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Home My WebLink About209-0281. 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: ______________________ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured feet feet true vertical feet feet Effective Depth measured feet feet true vertical feet feet Perforation depth Measured depth feet True Vertical depth feet Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas W DSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: 2. Operator Name: Senior Pet. Engineer: Senior Res. Engineer: CollapseBurstTVDLengthCasing Authorized Signature with date: Authorized Name: 5. Permit to Drill Number: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf measuredPlugs Junk measured STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 3. Address: 4. Well Class Before Work: Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureOil-Bbl measured true vertical Packer WINJ WAG Water-Bbl MD 15.Well Class after work: Exploratory Development ServiceStratigraphic 16.Well Status after work:Oil Gas WDSPL a GSTOR GINJ SUSP SPLUG 5.070, 25.071, & 25.283) WINJ W AG tion: tion: Gas-Mcf Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureOil-Bbl W ater-Bbl summary: olumes used and final pressure: epth feet epth feet true vertical depth) d and true vertical depth) Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Perforate Other Stimulate Alter Casing Change Approved Program Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ Development Exploratory Stratigraphic Service 6. API Number: mber):8.Well Name and Number: onic data per 20AAC25.071):10.Field/Pool(s): ry: ured feet feet tical feet feet ured feet feet tical feet feet CollapseBurstTVD 5.Permit to Drill Number: Size measuredPlugs Junkmeasured 4. W ell Class Before W ork: measured true vertical Packer MD Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 9:29 am, Nov 12, 2020 ConocoPhillips Alaska, Inc. PO Box 100360, Anchorage, AK 99510 209-028 50-103-20598-00-00 ADL 372103, 372104, 372105 CD3-304 None Colville River Field/Fiord Oil Pool 17843 6806 None None 17388 6620 15086 5907 Conductor 78' 16" 114 114 Surface 3961' 9.625" 3997 2469 Production 17798' 7" 17832 6801 17408 - 17440 6626 - 6637 see attached see attached see attached 17408' - 17440' MD Please see attached summary 195 1118 2705 1830 572 46 383 2780 1823 740 N/AKaylie Plunkett Senior Production Engineer Kaylie Plunkett Kaylie.B.Plunkett@conocophillips.com 265-6450 Scale Inhibition ✔ ✔ ✔✔ ✔ Kaylie Plunkett Digitally signed by Kaylie Plunkett Date: 2020.11.09 09:39:42 -09'00' DSR-11/13/2020VTL 2/24/21 RBDMS HEW 11/12/2020 SFD 11/17/2020 CD3-304 Scale Inhibition Treatment 10/11/20 Aqueous Scale Inhibitor Squeeze Job pumped on 10/11/20 from 1000 – 1345 hrs. LRS = Little Red Services ACF = Alpine Central Facility - Initial pressure TBG/IA/OA - 1466/1781/716 - ACF pumped 30 bbls seawater for a tubing flush at 3.0 bpm, TBG/IA/OA - 1581/1699/618 - LRS pumped 6.6 bbls ACPC19610A while ACF pumped 26 bbls seawater preflush at 0.6 – 3.0 bpm, TBG/IA/OA – 1532/1743/668 - LRS pumped 5 bbls SCAL16089A scale inhibitor while ACF pumped 28 bbls seawater at 0.6 – 3.0 bpm, TBG/IA/OA – 1588/1694/613 - ACF pumped 662 bbls seawater overflush at 2.5 – 3.4 bpm, TBG/IA/OA – 217/1546/481 Interval treated (MD): 17,408’ – 17,440’ Tubing (size, grade, measured and true vertical depth) 4.5" x 3.5", L-80, 17252' MD, 6578' TVD Packers and SSSV (type, measured and true vertical depth) Packer: Baker Premier Packer @ 15086' MD, 5907' TVD SSSV: WRDP @ 1607' MD, 1515' TVD y' Y n < Li STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION (o,n REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon LJ Plug Perforations LJ Fracture Stimulate LJ Pull Tubing LJ Operations shutdown Li Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Aller Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Scale Inhibitor Treatment ❑� 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConoeoPhlllips Alaska, Inc. DevelopmentEx ❑ Exploratory ry ❑ Stmtigraphic ❑ Service ❑ 209-028 3. Address: PO Box 100360 6. API Number: Anchorage, AK 99510 50-103-20598-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 372103, 372104, 372105 CRU CD3 -304 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): None Colville River Field / Fiord Oil Pool 11. Present Well Condition Summary: Total Depth measured 17843 feet Plugs measured None feet true vertical 6806 feet Junk measured None feet Effective Depth measured 17388 feet Packer measured 15086 feet true vertical 6620 feet true vertical 5907 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 114' 114' Surface 3961' 9.625" 3997' 2469' Intermediate Production 17798' 7" 17832' 6801' Liner Perforation depth Measured depth 17408 - 17440 feet True Vertical depth 6626 - 6637 feet Tubing (size, grade, measured and true vertical depth) 4.5" x 3.5", L-80, 17252' MD, 6578' TVD Packers and SSSV (type, measured and true vertical depth) Packer: Baker Premier Packer @ 15086' MD, 5907' TVD SSSV: WRDP @ 1607' MD, 1515' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 17408'- 17440' 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: 1 168 787 3793 1854 1 481 Subsequent to operation: 1 63 286 4413 1820 513 14. Attachments (required Per 20 AAC 25.070, 25.071, s 25.283) 15. Well Class after work: Daily Report of Well Operations ❑� 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. 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: Kavlle.B.PlunkettAcoo.com Authorized Signature: Date: 3 - I S - I Contact Phone: 265-6450 Form 10404 Revised 412017 ' ��/`j RBDMS4!�J MAH 2 0 2019 submit original Only CD3 -304 Scale Inhibition Treatment 2/17/19 Aqueous Scale Inhibitor Squeeze Job pumped on 2/17/19 from 10:52 —19:11 hrs. LRS = Little Red Services ACF = Alpine Central Facility - Initial pressure TBG/IA/OA-918/2000/308 - ACF pumped 30 bbls seawater for a tubing flush at .40—.83 bpm, TBG/IA/OA - 1807/1981/317 - LRS pumped 4.2 bbls ACPC19610A while ACF pumped 17 bbls seawater preflush at .40 —1.74 bpm, TBG/IA/OA —1813/1981/317 - LRS pumped 6.3 bbls SCAL16089A scale inhibitor while ACF pumped 27 bbls seawater at 1.52 bpm, TBG/IA/OA-1804/1925/315 - ACF pumped 840 bbls seawater overflush at 1.52 — 2.01 bpm, TBG/IA/OA-1616/1820/326 Interval treated (MD): 17,408'— 17,440' €L' '1tI.. i,6L,.I V ll..L.O - STATE OF ALASKA AL/104 OIL AND GAS CONSERVATION COMMIE/1PN MAR 0 5 2018 REPORT OF SUNDRY WELL OPERATIONS y��))///ll^^^^yy►►►►��'1, 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ ' p�Tat Ss bTrutif6wn ❑ 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 ❑✓ Exploratory ❑ 209-028 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O. Box 100360,Anchorage,AK 99510 50-103-20598-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 372103, 372104, 372105 CRU CD3-304 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): None Colville River Field/Fiord Oil Pool 11.Present Well Condition Summary: Total Depth measured 17843 feet Plugs measured None feet true vertical 6806 feet Junk measured None feet Effective Depth measured 17388 feet Packer measured 15086 feet true vertical 6620 feet true vertical 5907 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 114' 114' Surface 3961' 9.625" 3997' 2469' Intermediate Production 17798' 7" 17832' 6801' Liner Perforation depth Measured Depth: 17408- 17440 feet True Vertical Depth: 6626-6637 feet Tubing(size,grade,measured and true vertical depth) 4.5"x 3.5", L-80, 17252' MD, 6578'TVD Packers and SSSV(type,measured and true vertical depth) Packer: Baker Premier Packer @ 15086' MD, 5907'TVD SSSV: WRDP @ 1607' MD, 1515'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 17408'- 17440' 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: 463 339 3050 1925 514 Subsequent to operation: 503 267 3625 1913 545 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: 11 Daily Report of Well Operations 0 Exploratory❑ Development D 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 Kaylie.B.Plunkett@cop.com Printed Name Kaylie Plunkett Title Production Engineer Signature f 0 AtJAZk Phone 265-6450 Date 3— 1— 1 V`TL 3/16/i< 1M7/7RBDMS L,- h}:'R 2018 Form 10-404 Revised 5/2015 Submit Original Only - S 0 CD3-304 Scale Inhibition Treatment 2/1/18 Aqueous Scale Inhibitor Squeeze Job pumped on 2/1/18 from 08:52—20:09 hrs. LRS= Little Red Services ACF=Alpine Central Facility - Initial pressure TBG/IA/OA- 1493/1797/372 - ACF pumped 30 bbls seawater for a tubing flush at 1.0—2.8 bpm,TBG/IA/OA- 1400/1992/331 - LRS pumped 178 gals ACPC19610A at .65 bpm while ACF pumped 17 bbls seawater preflush at 2.6—2.8 bpm,TBG/IA/OA—1400/1713/312 - LRS pumped 266 gals SCAL16089A scale inhibitor at .65 bpm while ACF pumped 27 bbls seawater at 2.4—2.6 bpm,TBG/IA/OA—1391/1713/312 - ACF pumped 840 bbls seawater overflush at .7—2.4 bpm,TBG/IA/OA—1080/1764/255 Interval treated (MD): 17,408'—17,440' STATE OF ALASKA - AIL OIL AND GAS CONSERVATION COMMI 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 0 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development El Exploratory❑ 209-028 3.Address: Stratigraphic❑ Service ❑ 6.API Number: P.O. Box 100360,Anchorage, AK 99510 50-103-20598-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 372103, 372104, 372105 CRU CD3-304 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): None Colville River Field/Fiord Oil Pool 11.Present Well Condition Summary: Total Depth measured 17843 feet Plugs measured None feet true vertical 6806 feet Junk measured None feet Effective Depth measured 17388 feet Packer measured 15086 feet true vertical 6620 feet true vertical 5907 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 114' 114' Surface 3961' 9.625" 3997' 2469' Intermediate Production 17798' 7" 17832' 6801' RECEIVED Liner 77 Perforation depth Measured Depth: 17408- 17440 feet r R 6 [ DEC2 1 �, LJ Z SCAMS) MAR 0True Vertical Depth: 6626-6637 feet J AO ;CC Tubing(size,grade,measured and true vertical depth) 4.5"x 3.5", L-80, 17252' MD, 6578'TVD Packers and SSSV(type,measured and true vertical depth) Packer: Baker Premier Packer @ 15086' MD, 5907'TVD SSSV: WRDP @ 1607' MD, 1515'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 17408'- 17440' 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: 662 2595 1030 1156 344 Subsequent to operation: 636 2153 1172 1230 289 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations U Exploratory❑ DevelopmentU Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 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 John Cookson Email John.Cookson(c.cop.com Title Printed NamePetroleumEngineer Joh ookson Principal �, � 9 06 Signature ,�I Al••- Phone 265-6547 Date ( y 7-1.- 2.11 7- / 17- Form 10 404 Revised 5/2015 X447 RBDNIS i - DEC 2 2 2016 Submit Original Only • • CD3-304 Scale Inhibition Treatment 12/5/16 Aqueous Scale Inhibitor Squeeze Job pumped 12/5/16 from 10:50 to 14:25 hrs. LRS= Little Red Services ACF=Alpine Central Facility - Initial pressure TBG/IA/OA-326/1144/406 - ACF pumped 50 bbls seawater for a tubing flush at.1—2.8 bpm,TBG/IA/OA-300/1148/406 - LRS pumped 466 gals WAW5206 at.3 bpm while ACF pumped 100 bbls seawater preflush at 2.7 bpm,TBG/IA/OA—200/1030/315 - LRS pumped 932 gals SCW4004 scale inhibitor at .4 bpm while ACF pumped 89 bbls seawater at 2.7 bpm,TBG/IA/OA—200/1012/303 - ACF pumped 304 bbls seawater overflush at 2.7 bpm,TBG/IA/OA—200/991/300 Interval treated (MD): 17,408'—17,440' STATE OF ALASKA illiSKA OIL AND GAS CONSERVATION COM ISSION 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 Q Exploratory ❑ 209-028 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O. Box 100360,Anchorage,AK 99510 50-103-20598-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 372103, 372104, 372105 CRU CD3-304 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): None Colville River Field/Fiord Oil Pool 11.Present Well Condition Summary: Total Depth measured 17843 feet Plugs measured None feet true vertical 6806 feet Junk measured None feet Effective Depth measured 17388 feet Packer measured 15086 feet true vertical 6620 feet true vertical 5907 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 114' 114' Surface 3961' 9.625" 3997' 2469' Intermediate Production 17798' 7" 17832' 6801' Liner p I ' ,, RECEIVED Perforation depth Measured Depth: 17408- 17440 feet SCAN fg't i , True Vertical Depth: 6626-6637 feet 6 {fC FEB 2 4 201 Tubing(size,grade,measured and true vertical depth) 4.5"x 3.5", L-80, 17252' MD, 6578'TVD AOGCC Packers and SSSV(type,measured and true vertical depth) Packer: Baker Premier'Packer @ 15086' MD, 5907'TVD SSSV: WRDP @ 1607' MD, 1515'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 17408'- 17440' 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: 497 1803 1357 1152 283 Subsequent to operation: 534 1836 1424 1287 312 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 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 Kerry Freedman Email Kerrv.C.Freedman(c�cop.com Printed Name Kerry Freedman Title Principal Production Engineer / Signature / Phone 265-6579 Date 2.12.:3 //( ,-, irrt- 311101 RBDMS LL FEB 2 4 2016 Form 10-404 Revised 5/2015 /� Submit Original Only 0 • • CD3-304 Scale Inhibition Treatment 1/25/16 Aqueous Scale Inhibitor Squeeze Job pumped 1/25/16 from 07:38 to 10:30. LRS= Little Red Services ACF=Alpine Central Facility - Initial pressure TBG/IA/OA- 299/1161/346 - ACF pumped 50 bbls seawater for a tubing flush at 1.5—4.2 bpm,TBG/IA/OA-345/1090/300 - LRS pumped 466 gals WAW5206 at .4 bpm while ACF pumped 100 bbls seawater preflush at 4.2 bpm,TBG/IA/OA—130/1048/277 - LRS pumped 932 gals SCW4004 scale inhibitor at .4 bpm while ACF pumped 89 bbls seawater at 2.1 bpm,TBG/IA/OA—0/1023/259 - ACF pumped 304 bbls seawater overflush at 3.9 bpm,TBG/IA/OA—0/1000/256 Interval treated (MD): 17,408'—17,440' WNS PROD • CD3-304 ConocoPhillips Well Attributes Max Angle&MD TD Alaska.kw:. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) C<.a etismbtn`' 501032059800 FIORD KUPARUK PROD 74.96 3222.38 17,843.0 ••- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date DEVIATED-CD3-304,10/2920149:19:45 AM SSSV.WRDP Last WO: 42.40 4/24/2009 Venice/schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason.RESET WRDP hipshkf 10/29/2014 HANGER,31.2 )tr.E 111 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.250 36.0 114.0 114.0 62.50 H-40 WELDED , Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE 95/8 8.835 36.4 3.9972 2469.0 40.00 L-80 IBT< Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread _ PRODUCTION 7 6276 34.2 17,831.8 6,801.3 26.00 L-80 BTCM - f Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection ingeRAMONMSWASAMPini I , Ma TUBING 3 1/2 2.992 31.2 17,252.2 6,577.8 9.30 L-80 EUE 4.5•x3.5•@ 1664 CONDUCTOR,360-114.0 ,; . Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) 31.2 31.2 0.00 HANGER FMC TUBING HANGER 4.500 1,607,4 1,515.0 4222 NIPPLE SSSV BALD LANDING NIPPLE 3.813 1,664.1 1,556.1 45.02 XO Reducing CROSSOVER-4.5"x 3.5" 3.500 WRDP;1,607.2 - 15,030.7 5,889.7 71.89 SLEEVE-C BAKER CMU SLIDING SLEEVE w/2.813"DS PROFILE- 2.813 NIPPLE,1,6074 ;,j•, CLOSED 15,085.7 5,906.8 71.79 PACKER BAKER PREMIER PACKER 2.870 15,143.8 5,925.0 71.83 NIPPLE CAMCO D NIPPLE 2.750 `• 17,241.5 6,574.6 72.53 WLEG BAKER WIRELINE ENTRY GUIDE 2.867 TOther In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl + Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 1,607.2 1,514.9 42.21 WRDP 3.812"WRDP(SN HSS-276) 10/28/2014 1.125 GAS LIFT;2,497311- Perforations&Slots Shot Den Top(ND) Btrn(ND) (shots/@ Top(5KB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 17,408.0 17,440.0 6,626.4 6,637.5 4/30/2009 6.0 IPERF HES 2.0"Scalloped Guns,60 deg phase, millenium charges Mandrel Inserts St SURFACE,36.4-3,997.2 1. ati N Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ORB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com f_ 2,497.3 2,005.2 CAMCO KBG-2- 1 GAS LIFT GLV BK 0.156 1,742.0 4/15/2013 1R GAS LIFT,6.700.5 2 8,700.5 3,934.1 CAMCO KBG-2- 1 GAS LIFT GLV BK 0.188 1,794.0 4/15/2013 I1R 3 14,971.4 5,871.3 CAMCO KBG-2- 1 GAS LIFT OV BKO3 0.250 0.0 4/16/2013 R Notes:General&Safety End Date Annotation GAS LIFT,14.971 4 - 427/2009 NOTE:View Schematic w/Alaska Schematic9.0 SLEEVE-C;15,030.7 o a PACKER,15,085.7 ®I,; IN f' 1 NIPPLE,15,143.8 EA WLEG;17241.5ill I PERF;17408.0-17 440 0- PRODUCTION;34.2-17,831 8- A, STATE OF ALASKA - ALASKA OIL AND GAS CONSERVATION COM.._-.SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed Abandon r Repair w ell r Rug Perforations r Perforate rOther r Scale Inhibition Alter Casing r Pull Tubing r Stimulate-Frac Waiver r Treatment r r Time Extension Change Approved Program rOperat. Shutdow n r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 209-028 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-103-20598-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 372103,372104,372105 CRU CD3-304 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Colville River Field/Fiord Oil Pool 11.Present Well Condition Summary: Total Depth measured 17843 feet Plugs(measured) none true vertical 6806 feet Junk(measured) none Effective Depth measured 17743 feet Packer(measured) 15086 true vertical 6760 feet (true vertical) 5907 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 114 114 SURFACE 3961 9.625 3997 2469 PRODUCTION 17798 7 17832 6801 RECEIVED itN�iK ,,...��. a � FEB 2 6 2015 Perforation depth: Measured depth: 17408-17440 AOGCC True Vertical Depth. 6626-6638 Tubing(size,grade,MD,and ND) 4.5x3.5, L-80, 17252 MD,6578 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER PREMIER PACKER @ 15086 MD and 5907 TVD NIPPLE-SSSV BAL-O LANDING NIPPLE WITH WRDP INSTALLED @ 1607 MD and 1515 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 1 740 8-1 74 40 Treatment descriptions including volumes used and final pressure: see attached summary 13. Representative Daily Average Production or Injection Data oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 872 3773 2304 --- 328 Subsequent to operation 882 4032 2265 -- 332 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r' Service r Stratigraphic r 16.Well Status after work Oil r7 Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt. none Contact Kerry Freedman Cad 265-6579 Email Kerry.C.Freedmanconocophillips.com Printed Name Kerry Freedman Title Principal Production Engineer Signatur Phone:265-6579 Date 3...i.e.,(4..._ 2L 1=�(r--zo( c l T� 36///5— 4 37,4 Form 10-404 Revised 10/2012 Subm\,i Original Only RBDMS JY FEB 2 6 2015 . F WNS PROD CD3-304 m ConocoP` h" g illips Well Attributes Max Angle&MD TD Alaska,Inc. Wetmore APIIUWI Field Name Wellbore Status ncl(1) MD(ttKB) Act Bin)(fIKB) cr.xrY,n„Ihp, 501032059800 FIORD KUPARUK PROD 74.96 3,222.38 17,843.0 -,- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date DEVIATED.CD3.304,10/2920149;19;45 AM SSSV:WRDP Last WO: 42.40 4/24/2009 Vertical schematic(actual) Annotation Depth(ttKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:RESET WRDP hipshkf 10/29/2014 .t HANGER 31.2 ? �Sa- s.ng-Strings j E Casing Description OD(in) ID(in) Top MB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread 1 ti CONDUCTOR 16 15.250 36.0 114.0 114.0 62.50 H-40 WELDED I Casing Description OD(in) ID(in) Top(ttKB) Set Depth(ttKB) Set Depth(ND)...WULen 0...Grade Top Thread SURFACE 95/8 8.835 36.4 3,997.2 2,469.0 40.00 L-80 IBT< Casing Description .OD(in) ID(in) Top(5168) Set Depth(ttKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread • PRODUCTION 7 6.276 34.2 17,831.8 6,801.3 26.00 L-80 BTCM Tubing Strings • • • Tubing Description String Ma...•ID(in) Top(ftKB) Set Depth(ft..,Set Depth(TVD)(...WI(Ib/ft) Grade Top Connection /0‘9494043.02ABLSIGISWP91/4Pft -• 1. IW TUBING 3 12 2.992 31.2 17,252.2 6.577.8 9.30 L-80 EUE 4.5x3.5"@ 1664 CONDUCTOR;36.0-114.0 ` Completion Details Nominal ID Top(ftKB) Top(ND)(fIKB) Top Incl V) Item Des Com (in) 31.2 31.2 0.00 HANGER FMC TUBING HANGER 4.500 1,607.4 1,515.0 42.22 NIPPLE SSSV BAL-0 LANDING NIPPLE 3.813 1,664.1 1,556.1 45.02 XO Reducing CROSSOVER-4.5"x3.5" 3.500 WRDP;1,607.2 - 15,030.7 5,889.7 71.89 SLEEVE-C BAKER CMU SLIDING SLEEVE w/2.813"DS PROFILE- 2.813 NIPPLE;1,607.4 ,;I; CLOSED 15,085.7 5,906.8 71.79 PACKER BAKER PREMIER PACKER 2.870 15,143.8 5,925.0 71.83 NIPPLE CAMCO D NIPPLE 2.750 • 17,241.5 6,574.6 72.53 WLEG BAKER WIRELINE ENTRY GUIDE 2.867 i Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ttKB) (ttKB) (") Des Com Run Date ID(in) 1,607.2 1,514.9 42.21 WRDP 3.812"WRDP(SN HSS-276) 10/28/2014 1.125 GAS LIFT 2.4973 Perforations&Slots Shot Dens -- Top(ND) Btm(ND) (shots/f Top OtKB) Btm(ttKB) TVD) (ttKB) Zone Date t) Type Com 1 17,408.0 17,440.0 6,626.4 6,637.5 4/30/2009 ' 6.0'IPERF HES 2.0"Scalloped • Guns,60 deg phase, • millenium charges Mandrel Inserts St SURFACE;36.4-3.99].2) ati on Top(ND) Valve Latch Port Size TRO Run .- . N Top(ttKB) (ttKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com FI. 2,497.3 2,005.2 CAMCO KBG-2- 1 GAS LIFT GLV BK 0.156 1,742.0 4/15/2013 •1R GAS LIFT;8,700.5 e1, 2 8,700.5 3,934.1 CAMCO KBG-2- 1 GAS LIFT GLV BK 0.188 1,794.0 4/15/2013 1R 3 14,971.4 5,871.3 CAMCO KBG-2- 1 GAS LIFT OV BK03 0.250 0.0 4/16/2013 1R Notes:General&Safety • End Date Annotation GAS LIFT;14.971.4 4/27/2009 NOTE:View Schematic w/Alaska Schematic9.0 • SLEEVE-C;15,030.7 PACKER,15.0857 II,� 9 • L NIPPLE;16143.8 WLEG;17,241.5 - jr, ~ IPERF,17,408.0-17.440 0- PRODUCTION 31212.8318 a 18 CD3-304 Scale Inhibition Treatment 1/31/15 Aqueous Scale Inhibitor Squeeze Job pumped 1/31/15 from 16:30 to 18:43. LRS= Little Red Services - Initial pressure TBG/IA/OA-343/1650/340 - Pumped 50 bbls seawater preflush from seawater injection system at 3.8 bpm,TBG/IA/OA- 456/1578/321 - LRS pumped 312 gals WAW5206 at.4 bpm while seawater injection system pumped 67 bbls seawater at 3.9 bpm,TBG/IA/OA—850/1468/237 - LRS pumped 468 gals SCW4004 scale inhibitor at .65 bpm while seawater injection system pumped 63 bbls seawater at 3.9 bpm,TBG/IA/OA—850/1446/229 - Seawater injection system pumped 294 bbls seawater overflush at 3.9 bpm,TBG/IA/OA— 605/1392/215 Interval treated: 17,408'—17,440' Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the fife. (~ C~' _ ~ ~ ~ Well History File Identifier Or anizin (done) g g ^ Two-sided II I II'I II II II I II III ^ Rescan Needed III (I'I I' II I I II I III RE AN DIGITAL DATA OVERSIZED (Scannable) Color Items: ^ Diskettes, 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 Proogn I g III II IIII II III II III BY: Maria Date: ~ /s/ Scanning Preparation ~_ x 30 = _L~xv + ~,~' =TOTAL PAGES (Count does not include cover shee ) BY: Maria Date: ' / / ~/~D /s/ Production Scanning Stage 1 Page Count from Scanned File: ~v (Count does include cov r sheet) Number in Scannin Pre aration: 1~YES NO Page Count Matches 9 p BY: Maria Date: ~/Q' rQ /sl -~~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ IIIIIII Scannin is complete at this point unless rescanning is required. II (II'I II I II 9 ReScanned II I I I II II I I III I (III BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIIII III III II 10/6/2005 Well History File Cover Page doc • , STATE OF ALASKA ALA, .OIL AND GAS CONSERVATION COMI .ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r Rug Perforations r Perforate rOther Scale Inhibition Alter Casing r Pull Tubing r Stimulate-Frac Waiverr Treatment r r Time Extension Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 209-028 — 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service t 50-103-20598-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 372103,372104,372105 ' CD3-304 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Colville River Field/Fiord Oil Pool 11.Present Well Condition Summary: Total Depth measured 17843 feet Plugs(measured) none true vertical 6806 feet Junk(measured) none Effective Depth measured . 17743 feet Packer(measured) 15086 true vertical 6760 feet (true vertical) 5907 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 114 114 SURFACE 3961 9.625 3997 2469 PRODUCTION 17798 7 17832 6801 E E1 ti Perforation depth: Measured depth: 17408'-17440' NNE JUIt _ �r�� m i ,14 True Vertical Depth: 6627'-6638' 1� w Tubing(size,grade,MD,and TVD) 4.5 x 3.5, L-80, 17242 MD,6578 TVD p r Packers&SSSV(type,MD,and ND) PACKER-BAKER PREMIER PACKER @ 15086 MD and 5907 TVD RBDMS MAY 1 5 2014 NIPPLE-SSSV BAL-O LANDING NIPPLE @ 1607 MD and 1515 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 17408'-17440' Treatment descriptions including volumes used and final pressure: see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 674 1662 2449 1578 304 Subsequent to operation 988 2484 2649 1744 322 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development rq .Service r Stratigraphic r 16.Well Status after work: • Oil Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: none Contact Kerry Freedman t 265-6579 Email Kerry.C.Freedman@conocophillips.com Printed Name K r Freedman Title Principal Production Engineer Signature _ e — Phone:265-6579 Date �il l J yl z i y M.4.�— vz-i= S/22 /t 4 y �y Form 10-404 Revised 10/2012 Submit Original Only WNS CD3-304 `P Conoco Phillips Well ore At Attributes Field Name Well Status 'Max Angle MD TD 81KBBtm(ftKB) Alaska,Inc. 501032059800 FIORD KUPARUK PROD 74.96 3,222.38 17,843.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date •••Well CanTig:DEVIATED-CD3-304,4/18201311.06:19 AM SSSV:WRDP Last WO: 42.40 4/24/2009 Schematic-Actual Annotation Depth(ftK6) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:RESET WRDP,GLV C/O osborl 4/18/2013 Casing Strings HN10ER,31 Casing Description String 0... String ID...Top(ft66) Set Depth(f...Set Depth(ND).. String Wt...String... String Top Thrd E- - - - -_. - - - _ - CONDUCTOR 16 15.250 36.0 114.0 114.0 6250 H-40 WELDED 7.:::- SURFACE Casing Description String 0.., String ID...Top(MB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd SURFACE 9 5/8 8.835 36.4 3,997.2 2,469.0 40.00 L-80 IBT< Casing Description String 0... String ID...Top(ftK6) Set Depth(f...Set Depth('P/D)...String Wt...String... String Top Thrd • PRODUCTION 7 6.276 34.2 17,831.8 6,801.3 26.00 L-80 BTCM p Tubing Strings Tubing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd TUBING 31/2 2.992 31.2 17,252.2 6,578.3 9.30 L-80 EUE 4.5"x3.5"@ 1664 CONDUCTOR. Completion Details 36-114 Top Depth ITVD) Top Incl Nomi... atTop(RKB) ("KB) r Rem Description Comment ID(In) 31.2 31.2 -0.04 HANGER FMC TUBING HANGER 4.500 at 1,607.4 1,515.5 44.97 NIPPLE SSSV BAL-0 LANDING NIPPLE 3.813 At 1,664.1 1,556.1 46.11 XO Redudng CROSSOVER-4.5"x 3.5" 3.500 wRDP,112277 .6W a 15,030.7 5,889.6 71.75 SLEEVE-C BAKER CMU SLIDING SLEEVE w/2.813"DS PROFILE-CLOSED 2.813 NIPPLE,1,807 15,085.7 5,906.8 71.79 PACKER BAKER PREMIER PACKER 2.870 15,143.8 5,925.0 71.83 NIPPLE CAMCO D NIPPLE 2.750 • 17,241.5 6,575.4 73.63 WLEG BAKER WIRELINE ENTRY GUIDE 2.867 Other In Hole !reline retrievable plugs,valves,pumps,fish,etc.) Top Depth (TVD) Top Inc! Top(ftK6) (148) 1^) 1Description Comment Run Date ID(in) WRDP 1,515.4 44.97 3.812"WRDP(SN HSS-244) 4/16/2013 1.125 GAS LIFT, 2,497 _ Perforations&Slots Shot Top(ND) Btm(TVD) Dens Top(RKB)Btm(MB) (RKB) (*KB) Zone Dote (oh... Type Comment 17,408.0 17,440.0 6,627.2 6,637.7 4/30/2009 6.0 IPERF HES 2.0"Scalloped Guns,60 deg phase,millenium charges J Notes:General&Safety End Date Annotation SURFACE 4/27/2009 NOTE:View Schematic w/Alaska Schematic9.0 363.997 GAS LIFT. 8.700 . GAS LIFT, !: 14,971 SLEEVE-C, _ J II II15,031 l J LI:11-1 PACKER QUA 15.086 IIIIIIIIII NIPPLE,15,144 I G WLEG,17,242 Mandrel Details --- Top Depth' Top Port 5... (TVD) Incl OD Valve Latch Size TRO Run N...Top)ftK8) (RKB) (°) Make Model (in) Sem Type Type (in) (psi) Run Date Com... 1 2,497.3 2,004.8 69.76 CAMCO KBG-2-1R 1 GAS LIFT GLV BK 0.156 1,742.0 4/152013 2 8,700.5 3,934.0 71.94 CAMCO KBG-2-1R 1 GAS LIFT GLV BK 0.188 1,794.0 4/152013 IPERF, , ., 3 14,971.4 5,871.0 71.70 CAMCO KBG-2-1R 1 GAS LIFT OV BKO3 0.250 0.0 4/16/2013 17,40617,440 € ra PRODUCTION. & • 34-17,832 TD,17,843 . CD3-304 Scale Inhibition Treatment 3/17/2014 Aqueous Scale Inhibitor Squeeze Job pumped 3/17/14 from 10:00 to 14:10. - Initial pressure TBG/IA/OA-280/1574/483. - Pumped 50 bbls seawater preflush from seawater injection system at .84 bpm,TBG/IA/OA- 435/1561/427 - LRS pumped 256 gals WAW5206 at.4 bpm while seawater injection system pumped 55 bbls seawater at 1.7 bpm,TBG/IA/OA-488/1545/363 - LRS pumped 385 gals SCW4004 scale inhibitor at .65 bpm while seawater injection system pumped 52 bbls seawater at 2.4 bpm,TBG/IA/OA-549/1526/289 - Seawater injection system pumped 481 bbls seawater overflush at 3.5 bpm,TBG/IA/OA- 616/1393/137 Intervals treated: 17,408'—17,440' � �\� 7 n t' S T A'1 E ,i .': c a, - , Fie c -= 5:','‘__. ', i :2-\3:i a __ _.�{� c 333 West Sevcnih Avenue �i (�C;A'�.K\;�R SEAN \R\h.1.1, Ancnorocr Alaska 945C 3572 MJ Loveland Well Integrity Project SCANNED MAY 16 2014 ConocoPhillips Alaska, Inc. ,O 7 `^ P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CD3-304 Sundry Number: 314-032 Dear Ms. Loveland: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ae72,;" Cathy v Foerster Chair DATED this// day of January, 2014. Encl. ' ��STATE OF ALASKA `�" AU,....A OIL AND GAS CONSERVATION COMMIS-...N `/` A APPLICATION FOR SUNDRY APPROVALS ,i .1 I • 20AAC25.280 nz 11,01 IQ- e� I 1 1.Type of Request: Abandon E Plug for Redrill r Perforate New Pool r Repair well r Change Appy v�ec)<r' '7 4,f(C Suspend r Plug Perforations r Perforate r Pull Tubing r Time Extension r Operational r Re-enter Susp. r Stimulate r Alter casing r Other:Conductor Extension F, 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Developmen F_' 209-028 • 3.Address: 6.API Number: Stratigraphi r Service r P.O.Box 100360,Anchorage,Alaska 99510 50-103-20598-00 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No F CD3-304- 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 0372105,0372104,0372103 - Colville River Field/Fiord 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): 17843 ° 6806 , Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 114' 114' SURFACE 3961 9.625 3997' 2469' PRODUCTION 17798 7 17832' 6801' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 17408'-17440' ' 6627'-6638' 3.5 L-80 17242 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER PREMIER PACKER • MD=15086 TVD=5907 SSSV-WRDP • MD 1607,TVD 1515 12.Attachments: Description Summary of Proposal F 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r • Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/1/2014 Oil r- Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ IT 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: MJ Loveland/Martin Walters Email: n1878e.cop.com Printed Name MJ LovelancTi Well Integrity Project Signature „........,/7"---e.!!!! z/P Phone:659-7043 Date 1/11/14 Commission Use Only Sundry Number:31 y ✓a -V Conditions of approval: Notify Commission so that a representative may witness ✓✓✓✓ `` Plug Integrity r BOP Test r Mechanical Integrity Test IT Location Clearance r RBDM 9 Other: RBDM'c. . MAY 02014 Spacing Exception Required? Yes 0 No V Subsequent Form Required: / Q __.4 O APPROVED BY / 7 �/ Approved by: I�1MI ONER TH COMMISSION Date: / — / 7- / T A•• •o• d •plicationniis v I o months from th Edatc or approval. 1 Form 10-403(Revised 0/2012) O D I t .� I H iiki ,16/11 Submit Form and Attachments in Duplicate l/'L F ///6//9 f` v ,e. (gOr eL WNS CD3-304 ! . COnocoPhillips 0° Well Attributes Max Angle&MD TD Alaska 111e Wellbore API/UWI Field Name Well Status Incl(°I MD(ftKB) Act 8Ir0(ftKB) cnn.....„,,,p,.-1 501032059800 FIORD KUPARUK PROD 74.96 3,222.38 17,843.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date """WN Casae.DEVIATED-CD3-304,411012013 It OD 19AM SSSV:WRDP Last WO: 42.40 4/24/2009 Schematic-Actual Annotation Depth(8KB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:RESET WRDP,GLV C/O osborl 4/18/2013 Casing Strings HANGER,31 --- Casing Description String 0... String ID...Top(BOB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd ' - - -- CONDUCTOR 16 15.250 36.0 114.0 114.0 62.50 H-40 WELDED Casing Description String 0... String ID...Top(ROB) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd /._._.-1 SURFACE 9 5/8 8.835 36.4 3,997.2 2,469.0 40.00 L-80 IBT< ' Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd PRODUCTION 7 6.276 34.2 17,831.8 6,801.3 26.00 L-80 BTCM 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 31.2 17,252.2 6,578.3 9.30 L-80 EUE 4.5"x3.5"@ 1664 CONDUCTOR, Completion Details 36-114 Top Depth (TVD) Top Incl Nomi... ' Top(ftKB) (RKB) (') Item Description Comment ID(In) 31.2 31.2 -0.04 HANGER FMC TUBING HANGER 4.500 1. 1,607.4 1,515.5 44.97 NIPPLE SSSV BAL-O LANDING NIPPLE 3.813 1,664.1 1,556.1 46.11 XO Reducing CROSSOVER-4.5"x 3.5" 3.500 WRDP,1,607 NIPPLE,1,607Cit; 15,030.7 5,889.6 71.75 SLEEVE-C BAKER CMU SLIDING SLEEVE w/2.813"DS PROFILE-CLOSED 2.813 III15,085.7 5,906.8 71.79 PACKER BAKER PREMIER PACKER 2.870 ', 15,143.8 5,925.0 71.83 NIPPLE CAMCO D NIPPLE 2.750 17,241.5 6,575.4 73.63 WLEG BAKER WIRELINE ENTRY GUIDE 2.867 Other In Hole Wireline retrievable plugs,valves,pumps,fish,etc.) Top Depth (TVD) Top Incl L (15(B) Description Comment ..Run Date ID(in) 1,607.2 1,515.4 44.97 WRDP 3.812"WRDP(SN HSS-244) 4/16/2013 1.125 GAS LIFT, 4 - 2,497 Perforations&Slots Shot / ) Top(TVD) Btm(TVD) Dens Top(ftKB)Btm(ftKB) MB) (ftKB) Zone Date Oh.- Type Comment 17,408.0 17,440.0 6,627.2 6,637.7 4/30/2009 6.0 IPERF HES 2.0"Scalloped Guns,60 deg phase,millenium charges Notes:General&Safety End Date I Annotation SURFACE, 36FACE, 4/27/2009 NOTE:View Schematic w/Alaska Schematic9.0 GAS UFT. 8,700 (s GAS LIFT, SLEEVE-C. 15,031 i 1 1 H (_. 1 PACKER, 15,086 r III NIPPLEts•« i-- , 7/LEG,17.242- 'j 1 Mandrel Details Top Depth Top Port 5... (TVD) Incl OD Valve Latch Size TRO Run N...Top(ftKB) OMB) El Make Model (in) Sery Type Type (in) (psi) Run Date Corn... 1 2,497.3 2,004.8 69.76 CAMCO KBG-2-1R 1 GAS LIFT GLV BK 0.156 1,742.0 4/15/2013 2 8,700.5 3,934.0 71.94 CAMCO KBG-2-1R 1 GAS LIFT GLV BK 0.188 1,794.0 4/152013 IPERF, _.. , 3 14,971.4 5,871.0 71.70 CAMCO KBG-2-1R 1 GAS LIFT OV BKO3 0.250 0.0 4/162013 17,408.17,440- PRODUCTIO 17,8N, A 3432 TD,17,843 14.) 4 ', r r M.. r .k 1 4...4. ConocoPhillips ,,. , 1 1 .- Alaska (�� P.O. BOX 100360 A' "GCC ANCHORAGE,ALASKA 99510-0360 January 10, 2014 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,AK 99501 Commissioner Foesrter: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well CD3-304, PTD 209-028 conductor extension. Please contact Martin Walters or MJ Loveland at 659-7043 if you have any questions. Sincerely, 7 ------'----- --- ------------ MJ eland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska,Inc. Alpine Well CD3-304 (PTD 209-028) SUNDRY NOTICE 10-403 APPROVAL REQUEST January 10, 2014 This application for Sundry approval for Alpine well CD3-304 is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to SC. At some point during normal operations the conductor subsided about 10". With approval,the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Examine surface casing for any corrosion damage. 3. Extend the conductor to starter head and fill the void with cement and top off with sealant. 4. File 10-404 with the AOGCC post repair. NSK Well Integrity Projects Supervisor STATE OF ALASKA Al" OIL AND GAS CONSERVATION CONIISSION • REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ( Repair w ell E Rug Perforations 1 Perforate f` " Other firo Scale Inhibition Alter Casing (" Pull Tubing E Stimulate - Frac [ Waiver I Time Extension E Change Approved Program rOperat. Shutdow n f"" 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 jr Exploratory r - 209 -028 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service 3 - 50- 103 - 20598 -00 c 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 372103, 372104, 372105 -1 — CD3 - 304 9. Logs (List Togs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none Colville River Field / Fiord Oil Pool 11. Present Well Condition Summary: Total Depth measured 17843 feet Plugs (measured) none true vertical 6806 feet Junk (measured) none Effective Depth measured 17743 feet Packer (measured) 15086 true vertical 6760 feet (true vertical) 5907 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 114 114 SURFACE 3961 9.625 3997 2469 PRODUCTION 17798 7 17832 6801 6wr. �p D Perforation depth: Measured depth: 17408' 17440' "" � n 2013 ` AGCC True Vertical Depth: 6627' - 6638' Tubing (size, grade, MD, and TVD) 4.5 x 3.5, L-80, 17252 MD, 6578 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER PREMIER PACKER @ 15086 MD and 5907 TVD BAL-0 LANDING NIPPLE @ 1607 MD and 1516 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 17440' 17843' Treatment descriptions including volumes used and final pressure: see attached summary 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation 880 2120 1729 — 327 Subsequent to operation 1020 2250 1996 -- 322 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory E Development I✓ Service E' Stratigraphic 1" 16. Well Status after work: , Oil 5.7 Gas E WDSPL E Daily Report of Well Operations XXX GSTOR I WINJ r WAG £ " GINJ E SUSP j°°°°" SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Tim Nelson a, 265 -6859 Email Tim.J.Nelson a( conocophillips.com Printed Name Tim Nelson Title Staff Production Engineer Signature Phone: 265 -6859 Date j.4p/j rO /3 1 vL RSDMS APR 0 3 2013 4-4 1 1 j 3 Form 10 -404 Revised 10/2012 %9 Submit Original Only • • Scale Inhibition Treatment: CD3 -304 3/25/2013 Initial pressure TBG /IA /OA- 730/1658/402; Facility pumped 50 bbls SW preflush; LRS pumped 3.9 bbls WAW5206 (164 gal) at 0.4 bpm while facility pumped 34 bbls SW at 4 bpm, 532/1677/154; LRS pumped 39 bbls SCW4004 (1646 gal) at 0.6 bpm while facility pumped 223 bbls of SW at 4 bpm 531/1774/112; facility pumped 868 bbls of SW over - displacement. Interval treated for this well was 17440' — 17843' a WNS • CD3 -304 ConocoPhillips di Wen Attributes Max Angle & MD TD I I I . Alaska. Inc Wel!bore APUUWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) 501032059800 FIORD KUPARUK PROD 74.96 3222.38 17,843.0 °' Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date "' - SSSV: WRDP Last WO: 42.40 4/24/2009 Well Gonne'. DEVIATED - CD3 -304, 1 /91201 3 10:16 36 AM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason: RESET WRDP osborl 1/9/2013 Casing Strings MANGER. 31 1111. Casing Description String O. String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) .. String Wt... String String Top Thrd CONDUCTOR 16 15.250 36.0 114.0 114.0 62.50 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 9 5/8 8.835 36.4 3,997.2 2,469.0 40.00 L - 80 IBT< Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd _ _ _ _ PRODUCTION 7 6.276 34.2 17,831.8 6,801.3 26.00 L -80 BTCM Tubing Strings ' 1 p Tubing Description String 0... String ID ... Top (MKS) Set Depth (f... Set Depth (TVD) ... String Wt... String .. String Top Thrd TUBING 31/2 2.992 31.2 17,252.2 6,578.3 9.30 L -80 EUE 4.5 "x3.5" @ 1664 1 CONDUCTOR, _ 1 Completion Details 36 -114 _. Top Depth (TVD) Top 1061 Norni... Top (ftKB) (ftKB) (°) Item Description Comment ID (in) 31.2 31.2 -0.04 HANGER FMC TUBING HANGER 4.500 '` _ 1,607.4 1,515.5 44.97 NIPPLE SSSV BAL-O LANDING NIPPLE 3.813 1,664.1 1,556.1 46.11 XO Reducing CROSSOVER - 4.5" x 3.5" 3.500 WRDP, 1, 1 , 07 15,030.7 5,889.6 71.75 SLEEVE -C BAKER CMU SLIDING SLEEVE w/ 2.813" DS PROFILE - CLOSED 2.813 FP NIPPLE, 15,085.7 5,906.8 71.79 PACKER BAKER PREMIER PACKER 2.870 15,143.8 5,925.0 71.83 NIPPLE CAMCO D NIPPLE 2.750 ilk 17,241.5 6,575.4 73.63 WLEG BAKER WIRELINE ENTRY GUIDE 2.867 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Inc! Top (ftKB) (ftKB) (°) Description Comment Run Date ID (!n) 1,607.2 1,515.4 44.97 WRDP 3.812" WRDP (SN HRS - 66) 8/14/2012 1.125 GAS LIFT, 2,497 Perforations & Slots C Shot / 1 Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (MB) Zone Date Oft- Type Comment 17,408.0 17,440.0 6,627.2 6,637.7 4/30/2009 6.0 IPERF HES 2.0 "Scalloped Guns, 60 deg phase, millenium charges Notes: General & Safety End Date Annotation SURFACE, 4/27/2009 NOTE: View Schematic w/ Alaska Schematic9.0 38-3,997 r GAS LIFT, 8,700 1 GAS LIFT, 14,971 ..- ....... 1 SLEEVE -C, { - ' , 15,031 ` I PACKER, _ _ J l 15,086 L NIPPLE, 15,144 i d WLEG, 17.242 Mandrel Details Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) ( °) Make Modol (!n) Sery Type Type (in) (psi) Run Date Com... 1 2,497.3 2,004.8 69.76 CAMCO KBG -2 -1R 1 GAS LIFT DMY BK 0.000 0.0 4/28/2009 2 8,700.5 3,934.0 71.94 CAMCO KBG -2 -1R 1 GAS LIFT DMY BK 0.000 0.0 4/25/2009 IPERF, 3 14,971.4 5,871.0 71.70 CAMCO KBG -2 -1R 1 GAS LIFT OV BK 0.250 0.0 7/28/2012 17,408 - 17,440 P9ODTON, , A 34 TD, 17.843 • C-' A, C'-1b 3 -30¢ ? r zenotto Regg, James B (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Thursday, July 26, 2012 8:34 PM To: Regg, James B (DOA) Subject: Report of SCP on CD3 -304 (PTD 209 -028) 7 -26 -12 Attachments: CD3 -304 schematic.pdf Jim, Alpine producer CD3 -304 (PTD 209 -028) is experiencing sustained casing pressure of the inner annulus above 2000psi (currently at 2036psi). The well was shut in for plant maintenance on 7 -21 -12 and its IA pressure rose above 2000 psi on 7- 23 -12. Initial attempts to bleed the well today failed. An unchecked GLV is the suspected cause of the SCP and slickline will be mobilized in a couple of days to address the issue. A follow -up email will be sent when the issue has been resolved. Attached are the 90 day TIO plot and schematic. Brent Rogers / Kelly Lyons �� Q �� Problem Wells Supervisor CEO ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 1 • • CRU CD3 -304 PTD 2090280 7/26/2012 TIO Pressures Plot Well Name CD3 -304 Notes: Start Date 427 ±2012 Days 90 End Date 726;2012 Annular Communication Surveillance 2500 — 140 WHP — 120 2000 — — 100 1500 — 80 B _ al N -a — 60 1000 — 40 500 — 20 0 0 Apr -12 May -12 Jun -12 Jul -12 Aug -12 9500 ._ __.__...__.... .._.. 9000 3500 G 3000 6 2500 DGI 2000 MGI ° ua0 PWI 1000 SWI 500 .REPO Apr -12 May -12 Jun -12 Jul -12 Aug -12 Date WNS CD3-304 C i ft ip s Wel A ttr i bute s Via« MD TD__ • ,(flC Wellbore AP OUWI Field Na W Status Ind (.) MD (ftKB) Act Btm (ftKB) - ,0 9 , 4 501032059800 !FIORD KUPARUK I PROD 74.96 3,222.38 17,843.0 Comment H2S (ppm) Date Annotation End Date KB -0rd (ft) Rig Release Orte •• , Weil Confg 203 . 304 �1"21251261 0 101 l A SSSV: WRDP Last WO: 42.40 4/24/2009 • 3cheoolio.. dual Annotation Depth (ftKB) End Date Annotation Lent Mod ... End Date Last Tag: Rev Reason: RESET WRDP, GLV C/O Imosbor 12/25/2010 _..._ ._.. - „, . . - 91 t a�E a HANGER, 31 - String Top Thr . . • . . r t • t r WELDED h String Top Thrd •• 40.00 :r IBT< , _ String Top Thrd --- as • - r rr • BTCM ` + ` Tubing Descnp11 String 0... Stang ID Top (ftKB) Set Depth 11 Set Depth (TVD) ,.. String Wt... String .. String Top 7hrtl TUBING 4.5” @ 3 3 1 2.9 31.2 17,252 6,5 9.30 L -80 EUE .r a.�a - r w•., =r. = x3.5" @1664.1' CONDUCTOR. 36-114 -• h • -- Ali I Top Depth •:!.ii0P411:it II (7VD) Topinel Nomi... Top (ftKB) (ftKB) (e) _ ID (in) 31.' 31.2 -0.04 Hanger 4.500 3 1,607.4 1,515.5 0 Landing NIPPLE 3.813 WRDP,1so7 1,664.1 1,556.1 • • e :4 2.992 SAPETVVLV, %� s 15,030,7 5,889.6 a 2.813 1,607 15,085,7 5,906.8 71.79 PACKER Premier •: •e 2,87ID 2.870 - _ 15,143.8 5,925.0 71.83 NIPPLE Camco 2.75" D Nipple 2,750 I 17,241.5 6,575.4 84 • e 2.867 s = �' R : Z' 1 y ti x tt'i� Top Depth (TVD) Top (NCB) (ft ® 12/17/2010 ID (in) rrrggg , 607.2 1,515.4 e • ' a • 1.125 GAS LIFT, k - 2,497 �" ;. Btm (TVD) Itet Top (ttK8) : (ftKB) Zone Comment 17,408.0 17,440.0 6,627.2 6,637.7 4/30/2009 • t 1PERF HES 2.0 "Scalloped Guns, 60 deg 3 phase, millenium charges t Notes: General & Safety J, ` 'r 'tt . �.,n � , . P End Date Annotation SURFACE. 4/27/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 36 -3,997 WWII GAS LIFT, 8.700 GAS LIFT, 1 it!.. 4,971 l SLEEVE -C, 15,031 tillt. A. PACKER, 15,086 oenewnweare 111 NIPPLE, 15,144 t ''' AI WLEG, 17,242 Mandrel Details % t: Top Depth Top Port (TVD) Incl OD Valve Latch Si TRO Run Stn lop (NCB) (WS) ( °) Make Model (In) Sery Type Type (in) (psi) Run Date Corn -.. 1 2,497.3 2,004.81MCAMCOKBG -2 -1 1111 GAS DMY 0.000 0.04128/2009 2 8,700.5 3,934.0 CAMCO KBG -2 -1R GAS LIFT DMY 0.000 0.0 4/25/2009 IPERF, = - 3 1 4,971,4 5,871.0 71,70 CAMCO KBG -2 -1R GAS LIFT OV WM 0,250 0.0 12/17/2010 17,408- 17,440 - . PRODUCTION. A 34- 17,832 TEL 17.843 • WN CD3-304 C .3 h ill ° ,r Wen Attribute `,` , i 9 - - - '. �W g �A'i c s q ; i_.` � ° ! s .3= - ItiC W API /UWI Field Nano Well Statua Incl ( °) MD (ftKB) Act Btm (ttKB) j 501032059800 FIORD KUPARUK PROD 74.96 3,222 38 17,843.0 Comment H2S (ppm) Date Annotation End Date KB -0rd (ft) Rig Release Date • Well C''''' DEVIAT CD3 -304, 121 71 54 AM SSSV: WRDP Last WO: 42.40 4/24/2009 S chematic- :Actua25010 /0 l Annotation Depth (MB) End Date Annotation Last Mod... End Data Last Tag: Rev Reason: RESET WRDP, GLV C/0 Imosbor 12/25/2010 Cason ^'$trhi tS r _ HANGER, 31 �- y ' " 1 � t w5 � ¢aI t ll fid,1 S r _ � �,� � , Casing Description String 0... Stn ng ID ...'Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd k t CONDUCTOR 16 15.250 36.0 114.0 114.0 62.50 H WELDED __ ' .. JAV, Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) •.. String Wt... String ... String Top Thrd SURFACE 9 5/8 8.835 36.4 3,997.2 2,469.0 40.00 L -80 IBT< i+ Casing Desaiption String 0... String ID ... Top (ftKB) Set Depth (L.. Set Depth (TVD) ... String Wt... String ... String Top Thrd 1 q _ PRODUCTION 7 6.276 . 34 .2 17,831.8 6,801.3 26 00 L-80 BTCM Tubin• Strin•s F, uil 5 FIr - ' T b g Descr puon Str ng 0... String ID Top (ftKB) Set Depth (1... Set D pth (TVD) ... St ing Wt... St ing ... String Top Thrd TUBING 4.5 @ 31 2 3 1/2 2.992 31 2 17,252.2 6,578.3 9.30 L -80 EUE s4 _ = _ ac, ,, ^V b , x3.5" @1664.1' CONDUCTOR. _ • letion Details .. ° Z 36114 ToP Depth ( °) Item Description (TVD) Top Intl (ftKB) Comment ID (In) 31.2 31.2 -0.04 HANGER FMC Tubing Hanger 4.500 1,607.4 1,515.5'' SAFETY VLV SSSV Ba1-0 Landing NIPPLE 3.813 WRDP, 1,607 1,664.1 1,556.1 EMI X0 - Reducing X0 - 4 1/2" (ID 3.958, 12.6 #, L -80 IBTM) X 3.5" EUE 2.992 sAFETV vLV. _ 15,030.7 5,889.6 ® SLEEVE C Baker 31/2" CMU Sliding Sleeve W/2.813" DS Profile ( Closed) 2.813 6W - -_... 15,085.7 5,906.8 IIIM PACKER Premier Packer 7" X 3 1/2" (Baker) 5.98 OD 2,871D 2.870 15,143.8 5,925.0 NM NIPPLE Camco 2.75" D Nipple 2.750 17 241 5 6,575 4 73.63 WLEG 3 1/2'9.39L-80 EUE pup jt w/ Baker WLEG (4.51" OD) 2.867 E Other In Hole Wireline retrievable .lu • s, valves, pumps` fists Top Depth (TVD) Top Incl L. a, (RKB) (ftKB) ( °) Dosed. on Comment Run Date ID In) 1,607.2 1,515.4 44.97 WRDP 3.812" WRDP (SN HPS - 283) 12/17/2010 1.125 GAS LIFT, .497 , T 2 . 7. trorat L: ons & Slots Shot Top (TVD) atm (TVD) Dens Top (ftK8) Btm (RKB) (ftKB) (RKB) Zone Date (ch *" Type Commem 17,408.0 17,440.0 6,627.2 6,637.7 4/30/2009 6.0 IPERF HES 2.0 "Scalloped Guns, 60 deg phase, millenium charges ®' Annotation SU36.3,997 RFACE, 4/27/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 GASLIFT, T ir 1 IR 6,700 GAS LIFT, 14,971 is., 1 SLEEVE -C, 15.031 T PACKER,. 15,086 -o r 3 NIPPLE. 15.144 tr. I WLEG,17,242 !1.-. ;,: t1f- 9 €I +I`: e e. _ - . 7 Top Depth Top Port (TVD) Intl Valve Latch Size TRO Run Top ((MB) (RKB) (°) Make Model Sery Type Type ON (psi) Run Date Com... 2,497.3 2,004.8 69.76 CAMCO KBG-2-1R GAS LIFT DMY BK 0.000 0.0 4/28/2009 8,700.5 3,934.0 71.94 CAMCO KBG -2 -1R GAS LIFT DMY BK 0.000 0.0 4/25/2009 14,971.4 5,871.0 71.70 CAMCO KBG -2 -1R GAS LIFT OV BK 0.250 0.0 12/17/2010 17.40617,440 -�_-''.. PRODUCTION, 1 34. 17.832 TD, 17,843 STATE OF ALASKA ALAI OIL AND GAS CONSERVATION COMARION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon I Repair well """ Rug Perforations r Perforate r Other Scale Inhibitor Rill Tubing Treatment Alter Casing r g ( �` Stimulate - Fr ]°'-' W f"' Time Ex tension j"" Change Approved Rogram r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory f - 209 - 028 3. Address: 6. API Number: Stratigraphic f Service E P. O. Box 100360, Anchorage, Alaska 99510 -- 50 103 20598 - 00 ' 0 Q 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 372103, 372104, 372105 - CD3 - 304 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none Colville River Field / Fiord Oil Pool 11. Present Well Condition Summary: Total Depth measured 17843 feet Plugs (measured) None true vertical 6806 feet Junk (measured) None Effective Depth measured 17743 feet Packer (measured) 15086 true vertical 6760 feet (true vertucal) 5907 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 114 114 SURFACE 3961 9.625 3997 2469 PRODUCTION 17798 7 17832 6801 RCNED WitsiNEDMAR 1 b 2012 Perforation depth: Measured depth: 17408' 17440' MAR 1 k. 2012 True Vertical Depth: 6627' - 6637' 1kik0 0ll & Gas Cotes. Commission Tubing (size, grade, MD, and TVD) 3.5, L -80, 17252 MD, 6578 TVD Anchorage Packers & SSSV (type, MD, and TVD) PACKER - PREMIER PACKER 7" X 3 1/2" (BAKER) @ 15086 MD and 5907 TVD Bat-0 Landing Nipple @ 1607 MD and 1516 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 17408'- 17440' Treatment descriptions including volumes used and final pressure: see attached summary 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 920 3798 1710 -- 345 Subsequent to operation 1077 4335 1494 -- 379 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service r Stratigraphic r 16. Well Status after work: .- Oil jai Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP j`" SPLUG E 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Jack Walker (a 265 -6268 Printed Name Jack Walker A Title Principal Production Engineer j Signatur vv Phone: 265 -6268 Date 1 fin,, t t - / 2 MAR i4 zol 5/clI Form 10-404 Revised 11/2011 Submit Original Only W NS • CD3 -304 �? ConocoPhillip5 L € Well Attributes Max Angle & MD TD +:-' W API /UWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) Alaska, Inc 501032059800 FIORD KUPARUK PROD 74.96 3,222.38 17,843.0 c.urcsaiivIlim Comment H2S (ppm) Date Annotation End Date KB .Grd (ft) Rig Release Date "' SSSV: WRDP Last WO: 42.40 4/24/2009 Well Confiq: DEVIATED - CD3 -304 12125/201010: 11: 54 AM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag Rev Reason: RESET WRDP, GLV C/O Imosbor 12/25/2010 Casing Strings HANGER, 31 Casing Description Strang 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) .. String Wt... String String Top Thrd 111 CONDUCTOR 16 15.250 36.0 114.0 114.0 62.50 H WELDED Casing Description String 0... String ID ... 'Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.835 36.4 3,997.2 2,469.0 40.00 L - 80 IBT< ,.T.. - Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd " - _ _ PRODUCTION 7 6.276 342 17,831.8 6,801.3 26.00 L -80 BTCM a, e P Tubing Strings ,.�,`,,; Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f_. Set Depth (TVD) ... String Wt... String .. String Top Thrd TUBING 4.5" @ 31.2' 3 1/2 2.992 31.2 17,252.2 6,578.3 9.30 L -80 EUE x3.5" @1664 1' CONDUCTOR. Completion Details 36 -114 Top Depth (TVD) Top Inc! Nomi... Top (ftKB) (ftKB) (°) Item Description Comment ID (in) 31.2 31.2 -0.04 HANGER FMC Tubing Hanger 4.500 1,607.4 1,515.5 44.97 SAFETY VLV SSSV Ba1-0 Landing NIPPLE 3.813 waDP 1607 1,807 J 1,664.1 1,556.1 46.11 X0 - Reducing X0 - 4 1/2" (ID 3.958, 12.6#, L-80 IBTM) X 3.5" EUE 2.992 SAFETY VLV r i 15,030.7 5,889.6 71.75 SLEEVE -C Baker 31/2" CMU Sliding Sleeve W /2.813" DS Profile ( Closed) 2.813 15,085.7 5,906.8 71.79 PACKER Premier Packer 7" X 3 1/2' (Baker) 5.98 OD 2,871D 2.870 15,143.8 5,925.0 71.83 NIPPLE Camco 2.75" D Nipple 2.750 17,241.5 6,575.4 73.63 WLEG 3 1/2" 9.3# L-80 EUE pupjt w/ Baker WLEG (4.51" OD) 2.867 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Inc] Top (ftKB) (ftKB) ( °) Description Comment Run Date ID (in) --- 1,607.2 1,515.4 44.97 WRDP 1812" WRDP (SN HPS - 283) 12/17/2010 1.125 GAS LIFT, 2.497 Perforations & Slots Shot t Top (TVD) Btm (TVD) Dens Top IftKB) 8101 (ftKB) (ftKB) (ftKB) Zone Date Ish ., Type Comment 17,408.0 17,440.0 6,627.2 6,637.7 4/30/2009 6.0 IPERF HES 2.0 "Scalloped Guns, 60 deg phase, millenium charges Notes: General & Safety SURFACE, I End Date Annotation 4/27/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 36-3997 GAS LIFT. 8,700 T. GAS LIFT, t r-^ 14,971 SLEEVE -C, i , I 15,031 PACKER, J 15,086 eV- ':-' t , NIPPLE. 15,144 I at WLEG, 17,242 P Mandrel Details Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) l Make Model (in) Sery Type Type ON (psi) Run Date Com... 1 2,497.3 2,004.8 69.76 CAMCO KBG -2 -1R 1 GAS LIFT DMY BK 0.000 0.0 4/28/2009 2 8,700.5 3,934.0 71.94 CAMCO KBG -2 -1R 1 GAS LIFT DMY BK 0.000 0.0 4/25/2009 -M 111 IPERF, 3 14,971.4 5,871.0 71.70 CAMCO KBG -2 -1R 1 GAS LIFT OV BK 0.250 0.0 12/17/2010 17,408- 17,440 PRODUCTION, e, • 3417,832 TD, 17.843 • • CD3 -304 Scale Inhibition Treatment: 2/13/2012 Initial pressure TBG /IA /OA — 500/1291/403; Facility pumped 50 bbls SW preflush; LRS pumped 4 bbls WAW5206 (165 gal) at 0.4 bpm and facility pumped 34 bbls SW, 500/1313/403; LRS pumped 39 bbls SCW4004 (1650 gal) at 0.6 bpm and facility pumped 148 bbls of SW, 275/1386/0; facility pumped 868 bbls of SW over - displacement. STATE OF ALASKA ALASKA• AND GAS CONSERVATION COMMISS e REPORT OF SUNDRY WELL OPERATIONS A * to 1. Operations Performed: Abandon r Repair w ell r Rug Perforations r Stimulate r Other Alter Casing r Pull Tubing r '•. Perforate New Pool " Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 Exploratory r v 209 -028 3. Address: 6. API Number: Stratigraphic r Service F. P. O. Box 100360, Anchorage, Alaska 99510 — 50- 103- 20598 -00 ` 03 7. Property Designatii n (Lease Number): 8. Well Name and Number: ADL 372103, 372104, 372105 < CD3 - 304 9. Field /Pool(s): Colville River Field / Fiord Oil Pool 10. Present Well Condition Summary: Total Depth measured 17843 feet Plugs (measured) None true vertical 6806 feet Junk (measured) None Effective Depth measured 17743 feet Packer (measured) 15086 true vertical 6760 feet (true vertucal) 5907 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 114 114 SURFACE 3961 9.625 3997 2469 PRODUCTION 17798 7 17832 6801 �1. �` RECEIVE!) Perforation depth: Measured depth: 17408' - 17440' p, 2 1 True Vertical Depth: 6627 Maks Oil Tubing (size, grade, MD, and TVD) 3.5, L -80, 17252 MD, 6575 TVD ;'nCllfif Packers & SSSV (type, MD, and TVD) PACKER - PREMIER PACKER (BAKER)@ 15086 MD and 5907 TVD SAFETY VLV - SSSV Bal -O Landing NIPPLE @ 1607 MD and 1515 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 17408' - 17440' Treatment descriptions including volumes used and final pressure: see attached summary 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 955 2498 1638 -- 334 Subsequent to operation 987 3046 2065 -- 350 13. Attachments 14. Well Class after work: y Copies of Logs and Surveys run Exploratory r Development F." r Stratigraphic r 15. Well Status after work: Oil jz,7 Gas r WDSPL Daily Report of Well Operations XXX GSTOR `" WINJ r WAG r GINJ r SUSP r SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Tim Schneider 265 -6859 Printed Name Tim Schneider Title Staff Production Engineer Signature 4/ /iew41 Phone: 265 -6859 Date y...._ e../-/ Form 10-404 Revised 10/2010 MOMS 'APR 2 ubmit Original Onl y . • W NS CD3 -304 C({o ((��( i Well Attributes Max Angle & MD TO AlaASInc Wr fi� Weli bore APUUWI (Field Name Well Status 'noir) [MD (ftKB) Act Btm (ftKB) • r 501032059800 FIORD KUPARUK PROD 74.96 3,222.38 17,843.0 '� Comment H2S (ppm) Date Annotation End Date KB - Grd (ft) Rig Release Date "' SSSV WRDP I Last WO: 42.40 4/24/2009 eAC DEVIAT,Fb� 611 AM - _ = - ..s -- En - -_ $me tk, -A4uaL _ Annotation Depth(ftK6) End Date Annotation Last Mod ... End Dab Last Tag Rev Reason' RESET WRDP, GLV C/O Imosbor 12/25/2010 -- Casin Strings HANGER, 31 - Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) String Wt... String ... String Top Thrd CONDUCTOR 16 15.250 36.0 114.0 114.0 62.50 H-40 WELDED Casing Description String 0... String ID... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 9 5/8 8.835 36 4 3,997.2 2,469.0 40.00 L-80 IBT< ': Casing Description String 0... String ID... Top ( ftKB ) - Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd - - -- - -- - -- - _ - -.. .i'': - _ _ _ PRODUCT 1ON 7 6.276 34.2 17,831.8 6,801.3 26.00 L -80 BTCM "'' r Tubing Strings Tubing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (TVD) String Wt.. String ... String Top Thrd TUBING 45' @312 312 2.992 31.2 17,252.2 6,578.3 9.30 L -80 EUE x35" @1664.1' CONDUCTOR, Completion Details 36 -114 Top Depth - -- (TVD) Top Intl r i Top (ftKB) 9KB) (1 Item Description Comment ID(in) __ 31.2 31.2 -0.04 HANGER FMC Tubing Hanger 4.500 -...,� 1,607.4 1,51 44.97 SAFETY VLV SSSV Ba1-0 Landing NIPPLE 3.813 ', 1,664.1 1 556.1 46.11 X0 - Reducing X0 -4 1/2" (ID 3.958, 12.6#. L -80 IBTM) X 3.5" EUE 2.992 WRDP, 1,607 SAFETY VLV, _ 15,030.7 5889.6 71.75 SLEEVE - C Baker 312" CMU Sliding Sleeve W/2.813" DS Profile (Closed) 2.813 - 1,607 15,085.7 5,955 3 71.79 PACKER Premier Packer 7' X 3 12" (Baker) 5.98 OD 2,87 ID 2.870 I 15,143.8 5,92' ■ S 71.83 NIPPLE Camco 2.75" D Nipple 2.750 ' 17 241.5 6,5)", 4 73.63 WLEG 312" 9.36 L -80 EUE pup it wl Baker WLEG (4.51' OD) 2.867 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth' (TVD) Top Intl Top (ftKB) (ftKB) ( °) l)aseription Comment Run Date ID (in) 1,607.2 1,515 4 44.97 WRDP 3.812" WRDP (SN HPS -283) 12/17/2010 1.125 GAS LIFT. 2,497 Perforations & Slots Shot Top (TVD) Btm (TVD) Dens Top MKS) Sim MKS) ((KB) (ftKB) _ Zone Date (Oh--- T •• Comment 17,408.0 17,440.0 4,627.2 6,637.7 4/30/2009 6.0 IPERF HES 2.0 "Scalloped Guns, 60 deg phase, millenium charges Notes: Genera( & Safety _ -- End Date Annotation -- SURFACE, " -- 36 - 3,997 4/27/2009 NOTE VIEW SCHEMATIC w /Alaska Schemabc9.0 GAS LIFT, 8,700 GAS LIFT, �" 14,971 A SLEEVE -C, 15,031 PACKER. 15,086 l NIPPLE, 15,144 WLEG,17,242 ' Mandrel Details Top Depth Top Port (0/0) Incl OD Valve Latch Son TRO Run Stn Top (DICE) (ftKB) (1 Make Model (In) Sere Type TYpe 0^) (psi) Run Dab Can... 1 2,497.3 2,004.8 69.76 CAMCO KBG -2 -1R 1 GAS LIFT DMY BK 0.000 0.0 428/2009 2 8,700.5 3,934.0 71.94 CAMCO KBG -2 -1R 1 GAS LIFT DMY BK 0.000 0.0 4/25/2009 IPERP, _ _ -. - 3 14,971.4 5,871.0 71.70 CAMCO KBG -2 -1R 1 GAS LIFT OV BK 0.250 0.0 12/172010 17,408-17,440 i' PRODUCTION, I 3417,832 TD, 17,843 I • CD3 -304: Scale squeeze pumped 3/30/2011; initial TBG /IA /OA, 545/1650/728 psi; facility pumped 50 bbl pre -flush with injection water at 3.5 ppm; LRS pumped 116 gallons WAW5206 at 0.4 bpm while facility pumped 25 bbls injection water at 4 bpm, 619/1493/338; LRS pumped 1155 gallons SCW4004 at 0.6 bpm while facility pumped 156 bbls injection water at 4 bpm, 758/1380/ -9; facility pumped 906 bbl over - displacement with injection water at 3.4 bbpm; well shut in for 12 hours and returned to service. • • -1,..-- ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 a©_ oa.c6 February 3, 2011 9 3 O 4 Commissioner Dan Seamount � " LA Alaska Oil & Gas Commission • ~ F :i 1, ;, i 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 FEB 0 4 2011 i`l' =:gip O' - in . Cor E' - ,;stoat Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with 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 January 31, 2011. 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, , ; /17.-7- 1 / 44-1 ' -- / 7 MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Alpine Field Date 2/3/2011 CD3 Pad Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement _ pumped cement date . inhibitor sealant date ft bbls ft gal CD3 -106 50103206110000 2100010 16" NA 16" NA 7.65 1/31/2011 CD3 -110 50103205090000 2050410 4" NA 6" NA 2.13 1/31/2011 CD3 -112 50103205270000 2060320 3" NA 16" NA 2.73 1/31/2011 CD3 -114 50103205440000 2070330 5" NA _ 14" NA 2.55 1/31/2011 CD3 -121 50103206150000 2100220 32" NA 32" _ NA 27.2 1/31/2011 CD3 -122 50103206090000 2091530' 74" NA 74" NA 32.2 1/31/2011 CD3 -124 50103206120000 2100080 17" NA _ 17" NA 5.1 1/31/2011 CD3 -301A 50103205430100 2060170 9" NA 15" NA 4.25 1/31/2011 CD3 -302A 50103205220100 2100350 5" NA 16" NA 3.83 1/31/2011 CD3 -304 50103205980000 2090280 18" NA 18" NA 5.9 1/31/2011 DATA SUBMITTAL COMPLIANCE REPORT 716/2010 Permit to Drill 2090280 Well Name/No. COLVILLE RIV FIORD CD3-304 Operator CONOCOPHILLIPS ALASKA INC MD 17843 TVD 6807 Completion Date 4/29/2009 Completion Status 1-OIL Current Status 1-OIL API No. 50-103-20598-00-00 UIC N REQUIRED INFORMATION ~/ - Mud Log No- _ Samples No _ - - Directional Survey Yes DATAINFORMATgN Types Electric or Other Logs Run: GR/RES WeII Log Information: Log/ Electr Data Digital Dataset (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Ty Med/Frmt Number Name Scale Media No Start Stop CH Received Comments pt LIS Verification 3970 17843 Open 5/21/2009 LIS Veri, GR, NPHI~ NCNT, PEF, RPS, RHOB, RPD, RPX, DRHO, FCNT, RPM, FET, ROP ED C Lis 18063 I" nduction/Resistivity 3970 17843 Open 5/21/2009 LIS Veri, GR, NPHI, NCNT, PEF, RPS, RHOB, RPD, RPX, DRHO, FCNT, ~, RPM, FET, ROP ', og Induction/Resistivity 25 Col 2470 6806 Open 5/21/2009 TVD DGR, EWR, CTN, ALD o Ind~tion/Resistivity 25 Col 4000 17843 Open 5/21/2009 MD DGR, EWR, CTN, ALD D C 18064 °1nduction/Resistivity 4000 17800 Open 5/21/2009 EWR logs in CGM, EMF and PDS graphics Well Cores/Samples Information: ~I !I Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 7/6/2010 Permit to Drill 2090280 Well Name/No. COLVILLE RIV FIORD CD3-304 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20598-00-00 MD 17843 ND 6807 Completion Date 4/29/2009 Completion Status 1-OIL Current Status 1-OIL UIC N ADDITIONAL INFORMATION Well Cored? Y ~N Daily History Received? N Chips Received? 'Y-/-N Formation Tops Q/ N Analysis ~-1-14' Received? Comments: Compliance Reviewed By _-____ __ Date: _~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL .i'lE, ' ~u7~ 4laska Qid ~~;~ t'~;~~, ~~ri'rmissior~ i~, r~ t, i ~d, r,: ~ ~++~~ 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number: 209-028 ConocoPhillips Alaska, Inc. Development ^~ Exploratory ^ 7. Well Name: CD3-304 2. Address: 4b. Well Status: Oil ~ Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20598-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ^ or Continuation ^~ or Final ^ 309-380 12/1/2009 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 361 * 361 totals (bbls): 2009 / 4th 0 0 0 0 2o1o/1st 13791 100 0 13891 14 1/8/2010 3/6/2010 CD3-106, CD3-124 2010 / 2nd 17141 100 0 17241 14 4/1/2010 4/16/2010 CD3-123, CD3-302A 2010 / 3rd Total Ending Report is due on the 20th volume 30932 200 361* 31493 28 (bbls): 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): *freeze protect volumes, Leak-Off Test, In'ection test correct to the best of my knowledge. I hereby certify that the foregoing i s true a nd / ~ / ' ~ / / Signature: /cal.. ~_ l.~( Date: ZI ~ 1 L~? l~ ~. 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 STATE OF ALASKA ALAS~OIL AND GAS CONSERVATION COMM ON REPORT OF SUNDRY WELL OPERATIONS RECEIVED ~IAY 2 2010 t Operations Performed: Abandon ~ Repair w ell ~ Plug Perforations ~"' Stimulate ~18SI(~ o~l~l'~B~CElit, Epi11t111$$Iflfl Alter Casing Pull Tubing (- Perforate New Pbol ~ Waiver "` Time Extensio~8of't~Qe Change Approved Program ~ Operat. Shutdown )-" Perforate °" Re-enter Suspended Well "`"` 2. Operator Name: 4. Current Well Status: ,5. Permit to Drill Number: ~ ConocoPhillips Alaska, Inc. Development ~` Exploratory `"' 209-028 3. Address: Stratigraphic Service .API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20598-00 7. Property Qesignat~n: ~ 8. Well Name and Nu~ber: ADL 372103, 372104, 372105 CD3-304 9. Field/Pool(s): ~ Colville River Field / Fiord Oil Pool 10. Present Well Condition Summary: Total Depth measured 17843 feet Plugs (measured) None true vertical 6806 feet Junk (measured) None Effective Depth measured 17743 feet Packer (measured) 15086 true vertical 6760 feet (true vertucal) 5907 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 114 114 SURFACE 3961 9.625 3997 2469 PRODUCTION 17798 7 17832 6801 Perforation depth: Measured depth: 17408'-17440' True Vertical Depth: 6627'-6638' Tubing (size, grade, MD, and TVD) 3.5, L-80, 17252 MD, 6575 TVD Packers &SSSV (type, MD, and TVD) PACKER -PREMIER PACKER 7" X 3 1/2" (BAKER) @ 15086 MD and 5907 TVD SAFETY VLV -SSSV Bal-O Landing NIPPLE @ 1607 MD and 1515 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): see attachment Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1376 2352 709 -- 358 Subsequent to operation 1431 2372 847 -- 351 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run Exploratory Development Service .Well Status after work: Oil ~' Gas WDSPL ~" Daily Report of Well Operations XXX GSTOR '"" WAG "°" GASINJ " WINJ ~ SPLUG '° 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N!A if C.o. Exempt: none contact Brian Barreda ~ 265-6036 Printed Name Brian Barreda Title WNS Production Engineer Phone: 265-6036 Date Signature ~/~~ ~O ~~~ ~ 0 ~' ~S~'~Z5 Form 10-404 Revised 7/2009 ~`I RBDMS MAY 2 5 ~O'~~ ~Su~ t Original Only ~~ CD3-304 Well Events • DATE SUMMARY 4/30/10 Pumped scale squeeze from 10:15 to 12:32 hours on 4/30/2010. Aqueous squeeze, pumped 60 bbl SW pre-flush at 6 bpm. Pre-mixed 30 gal WAW-5206 with 9 bbl SW, pumped at 3 bpm with 100 psi on tbg. Pre-mixed 280 gal SCW-4004 with 45 bbl SW, pumped at 3 bpm with 100 psi on tbg. Overdisplaced with 330 bbl SW at 6 bpm. Tbg on vacuum at beginning of overdisplacement, rising to 250 psi. F/P'd with 50 bbl diesel. ~ • -'~ WNS ~, ~ ~ Conott~Ph~fGps ~I,. ._tty Well Attributes ' Welltgre APVU WI Field Name ' Well Status ( / 501032059800 FIORD KUPARUK PROD H2S (ppm) Date IMnotation End Date well c n ^EVwT6D c 033oda ~ SSSV: WRDP ~ b~eGio Asa of Ar n o ti ( Iasi W0: _ g , , fig _ __ $chemel Actu . A on De th ftK6 ta al. ~ p ( ) Entl Date AnnoUtion Last Tag' ~' I Rev Reason: RESET WRDP PaNGER 31 Casing Strings -- D r s D n N CD3-304 8MD ~TD KB) 'ACt Bim (ft KB) ,222.38 ' 17,843.0 rd (ft) Rig Release Date 42.40 4124/2009 (Last Mod ... End Data i Imosbor 4/26/2010 'Str' 'S[' T Thrd Casing Descnption CONDUCTOR Strmg 0... I 16 String ID . 15.250 .. Top (ftK8) 36.0 Set epth (... 114-0 et ept ( 1140 VI J~62.60 mg ... I H-00 nn o 9 P "- Casing Descr phon .String 0... String ID . .. Top (ftK8) Set Depth ((.-. Set Depth (ND) . ' String Wt.. . Str g .. _ String Top Thrd .SURFACE I, 9 6/8 8.835 36.4 3,997.2 2 469 0 40.00 L 80 IBT< _ '~ Casing Description ,String 0... String ID . .. Top (ftK8) Set Depth (i_. Set Depth (ND) ... String Wt.. . String ... Stnng Top Thrd 1 _ - .PRODUCTION 7 6.276 342 17,831.8 6,801.3 26.00 L80 BTCM i j __ 'Tubing Strings ._. . - _ _. ~ Tubing Des phon 'String O... String lD . .. Top (ftK8) Set Depth (i...Set Depth (ND). String Wl.. . Str g _ String Top Thrd 'TUBING 4.5'x3.5" _31/2 ( 2.992 ( 312 ( ( 17,252.2 6,578.3 9.30 L-80 EUE I Com le tion De tails "_~'~ :ONDUCTOR, _ j Top Depth 36-114 _ (ND) Top Incl Top (ftK6) (kK8) (°) Item Description Comment 31.2 31.2 -0.04 HANGER FMC Tubing Hanger ~ 1,607.4 1,6155 44 97 SAFETY VLV SSSV Bal-O Landing NIPPLE 1,664.1 1,556.1 46.11 XO -Reducing XO -4 1/2" IBTM Box by 3 1/2" EUE Pin wRDP 1 sm ' i 15,030.7 5,889.6 71.75 SLEEVE Baker 3 V2" CMU Sliding Sleeve W/2.813" DS Profile (Closed) SAFETY VLV,__ i,6g] i 15,085.7 5,906.8 - 71.79 PACKER - - Premier Packer 7" X 3 1/2" (Baker) 5.98 OD 2,87 ID '' 15,143.8 J 5,925.0 71.83 NIPPLE Camco 2.75" D Nipple ,, ~ 17,241.5 6,575.4 73.63 WLEG ~ _ 3 1/2" 9.3it L-80 EUE pupjt w/ Baker WLEG (4-51" OD) Gns269 _ ~ ,,Perforations & Slots I snnt Top (TVD) B[m (TVD) Dens Top (ftK8)' Btrn (ftK8( (ftK6) (ftK8) Zone Date (sh... Type Comment 1 7.408 1 1440 6,627.2 6 637.7 4/30/2009 '. 6.O.IPERF HES 2 0"Scalloped Guns, 60 deg V phase. millenium charges Notes: General 8 Safety 36-3,99] l ~, GAS LIFT. _ 6.]00 - __ -. ~ ,.~:,.eti_ CAS SLEEVE, 15.031 PACKER, _ -. 15,086 NIPPLE. 15,144 ~_ wLeG,,],z4z ~ Mandrel D etails _ _ __ -- - - Top Depth Top Port (TVD) Incl OD Valve Latch Size TRO R Stn Top (ftK6) (ftK8) (°) Make Model (in) Serv TYpe TYPe (~^) (Psi) 1 2,497.3 2,004.8 69.76 CAMCO KBG-2-1R 1 GAS LIFT DMY BK 0.000 Ill C 2 8,700.5 3,934.0 71.94 CAMCO KBG-2-1R 1 GAS LIFT DMY BK 0000 C iPFRF, -= 3 14,971.4 5,871.0 71.70 CAMCOKBG-2-1R i GAS LIFT OV BK 10250 C PRODUCTION. 3a-17.832 TD, 17.643 • ~~Q~C~ Ofd p~Q~~{Q /~..~A.~,~o~..ow Jack Walker WNS Production Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CD3-304 Sundry Number: 310-135 Dear Mr. Walker: a~ 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 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. Sincerely, Daniel T. Seamount, Jr. Chair d' `' DATED this 2 ~ day of April, 2010. Encl. • STATE OF ALASKA ~ `~ '° '°~~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION APR 1 9 201D APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ~"°' Rug for Redrill j°" Perforate New Pool ~'®' Repair w ell ~ ange ~~r~9ram Suspend j Rug Perforations Perforate ~" • Pull Tubing ~"°" Time Extension ~'° Operational Shutdown ( Re-enter Susp. Well ~'` Stimulate ~""' Alter casing ~ Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Development ~" Exploratory j"` 209-028 ConocoPhillips Alaska, Inc. 3. Address: 6. API Number: Stratigraphic ~'"' Service 50-103-20598-00 ' P. O. Box 100360, Anchorage, Alaska 99510 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes)': No (~ CD3-304 ' 9. Property Designation: 10. Field/Pool(s): ADL 372103, 372104, 372105 + Colville River Field / Fiord Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effeaive Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 17843 6806 17743' 6760' Burst Collapse ND MD Casing Length Size CONDUCTOR 78 16 114' 114' SURFACE 3961 9.625 3997' 2469' PRODUCTION 17798 7" 17832' 6801' Perforation Depth MD (ft): Perforation Depth TVD (ft): 17408'-17440' 6627'-6638' Packers and SSSV Type: PACKER -PREMIER PACKER SAFETY VLV -SSSV Bal-O Landing NIPPLE 12. Attachments: Description Sumrory of Proposal Detailed Operations Program ~"" BOP Sketch ~" 14. Estimated Date for Commencing Operations: ^^ ^^, ^ + 16. Verbal Approval: Date: Commission Representative: Size: (Tubing Grade: 3.5 L-80 Packers and SSSV MD (ft) and TVD (ft) MD= 15086 TVD= 5907 MD= 1607 TVD= 1515 13. Well Class after proposed work: Exploratory ~" Development 15. Well Status after proposed work: Oil ~ Gas ~" WDSPL WINJ ~"" GINJ ~"' WAG ~~ GSTOR 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Jack Walker ~ ) GL~u~dZ~-- ~~~ i~- V ~ Signature ~ Contact: Title: Phone: 265-6268 ig MD (ft): 17252 Service ~'"` Suspended ~"' Abandoned SPLUG ""' Jack Walker @ 265-6268 WNS Production Engineer Date ~ ~ ~ ~ ~-U / (.1 Number:~~ O'~'~~ Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ~'~` BOP Test ~""` Mechanical Integrity Test ~""" Location Clearance ~` Other: Subsequent Form Required: l~ ~ ®~.f APPROVED BY rove C(O~MMISSIONER THE COMMISSION ~~GI Y ~~-rte Form 10-403 Revised 1/2010 Date: J l ~ L • Submit in Dupplicate --sl> ~ /}- itj • CD3-304 Fiord Kuparuk Proposed Reperforating Program for 10- 403 Sundry Approval 19-Apr-10 Expected static bottomhole pressure is 3200 psi based on initial pressure measured 06-May- 2009 (2981 psi at 6850'ss datum) and subsequent injection and withdrawal. Maximum shut in tubing pressure expected is 1500 psi based on an 8 hr shut in on 08-Feb-2010. Proposed Procedure 1. Rig up and pressure test slickline. 2. Drift tubing with 2" dummy gun with 2.5" rollers. 3. Rig down slickline. 4. Rig up and pressure test electric line. 5. Re-perforate 17410-17440"MD with 2" Halliburton scalloped gun, Millenium charges, 6 shots per foot, 60-deg phasing. 6. Rig down electric line and turnover to drill site operator. ~~~. APR 1 ~ 2010 ~iaslca Oil & Gas Clans. ~ot~missi;~r~ 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: 209-028 ConocoPhillips Alaska, Inc. Development ^~ Exploratory ^ 7. Well Name: CD3-304 2. Address: 4b. Well Status: Oil 0 Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20598-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ^ or Continuation ^~ or Final ^ 309-380 12/1/2009 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 361 * 361 totals (bbls): 2009 / 4th 0 0 0 0 2010 / 1st 13791 100 0 13891 14 1/8/2010 3/6/2010 CD3-106, CD3-124 2010 / 2nd 2010 / 3rd Total Ending Report is due on the 20th volume 13791 100 361 * 14252 14 of the month following the final month of the quarter. Ex: (bbls): 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): *freeze rotect volumes, Leak-Off Test, In'ection test I hereby certify that the foregoin is true and correct to the best of my knowledge. Signature: ~ ~`~'~ Date: ~l'tL~2o[ o 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 l~ i ~ Z~} - d Z~~ PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD3-304 Rig: Doyon 19 Date: 1/9/2010 Volume Input _ _ __ Drilling Supervisor: D. Burley Pump used: Cement Unit ~ ' garrets ~ 0.1000 Bbls/Strk ~ Type of Test: Annulus Leak OfrTest for Disposal Adequacy ~ Pumping down annulus. ~ Casin Test PrE Hole Size: 8-3/4" ~ Casin Shoe Depth Hole Depth Pum pin Shut-in Pur RKB-CHF: 36.5 Ft 3.997 Ft-MD 2.469 Ft-TVD 14.800 Ft-MD 5.818 Ft-TVD Bbls psi Min psi Bbls Casing Size and Description: 9-s/8" 40#/Ft L-80 BTC ~ 0 0 Chan es for Annula r Ade ua c Test Pressure Int e rit Test 1 0.2 r casing shoe test results in comments Mud Weight: 7.5 ppg 2 0.4 cription references outer ~ casing string. Inner casing OD: 7.0 In. 3 0.6 ize is that drilled below outer casing. 4 0.8 timated TOC for Hole Depth. 5 1 Enter inner casing OD at right Desired PIT EMW: 15.5 ppg 6 1.2 Estimates for Test: 1027 psi 1.7 bbls 7 1.4 1500 off Pressure + Mud Weight 1020 + 7.5 PIT 15 Seca 0.052 x TVD 0.052 x 2469 Shut-in Pressu EMW at 3997 Ft-MD (2469 Ft-TVD) = 15.4 940__ looo w w a 500 0~ 0 1 2 3 4 5 6 Barrels ~~CASING TEST tLEAK-OFF TEST 9 5/8" Surface casing FIT = 18.0 ppg Used Little Red's pump truck to perform LOT 7 0 5 10 15 20 25 30 Shut-In time, Minutes O PIT Point mp Rate: Bbl/min ~ Shut-in n psi 0 950 1.5 2 860 2.5 855 3 845 8 1.6 1060 3.5 840 9 1.8 1060 4 835 10 2 1065 4.5 830 15 2.5 1085 5 825 20 3 1120 5.5 820 25 3.5 1140 6 820 30 4 1100 6.5 815 Volume Volume Volume Bled Back Pum ed Bled Back S S S 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: 209-028 ConocoPhillips Alaska, Inc. Development ^~ Exploratory ^ 7. Well Name: CD3-304 2. Address: 4b. Well Status: Oil ~ Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20598-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ~ or Continuation ^ or Final ^ 309-380 12/1/2009 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 361 * 361 * totals (bbls): 2009 / 4th 0 0 0 0 2010 / 1st 2010 / 2nd 2010 / 3rd Total Ending * * Report is due on the 20th Volume 0 0 361 361 0 (bbls): of the month followin the final month of the uarter. Ex: 9' p 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): *fr@eZ@ rotect volumes, Leak-Off Test, In'ection test I hereby certify that the foregoing is true a nd correct to the best of my knowledge. ^^ Signature: /~J.-. ~ ~.rti- Date: r ~:~ ~2' r `' 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 r~ ~ ~~ k ~ ~ n SEAN PARNELL, GOVERNOR ~ ~ ~+ ~ ALASKA OIIi A1~TD GAS ~~ 333 W. 7th AVENUE, SUITE 100 CO1~ST',IiQATIOI~T CODII~IISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 , FAX (907)276-7542 Mr. Mark Chambers Drilling Superintendent ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 Re: Colville River Field, CD3-304 Sundry Number: 309-380 Dear Mr. Chambers: ao~-o ~ 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. Sincerely, Daniel T. Seamount, Jr. ~, ~ Chair DATED this day of December, 2009 Encl. • ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 ~~~~""~~~!' • Telephone 907-276-1215 ~u ~~ ~d Gd,.d' November 9, 2009 ~~~ ~. U 2QQ9 Alaska Oil and Gas Conservation Commission ~115~~ Gib tit GaS COI1S. ~011'1(NIIggIAD 333 West 7`~ Avenue, Suite 100 ~pcFtorA~ Anchorage, Alaska 99501-3539 Re: Application for Sundry Approval for Annular Disposal of DrillinE Waste on well CD3-304 Dear Sir or Madam: ConocoPhillips Alaska, Ina. hereby requests that CD3-304 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 CD3-304 approximately January 9, 2010. 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 9-5/8" x 7" casing annulus 11. List of wells on CD3 pad and the lateral distance from the surface casing shoe. 12. Information regarding wells within'/4 mile radius at AOGCC: CD3-303 13, Information regarding remaining wells within '/4 mile radius included in sundry package: CD3-305 (also applying for sundry approval) 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 (15.2 ppg) occurred at a lower equivalent mud weight than the casing shoe test (18.0 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, Liz u a Sharon Allsup-Drake ATO-1530 Drilling Engineer cc: CD3-304We11 File Chip Alvord ATO-1577 ~ ~, ,~ STATE OF ALASKA ~~ ~ I~~lD I~~l/ 1 ~3 1()~~ ALASKA OIL AND GAS CONSERVATION COMMISSIka Oil & Gas Cons. Commission ANNULAR DISPOSAL APPLICATION Anchorage 20 AAC 25.080 1. Operator 3. Permit to Drill Name: 209-028 COnOCOPh1111pS Alaska 4. API Number: 50-103-20598-00 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD3-304 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: CD3-303, CD3-3(74 Torok and Seabee formation, shale, siltstone and sandstone b) Waste receiving zone: b) water wells within one mile: Sand layers below the C30 marker in the Seabee formation None c) Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Albian Torok Formation provide a lower barrier 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1658' 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 2311 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, reserve 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 9-.tan-10 added water needed to facilitate pumping of drilling mud or drilling cuttings, and other 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 TVD) ^~ Cement Bond Log (if required) ^ FIT Records w/LOT Graph Q Surf. Casing Cementing Data ^'~ Other 0 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: Title: ,~.2Gls ss~,PT Printed Phone Name: Chip Alvord Number: 265-6120 Commission Use Onl .O~nl/~'+.waL ~''~/ ~ 0 A~4 G ZS ~ S 0 LOT review and a al l roval Conditi n f ro . . pp v o s o app 7 ~ ~ Q Subsequent form req d: ~~ ` YZ 3 ~ b/ ~-~ w~-~, -/n '~ pproval number: ~ ~ !1 ~p'IbI' .~hi~ia.+iR~ a~is~S~~ APPROVED BY ~~ COMMISSIONER THE COMMISSION Date: A b ~~' pproved y: / Form 10-403RD Rev. 6/2004 ~ jZ, ! U INSTRUtlTIB'IQSL'!IG R~'~~ l Sut~mi~n Dupli ate/~~~~~' `j ~~~~ • Annulus Disposal Transmittal Form -Well CD3-304 AC1C.("C' RPmilatinnc 2n AAC 75 nRn (hl 1 Desi ation of the well or wells to receive drillin wastes: . CD3-304 2 The 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 barrier 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 maximum 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. Maximum 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 CD 1 &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 2311. psi. See attached calculation calculations showin how this value was determined. aae. 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 strings 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. NIA 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 CD3-1.22, CD3-1.21, CD3-120, CD3-301A, CD3-302A, CD3- will be enerated. 106 15 If the operator proposes not to comply with a limitation N/A established in (d) of this section, an explanation of why coin liance would be im rodent. 16 Any additional data required by the commission to confirm N/A containment of drillin waste. Well CD3-304 Date 11/9/2009 ~ ~, d ~~ U 0 0 0 r ~!!!i c,:::: '~' a U'' v', ',' N,,,,, o! 'a+'' '< 2,469 TVD • Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) Assumptions Maximum injection pressure of 1,500 psi Maximum density of the injection fluid is 12.0 ppg Pore pressure at the 9 5/8" casing shoe is 0.434 psi/ft Gas/Fluid Gradient in tubingJcasing annulus 0.07 psi/ft Header Pressure (for wells on gas lift) 1,000 psi TOC Est. @ 14,800' MD 5,818' TVD a.s "Tubing 6,669 TVD Version L0 - Jan'OS Pburst85% - PHydrostatic +PApplied - PFormation 4,888 = ( 2,469 * 0.052 * MWm~ ) + 1500 - (0.4337 * 2,469 ) MWmax = 34.7 PPg Surface Casing Strip Size 9.625 in Weight 40 ppf Grade L 80 rburStloo°r° 5,750 psi Pburst85 ~ 4,888 psi Depth of Shoe 2,469 ft FIT/LOT @ Shoe 18 ppg or 2,311 psi ~ FIT/LOT for Annulus 15.2 ppg Max Surf. Pressure 1,500 psi Maximum Fluid Density avoid Collapse of 2nd Casing String Pcollapse85% - PHydrostatic +PApplied - PGasGradient - PHeader 4,599 = ( 5,818 * 0.052 * MWm~ ) + 1,500 - (0.0700 * 5,818) - 1,000 MWmax = 14.9 PPg 2nd Casing Strip Size 7 in Weight 26 ppf Grade L 80 rcollapse100% 5,410 pSl Pcollapse85% 4,599 psi Top of Cement 5,818 ft Gas Gradient 0.07 psi/ft Max Surf. Pressure. 1,500 psi Header Press 1,000 psi Maximum Anticipated Pressure at Surface Casing Shoe Pmax avowable =Shoe TVD Depth * .052 * Shoe FIT/LOT Pmax allowable - ( 2,469 * .052 * 18 ) Pmax allowable - 2,311 PSI This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe". SURFACE CASING SHOE SEPARATION FROM CD3-304 CD3-304 x v Surface Casino Shoe ASP 4 Coordinates NAD 2T 390794.7 60032.> 0 ells Details ~ AOGCC Ann. Disp. Permit # ermit Date ource well Ann. Vol. ** tart Date nd Date is ante from Object well* Surface csg. Shoe X Coord. Surface csg. Shoe Y Coord. Surf LOT (ppg) Surface casing TVD (ft) Annular LOT (ppg) omments CD3-103 '.'87 d3J3D0.3 .~ui'4'~dd.4 17.1 2431 - 1n 4 no( hir annulrir disposal CC t-ri~3 306-020 11222006 CD3-11(1, CD3-111, CD3-112, CD3-307, CD3-302 64635 1/20/2006 3/4/2007 -419 -5,1-."~~ 6004 18.0 2414 I ~.'~ I-~.t~,i I~ 1 t ~i.~~:q~ld, ex 03/17/07 CD3~11D 2y69 31;8 ;63.7 60D4720.7 16.7 ~ 2439 15 t3 Low suiFi e shoe test CD's-111 307-066 212112001 CD3-114, CD3-301 26674 3/20/2007 4/20/2007 3311 -'-1 n 6004710.6 17.4 2469 14 ~~ CD3-112 ~ 307-002 1/11/2007 CD3-71 ; rD3-ttl7'GD3-30' 32DD7 1/22/2007 3/16/2007 _ 3571 ~ 3574D(i 8~ 8004382.6 ~ 18.0 ~ 2485 15.1 CD3-107/307 1531 389627.9 6004245.8 18.2 2479 15.3 Also known as CD3-107, second annlus, after cut and ull o erations Feb 2007 s- ~, C~3-302 ~ :.~ ~ 3D8-036 218/2008 CD3-113, CD3-118, CD3-303, CD3-107L1 28847 ~ 2112I20D8 ~ - 5/2/2008 - 2322 ~ _ ~ 388ft15.4 6004469.9 ' - 18.0 - 2505 15.0 CD3-113 307-067 31'2012007 CD3-316, CD3-316A 31964 Lis/2008 3/20/2008 3223 3876'~r:~- 6003901.1 18.0 2475 16.3 CD3-114 CL!;-'±~:~1 CD3-318A Y Y: 3D8-127- 4PIr',!2nn,1 CD3-Sot°.,c;D3-115. at6&1 1/11/2009 ~ 2/16/2009 3847 3188 1949 357024.7 -++';'141.7 388868.2 6003781.8 6005510.5 6003548.0 16.4 16.2 18.0 2485 2493 2476 14.2 15.1 15.9 - Low surface shoe test CD3-303 Y s08-426 12/~~_~~s D±-1I 23833 2/14/2009 3/27/2009 ~:,~,9 390091.0 6003906.6 18.0 2488 15.9 CD3-118 Y 4'112 386456,5 6D03425.3 1 is 6 2489 15.7 Low surface shoe test CD3-305 included 390135.8 6003161.5 I J 2467 14.70 CD3-115 Y:+r 3D9-087 3!1112009 CD3-304 20722 4/23/2009 3':?r34 368822.0 60D3553.0 115 0 2461 13.30 .CD3-304 included 0 390794.7 6003255.0 .d.0 2469 15.20 ~:D3-117 N 4324 386471.4 6003320.0 16.~ 2447 14.80 * Lateral distance in feet, between surface casing shoes, in the X-Y plane ** As of Nov 5, 2009 Note that this sheet is not the definitive record for annular disposal volumes • ~' ~ Project: Western North Slope COnOCOPhIIIIpS Site: CD3 Fiord Pad CD3-304 Well: CD3-304 Wellbore: CD3-304 Quarter Mile View HALLIBlJRT©N CD3-304 {aerry C7rillig 0 9 p1 C'O GO3A1 Gp3.10 ~~pQ+ 03;~ ~?~ Gp G ~' ,~ 95/8"x12 4''Q CD3-10 L1 ~---- ~' ~O ~ ~ ' ~ 1600 o ~ °~.~ ~~ ' ~ o `' `~ ~a 5/8" x 12 1 ~j ~~ i 9 5/8l 7 ~ /4^x 121/4" ~ I 800 - ~ w 5/8" x 12 1/4" 9 5/8" x 1 ~ 2 ~ o ~ w ~-. ~ ~ ~ '` ~ 9-5/8" x 12-1/4" -' \ \` O ~", --a ~ ~ . 0 0 ~ M ~ , ! C 1 r i ~" ~~ - w nj + ~/ ~ ~~ ~ ~ 61 i ~ V ~ ~ i 12-1/4" x 9-5/8 " ~! 9-5/8" ~ t To ~ ~ Z -800 " " ^ 9-5/8 x 12-1/4 .C ~ I o O to M ~ -1600 - -- ._-....-- __ _ .' i _,,, ' hm -2400 ... ._.---- --. _.__~ _.. -- - ---__- . - ~_ _._.. --- _ o a 1 y n~O q~ G 0 800 1600 2400 3200 4000 4800 5600 6400 West(-)/East(+) (800 ft/in) .J • CD3-304 9 5/8" SurFace Casing Detail well: CD3-3~4 f /`r~ 4 ~- try ~~i'~ Date: 4112/~E~€~9 /^ ry .. 1~~~~pJ. 4~n~C~~I Rig: Doan 19 . Alas Inc: ~:. ' ,~ L - Depth Jt Number Joints Well Equipment Description and Comments Page 1 Length Tops .. .. ...... . .. „_ RKB to L_andin Rin 36.45 ; ';Ii! , ' FMC 9 5/8" Casin Han er 2.38 36.45 Jts 3 to 102 100 Jts 9 5/8", 40#, BTCM Casin 3879.81 38.83 Hallil3urton 9 5/8" Float Collar 1.23 3918.64 Jts 1 to 2 2 Jts 9 518", 40#, BTCM Casin 75.16 3919.87 Ra Oil Tool 9 5/8" Silver Bullet Float Shoe 2.18 3995.03 9 5/$" Shoe 3997.21 3997.21 3997.21 3997.21 3997.21 3997.21 Casing shoe 3,997' MD / 2,469' TVD 3997.21 12 1/4" Hale TD 4,007' MD / 2,472' TVD 3997.21 3997.21 3997.21 TOTAL BOWSPRING CENTRALIZERS = 5fi 3997.21 3997.21 1 per jt on Jt # 1 - # 13 (stop ring on Jt # 1 & 2) 3997.21 and aver collars on jts# 15, 17, 19, 21, 23, 25, 27, 29, 31, 3997.21 33, 35, 37, 39, 41, 43,45, 47, 49, 51, 53, 55, 57, 59, 61, 63 3997.21 65, 67, 69, 71, 73, 75, 77, 79, 81, 83, 85, 87, 89, 91, 93, 95, 97, 99. 3997.21 3997.21 3997.21 3997.21 3997.21 3997.21 3997.21 3997.21 3997.21 Use Best-o-Life 2000 pipe dope 3997.21 3997.21 Ave MU torgue ~ 7800 ft/Ibs 3997.21 3997.21 3997.21 Remarks: Up Wt 175 K Dn Wt 135 K Block Wt 75 K Supervisors: Dave Burley /Peter Wilson /Steve Shultz Cement Detail Report CD3-304 String: Surface Casing Cement Job: DRILLING ORIGINAL, 4/812009 03:30 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 4/12/2009 12:33 4/12/2009 14:50 CD3-304 Comment Cemented 9 5/8" casing as follows: Rig pumped 92 bbls of 9.9 ppg mud with nut plug marker followed with 35 bbls of Biozan w/ nut plug marker as pre flush . Switch over to Dowell and pumped 3 bbls of FW, tested lines to 4,000 psi .Dropped bottom plug. Mixed & pumped 50 bbls of 10.5 ppg MudPUSH II spacer, ave. 5.7 bpm at 212 psi. Mixed & pumped 10.7 ppg lead slurry at 4.45 yield (ASL) ave. 7.0 bpm at 235 - 334 psi. Observed nut plug marker at shakers w/ 426 bbls lead slurry pumped (pumped down surge can, 434 bbls total 540 sxs) Switched to tail slurry and pumped b1 bbls (245 sxs) of 15.8 ppg tail cmt at 1.17 yield (Class G w/ additives) ave.5.1 bpm at 155 psi. Dropped-top plug w/ 20 bbls fresh water f/ Dowell, Switched to rig pumps & displaced cement w/ 257 bbls of 9.9 ppg mud @ 8.0 bpm, ICP 400, FCP 710 psi, slowed pump to 6.3 bpm at 600 psi (for the last 20 bbls of displacement) Bumped plug to 1100 psi. Checked floats OK, CIP @ 1450 hrs. Had full returns throughout job w/ 128 bbls of 10.7 ppg cement returns to surface. Reciprocated pipe until last 145 bbls of displacement. Cement Sta es Sta e # 1 Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? Surface Casing Cement Primary 36.0 3,997.0 Yes 128.0 Yes Yes O (start) (bbl/min) Q (end) (bbtlmin) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 8 5 7 490.0 1,100.0 Yes 25.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids 8~ Additives ~ Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 36.0 3,497.0 540 G 434.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Iblgal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 4.51 21.20 10.70 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 3,497.0 3,997.0 245 G 51.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.17 5.10 15.80 Additives Additive Type Concentration Conc Unit label ~ rage v, ~~cNv~«....«... ..,~.~.....,I r~ ~, Security Level: AK Development •~ ~ h ~ ' , ~ ,~ Daily Drilling Report ~" CD3-304 Report Number: 5 i ' .~. r b Rig: DOYON 19 Report Date: 4/12/2009 - AFEType NetworWlD_#~ TotafAFE+Sup 10246924 8,770,001.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Stan. (ftKB) Depth End (ftKB) CD3-304 Development FIORD KUPARUK 3.98 5.0 0.00 4,007.0 4,007.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 7,006.81 71,905.92 532,361.81 1,674,222.92 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 4/8/2009 4/9/2009 23.11 21.33 1.78 - 4/29!2009 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) SURFACE, 3,997.OftK6 Ops and Depth ~ Morning Report 24hr Forecast PU & standing back 5" DP Fin standing back DP, Test BOPE, MU Geopilot BHA #2 &RIH Last 24hr Summary Fin LD BHA #1, RU &RIH with 9 5/8" csg landing same @3,997', no problems. Circ & cond hole then cemented csg with 128 bbls of cmt back to surface. RU & tested csg to 3,500 psi for 30 min . RD Csg equip & landing jt. NU FMC wellhead & BOP stack. General Remarks Weather Head Count No Accidents and No Spills -1 Deg, WC -19, Overcast, Wind E @ 12 mph 48.0 Supervisor Title Dave Burley, Rig Supervisor Rig Supervisor Peter Wilson, Rig Supervisor Rig Supervisor Steve Shultz, Rig Engineer Rig Engineer Time Lo Start End Dur Time Depth Start Depth End - - - Time Time (hrs) Phase Op Code Activity Code': P-T-X Trbl Code Tfbl Glass (ftKB) (ftKB) Operation 00:00 00:45 0.75 SURFAC DRILL PULD P 30.0 0.0 Fin LD motor and bit on BHA #1 and cleaned rig floor. 00:45 02:15 1.50 SURFAC CASING RURD P 0.0 0.0 RU to run 9 5/8" csg with Franks fill up tool. 02:15 02:30 0.25 SURFAC CASING SFTY P 0.0 0.0 Held PJSM with rig crew and tong operator on running of casing and the associated hazards. 02:30 06:15 3.75 SURFAC CASING RNCS P 0.0 2,137.0 Ran 9 5/8" 40# L-80 BTCM casing as follows: Float shoe (Ray Oil Tools silver bullet) 2 jts csg -Float collar (Halliburton super seal II) - 2 jt csg (all connections made up w/ BakerLoc -filled pipe & checked floats) Cont. to RIH with 9 5/8" csg to 2,137 (55 jts total) 06:15 07:00 0.75 SURFAC CASING CIRC P 2,137.0 2,137.0 Est. circ and circ btms up @ 2,137', Staged pump rate up to 6 bbls/min. ICP 300 psi @ 3.2 bbls/min. FCP at 6 bbls/min @ 400 psi. st wt up 145K, so wt 120K 07:00 09:15 2.25 SURFAC CASING RNCS P 2,137.0 3,997.0 Cont. RIH with 9 5/8" csg from 2,137 to 3,958'. MU FMC hanger and landed csg with FS @ 3,997' and flt collar at 3,91,9'. No problems - PU wt 212K, SO wt 110K. Ran a total of 102 jts of 9 5/8", 40#, L-80, BTCM csg, total including float equip and hanger 3,960.76'. Ran 56 Bow spring cent and 2 stop rings per well plan. 09:15 10:00 0.75 SURFAC CEMENT RURD P 3,997.0 .3,997.0 RD Franks fill up tool and MU Dowell cement head. 10:00 12:15 2.25 SURFAC CEMENT CIRC P 3,997.0 3,997.0 Circ and cond. mud for cementing, staged pump rate up from 3.1 bpm at 410 psi to 7.1 bpm at 320 psi, cond. mud to 9.9 ppg. in and out with 15 YP. St wt up 175K, do wt 135K. Held PJSM on cement job while circ hole. Latest BOP Test Data ,.-: Date Comment.. Page 1/4 Report Printed: 11/2/2009 r1 i Security Level: AK Development Daily Drilling Report ;~ } , , , CD3-304 Report Number: 5 ~~:~ Rig: DOYON 19 Report Date: 4/12/2009 Time Lo - Start - End Dur - Time Depth Start Depth End Time Time (hrs) Phase ' Op Code Activity C_ ode P-T-X Trbl Code Trtil Class. (fiKB) (ftKB) Operation 12:15 15:00 2.75 SURFAC CEMENT CMNT P 3,997.0 3,997.0 Cemented 9 5/8" casing as follows: Riga pumped 92 bbls of 9.9 ppg mud with nut plug marker followed with 35 bbls of Biozan w/ nut plug marker as pre-flush . Switch over to Dowell and pumped 3 bbls of FW, tested lines to 4,000 psi . Dropped bottom plug. Mixed & pumped. 50 bbls of 10.5 ppg MudPUSH II spacer, - Mixed & ave. 5.7 bpm at 212 psi. pumped 10.7 ppg lead slurry at 4.45 yield (ASL) ave. 7.0 bpm at 235 - 334 psi. Observed nut plug marker at shakers w/ 426 bbls lead slurry pumped (pumped down surge can, 434 bbls total 540 sxs) Switched to tail slurry and pumped 51 bbls (245 sxs) of 15.8 ppg tail cmt at 1.17 yield (Class G w/ additives) ave.5.1 bpm at 155 psi. Dropped top plug w/ 20 bbls fresh water. f/ Dowell, Switched to rig pumps & displaced cement w/ 257 bbls of 9.9 ppg mud @ 8.0 bpm, ICP 400, FCP 710 psi, slowed pump to 6.3 bpm at 600 psi (for the last 20 bbls of displacement) Bumped plug to 1100 psi. Checked floats OK, CIP @ 1450 hrs. Had full returns throughout job w/ 128 bbls of 10.7 ppg cement returns to surface. Reciprocated pipe until last 145 bbls of displacement. 15:00 16:00 1.00 SURFAC CASING DHEQ P 3,997.0 3,997.0 RU and tested casing to 3,500 psi for 30 min. 16:00 17:45 1.75 SURFAC CASING RURD P 3,997.0 3,997.0 RD cmt head, landing jt, long bales and elevators. 17:45 19:00 1.25 SURFAC DRILL RURD P 3,997.0 3,997.0 Pulled mousehole, RD and pulled riser, ND surface adapter 19:00 20:15 1.25 SURFAC WELCTL NUND P 3,997.0 3,997.0 NU FMC wellhead and tested seals to 1,000 psi for 10 min. 20:15 23:30 3.25 SURFAC WELCTL NUND P 3,997.0 3,997.0 NU BOP stack, riser, flowlines and turn buckles, cleaned out under rig floor. 23:30 00:00 0.50 SURFAC DRILL RURD P 3,997.0 3,997.0 Brought Sperry Sun Geo span to rig floor and rigged up, installed mousehole in preparation to PU and stand back 5" DP via the mousehole. Mud Check Data YP Calc. Gel (10s) Gel (10m) Gel (30m) HTHP Filt Density Temp Solids, Corr. Type Depth (ftK6) Dens (Iblgal) Vs (slgt) PV Calc (cg) (Ibf/100f1') (Ibf/10Qft') (Ibf/100ft') Qbf/t00ft') MBT (Ib(pbl) (mL130min) pH (°F) (%) Spud 4,007.0 9.85 58 25.0 15.0 5.0 12.0 18.000 30.0 8.0 10.0 Spud 4,007.0 10.00 284 .33.0 100.0 86.0 99.0 123.000 30.0 8.0 -- .11.5 In'ection Flu id Fluid Source From Lease (bbl) Destination Vendor Manifest Number Note Cement CD3-304. 128.0 CD3-115 Cement Returns Cementing Fluids CD3-304 310.0 CD3-115 Cmt. Cont. Mud . Diesel 25.0 CD3-115 Freeze Protect & Inj Test Water 20.0 CD3-115 Water spacer Page 2/4 Report Printed: 11/2/2009 r~ .,, Security Level: AK Development .r -- ~ ~ Daily Drilling Report ~ CD3-304 ~ ' Report Number: 5 ,, ,, Rig: DOYON 19 Report Date: 4/12/2009 In'ection Fluid Fluid Sdiarce From Lease (bbl) Destination Vendor Manifest Number Note Water 20.0 CD3-115 Water Spacer Water Based Mud CD3-304 1280.0 CD3-115 WBM Water Based Mud CD3-304 120.0 CD3-115 WBM -- Drill Strin s: BHA No: 1 - 8" 4/5 5.3 st Mtr / Bit Run No. 1 - 12 114in Hu hes Christensen MXL-1X 5156102 Depth In (ftKB) Depth Out (ftKB) TFA (incl Noz) (in') Nozzles (/32") IADC Bit Dull String Wt (10001bf) 0.0 4,007.0 0.75 16/16/18/12 3-4-WT-A-E-1-NO-TD 59 Drill Strin Com onents `Jts % Item Description ._ OD (tn):. ID (in) Top Conn Sz (iri) Top Thread Cum Len (ft) _- Motor with Stabilizer 8 5.000 6 5/8 H 90 32.99 Float Sub 8 2.875 6 5/8 H 90 35.20 Stabilizer 8 3.063 . 6 5!8 H 90 42.04 MWD (HCIM) 8 1.920 6 5/8 Reg 48.96 MWD (DM) 8 1.920 6 5/8 Reg 57.81 MWD (TM) 8 1.920 6 5/8 H 90 67.26 UBHO 7.85 3.313 6 5/8 H 90 70.17 NMDC 7.62 2.813 6 5/8 H 90 101.12 NMDC 7.67 2.813 6 5/8 H 90 131.86 Drilling Jars -Mechanical 7.64 2.750 . 4 1/2 IF 166.30 24 HWDP 5 3.000 4 1/2 1F 903.00 Wellbores` Wellbore Name Wellbore APIIUWI CD3-304 501032059800 Section Size (tn) , _> ,, Act Top (ftK6) Act Btrnf(ftKB) Start Date End Dale COND1 16 36.0 114.0 4/1/2009 4/2/2009 SURFAC 12 1/4 114.0 4,007.0 4/9/2009 4/11/2009 INTRMI 8 3/4 4,007.0 1 7,843.0 4/8/2009 4/20/2009 Casin Strin s - - String OD String Wt Casing Descnphon Run Date ': (in) (IbsBt) String Grade Set Depth (ftK6) Comment.. SURFACE 4/12/2009 9 5/8 40.00 L-80 3,997.0 Ran 9 5/8" 40# L-80 BTCM casing as follows: Float shoe (Ray Oil Tools silver bullet) 2 jts csg -Float collar (Halliburton super sea- II) - 2 jt csg (all connections made up w/ BakerLoc -filled pipe & checked floats) Cont. to RIH with 9 5/8" csg to 2,137 (55 jts total) Est. circ and circ btms up @ 2,137', Staged pump rate up to 6 bbls/min. ICP 300 psi @ 3.2 bbls/min. FCP at 6 bbls/min @ 400 psi. st wt up 145K, so wt 120K Cont. RIH with 9 5/8" csg from 2,137 to 3,958'. MU FMC hanger and landed csg with FS @ 3,997' and flt collar at 3,919'. No problems - PU wt 212K, SO wt 110K. Ran a total of 102 jts of 9 5/8", 40#, L-80, BTCM csg, total including float equip and hanger 3,960.76'. Ran 56 Bow spring cent and 2 stop rings per well plan. Cemerit Surface Casin Cement -Started 4/12/2009 Type Wellbore Cemented String Cement Evaluation Results casing CD3-304 SURFACE, 3,997.OftKB Stg No. Description Top (ftKB) Bottom (ftKB) O (end) (bbl/... P (final) (psi) 1 Surface Casing Cement 36.0 3,997.0 5 490.0 Fluitl Class Amount(sscks) V (bbl) - Density(Ib/gal) Yield (ft /sack) Es6Top (ftKB)=, Est:Btm (ftKB) Lead Cement G 540 434.0 10.70 4.51 36.0 3,497.0 Tail Cement G 245 51.0 15.80 1.17 3,497.0 3,997.0 Page 3/4 Report Printed: 11/2/2009 r~ '' ~'~ 'q ~° ~. - ~ ... .. , Rig: DOYON 19 Daily Drilling Report CD3-304 Security Level: AK Development eport Number: 5 Report Date: 4/12/2009 Pressure Test Data Item Tested Date Pres (psi) Failed? Comment SURFACE, 3,997.OftKB 4/12/2009 3,500.0 No Tested 9 5/8" csg to 3,500 psi for 30 min. Page 4/4 Report Printed: 11!2/2009 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD3-3014 Rig: Dayon 19 Date: 4/13/:'009 Volume In ut Volume/Stroke Pum Rate: ('Drilling Supervisor: Dave Burf~y ! Peter V~`ii~~n Pump used: #2 Mud Pump ~ Strokes ~ 0.1i1L":0 Bbls/Strk ~ 7•p0 Strk/min O Type Of Test: OpenholeTest LOT/FIT ~ Pumping down annulus and DP. ~ Casin Test Pressure In te ri Test Hole Size: $-3/4" ~ Casin Shoe De th Hole De th Pum in Shu t-in Pum in Shut-in RKB-CHF: <tC3.5 Ft 399i'.0 Ft-MD 24F9.0 Ft-TVD 402"i".0 Ft-MD ~4'r8.0 Ft-TVD Strks si Min si Strks si Min si Casing Size and Description: s-5/s" 40#/Ft L-80 BTC ~ 0 30 0 3510 0 0 0.00 1080 Casin Test Pressure Inte ri Test ~ '(70 1 ~~ 10 1 2f1 0.15. 10:'0 Mud Weight: 10.0 ppg Mud Weight: 9.6 ppg 4 340 2 3510 2 50 0.30 .915 Mud 10 min Gel: 12.0 Lb/100 Ft2 Mud 10 min Gel: `I~'.C1 Lb/100 Ft2 6 400 3 .1510 :? 100 1.00 8'~5 Test Pressure: 3500.0 psi Rotating Weight: 125000.0 Lbs 8 640 4 3500 •1~ 165 1.50 °s;0 Rotating Weight: 73000.0 Lbs Blocks/Top Drive Weight: 75000.0 Lbs 10 ; 90 5 3500 5 225 2.00 8'20 Blocks/Top Drive Weight 73 000.0 Lbs Desired PIT EMW: 1?',,t7 ppg 1?_ 8701 6 3.:~C10 6 ;3201 2.50 805 Estimates for Test: 4 bbls Estimates for Test: 1078 si 1.2 bbl 14 930 7 3500 395 3.00 799 ~ ~ 16 1100 8 3500 8 470 3.50 782 EMW =Leak-off Pressure+ Mud Weight = 1080 PIT 15 Second 1cs 1220 9 3~;C10 9 5:s0 4.00 r'"l'9 + 9 6 0.052 x TVD 0.052 x 2469 Shut-in Pressure, si 20 134G 10 3500 10 590 4.50 788 EMW at 3997 Ft-MD (2469 Ft-TVD) = 18.0 1020 22 '1470 15 3500 11 845 5.00 700 Lost 10 psi during test, held 99.7°r6 24 161)0 20 3 500 1 ~ 720 5.50 7 )8 760 6 00 750 of test pressure. 26 1750 25 3500 13 . aooo ,; ~:~:' ~,~;;~;;~,-~ -; ;: ;-.r -~, '28 18~J0 30 ;_500 14 8001 6.50 'i"4y 30 2050 15 820 7.00 740 i":39 s5oo 32 2220 1C3 840 7.50 880 8 00 73v 34 2360 17 . % 18 905 8 50 ' 30 sooo :3C~ : 530 . 38 2680 19 9.4.0 00 9 724 . w z5oo 40 2840 20 9b(.1 9.50 "12`[ s;'? 3040 21 1000 10.00 720 ~ zooo 44 3'i 80 22 10115 w .1F; 3:3'0 23 10'?5 o~ 1500 , ~r 48 3510 24 1 C14C1 . F,. ~...~ .~... 25 1050 000 ......ani!: i!:. ..._I...:~v:.a:n~ ~i~ 2(3 1i18i.1 1 27 10°0 500 ~ - `" 25 30 5 10 15 20 0 o Shut-In time, Minutes o , 2 3 a 5 s Volume Pum ed Volume Bled Back Volume Pum ed Volume Bled Back Barrels 4.8 Bbls Bbls 2.7 Bbls Bbls CASING TEST -LEAK-OFF TEST O PIT Point J CD3-304 Surface Csg test & LOT 4-14-09 .xls Summary ~ ~ CD3-304 7" Production Casing Detail Well: ~~~°~.~= ~~ ~~~ - ~'~ ~ i~P_ ~-x=~~ _ - - _ _::- Date: 41~?f200•r ,~,,,p Rig: uoyon 19 klaskz;-.lne; ~~ Depth Jt Number Joints Well Equipment Description and Co ::~ Page 1 ___.~„- Length Tops • Doyon 19 RKB to LLDS 34.20 _. ~,. ::~ ~ ~ "'~~ FMC Gent/ Hanger 2.62 34.20 Jts 67 to 433 367 Jts 7" 26# L-$0 BTCM Csg 15054.51 36.82 1~larker.loint Pup Jt. 7" 26# L-80 Csg 10.08 15091.33 l~larl~er Joint -Pup Jt. 7" Z6# I_-$0 Csg 9.73 15101.41 Jts 12 to 66 55 Jts 7" 26# L-$0 BTCM Csg 2246.78 15111.14 3V1arl~er Joint - I~up Jt, '~" 26# L-&0 Csg 21:01 17357.92 Jts 3 to 11 9 Jts 7" 26# L-$0 BTCM Csg 363.89 17378.93 7°' a[liburton Fl~aat Gca[lar 1.00- 17742.82 Jts 1 to 2 2 Jts 7" 26# L-$0 BTCM Csg 85.83 . 17743.82 7" Ray Coil Tools " SiE~rer Bullet ° Float Shoe 2.10 17829.65 ~"° g}yoe ~ 17831.75 17831.75 17831.75 17831.75 8-314" HQIe TD 17,843' i~D f 6,806" TVD 17831.75 7 " Shsae ~€ 17,832' 1t~D ! 6,801' TVD 17831.75 17831.75 Total Centralizers: Tandem Rise 45 -Straight Blade 52 - 30 Stop Rings 17831.75 Tandem Rise Cent 2 per jt #1-15 and 1 per jt # 16 - 30 17831.75 (Flt Shoe 8~ FC 1lstraight blade installed) 17831.75 Straight blade cent. one per jt. on joint #'s 336, 337, 338 17831.75 Straight blade cent.one on every other jts, # 340 #o #432 17831.75 17831.75 17831.75 17831.75 17831.75 445 joints in shed to run 433 jts 17831.75 Last 12 jts. Out 17831.75 17831.75 17831.75 17831.75 17831.75 17831.75 17831.75 Remarks: Up Wt 395 K Dn Wt 125 K Block Wt 75 K Supervisors: Mickey /Browning Cement Detail Report ``, CD3-304 . .. String: Production Casing Cement Job: DRILLING ORIGINAL, 4/8/2009 03:30 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Production Casing Cement 4/23/2009 15:30 4/23/2009 18:30 CD3-304 Comment Cemented 7" casing as follows: Pumped CW 100 -Pressure test lines to 2,500 psi -Dropped btm plug -Pumped 50 bbls CW-100 @ 4.2 bbls/min with 450 psi -Mix & pumped 40 bbls 10.5 ppg MudPush @ 4.6 bbls/min with 470 psi -Mixed & pumped 87 bbls (135 sxs) 11.0 ppg, 3.35 yield lead slurry (Class G w/ additives) @ 5.9 bbls/min with 430 psi -Mixed & pumped 44 bbls (200 sxs) 15.8 ppg, 1.16 yield tail slurry (Class G w/ additives) at 4.2 bbls/min with 70 psi - Dropped top plug Displaced @ bbls/min - psi to psi for first bbls -slowed pumps to bbls/min -psi for last bbls of displacement. Final displacement pressure 750 psi. Bumped @ .displacement 669 bbls - CIP @ 1823 hrs.- Calc TOC @ 14,800'. No pipe movement and had full circulation throughout job. Check floats OK Cement Sta es Sta e # 1 Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Piug? Production Casing Primary Cement Job 14,800.0 17,843.0 Yes 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) 4 3 5 450.0 800.0 No No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids 8 Additives fluid - Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class . Volume Pumped (bbl) Lead Cement 14,800.0 16,800.0 135 G 87.0 Yield (ft'Isack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 3.35 11.00 Additives Additive Type Concentration Conc Unit label :Fluid. Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 16,800.0 17,842.0 200 G 44.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 15.80 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 11/2/2009 Security Level: AK Development ' °~ „~-; Daily Drilling Report ~ - CD3-304 Report Number: 16 . • ,. Rig: DOYON 19 Report Date: 4/23/2009 AFE Type Network/1D ~' Total AFE+Sup ,: 10246924 8,770,001.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3-304 Development FIORD KUPARUK 14.98 16.0 0.00 17,843.0 17,843.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 45,251.39 452,479.82 1,214,872.39 5,510,922.82 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 4/8/2009 4/9/2009 23.11 21.17 1.94 4!29/2009 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) PRODUCTION, 17,832.OftKB Ops and Depth @ Morning Report 24hr Forecast Testing Upper Rams P/U Tubing Hanger and Test t/ 5,000 Psi.- Cut & Slip Drill Line - Service Rig -Change Upper Rams & Test - R/U & Run Tubing per Detail Last 24hr Summary Continue to RIH w/ 7" Casing f/ 10,850' - 17,832' MD -Circ & Cond Mud Prior to Cement -Cement 7" casing w/ 87 Bbls of 11.0 PPG Lead and 44 Bbls of 15.8 PPG Tail -Displace Cement w/ 669 Bbls 9.2 PPG KCL Brine - CIP @ 1823 -Test Casing t/ 3500 Psi f/ 30 Minutes (Good) - R/D Tesco Tools -Set Packoff and Test t/ 5,000 Psi f/ 30 Minutes General Remarks Weather Head Count No Accidents and No Spills 18 Deg / WC -3 /Snow /Wind WSW @ 23 G 50.0 32 Mph Supervisor Title Don Mickey, Rig Supervisor Rig Supervisor Jeff Browning, Rig Supervisor Rig Supervisor Dave Egedahl, Rig Engineer Rig Engineer Jenaya Rohlfing, Rig Engineer Rig Engineer Time Lo ' Start End Dur Time - Depth Start Depth End Time Time (hrs) Phase Op Code Activity Code P-T-X Trbl Code Trbl Class. (ftK6) (ftKB) Operation 00:00 01:45 1.75 COMPZN CASING RNCS P 10,850.0 12,312.0 Continue to RIH w/ 7" Casing t/ 12312' MD (300 Jts in Hole) PU = 270k. SO = 127k. 01:45 03:15 1.50 COMPZN CASING CIRC P 12,312.0 12,312.0 Circ btms up + Staging pumps up from 2.5 bbls/min -ICP 350 psi to 6.5 bbls/min -FCP 560 Psi 03:15 08:15 5.00 COMPZN CASING RNCS P 12,312.0 16,049.0 Continue to RIH w/ 7" Casing t/ 16049' MD (390 Jts in Hole) PU = 360k. SO = 133k. 08:15 10:00 1.75 COMPZN CASING CIRC P 16,049.0 16,049.0 Circ btms up + Staging pumps up from 2.5 bbls/min -ICP 490 psi to 6.5 bbls/min -FCP 690 Psi 10:00 12:45 2.75 COMPZN CASING RNCS P 16,049.0 17,794.0 .Continue to RIH w/ 7" Casing t/ 17794' MD (433 Jts in Hole) PU = 395k. SO = 125k. 12:45 13:15 0.50 COMPZN CASING HOSO P 17,794.0 17,832.0 Make up 7" hanger, landing joint. Land casing w/ FS @ 17,831' FC @ 17,743' MD. Make up cement head. 13:15 15:00 1.75 COMPZN CEMENT CIRC P 17,832.0 17,832.0 Circulate and condition mud for cement job. Stage pump up to 6.5 BPM with 710 psi. 15:00 15:15 0.25 COMPZN CEMENT SFTY P 17,832.0 17,832.0 Pre job safety meeting for 7" cement job. Latest BOP Test Data Date'- Comment 4/22/2009 Test 7" u er rams to 250 si low and 3500 si hi h. Page 1/3 Report Printed: 11/2/2009 r r~ Security Level: AK Development e. Daily Drilling Report i CD3-304 Report Number: 16 . . Rig: DOYON 19 Report Date: 4/23/2009 Time Lo Start End Dur Time Depth Start Depth End Time Time (hrs) Phase Op Code Activity Code P-T-X Trbl Code Trbl Class. (ftKB) (ftKB) Operation 15:15 16:30 1.25 COMPZN CEMENT CMNT P 17,832.0 17,832.0 Cemented 7" casing as follows: Pumped CW 100 -Pressure test lines to 2,500 psi - Dropped btm plug -Pumped 50 bbls . CW-100 @ 4.2 bbls/min with 450 psi - Mix & pumped 40 bbls 10.5 ppg MudPush @ 4.6 bbls/min with 470 psi - Mixed & pumped 87 bbls (135 sxs) 11.0 ppg, 3.35 yield lead slurry (Class G wl additives) @ 5.9 bbls/min with 430 psi - Mixed & pumped 44 bbls (200 sxs) 15.8 ppg, 1.16 yield tail slurry (Class G w/ additives) at 4.2 bbls/min with 70 psi - Dropped top plug 16:30 18:30 2.00 COMPZN CEMENT DISP P 17,832.0 17,832.0 Displaced @ 7.0 bbls/min - 520 psi for the first 655 bbls -slowed pumps to 3.0 bbls/min - 750 psi for last 24 bbls of displacement. Final displacement pressure 726 psi. Bumped @ displacement 669 bbls - CIP @ 1823 hrs.- Calc TOC @ 14,800'. No pipe movement and had full circulation throughout job. Check floats OK 18:30 19:30 1.00 COMPZN CASING PRTS P 17,832.0 17,832.0 R/U and Test 7" Production Casing to 3,500 psi f/ 30 Minutes (Good) 19:30 20:30 1.00 COMPZN CASING RURD P 17,832.0 17,832.0 R/D Cementing and Casing Test head & Manifold 20:30 20:45 0.25 COMPZN CASING SFTY P 17,832.0 17,832.0 PJSM on UD Tesco Casing Running Tools 20:45 22:00 1.25 COMPZN CASING PULD P 17,832.0 17,832.0 UD Tesco Casing Running Tools 22:00 23:15 1.25 COMPZN CASING MPSP P 17,832.0 17,832.0 M/U Test Joint and Pull Thin Wall Wear Ring - M/U & Set 7" Packoff 23:15 00:00 0.75 COMPZN CASING PRTS P 17,832.0 17,832.0. Test 7" Packoff t/ 5,000 Psi f/ 30 Minutes Mud Check Data YP Gala- Gel (10s) - Gel (tOm) Gel (30m) HTHP Filt Density Temp Solids, Corr. Type Depth (ftKB) Dens (Iblgal) Vis_ (slgt) PV Calc (cp) (Ibf/100ft') (Ibf/100ft'). (Ibflt00ft') :(IbfI100ft') MBT (Ib/bbl) (mU30min) pH ': (°F) - (% ) 9.2 ppb 17,843.0 9.20 Brine ln'ection Fluid Fluid Source From Lease (bbl) Destination Vendor Manifest Number - Note Diesel CD3-304 5.0 CD3-115 Water Based Mud CD3-304 1160.0 CD3-115 Wel /bores Wellbore Name Wellbore API/UWI CD3-304 501032059800 Section .Size (in) _ _ _ Act Top (ftKB) Act Btm (ftKB) StaA Date End Date COND1 16 36.0 114.0 4/1/2009 4/2/2009 SURFAC 12 1/4 114.0 4,007.0 4/9/2009 4/11/2009 INTRMI 8 3/4 4,007.0 17,843.0 4/8/2009 4/20/2009 Casin Strin s String OD String Wt Casing Description - - Run Date (in) (Ibsfft) String Grade ' Set.Depfh (ftKBJ - Comment PRODUCTION 4/2 3/2009 7 26.00 L-80 17,832.0 Ran 45 Tandem Rise and 52 Straight Blade Centralizers Page 2/3 Report Printed: 11/2/2009 Security Level: AK Development - ~ _s =~ Daily Drilling Report _~ CD3-304 Report Number: 16 ,,. ~ ,, ,~ Rig: DOYON 19 Report Date: 4/23/2009 Cement Production Casin Cement -Started _ 4/23/2009 Type Welibore Cemented String Cement Evaluation Results casing CD3-304 PRODUCTION, 17,832.OftKB Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl/... P (final) (psi) 1 Production Casing Cement 14,800.0 17,843.0 3 450.0 Ftuid Class Amounf(sacks)" V (bbq "' Derisity (Ib1gaIJ" Yield"(ft'/sack) Est T op (ftKB) '` Est Btrn (ftKi3) Lead Cement G 135 87.0 11.00 3.35 14,800.0 16,800.0 Tail Cement G 200 44.0 15.80 1.16 16,800.0 17,842.0 Pressure Test Data Item Tested Date Pres (psi) Failed? Comment PRODUCTION, 17,832.OftKB 4/23/2009 3,520.0 No Tested 7" Casing to 3500 Psi f/ 30 Minutes - 100% Pressure Held Casing Hanger, 11 in 4/23/2009 5,000.0 No Tested 7" Packoff t/ 5,000 Psi f/ 30 Min Page 3/3 Report Printed: 11/2/2009 Well Name: CD3-304 Rig: Drilling Supervisor: Mickey / Bra~nrning Type of Test: Annulus Leak Off Test for Disposal Adequacy Hole Size: 8-3/4" ~ Casin Shoe I RKB-CHF: 34.0 Ft 3997.0 Ft-MD 24 Casing Size and Description: USE PICK LIST Chan es for Annular Ade uac Test Enter outer casing shoe test results in comments Casing description references outer casing string. Hole Size is that drilled below outer casing. Use estimated TOC for Hole Depth. Enter inner casing OD at right. EMW =Leak-off Pressure + Mud Weight = 0.052 x TVD EMW at 3997 Ft-MD 2 ~ooo w o: N 500 w a 0 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Doyorr 19 Date: 4f24l2009 Volume In u Pump used: Cement Unit ~ Barrels ~ ~ Pumping down annulus. ~ Cas i Hole De th Pum in Ft-TVD 14800.0 Ft-MD 5818.0 Ft-TVD Bbls psi Mud Weight:uppg Inner casing OD: 7.0 In. Desired PIT EMW: '15.0 ppg Estimates for Test: 642 si 0.2 bbls 667 + 10 PIT 15 Second 0.052 x 2469 Shut-in Pressure si Ft-TVD = 15.2 52s 0 5 10 15 20 25 0 5 10 15 20 25 30 Barrels Shut-In time, Minutes -'~~CASING TEST ~~ LEAK-OFF TEST O PIT Point ments: Pd,~mped Bbls of 10 PPG bribe Dawn 9 518" by 7" annulus -Leak. Off Occurred at 17.5 13b1s A" Dowell Cement unit to F'ump ~ 3f4 BPM - Followed LOT w1300 Bbls H2O Flush and 40 Bbl= Pum Rate: Bbls/Strk ~ ~•75:I Bbl/min ~ Shut-in Pum in Shut-in Min si Bbls si Min si 0 0 83 0.00 530 1 1 150 0.25 528 2 2 195 0.50 515 3 3 233 1.00 513 4 4 270 1.50 511 5 5 305 2.00 506 6 ~ ~a 345 .2.50 503 7 7 373 3.00 500 8 8 402 3.50 502 9 9 436 4.00 497 10 10 462 4.50 497 15 11 496 5.00 498 20 12 525 5.50 495 25 13 557 6.00 493 30 13.5 572 6.50 494 '14 586 7.00 494 14.5 596 7.50 492 15 610 8.00 490 15.5 626 8.50 489 '[ 6 642 9.00 489 16.5 650 9.50 490 17 658 10.00 4;:36 17.5 .667 'I 8 661 19.5 635 20 628 20.5 632 lume ~ Volume Volume Volume n ed Bled Back Pum ed Bled Back Bbls ;, Bbls 20.5 Bbls Bbls 67 Psi for 15.2 PPO EMW - Usec1 ezze Protect to 1500' TVD Summary • ~ ~~ ~ Details for CD3-305 3~s- ~~3 • Note to File CD3-304 (209-028...309-380) Colville River Unit (Fiord-Kuparuk) ConocoPhillips Alaska, Inc ConocoPhillips has made application for annular disposal for the subject well. This document examines the pertinent information for the well and recommends approval of ConocoPhiAips' request. --No unusual events were reported while drilling the surface hole of the well. --Surface casing was cemented to surface. No problems were reported. Approximately 12 bbls of cement was circulated to surface. The net cement remaining in the surface hole was 57% XS of the calculated hole volume. Reciprocation was stopped prior to cement reaching the shoe. -- On the initial leak off test, the pressure rises smoothly to 15.4 EMW where a change in slope occurs and continues to rise smoothly to 18.0 EMW. Minimal fluid was pumped in. The pressure declined during the observation period to about 15.2 EMW. Two pressure slopes are not uncommon at GRU. The initial leak off indicates that the surface casing shoe is well cemented. --No problems were reported drilling the intermediate hole. The 7" casing was run and successfully cemented. Full returns were noted. Although the casing was reciprocated, cement was not in the annulus when movement was halted. --An infectivity test down 9-5/8" x 7" annulus was conducted. Pressure steadily increases until the break at 15.2 EMW. The pressure declined with additional pumping to 14.9 EMW. During the observation period, the pressure declined to 13.7 EMW. The lower EMW of the pump in test indicates that the planned disposal should be conducted at EMWs below that of the shoe integrity. --CPA provided a listing of all surface casing shoes within '/4 mile radius of CD3-304. The nearest surface shoe is CD3-305, about 670' distant. The remaining well. is about 1000' distant. Examination of the cementing information did not reveal anything to preclude granting CPAI's request. Based on examination of the submitted information, I recommend approval of ConocoPhillips' request for the subject well. ~~~o~ Tom Maunder, PE Sr. Petroleum Engineer December 01, 2009 ~~ Gu chwartz Sr. etroleum Engineer G:\AOGCC\Common\tommaunder\Well Information\By Subject\Annular Disposal\091201-- CD3-304.doc Note to File CRU CD3-304 (PTD 2090280) November 16, 2008 Re: ConocoPhillips' Application for Sundry Approval for Annular Disposal of Drilling Wastes within Well CD3-304 Request ConocoPhillips requests approval to dispose of waste fluids generated through drilling operations by injection into the 9-5/8" x 7" annulus within well CD3-304. Recommendation Approve ConocoPhillips' request. Conclusions 1. The 9-5/8" surface casing shoe is set in this well at about 3,997' measured depth (-2,419' true vertical depth subsea, or "TVDSS"), near the base of a 400-foot thick mudstone and siltstone interval that persists throughout the area. This interval will provide confinement to prevent upward migration of injected waste. 2. There appears to be a sufficient volume of silty sandstone and sandy siltstone open to the annulus surrounding the 7" casing within this well to accept the proposed injected fluids. 3. The lower confining mudstone strata are sufficiently thick and laterally persistent to ensure injected materials remain within the target disposal interval. 4. There are no potential USDWs in this area. 5. Correlative rights will be protected. 6. The proposed disposal injection operations will not affect potential oil or gas reservoirs. 7. The area most strongly impacted by the proposed annular disposal activities will be limited to a radius of about 150' from the wellbore. Discussion CPAI's application was reviewed along with records and well logs from Colville River Unit (CRU) wells CD3-114, CD3-316, and the Fiord 1 exploratory well. An index map is provided in Figure 1, below. All footages presented herein represent measured depth, unless otherwise noted. All thickness footages represent stratigraphic thickness, unless otherwise noted. The CD3-304 development well was drilled to the Fiord Oil Pool within the CRU. ConocoPhillips, the operator, intends to dispose of drilling wastes utilizing an open annulus within CD3-304 that extends downward from the 9-5/8" surface casing shoe, which is set at about 3,997' (-2,419' TVDSS), to the top of cement for the 7" casing string, which is estimated to lie at about 14,075'1 (-5,540' TVDSS). This annulus lies within Sections 4, 10 and 11 of T12N, RSE, Umiat Meridian (see Figure 1). The annulus is located more than 2 miles from the current boundary of the CRU. The section of annulus in CD3-304 that will most likely accept the injected waste fluids (most likely receptor interval) is a portion of the Seabee formation that extends from about 4,235' to 4,470' i Top of cement estimate from \\Doaancoccft~s01\Shared\AOGCC\Common\tommaunder\aa2009 0712 Workinp- Well Cement Cm7~ent.xls, worksheet MIT II, PTD 209-028, column 30% Excess TOC. CD3-304 Note to File (-2,495' and -2,575' TVDSS; see Figure 2, below). This 80-foot thick interval contains numerous 1- to 2- foot thick beds of sandy siltstone and silty sandstone that are separated by siltstone, mudstone and shale. The aggregate stratigraphic thickness of the sandy siltstone and silty sandstone beds exposed to the annulus is about 10 feet. On the well log from CD3-304, the gamma ray curve suggests the presence of a thick, silty sandstone bed at the shoe of the 9-5/8" surface casing. This apparent silty sandstone bed is an artifact caused by circulating and cementing. In offset wells, the correlative sediments to those surrounding the 9-5/8" casing shoe consist of mudstone and siltstone (see Figure 3, below). The 9-5/8" surface casing shoe lies near the base of a 405-foot thick interval that is dominated by mudstone and siltstone. This interval is continuous throughout the area, and it will provide upper confinement for the disposed fluids. Beneath the most likely receptor interval is a 50-foot thick mudstone interval that is also continuous throughout the area. This interval, which lies between about 4,200' and 4,325' (-2,655' and -2,705' TVDSS), and two similar, thinner, underlying mudstone intervals will provide additional lower confinement for injected wastes. D3 302P62 f D3-302PB2 CD3-3D7 I ,,,, D3-302PB 1 - _ _ __ ~ A ~ ~ ~ O ~~ ~ " ~,,/ J 3 n ~ ~*o' .~ te ~~ ~ ~~ ~;' 1 ~:~ ;r ~~ ~~-. ~ CRU CD3-304 ^ ~` ~ ~2e+E Annulus r --~ --~~ CD3-~Oo „ .~ ,.fir ~ _ ,~ - ~~ ~ , ; PH .~ ~_ ~ :a- ~~-c.a,. i~.,.~, __ u ~>~< ~ ' FICR,D I ~ _.. ~ , „ I ~ .` r -__.... - -- CD3-304 CD3-30~ Most Likely Receptor ~ ` Interval - -,~ `.._y_.........,-. .. (highlighted with magenta) Area of Review ~ ~ , • Surface casing shoe (shaded blue) s { (, ~, ~ ~ ~ ~ ~ -DS-306 Cement top ~___ ,. . ;:; ,_...;>< . November 16, 2009 Page 2 of 5 Figure 1. Index Map (The path of the cross-section shown on Figure 3 is highlighted with a red line) In vicinity of Drill Site CD3, the base of permafrost occurs at about -1,250' TVDSS, which is about 1,200' shallower than the top of the likely receptor interval. Conclusion 3 of Area Injection Order 30, which governs the Fiord Oil Pool, states that there are no USDWs beneath the proposed affected area. i • CD3-304 Note to File November 16, 2009 Page 3 of 5 Nearby well CD3-114 is the only well that was mud logged on Drill Site CD3. In CD3-114, methane was first encountered at about l,l 15' (-1,050' TVDSS). In the Fiord 1 exploratory well, located about 1-3/4 miles to the east, methane was first encountered at 350' (about 310' TVDSS). So, the entire proposed disposal zone likely contains some gas. Upper Confinin Strata Most Lik Receptor Interval i Disposed Fluids Lower Confinin Strata Figure 2. CD3-304 Well Log Displaying Affected Intervals The shallowest oil show encountered in well CD3-114 was observed at 6,050" (-4,413' TVDSS), about 1,850" stratigraphically below the most likely receptor beds for the injected material. This show consisted only of 10% dull yellow sample fluorescence and a slow pale yellow sample cut in solvent, and the mud i • CD3-304 Note to File November 16, 2009 Page 4 of 5 logging geologist rated this show as being of "trace'" quality. In Fiord 1, about 2 miles to the southeast, the shallowest oil indicator is amoderate-quality show encountered between about 2,530' and 2,590' (-2,490' and 2,500' TVDSS). This show consisted on 60% to 80% sample fluorescence, with a briglrt yellow, streaming solvent cut; associated gases recorded were methane, ethane, propane and butane. The 501032037000 501032054400 501032055900 501032059800 501032016200 w ~ 18365 ft ~_ ___322 ft __ _~ ~ 541 ft __~ F 11329 ft L~ 1: CONOCOPHILLIPS ALASK CONOCOPHILLIPS ALASK CONOCOPHILLIPS ALASK CONOCOPHILLIPS ALASK ARCO NIGLIO 1 COLVILLE RIV UNIT CD3-114 COLVILLE RIV UNIT CD3-316 CRU CD3-304 FIORD 1 210 FSL 1170 FWL 3960 FNL 2703 FEL 1310 FSL 971 FEL 738 FEL 3912 FNL 526 FSL 420 FWL TWP: 12 N - Range: 4 E - Sec. 2 TWP: 12 N - Range: 5 E - Sec. 5 TWP: 12 N - Range: 5 E - Sec. 5 TWP: 12 N - Range: 5 E - Sec. 5 iWP: 12 N - Range: 5 E -Sec. 2 --~.~.I ._. _. ~ , - _ --~- .. _~ ® _ ~~ I Figure 3. Structural Cross-section from Nigliq 1 to Fiord 1 mud logging geologist recorded an "oil sheen" associated with the show along with trace amounts of brownish staining throughout the interval. This show was not cored, sidewall cored, or tested. The mud log from the nearby Fiord 1 well mudlog describes apoor-quality oil show extending from about 2,590' to 3,470' (-2,550' to -3,660' TVDSS), which consists mostly of yellow to bright yellow sample fluorescence (a trace to 60%) and pale to streaming solvent cut fluorescence, but no visible solvent cut or oil staining. All of these instances are judged to represent only small amounts of residual (non-mobile) oil. The shallowest significant oil staining within Fiord 1 occurs at about 4,000' (-3,960' TVDSS), where the mud log records alight- to medium-brown stained sandstone. This sandstone lies 1,400' stratigrapllically below the most likely waste receptor beds in CD3-304. So, at Drill Site CD3 the likely disposal interval does not contain potentially commercial quantities of oil or gas. _ f - -. r -I -~ ._ ,p .. - 9-5/8" Casing Shoe The chart presented in Figure 4, below, provides an estimate of the subsurface volume around CD3-304 that will be affected by the proposed annular disposal operations. There are about 10' of porous sandy CD3-304 Note to File November 16, 2009 Page 5 of 5 siltstone and silty sandstone beds within the likely waste receptor interval, according to a count using the gamma ray curve from CD3-304. Neutron and density porosity well logs were run across the proposed disposal interval in nearby well CD3-108. Inspection of these well logs suggests an average porosity of about 28% for the sandy siltstone and silty sandstone within the likely receptor interval. Based on these values, the proposed annular injection activities will directly affect the receptor beds only to a radius of about 150' from the wellbore, as indicated in the chart below. Injected Fluid vs Affected Radial Distance CD3-304 Wellbore (assumes 10' aggregate injection zone thickness and 28% porosity) 300 _.. __._ _______.__- _.--- _-._.___._.___ ........__ __.---_ --___.._ .._..--_-._ ._.__.__. ..___.-_-_ _..___. 250 0 ~ I a~ ~ 200 E 0 ~ w ~ m ~ ~ i 150 w 0 m ~ 100 ~i a~ U Q 50 I~ 0 0 5,000 10,000 15,000 20,000 25,000 30,000 35,000 Amount of Injected Fluid (barrels) Figure 4. Radial Distance Potentially Impacted by CD3-304 Annular Disposal Summary The limited volume of rock that will be affected by this proposed disposal injection program likely contains some gas, is situated beneath about 1,200' of permafrost, and is bounded above and below by continuous confining layers. There are no freshwater aquifers present, nor are there any potentially commercial hydrocarbons within the proposed injection interval beneath Drill Site CD3. The open annulus that will be used for disposal injection lies inside the CRU, well away from any external property lines, so correlative rights are not a concern. I reco mend approval of this annular disposal project. Steve Davies Senior Petroleum Geolo ist ,~ T CO~,L~I~ ~ ~il~ Y t~ ~ ~; ConocoPhillips May 26, 2009 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for CD3-304 (209-028) Dear Commissioner: G. L. Alvord Alaska Drilling Manager Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 ~~ ~ll)N ~- 2 ?~C~ IsslGa Oil ~ Gay Cony. ~~;~~~r>~i~sol Anchorage ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Colville well CD3-304. If you have any questions regarding this matter, please contact me at 265-6120 or Liz Galiunas at 265-6247. Sincerely, ~. ~ , V"\. G. L. Alvord Alaska Drilling Manager CPAI Drilling GLA/skad ~... t ~ ~~ i~r~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 22 WELL COMPLETION OR RECOMPLETION REPOF~T~A,ND~L~G~~~ 1a. Well Status: Oil ^ - Gas Plugged Abandoned ^ Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. e I df1~. (]R)f-IISS{OJ~ Development ~(j~~pr~~~loratory L_J Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: April 29, 2009 12. Permit to Drill Number: 209-028 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: April 9, 2009 13. API Number: 50-103-20598-00 - 4a. Location of Well (Governmental Section): Surface: 1368' FSL, 739' FEL, Sec. 5, T12N, R5E, UM - 7. Date TD Reached: April 20, 2009 14. Well Name and Number: CD3-304 Top of Productive Horizon: 1989' FNL, 1774' FEL, Sec. 11, T12N, R5E, UM 8. KB (ft above MSL): ~ RKBrf9c~ Ground (ft MSL): %~'~ ' AMSL p 15. Field/Pool(s): v.a9 Colville River Field Total Depth: 2111' FNL, 1275' FEL, Sec. 11, T12N, R5E, UM 9. Plug Back Depth (MD + TVD): • 17743' MD / 6760' TVD Fiord Oil Pool " 4b. Location of Well (State Base Plane Coordinates): Surface: x- 388305 - y- 6003860 ' Zone- 4 10. Total Depth (MD + TVD): 17843' TD / 6807' TVD 16. Properly Designation: , ADL 372103, 372104, 372105 TPI: x- 403067 y- 6000297 Zone- 4 Total Depth: x- 403565 - 6000169 t Zone- 4 11. SSSV Depth (MD + TVD): SSSV @ 1607' MD / 1514' TVD 17. Land Use Permit: LAS2112 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 (TVD): 1500' TVD 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 TVD HOLE CEMENTIN RECORD AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE G PULLED 16" 62.58# H-40 37' 114' 37' 114' 24" Portland Type 9.625" 40# L-80 37' 3997' 37' 2469' 12.25" 540 sx AS Lite, 245 sx Class G 7" 26# L-80 37' 17831' 37' 6801' 8.75" 135 sx Class G, 200 sx CI G 23. Open to production or injection? Yes / No ~ If Yes, list each 24. TUBING RECORD Interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET 4.5" / 3.5" 1670' ! 17258' 15086' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 17408'-17440' MD 6627' - 6638' TVD 6 spf DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED na 26. PRODUCTION TEST Date First Production May 10, 2009 Method of Operation (Flowing, gas lift, etc.) Gas Lift Oil Date of Test 5/18/2009 Hours Tested 9 hours Production for Test Period --> OIL-BBL 1275 GAS-MCF 831 WATER-BBL 0 CHOKE SIZE 100% GAS-OIL RATIO 844 Flow Tubing press. 287 psi Casing Pressure 1320 Calculated 2a-Hour Rate -> OIL-BBL 3073 GAS-MCF 2593 WATER-BBL 0 OIL GRAVITY -API (corr) not available 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No ^/ ~ 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 lthology 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. ~ ~,C,f~"r'I DTI() t •)a"` NONE ~ ~ }: 11El4 IEO c '• Form 10-407 Revised 2/2007 CONTINUED f9N REVERSE S~ID~• ,~1> ~ ~~,C~7~'~' ~~ ,~ REV € a 20D9 - w~ t ~ ~ t°'~ ~, ~~ !~°'~~1 / 6~~~/ G r1 r1 28. GEOLOGIC MARKERS (List all formations and ma ers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes Q No ~ If yes, list intervals and formations tested, Permafrost -Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1588' 1500' - needed, and submit detailed test information per 20 AAC 25.071. C-30 4072' 2493' C-20 5290' 2880' K-3 8507 3874' K-2 9169' 4078' Nanuq 15601' 6070' K-1 17159' 6550' Kuparuk C 17285' 6588' N/A Formation at total depth:. Kuparuk C 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Liz Galiunas # 2247 Printed Name G. L. Alvord Title: Alaska Drilling Manager ~ C t ~ G ~ /n~ Signature eG-4 ~ ~ ~ Phone ~~~ (~ t Zn Date ~~~~ INSTRUCTIONS Sharon Allsup-Drake @ 263-4612 General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well 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 ~J ConocoPhillips(Alaska) Inc. Western North Slope CD3 Fjord Pad CD3-304 Permit to Drill: 209-028 API : 50-103-20598-00 ~~ Definitive Survey Report 29 April, 2009 ~'~~ ... `~ ; Sperry Cirillir~g Servi~~a ConocoPhillips Definitive Survey Repoli Company: ConocoPhillips(Alaska) Inc. Project: Western North Slope Site: CD3 Fjord Pad Well: CD3-304 Wellbore: CD3-304 Design: CD3-304 Local Co-ordinate Reference: Well CD3-304 TVD Reference: CD3-304 (36.45+13.4) @ 49.85ft (Doyon 19) MD Reference: CD3-304 (36.45+13.4) @ 49.85ft (Doyon 19) Nort;It Reference: True Survey Calculation Method: Minimum Curvature • Database: CPAI EDM Production Project Westem North Slope Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor ~ ell... CD3-304 Well Position +N/-S 0.00 ft Northing: 6,003,860.61 ft Latitude: 70° 25' 10.196 N +E/-W 0.00 ft Easting: 388,305.13 ft - Longitude: 150° 54' 35.745 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.40ft Wellbore CD3-304 Magnetics Model Name Sample Dat® Declination Dip Angle Field Strength (°1 (°) (nT1 ~~ BGGM2007 4/14/2009 21.68 30.77 57.618 -- - ~ Design CD3-304 _ - Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 36.45 Vertical Section: Depth Fram (TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 36.45 0.00 _ O.OU _ 111.00 ISurvey Program Date From To (ft} (ft) Survey (Weifbore} Tooi Name Description Survey Date 75.00 724.00 CD3-304 Gyro (CD3-304) CB-GYRO-SS Camera based gyro single shot 4!9!2009 12: 799.14 17,812.08 CD3-304 MWD (CD3-304) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4!9/2009 12: - _ - - _~ Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) ( °1100'} (ft) Survey Tool Name 36.45 0.00 0.00 30.45 -13.40 0.00 0.00 6,003,860.61 ~ 380,305.13 " 0.00 0.00 UNDEFIWED 75.00 0.29 305.66 75.00 25.15 0.06 -0.08 6,003,860.66 388,305.05 0.75 -0.09 CB-GYRO-SS (1) 171.00 0.28 313.47 171.00 121.15 0.36 -0.45 6,003,860.97 388,304.69 0.04 -0.55 CB-GYRO-SS (1) 264.00 0.16 342.74 264.00 214.15 0.64 -0.65 6,003,861.26 388,304.49 0.17 -0.84 CB-GYRO-SS (1) 356.00 1.18 124.29 355.99 306.14 0.23 0.09 6,003,860.83 388,305.23 1.42 0.01 CB-GYRO-SS (1) 449.00 3.60 116.75 448.90 399.05 -1.62 3.49 6,003,858.93 388,308.60 2.62 3.84 CB-GYRO-SS (1) 540.00 6.21 116.41 539.56 489.71 -5.10 10.45 6,003,855.35 388,315.50 2.87 11.59 CB-GYRO-SS (1) 633.00 8.78 118.90 631.76 581.91 -10.77 21.17 6,003,849.52 388,326.14 2.78 23.63 CB-GYRO-SS (1) 724.00 13.71 120.28 720.99 671.14 -19.57 36.58 6,003,840.49 388,341.41 5.43 41.16 CB-GYRO-SS (1) 799.14 15.52 120.81 793.69 743.84 -29.21 52.90 6,003,830.61 388,357.58 2.42 59.86 MWD+IFR-AK-CAZ-SC (2) i 845.38 16.96 118.83 838.09 788.24 -35.63 64.12 6,003,824.03 388,368.71 3.34 72.63 MWD+IFR-AK-CAZ-SC (2) ~ 940.89 18.29 119.26 929.11 879.26 -49.67 89.40 6,003,809.61 388,393.77 1.40 101.27 MWD+IFR-AK-CAZ-SC (2) 1,035.20 18.74 118.10 1,018.54 968.69 -64.04 115.68 6,003,794.85 388,419_83 0.62 130.95 MWD+IFR-AK-CAZ-SC (2) 4/29/2009 2:37:20PM Page 2 COMPASS 2003.16 Build 42F C onocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well CD3-304 Project: Western North Slope TVD Reference: CD3-304 (36.45+13.4) @ 49.85ft (Doyon 19) Site: CD3 Fjord Pad MD Refere nce: CD3-304 (36.45+13.4) @ 49.85ft (Doyon 19) Well: CD3-304 North Reference: True Wellbore: CD3-304 Survey Ca lculation Met hod: Minimum Curvature Design: CD3-304 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section lftl (°) (°) (ft) (ft) 1ft) (ftl (ft) Ift) (° 1'100') (ft) Survey Tool Name 1,130.48 22.50 110.59 1,107.04 1,057.99 -77.56 345.97 6,003,780.88 388,445.51 4.47 164.07 MWD+IFR-Ah-Cf1Z-SC (2) 1,225.61 23.39 104.44 1,195.58 1,145.73 -88.56 181.02 6,003,769.35 388,484.78 2.84 200.73 MWD+IFR-AK-CAZ-SC (2) 1,320.82 26.86 703.54 1,281.77 1,231.92 -98.32 220.24 6,003,759.02 388,523.86 3.67 240.85 MWD+IFR-AK-CAZ-SC (2) 1,416.04 33.71 106.83 1,363.95 1,314.70 -111.02 266.50 6,003,745.62 388,569.92 7.40 288.59 MWD+IFR-AK-CAZ-SC (2) 1,465.73 35.57 107.29 1,404.83 1,354.98 -179.31 293.50 6,003,736.93 388,596.79 3.78 316.76 MWD+IFR-AK-CAZ-SC (2) 1,511.38 37.70 107.47 1,441.46 7,391.61 -127.44 319.50 6,003,728.41 388,622.66 4.67 343.95 MWD+IFR-AK-CAZ-SC (2) 1,606.52 42.18 108.40 1,514.39 1,464.54 -746.27 377.58 6,003,708.72 388,680.45 4.75 404.92 MWD+IFR-AK-CAZ-SC (2) 1,701.48 46.86 105.37 1,582.08 1,532.23 -165.53 441.29 6,003,688.51 388,743.85 5.41 471.29 MWD+IFR-AK-CAZ-SC (2) 1,750.34 47.84 105.26 1,615.19 1,565.34 -175.02 475.95 6,003,678.50 388,778.36 2.01 507.05 MWD+IFR-AK-CAZ-SC (2) 1,794.63 48.05 105.42 1,644.85 7,595.00 -183.72 507.66 6,003,669.33 388,809.94 0.54 539.78 MWD+IFR-AK-CAZ-SC (2) 1,897.40 50.70 102.76 1,707.86 1,658.01 -201.56 578.89 6,003,650.42 388,880.89 3.44 612.67 MWD+IFR-AK-CAZ-SC (2) 1,985.32 53.80 102.30 1,765.35 1,715.50 -217.66 651.37 6,003,633.24 388,953.12 3.32 686.11 MWD+IFR-AK-CAZ-SC (2) 2,081.10 56.20 102.53 1,820.29 1,770.44 -234.53 727.99 6,003,615.23 389,029.47 2.57 763.69 MWD+IFR-AK-CAZ-SC (2) i 2,176.71 59.15 100.97 1,871.41 1,821.56 -250.92 807.09 6,003,597.66 389,108.30 3.40 843.41 MWD+IFR-AK-CAZ-SC (2) 2,271.57 64.11 103.62 1,916.47 1,866.62 -268.69 888.60 6,003,578.67 389,189.54 5.80 925.87 MWD+IFR-AK-CAZ-SC (2) 2,324.79 65.44 104.16 1,938.90 1,889.05 -280.12 934.81 6,003,566.56 389,235.57 2.69 973.11 MWD+IFR-AK-CAZ-SC (2) 2,366.99 66.69 103.78 7,956.26 1,906.41 -289.56 972.78 6,003,556.55 389,273.38 3.03 1,071.93 MWD+IFR-AK-CAZ-SC (2) 2,461.45 68.37 103.87 1,992.36 1,942.51 -310.42 1,057.53 6,003,534.42 389,357.81 1.78 1,098.54 MWD+IFR-AK-CAZ-SC (2) 2,556.14 72.04 103.33 2,024.43 1,974.58 -331.36 1,144.11 6,003,512.19 389,444.06 3.91 1,186.87 MWD+IFR-AK-CAZ-SC (2) j 2,651.45 72.77 102.92 2,053.24 2,003.39 -351.99 1,232.59 6,003,490.24 389,532.21 0.87 1,276.87 MWD+IFR-AK-CAZ-SC (2) ~ 2,746.59 72.95 102.87 2,081.28 2,031.43 -372.28 1,321.21 6,003,468.63 389,620.51 0.20 1,366.87 MWD+IFR-AK-CAZ-SC (2) ~ 2,841.09 72.38 102.86 2,709.43 2,059.58 -392.37 7,409.16 6,003,447.23 389,708.14 0.60 1,456.17 MWD+IFR-AK-CAZ-SC (2) 2,936.44 71.42 102.58 2,139.06 2,089.21 -412.32 1,497.56 6,003,425.96 389,796.23 1.04 7,545.86 MWD+IFR-AK-CAZ-SC (2) 3,031.97 70.74 102.51 2,170.01 2,120.16 -431.94 1,585.72 6,003,405.03 389,884.07 0.72 1,635.19 MWD+IFR-AK-CAZ-SC (2) 3,126.95 73.08 103.06 2,199.52 2,149.67 -451.93 1,673.81 6,003,383.72 389,971.85 2.52 1,724.60 MWD+IFR-AK-CAZ-SC (2) 3,222.37 74.96 102.52 2,225.79 2,175.94 -472.24 1,763.27 6,003,362.08 390,060.98 2.04 1,815.38 MWD+IFR-AK-CAZ-SC (2) 3,316.27 72.96 101.07 2,251.73 2,201.88 -490.69 1,851.60 6,003,342.31 390,149.02 2.60 1,904.46 MWD+IFR-AK-CAZ-SC (2) 3,411.91 70.36 101.12 2,287.83 2,231.98 -508.16 7,940.67 6,003,323.52 390,237.82 2.72 1,993.88 MWD+IFR-AK-CAZ-SC (2) ~ 3,507.35 70.15 101.50 2,314.07 2,264.22 -525.77 2,028.76 6,003,304.58 390,325.62 0.43 2,082.43 MWD+IFR-AK-CAZ-SC (2) 3,602.82 71.31 101.45 2,345.57 2,295.72 -543.70 2,117.08 6,003,285.34 390,413.65 1.22 2,171.31 MWD+IFR-AK-CAZ-SC (2) 3,698.27 71.52 100.89 2,376.00 2,326.15 -561.23 2,205.83 6,003,266.49 390,502.13 0.60 2,260.45 MWD+IFR-AK-CAZ-SC (2) 3,794.22 72.30 100.07 2,405.79 2,355.94 -577.82 2,295.52 6,003,248.56 390,591.55 1.15 2,350.12 MWD+IFR-AK-CAZ-SC (2) ~ I 3,888.97 71.66 100.59 2,435.10 2,385.25 -593.97 2,384.16 6,003,231.08 390,679.93 0.85 2,438.67 MWD+IFR-AK-CAZ-SC (2) 3,952.26 71.80 100.37 2,454.94 2,405.09 -604.90 2,443.26 6,003,219.27 390,738.85 0.40 2,497.75 MWD+IFR-AK-CAZ-SC (2) 4,021.01 71.68 99.34 2,476.48 2,426.63 -616.08 2,507.58 6,003,207.13 390,803.00 7.43 2,561.81 MWD+IFR-AK-CAZ-SC (2) 4,065.57 77.78 98.83 2,490.67 2,440.82 -622.75 2,549.29 6,003,199.84 390,844.60 1.56 2,603.14 MWD+IFR-AK-CAZ-SC (2) 4,160.66 70.36 100.64 2,522.00 2,472.15 -637.92 2,637.78 6,003,183.34 390,932.84 1.99 2,691.19 MWD+IFR-AK-CAZ-SC (2) 4,255.46 70.73 101.96 2,553.57 2,503.72 -655.44 2,725.43 6,003,164.52 391,020.21 1.37 2,779.30 MWD+IFR-AK-CAZ-SC (2) ~ 4,350.47 71.00 102.79 2,584.72 2,534.87 -674.22 2,813.20 6,003,144.43 391,707.69 0.36 2,867.97 MWD+IFR-AK-CAZ-SC (2) ~~ 4,445.89 71.26 103.51 2,615.58 2,565.73 -694.30 2,901.23 6,003,123.04 391,195.40 1.34 - 2,957.35 MWD+IFR-AK-CAZ-SC (2) ~ 4/29/2009 2:37:20PM Page 3 COMPASS 2003.16 Build 4 2F C onocoP hillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. ' Locaf Co-ordinate Reference: Well CD3-304 Project: Western North Slope TVD References CD3-304 (36.45+13.4) @ 49.85ft (Doyon 19) Site: CD3 Fjord Pad MD Reference: CD3-304 (36.45+13.4) @ 49.85ft (Doyon 19) Well: CD3-304 North Reference: True Wellbore: CD3-304 Survey Ca lculation Method: Minimum Curvature Design: CD3-304 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°1 (°) (ft) lftl lft) Ift) (it) (ft) (°1100') (ft) Survey Tool Name 4,540.56 72.43 104.75 2,645.06 2,595.23 -716.25 2,988.45 6,003,099.74 391,282.28 1.78 3,046.66 MWD+iFR-AK-GAZ-SC (2) 4,635.30 72.30 104.84 2,673.78 2,623.93 -739.38 3,075.74 6,003,075.36 391,369.20 0.15 3,136.42 MWD+IFR-AK-CAZ-SC (2) 4,730.58 71.40 105.98 2,703.46 2,653.61 -763.43 3,163.02 6,003,050.00 391,456.10 1.48 3,226.53 MWD+IFR-AK-CAZ-SC (2) 4,825.74 70.87 106.49 2,734.23 2,684.38 -788.61 3,249.48 6,003,023.54 391,542.17 0.75 3,316.26 MWD+IFR-AK-CAZ-SC (2) 4,920.91 70.40 107.06 2,765.78 2,715.93 -814.52 3,335.44 6,002,996.34 391,627.73 0.75 3,405.80 MWD+IFR-AK-CAZ-SC (2) 5,016.30 71.53 106.83 2,796.90 2,747.05 -840.80 3,421.70 6,002,968.78 391,713.57 1.21 3,495.75 MWD+IFR-AK-CAZ-SC (2) j 5,111.19 72.11 105.70 2,826.50 2,776.65 -866.05 3,508.25 6,002,942.24 391,799.72 1.29 3,585.59 MWD+IFR-AK-CAZ-SC (2) I 5,206.06 72.61 105.77 2,855.25 2,805.40 -890.57 3,595.27 6,002,916.42 391,886.36 0.53 3,675.62 MWD+IFR-AK-CAZ-SC (2) i 5,301.25 72.55 105.16 2,883.75 2,833.90 -914.79 3,682.80 6,002,890.90 391,973.52 0.61 3,766.02 MWD+IFR-AK-CAZ-SC (2) 5,396.90 72.49 103.89 2,912.48 2,862.63 -937.67 3,771.12 6,002,866.70 392,061.47 1.27 3,856.67 MWD+IFR-AK-CAZ-SC (2) 5,492.07 77.76 101.93 2,941.68 2,891.83 -957.89 3,859.34 6,002,845.16 392,149.38 2.77 3,946.28 MWD+IFR-AK-CAZ-SC (2) 5,586.07 72.29 100.87 2,970.70 2,920.85 -975.58 3,947.04 6,002,826.17 392,236.80 1.21 4,034.50 MWD+IFR-AK-CAZ-SC (2) 5,681.64 71.97 99.77 3,000.03 2,950.18 -991.87 4,036.53 6,002,808.54 392,326.02 1.15 4,123.88 MWD+IFR-AK-CAZ-SC (2) 5,777.48 72.29 99.52 3,029.44 2,979.59 -1,007.75 4,126.46 6,002,791.91 392,415.70 0.42 4,213.31 MWD+IFR-AK-CAZ-SC (2) 5,872.10 73.45 101.44 3,057.31 3,007.46 -1,023.60 4,215.36 6,002,774.14 392,504.34 2.29 4,302.21 MWD+IFR-AK-CAZ-SC (2) 5,967.01 72.92 100.96 3,084.77 3,034.92 -1,041.25 4,304.48 6,002,755.16 392,593.18 0.74 4,391.73 MWD+IFR-AK-CAZ-SC (2) I 6,062.10 71.96 100.95 3,113.46 3,063.61 -1,058.48 4,393.49 6,002,736.60 392,681.91 1.01 4,481.00 MWD+IFR-AK-CAZ-SC (2) i 6,157.26 71.57 100.58 3,143.23 3,093.38 -7,075.36 4,482.28 6,002,718.40 392,770.43 0.55 4,569.94 MWD+IFR-AK-CAZ-SC (2) 6,252.53 71.90 100.88 3,173.09 3,123.24 -1,092.21 4,577.77 6,002,700.23 392,859.05 0.46 4,658.96 MWD+IFR-AK-CAZ-SC (2) 6,347.67 72.67 101.12 3,202.04 3,152.19 -1,109.50 4,660.13 6,002,681.61 392,947.74 0.84 4,748.21 MWD+IFR-AK-CAZ-SC (2) 6,442.57 73.06 100.46 3,230.00 3,180.15 -1,126.48 4,749.21 6,002,663.30 393,036.55 0.78 4,837.47 MWD+IFR-AK-CAZ-SC (2) 6,537.38 72.28 101.31 3,258.24 3,208.39 -1,143.56 4,838.09 6,002,644.88 393,125.15 1.19 4,926.56 MWD+IFR-AK-CAZ-SC (2) 6,632.47 72.37 102.13 3,287.11 3,237.26 -1,161.97 4,926.80 6,002,625.16 393,213.57 0.83 5,015.98 MWD+IFR-AK-CAZ-SC (2) 6,727.33 72.04 102.91 3,316.10 3,266.25 -1,181.55 5,014.97 6,002,604.26 393,301.43 0.86 5,105.31 MWD+IFR-AK-CAZ-SC (2) 6,822.25 71.58 103.22 3,345.74 3,295.89 -1,201.93 5,102.82 6,002,582.57 393,388.95 0.58 5,194.62 MWD+IFR-AK-CAZ-SC (2) 6,917.41 71.45 104.18 3,375.91 3,326.06 -7,223.31 5,190.50 6,002,559.89 393,476.30 0.97 5,284.14 MWD+IFR-AK-CAZ-SC (2) 7,012.50 72.36 103.87 3,405.44 3,355.59 -1,245.21 5,278.19 6,002,536.67 393,563.64 1.07 5,373.86 MWD+IFR-AK-CAZ-SC (2) 7,107.51 72.42 704.02 3,434.19 3,384.34 -1,267.03 5,366.08 6,002,513.54 393,651.19 0.16 5,463.73 MWD+IFR-AK-CAZ-SC (2) 7,202.39 72.67 104.02 3,462.69 3,412.84 -1,288.96 5,453.88 6,002,490.37 393,738.64 0.20 5,553.56 MWD+IFR-AK-CAZ-SC (2) 7,297.89 72.36 101.41 3,491.44 3,441.59 -1,309.00 5,542.71 6,002,468.94 393,827.16 2.62 5,643.67 MWD+IFR-AK-CAZ-SC (2) j 7,392.69 72.23 102.12 3,520.27 3,470.42 -1,327.42 5,631.12 6,002,449.20 393,915.28 0.73 5,732.81 MWD+IFR-AK-CAZ-SC (2) 7,487.88 72.75 102.30 3,548.91 3,499.06 -7,346.61 5,719.85 6,002,428.68 394,003.70 0.58 5,822.52 MWD+IFR-AK-CAZ-SC (2) 7,582.91 72.69 101.55 3,577.14 3,527.29 -1,365.36 5,808.63 6,002,408.61 394,092.18 0.76 5,912.12 MWD+IFR-AK-CAZ-SC (2) 7,678.12 72.73 101.06 3,605.43 3,555.58 -7,383.19 5,897.77 6,002,389.46 394,181.04 0.49 6,001.73 MWD+IFR-AK-CAZ-SC (2) 7,771.73 71.82 100.83 3,633.93 3,584.08 -1,400.12 5,985.31 6,002,371.22 394,268.31 1.00 6,089.53 MWD+IFR-AK-CAZ-SC (2) 7,868.40 71.91 99.57 3,664.02 3,614.17 -1,416.38 6,075.73 6,002,353.60 394,358.46 1.24 6,179.77 MWD+IFR-AK-CAZ-SC (2) i 7,963.32 71.24 100.03 3,694.03 3,644.18 -1,431.71 6,164.47 6,002,336.95 394,446.96 0.84 6,268.11 MWD+IFR-AK-CAZ-SC (2) 8,058.42 71.00 100.24 3,724.80 3,674.95 -1,447.54 6,253.05 6,002,319.79 394,535.28 0.33 6,356.48 MWD+IFR-AK-CAZ-SC (2) 8,153.64 70.08 101.25 3,756.52 3,706.67 -1,464.28 6,341.25 6,002,301.74 394,623.22 1.39 6,444.82 MWD+IFR-AK-CAZ-SC (2) 8,248.69 69.68 101.74 3,789.22 3,739.37 -1,482.07 6,428.71 6,002,282.65 394,710.39 0.64 6,532.84 MWD+IFR-AK-CAZ-SC (2) 4/29/2009 2:37:20PM Page 4 COMPASS 2003.16 Build 42F C onocoPhillips Defi nitive Surrey Report Company: ConocoPhillips (Alaska) Ina Local Co-ordinate Reference: Well CD3-304 Project: Western North Slope TVD Reference: CD3-304 (36.45+13.4) @ 49.85ft (Doyon 19) Site: CD3 Fjord Pad MD Refere nce: CD3-304 (36.45+13.4) @ 49.85ft (Doyon 19) Well: CD3-304 North Reference: True W@Ilbore: CD3-304 Survey Calculation Method: Minimum Curvature design: CD3-304 Database: CPAI EDM Production Survey i Map Map Vertical MD Inc Azi TVD NDSS +N/-S +E/-W Northing Easting DLS Section Iftl (~) l~) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 8,343.74 70.19 102.48 3,821.83 3,771.98 -1,500.80 6,516.00 6,002,262.62 394,791.39 0.91 6,62L05 MWp+iFR-AK-CAZ-SC (2) 8,438.91 71.38 103.19 3,853.15 3,803.30 -1,520.76 6,603.62 6,002,241.35 394,884.69 1.44 6,710.01 MWD+IFR-AK-CAZ-SC (2) 8,533.54 72.42 101.99 3,882.55 3,832.70 -1,540.36 6,691.40 6,002,220.43 394,972.16 1.63 6,798.98 MWD+IFR-AK-CAZ-SC (2) i 8,628.98 71.85 102.11 3,911.83 3,861.98 -1,559.33 6,780.24 6,002,200.75 395,060.70 0.61 6,888.71 MWD+IFR-AK-CAZ-SC (2) i 8,723.57 71.97 102.73 3,941.20 3,891.35 -1,578.67 6,868.05 6,002,179.50 395,148.20 0.64 6,977.62 MWD+IFR-AK-CAZ-SC (2) i 8,818.73 72.55 102.68 3,970.19 3,920.34 -1,598.60 6,956.47 6,002,158.24 395,236.30 0.61 7,067.31 MWD+IFR-AK-CAZ-SC (2) 8,913.98 72.22 103.23 3,999.02 3,949.17 -1,618.95 7,044.94 6,002,136.57 395,324.45 0.65 7,157.20 MWD+IFR-AK-CAZ-SC (2) 9,008.98 71.45 103.25 4,028.64 3,978.79 -1,639.63 7,132.80 6,002,114.59 395,411.99 0.81 7,246.64 MWD+IFR-AK-CAZ-SC (2) 9,104.40 72.36 103.47 4,058.27 4,008.42 -1,660.58 7,221.05 6,002,092.31 395,499.91 0.98 7,336.53 MWD+IFR-AK-CAZ-SC (2) 9,198.99 71.83 102.81 4,087.35 4,037.50 -1,681.05 7,308.70 6,002,070.54 395,587.23 0.87 7,425.69 MWD+IFR-AK-CAZ-SC (2) 9,294.02 72.36 102.34 4,116.57 4,066.72 -1,700.73 7,396.96 6,002,049.54 395,675.18 0.73 7,515.14 MWD+IFR-AK-CAZ-SC (2) 9,389.35 72.49 102.58 4,145.35 4,095.50 -1,720.34 7,485.70 6,002,028.61 395,763.61 0.28 7,605.02 MWD+IFR-AK-CAZ-SC (2) 9,484.17 72.55 102.81 4,173.84 4,123.99 -1,740.22 7,573.93 6,002,007.42 395,851.52 0.24 7,694.51 MWD+IFR-AK-CAZ-SC (2) 9,578.55 71.70 102.64 4,202.80 4,152.95 -1,760.00 7,661.55 6,007,986.32 395,938.83 0.92 7,783.40 MWD+IFR-AK-CAZ-SC (2) 9,674.74 71.77 101.95 4,232.95 4,183.10 -1,779.45 7,750.79 6,001,965.54 396,027.77 0.69 7,873.69 MWD+IFR-AK-CAZ-SC (2) 9,769.65 71.91 101.74 4,262.53 4,212.68 -1,797.96 7,839.06 6,001,945.71 396,115.73 0.26 7,962.72 MWD+IFR-AK-CAZ-SC (2) 9,864.92 72.36 101.39 4,291.76 4,241.91 -1,816.14 7,927.89 6,001,926.21 396,204.28 0.59 8,052.17 MWD+IFR-AK-CAZ-SC (2) 9,960.07 72.22 102.02 4,320.70 4,270.85 -1,834.53 8,016.65 6,001,906.50 396,292.74 0.65 8,141.62 MWD+IFR-AK-CAZ-SC (2) 10,055.10 72.74 101.44 4,349.31 4,299.46 -1,852.95 8,105.37 6,001,886.75 396,381.18 0.80 I 8,231.06 MWD+IFR-AK-CAZ-SC (2) 10,150.61 72.35 101.01 4,377.96 4,328.11 -1,870.69 8,194.74 6,001,867.68 396,470.26 0.59 8,320.85 MWD+IFR-AK-CAZ-SC (2) ~~ 10,246.08 77.20 101.20 4,407.82 4,357.97 -1,888.15 8,283.72 6,001,848.89 396,558.97 1.22 8,410.18 MWD+IFR-AK-CAZ-SC (2) 10,341.40 70.98 102.18 4,438.71 4,388.86 -1,906.43 8,372.03 6,001,829.30 396,646.98 1.00 8,499.16 MWD+IFR-AK-CAZ-SC (2) 10,436.39 71.56 104.00 4,469.21 4,419.36 -1,926.80 8,459.64 6,001,807.62 396,734.27 1.91 8,588.26 MWD+IFR-AK-CAZ-SC (2) 10,531.52 72.37 104.82 4,498.67 4,448.82 -1,949.31 8,547.25 6,001,783.80 396,821.53 1.18 8,678.12 MWD+IFR-AK-CAZ-SC (2) 10,626.93 72.55 103.82 4,527.42 4,477.57 -7,971.81 8,635.40 6,001,759.99 396,909.32 1.02 8,768.47 MWD+IFR-AK-CAZ-SC (2) 10,721.97 72.55 103.64 4,555.92 4,506.07 -1,993.33 8,723.47 6,001,737.15 396,997.06 0.18 8,858.41 MWD+IFR-AK-CAZ-SC (2) 10,817.15 72.76 103.16 4,584.30 4,534.45 -2,014.39 8,811.85 6,001,714.78 397,085.10 0.53 8,948.46 MWD+IFR-AK-CAZ-SC (2) 10,912.35 71.58 102.34 4,613.45 4,563.60 -2,034.39 8,900.24 6,001,693.46 397,173.17 1.49 9,038.75 MWD+IFR-AK-CAZ-SC (2) 11,007.34 72.04 102.02 4,643.10 4,593.25 -2,053.43 8,988.45 6,001,673.10 397,261.08 0.58 9,727.33 MWD+IFR-AK-CAZ-SC (2) 11,102.85 71.91 102.48 4,672.65 4,622.80 -2,072.70 9,077.21 6,001,652.51 397,349.53 0.48 9,217.09 MWD+IFR-AK-CAZ-SC (2) 11,197.48 72.04 103.11 4,701.94 4,652.09 -2,092.63 9,764.96 6,001,631.27 397,436.97 0.65 9,306.16 MWD+IFR-AK-CAZ-SC (2) 11,292.42 72.04 102.98 4,731.21 4,681.36 -2,113.01 9,252.94 6,001,609.57 397,524.63 0.13 9,395.60 MWD+IFR-AK-CAZ-SC (2) 17,387.55 72.36 102.41 4,760.29 4,710.44 -2,132.92 9,341.30 6,001,588.35 397,612.67 0.66 9,485.23 MWD+IFR-AK-CAZ-SC (2) 11,482.71 72.55 102.64 4,788.98 4,739.13 -2,152.59 9,429.88 6,001,567.35 397,700.94 0.30 9,574.97 MWD+IFR-AK-CAZ-SC (2) 11,577.74 71.63 102.48 4,818.20 4,768.35 -2,172.26 9,518.14 6,001,546.37 397,788.88 0.98 9,664.41 MWD+IFR-AK-CAZ-SC (2) 11,672.95 71.65 102.47 4,848.19 4,798.34 -2,191.78 9,606.37 6,001,525.54 397,876.80 0.02 9,753.78 MWD+IFR-AK-CAZ-SC (2) 11,768.06 72.10 102.59 4,877.78 4,827.93 -2,211.39 9,694.60 6,001,504.61 397,964.73 0.49 9,843.18 MWD+IFR-AK-CAZ-SC (2) 11,863.46 72.62 103.38 4,906.69 4,856.84 -2,231.82 9,783.19 6,001,482.86 398,053.00 0.96 9,933.21 MWD+IFR-AK-CAZ-SC (2) 11,958.37 72.10 103.52 4,935.45 4,885.60 -2,252.85 9,871.16 6,001,460.51 398,140.63 0.57 10,022.87 MWD+IFR-AK-CAZ-SC (2) 12,053.71 71.72 103.49 4,965.05 4,915.20 -2,274.02 9,959.28 6,001,438.03 398,228.42 0.40 10,112.72 MWD+IFR-AK-CAZ-SC (2) 4/29/2009 2:37:20PM Page 5 COMPASS 2003.16 Build 42F Company: ConocoPhillips(Alaska) Inc Project: Western North Slope Site: CD3 Fjord Pad Well: CD3-304 Wellbore: CD3-304 Design: CD3-304 Survey ConocoPhillips Definitive Survey Report i Local Co-ordinate Reference: Well CD3-304 TVD Reference: CD3-304 (36.45+13.4) @ 49.85ft (Doyon 19) MD Reference: CD3-304 (36.45+13.4) @ 49.85ft (Doyon 19) North Reference: True Survey Calculation Method: Minimum Curvature Database: CPAI EDM Production Map MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Iftl (°) (°) (ftl (ft) (ft) Ift) (ft) 12,148.85 72.16 103.04 4,994.55 4,944.70 -2,294.77 10,047.32 6,001,415.96 12,244.10 72.03 102.39 5,023.83 4,973.98 -2,314.72 10,135.73 6,001,394.70 12,339.41 72.68 100.82 5,052.72 5,002.87 -2,332.99 10,224.70 6,001,375.10 12,434.37 71.96 101.18 5,081.56 5,031.71 -2,350.25 10,313.51 6,001,356.51 12,529.39 71.30 101.71 5,111.51 5,061.66 -2,368.15 10,401.89 6,001,337.30 12,624.35 73.13 101.76 5,140.51 5,090.66 -2,386.54 10,490.42 6,001,317.59 12,719.66 72.87 100.89 5,168.38 5,118.53 -2,404.43 10,579.79 6,001,298.36 12,814.86 70.73 101.81 5,198.11 5,148.26 -2,422.23 10,668.46 6,001,279.24 12,910.08 71.38 102.52 5,229.03 5,179.18 -2,441.21 10,756.49 6,001,258.95 13,005.22 71.20 102.55 5,259.55 5,209.70 -2,460.76 10,844.46 6,001,238.08 13,100.77 71.30 103.61 5,290.26 5,240.41 -2,481.24 10,932.59 6,001,216.29 13,195.76 72.30 103.41 5,319.93 5,270.08 -2,502.32 11,020.33 6,001,193.90 13,290.04 72.36 102.50 5,348.55 5,298.70 -2,522.46 11,107.87 6,001,172.46 13,385.42 71.96 101.42 5,377.77 5,327.92 -2,541.28 11,196.69 6,001,152.32 13,479.08 71.76 101.28 5,406.93 5,357.08 -2,558.79 11,283.96 6,001,133.50 13,571.47 72.17 102.42 5,435.53 5,385.68 -2,576.83 11,369.93 6,001,114.17 13,666.01 71.78 102.12 5,464.79 5,414.94 -2,595.94 11,457.78 6,001,093.76 13,757.58 71.90 102.62 5,493.33 5,443.48 -2,614.58 11,542.77 6,001,073.85 13,850.97 71.46 104.25 5,522.68 5,472.83 -2,635.17 11,629.00 6,001,051.97 13,942.28 72.42 104.51 5,550.99 5,501.14 -2,656.73 11,713.09 6,001,029.15 14,034.85 72.41 104.43 5,578.96 5,529.11 -2,678.78 11,798.53 6,001,005.83 14,129.07 71.26 103.51 5,608.33 5,558.48 -2,700.40 11,885.40 6,000,982.92 14,223.25 71.46 102.24 5,638.43 5,588.58 -2,720.28 11,972.40 6,000,961.74 14,316.55 71.71 102.85 5,667.91 5,618.06 -2,739.51 12,058.81 6,000,941.22 14,410.52 72.22 103.40 5,697.00 5,647.15 -2,759.80 12,145.82 6,000,919.63 14,503.63 71.78 102.38 5,725.77 5,675.92 -2,779.55 12,232.14 6,000,898.59 14,597.47 71.64 102.44 5,755.22 5,705.37 -2,798.70 12,319.16 6,000,878.15 14,690.45 72.08 102.00 5,784.17 5,734.32 -2,817.40 12,405.52 6,000,858.15 14,783.47 71.78 101.51 5,813.02 5,763.17 -2,835.42 12,492.09 6,000,838.85 14,876.88 71.91 101.94 5,842.73 5,792.28 -2,853.46 12,579.00 6,000,819.51 14,970.33 72.11 102.27 5,870.99 5,821.14 -2,872.10 12,665.91 6,000,799.58 15,062.55 71.77 102.18 5,899.58 5,849.73 -2,890.66 12,751.60 6,000,779.73 15,155.52 71.84 102.23 5,928.61 5,878.76 -2,909.33 12,837.92 6,000,759.77 15,248.88 71.19 102.17 5,958.21 5,908.36 -2,928.05 12,924.46 6,000,739.77 15,342.69 71.19 103.49 5,988.46 5,938.61 -2,947.76 13,011.04 6,000,718.76 15,435.36 71.37 103.44 6,018.20 5,968.35 -2,968.20 13,096.40 6,000,697.05 15,528.62 72.17 103.31 6,047.38 5,997.53 -2,988.69 13,182.58 6,000,675.28 15,618.17 71.76 102.93 6,075.10 6,025.25 -3,008.02 13,265.50 6,000,654.71 15,710.00 71.96 103.17 6,103.69 6,053.84 -3,027.72 13,350.51 6,000,633.74 15,801.22 72.81 103.48 6,131.30 6,081.45 -3,047.76 13,435.12 6,000,612.44 Map Vertical Fasting DLS Section (ft) (°/100') (ft) Survey Tool Name 398,316.13 0.65 10,202.35 MWD+IFR-AK-GAZ-SC (2) 398,404.23 0.66 10,292.04 MWD+IFR-AK-CAZ-SC (2) 398,492.90 1.71 10,381.65 MWD+IFR-AK-CAZ-SC (2) 398,581.44 0.84 10,470.75 MWD+IFR-AK-CAZ-SC (2) 398,669.54 0.87 10,559.67 MWD+IFR-AK-CAZ-SC (2) 398,757.77 1.93 10,648.91 MWD+IFR-AK-CAZ-SC (2) 398,846.85 0.91 10,738.76 MWD+IFR-AK-CAZ-SC (2) 398,935.23 2.43 10,827.91 MWD+IFR-AK-CAZ-SC (2) 399,022.97 0.98 10,916.90 MWD+IFR-AK-CAZ-SC (2) 399,110.63 0.19 11,006.03 MWD+IFR-AK-CAZ-SC (2) 399,198.43 1.06 11,095.65 MWD+IFR-AK-CAZ-SC (2) 399,285.84 1.07 11,185.11 MWD+IFR-AK-CAZ-SC (2) 399,373.06 0.92 11,274.06 MWD+IFR-AK-CAZ-SC (2) 399,461.59 1.16 11,363.73 MWD+IFR-AK-CAZ-SC (2) 399,548.57 0.26 11,451.47 MWD+IFR-AK-CAZ-SC (2) 399,634.26 1.25 11,538.20 MWD+IFR-AK-CAZ-SC (2) 399,721.80 0.51 11,627.06 MWD+IFR-AK-CAZ-SC (2) 399,806.50 0.54 11,713.08 MWD+IFR-AK-CAZ-SC (2) 399,892.40 1.72 11,800.96 MWD+IFR-AK-CAZ-SC (2) 399,976.15 1.09 11,887.20 MWD+IFR-AK-CAZ-SC (2) 400,061.25 0.08 11,974.87 MWD+IFR-AK-CAZ-SC (2) 400,147.78 1.53 12,063.72 MWD+IFR-AK-CAZ-SC (2) 400,234.46 1.30 12,152.06 MWD+IFR-AK-CAZ-SC (2) 400,320.56 0.68 12,239.62 MWD+IFR-AK-CAZ-SC (2) 400,407.26 0.78 12,328.13 MWD+IFR-AK-CAZ-SC (2) 400,493.27 1.14 12,415.79 MWD+IFR-AK-CAZ-SC (2) 400,579.98 0.16 12,503.89 MWD+IFR-AK-CAZ-SC (2) 400,666.04 0.65 12,591.22 MWD+IFR-AK-CAZ-SC (2) 400,752.33 0.60 12,678.50 MWD+IFR-AK-CAZ-SC (2) 400,838.95 0.46 12,766.10 MWD+IFR-AK-CAZ-SC (2) 400,925.56 0.40 12,853.91 MWD+IFR-AK-CAZ-SC (2) 401,010.95 0.38 12,940.56 MWD+IFR-AK-CAZ-SC (2) 401,096.98 0.09 13,027.84 MWD+IFR-AK-CAZ-SC (2) 401,183.23 0.70 13,115.34 MWD+IFR-AK-CAZ-SC (2) 401,269.50 1.33 13,203.24 MWD+IFR-AK-CAZ-SC (2) 401,354.53 0.20 13,290.25 MWD+IFR-AK-CAZ-SC (2) 401,440.38 0.87 13,378.05 MWD+IFR-AK-CAZ-SC (2) 401,523.00 0.61 13,462.39 MWD+IFR-AK-CAZ-SC (2) 401,607.70 0.33 13,548.82 MWD+IFR-AK-CAZ-SC (2) 401,691.99 0.99 13,634.98 MWD+IFR-AK-CAZ-SC (2) 4/29/2009 2:37:20PM Page 6 COMPASS 2003.16 Burtd 42F ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well CD3-304 Project: Western North Slope TVD Reference: CD3-304 (36.45+13.4) @ 49.85ft (Doyon 19) Site: CD3 Fjord Pad MD Reference: CD3-304 (36.45+13.4) @ 49.85ft (Doyon 19) Well: CD3-304 North Reference: True Wellborn: CD3-304 Survey Calculation Method: Minimum Curvature Design: CD3-304 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi ND NDSS +N/-S +E/-W Northing Fasting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 15,894.61 71.36 102.93 6,160.02 6,110.17 -3,068.06 13,521.62 6,000,590.85 401,778.18 1.65 13,723.02 MWD+IFR-AK-CAZ-SC (2) 15,988.09 72.56 102.03 6,188.97 6,139.12 -3,087.27 13,608.41 6,000,570.35 401,864.65 1.58 13,810.92 MWD+IFR-AK-CAZ-SC (2) 16,081.43 72.87 101.24 6,216.71 6,166.86 -3,105.24 13,695.70 6,000,551.07 401,951.66 0.87 13,898.86 MWD+IFR-AK-CAZ-SC (2) 16,173.57 71.84 100.43 6,244.63 6,194.78 -3,121.75 13,781.94 6,000,533.28 402,037.63 1.40 13,985.28 MWD+IFR-AK-CAZ-SC (2) 16,268.18 71.52 100.14 6,274.37 6,224.52 -3,137.79 13,870.31 6,000,515.92 402,125.75 0.45 14,073.53 MWD+IFR-AK-CAZ-SC (2) 16,362.20 71.71 100.07 6,304.03 6,254.18 -3,153.44 13,958.14 6,000,498.96 402,213.33 0.21 14,161.14 MWD+IFR-AK-CAZ-SC (2) 16,455.15 72.15 99.87 6,332.86 6,283.01 -3,168.74 14,045.18 6,000,482.36 402,300.12 0.52 14,247.88 MWD+IFR-AK-CAZ-SC (2) 16,548.36 72.16 99.84 6,361.42 6,311.57 -3,183.92 14,132.59 6,000,465.87 402,387.29 0.03 14,334.93 MWD+IFR-AK-CAZ-SC (2) 16,641.69 71.66 100.45 6,390.40 6,340.55 -3,199.55 14,219.92 6,000,448.94 402,474.37 0.82 14,422.06 MWD+IFR-AK-CAZ-SC (2) 16,735.01 71.91 101.37 6,419.57 6,369.72 -3,216.33 14,306.96 6,000,430.86 402,561.14 0.97 14,509.33 MWD+IFR-AK-CAZ-SC (2) 16,828.53 72.61 103.05 6,448.07 6,398.22 -3,235.17 14,394.01 6,000,410.72 402,647.89 1.87 14,597.35 MWD+IFR-AK-CAZ-SC (2) 16,921.19 72.21 103.01 6,476.07 6,426.22 -3,255.08 14,480.07 6,000,389.53 402,733.63 0.43 14,684.82 MWD+IFR-AK-CAZ-SC (2) 17,012.96 71.77 104.35 6,504.45 6,454.60 -3,275.72 14,564.86 6,000,367.62 402,818.10 1.47 14,771.38 MWD+IFR-AK-CAZ-SC (2) 17,106.36 72.02 105.12 6,533.47 6,483.62 -3,298.30 14,650.72 6,000,343.76 402,903.60 0.83 14,859.63 MWD+IFR-AK-CAZ-SC (2) 17,199.65 72.42 105.31 6,561.96 6,512.11 -3,321.61 14,736.44 6,000,319.17 402,988.96 0.47 14,948.01 MWD+IFR-AK-CAZ-SC (2) 17,290.97 72.67 104.48 6,589.35 6,539.50 -3,344.01 14,820.63 6,000,295.52 403,072.79 0.91 15,034.63 MWD+IFR-AK-CAZ-SC (2) 17,384.01 70.86 103.32 6,618.47 6,568.62 -3,365.24 14,906.40 6,000,273.01 403,158.23 2.28 15,122.32 MWD+IFR-AK-CAZ-SC (2) 17,478.16 68.49 103.46 6,651.17 6,601.32 -3,385.68 14,992.28 6,000,251.29 403,243.79 2.52 15,209.82 MWD+IFR-AK-CAZ-SC (2) 17,571.60 66.45 103.29 6,686.97 6,637.12 -3,405.65 15,076.24 6,000,230.07 403,327.44 2.19 15,295.36 MWD+IFR-AK-CAZ-SC (2) 17,664.51 64.94 103.30 6,725.21 6,675.36 -3,425.12 15,158.65 6,000,209.37 403,409.53 1.63 15,379.27 MWD+IFR-AK-CAZ-SC (2) 17,758.35 62.17 103.83 6,766.99 6,717.14 -3,444.82 15,240.32 6,000,188.45 403,490.89 2.99 15,462.57 MWD+IFR-AK-CAZ-SC (2) 17,812.08 62.17 103.72 6,792.08 6,742.23 -3,456.13 15,286.47 6,000,176.45 403,536.86 0.18 15,509.71 MWD+IFR-AK-CAZ-SC (2) ' 17,843.00 62.17 103.72 6,806.51 6,756.66 -3,462.62 15,313.03 6,000,169.57 403,563.32 0.00 15,536.84 PROJECTED to TD 4/29!2009 2:37:20PM Page 7 COMPASS 2003.16 Burld 42F Concyctii~hillips ,' A rt;~.. it CONDUCTOR, 36-110 WRDP, 1,60] - SSSVS,1,60] ~ - - GAS LIFT, _ 2,497 SURFACE, 36-3,997 GAS LIFT. 8.700 IPE RF, 14,408-14 440 GAS LIFT, 14,971 PACKER, 16,086 WNS (bore APUU WI Feld Name 501032059800 FIORD KUPP lmenl -- H2S iV: WRDP CD3-304 Last Tag' -`_ ~ (Rev Reason: PERF, set WRDP, GLV C/O i ImosDOr ~ 5/17/2009 . Casin Strin s C sing Descnption String 0... String ID . .. Top (ftK6) Set Depth (f... Set Depth (ND) ... String Wt... Strmg ... '.String Top Thrd CONDUCTOR 16 15.250 36.0 114.0 114.0 62.50 H-40 Casing Description String 0... Skiing ID . .. Top (ftK8) Set Depth (f_. Set Depth (ND) ... String Wt... Str ng ... 'String Top Thrd SURFACE 9518 8.835 36.2 3,597.0 2,4690 40.00 L80 IBT<. Casing Description String 0... (String ID . .. Top (kK6) Set Depth (f... Set Depth (ND) ... String Wt... Str ng String Top Thrd PRODUCTION 7 6.276 344 17,832.0 6,8014 26.00 L80 BTCM ~ Strings Tubing - . _ . . Tubing Description String 0... String ID ... Top (ftK6) Set Depth (f... Set Depth (ND) ... String Wt... Strmg ... String Top Thrd - TUBING 31/2 2.992 31.0 17,252.0 6,578.2 9.30 L-80 EUE Gom letion De tails Top Depth (ND) Top Intl Top (ftK6) (ftK6) (°) Item D scription _ _ _ Comment ID (in) 31.0 31.0 -0.04 HANGER FMC Tubing Hanger 4.500 1,607.2 1,515.4 44.97 SSSVS SSSV Bal-O Landing NIPPLE 3.813 1,663.9 1,556 0 46.11 ~ XO - Retlucing XO -4 1/2" IBTM Box by 3 1/2"EUE Pin 2.992 15,030.6 5,889.6 71.751 SLEEVE Baker 3 1f2" CMU Sliding Sleeve W2.813" DS Profile (Closed) 2.813 15,085.5 5,906.8 71.79 ~ I,PACKER Premier Packer 7" X 3 1/2" (Baker) 5.98 OD 2,87 ID 2.870 75,143.6 5,924.9 71.83 NIPPLE Camco 2.75" D Nipple 2.750 YBROraL005 8 SIOIS Shot '~ Top (TVD) Btm (TVD) Dens ToP (ftK6)' Bim (ftK8) (ftK8) (ftK6) Zone Dale (ski- Type Comment 14,408 14,440 5,696.2 5,706.0 4/30!2009 6.0 (PERF HES 2.0"Scalloped Guns, 60 deg phase, millenium charges - _,..,, landrel Details --- - Top Depth T p PoA _ _- n I OD Valve Latch Sae TRO R n '.n Top LftK6) ( ) (°) 'i Model Make (in) Serv TYPe - TYp ~ ('^) (PS) Run D to __ Com... -_ '-' 1 2,497.1 2 004.7 69.75 CAMCO' KBG-2-1R 1 GAS LIFT DMY BK ' -0.000 0 0 4/28/2009 - 2 8,700.3 3,934.0 71.94 CAMCO KBG-2-1R 1 GAS LIFT ,DMY BK 0000 00 4/25/2009 3 14.971.2 5.870.9 71.70 CAMCO~KBG-2-1R 1 GAS LIFT 'iOV BK 0.250 0.0 4!28/2009 P RODUCTION,_ ___ __ 34-1],632 TD. 1],893 l~ • ConocoPh~lhps Time Log & Summary Wellview web Reporting Report Well Name: CD3-304 Rig Name: DOYON 19 Job Type: DRILLING ORIGINAL Rig Accept: 4/8/2009 1:00:00 PM Rig Release: 4/27/2009 12:00:00 AM Time Logs __ Dat From To Dur _ S. Depth E Depth __ Phase Code Subcod __ e T Comment 4/08/2009 _ 2a hr summary Moved rig from CD3-117 & RU, Accepted Rig @ 13:00 hrs, PU & stood back 35 stds of 5" DP, cut & slip drlg line. MU 12 1/4" BHA#1 03:30 04:45 1.25 0 0 MIRU MOVE DMOB P Prep rig for move, blew down water and steam lines, disconnected service lines and took ri off hi hline. 04:45 08:00 3.25 0 0 MIRU MOVE TRNS P PJSM, moved motors and pits, skidded rig floor and moved sub base off CD3-117 and moved to CD3-304. 08:00 10:00 2.00 0 0 MIRU MOVE TRNS P Spot and level sub base over well, set in its and motor com lex's. 10:00 13:00 3.00 0 0 MIRU MOVE RURD P RU water and steam lines, connected service loops and put rig on highline. ACCEPTED RIG @ h . 13:00 14:15 1.25 0 0 MIRU MOVE NUND P NU riser and flowline. 14:15 14:45 0.50 0 0 MIRU MOVE RURD P Installed mousehole, RU to PU 5" DP via the mousehole. 14:45 15:00 0.25 0 0 MIRU MOVE SFTY P Held PJSM on PU 5" DP via the mousehole and standin back. 15:00 19:30 4.50 0 0 MIRU MOVE PULD P PU and stood back 35 stds of 5" DP and 1 std of 8" DC's. Took on spud mud. 19:30 20:45 1.25 0 0 MIRU RIGMNT SLPC P PJSM then cut and slip 60' of drlg line and serviced ri . 20:45 23:30 2.75 0 65 SURFAt DRILL PULD P MU 12 1/4 BHA #1 RIH to 65', MU Bit #1 on 8" motor with ABI and 1.83 deg bend, MWD and uploaded MWD and RU S er 's G ro. 23:30 00:00 0.50 65 65 SURFA( DRILL OTHR P Filled conductor and riser checking for leaks, pressure tested mud line to 3,000 si. 4/09/2009 Drilled 12 1/4" hole from 114' to 2,039' 00:00 00:30 0.50 65 114 SURFA( DRILL PULD P PJSM - MU stand of flex collars - wash down to 114' 450 gpm / 590 psi / 40 r m 1 Payer 1 of 9~4 r Time Logs __ ~_ __ ! Date From _To Dur S. Depth E. De th Phase Code Subcode T_ Comment 00:30 12:00 11.50 114 805 SURFA( DRILL DDRL P Drill 12 1/4" Hole w/ Motor f/ 114' - 805' MD/799' TVD (691') Taking E-Line Gyros e/ Stand ADT 5.53, AST 2.79, ART 2.74 WOB 15K Torque On/Off 5,500/4,500 @ 60 RPM 550 GPM @ 1310 Psi P/U 115, S/O 115, Rot 112 Took 8 Gyro surveys with last Gyro surve at 724'. 12:00 00:00 12.00 805 2,039 SURFA( DRILL DDRL P Directionally drilled 12 1/4" hole from 805' to 2,039' MD/1,797' TVD (1,234'). ART 4.31 hrs, AST 3.09 hrs, ADT 7.4 hrs. 15-20K wob, 550 gpm, 1,600 psi, 60 rpm's, off btm torque 6K ft-Ibs, on btm 7,500 ft-Ibs. Rot wt 127K, u wt 137K, so wt 123K. 4/10/2009 Drilled 12 1/4" hole from 2,039' to 3,588' 00:00 08:30 8.50 2,039 2,799 SURFA( DRILL DDRL P Directionally drilled 12 1/4" hole from 2,039' to 2,799' MD/ 2080' TVD (719'). ART 4.31 hrs, AST 3.09 hrs, ADT 5.80 hrs. 15-20K wob, 600 gpm, 2,000 psi, 60 rpm's, off btm torque 7K ft-Ibs, on btm 9,500 ft-Ibs. Rot wt 125K, u wt 137K, so wt 114K. 08:30 09:00 0.50 2,799 2,799 SURFA( RIGMNT SVRG T Service rig - Drawworks & Iron rou hneck 09:00 09:30 0.50 2,799 2,799 SURFA( RIGMNT RGRP T Complete repair to #2 shaker 09:30 12:00 2.50 2,799 2,906 SURFA( DRILL DDRL P Directionally drilled 12 1/4" hole from 2,799' to 2,906' MD/ 2,126' TVD (107'). ADT 1.0 hrs, AST 0.34 hrs, ART 0.66 hrs. 25K wob, 550 gpm, 1,750 psi, 600 gpm, 2,100 psi. 60 rpm's, off btm torque 7K ft-Ibs, on btm 9,500 ft-Ibs. Rot wt 125K, up wt 140K, so wt 115K. 12:00 00:00 12.00 2,906 3,588 SURFA( DRILL DDRL P Directionally drilled 12 1/4" hole from 2,906' to 3,588' MD/ 2,342' TVD (682'). ART 7.07 hrs, AST 1.20 hrs, ADT 8.27 hrs. 25-30K wob, 625 gpm, 2,290 psi, 60 rpm's, off btm torque 7,500 ft-Ibs, on btm 8,500 ft-Ibs. Rot wt 127K, u wt 145K, so wt 114K. 4/11/2009 Drilled 12 1/4" hole from 3,588' to 4,007' (Csg Pt), Circ 2X Btms up then wiped hole by BROOH to HWDP w/no roblems, RIH &Circ hole clean. POOH on tri tank & be an LD BHA #1, no roblems POOH. 00:00 06:30 6.50 3,588 4,007 SURFA( DRILL DRLG P Directionall drilled 12 1/4" hole from 3,588' to 4,007' MD/ 2,472' TVD (419'). ART 5.14 hrs, AST 0.11 hrs, ADT 5.25 hrs. 20-25K wob, 625 gpm, 2,500 psi, 60 rpm's, off btm torque 7,000 ft-Ibs, on btm 9,000 ft-Ibs. Rot wt 127K, u wt 145K, so wt 115K. ~ ®®~e 'eye ~ €~f 1~ Time Logs -- - -- --- From To Dur S. De th E. De th Phase Code Subcode T Comment Date _ 06:30 08:00 1.50 4,007 3,752 SURFA( DRILL CIRC P Circulate and condition mud - 650 gpm / 2400 psi / 60 rpm -stood back 1 std / 20 minutes to 3,752' -Flow check well, static 08:00 14:00 6.00 3,752 900 SURFA( DRILL WPRT P Wipe hole from 3,752' to 900' - BROOH at 600 gpm / 1920 psi / 60 rpm -Reduced pump rate to 500 gpm / 1450 psi from 1600' - to 900' - Flow check well, static 14:00 16:00 2.00 900 4,007 SURFA( DRILL WPRT P RIH from 900' to btm at 4,007' with no roblems. 16:00 17:15 1.25 4,007 4,007 SURFA( DRILL CIRC P Circ hole 1.5X btms up and was clean at the shakers, circ at 650 gpm, 2,640 psi, 60 rpms with 7,500 ft-Ibs for ue. 17:15 17:30 0.25 4,007 4,007 SURFAc DRILL OWFF P Monitored well-static, blew down top drive. 17:30 21:30 4.00 4,007 166 SURFA( DRILL TRIP P POOH on the trip tank from 4,007 to 166' standing back HWDP, no roblems POOH. 21:30 00:00 2.50 166 30 SURFA( DRILL PULD P POOH LD jars and NMFDC's. lu ed into MWD tool & LD same. 4/12/2009 Fin LD BHA #1, RU &RIH with 9 5/8" csg landing same @3,997', no problems. Circ & cond hole then cemented csg with 128 bbls of cmt back to surface. RU & tested csg to 3,500 psi for 30 min. RD Csg equip & landin ~t. NU FMC wellhead & BOP stack. 00:00 00:45 0.75 30 0 SURFA( DRILL PULD P Fin LD motor and bit on BHA #1 and cleaned ri floor. 00:45 02:15 1.50 0 0 SURFA( CASING RURD P RU to run 9 5/8" csg with Franks fill u tool. 02:15 02:30 0.25 0 0 SURFA( CASING SFTY P Held PJSM with rig crew and tong operator on running of casing and the associated hazards. 02:30 06:15 3.75 0 2,137 SURFA( CASING RNCS P Ran 9 5/8" 40# L-80 BTCM casing as follows: Float shoe (Ray Oil Tools silver bullet) 2 jts csg -Float collar (Halliburton super seal II) - 2 jt csg all connections made up w/ BakerLoc -filled pipe & checked floats) Cont. to RIH with 9 5/8" csg to 2,137' 55 'ts total 06:15 07:00 0.75 2,137 2,137 SURFA( CASING CIRC P Est. circ and circ btms up @ 2,137', Staged pump rate up to 6 bbts/min. ICP 300 psi @ 3.2 bbls/min. FCP at 6 bbls/min @ 400 psi. st wt up 145K, so wt 120K 07:00 09:15 2.25 2,137 3,997 SURFA( CASING RNCS P Cont. RIH with 9 5/8" csg from 2,137 to 3,958'. MU FMC hanger and landed csg with FS @ 3,997' and flt co ar No problems - PU wt 212K, SO wt 110K. Ran a total of 102 jts of 9 5/8", 40#, L-80, BTCM csg, total including float equip and hanger 3,960.76'. Ran 56 Bow spring cent and 2 sto rin s er well Ian. 09:15 10:00 0.75 3,997 3,997 SURFA( CEMEN" RURD P RD Franks fill up toot and MU Dowell cement head. rage 3 of i~ i Time Lois _ __ -- _--- _-- T Comment Date From To Dur S De th E. De th Phase Code Subcode 10:00 12:15 2.25 3,997 3,997 SURFAC CEMEN" __ CIRC _ _ P _ Circ and cond. mud for cementing, staged pump rate up from 3.1 bpm at 410 psi to 7.1 bpm at 320 psi, cond. mud to 9.9 ppg. in and out with 15 YP. St wt up 175K, do wt 135K. Held PJSM on cement 'ob while circ hole. 12:15 15:00 2.75 3,997 3,997 SURFA( CEMEN" CMNT P Cemented 9 5/8" casing as follows: Rig pumped 92 bbls of 9.9 ppg mud with nut plug marker followed with 35 bbls of Biozan w/nut plug marker as pre flush .Switch over to Dowell and pumped 3 bbls of FW, tested lines to 4,000 psi .Dropped bottom plug. Mixed & pum ed 50 bbls of 10.5 MudPUSH II spacer, ave. 5.7 bpm at 212 psi. Mixed & pumped 10.7 ppg lead slurry at 4.45 yield (ASL) ave. 7.0 bpm at 235 - 334 psi. Observed nut plug marker at shakers w/ 426 bbls lead slurry pumped (pumped down surge can, 434 bbls total 540 sxs) Switched to tail slurry and pumped 51 bbls (245 sxs) of 15.8 ppg ai cmt at 1.17 yield (Class G w/ additives) ave.5.1 bpm at 155 psi. Dropped top plug w/ 20 bbls fresh water f/ Dowell, Switched to rig pumps & displaced cement w/ 257 bbls of 9.9 ppg mud @ 8.0 bpm, ICP 400, FCP 710 psi, slowed pump to 6.3 bpm at 600 psi (for the last 20 bbls of displacement) Bumped plug to 1100 psi. Checked floats OK, CIP @ 1450 hrs. Had full returns throu hout'ob w/ 128 bbls of 10.7 cement returns to surface. Reci rotated pipe until last 145 bbls of dis lacement. 15:00 16:00 1.00 3,997 3,997 SURFA( CASING DHEQ P RU and tested casing to 3,500 qsi for 30 min. 16:00 17:45 1.75 3,997 3,997 SURFA( CASING RURD P RD cmt head, landing jt, long bales and elevators. 17:45 19:00 1.25 3,997 3,997 SURFAC DRILL RURD P Pulled mousehole, RD and pulled riser, ND surface ada ter 19:00 20:15 1.25 3,997 3,997 SURFA( WELCTL NUND P NU FMC wellhead and tested seals to 1,000 si for 10 min. 20:15 23:30 3.25 3,997 3,997 SURFAC WELCTL NUND P NU BOP stack, riser, flowlines and turn buckles, cleaned out under rig floor. 23:30 00:00 0.50 3,997 3,997 SURFAC DRILL RURD P Brought Sperry Sun Geo span to rig floor and rigged up, installed mousehole in preparation to PU and stand back 5" DP via the mousehole. 4/13/2009 PU & stood back 116 stds of 5" DP. RU & Tested BOPE to 250/3,500 psi. Note: Bob Noble with AOGCC waived witnessin test. MU 8 3/4" Geo ilot BHA #2 RIH to 755'. a F~~ye ~ of 1 ~.__ Time Logs ~ Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 12:00 12.00 0 0 SURFAt DRILL PULD P PU and stood 116 stds of 5" DP via the mousehole. (50 stds "S" pipe & 66 stds "G" i e 12:00 12:45 0.75 0 0 SURFA( DRILL SVRG P Greased IBOP, serviced top drive and drawworks. 12:45 18:15 5.50 0 0 SURFA( WELCTL BOPE P RU and tested BOPE tested rams, valves and manifold to 250 psi low and 3,500 psi high, tested annular to 250/2,500 psi. Tested with 5" test jt. and performed Koomey test. NOTE: Bob Noble with AOGCC waived witnessin of the test. 18:15 18:45 0.50 0 0 SURFA( DRILL OTHR P Installed wear bushing. 18:45 21:00 2.25 0 105 SURFA( DRILL PULD P MU Geopilot BHA #2 RIH to 105', MU bit #2, 7600 geopilot and MWD and u loaded same. 21:00 22:00 1.00 105 105 SURFA( DRILL OTHR P Pressure tested Geospan to 3,500 psi then shallow tested MWD at 500 gpm, 620 psi and tool ck'd ok. Blew down to drive. 22:00 00:00 2.00 105 755 SURFA( DRILL PULD P Fin. MU BHA #2 RIH to 755'. Held PJSM then loaded radioactive sources, PU 3-NMFDC's, RIH with HWDP and 'ars. 4/14/2009 RIH W/6HA #2 PU''S" DP to 3810, cut & slip drlg line, wash down to top cmt @ 3850' -Clean out shoe track & rat hole -drill 20'new hole to 4027' -Circ clean -perform FIT to 18.0 ppg EMW -Change over to 9.6 ppg LSND mud -Drilled 8 3/4" hole with Geo ilot from 4,027' to 5,235'. 00:00 00:15 0.25 755 755 SURFA( DRILL SFTY P PJSM on picking up 5" DP 00:15 03:15 3.00 755 3,810 SURFA( DRILL TRIP P RIH f/ 755' picking up 5" DP f/ pipe shed to 3810' - PU wt. 150 SO wt 90 Picked u host reamers 03:15 04:45 1.50 3,810 3,810 SURFA( DRILL SLPC P PJSM -cut & slip 60' drill line - service TD 04:45 05:30 0.75 3,810 3,919 SURFA( DRILL WASH P Wash & ream f/ 3810' to 3850' (tag cmt).Clean out cmnt to FC lad 391 break in GP bearin s 05:30 09:30 4.00 3,919 4,007 SURFA( CEMEN' DRLG P Drill out Fc @ 3919' & cmt to 3995' (top of FS) drill FS to 3997' -clean out rat hole to 4007' 09:30 10:00 0.50 4,007 4,027 SURFA( DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 4007' tit 4027 MD 2478' TVD ADT - .21 hrs 10:00 11:00 1.00 4,027 4,027 SURFA( DRILL CIRC P Circ & cond. mud for FIT - 9.6 ppg in & out 11:00 12:00 1.00 4,027 4,027 SURFA( DRILL FIT P PJSM - RU & perform FIT to 18.0 _ ppg EMW w/ 1080 psi w! 9.6 ppg mud 2469' TVD - RD 12:00 12:30 0.50 4,027 4,027 INTRM1 DRILL CIRC P Change well over to 9.6 ppg LSND mud. s ~~~~ ~ s~f ~a ~_ • Time Logs __ Date From T o Dur S De th E. De th Phase Code Subcode T Comment 12:30 _ 00:00 11.50 4,027 5,235 INTRM1 DRILL DDRL _ __ P Drilled 8 3!4" hole with Geopilot from 4,027' to 5,235' MD/2,864' TVD (1,208') ADT 7.44 hrs. 12-18K wob, 650 gpm, 1,920 psi, 140 rpm's, off btm torque 10K ft-Ibs, on btm 11 K ft-Ibs, rot wt 135K, up wt 150K, so wt 123K. 9.7 ppg MW, ave ECD 11.0 ppg. Pumping hi-vis sweeps every 300' with good results. NOTE. Unable to get MI Swaco centrifuge to work. 4/15/2009 Drilled 8 3/4" Hole with Geopilot from 5,235' to 7,690' 00:00 12:00 12.00 5,235 6,431 INTRM1 DRILL DDRL P Drilled 8 3/4" hole w/ GP f/ 5235' to 6431' MD 3226' TVD ADT - 8,05 hrs. Footage - 1196' ECD- 11.1 ppg WOB 18/20 k RPM 150 GPM 650 @ 2250 psi String Wt. PU 180 SO 115 ROT 142 Torque on/off btm.- 12,000/11,500 ft/Ibs. NOTE: Centrifuge back on line @ 09:00 hrs 12:00 00:00 12.00 6,431 7,690 INTRM1 DRILL DDRL P Drilled 8 3/4" hole with Geopilot from 6,431' to 7,690' MD/3,609' TVD (1,259') ADT 7.38 hrs. 18-22K wob, 650 gpm, 2,610 psi, 150 rpm's, off btm torque 12K ft-Ibs, on btm 13,500 ft-Ibs, rot wt 150K, up wt 200K, so wt 120K. 9.6 ppg MW, ave ECD 11.25 ppg. Cont. pumping hi-vis sweeps eve 400' with ood results. 4/16/2009 Drilled 8 3/4" Hole with Geopilot from 7,690' to 10,260'. 00:00 12:00 12.00 7,690 8,807 INTRM1 DRILL DDRL P Drilled 8 3/4" hole w/ GP f/ 7690' to 8,807' MD 3967' TVD ADT- 7.48 hrs Footage -1117' ECD - 11.1 ppg WOB - 18/22 k RPM 150 GPM 650 @ 2680 psi String wt. PU 198 SO 125 ROT 158 Torque on/off btm.- 13,500/13,000 ft/Ibs 12:00 00:00 12.00 8,807 10,260 INTRM1 DRILL DDRL P Drilled 8 3/4" hole with Geopilot from 8,807' to 10,260' MD/4,412' TVD (1,453') ADT 7.06 hrs. 23-25K wob, 650 gpm, 2,400 psi, 150 rpm's, off btm torque 14,500 ft-Ibs, on btm 15,500 ft-Ibs, rot wt 159K, up wt 210K, so wt 130K. 9.7 ppg MW, ave ECD 11.15 4/17/2009 Drilled 8 3/4" Hole with Geopilot from 10,260' to 12,844' F'r€~ €~ of 'i a l J Time Lo~c s __ From To Dur S. De th E. De th Phase Code Subcode T Comment Date _ 00:00 12:00 12.00 10,260 11,512 INTRM1 DRILL DDRL P Drilled 8 3/4" hole w/ GP f/ 10,260' to 11,512' MD 4797 TVD ADT- 7.24 hrs Footage- 1252' ECD- 11.0 ppg WOB - 23/25 k RPM 150 GPM 675 @ 2760 psi String wt. PU 250 SO 126 ROT 170 Torque on/off btm.-18,000/16,500 ft/Ibs 12:00 00:00 12.00 11,512 12,844 INTRM1 DRILL DDRL P Drilled 8 3/4" hole with Geopilot from 11,512' to 12,844' MD/5,207' TVD (1,332') ADT 7.81 hrs. 25-30K wob, 675 gpm, 2,700 psi, 150 rpm's, off btm torque 16K ft-Ibs, on btm 16,500 ft-Ibs, rot wt 175K, up wt 240K, so wt 138K. 9.7 ppg MW, ave ECD 11.05 4/18/2009 Drilled 8 3/4" Hole with Geopilot from 12,844' to 15,465' 00:00 12:00 12.00 12,844 14,210 INTRM1 DRILL DDRL P Drilled 8 3/4" hole w/ GP f/ 12,844' to 14,210' MD 5633' TVD ADT- 7.67 hrs Footage- 1366' ECD- 11.12 ppg WOB 28/30 k RPM 150 GPM 675 2760 psi String wt. PU 302 SO 133 ROT 185 Torque on/off btm.- 20,000/19,500 ft/Ibs 12:00 00:00 12.00 14,210 15,465 INTRM1 DRILL DDRL P Drilled 8 3/4" hole with Geopilot from 14,210' to 15,465' MD/6,026' TVD (1,255') ADT 7.55 hrs. 25-28K wob, 675 gpm, 2,800 psi, 150 rpm's, off btm torque 21 K ft-Ibs, on btm 23K ft-Ibs, rot wt 195K, up wt 320K, so wt 138K. 9.75 ppg MW, ave ECD 11.0 4/19/2009 Drilled 8 3/4" Hole with Geopilot from 15,465' to 17,645' 00:00 12:00 12.00 15,465 16,605 INTRM1 DRILL DDRL P Drilled 8 3/4" hole w/ GP f/ 15,465' to 16,605' MD 6377' TVD ADT- 7.81 hrs. Footage- 1,140' ECD- 11.26 ppg WOB - 25/27 k RPM 150 GPM 675 @ 3150 psi String wt. PU 275 SO 160 ROT 203 Torque on/off btm.- 22,500/16,500 ft/Ib 12:00 00:00 12.00 16,605 17,645 INTRM1 DRILL DDRL P Drilled 8 3/4" hole with Geopilot from 16,605' to 17,645' MD/6,717' TVD (1,040') ADT 8.16 hrs. 25-28K wob, 675 gpm, 3,230 psi, 150 rpm's, off btm torque 17K ft-Ibs, on btm 21 K ft-Ibs, rot wt 208K, up wt 300K, so wt 160K. 9.75 ppg MW, ave ECD 11.28 • C~ T+me Loys _ ______-- Date From To Dur S. Depth E. Depth Phase Code Subc_ode T Comment 4/20/2009 2a hrSummarv Drilled 8 3/4" hole w/GP f/ 17,645' to 17,694' MD -Circ & trouble shoot MP #1 -Cracked fluid end -Drill f/ 17,694' to 17,843' MD 6806' TVD (with one pump @440 gpm )- total depth of section -Circ 3 X btms up - Wipertrip to 16,111' (20 stds) Monitor well (static) - RIH f/16,111' to 17,788' -Wash down to 17,843' -Circ 2 X btms up -Monitor well-static, spotted WBS pill POOH to 16,018', cont. to POOH on TT to 11,700' & pulled ti ht, MU to drive. 00:00 00:30 0.50 17,645 17,694 INTRM1 DRILL DDRL P Drilled 8 3/4" hole w/ GP f/ 17,645' to 17,694' MD 6738; TVD ADT-.64 hrs Footage - 49' ECD- 10.8 ppg WOB 13/15 k RPM 150 GPM 437 1580 si 00:30 01:30 1.00 17,694 17,694 INTRM1 DRILL CIRC T Circ & trouble shoot MP #1 -Found cracked fluid end - 01:30 04:15 2.75 17,694 17,843 INTRM1 DRILL DDRL P Drilled 8 3/4" hole f/ 17,694' to 17 843' MD 680 ' TVD -total de th of section ADT- 2.23 hrs Footage -149' ECD- 10.9 ppg WOB 20/23 k RPM 150 GPM 454 @ 1770 psi String wt. PU 300 SO 160 ROT 210 Torque on/off btm.- 22,500/17,000 ft/Ibs Note :Drilled with pump #2 while re airin MP #1 04:15 09:30 5.25 17,843 17,414 INTRM1 DRILL CIRC P Circ 3 X btms up @ 440 gpm @ 1550 psi w/ 150 rpm -Std back 1 std eve 30 mins. to 17,414' 09:30 12:00 2.50 17,414 16,111 INTRM1 DRILL WPRT P Wiper trip f/ 17,414' ti 16,111' back reaming w/ 100 rpm's - 440 gpm @ 1550 si - 12:00 13:15 1.25 16,111 17,788 INTRM1 DRILL TRIP P Blow down TD -Monitor well (static) - RIH f/ 16,11' to 17,788' - PU wt. 300 SO wt. 160 13:15 15:15 2.00 17,788 17,695 INTRM1 DRILL CIRC P Washed down from 17,788' to 17,843', circ 2X btms up and was clean at the shakers, 1st btms up with 1 pump at 440 gpm at 1,690 psi, 2nd btms up with both pumps on the hole at 650 gpm, 3,100 psi, 150 rpm's, stood back 1 std every 30 min. to 17,695'. 15:15 15:30 0.25 17,695 17,843 INTRM1 DRILL TRIP P RIH from 17,695' to 17,843'. Monitored well-static. 15:30 16:00 0.50 17,843 17,843 INTRM1 DRILL CIRC P Spotted WBS pill out the bit et 17,843', circ at 650 gpm, 3,150 psi, 150 r m's and 22K ft-Ibs for ue. 16:00 18:15 2.25 17,843 16,018 INTRM1 DRILL TRIP P POOH spotting WBS pill from 17,843' to 16,018' (above HRZ top), spotted pill at 3 bpm, 450 psi. up wt 295K. 18:15 18:30 0.25 16,018 16,018 INTRM1 DRILL OWFF P Monitored well-static, blew down top drive. P~rtdt2 ~ of 14 • Time Logs Comment __ _~i Date From To Dur S De th E. De th Phase Code Subcode T 18:30 21:45 3.25 16,018 12,749 INTRM1 DRILL TRIP _ P POOH wet on the trip tank from 16,018' to 12,749', monitored well-static. 21:45 22:15 0.50 12,749 12,749 INTRM1 DRILL CIRC P Pumped dry job and blew down top drive. 22:15 00:00 1.75 12,749 11,700 INTRM1 DRILL TRIP P POOH on the TT from 12,749' to 11,700' and dulled ticZht a, ttempted to work thru with no success, MU top drive. 4/21 /2009 POOH w/ Pumps f/ 11,700' - 4,000' MD -CBU - OWFF (Static) -POOH on TT U 661' MD -Stand Back HWDP and UD NMFDC's -Remove RA Sources & Read MWD Tools -Break Bit and UD Remainder of BHA #2 00:00 02:15 2.25 11,700 10,942 INTRM1 DRILL TRIP P POOH w/ Pump @ 600 gpm @ 2230 psi w/ 120 rpm f/ 11,700' to 10,942' - Flow ck static 02:15 03:45 1.50 10,942 10,085 INTRM1 DRILL TRIP P POOH on TT f/ 10942' to 10,085' - ullin ti ht 10,085' 03:45 04:45 1.00 10,085 9,704 INTRM1 DRILL TRIP P POOH w/ Pump @ 600 gpm @ 2050 psi w/ 120 rpm f/ 10,085' to 9,704' - Flow ck static 04:45 05:45 1.00 9,704 8,944 INTRM1 DRILL TRIP P POOH on TT f/ 9,704' to 8,944' - ullin ti ht 8,944' 05:45 07:45 2.00 8,944 8,278 INTRM1 DRILL TRIP P POOH w/ Pump @ 600 gpm @ 2030 psi w/ 120 rpm f/ 8,944' to 8,278' - Flow ck static 07:45 08:45 1.00 8,278 7,423 INTRM1 DRILL TRIP P POOH on TT f/ 8,278' to 7,423' - ullin ti ht 7,423' 08:45 12:00 3.25 7,423 6,186 INTRM1 DRILL TRIP P POOH w/ Pump @ 600 gpm @ 1900 si w/ 120 m f/ 7,423' to 6,186' 12:00 14:15 2.25 6,186 5,806 INTRM1 DRILL TRIP P POOH w/ Pumps @ 600 GPM & 1800 Psi, 120 RPM U 5806' MD 14:15 15:30 1.25 5,806 4,000 INTRM1 DRILL TRIP P POOH on TT f/ 5,806' - 4,000' MD 15:30 15:45 0.25 4,000 4,000 INTRM1 DRILL OWFF P OWFF Static 15:45 16:15 0.50 4,000 4,000 INTRM1 DRILL CIRC P CBU @ 550 GPM & 1420 Psi - 40 RPM - OWFF Static 16:15 18:45 2.50 4,000 661 INTRM1 DRILL TRIP P POOH on TT f/ 4,000' - 661' MD - OWFF Static 18:45 19:15 0.50 661 205 INTRM1 DRILL TRIP P Stand Back 6 Stands of HWDP 19:15 19:30 0.25 205 137 INTRM1 DRILL PULD P UD 2 NMFDC's 19:30 19:45 0.25 137 137 INTRM1 DRILL SFTY P PJSM on Pulling RA Sources 19:45 20:15 0.50 137 137 INTRM1 DRILL OTHR P Pull RA Sources 20:15 22:00 1.75 137 137 INTRM1 DRILL OTHR P Plug In and Read MWD Data - Service Geo-Pilot 22:00 23:30 1.50 137 0 INTRM1 DRILL PULD P UD BHA -Break Bit 23:30 00:00 0.50 0 0 INTRM1 DRILL RURD P UD BHA Tools /Clean & Clear Rig Floor 4/22/2009 Pull WB - RU & change top pipe rams to 7" & test -set thin wall WB - RU Tesco tools for 7" casing -PJSM on runnin 7" w/ Tesco -Ran 7" 26# L-80 MBTC cs to 10,650' MD 265 Jts in Hole - ® r~~g~a of ~~ ~~ t, J Time Lois ___ ~ ~ ___ Date From To Dur S D~th. E. Depth Phase Code Subcode T Comment _____ _ ~i 00:00 01:00 1.00 0 0 INTRM1 DRILL OTHR P Pull wear ring with blocks. Wear ring was ti ht had to pull 13,000 Ibs to remove. Observed several pieces of metal on top of pulling tool & several marks on outside of wear bushin 01:00 03:00 2.00 0 0 INTRM1 DRILL NUND P Chan e u per rams to 7". Test to 250 si low and 3500 si hi h. 03:00 03:30 0.50 0 0 INTRM1 DRILL OTHR P Install thin wall wear ring. 03:30 04:30 1.00 0 0 INTRM1 CASING RURD P Rig up Tesco 7" casing running tool. 04:30 05:00 0.50 0 0 INTRM1 CASING SFTY P Pre job safety meeting about using the Tesco casin tool. 05:00 12:30 7.50 0 4,124 INTRM1 CASING RNCS P Ran 7" 26# L-80 BTCM csg as follows: Ray Oil Tools "Silver Bullet" Float shoe - 2 jts csg - Halliburton Float collar - 2 jts csg - (first 4 joints made up w/ Baker Loc Filled pipe & checked float) - 7 jts csg - 21' Marker jt @ 17357.92' - 55 jts csg - 2 pup jts -csg -RIH with csg to 4,124' (100 jts total) Ran tandem rise centralizers 2~t on jts #2 - #15 with stop ring in middle of the jt. per well plan and 1~t on #16 - #30. PU = 140k. SO = 115k. 12:30 13:00 0.50 4,124 4,124 INTRM1 CASING CIRC P Pumped casing volume -Circulate and condition mud. Stage up pumps to 7 BPM with 280 si. 13:00 18:15 5.25 4,124 8,198 INTRM1 CASING RNCS P Continue running 7" 26# L-80 MBTC csg - f/ 4124' to 8198' (200jts total in hole 18:15 19:30 1.25 8,198 8,198 INTRM1 CASING CIRC P Circ btms up + Staging pumps up to 6.5 bbls/min -FCP 520 Psi 19:30 00:00 4.50 8,198 10,850 INTRM1 CASING RNCS P Continue to RIH w/ 7" Casing U 10,850' MD 265 Jts in Hole 4/23/2009 Continue to RIH w/ 7" Casing f/ 10,850' - 17,832' MD -Circ & Cond Mud Prior to Cement -Cement 7" casing w/ 87 Bbls of 11.0 PPG Lead and 44 Bbls of 15.8 PPG Tail -Displace Cement w/ 669 Bbls 9.2 PPG KCL Brine - CIP @ 1823 -Test Casing U 3500 Psi f/ 30 Minutes (Good) - R/D Tesco Tools -Set Packoff and Test U 5,000 Psi f/ 30 Minutes 00:00 01:45 1.75 10,850 12,312 INTRM1 CASING RNCS P Continue to RIH w/ 7" Casing U 12312' MD (300 Jts in Hole) PU = 270k. SO = 127k. 01:45 03:15 1.50 12,312 12,312 INTRM1 CASING CIRC P Circ btms up + Staging pumps up from 2.5 bbls/min -ICP 350 psi to 6.5 bbls/min -FCP 560 Psi 03:15 08:15 5.00 12,312 16,049 INTRM1 CASING RNCS P Continue to RIH w/ 7" Casing U 16049' MD (390 Jts in Hole) PU = 360k. SO = 133k. 08:15 10:00 1.75 16,049 16,049 INTRM1 CASING CIRC P Circ btms up + Staging pumps up from 2.5 bbls/min -ICP 490 psi to 6.5 bbls/min -FCP 690 Psi 10:00 12:45 2.75 16,049 17,794 INTRM1 CASING RNCS P Continue to RIH w/ 7" Casina U 17794' MD 433 Jts in Hole PU = 395k. SO = 125k. ~~ ~_ ~ v Pale 1~3 of 1~ ~ ~ Time Logs _ Date From To Dur S. De th E. De th Phase Code Subcode T Comment 12:45 13:15 0.50 17,794 17,832 INTRM1 CASING HOSO P Make up 7" hanger, landing joint. Land casing w/ FS @ 17,831' FC @ 17 743' MD. Make u cement head. 13:15 15:00 1.75 17,832 17,832 INTRM1 CEMEN" CIRC P Circulate and condition mud for cementjob. Stage pump up to 6.5 BPM with 710 si. 15:00 15:15 0.25 17,832 17,832 INTRM1 CEMEN" SFTY P Pre job safety meeting for 7" cement 'ob. 15:15 16:30 1.25 17,832 17,832 INTRM1 CEMEN" CMNT P Cemented 7" casing as follows: Pumped CW 100 -Pressure test lines to 2,500 psi -Dropped btm plug -Pumped 50 bbls CW-100 @ 4.2 bbls/min with 450 psi -Mix & pumped 40 bbls 10.5 ppg MudPush @ 4.6 bbls/min with 470 psi -Mixed & pumped 87 bbls (135 sxs) 11.0 ppg, 3.35 yield lead slurry (Class G w/ additives) @ 5.9 bbls/min with 430 psi -Mixed & pumped 44 bbls (200 sxs) 15.8 ppg, 1.16 yield tail slurry Class G w/ additives) at 4.2 bbls/min with 70 si - Dro ed to lu 16:30 18:30 2.00 17,832 17,832 INTRM1 CEMEN" DISP P Displaced @ 7.0 bbls/min - 520 psi for the first 655 bbls -slowed pumps to 3.0 bbls/min - 750 psi for last 24 bbls of displacement. Final displacement pressure 726 psi. Bumped @ displacement 669 bbls - CIP @ 1823 hrs.- Calc TOC @ 14,800'. No pipe movement and had full circulation throughout job. Check floats OK 18:30 19:30 1.00 17,832 17,832 INTRM1 CASING PRTS P R/U and Test 7" Production Casin to 3 500 si f/ 30 Minutes Good 19:30 20:30 1.00 17,832 17,832 INTRM1 CASING RURD P R/D Cementing and Casing Test head & Manifold 20:30 20:45 0.25 17,832 17,832 INTRM1 CASING SFTY P PJSM on UD Tesco Casing Running Tools 20:45 22:00 1.25 17,832 17,832 INTRM1 CASING PULD P UD Tesco Casing Running Tools 22:00 23:15 1.25 17,832 17,832 INTRM1 CASING MPSP P M/U Test Joint and Pull Thin Wall Wear Rin - M/U & Set 7" Packoff 23:15 00:00 0.75 17,832 17,832 INTRM1 CASING PRTS P Test 7" Packoff t/ 5,000 Psi f/ 30 Minutes 4/24/2009 Wash Stack -Test Tubing Bowl Sealing Surfaces w/ Elastomer Hanger U 5,000 Psi f/ 5 Minutes (Good) - Change Upper Rams t/ 3 1/2" by 6" Variables & Test U 250/3500 Psi (Good) - R/U and Run 3 1/2" EUE Com letion Strin to 12,915' MD 401 of 487 Jts of 3 1/2" EUE in Hole 00:00 01:00 1.00 0 0 COMPZ RPCOM PULD P Install wear ring (junk catcher). Rig up and flush BOP's. Rig down and ull ~unk wear rin . 01:00 03:15 .2.25 0 0 COMPZ RPCOM THGR P Make up and land tubing hanger with TWC installed, run in lock down screws. Rig up and test tubing hanger seals to 5000 psi. (test was good) Back out lock down screws and la down tubin han er. 4'arJe 11 of 14 ~ ~ Time Logs - -- _ Date From To Dur S. Depth E_D~th Phase Code Subcode T , -- Comment ___' 03:15 05:30 2.25 0 , 0 COMPZ _ RPCOM BOPE P Pre job safety meeting. Change out u er rams to 3 1!2 X 6" VBR and test 250 psi low and 3500 psi high. Chan a out saver sub to 4 1/2" IF. 05:30 06:00 0.50 0 0 COMPZ RPCOM PULD P Install tubing wear ring. 06:00 08:00 2.00 0 0 COMPZ RPCOM SLPC P Pre job safety meeting. Slip and cut 120' of drilling line. Service top drive and ad'ust brake. 08:00 09:00 1.00 0 0 COMPZ RPCOM PULD P Pick up tubing equipment to the floor and ri u to run 31/2" tubin . 09:00 09:30 0.50 0 0 COMPZ RPCOM SFTY P Pre job safety meeting to run 3 1/2" tubin . 09:30 12:00 2.50 0 2,097 COMPZ RPCOM RCST P Run Completion as Follows: WLEG, 66 Jts 3 1!2" 9.3 # L-80 EUE Tubin 12:00 00:00 12.00 2,097 12,915 COMPZ RPCOM RCST P Continue to RIH w/ ompletion String as Follows: DS Nipple w/ RHC plug, 1 Jt Tubing, Premier Packer, 1 Jt Tubing, 3 1/2" CMU Sliding Sleeve w/ DS profile (closed), 1 Jt Tubing, GLM w/ Dummy, 197 Jts Tubing, GLM w/ Dummy, 135 Jts Tubing (401 Jts 3 1/2" EUE in Hole /25/2009 Continue to RIH w/ Upper Completion per Detail t/ 17,252' MD - M/U and Test Metal to Metal Seal Tubing Hanger (Bad) -Replace Tubing Hanger w/ Elstomer Type and Test (Good) -Set TWC - N/D BOPE and N/U Tree -Test Tree t/ 5,000 Psi -Pull TWC - R/U and Displace Well Bore w! 424 Bbls 9.2 PPG inhibited Brine and 190 Bbls 6.8 PPG Diesel -Drop Ball & Rod -Set Packer w/ 4950 Psi -Test Tubing U 4,950 Psi f/ 30 Minutes 00:00 01:00 1.00 12,915 14,387 COMPZ RPCOM RCST P Continue running 3 1/2' completion f/ 12915' to 14387' 448 'ts totat 01:00 03:00 2.00 14,387 14,387 COMPZ RIGMNT RGRP T Repair hydraluic leak under rig floor - Service ri 03:00 04:30 1.50 14,387 15,646 COMPZ RPCOM RCST P Continue running completion f/ 14387' to 15586' (487 jts total of 3 1/2" 9.3# L-80 EUE Mod tbg) MU XO 3 1/2" EUE x 4 1/2" IBT- Run 1 jt 4 1/2' 12.6# L-80 IBTM tbg & PU SSSV to 15,646' 04:30 06:15 1.75 15,646 15,646 COMPZ RPCOM OTHR P RU Camco equipment -Connect control lines to SSSV & test lines to 5000 psi -Bring tbg hanger to rig floor 06:15 08:45 2.50 15,646 17,221 COMPZ RPCOM RCST P Continue Running completion -Ran 38 jts 4 1/2" 12.6# L-80 IBTM -band control lines w/ SS bands f/ 154,46' to 17,221' ~~a~~ 12 of 14 • Time Logs ____ _ _ ___ Date From To Dur S De th E. Depth Phase Code Subcode T Comment _ - 08:45 10:45 2.00 17,221 17,252 COMPZ RPCOM THGR P MU wearing bushing pulling tool & pulled tbg running wear bushing - MU FMC tbg hanger w/metal to metal seals -Run control line through hanger & test connections to 5000 psi OK -Land tbg on tbg hanger w/ tbg tail @ 17,252' - DS nipple @ 15,149' -Packer @ 15,091' -Sliding sleeve @ 15,036' -GLM # 1 w/ dummy @ 14,977' -GLM #2 w/ dummy @ 8706' -GLM # 3 w/shear valve @ 2503' -SSSV @ 1611' - RILDS 10:45 11:30 0.75 17,252 17,252 COMPZ RPCOM THGR P LD landing jt A -install TWC - MU landing jt. B - RU & test hanger seals -primary metal to metal seals failed - back u seals held 11:30 14:15 2.75 17,252 17,252 COMPZ RPCOM THGR T BOLDS -Pull hanger to rig floor - Change out tbg hanger f/ metal to metal seals to elastomer seals - Install TWC - MU landing jt B - Reland han er -Test hnager seals to 5000 psi OK - RD test line & LD landin 't. B 14:15 15:00 0.75 17,252 17,252 COMPZ RPCOM RURD P LD mouse hole - RD riser & fill up lilne 15:00 15:45 0.75 17,252 17,252 COMPZ WHDBO NUND P N/D BOPE -Stand Back and Secure for Move 15:45 17:15 1.50 17,252 17,252 COMPZ WHDBO SEOP P N/U Tree and Test t/ 5,000 Psi f/ 5 Minutes -terminate SSSV Control Lines 17:15 18:00 0.75 17,252 17,252 COMPZ RPCOM RURD P R/U to Displace & Test Tubing and Packer 18:00 23:00 5.00 17,252 17,252 COMPZ RPCOM CIRC P Dis lace Well Bore w/ 425 Bbls 9. PPG Inhibited Brine and 190 Bbls ICP 500 Psi @ 3 BPM, FCP 1150 Psi 3 BPM - SITP 750 Psi 23:00 00:00 1.00 17,252 17,252 COMPZ RPCOM PRTS P R/U Lubricator Dro Ball & Rod Surface Test Lines t/ 5,000 Psi -Set Packer w/ 5,000 Psi and Hold for Tubing Test f/ 30 Minutes -Lost 150 Psi Durin Test 4/26/2009 Test annulus t/ 3,500 Psi (Good) -Shear Open GLM -Set BPV -Secure well - LD 5" DP f/ derrick for rig move -Released Ri 0000 hrs on 27 A ril 2009 00:00 01:45 1.75 0 0 COMPZ RPCOWI PRTS P Bleed Pressure f/Tubing Through Manifold to Annulus -Pressure Up Annulus to 3500 Psi While leaving 2200 psi on Tubin_ -Test Packer t/,._,__,_ _._„ S' 3 sif/3 - Bleed Pressure f/Tubing and Shear Open GLM -Blow Down Lines to Cement Unit - Ri Down 01:45 03:15 1.50 0 0 COMPZ WHDBO SEQP P M/U FMC Lubricator and Install BPV -Secure Well SIMOPS "" Remove 4 1/2" Tubing f/ Pi a Shed ~~a~e 13 of 14 • Time Logs Date From __ To _ Dur S De th E. De th Phase Code Subcode T_ __ _ Comment 03:15 18:00 14.75 0 0 COMPZ MOVE PULD P LD 5" DP f/derrick via mouse hole for ri move 18:00 19:00 1.00 0 0 COMPZ MOVE SVRG P Service Iron Roughneck & Rig 19:00 00:00 5.00 0 0 COMPZ MOVE PULD P UD Remaining 5" Dp f/the Derrick SIMOPS: Move Ball Mill to CD4 and Shop and Camp to CD2 Released Ri 2400 ~_.~ r~aq~ 1~ of ~~ CD3-304 Post Rig Well Work DATE SUMMARY 4/28/09 PULLED DUMMY PACK OFF FROM BAL-O NIPPLE @ 1607' RKB, PULLED BALL & ROD FROM RHC PLUG BODY @ 15143' RKB, PULLED 1" SOV FROM STA# 1 @ 2497' RKB, SET 1" DMY VLV IN STA# 1 @ 2497' RKB, PULLED 1" DMY VLV FROM STA# 3 @ 14971' RKB, SET 1" OV W/ 1/4" PORT IN STA# 3 @ 14971' RKB, PULLED RHC PLUG BODY FROM CAMCO D NIPPLE @ 15143' RKB / 15181' SLM, RUN 10' X 2.65" DUMMY GUN & 10' 2.5" BAILER STIFF DRIFT TUBBING TO 17500' SLM / 17468' RKB TUBBING CLEAR. JOB COMPLETE 4/29/09 PERFORATED 17408'-17440' WITH HES 2.0" SCALLOPED GUNS LOADED ~ MILLENIUM CHARGES 6-SPF, 60-DEG PHASING. ATTEMPT TO PERFORM SBHPS. LEAVE SBHPS TOOLSTRING (SPARTEK GUAGES) IN THE WELL: TOOLSTRING SEPARATED AT 1-3/16", 12-THREAD, THREADED UNION (PIN UP) AT STND CABLE-HEAD. FISH EQUALS 1- 11/16"OD X 21.29' OAL. 5/3/09 RAN 2.65" CENT & 2.34" OVER SHOT SIT DOWN @ 17690' SLM UNABLE TO LATCH, MAKE SEVERAL ATTEMPTS TO LATCH W/ NO SUCCESS LIGHT MARKS ON OVER SHOT LDFN. JOB IN PROGRESS 5/6/09 RUN 2.5" LIB RECOVER GOOD MARKS OF FISH, RUN 2.72" CENT 8~ OVER SHOT LATCH E-LINE TOOL STRING @ 17670' SLM, RECOVER TOOL STRING & GAUGES, GAUGES MEASURED MAX BHP (PSI 3317.46 /TEMP 172.10), SET 3.812" WRDP-2 @ 1612' RKB (SER# HRS-311) GOOD CLOSURE TEST. JOB COMPLETE ~ ~. WELL LOG TRANSMITTAL To: State of Alaska May 5, 2009 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Data: CD3-304 AK-MW-6449149 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Bryan Burinda, Sperry Drilling, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted CD Rom with verification listing. API#: 50-103-20598-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY 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 $~? _ on.com d' AY 2 ~ [uu~ Date~~_,~~~ossi®n Signed: /~~~~ :arse < ~. WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD3-304 May 5, 2009 AK-MW-6449149 CD3-304 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Logs 50-103-20598-00 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Logs 50-103-20598-00 Digital Log Images: 1 CD Rom 50-103-20598-00 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: -~ ~ f. ~; MAY 2 1 2009 Signed: ~ ~ ~I~sk~ Oil ass ns• ~~ Andi® _,~ ~r.~-~ a~ ~~sa~3 1 Aj'G 1 Vi 1 Maunder, Thomas E (DOA) From: Galiunas, Elizabeth C [Elizabeth.C.Galiunas(c~conocophiilips.aim] Se~n#: Tuesday, April 21, 2009 8:45 AM To: Maunder, Thomas E (DOA) Cc: McKeever, Steve; Anderson, Nina M; Kemner, Tyrone T. Subject: CD3 Permafrost and CD3-304 SSSV placement Att~echnnents: GD3-1018 BHP witl~ temp TVD iog.xis ~~ -~ ~~ Hi, Tom, Here is the information we discussed yesterday. The plan is to set the BAL-O wireline retrievable SSSV at 1600' MD ! 1509' TVD. Attached is the temperature log data far CD3-108. From the data it appears the permafrost on CD3 is closer to 1000' ar less. The SSSV wilt be set around 500' ND below the permafrost. I trimmed dawn the BHP data, since the file was too large to send. Let me know i# you have any comments or questions. Liz Galiunas Alpine Drilling Engineer ConocoPhiilips Alaska Office: 90T-265-8247 Cell: 907-903-1200 6/16/2009 100 95 90 85 80 75 ~ 70 d ~ 65 ., ea Q, 60 E d ~ 55 50 45 40 35 30 act',-c a--~ 5~~~~~~~~s~~~o~~~- o~~ ~~3_ 3G~ 25 100 350 599 845 1077 1295 1489 1669 1827 1980 2138 2293 2447 2599 2750 2901 3055 3209 3364 3519 3679 3842 4003 TVD ~ ids- 03~ CD3-108 Temperature Log • s CD3-304 Qannik ~ Page 1 of 2 Maunder, Thomas E (DOA) From: Perfetta, Heather M [Heather.M.Perfetta@conocophillips.com] Sent: Monday, April 20, 2009 10:36 AM To: Davies, Stephen F (DOA) Cc: Galiunas, Elizabeth C; Noel, Brian; Doyon 19 Company Man; Boccanera, Justine; Maunder, Thomas E (DOA) Subject: RE: CD3-304 Qannik Steve, ~~ ~ ~~ ~~ Reply was received. Thank you. Enjoy the beautiful sunshine we are having!! Heather Heather Perfetta Staff Geologist ConocoPhillips Alaska, Inc. 700 G Street Anchorage, AK 99501 907-265-6374 heather. m. perfetta@conocophillips._co_m_ From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Monday, April 20, 2009 10:33 AM To: Perfetta, Heather M Cc: Galiunas, Elizabeth C; Noel, Brian; Doyon 19 Company Man; Boccanera, Justine; Maunder, Thomas E (DOA) Subject: RE: CD3-304 Qannik Heather, Based an the information provided, I do not consider the Qannik in CD3-304 to be a significant hydrocarbon zone. I see no need to cement the Qannik interval in CD3-304. Steve Davies Sr. Petroleum Geologist Alaska Oil and Gas Conservation Commission 793-1224 From: Perfetta, Heather M [mailto:Heather.M.Perfetta@conocophillips.com] Sent: Friday, April 17, 2009 3:27 PM To: Davies, Stephen F (DOA) Cc: Galiunas, Elizabeth C; Noel, Brian; Doyon 19 Company Man; Boccanera, Justine; Perfetta, Heather M Subject: CD3-304 Qannik Steve, We are currently drilling at the Fiord (CD3) pad where we drill through the Qannik on the way to the Kuparuk or Nechelik. In general, we have cemented the Qannik in wells directed west of the pad where Qannik is better quality, and have not cemented it in wells directed to the east where the sand is less amalgamated and poorer quality. Internally, we use 5' of continuous pay as a cementing criteria. We would like your concurrence on not 4/20/2009 CD3-304 Qannik ~ Page 2 of 2 cementing the Qannik interval in CD3-304. This is a Kuparuk development well. This well has a southeast azimuth from the CD3 pad. Log model results for the CD3-304 yield 0' of pay in the Qannik interval. CD3-304 is very similar, but lower quality, then the CD3-305 well drilled earlier this year and the CD3-303 well drilled previously. Neither of these wells were cemented in the Qannik interval. Thanks, Heather «Qan nik_C D3-304. ppt» Heather Perfetta Staff Geologist ConocoPhillips Alaska, Inc. 700 G Street Anchorage, AK 99501 907-265-6374 heather. m. perfetta@conocoph iI lips. com 4/20/2009 CD3-304 Qannik (K2) interval t i~ CD3-304PRELIM nv X~L=ocation: 1528337.04 Y Location: 6003fi07.82 Spud Date: K8: 49.7 TD X Location: TD V Location: 7" SHOE CASING: 1.65 G/C3 2 r~.5 r,q~ PHIT_1 MD STV _ ~ OHMM 100 __ V/V GR MWD R RPS MWD R 2 ~ NPHIS MWD R _ _ _ e~n,F~ ~:;~~nnM- = D r~i i 4000 ~ ~ 9100 _ _ _ _ <') 3 ~ ° r n.~ . _ 9150 _._ . ~~ ~ ~ ~~ ~-2 tC , ~ ---_~.._ ~ ~. 9200 __.-___. m _. ..._ _..,_ S ~ -- i ~ l -~- 050 -. ' 4 _ ,f ` ~ ' -, -.,_ _~ ... I 9250 _ - ~ - ~ ~ i_ - _-- ~) ~. ~ _ _ ~ ~--_-;- a- - - 9300 _ _ _._.. ,.,_.~, I ... ~_i ,, ~ _ ~__, ,' -+-- ~ ,~_ 7 ..~. ~- ~` ~ f~ -.. _ _.. ~,~. .. . ~- I Real-time Log Data } K2 Total 0' pav ._... _ ~.. ZPt~ ~~~1 r ~, ~,` I~ ..~ ~~ ~. ~~ ~ x~~ ALASSA OIL AI~TD GA.S CO1~T5ER~ATIOI~T CODIl-II55I01~ C. Alvord NSOD Drilling Manager ConocoPhillips Alaska Inc. PO Box 100360 Anchorage AK 99510-0360 SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Colville River Field, Fiord Oil Pool, CD3-304 ConocoPhillips Alaska Inc. Permit No: 209-028(revised) Surface Location: 3912' FNL, 738' FEL, SEC. 5, T12N, R5E Bottomhole Location: 2112' FNL, 1250' FEL, SEC. 11, T12N, R5E Dear Mr. Alvord: Enclosed is the revised approved application for permit to redrill the above referenced development well. This revision was necessary due a change in the bottomhole location greater than 500' laterally. This approval supersedes the original approval dated March 19, 2009. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). cerely, . ~ ~,, Daniel T. Searnount, Jr. Chair DATED this ~ day of April, 2009 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ~I® ,~~iaska Vii! has duns. Corrurrission 1a. Type of Work: Drill ^~ Re-drill ^ Re-entry ^ 1b. Current Well Class: Exploratory ^ Development Oil Q Stratigraphic Test ^ Service ^ Development Gas ^ Multiple Zon^ Single Zone ^~ ' 1c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ~ Blanket ^ Single Well Bond No. 59-52-180 11. Well Name and Number: CD3-304 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 17868' TVD: 6819' 12. Field/Pool(s): Colville River Field 4a. Location of Well (Governmental Section): Surface: 3912 FNL, 738 FEL, Sec. 5 , T 12 N R 5 E 7. Property Designation: ADL 372103, 372104, 372105 Fiord Oil Pool ' Tap of Productive Horizon: 2027' FNL, 1631' FEL Sec 11, T12N, R5E, UM 8. Land Use Permit: LAS2112 13. Approximate Spud Date: 4/8/2009 Total Depth: 2112' FNL, 1250' FEL Sec 11, T12N, R5E, UM 9. Acres in Property: 2560 14. Distance t Barest Property: ' FEL fro CRU Boundary ~~~~i ~~ ,Y,~: 4b. Location of Well (State Base Plane Coordinates): Surface: x- 388305 ` y- 6003860 Zone- 4 10. KB Elevation ~ tHeight above GL): 36.3 RKBL, 49.9 MSL 15. Distance to Nearest Well within Pool: CD3-305 2948' at 17709' MD 18. Deviated wells: Kickoff depth: 300' MD Maximum Hole Angle: 71.9° deg, 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3040 psig Surface: 2369 psig 18. Casing Program f Setting Depth Quantity of Cement Size Speci ications Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 62.5# H-40 Welded 77 37 37 114 114' pre-installed 12.25" 9-5/8" 40# L-80 BTC 3979 37 37 4016 2475 573 sx AS Lite, 230 sx 15.8 G 8.75" 7" 26# L-80 BTCM 17831 37 37 17868 6819 130 sx Lite Crete, 197 sx Class G, 198 Sx class G for K2 4.5" 12.6# L-80 IBT-M 17316 32 32 17348 6577 tubing 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD ND Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ^ BOP SketcQlI Drilling Progra~ Time v. Depth ' u Shallow Hazard Analysis ^/ Property Plat ^ Diverter Sketcu Seabed Repo^ 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 L. Galiunas Printed Name C. AI ord Title NSOD Drilling Manager Signature ~~ ~ ~ 1 U~rq Phon 265-6120 Date Commission Use Only Permit to Drill Number: ~~'-~)-~~ API Numbe~~r'':yy .-~ ~ 50- [!f~ ~~~~~'~~~ Permit Approval Date: - See cover letter for other requirements Conditions of approv If box is checked, well may not b`e us\ed~,to explore for, test, or produce coalbed me anejgas hydrates, or gas contained in shales: ~r,~l~c.[~~t'J~Ci.~~~ c~ G~p.<<~-~,~~5(~i(~ Aamples req'd: Yes ^o ~LrJ'' Mud log req'd: Yes ^ No [J~ Other: °~~®~~,~ rC~.t~~`5 ` H2S measures: Yes ^o ~ [/~ Directional svy req'd: Yes ^vf No ^ r7 SO ®~~ iti~ i~ihv~ Gt~,~~~Gc~~~'~- ~~~- APPROVED BY THE COMMISSION f ~ ~ / DATE: °iV / rr, arm al .r ~ ,COMMISSIONER ~~ ~ ~- ~~l Form 1001 Revised 12/2005 Submit in Duplicate CD3-304 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-1/4" Hole / 9-5/8" Casin Interval Event Risk Level Miti ation Strate Conductor Broach Low Monitor cellar continuous) Burin interval. Well Collision Low G ro sin le shots, travelin c tinder dia rams Gas Hydrates Low Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud tem eratures Running Sands and Gravel Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps.. Abnormal Pressure in Low Increased mud weight Surface Formations ° >2000' TVD Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of low densi cement slurries 8-3/4" Hole / 7" Casin 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 wei ht. Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted swee s. Abnormal Reservoir low Well control drills, increased mud weight. No Pressure mapped faults occur within 500' of the planned wellbore. Hydrogen Sulfide gas Low HzS drills, detection systems, alarms, standard well control ractices, mud scaven ers ORIGINAL Fiord: CD3-304 Procedure 1) Move on Doyon 19. 2) .Rig up riser, dewater cellar as needed. 3) Drill 12-%4" hole to the surface casing point as per the directional plan. (Directional/MWD). 4) Run and cement 9-5/8" surface casing. 5) Install and test BOPE to 3500 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 8-3/4" drilling BHA. 9) Drill 8-3/4" hole to intermediate casing point in the Kuparuk reservoir sand. (LWD Program: GR/RES/PWD/DENS/NEUT) 10) Run and cement 7" casing as per program. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. 11) Run 4'/" 12.6#, L-80 IBT Mod tubing, with XN nipple, premier packer, gas lift mandrels, and profile nipple. Space out and land hanger. 12) Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 13) Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 14) Circulate tubing to diesel and install freeze protection in the annulus. 15) Drop ball and rod, set packer and test tubing and annulus to 3500 psi / 30 mins. 16) Set BPV and secure well. Move rig off. Post rig well work will include pulling the ball and rod assembly, perforating the Kuparuk interval, and setting a wireline retrievable SSSV. ORIGINAL • Well Proximity Risks: Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD3-303 is the closest well with ellipse separation of 11' @ 576' MD. Drilling Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. ' Lost circulation: Faulting within the Kuparuk reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material is expected to be effective in dealing with lost circulation. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumping Operations: Incidental fluids developed from drilling operations on well CD3-304 will be injected into a permitted annulus on CD3 pad or the class 2 disposal well on CD1 pad. The CD3-304 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The significant hydrocarbon zone is the Qannik reservoir and by using a stage tool there will be 500' of cement fill above the top of the Qannik as per regulations. The Nanuq is not expected on CD3, but if found, will be cemented 500' above and 500' below the reservoir. Upon completion of CD3-304 form 10-403, Application for Sundry Operations, will be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080, could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C-40). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi _ (12.0 ppg) " (0.052)'` (2475') + 1,500 psi = 3044 psi Pore Pressure = 1,120 psi Therefore Differential = 3044 -1120 = 1924 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: OD Wt (ppf) Grade Range Connection Type Collapse 85% of Collapse Burst 85% of Burst 9-5/8" 40 L-80 3 BTC 9,090 psi 1,717 psi 5,750 psi 2,992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi oRiciNa~ DRILLING FLUID PROGRAM SPUD to 9-5/8"surface casing oint -12 %4" Intermediate hole to 7" casing point - 8 3/4" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg PV 10 - 25 YP 20 - 60 15 - 25 Funnel Viscosity 100 - 200 Initial Gels 4 - 8 10 minute gels <18 API Filtrate NC - 10 cc / 30 min 4 -12 cc/30 min (drilling) HPHT Fluid Loss at 160 PH 8.5-9.0 9.0-10.0 KCL Surface Hole: 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 reservoir is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. ORIGINAL #~ i Completion Schematic: CD3-304 Fiord Kuparuk Producer Completion 16" Insulated Conductor to 114' 4-'/" WL Retrievable SSSV BAL-O Landing Npl w/DB Profile (with control line) Sperry Sun Directional Plan P15 Slant Option Updated 04-06-09 9-5/8" 40 ppf L-80 BTCM Surface Casing 4016' MD / 2475' TVD Top of Cement ±/- 8694' MD / 3925' TVD K2/Qannik sand +/- 9194' MD / . 4092' TVD ES Cementer +/- g7g6' MD / 4267' TVD 71.9° Sail angle Top of intermediate cement 300' above packer depth 14800' MD / 5818' TVD Upper Completion: Top MD TVD 1) Tubing Hanger 32' 32' 2) 4-'/"", 12.6#/ft, IBT-Mod Tubing 3) 4'/:" WL R SSSV BAL-O Landing Npl 2200' 1884' (3.813")with DB Profile 4) 4-''/z"", 12.6#/ft„ IBT-Mod Tubing 5) Camco KBG-2 GLM with SOV (72°) 7000' 3400' Pinned for 2500 psi (IA to Tbg) 6) 4-%2"", 12.6#/ft„ IBT-Mod Tubing 7) Camco KBG-2 GLM with DV (72°) 14096' 5600' 8) 4-%z", 12.6#/ft„ IBT-Mod Tubing 9) Baker 4 '/:" CMU with 3.75" DB profile 15000' 5880' 10) 4 Y"", 12.6#/ft„ IBT-Mod Tubing (1jt) 11) Camco KBG-2 GLM with DV (72°) 15050' 5895' 12) 4-'/", 12.6#/ft„ IBT-Mod Tubing (1jt) 13) 4'/z" x 7" Baker Premier Packer 15100' 5911° 14) 4-'/"", 12.6#/ft„ IBT-Mod Tubing (1 jt) 15) 4'/Z" Camco 3.562" DB nipple 15150° 5927' with RHC Plug Installed 16) 4-%2"", 12.6#/ft„ IBT-Mod 17) Wireline entry guide (150' above Kup C) 17348' 6577' CMU Sliding sleeve for POGLM Kuparuk C 17498' MD / 6659' TVD Alpine 17748' MD / 6787' TVD Perforate Post Rig: +/- 17500' - 17550' (per geologist) SLB 2-7/8" Powerjet Omega 6SPF To be run post rig (with rollers ~ . And tracker on stand by). 7" 26 ppf L-80 BTC Mod Pro uction Casing @17868' MD,~TVD ~RIG4NAL CD3-304 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 (c) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size in Csg Setting Depth MD/TVD ft Fracture Gradient lbs. / al Pore pressure si ASP Drilling si 16 114 / 114 10.9 52 53 9 5/8 4016 / 2475 14.5 1120 1619 7" 17,868 / 6719 16.0 3040 2369 • NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 3500 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 ]D Where: ASP =Anticipated Surface pressure in psi FG =Fracture gradient at the casing seat in Ib/gal 0.052 =Conversion from Ib./gal to psi/ft 0.1 =Gas gradient in 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=53 psi OR ASP =FPP - (0.1 x D) = 1120 - (0.1 x 2475') = 872.5 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1] D _ [(14.5 x 0.052) - 0.1] x 2475 = 1619 psi OR ASP =FPP - (0.1 x D) = 3040 - (0.1 x 6719') = 2369 psi ORIGINAL Cementing Program: tr ~ 9 5/8" Surface Casing run to 4016' MD / 2475' TVD. Cement from 4016' MD to 3516' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 3516' to surface with Arctic Set Lite 3. Assume 250% excess annular volume in permafrost and 50% excess below the permafrost (1600' MD). Lead slurry: (3516'-1600') X 0.3132 ft3/ft X 1.5 (50% excess) = 900.1 ft3 below permafrost 1600' X 0.3132 ft3/ft X 3.5 (250% excess) = 1754 ft3 above permafrost Total volume = 900.1 + 1754 = 2655 ft3 => 573 Sx @ 4.63 ft3/sk System: 573 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.63 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% 5001 accelerator, 50% D124 extender and 9% BWOWI D044 freeze suppressant Tail slurry: 500' X 0.3132 ft3/ft X 1.5 (50% excess) = 234.9 ft3 annular volume 80' X 0.4341 ft3/ft = 34.7 ft3 shoe joint volume Total volume = 234.9 + 34.7 = 269.6 ft3 => 230 Sx @ 1.17 ft3/sk System: 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% 5001 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casino run to 17868' MD / 6719' TVD Cement from 17868' MD to 16868' MD with Class G + adds @ 15.8 PPG and from 16868' MD to 14800' MD (+/- 300' above the packer) with LiteCRETE @ 11.0 ppg. Assume 40% excess annular volume. Lead: (16868'-14800') X 0.1503 ft3/ft X 1.4 (40% excess) = 435.2 ft3 Total volume = 435.2 ft3 => 130 Sx @ 3.35 ft3/sk System: 130 Sx LiteCrete with 0.4% D046 antifoamer, 1.0 % D065 dispersant, 0.010% B155 retarder, 0.25% D167 fluid loss @ 11.0 PPG yielding 3.35 ft3/sk Tail: (17868'-16868') X 0.1503 ft3/ft X 1.4 (40% excess) = 210.4 ft3 annular vol. 80' X 0.2148 ft3/ft = 17.2 ft3 shoe joint volume Total volume = 210.4 + 17.2 = 227.7ft3 => 197 Sx @ 1.16 ft3/sk System: 197 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.16 ft3/sk Second Stage: Cement from ports in a ES stage 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: (9796'- 8694') X 0.1503 ft3/ft X 1.4 (40% excess) = 231.9 ft3 annular vol. Total Volume = 231.9 ft3 => 198 Sk @ 1.17 ft3/sk System: 198 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% 5002 accelerator @ 15.8 PPG yielding 1.17 ft3/sk ' By Weight Of mix Water, all other additives are BWOCement ORIGINAL • ConocoPhillips(Alaska) Inc. Western North Slope CD3 Fjord Pad Plan: CD3-304 Plan: CD3-304 Plan: CD3-304wp15 Standard Proposal Report 01 April, 2009 .mow NAD Z~ Sperry Qrilling Services ORIGINAL Database: EDM v16 Prod Company: ConocoPhillips(Alaska) Inc. Project: Western North Slope Site: CD3 Fjord Pad Welt Plan: CD3-304 Wellbore: Plan: CD3-304 Design: CD3-304wp15 Local Co-ordinate Reference: Well Plan: CD3-304 TVD Reference: Plan: CD3-304 (36.3+13.4) @ 49.70ft (Doyon 15 MD Reference: Plan: CD3-304 (36.3+13.4) @ 49.70ft (Doyon 15 ` North Reference: True Survey Calculation Method: Minimum Curvature , Project Western North Slope Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site CD3 Fjord Pad - - -_ Site Position: Northing: O.OOft Latitude: 53° 58' 39.152 N From: Map Easting: O.OOft Longitude: 152° 19' 23.267 W Position Uncertainty: 0.00 ft Slot Radius: Grid Convergence: -1.88 ° 'Well Plan: CD3-304 Well Position +N/S 0.00 ft Northing: 6,003,860.61 ft '' Latitude: 70° 25' 10.196 N +E/-W 0.00 ft Easting: 388,305.13 ft ' Longitude: 150° 54' 35.745 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.40ft Wellbore Plans CD3-304 Magnetics Model Name Sample Date L BGGM20 07 2/11/2009 Design CD3-3 04wp15 Audit Notes: Version: 5 Phase: Vertical Section: Depth From (TVD) (ft) 36.30 Ian Sections Measured Vertical TVD Depth Incl ination Azimuth Depth System {ft) (°) (°) (ft) ft 36.30 0.00 0.00 36.30 -13.40 300.00 0.00 0.00 300.00 250.30 500.00 4.00 115.00 499.84 450.14 900.00 16.00 115.00 893.04 843.34 2,510.56 71.94 102.48 2,008.21 1,958.51 17,301.27 71.94 102.48 6,593.62 6,543.92 17,301.51 71.94 102.47 6,593.70 6,544.00 17,498.87 68.98 102.47 6,659.70 6,610.00 17,717.67 62.42 102.47 6,749.70 6,700.00 17,867.67 62.42 102.47 6,819.16 6,769.46 Declination (°) 16.75 PLAN +Nl~ (ft) Dip Angle l°) 79.68 ConocoPhillips Standard Proposal Report Field Strength (nT) ', 57,280 J Tie On Depth: 36.30 +E/-W Direction (ftl f°) 0.00 111.00 +NlS +E/-W (ft) lftl 0.00 0.00 0.00 0.00 -2.95 6.32 -32.25 69.16 -314.64 1,102.58 -3,353.16 14,832.35 -3,353.21 14,832.57 -3,393.36 15,014.16 -3,436.40 15,208.76 -3,465.11 15,338.57 Dogleg Rate (°/100ft) 0.00 0.00 2.00 3.00 3.50 0.00 3.50 1.50 3.00 0.00 Build Turn Rate Rate .Tool Face (°/100ft) (°/100ft) (°) 0.00 0.00 0.00 0.00 0.00 0.00 2.00 0.00 115.00 3.00 0.00 0.00 3.47 -0.78 -14.33 0.00 0.00 0.00 0.17 -3.68 -87.26 -1.50 0.00 180.00 -3.00 0.00 180.00 0.00 0.00 0.00 4/1/2009 3:47:56PM Page 2 ~ ~ ~ ~II(PgS~20p3.16 Build 42F ~~~~ ~ ~~ Database: EDM v16-Prod Company: ConocoPhillips(Alaska) Inc Project: Western North Slope Site: CD3 Fjord Pad Well: Plan: CD3-304 Wellbore: Plan: CD3-304 Design: CD3-304wp15 -_ Planned Survey Measured Vertical Depth Inclination Azimuth Depth 36.30 . 0.00 0.00 36.30 100.00 0.00 0.00 100.00 200.00 0.00 0.00 200.00 r 300.00 0.00 0.00 300.00 Start Build 2.00 400.00 2.00 115.00 399.98 500.00 4.00 115.00 499.84 Start Build 3.00 600.00 7.00 115.00 599.37 700.00 10.00 115.00 698.26 800.00 13.00 115.00 796.24 900.00 16.00 115.00 893.04 Start DLS 3.50 TFO - 14.34 1,000.00 19.41 112.39 988.29 1,100.00 22.85 110.54 1,081.56 1,200.00 26.30 109.16 1,172.49 1,300.00 29.76 108.07 1,260.74 1,400.00 33.23 107.19 1,346.00 1,500.00 36.71 106.46 1,427.93 1,600.00 40.19 105.85 1,506.24 1,700.00 43.67 105.31 1,580.63 1,800.00 47.15 104.84 1,650.83 1,900.00 50.64 104.42 1,716.56 2,000.00 54.12 104.04 1,777.59 2,100.00 57.61 103.69 1,833.70 2,200.00 61.10 103.36 1,884.66 2,300.00 64.59 103.06 1,930.29 2,400.00 68.08 102.78 1,970.43 2,500.00 71.57 102.51 2,004.91 2,510.56 71.94 102.48 2,008.21 2,510.57 71.94 102.48 2,008.22 Start 14790.83 hold at 2510.57 MD 2,600.00 71.94 102.48 2,035.94 2,700.00 71.94 102.48 2,066.94 2,800.00 71.94 102.48 2,097.95 2,900.00 71.94 102.48 2,128.95 3,000.00 71.94 102.48 2,159.95 3,100.00 71.94 102.48 2,190.95 3,200.00 71.94 102.48 2,221.95 3,300.00 71.94 102.48 2,252.96 3,400.00 71.94 102.48 2,283.96 3,500.00 71.94 102.48 2,314.96 3,531.42 . 71.94 102.48 2,324.70 C-40 3,600.00 71.94 102.48 2,345.96 C ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: CD3-304 TVD Reference: Plan: CD3-304 (36.3+13.4) @ 49.70ft (Doyon 19 MD Reference: Plan: CD3-304 (36.3+13.4) @ 49.70ft (Doyon 19 North Reference: True Survey Calculation Method: Minimum Curvature Map Map TVDss +N/S +E/-W Northing Easting DLS Vert Section ft (ft) (ft) {ftl (ft) -13.40 -13.40 0.00 0.00 6,003,860.61 388,305.13 0.00 0.00 50.30 0.00 0.00 6,003,860.61 388,305.13 0.00 0.00 150.30 0.00 0.00 6,003,860.61 388,305.13 0.00 0.00 250.30 0.00 0.00 6,003,860.61 388,305.13 0.00 0.00 350.28 -0.74 1.58 6,003,859.85 388,306.70 2.00 1.74 450.14 -2.95 6.32 6,003,857.56 388,311.41 2.00 6.96 549.67 -7.00 15.01 6,003,853.38 388,320.03 3.00 16.52 648.56 -13.25 28.40 6,003,846.94 388,333.33 3.00 31.26 746.54 -21.67 46.47 6,003,838.25 388,351.27 3.00 51.15 843.34 -32.25 69.16 6,003,827.33 388,373.79 3.00 76.12 938.59 -44.41 97.02 6,003,814.76 388,401.47 3.50 106.49 1,031.86 -57.56 130.58 6,003,801.11 388,434.82 3.50 142.53 1,122.79 -71.64 169.69 6,003,786.44 388,473.72 3.50 184.10 1,211.04 -86.61 214.23 6,003,770.81 388,518.02 3.50 231.04 1,296.30 -102.42 264.01 6,003,754.26 388,567.56 3.50 283.18 1,378.23 -118.99 318.87 6,003,736.87 388,622.15 3.50 340.33 1,456.54 -136.28 378.58 6,003,718.69 388,681.60 3.50 402.28 1,530.93 -154.21 442.94 6,003,699.80 388,745.67 3.50 468.78 1,601.13 -172.72 511.69 6,003,680.27 388,814.14 3.50 539.60 1,666.86 -191.73 584.59 6,003,660.16 388,886.73 3.50 614.47 1,727.89 -211.19 661.36 6,003,639.56 388,963.20 3.50 693.11 1,784.00 -231.01 741.71 6,003,618.54 389,043.24 3.50 775.23 1,834.96 -251.13 825.35 6,003,597.18 389,126.55 3.50 860.52 1,880.59 -271.46 911.95. 6,003,575.55 389,212.84 3.50 948.67 1,920.73 -291.94 1,001.21 6,003,553.75. 389,301.78 3.50 1,039.33 1,955.21 -312.47 1,092.79 6,003,531.85 389,393.03 3.50 1,132.19 1,958.51 -314.64 1,102.58 6,003,529.53 389,402.78 3.50 1,142.10 1,958.52 -314.64 1,102.59 6,003,529.53 389,402.79 0.00 1,142.11 1,986.24 -333.02 1,185.60 6,003,509.92 389,485.52 0.00 1,226.20 2,017.24 -353.56 1,278.43 6,003,487.99 389,578.02 0.00 1,320.22 2,048.25 -374.10 1,371.26 6,003,466.06 389,670.52 0.00 1,414.25 2,079.25 -394.65 1,464.09 6,003,444.13 389,763.02 0.00 1,508.27 2,110:25 -415.19 1,556.91 6,003,422.20 389,855.52 0.00 1,602.29 2,141.25 -435.73 1,649.74 6,003,400.28 389;948.02 0.00 1,696.32 2,172.25 -456.28 1,742.57 6,003,378.35 390,040.52 0.00 1,790.34 2,203.26 -476.82 1,835.39 6,003,356.42 390,133.03 0.00 1,884.36 2,234.26 -497.36 1,928.22 6,003,334.49 390,225.53 0.00 1,978.39 2,265.26 -517.91 2,021.05 6,003,312.56 390,318.03 0.00 2,072.41 2,275.00 -524.36 2,050.21 6,003,305.67 390,347.09 0.00 2,101.95 2,296.26 -538.45 2,113.87 6,003,290.64 390,410.53 0.00 2,166.44 4/1/2009 3:47:56PM Page 3 COMPASS 2003.16 Build 42F ORIGINAL ~: ~ ~ ,. ~~ ~, ~~ _ , Database: EDM v16 Prod Company: ConocoPhillips(Alaska) Inc. Project: Western North Slope Site: CD3 Fjord Pad WeIL• Plan: CD3-304 Wellbore: Plan: CD3-304 Design: CD3-304wp15 i, Planned Survey ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: CD3-304 ND Reference: Plan: CD3-304 (36.3+13.4) @ 49.70ft (Doyon 19 MD Reference: Plan: CD3-304 (36.3+13.4) @ 49.70ft (Doyon 19 North Reference: True Survey Calculation Method: Minimum Curvature Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/S +Ei-W Northing Easting DLS Vert Section (ft} (°) (°) (ft) ft (ft) (ft) (ft) (ft) 2,327.26 3,700.00 71.94 102.48 2,376.96 2,327.26 -558.99 2,206.70 6,003,268.71 390,503.03 0.00 2,260.46 3,800.00 71.94 102.48 2,407.97 2,358.27 -579.54 2,299.53 6,003,246.78 390,595.53 0.00 2,354.48 3,900.00 71.94 102.48 2,438.97 2,389.27 -600.08 2,392.36 6,003,224.85 390,688.03 0.00 2,448.51 4,000.00 71.94 102.48 2,469.97 2,420.27 -620.62 2,485.18 6,003,202.92 390,780.53 0.00 2,542.53 4,016.23 71.94 102.48 2,475.00 2,425.30 -623.96 2,500.24 6,003,199.36 390,795.54 0.00 2,557.79 9 5/8" x 12 114" 4,063.64 71.94 102.48 2,489.70 2,440.00 -633.70 2,544.26 6,003;188.97 390,839.40 0.00 2.602.37 ~ C~0 4,100.00 71.94 102.48 2,500.97 2,451.27 -641.17 2,578.01 6,003,180.99 390,873.04 0.00 2,636.55 4,200.00 71.94 102.48 2,531.97 2,482.27 -661.71 2,670.84 6,003,159.07 390,965.54 0.00 2,730.58 4,300.00 71.94 102.48 2,562.98 2,513.28 -682.25 2,763.66 6,003,137.14 391,058.04 0.00 2,824.60 4,400.00 71.94 102.48 2,593.98 2,544.28 -702.80 2,856.49 6,003,115.21 391,150.54 0.00 2,918.62 4,500.00 71.94 102.48 2,624.98 2,575.28 -723.34 2,949.32 6,003,093.28 391,243.04 0.00 3,012.65 4,600.00 71.94 102.48 2,655.98 2,606.28 -743.89 3,042.14 6,003,071.35 391,335.54 0.00 3,106.67 4,700.00 71.94 102.48 2,686.98 2,637.28 -764.43 3,134.97 6,003,049.43 391,428.04 0.00 3,200.69 4,800.00 71.94 102.48 2,717.99 2,668.29 -784.97 3,227.80 6,003,027.50 391,520.54 0.00 3,294.72 4,900.00 71.94 102.48 2,748.99 2,699.29 -805.52 3,320.63 6,003,005.57 391,613.05 0.00 3,388.74 5,000.00 71.94 102.48 2,779.99 2,730.29 -826.06 3,413.45 6,002,983.64 391,705.55 0.00 3,482.77 5,100.00 71.94 102.48 2,810.99 2,761.29 -846.60 3,506.28 6,002,961.71 391,798.05 0.00 3,576.79 5,200.00 71.94 102.48 2,841.99 2,792.29 -867.15 3,599.11 6,002,939.78 391,890.55 0.00 3,670.81 5,300.00 71.94 102.48 2,873.00 2,823.30 -887.69 3,691.93 6,002,917.86 391,983.05 0.00 3,764.84 5,353.88 71.94 102.48 2,889.70 2,840.00 -898.76 3,741.95 6,002,906.04 392,032.89 0.00 3,815.50 C-20 5,400.00 71.94 102.48 2,904.00 2,854.30 -908.23 3,784.76 6,002,895.93 392,075.55 0.00 3,858.86 5,500.00 71.94 102.48 2,935.00 2,885.30 -928.78 3,877.59 6,002,874.00 392,168.05 0.00 3,952.88 5,600.00 71.94 102.48 2,966.00 2,916.30 -949.32 3,970.41 6,002,852.07 392,260.55 0.00 4,046.91 5,700.00 71.94 102.48 2,997.00 2,947.30 -969.86 4,063.24 6,002,830.14 392,353.06 0.00 4,140.93 5,800.00 71.94 102.48 3,028.00 2,978.30 -990.41 4,156.07 6,002,808.22 392,445.56 0.00 4,234.95 5,900.00 71.94 102.48 3,059.01 3,009.31 -1,010.95 4,248.90 6,002,786.29 392,538.06 0.00 4,328.98 6,000.00 71.94 102.48 3,090.01 3,040.31 -1,031.49 4,341.72 6,002,764.36 392,630.56 0.00 4,423.00 6,100.00 71.94 102.48 3,121.01 3,071.31 -1,052.04 4,434.55 6,002,742.43 392,723.06 0.00 4,517.02 6,200.00 71.94 102.48 3,152.01 3,102.31 -1,072.58 4,527.38 6,002,720.50 392,815.56 0.00 4,611.05 6,300.00 71.94 102.48 3,183.01 3,133.31 -1,093.12 4,620.20 6,002,698.58 392,908.06 0.00 4,705.07 6,400.00 71.94 102.48 3,214.02 3,164.32 -1,113.67 4,713.03 6,002,676.65 393,000.56 0.00 4,799.09 6,500.00 71.94 102.48 3,245.02 3,195.32 -1,134.21 4,805.86 6,002,654.72 393,093.07 0.00 4,893.12 6,600.00 71.94 102.48 3,276.02 3,226.32 -1,154.75 4,898.68 6,002,632.79 393,185.57 0.00 4,987.14 6,700.00 71.94 102.48 3,307.02 3,257.32 -1,175.30 4,991.51 6,002,610.86 393,278.07 0.00 5,081.17 6,800.00 71.94 102.48 3,338.02 3,288.32 -1,195.84 5,084.34 6,002,588.93 393,370.57 0.00 5,175.19 6,900.00 71.94 102.48 3,369.03 3,319.33 -1,216.38 5,177.16 6,002,567.01 393,463.07 0.00 5,269.21 7,000.00 .71.94 102.48 3,400.03 3,350.33 -1,236.93 5,269.99 6,002,545.08 393,555.57 0.00 5,363.24 7,100.00 71.94 102.48 3,431.03 3,381.33 -1,257.47 5,362.82 6,002,523.15 393,648.07 0.00 5,457.26 7,200.00 71.94 102.48 3,462.03 3,412.33 -1,278.01 5,455.65 6,002,501.22 393,740.57 0.00 5,551.28 7,300.00 71.94 102.48 3,493.03 3,443.33 -1,298.56 5,548.47 6,002,479.29 393,833.08 0.00 5,645.31 7,400.00 71.94 102.48 3,524.04 3,474.34 -1,319.10 5,641.30 6,002,457.37 393,925.58 0.00 5,739.33 7,500.00 71.94 102.48 3,555.04 3;505.34 -1,339.64 5,734.13 6,002,435.44 394,018.08 0.00 5,833.35 4/1/2009 3:47:56PM Page 4 COMPASS 2003.16 Build 42F i • Database: EDM v16 Prod Company: ConocoPhillips(Alaska) Inc. Project: Western North Slope Site: CD3 Fjord Pad Well: Plan: CD3-304 Wellbore: Plan: CD3-304 Design: CD3-304wp15 Planned Survey Measured Depth Inclination Azimuth 7,600.00 71.94 102.48 7,700.00 71.94 102.48 7,800.00 71.94 102.48 7,900.00 71.94 102.48 8,000.00 71.94 102.48 8,100.00 71.94 102.48 8,200.00 71.94 102.48 8,300.00 71.94 102.48 8,400.00 71.94 102.48 8,500.00 71.94 102.48 8 569.81 71.94 102.48 K~ 8,600.00 8,700.00 8,800.00 8,900.00 9,000.00 9,095.58 K-3 Basal 9,100.00 9,200.00 9,234.28 K-2 9,300.00 9,400.00 9,500.00 9,563.30 K-2 Basal 9,600.00 9,700.00 9,800.00 9,900.00 10,000.00 10,100.00 10,200.00 10,300.00 10,400.00 10,500.00 10,600.00 10,700.00 10,800.00 10,900.00 11,000.00 11,100.00 11,200.00 Vertical Depth (~) 3,586.04 3,617.04 3,648.04 3,679.05 3,710.05 3,741.05 3,772.05 3,803.05 3,834.06 3,865.06 3,886.70 TVDss ft 3,536.34 3,567.34 3,598.34 3,629.35 3,660.35 3,691.35 3,722.35 3,753.35 3,784.36 3,815.36 3,837.00 ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: CD3-304 TVD Reference: Plan: CD3-304 (36.3+13.4) @ 49.70ft (Doyon 19 MD Reference: Plan: CD3-304 (36.3+13.4) @ 49.70ft (Doyon 19 North Reference: True Survey Calculation Method: Minimum Curvature _- - - _ - -- +N/S (ft) -1,360.19 -1,380.73 -1,401.27 -1,421.82 -1,442.36 -1,462.90 -1,483.45 -1,503.99 -1,524.53 -1,545.08 -1,559.42 +E!_yy (ft) 5,826.95 5,919.78 6,012.61 6,105.43 6,198.26 6,291.09 6,383.92 6,476.74 6,569.57 6,662.40 6,727.20 Map Northing (ft) 6,002,413.51 6,002,391.58 6,002,369.65 6,002,347.72 6,002,325.80 6,002,303.87 6,002,281.94 6,002,260.01 6,002,238.08 6,002,216.16 6,002,200.85 Map Fasting (n) 394,110.58 394,203.08 394,295.58 394,388.08 394,480.59 394,573.09 394,665.59 394,758.09 394,850.59 394,943.09 395,007.67 DLS 3,536.34 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Vert Section 5,927.38 6,021.40 6,115.42 6,209.45 6,303.47 6,397.50 6,491.52 6,585.54 6,679.57 6,773.59 6,839.23 71.94 102.48 3,896.06 3,846.36 -1,565.62 6,755.22 6,002,194.23 395,035.59 0.00 6,867.61 71.94 102.48 3,927.06 3,877.36 -1,586.16 6,848.05 6,002,172.30 395,128.09 0.00 6,961.64 71.94 102.48 3,958.06 3,908.36 -1,606.71 6,940.88 6,002,150.37 395,220.60 0.00 7,055.66 71.94 102.48 3,989.07 3,939.37 -1,627.25 7,033.70 6,002,128.44 395,313.10 0.00 7,149.68 71.94 102.48 4,020.07 3,970.37 -1,647.79 7,126.53 6,002,106.51 395,405.60 0.00 7,243.71 71.94 102.48 4,049.70 4,000.00 -1,667.43 7,215.26 6,002,085.55 395,494.01 0.00 7,333.58 71.94 102.48 4,051.07 4,001.37 -1,668.34 7,219.36 6,002,084.59 395,498.10 0.00 7,337.73 71.94 102.48 4,082.07 4,032.37 -1,688.88 7,312.19 6,002,062.66 395,590.60 0.00 7,431.75 71.94 102.48 4,092.70 4,043.00 -1,695.92 7,344.01 6,002,055.14 395,622.31 0.00 7,463.99 71.94 102.48 4,113.07 4,063.37 -1,709.42 7,405.01 6,002,040.73 395,683.10 0.00 7,525.78 71.94 102.48 4,144.07 4,094.37 -1,729.97 7,497.84 6,002,018.80 395,775.60 0.00 7,619.80 71.94 102.48 4,175.08 4,125.38 -1,750.51 7,590.67 6,001,996.87 395,868.10 0.00 7,713.82 71.94 102.48 4,194.70 4,145.00 -1,763.51 7,649.42 6,001,982.99 395,926.65 0.00 7,773.34 71.94 102.48 4,206.08 4,156.38 -1,771.06 7,683.49 6,001,974.95 395,960.61 0.00 7,807.85 71.94 102.48 4,237.08 4,187.38 -1,791.60 7,776.32 6,001,953.02 396,053.11 0.00 7,901.87 71.94 102.48 4,268.08 4,218.38 -1,812.14 7,869.15 6,001,931.09 396,145.61 0.00 7,995.90 71.94 102.48 4,299.08 4,249.38 -1,832.69 7,961.97 6,001,909.16 396,238.11 0.00 8,089.92 71.94 102.48 4,330.09 4,280.39 -1,853.23 8,054.80 6,001,887.23 396,330.61 0.00 8,183.94 71.94 102.48 4,361.09 4,311.39 -1,873.77 8,147.63 6,001,865.30 396,423.11 0.00 8,277.97 71.94 102.48 4,392.09 4,342.39 -1,894.32 8,240.46 6,001,843.38 396,515.61 0.00 8,371.99 71.94 102.48 4,423.09 4,373.39 -1,914.86 8,333.28 6,001,821.45 396,608.11 0.00 8,466.01 71.94 102.48 4,454.09 4,404.39 -1,935.40 8,426.11 6,001,799.52 396,700.62 0.00 8,560.04 71.94 102.48 4,485.10 4,435.40 -1,955.95 8,518.94 6,001,777.59 396,793.12 0.00 8,654.06 71.94 102.48 4,516.10 4,466.40 -1,976.49 8,611.76 6,001,755.66 396,885.62 0.00 8,748.08 71.94 102.48 4,547.10 4,497.40 -1,997.03 8,704.59 6,001,733.74 396,978.12 0.00 8,842.11 71.94 102.48 4,578.10 4,528.40 -2,017.58 8,797.42 6,001,711.81 397,070.62 0.00 8,936.13 71.94 102.48 4,609.10 4,559.40 -2,038.12 8,890.24 6,001,689.88 397,163.12 0.00 9,030.15 71.94 102.48 4,640.11 4,590.41 -2,058.66 8,983.07 6,001,667.95 397,255.62 0.00 9,124.18 71.94 102.48 4,671.11 4,621.41 -2,079.21 9,075.90 6,001,646.02 397,348.12 0.00 9,218.20 71.94 102.48 4,702.11 4,652.41 -2,099.75 9,168.72 6,001,624.10 397,440.63 0.00 9,312.22 4/1/2009 3:47:S6PM Page 5 COMPASS 2003.16 Build 42F ORIGINAL ~~ ~` Database: EDM v16 Prod Company: ConocoPhillips(Alaska) Inc. Project: Western North Slope Site: CD3 Fjord Pad Well: Plan: CD3-304 Wellbore: Plan: CD3-304 Design: CD3-304wp15 Planned Survey ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: CD3-304 ND Reference: Plan: CD3-304 (36.3+13.4) @ 49.70ft (Doyon 19 MD Reference: Plan: CD3-304 (36.3+13.4) @ 49.70ft (Doyon 19 North Reference: True Survey Calculation Method: Minimum Curvature Measured Vertical Depth Inclination Azimuth Depth TVDss +N/-S (ft) (°) (°- (ft) ft (ft) 11,300.00 11,400.00 11,500.00 11,600.00 11,700.00 11,800.00 11,900.00 12,000.00 12,100.00 12,200.00 12,300.00 12,400.00 12,500.00 12,600.00 12,700.00 12,800.00 12,900.00 13,000.00 13,100.00 13,200.00 13,300.00 13,400.00 13,500.00 13,600.00 13,700.00 13,800.00 13,900.00 14,000.00 14,100.00 14,200.00 14,300.00 14,400.00 14,500.00 14,600.00 14,700.00 14,800.00 14,900.00 14,901.67 Albian 97 15,000.00 15,100.00 15,200.00 15,300.00 15,400.00 15,500.00 71.94 102.48 4,733.11 4,683.41 -2,120.29 71.94 102.48 4,764.11 4,714.41 -2,140.84 71.94 102.48 4,795.12 4,745.42 -2,161.38 71.94 102.48 4,826.12 4,776.42 -2,181.92 71.94 102.48 4,857.12 4,807.42 -2,202.47 71.94 102.48 4,888.12 4,838.42 -2,223.01 71.94 102.48 4,919.12 4,869.42 -2,243.55 71.94 102.48 4,950.13 4,900.43 -2,264.10 71.94 102.48 4,981.13 4,931.43 -2,284.64 71.94 102.48 5,012.13 4,962.43 -2,305.18 71.94 102.48 5,043.13 4,993.43 -2,325.73 71.94 102.48 5,074.13 5,024.43 -2,346.27 71.94 102.48 5,105.14 5,055.44 -2,366.81 71.94 102.48 5,136.14 5,086.44 -2,387.36 71.94 102.48 5,167.14 5,117.44 -2,407.90 71.94 102.48 5,198.14 5,148.44 -2,428.44 71.94 102.48 5,229.14 5,179.44 -2,448.99 71.94 102.48 5,260.15 5,210.45 -2,469.53 71.94 102.48 5,291.15 5,241.45 -2,490.07 71.94 102.48 5,322.15 5,272.45 -2,510.62 71.94 102.48 5,353.15 5,303.45 -2,531.16 71.94 102.48 5,384.15 5,334.45 -2,551.70 71.94 102.48 5,415.15 5,365.45 -2,572.25 71.94 102.48 5,446.16 5,396.46 -2,592.79 71.94 102.48 5,477.16 5,427.46 -2,613.33 71.94 102.48 5,508.16 5,458.46 -2,633.88 71.94 102.48 5,539.16 5,489.46 -2,654.42 71.94 102.48 5,570.16 5,520.46 -2,674.96 71.94 102.48 5,601.17 5,551.47 -2,695.51 71.94 102.48 5,632.17 5,582.47 -2,716.05 71.94 102.48 5,663.17 5,613.47 -2,736.60 71.94 102.48 5,694.17 5,644.47 -2,757.14 71.94 102.48 5,725.17 5,675.47 -2,777.68 71.94 102.48 5,756.18 5,706.48 -2,798.23 71.94 102.48 5,787.18 5,737.48 -2,818.77 71.94 102.48 5,818.18 5,768.48 -2,839.31 71.94 102.48 5,849.18 5,799.48 -2,859.86 71.94 102.48 5,849.70 5,800.00 -2,860.20 Map Map +El-W Northing Easting DLS Vert Section (ft) (ft) (ft) 4,683.41 9,261.55 6,001,602.17 397,533.13 0.00 9,406.25 9,354.38 6,001,580.24 397,625.63 0.00 9,500.27 9,447.21 6,001,558.31 397,718.13 0.00 9,594.30 9,540.03 6,001,536.38 397,810.63 0.00 9,688.32 9,632.86 6,001,514.45 397,903.13 0.00 9,782.34 9,725.69 6,001,492.53 397,995.63 0.00 9,876.37 9,818.51 6,001,470.60 398,088.13 0.00 9,970.39 9,911.34 6,001,448.67 398,180.64 0.00 10,064.41 10,004.17 6,001,426.74 398,273.14 0.00 10,158.44 10,096.99 6,001,404.81 398,365.64 0.00 10,252.46 10,189.82 6,001,382.89 398,458.14 0.00 10,346.48 10,282.65 6,001,360.96 398,550.64 0.00 10,440.51 10,375.48 6,001,339.03 398,643.14 0.00 10,534.53 10,468.30 6,001,317.10 398,735.64 0.00 10,628.55 10,561.13 6,001,295.17 398,828.14 0.00 10,722.58 10,653.96 6,001,273.24 398,920.65 0.00 10,816.60 10,746.78 6,001,251.32 399,013.15 0.00 10,910.63 10,839.61 6,001,229.39 399,105.65 0.00 11,004.65 10,932.44 6,001,207.46 399,198.15 0.00 11,098.67 11,025.26 6,001,185.53 399,290.65 0.00 11,192.70 11,118.09 6,001,163.60 399,383.15 0.00 11,286.72 11,210.92 6,001,141.68 399,475.65 0.00 11,380.74 11,303.75 6,001,119.75 399,568.15 0.00 11,474.77 11,396.57 6,001,097.82 399,660.66 0.00 11,568.79 11,489.40 6,001,075.89 399,753.16 0.00 11,662.81 11,582.23 6,001,053.96 399,845.66 0.00 11,756.84 11,675.05 6,001,032.03 399,938.16 0.00 11,850.86 11,767.88 6,001,010.11 400,030.66 0.00 11,944.88 11,860.71 6,000,988.18 400,123.16 0.00 12,038.91 11,953.53 6,000,966.25 400,215.66 0.00 12,132.93 12,046.36 6,000,944.32 400,308.16 0.00 12,226.95 12,139.19 6,000,922.39 400,400.67 0.00 12,320.98 12,232.02 6,000,900.47 400,493.17 0.00 12,415.00 12,324.84 6,000,878.54 400,585.67 0.00 12,509.03 12,417.67 6,000,856.61 400,678.17 0.00 12,603.05 12,510.50 6,000,834.68 400,770.67 0.00 12,697.07 12,603.32 6,000,812.75 400,863.17 0.00 12,791.10 12,604.87 6,000,812.39 400,864.72 0.00 12,792.67 71.94 102.48 5,880.18 5,830.48 -2,880.40 12,696.15 6,000,790.82 400,955.67 0.00 12,885.12 71.94 102.48 5,911.19 5,861.49 -2,900.94 12,788.98 6,000,768.90 401,048.17 0.00 12,979.14 71.94 102.48 5,942.19 5,892.49 -2,921.49 12,881.80 6,000,746.97 401,140.68 0.00 13,073.17 71.94 102.48 5,973.19 5,923.49 -2,942.03 12,974.63 6,000,725.04 401,233.18 0.00 13,167.19. 71.94 102.48 6,004.19 5,954.49 -2,962.57 13,067.46 6,000,703.11 401,325.68 0.00 13,261.21 71.94 102.48 6,035.19 5,985.49 -2,983.12 13,160.28 6,000,681.18 401,418.18 0.00 13,355.24 4/1/2009 3:47:56PM Page 6 COMPASS 2003.16 Build 42F ORIGINAL Database: EDM v16 Prod Company: ConocoPhillips(Alaska) Inc. Project: Western North Slape Site: CD3 Fjord Pad Well: Plan: CD3-304 Wellbore: Plan: CD3-304 Design: CD3-304wp15 r Planned Survey Measured Vertical Depth Incli nation Azimuth Depth NDss +N/S +E/-W (ft) (°) (°? (ft) ft (ft) (ft) 15,600.00 71.94 102.48 6,066.20 6,016.50 -3,003.66 13,253.11 15,659.69 71.94 102.48 6,084.70 6,035.00 -3,015.92 13,308.52 Albian 96 (Nanuq) 15,700.00 71.94 102.48 6,097.20 6,047.50 -3,024.20 13,345.94 15,800.00 71.94 102.48 6,128.20 6,078.50 -3,044.75 13,438.77 15,900.00 71.94 102.48 6,159.20 6,109.50 -3,065.29 13,531.59 16,000.00 71.94 102.48 6,190.20 6,140.50 -3,085.83 13,624.42 16,100.00 71.94 102.48 6,221.21 6,171.51 -3,106.38 13,717.25 16,200.00 71.94 102.48 6,252.21 6,202.51 -3,126.92 13,810.07 16,300.00 71.94 102.48 6,283.21 6,233.51 -3,147.46 13,902.90 16,400.00 71.94 102.48 6,314.21 6,264.51 -3,168.01 13,995.73 16,500.00 71.94 102.48 6,345.21 6,295.51 -3,188.55 14,088.55 16,600.00 71.94 102.48 6,376.22 6,326.52 -3,209.09 14,181.38 16,649.95 71.94 102.48 6,391.70 6,342.00 -3,219.35 14,227.75 Top HRZ 16,700.00 71.94 102.48 6,467.22 6,357.52 -3,229.64 14,274.21 16,800.00 71.94 102.48 6,438.22 6,388.52 -3,250.18 14,367.04 16,900.00 71.94 102.48 6,469.22 6,419.52 -3,270.72 14,459.86 17,000.00 71.94 102.48 6,500.22 6,450.52 -3,291.27 14,552.69 17,014.44 71.94 102.48 6,504.70 6,455.00 -3,294.23 14,566.09 Base HRZ 17,100.00 71.94 102.48 6,531.23 6,481.53 -3,311.81 14,645.52 17,166.04 71.94 102.48 6,551.70 6.502.00 -3,325.38 14,706.82 K-1 17,200.00 71.94 102.48 6,562.23 6,512.53 -3,332.35 14,738.34 17,300.00 71.94 102.48 6,593.23 6,543.53 -3,352.90 14,831.17 17,301.27 71.94 102.48 6,593.62 6,543.92 -3,353.16 14,832.35 17,301.50 71.94 102.48 6,593.69 6,543.99 -3,353.20 14,832.56 Start DLS 1. 50 TFO 1 80.00 17,301.51 71.94 102.47 6,593.70 6,544.00 -3,353.21 14.832.57 CD3-304wp14 Top Kuaruk 17,301.52 71.94 102.47 6,593.70 6.544.00 -3,353.21 14,832.58 Kuparuk D 17,400.00 70.46 102.47 6,625.43 6,575.73 -3,373.34 14,923.61 17,436.20 69.92 102.47 6,637.70 6,588.00 -3,380.69 14,956.86 Kuparuk C 17,498.86 68.98 102.47 6,659.70 6,610.00 -3,393.36 15,014.15 Start DLS 3. 00 TFO 1 80.00 17,498.87 68.98 102.47 6,659.70 6.610.00 -3,393.36 15.014.16 LCU 17,500.00 68.95 102.47 6,660.11 6,610.41 -3,393.59 15,015.19 17,600.00 65.95 102.47 6,698.46 .6,648.76 -3,413.53 15,105.35 17,700.00 62.95 102.47 6,741.59 6,691.89 -3,433.01 15,193.43 17,717.66 62.42 102.47 6,749.69 6,699.99 -3,436.40 15,208.75 Start 150.00 hold at 17717.66 MD ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: CD3-304 ND Reference: Plan: CD3-304 (36.3+13.4) @ 49.70ft (Doyon 19 MD Reference: Plan: CD3-304 (36.3+13.4) @ 49.70ft (Doyon 19 North Reference: True Survey Calculation Method: Minimum Curvature Map Map Northing Easting DLS Vert Section (ft) (ft) 6,016.50 6,000,659.26 401,510.68 0.00 13,449.26 6,000.646.17 401,565.89 0.00 13,505.38 6,000,637.33 401,603.18 0.00 13,543.28 6,000,615.40 401,695.68 0.00 13,637.31 6,000,593.47 401,788.18 0.00 13,731.33 6,000,571.54 401,880.69 0.00 13,825.36 6,000,549.62 401,973.19 0.00 13,919.38 6,000,527.69 402,065.69 0.00 14,013.40 6,000,505.76 402,158.19 0.00 14,107.43 6,000,483.83 402,250.69 0.00 14,201.45 6,000,461.90 402,343.19 0.00 14,295.47 6,000,439.97 402,435.69 0.00 14,389.50 6,000,429.02 402,481.90 0.00 14,436.46 6,000,418.05 402,528.19 0.00 14,483.52 6,000,396.12 402,620.70 0.00 14,577.54 6,000,374.19 402,713.20 0.00 14,671.57 6,000,352.26 402,805.70 0.00 14,765.59 6,000,349.10 402,819.06 0.00 14,779.17 6,000,330.33 402,898.20 0.00 14,859.61 6,000,315.85 402,959.29 0.00 14,921.71 6,000,308.41 402,990.70 0.00 14,953.64 6,000,286.48 403,083.20 0.00 15,047.66 6,000,286.20 403,084.38 0.00 15,048.85 6,000,286.15 403,084.59 0.00 15,049.07 6,000,286.15 403,084.60 68.93 15,049.08 6,000.286.14 403,084.61 0.00 15,049.09 6,000,264.66 403,175.31 1.50 15,141.28 6, 000,256.81 403,208.45 1.50 15,174.96 6,000,243.28 403,265.54 1.50 15,232.98 6,000,243.28 403,265.55 1.50 15,233.00 6,000,243.04 403,266.57 3.00 15,234.04 6,000,221.75 403,356.42 3.00 15,325.36 6,000,200.96 403,444.19 3.00 15,414.57 6,000,197.34 403,459.46 3.00 15,430.09 4/1/2009 3:47:56PM Page 7 COMPASS 2003.16 Build 42F OR161NAL s • ConocoPhillips ~ ~ ~"` `~ ~~"~ry Standard Proposal Report ~ ~~ ~ Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan: CD3-304 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Plan: CD3-304 (36.3+13.4) @ 49.70ft (Doyon 19 Project: Western North Slope MD Reference: Plan: CD3-304 (36.3+13.4) @ 49.70ft (Doyon 19 Site: CD3 Fjord Pad North Reference: True WeIL• Plan: CD3-304 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD3-304 Design: CD3-304wp15 Planned Survey Measured Vertical Map Depth Inclination Azimuth Depth TVDss +N/S +E/-W Northing (ft} (°) (°) (ft) ft (ft) (ft1 (ft) 17,717.67 62.42 102.47 6,749.70 6,700.00 -3,436.40 15.208.76 6,000,197.34 Top Alpine 17,800.00 62.42 102.47 6,787.82 6,738.12 -3,452.16 15,280.01 6,000,180.52 17,867.66 62.42 102.47 6,819.15 6,769.45 -3,465.10 15,338.56 6,000,166.70 TD at 17867.66 - 7" x 8-3/4" 17,867.67 62.42 102.47 6,819.16 ~ 6,769.46 -3,465.11 15,338.57 6,000,166.70 Targets Target Name Map Fasting DLS Vert Section (ft1 s,7oa.oo 403,459.47 3.00 15,430.10 403,530.47 0.00 15,502.26 403,588.82 0.00 15,561.56 403,588.83 0.01 15,561.58 - hitlmiss target Dip Angle Dip Dir. TVD +N/S +E/-W Northing Fasting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) CD3-304wp14 Top Kuaruk 0.00 6,593.70 -3,353.21 14,832.57 6,000,286.15 403,084.60 - plan hits target - Point Casing Paints Measured Vertical Casing Hole ~ Depth Depth l Diameter Diameter i fft1 (ft1 Name ("1 (") 4,016.23 2,475.00 9 5/8" x 12 1/4" 9-5/8 12-1/4 17,867.66 6,819.15 7" x 8-3/4" 7 8-3/4 Formations Measured Vertical Vertical I DIP Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (°) (°) 3,531.42 2,324.70 C~0 8,569.81 3,886.70 K-3 17,436.20 6,637.70 Kuparuk C 17,166.04 6,551.70 K-1 17,014.44 6,504.70 Base HRZ 16,649.95 6,391.70 Top HRZ 5,353.88 2,889.70 C-20 9,095.58 4,049.70 K-3_Basal 17,301.52 6,593.70 Kuparuk D 9,234.28 4,092.70 K-2 4,063.64 2,489.70 C-30 14,901.67 5,849.70 Albian 97 9,563.30 4,194.70 K-2_Basal 17,717.67 6,749.70 Top Alpine 0.00 17,498.87 6,659.70 LCU 0.00 15,659.69 6,084.70 Albian 96 (Nanuq) 4/1/2009 3:47:56PM Page 8 COMPASS 2003.16 Burld 42F ORIGINAL Database: EDM v16 Prod Company: ConocoPhillips(Alaska) Inc Project: Western North Slope Site: CD3 Fjord Pad WeIL• Plan: CD3-304 Wellhore: Plan: CD3-304 Design: CD3-304wp15 Plan Annotations Measured Vertical Local Coordinates Depth Depth +NI-S +E/-W (ft) (ft) (ft) (ft) Comment 300.00 300.00 0.00 0.00 Start Build 2.00 500.00 499.84 -2.95 6.32 Start Build 3.00 900.00 893.04 -32.25 69.16 Start DLS 3.50 TFO -14.34 2,510.57 2,008.22 -314.64 1,102.59 Start 14790.83 hold at 2510.57 MD 17,301.50 6,593.69 -3,353.20 14,832.56 Start DLS 1.50 TFO 180.00 17,498.86 6,659.70 -3,393.36 15,014.15 Start DLS 3.00 TFO 180.00 17,717.66 6,749.69 -3,436.40 15,208.75 Start 150.00 hold at 17717.66 MD 17,867.66 6,819.15 -3,465.10 15,338.56 TD at 17867.66 Local Co-ordinate Reference: Well Plan: CD3-304 ND Reference: Plan: CD3-304 (36.3+13.4) @ 49.70ft (Doyon 19 MD Reference: Plan: CD3-304 (36.3+13.4) @ 49.70ft (Doyon 19 North Reference: True Survey Calculation Method: Minimum Curvature ConocoPhillips Standard Proposal Report 4/1/2009 3:47:S6PM Page 9 COMPASS 2003.16 Build 42F ~~. ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD3 Fiord Pad Plan: CD3-304 Plan: CD3-304 CD3-304wp15 Clearance Summary a Anticollision Report 31 March, 2009 Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad -Plan: CD3-304 -Plan: CD3-304 -CD3-304wp15 Well Coordinates: 6,003,607.82 N, 1,528,337.04E (70° 25' 09.03" N, 150° 54' 47.12" 1N) Datum Height: Plan: CD3-304 (36.3+13.4) ~ 49.70ft (Doyon 19) Scan Range: 0.00 to 17,867.66 ft. Measured Depth. Scan Radius is 1,983.14 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied ~ Version: 2003.16 Build: 42F Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 LL~~.~ ~ _ .~_ y Sperry grilling Services ORIGINAL CD3-302PB1 GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference CD3-304wp15 36.30 To 17867.66 CD3-302 CD3-302PB3 CD3-3b2PB2 ~ CD3-301 CD3-307 CD3-108 ~ CD3-303 ~' ~~,, ~~ CD3-301PB1 CD3-107L1 ~~~, ~ 0/~fi0 -_ ~~ CD3-107 ---- ---- -301330 ~'~ ~~ ~~:~`'~ 30 CD3-110 {,- CD3-109 - ---------- --_ ~ ~`; 20 CD3-111 L1 1I', "~ 11 S f ! ~ 60 CD3-11 ~~~ -60 / 300. , ~` ~ ~ I~ ~ ,, i ~;' ~ ~ CD3-112 ~~ `~ ~ ~ ~~~ ~ _~ t ~~ r o ~ ~~ CD3-114 r ~ ~ CD3-113 ~ ~ ,~ ~`~ ' -90 ~ 270 e~' .~11~, `' 80 CD3-316APB1 ~F' ~ ~.- ~ '~~~ ~._ ~' ~ ~~ ~ CD3-115 l~ r', ~. ,,, ;- ~ ~,-~, , ~ - I ~, i) t , CD3-316A ~`~"~' ~.Vi~l f ~~ 10 CD3-316 _120 / 240 ~ ` _ ~`~ ~ 120 CD3-305 //'~ ~,~ CD3-305PB1 ~f `~ 200 -150 / 210 ~ I 150 l -180 / 180 CD3-306 (wp01) Travelling Cylinder Azimuth (TFO+AZI) [9 vs Centre to Centre Separation [100 ftlin] -120 / 240'. Ellipsoid Color 36 250 1750 """ 2000 5000 -- ------ 6000 14000 1600 250 500 2000 """'2500 6000 7000 16000 1800 500 750 2500 3000 7000 8000 18000 "" '""""""" 2000 750 - 1000 3000 3500 8000 9000 20000 2500 1000 1250 3500 4000 9000 - 10000 1250 - 1500 4000 4500 10000 12000 1500 1750 4500 5000 12000 14000 CD3-303 0 / 360 . ~% -30 / 330 `~ r 30 '~ \ .',~ CD3-302PB3 ,~- ~~~ ~~ ,CD3-302PB2 i ~~ ~~; 60 ~ -~A, - " CD3-302PB1 ~~ ~ ~ F, ~ CD3-302 _~ -150/2 -180 / 180 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre Separarion [25 ft/in] -60/~ GD3-305PB1 CD3-305 -90 / 270 F-~~ ~ ~ i f HALLI~URTON Anticollision Report for Plan: CD3-304 -CD3-304wp15 ConocoPhillips(Alaska) Inc. -WNS Western North Slope Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad -Plan: CD3-304 -Plan: CD3-304 -CD3-304wp15 Scan Range: 0.00 to 17,867.66 ft. Measured Depth. Scan Radius is 1,983.14 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on ',Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name -Design (ft) (ft) (ft) (ft) ft CD3 Fiord Pad CD3-107 -CD3-107 -CD3-107 374.16 57.33 374.16 49.39 375.00 7.222 Centre Distance Pass -Major Risk CD3-107 -CD3-107 -CD3-107 472.63 58.23 472.63 48.25 474.97 5.837 Clearance Factor Pass -Major Risk CD3-107 -CD3-107L1 -CD3-107L1 373.95 57.33 373.95 49.39 375.00 7.226 Centre Distance Pass -Major Risk CD3-107 -CD3-107L1 -CD3-107L1 472.45 58.23 472.45 48.25 475.00 5.838 Clearance Factor Pass -Major Risk CD3-107 -CD3-307 -CD3-307 374.01 57.33 374.01 49.39 375.00 7.225 Centre Distance Pass -Major Risk CD3-107 -CD3-307 -CD3-307 472.51 58.23 472.51 48.25 475.00 5.838 Clearance Factor Pass -Major Risk CD3-108 -CD3-108 -CD3-108 445.35 75.75 445.35 67.48 450.00 9.157 Centre Distance Pass -Major Risk CD3-108 -CD3-108 -CD3-108 542.32 76.66 542.32 66.57 550.00 7.595 Clearance Factor Pass -Major Risk CD3-109 -CD3-109 -CD3-109 36.40 99.79 36.40 98.88 36.30 109.272 Centre Distance Pass -Major Risk CD3-109 -CD3-109 -CD3-109 684.95 104.32 684.95 90.44 700.00 7.516 Clearance Factor Pass -Major Risk CD3-110 -CD3-110 -CD3-110 421.04 117.58 421.04 108.72 425.00 13.265 Centre Distance Pass -Major Risk CD3-110 -CD3-110 -CD3-110 517.28 118.56 517.28 107.83 525.00 11.046 Clearance Factor Pass -Major Risk CD3-111 -CD3-111 -CD3-111 36.40 139.62 36.40 138.71 36.10 152.879 Centre Distance Pass -Major Risk CD3-111 -CD3-111 -CD3-111 324.35 142.34 324.35 135.49 325.00 20.775 Clearance Factor Pass -Major Risk CD3-111 -CD3-111 L1 -CD3-111 L1 36.40 139.62 36.40 138.71 36.10 152.879 Centre Distance Pass -Major Risk CD3-111 -CD3-111 L1 -CD3-111 L1 324.35 142.34 324.35 135.49 325.00 20.775 Clearance Factor Pass -Major Risk CD3-112 -CD3-112 -CD3-112 225.39 158.86 225.39 154.16 225.00 33.816 Centre Distance Pass -Major Risk CD3-112 -CD3-112 -CD3-112 300.00 159.45 300.00 153.13 300.00 25.233 Clearance Factor Pass -Major Risk CD3-113 -CD3-113 -CD3-113 36.60 180.22 36.60 179.30 36.80 196.775 Centre Distance Pass -Major Risk CD3-113 -CD3-113 -CD3-113 395.16 181.27 395.16 172.85 400.00 21.548 Clearance Factor Pass -Major Risk CD3-114 -CD3-114 -CD3-114 36.40 199.92 36.40 199.01 36.75 218.912 Centre Distance Pass -Major Risk CD3-114 -CD3-114 -CD3-114 370.77 200.93 370.77 193.04 375.00 25.487 Clearance Factor Pass -Major Risk CD3-115 -CD3-115 -CD3-115 299.70 219.78 299.70 213.46 300.00 34.801 Centre Distance Pass -Major Risk CD3-115 -CD3-115 -CD3-115 370.46 220.61 370.46 212.73 375.00 28.012 Clearance Factor Pass -Major Risk CD3-301 -CD3-301 -CD3-301 149.48 60.07 149.48 57.00 150.00 19.601 Centre Distance Pass -Major Risk CD3-301 -CD3-301 -CD3-301 552.06 62.18 552.06 50.37 550.00 5.263 Clearance Factor Pass -Major Risk CD3-301 -CD3-301 P61 -CD3-301 PB1 149.48 60.07 149.48 57.00 150.00 19.601 Centre Distance Pass -Major Risk CD3-301 -CD3-301 PB1 -CD3-301 PB1 552.06 62.18 552.06 50.37 550.00 5.263 Clearance Factor Pass -Major Risk 31 March, 2009 - 10:34 Page 2 of 6 COMPASS ~~ , ~~ HA~L~BUr~TON Anticollision Report for Plan: CD3-304 -CD3-304wp15 ConocoPhillips(Alaska) Inc. -WNS Western North Slope Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad -Plan: CD3-304 -Plan: CD3-304 -CD3-304wp15 Scan Range: 0.00 to 17,887.66 ft. Measured Depth. Scan Radius is 1,983.14 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name- Welibore Name- Design (ft) (ft) (ft) (ft) ft CD3-302 -CD3-302 -CD3-302 174.70 40.15 174.70 36.55 175.00 11.141 Centre Distance Pass -Major Risk CD3-302 -CD3-302 -CD3-302 249.70 40.79 249.70 35.56 250.00 7.797 Clearance Factor Pass -Major Risk CD3-302 -CD3-302PB1 -CD3-302PB1 174.30 40.15 174.30 36.56 175.00 11.168 Centre Distance Pass -Major Risk CD3-302 -CD3-302PB1 -CD3-302PB1 249.30 40.78 249.30 35.56 250.00 7.808 Clearance Factor Pass -Major Risk CD3-302 -CD3-302PB2 -CD3-302P62 174.30 40.15 174.30 36.56 175.00 11.168 Centre Distance Pass -Major Risk CD3-302 -CD3-302P62 -CD3-302PB2 249.30 40.78 249.30 35.56 250.00 7.808 Clearance Factor Pass -Major Risk CD3-302 -CD3-302P63 -CD3-302PB3 174.70 40.15 174.70 36.55 175.00 11.141 Centre Distance Pass -Major Risk CD3-302 -CD3-302P63 -CD3-302PB3 249.70 40.79 249.70 35.56 250.00 7.797 Clearance Factor Pass -Major Risk CD3-303 -CD3-303 -CD3-303 36.40 20.24 36.40 19.32 36.35 22.159 Centre Distance Pass -Major Risk CD3-303 -CD3-303 -CD3-303 576.27 23.22 576.27 10.99 575.00 1.900 Clearance Factor Pass -Major Risk CD3-305 -CD3-305 -CD3-305 324.17 19.10 324.17 12.85 325.00 3.055 Centre Distance Pass -Major Risk CD3-305 -CD3-305 -CD3-305 398.73 19.98 398.73 12.27 400.00 2.591 Clearance Factor Pass -Major Risk CD3-305 -CD3-305PB1 -CD3-305P61 324.17 19.10 324.17 12.85 325.00 3.055 Centre Distance Pass -Major Risk CD3-305 -CD3-305PB1 -CD3-305P61 398.73 19.98 398.73 12.27 400.00 2.591 Clearance Factor Pass -Major Risk CD3-316 -CD3-316 -CD3-316 250.19 238.19 250.19 232.95 250.00 45.489 Centre Distance Pass -Major Risk CD3-316 -CD3-316 -CD3-316 323.66 238.73 323.66 231.89 325.00 34.902 Clearance Factor Pass -Major Risk CD3-316 -CD3-316A -CD3-316A 250.19 238.19 250.19 232.95 250.00 45.489 Centre Distance Pass -Major Risk CD3-316 -CD3-316A -CD3-316A 323.66 238.73 323.66 231.89 325.00 34.902 Clearance Factor Pass -Major Risk CD3-316 -CD3-316APB1 -CD3-316APB1 250.19 238.19 250.19 232.95 250.00 45.489 Centre Distance Pass -Major Risk CD3-316 -CD3-316APB1 -CD3-316APB1 323.66 238.73 323.66 231.89 325.00 34.902 Clearance Factor Pass -Major Risk Plan: CD3-306 -Plan: CD3-306 -CD3-306 (wp01) 276.10 39.84 276.10. 34.10 275.00 6.943 Centre Distance Pass -Major Risk Plan: CD3-306 -Plan: CD3-306 -CD3-306 (wp01) 572.75 42.18 572.75 29.96 575.00 3.452 Clearance Factor Pass -Major Risk CD4 Nanuq Pad 31 March, 2009 - 10.34 Page 3 of 6 COMPASS ~~.~~~~ ~ ~~ ~ • • ConocoPhillips(Alaslca) Inc. -WNS - -- • Western North Slope Anticollision Report for Plan: CD3-304 -CD3-304wp15 Survey tool program From To Survey/Plan Survey Tool (ft) (ft) 36.30 1,000.00 CD3-304wp15 CB-GYRO-SS 1,000.00 17,867.66 CD3-304wp15 MWD+IFR-AK-CAZ-SC Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor =Distance Between Profiles / (Distance Between Profiles -Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. r ~ ~J C 31 March, 2009 - 10:34 Page 4 of 6 COMPASS ^a~siNa~ ConocoPhillips(Alaska) Inc. -WNS HAL~IBURTON Western North Slope Anticollision Report for Plan: CD3-304 -CD3-304wp15 Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to Plan: CD3-304 (36.3+13.4) @ 49.70ft (Doyon 19). Northing and Easting are relative to Plan: CD3-304. Coordinate System is US State Plane 1983, Alaska Zone 4. Central Meridian is -150.00°, Grid Convergence at Surtace is: -0.86 °. La~dr -~- C31 r-• ~ C 1800 O O fD C O .~ CO 1200 s1 (17 Q) a--~ C 0 60C +-~ Q) C i ~ ~ i ~ i i i ~ i -~ i i i i i i i i -~_ -fir ~ i ~ i i i i i i i i i i i i i $. i i ~ ~ i i i i i i i i i i -~- ~ ~ ~ ~ ~ $ i i i r i i i i i i -~ i i i i _~ i i i i i i i ~ ~ i i i i i $ i i i i i ~- i i i i ~ i i i i ~_ i i i i i - -- t -~----- - ~----- ----I ----' ----' - ~------ ~----- - ~--- ~- ---! i i ~ i ~ i i i ~ -~ i i i i i i i i i i ~_ i ( 7 30 00 60 00 90 00 12000 10 00 -e- Measured Depth X3000 ftfin) -~-" i~F 03.302, CD3-302PB3, CD3-302PB3 kf2 D3-302, CD3-302, CD3-3D2 V3 D3-3 D2, CD3-302PB1, CD3-3D2P@1 V11 D3-3 D2, CD3-302PB2, CD3-3D2P82 VB D3-1 D9, CD3.109, CD3-1 D9 V5 D3-111, CD3.111L1,CD3-111L1 V1 D3-111, CD3-111, CD3.111 V7 Ian:CD4.303,PIan:CD4-3035T1,CD4.3D35T1wp0 ^3-112, CD3-1 12, CD3.112 V3 03-1 10, CD3-1 1 D, CD3-1 10 V12 D3-115, CD3-1 15, CD3.115 WO D3.113, CD3-113, CD3.113 V6 03.108, CD3-108, CD3.108 U14 D3-316, CD3.316, CD3.316 VD D3-316,CD3.316AP@1,C03-316APB1 W D3-31 6, CD3-31 6A, CD3-31 6A VO ^3-1D7,CD3-1D7L1,CD3-1D7L1 W D3.1D7, CD3-307, CD3.3D7 V4 D3-107, CD3-107, CD3.107 V7 relim:2N-Cairn DD0,2N-Cairn ODO-A,2N-Cairn DD D3-3D3, CD3-303, CD3.3D3 VD D3-3D1,CD3-301PBi,CD3-301PB1 V1 D3-3D 1, CD3-301,CD3.3D1 V4 D3.114, CD3-114, CD3-114 U14 Ian:CD3.3DB,PIan:CD3.306,CD3-306 (wp01)V14 ^3-305, CD3-305, CD3.3D5 VD rn't_zn,s rnz.nn~aai r•n't.~nRaai am • • 31 March, 2009 - 10:34 Page 5 of 6 COMPASS ConocoPhillips(Alaska) Inc. -WNS HAL~.~BUR1-~~ Western North Slope Anticollision Report for Plan: CD3-304 -CD3-304wp15 Clearance Factor Plot: Measured Depth versus Separation(Clearance) Factor 10.00 8.i X7.50 C 0 ~6.'_' S a to o ~.~~ n U,a.75 _.50 i.25 0.170 ~ - 4 _ - { 4.... E -- ~~ - I - I I ~. ' . ~' t ~ i ----- . . -.. _- - ~ -- ._I - -~-- __ .--.._ -_ ___ I - . J.. _ ~.7 ' ~ ~~ i I ~ ~ ~I .yl I , :; ~ = _ , li ~~ E I - ~ , - ,~ ~ 1.~ ' ~ s I ~ ~ i ~~ .d I~ i a -- t- ~ ., .,. ,,, _ °, k i , e_ , i x f rt- i _.. Y... , I ~ i ~ ~ i i ~ ~ I I ~ ~ ° ~. L' ~~ __- - i _. -__ i s I -- , ~ ~ s -- ~ i i { _'._ ~ ... I ~ . i 4 { 0 1250 ~Suu J750 5007 G50 7500 8'60 1000D 11'.50 1::500 i'.3750 15000 Measured Depth (2500 ftfin) CD3.302, CD3-302P B3, CD3-3D2P B3 t!2 CD3.302, CD3-302, CD3-3D2 V3 CD3.3D2,CD3-302PB1,CD3-3D2PB1 V11 C 03.3D2 ,CD3-302 P B2, CD3-302 P 82 VB CD3.1D9, CD3-109, CD3-1D9 V5 CD3-111,CD3.111L1,CD3-111 L1 V1 CD3.111,CD3.111, CD3-111 V7 Plan: CD43D3, PIan:CD4-3D3ST1,CD4-3D3ST1wpD6 V7 CD3-112, CD3.112, CD3.112 V3 CD3-110, CD3-110, CD3.11D V12 CD3-115, CD3-115, CD3-115 VD CD3-113, CD3-113, CD3.113 VB CD3-108, CD3-1D8, CD3-1D8 V14 CD3.316, CD3-316, CD3-316 VD CD3.316,CD3-316APB1,CD3-316APB1 VD CD3-316, C D3.316A, C D3-316A VD CD3.1D7,CD3.1D7L1, CD3.107L1 VD CD3.107, CD3-3 D7, CD3-307 V4 CD3.1D7, CD3-107, CD3-1 D7 V7 Prelim:2N-CairnDD0,3N-CairnDDD-A, 2N-CairnDD4-A(i CD3.3D3, CD3-303, CD3-3D3 VD CD3.301,CD3-3D1PB1,CD3.3D1PB1 V1 CD3-301 , C D3.3D1 , CD3.301 V4 CD3-114, CD3-114, CD3-114 V14 Plan: CD3-306, PIan:CD3-306,CD3.306 (wpD1) V14 CD3.305,CD3.3D5, CD3-3D5 VD CD3-305,CD3-305PB1, CD3-305PB1 1+t7 31 March, 2009 - 10:34 Page 6 of 6 COMPASS .Page 1 of 1 Maunder, Thomas E (DOA) from: Maunder, Thomas E (DOA) Sent: Wednesday, April 08, 2009 4:18 PM To: Liz Galiunas Subject: CD3-304 (revised) Liz, The approved copy of the revised permit will not be out today. I have spoken with Commissioner Foerster and she agrees that you already have a valid permit. It is acceptable to begin operations and we will get the revised copy to you tomorrow. The PTD and API number did not change. A copy of this message should be available at the rig. Tom Maunder, PE AOGCC 6/16/2009 ConocoPhillips Alaska, Inc. • Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 April 4, 2009 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 ~~~~~ Conoco hilli s U p ~~i ~+d~ 'alfl`i'u An~hora~~ ~tntnrr~ission Re: Application for change of Approved Program: Permit to Drill CD3-304 (Permit no. 209-028) Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for an amendment to the approved Permit to Drill for CD3- 304 (PTD #209-028). This request is to change the approved program from a horizontal well to a high angle slant well. CD3-304 will be an onshore producer well from the Fiord CD3 drilling pad. The intended spud date for this well is 04/8/2009. It is intended that Doyon Rig 19 be used to drill the well. Due to limited time left for the ice road to CD3, CD3-304 will be drilled to penetrate the Kuparuk reservoir as a high angle slant. There is not enough time in the ice road season to drill CD3-304 as a horizontal well. After setting 7" intermediate casing, the well will be completed as a producer, perforated, and. flowed back to mitigate reservoir damage. The well will then be hooked up to begin production. It is expected that the Qannik could be considered a significant hydrocarbon bearing zone. 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. A waiver for the diverter is requested. This will be the 4th winter season of drilling on the Fiord pad and there has been no significant indication of gas or shallow gas hydrates. 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. A proposed drilling program. 3. A drilling fluids program summary. 4. Proposed completion diagram. 5. Pressure information as required by 20 ACC 25.035 (d) (2). 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Liz Galiunas at 265- 6247, or Chip Alvord at 265-6120. Sincerely, ~._ Liz Galiunas Drilling Engineer Attachments cc: CD3-304 Well File /Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1570 Jack Walker ATO 1740 • Lanston Chin Kuukpik Corporation ~_~ ,_ . ~~~~ P~R~It~ C>~#~CK~.t~7 Field & Pool COLVILLE RIVER, FIORD OIL.-120120 _ _ _ Well Name: COLVILLE RIV FIORD CD3-304 _________Program DEV ___ _ __ Well bore seg PTD#:2090280 Company CON_OCOPHILLIPS ALASKA INC ____ __ __ Initial ClasslType DEV / 1-O1L GeoArea 690 - _ _ __ _ Unit 50360 __ __ OnlOff Shore On_ _ Annular Disposal ^ Administration 1 Permit fee attached _NA- ~',2 Lease number appropriate Yes $urf_ace location in ADL 372105; wellbore passes thru ADL 372104; productive interval-& TD in ADL 312103._ 3 Unique well_name and number Yes Previously perm_itled as 2050240, but that permit expired 21812008.- 1,4 Well located in a defined pool _ Yes ',5 Well located proper distance_from drilling unit_boundary Yes well is locatetl_6500' from CRU exterior boundary.. 6 Well located proper tlistance_fro_m other wells_ Yes Nearest well_is CD3-305, which. is 3000' to SW. 7 Sufficient acreage available in drilling unit. Yes 8 If deviated, is wellbore plat_included Yes i9 Operator only affected party Yes i10 _Operator has appropriate bond in force Yes I~11 Permit can be issued without conservation order _ _ - _ Yes - Appr Date ''12 Permit_can be issued without administrative approval Yes 113 Can permit be approved before 15-day wait Yes SFD 4/812009 ~ '14 Well located within area and-strata authorized by Infection Order # (put_IO# in_comments) (For_ NA 15 All wells_within 114 mile_area of review identified (For service well only) NA 18 .Pre-produced injector:. duration ofpre-production less than_ 3 months (For service well. only) NA 17 Nonconven, gas conforms to A$31,05.030Q,1.A),Q,2.A-D) NA --- 18 ___ _ Conductor string provided Yes --- Engineering i19 Surface casing. protects all known_ USDWs NA No aquifers, A1O18A, conclusion 3. '220 _CMT vol atlequateto circulate on conductor. & surf csg Yes 21 _CMT-vol. adequatetotie-in long string to-surf csg No I22 CMT will coyer all known_pro_ductiye horizons Yes i23 Casing designs adequate for C, T, B & permafrost Yes x',24 Adequate tankage. or reserve pit Yes Rig equipped with steel pits. No reserve pit planned. All waste_to approved annuli or disposal well(s).. ',25 If a re-drill, has_a 10-403 for abandonment been approved _NA 1,28 Adequate wellbore separation proposed. Yes Proximity analysis performed. Traveling cylinder path calculated.. Gyros likely in Surface hole, 27 If diverter required, does it meet regulations. lJA Diyerter waiver requested.. No issues tlrillmg at CD3._ 20 AAC 25.035_(h)(2). 28 fluid program schematic & equip list adequate Drilling Yes Maximum expected formation. pressure 8.7 EMW._ MW planned up to 9,8-ppg in 8-314" hole and 8.8 ppg in zone, Appr Date . TEM 41812009 ,29 BOPEs, do they meet regulation Yes X30 BOPE_press rating appropriate; Pest t_o_(put psig in comments) Yes MASP calculated at 2389 psi. 3500 psi BOP testplanned, 31 Choke manifold complies wlAPl RP-53 (M_ay 84)_ _ _ Yes ~32 Work will occur without operation shutdown Yes 33 Is presence of H2$ gas probable No_ H2S not reported in CRU. Rig equipped with sensors and alarms. ___ __ 'i34 Mechanical condition of wells within AOR verified (For service well only) - NA -- _ -- _ _ __ -- _____ ___ __ _ i _ 35 _ _ _ __ -- - .Permit can be issued w!o hydrogen sulfide measures Yes None expected Geolo 9Y !38 Data_presented on potential overpressure zones. Yes Expected r_esevoir pressure is 8.7 ppg EMW; will be drilled with 8,8 to 9,S ppg mud.- Appr Date 137 Seismic_analysis ofshallow gas zones NA Will be about the 19th well drilled from CD3 Dnll Site._ No shallow_gas o[ hydrates have been encountered SFD 4/8/2009 38 Seabed condition survey (ifoff-shore) NA while drilling from_this pad. 1,39 Contact namelpho_ne for weekly_progress reports [exploratory only] NA Geologic Engineering Pu ~ Re-issue needed due to bottom hole change. Commissioner: DTS Date: Commissioner: (Date Com /-~~~ N ~ C~ DateQQ ~/~0~ A~ / ' _ Page 1 of 1 Maunder, Thomas E (DOA) From: Galiunas, Elizabeth C [Elizabeth.C.Galiunas@conocophillips.comj Sent: Wednesday, April 01, 2009 3:12 PM To: Maunder, Thomas E {DOA) Cc: McKeever, Steve; Noel, Brian Subject: CD3-304 Change to approved program PTD#209-028 Tom, Due to timing on CD3, we are forced to change out plan for CD3-304 from a horizontal to a high angle slant wetl. I will be sending over the sundry information (change to approved program) within the next day. I just wanted you to know this is coming. We should not be moving to this well until April 7th. Thanks, Liz Galiunas Alpine Drilling Engineer ConocoPhillips Alaska Office: 907-265-6247 Cell: 907-903-1200 6/16/2009 r ~ `'~71~ it r~je n i l~ Ni;r J~',1I1L~ U~ /~i~d C1,~ni ALASSA OIL A1~TD GA,S C01~5ER~'ATIOI~T C01rII-IISSIOI~T S. McKeever NSOD Drilling Superintendent ConocoPhillips Alaska Inc. PO Box 100360 Anchorage AK 99510-0360 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Colville River Field, Fiord Oil Pool, CD3-304 ConocoPhillips Alaska Inc. Permit No: 209-028 Surface Location: 3912' FNL, 738' FEL, SEC. 5, R12N, R5E Bottomhole Location: 3817' FNL, 23' FEL, SEC. 11, T12N, R5E Dear Mr. McKeever: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, Daniel T. Seam~ount, Jr. Chair DATED this ~ day of March, 2009 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA SS O ~~G ~~t~ ~ ~ 2ao9 ALASKA OIL AND GAS CONSERVATION COMMI I N PERMIT TO DRILL ~ 1~sks ~~~~ ~`~ ~s forts. ~ar~ttm-ssi®r~ 20 AAC 25.005 ~ I L~ AnC~i0C8~ 1a. Type of Work: 1b. Current Well Class: Exploratory .71 ,~ IDevelopment Oil ,. i 7,,; " 1c. Specify if well is proposed for: Drill Q. Re-drill ^ j Stratigraphic Test ^ Service ^ Development Gas ^ 8 Coalbed Methane ^ Gas Hydrates ^ Re-entry ^ Multiple ZonO Single Zone ^ Shale Gas ^ 2. Operator Name: 5. Bond: ~ Blanket ^ Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 ~ CD3-304 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 19948' ~ TVD: 6643' Colville River Field 3l ~~6 4a. Location of Well (Governmental Section): 7. Property Designation: ~l Y Surface: 3912 FNL, 738 FEL, Sec. 5 , T 12 N R 5 E • ADL 372103, 372104, 372105 ~ Fiord K k Oil Pool Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2097 FNL, 1454 FEL, Sec.11 , T 12 N R 5 E LAS2112 4/2/2009 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 9A00rFEL from CRU Boundary 3817' FNL, 23 FEL, Sec. 11, T 12 N R 5 E 2560 4b. Location of Well (S ate Base Plane Coordinates): .- -_kg~~, ~ _ ~ ~ 10. KB Elevation 15. Distance to Nearest Well within Pool: Surface: x- _ ~- ~`~ - 6003886 ' Z ne- 4 ~~ 3. t 7~ Y 36.3 RKBL, 49.9 MSL' (Height above GL): CD3-305 2948' at 17709' MD 16. Deviated wells: Kickoff depth: 400' MD ~ 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: g0° deg Downhole: 3005 psig Surface: 2341 psig . 18. Casing Program f Setting Depth Quantity of Cement Speci ications Bottom T or sacks f Size op c. . Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 62.5# H~0 Welded 77 37 37 114 114' pre-installed 12.25" 9-5/8" 40# L-80 BTC 3966 37 37 4003 ~ 2475 ~ 584 sx AS Lite, 230 sx 15.8 G 8.75" 7" 26# L-80 BTCM 17672 37 37 17709 6642 ~ 388 sx Class G, 192 Sx class G for K2 4.5" 12.6# L-80 IBT-M 17478 32 32 17510 6616 tubing 6.125" 4.5" 12.6# L-80 SLHT 2425 17513 6616 19938 6816 Slotted Liner with Blanks 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Drilling Progra~/ Time v. Depth F^ Shallow Hazard Analysis Q Q 20. Attachments: Filing Fee ^ BOP Sketc l ~I Property Plat ^ Diverter Sketc^ Seabed Repo^ 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 N Anderson Title NSOD Drilling Superintendent Printed Name S. cKeev Signature C~~G~!" ' Phon 265-1319 Date ~ ~j d r! ~~/f b Commission Use Only Permit to Drill API Number: Permit Approval See cover letter Number: ~„~} ~ ~' ~ ~ ~ ~,.-d~ 50-~~~~ s~G.~d,~ ~~ ~ Date: ~+ ~~ a for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed m thane as hydrates, or gas contained in shales: 'd: Yes ^o ~> LJ Mud log req'd: Yes ^ No [~ ~ ~ ~ ~~ s~ m les re ~~v~~~~-.~~~~ - aS,~ a p q H2S measures: Yes ^o T/p t[~ Directional svy req'd: Yes i[~ />/~ ^ 9-` ~~1~~,~.~-~ Other: 3~ ~ r `"'~ ~ APPROVED BY THE COMMISSION ~_~_~~ DATE: ,COMMISSIONER \~ 3~i2 ~'' Form 10-401 Revised 12/2005 -~~ Submit in - ~~~ i ~J ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 February 13, 2009 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD3-304 Dear Sir or Madam: C~ Conodti~ FEES ~ ~ 2009 Aloaka Vii! & dos Cans. Commission Anchorage ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore horizontal production well from the Fiord CD3 drilling pad. The intended spud date for this well is 04/02/2009. It is intended that Doyon Rig 19 be used to drill the well. An approved PTD (# 206-024) for CD3-304 was approved in February 2006 and has expired. The well plan has been altered due to changes in the Fiord drilling program. CD3-304 is intended to be a horizontal Kuparuk C sand producer. After setting 7" intermediate casing, the. horizontal section will be drilled and the well completed as slotted liner producer. The well will be flowed back to mitigate formation damage. r It is expected that the K2 (Qannik) sand will be considered a significant hydrocarbon bearing zone. The Kuparuk will be cemented 500' above top of the sand. A stage tool will be run to cement off the Qannik with 500' of cement above and below the interval. Lead cement will be pumped, then the stage tool will be opened and a second cement job pumped to isolate the Qannik. 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) be granted. Since the beginning of CD3 in 2005 there has not been a significant show of shallow gas or gas hydrates. ~ 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. A proposed drilling program 3. A drilling fluids program summary 4. Proposed completion diagram 5. Pressure information as required by 20 ACC 25.035 (d)(2). 6. Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b)• Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. 4. LOT Procedure.. If you have any questions or require further information, please contact Nina Anderson at 265- 6403 or Steve McKeever at 265-6826. Sincerely, Nina Anderso Drilling Engineer Attachments cc: CD3-304 Well File /Sharon Allsup Drake ATO 1530 Steve McKeever ATO 1590 Liz Galiunas ATO 1706 Jack Walker ATO 1740 Lanston Chin Kuukpik Corporation CD3-304 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-1/4" Hole / 9-5/8" Casin Interval Event Risk Level Miti ation Strate Conductor Broach Low Monitor cellar continuous) Burin interval. Well Collision Low G ro sin le shots, travelin c tinder dia rams Gas Hydrates Low ~ Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud tem eratures Running Sands and Gravel Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Abnormal Pressure in Low ,, Increased mud weight Surface Formations >2000' TVD Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of low densit cement slurries 8-3/4" Hole / 7" Casing Interva_I 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 wei ht. Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted swee s. Abnormal Reservoir low / Well control drills, increased mud weight. No Pressure mapped faults occur within 700' of the planned wellbore. Hydrogen Sulfide gas Low ,~ H2S drills, detection systems, alarms, standard well control ractices, mud scaven ers 6-1 /8" Hole /Horizontal Production Hole Event Risk Level Miti ation Strate Lost circulation moderate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitorin ,wei hted swee s. Abnormal Reservoir Medium ,/ BOPE drills, Keep mud weight above 8.8 ppg. Pressure Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud wei ht. Hydrogen Sulfide gas Low / H2S drills, detection systems, alarms, standard well control ractices, mud scaven ers ORIGI~~,gt_ Fiord : CD3-304 Procedure 1. Move on Doyon 19. 2. Drill 12-%4° hole to the surface casing point as per the directional plan. (Directional/MWD). 3. Run and cement 9-5/8" surface casing. 4. Install and test BOPE to 3500 psi. 5. Pressure test casing to 3500 psi. 6. Drill out 20' of new hole. Perform leak off test. 7. Pick up and run in hole with 8-3/4" drilling BHA. J 8. Drill 8-3/4" hole to intermediate casing point in the Kuparuk C sand. (LWD Program: GR/RES/PWD) 9. Run and cement 7" casing as per program. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. 10. BOPE test to 3500 psi. 11. Run drilling assembly (LWD Program: GR/RES/PWD). Pressure test casing to 3500 psi. 12. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.0 ppg EMW. r 13. Drill 6-1/8" horizontal section to well TD. 14. Circulate the hole clean and pull out of hole. 15. Run lower completion of 4-%", 12.6# L-80 SLHT blank and slotted liner and liner hanger. 16. Run upper completion of 4-'/z, 12.6#, L-80 tubing with BAL-O SSSV in DB Npl, packer, 3 GLM with shear out valve in lower mandrel, Sliding Sleeve, XN profile and wireline entry guide. Land hanger. 17. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 18. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 19. Shear valve in the gas lift mandrel. 20. Circulate tubing to diesel and install freeze protection in the annulus. 21. Drop ball and rod, set packer and test tubing and annulus to 3500 psi / 30 mins. 22. Set BPV and secure well. Move rig off. Post rig well work will include pulling the ball and rod assembly, and GLV change out. OR!6!~^,L Well Proximity Risks: Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in the following attachments. CD3-305 is the nearest existing well to the CD3-304 plan with 19.98' well to well separation at 398.73' MD. Drilling Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. '~ Lost circulation: Faulting and low reservoir pressure within the Kuparuk reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material and well bore strengthening pills are 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 Pumping Operations: Incidental fluids developed from drilling operations on well CD3-304 will be injected into a permitted annulus on CD3 pad or the class 2 disposal well on CD1 pad. The CD3-304 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The significant hydrocarbon zones are the Kuparuk, and the Qannik reservoir. There will be 500' of cement above the top of the Qannik reservoir. Upon completion of CD3-304 form 10-403, Application for Sundry Operations, will be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080, could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C-40). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) " (0.052)'` (Surf. Shoe TVD) + 1,500 psi _ (12.0 ppg) * (0.052) * (2475') + 1,500 psi = 3044 psi Pore Pressure = 1,120 psi Therefore Differential = 3044 -1120 = 1924 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: OD Wt (ppf) Grade Range Connection Type Collapse 85% of Collapse Burst 85% of Burst 9-5/8" 40 L-80 3 BTC 9,090 psi 1,717 psi 5,750 psi 2,992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi DRILLING FLUID PROGRAM SPUD to 9-5/8"surface casing oint - 12 %4" Intermediate hole Pilot hole and to 7" casing oint - 8'/" Production Hole Section - 6 1/8" Density 8.8 - 9.6 ppg 9.6 - 9.8 PP9 8.8 PP9 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 NA HPHT Fluid Loss at 160 (drilling) 12-14 cc/30 min PH 8.5-9.0 9.0-10.0 9.0-9.5 KCL 6% Surface Hole: 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: The intermediate section will be drilled with fresh water gel /polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the reservoir is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section The horizontal production interval will be drilled with a M-I Flo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with ± 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. ~~~~~~ Completion Schematic Planned CD3-304 Fiord Kuparuk Producer Completion ~ '''''~ 16" Insulated Conductor to 114' 3 ~ 4-'/z' 12.6 ppf L-80 IBT Mod. Tubing ~~ ! 4-%" Wireline Retrievable SSSV BAL-O Landing Npl w/DB Profile dual control lines 9-5/8" 40 ppf L-80 BTCM Surface Casing 4003' MD / 2475' TVD TOC +/- 8694" M D / 3936' TVD Stage Cementing Tool +/- 9759' M D / 4269' TVD Top of intermediate cement 300' above packer depth 15650' MD / 6105' TVD Sperry Sun Directional Plan wp11 Updated 02-11-09 Completion: Top MD TVD 1) Tubing Hanger 32' 32' 2) 4'/="", 12.6#/ft, IBT-Mod Tubing 3) 4'/=" SSSV BAL-O Landing Npl 2300' 1931' 4) 4-''/2"', 12.6#/ft„ IBT-Mod Tubing 5) Camco KBG2 GLM (3.958" ID) w/dummy 6971' 3400' 6) 4'/=°", 12.6#/ft„ IBT-Mod Tubing 7) Camco KBG2 GLM (3.958" ID) w/dummy 14030' 5600' 8) 4'/z"', 12.6#/ft„ IBT-Mod Tubing 9) Camco KBG-2 GLM with DCK2 SOV 15900' 6183' pinned to 2500 psi K2/Qannik sand 10) 4-Y="", 12.6#/ft„ IBT-Mod Tubing (1 jts) +/- 9194' MD / 11) 4-'/" x 7" Baker Premier Packer 15950' 6198' 12) 4-'/"", 12.6#/ft„ IBT-Mod Tubing (1 jt) ' 4093 TVD 13) 3.813" HES "XN" npl (3.725" NoGo) 16000' 6213' with RHC Plug 14) 4-'/"", 12.6#/ft„ IBT-Mod Tubing 15) 4 '/_" IBT with mule shoe WLEG sub 17510' 6616' up 3' from locating from TOL' Lower Completion: Too MD TVD Item 16) Baker 5" x 7" Flexlock Liner Hanger 17513' 6616' 17) 4-''/z' 12.6 #/ft, SLHT Tubing +/- 3 jts 18) 4-''/i' 12.6 #/ft, SLHT liner w/ blank across shale and slots across sand ~ 19) Orange Peel Shoe 19938' 6616' Kuparuk C 17663' MD / 6638' TVD 4-''/i' 12.6#/ft L-80 SLHT Mod Slotted liner Pattern: 32 Slots / ft, 2 '-'/a" x 1!8" SIotS 7" 26 ppf L-80 BTC Mod Production Casing @ 17,709 MD, 6642' TVD TD 6-1/8" hole 19,948' MD / 6643' TVD f ~ t ~ ~ ~ CD3-304 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 (c) (3,4) and as required in 20 ACC 25.035 (d) (2)) ~J 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 lbs. / al Pore pressure si ASP Drilling si 16 114 / 114 10.9 52 53 9 5/8 4003 / 2475 14.5 1120 1619 7" / TD 17719 / 6642 16.0 3005 2341 N/A 19948 / 6643 16.0 3005 - N/A NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 3500 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]D Where: ASP =Anticipated Surface pressure in psi FG =Fracture gradient at the casing seat in Ib/gal 0.052 =Conversion from Ib./gal to psi/ft 0.1 =Gas gradient in 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=53 psi OR ASP =FPP - (0.1 x D) = 1120 - (0.1 x 2500') = 870 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1] D _ [(14.5 x 0.052) - 0.1 ] x 2475 = 1619 psi OR ASP =FPP - (0.1 x D) = 3005 - (0.1 x 6642') = 2341 psi 3. Drilling below intermediate casing (7") ASP =FPP - (0.1 x D) = 3005 - (0.1 x 6643) = 2341 psi ~Rlrl~igl Cementing Program: 9 5/8" Surface Casing run to 4003' MD / 2475' TVD. Cement from 4003' MD to 3503' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 3503' to surface with Arctic Set Lite 3. Assume 250% excess annular volume in permafrost and 50% excess below the permafrost (1686' MD). Lead slurry: (3503'-1686') X 0.3132 ft3/ft X 1.5 (50% excess) =853.6 ft3 below permafrost 1686' X 0.3132 ft3/ft X 3.5 (250% excess) = 1848.2 ft3 above permafrost Total volume = 853.6 + 1848.2 = 2701.8 ft3 => 584 Sx @ 4.63 ft3/sk System: 584 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.63 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% 5001 accelerator, 50% D124 extender and 9% BWOWI D044 freeze suppressant Tail slurry: 500' X 0.3132 ft3/ft X 1.5 (50% excess) = 234.9 ft3 annular volume 80' X 0.4341 ft3/ft = 34.7 ft3 shoe joint volume Total volume = 234.9 + 34.7 = 269.6 ft3 => 230 Sx @ 1.17 ft3/sk System: 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% 5001 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casing run to 17709' MD / 6642' TVD Cement from 17709' MD to 15650 +/-' MD (minimum 500' MD above top of Kuparuk C reservoir) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Tail: (17709' -15650') X 0.1503 ft3/ft X 1.4 (40% excess) = 433 ft3 annular vol. 80' X 0.2148 ft3/ft = 17.2 ft3 shoe joint volume Total volume = 433 + 17.2 = 450 ft3 => 388 Sx @ 1.16 ft3/sk System: 388 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.16 ft3/sk Second Stage: Cement from ports in a ES stage 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: (9759'- 8694') X 0.1503 ft3/ft X 1.4 (40% excess) = 224.1 ft3 annular vol. Total Volume = 224.1 ft3 => 192 Sk @ 1.17 ft3/sk System: 192 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% 5002 accelerator @ 15.8 PPG yielding 1.17 ft3/sk ' By Weight Of mix Water, all other additives are BWOCement ConocoPhillips(Alaska) Inc. Western North Slope CD3 Alpine Pad Plan: CD3-304 Plan: CD3-304 Plan: CD3-304wp11 Standard Proposal Report 11 February, 2009 ^ [ IV~ ~: ; H~~LIBiLJRT~~I Sperry"..Drilling. Services ORIGINAL Western North Slope D DDI: 7.017 PI an: CD3 304 CD3-304wp11 Plan: CD3304 CD3304wp11 9 5/8" x 1 2 1/4" C V7 + -2500 ~ . 7" x 8-3/4" i - L ' CD3-304wp11 Heel .~ ~ -5000 4-1/2" x 6-1/8- - - - - _ 11 Toe ~ CD3-304w ~~ p ~Q ff` O ~ ~~ G 0 2500 5000 7500 10000 12500 15000 West(-)/East(+) (2500 ft/in) 0 ~ O O O M .... L ~ 3000 a~ 0 ca _U ~ -1/8" ~ 6000 f`- 4wp11 e 0 3000 6000 9000 12000 15000 '18000 - - Q. 0 10 20 9 5/8" x 12 1 /4" 3 ~ y ~~ o ___, ..,,, __._._ _..._______ _ _ _ _ ~_~_ _..._.~__ . ___~ _~ __ _.____ __._~___.,. _-._ _.. ~_ C-3 c-2o _ K_~ _ K-3_Basal '---__K-2 nN K-2 Basal Albian 97 Albian 96 (Nanuq) 4-1/2" x 6 7" x 8-3/4" _ -.._.....----~..._...,...__ _._. ----- _ - - _ - - -Top HRZ ~ ..____.~__~_....- P ~ ~ -- ~ , - - - - ' 11 H l~ CD3304 ~;, CD3-30 K-1 ~ ~ k D Base HRZ ~ ee ~ w ~ u aru P Kuparuk G j ~ a ~~~~~~~ ~ ~: ,~' ~ _. HALLI~URTON Database: EDM v16 Prod Company: ConocoPhillips(Alaska) Inc. Project: Westem North Slope Site: CD3 Alpine Pad Well: Plan: CD3-304 Wellbore: Plan: CD3-304 Design: CD3-304wp11 ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: CD3-304 TVD Reference: Plan: CD3-304 (36.3+13.4) @ 49.70ft (Doyon 19 MD Reference: Plan: CD3-304 (36.3+13.4) @ 49.70ft (Doyon 19 North Reference: True Survey Calculation Method: Minimum Curvature ~raject Western North Slope tap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level leo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point tap Zone: Alaska Zone 04 Using geodetic scale factor Site CD3 Alpine Pad - Site Position: Northing: O.OOft Latitude: 53° 58' 39.152 N From: Map Easting: O.OOft Longitude: 152° 19' 23.267 W Position Uncertainty: 0.00 ft Slot Radius: Grid Convergence: -1 88 ° 304 Well Plan• CD3- Well Position +N/S 0.00 ft Northing: 6,003,860.61 ft Latitude: 70° 25' 10.196 N +E/-W 0.00 ft Easting: 388,305.13 ft Longitude: 150° 54' 35.745 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.40ft -- Wellbore Plan: CD3-304 Magnetics Model Name Sample Date Declination Dip Angle (') (°) BGGM2007 2/11/2009 16.75 79.68 s ..... , , ~ .; Design CD3-304wp11 Audit Notes: Field Strength (nT) 57,280 Version: 5 Phase: PLAN Tie On Depth: 36.30 Vertical Section: Depth From (TVD) +N/S +E/-W Direction (ft) (ft) (ft) (°) L 36.30 0.00 0.00 111.00 J ,..~ .. Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System- +N/S +E/-W Rate Rate Rate Tool Face (ft) (') (') (ft) ft (ft) (ft) (°l100ft) (°HDOft) (°liDOft) (°) 36.30 0.00 0.00 36.30 -13.40 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 250.30 0.00 0.00 0.00 0.00 0.00 0.00 500.00 4.00 115.00 499.84 450.14 -2.95 6.32 2.00 2.00 0.00 115.00 900.00 16.00 115.00 893.04 843.34 -32.25 69.16 3.00 3.00 0.00 0.00 2,510.58 71.84 101.10 2,009.66 1,959.96 -294.96 1,106.22 3.50 3.47 -0.86 -15.91 16,536.92 71.84 101.10 6,381.04 6,331.34 -2,861.70 14,184.50 0.00 0.00 0.00 0.00 17,665.36 82.81 140.10 6,637.70 6,588.00 -3,416.54 15,106.47 3.50 0.97 3.46 78.99 17,904.89 90.00 140.10 6,652.70 6,603.00 -3,599.81 15,259.71 3.00 3.00 0.00 0.00 17,971.55 92.00 140.10 6,651.54 6,601.84 -3,650.94 15,302.47 3.00 3.00 0.00 0.00 18,051.55 92.00 140.10 6,648.74 6,599.04 _3,712.28 15,353.75 0.00 0.00 0.00 0.00 18,114.22 90.12 140.10 6,647.59 6,597.89 -3,760.34 15,393.94 3.00 -3.00 0.00 179.97 19,948.42 90.12 140.11 6,643.70 6,594.00 -5,167.56 16,570.38 0.00 0.00 0.00 72.06 2/112009 4:05:43PM Page 2 COMPASS 2003.16 Build 42F ~ .rte w ~ , _. ~s-~ ~~. T Database: EDM v16 Prod Company: ConocoPhillips(Alaska) Inc Project: Western North Slope Site: CD3 Alpine Pad Well: Plan: CD3-304 Wellbore: Plan: CD3-304 Design: CD3-304wp11 Planned Survey ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: .Well Plan: CD3-304 TVD Reference: Plan: CD3-304 (36.3+13.4) @ 49.70ft (Doyon 19 MD Reference: Plan: CD3-304 (36.3+13.4) @ 49.70ft (Doyon 19 North Reference: .True Survey Calculation Method: Minimum Curvature 'I Measured Vertical Map Map ' ' Depth Inclination Azimuth Depth TVDss +N/S +Ei_yy Northing Easting DLS Vert Section (ft} (°) (°) (ft) ft (ft) (ft} (ft1 lft) -13.40 36.30 0.00 0.00 36.30 -13.40 0.00 0.00 6,003,860.61 388,305.13 0.00 0.00 100.00 0.00 0.00 100.00 50.30 0.00 0.00 6,003,860.61 388,305.13 0.00 0.00 200.00 0.00 0.00 200.00 150.30 0.00 0.00 6,003,860.61 388,305.13 0.00 0.00 300.00 0.00 0.00 300.00 250.30 0.00 0.00 6,003,860.61 388,305.13 0.00 0.00 Start Build 2.00 400.00 2.00 115.00 399.98 350.28 -0.74 1.58 6,003,859.85 388,306.70 2.00 1.74 500.00 4.00 115.00 499.84 450.14 -2.95 6.32 6,003,857.56 388,311.41 2.00 6.96 Start Build 3.00 600.00 7.00 115.00 599.37 549.67 -7.00 15.01 6,003,853.38 388,320.03 3.00 16.52 700.00 10.00 115.00 698.26 648.56 -13.25 28.40 6,003,846.94 388,333.33 3.00 31.26 800.00 13.00 115.00 796.24 746.54 -21.67 46.47 6,003,838.25 388,351.27 3.00 51.15 900.00 16.00 115.00 893.04 843.34 -32.25 69.16 6,003,827.33 388,373.79 3.00 76.12 Start DLS 3.50 TFO - 15.91 1,000.00 19.39 112.11 988.30 938.60 -44.33 97.04 6,003,814.84 388,401.49 3.50 106.48 1,100.00 22.81 110.06 1,081.58 1,031.88 -57.23 130.64 6,003,801.44 388,434.88 3.50 142.47 1,200.00 26.25 108.52 1,172.54 1,122.84 -70.90 169.83 6,003,787.18 388,473.86 3.50 183.96 1,300.00 29.71 107.31 1,260.84 1,211.14 -85.30 214.47 6,003,772.11 388,518.28 3.50 230.79 1,400.00 33.17 106.34 1,346.15 1,296.45 -100.37 264.39 6,003,756.30 388,567.97 3.50 282.80 1,500.00 36.64 105.53 1,428.15 1,378.45 -116.06 319.41 6,003,739.79 388,622.74 3.50 339.79 1,600.00 40.11 104.84 1,506.53 1,456.83 -132.30 379.32 6,003,722.65 388,682.39 3.50 401.54 1,700.00 43.59 104.24 1,581.01 1,531.31 -149.04 443.89 6,003,704.95 388,746.70 3.50 467.82 1,800.00 47.07 103.72 1,651.30 1,601.60 -166.21 512.89 6,003,686.75 388,815.43 3.50 538.39 1,900.00 50.55 103.25 1,717.15 1,667.45 -183.76 586.06 6,003,668.12 388,888.32 3.50 612.99 2,000.00 54.04 102.83 1,778.30 1,728.60 -201.60 663.12 6,003,649.12 388,965.11 3.50 691.33 2,100.00 57.52 102.44 1,834.53 1,784.83 -219.68 743.80 6,003,629.84 389,045.49 3.50 773.12 2,200.00 61.01 102.09 .1,885.63 1,835.93 -237.93 827.78 6,003,610.33 389,129.18 3.50 858.06 2,300.00 64.50 101.75 1,931.41 1,881.71 -256.29 914.75 6,003,590.68 389,215.86 3.50 945.84 2,400.00 67.98 101.44 1,971.69 1,921.99 -274.67 1,004.39 6,003,570.96 389,305.21 3.50 1,036.12 2,500.00 71.47 101.13 2,006.33 1,956.63 -293.03 1,096.37 6,003,551.24 389,396.90 3.50 1,128.56 2,510.58 71.84 101.10 2,009.66 1,959.96 -294.96 1,106.22 6,003,549.15 389,406.72 3.50 1,138.45 2,510.59 71.84 101.10 2,009.67 1,959.97 -294.96 1,106.23 6,003,549.15 389,406.73 0.00 1,138.46 Start 14026.21 hold at 2510.59 MD 2,600.00 71.84 101.10 2,037.53 1,987.83 -311.33 1,189.60 6,003,531.54 389,489.84 0.00 1,222.16 2,700.00 71.84 101.10 2,068.70 2,019.00 -329.63 1,282.84 6,003,511.85 389,582.79 0.00 1,315.76 2,800.00 71.84 101.10 2,099.86 2,050.16 -347.92 1,376.08 6,003,492.16 389,675.74 0.00 1,409.37 2,900.00 71.84 101.10 2,131.03 2,081.33 -366.22 1,469.32 6,003,472.47 389,768.68 0.00 1,502.98 3,000.00 71.84 101.10 2,162.19 2,112.49 -384.52 1,562.57 6,003,452.78 389,861.63 0.00 1,596.58 3,100.00 71.84 101.10 2,193.36 2,143.66 -402.82 1,655.81 6,003,433.09 389,954.58 0.00 1,690.19 3,200.00 71.84 101.10 2,224.52 2,174.82 -421.12 1,749.05 6,003,413.40 390,047.53 0.00 1,783.79 3,300.00 71.84 101.10 2,255.69 2,205.99 -439.42 1,842.29 6,003,393.71 390,140.48 0.00 1,877.40 3,400.00 71.84 101.10 2,286.86 2,237.16 -457.72 1,935.53 6,003,374.02 390,233.43 0.00 1,971.00 3,500.00 71.84 101.10 2,318.02 2,268.32 -476.02 2,028.77 6,003,354.33 390,326.38 0.00 2,064.61 3,521.43 71.84 101.10 2,324.70 2,275.00 -479.94 2,048.75 6,003,350.11 390,346.30 0.00 2,084.67 C-40 3,600.00 71.84 101.10 2,349.19 2,299.49 -494.32 2,122.01 6,003,334.64 390,419.32 0.00 2,158.22 2/112009 4:05.~43PM Page 3 COMPASS 2003.16 Build 42F ~~~~~~ ~` ~ . ConocoPhillips "'... ~ ~ ~-.~~:e.p ~~ T Sta ndard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan: CD3-304 Company: ConocoPhillips(Alaska) Inc. ND Reference: Plan: CD3-304 (36.3+13.4) @ 49.70ft (Doyon 19 Project: Western North Slope MD Reference: Plan: CD3-304 (36.3+13.4) @ 49.70ft (Doyon 19 Site: CD3 Alpine Pad North Reference: True Well: Plan: CD3-304 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD3-304 u Design: CD3-304wp11 Planned Survey Measured Vertical Map Map Depth In clination Azimuth Depth NDss +N/-S +E/_yl/ Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft} (ft} (ft) (ft} 2,330.65 3,700.00 71.84 101.10 2,380.35 2,330.65 -512.62 2,215.25 6,003,314.95 390,512.27 0.00 2,251.82 3,800.00 71.84 101.10 2,411.52 2,361.82 -530.92 2,308.49 6,003,295.25 390,605.22 0.00 2,345.43 3,900.00 71.84 101.10 2,442.68 2,392.98 -549.22 2,401.73 6,003,275.56 390,698.17 0.00 2,439.03 4,000.00 71.84 101.10 2,473.85 2,424.15 -567.52 2,494.97 6,003,255.87 390,791.12 0.00 2,532.64 4,003.70. 71.84 101.10 2,475.00 2,425.30 -568.19 2,498.42 6,003,255.14 390,794.55 0.00 2,536.10 9 5/8" x 1 2 1/4" 4,050.86 71.84 101.10 2,489.70 2,440.00 -576.83 2,542.40 6,003,245.86 390,838.40 0.00 2,580.25 C-30 4,100.00 71.84 101.10 2,505.01 2,455.31 -585.82 2,588.21 6,003,236.18 390,884.07 0.00 2,626.24 4,200.00 71.84 101.10 2,536.18 2,486.48 -604.12 2,681.45 6,003,216.49 390,977.01 0.00 2,719.85 4,300.00 71.84 101.10 2,567.34 2,517.64 -622.42 2,774.70 6,003,196.80 391,069.96 0.00 2,813.46 4,400.00 71.84 101.10 2,598.51 2,548.81 -640.72 2,867.94 6,003,177.11 391,162.91 0.00 2,907.06 4,500.00 71.84 101.10 2,629.68 2,579.98 -659.02 2,961.18 6,003,157.42 391,255.86 0.00 3,000.67 4,600.00 71.84 101.10 2,660.84 2,611.14 -677.31 3,054.42 6,003,137.73 391,348.81 0.00 3,094.27 4,700.00 71.84 101.10 2,692.01 2,642.31 -695.61 3,147.66 6,003,118.04 391,441.76 0.00 3,187.88 4,800.00 71.84 101.10 2,723.17 2,673.47 -713.91 3,240.90 6,003,098.35 391,534.71 0.00 3,281.48 4,900.00 71.84 101.10 2,754.34 2,704.64 -732.21 3,334.14 6,003,078.66 391,627.65 0.00 3,375.09 5,000.00 71.84 101.10 2,785.50 2,735.80 -750.51 3,427.38 6,003,058.96 391,720.60 0.00 3,468.70 5,100.00 71.84 101.10 2,816.67 2,766.97 -768.81 3,520.62 6,003,039.27 391,813.55 0.00 3,562.30 5,200.00 71.84 101.10 2,847.83 2,798.13 -787.11 3,613.86 6,003,019.58 391,906.50 0.00 3,655.91 5,300.00 71.84 101.10 2,879.00 2,829.30 -805.41 3,707.10 6,002,999.89 391,999.45 0.00 3,749.51 5,334.34 71.84 101.10 2,889.70 2,840.00 -811.69 3,739.12 6,002,993.13 392,031.36 0.00 3,781.65 C-20 5,400.00 71.84 101.10 2,910.16 2,860.46 -823.71 3,800.34 6,002,980.20 392,092.40 0.00 3,843.12 5,500.00 71.84 101.10 2,941.33 2,891.63 -842.01 3,893.58 6,002,960.51 392,185.35 0.00 3,936.72 5,600.00 71.84 101.10 2,972.50 2,922.80 -860.31 3,986.83 6,002,940.82 392,278.29 0.00 4,030.33 5,700.00 71.84 101.10 3,003.66 2,953.96 -878.61 4,080.07 6,002,921.13 392,371.24 0.00 4,123.94 5,800.00 71.84 101.10 3,034.83 2,985.13 -896.91 4,173.31 6,002,901.44 392,464.19 0.00 4,217.54 5,900.00 71.84 101.10 3,065.99 3,016.29 -915.21 4,266.55 6,002,881.75 392,557.14 0.00 4,311.15 6,000.00 71.84 101.10 3,097.16 3,047.46 -933.51 4,359.79 6,002,862.06 392,650.09 0.00 4,404.75 6,100.00 71.84 101.10 3,128.32 3,078.62 -951.81 4,453.03 6,002,842.37 392,743.04 0.00 4,498.36 6,200.00 71.84 101.10 3,159.49 3,109.79 -970.11 4,546.27 6,002,822.67 392,835.99 0.00 4,591..96 6,300.00 71.84 101.10 3,190.65 3,140.95 -988.40 4,639.51 6,002,802.98 392,928.93 0.00 4,685.57 6,400.00 71.84 101.10 3,221.82 3,172.12 -1,006.70 4,732.75 6,002,783.29 393,021.88 0.00 4,779.18 6,500.00 71.84 101.10 3,252.98 3,203.28 -1,025.00 4,825.99 6,002,763.60 393,114.83 0.00 4,872.78 6,600.00 71.84 101.10 3,284.15 3,234.45 -1,043.30 4,919.23 6,002,743.91 393,207.78 0.00 4,966.39 6,700.00 71.84 101.10 3,315.32 3,265.62 -1,061.60 5,012.47 6,002,724.22 393,300.73 0.00 5,059.99 6,800.00 71.84 101.10 3,346.48 3,296.78 -1,079.90 5,105.72 6,002,704.53 393,393.68 0.00 5,153.60 6,900.00 71.84 101.10 3,377.65 3,327.95 -1,098.20 5,198.96 6,002,684.84 393,486.63 0.00 5,247.20 7,000.00 71.84 101.10 3,408.81 3,359.11 -1,116.50 5,292.20 6,002,665.15 393,579.57 0.00 5,340.81 7,100.00 71.84 101.10 3,439.98 3,390.28 -1,134.80 5,385.44 6,002,645.46 393,672.52 0.00 5,434.42 7,200.00 71.84 101.10 3,471.14 3,421.44 -1,153.10 5,478.68 6,002,625.77 393,765.47 0.00 5,528.02 7,300.00 71.84 101.10 3,502.31 3,452.61 -1,171.40 5,571.92 6,002,606.08 393,858.42 0.00 5,621.63 7,400.00 71.84 101.10 3,533.47 3,483.77 -1,189.70 5,665.16 6,002,586.38 393,951.37 0.00 5,715.23 7,500.00 71.84 101.10 3,564.64 3,514.94 -1,208.00 5,758.40 6,002,566.69 394,044.32 0.00 5,808.84 2/11!2009 4:05:43PM Page 4 COMPASS 2003.16 Build 42F { # ~ ~ i"1 1 F i 4 Database: EDM v16 Prod Company: ConocoPhillips(Alaska) Inc. Project: Western North Slope Site: CD3 Alpine Pad Well: Plan: CD3-304 Wellbore: Plan: CD3-304 Design: CD3-304wp11 Planned Survey ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: CD3-304 TVD Reference: Plan: CD3-304 (36.3+13.4) @ 49.70ft (Doyon 19 MD Reference: Plan: CD3-304 (36.3+13.4) @ 49.70it (Doyon 19 North Reference: True Survey Calculation Method: Minimum Curvature Measured Vertical Map Map Depth Incli nation Azimuth Depth TVDss +N/S +Ei-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft} (ft) (ft} (ft) 3,546.10 i, 7,600.00 71.84 101.10 3,595.80 3,546.10 -1,226.30 5,851.64 6,002,547.00 394,137.27 0.00 5,902.44 7,700.00 71.84 101.10 3,626.97 3,577.27 -1,244.60 5,944.88 6,002,527.31 394,230.21 0.00 5,996.05 7,800.00 71.84 101.10 3,658.14 3,608.44 -1,262.90 6,038.12 6,002,507.62 394,323.16 0.00 6,089.65 7,900.00 71.84 101.10 3,689.30 3,639.60 -1,281.20 6,131.36 6,002,487.93 394,416.11 0.00 6,183.26 8,000.00 71.84 101.10 3,720.47 3,670.77 -1,299.50 6,224.60 6,002,468.24 394,509.06 0.00 6,276.87 8,100.00 71.84 101.10 3,751.63 3,701.93 -1,317.79 6,317.85 6,002,448.55 394,602.01 0.00 6,370.47 8,200.00 71.84 101.10 3,782.80 3,733.10 -1,336.09 6,411.09 6,002,428.86 394,694.96 0.00 6,464.08 8,300.00 71.84 101.10 3,813.96 3,764.26 -1,354.39 6,504.33 6,002,409.17 394,787.91 0.00 6,557.68 8,400.00 71.84 101.10 3,845.13 3,795.43 -1,372.69 6,597.57 6,002,389.48 394,880.85 0.00 6,651.29 8,500.00 71.84 101.10 3,876.29 3,826.59 -1,390.99 6,690.81 6,002,369.79 394,973.80 0.00 6,744.89 8,533.39 71.84 101.10 3,886.70 3,837.00 -1,397.10 6,721.94 6,002,363.21 395,004.84 0.00 6,776.15 K-3 8,600.00 71.84 101.10 3,907.46 3,857.76 -1,409.29 6,784.05 6,002,350.09 395,066.75 0.00 6,838.50 8,700.00 71.84 101.10 3,938.62 3,888.92 -1,427.59 6,877.29 6,002,330.40 395,159.70 0.00 6,932.11 8,800.00 71.84 101.10 3,969.79 3,920.09 -1,445.89 6,970.53 6,002,310.71 395,252.65 0.00 7,025.71 8,900.00 71.84 101.10 4,000.96 3,951.26 -1,464.19 7,063.77 6,002,291.02 395,345.60 0.00 7,119.32 9,000.00 71.84 101.10 4,032.12 3,982.42 -1,482.49 7,157.01 6,002,271.33 395,438.55 0.00 7,212.92 9,056.40 71.84 101.10 4,049.70 4,000.00 -1,492.81 7,209.60 6,002,260.22 395,490.97 0.00 7,265.72 K-3 Basal 9,100.00 71.84 101.10 4,063.29 4,013.59 -1,500.79 7,250.25 6,002,251.64 395,531.49 0.00 7,306.53 9,194.38 71.84 101.10 4,092.70 4,043.00 -1,518.06 7,338.25 6,002,233.06 395,619.22 0.00 7,394.87 K-2 9,200.00 71.84 101.10 4,094.45 4,044.75 -1,519.09 7,343.49 6,002,231.95 395,624.44 0.00 7,400.13 9,300.00 71.84 101.10 4,125.62 4,075.92 -1,537.39 7,436.73 6,002,212.26 395,717.39 0.00 7,493.74 9,400.00 71.84 101.10 4,156.78 4,107.08 -1,555.69 7,529.98 6,002,192.57 395,810.34 0.00 7,587.35 9,500.00 71.84 101.10 4,187.95 4,138.25 -1,573.99 7,623.22 6,002,172.88 395,903.29 0.00 7,680.95 9,521.66 71.84 101.10 4,194.70 4,145.00 -1,577.95 7,643.42 6,002,168.61 395,923.42 0.00 7,701.23 K-2 Basal 9,600.00 71.84 101.10 4,219.11 4,169.41 -1,592.29 7,716.46 6,002,153.19 395,996.24 0.00 7,774.56 9,700.00 71.84 101.10 4,250.28 4,200.58 -1,610.59 7,809.70 6,002,133.50 396,089.19 0.00 7,868.16 9,800.00 71.84 101.10 4,281.44 4,231.74 -1,628.88 7,902.94 6,002,113.80 396,182.13 0.00 7,961.77 9,900.00 71.84 101.10 4,312.61 4,262.91 -1,647.18 7,996.18 6,002,094.11 396,275.08 0.00 8,055.37 10,000.00 71.84 101.10 4,343.78 4,294.08 -1,665.48 8,089.42 6,002,074.42 396,368.03 0.00 8,148.98 10,100.00 71.84 101.10 4,374.94 4,325.24 -1,683.78 8,182.66 6,002,054.73 396,460.98 0.00 8,242.59 10,200.00 71.84 101.10 4,406.11 4,356.41 -1,702.08 8,275.90 6,002,035.04 396,553.93 0.00 8,336.19 10,300.00 71.84 101.10 4,437.27 4,387.57 -1,720.38 8,369.14 6,002,015.35 396,646.88 0.00 8,429.80 10,400.00 71.84 101.10 4,468.44 4,418.74 -1,738.68 8,462.38 6,001,995.66 396,739.83 0.00 8,523.40 10,500.00 71.84 101.10 4,499.60 4,449.90 -1,756.98 8,555.62 6,001,975.97 396,832.77 0.00 8,617.01 10,600.00 71.84 101.10 4,530.77 4,481.07 -1,775.28 8,648.87 6,001,956.28 396,925.72 0.00 8,710.61 10,700.00 71.84 101.10 4,561.93 4,512.23 -1,793.58 8,742.11 6,001,936.59 397,018.67 0.00 8,804.22 10,800.00 71.84 101.10 4,593.10 4,543.40 -1,811.88 8,835.35 6,001,916.90 397,111.62 0.00 8,897.83 10,900.00 71.84 101.10 4,624.26 4,574.56 -1,830.18 8,928.59 6,001,897.21 397,204.57 0.00 8,991.43 11,000.00 71.84 101.10 4,655.43 4,605.73 -1,848.48 9,021.83 6,001,877.51 397,297.52 0.00 9,085.04 11,100.00 71.84 101.10 4,686.60 4,636.90 -1,866.78 9,115.07 6,001,857.82 397,390.47 0.00 9,178.64 11,200.00 71.84 101.10 4,717.76 4,668.06 -1,885.08 9,208.31 6,001,838.13 397,483.41 0.00 9,272.25 2/11/"1009 4:05:43PM ~Pg ~ y ~ r ~ COMPASS 2003.16 Build 42F Database: EDM v16 Prod Company: ConocoPhillips(Alaska) Inc. Project: Western North Slope Site: CD3 Alpine Pad Well: Plan: CD3-304 Wellbore: Plan: CD3-304 Design: CD3-304wp11 Planned Survey i ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: CD3-304 ND Reference: Plan: CD3-304 (36.3+13.4) @ 49.70ft (Doyon 19 MD Reference: Plan: CD3-304 (36.3+13.4) @ 49.70ft (Doyon 19 North Reference: True Survey Calculation Method: Minimum Curvature Measured Vertical Map Map i Depth Incl ination Azimuth Depth NDss +N/S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 4,699.23 11,300.00 71.84 101.10 4,748.93 4,699.23 -1,903.38 9,301.55 6,001,818.44 397,576.36 0.00 9,365.85 11,400.00 71.84 101.10 4,780.09 4,730.39 -1,921.68 9,394.79 6,001,798.75 397,669.31 0.00 9,459.46 11,500.00 71.84 101.10 4,811.26 4,761.56 -1,939.97 9,488.03 6,001,779.06 397,762.26 0.00 9,553.07 11,600.00 71.84 101.10 4,842.42 4,792.72 -1,958.27 9,581.27 6,001,759.37 397,855.21 0.00 9,646.67 11,700.00 71.84 101.10 4,873.59 4,823.89 -1,976.57 9,674.51 6,001,739.68 397,948.16 0.00 9,740.28 11,800.00 71.84 101.10 4,904.75 4,855.05 -1,994.87 9,767.75 6,001,719.99 398,041.11 0.00 9,833.88 11,900.00 71.84 101.10 4,935.92 4,886.22 -2,013.17 9,861.00 6,001,700.30 398,134.05 0.00 9,927.49 12,000.00 71.84 101.10 4,967.09 4,917.39 -2,031.47 9,954.24 6,001,680.61 398,227.00 0.00 10,021.09 12,100.00 71.84 101.10 4,998.25 4,948.55 -2,049.77 10,047.48 6,001,660.92 398,319.95 0.00 10,114.70 12,200.00 71.84 101.10 5,029.42 4,979.72 -2,068.07 10,140.72 6,001,641.23 398,412.90 0.00 10,208.31 12,300.00 71.84 101.10 5,060.58 5,010.88 -2,086.37 10,233.96 6,001,621.53 398,505.85 0.00 10,301.91 12,400.00 71.84 101.10 5,091.75 5,042.05 -2,104.67 10,327.20 6,001,601.84 398,598.80 0.00 10,395.52 12,500.00 71.84 101.10 5,122.91 5,073.21 -2,122.97 10,420.44 6,001,582.15 398,691.75 0.00 10,489.12 12,600.00 71.84 101.10 5,154.08 5,104.38 -2,141.27 10,513.68 6,001,562.46 398,784.69 0.00 10,582.73 12,700.00 71.84 101.10 5,185.24 5,135.54 -2,159.57 10,606.92 6,001,542.77 398,877.64 0.00 10,676.33 12,800.00 71.84 101.10 5,216.41 5,166.71 -2,177.87 10,700.16 6,001,523.08 398,970.59 0.00 10,769.94 12,900.00 71.84 101.10 5,247.57 5,197.87 -2,196.17 10,793.40 6,001,503.39 399,063.54 0.00 10,863.55 13,000.00 71.84 101.10 5,278.74 5,229.04 -2,214.47 10,886.64 6,001,483.70 399,156.49 0.00 10,957.15 13,100.00 71.84 101.10 5,309.91 5,260.21 -2,232.77 10,979.88 6,001,464.01 399,249.44 0.00 11,050.76 13,200.00 71.84 101.10 5,341.07 5,291.37 -2,251.07 11,073.13 6,001,444.32 399,342.39 0.00 11,144.36 13,300.00 71.84 101.10 5,372.24 5,322.54 -2,269.36 11,166.37 6,001,424.63 399,435.33 0.00 11,237.97 13,400.00 71.84 101.10 5,403.40 5,353.70 -2,287.66 11,259.61 6,001,404.94 399,528.28 0.00 11,331.57 13,500.00 71.84 101.10 5,434.57 5,384.87 -2,305.96 11,352.85 6,001,385.24 399,621.23 0.00 11,425.18 13,600.00 71.84 101.10 5,465.73 5,416.03 -2,324.26 11,446.09 6,001,365.55 399,714.18 0.00 11,518.79 13,700.00 71.84 101.10 5,496.90 5,447.20 -2,342.56 11,539.33 6,001,345.86 399,807.13 0.00 11,612.39 13,800.00 71.84 101.10 5,528.06 5,478.36 -2,360.86 11,632.57 6,001,326.17 399,900.08 0.00 11,706.00 13,900.00 71.84 101.10 5,559.23 5,509.53 -2,379.16 11,725.81 6,001,306.48 399,993.03 0.00 11,799.60 14,000.00 71.84 101.10 5,590.39 5,540.69 -2,397.46 11,819.05 6,001,286.79 400,085.97 0.00 11,893.21 14,100.00 71.84 101.10 5,621.56 5,571.86 -2,415.76 11,912.29 6,001,267.10 400,178.92 0.00 11,986.81 14,200.00 71.84 101.10 5,652.73 5,603.03 -2,434.06 12,005.53 6,001,247.41 400,271.87 0.00 12,080.42 14,300.00 71.84 101.10 5,683.89 5,634.19 -2,452.36 12,098.77 6,001,227.72 400,364.82 0.00 12,174.03 14,400.00 71.84 101.10 5,715.06 5,665.36 -2,470.66 12,192.02 6,001,208.03 400,457.77 0.00 12,267.63 14,500.00 71.84 101.10 5,746.22 5,696.52 -2,488.96 12,285.26 6,001,188.34 400,550.72 0.00 12,361.24 14,600.00 71.84 101.10 5,777.39 5,727.69 -2,507.26 12,378.50 6,001,168.65 400,643.67 0.00 12,454.84 14,700.00 71.84 101.10 5,808.55 5,758.85 -2,525.56 12,471.74 6,001,148.95 400,736.61 0.00 12,548.45 14,800.00 71.84 101.10 5,839.72 5,790.02 -2,543.86 12,564.98 6,001,129.26 400,829.56 0.00 12,642.05 14,832.03 71.84 101.10 5,849.70 5,800.00 -2,549.72 12,594.84 6,001,122.96 400,859.33 0.00 12,672.03 Albian 97 14,900.00 71.84 101.10 5,870.88 5,821.18 -2,562.16 12,658.22 6,001,109.57 400,922.51 0.00 12,735.66 15,000.00 71.84 101.10 5,902.05 5,852.35 -2,580.45 12,751.46 6,001,089.88 401,015.46 0.00 12,829.27 15,100.00 71.84 101.10 5,933.21 5,883.51 -2,598.75 12,844.70 6,001,070.19 401,108.41 0.00 12,922.87 15,200.00 71.84 101.10 5,964.38 5,914.68 -2,617.05 12,937.94 6,001,050.50 401,201.36 0.00 13,016.48 15,300.00 71.84 101.10 5,995.55 5,945.85 -2,635.35 13,031.18 6,001,030.81 401,294.31 0.00 13,110.08 15,400.00 71.84 101.10 6,026.71 5,977.01 -2,653.65 13,124.42 6,001,011.12 401,387.25 0.00 13,203.69 15,500.00 71.84 101.10 6,057.88 6,008.18 -2,671.95 13,217.66 6,000,991.43 401,480.20 0.00 13,297.29 2/11/2009 4:05:43PM Page 6 COMPASS 2003.16 Build 42F ~ I s ',.,J' ~ t ~J Database: EDM v16 Prod Company: ConocoPhillips(Alaska) Inc Project: Western North Slope Site: CD3 Alpine Pad Well: Plan: CD3-304 Wellbore: Plan: CD3-304 Design: CD3-304wp11 Planned Survey ConocoPhillips Standard Proposal Report local Co-ordinate Reference: Well Plan: CD3-304 TVD Reference: Plan: CD3-304 (36.3+13.4) @ 49.70ft (Doyon 15 MD Reference: Plan: CD3-304 (36.3+13.4) @ 49.70ft (Doyon 15 North Reference: True Survey Calculation Method: Minimum Curvature Measured Vertical Depth Incli nation Azimuth Depth TVDss +NlS +E!-W (ftl (°) (°- (ftl ft (ft) (ft) 15,586.07 71.84 101.10 6,084.70 6,035.00 -2,687.70 13,297.91 Albion 96 (N anuq) 15,600.00 71.84 101.10 6,089.04 6,039.34 -2,690.25 13,310.90 15,700.00 71.84 101.10 6,120.21 6,070.51 -2,708.55 13,404.15 15,800.00 71.84 101.10 6,151.37 6,101.67 -2,726.85 13,497.39 15,900.00 71.84 101.10 6,182.54 6,132.84 -2,745.15 13,590.63 16,000.00 71.84 101.10 6,213.70 6,164.00 -2,763.45 13,683.87 16,100.00 71.84 101.10 6,244.87 6,195.17 -2,781.75 13,777.11 16,200.00 71.84 101.10 6,276.03 6,226.33 -2,800.05 13,870.35 16,300.00 71.84 101.10 6,307.20 6,257.50 -2,818.35 13,963.59 16,400.00 71.84 101.10 6,338.37 6,288.67 -2,836.65 14,056.83 16,500.00 71.84 101.10 6,369.53 6,319.83 -2,854.95 14,150.07 16,536.80 71.84 101.10 6,381.00 6,331.30 -2,861.68 14,184.38 Start DLS 3. 50 TFO 7 8.99 16,536.92 71.84 101.10 6,381.04 6,331.34 -2,861.70 14,184.50 16,571.35 72.08 102.35 6,391.70 6,342.00 -2,868.35 14,216.55 Top HRZ 16,600.00 72.28 103.38 6,400.47 6,350.77 -2,874.43 14,243.14 16,700.00 73.02 106.96 6,430.31 6,380.61 -2,899.41 14,335.24 16,800.00 73.82 110.52 6,458.85 6,409.15 -2,930.20 14,425.98 16,900.00 74.69 114.04 6,485.99 6,436.29 -2,966.68 14,515.03 16,972.35 75.35 116.57 6,504.70 6,455.00 -2,996.56 14,578.20 Base HRZ 17,000.00 75.60 117.54 6,511.64 6,461.94 -3,008.73 14,602.04 17,100.00 76.57 121.00 6,535.68 6,485.98 -3,056.18 14,686.70 17,170.81 77.29 123.44 6,551.70 6,502.00 -3,092.96 14,745.05 K-1 17,200.00 77.59 124.44 6,558.05 6,508.35 -3,108.86 14,768.68 17,300.00 78.65 127.85 6,578.64 6,528.94 -3,166.57 14,847.69 17,379.48 79.52 130.54 6,593.70 6,544.00 -3,215.88 14,908.17 Kuparuk D 17,400.00 79.74 131.23 6,597.39 6,547.69 -3,229.09 14,923.43 17,500.00 80.88 134.59 6,614.23 6,564.53 -3,296.20 14,995.61 17,600.00 82.04 137.93 6,629.08 6,579.38 -3,367.64 15,063.97 17,665.36 82.81 140.10 6,637.70 6,588.00 -3,416.54 15,106.47 Kuparuk C 17,665.39 82.81 140.10 6,637.70 6,588.00 -3,416.57 15,106.49 Start Build 3.00 17,700.00 83.85 140.10 6,641.72 6,592.02 -3,442.93 15.128.53 17,709.36 84.13 140.10 6,642.70 6,593.00 -3.450.07 15,134.51 7" x 8-3l4" 17,800.00 86.85 140.10 6,649.82 6,600.12 -3,519.39 15,192.46 17,900.00 89.85 140.10 6,652.69 6,602.99 -3,596.06 15,256.58 17,904.89 90.00 140.10 6,652.70 6,603.00 -3,599.81 15,259.71 CD3-304wp 11 Heel Map Map Northing Fasting DLS Vert Section (ft) (ft) 6,035.00 6,000,974.48 401,560.20 0.00 13,377.86 6,000,971.74 401,573.15 0.00 13,390.90 6,000,952.05 401,666.10 0.00 13,484.51 6,000,932.36 401,759.05 0.00 13,578.11 6,000,912.66 401,852.00 0.00 13,671.72 6,000,892.97 401,944.95 0.00 13,765.32 6,000,873.28 402,037.89 0.00 13,858.93 6,000,853.59 402,130.84 0.00 13,952.53 6,000,833.90 402,223.79 0.00 14,046.14 6,000,814.21 402,316.74 0.00 14,139.75 6,000,794.52 402,409.69 0.00 14,233.35 6,000,787.27 402,443.89 0.00 14,267.80 6,000,787.25 402,444.01 0.00 14,267.91 6,000,780.12 402,475.95 3.50 14,300.22 6,000,773.65 402,502.45 3.50 14,327.22 6,000,747.30 402,594.16 3.50 14,422.16 6,000,715.16 402,684.42 3.50 14,517.91 6,000,677.34 402,772.90 3.50 14,614.11 6,000,646.53 402,835.62 3.50 14,683.80 6,000,634.00 402,859.27 3.50 14,710.41 6,000,585.29 402,943.20 3.50 14,806.45 6,000,547.65 403,000.99 3.50 14,874.11 6,000,531.40 403,024.38 3.50 14,901.87 6,000,472.52 403,102.51 3.50 14,996.31 6,000,422.31 403,162.24 3.50 15,070.45 6,000,408.87 403,177.30 3.50 15,089.43 6,000,340.70 403,248.46 3.50 15,180.86 6,000,268.26 403,315.74 3.50 15,270.28 6,000,218.73 403,357.49 3.50 15,327.48 6,000,218.70 403,357.51 0.00 15,327.51 6,000,192.01 403,379.16 3.00 15,357.54 I 6,000,184.78 403,385.02 3.00 15,365.67 6,000,114.61 403,441.93 3.00 15,444.62 6,000,036.99 403,504.89 3.00 15,531.95 6,000,033.20 403,507.96 3.00 15,536.22 2/112009 4:05:43PM Page 7 COMPASS 2003.16 Build 42F s 1 ~ 9 ~ Database: EDM v16 Prod Company: ConocoPhillips(Alaska) Inc. Project: Western North Slope Site: CD3 Alpine Pad Well: Plan: CD3-304 Wellbore: Plan: CD3-304 Design: CD3-304wp11 'I Planned Survey ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: CD3-304 TVD Reference: Plan: CD3-304 (36.3+13.4) @ 49.70ft (Doyon 19 MD Reference: Plan: CD3-304 (36.3+13.4) @ 49.70ft (Doyon 19 North Reference: True Survey Calculation Method: Minimum Curvature Measured Vertical Depth Inclination Azimuth Depth TVDss +NJS +E/-W (ft) [°) (°) (ft) ft (ft) (ft) 17,971.55 92.00 140.10 6,651.54 6,601.84 -3,650.94 15,302.47 18,000.00 92.00 140.10 6,650.54 6,600.84 -3,672.76 15,320.70 18,051.55 92.00 140.10 6,648.74 6,599.04 -3,712.28 15,353.75 18,100.00 90.55 140.10 6,647.67 6,597.97 -3,749.44 15,384.82 18,114.22 90.12 140.10 6,647.59 6,597.89 -3,760.34 15,393.94 18,200.00 90.12 140.10 6,647.41 6,597.71 -3,826.15 15,448.96 18,300.00 90.12 140.10 6,647.20 6,597.50 -3,902.87 15,513.11 18,400.00 90.12 140.10 6,646.99 6,597.29 -3,979.59 15,577.25 18,500.00 90.12 140.10 6,646.78 6,597.08 -4,056.31 15,641.39 18,600.00 90.12 140.10 6,646.56 6,596.86 -4,133.02 15,705.54 18,700.00 90.12 140.10 6,646.35 6,596.65 -4,209.74 15,769.68 18,800.00 90.12 140.10 6,646.14 6,596.44 -4,286.46 15,833.82 18,900.00 90.12 140.10 6,645.93 6,596.23 -4,363.18 15,897.96 19,000.00 90.12 140.10 6,645.72 6,596.02 -4,439.90 15,962.10 19,100.00 90.12 140.10 6,645.51 6,595.81 -4,516.62 16,026.24 19,200.00 90.12 140.11 6,645.30 6,595.60 -4,593.35 16,090.38 19,300.00 90.12 140.11 6,645.08 6,595.38 -4,670.07 16,154.51 19,400.00 90.12 140.11 6,644.87 6,595.17 -4,746.79 16,218.65 19,500.00 90.12 140.11 6,644.66 6,594.96 -4,823.51 16,282.79 19,600.00 90.12 140.11 6,644.44 6,594.74 -4,900.24 16,346.92 19,700.00 90.12 140.11 6,644.23 6,594.53 -4,976.96 16,411.06 19,800.00 90.12 140.11 6,644.02 6,594.32 -5,053.69 16,475.19 19,900.00 90.12 140.11 6,643.80 6,594.10 -5,130.41 16,539.33 19,948.42 90.12 140.11 6,643.70 ~ 6,594.00 -5,167.56 16,570.38 CD3-304wo11 Toe Map Northing (ft) 5,999,981.44 5,999,959.36 5,999,919.35 5,999,881.73 5,999,870.69 5,999,804.07 5,999,726.41 5,999,648.75 5,999,571.09 5,999,493.42 5,999,415.76 5,999,338.10 5,999,260.43 5,999,182.77 5,999,105.10 5,999,027.43 5,998,949.77 5,998,872.10 5,998,794.43 5,998,716.76 5,998,639.10 5,998,561.43 5,998,483.76 5,998,446.15 Map Fasting - (ft) 403,549.94 403,567.85 403,600.30 403,630.81 403,639.76 403,693.79 403,756.78 403,819.76 403,882.74 403,945.72 404,008.70 404,071.68 404,134.66 404,197.64 404,260.62 404,323.60 404,386.58 404,449.55 404,512.53 404,575.51 404,638.48 404,701.45 404,764.43 404,794.92 DLS 6,601.84 3.00 0.00 0.00 3.00 3.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Vert Section 15,594.46 15,619.31 15,664.32 15,706.64 15,719.07 15,794.02 15,881.40 15,968.77 16,056.15 16,143.52 16,230.90 16,318.27 16,405.65 16,493.02 16,580.40 16,667.77 16,755.14 16,842.51 16,929.88 17,017.26 17,104.63 17,192.00 17,279.37 17,321.67 Targets --- - i Target Name ~ - hitlmiss target Dip Angle Dip Dir. TVD +Nl~ +E/-4111 Northing Fasting -Shape (°) (~) (~1 (n) (ft) ln) (ft) CD3-304wp11 Toe 0.00 0.00 6,643.70 -5,167.56 16,570.38 5,998,446.15 404,794.92 - plan hits target - Point CD3-304wp11 Heel 0.00 0.00 6,652.70 -3,599.81 15,259.71 6,000,033.20 403,507.96 - plan hits target - Point -- _.- Casing Points _ . Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 4,003.70 2,475.00 9 5/8" x 12 1/4" 9-5/8 12-1/4 17,709.36 6,642.70 7" x 8-3/4" 7 8-3/4 19,948.44 4-1/2" x 6-1/8" 4-1/2 6-1 /8 2/112009 4:05:43PM Page 8 COMPASS 2003.16 Build 42F Database: EDM v16 Prod Company: ConocoPhillips(Alaska) Inc. Project: Western North Slope Site: CD3 Alpine Pad Well: Plan: CD3-304 Wellbore: Plan: CD3-304 Design: CD3-304wp11 Formations Measured Vertical Vertical Depth Depth Depth SS (ft) (ft) ft 14,832.03 5,849.70 3,521.43 2,324.70 9,521.66 4,194.70 4,050.86 2,489.70 9,194.38 4,092.70 15,586.07 6,084.70 5,334.34 2,889.70 17,379.48 6,593.70 9,056.40 4,049.70 16,571.35 6,391.70 17,170.81 6,551.70 8,533.39 3,886.70 16,972.35 6,504.70 17,665.36 6,637.70 Plan Annotations ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: CD3-304 TVD Reference: Plan: CD3-304 (36.3+13.4) @ 49.70ft (Doyon 19 MD Reference: Plan: CD3-304 (36.3+13.4) @ 49.70ft (Doyon 19 North Reference: True Survey Calculation Method: Minimum Curvature Name Albion 97 C-40 K-2 Basal C-30 K-2 Albion 96 (Nanuq) C-20 Kuparuk D K-3 Basal Top HRZ K-1 K-3 Base HRZ Kuparuk C Dip pip Direction Lithology {°) {°) ~, Measured Vertical Local Coordinates Depth Depth +N/S +E/-W (ft) (ft) (ft) (ft) Comment 300.00 300.00 0.00 0.00 Start Build 2.00 500.00 499.84 -2.95 6.32 Start Build 3.00 900.00 893.04 -32.25 69.16 Start DLS 3.50 TFO -15.91 2,510.59 2,009.67 -294.96 1,106.23 Start 14026.21 hold at 2510.59 MD 16,536.80 6,381.00 -2,861.68 14,184.38 Start DLS 3.50 TFO 78.99 17,665.39 6,637.70 -3,416.57 15,106.49 Start Build 3.00 19,948.44 TD at 19948.44 N.4D z~ 2/11/2009 4:05:43PM Page 9 COMPASS 2003.16 Build 42F Vim,, e r.4: g ~ f ~ ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD3 Fiord Pad Plan: CD3-304 Plan: CD3-304 CD3-304wp11 z ~iip~rr ~r~illire ."'" r~vi Clearance Summary Anticollision Report 11 February, 2009 ~ Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad -Plan: CD3-304 -Plan: CD3-304 -CD3-304wp11 Well Coordinates: 6,003,607.82 N, 1,528,337.04E (70° 25' 09.03" N, 150° 54' 47.12" W) „ ~ ~ Datum Height: Plan: CD3~04 (36.3+13.4) @ 49.70ft (Doyon 19) ~~ Scan Range: 0.00 to 19,948.44 ft. Measured Depth. Scan Radius is 2,191.21 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 42F Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 Y~, _.. Sperry Orllling Ser•vlces i ~ i't CD3-302PB1 GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference CD3-304wp11 36.30 To 19948.44 CD3-302 CD3-302PB3 CD3-301 3s GD3-108 CD3-302PB2 ~ 250 - CD3-307 CD3-303 ,~ 500 - -_ _ CD3-301 P61 750 CD3-107L1 ~~ ~ D-/3fio looo - -~ -_ _~'~__ „ r~;" 1250 - CD3-107 ---- ~0/331~ `"~ ~ "` 30 1500 -- ~ ti CD3-109 ------------ --- CD3-111 L1 CD3-110 ~.. _ I ~ ` -60 / 300 ~ ,~ ~ 60 CD3-305 _30 / 3; CD3-11~ . ~ ~., ~ ~~. t ~t ~ ~ ~ r~ _: ~ ~ * CD3-30,~PB1 ,~ D3-112 t ~~ ~~ ~ _..... , ; ~ „ r , C~3-114 ~ ~ ~ 1 ~ ~ ~~ ~, ~~ -60 / ~~,00 , 'C~3-113 , ~. -' ; , __ ~,~ CD3~05PB1wp05 yCL'f3-115wp ~/~70~-r `~';., ~-' 90 r '`~' CD3-305wp05 - ~ r,( \ - - CD3-316A -~ ,~, CD3-316 _120 / 240~~" ,~`~ ~ ``~~ ' 120 CD3-305P61wp05 :-=fi CD3-305wp05 `~ I~` 200 CD3-305 -150 / 210 ~ ~ 150 CD3-305PB1 ~~ _180/180 CD3-306 (wp01) Travelling Cylinder Azimuth (TFO+AZI) [9 vs Centre to Centre Separation [100 ft/in] Azimidh (TFO+AZI) [°] vs Centre to Centre ~~~ Ellipsoid Color 250 1750 2000 5000 6000 14000 16000 500 2000 2500 6000 7000 16000 18000 750 2500 3000 7000 8000 18000 20000 1000 3000 3500 8000 9000 20000 25000 1250 3500 4000 9000 10000 1500 4000 4500 10000 12000 1750 4500 5000 12000 14000 CD3-303 0 / 360 i - ~~~ ~~ fi7 - ~~ ~. / • CD3; 302PB3 GD3-302PB2 0~~ '~~ CD3-302PB1 CD3-302 90 T k ~- ~ \ ~ i` ' . ~~` -120 / 240 ~ ~/; 25 ~ ~ 120 ~~~ .~ ~~; CD3-306 (wp01) -150 / 210 150 50 -180 / 180 HALLIBURTC]N ConocoPhillips(Alaska) Inc. -WNS Western North Slope Anticollision Report for Plan: CD3-304 -CD3-304wp11 Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad -Plan: CD3-304 -Plan: CD3-304 -CD3-304wp11 Scan Range: 0.00 to 19,948.44 ft. Measured Depth. Scan Radius is 2,191.21 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name -Design (ft) (ft) (ft) (ft) ft CD3 Fiord Pad CD3-107 -CD3-107 -CD3-107 374.16 57.33 374.16 49.39 375.00 7.222 Centre Distance Pass -Major Risk CD3-107 -CD3-107 -CD3-107 472.63 58.23 472.63 48.25 474.97 5.837 Clearance Factor Pass -Major Risk CD3-107 -CD3-107L1 -CD3-107L1 373.95 57.33 373.95 49.39 375.00 7.226 Centre Distance Pass -Major Risk CD3-107 -CD3-107L1 -CD3-107L1 472.45 58.23 472.45 48.25 475.00 5.838 Clearance Factor Pass -Major Risk CD3-107 -CD3-307 -CD3-307 374.01 57.33 374.01 49.39 375.00 7.225 Centre Distance Pass -Major Risk CD3-107 -CD3-307 -CD3-307 472.51 58.23 472.51 48.25 475.00 5.838 Clearance Factor Pass -Major Risk CD3-108 -CD3-108 -CD3-108 445.35 75.75 445.35 67.48 450.00 9.157 Centre Distance Pass -Major Risk CD3-108 -CD3-108 -CD3-108 542.32 76.66 542.32 66.57 550.00 7.595 Clearance Factor Pass -Major Risk CD3-109 -CD3-109 -CD3-109 36.40 99.79 36.40 98.88 36.30 109.272 Centre Distance Pass -Major Risk CD3-109 -CD3-109 -CD3-109 684.95 104.32 684.95 90.44 700.00 7.516 Clearance Factor Pass -Major Risk CD3-110 -CD3-110 -CD3-110 421.04 117.58 421.04 108.72 425.00 13.265 Centre Distance Pass -Major Risk CD3-110 -CD3-110 -CD3-110 517.28 118.56 517.28 107.83 525.00 11.046 Clearance Factor Pass -Major Risk CD3-111 -CD3-111 -CD3-111 36.40 139.62 36.40 138.71 36.10 152.879 Centre Distance Pass -Major Risk CD3-111 -CD3-111 -CD3-111 324.35 142.34 324.35 135.49 325.00 20.775 Clearance Factor Pass -Major Risk CD3-111 -CD3-111 L1 -CD3-111 L1 36.40 139.62 36.40 138.71 36.10 152.879 Centre Distance Pass -Major Risk CD3-111 -CD3-111 L1 -CD3-111 L1 324.35 142.34 324.35 135.49 325.00 20.775 Clearance Factor Pass -Major Risk CD3-112 -CD3-112 -CD3-112 225.39 158.86 225.39 154.16 225.00 33.816 Centre Distance Pass -Major Risk CD3-112 -CD3-112 -CD3-112 300.00 159.45 300.00 153.13 300.00 25.233 Clearance Factor Pass -Major Risk CD3-113 -CD3-113 -CD3-113 36.60 180.22 36.60 179.30 36.80 196.775 Centre Distance Pass -Major Risk CD3-113 -CD3-113 -CD3-113 395.16 181.27 395.16 172.85 400.00 21.548 Clearance Factor Pass -Major Risk CD3-114 -CD3-114 -CD3-114 36.40 199.92 36.40 199.01 36.75 218.912 Centre Distance Pass -Major Risk CD3-114 -CD3-114 -CD3-114 370.77 200.93 370.77 193.04 375.00 25.487 Clearance Factor Pass -Major Risk CD3-301 -CD3-301 -CD3-301 149.48 60.07 149.48 57.00 150.00 19.601 Centre Distance Pass -Major Risk CD3-301 -CD3-301 -CD3-301 552.06 62.18 552.06 50.37 550.00 5.263 Clearance Factor Pass -Major Risk CD3-301 -CD3-301 P61 -CD3-301 PB1 149.48 60.07 149.48 57.00 150.00 19.601 Centre Distance Pass -Major Risk CD3-301 -CD3-301 P61 -CD3-301 PB1 552.06 62.18 552.06 50.37 550.00 5.263 Clearance Factor Pass -Major Risk CD3-302 -CD3-302 -CD3-302 174.70 40.15 174.70 36.55 175.00 11.141 Centre Distance Pass -Major Risk CD3-302 -CD3-302 -CD3-302 249.70 40.79 249.70 35.56 250.00 7.797 Clearance Factor Pass -Major Risk • r L 11 February, 2009 - 15:17 Page 2 of 6 COMPASS HALLIBURTON ConocoPhillips(Alaska) Inc. -WNS Western North Slope Anticollision Report for Plan: CD3-304 -CD3-304wp11 Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad -Plan: CD3-304 -Plan: CD3~04 - CD3~04wp11 Scan Range: 0.00 to 19,948.44 ft. Measured Depth. Scan Radius is 2,191.21 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name -Design (ft) (ft) (ft) (ft) ft CD3-302 -CD3-302P61 -CD3-302P61 174.30 40.15 174.30 36.56 175.00 11.168 Centre Distance Pass -Major Risk CD3-302 -CD3-302PB1 -CD3-302PB1 249.30 40.78 249.30 35.56 250.00 7.808 Clearance Factor Pass -Major Risk CD3-302 -CD3-302PB2 -CD3-302PB2 174.30 40.15 174.30 36.56 175.00 11.168 Centre Distance Pass -Major Risk CD3-302 -CD3-302PB2 -CD3-302P62 249.30 40.78 249.30 35.56 250.00 7.808 Clearance Factor Pass -Major Risk CD3-302 -CD3-302PB3 -CD3-302PB3 174.70 40.15 174.70 36.55 175.00 11.141 Centre Distance Pass -Major Risk CD3-302 -CD3-302P63 -CD3-302PB3 249.70 40.79 249.70 35.56 250.00 7.797 Clearance Factor Pass -Major Risk CD3-303 -CD3-303 -CD3-303 36.40 20.24 36.40 19.32 36.35 22.159 Centre Distance Pass -Major Risk CD3-303 -CD3-303 -CD3-303 576.27 23.22 576.27 10.99 575.00: 1.900 Clearance Factor Pass -Major Risk ~„ CD3-305 -CD3-305 -CD3-305wp05 299.80 19.96 299.80 13.70 300.00 3.189 Centre Distance Pass -Major Risk 'r°"`~ CD3-305 -CD3-305 -CD3-305wp05 374.38 20.73 374.38 12.85 375.00 2.630 Clearance Factor Pass -Major Risk ~'-"-~ CD3-305 -CD3-305 -CD3-305 324.17 19.10 324.17 12.85 325.00 3.055 Centre Distance Pass -Major Risk ~-~ CD3-305 - GD3-305 -CD3-305 398.73 19.98 398.73 12.27 400.00 2:591 Clearance Factor Pass -Major Risk CD3-305 -CD3-305PB1 -CD3-305PB1 324.17 19.10 324.17 12.85 325.00 3.055 Centre Distance Pass -Major Risk ~'°" CD3-305 -CD3-305P61 -CD3-305PB1 398.73 19.98 398.73 12.27 400.00 2.591 Clearance Factor Pass -Major Risk .~- y..... CD3-305 -CD3-305P61 -CD3-305P61wp05 299.80 19.96 299.80 13.70 300.00 3.189 Centre Distance Pass -Major Risk .. t CD3-305 -CD3-305PB1 -CD3-305P61wp05 374.38 20.73 374.38 12.85 375.00 2.630 Clearance Factor Pass -Major Risk CD3-316 -CD3-316 -CD3-316 250.19 238.19 250.19 232.95 250.00 45.489 Centre Distance Pass -Major Risk CD3-316 -CD3-316 -CD3-316 323.66 238.73 323.66 231.89 325.00 34.902 Clearance Factor Pass -Major Risk CD3-316 -CD3-316 -CD3-316PB1wp04 275.20 239.78 275.20 234.05 275.00 41.895 Centre Distance Pass -Major Risk CD3-316 -CD3-316 -CD3-316P61wp04 370.58 240.50 370.58 232.68 375.00 30.753 Clearance Factor Pass -Major Risk CD3-316 -CD3-316A -CD3-316A 250.19 238.19 250.19 232.95 250.00 45.489 Centre Distance Pass -Major Risk CD3-316 -CD3-316A -CD3-316A 323.66 238.73 323.66 231.89 325.00 34.902 Clearance Factor Pass -Major Risk CD3-316 -CD3-316AP61 -CD3-316AP61 250.19 238.19 250.19 232.95 250.00 45.489 Centre Distance Pass -Major Risk CD3-316 -CD3-316APB1 -CD3-316APB1 323.66 238.73 323.66 231.89 325.00 34.902 Clearance Factor Pass -Major Risk Plan: CD3-306 -Plan: CD3-306 -CD3-306 (wp01) 276.10 39.84 276.10 34.10 275.00 6.943 Centre Distance Pass -Major Risk Plan: CD3-306 -Plan: CD3-306 -CD3-306 (wp01) 572.75 42.18 572.75 29.96 575.00 3.452 Clearance Factor Pass -Major Risk Rig: CD3-115 -Rig: CD3-115 -CD3-115 RigSurveys 299.70 219.78 299.70 213.46 300.00 34.801 Centre Distance Pass -Major Risk Rig: CD3-115 -Rig: CD3-115 -CD3-115 RigSurveys 370.46 220.61 370.46 212.73 375.00 28.012 Clearance Factor Pass -Major Risk Rig: CD3-115 -Rig: CD3-115 -CD3-115wp07 275.20 220.04 275.20 214.32 275.00 38.446 Centre Distance Pass -Major Risk Rig: CD3-115 -Rig: CD3-115 -CD3-115wp07 370.94 220.77 370.94 212.94 375.00 28.209 Clearance Factor Pass -Major Risk L 11 February, 2009 - 15:17 Page 3 of 6 COMPASS ConocoPhillips(Alaska) Inc. -WNS :-~ `~ HALLIBURTON Western North Slope Anticollision Report for Plan: CD3-304 -CD3-304wp11 Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad -Plan: CD3-304 -Plan: CD3-304 -CD3-304wp11 Scan Range: 0.00 to 19,948.44 ft. Measured Depth. Scan Radius is 2,191.21 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Site Name Comparison Well Name - Wellbore Name -Design CD4 Nanuq Pad ;,; Kuparuk 3S Pad Survev tool aroaram Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Depth Distance Depth Separation Depth Factor Minimum Separation Warning (ft) (ft) (ft) (ft) ft From To Survey/Plan (ft) Ift) 36.30 1,000.00 CD3-304wp11 1,000.00 19,948.44 CD3-304wp11 Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor =Distance Between Profiles / (Distance Between Profiles -Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. Survey Tool CB-GYRO-SS MW D+I F R-AK-CAZ-SC 11 February, 2009 - 15:17 Page 4 of 6 COMPASS • LJ ConocoPhillips(Alaska) Inc. -WNS HALLIBURTON Western North Slope Anticollision Report for Plan: CD3-304 -CD3-304wp11 Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to Plan: CD3-304 (36.3+13.4) @ 49.70ft (Doyon 19). Northing and Easting are relative to Plan: CD3-304. Coordinate System is US State Plane 1983, Alaska Zone 4. Central Meridian is -150.00°, Grid Convergence at Surface is: -0.86 °. La~d~r Flat -~- -~ C 1950 .~,.~ g a'~ ~ C `~' O F ~~~ _.~ (O ,~ ca 1300 .~ ~ 9~ ~ ~f1~ _~ Q? i i ~ +~ C Q7 O ~~~ a--~ 4} C Q) i ~ i i i i i ~ i i i ~~ i i i ~ ~ ~ $, } i i i _~ r ~ ~ ~~ i i i i i ~ i i i ~ ~ ~ i i i ~ i i ~ ~ ~~ ~ ~ ~ ~ -34- '~s- i i i i i i i i ~ i ~~ ~ i i i -~ i ~ i i ~}. i i i i i i ^~'- ~ i i i i -~' i i i i i i i i i i i i i i ~ i i i i i ~ i ~- i i i i i i i i i i ~,_ n ~D DD 6DOD 90 0D 1~DDD 150 00 ~' Measured Depth (3000 ftfin~ -Cr ~- V U3-J UL, 4.U3.3VL, I.UJ-JV2 VJ D3-3D2,CD3.302PB1,CD3.302P@1 V11 D3-3D2, CD3.302 P@2, CD3.302P @2 V6 D3-1D9, CD3.1D9, CD3-109 V5 D3-111, CD3.111 L1, CD3-111 L1 V1 D3-111, C03.111 ,CD3-111 V7 Ian: C D4-303, Plan: CD4-303ST1, CD4.303 ST1wp06 D3.112, CD3-112, CD3-112 V3 D3-110, CD3-11D, CD3-11D V12 ig: CD3-115, Rig: C D3-115, CD3.115wp07 V4 D3-113, CD3.113, CD3-113 V6 D3-1D8, CD3.108, CD3.1D8 V14 D3.316, CD3.316, CD3-316P B1w p04 V8 D8-318, CD3.316,CD3-318 VD D3-316, CD3-316AP@1,CD3-316APB1 VD D3-316, CD3-316A, CD3.316AVD D3-107, CD3.1D7L1,CD3-107L1 VD D3-107, C03.3D7, CD3-307 V4 D3-1D7, CD3-107, CD3-107 V7 relim:2N-Cairn DD0,2N-Cairn DDO-A,2N-Cairn DD 03-3D3, CD3-303, CD3-3D3 VO D3-3D1,CD3.3D1PB1,CD3.301PB1 V1 D3-301, CD3.301 ,CD3-3D1 V4 D3-114, CD3.114,CD3-114 V14 Ian: C D3-306, Plan: CD3.306, CD3-306 (wp01) V14 D3-305, CD3.3D5,CD3-3D5wp05 1!0 D3-3D5, C D 3.305 P B 1, C D3.305 P@ 1 w p05 V4 D3-305, CD3.305,CD3-3D5 VD u ~~ ~ J 11 February, 2009 - 15:17 Page 5 of 6 COMPASS ConocoPhillips(Alaska) Inc. -WNS HALLIk3URTt3N Western North Slope Anticollision Report for Plan: CD3-304 -CD3-304wp11 Clearance Factor Plot: Measured Depth versus Separation(Clearance) Factor 14J~9 .1 .r} 7 ~~ - ~J C x a '` ~' sus 0 U to ., Q 5~~ ~ • ~ ~ ;x . n N _ r.~7 3.75 Wse I ^ f . . 4l3[ i ry ~ € ~ ~_p ~, _ I ~ i I i_ ~ ~~r ~ _ _ '~~ s', -- ;_... I -- - ~~ R :-_ G ,-I I ~ _ o ,, . i ...._~ ~.~ _„ ' ~ s- tl I- - - i -- - -- - _~,p.., . u pp, s p s-, , I '-~ ; I I . , q, ' R i i 'Y r 1 ~... {. t ~ ~, d ~ 3 I .._. - ' I i, d " ~ I _ a i ...~. ~ ~ ~~ _ ~ ~ i ~ ~ y a i i ~ - `s~ E ._ s i - --- ~ ...a... x ~ - -- -_ .. ..,, ~.i ~_ .-e ,, i ,~ N' i ~' _-~_.. - ... _.. - ` - y + .. .: ~ , ~.. 3 ii ~ , E ... , , I~ - - - __ I I-- ' s - 9 a i i ~ I ~ ~ I_f ° ~ r i I ~ E 0 1=so ^soo also soao rasa asI3D slso looo0 1i~so i~s0o 1a75o Isooo Measured Depth (2500 ftAn) CD3-3D3, CD3-302PB1, CD3-302PB1 V11 CD3-3D2, CD3-302PB2, C03.3D2PB2 VB CD3-109, CD3-109, CD3-109 V5 CD3.111, CD3-111L1, CD3-111 L1 V1 CD3-111, CD3-111, CD3-111 V7 Plan: CD4-303, Plan: CD4.303ST1,CD4-3D3STiwp06 VF CD3-112, CD3-112, CD3-112 ~f3 CD3.110, CD3.11D, CD3.110 V12 Rig: CD3.115, Rig: CD3-115, CD3-115wp07 4~3 CD3-113, CD3-113, CD3-113 VB CD3-108, CD3-1D$, CD3-108 U14 C03.316, CD3-316, CD3.316PB1wp04 V8 CD3-316, CD3.316, CD3.316 VD CD3-316, CD3-316APB1, CD3-316APB1 ~ CD3-316, CD3-316A, CD3-316ALti CD3-107, CD3.107L1, CD3-107L1 W CD3-107, CD3.307, CD3.307 V4 CD3-107, CD3-107, CD3-107 VF Prelim:2N-Cairn DD0,2N-Cairn DDO-R,2N-Cairn DDO-A( CD3-303, CD3-303, CD3-303 W CD3-3D1,CD3-301PB1,CD3.301PB1 V1 CD3.3D1, CD3.301, CD3.3D1 V4 CD3-114, CD3.114, CD3-114 V14 Plan: CD3-306, Plan: CD3.306, CD3-3D6 (wpD1) V14 CD3.305, CD3-305, CD3-3D5wp05 UD CD3-305, CD3.305PB1, CD3-305PB1wp05 V4 CD3-3D5, CD3-3D5,CD3-305 VO CD3.305, CD3-305PB1, CD3-305PB1 V0 11 February, 2009 - 15:17 Page 6 of 6 COMPASS Project: Western North Slope ConocoPhillips Site: CD3 Fiord Pad C D 3-304wp 11 304 Pl CD3 an: - Well: Wellbore: Plan: CD3~04 Quarter Mile View CD3-304wp11 1 ,~p 1~9 'S'~~~ G°~ O''~ G° 3-107L1 ---_ ~ d w I 5000 0 _ _ c~3' ~n I r'.o a j I 2500 ~ ...... ~ _.._ w ---...._ ~; . . _.. ...._._ _._. . .~ C ~, ~ w y 'fl W o ! ~ iO ' % O M M / ~~ Y, -- ~ _-_. _. _.. _ CV .-. L z --- -2500 P ` ~ hm i ~ Q -M ~~ M Q^^ ~ °~~ -5000 3 ~~ ~ I G° ~ i i -7500 ~ I I 2500 5000 7500 10000 12500 15000 17500 20000 22500 West(-)/East(+) (2500 ft/in) Opxraa: CamcNNNps(AbkW hc.-NNS 6eS]Ca~ctNn: -0D6 bDNa SN/A gel2 Wulxn Nal~Sbpe MoAnNkDxFa1M: ZI]] AIE NO: iN/A N§k CDSa01wp11 Dy: SOJ] AYINa SN/A ~ SN/p payepper IDO ft SYNem fiVDl ¢eMenu: Neon Sea lsvN sarlm.lowen Origind VS Plane: i11.OD ra.m xa ria~:cwapa %: 16RSJD)M H VIEW VS Plan6: ~ f ~.~ RKBN~1: 09)0 S V: 6DDS60)DP tt aNISYMem: aalSaud/W4 SaNbn NS)leMenro: Sbl CommenTs: POOL: Pgan View 8 ~ 88p O 8 ~ 8 N 8 ~ $ 8 $ ~ N 5 ~~~~w~ ~~ w• ~~~ww•t_ ~e1w •n •~e ~>fe1 ~, ;j '« __~. _y., 9c L Q D1 O t D7 0) E 0 Combo Preuew Page 1 of i (CD3304wp11 Todbox>ds) )02000 loiooo ~ooooo >99000 79800D 7970DD i960D0 2/11/2009 3:51 PM 8 VerTicd SecTion dong "View VS Plane" Closest in POOL ClosestAQproach: Reference Well: CD3-3 04wp11 Plan Offset Well: CD3-308 Coords. - Coords. - ASP ASP 3-D dr-ctr I i .e:~~l Meas. Incl. TRUE Subsea N(+)/S(-) V'~ew VS Meas. Incl. TRUE Subsea N(+)/5(-) View VS Distance. `"' ~ Depth Angle Azi. TVD E(+)/W(- (111) meets Depth Angle Azi. TVD E(+)/W(- (111j meets ~ D'stance (2948.47 m Distance (2948.47 ft) in POOL (17709 ft) in POOL (17709 - 19948.44 MD) to - 19948.44 MD) to CD3-305 (15222 - CD3-304wp11 Plan 294$.5 '..".'1ili~'I 17709.39 84.13 140.1 6593242 5999932 1543418 15365.47 16859 MD) 16151.3 89.88 145.06 6613.38 5998276 1540979 13734.83 (15222 - 16859 MD I ~1 / CD3-304wp11 PodSummary.xls 2111/2009 3:54 PM • • CD3-304 Surface Location: ~ CF'AI foo~dinate Converter From: ----- I To: i Datum: IJADS; .,; Region: alaska Datum: NAD27 Region: alaska ~. 3'~ LatitudelLongitude Decimal Degrees. ~ ~"' LatitudelLongitude 'Decimal Degrees ~ ' '' ~' UTM Zone: ~~ ~ South UTM Zone:'True i~ South I I ~ :~ State Plane Zone: ~- _.d .l Units: us-ft ±~ i State Plane Zone: 1Tr~~ Units: us-ft ~ l-' ,, _-, i -~rdy;; ~ Legal Description (NAD27 only] ' r ~- Stacking Coordinates: - --- ---- - ------------ --Legal Description ----- - ---- ---- _ ___.. ------_-__-- ,~ ~: 1525337.04 ii r----- 3 i ' ~ - Township: ;012 N Range: 005 E +~ ~~ !' Y: 6003607.82 Meridian: ,~_~ + Sectian~u i' 3 I _ -- - - --------- - --- ------~ ---- _' - IFNL + ;39120172 FEL + ~~3°.79029 - ----------- ...... - -_ ....-- -- ...- -- ... .. -- --- -- - - i .........................._._._......................... I Transform Quit Help CD3-304wp11 Intermediate Casing Point: . - T #^:.. ~ CPdI Ordinate (~anverter~ ~~' ' - 4 i ; -From: - -- - - - To: - _- - - _ r i _ ~ Daturn: Np,pgl Region: dla-k;a + Datum: NAD?7 ~ Region: ala~ka i-' LatitudelLongitude ~L~ecimal Degrees ~ ~' LatitudelLongitude D~ma Degrees +j I I ~"" UTM Zane: ~- (""' South ~ ~" UTM Zane: True ("v South ' ~ State Plane Zone: ~:~ ~ Units: ,as.jt ~i ~ I i' State Plane Zane: True ~±! Units: ~us-ft + r~ ~ _,;:_ - ~~ Legal Description (PJAD27 only] ~ - -- - - _ _ _._ . ' ~-- _ __ _- _ - - - _ --- f Starting Coordinates - -- - - - Legal Description ! -- ' X: '1543417.07 Township: 3012 =.N ~Jj Range: ;005 E + i Y: 5999952.59 'i ~ Sectian:ll r I I Meridian: U ±~ r ~FNL 2037.165) :FEL 1454.3539 . ._Transform . .. _ Uuit Help ORIGIN:4L 11 TD: Fem. CPAI Coordinate Converter '`' _~~~' Datum: ~] Regron: alaska ~ ~ Datum: hJ,gpW~7 ~~ Region: ial~ I:.a r ~' LatitudelLongitude Decimal Degrees ~ ~ ~ '~ latitudefLongikude ',,Decimal Degrees ~~ i ~~ I ~' UTM Zane: ~ i Sauth i ` UTP~I Zone: True 1- Sor.rkh ;~ State Plane Zone: i'" ~ Units: us-fk~ '^ State Plane Zone: ;True ~ Uruks: us-ft [-` -. _ , _. _. -; o ~: Legal Descripkion (N;~D27 unlyJ .I -_ -.- ~--- 5t rh or n t s.-------------- -----...- ------ Le alDescri Lion -- -- - .. ----- ---- ~- a ng Co di a e g p - I X: ~15448~7.00 Township: X01 t•J w Rar~ge: Or~5 Ems' I 2 ~ J 1 Y: 599919A.Oii Meridian: ~~ ~~ Section:17 - - ~ -_- FhJL ~~117.71°7 jFEL ~ 2:3.552406 ............T ransform......_...... Ii i ----Quit ~ ~. HeIP~ I ~RIGII~'AL REV DATE BY CK APP D PT[ON REV DATE BY CK AP DESCRIPTION 5 4/8/07 AG DB C.A. UPDATED P 7041ACS 4 5/13/06 CZ DB G. UPDATED PER K66035ACS N ~' ROJEC ~~~~ y ~, Oil LL 51 E `--x v - :D-s r _ AL~.I~~ ~ °' PIPE ~ _s ` `~ ~ ~ ' ~ + P ~: ~ -'; ~q ~ (s. $ r ~,~Nt~?, A yy~ LOCATION OF y. ~ •-I ~" TH15 SURVEY ;?; k~ P,NE :i?2N =: ALPINE SATELLITE DEVELOPMENT ~~ .- r~IN VICINITY MAP NOT TO SCALE OF pAD `DAR StiGTS SKW CD - 3 DD PAo '~ ~ $ ~ ~ ~ ~,~ C~tdk~}4 P V' SA p 5 ~ ~ a , 8$ i ~~,. M:` ~ . _L 8$ p ~ ~g$$ ~ ~~~ i~ $~ .• _ o ° ~ o - DVCZft ~ ~QaVIf. PR~ A~ ~~ p i ~ ) ~t . Q~GG}N ~OOV1.E RA SK 4 SE wpR PLANT N MER~~~CY ~ ASPC ~AR~ERS N ~ ~ ~ ~ 13~~H0` w ~ w ~ LEGEND; O PROPOSED CONDUCTOR o ~' z 9 O "a ~ ~ z • EXISTING CONDUCTOR ~ ~r ° ~, ~ ~ ~y ~ u1 ox' 0 P 0 KUUKPIK ~, ~~~ - L~CMF~ 19@ E81a1/aia ~ N~a1ay~ AWIr OYOf ~ QIOO~ST5dM6 No-soRS (WileNnaY Alpine Survey Office yl ALPINE MODULE:CD30 UNIT: CD ConocoPhilli s ALPINE PROJECT p CD-3 WELL CONDUCTORS Alaska, Inc. AS-BUILT LOCATIONS CADD FfLE NO. 05-PJ3-~3-1A 11 3 4J5 DRAN7NG NO. CE-GD3(~ -111 PART: 1 of 3 REV: 5 ORIGINAL 6 14/8/07 1 AG 1 DB 1 C.A.1 REVISED 1~k K07041 ACS 1 5 (5/13/06 CZ 1 DB 1 C~UPDATED PER Km6035ACS ALL CONDUCTORS ARE LOCATED IN PROTRACTED SEC.5, T 12 N, R 5 E, U.f~l. SEC. LINE 0 S EXIST WELL 'Y' 'X` LAT.(N) LONG.(W} FSL F L GND PAD CD3-301 1 150' 54' 45.411 7.3 13.5 CD3-302 6 003 616.72 1 528 376.38 70' 25' 09.124" 150' S4' 45.972" 1377' 700' 7.3 13.2 CD3-303 1 150' 54' 46.547 1 7 7 7.3 13.3 CD3-3@4 7.3 13.4 CD3-305 6 003 603.48 1 528 317.56 150' 54' 47.691" 1363' 758' 7.3 13.6 CD3-106 6 003 599.43 1 528 298.37 70' 25' 08.942" 15@' 54' 48.252 1359' 777' 7.3 13,4 CD3-107 6 003 594.38 1 528 278,93 150' 54' 48.820' 1354 797' 7.3 13,2 CD3-108 6 003 589.85 1 528 259.61 4 150' S4' 49.385° 1349' 816' 7.3 13.1 CD3-109 6 003 585.27 1 528 239.85 7@' 25 08.794 150' 54 49.962 1344 836 7.3 13.1 CD3-110 6 003 580.97 1 528 220.32 70' 25' 08.749" 150' S4' 50.533 1339' 855' 7.3 13.0 CD3-111 6 003 576.13 1 528 201.@8 150' 54' 51.095' 1334' 874' 7.3 12.9 CD3-112 6 003 572.43 1 528 181.20 70' 25' 08.660" 150' 54' 51.676' 1330' 894' 7.3 13.1 CD3-113 6 003 567.62 1 528 161.38 150' 54 52.255 1 7.3 CD3-114 6 003 563.04 1 528 142.21 70' 25' @8.561" 150' 54' 52.815" 1320' 933' 7.3 CD3-115 6 003 558.57 1 528 122.60 150' 54' 53.388' 1 7.3 CD3-116 6 @03 554,04 1 528 103.39 .4 150' 54' 53.950 1 7.3 CD3-117 6 003 549.51 1 528 083.99 150` 54 54.516 1 1 7.3 CD3-X18 6 003 544.88 1 52B 064.44 70' 25' 08.372" 15@' S4' 55.086" 1 1' 1 7.3 CD3- 7.3 CD3- 7.3 CD3- 7.3 CD3- 7.3 CD3- 7.3 CD3- 7.3 NOTES: 1. COORDINATES SHOWN HEREON ARE ALASKA STATE PLANE, ZONE 4, NAD 83. 2. ELEVAT10N5 SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL (B.P.M.S.L.) yi ALPINE MODULE:CD30 UNIT: CD ConocoPhillips ALPINE PROJECT CD-3 WELL CONDUCTORS Alaska, Inc. AS-BUILT LOCATIONS CADD FILE N0. DRAWING N0; PART: REV_ 05-~3-03-1A-2 3-17-05 CE-CD3-111 2 of 3 ~ REV DATE BY CK APP D T[DN REV DATE BY CK AP DESCRIPTION 4 4/$/07 AG DB C, A. REVISED K07041ACS 3 5/13/06 CZ GD C. PDATED PER K06035ACS NOTES 1. ALL COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, NAD 83. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL. ORIGINAL GROUND ELEVATIONS WERE DERIVED FROM THE AVERAGE ELEVATION ALONG THE TOE OF THE CD-3 GRAVEL PAD. 3. BASIS OF COORDINATES: ALPINE PERMANENT CONTROL MONUMENTS PER SURVEY BY KUUKPIK/LCMF, MARCH 2005 4. DATES OF AS-BUILT SURVEYS: WELL CONDUCTORS CD3-108, CD3-109, CD3-110, CD3-111, 3/16/05, FB 2005-08 PGS 52-53; CD3-301, CD3-302, 3/19/05, FB 2005-09 PGS. 24-25; CD3-304, 4/16/05, FB 2005-12 PGS 35-37. CD3-303 2/10/06, FB 2006-03 PG 11. CD3-112, 2/23/06, FB 2006-05 PGS 29-31. CD3-107, 3/26/06, FB 2006-09, PGS.9,25-27. CD3-305, CD3-106, CD3-113, CD3-114, CD3-115, CD3-116, CD3-117, 5/2/06, FB 2006-11 PGS 57-61; CD3-X18, 4/7/07, FB 2007-07 PG. 67. SURVEYOR'S CERTIRCATE !~~-~r~1N~~ I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED OF ~~~.~E p~gS~ + Y I T H ~F L U E R 1 UI I .. `. '~ M D REC NDER M OR URVEY MADE BY REPRESENTS A 5 LT # AS-B EREON ACTUALLY EXIST ~ •'• S' # 1# SUPERVISION, THAT THE MONUMENTS SHOWN H ;• •. DIMENSIONS AND OTHER DETAILS ARE T : ALL *#` AS DESCRIBED, AND THA i * ~ CORRECT .° . . • s 49th 1 /.....::.....~ .............................i..... LS-5077 ^ / DATE: REGISTRATION N0. • ~ Donald G. Bruce t o~ ~ • # ~ • •'•. No. LS-5077 :' ~4r ~ # c .•~ KUUKPIK ...~~a~ ~##~~FO ;•• ~ , • ............ ~ _ ~~~ -~~w..rr~woe c~ ~ ~s Alpine Survey Office y~ ALPINE MODULE:CD30 UNIT: CD Philli s C ALPINE PROJECT p onoco CD-3 WELL CONDUCTORS Alaska, Inc. AS-BUILT LOCATIONS CADD FILE N©. PJ5-P~3-03-1A-3 3-17-p5 DRAWING N0: CE-CD3~J-111 PART: 3 of 3 REV: 4 oRie~r~a~ ~ ~ TRANSMITTAL LETTER CHECKLIST WELL NAME --_1..~-~ ~-~ ~~ ~ .`" ~~-jc~ ,~~ ~~~ Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: (~~! ~ t'- /~ ~ L~~ POOL: /C~~y' ~ Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / ink is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throu h tar et zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well. testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing ro ram . Rev: l/1(/2008 ~j ~, j~~j '( ~}~~j~(~,,;~~` ~° Field & Pool COLVILLE RIVER, FIORD OIL -120120 _ _ _ • Well Name: COLVILLE RIVFIORD CD3-304__ _ __ Program DEV _ _ Well bore seg ^ ~.,. , PTD#.2090280 C om an CONOCOPHILLIPS ALASKA INC ____ __ __ _- _ Initial ClasslType DEV 1 PEND GeoArea 890 _ __- ___ Unit 50360 _. __ OnlOff Shore On __ Annular Disposal ^ Administration !1 Permit fee attached NA '2 Lease number appropriate. - - - - - Yes - Surface location in ADL 372105; wellbore passes thru ADL 372104; productive interval & TD in ADL 372103.- ',3 Unique well-name and number Yes - Pr_eyiou_slypermitted as 2060240, but that permit expired 2/8/2008, 4 Well located ina definedpool - - - - Yes II~5 Well located proper distance from drilling unit-boundary. Yes - well is located-5300' from CRU_exterior boundary.. 6 Well located proper distance_from other wells- - - - Yes Nearest well is CD3-305., which is 3000' to SW. ~7 Sufficient acreage available in_drilling unit Yes 8 If deviated, is_wellborep/at-included Yes 9 Operator only affected party _ - Yes 10 Operator has appropriate bond in force Yes ',11 Permit can be issued without conservation order- Yes - - _ Appr Date I12 Permit can be issued without administ[ativ_e-approval Yes 13 Can permit be approved before 15-day-wait. Yes - SFD 3/1712009 x,14 Well located within area and strata authorized by Injection Order # (put 10# in-comments). (For NA '15 All wells-v~ithin 114 mile area of review identified (For service well only)- _ NA 16 .Pre-produced injector:. duration of pre-production less than 3 months_(For service well. only) - _ NA 17 Nonconyen, gas conforms to AS31,05,030(j,1.A),Q,2.A-D) - NA - ~18 Conductor string_provided Yes Engineering 19 Surface casing protects all known U$DWS NA_ No aquifers, A1O18A, conclusion 3. X20 CMT vol adequate_to circulate on conductor 8~ surf csg _ - _ Yes - 1~21 CMT. vol adequateto tie-in long siring tosurf csg- - No '22 CMT will cover all known_productive horizons- Yes - - - 223 Casing designs adequate for C, T, 6 & permafrost. - Yes 24 Adequate tankage or reserve pit Yes Rig equipped with steel pits. No reserve pit planned.- All_waste-to approved annuli or-disposal well(s).. - - - _ i25 If a re-drill, has_31.0-403 for abandonment been approved - - - NA _ - - 26 Adequate wellbore separationproposed - Yes Proximityanalysis performed. Traveling cylinder path calculated. Gyros likely in surface. hole. x!27 If diverter required, does it meet regulations_ NA- - - Diverter waiver requested, No issues drilling at CD3._ 20 AAC 25.035_(h)(2). Appr Date 2.28 Drilling fluid program schematic_& equip list adequate- Yes Maximum expected formation pressure 8,7-EMW. MW planned up to 9,8-ppg in 8-314" hole and 8.8 ppg in zone. TEM 3!18!2009 '29 BOPEs, do they meet regulation Yes „_ _/~ y 30 BOPE-press rating appropriate; test to (put prig in comments) Yes MASP calculated at 2341 psi 3500-psi BOP testplanned, - _ - _ - (~ V P~'A11 y ~ 31 Chokemanifold complies w1APl_RP-53 (May 84)- - - - Yes ~ '~/~ '132 Work will occur without operation shutdown- Yes !33 Is presence-of H2S gas probable - No H2S not reported in CRU._ Rig equipped with sensors and alarms. - - - 34 Mechanical condition of wells within A0R verified (Fo[ service well only) NA- - - _ _ - - - 35 -- Permit can be issued wJo hydrogen_sulfiderneasures Yes - None expected Geology 36 Data-presented on potential overpressure zones Yes Expected resevou pressure is 8.7 ppg- EMW, will be drilled v~ith 8 8 to 9,6-ppg mud.- Appr Date '37 Seismic analysisof shallow gas-zones NA_ - _ Will be about the 19th well drilled from CD3 Drill-Site.- Noshallow-gas or hydrates have been encountered SFD 3117!2009 38 $eaked condition surrey (if pff-shore) - _ _ NA- while drilling from this pad. _ _ _ - 39 Contact namelphone for weekly progress reports [exploratory only] NA_ - - - Geologic Engineering Public Date: Date Date Commissioner: Com i stoner: Co loner ~ ~ 3-/8-d f 3''~~-~~ • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. CD3-304.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri May O1 15:09:14 2009 Reel Header Service name .............LISTPE Date . ...................09/05/01 Ori9in ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS writing Library. scientific Technical services Tape Header Service name .............LISTPE Date . ...................09/OS/O1 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LI5 writing Library. scientific Technical services Physical EOF comment Record. TAPE HEADER Colville River unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 Mw-000644914 J. BOBBITT D. MICKEY SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD C'o`~~S ~~ - CD3-304 501032059800 ConocoPhillips Alaska Inc. Sperry Sun O1-MAY-09 5 12N 5E 3912 738 .00 49.85 13.40 Page 1 ~`~~o~ 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: CD3-304.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.750 9.625 3997.0 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUN 2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR PHASE-4), DRILLSTRING DYNAMICS SENSOR (DDSr), PRESSURE WHILE DRILLING (PWD), COMPENSATED THERMAL NEUTRON (CTN), AND AZIMUTHAL LITHO DENSITY (ALD). 5. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT CONOCO-PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR THE DRILLSITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 6. MWD RUNS 1-2 REPRESENT THE WELL CD3-304 WITH API#: 50-103-20598-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 17843 ft MD, 6807 ft TVD. SROP = RATE OF PENETRATION WHILE DRILLING. SGRC = GAMMA RAY COMBINED. SEXP = PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = FORMATION EXPOSURE TIME. TNPS = THERMAL NEUTRON POROSITY (SANDSTONE MATRIX). CTFA = AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = BULK DENSITY-COMPENSATED (LOW-COUNT RATE BIN). SCO2 = STANDOFF CORRECTION (LOW-COUNT RATE BIN). SNP2 = PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT RATE BIN). PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 8 3/4" FIXED MUD WEIGHT: 9.6 - 9.85 PPG Page 2 • CD3-304.tapx MUD SALINITY: 500 PPM CHLORIDES MUD TYPE: WATER BASED MUD FORMATION WATER SALINITY: 14,545 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT. EXCEPT FOR ROP AND GAMMA RAY, THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. THE GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......09/05/01 Maximum Physical Record..65535 File Type. ............Lo Previous File Name.......ST5LI6.000 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 3970.0 17805.5 NPHI 3987.0 17751.5 NCNT 3987.0 17751.5 PEF 3987.0 17765.0 RPS 3987.0 17789.0 RHOB 3987.0 17765.0 RPD 3987.0 17789.0 RPX 3987.0 17789.0 DRHO 3987.0 17765.0 FCNT 3987.0 17751.5 RPM 3987.0 17789.0 FET 3987.5 17789.0 ROP 4007.5 17843.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MwD 2 3970.0 17843.0 REMARKS: MERGED MAIN PA55. Data Format specification Record Data Record Type ..................0 Page 3 ~ r CD3-304.tapx Data Specification Block Type.....0 Logging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name Service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MWD CP30 4 1 68 4 2 NCNT MWD CP30 4 1 68 8 3 RHOB MWD G/CC 4 1 68 12 4 DRHO MWD G/CC 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD B/E 4 1 68 44 12 ROP MWD FPH 4 1 68 48 13 NPHI MWD PU 4 1 68 52 14 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 3970 17843 10906.5 27747 3970 17843 FONT MwD CP30 838.05 10097.4 1498.62 27530 3987 17751.5 NCNT MWD CP30 178691 346942 224056 27530 3987 17751.5 RHOB MWD G/CC 0.57 3.015 2.40266 27557 3987 17765 DRHO MWD G/CC -3.959 0.284 0.0579869 27557 3987 17765 RPD MWD OHMM 0.2 2000 9.04011 27605 3987 17789 RPM MWD OHMM 0.31 2000 7.78654 27605 3987 17789 RPS MWD OHMM 0.48 1623.98 5.96131 27605 3987 17789 RPX MWD OHMM 0.75 1714.82 5.65789 27605 3987 17789 FET MWD HR 0.22 77.44 0.652716 27604 3987.5 17789 GR MWD API 43.57 419.54 122.691 27672 3970 17805.5 PEF MwD B/E 1.72 12.5 2.79796 27557 3987 17765 ROP MWD FPH 0 346.93 168.577 27672 4007.5 17843 NPHI MWD Pu 6.61 62.16 35.0284 27530 3987 17751.5 First Reading For Entire File..........3970 Last Reading For Entire File...........17843 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......09/05/01 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF Page 4 CD3-304.tapx File Header service name... .......STSLI6.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......09/05/01 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 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 SGRC 3970.0 17805.5 SEMP 3987.0 17789.0 SNP2 3987.0 17765.0 SEXP 3987.0 17789.0 TNPS 3987.0 17751.5 SESP 3987.0 17789.0 SEDP 3987.0 17789.0 CTFA 3987.0 17751.5 SCO2 3987.0 17765.0 SBD2 3987.0 17765.0 CTNA 3987.0 17751.5 SFXE 3987.5 17789.0 SROP 4007.5 17843.0 LOG HEADER DATA DATE LOGGED: 20-APR-09 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 17843.0 TOP LOG INTERVAL (FT): 4007.0 BOTTOM LOG INTERVAL (FT): 17843.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 62.2 MAXIMUM ANGLE: 73.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 11145694 EWR4 EWR-Phase 4 96540 CTN Thermal Neutron 181187 ALD Azimuthal Litho -Den 224808 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT): 3997.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 9.60 Page 5 ~ ~ CD3-304.tapx MUD VISCOSITY (S): 37.0 MUD PH: 9.6 MUD CHLORIDES (PPM): 500 FLUID LOSS (C3): 4.0 RESISTIVITY (OHMM) AT TEMP ERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.560 69.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.498 150.0 MUD FILTRATE AT MT: 1.550 69.0 MUD CAKE AT MT: 1.700 69.0 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 Loggin Direction ............ .....DOwn optical log depth units...... .....Feet Data Reference Point ......... .....Undefin ed Frame Spacing....... ....... .....60 .lIN Max frames per record ........ .....undefin ed Absent value ................. .....-999 Depth units. .. .. ..... Datum Specification Block sub -type...0 Name service order units size N sam Rep code offset channel DEPT FT 4 1 68 0 1 FCNT MwD020 CP30 4 1 68 4 2 NCNT MwD020 CP30 4 1 68 8 3 RHOB MWD020 G/CC 4 1 68 12 4 DRHO MWD020 G/CC 4 1 68 16 5 RPD MwD020 OHMM 4 1 68 20 6 RPM MwD020 OHMM 4 1 68 24 7 RPS MWD020 OHMM 4 1 68 28 8 RPX MwD020 OHMM 4 1 68 32 9 FET MWD020 HR 4 1 68 36 10 GR MWD020 API 4 1 68 40 11 PEF MWD020 B/E 4 1 68 44 12 ROP MWD020 FPH 4 1 68 48 13 NPHI MWD020 PU 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3970 17843 10906.5 27747 3970 17843 FCNT MWD020 CP30 838.05 10097.4 1498.62 27530 3987 17751.5 NCNT MWD020 CP30 178691 346942 224056 27530 3987 17751.5 RHOB MWD020 G/CC 0.57 3.015 2.40266 27557 3987 17765 DRHO MWD020 G/CC -3.959 0.284 0.0579869 27557 3987 17765 RPD MwD020 OHMM 0.2 2000 9.04011 27605 3987 17789 RPM MWD020 OHMM 0.31 2000 7.78654 27605 3987 17789 RPS MWD020 OHMM 0.48 1623.98 5.96131 27605 3987 17789 RPX MWD020 OHMM 0.75 1714.82 5.65789 27605 3987 17789 FET MwD020 HR 0.22 77.44 0.652716 27604 3987.5 17789 Page 6 ~ ~ CD3-304.tapx GR MWD020 API 43.57 419.54 122.691 27672 3970 17805.5 PEF MwD020 B/E 1.72 12.5 2.79796 27557 3987 17765 ROP MWD020 FPH 0 346.93 168.577 27672 4007.5 17843 NPHI MwD020 Pu 6.61 62.16 35.0284 27530 3987 17751.5 First Reading For Entire File..........3970 Last Reading For Entire File...........17843 File Trailer Service name... .......sTSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......09/05/01 Maximum Physical Record..65535 File Type ................L0 Next File Name...........sTSLIB.003 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................09/05/01 Origin ...................sTS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................sTS LIS writing Library. Reel Trailer Service name .............LISTPE Date . ...................09/05/01 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Physical EOF End Of LIS File Scientific Technical services scientific Technical services Page 7