 371250.82 CB-GYRO-SS 260.00 0.65 98.00 259.99 205.66 -0.13 1.55 5974157.37 371251.70 CB-GYRO-SS ~ 350.00 1.15 352.00 349.99 295.66 0.69 1.93 5974158.19 371252.09 CB-GYRO-SS ; 434.22 2.74 347.02 434.16 379.83 3.49 1.36 5974161.00 371251.57 MWD+IFR-AK-CAZ-SC 475.77 2.88 344.33 475.66 421.33 5.47 0.85 5974162.98 371251.10 MWD+IFR-AK-CAZ-SC 569.60 4.66 329.35 569.28 514.95 11.02 -1.73 5974168.57 371248.61 MWD+IFR-AK-CAZ-SC 662.19 6.94 327.39 661.39 607.06 18.96 -6.66 5974176.60 371243.82 MWD+IFR-AK-CAZ-SC 751.59 8.57 329.38 749.97 695.64 29.25 -12.96 5974186.99 371237.69 MWD+IFR-AK-CAZ-SC 840.36 10.68 331.50 837.49 783.16 42.17 -20.26 5974200.04 371230.62 MWD+IFR-AK-CAZ-SC i 936.08 15.38 332.92 930.72 876.39 61.28 -30.27 5974219.31 371220.93 MWD+IFR-AK-CAZ-SC i ~ 1031.16 22.14 330.83 1020.69 966.36 88.18 -44.76 5974246.46 371206.91 MWD+IFR-AK-CAZ-SC ~ ~ 1126.35 24.97 324.61 1107.96 1053.63 120.23 -65.15 5974278.85 371187.08 MWD+IFR-AK-CAZ-SC 1221.25 25.36 318.22 1193.87 1139.54 151.72 -90.30 5974310.77 371162.48 MWD+IFR-AK-CAZ-SC 1316.88 26.95 316.19 1279.70 1225.37 182.63 -118.94 5974342.17 371134.37 MWD+IFR-AK-CAZ-SC 1411.98 29.98 312.32 1363.30 1308.97 214.19 -151.44 5974374.27 371102.42 MWD+IFR-AK-CAZ-SC ; 1506.96 33.28 310.76 1444.16 1389.83 247.19 -188.74 5974407.91 371065.70 MWD+IFR-AK-CAZ-SC ~ 1602.86 36.45 307.81 1522.85 1468.52 281.85 -231.19 5974443.28 371023.85 MWD+IFR-AK-CAZ-SC i 1697.96 38.16 303.58 1598.50 1544.17 315.43 -278.00 5974477.66 370977.63 MWD+IFR-AK-CAZ-SC ~i ; 1793.31 41.08 300.86 1671.94 1617.61 347.80 -329.44 5974510.90 370926.75 MWD+IFR-AK-CAZ-SC i 1888.84 44.32 300.45 1742.14 1687.81 380.82 -385.17 5974544.87 370871.61 MWD+IFR-AK-CAZ-SC i 1983.94 47.74 301.54 1808.16 1753.83 416.07 -443.82 5974581.13 370813.57 MWD+IFR-AK-CAZ-SC ~ 2078.92 51.29 301.45 1869.82 1815.49 453.81 -505.41 5974619.91 370752.65 MWD+IFR-AK-CAZ-SC 2173.50 54.40 299.44 1926.94 1872.61 491.97 -570.40 5974659.18 370688.33 MWD+IFR-AK-CAZ-SC 2268.51 58.13 297.46 1979.69 1925.36 529.58 -639.86 5974697.97 370619.53 MWD+IFR-AK-CAZ-SC 2363.28 61.28 295.86 2027.50 1973.17 566.27 712.99 - 5974735.91 370547.05 + MWD IFR-AK-CAZ-SC 2458.51 64.47 294.37 2070.91 2016.58 602.22 789.72 - 5974773.17 370470.95 MWD+IFR-AK-CAZ-SC ! 2553.40 67.43 293.94 2109.58 2055.25 637.67 -868.78 5974809.97 370392.51 MWD+IFR-AK-CAZ-SC ~ ~ Halliburton Company Survey Report ~~,Ca~npanx: CQnctcoPhillipsAi~st~a fi'~~.= ~at~ ~f15/~Ut~7': r~~~~ T~ ~ 1~~:26:14 ' Pagec '~, Z 'FY~id: , Cohrille,Rtrt~i Urrit , . ~Go-nrdinat~iE}R~fei~e~ce: -; : SiVelt: CD2 72 -;Tru~ North' SSte: Alpi{te;~C}~ ~ " ~ ~ : ~ 'Vert~~at Y~}R+~fieret~ce CF2-72.543 ~ - % We1~: ~ ~C1~-'~2 ~~ ~ - ~ "~ ~ ~ ~; . ~ ~ 5e~tiun (~'S) Refereuee ; . ` ° Weti {O.OON,~i QQ~,303 f~}A~~ ~ ~ ~ a VNei~path: CB~^-7~ Survey r~akulahi-ri 1vlechod. ' IVliriimur~t ~u~fure . ~G. C?i'act~ Survey 14ID Iue~ :. A2im 'T~i) SysTYD 1'tiT15 ' EIW Mapl~F Msp~ "T~I ft d2t~ d@g ' ft ft ' ' ff , ft : ; . 'ft' ° ` ~t: 2647 .86 68.98 294. 16 2144. 65 2090. 32 673. 42 -948. 87 5974847 .08 370313 .06 MWD+IFR-AK-CAZ-SC 2743 .09 68.94 294. 30 2'178. 84 2124. 51 709. 89 -1029. 92 5974884 .94 370232 .65 MWD+IFR-AK-CAZ-SC ~ 2839 .07 68.89 292. 49 2213. 37 2159. 04 745. 45 -1112. 11 5974921. 90 370151. 09 MWD+IFR-AK-CAZ-SC I 2933 .64 67.46 292. 59 2248. 53 2194. 20 779. 10 -1193. 19 5974956. 94 370070. 60 MWD+IFR-AK-CAZ-SC ~ 3028 .89 67.69 292. 89 2284. 86 2230. 53 813. 14 -1274. 40 5974992. 36 369990. 00 MWD+IFR-AK-CAZ-SC 3124 .04 67.83 292. 86 2320. 88 2266. 55 847. 37 -1355. 54 5975027. 98 369909. 47 MWD+IFR-AK-CAZ-SC 3219 .25 67.99 293. 34 2356. 68 2302. 35 881. 98 -1436. 69 5975063. 98 369828 .93 MWD+IFR-AK-CAZ-SC ~ 3279 .67 67.92 293. 00 2379. 36 2325. 03 904. 02 -1488. 17 5975086. 89 369777 .84 MWD+IFR-AK-CAZ-SC ~ 3367 .72 68.27 294. 48 2412. 21 2357. 88 936. 91 -1562. 95 5975121 .06 369703 .64 MWD+IFR-AK-CAZ-SC 3462 .61 67.67 294. 57 2447. 80 2393. 47 973. 42 -1642. 98 5975158 .93 369624 .26 MWD+IFR-AK-CAZ-SC 3557 .78 68.53 294. 71 2483. 30 2428. 97 1010. 23 -1723. 24 5975197 .12 369544 .65 MWD+IFR-AK-CAZ-SC ~ 3652 .70 68.91 295. 26 2517. 75 2463. 42 1047. 59 -1803. 41 5975235 .85 369465 .14 MWD+IFR-AK-CAZ-SC 3746 .75 68.76 294. 67 2551. 71 2497. 38 1084. 61 -1882. 92 5975274 .22 369386 .28 MWD+IFR-AK-CAZ-SC i 3841 .18 68.77 294. 80 2585. 91 2531. 58 1121. 44 -1962. 86 5975312 .41 369306 .99 MWD+IFR-AK-CAZ-SC 3938 .52 68.90 294. 66 2621. 05 2566. 72 1159. 41 -2045. 31 5975351. 79 369225 .21 MWD+IFR-AK-CAZ-SC ~ 4033 .90 68.79 294. 75 2655. 47 2601. 14 1196. 59 -2126. 12 5975390. 35 369145 .06 MWD+IFR-AK-CAZ-SC I 4129 .32 68.51 293. 93 2690. 21 2635. 88 1233. 22 -2207. 09 5975428. 36 369064 .73 i MWD+IFR-AK-CAZ-SC 4224 .42 67.85 293. 80 2725. 56 2671. 23 1268. 94 -2287. 83 5975465 .46 368984 .63 MWD+IFR-AK-CAZ-SC 4319 .70 68.03 294. 33 2761. 35 2707. 02 1304. 95 -2368. 46 5975502 .84 368904 .64 MWD+IFR-AK-CAZ-SC 4414 .97 68.02 294. 58 2797. 00 2742. 67 1341. 52 -2448. 88 5975540 .79 368824 .86 MWD+IFR-AK-CAZ-SC 4509 .91 67.84 293. 59 2832. 67 2778. 34 1377. 43 -2529. 20 5975578 .06 368745 .17 MWD+IFR-AK-CAZ-SC I 4605 .31 67.90 294. 04 2868. 61 2814. 28 1413. 11 -2610. 05 5975615 .13 368664 .96 MWD+IFR-AK-CAZ-SC ; 4700 .22 67.72 293. 50 2904. 45 2850. 12 1448. 53 -2690. 48 5975651 .92 368585 .16 MWD+IFR-AK-CAZ-SC ~ 4795 .24 67.93 293. 04 2940. 32 2885. 99 1483. 29 -2771. 31 5975688 .06 368504 .94 MWD+IFR-AK-CAZ-SC ; 4890 .60 67.93 292. 98 2976. 15 2921. 82 1517. 84 -2852. 65 5975724 .00 368424 .21 MWD+IFR-AK-CAZ-SC i 4985 .71 68.20 292. 33 3011. 68 2957. 35 1551. 82 -2934. 07 5975759 .37 368343 .39 MWD+IFR-AK-CAZ-SC 5080 .76 68.33 293. 37 3046. 88 2992. 55 1586. 11 -3015. 43 5975795 .04 368262 .64 MWD+IFR-AK-CAZ-SC 5175 .86 68.24 293. 35 3082. 06 3027. 73 1621. 14 -3096. 54 5975831 .46 368182 .15 MWD+IFR-AK-CAZ-SC 5270 .63 68.24 293. 69 3117. 20 3062. 87 1656. 26 -3177. 24 5975867 .96 368102 .07 MWD+IFR-AK-CAZ-SC 5363 .91 68.06 293. 73 3151. 91 3097. 58 1691. 08 -3256. 52 5975904 .13 368023 .41 MWD+IFR-AK-CAZ-SC 5460 .99 68.32 294. 79 3187. 98 3133. 65 1728. 11 -3338. 69 5975942 .56 367941 .90 MWD+IFR-AK-CAZ-SC 5556 .61 68.31 295. 37 3223. 31 3168. 98 1765. 77 -3419. 16 5975981 .60 367862 .09 MWD+IFR-AK-CAZ-SC ~ ~ 5651 .30 68.56 295. 38 3258. 12 3203. 79 1803. 51 -3498. 73 5976020 .70 367783 .19 MWD+IFR-AK-CAZ-SC ' ~ 5747 .17 68.57 296. 15 3293. 15 3238. 82 1842. 30 -3579. 09 5976060 .86 367703 .50 MWD+IFR-AK-CAZ-SC ~ i 5842 .19 68.16 296. 00 3328. 19 3273. 86 1881. 12 -3658. 43 5976101 .03 367624 .85 MWD+IFR-AK-CAZ-SC I 5937 .84 68.36 295. 81 3363. 62 3309. 29 1919. 94 -3738. 35 5976141 .21 367545 .62 MWD+IFR-AK-CAZ-SC i I 6032 .76 68.64 295. 51 3398. 40 3344. 07 1958. 18 -3817. 95 5976180 .81 367466 .69 MWD+IFR-AK-CAZ-SC 6127 .68 68.51 294. 96 3433. 08 3378. 75 1995. 85 -3897. 88 5976219 .85 367387 .43 MWD+IFR-AK-CAZ-SC 6222 .74 68.02 292. 90 3468. 28 3413. 95 2031. 67 -3978. 59 5976257 .04 367307 .35 MWD+IFR-AK-CAZ-SC ~ 6317 .90 68.10 293. 20 3503. &4 3449. 51 2066. 23 -4059. 81 5976292 .99 367226 .75 MWD+IFR-AK-CAZ-SC ( 6413 .11 68.10 292. 37 3539. 35 3485. 02 2100. 44 -4141. 25 5976328 .59 367145 .91 MWD+IFR-AK-CAZ-SC ~ 6507 .92 68.26 292. 87 3574. 59 3520. 26 2134. 29 -4222. 50 5976363 .83 367065 .26 MWD+IFR-AK-CAZ-SC I ' 6602 .87 68.08 292. 59 3609. 90 3555. 57 2168. 35 -4303. 79 5976399 .27 366984 .57 MWD+IFR-AK-CAZ-SC 6697 .53 68.39 293. 07 3645. 00 3590. 67 2202. 46 -4384. 82 5976434 .77 366904 .15 MWD+IFR-AK-CAZ-SC 6792 .65 68.29 292. 50 3680. 11 3625. 78 2236. 70 -4466. 32 5976470 .40 366823 .25 MWD+IFR-AK-CAZ-SC 6887 .90 68.20 292. 81 3715. 41 3661. 08 2270. 77 -4547. 96 5976505 .86 366742 .21 MWD+IFR-AK-CAZ-SC I 6983 .26 68.19 293. 40 3750. 83 3696. 50 2305. 52 -4629. 40 5976542 .00 366661 .39 MWD+IFR-AK-CAZ-SC 7078 .77 67.99 293. 96 3786. 47 3732. 14 2341. 10 -4710. 55 5976578 .97 366580 .87 MWD+IFR-AK-CAZ-SC ( ~ 7174 .04 67.57 294. 94 3822. 50 3768. 17 2377. 61 -4790. 83 5976616 .84 366501 .23 MWD+IFR-AK-CAZ-SC ~ i 7269 .18 67.91 297. 46 3858. 54 3804. 21 2416. 48 -4869. 83 5976657 .06 366422 .92 MWD+IFR-AK-CAZ-SC ~ 7364 .49 68.53 298. 09 3893. 91 3839. 58 2457 72 -4948. 13 5976699 .64 366345 .34 MWD+IFR-AK-CAZ-SC I 7459 .65 68.65 297. 05 3928. 65 3874. 32 2498.73 -5026. 67 5976741 .98 366267 .53 MWD+IFR-AK-CAZ-SC ~ ~ Halliburton Company Survey Report Cont~rany: Cor~a~Phillips ~laFska-tAe i ~k1d: ~fl~U1~~2 ~IY2f Ut1t~ p ~ /Welt Ci~2-72 ~ : W~ etipath. G[32 7~ Survey ~ ~~, 14IB ~; ~nc~ . . Azim : ~'~?D ~ ~ ~~~ ~ ft r ~ ~ecJ , „ tieg ~~. ft s 1`i~l)~ -~ ~ ~ ft ~- Da~e: ~ 6/1~12~007 : 1'~ne. 1~:2614 ~ ~ P'age~ ~ 3 CO~OYf11riHE~{~[E}ItCfCI'CHCC:' {~2~~: ~~2 ~ ~Ft1~~0l~~3- °S aua (V~ ~~e~ere~e~ ce GB2-7~; 54 3 . " V~lell {~.~bN,4:t~~ 3U3 Ot1Az~~ . ~ 5ur~ey Cakulaaon Method: M{inimum Cuer~ature +" ~1b ~raGe i~T/S~ ~ E1W 1~p1~T l~spE ~ , ~~ T~I ~~~ f~ ~k '~ ~t ft ~~ 7555.15 68.64 294.44 3963.43 3909.10 2537.36 -5106.77 5976781.98 366188.11 MWD+IFR-AK-CAZ-SC 7646.09 68.64 294.47 3996.55 3942.22 2572.42 -5183.87 5976818.36 366111.63 MWD+IFR-AK-CAZ-SC 7744.63 68.69 294.90 4032.40 3978.07 2610.75 -5267.27 5976858.11 366028.91 MWD+IFR-AK-CAZ-SC 7840.06 68.44 293.89 4067.28 4012.95 2647.44 -5348.16 5976896.18 365948.66 MWD+IFR-AK-CAZ-SC 7935.13 68.57 293.73 4102.11 4047.78 2683.15 -5429.09 5976933.27 365868.36 MWD+IFR-AK-CAZ-SC 8030.11 68.44 293.44 4136.92 4082.59 2718.51 -5510.08 5976970.02 365788.00 MWD+IFR-AK-CAZ-SC 8125.20 68.39 293.07 4171.90 4117.57 2753.42 -5591.32 5977006.31 365707.38 MWD+IFR-AK-CAZ-SC ! 8221.41 67.98 292.54 4207.65 4153.32 2788.04 -5673.66 5977042.34 365625.65 MWD+IFR-AK-CAZ-SC 8315.79 68.56 292.78 4242.59 4188.26 2821.82 -5754.56 5977077.50 365545.35 MWD+IFR-AK-CAZ-SC i 8410.71 68.42 292.52 4277.40 4223.07 2855.83 -5836.06 5977112.90 365464.45 MWD+IFR-AK-CAZ-SC 8506.15 68.04 292.15 4312.79 4258.46 2889.51 -5918.05 5977147.98 365383.07 MWD+IFR-AK-CAZ-SC ~ 8601.80 68.00 292.47 4348.59 4294.26 2923.18 -6000.10 5977183.05 365301.60 MWD+IFR-AK-CAZ-SC 8697.00 67.91 292.76 4384.33 4330.00 2957.11 -6081.56 5977218.38 365220.75 MWD+IFR-AK-CAZ-SC 8792.57 67.83 291.82 4420.33 4366.00 2990.69 -6163.47 5977253.35 365139.43 MWD+IFR-AK-CAZ-SC 8887.89 68.46 292.87 4455.81 4401.48 3024.32 -6245.29 5977288.38 365058.21 MWD+IFR-AK-CAZ-SC ; 8983.15 68.27 294.91 4490.94 4436.61 3060.18 -6326.25 5977325.62 364977.88 MWD+IFR-AK-CAZ-SC 9078.47 68.46 296.04 4526.08 4471.75 3098.29 -6406.24 5977365.10 364898.57 MWD+IFR-AK-CAZ-SC ~ 9173.12 68.52 296.22 4560.79 4506.46 3137.07 -6485.30 5977405.23 364820.19 MWD+IFR-AK-CAZ-SC i 9267.52 68.41 296.20 4595.44 4541.11 3175.86 -6564.08 5977445.35 364742.09 MWD+IFR-AK-CAZ-SC I 9362.85 68.39 296.42 4630.53 4576.20 3215.14 -6643.53 5977486.00 364663.33 MWD+IFR-AK-CAZ-SC 9458.20 68.20 296.68 4665.80 4611.47 3254.74 -6722.78 5977526.94 364584.78 MWD+IFR-AK-CAZ-SC 9553.44 68.31 295.64 4701.08 4646.75 3293.74 -6802.18 5977567.30 364506.07 MWD+IFR-AK-CAZ-SC 9648.96 68.38 293.89 4736.33 4682.00 3330.93 -6882.79 5977605.86 364426.12 MWD+IFR-AK-CAZ-SC 9741.26 67.93 293.08 4770.68 4716.35 3365.07 -6961.37 5977641.34 364348.15 MWD+IFR-AK-CAZ-SC j 9839.05 67.44 292.46 4807.81 4753.48 3400.08 -7044.78 5977677.78 364265.35 MWD+IFR-AK-CAZ-SC ~ i 9934.03 67.28 292.11 4844.37 4790.04 3433.32 -7125.89 5977712.41 364184.83 MWD+IFR-AK-CAZ-SC 10029.02 67.72 292.07 4880.72 4826.39 3466.33 -7207.21 5977746.80 364104.10 MWD+IFR-AK-CAZ-SC 10123.77 68.39 292.16 4916.13 4861.80 3499.41 -7288.63 5977781.28 36402327 MWD+IFR-AK-CAZ-SC 10218.99 68.59 291.87 4951.04 4896.71 3532.62 -7370.76 5977815.89 363941.73 MWD+IFR-AK-CAZ-SC 10314.00 68.45 292.24 4985.83 4931.50 3565.82 -7452.70 5977850.48 363860.37 MWD+IFR-AK-CAZ-SC 10409.22 68.13 293.83 5021.06 4966.73 3600.43 -7534.11 5977886.49 363779.58 MWD+IFR-AK-CAZ-SC 10503.63 68.04 295.84 5056.30 5001.97 3637.22 -7613.59 5977924.63 363700.74 MWD+IFR-AK-CAZ-SC 10599.03 68.20 295.91 5091.85 5037.52 3675.85 -7693.24 5977964.62 363621.77 MWD+IFR-AK-CAZ-SC 10691.03 68.45 295.01 5125.83 5071.50 3712.60 -7770.44 5978002.69 363545.23 MWD+IFR-AK-CAZ-SC 10788.81 68.71 294.57 5161.54 5107.21 3750.77 -7853.07 5978042.27 363463.27 MWD+IFR-AK-CAZ-SC ~ 10883.88 68.26 294.77 5196.41 5142.08 3787.68 -7933.45 5978080.55 363383.55 MWD+IFR-AK-CAZ-SC 10979.31 67.64 295.11 5232.23 5177.90 3824.98 -8013.65 5978119.22 363304.00 MWD+IFR-AK-CAZ-SC ~ 11074.40 67.93 295.11 5268.18 5213.85 3862.34 -8093.36 5978157.93 363224.95 MWD+IFR-AK-CAZ-SC ~ ~ 11169.49 68.50 294.84 5303.47 5249.14 3899.62 -8173.40 5978196.58 363145.57 MWD+IFR-AK-CAZ-SC ~ 11264.55 68.54 294.36 5338.28 5283.95 3936.44 -8253.83 5978234.78 363065.79 MWD+IFR-AK-CAZ-SC 11359.91 68.57 294.03 5373.15 5318.82 3972.82 -8334.79 5978272.54 362985.47 MWD+IFR-AK-CAZ-SC 11455.22 68.72 294.48 5407.85 5353.52 4009.28 -8415.72 5978310.38 362905.18 MWD+IFR-AK-CAZ-SC 11550.11 68.64 294.12 5442.35 5388.02 4045.66 -8496.29 5978348.13 362825.26 MWD+IFR-AK-CAZ-SC 11645.67 68.44 293.90 5477.31 5422.98 4081.85 -8577.53 5978385.71 362744.66 MWD+IFR-AK-CAZ-SC 11740.68 67.77 293.87 5512.74 5458.41 4117.54 -8658.13 5978422.78 362664.69 MWD+IFR-AK-CAZ-SC 11835.99 67.33 293.61 5549.14 5494.81 4153.00 -8738.77 5978459.62 362584.68 MWD+IFR-AK-CAZ-SC ! 11930.95 67.36 293.12 5585.72 5531.39 4187.76 -8819.21 5978495.74 362504.85 MWD+IFR-AK-CAZ-SC ! 12025.87 67.59 293.11 5622.08 5567.75 4222.18 -8899.85 5978531.54 362424.82 MWD+IFR-AK-CAZ-SC ~ I 12120J4 68.05 293.18 5657.90 5603.57 425671 -8980.63 5978567.45 362344.65 MWD+IFR-AK-CAZ-SC ~ 12216.21 68.39 293.38 5693.32 5638.99 4291.75 -9062.07 5978603.88 362263.84 MWD+IFR-AK-CAZ-SC i 12311.21 68.65 293.89 5728.11 5673.78 4327.19 -9143.05 5978640.70 362183.48 MWD+IFR-AK-CAZ-SC I 12406.92 68.85 294.22 5762.79 5708.46 4363.55 -9224.51 5978678.45 362102.66 MWD+IFR-AK-CAZ-SC i 12501.87 68.57 293.96 5797.27 5742.94 4399.66 -9305.27 5978715.94 362022.54 MWD+IFR-AK-CAZ-SC ~ _ ~ ~ Halliburton Company Survey Report ~ ' ' ' " Campany, : CU nt,~GD Philli pS Alask~ [ nc. Da te: 6/'I ~f20U 7 ::;.,, Thn e f2.26:1+ ~ Pa~~: ~ Fi~eld: ' CQkvilNe Ftiwer Unit Ca~-rdinate(NE}Ref~r~nce ~..: . .We[L' C[}2-72, "Crue.trlQrth ' Siie: Alpine Cf?~ F iI Vertical ("TYD) lieference Gi~2 72': 54.3 ' E ,~'ell: ~ ~D~-72 ~et~on G'~S; ~R~f~re~ee ' 1N~p (0.04N,A.4bE 3{~~:fl~IAZi~ ~~ !":~We~mh: CD2-7~ ~urvey ~alenNatia n Mec6od: '~~ Ntinir~iuejn Curua#~~ _~ '~~ l~b: ;, O~ac[e ' Survey A ~ll Inc~ ~ Azim ~ - TV D ~ `I`VI? 9~s. 1~i tS i~Y ~ ~E1 ~ - 1Na pAi Ma pE ~ ~ ~o~( a C„~ ,,..„ !~ ~~~. . ~ .~ d .~ p : ~ ~l . . p Al ~~~. _.. _ ., . . . p ~~~. 1( q ~G ~~~.. ..." y~ ~G . . p Il ~~~. . , .: ,.'" . : I 12596. 67 68. 04 294.67 5832. 31 5777.98 4435. 93 -9385. 54 5978753. 58 361942. 91 MWD+IFR-AK-CAZ-SC 12692. 43 67. 64 295.19 5868. 43 5814.10 4473. 31 -9465. 97 5978792. 33 361863. 15 MWD+IFR-AK-CAZ-SC 12786. 90 67. 72 294.73 5904. 31 5849.98 4510. 19 -9545. 20 5978830. 56 361784. 57 MWD+IFR-AK-CAZ-SC 12882. 07 67. 52 293.82 5940. 55 5886.22 4546. 37 -9625. 42 5978868. 11 361704. 99 MWD+IFR-AK-CAZ-SC 12977. 56 68. 24 294.15 5976. 51 5922.18 4582. 33 -9706. 24 5978905. 45 361624. 80 MWD+IFR-AK-CAZ-SC 13072. 68 68. 98 294.51 6011. 20 5956.87 4618. 82 -9786. 94 5978943. 32 361544. 74 MWD+IFR-AK-CAZ-SC i 13167. 83 68. 72 294.23 6045. 53 5991.20 4655. 43 -9867. 77 5978981. 31 361464. 56 MWD+IFR-AK-CAZ-SC i 13263, 23 68 .51 294.48 6080. 31 6025.98 4692. 07 -9948. 70 5979019. 33 361384. 28 MWD+IFR-AK-CAZ-SC ~ 13358. 46 68. 05 293.92 6115. 56 6061.23 4728. 33 -10029. 39 5979056. 97 361304. 23 MWD+IFR-AK-CAZ-SC I 13453. 87 68 .11 293.70 6151. 17 6096.84 4764. 07 -10110. 37 5979094. 08 361223. 88 MWD+IFR-AK-CAZ-SC ~ 13548. 88 68 .05 294.17 6186. 64 6132.31 4799. 82 -10190. 93 5979131. 22 361143. 95 MWD+IFR-AK-CAZ-SC i 13644. 56 68 .33 293J0 6222. 19 6167.86 4835. 86 -10272. 13 5979168. 64 361063. 40 MWD+IFR-AK-CAZ-SC 13739 .67 68 .37 294.05 6257. 28 6202.95 4871. 64 -10352. 96 5979205. 80 360983. 19 MWD+IFR-AK-CAZ-SC 13835. 01 68. 32 294.62 6292. 46 6238.13 4908. 16 -10433. 70 5979243. 69 360903. 10 MWD+IFR-AK-CAZ-SC 13930. 23 68. 40 294.99 6327. 58 6273.25 4945. 29 -10514. 04 5979282. 20 360823. 41 MWD+IFR-AK-CAZ-SC 14025. 42 68. 64 295.57 6362. 43 6308.10 4983. 11 -10594. 14 5979321. 39 360743. 99 MWD+IFR-AK-CAZ-SC 14120. 77 68. 24 294.55 6397. 47 6343.14 5020. 68 -10674. 47 5979360. 32 360664. 32 MWD+IFR-AK-CAZ-SC , 14215. 63 67. 80 295.00 6432. 98 6378.65 5057. 54 -10754. 33 5979398. 55 360585. 10 MWD+IFR-AK-CAZ-SC 14310. 99 67. 47 294.65 6469. 26 6414.93 5094. 56 -10834. 37 5979436. 94 360505. 72 MWD+IFR-AK-CAZ-SC 14406. 02 67. 79 294.82 6505. 43 6451.10 5131. 33 -10914. 19 5979475. 07 360426. 55 MWD+IFR-AK-CAZ-SC i 14501. 50 67. 52 294.26 6541. 73 6487.40 5168. 01 -10994. 52 5979513. 12 360346. 87 MWD+IFR-AK-CAZ-SC I ~ 14596. 42 68 .77 292.26 6577. 07 6522.74 5202. 79 -11075. 45 5979549. 28 360266. 55 MWD+IFR-AK-CAZ-SC 14691. 66 69 .06 292.14 6611. 33 6557.00 5236. 37 -11157. 73 5979584. 26 360184. 87 MWD+IFR-AK-CAZ-SC 14786. 59 68 .56 292.62 6645. 64 6591.31 5270. 07 -11239. 57 5979619. 36 360103. 62 MWD+IFR-AK-CAZ-SC 14881. 65 68 .27 293.49 6680. 61 6626.28 5304. 68 -11320. 91 5979655. 36 360022. 90 MWD+IFR-AK-CAZ-SC 14976 :51 68 .12 293.43 6715. 85 6661.52 5339. 75 -11401. 70 5979691. 80 359942. 73 MWD+IFR-AK-CAZ-SC ~ 15071 .81 67 .99 293.43 6751. 47 6697.14 5374. 89 -11482. 81 5979728. 34 359862. 25 I MWD+IFR-AK-CAZ-SC i 15166. 67 68. 45 294.12 6786. 66 6732.33 5410. 41 -11563. 42 5978765. 23 359782. 26 MWD+IFR-AK-CAZ-SC ~ 15262. 17 68. 18 294.28 6821. 95 6767.62 5446. 78 -11644. 36 5979802. 98 359701. 96 MWD+IFR-AK-CAZ-SC 15357. 13 67. 77 294.67 6857. 56 6803.23 5483. 25 -11724. 48 5979840. 82 359622. 49 MWD+IFR-AK-CAZ-SC 15452. 28 67. 87 294.88 6893. 48 6839.15 5520. 18 -11804. 48 5979879. 11 359543. 14 MWD+IFR-AK-CAZ-SC ~ 15546. 96 68 .72 294.65 6928. 50 6874.17 5557. 03 -11884. 36 5979917. 32 359463. 91 MWD+IFR-AK-CAZ-SC i 15641. 96 68 .91 293.96 6962. 83 6908.50 5593. 48 -11965. 08 5979955. 16 359383. 83 MWD+IFR-AK-CAZ-SC ; 15737. 42 67 .24 294.08 6998. 47 6944.14 5629. 53 -12045. 97 5979992. 58 359303. 58 MWD+IFR-AK-CAZ-SC ~ 15831. 90 67 .33 294.72 7034. 96 6980.63 5665. 53 -12125. 34 5980029. 94 359224. 85 MWD+IFR-AK-CAZ-SC 15925. 03 68 .78 294.20 7069. 76 7015.43 5701. 30 -12203. 96 5980067. 04 359146. 86 MWD+IFR-AK-CAZ-SC I 16019 .28 68 .39 295.13 7104. 17 7049.84 5737. 91 -12283. 70 5980105. 02 359067. 77 MWD+IFR-AK-CAZ-SC ( 16112 .53 68 .98 295.28 7138. 07 7083.74 5774. 91 -12362. 30 5980143. 36 358989. 82 MWD+IFR-AK-CAZ-SC 16206 .80 71 .54 296.33 7169. 91 7115.58 5813. 53 -12442. 17 5980183. 35 358910. 63 MWD+IFR-AK-CAZ-SC 16299 .70 73 .49 296.26 7197. 82 7143.49 5852. 78 -12521. 61 5980223. 95 358831. 89 MWD+IFR-AK-CAZ-SC i 16393 .02 77 .12 294.65 7221. 49 7167.16 5891. 56 -12603. 10 5980264. 12 358751. 08 MWD+IFR-AK-CAZ-SC 16486. 33 80. 51 292.73 7239. 59 7185.26 5928. 33 -12686. 91 5980302. 31 358667. 92 MWD+IFR-AK-CAZ-SC 16579. 29 82 .63 292.87 7253. 21 7198.88 5963. 96 -12771. 68 5980339. 39 358583. 78 MWD+IFR-AK-CAZ-SC 16671. 80 82 .07 293.68 7265. 53 7211.20 6000. 19 -12855. 90 5980377. 06 358500. 20 MWD+IFR-AK-CAZ-SC 16727. 23 82 .83 294.48 7272. 81 7218.48 6022. 61 -12906. 07 5980400. 34 358450. 43 MWD+IFR-AK-CAZ-SC i 16823. 71 83 .46 297.43 7284. 33 7230.00 6064. 53 -12992. 19 5980443. 73 358365. 05 MWD+IFR-AK-CAZ-SC i i 16917 J8 85 .12 301.50 7293. 69 7239.36 6110. 56 -13073. 66 5980491. 15 358284. 39 MWD+IFR-AK-CAZ-SC ( 17014 .41 86 .36 305.34 7300. 87 7246.54 6163. 63 -13154. 07 5980545. 58 358204. 91 MWD+IFR-AK-CAZ-SC 17110 .16 87 .17 307.01 7306. 28 7251.95 6220. 05 -13231. 23 5980603. 32 358128. 73 MWD+IFR-AK-CAZ-SC ' ~ 17204 .05 86 .24 309.54 7311. 67 7257.34 6278. 11 -13304. 81 5980662. 63 358056. 16 MWD+IFR-AK-CAZ-SC I 17299 .13 88 .22 312.58 7316. 27 7261.94 6340. 48 -13376. 41 5980726. 21 357985. 65 MWD+IFR-AK-CAZ-SC ~~I 17394 .96 91 .80 315.37 7316. 25 7261.92 6407. 00 -13445. 36 5980793. 90 357917. 87 MWD+IFR-AK-CAZ-SC _ ~ ~ Halliburton Company Survey Report Coenpany: CoriacAPhillipS Alaska.tnG. T)ate, Bl1512Q07 Time: 12:26s14 f,'Paget .' S ~;Fjeld:-; ; CoEYi~Riverl3ni[ Gu-4rdinate(NE)Ref~r~cg: ' UVe1L C[?2-72, True I~t~rttt: ~~'8~te A~pi~ ~f~ Yc~tir.a~("I"~'D)lieferex~e: CC~2-72'~ 54 3 %= ~ , i ~v~~~ - es~~ ~~ ~~ ~vs~ ~z~r~~~; w~~~ ta.oor~,o.~~~,~r~~~~~~ ~.. Weiipath: ~C3~-`72 S~u'rvey CaIeulation MeEh+o+l: ' Ntinimum Cttivature Db: ('~f8cte ~ Survey t. _~~~ 1-~ll. ' ~n~l Azim TVD. -`~ , ~ysT1?I? 11T1fi ~lW '- ~ Ii~apN ' ~Via'~E ~~Toui - ~'~~ €t '~. ds9 ~=d8~ . :.. ft ~ ft '~~, , '~~ fk . ,:: : ft ~ ~ ~ fk , #t,, ;: , ,-;; 17486.35 91.43 316.41 7313.68 7259.35 6472.59 -13508.94 5980860.57 357855.42 MWD+IFR-AK-CAZ-SC ~ 17586.08 92.60 318.22 7310.17 7255.84 6545.85 -13576.51 5980934.97 357789.13 MWD+IFR-AK-CAZ-SC i 17681.69 92.72 322.29 7305.73 7251.40 6619.27 -13637.56 5981009.43 357729.35 MWD+IFR-AK-CAZ-SC ; 17777.16 92.85 324.75 7301.09 7246.76 6695.94 -13694.25 5981087.05 357673.99 MWD+IFR-AK-CAZ-SC ~ 17872.88 92.66 327.37 7296.49 7242.16 6775.25 -13747.63 5981167.26 357621.99 i MWD+IFR-AK-CAZ-SC ~ 17968.33 93.96 330.03 7290.98 7236.65 6856.67 -13797.13 5981249.50 357573.89 MWD+IFR-AK-CAZ-SC 18063.87 94.45 332.10 7283.97 7229.64 6940.05 -13843.22 5981333.66 357529.24 MWD+IFR-AK-CAZ-SC ~ 18154.83 94.58 334.18 7276.81 7222.48 7020.94 -13884.19 5981415.23 357489.67 MWD+IFR-AK-CAZ-SC 18254.59 94.02 335.67 7269.33 7215.00 7111.04 -13926.35 5981506.04 357449.07 MWD+IFR-AK-CAZ-SC 18350.74 90.88 334.53 7265.22 7210.89 7198.16 -13966.79 5981593.83 357410.13 MWD+IFR-AK-CAZ-SC 18446.03 90.56 333.53 7264.02 7209.69 7283.82 -14008.51 5981680.19 357369.89 MWO+IFR-AK-CAZ-SC 18541.50 88.15 331.80 7265.10 7210.77 7368.62 -14052.34 5981765.72 357327.52 MWD+IFR-AK-CAZ-SC 18636.74 89.21 335.16 7267.29 7212.96 7453.80 -14094.85 5981851.61 357286.49 MWD+IFR-AK-CAZ-SC i 18728.66 90.01 337.56 7267.92 7213.59 7538.00 -14131.71 5981936.42 357251.09 MWD+IFR-AK-CAZ-SC ~ 18826.39 89.82 338.07 7268.06 7213.73 7628.49 -14168.61 5982027.53 357215.75 ~ MWD+IFR-AK-CAZ-SC j 18921.33 90.62 337.30 7267.70 7213.37 7716.32 -14204.66 5982115.96 357181.22 MWD+IFR-AK-CAZ-SC 19016.68 91.12 337.74 7266.25 7211.92 7804.41 -14241.11 5982204.65 357146.28 MWD+IFR-AK-CAZ-SC 19111.96 91.42 336.15 7264.14 7209.81 7892.06 -14278.41 5982292.92 357110.49 MWD+IFR-AK-CAZ-SC 19206.64 91.24 334.00 7261.94 7207.61 7977.89 -14318.30 5982379.42 357072.09 MWD+IFR-AK-CAZ-SC 19298.56 89.64 334.06 7261.24 7206.91 8060.52 -14358.55 5982462.72 357033.27 MWD+IFR-AK-CAZ-SC i j 19397.83 90.19 334.88 7261.38 7207.05 8150.10 -14401.33 5982553.01 356992.03 MWD+IFR-AK-CAZ-SC ' 19493.13 89.64 336.17 7261.52 7207.19 8236.83 -14440.82 5982640.41 356954.05 MWD+IFR-AK-CAZ-SC 19588.45 89.94 337.81 7261.87 7207.54 8324.57 -14478.07 5982728.76 356918.30 MWD+IFR-AK-CAZ-SC ~ 19681.53 90.81 340.45 7261.26 7206.93 8411.53 -14511.23 5982816.27 356886.65 MWD+IFR-AK-CAZ-SC i 19778.72 90.56 338.90 7260.10 7205.77 8502.66 -14544.98 5982907.96 356854.47 I MWD+IFR-AK-CAZ-SC ~ 19872.03 90.07 335.00 7259.59 7205.26 8588.50 -14581.51 5982994.41 356819.42 MWD+IFR-AK-CAZ-SC 19969.06 87.35 332.97 7261.77 7207.44 8675.67 -14624.05 5983082.28 356778.39 MWD+~FR-AK-CAZ-SC 20064.36 89.76 335.78 7264.18 7209.85 8761.55 -14665.24 5983168.86 356738.68 MWD+~FR-AK-CAZ-SC 20159.58 91.80 336.87 7262.88 7208.55 8848.74 -14703.47 5983256.68 356701.95 MWD+IFR-AK-CAZ-SC ~ 20254.09 92.78 337.22 7259.11 7204.78 8935.70 -14740.30 5983344.25 356666.63 MWD+IFR-AK-CAZ-SC 20346.54 90.01 334.14 7256.85 7202.52 9019.99 -14778.40 5983429.18 356629.99 MWD+IFR-AK-CAZ-SC 20444.52 90.25 332.56 7256.63 7202.30 9107.47 -14822.30 5983517.39 356587.60 MWD+IFR-AK-CAZ-SC 20539.96 89.64 333.05 7256.72 7202.39 9192.36 -14865.92 5983603.01 356545.45 MWD+IFR-AK-CAZ-SC 20635.22 90.25 334.60 7256.81 7202.48 9277.85 -14907.94 5983689.20 356504.90 MWD+IFR-AK-CAZ-SC i ~ 20730.92 90.25 336.74 7256.39 7202.06 9365.04 -14947.36 5983777.05 356466.98 MWD+IFR-AK-CAZ-SC 20821.63 91.24 336.57 7255.22 7200.89 9448.32 -14983.31 5983860.93 356432.48 MWD+IFR-AK-CAZ-SC 20921.52 92.41 335.36 7252.03 7197.70 9539.50 -15023.97 5983952.78 356393.39 MWD+IFR-AK-CAZ-SC ~ i 21016.93 93.46 333.54 7247.15 7192.82 9625.46 -15065.06 5984039.43 356353.79 MWD+IFR-AK-CAZ-SC ~ 21048.58 93.89 333.71 7245.12 7190.79 9653.76 -15079.09 5984067.96 356340.24 MWD+IFR-AK-CAZ-SC i i ' 21089.00 93.89 333.71 7242.38 r 7188.05 9689.91 -15096.95 5984104.42 A 356323.01 PROJECTED to TD ~ ~ Cc~nocoPhillips Time Log Summary 1tielN±ew Web Repo?7mg Well Name: CD2-72 Job Type: DRILLING ORIGINAL 04/29/2007 17:00 00:00 7.00 MIRU MOVE MOB P Move rig camp f/ CD3 to CD4 - Move ball mill & i e shed f/ CD3- to CD2 04/30/2007 00:00 15:00 15.00 MIRU MOVE DMOB P Continue rig move - Moved Sub base/derrick - pit & motor complexes f/ CD3 to CD2-72 - Spot sub over well - Mate up piU motor complexes & pipe shed. Skid floor. 15:00 17:30 2.50 SURFA DRILL OTHR P PU riser & measure for modification. Hook up service lines - Rig accepted 1600 hrs. 17:30 00:00 6.50 SURFA DRILL OTHR P Prep for rig maintenance - String High Line cable - Prep pits - Began loading i e shed w/ 5" drill i e. 05/01/2007 00:00 05:30 5.50 SURFA DRILL OTHR P Load pipe shed w/ 5" DP - Work on MP #1 - Service rig - Prep mud pits for welder 05:30 09:00 3.50 SURFA DRILL PULD P PU 5" DP f/ shed & Std back in derrick 09:00 10:30 1.50 SURFA DRILL OTHR T Work on high line 10:30 11:30 1.00 SURFA DRILL PULD P Continue PU 5" DP f/ shed 11:30 13:30 2.00 SURFA DRILL OTHR T Work on high line 13:30 15:00 1.50 SURFA DRILL RURD P NU surFace riser - Load 5" S drill pie in shed 15:00 17:30 2.50 SURFA DRILL PULD P Continue PU 5" DP f/ shed & std back in derrick 17:30 18:00 0.50 SURFA RIGMN' SVRG P Service rig 18:00 21:30 3.50 SURFA DRILL PULD P Continue PU 5" DP f/ shed & std back in derrick 21:30 22:30 1.00 SURFA RIGMN RGRP P PJSM - Install section of arctic dump line in um room 22:30 00:00 1.50 0 0 SURFA DRILL PULD P Continue PU 5" DP f/ shed & Std back in derrick 05/02/2007 00:00 09:30 9.50 0 0 SURFA DRILL PULD P Pick up and stand back 5" drill pipe - Set back 8" flex collars and 'ars 05/03/2007 08:00 10:30 2.50 0 73 SURFA DRILL PULD P MU BHA #1: Bit, Spery Drill Motor @ 1.83, NM float sub, IBS, NMXO, DM HOC, HCIM, TM HOC, UBHO - Initialize MWD - fill hole and check for leaks - PT mud line to 3500 si 02:30 03:00 0.50 73 73 SURFA DRILL SFTY P Held Pre-Spud meeting with rig team. 05/04/2007 13:30 14:30 1.00 73 114 SURFA DRILL PULD P Rig down 2" circulating hose from bha - PU and Initialize MWD tools - MU 8" drill collars - circulate down to 114' 01:00 I 10:30 I 9.50 I 114 I 709 DRILL DDRL P Spud well @ 1430 hours. Drill 13 1/2" hole w/ motor f/114' to 709' MD 708' TVD WOB 10/15 k RPM 45 GPM 495 @ 960 psi String wt. PU 110 SO 110 Rot 110 Torque on/off btm. - 5500l4000 ft/Ibs. G ro surve s 80', 170', 260' & 350' 00:00 12:00 12.00 709 1,845 SURFA DRILL DDRL P Drill 13 1/2" hole w/ motor f/709' to 1845' MD 1703' TVD WOB 20/25 k RPM 50 GPM 500/600 @ 1180/1570 psi ADT= 8.35 hrs. ART-3.25 hrs. AST-5.1 hrs. String wt. PU 130 SO 120 Rot 127 Tor ue on/off btm. - 7500/6000 ft/Ibs. 12:00 00:00 12.00 1,845 2,697 SURFA DRILL DDRL P Drill 13 1/2" hole w/ motor f/ 1845' to 2697' MD 2162' TVD ADT - 8.48 hrs. = ART - 5.28 hrs AST 3.2 hrs WOB 15/20 k RPM 50 GPM 705 @ 2230 psi String wt. PU 130 SO 117 Rot 125 Tor ue on/off btm - 8000/7000 ftllbs. 05/06/2007 00:00 12:00 12.00 2,697 3,191 SURFA DRILL DDRL P Drill 13 1/2" hole w/ motor f/ 2697' to 3191' MD 2346' TVD ADT - 8.71 hrs. = ART - 7.75 hrs AST 0.96 hrs WOB 20/30 k RPM 50 GPM 700 @ 2490 psi String wt. PU 133 SO 115 Rot 130 Tor ue on/off btm - 8500/7500 ft/Ibs. 12:00 13:30 1.50 3,191 3,328 SURFA DRILL DDRL P Drill 13 1/2" hole w/ motor f/ 3191' to 3328' MD 2397' ND ADT - 1.42 hrs WOB 20/30 k RPM 50 GPM 706 @ 2480 psi String wt. PU 133 SO 117 Rot 130 Tor ue onloff btm. - 8000/7000 ft/Ibs 13:30 14:30 1.00 3,328 3,328 SURFA DRILL CIRC P Circulate and condition mud - 750 gpm / 2530 psi / 60 rpm @ 6500 ft/Ibs Flow check well, static 14:30 18:30 4.00 3,328 3,328 SURFA DRILL WPRT P Perform wiper trip from 3328' - POOH from 3328' to 988' - 700 gpm / 2230 psi / 60 rpm - Reduced pumps to 550 gpm / 1320 psi - from 1550' to 988' Monitor well - static 18:30 19:45 125 3,328 3,328 SURFA DRILL WPRT P RIH f/ 988' to 3271' - hole in good condition - Wash down f/ 3271' to 3328' 19:45 20:45 1.00 3,328 3,328 SURFA DRILL CIRC P Circ hole clean for trip out for casing - 700 m 2450 si 20:45 00:00 3.25 3,328 893 SURFA DRILL TRIP P Blow down TD - Monitor well - Static - POOH on TT f/ 3228' to 893' - hole in qood condition & taking proper fill /' ~ ~ '~. TI1'C1@ C:. ~ `~ ~~" : ~ .~ i\~\~~ ~ ..o\. ~ .... . .a '~~. , ~; . ~ .. . ~ ::v . , , i'" a . ~t~ ~ i :~ '~. ~.ti ..r., ~.. a~` . ; ~ .:^~. ~ ~ .: , ~ : : ":~. \ ~x ~ '., ~ ~ : ~w. ~'~. . ,~ '~~. ~i'~~ . ~ ~ ~~~ll'Ct ~ ~~~\ ~~ ~~~~\~\ c, ~~. ; - v~7. ~ ~1 y ~~: _ ., ~ ..<~~ ~~~ ~ '. ~~: ~.." ~ ~ . ~~. ~ ~ ~ ~ ~ ~ • ' ~~~.r ~ \~~; 05/06/2007 893 SURFA DRILL Dropped top plug w/ 20 bbls fresh water f/ Dowell - Switched to rig pumps & displaced cement w/ 179.5 bbis 9.9 ppg mud @ 7.5 BP 0 to 837 psi slow p to 4.0 BPM (for 7 bbls of displacement) ` '' ` umped plug w/ 1200 psi - Check .~,~ C J floats OK - CIP @ 1616 hrs. - Full p`~ ~ c~- g' ' ation throughout job w/ 100 bbls ~ ~ ~ 10.7 ppg nt returns to surface - reciprocated pipe circulating & into cement job to 50 bbls o displacement - hole getting sticky - landed casin for remainder of ~ob 05/07/2007 00:00 01:00 1.00 893 73 SURFA DRILL TRIP P Flow check well, static- POOH from 893' to 73' 01:00 03:15 225 73 0 SURFA DRILL PULD P PJSM - LD UBHO, TM HOC, HCIM, DM HOC, NMXO, IBS, FS, Motor and bit - clear tools from ri floor 03:15 05:30 2.25 0 0 SURFA CASIN< RURD P Pull riser donut - Lay down drilling elevators and bails - install fill -up tool, casing bails, elavators, slips, PU sling and ton s 05:30 05:45 0.25 0 0 SURFA CASINC SFTY P Held PJSM with crew 05:45 08:45 3.00 0 1,710 SURFA CASINC RNCS P Ran 10 3/4" 45.5# L-80 BTC csg as follows: FS (Weatherford) 2 jts. FC (Halliburton) 2 jts.( first 4 connections made up w/BakerLoc - filled pipe & checked floats) 38 jts. to 1710' (42 jts. total PUW 150K SOW 115K 08:45 09:15 0.50 1,710 1,710 SURFA CASINC CIRC P CBU - ICP 3.5 bpm / 300 psi - FCP 7.0 bpm / 410 psi - PUW 140K SOW 125K 09:15 11:30 2.25 1,710 3,318 SURFA CASINC RNCS P Continue running 10 3/4"' 45.5# L-80 BTC csg from 1710' to 3277' (81 jts total) MU FMC fluted hanger and land cs w/ FS 3318' & FC 3232' 1130 12:00 0.50 3,318 3,318 SURFA CEME~ RURD P Lay down fill-up tool - blow down top drive - RU cement head and lines 12:00 14:15 2.25 3,318 3,318 SURFA CEME CIRC P Stage pumps up to 8 bpm - circulate and conditiom mud for cementing - Reciprocated pipe with full returns throughout - FCP= 8 bpm / 320 psi - PUW 190K SOW 143K - Held PJSM with Dowell and riq crew ! 05/07/2007 14:15 17:30 3.25 3,318 3,318 SURFA CEME~ DISP P Cemented 10 3/4" casing as follows: Pumped 50 bbis of 9.9 ppg mud with nut plug marker followed with 40 bbls of Biozan as pre flush w/ nut plug marker - Switch over to Dowell - Pumped 10 bbls CW 100 - tested lines to 3000 psi - pumped 10 bbis CW 100 - Dropped btm plug - Mixed & pumped 50 bbis 10.5 ppg MudPUSH II spacer @ 4.8 BPM @ 165 psi - Mixed & pumped 425 bbls 10.7 ppg Lead slurry (ASL) @ 7.0 BPM / 240 - 290 psi - Observed nut plug marker @ shakers w/ 410 bbls lead slurry pumped - (pumped down surge can 425 bbls total) Switched to tail slurry - Mixed & pumped 67 bbls 15.8 ppg lead slurry (Class G w/ 2% S1, 0.2%D46,0.3%D65) @ 3.0 BPM @ 220 psi - Dropped top plug w/ 20 bbls fresh water f/ Dowell - Switched to rig pumps & displaced cement w/ 288 bbis 9.9 ppg mud @ 82 BPM / 447 to 761 psi slowed pump to 4.2 BPM / 540 psi(for the last 7 bbls of displacement) Bumped plug to 1070 psi - Check floats OK - CIP @ 1720 hrs. - Full circulation throughout job w/ 148 bbls 10.7 ppg cement returns to surface - reciprocated pipe while cementing and first 152 bbls of mud displacement - hole getting sticky - lost 35K SOW - landed casing for remainder of'ob 17:30 48:00 0.50 3,318 3,318 SURFA CASINC DHEQ P RU and test casing to 3000 psi for 30 minutes - bleed off and blow down lines 18:00 19:00 1.00 3,318 3,318 ISURFA CEME~ RURD P RD cmt lines & cmt head - LD landing 19:00 20:30 1.50 3,318 3,318 SURFA DRILL RURD P RD surface riser - Remove starting head 20:30 21:15 0.75 3,318 3,318 SURFA DRILL OTHR P Install FMC wellhead with flow line oriented w/ surveyed scribe line on conductor - Tested to 1000 psi for 10 mins. 21:15 22:15 1.00 3,318 3,318 SURFA WELCT NUND P NU BOPE & flow line 22:15 22:45 0.50 3,318 3,318 SURFA WELCT OTHR P Install lower test plug & fill BOPE stack w/ water 22:45 00:00 1.25 3,318 3,318 SURFA WELCT BOPE P Test BOPE - Test Annular to 250 & 3500 psi - Testing pipe rams & choke manifold - choke & kill line valves to 250 & 5000 si 05/08/2007 00:00 04:00 4.00 0 0 SURFA WELCT BOPE P Complete BOPE testing - witnessed by Bob Noble (AOGCC) - pull test plug - set wear bushina - blow down lines 05/08/2007 04:00 04:30 0.50 0 0 SURFA DRILL PULD P Install drilling bails and 5" drill pipe elevators on to drive 04:30 05:15 0.75 0 0 SURFA DRILL PULD P Lay down 8" flex collars and drilling 'ars 05:15 08:15 3.00 0 176 SURFA DRILL PULD P MU BHA #2 - Bit - 7600 GeoPilot - pony collar - PWD - Stab - HCIM/RES - TM HOC - Initialize tools - MU FS - IBS - 3 nmflex collars - 08:15 09:00 0.75 176 725 SURFA DRILL TRIP P RIH with hwdp to 937' - lay down 7 ~oints of excess hwd to 725' 09:00 09:30 0.50 725 725 SURFA DRILL TRIP P Pressure test GeoSpan hoses to 3500 psi - Shallow test tools - 450 gpm / 800 si 09:30 11:00 1.50 725 3,100 SURFA DRILL TRIP P RIH with 5" drill pipe from 725' to 3100' - picked up 9 7/8" Ghost reamersa @ 760' & 1815' 11:00 12:30 1.50 3,100 3,100 SURFA RIGMN SVRG P Slip and cut drilling line - service top drive and drawworks 12:30 17:00 4.50 3,100 3,328 SURFA CEME~ COCF P Wash down from 3100' - Dril{ out wiper plugs, FC, cement and FS - clean out rathole to 3328' - 530 gpm / 1330 psi / 70 r m 17:00 17:45 0.75 3,328 3,348 SURFA DRILL DRLG P Dri11 20' of new hole from 3328' to 3348' - 700 gpm / 2180 psi / 100 rpm @ 6500 ft/Ibs 17:45 18:00 0.25 3,348 3,348 SURFA CEME ,CIRC P CBU - 700 gpm / 2180 psi / 100 rpm 18:00 18:45 0.75 3,348 3,348 SURFA CEME~ LOT P Rigged up and performed LOT to 16.2 PPG EMW. 18:45 00:00 5.25 3,348 3,955 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/ Geopilot f/ 3.348' to 3,955' MD 2,627' ND ADT - 3.10 hrs.W06 10/12 k RPM 130 GPM 705 @ 1620 psi String wt. PU 143 SO 117 Rot 130 Tor ue on/off btm - 9000/8000 ft/Ibs. 00:00 09:30 9.50 3,955 5,207 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/ Geopilot f! 3.955' to 5,207' MD 3093' ND ADT - 6.31 hrs.WOB 5/12 k RPM 130 GPM 700 @ 2180 psi String wt. PU 160 SO 120 Rot 136 Tor ue on/off btm - 11000/9500 ft/Ibs. 09:30 09:45 0.25 5,207 5,207 INTRM1 DRILL OTHR T After backreaming hole from 5,207' to 5,112, hole packed off - worked pipe and re ained circulation 09:45 10:15 0.50 5,207 5,207 INTRM1 DRILL CIRC T Staged pumps up to drilling rate - 700 gpm / 2200 psi / 130 rpm - CBU to clean annulus 10:15 12:00 1.75 5,207 5,340 ~ INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/ Geopilot f/ 5,207' to 5340' MD 3144' TVD ADT -.79 hrs.WOB 10/15 k RPM 130 GPM 700 @ 2190 psi String wt. PU 160 SO 120 Rot 136 Torque on/off btm - 11000/9500 ft/Ibs. 05/09/2007 12:00 00:00 12.00 5,340 6,697 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/ Geopilot f/ 5,340' to 6,697' MD 3,645' ND ADT - 7.27 hrs.W06 10/12 k RPM 130 GPM 700 @ 2410 psi String wt. PU 175 SO 120 Rot 140 Torque on/off btm - 12000/10,000 ft/Ibs. ECD 11 05/10/2007 00:00 12:00 12.00 6,697 7,930 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w! Geopi-ot f/ 6,697' to 7,930' MD 4,100' ND ADT - 7.54 hrs.W06 10/15 k RPM 150 / 170 GPM 700 / 725 @ 2560 / 2670 psi String wt. PU 180 SO 135 Rot 155 Torque on/off btm - 13500/12,000 ft/Ibs. ECD 10.66 12:00 00:00 12.00 7,930 9,203 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/ Geopilot f/ 7,930' to 9,203' MD 4,572' TVD ADT - 7.50 hrs.W06 10/15 k RPM 150 / 170 GPM 730 @ 2340 psi String wt. PU 235 SO 130 Rot 165 Torque on/off btm - 17,000l16,000 ft/Ibs. ECD 10.61 05/11/2007 00:00 12:00 12.00 9,203 10,730 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/ Geopilot f/ 9,203' to 10,730' MD 5,139' ND ADT - 8.09 hrs.W06 10/15 k RPM 150 / 170 GPM 730 @ 2700 psi String wt. PU 245 SO 135 Rot 175 Torque on/off btm - 17,000l15,500 ft/Ibs. ECD 10.7 12:00 00:00 12.00 10,730 92,004 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/ Geopilot f/ 10,730' to 12,004' MD 5,614' ND ADT - 8.14 hrs.W06 10/15 k RPM 150 / 170 GPM 748 @ 2680 psi String wt. PU 230 SO 145 Rot 175 Torque on/off btm - 18,000l14,500 ft/Ibs. ECD 10.76 05/12/2007 00:00 12:00 12.00 12,004 13,410 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/ Geopilot f/ 12,004' to 13,410' MD 6135' ND ADT - 7.54 hrs. WOB 15/20 k- RPM 150 / 170 - GPM 750 @ 2580 psi String wt. PU 252 SO 152 Rot 195 Torque on/off btm - 19,500/17,500 ft/Ibs. ECD 10.87 12:00 00:00 12.00 13,410 14,950 INTRMI DRILL DDRL P Drilled 9 7/8" hole w/ Geopilot f/ 13,410' to 14,950' MD 6706' ND ADT - 7.99 hrs. WOB 20/25 k- RPM 160 - GPM 750 @ 3410 psi String wt. PU 240 SO 165 Rot 195 Torque on/off btm - 19,000/14,000 11 05/13/2007 00:00 12:00 12.00 14,950 15,980 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/ Geopilot f/ 14,950' to 15,980' MD 7089' TVD ADT - 8.11 hrs. WOB 20/25 k- RPM 160 - GPM 725 @ 3810 psi String wt. PU 270 SO 162 Rot 210 Torque on/off btm - 20,500/18,000 ft/Ibs. ECD 11.19 12:00 17:15 5.25 15,980 16,390 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/ Geopilot f/ 15,980' to 16,390' MD 7221' TVD ADT - 3.73 hrs. WOB 20/25 k- RPM 160 - GPM 725 @ 3880 psi String wt. PU 270 SO 163 Rot 210 Torque on/off btm - 20,000/18,000 ft/Ibs. ECD 11.19 17:15 17:45 0.50 16,390 16,390 INTRM1 DRILL CIRC P Circulated while evaluating logs. 725 GPM 3880 si 160 RPM. 17:45 23:00 5.25 16,390 16,707 INTRM1 DRILL DDRL P Drilled 9 7/8" hole w/ Geopilot f/ 16,390' to 16,707' MD 7270' ND ADT - 3.74 hrs. WOB 20/25 k- RPM 160 - GPM 725 @ 4000 psi String wt. PU 275 SO 165 Rot 210 Torque on/off btm - 20,000/19,000 ft/Ibs. ECD 11.2 23:00 00:00 1.00 16,707 16,707 INTRM1 DRILL CIRC P Pumped sweep and circulated with 725 GPM 4000 si. 100 RPM. 05/14/2007 00:00 03:00 3.00 16,707 16,330 INTRM1 DRILL CIRC P Circulate sweep around - continue to circulate and condition mud 700 gpm / 3740 psi / 100 rpm - set back 1stdl30 min to 16,330' 03:00 05:00 2.00 16,330 15,387 INTRM1 DRILL TRIP P Wipe hole from 16,330' to 15,387' - 600 gpm / 2730 psi / 100 rpm - Max over ull 10k - Flow check well, static 05:00 05:45 0.75 15,387 16,702 INTRM1 DRILL TRIP P RIH from 15,387' to 16,609' - Stage pumps up to 725 gpm / 3810 psi - Precautionary wash and ream from 16,609;' to 16,702' - Pumped high vis sweep - circulate and condition mud - 725 m/ 3810 si / 130 r m 05:45 09:30 3.75 16,702 16,702 INTRM1 DRILL CIRC P Stage pumps up to 725 gpm / 3810 psi - Precautionary wash and ream from 16,609;' to 16,702' - Pumped high vis sweep - circulate and condition mud - 725 gpm / 3810 psi / 130 rpm - Flow check well, static 09:30 10:15 0.75 16,702 16,702 INTRM1 DRILL CIRC P Pump WBS and Casing running pills and displace to bit - 7.0 bpm / 970 psi l70r m 10:15 12:30 2.25 16,702 15,291 INTRM1 DRILL TRIP P POOH from 16702' to 15,291' - spotting pills into open hole - 3.0 bpm / 370 psi - Flow check well, static - Blow down too drive ~ ~ 05/14/2007 12:30 22:30 10.00 15,291 4,550 INTRM1 DRILL TRIP P POOH on trip tank from 15,291' to 4,550'. Tight though the K-2. High over pull at 4,350'. Pipe sticking. Worked free. 22:30 23:30 1.00 4,550 4,350 INTRM1 DRILL TRIP P Backreamed 2 stands from 4,550' to 4,350'. 550 GPM 100 RPM. 23:30 00:00 0.50 4,350 4,155 INTRM1 DRtLL TRIP P POOH on trip tank from 4,350' to 4,155'. Still getting over pull of up to 50 K over. 05/15/2007 00:00 00:30 0.50 4,155 4,064 INTRM1 DRILL TRIP P POOH from 4,155' to 4,064' on trip tank. Hole ti ht. 00:30 02:00 1.50 4,064 3,303 INTRMI DRILL TRIP NP POOH backreaming from 4,064' to 3,303' 550 gpm 100 rpm. Stabilizer and bit on BHA overpulled 25 K when ulled into casin shoe. 02:00 03:15 125 3,303 3,303 INTRM1 DRILL CIRC P CBU working up to 700 GPM 100 -140 RPM. Obseved well at the shoe. Well static after 30 min. 03:15 03:45 0.50 3,303 3,112 INTRM1 DRILL TRIP P Pumped dry job. POOH on trip tank from 3,303' to 3,112'. Incorrect hole fill. 03:45 08:00 4.25 3,112 726 INTRM1 DRILL TRIP NP POOH with pump @ 5 BPM from 3,112' to 726' Laid down Ghost reamer. 08:00 08:15 0.25 726 726 INTRMI DRILL OWFF P Observed well static. 08:15 10:00 1.75 726 160 INTRM1 DRILL TRIP NP POOH with pump @ 5 BPM from 726' to 160'. 10:00 14:00 4.00 160 0 INTRM1 DRILL PULD NP POOH and laid down BHA. Attempted to pull on trip tank. Incorrect hole fill. Bit was severly balled up giving piston effect. 14:00 14:45 0.75 0 0 INTRMI DRILL RURD P Took off short bales and pulled wear bushin . 14:45 16:15 1.50 0 0 INTRM1 CASIN( NUND P Set test plug and changed rams to 7 5/8". Tested rams. 16:15 18:00 1.75 0 0 INTRM1 CASIN( RURD P Set thin wear bushing and rigged up to run casin . PJSM. 18:00 21:45 3.75 0 3,304 INTRM1 CASINC RNCS P Ran 78 Jts 7 5/8" 29.7 # L-80 BTCM casin to 3,304'. 21:45 22:45 1.00 3,304 3,304 INTRM1 RIGMN SVRG P Changed leaking swivei packing. 22:45 00:00 1.25 3,304 4,242 INTRM1 CASIN( RNCS P Ran 22 Jts 7 5/8" 29.7 # L-80 BTCM casin to 4,242'. 05/16/2007 00:00 01:00 1.00 4,242 5,087 INTRM1 CASIN( RNCS P Ran 20 Jts 7 5/8" 29.7 # L-80 BTCM casin to 5,087' 01:00 01:45 0.75 5,087 5,087 INTRM1 CASINC CIRC P Broke circulation. Staged pumps up to 5.5 BPM 420 PSI. Pumped casing volume + 10 Bbis. Up wt 162 K down 145 K. 01:45 05:15 3.50 5,087 8,305 INTRM1 CASIN RNCS P Ran 76 Jts 7 5/8" 29.7 # L-80 BTCM casin to 8305' 05:15 05:30 0.25 8,305 8,305 INTRM1 CASIN RNCS P MU Tam port collar 05:30 08:00 2.50 8,305 10,181 INTRM1 CASIN( RNCS P Ran 44 Jts 7 5/8" 29.7 # L-80 BTCM casinq to 10181' • 05/16/2007 08:00 11:00 3.00 10,181 10,181 INTRM1 CASINC CIRC P Broke circulation. Staged pumps up to 4 BPM 480 PSI. Up wt 265 K down 145 K. Lost 295 Bbis while circulating with artial retums. 11:00 14:30 3.50 10,181 12,713 INTRMI CASIN( RNCS P Ran 60 Jts 7 5/8" 29.7 # L-80 BTCM casin to 12713' 14:30 16:15 1.75 12,713 12,713 INTRM1 CASINC CIRC P Broke circulation. Staged pumps up to 4.4 BPM 530 PSI. Up wt 310 K down 150 K. 16:15 20:00 3.75 12,713 15,267 INTRM1 CASIN( RNCS P Ran 20 Jts 7 5/8" 29.7 # L-80 BTCM casin to 15267' 20:00 22:00 2.00 15,267 15,267 INTRM1 CASIN( CIRC P Broke circulation. Staged pumps up to 5.5 BPM 580 PSI. Up wt 415 K down 160 K 22:00 00:00 2.00 15,267 16,654 INTRM1 CASIN RNCS P Ran 73 Jts 7 5/8" 29.7 # L-80 BTCM casing to TD, 16654'. Total losses 180 bbls. 05/17/2007 00:00 00:15 0.25 16,654 16,693 INTRM1 CASIN RNCS P Made up landing jt and landed casing 16,693'. 00:15 00:45 0.50 16,693 16,693 INTRM1 CEME~ RURD P Rigged up cement head and lines. 00:45 03:15 2.50 16,693 16,693 INTRM1 CEME~ CIRC P Broke circulation. Staged pumps up to 7 BPM 580 PSI. Up wt 475 K down 165 K. Circulated 10.3 PPG in and out. 03:15 06:00 2.75 16,693 0 INTRM1 CEME~ DISP P PJSM on cementing - Cemented 1st stage 7 5/8" csg as follows: Pumped 5 bbls CW-100 - Test lines to 3700 psi - Pumped 15 bbls CW-100 @ 3bbls/min r @ 180 psi - Mixed & pumped 40 bbls 10.5 ppg MudPush (Problem getting MP up to weight) @ 3 bbls/min @ 260 psi - Dropped btm plug - Mixed & pumped 61.1 bbis 15.8. ppg Tail slurry (class G w/ additives) @ 4.5 bbls/min @ 350 psi - Dropped top plug w/ 20 bbls water f/Dowell - switched to rig pumps & displaced cmt w/ 744.3 bbls 10.3 ppg LSND mud @ 7 bbis./min @ 500 psi for first 720 bbis slowed pumps to 4 bbls/min @ 400 psi for last 24.3 bbls - Bumped plug w/ 900 psi - CIP @ 05:52 hrs. Checked floats Did not hold - Full returns throughout job - Reciprocated pipe for first 720 bbls of displacement - landed pipe when pumps were slowed to 4 bbls/min. 06:00 06:30 0.50 0 0 INTRM1 CASINC DHEQ P Attempted casing test pressure bled off to 200 psi. Closed rams after plug bump due to flow out the back side. Put 200 psi on casing annulus had 110 si. 06:30 12:00 5.50 0 0 INTRM1 CEMEI~ WOC NP WOC. Rig service and dressed Iron rou hneck for 4". 12:00 13:00 1.00 0 0 INTRM1 CEME(~ RURD P Laid down cement head and landing ioint. Pulled wear bushino. 05/17/2007 13:00 14:15 1.25 0 0 INTRM1 CASIN( DHEQ P Set and tested pack off to 5000 psi. 14:15 15:45 1.50 0 0 INTRM1 CASIN( NUND P Set test plug. Changed top rams to VBR and tested. 15:45 16:45 1.00 0 0 INTRM1 DRILL PULD P Pulled test plug and set wear bushing. 16:45 18:30 1.75 0 35 INTRM1 CEME~ PULD P Made up Baker plug dropping head and laid down. Made up Tam running tool. 18:30 00:00 5.50 35 3,500 INTRM1 CEME~ TRIP P RIH with running tool picking up 110 ~ts 4" DP from i e shed. 05/18/2007 00:00 05:00 5.00 3,500 8,387 INTRM1 CEME~ TRIP P RIH with running tool picking up 157 'ts 4" DP from i e shed. 05:00 05:15 0.25 8,387 8,387 INTRM1 CEME~ Cycled Port collar open and closed. 05:15 0630 1.25 8,387 8,356 INTRM1 CASINC DHEQ T POOH 1 jt. RU to test casing Attempted to test casing. Pumped in @ 1500 psi. Bled to 600 psi in 10 min and held. Installed gauge on outter annulus to check port collar for leak 0 si. Ri ed down. 06:30 08:30 2.00 8,356 8,387 INTRM1 CEME~ RURD P PJSM on 2nd stage cementjob. Picked up Plug Dropping Head and checked out. Rigged up lines. Opened ort collar. 08:30 09:15 0.75 8,387 8,387 INTRM1 CEME~ CIRC P Circulated DP volume + 10 Bbls. 3 BPM 600 si. 09:15 13:00 3.75 8,387 8,387 INTRMI CEME~ CIRC P Dropped ball and pumped down @ 3 BPM. Seated with 970 psi. Held for 5 min. Bled pressure to 100 psi. Opened Port Collar. Circulated 340 Bbls @ 3.5 BPM 430 psi taking returns up 7 5/8" X 10 3/4" annulus. 13:00 14:30 1.50 8,387 8,387 INTRM1 CEME~ DISP P Cemented 2nd stage 7 5/8" csg as foliows: Pumped 5 bbls CW-100 - Test lines to 3500 psi - Pumped 15 bbls CW-100 @ 3.1 bbls/min @ 480 psi - Mixed & pumped 30 bbls 10.5 ppg MudPush @ 3 bbls/min @ 460 psi -- Mixed & pumped 60.3 bbls 15.8. ppg Tail slurry (class G w/ additives) @ 4 bbls/min @ 550 psi - Dropped Dart w/ 20 bbis water f/Dowell - switched to rig pumps & displaced cmt w/ 65.5 bbls 10.3 ppg LSND mud @ 3.5 bbls./min @ 500 psi Bumped dart w/ 900 psi - CIP @ 15:10 hrs. Attempted to blow out ball. Did not go - Full returns throu hout 'ob - Closed ort collar. 14:30 15:15 0.75 8,387 8,387 INTRM1 CEME~ CIRC P Rigged up and Reversed Drill pipe volume. 15:15 16:15 1,00 8,387 8,005 INTRM1 CEME~ TRIP P Broke out Plug dropping head and laid down. POOH 5 stands. 16:15 23:30 7.25 8,005 8,005 INTRM1 DRILL PULD P Rigged up and laid down 5" DP in the mouse hole. 23:30 00:00 0.50 8,005 8,005 INTRM1 RIGMN SVRG P Serviced rig and top drive. 05/19/2007 00:00 02:00 2.00 8,005 8,005 INTRM1 RIGMN SVRG P Slipped and cut Qrilling line. 02:00 08:15 6.25 8,005 3,628 INTRM1 CEME~ TRIP P POOH on Trip Tank from 8,005' to 3,628'. Pulling speed was limited by tool size 6.9" cu s. 08:15 08:30 0.25 3,628 3,628 INTRM1 WELCT OWFF P Observed well (Precautionary). 08:30 15:30 7.00 3,628 0 INTRM1 CEME~ TRIP P POOH on Trip Tank from 3,628' to surface. Pulling speed was limited by tool size 6.9" cups. Laid down Tam Combo Tool. 15:30 16:30 1.00 0 0 INTRM1 CEME PULD P Picked up Baker plug dropping swivel and broke out subs. 16:30 17:00 0.50 0 0 INTRM1 DRILL RURD P PJSM and rigged up to lay down 5" DP. 17:00 17:30 0.50 0 0 INTRM1 RIGMN SVRG P Serviced rig. 17:30 00:00 6.50 0 0 INTRMI DRILL PULD P Laid down 5" DP from derrick in the mousehole. 05/20/2007 00:00 03:00 3.00 0 0 INTRM1 DRILL PULD P Continued laying down 5" DP from derrick in mousehole. 03:00 03:45 0.75 0 0 INTRM1 CASIN DHEQ NP Rigged up and attempted to test casing. Leaked off @ 1,090 psi. Blew down lines, ri ed down. 03:45 04:30 0.75 0 45 INTRM1 DRILL PULD NP Picked up 6 3/4" bit and Stabilizer BHA. 04:30 12:00 7.50 45 8,297 INTRM1 DRILL PULD NP RIH picking up singles from pipe shed to 8,297'. 12:00 14:00 2.00 8,297 8,580 INTRM1 DRILL CIRC NP Washed down from 8,297' to 8,580'. 220 GPM 850 psi 90 RPM. CBU. Flow check static. 14:00 1930 5.50 8,580 0 INTRM1 DRILL TRIP NP POOH on trip tank from 8,580' to surface. Laid down BHA. Bit had some cement between teeth. 19:30 00:00 4.50 0 7,913 INTRM1 DRILL PULD NP Made up Baker Retritveamatic packer and RIH to 7,913'. 05/21/2007 00:00 01:00 1.00 7,913 8,581 INTRM1 DRILL PULD NP RIH to 8,581'. Picked up 4" from pipe shed. 01:00 01:45 0.75 8,581 8,501 INTRM1 CASIN DHEQ NP Set packer. Rigged up and tested casing to 3,250 psi for 10 min. Rigged down. 01:45 06:00 4.25 8,501 13,149 INTRMI DRILL PULD NP RIH to 13,149'. Picked up 4" from pipe shed. 06:00 07:45 1.75 13,149 16,386 INTRM1 DRILL TRIP NP RIH with stands to 16,386'. 07:45 09:15 1.50 16,386 16,386 INTRM1 CASINC DHEQ NP Set packer. Rigged up and tested casing to 3,500 psi for 30 min. Rigged down. 09:15 11:45 2.50 16,386 16,386 INTRM1 DRILL CIRC NP CBU at 5 BPM 1340 psi. 11:45 12:30 0.75 16,386 16,386 INTRM1 DRILL FIT NP FIT to 12.9 PPG EMW. Blew down lines and flow checked weli static. 12:30 22:30 10.00 16,386 0 INTRM1 DRILL TRIP NP POOH with packer and laid down acker. 22:30 00:00 1.50 0 0 INTRM1 WELCT BOPE P Pulled wear bushing and set test plug with test Jt. RU to test BOP. 05/22/2007 00:00 05:45 5.75 0 0 INTRM1 WELCT BOPE P Test BOPE to 250 - 5000 psi with annular to 3500 psi. Pull test plug and set wear bushing. Witness of test was waived b AOGCC re John Cris . 05:45 09:30 3.75 0 389 INTRM1 DRILL PULD P MU BHA #4. Upioad MWD. Pressure test GeoSpan to 3500 psi. MU NMFC"S and HWDP. Shallow test tools. MU HWDP and ~ars. 09:30 12:00 2.50 389 5,148 INTRM1 DRILL TRIP P RIH w/ 4" DP from derrick from 389' to 5148'. Fill i e eve 20 stds. 12:00 14:00 2.00 5,148 9,912 INTRM1 DRILL TRIP P Continue to RIH with 4" DP from 5148' to 9912', fillin i e eve 20 stds. 14:00 19:00 5.00 9,912 9,912 INTRM1 RIGMN SVRG P PJSM Cut and slip 1800' of drilling line. New s ool. 19:00 21:30 2.50 9,912 16,479 INTRM1 DRILL TRIP P RIH to 16479' 21:30 22:00 0.50 16,479 16,606 INTRM1 DRILL REAM P Wash down from 16479' to 16606', 275 m, 3200 si, 90 r m 22:00 22:30 0.50 9,912 9,912 INTRM1 DRILL LOT P Test Casing to 950 psi to ensure port collar is closed. 22:30 00:00 1.50 16,606 16,610 INTRM1 CEME~ DRLG P Drill out float equipment from 16606' to 16610'. 05/23/2007 00:00 05:00 5.00 16,610 16,707 INTRM1 CEME~ DRLG P Finish drill out float equipment and cement from 16,610' to 16,693'. Clean out rathole to 16,707'. 05:00 05:45 0.75 16,707 16,727 INTRM1 DRILL DDRL P Drill out 20' new formation from 16,707' to 16,727'. 05:45 06:15 0.50 16,727 16,727 INTRM1 DRILL CIRC P Start CBU for LOT. Initial circ rate/press - 294 gpm / 3100 psi. Pressure dro ed to 2350 si 06:15 08:30 2.25 16,727 16,727 INTRM1 DRILL CIRC T Trouble shoot drilll pipe pressure loss. Pressure surface equipment to 3000 psi. OK. Isolate Geospan unit. Had slight flow out annulus. Shut well in. Annulus pressure - 0. Open well. Well is static. Review PWD data. 08:30 13:00 4.50 16,727 12,005 INTRMI DRILL TRIP T POH slow from 16,727' to 12005' checking for washout. Pipe initially came d but rauduall came wet. 13:00 16:00 3.00 12,005 16,727 INTRM1 DRILL TRIP T Break circ at 294 gpm at 2860 psi. RIH with 10 stands at a time. Circ at 294 gpm. Located washout in drill pipe box through pin on following joint on stand #147 (74 jts off bottom) Lay down 2 damaged jts + 1 jt: RIH to 16,727'. 16:00 17:00 1.00 16,727 16,727 INTRM1 DRILL CIRC P CBU for LOT at 300 gpm, 50 rpm, 3060 si. 17:00 19:00 2.00 16,727 16,727 INTRM1 DRILL LOT P Perform FIT. Max pressure reached 870 psi = 12.5 ppg. Pressure bled to 400 psi. Perfrom second LOT to verify first test. Max pressure reached is 570 si. Leveled off to 375 si. 19:00 2130 2.50 16,727 16,727 INTRM1 DRILL CIRC P PJSM. Displace to 9.6 ppg FlaPro at 300 gpm, 90 rpm, 2840 psi. Flow check. Static. ^ 05/23/2007 21:30 00:00 2.50 16,727 16,742 INTRM1 DRILL DRLG P Drilled from 16727' - 16742' MD / 7275' TVD. Encountered hard spot in last 12', drilled at 4 f h. 05/24/2007 00:00 02:30 2.50 16,742 16,872 INTRM1 DRILL DDRL P Drilled 6 3/4" hole w/ Geopilot f/ 16,742' to 16,872' MD 7289' TVD ADT - 1.66 hrs. WOB10/12 k- RPM 140 - GPM 320 @ 3760 psi String wt. PU 210 SO 145 Rot 175 Torque on/off btm -11,000/10,000 ft/Ibs. ECD 10.85 02:30 02:45 025 16,872 16,872 INTRM1 DRILL OWFF P Had 240 psi pressure increase on drill pipe and increase in flow. Moniitor well. Had air breaking out at surface. Calibrate as detector to confirm. 02:45 03:15 0.50 16,872 16,870 INTRM1 DRILL OTHR P Position Geotap at 16,790' and took formation pressure reading of 3,698 si. 03:15 06:30 3.25 16,870 17,050 INTRM1 DRILL DDRL P Drilled 6 3/4" hole w/ Geopilot f/ 16,872' to 17,050' MD 7303' ND ADT - 2.34 hrs. W0B10/12 k- RPM 140 - GPM 320 @ 3520 psi String wt. PU 212 SO 145 Rot 177 Torque on/off btm - 11,000/19,500 ft/Ibs. ECD 10.78 06:30 06:45 0.25 17,050 17,050 INTRM1 DRILL OTHR P Position Geotap at 16,940' and took formation pressure reading of 3,657 06:45 12:00 5.25 17,050 17,336 INTRM1 DRILL DDRL P Drilled 6 3/4" hole w/ Geopilot f/ 17,050' to 17,336' MD 7321' ND ADT - 3.85 hrs. W0610/12 k- RPM 140 - GPM 320 @ 3550 psi String wt. PU 215 SO 148 Rot 178 Torque on/off btm - 11,000/19,500 ft/Ibs. ECD 10.97 12:00 14:30 2.50 17,336 17,527 INTRM1 DRILL DDRL P Drilled 6 3/4" hole w/ Geopilot f/ 17,336' to 17527' MD 7306' ND ADT - 2.24 hrs. W0612/14 k- RPM 140 - GPM 320 @ 3820 psi String wt. PU 215 SO 145 Rot 180 Torque on/off btm - 11,500/10,000 ft/Ibs. ECD 10.97 1430 15:00 0.50 17,527 17,525 INTRM1 DRILL OTHR NP Attempted to GeoTap at 17525' & 17522'. Failed. Could not get good test. 15:00 18:00 3.00 17,525 17,718 INTRM1 DRILL DDRL P Drilled 6 3/4" hole w/ Geopilot f/ 17,336' to 17718' MD / 7302' ND ADT - 2.2 hrs. Began losing mud at 17615' (encountered fault). Loses up to 168 b h. 18:00 19:30 1.50 17,718 17,718 IINTRM1 DRILL CIRC NP Build and start pumping 32 bbl, 18 ppb LCM pill at 4 bpm, 75 rpm, 1340 psi. • 05/24/2007 1930 20:00 0.50 17,145 17,145 INTRM1 DRILL TRIP NP Flow check. Observed slight flow. With pill at bit, POOH with pump and spot pill from 17718-17145' (6 stands) at 2 b m, 500 si. 20:00 20:30 0.50 17,145 17,145 INTRM1 DRILL CIRC NP Circulate and condition at 2 bpm, 50 rpm, 600 psi and check losses. Observed 160 b h losses. 20:30 21:00 0.50 17,145 17,623 INTRM1 DRILL TRIP NP RIH to 17623' MD to GeoTap A Sand after encounterin fault. 21:00 22:00 1.00 1,762 17,718 INTRMI DRILL OTHR P Washed down to 17718' and perform GeoTap at 17708' while building forma squeeze pill. Geo tap showed 10.32 EMW, 3920 si. 22:00 23:00 1.00 17,718 17,718 INTRM1 DRILL CIRC NP PJSM. Spot 25 bbl forma squeeze. Spot 10 bbl on bottom at 2 bpm, 50 r m, 720 si. 23:00 00:00 1.00 17,718 16,954 INTRM1 DRILL CIRC NP Flow check, saw slight flow. POOH with pump and spot pill 1.8 bbl/std for last 15 bbl of pill from 17718' to 16954' (to be above pill). At 1 bpm, 140 psi. PU 235k, SO 150k. 05/25/2007 00:00 00:15 0.25 16,954 16,638 INTRM1 DRILL CIRC NP Finish pump out of hole to 16,638' 00:15 03:15 3.00 16,638 16,638 INTRM1 DRILL OTHR NP Close well in. Pump down drill pipe and annulus. Bump pressure to 50 psi every 10 mins. Pressure would immediately bleed to 0. Total of 20 bbls s ueezed awa . 03:15 05:00 1.75 16,638 16,638 INTRM1 DRILL CIRC NP Open well. Circ at 2 bpm at 510 psi. 05:00 05:30 0.50 16,638 17,623 INTRMI DRILL TRIP NP RIH to 17,623'. 05;30 06:00 0.50 17,623 17,718 INTRM1 DRILL CIRC NP Wash and ream to 17,718'. Mix 35 bbls form-a-s ueeze ill. 06:00 08:30 2.50 17,718 16,669 INTRM1 DRILL CIRC NP Spot 10 bbis pill out bit. POH to 16,669' s ottin form-a-s ueeze ill. 08:30 11:00 2.50 16,669 1,669 INTRM1 DRILL OTHR NP Monitor well for loss. Approx 1 bph. Close well in. Attempt to squeeze pill into formation by maintaining 50 psi on annulus. Pressure would bleed to zero. Pum ed totai of 19 bbls. 11:00 12:00 1.00 1,669 17,623 ~ INTRM1 DRILL TRIP NP RIH to 17,623'. 12:00 13:30 1.50 17,623 17,623 INTRM1 DRILL CIRC NP Establish circulation at 17,623'. Mix and spot 40 bbls form-a-sqeeze pill. Pump pill out bit at 7 bpm. Lost approx 20 bbls pill to formation. Losses at 294 m- 132 b h. 13:30 14:30 1.00 17,623 17,718 INTRM1 DRILL CIRC NP Attempt geotaps at 17,592' and 17,560' while establishing circulating rates and losses. Unable to obtain formation pressure. Losses at 210 qpm - 90 bph. Wash to 17,718'. • 05/25/2007 14:30 23:00 8.50 17,718 18,196 INTRM1 DRILL DDRL P Drilled 6 3/4" hole w/ Geopilot f/ 17,718' to 18,196' MD 7273' ND ADT - 6.5 hrs. W0612/15 k- RPM 140 - GPM 212 @ 2130 psi String wt. PU 218 SO 143 Rot 181 Torque on/off btm - 11,000/10,000 ft/Ibs. ECD 10.7 23:00 23:30 0.50 18,196 18,196 INTRM1 DRILL OTHR P Obtain Geotap at 18,120'. 3937 psi - 10.4 EMW 23:30 00:00 0.50 18,196 18,230 INTRMI DRILL Drilled 6 3/4" hole w/ Geopilot f/ 18,196' to 18,230' MD 7274' TVD ADT -.3 hrs. W0612/15 k- RPM 140 -GPM212@2130psi String wt. PU 218 SO 143 Rot 181 Torque on/off btm - 11,000/10,000 ft/Ibs. ECD 10.7 ppg 00:00 ~ 12:00 ~ 12.00 ~ 18,230 ~ 18,963 ~INTRM1 ~ DRILL ~ DDRL 12:00 ~ 00:00 I 12.00 ~ 18,963 ~ 19,790 IINTRM1 ~ DRILL ~ DDRL I Dailv mud loss to formation - 620 bbls P Drilled 6 3/4" hole w/ Geopilot f/ 18,230' to 18,963' MD 7266' T1/D ADT - 9.48 hrs. W0612/15 k- RPM 140 - GPM 212 @ 2100 psi String wt. PU 218 SO 143 Rot 180 Torque on/off btm - 12,000/10,500 ft/Ibs. ECD 10.8 ppg Tour mud loss to formation - 742 bbls GeoTap pressure at 18,662' - 3686 psi - EMW 9.75 oaa P Drilled 6 3/4" hole w/ Geopilot f/ 18,963' to 19,790' MD 7259' ND ADT - 9.32 hrs. WOB11/14 k- RPM 140 - GPM 212 @ 2160 psi String wt. PU 225 SO 135 Rot 182 Torque on/off btm - 13,500/11,500 ft/Ibs. ECD 10.73 ppg Tour mud loss to formation - 784 bbls GeoTap pressure at 19,308' - 3717 psi - EMW 9.84 05/27/2007 00:00 00:15 0.25 19,790 19,815 INTRM1 DRILL DDRL P Drilled 6 3/4" hole w/ Geopilot f/ 19,790' to 19,815' MD 7257' TVD ADT -.25 hrs. WOB 11/14 k- RPM 140 - GPM 212 @ 2160 psi String wt. PU 225 SO 135 Rot 182 Torque on/off btm - 13,500/11,500 ft/Ibs. ECD 10.73 ppq 05/27/2007 00:15 01:00 0.75 19,815 19,815 INTRMI DRILL OTHR P Attempt Geotap at 19,784'. Unable to obtain formation pressure. Take Geotap at 19,816 - 3709 psi - 9.82 ppg EMW 01:00 10:15 9.25 19,815 20,386 INTRM1 DRILL DDRL P Drilled 6 3/4" hole w/ Geopilot f/ 19,815' to 20,386' MD 7251' ND ADT - 7.46 hrs. WOB 8/15 k- RPM 140 - GPM 212 @ 2300 psi String wt. PU 235 SO 135 Rot 182 Torque on/off btm - 14,000/12,500 ft/Ibs. ECD 10.8 10:15 10:45 0.50 20,386 20,386 INTRM1 DRILL OTHR P Take Geotap at 20,355' - 3686 psi - 9.78 EMW 10:45 12:00 1.25 20,386 20,445 INTRM1 DRILL DDRL P Drilled 6 3/4" hole w/ Geopilot f/ 20,386' to 20,445' MD 7259' ND ADT -.72 hrs. WOB 8/15 k- RPM 140 - GPM 212 @ 2300 psi String wt. PU 235 SO 135 Rot 182 Torque on/off btm - 14,000/12,500 ft/Ibs. ECD 10.8 ppg Lost 655 bbls to formation last 12 hrs 12:00 00:00 12.00 20,445 21,084 INTRM1 DRILL DDRL P Drilled 6 3/4" hole w/ Geopilot f/ 20,445 to 21,084' MD 7241' ND ADT - 9.81 hrs. WOB 8/15 k- RPM 140 - GPM 212 @ 2300 psi String wt. PU 235 SO 125 Rot 180 Torque on/off btm - 14,500/13,500 ft/Ibs. ECD 10.8 ppg Geotap at 20,834' - 3682 psi - 9.76 ppg EMW Lost 442 bbls mud to formation last 12 hrs. Total mud loss for horizonta~ section - 4106 bbls Lost control of Geopilot approx 20,750'. 05/28/2007 00:00 01:00 1.00 21,084 21,089 INTRM1 DRILL DDRL P Drilled 6 3/4" hole w/ Geopilot f/ 21,084 to 21,089' MD 7242' ND ADT - 1.36 hrs. WOB 15/17 k- RPM 140 - GPM 212 @ 2350 psi String wt. PU 235 SO 128 Rot 180 Torque on/off btm - 14,500l13,500 ft/Ibs. ECD 10.8 ppg Drilled into shale above sand. Lost 342 bbls mud to formation last 12 hrs. 01:00 02:30 1.50 21,089 21,089 INTRM1 DRILL CIRC P Circ open hole clean. Geotap at 20.886' - 3681 psi - 9.76 ppq EMW 05/28/2007 02:30 03:00 0:50 21,089 21,089 INTRM1 DRILL OWFF P Monitored flow back for 20 mins. Gained 15 bbls in its. 03:00 06:00 3.00 21,089 21,089 INTRM1 DRILL CIRC P CBU + mud loss to formation at 5 bpm - 2170 psi - 90 rpms. No gas or oii in returns. 06:00 12:30 6.50 21,089 16,669 INTRM1 DRILL TRIP P POH w/ pump from 21,089' to 16,669' at 3.5 bpm - 1040 psi - no rotary. No ti ht hole. 12:30 12:45 0.25 16,669 1,669 INTRM1 DRILL OWFF P Monitorwel-. 3%to 1%flow in 15 min. 12:45 16:30 3.75 1,669 1,669 INTRM1 DRILL CIRC P Circ and increase mud wt from 9.8 to 10.1 16:30 17:30 1.00 1,669 1,669 INTRM1 DRILL OWFF P Monitorwell. Flowed back>5 bbls. Well static after 30 min. Well taking 2 b h after 1 hr. 17:30 00:00 6.50 1,669 11,054 INTRM1 DRILL TRIP P POH slow on trip tank from 16,669' to 11,054'. Lost 595 bbls mud to formation last 24 hrs. Total mud loss for horizontai section - 4701 bbls 05/29/2007 00:00 07:45 7.75 11,054 389 INTRM1 DRILL TRIP P POOH from 11,054'to 389' -flow check well, slight losses observed - retrieve drift from drill strin 07:45 10:30 2.75 389 0 INTRM1 DRILL PULD P Stand back hwdp - download Iwd tools - la down BHA com onents 1030 11:30 1.00 0 0 INTRM1 DRILL OTHR P Clear tools and Geo-Span skib from rig floor - clean up trip mess - Static losses 9 b h 11:30 12:00 0.50 0 0 INTRM1 DRILL PULD T MU Tam Combo tool 12:00 16:30 4.50 0 8,390 INTRM1 DRILL TRIP T RIH with combo tool on 4" drill pipe - locate Tam port collar @ 8390' DP measurements - Mud losses to hole - 16b h 1630 18:30 2.00 8,390 8,292 INTRM1 DRILL OTHR T tagged PC sleeve with 2-3K SOW - pulled 10K over PUW - observed string wt. drop back to PUW of 165K - pulled 10K over PUW and tested Port collar with 1000 psi / 1500 psi / 1800 psi / 2000 psi / 2200 psi - sheared out solid choke @ 2330 psi - released combo tool from port collar - laid down one sin le and stood back 1 stand to 8292' 18:30 20:30 2.00 8,292 8,290 INTRM1 RIGMN SVRG P Cut & slip drill line - service TD 20:30 00:00 3.50 8,290 4,488 INTRM1 DRILL TRIP T POOH w/ Combo tool f/ 8290' to 4488' 05/30/2007 00:00 03:00 3.00 4,488 0 INTRM1 DRILL TRIP T POOH from 4,488' - lay down Combo Tool 03:00 03:45 0.75 0 0 COMPZ RPCOh RURD P Rig up to run 4 1/2" liner 03:45 04:00 0.25 0 0 INTRMI RPCOh SFTY P Held Pre-job Safety and Opts meeting with crew 05/30/2007 04:00 10:00 6.00 0 4,511 INTRM1 RPCOh RCST P MU baker V-Set shoe - PU and RIH with 109 jts of 4 1/2", 12.6#, L-80 Liner, 17 Perf pups, 2 Swell Packers, 1 constrictor - MU Baker Flex Lock hanger assembly -OA Liner legth = 4511.20' - Avera e losses ~ 16 b h 10:00 10:45 0.75 4,511 4,511 INTRMI RPCOf~ OTHR P RD tongs & clear floor 10:45 20:00 9.25 4,511 20,950 INTRM1 RPCOh RCST P RIH w/ 4 1/2" liner on 4" DP w/ shoe to 20,950' 20:00 21:00 1.00 20,950 20,950 INTRM1 RPCO OTHR P Drop ball - pump down ball to set hanger - Pressure up to 1800 psi - slack off to block wt. - hanger set - Pressure up to 3500 psi to release runnin tool - to of liner 16,438.80' 21:00 22:00 1.00 20,950 16,410 INTRM1 RPCO OTHR P Std back 1 stand DP to 16,410' - observed slight flow - monitor well static in 20 mins. 22:00 00:00 2.00 16,410 15,740 INTRM1 RPCOh TRIP P POOH w/ DP f/ 16,410' to 15,740' - improper hole fill - well was swabbing - monitor well fluid level in annulus dro ed 3' in 15 mins. 05/31/2007 00:00 13:00 13.00 15,740 0 INTRM1 RPCOh TRIP P Pooh from 15,740' - lay down Baker runnin tools - hole takin ~ 15 b h 13:00 15:30 2.50 0 0 INTRM1 WELCT OTHR P Pull wear bushing - change top rams to 3 1/2" - install test plug and joint - fill stack with water - test rams to 250 / 5000 si - LD test'oint and lu 15:30 16:00 0.50 0 0 INTRM1 RPCOh RURD P Rig up to run 3 1/2" Completion 16:00 16:15 0.25 0 0 INTRM1 RPCOh SFTY P Held Pre-job Safety and Ops meeting with crew 16:15 00:00 7.75 0 6,992 INTRM1 RPCOh RCST P Run 3 1/2" 9.3# EUE Mod. Tbg & completion equipment as follows: WLEG - 14 jts tbg - XN nipple - 2 jts tbg - 3 1/2" 9.3# EUE pup jt - Baker S-3 packer - 3 1/2" 9.3# EUE pup jt. - 1 jt. tbg - Camco GLM assembly w/ shear valve - 126 jts. tbg - Camco GLM assembly w/ dummy valve - 49 'ts. tb to 6992' 06/01/2007 00:00 07:15 7.25 6,992 14,143 INTRM1 RPCO RCST P Continue running 3 1/2" 9.3# EUE Mod. Tbg from 6,992' to 14,143' (450 'ts. total 07:15 08:15 1.00 14,143 14,160 INTRM1 RPCO PULD P MU Camco TRMAXX-5E SSSV - move spooler to floor - run line through sheave - attatch controle line and PT to 6000 si 08:15 12:30 4.25 14,160 16,430 INTRM1 RPCO RCST P Continue running 3 1/2", 9.3#, EUE Mod. Tbg from 14,160', tagged TOL @ 16,429.86' (tubing measurements) - unable to ass TOL. 12:30 15:45 3.25 16,430 16,430 INTRM1 RPCOh OTHR P RU and circ - worked 2.5 rounds into tubing string reciprocating pipe attempting to enter liner tie back sleeve - unable to pass TOL. 06/01l2007 15:45 19:00 3.25 16,430 16,427 INTRM1 RPCOti HOSO P Lay down 5 jts of 3 1/2" tubing - MU xo - PU space out pups, 2 jts of 4 1/2" 12.6#, L-80, IBTM - MU FMC tubing hanger - Strip sssv control line through hanger and PT fittings to 6000 psi - land hanger in wellhead w/ wleg spaced out 2.6' above TOL. - PU wt. 165 SO wt. 110 19:00 19:45 0.75 16,427 16,427 INTRM1 RPCOh OTHR P RI lack downs - LD landing jt A- Install TWC - MU landing jt. B- Test hanger seals to 5000 psi for 5 mins. LD landin 't. B 19:45 20:30 0.75 16,427 16,427 INTRM1 RPCOti OTHR P LD tbg running equipment 20:30 21:30 1.00 16,427 16,427 INTRM1 RPCOti NUND P PJSM - ND flow line - turnbuckles - remove service lines - pull mouse hole - ND & set back BOP stack 21:30 23:00 1.50 16,427 16,427 INTRMI RPCOh NUND P Terminate control line through wellhead - NU tree - RU lubricator & test to 5000 si - Pull TWC 23:00 23:45 0.75 16,427 16,427 INTRM1 RPCOI~ RURD P RU squeeze manifold & hardlines to wellhead on tb & annulus valves 23:45 00:00 0.25 16,427 16,427 INTRM1 RPCOti SFTY P Held PJSM on displacement with rig crews 06/02/2007 00:00 02:45 2.75 0 0 INTRMI RPCO CIRC P Test lines to 2500 psi - pumped 20 bbls of 9.6 ppg brine - 35 bbis of viscousified brine - followed by 310 bbls of 9.6 ppg brine 2.5 bpm / ICP 780 psi - FCP 520 psi - Averaged 72% returns 02:45 06:00 3.25 0 0 INTRM1 DRILL CIRC P Lined up to Dowell - PT lines to 2500 psi - pumped 550 bbls of 9.6 ppg corrosion inhibited brine 3.0 bpm / 700 - 920 si 06:00 07:15 1.25 0 0 INTRMI RPCOh FRZP P Displace tubing to diesel and freeze protect annulus to 1900' - Dowell pumped 220 bbis of diesel - 3.0 bpm / 1027 - 1425 psi - Shut in pressures - tubin =1200 si, Annulus = 250 si 07:15 08:30 1.25 0 0 INTRM1 RPCOh PACK P RU Doyon lubicator and drop setting ball/rod - RU and test lines to 5200 psi - set acker with 4550 si 08:30 10:15 1.75 0 0 INTRM1 RPCOh DHEQ P Pressure test tubing to 4500 psi, bled to 4218 psi in 30 minutes - bleed off tubing to 2000 psi - RU and test 3 1/2" x 7 5/8" annulus to 3540 psi - bled to 3454 psi in 30 minutes - Bled annulus to 0 psi, tubing to 1200 psi - pressure up on annulus - DK2 valve sheared @ 2400 psi - Bled off tubing and annulus - shut in well with 1400 psi on tubing and 400 si on annulus 10:15 11:00 0.75 0 0 INTRM1 RPCO RURD P Blow down and vac out lines - RD hardlines and circulatina manifold. i / ~ • 04-Ju1-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD2-72 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 54.33' MD Window / Kickoff Survey 0.00' MD (if applicable) Projected Survey: 21,089.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ o~ Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) a ~~ --~ ~ s ) 'I'hanks - CD2-72 permit to drill ~ • Tom, Thanks again for heiping process the permit to drili application for CD2-72 last week. We try to avoid asking for such fast tum-around, but occasionally we are put in that position. Please pass on my sincere thanks to everyone else who hetped get the permit processed as quickly as it was. Sub;j~ct: FW: CD2 annular issues Fra~; "~o~son, Vem" <Vem.Jahnson@conocophillips.com> _ . : Date: Man, 30 Apr 2007 15:45:32 -0800 To: Thomas Maunder <tom maunde ~a?admin.state.ak.us> CC: "Crurnrine, Tim Wiliiam" <I'im.W.Crumrine@conocophillips.com> Tom, I spoke to Tim Crumrine, who has looked into whether there have been OA pressure issues with our Problem Well group, and there has been no evidence of a problem. Some data was sent to Dave Roby including data on CD2-404 and the CD2 OA pressures from 12/05 until 12/06. We had SPIDR gauge data on the CD2-23 and 2-11 (two closest well to CD2-404) from the injection test in January. The problem wells group reviewed the injection data that I sent and there was no correlation between the injection test and OA pressures on the CD2-11 and CD2-23. Let me know if you need anything else. Sabject: CD2-~2 diverter From: "Johnson, Vern" <Vern.Johnson@conocophillips.com> Date: Mon, 30 Apr 2007 12:50:25 -0800 To: Thomas Maunder <tom maunder(a7,,admin.state.ak.us> Tom, Do you have a preliminary indication whether or not the diverter waiver request for CD2-72 will be approved? We will be drilling from CD2 on new gravel, with a slightly different wellhead height than previous wells, so if a diverter is needed we would need to sfiart modifying the length now. Let me know, or call if you want to discuss. ~~. ~~~~~ Regards ' ~~~ ~r~~ ~~ Vern ~ ~~~~ ~ ~ Chip Alvord WNS Drilling Team Lead ConocoPhillips Alaska, Inc PO Box 100360 Anchorage, AK 9951-0360 Re: CoIville River Field, Alpine Oil Pool, CD2-72 ConocoPhillips Alaska, Inc Permit No: 207-057 Surface Location: 2208' FNL, 1984' FEL, SEC. T11N, R4E, UM Bottomhole Location: 2635' FNL, 1402' FEL, SEC. 29, T12N, R4E, UM Deax Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accord nce with AS 31.05 and Title 20, Chapter 25 of the Alaska Administra ' e Code unless the Commission specifically authorizes a variance. Fai ure to comply with an applicable provision of AS 31.05, Title 20, Chapter 5 of the Alaska Administrative Code, or a Commission order, or the terms an conditions of this permit may result in the revocation or suspension of the permit. ~~Vhen 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). Sincerel Dan T. Seamount Commissioner DATED this ~day of May, 2007 cc: Department of Fish 8a Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~j ~~C~IVED MAY 4 3 2001 PERMIT TO DRILL ~~~ske qci & Ges Cons. Commissian 20 AAC 25A05 Ar~chorage _ ._„ , 1a. Type of Work: 1 b. Current Well Class: Exploratory ~ Development Oil ~ 1 c. Specify if well is proposed for: Drill Q Re-drill ^ Stratigraphic Test ^ Service ^ Development Gas ~ Coalbed Methane ^ Gas Hydrates ^ Re-entry ^ Multiple Zone^ Single Zone Q Shale Gas ^ 2. Operator Name: 5. Bond: ~ Blanket Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 ~ CD2-72 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 / , MD: 21568` TVD: 7282' Colvilfe Rnrer Field 4a. Location of Well (Govemmental Section): 7. Property Designation: ~~,N r: ~L 1 Surface: 2208` ~~~, ~~$4` FEL, ~`J@C ~, T~'{ ~, ~~~, ~fl~ ADL 380075. 387207, 387212 2 ;, ASFt Alpine Oil Pool ~ Top of Productive Horizon: 8. Land Use Permit: ~ L 1 ~ 3` 13. Approximate Spud Date: 9548' FNL, 4183` FEL Sec 33, T12N, R4E, UIVI 380075 5/3C2047 Total Depth: 9. Acres in Property: 14. Distance to ~~ yuj'/~ ((~„ ~/{ y.~ Nearest Propsrty: 6 miles from Fio d PA 2635` FNL, 1402` FEL, Sec 29, T12N, R4E, UNt 2560 ~1 5•3-:y 7 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation ~l~pG1 ~~f~,~L ~ 15. Distance to Nearest / Surface: x- 371250 ' y- 5974157 ~ Zone- 4 ` 5 3~ (Height above GL): 37' RKB feet ~E~3 w~~hin Paol: CD2-31: 1401' ~t 165$8' fV1D , 16. Deviated wells: Kickoff depth: 350' ~ ft. 17. Maximum Anticipated Pressures in psig (see zo,aAC zs.o35) Maximum Hole Ang1e: 9Q° de9 Downhole: 3295 psig ~ Surface: 2567 psig ' 18. Casing Program Setting Depth Quantity of Cement SpecifiCations T Bottom or sacks f c Size op . . Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 24" `~" ~2 ~~ Ft-4~ ~~e(c~~~ 77 37 37 114 - 114` ~~ pre-instaAed s~~°~ t~_3,'4" 45 5# L-S~ B~C~ 33p2 37 37 3339 • 2400 • 669 sx ASL3, 270 sx 15.8 cl G 9.875" 7-5/8" 297# L-80 BTCM 16532 37 37 16569 7267 ~ 253 sx 15.8G & 262 sk 15.SG for Qannik 6.75" 3.5" 9.3# L-80 EUE-M 16322 32 32 16354 722d Tbg 5.75" 4.5" 12.6# L-80 IBTM 5224 16334 7219 21558 - 7282 ~ perfarated and biank Liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length 6ize Cement Volume MD ND Cond uctor/Structu ral Surface Intermediate Production Perforation Depth MD (ft): Perforation Depth ND (ft): 20. Attachments: Filing Fee ~ BOP Sketch~ Drilling ProgramQ Time v, Depth F^ Shallow Hazard Analysis ~ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Progr~ 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. ContaCt il. JohRSOn Printed Name C. Alvord Title WNS Drilling Team Lead Signature ' ' Phone +~/_S'_(~ ~2o Date ~l /2G IZ~~ ~ 3,~ ~t~ [ r Commission Use Only Permit to Drill API Number: Permit Approval See cover letter Number: ~ ~.~~7 -~, :~ ~ 50- ~-~ L i~~ ~~~ ~- ~ Date: • • `~ d for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: ~ Samples req'd: Yes ^ No ["r Mud log req'd: Yes ^ No [,/ Other: ~~'~~~~i.,`~v~Zu~.,~a~~~~ ~~.. H2S measures: Yes [] No [v]' Directional svy req'd: Yes [v~No ^ ~~v~c-~c-wG"ZJC-:c~ c~~ ~~~--"~~0~ >~- ~ ~ PROVED BY THE COMMISSION DATE: ~ / ~ MISSIONER r.,~.,, ~n_nn~ Rcvicer! 19/9f1llri ~ ~ " v ,/~~ `~ . .i _ "' % ConocoPhillips Alaska, Inc~ ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 May 3, 2007 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Appiication for Permit to Drill CD2-72 Dear Sir or Madam: ConocoPhilli s p ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the CD2 drilling pad. The intended spud date for this well is 05/03/07. It is intended that Doyon Rig 19 be used to drill the welL i After setting 7-5/8" intermediate casing, the horizontal section will be drilled and the well completed with a perforated liner and tubing. At the end of the rig work program, the well will be flowed back for 2-3 ~ days to mitigate reservoir damage. The well will then be closed in awaiting completion of well work and facilities connection that will allow the well to begin production. It is expected that the K2 (Qannik) sand could be considered a significant hydrocarbon bearing zone. After running 7-5/8" casing, it is planned to pump lead cement, then open a stage tool and pump a second cement job to isolate the K2 with 500' of cement above and below the interval. This will leave a mud gap between the two stages. '/~ It is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. There have been 60 surface hoies drilled at CD2 and there has not been a significant show of ' shallow gas or gas hydrates through the surface hole interval. -'/~ Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program. 4. A proposed completion diagram. 5. A drilling fluids program summary. 6. Pressure information as required by 20 ACC 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 is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Riser setup If you have any questions or require further information, please contact Vern Johnson, 265-6081, or Chip Alvord at 265-6120. ~ ~ Sin y, ~j ~~~~,~ ~ - ~--- Vern Johnson Drilling Engineer Attachments cc: CD2-72 Well File / Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1700 Liz Galiunas ATO 1704 Tim Schnieder ATO 1706 Lanston Chin Kuukpik Corporation ~ ~ CD2-72 Drilling Hazards Summary (See WeA Plan Attachment: Detailed Risk Information for further discussion of these risks) 13-1/2" Hole / 10-3/4" Casina Interval Event Risk Level Miti ation Strate Conductor Broach Low Monitor cellar continuousl durin interval. Well Collision Low G o sin le shots, travelin c linder 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 temperatures 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' TVD Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of low density cement slurries 9-7/8" Hole / 7-5/8" Casinq 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' TVD increase mud weight. Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, mud properties, proper hole fi(fing, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. Abnormal Reservoir low ~. Well control drills, increased mud weight. No Pressure mapped faults occur within 700' of the planned wellbore. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers 6-3/4" 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 rheology, 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) monitoring, weighted sweeps. 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 weight. Hydrogen Sulfide gas Low HZS drills, detection systems, alarms, standard well , control practices, mud scavengers ORIGlNAL ~ Procedure 1. Move on Doyon 19. ~ 2. Rig up riser, dewater cellar as needed. 3. Drill 13-1/2" hole to the surface casing point as per the directional plan. (Directional/MWD). 4. Run and cement 10-3/4" surface casing. 5. Install and test BOPE to 5000 psi. 6. Pressure test casing to 2500 psi. 7. Drill out 20' of new hole. Perform leak off test. 8. Pick up and run in hole with 9-7/8" drilling BHA. i 9. Drill 9-7/8" hole to intermediate casing point in the Alpine D. (LWD Program: GR/RES/PWD) 10. Run and cement 7-5/8" casing as per program. Carry out a leak off test down the 10-3/4"x7-5/8" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. - 11. BOPE test to 5000 psi. / i 12. Drill 6-3/4" horizontal section to well TD (LWD Program: GR/RES/PWD). 13. Circulate the hole clean and puil out of hole. 14. Run lower completion with 4-1/2" perforated liner and liner hanger. 15. Run 3-%z, 9.3#, L-80 tubing with SCSSSV, gas lift mandrels, packer, XN nipple and stinger assembly. Sting in, space out and land hanger. 16. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 17. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 18. Circulate tubing to diesel and install freeze protection in the annulus. 19. Drop ball and rod, set packer and test tubing and annulus to 3500 psi / 30 mins. 20. Set BPV and secure well. Move rig off. QR~GlNAL ~ ~ Wetl Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD2-31 is the nearest existing well to the CD2-72 plan at 67' well to weii separation at 1844' MD. Drillinq Area Risks: There are no~high-risk events. It is possible the Alpine A sand has highe~ than normal pressure due to local injection. Additional flow checks will be made to ensure sufficient mud weight is used. Lost circulation: Faulting within the Alpine 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. Annular Pumpinq Operations: Incidental fluids developed from drilling operations on well CD2-72 will be injected into a permitted annulus on CD2, likely CD2-56 or the class 2 disposal well on CD1 pad. The CD2-72 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 1500' TVD. DRILLING FLUID PROGRAM SPUD to 10-3/4"surface casing point -13- 1/2„ Intermediate hole to 7- 5/8"" casing point - 9-7/8" Production Hole Section - 6 3/4" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.8-10.5 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 8.5 - 9.0 9.0 - 1 0.0 9.0 - 9.5 PH 6 % KCL Surface Hole: i A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep flow line viscosity at ± 200 sec/qt 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 Nechelik 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 dril! solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section : The horizontal interval will be drilled with a M-I Flo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with ± 30PPB calcium carbonate bridging material to minimize formation damage. Flo-Vis Polymer and Dual-Flo starch will be used for viscosity and fluid loss control respectively. ~RIGINAL ~ Completion Schematic M Colville River Field CD2-72 Production Well Completion Plan Updated 04/25/2007 ~ Sperry Drilling Services is~~ Conductor to 114~ plan WP07 - 4-'/z" space out pups -3-'/z" x 4-'/2' cross-over, 2 jts below 4-'/z" hanger 3-1/2" Camco TRMAXX-5E SSSV Nipple (2.813" ID) at 1995' ND=2300' MD -2.813" X-Over -Single Y<"x0.049" s/s control line Packer Fluid mix: Diesel in tubing and annulus 10-3/4" 45 5 ppf L-80 BTC-mod Uuoer Comnletion . ~~ Tubing Hanger Surface Casing @ 3339' MD / 2400' TVD ~ Z) 4-'/2' 12.6 #/ft IBT-Mod Tubing (2) ' ' 3) 4- 12.6 #/ft IBT-Mod PUPS /i cemented to surface ' 4) Crossover 5) 3-1/2", 9.3#/ft, EUE-Mod Tubing Cement to +/- 7326' ~ 6) Camco TRMAXX-5E SSSV w/ x profile MD / 3881' ND 7) 3-1/2", 9.3#/ft, EUE-Mod Tubing ~ 8) Camco KBMG GLM (2.867" ID) w/dummy Qannik interval top +/- 9) 3-1/2", 9.3#/ft, EUE-Mod Tubing 7826' MD / 4066' ND ' 10) Camco KBMG GLM (2.867" ID) w/dummy 11) 3-1/2", 9.3#/ft, EUE-Mod Tubing 12) Camco KBMG GLM (2.867" ID) w/DCK2 shear TAM port collar +/- 13) 3-'/z' 9.3#/ft, EUE-M (2) 8346' MD / 4259' TVD 14) Baker S3 Packer 15) 3-YZ' 9.3#/ft, EUE-M (2) 16) HES "XN" (2.75" min ID) @ 68° 17) 3-Y~' 9.3#/ft, EUE-M 18) BOT Stinger with Fluted WLEG/pup/shear sub Camco KBMG GLM (2.867" ID) bottom, 3' spaceout @ at 5700' TVD for E Dummy with 1" BK-2 Latch Lower Completion: 19) Baker 5"x7" Flexlock Liner Hanger w/setting sleeve 20) 4-Yz' 12.6#/ft L-80 IBTM Tubing with 5' Perforated pups 21) BakerShoe Camco KBMG GLM (2.867" ID) with 1" DCK2 shear valve set for 2500 spi Baker Flexlock hanger with setting sleeve top at ~ +/- 16334' MD TOC @ +/- 15660' MD / 6976' Top Alpine D 16548 MD / 7264 Top Alpine A 16767 MD / 7287 ND 7-5/8" 29.7 ppf L-80 BTC Mod Production Casing @ 16569' MD / 7267' TVD @ +/-g2° In Alpine D MD ND 32' 32' 2300' 1995' 6032' 3400' 12225' S700' 12480' 7004' 15960' 7087' 16036' 7115' 16325' 7216' 16354' Top MD ND 16334' 7219' 21558' 7282' I°° I I~° I I~° I J'', 4-Yi' 12.6#/ft L-80 IBTM liner, Well TD at 1 ea 5 ft perforated pup with 21568' MD /' rigid straight centralizer per 4 72g2' T~/p ~ joints ORIGINAL ~ PRESSURE INFORMATION (per 20 ACC 25.005 ( c)(3,4) and as required in 20 ACC 25.035 (d) (2)) ~ The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size in Csg Setting Depth MD/TVD(ft) Fracture Gradient (Ibs. / gal) Pore pressure psi ASP Drilling (psi) 16 114 / 114 10.9 52 53 10-3/4" 3339 / 2400 14.5 1086 1570 7-5/8" 16569 / 7267 16.0 3288 2567 N/A 21568 / 7282 16.0 3295 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) surFace pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP =[(FG x 0.052) - 0.1 jD 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 psi/ft D= true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP -(0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS Drilling below conductor casing (16") ASP =[(FG x 0.052) - 0.1] D =[(10.9x0.052)-0.1]x114=53psi OR ASP = FPP - (0.1 x D) = 1086 -(0.1 x 2400') = 846 psi 2. Drilling below surface casing (10-3/4") ASP =[(FG x 0.052) - 0.1 ] D _[(14.5 x 0.052) - 0.1] x 2400 = 1570 psi OR ASP = FPP - (0.1 x D) = 3288 -(0.1 x 7267) = 2561 psi 3. Drilling below intermediate casing (7-5/8") ASP = FPP - (0.1 x D) = 3295 -(0.1 x 7282') = 2567 psi ~ ~~~~~~~~~ ~ ~ Cementin~ Program: 10-3/4" Surface Casinq run to 3339' MD / 2400' TVD.~ Cement from 3339' MD to 2839' (500' of fill) with Class G+ Adds @ 15.8 PPG, and from 2839' to ~ surface with Arctic Set Lite 3. Assume 300°/a excess annular volume in permafrost and 50% excess below the permafrost (1569' MD). Lead siurry: (2839-1569') X 0.3637 ft3/ft X 1.5 (50% excess) = 692.8 ft3 below permafrost 1569' X 0.3637 ft3/ft X 4(300% excess) = 2282.6 ft3 above permafrost Total volume = 692.8 + 2282.6 = 2975.4 ft3 => 669 Sx @ 4.45 ft3/sk System: 669 Sx ArcticSet Lite 3@ 10.7 PPG yielding 4.45 ft3/sk, Class G+ 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% S001 accelerator, 50% D124 extender and 9% BWOW' D044 freeze suppressant Tail slurry: 500' X 0.3637 ft3/ft X 1.5 (5Q°/a excess) = 272.8 ft3 annular volume 80' X 0.5397 ft3/ft = 43.1 ft3 shoe joint volume Total volume = 272.8 + 43.1 = 315.9 ft3 => 270 Sx @ 1.17 ft3/sk System: 270 Sx Class G+ 0.2% D046 antifoamer, + 1%S2, 0.2%D46, 0.3%D65 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7-5/8" Intermediate Casinq run to 16569 MD / 7267' TVD ~ ~ Second Staqe: Cement from 16569' MD to 15660' MD (minimum 300' MD above the packer) with Class G+ adds @ 15.8 PPG. Assume 40% excess annular volume. Tail: (16569' -15660') X 0.2146 ft3/ft X 1.4 (40% excess) = 273.1 ft3 annular vol. 80' X 0.2577 ft3/ft = 20.6 ft3 shoe joint volume Total volume = 273.1 + 20.6 = 293.7 ft3 => 253 Sx @ 1.16 ft3/sk System: 253 Sx Class G+ Class G+ 1%S2, 0.2%D46, 0.3%D65 @ 15.8 PPG yielding 1.16 ft3/sk Second Stage: Cement from ports in a TAM port collar set 500' below the K2 interval to +/- 500' above the ~ K2 interval with Class G+ additives @ 15.8 ppg. Assume 40% excess annular volume Lead: (8346'-7326') X 0.2146 ft3/ft X 1.4 (40% excess) = 306.4 ft3 annular vol. Total Volume = 306.4 ft3 => 262 Sk @ 1.17 ft3/sk System: 262 Sx Class G+ 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S002 accelerator @ 15.8 PPG yielding 1.17 ft3/sk ' B Wei ht Of mix Water, all other additives are BWOCement~ ~~~~~l ` L. Y 9 ~ ~ ~ ~ ConocoPhillips Alaska, Inc. CPAI Report Company: ConocoPhiilips Alaska Inc. Date: 4/20/2007 Time: 11:00:45 Page: 1 Field: Colville River Unit Caordinate(NE) Reference: Well: Plan: CD2-72, True Norkh ~ Site: Aipine CD2 Vertical (TVD) Reference: CD2-72wp07 53.9 Well: Pian: CD2-72 Section (VS) Reference: WeN (O.OON;O.OOE,303:40Azi) Wellpath: Pian: CD2-72 Survey Calculation Method: Minimum Cprvature ~ Db: Oracle Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/1OOft deg/100ft deg/100ff deg 36.30 0.00 0.00 36.30 0.00 0.00 0.00 0.00 0.00 0.00 351.70 0.00 0.00 351.70 0.00 0.00 0.00 0.00 0.00 0.00 651.70 7.50 330.00 650.84 16.98 -9.80 2.50 2.50 0.00 330.00 851.70 12.50 330.00 847.74 47.05 -27.16 2.50 2.50 0.00 0.00 1051.70 19.50 330.00 1039.88 94.76 -54.71 3.50 3.50 0.00 0.00 2567.64 68.20 294.08 2113.65 640.62 -883.87 3.50 3.21 -2.37 -42.96 16174.39 68.20 294.08 7165.81 5795.73 -12418.35 0.00 0.00 0.00 0.00 16568.56 82.00 294.08 7266.90 5950.78 -12765.28 3.50 3.50 0.00 -0.01 CD2-72wp06 Heel 16926.63 90.00 301.27 7291.89 6116.54 -13081.09 3.00 2.23 2.01 42.20 18074.42 90.14 335.71 7290.44 6963.16 -13830.41 3.00 0.01 3.00 89.75 21568.33 90.14 335.71 7281.90 10147.66 -15267.86 0.00 0.00 0.00 0.00 CD2-72wp02 Toe Plan: CD2-72wp07 Date Composed: 4/3/2007 AW1A Version: 21 Principai: Yes Tied-to: From Well Ref. Point Field: Colville River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 ' Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) l Coordinate System: Well Centre Sys Datum: Mean Sea Level - Geomagnetic Model: bggm2006 Site: Alpine CD2 CD2-15 Center of Pad Site Position: Northing: 5974641.66 ft Latitude: 70 20 20.225 N From: Map Easting: 371696.24 ft Longitude: 151 2 28.083 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Coovergence: -0.98 deg Well: Plan: CD2-72 Slot Name: Alpine West Well Position: +N/-S -491.73 ft Northing: 5974157.53 ft~ Latitude: 70 20 15.389 N +E/-W -437.78 ft Easting : 371250.15 ft~ Longitude: 151 2 40.869 W Position Uncertainty: 0.00 ft Wellpath: Plan: CD2-72 Drilled From: Well Ref. Point Tie-on Depth: 36.30 ft Current Datum: CD2-72wp07 Height 53.90 ft Above System Datum: Mean Sea ~evel ~ Magnetic Data: 4/19/2007 Declination: 22.80 deg Field Strength: 57562 nT Mag Dip Angle: 80.70 deg Vertical Section: Depth From (1'VD) +N/-S +E/-W Direction ft ft ft deg 36.30 0.00 0.00 303.00 Survey Program for Definitive Welipath Date: 4/3/2007 Validated: No Version: 0 Actual From To Survey Toolcode Tool Name ft ft ~~~GIC~~L WELL DETAILS Name +N/-S +E/-W Northing Easting Latitude Longitude Slot Plan: CD2-72 -491.73 -437.78 5974157.53 371250.15 70°20'15.389N 151°02'40.869W N/A WELLPATH DETAILS Plan: CD2-72 Rig: Doyon 19 Ref Datum: CD2-72wp07 53.90ft V.Section Origin Origin Starting Angle +N/-S +E/-W From TVD 303.00° 0.00 0.00 36.30 T M Azimuths to True North Magnetic North: 22.80° Magnetic Field Strength: 57562nT Dip Angle: 80.70° Date: 4/19/2007 Model: bggm2006 SURVEY PROGRAM Depth Fm Depth To Survey/Plan Tool 3630 1001.70 Planned: CD2-72wp07 V21 CB-GYRO-SS 1001.70 2156833 Planned: CD2-72wp07 V21 MWD+IFR-AK-CAZ-SC a a ~ ~ > 2 F PLAN DETAILS CD2-72wp07 AW1A Version 21 4/3/2007 Start Point MD Inc Azi TVD +N/-S +E/-W 36.30 0.00 0.00 36.30 0.00 0.00 "a"~~"RT°" ~onocaPhillips spsrry D~illing serokes ~I~ Vertical Section at 303.00° [SOOOft/in] 15000 'D2-72w 07 I ' ' ' I I 1000 ~ a ' oo I o ~ ~ o0 ~ ~ 500 o ~ ~ ho 5 I N . . _ ... . .. _...._ oo . ,. '~ . .~. o I . I ~° p0 0 - I I I _ , ' ' -- ' -15000 -10000 -5000 0 West(-)/East(+) [SOOOft/in] REFERENCE INFORMATION Co-ordinate (NB) Reference: Well CenVe: Plan: CD2-72, True North ~ Vertical (TVD) Reference: CD2-72wp07 53.90 Section (VS Reference: Slot - (O.OON,O.OOE) Measured Dept Reference: CD2-72wp07 53.90 Calculation Method: Minimum Curvature ~ ~ ~ ConocoPhillips Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska InC. Date: 4/20/2007 Time: 13:00:45 Page: 2 Field: Colville River Unit Go-ordinate(NE) Reference: Weil: Plan: CD2-72, Tru~ North ~ Site: Aipine CD2 Vertica l (1'VD) Reference: C D2-72wp07 53,9 i We1L• Plan: C D2-72 Sec tion (VS) Reference: ''WeII (O.OON,O .UOE,303.OOAzi) Wetlpath: Plan. C D2-72 Survey Calcula6on Method: Minimum Curvature Db: Oracie Survey NID Incl Azim TVD Sys TVD N/S E/W MapN M$pE DLS VS Comme t ft deg deg ft ft ft ft ft ft deg/100ft ft 36. 30 0 .00 0 .00 36 .30 -17 .60 0 .00 0 .00 5974157 .53 371250 .15 0.00 0 .00 100. 00 0. 00 0 .00 100 .00 46 .10 0 .00 0 .00 5974157. 53 371250 .15 0.00 0 .00 200. 00 0. 00 0 .00 200 .00 146 .10 0 .00 0 .00 5974157. 53 371250 .15 0.00 0 .00 300. 00 0. 00 0 .00 300 .00 246 .10 0 .00 0 .00 5974157. 53 371250 .15 0.00 0 .00 351. 70 0. 00 0 .00 351 .70 297. 80 0 .00 0 .00 5974157. 53 371250 .15 0.00 0 .00 KOP; 2.5 DLS, 3 400. 00 1. 21 330 .00 400 .00 346. 10 0 .44 -0 .25 5974157. 98 371249. 90 2.50 0 .45 500. 00 3. 71 330 .00 499 .90 446. 00 4 .15 -2 .40 5974161. 72 371247. 82 2.50 4 .27 600. 00 6. 21 330 .00 599 .51 545. 61 11 .64 -6 .72 5974169. 28 371243 .63 2.50 11 .97 651. 70 7. 50 330 .00 650 .84 596. 94 16 .98 -9 .80 5974174. 67 371240 .64 2.50 17 .47 700. 00 8. 71 330 .00 698 .66 644. 76 22 .88 -13 .21 5974180. 63 371237 .34 2.50 23 .54 800. 00 11. 21 330 .00 797 .15 743 .25 37 .85 -21 .85 5974195. 75 371228 .95 2.50 38 .94 851. 70 12. 50 330 .00 847 .74 793 .84 47 .05 -27 .16 5974205. 03 371223 .80 2.50 48 .40 Build; 3.5 DLS 900. 00 14. 19 330 .00 894 .74 840 .84 56 .70 -32 .74 5974214. 78 371218 .39 3.50 58 .34 1000. 00 17. 69 330 .00 990 .88 936 .98 80 .48 -46 .47 5974238. 79 371205 .08 3.50 82 .80 1051. 70 19. 50 330 .00 1039 .88 985 .98 94 .76 -54 .71 5974253 .21 371197 .08 3.50 97 .49 1100. 00 20. 77 326 .75 1085 .22 1031. 32 108 .90 -63 .44 5974267. 50 371188. 60 3.50 112 .51 1200. 00 23. 56 321 .12 1177 .84 1123. 94 139 .29 -85 .70 5974298. 26 371166 .86 3.50 147 .74 1300. 00 26. 50 316 .66 1268 .45 1214 .55 171 .09 -113 .57 5974330. 53 371139 .55 3.50 188 .43 1400. 00 29. 56 313 .04 1356 .71 1302. 81 204 .16 -146 .92 5974364. 17 371106 .77 3.50 234 .42 1500. 00 32. 71 310 .06 1442 .30 1388 .40 238 .40 -185 .64 5974399. 06 371068 .64 3.50 285 .54 1600. 00 35. 91 307 .54 1524 .90 1471 .00 273 .66 -229 .59 5974435. 07 371025 .31 3.50 341 .60 1700. 00 39. 15 305 .39 1604 .19 1550 .29 309 .83 -278 .59 5974472. 07 370976 .94 3.50 402 .39 1800. 00 42. 43 303 .53 1679 .89 1625 .99 346 .76 -332 .47 5974509. 92 370923 .71 3.50 467 .69 1900. 00 45. 74 301 .88 1751 .71 1697 .81 384 .32 -391 .02 5974548. 47 370865 .82 3.50 537 .25 2000. 00 49. 07 300 .41 1819 .38 1765 .48 422 .36 -454 .03 5974587. 59 370803 .48 3.50 610 .81 2100. 00 52. 42 299 .08 1882 .65 1828 .75 460 .75 -521 .25 5974627. 13 370736 .93 3.50 688 .11 2200. 00 55. 77 297 .86 1941 .29 1887. 39 499 .35 -592 .45 5974666. 93 370666. 4T 3.50 768 .84 2300. 00 59. 14 296 .74 1995 .07 1941. 17 538 .00 -667 .36 5974706. 86 370592. 18 3.50 852 .71 2400. 00 62. 52 295 .70 2043 .80 1989. 90 576 .56 -745 .68 5974746. 76 370514. 54 3.50 939 .40 2500. 00 65. 91 294 .72 2087 .29 2033. 39 614 .90 -827 .15 5974786. 49 370433. 75 3.50 1028 .60 2567. 64 68. 20 294 .08 2113 .65 2059. 75 640 .62 -883 .87 5974813. 18 370377. 48 3.50 1090 .18 Sail; 68.2° for 13 2600. 00 68. 20 294 .08 2125 .67 2071. 77 652 .88 -911 .30 5974825. 91 370350. 27 0.00 1119 .87 2700. 00 68. 20 294 .08 2162 .80 2108. 90 690 .77 -996 .07 5974865. 24 370266. 17 0.00 1211 .59 2800. 00 68. 20 294 .08 2199 .93 2146. 03 728 .66 -1080 .84 5974904. 57 370182 .07 0.00 1303 .32 2900. 00 68. 20 294 .08 2237 .06 2183. 16 766 .54 -1165 .61 5974943. 91 370097 .97 0.00 1395 .05 3000. 00 68. 20 294 .08 2274 .19 2220. 29 804 .43 -1250 .38 5974983. 24 370013 .86 0.00 1486 .78 3100. 00 68. 20 294 .08 2311 .32 2257 .42 842 .31 -1335 .15 5975022. 57 369929 .76 0.00 1578 .51 3200. 00 68. 20 294 .08 2348 .45 2294. 55 880 .20 -1419 .92 5975061. 91 369845 .66 0.00 1670 .24 3300. 00 68. 20 294 .08 2385 .58 2331. 68 918 .09 -1504 .69 5975101. 24 369761. 56 0.00 1761 .97 3338. 84 68. 20 294 .08 2400 .00 2346. 10 932 .80 -1537 .62 5975116. 52 369728. 90 0.00 1797 .60 10 3/4" 3373. 58 68. 20 294 .08 2412 .90 2359. 00 945 .97 -1567 .07 5975130. 18 369699. 68 0.00 1829 .47 C-30 3400. 00 68. 20 294 .08 2422 .71 2368. 81 955 .97 -1589 .46 5975140. 57 369677. 46 0.00 1853 .70 3500. 00 68. 20 294 .08 2459 .84 2405. 94 993 .86 -1674 .23 5975179. 91 369593 .36 0.00 1945 .42 3600. 00 68. 20 294 .08 2496 .97 2443. 07 1031 .75 -1759 .00 5975219. 24 369509 .26 0.00 2037 .15 3700. 00 68. 20 294 .08 2534 .10 2480 20 1069 .63 -1843 .77 5975258. 57 369425 .16 0.00 2128 .88 3800. 00 68. 20 294 .08 2571 .23 2517 .33 1107 .52 -1928 .54 5975297. 91 369341 .06 0.00 2220 .61 3900. 00 68. 20 294 .08 2608 .36 2554 .46 1145 .41 -2013 .31 5975337. 24 369256 .96 0.00 2312 .34 4000. 00 68. 20 294 .08 2645 .49 2591 .59 1183 .29 -2098 .08 5975376. 57 369172 .86 0.00 2404 .07 4100. 00 68. 20 294 .08 2682 .62 2628 .72 1221 .18 -2182 .85 5975415. 91 369088 .76 0.00 2495 .80 4200. 00 68. 20 294 .08 2719 .75 2665. 85 1259 .06 -2267 .63 5975455. 24 369004. 66 0.00 2587 .53 4300. 00 68. 20 294 .08 2756 .88 2702. 98 1296 .95 -2352 .40 5975494. 57 368920. 56 0.00 2679 .26 4359. 32 68. 20 294 .08 2778 .90 2725. 00 1319 .42 -2402 .68 5975517. 90 368870. 67 0.00 2733 .67 C-20 4400. 00 68. 20 294 .08 2794 .01 2740. 11 1334 .84 -2437 .17 5975533. 90 368836. 46 0.00 2770 .98 Mi ~ ~ ~ ~ ~ ~l ~ ~ ~ ~ ConocoPhillips Alaska, Inc. CPAI Report Company: ConoCOPhillips Alaska InC. Date: 4/20/2007 Time: 11:00:45 Page: 3, Field: Colville River Un it Co-ordinate(NE) Re ferencec Well: Plan: CD2-72, True NOrth Site: Al pine CD2 Vertica l (TVD) Refereace: C D2-72wp07 53 .9 We1L• Pl an: C D2-72 Sec tion (VS) Reference: Well (O.OON,0.04E,303.QOAzi) Wellpath: Plan: C D2-~2 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVb N/S E/W MapN MapE DLS VS Comme t ft deg deg ft ft ft ft ft ft deg/100ft ft 4500. 00 68. 20 294 .08 2831 .14 2777. 24 1372 .72 -2521 .94 5975573. 24 368752 .36 0.00 2862 .71 4600. 00 68. 20 294 .08 2868 .26 2814 .36 1410 .61 -2606 .71 5975612. 57 368668 .26 0.00 2954 .44 4700. 00 68. 20 294 .08 2905 .39 2851 .49 1448 .50 -2691 .48 5975651. 90 368584 .16 0.00 3046 .17 4800. 00 68. 20 294 .08 2942 .52 2888 .62 1486 .38 -2776 .25 5975691. 24 368500 .06 0.00 3137 .90 4900. 00 68. 20 294 .08 2979 .65 2925 .75 1524 .27 -2861 .02 5975730. 57 368415 .96 0.00 3229 .63 5000. 00 68. 20 294 .08 3016 .78 2962 .88 1562 .16 -2945 .79 5975769. 90 368331 .86 0.00 3321 .36 5100. 00 68. 20 294 .08 3053 .91 3000 .01 1600 .04 -3030 .56 5975809. 24 368247 .75 0.00 3413 .09 5200. 00 68. 20 294 .08 3091 .04 3037 .14 1637 .93 -3115 .33 5975848. 57 368163 .65 0.00 3504 .81 5300. 00 68. 20 294 .08 3128 .17 3074 .27 1675 .82 -3200 .10 5975887. 90 368079 .55 0.00 3596 .54 5400. 00 68. 20 294 .08 3165 .30 3111 ,40 1713 .70 -3284 .87 5975927. 24 367995 .45 0.00 3688 .27 5500. 00 68 .20 294 .08 3202 .43 3148 .53 1751 .59 -3369 .64 5975966. 57 367911 .35 0.00 3780 .00 5600. 00 68 .20 294 .08 3239 .56 3185 .66 1789 .47 -3454 .41 5976005. 90 367827 .25 0.00 3871 .73 5700. 00 68. 20 294 .08 3276 .69 3222 .79 1827 .36 -3539 .18 5976045. 23 367743 .15 O.QO 3963 .46 5800. 00 68. 20 294 .08 3313 .82 3259. 92 1865 .25 -3623 .95 5976084. 57 367659 .05 0.00 4055 .19 5900. 00 68. 20 294 .08 3350 .95 3297 .05 1903 .13 -3708 .72 5976123. 90 367574 .95 0.00 4146 .92 6000. 00 68. 20 294 .08 3388 .08 3334. 18 1941 .02 -3793 .49 5976163. 23 367490 .85 0.00 4238 .64 6100. 00 68. 20 294 .08 3425 .21 3371. 31 1978 .91 -3878 .26 5976202. 57 367406 .75 0.00 4330 .37 6200. 00 68. 20 294 .08 3462 .34 3408. 44 2016 .79 -3963 .03 5976241. 90 367322 .65 0.00 4422 .10 6300. 00 68. 20 294 .08 3499 .47 3445. 57 2054 .68 -4047 .80 5976281. 23 367238 .55 0.00 4513 .83 6400. 00 68. 20 294 .08 3536 .60 3482. 70 2092 .57 -4132 .57 5976320. 57 367154 .45 0.00 4605 .56 6500. 00 68. 20 294 .08 3573 .73 3519. 83 2130 .45 -4217 .34 5976359. 90 367070 .35 0.00 4697 .29 6600. 00 68. 20 294 .08 3610 .86 3556. 96 2168 .34 -4302 .11 5976399. 23 366986 .25 0.00 4789 .02 6700. 00 68. 20 294 .08 3647 .99 3594 .09 2206 .22 -4386 .88 5976438. 57 366902 .15 0.00 4880 .75 6800. 00 68. 20 294 .08 3685 .12 3631 .22 2244 .11 -4471 .65 5976477. 90 366818 .05 0.00 4972 .47 6900. 00 68. 20 294 .08 3722 .25 3668 .35 2282 .00 -4556 .42 5976517. 23 366733 .95 0.00 5064 .20 7000. 00 68. 20 294 .08 3759 .38 3705 .48 2319 .88 -4641 .19 5976556. 57 366649 .85 0.00 5155 .93 7100. 00 68. 20 294 .08 3796 .51 3742 .61 2357 .77 -4725 .96 5976595. 90 366565 .75 0.00 5247 .66 7200. 00 68. 20 294 .08 3833 .64 3779. 74 2395 .66 -4810 .73 5976635. 23 366481. 65 0.00 5339 .39 7222. 25 68. 20 294 .08 3841 .90 3788. 00 2404 .09 -4829 .60 5976643. 98 366462. 93 0.00 5359 .80 K-3 Marker 7300. 00 68. 20 294 .08 3870 .77 3816. 87 2433 .54 -4895 .50 5976674. 56 366397. 54 0.00 5431 .12 7400. 00 68. 20 294 .08 3907 .90 3854. 00 2471 .43 -4980 .27 5976713. 90 366313 .44 0.00 5522 .85 7500. 00 68. 20 294 .08 3945 .03 3891 .13 2509 .32 -5065 .04 5976753. 23 366229 .34 0.00 5614 .58 7600. 00 68. 20 294 .08 3982 .16 3928 .26 2547 .20 -5149 .82 5976792. 56 366145 .24 0.00 5706 .30 7700. 00 68. 20 294 .08 4019 .29 3965 .39 2585 .09 -5234 .59 5976831. 90 366061 .14 0.00 5798 .03 7752. 82 68. 20 294 .08 4038 .90 3985 .00 2605 .10 -5279 .36 5976852. 67 366016 .72 0.00 5846 .49 Basal K-3 7800. 00 68. 20 294 .08 4056 .42 4002 .52 2622 .98 -5319 .36 5976871. 23 365977 .04 0.00 5889 .76 7825. 54 68. 20 294 .08 4065 .90 4012 .00 2632 .65 -5341 .01 5976881. 28 365955 .56 0.00 5913 .19 K-2 Marker 7900. 00 68. 20 294 .08 4093 .55 4039 .65 2660 .86 -5404 .13 5976910. 56 365892 .94 0.00 5981 .49 8000. 00 68. 20 294 .08 4130 .68 4076 .78 2698 .75 -5488 .90 5976949. 90 365808 .84 0.00 6073 .22 8059. 86 68. 20 294 .08 4152 .90 4099 .00 2721 .42 -5539 .64 5976973. 44 365758 .50 0.00 6128 .12 Basal K-2 8100. 00 68. 20 294 .08 4167 .81 4113 .91 2736 .63 -5573 .67 5976989. 23 365724 .74 0.00 6164 .95 8200. 00 68. 20 294 .08 4204 .94 4151 .04 2774 .52 -5658 .44 5977028. 56 365640 .64 0.00 6256 .68 8300. 00 68. 20 294 .08 4242 .07 4188. 17 2812 .41 -5743 .21 5977067. 90 365556. 54 0.00 6348 .41 8400. 00 68. 20 294 .08 4279 .19 4225. 29 2850 .29 -5827 .98 5977107. 23 365472. 44 0.00 6440 .13 8500. 00 68. 20 294 .08 4316 .32 4262. 42 2888 .18 -5912 .75 5977146. 56 365388. 34 0.00 6531 .86 8600. 00 68. 20 294 .08 4353 .45 4299. 55 2926 .07 -5997 .52 5977185. 89 365304. 24 0.00 6623 .59 8700. 00 68. 20 294 .08 4390 .58 4336. 68 2963 .95 -6082 .29 5977225. 23 365220. 14 0.00 6715 .32 8800. 00 68. 20 294 .08 4427 .71 4373. 81 3001 .84 -6167 .06 5977264. 56 365136. 04 0.00 6807 .05 8900. 00 68. 20 294 .08 4464 .84 4410. 94 3039 .73 -6251 .83 5977303. 89 365051. 94 0.00 6898 .78 9000. 00 68. 20 294 .08 4501 .97 4448. 07 3077 .61 -6336 .60 5977343. 23 364967 .84 0.00 6990 .51 9100. 00 68. 20 294 .08 4539 .10 4485. 20 3115 .50 -6421 .37 5977382. 56 364883 .74 0.00 7082 .24 9200. 00 68. 20 294 .08 4576 .23 4522. 33 3153 .38 -6506 .14 5977421. 89 364799 .64 0.00 7173 .96 ~~~~C~~~ ~ onocoPhillips Alaska, Inc. CPAI Report Company: ConOCOPhillips Alaska Ina Date: 4/20/2007 Time: 11: 00:45 Page: 4 Field., Colville River Un it Co-ordinate(NE) Re ference: - Well: Plan: CD2-72, True North Site: Alpine CD2 Vertica l (TVD) Refe rence: ' C D2-72wp07 53.9 We1L• Plan: C D2-72 Section (VS) Reference: WeIF (O.OON,O .OOE,303.OOAzi)- Wellpath: Plan: C D2-72 Survey CalculatioaMethod: Minimum Curvature bb: Oracle Sur~ ey ;NID Incl Azim TVD Sys TVD N/S E/W MapN MapE DIS VS Comme t ft deg deg ft ft ft ft ft ft deg/100ft #t Ei300. 00 68 .20 294 .08 4613 .36 4559 .46 3191 .27 -6590.91 5977461 .23 364715 .54 0.00 7265 .69 Ei400. 00 68 .20 294 .08 4650 .49 4596 .59 3229 .16 -6675.68 5977500 .56 364631 .43 0.00 7357 .42 Si500. 00 68 .20 294 .08 4687 .62 4633 .72 3267 .04 -6760.45 5977539 .89 364547 .33 0.00 7449 .15 5i600. 00 68. 20 294 .08 4724 .75 4670 .85 3304 .93 -6845.22 5977579 .23 364463 .23 0.00 7540 .88 £i700. 00 68. 20 294 .08 4761 .88 4707 .98 3342 .82 -6929.99 5977618. 56 364379 .13 0.00 7632 .61 £i800. 00 68. 20 294 .08 4799 .01 4745 .11 3380 .70 -7014.76 5977657. 89 364295 .03 0.00 7724 .34 Ei900. 00 68. 20 294 .08 4836 .14 4782 .24 3418 .59 -7099.53 5977697. 23 364210 .93 0.00 7816 .07 1 C1000. 00 68. 20 294 .08 4873 .27 4819 .37 3456 .48 -7184.30 5977736. 56 364126 .83 0.00 7907 .79 1 C1100. 00 68. 20 294 .08 4910 .40 4856 .50 3494 .36 -7269.07 5977775. 89 364042 .73 0.00 7999 .52 1 Ci200. 00 68. 20 294 .08 4947 .53 4893 .63 3532 .25 -7353.84 5977815. 22 363958 .63 0.00 8091 .25 1 C1300. 00 68. 20 294 .08 4984 .66 4930 .76 3570 .14 -7438.61 5977854. 56 363874 .53 0.00 8182 .98 1 C1400. 00 68. 20 294 .08 5021 .79 4967 .89 3608 .02 -7523.38 5977893. 89 363790 .43 0.00 8274 .71 1 C1500. 00 68. 20 294 .08 5058 .92 5005 .02 3645 .91 -7608.15 5977933. 22 363706 .33 0.00 8366 .44 1 C1600. 00 68. 20 294 .08 5096 .05 5042 .15 3683 .79 -7692.92 5977972. 56 363622 .23 0.00 8458 .17 1 Ci672. 32 68. 20 294 .08 5122 .90 5069 .00 3711 .19 -7754.23 5978001. 00 363561 .41 0.00 8524 .50 Albian 97 1 C1700. 00 68. 20 294 .08 5133 .18 5079. 28 3721 .68 -7777.69 5978011. 89 363538. 13 0.00 8549 .90 1 C1800. 00 68. 20 294 .08 5170 .31 5116. 41 3759 .57 -7862.46 5978051. 22 363454. 03 0.00 8641 .62 1 C1900. 00 68. 20 294 .08 5207 .44 5153. 54 3797 .45 -7947.23 5978090. 56 363369. 93 0.00 8733 .35 11000. 00 68. 20 294 .08 5244 .57 5190. 67 3835 .34 -8032.01 5978129. 89 363285 .83 0.00 8825 .08 11100. 00 68. 20 294 .08 5281 .70 5227. 80 3873 .23 -8116.78 5978169. 22 363201 .73 0.00 8916 .81 11200. 00 68. 20 294 .08 5318 .83 5264 .93 3911 .11 -8201.55 5978208. 56 363117 .63 0.00 9008 .54 11300. 00 68. 20 294 .08 5355 .96 5302 .06 3949 .00 -8286.32 5978247. 89 363033 .53 0.00 9100 .27 11400. 00 68. 20 294 .08 5393 .09 5339 .19 3986 .89 -8371.09 5978287. 22 362949 .43 0.00 9192 .00 11500. 00 68. 20 294 .08 5430 .22 5376 .32 4024 .77 -8455.86 5978326. 56 362865 .32 0.00 9283 .73 11600. 00 68. 20 294 .08 5467 .35 5413 .45 4062 .66 -8540.63 5978365. 89 362781 .22 0.00 9375 .45 11700. 00 68. 20 294 .08 5504 .48 5450 .58 4100 .54 -8625.40 5978405. 22 362697 .12 0.00 9467 .18 11800. 00 68. 20 294 .08 5541 .61 5487. 71 4138 .43 -8710.17 5978444. 55 362613. 02 0.00 9558 .91 11900. 00 68. 20 294 .08 5578 .74 5524. 84 4176 .32 -8794.94 5978483. 89 362528. 92 0.00 9650 .64 12000. 00 68. 20 294 .08 5615 .87 5561. 97 4214 .20 -8879.71 5978523. 22 362444. 82 0.00 9742 .37 12100. 00 68. 20 294 .08 5653 .00 5599. 10 4252 .09 -8964.48 5978562. 55 362360. 72 0.00 9834 .10 1~!200. 00 68. 20 294 .08 5690 .13 5636. 23 4289 .98 -9049.25 5978601. 89 362276. 62 0.00 9925 .83 1~!300. 00 68. 20 294 .08 5727 .25 5673. 35 4327 .86 -9134.02 5978641. 22 362192. 52 0.00 10017 .56 11400. 00 68. 20 294 .08 5764 .38 5710. 48 4365 .75 -9218.79 5978680. 55 362108. 42 0.00 10109 .29 11500. 00 68. 20 294 .08 5801 .51 5747. 61 4403 .64 -9303.56 5978719. 89 362024. 32 0.00 10201 .01 1~!565. 68 68. 20 294 .08 5825 .90 5772. 00 4428 .52 -9359.23 5978745. 72 361969. 09 0.00 10261 .26 Albian 96 12600. 00 68. 20 294 .08 5838 .64 5784. 74 4441 .52 -9388.33 5978759. 22 361940. 22 0.00 10292 .74 12700. 00 68 20 294 .08 5875 .77 5821. 87 4479 .41 -9473.10 5978798. 55 361856. 12 0.00 10384 .47 1~!800. 00 68. 20 294 .08 5912 .90 5859. 00 4517 .30 -9557.87 5978837. 89 361772 .02 0.00 10476 .20 12900. 00 68 20 294 .08 5950 .03 5896. 13 4555 .18 -9642.64 5978877. 22 361687. 92 0.00 10567 .93 18000. 00 68. 20 294 .08 5987 .16 5933. 26 4593 .07 -9727.41 5978916. 55 361603. 82 0.00 10659 .66 1;{100. 00 68. 20 294 .08 6024 .29 5970. 39 4630 .95 -9812.18 5978955. 88 361519. 72 0.00 10751 .39 1:5200. 00 68. 20 294 .08 6061 .42 6007. 52 4668 .84 -9896.95 5978995. 22 361435. 62 0.00 10843 .12 1;5300. 00 68. 20 294 .08 6098 .55 6044. 65 4706 .73 -9981.72 5979034. 55 361351. 52 0.00 10934 .84 1;l400. 00 68. 20 294 .08 6135 .68 6081. 78 4744 .61 -1.Oe04 5979073. 88 361267. 42 0.00 11026 .57 1;f500. 00 68. 20 294 .08 6172 .81 6118. 91 4782 .50 -1.Oe04 5979113. 22 361183. 32 0.00 11118 .30 1:i600. 00 68. 20 294 .08 6209 .94 6156. 04 4820 .39 -1.Oe04 5979152. 55 361099. 21 0.00 11210 .03 1:f700. 00 68. 20 294 .08 6247 .07 6193. 17 4858 .27 -1.Oe04 5979191. 88 361015 .11 0.00 11301 .76 1:f800. 00 68, 20 294 .08 6284 .20 6230 .30 4896 .16 -1.Oe04 5979231. 22 360931 .01 0.00 11393 .49 1:f900. 00 68, 20 294 .08 6321 .33 6267 .43 4934 .05 -1.Oe04 5979270. 55 360846 .91 0.00 11485 .22 14000. 00 68, 20 294 .08 6358 .46 6304 .56 4971 .93 -1.Oe04 5979309. 88 360762 .81 0.00 11576 .95 1~4100. 00 68. 20 294 .08 6395 .59 6341. 69 5009 .82 -1.Oe04 5979349. 22 360678. 71 0.00 11668 .67 1~G200. 00 68. 20 294 .08 6432 .72 6378. 82 5047 .70 -1.Oe04 5979388. 55 360594. 61 0.00 11760 .40 1~G300. 00 68. 20 294 .08 6469 .85 6415. 95 5085 .59 -1.Oe04 5979427. 88 360510. 51 0.00 11852 .13 ~ ~ ~ ~ ~ ~ ~ ~ ~ onocoPhillips Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska Inc. Date: 4/20/2007 Time: 11 `00:45 P~ge: 5 Field: Colviile River Un it Co-ordiaate(NE}Rt #erence: WeIL' Plan: CD2-72, True North Site: Al pine CD2 Vertical (TVD} Refe rence: C D2-72wp07 53.9 Well: Pl an: C D2-72 Section (VS) Reference: Well (O.OON,O .OOE,303.OOAzi) Wellpath: Pl an: C D2-72 Survey Calcuta6ou Method: Minimum Curvature Db:- Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE DLS VS Comme t ft deg deg ft ft ft ft ft ft deg/100ft ft 14400 .00 68. 20 294 .08 6506 .98 6453. 08 5123 .48 -1.Oe04 5979467. 22 360426 .41 0.00 11943 .86 14500 .00 68. 20 294 .08 6544 .11 6490. 21 5161 .36 -1.Oe04 5979506. 55 360342 .31 0.00 12035 .59 14600 .00 68. 20 294 .08 6581 .24 6527. 34 5199 .25 -1.1e04 5979545. 88 360258 .21 0.00 12127 .32 14700 .00 68. 20 294 .08 6618 .37 6564. 47 5237 .14 -1.1e04 5979585. 21 360174 .11 0.00 12219 .05 14800 .00 68. 20 294 .08 6655 .50 6601. 60 5275 .02 -1.1e04 5979624. 55 360090 .01 0.00 12310 .78 14900 .00 68. 20 294 .08 6692 .63 6638. 73 5312 .91 -1.1e04 5979663. 88 360005 .91 0.00 12402 .50 15000 .00 68. 20 294 .08 6729 .76 6675. 86 5350 .80 -1.1e04 5979703. 21 359921. 81 0.00 12494 .23 15100 .00 68. 20 294 .08 6766 .89 6712. 99 5388 .68 -1.1e04 5979742. 55 359837. 71 0.00 12585 .96 15200 .00 68. 20 294 .08 6804 .02 6750. 12 5426 .57 -1.1e04 5979781. 88 359753. 61 0.00 12677 .69 15300 .00 68. 20 294 .08 6841 .15 6787. 25 5464 .46 -1.1e04 5979821. 21 359669. 51 0.00 12769 .42 15400 .00 68. 20 294 .08 6878 .28 6824. 38 5502 .34 -1.1e04 5979860. 55 359585. 41 0.00 12861 .15 15404 .37 68. 20 294 .08 6879 .90 6826. 00 5504 .00 -1.1e04 5979862. 27 359581. 73 0.00 12865 .16 HRZ 15500 .00 68. 20 294 .08 6915 .41 6861. 51 5540 .23 -4.1e04 5979899. 88 359501 .31 0.00 12952 .88 15600 .00 68. 20 294 .08 6952 .54 6898 .64 5578 .11 -1.1e04 5979939. 21 359417 .21 0.00 13044 .61 15700 .00 68. 20 294 .08 6989 .67 6935 .77 5616 .00 -1.2e04 5979978. 55 359333 .10 0.00 13136 .33 15800 .00 68. 20 294 .08 7026 .80 6972 .90 5653 .89 -1.2e04 5980017. 88 359249 .00 0.00 13228 .06 15878 .39 68. 20 294 .08 7055 .90 7002. 00 5683 .58 -1.2e04 5980048. 71 359183. 08 0.00 13299 .97 Base HRZ 15900 .00 68. 20 294 .08 7063 .93 7010. 03 5691 .77 -1.2e04 5980057. 21 359164. 90 0.00 13319 .79 16000 .00 68. 20 294 .08 7101 .06 7047. 16 5729 .66 -1.2e04 5980096. 54 359080. 80 0.00 13411 .52 16023 .82 68. 20 294 .08 7109 .90 7056. 00 5738 .69 -1.2e04 5980105. 91 359060. 77 0.00 13433 .37 K-1 Marker 16100 .00 68. 20 294 .08 7138 .18 7084. 28 5767 .55 -1.2e04 5980135. 88 358996. 70 0.00 13503 .25 16139 .63 68. 20 294 .08 7152 .90 7099. 00 5782 .56 -1.2e04 5980151. 47 358963. 37 0.00 13539 .60 Kuparuk Fm 16174 .39 68. 20 294 .08 7165 .81 7111. 91 5795 .73 -1.2e04 5980165. 14 358934. 14 0.00 13571 .49 Build; 3.5 DLS 16200 .00 69. 10 294 .08 7175 .13 7121. 23 5805 .46 -1.2e04 5980175. 24 358912. 54 3.50 13595 .05 16280 .23 71. 91 294 .08 7201 .90 7148. 00 5836 .32 -1.2e04 5980207. 28 358844. 04 3.50 13669 .76 LCU-Miluveach 16300 .00 72. 60 294 .08 7207. 93 7154. 03 5844 .OQ -1.2e04 5980215. 25 358826. 99 3.50 13688 .36 16400 .00 76. 10 294 .08 7234. 90 7181. 00 5883 .29 -1.2e04 5980256. 04 358739. 78 3.50 13783 .47 16448 .74 77. 81 294 .08 7245. 90 7192. 00 5902 .66 -1.2e04 5980276. 15 358696. 77 3.50 13830 .38 Miluveach A 16500 .00 79. 60 294 .08 7255. 94 7202. 04 5923 .17 -1.2e04 5980297. 44 358651. 25 3.50 13880 .04 16547 .92 81. 28 294 .08 7263. 90 7210. 00 5942 .45 -1.2e04 5980317. 46 358608. 44 3.50 13926 .72 Alpine D 16568 .56 82. 00 294 .08 7266. 90 7213. 00 5950 .78 -1.2e04 5980326. 11 358589. 96 3.50 13946 .89 CD2-72wp06 He I 16600 .00 82. 70 294 .72 7271. 09 7217. 19 5963 .65 -1.2e04 5980339. 46 358561. 80 3.00 13977 .70 16700 .00 84. 93 296 ,74 7281 .86 7227. 96 6006 .81 -1.2e04 5980384. 15 358473. 01 3.00 14076 .31 16766 .81 86. 42 298 .08 7286 .90 7233. 00 6037 .47 -1.2e04 5980415. 82 358414. 42 3.00 14142 .60 Alpine A Sand 16800 .00 87. 16 298 .74 7288 .76 7234. 86 6053 .24 -1.2e04 5980432. 09 358385. 55 3.00 14175 .64 16900 .00 89. 40 300 ,74 7291. 75 7237. 85 6102 .82 -1.3e04 5980483. 15 358299. 64 3.00 14275 .42 16926 .63 90. 00 301 .27 7291. 89 7237. 99 6116 .54 -1.3e04 5980497. 25 358277. 06 3.00 14302 .03 Land; 10' below t 17000 .00 90. 01 303 .47 7291. 88 7237. 98 6155 .82 -1.3e04 5980537. 59 358215. 78 3.00 14375 .40 17100 .00 90. 02 306 .47 7291. 86 7237. 96 6213 .14 -1.3e04 5980596. 30 358134. 85 3.00 14475 .33 17200 .00 90. 04 309 .47 7291 .81 7237. 91 6274 .66 -1.3e04 5980659. 16 358057. 11 3.00 14574 .94 17300 .00 90. 05 312 .47 7291 .73 7237. 83 6340 .22 -1.3e04 5980726. 00 357982. 76 3.00 14673 .96 17400 .00 90. 06 315 .47 7291 .64 7237. 74 6409 .65 -1.3e04 5980796. 65 357912. 01 3.00 14772 .12 17500 .00 90. 07 318 .47 7291 .52 7237. 62 6482 .74 -1.3e04 5980870. 90 357845. 05 3.00 14869 .15 17600 .00 90. 09 321 .47 7291 .38 7237. 48 6559 .31 -1.3e04 5980948. 55 357782. 07 3.00 14964 .78 17700 .00 90. 10 324 .47 7291. 22 7237. 32 6639 .13 -1.3e04 5981029. 39 357723. 25 3.00 15058 .76 17800 .00 90. 11 327 .47 7291. 04 7237. 14 6722 .00 -1.3e04 5981113. 20 357668. 73 3.00 15150 .81 17900 .00 90. 12 330 .47 7290. 84 7236. 94 6807 .69 -1.3e04 5981199. 75 357618. 68 3.00 15240 .70 18000 .00 90. 13 333 .47 7290. 62 7236. 72 6895 .95 -1.3e04 5981288. 80 357573. 22 3.00 15328 .18 18074 .42 90. 14 335 .71 7290. 44 7236. 54 6963 .16 -1.3e04 5981356. 55 357542. 45 3.00 15391 .57 18100 .00 90. 14 335 .71 7290. 38 7236. 48 6986 .48 -1.3e04 5981380. 04 357532. 33 0.00 15413 .09 18200 .00 90. 14 335 .71 7290. 14 7236. 24 7077 .62 -1.3e04 5981471. 87 357492. 76 0.00 15497 .24 18300 .00 90. 14 335 .71 7289. 89 7235. 99 7168 .77 -1.3e04 5981563. 70 357453. 19 0.00 15581 .38 ~~~~~~~~ i !~ ConocoPhillips Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska Inc. Date: 4/20/2007 Time: 91:00:45 Page: 6 Field: Colville River Unit Go-ordinate(NE) Re ference: Vtteil: Plan: CD2-72, True North Site: Alpine CD2 Vertica l (TVD) Reference: ' G D2-72wp07 53.9 We1L• Plan: CD2-72 Section (VS) Reference: WeII (O;OUN,O .OOE,303 .OOAzi) Wellpath: Pian: CD2-72 Sarvey CalculaNon Method: Minimum Curvature Db:' QraGe Survey NID Incl Azim TVD Sys TVD N!S E/W MapN MapE DLS VS Comme t ft deg deg ft ft `ft ft ft ft deg/100ft ft 18400.00 90.14 335.71 7289.65 7235 .75 7259. 91 -1.3e04 5981655 .53 357413 .63 0.00 15665. 53 18500.00 90.14 335.71 7289.40 7235 .50 7351. 06 -1.4e04 5981747. 36 357374 .06 0.00 15749. 67 18600.00 90.14 335.71 7289.16 7235 .26 7442. 20 -1.4e04 5981839 .19 357334 .49 0.00 15833. 82 18700.00 90.14 335.71 7288.91 7235 .01 7533. 34 -1.4e04 5981931 .02 357294 .92 0.00 15917. 96 18800.00 90.14 335.71 7288.67 7234 .77 7624. 49 -1.4e04 5982022 .85 357255 .35 0.00 16002. 11 18900.00 90.14 335.71 7288.42 7234 .52 7715. 63 -1.4e04 5982114 .68 357215 .79 0.00 16086. 25 19000.00 90.14 335.71 7288.18 7234 .28 7806. 78 -1.4e04 5982206 .51 357176 .22 0.00 16170. 40 19100.00 90.14 335.71 7287.94 7234 .04 7897. 92 -1.4e04 5982298 .34 357136 .65 0.00 16254. 54 19200.00 90.14 335.71 7287.69 7233 .79 7989. 07 -1.4e04 5982390 .17 357097 .08 0.00 16338. 69 19300.00 90.14 335.71 7287.45 7233 .55 8080. 21 -1.4e04 5982482 .00 357057 .52 0.00 16422. 83 19400.00 90.14 335.71 7287.20 7233 .30 8171. 35 -1.4e04 5982573 .83 357017 .95 0.00 16506. 98 19500.00 90.14 335.71 7286.96 7233 .06 8262. 50 -1.4e04 5982665 .66 356978 .38 0.00 16591. 12 19600.00 90.14 335.71 7286.71 7232 .81 8353. 64 -1.4e04 5982757 .49 356938 .81 0.00 16675. 27 19700.00 90.14 335.71 7286.47 7232 .57 8444. 79 -1.4e04 5982849 .31 356899 .25 0.00 16759. 41 19800.00 90.14 335.71 7286.22 7232 .32 8535. 93 -1.4e04 5982941. 14 356859 .68 0.00 16843. 56 19900.00 90.14 335.71 7285.98 7232 .08 8627. 08 -1.4e04 5983032. 97 356820 .11 0.00 16927. 70 20000.00 90.14 335.71 7285.73 7231 .83 8718. 22 -1.4e04 5983124. 80 356780 .54 0.00 17011. 85 20100.00 90.14 335.71 7285.49 7231 .59 8809. 37 -1.4e04 5983216. 63 356740 .98 0.00 17096. 00 20200.00 90.14 335.71 7285.25 7231 .35 8900. 51 -1.4e04 5983308. 46 356701 .41 0.00 17180. 14 20300.00 90.14 335.71 7285.00 7231 .10 8991. 65 -1.4e04 5983400. 29 356661 .84 0.00 17264. 29 20400.00 90.14 335.71 7284.76 7230 .86 9082. 80 -1.4e04 5983492. 12 356622 .27 0.00 17348. 43 20500.00 90.14 335.71 7284.51 7230 .61 9173. 94 -1.4e04 5983583. 95 356582 .70 0.00 17432. 58 20600.00 90.14 335.71 7284.27 7230 .37 9265. 09 -1.4e04 5983675. 78 356543 .14 0.00 17516. 72 20700.00 90.14 335.71 7284.02 7230 .12 9356. 23 -1.4e04 5983767. 61 356503 .57 0.00 17600. 87 20800.00 90.14 335.71 7283.78 7229 .88 9447. 38 -1.4e04 5983859. 44 356464 .00 0.00 17685. 01 20900.00 90.14 335.71 7283.53 7229 .63 9538. 52 -1.4e04 5983951. 27 356424 .43 0.00 17769. 16 29000.00 90.14 335.71 7283.29 7229 .39 9629. 66 -1.5e04 5984043. 10 356384 .87 0.00 17853. 30 21100.00 90.14 335.71 7283.05 7229. 15 9720. 81 -1.5e04 5984134. 93 356345 .30 0.00 17937. 45 21200.00 90.14 335.71 7282.80 7228. 90 9811. 95 -1.5e04 5984226. 76 356305 .73 0.00 18021. 59 21300.00 90.14 335.71 7282.56 7228 .66 9903. 10 -1.5e04 5984318. 59 356266 .16 0.00 18105. 74 21400.00 90.14 335.71 7282.31 7228 .41 9994. 24 -1.5e04 5984410. 42 356226 .60 0.00 18189. 88 21500.00 90.14 335.71 7282.07 7228 .17 1.OOe04 -1.5e04 5984502. 25 356187 .03 0.00 18274. 03 . 21568.33 90.14 335.71 7281.90 ~ 7228 .00 1.01 e04 -1.5e04 5984564. 99 356159 .99 0.00 18331. 52 CD2-72wp02 To Targets Map Map ~---- Lgtitude ----> <-- Longitude ---> Name Description TVD +N/-S +E/-W Northing Easting Deg!Min' Sec Deg Min Sec Dip. Dic ft ft ft ft ft CD2-72wp06 Hee l 7266.90 5950.78 -12765.28 5980326.11 358589.96 70 21 13 .807 N 151 8 53.993 W CD2-72wp02 Toe 7281.90 101 47.66 -15267.86 5984564.99 356159.99 70 21 55 .036 N 151 10 7.393 W Annotation NID TVD ft ft 351.70 351.70 KOP; 2 .5 DLS, 351' MD 851.70 847.74 Build; 3 .5 DLS 2567.64 2113.65 Sail; 68 .2° for 13606' MD 3338.84 2400.00 Surf csg; 2400' ND 16174.39 7165.81 Build; 3 .5 DLS 16568.56 7266.90 Int csg; 5' below top D 16926.63 7291.89 Land; 1 0' below top reservoir 21568.32 7281.90 TD; 21568' MD ~~~~-~l~~~ ~ ~ ConocoPhillips Alaska, Inc. CPAI Report Company: ConoCOPhillips Alaska Inc. Date: 4/20/20~7 Time: 41:00:45 F'~ge: 7 Field: Colville River Unit Co-ordinate(NE) Reference: Well: Plan: CD2-72, True NOrth " Site: Alpine CD2 - Vertical (TVD) Reference: CD2-72wp07 53.9 Well: Plan: CD2-72 Secfion (VS} Reference: Well (O.OON,O.OOE,303.Q0Pazi) Wellpath: Plan: CD2-72 Survey Catculation Method: Minimum Curvatiure' Db: OraGe Casing Points MD TVD Diameter Hole Size Name ft ft in irt 3338.84 2400.00 10.750 13.500 10 3/4" 16568.56 7266.90 7.625 9.875 7 5/8" 21568.33 7281.90 3.500 6.750 3 1/2" Formarion s MD TVD Formafions Litholog,y Dip Angle Dip I)irection ft ft deg ` cleg 3373.58 2412.90 C-30 0.00 0.00 4359.32 2778.90 C-20 0.00 0.00 7222.25 3841.90 K-3 Marker 0.00 0.00 7752.82 4038.90 Basal K-3 0.00 0.00 7825.54 4065.90 K-2 Marker 0.00 0.00 8059.86 4152.90 Basal K-2 0.00 0.00 10672.32 5122.90 Albian 97 0.00 0.00 12565.68 5825.90 Albian 96 0.00 0.00 15404.37 6879.90 HRZ 0.00 0.00 15878.39 7055.90 Base HRZ 0.00 0.00 16023.82 7109.90 K-1 Marker 0.00 0.00 16139.63 7152.90 Kuparuk Fm 0.00 0.00 16280.23 7201.90 LCU-Miluveach 0.00 0.00 16448.74 7245.90 Miluveach A 0.00 0.00 16547.92 7263.90 Alpine D 0.00 0.00 16766.81 7286.90 Alpine C 0.00 0.00 16766.81 7286.90 Alpine A Sand 0.00 0.00 ~~~~~~~~~~ ~ ~ ConocoPhillips Alaska, Inc. Anticollision Report Company: ConoCOPhillips Alaska InC. Date: 4/20/2007 Time: 11:22:19 Page: 1 Field: Colvilie River Unit Reference Sitr. Alpine CD2 Co-ordinate(NE) Refe rence: WeIL' Plan: CD2-72, True 1~4rth Reference We1L Plan: CD2-72 Vertical (TVD) Reference: GD2-72wp07 53.9 Reference Wellpath: Plan: CD2-72 Db: ' OraCle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Plan: CD2-72wp07 & NOT PLANNED P Interpolation Method: MD IntervaL• 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 36.30 to 21568.33 ft Scan Method: Trav Cylinder North Maximum Radius: 2353.20 ft Error Surface: Ellipse + Casing Casing Points MD TVD Diameter Hole Size Name ft ft in in 3338.84 2400.00 10.750 13.500 10 3/4" 16568.56 7266.90 7.625 9.875 7 5/8" 21568.33 7281.90 3.500 6.750 3 1/2" Plan: CD2-72wp07 Date Composed: 4/3/2007 AW1 A Versio n: 21 Principal: Yes Tied-to: From Well Ref. Point Summary <___.______________ Offset Wellpath -------------------a Reference Offset Ctr-Ctr No-Go Ailowablc Site Well Wellpath NID MD Distance Area Deviatian Warning ft ft ft ft ft Alpine CD2 CD2-02 CD2-02 V5 1675.02 1600.00 654.70 33.78 620.92 Pass: Major Risk Alpine CD2 CD2-05 CD2-05 V9 1752.71 1975.00 189.65 31.08 158.57 Pass: Major Risk Alpine CD2 CD2-05 CD2-05L1 V4 1752.71 1975.00 189.65 30.97 158.68 Pass: Major Risk Alpine CD2 CD2-15 CD2-15 V3 2140.20 2325.00 480.17 55.53 424.65 Pass: Major Risk Alpine CD2 CD2-15 CD2-15PB1 V1 2140.20 2325.00 480.17 55.49 424.68 Pass: Major Risk Alpine CD2 CD2-15 CD2-15PB2 V2 2140.20 2325.00 480.17 55.49 424.68 Pass: Major Risk Alpine CD2 CD2-18 CD2-18 V19 2516.97 2600.00 162.96 52.93 110.03 Pass: Major Risk Alpine CD2 CD2-18 CD2-18PB1 V5 2493.97 2575.00 159.93 51.95 107.98 Pass: Major Risk Alpine CD2 CD2-21 CD2-21 V19 2143.54 2275.00 297.38 47.08 250.30 Pass: Major Risk Alpine CD2 CD2-21 CD2-21 PB1 V7 2143.54 2275.00 297.38 46.97 250.41 Pass: Major Risk Alpine CD2 CD2-24 CD2-24 VO 2208.46 2500.00 313.48 39.86 273.61 Pass: Major Risk Alpine CD2 CD2-24 CD2-24PB1 V1 2208.46 2500.00 313.48 39.86 273.61 Pass: Major Risk Alpine CD2 CD2-30 CD2-30 V31 1421.37 1600.00 271.82 26.11 245.71 Pass: Major Risk Alpine CD2 CD2-31 CD2-31 V7 1844.25 2050.00 66.77 35.95 30.82 Pass: Major Risk Alpine CD2 CD2-31 CD2-31 P61 V4 1844.25 2050.00 66.77 35.95 30.82 Pass: Major Risk Alpine CD2 CD2-404 CD2-404 V5 2267.27 2300.00 455.36 48.78 406.58 Pass: Major Risk Alpine CD2 CD2-40 CD2-40 V9 1363.55 1550.00 399.04 23.92 375.12 Pass: Major Risk Alpine CD2 CD2-40 CD2-40P61 V10 1363.55 1550.00 399.04 23.92 375.12 Pass: Major Risk Alpine CD2 CD2-43 CD2-43 V15 1275.46 1475.00 354.40 23.58 330.83 Pass: Major Risk Alpine CD2 CD2-43 CD2-43P61 V12 1275.46 1475.00 354.40 23.58 330.83 Pass: Major Risk Alpine CD2 CD2-54 CD2-54 V6 1120.78 1275.00 326.08 22.05 304.02 Pass: Major Risk Alpine CD2 CD2-54 CD2-54L1 V4 1120.78 1275.00 326.08 21.94 304.13 Pass: Major Risk Alpine CD2 CD2-59 CD2-59 V12 1363.65 1600.00 337.44 25.02 312.42 Pass: Major Risk Alpine CD2 CD2-59 CD2-59PB1 V5 1363.65 1600.00 337.44 24.92 312.53 Pass: Major Risk Alpine CD2 Plan: CD2-461 Plan: CD2-461 VO Plan: 1018.36 1050.00 223.76 21.51 202.26 Pass: Major Risk Alpine CD2 Plan: CD2-462 Plan: CD2-462 VO Plan: 351.67 350.00 201.15 7.45 193.71 Pass: Major Risk Alpine CD2 Plan: CD2-463 Plan: CD2-463wp04 V3 P 351.69 350.00 180.45 7.56 172.89 Pass: Major Risk Alpine CD2 Plan: CD2-463 Plan: CD2-463wp05 V3 P 351.70 350.00 180.33 7.24 173.10 Pass: Major Risk Alpine CD2 Plan: CD2-464 Plan: CD2-464 V2 Plan: 400.29 400.00 160.33 8.05 152.28 Pass: Major Risk Alpine CD2 Plan: CD2-465 Plan: CD2-465 V2 Plan: 1109.24 1125.00 100.91 24.49 76.42 Pass: Major Risk Alpine CD2 Plan: CD2-466 Plan: CD2-466 V3 Plan: 572.48 575.00 120.40 12.35 108.05 Pass: Major Risk Alpine CD2 Plan: CD2-467 Plan: CD2-467 V2 Plan: 1000.42 1025.00 98.27 20.19 78.08 Pass: Major Risk Alpine CD2 Plan: CD2-468 Plan: CD2-468 V2 Plan: 2413.92 2600.00 61.24 47.20 14.04 Pass: Major Risk Alpine CD2 Plan: CD2-469 Plan: CD2-469 VO Plan: 670.53 675.00 54.55 12.83 41.72 Pass: Major Risk Alpine CD2 Plan: CD2-470 Plan: CD2-470 VO Plan: 672.50 675.00 33.48 13.26 20.22 Pass: Major Risk Alpine CD2 Plan: CD2-471 Plan: CD2-471 VO Plan: 401.45 400.00 20.48 7.96 12.52 Pass: Major Risk Alpine Satellites Alpine West 1 VO Plan: (Prelim) V1 17128.27 14130.28 1543.79 456.23 1087.56 Pass: Major Risk Prelim: Alpine CD5 Prelim: AW-1A Prelim: AW-1A VO Plan: 18663.37 15875.00 418.55 360.86 57.69 Pass: Major Risk Prelim: Alpine CD5 Prelim: AW-2A Prelim: AW-2A V0 Plan: 18024.14 14350.00 1788.92 592.03 1196.89 Pass: Major Risk GRAM ~j?""~~~~~~ ~ ~~~~~ ~~.~~~~~ REFfFFNCFINFORMATION ANTI-COLLISION SETTINGS n Method:MD [nterval: 25.00 e From: 36.30 To: 21568.33 ;ange: 2353.20 Reference: P-an: CD2 72wp07 From Colour To MD 36 250 25~ S~U SU~ 75U 750 1~U~ IDUO 125~ 1250 1500 1500 1750 ~-` ~ 1750 2000 - 2000 2500 - -0 ~ '~ 2500 -..°- - 3000 ; / I~, ~ ~~ ~'6Z~-~S$ (~ ~D2-465) ' ~ , , ~ 000 ` 4500 ' ~s 0 _5000 -- ~~ ~ ='= ~~ ~- _ OO~a, •- . :. 6000 . ..'~ ! GO( ( ~ ~s- 7000 ~ ~ , 70 n , ~ 8000 ~ ~ l~ y ~ ~i ~ *_ i ~ ~ 9000 ~i~i~ , ~, i ~ j : ;~- ' 10000 , ~rt • ~ . p~ a~I~I~ ~ 12000 CaorCina~e(WE)Relerence. WeXCenire PWn'.CDl-]2,TrueNOrlh Ve~ical (NO) Re~erence~. CD2~l2v.p0153.90 SecMOn (V5) Re~erence~. Sbt- ~0 OON O.OOE) MeasureE ~ept~ Rekrer~ce~. C~]-]2wp0] 53.90 Galculation Methotl~. Minimum Curvature SURVEY PROGRaM D pth Fm Dep1h To Survey/Plan Tool 3.30 1001.70 Planned: CD2-72wp07 V21 CB-GYRO-SS 1 I.70 21568.33 Pl anned: CD2-72wp07 V21 bIWD+IFR-AK-CAZ-SC S[:C77llN UtiTAILS Jec MD I~c A[t TVD +N/-S +E/-W DLeg TFace VSec l'arget 1 367D 0,00 0.00 3630 0.1~ Ol)0 0.00 000 000 35170 000 UOU 351~U (I.fb 000 O.W 0.00 UOU 3 (517(1 7.50 33UU0 65U.64 I698 A.AO 2.50 330.00 I'7.47 4 ri517U 1250 ;3(I.UO 84774 4705 -271G 2.50 O.f10 4R.40 5 1051.7U 19.50 13f1.00 IDi9.88 9476 SJ.71 3.50 ~W ')749 6 2567.bJ 6A.20 294.ON 211365 ~i40.62 -l4N3.%7 350 -0Lb 1090.IN 7 1617Ji9 (820 29408 716581 5795Ji -724183> U00 0.00 Ii571A9 X Ih56A 5! X2110 29411% 72GG.90 5950.78 -727G> 2R 3.50 -0.01 13946.89 Cll2-72wp0613ec1 Y 1692G63 9000 i0127 72918Y G11654 -1i08109 300 J220 1430203 io iama~z ~n.w ass.~i ~zm~aa e~~~.~e -uxso.ai sno s9~s iss~is~ 11 2156N1i 90.14 135.71 728190 10147.66 -15267NG 000 0.00 IR33152 CD2-72wp02Toe ~~ ,; ~l ~1• ~~ ~n' ~-~bZ}vp04) ' k, ~'~' .~1'~~" an: o ~ ~"' 18000 From Colour To ] , ~•\~. - - 36 250 .~ ' 20000 ;a - , ; ~~ ~+-~~'[~„~^~` 25000 _- -- 500 7~0 f•~ P~n: CD2-463 (Pla . D2-463wp05) p. ~~~ ,Plan: CD2-461 (P : CD2-461) ~ ~ 750~ ~00 /~,~ ~jr ` ~ ~„ ^ •; 150 -v .~.- s ~~/X ~/ X o 175 .i~i~~ , , 0 0 27C Plan: CD2-4 l (Plan: (Plan: CD2-470) ""~'~'~~ ~o ~ 1 A~C4f2?d~~~~}?~C~2~~69> '80~Plan: CD2-468 (Plan: CD2-468) ~- - 1 - -- i '-° 24 _ _ 1 " ~~~ 1 \ -_ ,.~~ _ ~ ' DETAIL S >s Alaskn Inc eennp ~~~~„~~~„ ~~~a~~~,~ Sl W1A o-a~ ai~a«Honn -.u~~o~~i + c~»,~ iWes Rased Cylinder Azimulh (TFO+AZI) ~deg~ vs Cenfre Po Centre Separxtion ~100fUin~ w +~ Plan: CD2-470 (Plan: CD2-470) ~8~ Travellino Cylinder Azimuth (TFO+pZI) [deg] vs Centre to Centre Separation [20ft/in] 14000 I I i , ' . i i CD2-0 2 CD2-02 , , ' CD 2-21 CD2-21 PB 1 ' 12000 , , I , , CD 2-21 CD2-21 , ' - _ J , , ,, , CD2-72w 07 , , ' , ' 10000 , , ', , I ~ ~ ~ I o N 8000 , , ~ .-. , , , ~ CD2-18 CD2- 18 CD2-15 CD2-15 ~ ~ ~ , , CD2-15 CD2-15PB2 - - - ,~ ~ 6000 , , , ~ ~ , .. ~ ~ ' , CD2-24 CD2-24 ' - I~ 2-15PB 1 I CD2-31 CD2-31 , ~ j `~ CD2-59 CD2-59 :~,~ 4000 ~ ~.N, , ~ ~` ~ ~. I , , ~{~ ~ ,, ' , ~" 2000 ' , u~ ~ , ~ , , CD2-24 CD2-24PB 1 , CD2- 30 CD2-30 CD2-59 CD 2-59PB 1 , ~ CD2-5 4 CD2-54L1 p2-31PB CD2-59 CD2-59 PB 1 -22000 -20000 -18000 -16000 -14000 -12000 -10000 -8000 -6000 -4000 West(-)/East(+) [2000ft/in] FW: CD2 annular issues Tom, I spoke to Tim Crumrine, who has looked inta whether there have beer~ OA pressure issues with our Problem Well group, and th~re has been no evidence af a probl~m. Some data ~nras sent to Dave Raby including data on CD2-404 and the CD2 OA pressures from 12/05 until 12/06. tl~le had SPiDR gauge dat~ on the CC}2-23 and 2-11 (twva cE~sest wel! to C~2-404} from the injection test in Ja-~uary. The problem vuelis group reviewed the injection data that I sent and there was na correlatian between the injection test and (JA pressures on the CD2-11 and CDZ-23. Let me know if you need anything eise. Ver~a Johnson 265-6081 1 of 1 5/3/2007 2:51 PM ~ • LJ • ~~..~~_~ ~~ _ _~: SHARON K..ALLSUP-DRAKE y 1182 CONOCOPHILLIPS AT01530 700 G ST. ANCHORAGE AK 9950f °ArE ~ ~ / • 756-1551/441 PAY TO THE ~T~ ~ OF / t"~ l~M t ~ ~~ ~/~ O~ ORDER OF ' C,- , ~~ k'~ S f+^-~~O ~Oc]~~ A ~k.wre, IJ ~«.~.~~<t JPMorganChase ~ j va~id uP To 5000 ~onars JPMorgan Chase Bank; N.A. ' Columbus, OH . //~ MEMO ~--f~Z ' / G_ --~~/j,,,~ --- ~ -~~ G~-' _" -- - --~'L! --- - -~ ~:0441155Li~:.5 28 74 7 190 79 2 7u^L18C m ~ ~ TRAYSMIT'I'AL LE'I'T~R C~iECKLIST `VELL vA1~tE C~~'C ~~D ~ - ? ~. PTD# ~ ~7- C~ ~ ~ " Develo . pment Serv~ce Exploratory Strahgraphic Test iYoe-ConventioQal Welt Cirele 4ppropriate Letter / Paragraphs to be Inc[uded ia Transm~ittal Letter ' CHECK ; WHAT APPLIES L ~ The permit is for a new weil6oce segment of exi;ting ~ wel! ' in I P~~it No. , AP[ No. ~0- are ; - - : Production shouid continue to be reported as a function of the' ; original 4PI number sta.ted above. ; ~ PILOT HOLE i In accorda~ce with z0 A.4C 2~.OU5(~, al! record;, data and lo~s ~ I ~ acquired for the pilot hole must be cteazly differentiated in both , ~ ; well nacne ( PI~ ar~d API rt~trrtbec I i '(SO- - -_) from records, data and logs ~ I i acquired for we(t _ . i ~ SPACING ~ ~ EXCEPTION The permit is approved subject to fuil compliance with 20 AAC 2~ 0 ~ . 55. Approvat to perforate and r(~ Od4Ce / inject is contingent I ' i ; i I upon issuance of a conservation order approving a spacing i ~ exceptiort. ' ~ ~ assum~s the ~ liability ofany protest to the spacireg exception that may occur. i i ~ ~ DRY DCTCH ' AlI dry ditch samp(e sets su6mitted to tt~e-Eommission must be in ; ~ i SA.tifPLE I no greater than 30' samp[e intecvals from be(ow the pecmafrost or ; ' ~ ~ ~ from where samp[es are first caught and t 0' sample intervals ; ~ ~ i ~ ~ through tar~et zones. ~ ; ' , j 1~1on-Conventional W ~l ~ Ptease note the following_ special condition of this permic: ; ~ producrioR or production testing of coa! bed methane is nat allowed i ! ~ z ~ for ~~e of wet!) until after (C_ OtIlDany Name) has cleslgrted and I ; ~ ~~mp(emented a water we!( testing program to provide base[ine data ; ~ i on water quality and quarttity. ~om~y Namc) must contact the I ' I ~ 1 Commission to obtain advance approva:l of such wate~ we11 teshng ; ~ - prostram ~ ADD-ONS ` TEXT FOR APPROVAL LETTER ; (OPT[ONS) I ; ; I , MtiLTI LATERA i (tf tast two digits ; AP! number ; between 60-69) Rev: I 2~i06 C:' jocly~transmittal checklist ~ ~ ^^ ~ o r ~ N~ , ~ ~ , ~ ~ ~ , , ~ ~ ~ ~ ~ , ~ ~ ~ ~ ~ ~ ~ I ~ ~ ~ , ~ ~ ~ ~ ~ , ~ , ~ . , ~ , ~ ~ , ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ , ~ ~ ~ , ~ m~ N d y N ~ N~ ~ ~ ~ ~ , ~ ~ ~ , , ~ ~ ~ . ~ ~ ~ . . ~ , ~ ~ ~ ~ ~ , ~ ~ ~ ~ , ~ _ N ~ ~ M~ ~ ~ ~ , ~ ~ ~ ~ , ~ ~ ~ ~ I , , ~ ~ ~ : , ~ ~ ~ ~~, O 'Q j J~ ~ ~~ ~ . , ~ ~ ~ ~ ~ N ~ ~ ~ ~ , ~ ~ , , ~ , ~ , ~ . ~ ~ ~ , , ~ , ~ ~ ~ ~ ~ , ~ ~ , ~ , .=~ ~ ~ ~ ~ ~ ~ ~~ ~ ~ ~ ~ , ~ , ~ ~ ~ , i ~, ~~ p~ ' UT ~ C ~ ~ Q, - ~ ~ Q~ ~~ ~ ~ ~ ~ ~ , ~ , , ~ ,( i . ~ ~ ~ ~ ~ N~ 3 ~ , ~ Q 3 '~~ ~ , . ~ , . 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L o c a ~ , o Q o v a ¢ a ~ W ¢ ~ ~ au"i ~ ~ Well History File APPENDIX Information of detailed nature that is not particulariy germane to the Well Permitting Process but is part of the history file. To irnprove the readability of the Well History file and to simpl'rfy finding infoRnation, information of this nature is accumulaled at the end of the file under APPENDIX. No special efiori has been made to chronologically organize this category of information. C~ Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Jul 17 11:00:42 2007 Reel Header Service name .............LISTPE Date .....................07/0'J/17 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................07/07/17 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 Alpine MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MWD RUN 2 JOB NUMBER: W-0005030483 LOGGING ENGINEER: E. QUAM OPERATOR WITNESS: D. BURLEY # SURFACE LOCATION SECTION: TOWNSHIP: RANGE : FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL; # WELL CASING RECORD C~ Scientific Technical Services Scientific Technical Services CD2-72 501032054600 ConocoPhillips Alaska Inc. Sperry Drilling Services 16-JUL-07 MWD RUN 3 W-0005030483 D. RICHARDSO D. LUTRICK 2 11N 4E 3072 1984 54.33 17.60 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 3318.0 2ND STRING 6.750 7.625 16693.0 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTFiERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED. ao~ - oS~ # ~53s~( • ~ 4. MWD RUNS 2, 3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WFIILE DRILLING (PWD), AND GEO-PILOT ROTARY STEERABLE BHA (GP). RUN 3 ALSO INCLUDED GEO-TAP FORMATION PRESSURE TESTER. 5. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. 6. MWD RUNS 1-3 REPRESENT WELL CD2-72 WITH API#: 50-103-20546-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 21089'MD/7242'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. $ File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/07/17 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 3288.5 21031.5 RPD 3300.0 21038.5 FET 3300.0 21038.5 RPS 3300.0 21038.5 RPM 3300.0 21038.5 RPX 3300.0 21038.5 ROP 3328.5 21089.0 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT i7NSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 3288.5 16707.0 MWD 3 16707.0 21089.0 $ # 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 Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3288.5 21089 12188.8 35602 3288.5 21089 RPD MWD OHMM 0.1 2000 16.2166 35478 3300 21038.5 RPM MWD OHMM 0.1 2000 14.5014 35478 3300 21038.5 RPS MWD OHMM 0.07 2000 12.29 35478 3300 21038.5 RPX MWD OHMM 0.07 2000 7.95989 35478 3300 21038.5 FET MWD HOUR 0.2 241.94 1.4771 35478 3300 21038.5 GR MWD API 42.35 332.42 97.3709 35487 3288.5 21031.5 ROP MWD FT/H 0.35 397.64 169.112 35522 3328.5 21089 First Reading For Entire File..........3288.5 Last Reading For Entire File...........21089 File Trailer Service name ........... ..STSLIB.001 Service Sub Level Name. .. Version Number......... ..1.0.0 Date of Generation..... ..07/07/17 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..... ..07/07/17 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 3288.5 16666.5 FET 3300.0 16653.0 RPX 3300.0 16653.0 RPS 3300.0 16653.0 RPM 3300.0 16653.0 • RPD 3300.0 16653.0 ROP 3328.5 16707.0 $ # 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): 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: 13-MAY-07 Insite 74.11 Memory 16707.0 3328.0 16707.0 67.7 82.6 TOOL NUMBER 134745 121079 9.875 3318.0 Polymer 9.90 42.0 9.6 400 6.5 • 1.400 72.0 .630 167.0 1.200 72.0 2.500 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-t ype...0 Name Service Order Units Si ze 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 3288.5 16707 9997.75 26838 3288.5 16707 RPD MWD020 OHMM 0.1 2000 8.79705 26707 3300 16653 RPM MWD020 OHMM 0.1 1743.45 8.03489 26707 3300 16653 RPS MWD020 OHMM 0.48 2000 7.2148 26707 3300 16653 RPX MWD020 OHMM 1.05 2000 6.82369 26707 3300 16653 FET MWD020 HOUR 0.2 53.9 0.619277 26707 3300 16653 GR MWD020 API 42.35 332.42 107.687 26757 3288.5 16666.5 ROP MWD020 FT/H 0.41 397.64 197.058 26758 3328.5 16707 First Reading For Entire File..........3288.5 Last Reading For Entire File...........16707 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/07/17 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.......07/07/17 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 16653.5 21038.5 RPD 16653.5 21038.5 RPM 16653.5 21038.5 FET 16653.5 21038.5 RPS 16653.5 21038.5 GR 16667.0 21031.5 ROP 16707.5 21089.0 $ # LOG HEADER DATA DATE LOGGED: 28-MAY-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 21089.0 TOP LOG INTERVAL (FT): 16707.0 BOTTOM LOG INTERVAL (FT): 21089.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 82.8 MAXIMUM ANGLE: 94.6 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 203301 EWR4 Electromag Resis. 4 159436 $ • • # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 16693.0 # BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.80 MUD VISCOSITY (S): 45.0 MUD PH: 9.6 MUD CHLORIDES (PPM): 83000 FLUID LOSS (C3): 12.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .140 64.0 MUD AT MAX CIRCULATING TERMPERATURE: .060 158.0 MUD FILTRATE AT MT: .120 64.0 MUD CAKE AT MT: .185 64.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 16653.5 21089 18871.3 8872 16653.5 21089 RPD MWD030 OHMM 1.2 2000 38.8087 8771 16653.5 21038.5 RPM MWD030 OHMM 1.06 2000 34.1913 8771 16653.5 21038.5 RPS MWD030 OHMM 0.07 2000 27.7436 8771 16653.5 21038.5 RPX MWD030 OHMM 0.07 1390.25 11.4195 8771 16653.5 21038.5 FET MWI1030 HOUR 0.4 241.94 4.0891 8771 16653.5 21038.5 GR MWD030 API 43.2 143.29 65.7518 8730 16667 21031.5 ROP MWD030 FT/H 0.35 231.85 83.7853 8764 16707.5 21089 First Reading For Entire File..........16653.5 Last Reading For Entire File...........21089 File Trailer Service name ........... ..STSLIB.003 Service Sub Level Name. .. Version Number......... ..1.0.0 Date of Generation..... ..07/07/17 Maximum Physical Record..65535 File Type .............. ..LO . ~r i Next File Name.....,.....STSLIB.004 Physical EOF Tape Trailer Service name .............LISTPE Date .....................07/07/17 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 .....................07/07/17 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
