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210-002
! " # "$ %&$ ' () * +$! , *' -. !/ 0"! ! 1. -. 23 243,/ 3 5 - / " * ' +16 ! +070 ! ( ' +06 233+ +071 +,67 8 2100#6439&640#+0398' : +174#+141&+141#+0719 - ;&& / % :- *& / 2 <; * $ - / 6 < 4" % ' * " () * ' . * +" % = "'. ( ' = =$!>?.?= *! !5 () 8% ! 8% ; ( ( % @ 2+6#6,02 "$!>"= 6024 " #A 3, 2,24 +06 604 #A % 74B 210+ A )336+3& &C11436 7" A " % 767 ' * $ D ' 2022011 7 ? '6#3+. (.C .C$.!'= !( :$! 88$$! 23#332 43#36#23+#+3#33 > % . '.6+77,3&6+77,&6,234 210+EF+16E ,$* * *% !5 6+ 7 -< 23 243,3&243,&G24206/ 42+ = #8 ,36 ; ;! . 66609 4 ' ! 6234 5 ! % ! 21+9 $ +B 1+24B ,B ,+9 2+1+9 3, 27,4 +177 +071 2 ! ! ( ( !!" 3#737 652323 " 63* By Samantha Carlisle at 9:38 pm, Feb 24, 2021 Mark Shulman Digitally signed by Mark Shulman Date: 2021.02.24 17:15:15 -09'00' DSR-2/25/21 Alpine Oil RBDMS HEW 2/25/2021 VTL 3/3/21 SFD 2/26/2021 SFD 2/26/2021 CD3-106 and CD3-106L1 Scale Inhibition Treatment Scale Inhibitor Squeeze Job pumped from 1400 - 1900 hrs on 1/22/21. LRS = Little Red Services ACF = Alpine Central Facility x Initial pressure TBG/IA/OA – 1500/2000/250 x LRS and ACF pumped 90 bbls WAW5206/Diesel pre-flush at 1 – 2 bpm x LRS and ACF pumped 280 bbls WAW5206/Diesel pre-flush at 1-2 bpm x LRS pumped 290 bbls Seawater/SCW3001 scale inhibitor main treatment at 1-2 bpm x ACF pumped 2693 bbls dead oil/M209 over-flush at 3-4 bpm, TBG/IA/OA – 1030/1875/194 Interval treated: 13372’ – 17664’ MD (CD3-106) and 12986’ – 16193’ MD (CD3-106L1) Tubing: 4.5" x 3.5", L-80, 12184' MD, 6794' TVD Packer: Baker Premier Packer, 12006' MD, 6734' TVD SSSV: Camco TRMAXX-5E, 2063' MD, 1995' TVD, locked out and WRDP installed Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag: SLM CD3-106 pproven Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Pull & Reset WRDP 4/6/2020CD3-106 boehmbh Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 29.0 Set Depth (ftKB) 107.0 Set Depth (TVD)… 107.0 Wt/Len (l… 62.50 Grade H-40 Top Thread Welded Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 29.4 Set Depth (ftKB) 2,725.4 Set Depth (TVD)… 2,475.1 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC-Mod Casing Description INTERMEDIATE OD (in) 7 ID (in) 6.28 Top (ftKB) 25.0 Set Depth (ftKB) 12,986.2 Set Depth (TVD)… 6,944.6 Wt/Len (l… 26.00 Grade L-80 Top Thread BTCM Casing Description LINER (off L1) OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 13,372.1 Set Depth (ftKB) 17,664.0 Set Depth (TVD)… 6,886.2 Wt/Len (l… 12.60 Grade L-80 Top Thread SLHT Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 13,372.16,951.193.40SLEEVE BAKER HR SETTING SLEEVE 4.410 Tubing Strings Tubing Description TUBING 4.5"x3.5" @ 112' String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 22.0 Set Depth (ft… 12,184.2 Set Depth (TVD) (… 6,794.2 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rdMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 22.0 HANGER FMC 4 1/2" Tbg Hanger 4.500 112.5 112.5 0.09 XO Reducing XO 4.5' x 3.5" 3.000 2,062.5 1,996.4 32.77 Safety Valve 3 1/2" Camco TRMAXX-5E SSSV w/ 2.813" X Profile (Flapper & Hydraulic Sleeve Locked out 4/22/2018) 2.813 12,006.4 6,734.7 68.04PACKER Baker 3.5" X 7" Premier Packer 3.010 12,054.36,752.269.27NIPPLE 3.5" HES "XN" Nipple 2.813" Polish Bore w/ 2.75" No-Go 2.750 12,183.7 6,794.0 73.18 WLEG Wireline entry guide 2.990 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in)SN 2,062.5 1,996.4 32.77 WRDP WRDP (SN: HTS-618, OAL=89") ON 2.81" X -LOCK w/ FRUEDENBERG PACKING 4/6/2020 1.500 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 13,390.014,550.06,950.06,908.82/20/2010 32.0SLOTSSlots 1/8x2.25", 8 slots/row, 4 rows/ft; no slots 3' from box/pin 15,031.217,659.4 6,916.66,886.4 2/20/2010 32.0SLOTSSlots 1/8x2.25", 8 slots/row, 4 rows/ft; no slots 3' from box/pin Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in)Serv Valve Type Latch Ty pe Port Size (in) TRO Run (psi)Run Date Com 1 4,679.5 3,418.3CAMCO KBMG 1 GAS LIFT DMY BK 3/19/2019 2 9,487.9 5,589.7 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 2,023.03/19/2019 3 11,884.5 6,686.2CAMCO KBMG 1 GAS LIFT OVBK 0.2503/19/2016 Notes: General & Safety End Date Annotation 3/17/2013 NOTE: DRIFT TBG to 12,450' SLM 3/20/2010 NOTE: CD3-106L1 top in main wellbore, CD3-106 liner a Plop & Drop off CD3-106L1 (see attachment) 3/20/2010 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 MULTIPLE LATERALS, CD3-106, 5/28/2020 11:05:20 AM Vertical schematic (actual) LINER (off L1); 13,372.1- 17,664.0 SLOTS; 15,031.2-17,659.4 SLOTS; 13,390.0-14,550.0 L1 LINER; 12,795.2-16,183.0 SLOTS; 12,987.9-13,501.5 INTERMEDIATE; 25.0-12,986.2 WLEG; 12,183.7 NIPPLE; 12,054.3 PACKER; 12,006.4 GAS LIFT; 11,884.5 GAS LIFT; 9,487.9 GAS LIFT; 4,679.5 SURFACE; 29.4-2,725.4 WRDP; 2,062.5 Safety Valve; 2,062.5 CONDUCTOR; 29.0-107.0 HANGER; 22.0 WNS PROD KB-Grd (ft) 28.00 Rig Release Date 3/6/2010 CD3-106 ... TD Act Btm (ftKB) 17,664.0 Well Attributes Field Name FIORD NECHELIK Wellbore API/UWI 501032061100 Wellbore Status PROD Max Angle & MD Incl (°) 95.43 MD (ftKB) 16,077.06 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm)DateComment SSSV: WRDP Casing Strings Casing Description L1 LINER String O... 4 1/2 String ID ... 3.958 Top (ftKB) 12,795.2 Set Depth (f... 16,183.0 Set Depth (TVD) ... 6,849.0 String Wt... 12.60 String ... L-80 String Top Thrd SLHT Liner Details Top (ftKB) Top Depth (TVD) (ftKB) Top Incl (°)Item Description Comment Nomi... ID (in) 12,795.2 7,072.0 104.23 SLEEVE Baker 5" X 7" "HR" Liner Setting Sleeve 4.950 12,808.0 7,066.0 103.86 NIPPLE Baker 5" "RS" Packoff Seal Nipple 4.870 12,811.6 7,064.4 103.76 HANGER Baker 5" X 7" "DG" Flex-Lock Liner Hanger 4.880 12,821.5 7,059.9 103.48 XO Bushing Baker 5" TCK x 4-1/2" SLHT Cross over Bushing 3.970 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Zone Date Shot Dens (sh...Type Comment 12,987.9 13,501.5 6,998.3 6,958.7 3/3/2010 32.0 SLOTS Slots 1/8x2.25", 8 slots/row, 4 rows/ft; no slots 3' from box/pin 13,581.5 16,179.8 6,958.2 6,849.3 3/3/2010 32.0 SLOTS Slots 1/8x2.25", 8 slots/row, 4 rows/ft; no slots 3' from box/pin Notes: General & Safety End Date Annotation 3/20/2010 NOTE: CD3-106L1 top in main wellbore, CD3-106 liner a Plop & Drop off CD3-106L1 (see attachment) 3/20/2010 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 Comment SSSV: TRDPWell Config: MULTIPLE LATERALS - CD3-106L1, 4/12/2012 1:02:18 PM Schematic - Actual TD (CD3-106L1), 16,193 L1 LINER, 12,795-16,183 SLOTS, 13,582-16,180 SLOTS, 12,988-13,502 NTERMEDIATE, 25-12,986 WLEG, 12,184 NIPPLE, 12,054 PACKER, 12,006 GAS LIFT, 11,885 GAS LIFT, 9,488 GAS LIFT, 4,680 SURFACE, 29-2,725 Safety Valve, 2,063 CONDUCTOR, 29-107 HANGER, 22 Annotation Last Tag: Depth (ftKB) End Date Annotation Rev Reason: WELL REVIEW Last Mod ... osborl End Date 4/12/2012 WNS KB-Grd (ft) 28.00 Rig Release Date 3/6/2010 Annotation Last WO: End Date CD3-106L1 H2S (ppm) Date Mandrel Details Stn Top (ftKB) Top Depth (TVD) (ftKB) Top Incl (°)Make Model OD (in)Serv Valve Type Latch Type Port Size (in)TRO Run (psi)Run Date Com... 1 4,679.5 3,418.5 65.24 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,935.0 3/9/2010 2 9,487.9 5,589.7 62.21 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,951.0 3/9/2010 3 11,884.5 6,685.3 64.99 CAMCO KBMG 1 GAS LIFT OV BK 0.313 0.0 3/9/2010 ... TD Act Btm (ftKB) 16,193.0 Well Attributes Wellbore API/UWI 501032061160 Field Name FIORD NECHELIK Well Status PROD Max Angle & MD Incl (°) 96.06 MD (ftKB) 16,126.76 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: ______________________ 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 12:34 pm, Nov 09, 2020 ConocoPhillips Alaska, Inc. PO Box 100360, Anchorage, AK 99510 210-002 50-103-20611-60-00 ADL 364470, 364471, 372105 CD3-106L1 None Colville River Field/Fiord Oil Pool 16193 6848 None None 16183 6849 12006 6734 Conductor 78' 16" 107 107 Surface 2696' 9.625" 2725 2475 Intermediate 12961' 7" 12986 6944 Liner 3388' 4.5" 16183 6849 12988 - 16180 6945 - 6849 see attached see attached see attached 12986' - 16193' MD Please see attached summary. One treatment for both laterals. 732 2257 3161 1852 372 532 2368 3296 1791 292 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 09:09:24 -09'00' DSR-11/10/2020VTL 2/24/21 SFD 11/9/2020RBDMS HEW 11/9/2020 CD3-106 and CD3-106L1 Scale Inhibition Treatment 10/7/20 Hybrid Scale Inhibitor Squeeze Job pumped from 1100 - 1750 hrs on 10/7/20. LRS = Little Red Services ACF = Alpine Central Facility x Initial pressure TBG/IA/OA – 933/1803/556 x LRS and ACF pumped 90 bbls WAW5206/Diesel pre-flush at 0.3 – 1.4 bpm, TBG/IA/OA – 800/1705/211 x LRS pumped 90 bbls Seawater/SCW3001 scale inhibitor main treatment at 1.3 – 1.5 bpm, TBG/IA/OA – 276/1632/191 x ACF pumped 358 bbls Diesel over-flush at 1.4 bpm, TBG/IA/OA – 867/1750/180 Interval treated: 13372’ – 17664’ MD (CD3-106) and 12986’ – 16193’ MD (CD3-106L1) Tubing: 4.5" x 3.5", L-80, 12184' MD, 6794' TVD Packer: Baker Premier Packer, 12006' MD, 6734' TVD SSSV: Camco TRMAXX-5E, 2063' MD, 1995' TVD, locked out and WRDP installed DSR-4/9/2020VTL 4/10/20 HECEIV'E® STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION NOV 13 2019 REPORT OF SUNDRY WELL OPERATIONS A f%?%r.. 1. Operations Abandon Plug Perforations Ll Fracture Stimulate U Pull Tubing Li Operations shutdown LJ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Soap Well ❑ Other: Scale Inhibitor Treatment ❑� 2. Operator ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: DevelopmentEx lorato ❑ P ry ❑ Stratigraphic ❑ Service ❑ 210-002 3. Address: PO BOX 100360 6. API Number: Anchorage, AK 99510 50-103-20611-60 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 364470, 364471, 372105 CRU CD3 -1061-1 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 16193 feet Plugs measured None feet true vertical 6848 feet Junk measured None feet Effective Depth measured 16183 feet Packer measured 12006 feet true vertical 6849 feet true vertical 6734 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 107' 107' Surface 2696' 9.625" 2725' 2475' Intermediate 12961' 7" 12986' 6944' Production Liner 3388' 4.5" 16183' 6849' Perforation depth Measured depth Slotted liner from 12988' - 13502' and 13582'- 16180' True Vertical depth 6945' - 6959' and 6958' - 6849' Tubing (size, grade, measured and true vertical depth) 4.5" x 3.5", L-80, 12184' MD, 6794' TVD Packers and SSSV (type, measured and true vertical depth) Packer: Baker Premier Packer, 12006' MD, 6734' TVD SSSV: Camco TRMAXX-5E, 2063' MD, 1995' TVD, locked out and WRDP installed 12. Stimulation or cement squeeze summary: Intervals treated (measured): 12986'- 16193' Treatment descriptions including volumes used and final pressure: Please see attached summary. One treatment for both laterals. 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 401 1168 3028 1945 346 Subsequent to operation: 377 1043 3328 1483 308 14. Attachments (required per 20 n C 25.070, 25.071, s 25.283) 15. Well Class after work: Daily Report of Well Operations Exploratory ❑ Development p ❑ 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. 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 En ineer Contact Email: Kaylie.B.Plunkettacoo com f _ Authorized Signature: /' +- .�V V Date: I I —I — (I Contact Phone: 265-6450 Form 10-404 Revised 4/2017 /2��b�y RgDMS11PNOV 14 2019 Submit Original Only CD3 -106 and CD3 -1061.1 Scale Inhibition Treatment 10/13/19 Hybrid Scale Inhibitor Squeeze Job pumped from 0730 - 1700 hrs on 10/13/19. LRS = Little Red Services ACF = Alpine Central Facility - Initial pressure TBG/IA/OA-260/1928/177 - LRS and ACF pumped 90 bbis diesel/WAW5206 preflush at 0.4 bpm, TBG/IA/OA - 1350/1858/157 - LRS pumped 90 bbls seawater and SCW3001 scale inhibitor treatment at 1.5 bpm, TBG/IA/OA - 916/1790/150 - ACF pumped 358 bbls diesel overflush at 0.6 —1.3 bpm, TBG/IA/OA - 1692/1777/152 - Final pressure TBG/IA/OA-1610/1794/154 Interval treated: 13372'— 17664' MD (CD3 -106) and 12986'— 16193' MD (CD3 -106L1) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS V a. *W. %0 `. t, 1a 111 - HAR 19 21019 G` 0GQQ 1. Operations Abandon LJ Plug Perforations Lj Fracture Stimulate Li Pull Tubing LJ Operations shutdown LJ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Scale Inhibitor Treatment ❑✓ 2. Operator ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory ❑ Stratigraphic ❑ Service ❑ 210-002 3. Address: PO BOX 100360 6. API Number: Anchorage, AK 99510 50-103-20611-60 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 364470, 364471, 372105 CRU CD3 -1061-1 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 16193 feet Plugs measured None feet true vertical 6848 feet Junk measured None feet Effective Depth measured 16183 feet Packer measured 12006 feet true vertical 8849 feet true vertical 6734 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 107' 107' Surface 2696' 9.625" 2725' 2475' Intermediate 12961' 7" 12986' 6944' Production Liner 3388' 4.5" 16183' 6849' Perforation depth Measured depth Slotted liner from 12988' - 13502' and 13582' - 16180' True Vertical depth 6945' - 6959' and 6958' - 6849' Tubing (size, grade, measured and true vertical depth) 4.5" x 3.5", L-80, 12184' MD, 6794' TVD Packers and SSSV (type, measured and true vertical depth) Packer: Baker Premier Packer, 12006' MD, 6734' TVD SSSV: Carrico TRMAXX-5E, 2063' MD, 1995' TVD, locked out and WRDP installed 12. Stimulation or cement squeeze summary: Intervals treated (measured): 12986'- 16193' Treatment descriptions including volumes used and final pressure: Please see attached summary. One treatment for both laterals. 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 365 2958 3063 1857 455 Subsequent to operation:1 no well test yet due to Test Separator maintenance 14. Attachments (required per 20 AAC 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations ❑� Exploratory ❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 18. 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: Kavlie.B.Plunkett(0�coo com Authorized Signature: t"-1�.�.77c Date: Contact Phone: 265-6450 VIZ 3/2//1-7 Form 10404 Revised 4/2017 3 A / �% RsoMskev/MAR 19 2019 Submit Original Only CD3 -106 and CD3 -106L1 Scale Inhibition Treatment 2/14/19— 2/15/19 Hybrid Scale Inhibitor Squeeze Job pumped from 15:00 hrs on 2/14/19 to 09:30 hrs on 2/15/19. LRS = Little Red Services • Initial pressure TBG/IA/OA —1500/1810/250 • LRS pumped 290 bbls WAW5206/Diesel/M209 preflush at 1.0 — 3.5 bpm, TBG/IA/OA — 1350/1700/150 • LRS pumped 290 bbls Seawater/SCW3001 scale inhibitor main treatment at 3.5 — 3.8 bpm, TBG/IA/OA —1000/1600/150 • LRS pumped 2702 bbls Crude/M209 overflush at 3.5 bpm, TBG/IA/OA —1950/1580/180 • Final pressure, TBG/IA/OA-0/1600/150 Interval treated: 13372'— 17664' MD (CD3 -106) and 12986'— 16193' MD (CD3 -106 Ll) STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMMIS 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 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 2 Exploratory❑ 210-002 3.Address: Stratigraphic❑ Service ❑ 6.API Number: P.O. Box 100360,Anchorage, AK 99510 50-103-20611-60 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 364470, 364471, 372105 CRU CD3-106L1 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 16193 feet Plugs measured None feet true vertical 6848 feet Junk measured None feet Effective Depth measured 16183 feet Packer measured 12006 feet true vertical 6849 feet true vertical 6734 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 107' 107' Surface 2696' 9.625" 2725' 2475' Intermediate 12961' 7" 12986' 6944' RECEIVED Production Liner 3388' 4.5" 16183' 6849' MAR 0 9 2018 Perforation depth Measured Depth: Slotted liner from 12988'- 13502'and 13582'- 16180' AOGCC True Vertical Depth: 6945'-6959'and 6958'-6849' SC Tubing(size,grade,measured and true vertical depth) 4.5"x 3.5", L-80, 12184' MD, 6794'TVD Packers and SSSV(type,measured and true vertical depth) Packer: Baker Premier Packer, 12006' MD, 6734'TVD SSSV: Camco TRMAXX-5E, 2063' MD, 1995'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 12986'- 16193' Treatment descriptions including volumes used and final pressure: Please see attached summary. One treatment for both laterals. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 782 2039 2953 1758 329 Subsequent to operation: 894 3499 3204 1738 352 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations I] ExploratoryD DevelopmentU Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil El Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR 0 WINJ ❑ WAG 0 GINJ 0 SUSP❑ SPLUGD 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 A lQ0 S 009 Email Kaylie.B.Plunkett(c cop.com, Printed Name Kaylie Plunkett Title Production Engineer Signature Phone -./ g 265-6450 Date 3 l/T1.- 3/i6/18 �j�Y� RBDS 1,t-, MAR - 9 2018 Form 10-404 Revised 5/2015 Submit Original Only 4110 CD3-106 and CD3-106L1 Scale Inhibition Treatment 2/18/18—2/19/18 Hybrid Scale Inhibitor Squeeze Job pumped from 20:45 hrs on 2/18/18 to 20:15 hrs on 2/19/18. LRS= Little Red Services ACF=Alpine Central Facility • Initial pressure TBG/IA/OA—313/1720/492 • LRS pumped 295 bbls WAW5206/Diesel/M209 preflush at 2.0—3.0 bpm,TBG/IA/OA— 438/1575/140 • LRS pumped 289 bbls Seawater/SCW3001 scale inhibitor main treatment at 2.0 bpm,TBG/IA/OA —8/1510/133 • LRS pumped 2713 bbls Dead Crude/M209 overflush at 2.0-3.5 bpm,TBG/IA/OA- 1265/1472/139 Interval treated: 13372'—17664' MD (CD3-106)and 12986'—16193' MD(CD3-106 L1) RECEIVED STATE OF ALASKA AL.OIL AND GAS CONSERVATION COMAION DE_l. 1 9 2017 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 ❑ 210-002 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O. Box 100360,Anchorage,AK 99510 50-103-20611-60 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 364470, 364471, 372105 CRU CD3-106L1 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 16193 feet Plugs measured None feet true vertical 6848 feet Junk measured None feet Effective Depth measured 16183 feet Packer measured 12006 feet true vertical 6849 feet true vertical 6734 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 107' 107' Surface 2696' 9.625" 2725' 2475' Intermediate 12961' 7" 12986' 6944' Production Liner 3388' 4.5" 16183' 6849' ANNED IAN E. Perforation depth Measured Depth: Slotted liner from 12988'- 13502'and 13582'- 16180' True Vertical Depth: 6945'-6959'and 6958'-6849' Tubing(size,grade,measured and true vertical depth) 4.5"x 3.5", L-80, 12184' MD, 6794'TVD Packers and SSSV(type,measured and true vertical depth) Packer: Baker Premier Packer, 12006' MD, 6734'TVD SSSV: Camco TRMAXX-5E, 2063' MD, 1995'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 12986'- 16193' Treatment descriptions including volumes used and final pressure: Please see attached summary. One treatment for both laterals. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 604 845 2963 1761 280 Subsequent to operation: 416 545 2360 1992 384 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑✓ Exploratory❑ Development ❑I Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Kaylie Plunkett Email Kaylie.B.Plunkett(a)cop.com Printed Name Kaylie Plunkett Title Production Engineer Signature --X-3C -,-i pPhone 265-6450 Date /2-18- (7 v r e/2—/i ,/3( RE'Zatr33 G L_ i 9 L01 Submit Original Only Form 10-404 Revised 5/2015 Z `!/ • S CD3-106 and CD3-106L1 Scale Inhibition Treatment 11/19/17 Hybrid Scale Inhibitor Squeeze Job pumped from 12:30—21:05 hrs on 11/19/17. LRS= Little Red Services ACF=Alpine Central Facility • Initial pressure TBG/IA/OA—259/1824/669 • LRS pumped 90 bbls WAW5206/Diesel preflush at 1.0—1.8 bpm,TBG/IA/OA—521/1678/108 • LRS pumped 90 bbls Seawater/SCW3001 scale inhibitor main treatment at 1.8 bpm,TBG/IA/OA —0/1603/98 • ACF pumped 341 bbls Diesel overflush at 1.04 bpm,TBG/IA/OA—682/1556/89 Interval treated: 13372'—17664' (CD3-106) and 12986'—16193' (CD3-106 L1) (III WNS •OD •3-106L1 ConotoPhiltips 010.,i /t wen Attributes Max Angle&MD TD Alaska.Int, xt'll� Wellbore ARAMFloid Name Welibnre Status net(') MD(BKA) Act Atm MKS) corampfIi8ltps 501032061160 FIORD NECHELIK PROD96.06 16,126.76 16,193.0 ... Comment ASS(ppm) Date Annotation End Dale KB-Grd(h) Rig Release Date MULTIPLE LATERALS-003-10611,12/192017 t020:56 AAI SSSV:TRDP I-asl WO: 28.00 3/6/2010 Vertical schemabc(x+um) Annotation Depth(eK0) End Date Annotation Last Mod By End Date (�� Last Tag: Rev Reason:WELL REVIEW osborl 4/12/2012 HANGER,220iii VEi : Casing Stings Casing Description OD(In) ID(In) Top(1IKA) Set Depth(fte(3) Set Depth(TVD)... WI/Len(I.,.Grade Top Thread ti j; Li LINER 41/2 3.958 12,795.2 16,183.0 6,849.0 12.60 L-80 SLHT Liner Details Nominal ID Top(rRNA) Top(TVD)(BUB) Tap loot p1 Item Des Com (in) ,uwuut mne„ ,,, ruw _.,auu 12,795.2 SLEEVE Baker 5"X 7""FIR"Liner Setting Sleeve 4.950 12,808.0 NIPPLE Baker 5""RS"Packoff Seal Nipple 4.870 t 12,811.6 HANGER Baker 5"X 7""DG"Flex-Lock Liner Hanger 4.880 12,821.5 XO Bushing 'Baker 5"TCK x 4-1/2"SLHT Cross over Bushing 3.970 CONDUCTOR,200 070 ,. • Perforations&Slots Shot Dans 6 Top(TVD) elm(TVD) (shots/ t g Top(f1K13) elm(ftKB) (MB) (BKS) Zone Date P) Type Com 12,987.9 13,501.5 6,959.2 3/3/2010 32.0 SLOTS Slots 118x2.25",8 111 slots/row,4 rows/ft;no slots 3'from box/pin Safety VaNe;2,062 513,581.5 16,179.8 6,958.8 6,849.3 3/3/2010 32.0 SLOTS Slots 118x2.25",8 ® slots/row,4 rows/ft;no slots 3'from box/pin Notes:General&Safety End Date Annotation 1 3/20/2010 NOTE:CD3-106L1 top in main wellbore,CD3-106 liner a Plop 8 Drop off CD3-106L1(see attachment) 3/2.0/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 SURFACE;20.42,725.4 I GAS LIFT;4,679.5 I GAS LIFT;9487.9 4 11 11 II GAS LIFT;11.864.5 i Il si PACKER;12,008.4 piea_ se k. I NIPPLE;12.054.3 (1.7# ill WLEG,12163.7 t 1 i I ,,_r nTERMEDIATE.25 0.12.985.2 SLOTS;12,987.9-13.f01 5 1 SLOTS;13.5x7.5-i 6,179 D Lt LINER;12:795.2-16,103.0 STATE OF ALASKA • • AKA OIL AND GAS CONSERVATION COMMISSION 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 El 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 0 Exploratory El 210-002 3.Address: Stratigraphic❑ Service ❑ 6.API Number: P.O. Box 100360, Anchorage, AK 99510 50-103-20611-60 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 364470, 364471, 372105 CRU CD3-106L1 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 16193 feet Plugs measured None feet true vertical 6848 feet Junk measured None feet Effective Depth measured 16183 feet Packer measured 12006 feet true vertical 6849 feet true vertical 6734 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 107' 107' Surface 2696' 9.625" 2725' 2475' Intermediate 12961' 7" 12986' 6944' RECEIVED Production Liner 3388' 4.5" 16183' 6849' MAR 2 8 2017 Perforation depth Measured Depth: Slotted liner from 12988'- 13502'and 13582'- 16180' True Vertical Depth: 6945'-6959'and 6958'-6849' `a OG GC Tubing(size,grade,measured and true vertical depth) 4.5"x 3.5", L-80, 12184' MD, 6794'TVD Packers and SSSV(type,measured and true vertical depth) Packer: Baker Premier Packer, 12006' MD, 6734'TVD SSSV: Camco TRMAXX-5E, 2063' MD, 1995'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 12986'- 16193' iiCARtie0 MA k; J 17, Treatment descriptions including volumes used and final pressure: Please see attached summary. One treatment for both laterals. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 704 4064 2043 1506 360 Subsequent to operation: 868 4501 2059 1434 358 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ DevelopmentE Service El Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ El WAG ❑ GINJ❑ SUSP El 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@cop.com Printed Name ///27:t,,1 Qfoaks Title Principal Production Engineer Signaturet ��� �� ^"''` Phone 265-6547 Date '. /2.8/(r_2'. /2.8/(r_ VT- 5-1/0//7' ,,4, 7 RBDMS \,U APR - 3 2017 Form 10-404 Revised 5/2015 Submit Original Only • • CD3-106 and CD3-106L1 Scale Inhibition Treatment 2/23/17—2/24/17 Hybrid Scale Inhibitor Squeeze Job pumped from 2/23/17 at 23:15 hrs to 2/24/17 at 18:15 hrs. LRS= Little Red Services • Initial pressure TBG/IA/OA—194/1407/224 • LRS pumped 290 bbls WAW5206/Diesel/M209 preflush at 2.45 bpm,TBG/IA/OA—218/1318/90 • LRS pumped 290 bbls Seawater and SCW720 scale inhibitor main treatment at 2.45 bpm, TBG/IA/OA—0/1270/96 • LRS pumped 2702 bbls Dead Crude/M209 overflush at 2.5—4.0 bpm,TBG/IA/OA—610/1242/91 Interval treated: 13372'—17664' (CD3-106) and 12986'—16193' (CD3-106 L1) y STATE OF ALASKA • AllikA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other:Scale Inhibitor Treatment ❑., 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Exploratory ❑ 210-002 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O. Box 100360, Anchorage, AK 99510 50-103-20611-60 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 364470, 364471, 372105 CRU CD3-106L1 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 16193 feet Plugs measured None feet true vertical 6848 feet Junk measured None feet Effective Depth measured 16183 feet Packer measured 12006 feet true vertical 6849 feet true vertical 6731---'feet"- Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 107' 107' Surface 2696' 9.625" 2725' 2475' Intermediate 12961' 7" 12986' 6944' SCANNED JUN 2 4 2016 Production Liner 3388' 4.5" 16183' 6849' �l®E C E'V Perforation depth Measured Depth: Slotted liner from 12988'- 13502'and 13582'- 16180' APR 2 1 2016 True Vertical Depth: 6945'-6959'and 6958'-6849' AOGCC A"1OGVC Tubing(size,grade,measured and true vertical depth) 4.5"x 3.5", L-80, 12184' MD, 6794'TVD Packers and SSSV(type,measured and true vertical depth) Packer: Baker Premier Packer, 12006' MD, 6734'TVD SSSV: Camco TRMAXX-5E, 2063' MD, 1995'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 12986'- 16193' Treatment descriptions including volumes used and final pressure: Please see attached summary. One treatment for both laterals. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 1373 4671 1698 1469 375 Subsequent to operation: 1106 4839 2195 1706 390 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations E Exploratory❑ Development ❑., Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil E Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Kerry Freedman Email Kerry.C.Freedman@cop.com Printed Name Kerry Freedman Title Principal Production Engineer Signature /1A-1-4•044--1------ Phone 265-6579 Date Y(ZoI/6 VFL 57.1/i � Form 10-404 Revised 5/2015 L .�/� RBDMS VU An2 2016 Submit Original Only r- WNS • CD3-106L1 a ConocoPhiflips "' Well Attributes Max Angle&MD TD IncWellbore APIIUWI Field Name Well Status Incl(°) MD(ftKB) Act Btm(ftKB) • Alaska. u>x>.d.,,wps-. 501032061160 FIORD NECHELIK PROD 96.06 16,126.76 16,193.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date Won Cone.MULTIPLE LATERALS-CD3-1061.1,411 2/2 012 1.0218 PM SS$V:TRDP Last WO: 28.00 3/6/2010 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:WELL REVIEW osborl 4/12/2012 HANGER.22 Casing Strings ` Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd L1 LINER 41/2 3.958 12,795.2 16,183.0 6,849.0 12.60 L-80 SLHT Liner Details P Top Depth I (TVD) Top not Nomf... Top(MEI) B) (°) Item Description Comment ID(in) 12,795.2 7,072.0 104.23 SLEEVE Baker 5"X T'"HR"Liner Setting Sleeve 4.950 12,808.0 7,066.0 103.86 NIPPLE Baker 5""RS"Packoff Seal Nipple 4.870 12,811.6 7,064.4 103.76 HANGER Baker 5"X 7""DG"Flex-Lock Liner Hanger 4.880 3.970 12,821.5 7,059.9 103.48 XO Bushing Baker 5"TCK x 4-1/2"SLHT Cross over Bushing Perforations&Slots Shot CONDUCTOR, 29-107 Top(TVD) Btm(VD) Dens Top(ftKB)Btm(ftKB) (ttKB) (ftKB) Zone Date (sh-- Type Comment 12,987.9 13,501.5 $998:5 6,958.7 3/3/2010 32.0 SLOTS Slots 1/8x2.25",8 slots/row,4 rows/ft; 0444..S" no slots 3'from box/pin 13,581.5 16,179.8 6,958.2 6,849.3 3/3/2010 32.0 SLOTS Slots 118x2.25",8 slots/row,4 rows/ft; no slots 3'from box/pin Safety VaNe. . o" 2°� Notes:General&Safety I End Date Annotation 3/20/2010 NOTE:CD3-106L1 top in main wellbore,CD3-106 liner a Plop&Drop off CD3-1061_1(see attachment) 3/20/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 SURFACE,__Al 29-2.725 Ft GAS LIFT. H'.`'"0 4,680 GAS LIFT, 9,488 III III Ir GAS LIFT, 11,885 111 I PACKER. 12,006 011.1111110 ER. all NIPPLE.12,054 . WLEG,12.184 k: iag Mandrel Details Top Depth Top Port (ND) Incl OD Valve Latch Size TRO Run Ste Top(ftKB) (ftKB) (°) Make Model (in) Sere Type Type (in) (psi) Run Date Corn... 1 4,679.5 3,418.5 65.24 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,935.0 3/9/2010 2 9,487.9 5,589.7 62.21 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,951.0 3/9/2010 3 11,884.5 6,685.3 64.99 CAMCO KBMG 1 GAS LIFT OV BK 0.313 0.0 3/9/2010 NTERMEDIATE, N. , 25-12,986 SLOTS. 12,988-13,502 SLOTS, r 13,582-16,180\ L1 LINER, 12,795-16,183 TD (CD3.106L1), 16,193 • CD3-106 and CD3-106L1 Scale Inhibition Treatment 3121/16—3/22/16 Non-Aqueous Scale Inhibitor Squeeze Job pumped from 3/21/16 at 11:00 hrs to 3/22/16 at 01:30 hrs, LRS=Little Red Services • Initial pressure TBG/IA/OA—825/1324/632 • LRS pumped 289 bbls WAW5206/Diesel/M209 preflush at 1-4.3 bpm,TBG/IA/OA-- 980/1234/85 • LRS pumped 289 bbls 70/30 EG/Water and SCW3001WC scale inhibitor main treatment at 2— 4.39 bpm,TBG/IA/OA—206/1210/74 • LRS pumped 2704 bbls Dead Crude overflush at 3—4.2 bpm,TBG/IA/OA--1867/1114/38 Interval treated: 13372'—17664'(CD3-106)and 12986'—16193' (CD3-106 L1) • STATE OF ALASKA • SKA OIL AND GAS CONSERVATION COMMISSION • REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other:Scale Inhibitor Treatment ❑., 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development E Exploratory ❑ 210-002 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O. Box 100360,Anchorage,AK 99510 50-103-20611-60 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 364470, 364471, 372105 CRU CD3-106L1 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 16193 feet Plugs measured None feet true vertical 6848 feet Junk measured None feet Effective Depth measured 16183 feet Packer measured 12006 feet true vertical 6849 feet true vertical 6734 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 107' 107' SCANNED l+ ,t? 2 7,1 _r;iE! Surface 2696' 9.625" 2725' 2475' Intermediate 12961' 7" 12986' 6944' Production Liner 3388' 4.5" 16183' 6849' RECEWED Perforation depth Measured Depth: Slotted liner from 12988'- 13502'and 13582'- 16180' MAR 1 0 2016 AOGCCTrue Vertical Depth: 6945'-6959'and 6958'-6849' Tubing(size,grade,measured and true vertical depth) 4.5"x 3.5", L-80, 12184' MD, 6794'TVD Packers and SSSV(type,measured and true vertical depth) Packer: Baker Premier Packer, 12006' MD, 6734'TVD SSSV: Camco TRMAXX-5E, 2063' MD, 1995'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 12986'- 16193' Treatment descriptions including volumes used and final pressure: Please see attached summary. One treatment for both laterals. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 1119 4053 2219 1555 360 Subsequent to operation: 1199 4210 2025 1591 349 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 Kerry.C.Freedman@cop.com Printed Name Kerry Freedman Title Principal Production Engineer Signature /"4.4.104.----- Phone 265-6579 Date 31' I U. '71r-rL 3///i//Ib Form 10-404 Revised 5/2015 RBDMS LV MAR 1 1 2016 Submit Original Only • CD3-106 and CD3-106L1 Scale Inhibition Treatment 2/11/16 Non-Aqueous Scale Inhibitor Squeeze Job pumped on 2/11/16 from 03:30—04:30 hrs. LRS= Little Red Services - Initial pressure TBG/IA/OA-1341/1683/413 - LRS pumped 50 bbls Diesel/M209/WAW5206 preflush at .5—1.5 bpm,TBG/IA/OA— 733/1816/53 - Job shut down to evaluate IA pressure response Interval treated: 13372'—17664' (CD3-106) and 12986'—16193' (CD3-106 L1) 40 WNS CD3-106L1 • COnOCQiilj ,q�,q��6`�M Well Attributes Max Angle&MD TD Alaska'IIx i'" Wellbore API/UWI Field Name Well Status Indy) MD(ftKB) Act Btm(ftKB) conoconl.nl,ps', 501032061160 FIORD NECHELIK PROD 96.06 16,126.76 16,193.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date "' SSSV:TRDP Last WO: 28.00 3/6/2010 Well Conrp:MULTIPLE LATERALS-CO3-106L1,4/1220121:0218 RA Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:WELL REVIEW osborl 4/12/2012 HANGER,22 Al' Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String WE..String...String Top Thrd L1 LINER 4 1/2 3.958 12,795.2 16,183.0 6,849.0 12.60 L-80 SLHT < ''. 7 Liner Details Top Depth (TVD) Top Incl Nomi... Top(MB) (ftKB) Fl Item Description Comment ID(In) 12,795.2 7,072.0 104.23 SLEEVE Baker 5"X 7""HR"Liner Setting Sleeve 4.950 12,808.0 7,066.0 103.86 NIPPLE Baker 5""RS"Packoff Seal Nipple 4.870 12,811.6 7,064.4 103.76 HANGER Baker 5"X 7""DG"Flex-Lock Liner Hanger 4.880 _11 12,821.51 7,059.9 103.48 XO Bushing Baker 5"TCK x 4-1/2"SLHT Cross over Bushing 3.970 coNDucTOR. Perforations&Slots 29-107 f Shot .. Top(TVD) Btm(TVD) Dens it Top(ftKB) Btm(ftKB) 151(8) (5103) Zone Date (sh.- Type Comment 12,987.9 13,501.5 Al610851. 6,958.7 3/3/2010 32.0 SLOTS Slots 1/8x2.25",8 slots/row,4 rows/ft; III /n484.S no slots 3'from box/pin 13,581.5 16,179.8 O 16,958.2 6,849.3 3/3/2010 32.0 SLOTS Slots 1/8x2.25",8 slots/row,4 rows/ft; no slots 3'from box/pin Safety VaNe, 2,063 Notes:General&Safety IIIEnd Date Annotation vim 3/20/2010 NOTE:CD3-106L1 top in main wellbore,CD3-106 liner a Plop&Drop off CD3-106L1(see attachment) 3/20/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 SURFACE,__J 29-2,725 dt GAS LIFT. 4,680 t E. GAS LIFT -.:..y 9.498 GAS LIFT, 11,885 17. PACKER. 12.006 NIPPLE,12,054- - WLEG,12.184 --- 11 n SW Mandrel Details 1 Top Depth Top Port (TVD) Incl OD Valve Latch Size TRO Run Stn Top(KKR) (MB) Fl Make Model (in) Sery Type Type (in) (Pei) Run Date Com... 1 4,679.5 3,418.5 65.24 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,935.0 3/9/2010 2 9,487.9 5,589.7 62.21 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,951.0 3/9/2010 3 11,884.5 6,685.3-64.99 CAMCO KBMG 1 GAS LIFT OV BK 0.313 0.0 3/9/2010 NTERMEDIATE, a 4 25.12,986 12,966-13 SLOTS,,502 M SLOTS, 13,582-1R.1801 - L1 LINER, 12,795-16,183NTI 1 (CD3.106L1), 16,193 STATE OF ALASKA ALI-._.,A 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 Inhibitor Alter Casing r Pull Tubing r Stimulate-Frac Waiver r, Treatment r r Time Extension Change Approved Program fOperat. 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 210-002 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-103-20611-60 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 364470,364471,372105 CRU CD3-106L1 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Colville River Field/Fiord Oil Pool RECEIVED 11.Present Well Condition Summary: APR 0 7 2015 Total Depth measured 16193 feet Plugs(measured) none true vertical 6848 feet Junk(measured) none AOGCC Effective Depth measured 16183 feet Packer(measured) 12006'1 V true vertical 6849 feet (true vertical) 6734 Casing Length Size MD TVD Burst Collapse Conductor 78' 16" 107' 107' Surface 2696' 9.625" 2725' 2475' Intermediate 12961' 7" 12986' 6944' Liner 3388' 4.5" 16183' 6850' Perforation depth. Measured depth: slotted liner from 12988-13502', 13582'-16180' SCANNED ' ' ' ' -t True Vertical Depth: 6998'-6959',6958'-6849' Tubing(size,grade,MD,and ND) 4.5 x 3.5, L-80, 12184 MD,6794 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER PREMIER PACKER @ 12006 MD and 6734 ND SSSV-CAMCO TRMAXX-5E SSSV @ 2063 MD and 1995 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 12986'-16183' Treatment descriptions including volumes used and final pressure: one treatment for both laterals-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 985 471 1629 1642 296 Subsequent to operation 1017 559 1580 1528 310 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development F Service r Stratigraphic r 16.Well Status after work: Oil 17 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 A 265-6579 Email Kerry.C.Freedman(c�conocophillips.com Printed Name Kerry Freedman Title Principal Production Engineer Signature Phone:265-6579 Date -7A,....6._____ Ar ill LOt 5— k- k-Ti- 4/iO/15 RBDMSI APR - 7 2015 ,4 y/,/s Form 10-404 Revised 10/2012 Submit Original Only CD3-106 Scale Inhibition Treatment 3/7/15-3/8/15 Non-Aqueous Scale Inhibitor Squeeze Job pumped from 3/7/15 10:45 to 3/8/15 11:00. LRS= Little Red Services - Initial pressure TBG/IA/OA—1500/1600/600 - LRS pumped 289 bbls Diesel/M209/WAW5206 pre-flush at 1—4.8 bpm,TBG/IA/OA— 700/1723/28 - LRS pumped 289 bbls 70/30 EG/Water and SCW3001WC scale inhibitor main treatment at 1-4 bpm,TBG/IA/OA—290/1867/30 - LRS pumped 2704 bbls Dead Crude/M209 over-flush at .5-4 bpm,TBG/IA/OA—712/1935/29 Interval treated: 12,986'—16183' t WNS CD3-106L1 , ConocoPhillips /= Well Attributes Max Angle&MD TD "„i,. 1f1 Wellbore API/MI Field Name Well Status Incl(") MD(MB) Ad Btm(KKB) Lmo.rta4s 501032061160 FIORD NECHELIK PROD 96.06 16,126.76 16,193.0 w. Comment H2S(ppm) Date Annotation End Date KB-God(R) Rig Release Date Wen Contig'.MULTIPLE LATERALS-CD3-1D6L14/12/2012 1.0218 PMSSSV:TRDP Last WO. 28.00 3/6/2010 Schematic-Actual- Annotation Depth(RKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:WELL REVIEW osborl 4/12/2012 RANGER,22 Casing Strings Casing Description String 0... String ID...Top(11KB) Set Depth(f...Set Depth(11/0)...String Wt_.String...String Top Thrd L1 LINER 41/2 3.958 12,795.2 16,183.0 Top Depth 6,849.0 12.60 L-80 SLHT s Liner Details 49 "/ 7 IND) Top Incl Nomi... Top(5KB) (KKB) I") Item Description Comment ID(In) 12,795.2 7,072.0 104.23 SLEEVE Baker 5"X 7""HR”Liner Setting Sleeve 4.950 12,808.0 7,066.0 103.86 NIPPLE Baker 5""RS"Packoff Seal Nipple 4.870 12,811.6 7,064.4 103.76 HANGER Baker 5"X7""DG"Flex-Lock Liner Hanger 4.880 12,821.5 7,059.9 103.48 XO Bushing Baker 5"TCK x 4-1/2"SLIT Cross over Bushing 3.970 CONDUCTOR, Perforations&Slots 24107 I Shot Top(ND) Btm(TVD) Dens /, Top(RKB)Btm(RKB) (RKB) (KKB) Zone Date Oh— Type Comment / 12,987.9 13,501.5 6,998.3 6,958.7 3/3/2010 32.0 SLOTS Slots 1/8x2.25",8 slots/row,4 rows/ft; no slots 3'from box/pin 13,581.5 16,179.8 6,958.2 6,849.3 3/3/2010 32.0 SLOTS Slots 1/8x2.25",8 slots/row,4 rows/ft; no slots 3'from box/pin Safety Valve, J..��'I 2,063 j Notes:General&Safety End Date Annotation _ --_ 3/20/2010 NOTE:CD3-106L1 top in main wellbore,CD3-106 liner a Plop 8 Drop off CD3-106L1(see attachment) e 3/20/2010 NOTE:VIEW SCHEMATIC w/Alaska Schema)1c9.0 F n SU242.725RFACE,__ J IL a GAS LIFT, N 4,680 IN I GAS LIFT. 9,468 a a MI GAS LIFT. _ 11.685P II IIII PACKER, 12,0E6 -V_7_'.. NIPPLE,12,054 im WLEO,12,104 1 ri t$ Mandrel Details Top Depth Top Port (ND) Inol OD Valve Latch Size TRO Run Stn Top(RKB) (R103) ('I Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 4,679.5 3,418.5 65.24 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,935.0 3/9/2010 2 9,487.9 5,589.7 62.21 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,951.0 3/9/2010 3 11,884.5 6,685.31 64.99 CAMCO KBMG 1 GAS LIFT OV BK 0.313 0.0 3/9/2010 NTERMEDIATE, 8 4 25-12,986 SLOTS. ;Y 12.986-13.502 p ,. SLOTS. •I 13,582-16.180 (i. LI LINER, Ee 12,795-16,TD-\ t (003-106L1), 1 16,193 0 0 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Qi 0 - ODD,,. Well History File Identifier Organizing (done) ❑ Two -sided III III 11111 1 ❑ Rescan Needed 1 1111I 11111 RES AN DIGITAL DATA OVERSIZED (Scannable) olor 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: Date: g5 t v, /s/ ryi I° 1 Project "ect Proofin 1 1 I IIII Proofing BY: C qi Maria Date: ! a /s/ 01 P Scanning Preparation x 30 = 0 + V = TOTAL PAGES (0 9 (Count does not include cover sheet) ,/l n BY: Date: j !s D... (Count C r j Production Scanning [ lIlIlIlIlIlIll / � Stage 1 Page Count from Scanned File: � v (Count does include cove sheet) Pa•e Count Matches Number in Scanning Preparation: YES NO BY: gdp Date: 061 / /s/ P Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. I III IIIIIII 1111 ReScanned 111111111111111111 BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIII 1111111 III 12/22/2011 Well History File Cover Page.doc • STATE OF ALASKA • • - ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ("" Repair w ell I Rug Perforations f Perforate E Other jy scale inhibition treatment • Alter Casing f Pull Tubing I Stimulate - Frac i Waiver r Time Extension Change Approved Program EOperat. Shutdow n E Stimulate - Other fa Re -enter Suspended Well f 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. • Development (✓' • Exploratory I 210 -002 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service I 50 103 - 20611 - 60 • 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 364470, 364471, 372105 CD3 - 106L1 • 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 16193 ' feet Plugs (measured) none true vertical 6848 feet Junk (measured) none Effective Depth measured 16183 feet Packer (measured) 12006 true vertical 6850 feet (true vertical) 6734 Casing Length Size MD TVD Burst Collapse Conductor 78' 16" 107' 107 Surface 2696' 9.625" 2725' 2475 Intermediate 12961' 7" 12986' 6944 Liner 3388 4.5" 16183' 6850 RECEIVED MAY 1 3 2013 Perforation depth: Measured depth: slotted liner 12988'- 13502', 13582'- 16180' True Vertical Depth: 6998'- 6959', 6958' -6849' AOGCC Tubing (size, grade, MD, and TVD) 4.5 x 3.5, L - 80, 12184 MD, 6794 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER PREMIER PACKER @ 12006' MD and 6734' TVD SSSV - CAMCO TRMAXX - 5E @ 2063 MD' and 1995' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 12986'4 6183' there was one treatment (see attached summary) for both Treatment descriptions including volumes used and final pressure: laterals - the volumes listed for each lateral reflect the one treatment. 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation 2099 3676 1011 -- 350 Subsequent to operation 2552 2842 1407 -- 350 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development Pi Service Stratigraphic I 16. Well Status after work: Oil i*o • Gas E WDSPL 1 Daily Report of Well Operations XXX GSTOR E VVINJ E WAG r �e GINJ is SUSP Il 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 Tim Nelson a 265 -6859 Email Tim.J.Nelsonacop.com Printed Name Tim Nelson Title Staff Production Engineer Signature Phone: 265 -6859 Date / /0 � l3 Sri- r RBDMS MAY 13 2013 -/3/13 Form 10 -404 Revised 10/2012 ` " r� Submit Original Only • Scale Inhibition Treatment: CD3 -106L1 4/30/2013 Initial pressure TBG /IA /OA- 200/1482/670; LRS pumped 290 bbl arctic low endpoint diesel containing 1680 gal WAW5206 at 3.2 bpm, 350/1590/VAC; 290 bbl of 60:40 EG containing 1980 gal SCW3001WC was then pumped at 2.2 bpm, 50/1565/VAC; and 2732 bbl of crude overflush at 2 bpm. Final pressures 437/1848/VAC. WNS • CD3 -106L1 Conoco Phillips ,-, 'sue Well Attributes Max Angle & MD TD (Alaska Inc Wellbore API/UWI Field Name Well Status Inc' ( °) MD (ftKB) Act Btm (ftKB) 501032061160 FIORDNECHELIK PROD 96.06 16,126.76 16,193.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date "' SSSV: TRDP Last WO: 28. 3/6/2010 7/ell Contip MULTIPLE LATERALS - CD3-106L1 4/1220121: 02:18 PM schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason: WELL REVIEW osborl 4/12/2012 HANGER, 22 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd H L1 LINER 4i 1/2 3.958 12,795.2 16,183.0 6,849.0 12.60 L -80 SLHT Liner Details Top Depth (ND Top Incl Nomi... — , Top (ftKB) (ftKB) (°) Item Description Comment ID (In) 12,795.2 7,072.0 104.23 SLEEVE Baker 5" X 7" "HR" Liner Setting Sleeve 4.950 12,808.0 7,066.0 103.86 NIPPLE Baker 5" "RS" Packoff Seal Nipple 4.870 12,811.6 7,064.4 103.76 HANGER Baker 5" X 7" "DG" Flex-Lock Liner Hanger 4.880 - 12,821.5 7,059.9 103.48 X O Bushing Baker 5" TCK x 4 -1/2" SLHT Cross over Bushing 3.970 Perforations & Slots CONDUCTOR, Shot 29-107 Dens Top (TVD) Btm(TVD) Ur Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date (ch... Type Comment 12,987.9 13,501.5 6,998.3 6,958.7 3/3/2010 32.0 SLOTS Slots 1/8x2.25 ", 8 slots/row, 4 rows/ft; S r no slots 3' from box/pin MIL 13,581.5 16,179.8 6,958.2 6,849.3 3/3/2010 32.0 SLOTS Slots 1 /8x2.25 ", 8 slots /row, 4 rows/ft; no slots 3' from box/pin Safety Valve, a0 • 1 2063 Notes: General & Safety I End Date Annotation 3/20/2010 NOTE: CD3 -106L1 top in main wellbore, CD3 -106 liner a Plop & Drop off CD3 -106L1 (see attachment) 3/20/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 SURFACE, L. 29 -2,725 GAS LIFT, c. 4.680 1 GAS LIFT. 9.488 c C' t GAS LIFT. 11,885 illi IF PACKER, 12,006 I r NI NIPPLE. 12,054 It IR WLEG, 12,184 J _. . it I WI Mandrel Details Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) (1 Make Model (in) Sew Type Type ('n) (psi) Run Date Corn... 1 4,679.5 3,418.5 65.24 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,935.0 3/9/2010 2 9,487.9 5,589.7 62.21 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,951.0 3/9/2010 3 11,884.5 6,685.3 64.99 CAMCO KBMG 1 GAS LIFT OV BK 0.313 0.0 3/9/2010 NTERMEDIATE, 25- 12,986 SLOTS. 19988- 13,502 SLOTS, 13,582- 16,180 11 LINER, 12,795-16,183 TD � (CD3.106L1), • 16,193 o T • STATE OF ALASKA 0 RECEIVE[ ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 2 5 ; 2010 la. Well Status: oil WELL C PLETIO� O R 1 Commission C ass: 20AAC 25.105 20AAC 25.110 Development Q Explorator ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: March 5, 2010 210 - 0020 / 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 February 24, 2010 50 103 - 20611 - 60 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1359' FSL, 777' FEL, Sec. 5, T12N, R5E, UM March 1, 2010 CD3 - 106L1 Top of Productive Horizon: 8. KB (ft above MSL): 41.4' RKB 15. Field /Pool(s): 405' FSL, 1190' FWL, Sec. 29, T13N, R5E, UM GL (ft above MSL): 13.4' AMSL Colville River Field Total Depth: 9. Plug Back Depth (MD + TVD): 1854' FNL, 248' FEL, Sec. 30, T13N, R5E, UM 16183' MD / 6850' TVD Fiord Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 388266.46 y 6003852 Zone 4 16193' MD / 6848' TVD ADL 364470, 364471, 372105 TPI: x - 387710 y - 6013467 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 386308 y 6016509 Zone 4 2062' MD / 1996' TVD 380077 18. Directional Survey: Yes p No 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) approx. 1500' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re drill /Lateral Top Window MD/TVD GR/Res not applicable 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 28' 107' 28' 107' 24" pre - set 9 -5/8" 40# L -80 28' 2725' 28' 2475' 12.25" 410 sx ArcticSet III, 232 sx Class G 7" 26# L -80 28' 12986' 28' 6944' 8.75" 304 sx Class G, 271 sx Class G 4.5" 12.6# L -80 12795' 16183' 6920' 6850' 6.125" slotted / blank liner 24. Open to production or injection? Yes Q No ❑ If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3.5" 12184' 12006' MD / 6734' TVD slots from 16179'- 13581' MD 6839' -6958' TVD 13501' 12987' MD 6958' - 6944' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED none 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) March 11, 2010 gas lift oil Date of Test Hours Tested Production for OIL - BBL GAS - MCF WATER - BBL CHOKE SIZE GAS - OIL RATIO 3/12/2010 6.5 Test Period - -> 551 246 88 25% 435 Flow Tubing Casing Pressure Calculated OIL - BBL GAS - MCF WATER - BBL OIL GRAVITY - API (corr) Press. 893 psi not available 24 - Hour Rate - 2033 910 326 not available 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No Q Sidewall Cores Acquired? Yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water " °� , oge (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. a , to axi VE}UFIEP .1 NONE Form 10 -407 Revised 12/2009 NTINUED ON REVERSE Submit original only RBDMS MAR 25 201 €7• Zl. /o / cf/A1410 C7 28. GEOLOGIC MARKERS (List all formations and markers ncountered): 29. • FORMATION TESTS NAME MD TVD Well tested? ❑ Yes mi 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 1527' 1500' needed, and submit detailed test information per 20 AAC 25.071. C30 2748' 2488' C20 3465' 2880' K -3 5850' 3926' K -2 6248' 4112' Nanuq 10400' 6001' K -1 12125' 6776' Kuparuk 12270' 6817' Kuparuk C 12455' 6861' Nechelik 12828' 6926' N/A Formation at total depth: Nechelik 30. LIST OF ATTACHMENTS Summary of Daily Operations, Final directional survey, schematic f 3'ZSjZOIO 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mi Winfree @ 265 - 6820 Printed Name GGL.. Alvord Title: Alaska Drilling Manager Signature �°' Phone 265 - 6120 Date 3 1 /2 41Zota Sharon Allsup -Drake INSTRUCTIONS 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 la: 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 12/2009 1 WNS • CD3 -106L1 Ctntl000P1lllt Well Attributes Max Angle & MD TD Wellbore APUUWI Field Name Well Status Inc/ ( MD (ftKB) Act Btm (1106) `"'k�' 1N: tano, ,,,,s -n 501032061160 i F IORD NE( 1 1L LIN, PROD 1 96.06 16,126 /6 16,193.0 Comment 925 (ppm) Date Annotation End Date KB -Grd (f1) Rig Release Date ell COnfg MULTIPL LAT RALS - CD3- 106L1,37 $S$V: TRDP P (ftKB) Last WO' '. 28.00 316/2010 Schematic Actual Annotation Depth ftKB ) End Date Annotation Last Mod ... End Date Last Tag: I' -._ Rev Reason' GLV C /O, Pull RHC, BaII /Rod . Imosbor l 3/20/2010 HANGER, 22 -- ,N [ Casin g Strings_ Casin Description String O String ID Top (ftKB) Sot Depth (f_. Set Depth (TVD) - 1Strmg Wt... String _ String Top Thrd L1 LINER 41 2 I 12,795. 16,183.0 68490 1260 L-80 SLH T I '7 Li Details___ Top Depth _ (TVD) Top Incl Nomi... Top(ftKB) (ftKB) (3 Item Description Comment ID(in) ., . r „ „. . r , , ., , . r r , , H 1 2,795. 2 7,072.0 104.23 Setting SLV Baker 5" X 7" "HR" Liner Setting Sleeve 4.950 12,808.0 7,066.0 103.86 NIPPLE Baker 5" "RS" Packoff Seal Nipple 4.870 12.811.6 7,064.4 103.76 HANGER Baker 5" X 7" "DG" Flex -Lock Liner Hanger 4.880 12821.5'. 7,059.9' 103 481 XO Bushing Baker 5" TCK x 4 - 1/2" SLHT Cross over Bushing 3.970 Perforations & Slots CONDUCTOR, - Shot 29-107 Top (TVD) Btm (TVD) , . Dens ' Top (ftKB)' Btm (ft 95 (ftKB) IRKS) Zone Date ( "' Type Comment 12,988 13,502 6,998.3 0 958./ 3/3/2010 SLOTS Slots 1/8x2.25", 8 slots /row, 4 rows/t, no slots 3' from box/pin 13,582 16,180 6,958.2 6 849.3 3/3/2010 SLOTS Slots 1/8x2.25 ", 8 slots /row, 4 rows/R; Safety Valve, no slots 3' from box/pin 2,063 . -L... Notes: General & Safety +, End Date Annotation — ' If 120/2010 NOTE: CD3 -106L1 top In main wellbore, CD3 -106 liner a Plop & Drop off CD3 -106L1 (see attachment) I 3/20/2010 ( NOTE: VIEW SCI- IEMvIP, 1IC w /Alaska Schemahc9.0 i ,. , i , i , I , SURFACE. 29 'L. GAS LIFT, 4,680 GAS LT,__ 9,4 - GAS LIT '1885 PACKER, 12,006 NIPPLE, 12,054 - - -- . WLEG,12,184 Mandrel Details .. �4..-± Top Depth Top Port (190) Ind OD Valve Latch Size TRO Run . i Stn TopjltKB)__ (I ) ( °) Make Model P ^) Gov Type Type ^) (Psi) Run Date Com... 1 4,679.5 3,418.5 65.24 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,935.0 3/9/2010 2 9,487.9 5,589.7 62.21 CAMCO KBMG 1 GAS LIFT GLV '' 0.188 1,951 0 3/9/2010 3 11,884.5 6,685.3 64.99 CAMCO KBMG 1 GAS LIFT OV BK 0.3131 0. 3/9/2010 NTERMEDIATE, 25- 12,986 SLOTS, _. - :, _. 12,988 - 13,502 SLOTS, I ,�j T 13,582 - 16,180__ L1 LINER, 12,795-16,18 3 D (CD3'106L1), 16,193 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:30 16:45 6.25 6,732 0 COMPZ CASING TRIP P Pump out of hole at rate of 1 bpm @ 300 psi f/ to 3,366', POOH on elevators, Lay down running tool. Calculated displacement 74 bbls / Actual 111 bbls 16:45 19:00 2.25 0 0 COMPZ DRILL PULD P Lay down 2 bad stands 4" drill pipe from derrick, Clean rig floor, Rig to test BOP 19:00 00:00 5.00 0 0 COMPZ WHDBO BOPE P Test BOPE w/ 3 -1/2 ", 4" & 4 -1/2" test joints to 250 psi low & 3500 psi high, Annular to 250 psi low & 2500 psi high. BOP test waived by AOGCC Lou Grimaldi. 02/24/2010 Complete BOP test - PU BHA # 6 - RIH - Displace well w/ new FLOTHRU 10.5 ppg mud w/ micronised barite -Cut trough and time drill f/ 13,270' to 13,272' MD le 00:00 04:15 4.25 0 0 COMPZ WHDBO BOPE P Test BOPE w/ 3 -1/2 ", 4" & 4 -1/2" 5 1 test joints to 250 psi low & 3500 psi high, Annular to 250 psi low & 2500 psi high. BOP test waived by AOGCC Lou Grimaldi. • 04:15 08:15 4.00 0 381 PROD2 DRILL PULD P PJSM - PU BHA #6 to 80' - Upload MWD - Con tinue PU BHA # 6 to 381' 08:15 15:15 7.00 381 13,037 PROD2 DRILL TRIP P RIH f/ 381' to 12,947' filling every 20 stds - Wash down 90' to 13,037' - PUW - 177k - SOW - 78k 11; 15:15 16:00 0.75 13,037 13,037 PROD2 RIGMNT SVRG P Service Top drive 16:00 17:15 1.25 13,037 13,323 PROD2 DRILL REAM P Wash & Ream f/ 13037' to 13,323' w/ 137 gpm, 1250 psi - PUW 120k - SOW 118k 17:15 19:15 2.00 13,272 13,229 PROD2 DRILL CIRC P CBU - Displace well w/ 10.5 ppg FLOTHRU w/ micronised barite 19:15 21:45 2.50 13,229 13,270 PROD2 DRILL REAM P PU and Cutting trough f/ 13,229- 13,270 MD 21:45 00:00 2.25 13,270 13,272 PROD2 DRILL DDRL P Time drill f/ 13,270 to 13,272' MD (6955' TVD) -PUW 124k - SOW 118k - ROW 120k - ECD 11.37 - Max gas observed 60 units -Total losses for day = 112 bbls 02/25/2010 Time drill f/ 13,270' to 13,294' - Drill ahead f/ 13,294' to 13,410' - ADT = 13.3 hrs 00:00 03:45 3.75 13,272 13,280 PROD2 DRILL DDRL P Continue time drilling f/ 13272' to 13274' MD at 1 fph - 13274' to 13276' at 2 fph, 2 -4k WOB - 13276' to 13280' at 4 fph w/ 2k WOB - ROP increase to 400 fph w/ Ok WOB - Slack off to 13285' - Appeared to fall into original well bore 03:45 07:15 3.50 13,229 13,270 PROD2 DRILL DDRL P PU and cut trough f/ 13229' to 13270' w/ 200 gpm, 1500 psi - 90 RPM w/ 13k tq Page 25 of 32 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:15 12:00 4.75 13,270 13,274 PROD2 DRILL DDRL P Time drilling f/ 13270' to 13274' at 1 fph - 200 gpm, 1500 psi - 110 RPM w/ 13k tq -PUW 124k -SOW 118k -ROW 123k -Tq on 13k - Tq off 13k -ECD 11.42 ppg - Losses for tour = 152 bbls 12:00 20:15 8.25 13,274 13,294 PROD2 DRILL DDRL P Time drilling f/ 13274' to 13294' 20:15 00:00 3.75 13,294 13,410 PROD2 DRILL DDRL P Drill ahead f/ 13294' to 13410' MD (6958' TVD) - 200 gpm, 1800 psi - 110 RPM, 13k tq PUW 155k -SOW 90k -ROW 125k -Tq on13k- Tg off 11.5k -ECD 11.74 ppg - ADT for day =13.3 hrs - Losses for tour = 160 bbls - Losses for day = 312 bbls 02/26/2010 Dir. drill to 14131' MD - POH for Sperry tool failure 00:00 12:00 12.00 13,410 14,008 PROD2 DRILL DDRL P Dir. drilling f/ 13410' to 14008' MD (6928' TVD) WOB 15k - 192 gpm, 1800 psi - 120 RPM w/ 13k tq - ADT = 9.48 hrs -PUW 165k - SOW 80k - ROW 120k TO on 13k off 11k -ECD = 11.87 ppg - Losses for tour 387 bbls 12:00 13:45 1.75 14,008 14,131 PROD2 DRILL DDRL P Dir. drilling f/ 14008' to 14131' MD (6922' TVD) - WOB 15k - 192 gpm, 1800 psi - 120 RPM w/ 13k tq - ADT = 1.98 hrs -PUW 160k - SOW 85k - ROW 125k TQ on 13k off 11k -ECD = 11.82 ppg - Losses for tour 64 bbls 13:45 14:45 1.00 14,131 14,131 PROD2 DRILL DHEQ T Lost communication w/ Sperry tools. Attempt restart w/ no success 14:45 15:30 0.75 14,131 14,131 PROD2 DRILL CIRC T CBU w/ 203 gpm, 1800 psi - 120 RPM w/ 11 k tq 15:30 16:45 1.25 14,131 12,948 PROD2 DRILL REAM T Back ream OOH f/ 14131' to 12948' MD - 80 RPM - 120 gpm, 800 psi 16:45 17:15 0.50 12,948 12,948 PROD2 DRILL OWFF T Observe well, flow check - Well breathing 30 bbls hr - Slowed to 6 bbls hr. 17:15 21:00 3.75 12,948 9,000 PROD2 DRILL TRIP T Pump out of hole f/ 12948' to 9000' MD w/ 120 gpm 21:00 22:15 1.25 9,000 9,000 PROD2 DRILL OWFF T Flow check well - Flowing back 15 bbls hr - Slowed to 1/2 bph 22:15 22:45 0.50 9,000 8,528 PROD2 DRILL TRIP T POH on elevators f/ 8905' to 8528' MD - Incorrect fill (swabbing) 22:45 00:00 1.25 8,528 7,886 PROD2 DRILL TRIP T Pump out of hole f/ 8528' to 7886' MD -120 gpm - Drilling losses for tour = 52 bbls -Tripping in losses for tour = 12 bbls -Total losses for day = 411 bbls 02/27/2010 Finish pump out - Change out Sperry tools - PU BHA #7 - RIH - Dir. drill f/ 14131' Page 26 of 32 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 04:00 4.00 7,886 3,840 PROD2 DRILL TRIP T Continue pump out f/ 7886' to 3840' MD w/ 120 gpm, 500 psi 04:00 07:00 3.00 3,840 381 PROD2 DRILL TRIP T Monitor well (Static) - Blow down TD - POH on elevators f/ 3840' to 381' (BHA) - PUW 82k 07:00 09:30 2.50 381 0 PROD2 DRILL PULD T Stand back HWDP, NMDC - Download MWD - LD remainder of BHA #6 - Calculated fill for trip = 50.3 bbls - Actual fill for trip = 61.89 bbls 09:30 09:45 0.25 0 0 PROD2 DRILL PULD T Clean rig floor / Clear of all equipment not needed for upcoming operation. 09:45 12:15 2.50 0 93 PROD2 DRILL PULD T MU Bit, Geo- Pilot, MWD tools - Upload same 12:15 12:45 0.50 93 476 PROD2 DRILL PULD T MU remaider of BHA #7 - RIH w/ 1 std 4" DP to 476' MD 12:45 13:15 0.50 476 476 PROD2 DRILL CIRC T Break in bearings on Geo -Pilot - Shallow test MWD - OK 13:15 16:00 2.75 476 7,020 PROD2 DRILL TRIP T RIH to 7020' MD - Fill every 20 stds 16:00 16:30 0.50 7,020 7,020 PROD2 DRILL CIRC T Fill pipe - CBU w/ 200 gpm, 1200 psi 16:30 19:45 3.25 7,020 13,887 PROD2 DRILL TRIP T Continue RIH to 13887' MD - Fill every 20 stds 19:45 20:15 0.50 13,887 14,131 PROD2 DRILL REAM T As precaution, ream f/ 13887' to bottom at 14131' MD w/ 200 gpm, 1700 psi - 120 RPM, 11k tq 20:15 00:00 3.75 14,131 14,290 PROD2 DRILL DDRL P Dir. drill f/ 14131' to 14290' MD (6913' TVD) - WOB 15k - 188 gpm, 1650 psi - 120 RPM, 13k tq - PUW 160k - SOW 80k- ROW 120k - TQ on 13k - Off 10k - ECD's = 11.69 ppg -Pump 15 bbls LCM pill every connection - Losses for tour & day = 184 bbls -ADT = 2.16 hrs -Max gas = 72 Units 02/28/2010 Dir.drill f/ 14290 to 15525' MD (6882' TVD)- Pump 15 bbls LCM sweep at each connection 00:00 12:00 12.00 14,290 14,970 PROD2 DRILL DDRL P Dir. drill f/ 14290' to 14970' MD (6913' TVD) - WOB 15 -17k - 192 gpm, 1800 psi - ADT = 9.2 hrs -PUW 165k - SOW 82k - ROW 119k - TQ on 14k, OFF 12k at 120 RPM - Continue to pump 15 bbls LCM pill every connection -ECD's = 11.97 ppg - MW = 10.5 ppg - Losses for tour = 312 bbls 12:00 00:00 12.00 14,970 15,525 PROD2 DRILL DDRL P Dir. drill f/ 14970' to 15525' MD (6882' TVD) - WOB 15 -17k - 192 gpm, 1800 psi - ADT = 8.75 hrs - -PUW 165k - SOW 82k - ROW 120k - TQ on 14k, OFF 12k at 120 RPM - Continue to pump 15 bbls LCM pill every connection -ECD's = 12.1 ppg - MW = 10.5 ppg - Losses for tour = 334 bbls -Total losses for day = 646 bbls Page 27 of 32 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/01/2010 24 hr Summary Dir. drill f/ 15,525' to 6 1/8' TD at 16,193' MD (6850 TVD) - Circ. hole clean while BROOH at 2.5' min. to 15673' - Cont. BROOH at 45' min 00:00 07:15 7.25 15,525 15,952 PROD2 DRILL DDRL P Dir. drill f/ 15,525' to 15,952' (6865' TVD) - WOB 15 -18k - 192 gpm, 1950 psi - 120 RPM, 14k tq on, 11k off - ECD's = 11.98 ppg PUW 162k - SOW 83 k - ROW 124k 07:15 08:15 1.00 15,952 15,952 PROD2 DRILL SRVY P MAD Pass f/ 15,920'- 15,858' MD 08:15 12:00 3.75 15,952 16,116 PROD2 DRILL DDRL P Dir. drill f/ 15,952 to 16,116' (6857' TVD) - WOB 15 -18k - 192 gpm, 1950 psi - 120 RPM, 14k tq on, 11k off - ECD's = 11.98 ppg -PUW 162k - SOW 83 k - ROW 124k -ADT for tour 8.79 hrs - Losses for tour = 294 bbls 12:00 18:30 6.50 16,116 16,193 PROD2 DRILL DDRL P Dir. drill f/ 16,116' to 6 1/8" TD at 16,193' (6850' TVD) - WOB 20k -192 fD gpm, 2100 psi - 90 RPM, 14k tq on, 11k off - ECD's = 12.05 ppg PUW 160k - SOW 80 k - ROW 122k -ADT for tour 5.77 hrs - Total for day = 14.56 - Losses for tour = 279 bbls -Total loss for day = 573 bbls 18:30 22:30 4.00 16,193 15,673 PROD2 DRILL CIRC P Circ. hole clean while BROOH at 2.5' min f/ 16193' to 15673' MD -200 gpm, 2150 psi -130 RPM, 11k TQ - Performed spill drill - AMAS in 1 min. 48 sec. 22:30 00:00 1.50 15,673 PROD2 DRILL REAM P Continue BROOH at 45' min to 15,015' MD- Same parameters as above 03/02/2010 BROOH after 6 1/8" TD - Performed "exhale" test at shoe - CDL - Pumped out of hole to 2634' - LD BHA # 7 00:00 02:45 2.75 PROD2 DRILL REAM P Continue BROOH f/ 15,015' to 12,948' MD at 30' min w/ 200 gpm, 1800 psi - 130 RPM w/ 8k TQ - Calculated fill = 13.75 bbls - Actual fill = 52.92 bbls -Loss = 44 bbls 02:45 04:00 1.25 PROD2 DRILL CIRC P CBU w/ 200 GPM, 1675 psi, 90 RPM, 7k TQ - Losses while circ. = 21 bbls -ECD's = 11.85 ppg 04:00 06:00 2.00 PROD2 DRILL OWFF P RU & perform "exhale" test - #1 = 30 min. shut -in w/ 20 psi SIDPP & 0 SICP - Bleed back .34 bbls - Test #2 = 0 SIDPP & 0 SICP w/ .17 bbls bleed back - RD test equip. - Blow down lines Page 28 of 32 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 07:15 1.25 PROD2 DRILL CIRC P CBU at 12,948' w/ 200 gpm, 1850 psi - 90 RPM w/ 7k TQ - Losses while circ. = 37 bbls -ECD's = 11.85 ppg 07:15 09:00 1.75 PROD2 RIGMNT SLPC P Slip & cut 66' drilling line - Service TD - Inspect derrick 09:00 10:15 1.25 PROD2 DRILL CIRC P CBU at 12,948' w/ 200 gpm, 1700 psi - 90 RPM w /8kTQ - Losses while circ. = 30 bbls - Losses for tour = 132 bbls -ECD's = 11.92ppg 10:15 12:00 1.75 PROD2 DRILL TRIP P Pump out of hole f/ 12,948' to 12,101' MD w/ 120 gpm, 875 psi 12:00 20:00 8.00 PROD2 DRILL TRIP P Continue pump out of hole f/ 12,101' to 2634' MD w/ 120 gpm - Dropped 2 1/8" DP drift at 8246' (STD # 84) 20:00 20:15 0.25 PROD2 DRILL OWFF P Observe well - Static 20:15 21:00 0.75 PROD2 DRILL TRIP P POH on elevators f/ 2634' to 382' (BHA) 21:00 21:15 0.25 PROD2 DRILL OWFF P Observe well - Static 21:15 22:30 1.25 PROD2 DRILL PULD P LD BHA # 7 (4 HWDP, bumper sub, 1 HWDP, jars, 3 NMDC's) - Recovered DP drift at bumper sub 22:30 00:00 1.50 PROD2 DRILL PULD P Download MWD tools - Losses for tour = 44 bbls - Losses for day = 176 bbls 03/03/2010 LD BHA #7 - Test annular - RU & run 4 1/2' 12.6# slotted liner to 16,183' - set liner (Top at 12,795) - CBU - Pump out of hole (breathing) 00:00 01:00 1.00 0 0 PROD2 DRILL PULD P LD BHA # 7 01:00 01:30 0.50 0 0 PROD2 WHDBO BOPE P Pull wear ring - RU BOP test equip. 01:30 02:30 1.00 0 0 PROD2 WHDBO BOPE P Test annular w/ 4" test it. - 250 psi low, 2500 psi high - Record on chart - RD test equip. - Install wear ring 02:30 03:15 0.75 0 0 COMPZ CASING SFTY P PJSM - RU casing equip. for 4 1/2" liner 03:15 06:00 2.75 0 3,555 COMPZ CASING RUNL P Run 4 1/2" slotted liner (84 jts) to 3555' MD 06:00 07:00 1.00 3,555 3,555 COMPZ CASING RUNL P MU Baker "Flex Lock" liner hanger & running tool 07:00 12:00 5.00 3,490 10,034 COMPZ CASING RUNL P Run 4 1/2" liner on 4" DP - Break circ. w/ 1.5 bpm, 80 psi at 3490' - ROW, 62k - Continue RIH to 8996' MD - Break circ. w/ 1.8 bpm, 325 psi - ROW 100k - RIH to 10,034' -PUW = 135k - SOW = 77k 12:00 13:45 1.75 10,034 12,956 COMPZ CASING RUNL P Continue RIH w/ liner on DP f/ 10,034' to 12,956' MD (Drift DP f/ 11,353' to 12,956') - Continue to record T &D data per Engineer 13:45 14:30 0.75 12,956 12,956 COMPZ CASING CIRC P Circ. DP & liner vol w/ 3 bpm 700 psi Page 29 of 32 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:30 16:30 2.00 12,956 16,193 COMPZ CASING RUNL P Continue RIH w/ line f/ 12,956' to 16,193' - Tagged bottom w/ 5k down wt 16:30 18:00 1.50 16,193 16,183 COMPZ CASING CIRC P PU 10' to 16,183' - Drop setting ball - Pump down on seat w/ 2 bpm reducing to 1 bpm , 400 psi, at 1000 stks away - At 1234 stks, pressure to 2000 psi to set hanger - slack off to 35k, PU to 60k - Increase pressure to 3200 psi to release running tool - Pressure and shear seat w/ 4200 psi - PUW before release = 180k - After = 165' at 12,795' MD 18:00 19:15 1.25 12,722 12,722 COMPZ DRILL CIRC P PU to 12,722' - CBU w/ 8 bpm, 2500 psi (10 min) - Reduce rate to 5 bpm, 1400 psi to reduce loss rate - Losses fell f/ 100 bph to 15 bph -Total lossses = 25 bbls 19:15 00:00 4.75 12,795 8,335 COMPZ DRILL TRIP P Observe well (breathing) - Pump out of hole f/ 12,795' to 8335' MD - Calculated fill = 24 bbis - Actual fill = 37 bbis 03/04/2010 Cont. POH - LD running tool - Swap wear rings - RU & run 3 1/2" completion per running order 00:00 03:00 3.00 8,335 4,567 COMPZ DRILL TRIP P Continue Pump OOH f/ 8345' to 4567' MD w/ 3 bpm, 400 psi -(9.4 bbis over calculated fill) - Monitor well (Static) 03:00 04:15 1.25 4,567 3,827 COMPZ DRILL TRIP P Attempt to POH on elevators f/ 4567' to 3827' MD -1.21 bbls under calculated fill 04:15 05:45 1.50 3,827 2,439 COMPZ DRILL TRIP P Continue Pump OOH f/ 3827' to 2439" MD w/ 3 bpm, 400 psi -(2.2 bbis over calculated fill) - Monitor well (Static) 05:45 07:15 1.50 2,439 0 COMPZ DRILL TRIP P Monitor well (Static) - POH on elevators f/ 2439' to surface - .50 over calculated fill 07:15 07:45 0.50 0 0 COMPZ DRILL PULD P Inspect & LD liner running tool (OK) 07:45 08:30 0.75 0 0 COMPZ DRILL PULD P Pull wear ring - Run tubing wear ring 08:30 09:30 1.00 0 0 COMPZ RPCOM SFTY P PJSM - RU tubing tongs and equip. 09:30 12:00 2.50 0 878 COMPZ RPCOM RCST P Run 3 1/2' 9.3# completion Der running order - PU WLEG - 4 jts 3 1/2" tbg - HES "XN" nipple (2.813" ID w/ 2.75" No -Go) - 1 jt 3 1/2" tubing - Baker 7" x 3 1/2" Premier packer (baker lock all connections below packer) - Ran total of 26 jts at tour change -Total losses for tour = 10.9 bbis 12:00 20 :30 8.50 878 10,117 COMPZ RPCOM RCST P Continue run 3 1/2' completion per running order - Ran jts 27 - 316 to 10,117' MD (WLEG depth) Page 30 of 32 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:30 22:00 1.50 10,117 10,117 COMPZ RPCOM SSSV P PJSM - PU 3 1/2" Camco TRMAXX - 5E SSSVw/5.916'ODx2.812' ID - PU control line spool - RU same 22:00 00:00 2.00 10,117 10,988 COMPZ RPCOM RCST P Continue RIH w/ 3 1/2" completion to 10,988' (WLEG depth) - Losses for tour = 27 bbls - Losses for day = 38 bbls 03/05/2010 Finished running 3 -1/2" completion, Pull W.B., M/U & land hanger, Attempt to test hanger- N.G., Change out Hanger & Test same to 5000 psi- OK, N/D BOP, N/U Tree, Displace well over to 10.0 ppg brine & spot corrsion inhibitor around WLEG, Drop Ball & Rod, Set PKR w/ 4200 psi, Test tbg to 4000 psi f/ 30 min -OK, Test csg to 3500 psi - OK, Shear out SOV, Frz protect well w/ 160 bbls diesel. 00:00 02:30 2.50 10,988 12,162 COMPZ RPCOM RCST P Continue RIH w/ 3 1/2" completion to 12,162' (WLEG depth). Note; Used 66 stanless steel bands on control line. 02:30 03:30 1.00 12,162 12,162 COMPZ RPCOM THGR P RU and retrived wear bushing. 03:30 04:45 1.25 12,162 12,162 COMPZ RPCOM HOSO P Pick up tubing Hanger & Landing Jt., Install SSSV control line & Test same to 5000 psi - OK 04:45 05:30 0.75 12,162 12,184 COMPZ RPCOM HOSO T Land tubing Hanger, Rig & Test hanger to 5000 psi - No good, Rig down test equip. 05:30 10:15 4.75 12,184 12,184 COMPZ RPCOM HOSO T Pull hanger, Change out tuging hangers, Reinstall SSSV Control line & test to 5000 psi - OK, Land hanger & test hanger to 5000 psi - OK. 10:15 11:00 0.75 12,184 12,184 COMPZ DRILL RURD P PJSM, Clear rig floor of excess tubing running equipment. 11:00 11:45 0.75 12,184 12,184 COMPZ WHDBO NUND P PJSM, Remove surface diverter from cellar. 11:45 13:15 1.50 12,184 12,184 COMPZ WHDBO NUND P Nipple down BOPE & rack back on stump. 13:15 14:00 0.75 12,184 12,184 COMPZ WHDBO NUND P Work on SSSV control line on hanger. 14:00 15:00 1.00 12,184 12,184 COMPZ WHDBO NUND P Install & Nipple up Tree, Test same to 5000 psi f/ 10 min. 15:00 15:45 0.75 12,184 12,184 COMPZ WHDBO MPSP P Pull 2 way check, Open SSSV. 15:45 16:30 0.75 12,184 12,184 COMPZ DRILL RURD P Rig pump lines to displace well to 10.0 ppg Brine. 16:30 21:00 4.50 12,184 12,184 COMPZ DRILL CIRC P Circ 620 bbls 10.0 ppg brine including spacers and change well over to 10.0 ppg brine followed by 32 bbls corrosion inhibited brine & spot same around WLEG to btm GLM, Pumped at rate of 3.0 bpm @ 500 psi, Final tbg press. 50 psi. 21:00 23:15 2.25 12,184 12,184 COMPZ DRILL PRTS P Rig lubricator w/ ball & rod, Drop same and allow to fall, Pressure up on tubing to 4200 psi to set packer, Hold 4000 psi on tubing f/ 30 min - OK, Bleed tubing press. to 2000 psi, Pressure 3 -1/2" x 7" casing to 3500 psi & hold f/ 30 min - OK, Bleed all pressure, Pressure up on annulus & shear SOV w/ 2600 psi OK. Page 31 of 32 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:15 00:00 0.75 12,184 12,184 COMPZ DRILL FRZP P PJSM, Rig Little Red Service, Test lines to 3000 psi, Begin pumping 160 bbls Freeze Protect diesel down 3 -1/2" tubing taking returns up 3 -1/2" x 7" annulus at rate of 1 bpm @ 400 psi. 03/06/2010 Finish freeze protecting well, Rig & set BPV, UD 4" DP f/ DRK, Release rig @ 20:00 hrs 3/6/10 00:00 03:00 3.00 12,184 12,184 COMPZ DRILL FRZP P Continue pumping total of 160 bbls Freeze Protect diesel down 3 -1/2" tubing taking returns up 3 -1/2" x 7" annulus at rate of 1 bpm @ 400 psi, Rig down Little Red. 03:00 06:00 3.00 COMPZ WHDBO NUND P PJSM, Rig lubricator & set BPV in Tree, Rig down same, Install tree cap finish dressing tree, Secure well. 06:00 20:00 14.00 COMPZ DRILL PULD P PJSM, Rig & Lay down total of 186 stands 4" drill pipe from derrick, Lay down mouse hole. RELEASE RIG @ 20:00 hrs 3/6/2010 Page 32 of 32 • • • = s; i ConocoPhillips(Alaska) Inc. Western North Slope CD3 Fiord Pad - CD3 -106L1 501032061160 Definitive Survey Report 09 March, 2010 i. L Sperry Drilling Services II • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well CD3 -106 Project Western North Slope TVD Reference: Plan: CD3 -106 (28 +13.4) © 41.40ft (Doyon 141) Site: CD3 Fiord Pad MD Reference: Plan: CD3 -106 (28 +13.4) @ 41.40ft (Doyon 141) Well: CD3 - 106 North Reference: True Wellbore: CD3 - 106L1 Survey Calculation Method: Minimum Curvature Design: CD3 -106L1 Database: CPAI EDM Production 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 Well CD3 - 106 Well Position +NI - 0.00 ft Northing: 6,003,852.22 ft Latitude: 70° 25' 10.108 N I +E/ - 0.00 ft Easting: 388,266.46 ft Longitude: 150° 54' 36.875 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.40ft Wellbore CD3 - 106L1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength r) ( °) (nT) BGGM2007 1/6/2010 21.28 80.78 57,638 Design CD3 - 106L1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 13,253.49 Vertical Section: Depth From (TVD) +W-S +E/ -W Direction (ft) (ft) (ft) r) I 28.00 0.00 0.00 337.00 Survey Program Date From To (ft) (ft) Survey (Wellbore) Tool Name Description Survey Date 100.00 817.00 CD3 -106 Gyro (CD3 -106) CB- GYRO -SS Camera based gyro single shot 1/21/2010 1; 856.97 2,689.44 CD3 -106 MWD (CD3 -106) MWD +IFR- AK- CAZ -SC MWD +IFR AK CAZ SCC 1/21/2010 1; 2,778.23 12,785.08 CD3 -106 MWD (CD3 -106) MWD +IFR- AK- CAZ -SC MWD +IFR AK CAZ SCC 1/26/2010 1: 12,850.59 12,971.87 CD3 -106 MWD (CD3 -106) MWD +IFR- AK- CAZ -SC MWD +IFR AK CAZ SCC 2/6/2010 12: 13,065.67 13,253.49 CD3 -106 MWD (CD3 -106) MWD +IFR- AK- CAZ -SC MWD +IFR AK CAZ SCC 2/12/2010 1; 13,270.00 14,007.84 CD3 -106L1 MWD (CD3- 106L1) MWD +IFR- AK- CAZ -SC MWD +IFR AK CAZ SCC 2/25/2010 1; 14,101.12 16,126.76 CD3 -106L1 MWD (CD3- 106L1) MWD +IFR- AK- CAZ -SC MWD +IFR AK CAZ SCC 2/27/2010 1; Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/S +E/ -W Northing Easting DLS Section (ft) ( °) (1 (ft) (ft) (ft) (ft) (ft) (ft) ( °1100•1 (ft) Survey Tool Name 28.00 0.00 0.00 28.00 -13.40 0.00 0.00 6,003,852.22 388,266.46 0.00 0.00 UNDEFINED 100.00 0.09 91.70 100.00 58.60 0.00 0.06 6,003,852.22 388,266.52 0.12 -0.02 CB- GYRO -SS (1) 172.00 0.10 85.66 172.00 130.60 0.00 0.18 6,003,852.22 388,266.63 0.02 -0.07 CB- GYRO -SS (1) 266.00 0.52 153.51 266.00 224.60 -0.37 0.45 6,003,851.84 388,266.90 0.52 -0.52 CB- GYRO -SS (1) 358.00 1.26 157.38 357.99 316.59 -1.68 1.02 6,003,850.52 388,267.46 0.81 -1.95 CB- GYRO -SS (1) 450.00 2.43 155.35 449.94 408.54 -4.39 2.23 6,003,847.80 388,268.62 1.27 -4.91 CB- GYRO -SS (1) 542.00 5.53 143.02 541.71 500.31 -9.70 5.71 6,003,842.43 388,272.02 3.48 -11.16 CB- GYRO -SS (1) 632.00 9.69 136.86 630.89 589.49 -18.70 13.50 6,003,833.32 388,279.67 4.70 -22.49 CB- GYRO -SS (1) 700.00 10.86 132.28 697.80 656.40 -27.18 22.15 6,003,824.71 388,288.20 2.10 -33.68 CB- GYRO -SS (1) 3/9/2010 2:27:31 PM Page 2 COMPASS 2003.16 Build 69 • 0 • ConocoPhillips (Alaska) Inc. Definitive Survey Report . Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well CD3 -106 Project: Western North Slope TVD Reference: Plan: CD3 -106 (28 +13.4) @ 41.40ft (Doyon 141) Site: CD3 Fiord Pad MD Reference: Plan: CD3 -106 (28 +13.4) @ 41.40ft (Doyon 141) Well: CD3 - 106 North Reference: True Wellbore: CD3 - 106L1 Survey Calculation Method: Minimum Curvature Design: CD3 - 106L1 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/ -W Northing Easting DLS Section (ft) ( (1 (ft) (ft) (ft) (ft) (ft) (ft) moo') (ft) Survey Tool Name 750.00 11.24 132.10 746.88 705.48 -33.62 29.25 6,003,818.17 388,295.20 0.76 -42.38 CB- GYRO -SS (1) 817.00 11.73 130.07 812.54 771.14 -42.38 39.31 6,003,809.26 388,305.13 0.95 -54.37 CB- GYRO -SS (1) 856.97 11.96 129.76 851.65 810.25 -47.65 45.60 6,003,803.90 388,311.34 0.60 -61.68 MWD +IFR -AK- CAZ -SC (2) ! 947.77 12.50 114.29 940.42 899.02 -57.71 61.79 6,003,793.60 388,327.38 3.65 -77.27 MWD +IFR -AK- CAZ -SC (2) 1,041.82 10.97 111.57 1,032.50 991.10 -65.19 79.39 6,003,785.86 388,344.86 1.73 -91.03 MWD +IFR -AK- CAZ -SC (2) I 1,133.41 9.54 104.35 1,122.63 1,081.23 -70.27 94.85 6,003,780.54 388,360.24 2.10 - 101.75 MWD +IFR -AK- CAZ -SC (2) 1,226.23 9.99 89.90 1,214.12 1,172.72 -72.16 110.36 6,003,778.42 388,375.72 2.68 - 109.55 MWD +IFR -AK- CAZ -SC (2) 1,318.49 10.82 65.90 1,304.90 1,263.50 -68.61 126.27 6,003,781.73 388,391.68 4.75 - 112.50 MWD +IFR -AK- CAZ -SC (2) 1,411.31 12.29 38.08 1,395.91 1,354.51 -57.27 140.33 6,003,792.86 388,405.91 6.14 - 107.55 MWD +IFR -AK- CAZ -SC (2) 1,503.43 15.71 22.12 1,485.31 1,443.91 -37.98 151.08 6,003,811.98 388,416.94 5.57 -94.00 MWD +IFR -AK- CAZ -SC (2) 1,595.58 18.93 18.08 1,573.27 1,531.87 -12.21 160.42 6,003,837.61 388,426.67 3.73 -73.92 MWD +IFR -AK- CAZ -SC (2) 1,685.77 19.76 9.82 1,658.39 1,616.99 16.73 167.56 6,003,866.43 388,434.24 3.17 -50.08 MWD +IFR -AK- CAZ -SC (2) 1 1,778.68 21.82 2.81 1,745.26 1,703.86 49.46 171.09 6,003,899.10 388,438.25 3.47 -21.33 MWD +IFR -AK- CAZ -SC (2) 1,871.07 25.82 0.26 1,829.76 1,788.36 86.74 172.02 6,003,936.37 388,439.75 4.47 12.63 MWD +IFR -AK- CAZ -SC (2) 1 1,967.53 29.57 1.40 1,915.16 1,873.76 131.56 172.70 6,003,981.16 388,441.09 3.93 53.62 MWD +IFR -AK- CAZ -SC (2) 2,060.74 32.72 1.88 1,994.92 1,953.52 179.74 174.09 6,004,029.32 388,443.20 3.39 97.43 MWD +IFR -AK- CAZ -SC (2) ■ 2,151.94 35.47 2.11 2,070.44 2,029.04 230.83 175.87 6,004,080.37 388,445.75 3.02 143.76 MWD +IFR -AK- CAZ -SC (2) 2,246.73 38.61 1.22 2,146.09 2,104.69 287.89 177.51 6,004,137.40 388,448.25 3.36 195.65 MWD +IFR -AK- CAZ -SC (2) 2,337.37 42.30 0.23 2,215.05 2,173.65 346.69 178.24 6,004,196.17 388,449.85 4.13 249.49 MWD +IFR -AK- CAZ -SC (2) 2,429.24 43.33 0.42 2,282.44 2,241.04 409.13 178.59 6,004,258.59 388,451.14 1.13 306.82 MWD +IFR -AK- CAZ -SC (2) 2,524.10 46.87 359.21 2,349.39 2,307.99 476.31 178.36 6,004,325.76 388,451.91 3.84 368.75 MWD +IFR -AK- CAZ -SC (2) 2,617.44 51.10 357.84 2,410.63 2,369.23 546.69 176.52 6,004,396.16 388,451.12 4.66 434.26 MWD +IFR -AK- CAZ -SC (2) 2,689.44 54.19 356.36 2,454.32 2,412.92 603.84 173.61 6,004,453.34 388,449.07 4.59 488.00 MWD +IFR -AK- CAZ -SC (2) 2,778.23 56.29 355.68 2,504.94 2,463.54 676.60 168.54 6,004,526.16 388,445.09 2.45 556.96 MWD +IFR -AK- CAZ -SC (3) 2,872.19 56.43 354.92 2,556.99 2,515.59 754.56 162.13 6,004,604.21 388,439.85 0.69 631.23 MWD +IFR -AK- CAZ -SC (3) 2,963.08 56.94 355.77 2,606.91 2,565.51 830.27 155.96 6,004,679.99 388,434.82 0.96 703.32 MWD +IFR -AK- CAZ -SC (3) 3,058.46 57.06 355.82 2,658.86 2,617.46 910.04 150.10 6,004,759.83 388,430.15 0.13 779.05 MWD +IFR -AK- CAZ -SC (3) 3,150.52 56.48 356.51 2,709.31 2,667.91 986.88 144.95 6,004,836.73 388,426.15 0.89 851.79 MWD +IFR -AK- CAZ -SC (3) 3,242.73 56.64 356.87 2,760.12 2,718.72 1,063.69 140.51 6,004,913.60 388,422.86 0.37 924.23 MWD +IFR -AK- CAZ -SC (3) 3,336.06 57.29 356.97 2,811.00 2,769.60 1,141.82 136.30 6,004,991.77 388,419.82 0.70 997.79 MWD +IFR -AK- CAZ -SC (3) 3,428.17 57.67 357.02 2,860.52 2,819.12 1,219.38 132.23 6,005,069.38 388,416.91 0.42 1,070.78 MWD +IFR -AK- CAZ -SC (3) 3,521.51 59.46 356.69 2,909.19 2,867.79 1,298.90 127.86 6,005,148.95 388,413.73 1.94 1,145.68 MWD +IFR -AK- CAZ -SC (3) 1 3,613.42 61.39 356.61 2,954.55 2,913.15 1,378.69 123.19 6,005,228.80 388,410.26 2.10 1,220.96 MWD +IFR -AK- CAZ -SC (3) 3,706.81 62.65 356.01 2,998.37 2,956.97 1,460.99 117.88 6,005,311.16 388,406.18 1.46 1,298.79 MWD +IFR -AK- CAZ -SC (3) I 3,799.13 63.29 356.12 3,040.32 2,998.92 1,543.04 112.23 6,005,393.27 388,401.76 0.70 1,376.52 MWD +IFR -AK- CAZ -SC (3) 3,891.87 64.16 355.49 3,081.38 3,039.98 1,625.97 106.15 6,005,476.28 388,396.92 1.12 1,455.24 MWD +IFR -AK- CAZ -SC (3) 3,984.25 64.50 355.43 3,121.40 3,080.00 1,708.97 99.56 6,005,559.36 388,391.58 0.37 1,534.21 MWD +IFR -AK- CAZ -SC (3) 4,076.17 64.71 355.48 3,160.82 3,119.42 1,791.75 92.98 6,005,642.22 388,386.24 0.23 1,612.98 MWD +IFR -AK- CAZ -SC (3) 4,169.32 64.58 355.16 3,200.71 3,159.31 1,875.64 86.11 6,005,726.20 388,380.62 0.34 1,692.89 MWD +IFR -AK- CAZ -SC (3) i 4,261.63 64.56 354.91 3,240.35 3,198.95 1,958.70 78.90 6,005,809.35 388,374.65 0.25 1,772.16 MWD +IFR -AK- CAZ -SC (3) 3/9/2010 2:27:31 PM Page 3 COMPASS 2003.16 Build 69 • • • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well CD3 -106 Project Western North Slope TVD Reference: Plan: CD3 -106 (28 +13.4) @ 41.40ft (Doyon 141) Site: CD3 Fiord Pad MD Reference: Plan: CD3 -106 (28 +13.4) © 41.40ft (Doyon 141) Well: CD3 - 106 North Reference: True Weilbore: CD3 - 106L1 Survey Calculation Method: Minimum Curvature Design: CD3 - 106L1 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Az! TVD TVDSS +N!S +EI -W Northing Easting DLS Section (ft) ( ( (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,353.33 64.64 355.45 3,279.68 3,238.28 2,041.24 71.94 6,005,891.98 388,368.93 0.54 1,850.86 MWD +IFR -AK- CAZ -SC (3) 4,447.11 64.78 355.95 3,319.74 3,278.34 2,125.79 65.58 6,005,976.61 388,363.84 0.50 1,931.18 MWD +IFR -AK- CAZ -SC (3) 4,539.00 64.97 356.31 3,358.76 3,317.36 2,208.80 59.96 6,006,059.68 388,359.47 0.41 2,009.78 MWD +IFR -AK- CAZ -SC (3) 4,632.17 64.85 356.42 3,398.27 3,356.87 2,293.01 54.61 6,006,143.95 388,355.38 0.17 2,089.38 MWD +IFR -AK- CAZ -SC (3) 4,724.77 65.06 356.49 3,437.47 3,396.07 2,376.74 49.43 6,006,227.75 388,351.45 0.24 2,168.49 MWD +IFR -AK- CAZ -SC (3) 4,815.51 64.70 355.97 3,475.99 3,434.59 2,458.72 44.02 6,006,309.79 388,347.27 0.65 2,246.06 MWD +IFR -AK- CAZ -SC (3) 4,909.00 63.97 356.18 3,516.48 3,475.08 2,542.79 38.26 6,006,393.93 388,342.76 0.81 2,325.70 MWD +IFR -AK- CAZ -SC (3) 5,002.03 64.36 355.87 3,557.02 3,515.62 2,626.32 32.45 6,006,477.53 388,338.21 0.52 2,404.86 MWD +IFR -AK- CAZ -SC (3) 5,094.95 64.03 355.32 3,597.47 3,556.07 2,709.72 26.03 6,006,561.02 388,333.04 0.64 2,484.14 MWD +IFR -AK- CAZ -SC (3) 5,188.96 64.69 355.48 3,638.15 3,596.75 2,794.20 19.23 6,006,645.58 388,327.51 0.72 2,564.56 MWD +IFR -AK- CAZ -SC (3) 5,278.07 64.79 355.48 3,676.17 3,634.77 2,874.54 12.88 6,006,726.00 388,322.36 0.11 2,641.00 MWD +IFR -AK- CAZ -SC (3) 5,374.02 64.44 354.73 3,717.31 3,675.91 2,960.91 5.48 6,006,812.46 388,316.26 0.79 2,723.39 MWD +IFR -AK- CAZ -SC (3) 5,461.19 64.76 354.41 3,754.70 3,713.30 3,039.30 -1.97 6,006,890.95 388,309.98 0.49 2,798.46 MWD +IFR -AK- CAZ -SC (3) 5,558.45 64.30 353.85 3,796.52 3,755.12 3,126.65 -10.95 6,006,978.41 388,302.31 0.70 2,882.37 MWD +IFR -AK- CAZ -SC (3) 5,650.93 63.66 353.17 3,837.09 3,795.69 3,209.22 -20.34 6,007,061.11 388,294.15 0.96 2,962.05 MWD +IFR -AK- CAZ -SC (3) 5,744.25 63.39 353.14 3,878.70 3,837.30 3,292.16 -30.30 6,007,144.18 388,285.44 0.29 3,042.28 MWD +IFR -AK- CAZ -SC (3) 5,835.65 63.08 353.73 3,919.86 3,878.46 3,373.23 -39.63 6,007,225.37 388,277.33 0.67 3,120.56 MWD +IFR -AK- CAZ -SC (3) 5,929.30 61.95 353.89 3,963.08 3,921.68 3,455.82 -48.59 6,007,308.09 388,269.61 1.22 3,200.09 MWD +IFR -AK- CAZ -SC (3) 6,021.41 62.08 354.24 4,006.30 3,964.90 3,536.73 -57.00 6,007,389.10 388,262.41 0.36 3,277.84 MWD +IFR -AK- CAZ -SC (3) 6,114.43 62.10 354.13 4,049.84 4,008.44 3,618.50 -65.32 6,007,470.98 388,255.30 0.11 3,356.37 MWD +IFR -AK- CAZ -SC (3) 6,205.96 62.42 354.26 4,092.44 4,051.04 3,699.10 -73.52 6,007,551.69 388,248.32 0.37 3,433.76 MWD +IFR -AK- CAZ -SC (3) 6,300.02 62.99 354.07 4,135.58 4,094.18 3,782.25 -82.02 6,007,634.95 388,241.07 0.63 3,513.63 MWD +IFR -AK- CAZ -SC (3) 6,390.10 63.07 353.99 4,176.43 4,135.03 3,862.10 -90.37 6,007,714.91 388,233.91 0.12 3,590.39 MWD +IFR -AK- CAZ -SC (3) 6,484.39 62.87 354.22 4,219.28 4,177.88 3,945.65 -98.99 6,007,798.57 388,226.54 0.30 3,670.67 MWD +IFR -AK- CAZ -SC (3) 6,578.04 62.72 355.17 4,262.10 4,220.70 4,028.58 - 106.69 6,007,881.60 388,220.08 0.92 3,750.01 MWD +IFR -AK- CAZ -SC (3) 6,671.13 62.71 354.28 4,304.77 4,263.37 4,110.96 - 114.30 6,007,964.08 388,213.71 0.85 3,828.82 MWD +IFR -AK- CAZ -SC (3) 6,763.82 62.72 354.44 4,347.26 4,305.86 4,192.94 - 122.39 6,008,046.16 388,206.84 0.15 3,907.44 MWD +IFR -AK- CAZ -SC (3) 6,856.31 62.44 354.60 4,389.85 4,348.45 4,274.66 - 130.24 6,008,127.98 388,200.23 0.34 3,985.73 MWD +IFR -AK- CAZ -SC (3) 6,948.86 62.15 355.34 4,432.88 4,391.48 4,356.28 - 137.42 6,008,209.70 388,194.26 0.77 4,063.68 MWD +IFR -AK- CAZ -SC (3) 7,046.39 62.30 355.17 4,478.33 4,436.93 4,442.28 - 144.56 6,008,295.78 388,188.42 0.22 4,145.63 MWD +IFR -AK- CAZ -SC (3) 7,131.82 62.42 355.13 4,517.96 4,476.56 4,517.69 - 150.96 6,008,371.28 388,183.15 0.15 4,217.54 MWD +IFR -AK- CAZ -SC (3) 7,226.26 63.12 354.87 4,561.18 4,519.78 4,601.35 - 158.28 6,008,455.02 388,177.08 0.78 4,297.40 MWD +IFR -AK- CAZ -SC (3) 7,319.10 63.13 355.45 4,603.14 4,561.74 4,683.86 - 165.26 6,008,537.63 388,171.33 0.56 4,376.09 MWD +IFR -AK- CAZ -SC (3) 7,411.42 62.76 356.41 4,645.14 4,603.74 4,765.87 - 171.10 6,008,619.71 388,166.72 1.01 4,453.86 MWD +IFR -AK- CAZ -SC (3) 7,502.09 62.79 355.43 4,686.62 4,645.22 4,846.29 - 176.84 6,008,700.20 388,162.19 0.96 4,530.13 MWD +IFR -AK- CAZ -SC (3) 7,596.82 63.20 356.51 4,729.63 4,688.23 4,930.48 - 182.77 6,008,784.46 388,157.52 1.10 4,609.94 MWD +IFR -AK- CAZ -SC (3) 7,689.55 63.46 357.78 4,771.25 4,729.85 5,013.24 - 186.89 6,008,867.26 388,154.63 1.26 4,687.74 MWD +IFR -AK- CAZ -SC (3) 7,782.65 63.12 357.31 4,813.10 4,771.70 5,096.33 - 190.45 6,008,950.39 388,152.32 0.58 4,765.61 MWD +IFR -AK- CAZ -SC (3) 7,875.23 63.12 356.61 4,854.96 4,813.56 5,178.79 - 194.83 6,009,032.90 388,149.17 0.67 4,843.23 MWD +IFR -AK- CAZ -SC (3) 7,967.79 63.12 356.22 4,896.81 4,855.41 5,261.19 - 200.00 6,009,115.36 388,145.24 0.38 4,921.09 MWD +IFR -AK- CAZ -SC (3) 3/9/2010 2:27:31 PM Page 4 COMPASS 2003.16 Build 69 • • • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well CD3 -106 Project: Western North Slope TVD Reference: Plan: CD3 -106 (28 +13.4) @ 41.40ft (Doyon 141) Site: CD3 Fiord Pad MD Reference: Plan: CD3 -106 (28 +13.4) © 41.40ft ( Doyon 141) Well: CD3 - 106 North Reference: True Wellbore: CD3 - 106L1 Survey Calculation Method: Minimum Curvature Design: CD3 - 106L1 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N!-S +E1 -W Northing Easting DLS Section (ft) ( ( (ft) (ft) (ft) (ft) (ft) (ft) mow) (ft) Survey Tool Name 8,060.23 62.93 356.08 4,938.74 4,897.34 5,343.38 - 205.53 6,009,197.62 388,140.94 0.25 4,998.92 MWD +IFR -AK- CAZ -SC (3) 8,153.24 62.51 355.46 4,981.37 4,939.97 5,425.82 - 211.62 6,009,280.14 388,136.08 0.74 5,077.18 MWD +IFR -AK- CAZ -SC (3) 8,245.51 62.72 355.10 5,023.81 4,982.41 5,507.47 - 218.37 6,009,361.87 388,130.56 0.41 5,154.98 MWD +IFR -AK- CAZ -SC (3) 8,338.14 62.39 355.71 5,066.50 5,025.10 5,589.41 - 224.95 6,009,443.89 388,125.21 0.68 5,232.98 MWD +IFR -AK- CAZ -SC (3) 8,430.56 63.06 356.58 5,108.86 5,067.46 5,671.37 - 230.47 6,009,525.92 388,120.91 1.11 5,310.58 MWD +IFR -AK- CAZ -SC (3) 8,523.68 63.07 355.68 5,151.04 5,109.64 5,754.20 - 236.08 6,009,608.81 388,116.55 0.86 5,389.01 MWD +IFR -AK- CAZ -SC (3) 8,612.41 63.05 354.83 5,191.24 5,149.84 5,833.03 - 242.62 6,009,687.72 388,111.19 0.85 5,464.13 MWD +IFR -AK- CAZ -SC (3) 8,708.02 62.56 354.80 5,234.93 5,193.53 5,917.72 - 250.30 6,009,772.52 388,104.77 0.51 5,545.09 MWD +IFR -AK- CAZ -SC (3) 8,800.18 62.10 355.66 5,277.73 5,236.33 5,999.06 - 257.09 6,009,853.94 388,099.20 0.97 5,622.62 MWD +IFR -AK- CAZ -SC (3) 8,893.96 62.70 354.91 5,321.18 5,279.78 6,081.88 - 263.93 6,009,936.85 388,093.61 0.95 5,701.53 MWD +IFR -AK- CAZ -SC (3) 8,986.60 63.95 355.54 5,362.77 5,321.37 6,164.37 - 270.81 6,010,019.43 388,087.96 1.48 5,780.15 MWD +IFR -AK- CAZ -SC (3) 9,077.51 63.61 355.32 5,402.93 5,361.53 6,245.67 - 277.31 6,010,100.80 388,082.68 0.43 5,857.52 MWD +IFR -AK- CAZ -SC (3) 9,167.85 62.98 355.05 5,443.53 5,402.13 6,326.09 - 284.09 6,010,181.31 388,077.11 0.75 5,934.20 MWD +IFR -AK- CAZ -SC (3) 9,263.58 62.92 353.74 5,487.07 5,445.67 6,410.94 - 292.41 6,010,266.26 388,070.05 1.22 6,015.55 MWD +IFR -AK- CAZ -SC (3) 9,357.57 63.19 357.83 5,529.67 5,488.27 6,494.47 - 298.56 6,010,349.87 388,065.15 3.89 6,094.85 MWD +IFR -AK- CAZ -SC (3) 9,448.73 62.31 357.40 5,571.41 5,530.01 6,575.44 - 301.94 6,010,430.88 388,062.99 1.05 6,170.70 MWD +IFR -AK- CAZ -SC (3) 9,540.67 62.02 355.72 5,614.34 5,572.94 6,656.59 - 306.81 6,010,512.09 388,059.33 1.65 6,247.31 MWD +IFR -AK- CAZ -SC (3) 9,633.19 61.68 355.88 5,657.99 5,616.59 6,737.95 - 312.79 6,010,593.52 388,054.58 0.40 6,324.53 MWD +IFR -AK- CAZ -SC (3) 9,727.62 63.35 357.34 5,701.58 5,660.18 6,821.57 - 317.73 6,010,677.20 388,050.89 2.24 6,403.44 MWD +IFR -AK- CAZ -SC (3) 9,818.41 63.89 356.45 5,741.92 5,700.52 6,902.79 - 322.14 6,010,758.46 388,047.69 1.06 6,479.92 MWD +IFR -AK- CAZ -SC (3) 9,911.69 64.56 356.41 5,782.48 5,741.08 6,986.62 - 327.37 6,010,842.36 388,043.72 0.72 6,559.13 MWD +IFR -AK- CAZ -SC (3) 10,004.31 64.28 356.31 5,822.47 5,781.07 7,070.00 - 332.67 6,010,925.79 388,039.66 0.32 6,637.95 MWD +IFR -AK- CAZ -SC (3) 10,097.15 63.47 356.40 5,863.35 5,821.95 7,153.18 - 337.97 6,011,009.04 388,035.61 0.88 6,716.59 MWD +IFR -AK- CAZ -SC (3) 10,189.96 63.33 355.86 5,904.90 5,863.50 7,235.98 - 343.57 6,011,091.91 388,031.25 0.54 6,795.00 MWD +IFR -AK- CAZ -SC (3) 10,282.44 62.65 355.55 5,946.90 5,905.50 7,318.14 - 349.74 6,011,174.14 388,026.31 0.79 6,873.04 MWD +IFR -AK- CAZ -SC (3) 10,374.60 62.76 354.67 5,989.17 5,947.77 7,399.74 - 356.73 6,011,255.83 388,020.55 0.86 6,950.88 MWD +IFR -AK- CAZ -SC (3) 10,468.62 61.75 354.42 6,032.94 5,991.54 7,482.57 - 364.63 6,011,338.77 388,013.89 1.10 7,030.22 MWD +IFR -AK- CAZ -SC (3) 10,559.66 62.25 353.91 6,075.68 6,034.28 7,562.54 - 372.81 6,011,418.84 388,006.91 0.74 7,107.02 MWD +IFR -AK- CAZ -SC (3) 10,648.87 61.94 355.07 6,117.43 6,076.03 7,641.01 - 380.38 6,011,497.41 388,000.52 1.20 7,182.21 MWD +IFR -AK- CAZ -SC (3) 10,745.29 61.31 353.67 6,163.25 6,121.85 7,725.43 - 388.70 6,011,581.94 387,993.46 1.43 7,263.17 MWD +IFR -AK- CAZ -SC (3) 10,837.59 62.78 353.45 6,206.52 6,165.12 7,806.44 - 397.84 6,011,663.07 387,985.53 1.61 7,341.32 MWD +IFR -AK- CAZ -SC (3) 10,930.09 62.95 354.31 6,248.71 6,207.31 7,888.29 - 406.62 6,011,745.04 387,977.98 0.85 7,420.09 MWD +IFR -AK- CAZ -SC (3) 11,022.80 63.39 355.91 6,290.55 6,249.15 7,970.72 - 413.67 6,011,827.55 387,972.17 1.61 7,498.72 MWD +IFR -AK- CAZ -SC (3) 11,115.40 63.54 355.87 6,331.92 6,290.52 8,053.35 - 419.61 6,011,910.26 387,967.47 0.17 7,577.10 MWD +IFR -AK- CAZ -SC (3) 11,207.14 63.48 355.60 6,372.84 6,331.44 8,135.23 - 425.71 6,011,992.21 387,962.59 0.27 7,654.86 MWD +IFR -AK- CAZ -SC (3) 11,301.71 62.97 356.05 6,415.45 6,374.05 8,219.44 - 431.86 6,012,076.49 387,957.70 0.69 7,734.77 MWD +IFR -AK- CAZ -SC (3) 11,393.55 62.56 356.09 6,457.48 6,416.08 8,300.90 - 437.46 6,012,158.03 387,953.33 0.45 7,811.95 MWD +IFR -AK- CAZ -SC (3) 11,487.08 61.82 355.76 6,501.11 6,459.71 8,383.42 - 443.33 6,012,240.62 387,948.68 0.85 7,890.20 MWD +IFR -AK- CAZ -SC (3) 11,578.40 61.52 355.81 6,544.45 6,503.05 8,463.59 - 449.24 6,012,320.85 387,943.98 0.33 7,966.30 MWD +IFR -AK- CAZ -SC (3) 11,670.28 61.22 355.47 6,588.47 6,547.07 8,544.00 - 455.37 6,012,401.34 387,939.05 0.46 8,042.72 MWD +IFR -AK- CAZ -SC (3) 3/9/2010 2.27:31PM Page 5 COMPASS 2003.16 Build 69 • • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well CD3 -106 Project Western North Slope TVD Reference: Plan: CD3 -106 (28 +13.4) @ 41.40ft(Doyon 141) Site: CD3 Fiord Pad MD Reference: Plan: CD3 -106 (28 +13.4) @ 41.40ft (Doyon 141) Well: CD3 - 106 North Reference: True Wellbore: CD3 - 106L1 Survey Calculation Method: Minimum Curvature Design: CD3 - 106L1 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Az' TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) l (ft) (ft) (ft) (ft) (ft) (ft) (1100') (ft) Survey Tool Name 11,763.88 62.28 354.32 6,632.77 6,591.37 8,626.12 - 462.71 6,012,483.56 387,932.94 1.57 8,121.18 MWD +IFR -AK- CAZ -SC (3) 11,857.55 64.48 355.13 6,674.74 6,633.34 8,709.50 - 470.41 6,012,567.03 387,926.50 2.47 8,200.94 MWD +IFR -AK- CAZ -SC (3) 11,949.16 66.61 354.72 6,712.67 6,671.27 8,792.56 - 477.78 6,012,650.19 387,920.36 2.36 8,280.28 MWD +IFR -AK- CAZ -SC (3) 12,041.44 68.92 353.09 6,747.58 6,706.18 8,877.48 - 486.86 6,012,735.23 387,912.56 2.99 8,362.00 MWD +IFR -AK- CAZ -SC (3) 12,134.50 71.48 351.72 6,779.11 6,737.71 8,964.26 - 498.44 6,012,822.17 387,902.28 3.08 8,446.40 MWD +IFR -AK- CAZ -SC (3) 12,226.09 74.65 349.92 6,805.78 6,764.38 9,050.74 - 512.43 6,012,908.84 387,889.59 3.94 8,531.47 MWD +IFR -AK- CAZ -SC (3) 12,319.20 75.61 347.09 6,829.68 6,788.28 9,138.92 - 530.37 6,012,997.26 387,872.98 3.11 8,619.65 MWD +IFR -AK- CAZ -SC (3) 12,413.56 76.82 345.83 6,852.17 6,810.77 9,228.01 - 551.82 6,013,086.66 387,852.86 1.82 8,710.04 MWD +IFR -AK- CAZ -SC (3) 12,504.51 78.52 343.17 6,871.59 6,830.19 9,313.61 - 575.57 6,013,172.60 387,830.39 3.41 8,798.12 MWD +IFR -AK- CAZ -SC (3) 12,597.90 80.77 340.21 6,888.38 6,846.98 9,400.81 - 604.44 6,013,260.22 387,802.84 3.94 8,889.67 MWD +IFR -AK- CAZ -SC (3) 12,692.33 80.65 335.52 6,903.63 6,862.23 9,487.11 - 639.54 6,013,347.02 387,769.04 4.90 8,982.82 MWD +IFR -AK- CAZ -SC (3) 12,785.08 80.34 331.73 6,918.95 6,877.55 9,569.05 - 680.17 6,013,429.56 387,729.64 4.04 9,074.12 MWD +IFR -AK- CAZ -SC (3) 12,850.59 81.51 329.93 6,929.29 6,887.89 9,625.53 - 711.70 6,013,486.50 387,698.96 3.25 9,138.43 MWD +IFR -AK- CAZ -SC (4) 12,945.35 84.35 329.34 6,940.95 6,899.55 9,706.66 - 759.23 6,013,568.32 387,652.65 3.06 9,231.68 MWD +IFR -AK- CAZ -SC (4) 12,971.87 85.04 328.86 6,943.40 6,902.00 9,729.32 - 772.79 6,013,591.18 387,639.44 3.17 9,257.84 MWD +IFR -AK- CAZ -SC (4) 13,065.67 86.84 327.27 6,950.04 6,908.64 9,808.72 - 822.28 6,013,671.30 387,591.14 2.56 9,350.26 MWD +IFR -AK- CAZ -SC (5) 13,159.06 88.14 325.82 6,954.13 6,912.73 9,886.56 - 873.71 6,013,749.89 387,540.89 2.08 9,442.01 MWD +IFR -AK- CAZ -SC (5) 13,253.49 90.24 327.35 6,955.47 6,914.07 9,965.36 - 925.71 6,013,829.46 387,490.08 2.75 9,534.87 MWD +IFR -AK- CAZ -SC (5) r 13,270.00 90.79 327.49 6,955.32 6,913.92 9,979.27 - 934.60 6,013,843.51 387,481.40 3.44 9,551.15 MWD +IFR -AK- CAZ -SC (6) 13,348.45 88.57 328.47 6,955.76 6,914.36 10,045.78 - 976.19 6,013,910.62 387,440.82 3.09 9,628.62 MWD +IFR -AK- CAZ -SC (6) 13,443.24 88.51 328.67 6,958.17 6,916.77 10,126.64 - 1,025.60 6,013,992.20 387,392.62 0.22 9,722.35 MWD +IFR -AK- CAZ -SC (6) 13,536.61 90.05 328.71 6,959.35 6,917.95 10,206.40 - 1,074.12 6,014,072.68 387,345.31 1.65 9,814.73 MWD +IFR -AK- CAZ -SC (6) 13,630.36 93.02 329.59 6,956.84 6,915.44 10,286.85 - 1,122.17 6,014,153.83 387,298.47 3.30 9,907.56 MWD +IFR -AK- CAZ -SC (6) 13,724.63 95.06 330.02 6,950.19 6,908.79 10,368.12 - 1,169.46 6,014,235.79 387,252.40 2.21 10,000.85 MWD +IFR -AK- CAZ -SC (6) 13,816.66 94.57 330.49 6,942.47 6,901.07 10,447.74 - 1,214.96 6,014,316.08 387,208.11 0.74 10,091.92 MWD +IFR -AK- CAZ -SC (6) 13,913.10 94.39 331.18 6,934.94 6,893.54 10,531.70 - 1,261.81 6,014,400.72 387,162.52 0.74 10,187.51 MWD +IFR -AK- CAZ -SC (6) 14,007.84 93.33 332.43 6,928.56 6,887.16 10,615.00 - 1,306.47 6,014,484.68 387,119.12 1.73 10,281.64 MWD +IFR -AK- CAZ -SC (6) 14,101.12 93.51 332.98 6,922.99 6,881.59 10,697.75 - 1,349.17 6,014,568.04 387,077.66 0.62 10,374.49 MWD +IFR -AK- CAZ -SC (7) 14,194.92 92.77 334.10 6,917.86 6,876.46 10,781.60 - 1,390.90 6,014,652.50 387,037.20 1.43 10,467.98 MWD +IFR -AK- CAZ -SC (7) 14,288.63 92.83 336.60 6,913.28 6,871.88 10,866.66 - 1,429.94 6,014,738.13 386,999.44 2.67 10,561.53 MWD +IFR -AK- CAZ -SC (7) ' 14,382.12 93.20 338.65 6,908.36 6,866.96 10,952.99 - 1,465.47 6,014,824.97 386,965.20 2.23 10,654.88 MWD +IFR -AK- CAZ -SC (7) 14,476.64 91.72 338.72 6,904.30 6,862.90 11,040.96 - 1,499.80 6,014,913.44 386,932.20 1.57 10,749.27 MWD +IFR -AK- CAZ -SC (7) 14,570.91 90.79 337.86 6,902.24 6,860.84 11,128.52 - 1,534.66 6,015,001.50 386,898.66 1.34 10,843.49 MWD +IFR -AK- CAZ -SC (7) 14,664.60 91.16 335.48 6,900.64 6,859.24 11,214.53 - 1,571.76 6,015,088.05 386,862.86 2.57 10,937.16 MWD +IFR -AK- CAZ -SC (7) 14,759.78 91.97 334.46 6,898.04 6,856.64 11,300.74 - 1,612.01 6,015,174.84 386,823.90 1.37 11,032.24 MWD +IFR -AK- CAZ -SC (7) 14,853.09 91.85 336.42 6,894.93 6,853.53 11,385.55 - 1,650.77 6,015,260.22 386,786.42 2.10 11,125.46 MWD +IFR -AK- CAZ -SC (7) 14,947.80 91.54 336.39 6,892.13 6,850.73 11,472.31 - 1,688.66 6,015,347.53 386,749.83 0.33 11,220.13 MWD +IFR -AK- CAZ -SC (7) 15,042.13 90.73 336.23 6,890.26 6,848.86 11,558.67 - 1,726.56 6,015,434.44 386,713.24 0.88 11,314.43 MWD +IFR -AK- CAZ -SC (7) 15,133.31 91.47 335.74 6,888.51 6,847.11 11,641.94 - 1,763.66 6,015,518.25 386,677.39 0.97 11,405.58 MWD +IFR -AK- CAZ -SC (7) 15,229.82 90.54 337.31 6,886.82 6,845.42 11,730.45 - 1,802.09 6,015,607.31 386,640.29 1.89 11,502.07 MWD +IFR -AK- CAZ -SC (7) 3/9/2010 2:27:31 PM Page 6 COMPASS 2003.16 Build 69 • • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well CD3 -106 Project Western North Slope TVD Reference: Plan: CD3 -106 (28 +13.4) © 41.40ft (Doyon 141) Site: CD3 Fiord Pad MD Reference: Plan: CD3 -106 (28 +13.4) © 41.40ft (Doyon 141) Well: CD3 -106 North Reference: True Wellbore: CD3 - 106L1 Survey Calculation Method: Minimum Curvature Design: CD3 - 106L1 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/ -W Northing Easting DLS Section (ft) ( °) (1 (ft) (ft) (ft) (ft) (f() (i() ( °1100') (ft) Survey Tool Name 15,322.05 91.91 342.51 6,884.85 6,843.45 11,817.01 - 1,833.76 6,015,694.34 386,609.93 5.83 11,594.12 MWD +IFR -AK- CAZ -SC (7) 15,367.98 90.05 342.84 6,884.06 6,842.66 11,860.85 - 1,847.43 6,015,738.37 386,596.91 4.11 11,639.82 MWD +IFR -AK- CAZ -SC (7) 15,416.97 90.48 343.61 6,883.83 6,842.43 11,907.75 - 1,861.57 6,015,785.48 386,583.48 1.80 11,688.52 MWD +IFR -AK- CAZ -SC (7) 15,510.52 93.08 342.18 6,880.93 6,839.53 11,997.11 - 1,889.07 6,015,875.23 386,557.32 3.17 11,781.52 MWD +IFR -AK- CAZ -SC (7) 15,602.84 92.64 341.07 6,876.32 6,834.92 12,084.61 - 1,918.13 6,015,963.15 386,529.57 1.29 11,873.42 MWD +IFR -AK- CAZ -SC (7) 15,698.49 92.65 339.14 6,871.91 6,830.51 12,174.46 - 1,950.65 6,016,053.46 386,498.41 2.02 11,968.82 MWD +IFR -AK- CAZ -SC (7) 15,791.20 91.29 336.63 6,868.72 6,827.32 12,260.29 - 1,985.53 6,016,139.79 386,464.82 3.08 12,061.46 MWD +IFR -AK- CAZ -SC (7) 15,884.47 91.22 335.58 6,866.68 6,825.28 12,345.54 - 2,023.30 6,016,225.60 386,428.33 1.13 12,154.69 MWD +IFR -AK- CAZ -SC (7) 15,979.36 92.09 335.30 6,863.94 6,822.54 12,431.81 - 2,062.72 6,016,312.44 386,390.21 0.96 12,249.51 MWD +IFR -AK- CAZ -SC (7) 16,075.09 93.52 335.65 6,859.25 6,817.85 12,518.79 - 2,102.41 6,016,400.00 386,351.83 1.54 12,345.09 MWD +IFR -AK- CAZ -SC (7) 16,126.76 96.06 337.71 6,854.94 6,813.54 12,566.07 - 2,122.79 6,016,447.57 386,332.16 6.32 12,396.57 MWD +IFR -AK- CAZ -SC (7) 16,193.00 96.06 337.71 6,847.94 6,806.54 12,627.02 - 2,147.77 6,016,508.88 386,308.09 0.00 12,462.43 PROJECTED to TD 3/9/2010 2:27:31 PM Page 7 COMPASS 2003.16 Build 69 SEAN PARNELL, GOVERNOR ALASKA. OIL ` GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION II COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Mr. G.L. Alvord CPAI Drilling Manager ConocoPhillips Alaska Inc. P.O. Box 100360 Anchorage, Alaska 99510 -0360 Re: Colville River Field, Fiord Oil Pool, CD3 -106L1 ConocoPhillips Alaska Inc. Permit No: 210 -002 Surface Location: 3921' FNL, 777' FEL, SEC. 5, T12N, R5E Bottomhole Location: 1642' FNL, 330' FEL, SEC. 30, T13N, R5E Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well Colville River Unit CD3 -106, Permit No. 2100010, API No. 50 -103- 20611- 00 -00. Production should continue to be reported as a function of the original API number stated above. 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, I 7 Daniel T. Seamount, Jr. Chair DATED this O day of January, 2010 cc: Department of Fish & Game, Habitat Section w/o encl. (via e -mail) Department of Environmental Conservation w/o encl. (via e -mail) F i , . :'tV r STATE OF ALASKA " ALOIA OIL AND GAS CONSERVATION COMM ON 03 PERMIT TO DRILL 20 AAC 25.005 F t,;s, ;: C ;4„ CQmrlSSkrft la. Type of Work: 1b. Proposed Well Class: Development - Oil 0 ' Service - Winj ❑ Single Zone 0 lc. Specify if:weli is prnppsed for: Drill 0 ' Redrill ❑ Stratigraphic Test ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Re -entry ❑ Exploratory ❑ Service - WAG ❑ Service - Disp ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket 0 Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc Bond No. 59 -52 -180 • CD3 -106L1 ` 3. Address: 6. Proposed Depth: 12. Field /Pool(s): P.O. Box 100360 Anchorage, AK 99510 -0360 MD: 16,417' • TVD: 6,809' • Colville River Field 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Fiord Oil Pool • Surface: 3921FNL, 777FEL, Sec 5, T12N, R5E • ADL 364470 ADL 364471 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 359FSL, 1179FWL, Sec 29, T13N, R5E ALK 380077 1/15/2010 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 1642FNL, 330FEL, Sec30, T13N, R5E • 2560 0.7 miles to AVCG boundary 4b. Location of Well (State Base Plane Coordinates - NAD,27): 10. KB Elevation above MSL: i79 7 4 f feet 15. Distance to Nearest Well Open Surface: x - 1328298 / y- _609359$" Zone 4 GL Elevation above MSL: / ? 13.4 feet to Same Pool: 135' to CD3 -109 3c -% �c>• 6L)c.3ESZ. -- , ' ` s ' (` at15,350'MD 16. Deviated wells: /.3�? Kickoff depth: 1 3,52 eet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) s'' t•y�U Maximum Hole Angle: ,(b 91 degrees' Downhole: 3,574 • Surface: 2,886 , 18. Casing Program: Specifications f' ' Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 62.5# H -40 Welded 80 28 28 108 • 108 Pre- installed 12 -1/4" 9 -5/8" 40# L -80 BTC 2712 28 28 2740 . 2500 . 480 sx AS Litelll, 240 sx 15.8 "G" 8 -3/4" 7" 26# L -80 BTCM 12760 26 26 12786 6924 - 230 sx 15.8 "G ". 2nd stage 290 sx "G" 6 -1/8" 4 -1/2" 12.6# L -80 SLHT 3091 13326 6954 16417 6809 OH 3 -1/2" 9.3# L -80 EUE 12476 24 24 12500 6876 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): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor /Structural - Surface .... a,. • '{ KK4 . Intermediate Production ' ' ,. ,r _`F xct . Liner . " Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program 0 Time v. Depth Plot ❑ Shallow Hazard Analysis 0 Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Printed Name G.L. Alvord Title CPA! Drilling Manager Signature A,04..„( ,, Phone 265120 Date 1/4/2010 Commission Use Only Permit to API Number � / / Permit Appr al See cover letter for other Number: ,1 k--- " ( --' ( -- ) - 50- lZ? _ 6•t-'' e s / 1 � -DeD Date: / 'Q /D requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coal ed methane, gas hydrates, or gas contained in shales: L '' Other: $ 3 500 p s,- Bo /' Ts 7 Samples req'd: Yes ❑ No [/ Mud log req'd: Yes ❑ No 2/ �-- H measures: Yes ❑ No °' Directional svy req'd: Yes "No ❑ * 2 Soo P sz J�h+. I >= s 4 6, - r / _ ' APPROVED BY THE COMMISSION B J / D ATE: - / , COMMISSIONER ` , (.6- /c) ..� Form 10 - 401 (Revised 7/2009) This permit is valid for 24 months from the date of approval (20 AAC 25.005(g)) Submit in Du uplica t , J � lS.,Z, • • Procedure Operations in normal font are for CD3 -106 and are shown here for convenience: 1. Move on Doyon 141. 2. Rig up riser, dewater cellar as needed. 3. Drill 12 -1/4" 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 3000 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 Nechelik reservoir. (GR/RES /PWD /Dens /Neut). 10. Run and cement 7" casing as per program. Perform a leak off test down the 9 -5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. . If needed, a second stage cement job will be pumped to isolate the K2 (Qannik) formation. 11. Freeze protect the casing annulus to surface 12. BOPE test to 3500 psi. 13. PU 6 -1/8 drilling BHA. RIH and test 7" casing to 3,500 psi. 14. Drill out 7" shoe track. Drill 20' of new hole. Perform formation integrity test. 15. Displace to Flo -Thru drilling fluid 16. Drill 6 -1/8" horizontal section to well TD (LWD Program: GR/RES /PWD). 17. Circulate the hole clean and pull out of hole. 18. If any portion of the horizontal hole is out of zone, RU and run 4 -1/2 ", 12.6 #, L -80 lower completion with slotted /blank liner. This liner will be dropped off in the lateral and not tied back to the tubing. The following operations in bold are procedures for CD3 -106L1 ✓ 19. PU 6 -1/8" Drilling BHA and RIH to CD3106L1 KOP. • 20. Low side open hole sidetrack at 13,326' MD and drill to CD3 -106L1 TD. P-ri> 21. If any portion of the horizontal hole is out of zone, RU and run 4 -1/2 ", 12.6 #, L -80 lower completion with slotted /blank liner. This liner will be run with a Baker SBE, Flexlock liner hanger, and ZXP liner top packer. 22. Run 3 - 9.3 #, L -80 tubing upper completion with SSSV, gas lift mandrels, XN landing nipple, and seal bore - assembly. Sting in, space out and land hanger. + V yr« r , • • 23. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. ' 24. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 25. Circulate tubing to diesel and install freeze protection in the annulus. 26. Set BPV and secure well. Move rig off. • • Completion Schematic ConocoPhillips Alaska CD3- 106/106L1 Nechelik Producer Updated - 01/2/2009 Sperry Well plans / 16° Conductor to 108' CD3- 106wp09 CD3- 106L1wp10 Upper Completion MD ND 1) Tubing Hanger 24' 24' 2) 4 -1/2 ", 12.6 # /ft, IBT -Mod Tubing (2jts) 3) Crossover 4 -1/2" x 3 -1/2" 4) 3 -1/2" Camco TRMAXX -5E SSSV (2.812" ID) 2,200' 2,010' 9- 5/8 "40ppf L-80 BTC 5) 3 -1/2 ", 9.3 # /ft, EUE -Mod Tubing Surface Casing 6) 3 -1/2" Camco KBMG -GLM w/ DV 4,678' 3,400' at 2,739' MD / 2,500' TVD Cemented to Surface 7) 3 -1/2 ", 9.3 # /ft, EUE -Mod Tubing 8) 3 -1/2" Camco KBMG -GLM w/ DV 9,497' 5,600' GL 9) 3 -1/2 ", 9.3 # /ft, EUE -Mod Tubing 10) 3 -1/2" Camco KBMG GLM w/ DCK2 Shear 12,420' 6,858' 11) 3 -1/2 ", 9.3 # /ft, EUE -Mod Tubing (2 jts) 3-1/2" 9.3 ppf L -80 EUE Tubing 12) 3 -1/2 ", "XN" Nipple 12,460' 6,867' 13) 3-W Baker Casing Seal Assembly TOC = 5,700 Lower Completion MD ND Oannik Interval Top 0/- 6,265' MD / 4,124' TVD Base + /_6,300'MD /4,140'TVD 1) Baker 7 "X 5" ZXP Liner Top Packer 12,500' 6,876' 7" X 5" Flexlock liner hanger 20' Seal Bore Extension Stage Collar 0 ] +/- 6,800' MD / 4,368' TVD XO Sub 5" BTC box by 4 -'/2" SLHT pin 2) 4-%" 12.6 #, L -80, SLHT, Blank/Slotted Liner GL CD3 -106 7" 26 ppf L -80 BTC -M Production Casing 6,874' TVD at 12,786' = 6,924' TVD @ +/- 83.0° /5, 4 -Y" 12 68, L -80, SLHT, Slotted Liner TOC @ 0/- 11,700' MD / 6,762' TVD * ^' 1 Top of Nechelik- 7' MD 12,876' MD / 6,934' TVD 6,809' TVD - ,11 L1 Kick Off Depth: / 13,326' MD 6,954' TVD ORG1NAL • DRILLING FLUID PROGRAM Production Hole Section — 6 1/8" Density 10 ppg PV 10 —15 YP 25 — 30 Funnel Viscosity Initial Gels 10 — 15 10 minute gels 12 - 20 API Filtrate HPHT Fluid Loss at 160 12 - 14 cc /30 min PH 9.0 -9.5 KCL 6 % Production Hole Section : The CD3 -106L1 horizontal interval will be drilled with a M -I Flo -Thru drill -in fluid. The base fluid will consist of 3% KCI, with ± 30PPB calcium carbonate bridging material to minimize formation damage. Flowzan Polymer and THRUTROL starch will be used for viscosity and fluid loss control respectively. F a l f :t `4 • • PRESSURE INFORMATION (per 20 ACC 25.005 ( c ) (3,4) and as required in 20 ACC 25.035 (d) (2)) The table below shows data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Setting Fracture Pore Casing Size Depth Gradient pressure ASP Drilling (in) MD /TVD(ft) (Ibs. / gal) (psi) (psi) 16 108 / 108 10.9 52 50 9 -5/8" 2,739 / 2,500 14.5 1,090 1,635 7" 12,786 / 6,924 16.0 3,492 2,886 N/A 16,417 / 6,809 16.0 3,540 - N/A • NOTE: The Doyon 141 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 lb/gal 0.052 = Conversion from lb./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 1. Drilling below conductor casing (16 ") ASP = [(FG x 0.052) — 0.1] D _ [(10.9 x 0.052) — 0.1] x 108 = 54 psi OR ASP = FPP — (0.1 x D) = 1,090' — (0.1 x 2,400') = 850 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 2,500 = 1,635 psi OR ASP = FPP — (0.1 x D) = 3,492 — (0.1 x 6,924) = 2,800 psi 3. Drilling below intermediate casing (7 ") ASP = FPP — (0.1 x D) = 3,492 — (0.1 x 6,924') = 2,886 psi to A CSI`. Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD3 -109 is the nearest existing well to the CD3 -106 plan at 135' well to well separation at 15,350' - MD. The proposed well path passes minor risk criteria when a tolerable collision risk of 1/100 is applied. At the closest intersection point between CD3 -106 and CD3 -109, there are indications that the CD3 -109 well bore is collapsed, further mitigating the risk of collision. Drilling Area Risks: There are no high -risk events. Lost circulation: Faulting within the Nechelik reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material is expected to be effective in dealing with lost circulation. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumping Operations: Incidental fluids developed from drilling operations on well CD3 -106L1 will be injected into a permitted annulus on ' CD3, or the class 1 disposal well on CD1 pad. Upon completion of CD3- 106L1, 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) * (2400') + 1,500 psi = 2,997 psi Pore Pressure = 1,086 psi Therefore Differential = 2,997 — 1,086 = 1,911 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: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9 -5/8" 40 L -80 3 BTC 3,090 psi 2,626 psi 5,750 psi 4,887 psi 7" 26 L -80 3 BTC -M 5,410 psi 4,598 psi 7,240 psi 6,154 psi a ate; f fi • • Cementing Program: Not applicable to the CD3-106L1. n " 1 1 ConocoPhillips Alaska, Inc. Post Office Box 100360 y Anchorage, Alaska 99510 -0360 ConocoPhillips Telephone 907 - 276 -1215 CD3 -106L1 Drilling Hazards Summary 6 -1/8" Hole / Horizontal Production Hole Event Risk Level Mitigation Strategy Reduced pump rates, reduced trip speeds, real time Lost Circulation Moderate equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Reduced trip speeds, Pump out to 7 -5/8" shoe, mud Hole Swabbing on Trips Moderate properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. BOPE drills, Keep mud weight above 8.8 ppg. ✓ Abnormal Reservoir Medium ✓ Check for flow during connections and if needed, Pressure increase mud weight. Well control drills, increased mud weight. Hydrogen Sulfide Gas Low H drills, detection systems, alarms, standard well ,/ control practices, mud scavengers REIM I ConocoPhillips(Alaska) Inc. Western North Slope CD3 Fjord Pad Plan: CD3 -106 Plan: CD3 -106L1 Plan: CD3- 106L1wp10 Standard proposal Report N /1 D 2 V Lea /.�wM. �w . ■ v . ... �"'' 04 January, 2010 Permit it ? a HALLIBURTON MOM ilIMENIIII Sperry Drilling Services N ORIGINAL IIPPV Project: Western North Slope Site: CD3 Fiord Pad CD 3 -106 L 1 wp 10 West( -)/East( (1000 ft/in) ConocoPh i l l i ps Well Site: Flan: CD3 -106L1 aaoo z000 000 0 I I I I I I I I I I I I I Alaska - DOI< 60'. Relatnaly shod, simple wills or simple profiles with lax la-Wally DDI 60 -64' Shorter wells with high tortuosity or longer wells with low laluoely DDI = 6 °716 001 64 - 8 8' Long wells with relative./ tortuous profiles - -- DDI 0 6.8 . Long, tortuous profiles 0th a high degree of afSouly HALLIBURTON REFERENCE INFORMATION Suisse LOGO^ 13000 I CD3•166L1wp1¢ 13000 Co-a4nate(WE) Reference WM Pla.: CD3 -106, True North EasUn 8628298. 4-11 x 6. 118••. � - A�1 V ertical (TVD) Refwence Mar CD3 - 306(36.3.13.4) 0 49700 (Delon 19) Ground Le. 13.40 - `�i - perry Section (VS) Reference: Slat- (D00N, 0.00E) ry Drillin g Calculation Method Minimum Curvature Latitude ]0 °25'8.68211 Geodetic zone Alaska Zone Longitude 150°54•4e.252 w _ I CD3 - 106L1wp10 Rio - 15:30 December 29 2009 Geodetic Oaum. North Amcican Datum 1983 6 1 0p0 CASING DETAILS SURVEY PROGRAM _ - ND TVDSS MD Name Sae 2500.00 245030 2739.79 9-5/8 95/8 412 -1/4' 36.30 100000 CD3- 10656909(Plan: CD3 -108) CB- G000-SS 692470 687500 12738.16 7 7•x8 -3/4• 1000.00 13326.00 CO3- 106wp09 (Plan: CD3 -106) MWD.IFR-AKCAZ -SC - 1 31° - 6809.70 6760.00 18417.46 4 -1/2 4- 112 -1/8• 13326.00 16417.46 CD3- 106L1wp10(Ran: CD3- 106L1) MWDO1FR- 015CA2 -SC _ -. 12000 - -12000 Targets _ Start 1401.52 hold at 15015.94 MD Name TVDS5 .14.6 .6/-W Northing Fasting Shape � - - 0O3- 106L1wp10Toe 676000 1283859 - 223263 601618900 152625900 Circle (Radius, 100.001 8 N CD3-106L1wp10 Mid 6805.00 1139935 - 162990 601502100 152684000 Pant D Ca ° o - 1ep55 - SECTION DETAILS + _ CD3- 106L1wp10 M • Start DLS 2.00 TFO - 135.65 _ Z Sec MD Inc A41 TVO NDSS .841-8 COM Northing EastIng DLeg TFace VSec Target r 0 1 1332600 91.49 325.00 695405 6904.35 10026.32 -98057 6013638.49 152746958 0.00 0.00 9812.42 0 S 2 13418.00 88.83 325.47 695310 6904.10 10100.25 - 1031.88 6013713.17 152741815 3.00 170.00 9700.52 Z - - 3 13466.00 88.83 325.47 695452 6905.12 10141.43 - 1060.22 6013754.77 1527390.67 0.00 0.00 9749.50 3A1 4 13516.00 88.83 326.97 695684 6906.14 10182.98 - 1088.02 6013796.73 1527363.50 100 90.00 9798 60 t Start 450.00 hold at 14331.44 MD 5 13571.04 90.00 328.14 6956.40 6906.70 10229.43 - 1117.55 6013843.61 1527334.65 3.00 45.00 9852.90 0 11000 - - 11000 -e 6 13859.84 95.00 331.03 694180 6894.10 10478.13 - 126157 6014094.45 1527192.42 2.00 30.00 10138 88 0 - O 7 14331.44 95.00 340.50 6902.61 6852.91 10906.03 - 1456.18 6014525.17 1527006.27 2.00 8959 1060803 CO 8 14781.44 95.00 340.50 6863.39 6813,69 11328.61 - 1605.82 601494991 1526863.01 0.00 0.00 11055.48 ' 9 1501694 91.64 337.22 684981 6800.11 11546.90 . 1690.24 6015169.43 1526781.89 2.00 - 135.6511289.41 - - 10 16417.46 91.64 337.22 6809.70 6750.00 12838.59 - 2232.63 6016469.00 1528259.00 0.00 0.00 1269934 CO3- 106L1wp10 Two 0 - 1p Start OLS 2.00 TFO 89.59 - Start DLS 2.00 TFO 30.00 - _ Start Start DLS 3.00 TFO 45.00 10000- Start DLS 3.00 TFO 90.00 - - 10000 asoo 9350 10200 I 11050 - 1 1 I I I I I I I I I I I Start 50 hold a[ 1341 MD �� 0 _ 7" x 8 -3/4" - KOP: DLS 3.00 TFO 170.00 - �a 5100- _ - 9000- - _ 9000 -3 00 I 2 1 00 _T I I 0 - West(- ) /East(4-) (1000 ft/in) KOP: DLS 3.00 TFO 170.00 Start 50.00 hold at 13416.00 MD N 5950- St art DLS 3 00 TFO 90.00 -5950 _ ANNOTATIONS co a (SD TVDSS MD Annotation .0 - ' Start DLS 3.00 TFO 45.00 - Cl 69 6904 35 13326 00 KOP' DLS 300TFO 170.00 ! 695380 6904.10 1341600 stet 50.00 hold x11341600 MD CL Start DLS 2.00 TFO 30.00 tJ 695482 6905.12 13466 00 slat OLS 300 TFO 90.00 • 6955 84 6906.14 13518 00 Start DLS 3.00 TFO 45.00 Start DLS 2 TFO 89.59 "C1 6956.40 6906.70 13571,04 Start DLS 2.00 TFO 30.00 4 -1 /Tx 6-1/8 _ j. 694380 6894.10 13859 84 Slat DLS 290 TFO 89.59 A l i - Start 450.00 hold at 14331.44 MD 6902 61 6852.91 14331 44 Stmt 450 00 held at 14331 44 MD _ Start DLS 2.00 TFO - 135.65 6863.39 6813 69 14781 44 Start DLS2007FO -13565 ICD3 106L1wp10 _ 684981 6800.11 1501594 81x1140152 hold al 1501594 MD 4,''' oo° Start 1401.52 hold at 15015.94 MD 0 6809 70 6760,00 16417 46 TD d 16417,40 H 9- o • 0 0° - seoo m � 7 " 2 Ei23/4" o°, .. O�D� - Amy rn - fiaoo • • Ue O p - - FORMATION TOP DETAILS LO" 33 Cl O p _ No formation data is a+9lapie ° ICD3 106Liwp10 Tde 7650 - - 7650 1 1 1 1 1 I 1 1 1 1 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 8500 9350 10200 11050 11900 12750 13600 Vertical Section at 337.00 ° (850 (Sin) Project: Western North Slope Site: CD3 Fiord Pad CD3 -106L1 wp10 West(- ) /East(t.) (1000 ft/in) ConocoPhillips Well: Plan: CD3 -1o6 O -9000 -1000 0 Wellbore: Plan: CD3 -106L I I I 1 -_ _I_ 1 I L I I 1 I I I 1 Al aska DOI.60 Relatively shed, ample wells or ample pro •mth lo tortuosity 1CD2 -10 DDI 80 -6.4 Shona tortuosity wells with high tortuosity longer e nh is iosiry DDI 6.716 1 � "'" DPI 64 -6.8 Long wells with relatiVely tortuous potties - DDI > 6.8 . Long. tortuous plea with a high degree of difficulty • HALLIBURTO N REFERENCE INFORMATION Surface Location . 1 3000 - I CD3106L1Wp10 -13000 Co-6.11144e (N•E) Reference Well Rai: CD3 -106, True 9041 Northing 600359943 /c1 Verbal (ND) Relaenc6 Plan: CD3-306 (36 3+13 41(/ 49 700 (Doyen 19) Eating 1528298.3] }r 4-1/2" x 6- 1/8'r d 9- nd Level 1140 - Sperry Drilling Section • Ref :tong ncl- (00ure 0 00E) Gw Latude ]025'8942N V` � atim ceadalo zone. Alaska zone a longitude 150 ere 252 w I CD3- 106L1wp10 Tole 15:27, December 29 2009 Geodetic Datum. North American Daum 1983 - - AT 0 0 CASING DETAILS SURVEY PROGRAM _ TVD TVDSS MD Name Size 250000 2450.30 273979 9-5/8 95/8'x12 -1/4' 36.30 100000 CO3-106,09 (Plan: CD3 -108) CBGYR63S ° • 692470 687500 12788.18 7 7'x8 -3/4' 100000 1332600 CO3- 1068p091P 145: CO3 -106) MWD+IFR-AK.CAZSC - '5' - 6809.70 676600 16417.46 4 -1/2 4. 1/2'x6.1/8' 13326.00 16417.46 003.106L18010 (Plan: 093- 106L1) MWD+IFR 12000- - 12000 Targets Start 1401.52 hold at 15015.94 MD None TVDSS +W - DE/ -W Northing Fasting Shape - CD3106Liwp10Te 876000 1283859 - 223263 601646900 152625900 Circle (Radius 10600) N CD3.106L1wp10 652 680500 11399.35 -162990 601502100 1526840.00 Pant D o O o ,,,-...., o SECTION DETAILS � - - CD3 106L1wp10 M•• Start DLS 2.00 TFO - 135.65 _ i Sac MD Inc Ail TVD TVDSS ONIS COW Northing Fasting DLeg TFace VSec Target i - i 1 1 3326.00 91.49 325.00 6954.05 6904.35 10026.32 -980.57 9013938.49 1527469.58 066 0.00 9612.42 6 1 2 341600 88.83 325.47 6953.80 6904.10 10100.25 - 1031.88 6013713.17 1527418.38 3.00 170.00 9700.52 Z - - 3 3466.00 88.83 325.47 6954.82 6905.12 10141.43 . 1060.22 6013754.77 1527390.67 0.00 0.00 9749.50 > •� 4 3516.00 88 83 326.97 6955.84 6906.14 10182.98 - 1088.02 6013796.73 1527363.50 100 90.00 979660 Start 450.00 hold at 14331.44 MD 5 3571.04 90.00 328.14 6956.40 6906.70 10229.43 - 1117.55 6013843.61 1527334.68 3.00 45.00 9852.90 1 11000- O -11000 0 0 6 3859.94 9500 331.03 6943.80 6894.10 10478.13 - 1263.57 6014094.45 1527192.42 200 30.00 10138.88 _ - 7 4331.44 9500 340.50 6902.61 6852.91 10906.03 - 1456.18 6014525.17 1527008.27 2.00 89.59 10608.03 0 - O 8 4781.44 95.00 340.50 6863.39 6813.69 11328.61 - 1605.62 6014949.91 1526863.01 0.00 0.00 11055.48 \� S 9 5015.94 91.64 337.22 6849.81 6800.11 11546.90 -1690.24 6015169.43 1526781.89 2.00 - 135.65 11289.41 - - 10 6417.46 91.64 337.22 680970 8760.00 12838.59 . 2232.63 6016469.00 1526259.00 0.00 0.00 12690.34 CO3- 106L189610 Toe _ 1p s'' Start DLS 2.00 TFO 89.59 - C , Start DLS 2.00 TFO 30.00 - _ Start DLS 3.00 TFO 45.00 - _ '-"".... 18040- Start DLS 3.00 TFO 90.00 - -10000 G I I I 9350 I 10200 11050 - Start 50.00 hold at 13416.00 MD 1 ` 1e0 7" x 83/4" KOP: DLS 3.00 TFO 170.00 5100 - - - b 9000 I I - I I 1 1 1 - -- - 9000 -3000 -2000 -1000 0 - west( - )/East( 9 (1000 ft/in) KOP: DLS 3.00 TFO 170.00 c _ Start 50.00 hold at 13416.00 MD tu LO 5950- Start DLS 3.00 TFO 90.00 -6350 N ANNOTATIONS CO A. T TVDSS MD Aawtaron w - ' Start DLS 3.00 TFO 45.00 - (3 VD 6954.05 6904.35 1332600 COP: DLS3 00TFO 17000 Ll 6953.80 6904.10 1341000 Start 50 00 hold at 1341600 MD Start DLS 2.00 TFO 30.00 6954.82 6905.12 1346600 Start DLS 3.00 TFO 9000 6955.84 6906.14 1351600 Stet DLS 3 00 TFO 45.00 - Start DLS 2.00 TFO 89.59 695640 6906.70 13571.04 Stet DLS 2.00 TFO 3000 4-1/2" 6943.80 6894.10 13859 Slat DLS 200TFO 8959 v - Start 450.00 hold at 14331.44 MD - 6902.61 6852.91 14331.44 Start 450.00 hold al 1433144 MD Start DLS 2.00 TFO -135.65 ( 686339 6813 69 14781.44 Start 2.00 t DLS TFO -135 fi5 j t O ICD3- 106L cn 6845.81 6800.11 1501594 S 140152 hold at 15015.94 MD 0i o° I Start 1401.52 hold at 15015.94 MD o 690970 6760.00 16417.46 TD a 16417.46 - ^o o I ICD3 -10 _ 0 m n 1 1 - • 8 - - FORMATION TOP DETAILS r O O J _ " O ° O - NO formMt n d&5. a B+aleple ° ICD3- 106L1wp10 Tc{e I - 7650- -7650 I I I I I I I I I I 1 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 8500 9350 10200 11050 11900 12750 13600 Vertical Section at 337.00 °(850 ft/in) Easting (3500 ft/in) , I I I 1 i 1 1 i i i i 1 i 1 1 1 I l u I l 1 1 1 I 1 1 i i i I mil 1 1 1 1 1 , , , , 1 1 1 1 1 1 1 i 1 1 1 1 1 1 1 I l l I I I [ 1 1 1 I 1 I I I i 1 1 1 I 1 1 1 1 I 1 1 1 [I — ConocoPhillips(Alaska) Inc. -WNS Date prepared: Western North Slope 16:00, December 29 2009 CD3 Fiord Pad CD3 -109 CD3- 106L1w 10 CD3- 126wp02 - CD3- 106wp09 P CD3 -125w• 12 — CD3 -108 — CD3- 10` — CD3 01Awp07 (wo in progre ....) -_ CD3 -1 L1 Cm 4_1 CD3-1 1 CD3-111 CD3 -1 • • CD3 -11 ' D3 -30: A wp13 \■ D3 -301 P: wp6 CD3 -1 A - CD3 -30 — 0 CD3 -1. gD3 -1 5 l ��; . f'2PB. ` CD3 -307 - = CD3 -124 01133-1 �� -302 - :1 = o z �� NI ��� ��c- •_ CD3 303 = � £swp01 • —� CD 316 C -16� � CD3- 199wp01 �� CD3 -12. �.��. 119w.. _ CD3-121wp02 _CD3 -31 — CD3-305F- - CD3- 122wp03 CD3- 123wp02 CD3 -3c5 - , i i I i t i I i i i l I I I I I 1 1 1 1 1 1 I 1 I 1 1 1 1 1 1 1 I i I I I l I I I I l I 1 1 I I I I I 1 1 1 1 1 1 1 1 1 1 1 I I I 1 1 1 1 1 1 1 1 1 1 I I I I I I I I I I 1 I I I l 1 Easting (3500 ft/in) 4110 11 lb ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co- ordinate Reference: Well Plan: CD3 - 106 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Plan: CD3 -306 (36.3 +13.4) @ 49.70ft (Doyon 18 Project Western North Slope MD Reference: Plan: CD3 -306 (36.3 +13.4) @ 49.70ft (Doyon 18 Site: CD3 Fjord Pad North Reference: True Well: Plan: CD3 -106 Survey Calculation Method: Minimum Curvature Welibore: Plan: CD3 -106L1 Design: CD3- 106L1wp10 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: 469.98ft Latitude: 53° 58' 43.652 N From: Map Easting: - 401.25ft Longitude: 152° 19' 30.231 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: - 1.88 ° Well Plan: CD3 -106 Well Position +N / -S 0.00 ft Northing: 6,003,852.22 Latitude: 70° 25' 10.108 N 1 +E / - 0.00 ft Easting: 388,266.46 Longitude: 150° 54' 36.875 W Position Uncertainty 0.00ft Wellhead Elevation: ft Ground Level: 13.40ft Wellbore Plan: CD3 - 106L1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength ( ( (nT) BGGM2007 12/28/2009 16.37 79.70 57,320 Design CD3- 106L1wp10 Audit Notes: ' Version: Phase: PLAN Tie On Depth: 13,326.00 Vertical Section: Depth From (TVD) +N/-S +E/ -W Direction (ft) (ft) (ft) ( °) 36.30 0.00 0.00 337.00 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth inclination Azimuth Depth System +N /-S +EI -W Rate Rate Rate Tool Face (ft) ( ( (ft) ft (ft) (ft) ( °/100ft) ( °/100ft) ( °/100ft) (°) 13,326.00 91.49 325.00 6,954.05 6,904.35 10,026.32 - 980.57 0.00 0.00 0.00 0.00 13,416.00 88.83 325.47 6,953.80 6,904.10 10,100.25 - 1,031.88 3.00 -2.95 0.52 170.00 13,466.00 88.83 325.47 6,954.82 6,905.12 10,141.43 - 1,060.22 0.00 0.00 0.00 0.00 1 13,516.00 88.83 326.97 6,955.84 6,906.14 10,182.98 - 1,088.02 3.00 0.00 3.00 90.00 13,571.04 90.00 328.14 6,956.40 6,906.70 10,229.43 - 1,117.55 3.00 2.12 2.12 45.00 13,859.84 95.00 331.03 6,943.80 6,894.10 10,478.13 - 1,263.57 2.00 1.73 1.00 30.00 14,331.44 95.00 340.50 6,902.61 6,852.91 10,906.03 - 1,456.18 2.00 0.00 2.01 89.59 14,781.44 95.00 340.50 6,863.39 6,813.69 11,328.61 - 1,605.82 0.00 0.00 0.00 0.00 1 15,014.49 91.64 337.26 6,849.89 6,800.19 11,545.58 - 1,689.64 2.00 -1.44 -1.39 - 135.99 16,417.32 91.64 337.26 6,809.70 6,760.00 12,838.85 - 2,231.64 0.00 0.00 0.00 0.00 1/4/2010 8:59:25AM .,, i .;P10g9"2 1 a : „ COMPASS 2003.16 Build 69 • • ConocoPhillips HALL.1BURT ®N Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan: CD3 - 106 Company: ConocoPhillips(Alaska) Inc. ND Reference: Plan: CD3 -306 (36.3 +13.4) @ 49.70ft (Doyon 19 Project: Western North Slope MD Reference: Plan: CD3 -306 (36.3 +13.4) @ 49.70ft (Doyon 19 Site CD3 Fjord Pad North Reference: True Welk Plan: CD3 -106 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD3 -106L1 Design: CD3- 106L1wp10 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +E/ -W Northing Easting DLS Vert Section (ft) ( °) ( °) (ft) ft (ft) (ft) (ft) (ft) 6,904.35 13,326.00 91.49 325.00 6,954.05 6,904.35 10,026.32 - 980.57 6,013,891.23 387,436.14 3.00 9,612.42 KOP: DLS 3.00 TFO 170.00 13,400.00 89.30 325.39 6,953.54 6,903.84 10,087.08 - 1,022.81 6,013,952.61 387,394.82 3.00 9,684.85 13,416.00 88.83 325.47 6,953.80 6,904.10 10,100.25 - 1,031.88 6,013,965.91 387,385.94 3.00 9,700.52 Start 50.00 hold at 13416.00 MD 13,466.00 88.83 325.47 6,954.82 6,905.12 10,141.43 - 1,060.22 6,014,007.51 387,358.23 0.00 9,749.50 Start DLS 3.00 TFO 90.00 13,500.00 88.83 326.49 6,955.51 6,905.81 10,169.61 - 1,079.24 6,014,035.96 387,339.64 3.00 9,782.86 13,516.00 88.83 326.97 6,955.84 6,906.14 10,182.98 - 1,088.02 6,014,049.47 387,331.06 3.00 9,798.60 Start DLS 3.00 TFO 45.00 13,571.04 90.00 328.14 6,956.40 6,906.70 10,229.43 - 1,117.55 6,014,096.35 387,302.23 3.00 9,852.90 Start DLS 2.00 TFO 30.00 13,600.00 90.50 328.43 6,956.27 6,906.57 10,254.06 - 1,132.77 6,014,121.20 387,287.38 2.00 9,881.52 13,700.00 92.23 329.43 6,953.89 6,904.19 10,339.68 - 1,184.37 6,014,207.58 387,237.08 2.00 9,980.49 13,800.00 93.96 330.43 6,948.48 6,898.78 10,426.09 - 1,234.40 6,014,294.72 387,188.35 2.00 10,079.58 , 13,859.84 95.00 331.03 6,943.80 6,894.10 10,478.13 - 1,263.57 6,014,347.18 387,159.97 2.00 10,138.88 I Start DLS 2.00 TFO 89.59 13,900.00 95.01 331.84 6,940.30 6,890.60 10,513.26 - 1,282.69 6,014,382.60 387,141.37 2.00 10,178.70 14,000.00 95.01 333.85 6,931.57 6,881.87 10,601.90 - 1,328.16 6,014,471.89 387,097.23 2.00 10,278.05 14,100.00 95.02 335.85 6,922.82 6,873.12 10,692.06 - 1,370.50 6,014,562.68 387,056.26 2.00 10,377.59 14,200.00 95.01 337.86 6,914.08 6,864.38 10,783.66 - 1,409.65 6,014,654.84 387,018.49 2.00 10,477.20 14,300.00 95.00 339.87 6,905.35 6,855.65 10,876.57 - 1,445.56 6,014,748.27 386,983.97 2.00 10,576.76 14,331.44 95.00 340.50 6,902.61 6,852.91 10,906.03 - 1,456.18 6,014,777.89 386,973.79 2.00 10,608.03 Start 450.00 hold at 14331.44 MD , 14,400.00 95.00 340.50 6,896.63 6,846.93 10,970.42 - 1,478.98 6,014,842.60 386,951.96 0.00 10,676.21 14,500.00 95.00 340.50 6,887.92 6,838.22 11,064.32 - 1,512.23 6,014,936.99 386,920.12 0.00 10,775.64 14,600.00 95.00 340.50 6,879.20 6,829.50 11,158.23 - 1,545.49 6,015,031.37 386,888.28 0.00 10,875.07 14,700.00 95.00 340.50 6,870.49 6,820.79 11,252.14 - 1,578.74 6,015,125.76 386,856.44 0.00 10,974.51 14,781.44 95.00 340.50 6,863.39 6,813.69 11,328.61 - 1,605.82 6,015,202.62 386,830.51 0.00 11,055.48 I Start DLS 2.00 TFO - 135.65 14,800.00 94.73 340.24 6,861.81 6,812.11 11,346.03 - 1,612.03 6,015,220.13 386,824.55 2.00 11,073.95 14,900.00 93.29 338.85 6,854.82 6,805.12 11,439.49 - 1,646.89 6,015,314.09 386,791.10 2.00 11,173.60 15,000.00 91.85 337.46 6,850.33 6,800.63 11,532.21 - 1,684.06 6,015,407.35 386,755.33 2.00 11,273.47 15,014.49 91.64 337.26 6,849.89 6,800.19 11,545.58 - 1,689.64 6,015,420.81 386,749.95 2.00 11,287.96 15,015.94 91.64 337.26 6,849.85 6,800.15 11,546.92 - 1,690.20 6,015,422.15 386,749.41 0.00 11,289.41 Start 1401.52 hold at 15015.94 MD 15,100.00 91.64 337.26 6,847.44 6,797.74 11,624.41 - 1,722.68 6,015,500.11 386,718.10 0.00 11,373.43 15,200.00 91.64 337.26 6,844.57 6,794.87 11,716.60 - 1,761.31 6,015,592.86 386,680.85 0.00 11,473.39 15,300.00 91.64 337.26 6,841.71 6,792.01 11,808.79 - 1,799.95 6,015,685.61 386,643.60 0.00 11,573.35 15,400.00 91.64 337.26 6,838.84 6,789.14 11,900.98 - 1,838.58 6,015,778.36 386,606.36 0.00 11,673.30 15,500.00 91.64 337.26 6,835.98 6,786.28 11,993.17 - 1,877.22 6,015,871.11 386,569.11 0.00 11,773.26 15,600.00 91.64 337.26 6,833.11 6,783.41 12,085.36 - 1,915.86 6,015,963.86 386,531.86 0.00 11,873.22 15,700.00 91.64 337.26 6,830.25 6,780.55 12,177.55 - 1,954.49 6,016,056.61 386,494.61 0.00 11,973.18 i 15,800.00 91.64 337.26 6,827.38 6,777.68 12,269.74 - 1,993.13 6,016,149.36 386,457.36 0.00 12,073.14 L 15,900.00 91.64 337.26 6,824.52 6,774.82 12,361.93 - 2,031.77 6,016,242.11 386,420.11 0.00 12,173.09 1/4/2010 8:59:25AM Page 3 COMPASS 2003.16 Build 69 r ; 1t 1 1. _ c • ConocoPhillips HALLI B U RTO N Standard Proposal Report Database: EDM v16 Prod Local Co- ordinate Reference: Well Plan: CD3 - 106 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Plan: CD3 -306 (36.3 +13.4) @ 49.70ft (Doyon 19 Project: Western North Slope MD Reference: Plan: CD3 -306 (36.3 +13.4) @ 49.70ft (Doyon 19 Site: CD3 Fjord Pad North Reference: True Well: Plan: CD3 - 106 Survey Calculation Method: Minimum Curvature Welibore: Plan: CD3 - 106L1 Design: CD3- 106L1wp10 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) ( °) (°) (ft) ft (ft) (ft) (ft) (ft) 6,771.95 16,000.00 91.64 337.26 6,821.65 6,771.95 12,454.12 - 2,070.40 6,016,334.86 386,382.86 0.00 12,273.05 16,100.00 91.64 337.26 6,818.79 6,769.09 12,546.31 - 2,109.04 6,016,427.62 386,345.61 0.00 12,373.01 16,200.00 91.64 337.26 6,815.93 6,766.23 12,638.50 - 2,147.67 6,016,520.37 386,308.37 0.00 12,472.97 16,300.00 91.64 337.26 6,813.06 6,763.36 12,730.69 - 2,186.31 6,016,613.12 386,271.12 0.00 12,572.93 16,400.00 91.64 337.26 6,810.20 6,760.50 12,822.88 - 2,224.95 6,016,705.87 386,233.87 0.00 12,672.88 • 16,417.32 91.64 337.26 6,809.70 6,760.00 12,838.85 - 2,231.64 6,016,721.93 386,227.42 0.00 12,690.19 L_ CD3-106L1wp10 Toe Targets Target Name - hit/miss target Dip Angle Dip Dir. TVD +N/-S +E / -W Northing Easting - Shape ( °) ( °) (ft) (ft) (ft) (ft) (ft) CD3- 106L1wp10 Toe 0.00 0.00 6,809.70 12,838.85 - 2,231.64 6,016,721.93 386,227.42 - plan hits target center - Circle (radius 100.00) CD3- 106L1wp10 Mid 0.00 0.00 6,854.70 11,399.55 - 1,629.01 6,015,273.90 386,808.38 - plan misses target center by 3.80ft at 14856.45ft MD (6857.56 TVD, 11398.87 N, - 1631.43 E) - Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name P7 (') 2,739.79 2,500.00 9 -5/8" x 12 -1/4" 9 -5/8 12 -1/4 1 12,786.16 6,924.70 7" x 8 -3/4" 7 8 -3/4 1 16,417.46 4 -1/2" x 6 -1/8" 4 -1/2 6 -1/8 ! 1 i Plan Annotations Measured Vertical Local Coordinates Depth Depth +N /-S +E/ -W (ft) (ft) (ft) (ft) Comment 13,326.00 6,954.05 10,026.32 - 980.57 KOP: DLS 3.00 TFO 170.00 13,416.00 6,953.80 10,100.25 - 1,031.88 Start 50.00 hold at 13416.00 MD 13,466.00 6,954.82 10,141.43 - 1,060.22 Start DLS 3.00 TFO 90.00 13,516.00 6,955.84 10,182.98 - 1,088.02 Start DLS 3.00 TFO 45.00 13,571.04 6,956.40 10,229.43 - 1,117.55 Start DLS 2.00 TFO 30.00 13,859.84 6,943.80 10,478.13 - 1,263.57 Start DLS 2.00 TFO 89.59 14,331.44 6,902.61 10,906.03 - 1,456.18 Start 450.00 hold at 14331.44 MD 14,781.44 6,863.39 11,328.61 - 1,605.82 Start DLS 2.00 TFO - 135.65 15,015.94 6,849.85 11,546.92 - 1,690.20 Start 1401.52 hold at 15015.94 MD 16,417.46 TD at 16417.46 1/4/2010 8:59:25AM ".- a, .. 1 f 0 , ei COMPASS 2003.16 Build 69 ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD3 Fiord Pad Plan: CD3 -106 Plan: CD3 -106L1 CD3- 106L1wp10 • Sperry Drilling Services I lo Clearance Summary Anticollision Report Major Risk Tom. required 29 December, 2009 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad - Plan: CD3 -106 - Plan: CD3 -106L1 - CD3- 106L1wp10 Well Coordinates: 6,003,599.43 N, 1,528,298.37 E (70° 25' 08.94" N, 150° 54' 48.25" W) Datum Height: Plan: CD3 -306 (36.3 +13.4) @ 49.70ft (Doyon 19) Scan Range: 13,326.00 to 16,417.46 ft. Measured Depth. Scan Radius is 1,838.12 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 69 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 HALLIBURTON Sperry Drilling Services ConocoPhillips(Alaska) Inc. -WNS HALLIBURTON Western North Slope Anticollision Report for Plan: CD3 -106 - CD3- 106L1wp10 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad - Plan: CD3 -106 - Plan: CD3 -106L1 - CD3- 106L1wp10 Scan Range: 13,326.00 to 16,417.46 ft. Measured Depth. Scan Radius is 1,838.12 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 -109 - CD3 -109 - CD3 -109 3 W51. -1$4111 111111.1111 1 0.422 Centre Distance a FAIL - Major Risk CD3 - 109 - CD3 - 109 - CD3 - 109 16,405.39 46111 0.448 Clearance Factor, LAIL - Major Risk CD3 -301 - Plan: CD3 -301A - CD3- 301Awp07 (work in 13,334.78 379.45 13,334.78 103.78 13,675.00 1.376 Clearance Factor Pass - Major Risk Plan: CD3 -106 - Plan: CD3 -106 - CD3- 106wp09 0.358 Clearance Factor D 23 Survey tool program From To Survey /Plan Survey Tool (ft) (f 36.30 1,000.00 CB- GYRO -SS 1,000.00 13,326.00 M W D +I F R -AK- CAZ -SC 13,326.00 16,417.46 CD3- 106L1wp10 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. 29 December, 2009 - 15:38 Page 2 of 4 COMPASS ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD3 Fiord Pad Plan: CD3 -106 Plan: CD3 -106L1 CD3- 106L1wp10 I s 4 IA Sperry Drilling Services �.¢ io t Clearance Summary Minor Risk Anticollision Report TC required 29 December, 2009 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad - Plan: CD3 -106 - Plan: CD3 -106L1 - CD3- 106L1wp10 Well Coordinates: 6,003,599.43 N, 1,528,298.37 E (70° 25' 08.94" N, 150° 54' 48.25" W) • Datum Height: Plan: CD3 -306 (36.3 +13.4) @ 49.70ft (Doyon 19) Scan Range: 13,326.00 to 16,417.46 ft. Measured Depth. Scan Radius is 1,838.12 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 69 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 HALLIBURTON Rl ! i Sperry Drilling Services I I GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 15:53, December 29 2009 i CD3- 106L1wp10 Ellipsoid Color 13326.00 To 16417.46 0 13200 13800 13900 15250 15500 17000 1725C CD3- 301Awp07 (work in 13200 13300 13900 14000 15500 15750 17250 1750C progress ...) 13300 13400 14000 14250 15750 - - -"— 16000 17500 1775C 0 / 360 13400 — 13500 14250 14500 16000 16250 17750 " "'" 1800C illip 13500 13600 14500 14750 16250 16500 13600 13700 14750 15000 16500 16750 30 / 330 13700 13800 15000 15250 16750 17000 r • a im -60 / 300 \ 60 0 / 360 50 "A, 4 ! -30 / 330 30 rj A d \ ss„,,.........._____10. r)3 \ ;A • .N„ 4: -60 / 300 60 \'''. _90 / 270 - 90 �„j�r »<. CD3 -109 90/270 ' etr'• 90 CD3- 106wp09 :D3- 106wp05 120 / 240 120 -120 / 240 120 • 200 -150 / 210 150 -150 /210 150 50 300 1 CR, required - 180 /180 -180 / 180 Travelling Cylinder Azimuth (TFO +AZI) [ vs Centre to Centre Separation [25 ft /in] Easting (3500 ft/in) ,JIII,J I 1I„ iil m ilt∎Il liiiiIiiiiIIIIIImiIiiiiIiiiiIimIiiiil m iImIIitilIii,iIii - ConocoPhillips(Alaska) Inc. -WNS Western North Slope 15 52,? D� �Ir 2 9 r.200 CD3 Fiord Pad CD3 -109 - - CD3- 126wp02 - _ CD3- 106wp09_ CD3- 106L1wp10 - CD3- 125w.02 - - = CD3 -108 — CD3- 10` CD3- 01Awp07 (wo in progres,...) - CD3 -1 L1 Cris; �t ft1 - CD3 -1 1 - • — CD3-111 CD3 -1 ■ - CD3 -11 ' D3 -30 = i wp13 • D3 -301 P: wp6 - - CD3 -1 4 ` - z o _ 1r CD3 -30O ' 3 A. J = CD3 -1 5 6 - -ii 2PB C C -307 = W CD3 -117 ,f •14/ = ° 1. z // ill CD3 -303 -y-' - CD 316 C I ! 115AAwp01 • CD3- 199wp01 • 113- 119w.; - CD3-:304 CD3- 305PB1 — CD3 -305 - , 1 1 1 1 1 I I I I I 1 I I 1 1 1 1 1 1 1 1 1 1 I I I I I f I I 1 1 1 1 1 1 1 I 1 1 1 1 1 F I I 1 1 1 1 7 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I I I I 1 1 1 1 1 1 1 1 1 1 1 1 Easting (3500 ft/in) IC I ConocoPhillips(Alaska) Inc. -WNS HALLIBURTON Western North Slope Anticollision Report for Plan: CD3 -106 - CD3- 106L1wp10 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad - Plan: CD3 -106 - Plan: CD3 -106L1 - CD3- 106L1wp10 Scan Range: 13,326.00 to 16,417.46 ft. Measured Depth. Scan Radius is 1,838.12 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 -109 - CD3-109 - CD3-109 15,355.85 136.27 15,355.85 135.76 17,975.00 266.465 Clearance Factor Pass - Minor 1/100 CD3 -301 - Plan: CD3 -301A - CD3- 301Awp07 (work in 13,334.78 379.45 13,334.78 103.78 13,675.00 1.376 Clearance Factor Pass - Major Risk Plan: CD3 -106 - Plan: CD3 -106 - CD3- 106wp09 13,350.00 0.30 13,350.00 -0.28 13,350.00 0.520 Clearance Factor FAIL - Minor 1/10 Survey tool program From To Survey /Plan Survey Tool (ft) (ft) 36.30 1,000.00 CB- GYRO -SS 1,000.00 13, 326.00 M W D +I F R -AK- CAZ -SC 13,326.00 16,417.46 CD3- 106L1wp10 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. 29 December, 2009 - 15:47 Page 2 of 4 COMPASS ConocoPhillips(Alaska) Inc. -WNS HALLIBURTON Western North Slope Anticollision Report for Plan: CD3 -106 - CD3- 106L1wp10 Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to Plan: CD3 -306 (36.3 +13.4) @ 49.70ft (Doyon 19). Northing and Easting are relative to Plan: CD3 -106. Coordinate System is US State Plane 1983, Alaska Zone 4. Central Meridian is - 150.00 °, Grid Convergence at Surface is: -0.86 °. I 41-4 14I , ,IJJ , VJ - JU I VT -6- CO3-108,CO3-108.C1:13-108 V14 Ladder $ cD3.109,CD3- 109,CD3.1ooV6 - 6- CO3- 110,CD3.110,CD3- 110V12 III Plot lot , , CO3- 111,C133 -111 ,CD3 -111 V7 I -e- CD3- 111,CO3 -111 L1, CD3 -111 L1 V1 I I I I I I _ C I I I I I ` �i 1 - CO3.112.0O3.112.0O3 -112 V3 ,e 4 _ 900 I I I for. I -9- CD3.113,CD3- 113,CD3.113 V6 ( O I I I I I I 4 CD3.114,CD3.114,CO3.114V14 I I I I I I CO I I I I I I - CD3.115,CD3- 115,CO3.115VD I I - -- - -- I I I V. I CD3- 117,CO3- 117,CO3.1171N - "" C I I I I I 1 S p I I I I I I -0- CD3.301,CO3.301,CD3 -301 V1 - ,.,., (4 I I I I I y I $ CD3- 301,CO3- 301PB1,CD3.301PB1 V1 ,.. °. I 6 00 I I I I I \� I t -" jam -F CD3- 301,PIan: CD3 -301A, CD3- 301Ap07(work inprogres<_.... ' ( I -e- CD3. 301, Plan :CD3.301APB1,CD3- 301APB1wp06VD t I I I I I I -e- CD3- 302,CD3- 302,CD3 -302 V3 a--I I I I I -)(- CD3- 302.0O3.302PB1,CO3- 302PB1 V11 C I I I 1 / I Cl) I I I I I I -- COC- 302,003- 302PB2,CO3- 302PB2V6 0 I I I I I I 300 I I I II I -9- CD3.302,CD3- 302P83,CD3.302PB3 V2 I I I I I I I I $ CD3 - 302 , Plan: CO3- 302A,CD3- 302fiwp13Vll 0) I I I I fi r:, `' -4- CD3- 303,CO3- 303,CD3 -303V0 • I I I I ----- I -1 i 11". - , - I - "Z____ -4- CD3- 304.0O3.304,CO3 -304V0 0 I I I I I .;:■!ii.12■I 1 (0 I I I I I I -0- C1 - 305,CD3.306.CD3 -305V0 I I I I I I fi I )4 C133- 305,CD3- 305P81,CO3- 305PB1 VD I I I I 1 I I I I 0 e I $ CD3- 316,CD3- 316,CD3 -316V0 0 3000 6000 9000 12000 15000 $ CD3-316,CD3.316A,CD3- 316AVI) Measured Depth (3000ft /in - c04- 316,cG - 316APB1 316APB1 VD - e- Plan: CD3- 106,PIan:CD3.106,CD3- 106wp09VD - -0— Plan•r:n.3.110 Plan -r:n:i -iin f:nI- 11oulnf19\lrI 29 December, 2009 - 15:47 Page 3 of 4 COMPASS ConocoPhillips(Alaska) Inc. -WNS HALLI BURTON Western North Slope Anticollision Report for Plan: CD3 -106 - CD3- 106L1wp10 Clearance Factor Plot: Measured Depth versus Separation(Clearance) Factor CD 3-108, CO3 -108, C 03.108 V14 1 - 1 E • C 03-109, CD3- 109,CD3 -109V5 - I400 - - - -- I Z. Z. CD3 -110, CD3 -110, CO3 -110 V12 CO3- 111,003- 111,CD3.111V7 I CD3- 111,CD3.111L1, CD3 -111L1 V1 III 8; 5 CO3 -112, CO3.112, CO3 -112 V3 � , CO3.113,CO3- 113,CO3.113V16 - c CO3- 114,CO3- 114,CO3- 114V14 2 _ : CO3.115,CD3- 115,CD3 -115 VD C) o _ CO3 -117, CO3 -117, CD3.117 VO Ln o - CD3 -301, CD3 -301 , CO3 -301 V4 CO3.301,CO3.301PB1,CO3- 301P01 VI �"�'") v - - E CD3.301,PIan: CD3- 301A,C 03.301Awp07 (work inprogress...)' 0 6ro - i CD3- 3O1,PIan :CD3- 301APB1,CO3.301APB1wp06VO CD3 -302, CD3 -302, CD3 -302 V3 to - CD3 -302, CO3- 302PB1,CD3- 302P81 V11 [ten 3;6 K CD 302,CO3.302PB2,CO3- 302P82 V6 1--- _ � CO3.302,CO3.302PB3,CO3- 302PB3 V2 - ah CD 3-302, PIan:CD3.302A,CO3- 3O2Awp13VO 250 C 03 -303, CD3 -303, CD3 -303 VO - C 03 -304, CD3.304, CD3 -304 VO CD3 -305, CD3 -305, CO3.305 V>7 CO3- 305,CO3.305PB1,CO3- 305PB1 VD C 03 -316, CO3-316, CO3 -316 VO - 1 I W . CD3.316,CO3- 316A,CO3- 316AV0 OW 1 1 1 1 1 1 1 i 1 I I i i i l i i i i i I I I i 1 1 1 i I i t ' [L i l l I I I ! i i i i I I I 1 1 1 1 1 O I J0 CO 3 1600 dm 7500 9760 10600 I me 16060 16600 18000 C D 3 -316, CD3 -316A P B 1, C D3 -316AP B 1 VD M6sasuredDepth (3000 Min) - Plan: CO3-106, Plan: CD3 -106, CD3- 106w pO9 VO Plan: CO3 -119, Plan: CD 3-119, CD3- 119wp02 VO 29 December, 2009 - 15:47 Page 4 of 4 COMPASS Easting (1500 ft/in) I I I I I l l 11 1111111 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 l 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I l l l l I l l l l 1 1 1 1 1 1 1 1 l 1 1 1 1 1 , 1 1 ,4 1 1 1 1 1 1 1 1 1 1 ConocoPhillips(Alaska) Inc. -WNS ew't " - ' 0 . , z a = Western North Slope CD3 - 109 � _ CD3 Fiord Pad — CD3 -106L 1 wp1 /_, _ — CD3 -108 - CD3 -110 • CD3-111L1 _- CD3 -301 - a _ CD3 -31 �'107L1 _ - alc = CD3 -111 co o CD3 -107 _ 3 : , z CD3 -112 — • D3 -302 CD3- 02PB3 — CD3- 302PB2 l iiii I 1 111 1111[1111111111 1111111111ETTl III I[Tri1 1111111 1111 11111111111111111111Tii Easting (1500 ft/in) Opera: CmocoPNlpsCAIS*W hc. -WN5 GidCarreclion: - 086 Job No: SN /A Field Western North SIop• Magiet lo 0 animation' 21]9 AR Not tN /A Wet CD3 -1061.1 wp10 op: 80.78 ° API Not tN /A Rig: tlN /A Do egper 100 It System eV (3) Reference: Mem Sent/wet Surface pcdlon Original VS Plane: 337.00 ° Parent Wet Pim:CD3 -106 x 1529299.37 f View VS Plane: 337.00 ° ROB Wag,): 49.70 t y' 600359943 ft UM System: API Saed/ W5 Section (VS) Retnenan Slot Comments: POOL: 8 s o s s 8 s 8 s CD3- 106L1wp10 Plan: 13326' to 16417.46' MD — _ -- — -- — CD3 -109: 9775' to 20321' MD 6018800 CD3 -110: 8735' to 17991' MD CD3 -108: 11056' to 18915' MD -- - - - - -- — 6017800 - - -- — — - 6016800 • \..... — - -- 6015800 i '° - S - 6014800 "1 Section View —� CD3- 106L1wp10 Plan —CD3 -109 —CD3 -110 —41— CD3 -102 , - -- —`— „: :: _::. wil 6013800 .,... ' - . . ,' \ r 1 -- 6012800 ■ — -- ----_. - L -- -- 6011800 6010800 .c m East( +) / West( -) O O III t N 1 N 2 E m N o Vertical Section along View VS Plane” Combo Preview Page 1 of 1 (CD3- 106L1wp10 Toolbox)ds) 12/29/2009 4:40 PM Closest in POOL Closest Approach: Reference Well: CD3- 106L1wp10 Plan Offset Well: CD3 -109 Coords. - Coords. - ASP ASP 3- Dctr -ctr Meas. Incl. TRUE Subsea N( +) /S( -) View VS Meas. Incl. TRUE Subsea N( +) /S( -) View VS Distance. Depth Angle Azi. TVD E( +) /W(- (337) Comments Depth Angle Azi. TVD E( +) /W(_ (337) Comments POOL Min Distance (135.59 it) Distance (135.39 ft) in POOL (13326 - in POOL (13326 - 16417.46 MD) to . 16417.46 MD) to CD3- 106L1wp10 CD3 -109 (9775 - Plan (9775 - 20321 135.39 15350 91.64 337.22 6790.63 6015480 1526658 1162294 20321 MD) 17968.54 90.52 336.72 6835.47 6015529 1526776 11614.6 MD) Closest Approach: Reference Well: CD3- 106L1wp10 Plan Offset Well: CD3 -108 . Coords. - Coords. - -,„ ASP ASP ,,..".,,,X 3-D ctr -ctr Meas. Incl. TRUE Subsea N( + ) /S( -) View VS Meas. Incl. TRUE Subsea N( +) /S( -) View VS ....y.... Distance. Depth Angle Azi. TVD E( +) /W(- (337) Comments Depth Angle Azi. TVD E( +) /W(- (337) Comments _ -., POOL Min POOL Min Distance (1990.84 Distance (1990.84 ft) in POOL (13326 '"'� ft) in POOL (13326 - 16417.46 MD) to _ _ - 16417.46 MD) to CD3-106L1wp10 CD3 -108 (11056 - Plan (11056 - 1891E 1990.8 15650 91.64 337.22 6782.05 6015758 1526546 1192282 18915 MD) 18915 103.77 323.05 6765.046 6016493 1528396 11906.08 MD) Closest Approach: Reference Well: CD3- 106L1wp10 Plan Offset Well: CD3 -110 Coords. - Coords. - ASP ASP 3 -D ctrctr Meas. Incl. TRUE Subsea N( +) /S( -) View VS Meas. Incl. TRUE Subsea N( +) /S( -) View VS Distance. Depth Angle Azi. TVD E( +) /W(- (337) Comments Depth Angle Azi. TVD E( +) /W(- (337) Comments POOL Min POOL Min Distance (2148.68 Distance (2148.68 ft) in POOL (13326 ft) in POOL (13326 - 16417.46 MD) to - 16417.46 MD) to CD3- 106L1wplO CO3 -110 (8735 - Plan (8735 - 17991 2148.7 13516 88.83 326.97 6906.194 6013798 1527364 9798.216 17991 MD) 14460.34 91.4 327.32 6887.5 6012660 1525541 9419.29 MD) PoolSummaryl 12/29/2009 4:45 PM REV DATE BY CK APP • DESCRIPTION REV DATE BY 0 APP DESCRIPTION 5 4/8/07 AG DB C.A. UPDATED PER K07041ACS 6 4/13/09 AG DB C.A. UPDATED PER K090003ACS N 1111111ZIrMari PA iW _ .. r X611 7 Y ' 0 ii r 1 IRA p 1 h 1 ALPINE SATELLITE DEVELOPMENT j W ��., VICINITY MAP NOT TO SCALE pE51GN SNO ER OF P AO CD -3 PAD m , o $> v , 7 , , ^ G H EM1 F PRM ,nom %-- ;, • TPN 1 � v Yoi� jo P NEASEi 1NG F ` .' N,00U1 -E S10R oGESE SK \14P, R PLANT 0r ASPC E Q U AR S ERS N 13'00'00" w w LCMF LEGEND: 0 0 z z 0 PROPOSED CONDUCTOR . w �° N N • EXISTING CONDUCTOR ° Ny 1.- ifz. --' Z o v o 0 KUUKPIK w W 4 LCMF U. N 139 E 51�t Ave Mohotps, Ask. 99503 (99 N D i n e DMce ( 39]16]6 4 ]39 Alpine Survey Office IIPV ALPINE MODULE: CD30 UNIT: CD ConocePhillips CD -3 ALPINE WELL CONDUCTORS Alaska, Inc. AS -BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 05- 03 -03 -1A 11/3/05 CE —Ci3 -111 1 OF 3 6 }iyir' 4 1 1, 0 11 4 1 REV DATE BY CK APP • DESCRIPTION REV DATE BY APP DESCRIPTION 6 4/8/07 AG DB C.A. ISSUED PER K07041ACS 7 4/13/09 AG DB C.A. UPDATED PER K090003ACS ALL CONDUCTORS ARE LOCATED IN PROTRACTED SEC.5, T 12 N, R 5 E, U.M. SEC.LINE 0/S EXIST WELL 'Y' 'X' LAT.(N) LONG.(W) FSL FEL GND PAD CD3 -X98 6,003,630.37 1,528,434.35 70' 25' 09.267" 150° 54' 44.278" 1392' 642' 7.3 12.5 CD3 -X99 6,003,625.99 1,528,415.38 70' 25' 09.221" , 150° 54' 44.833" 1387' 661' 7.3 12.8 CD3 -301 6,003,621.33 1,528,395.58 70' 25' 09.172" 150' 54' 45.411" 1382' 680' 7.3 13.5 CD3 -302 6,003,616.72 1,528,376.38 70' 25' 09.124" 150° 54' 45.972" 1377' 700' 7.3 13.2 CD3 -303 6,003,612.52 1,528,356.72 70' 25' 09.080" 150' 54' 46.547" 1373' 719' 7.3 13.3 CD3 -304 6,003,607.82 1,528,337.04 70' 25' 09.031" , 150° 54' 47.122" 1368' 739' 7.3 13.4 CD3 -305 6,003,603.48 1,528,317.56 70' 25' 08.985" 150° 54' 47.691" 1363' 758' 7.3 13.6 CD3 -106 6 00.3.599 43 1.528.298.37 70° 25' 08 942" 150° 54' 48.252" 1359' 777' 7.3 13.4 CD3 -107 6,003,594.38 1,528,278.93 70' 25' 08.890" 150° 54' 48.820" 1354' 797' 7.3 13.2 CD3 -108 6,003,589.85 1,528,259.61 70' 25' 08.842" 150° 54' 49.385" 1349' 816' 7.3 13.1 CD3 -109 6,003,585.27 1,528,239.85 70° 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° 54' 50.533" 1339' 855' 7.3 13.0 CD3 -111 6,003,576.13 1,528,201.08 70' 25' 08.699" 150' 54' 51.095" 1334' 874' 7.3 12.9 0D3 -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 70° 25' 08.609" 150° 54' 52.255" 1325' 914' 7.3 13.1 CD3 -114 6,003,563.04 1,528,142.21 70' 25' 08.561" 150° 54' 52.815" 1320' 933' 7.3 13.3 003 -115 6,003,558.57 1,528,122.60 70' 25' 08.515" , 150° 54' 53.388" 1315' 953' 7.3 13.2 CD3 -116 6,003,554.04 1,528,103.39 70' 25' 08.467" 150° 54' 53.950" 1311' 972' 7.3 13.2 CD3 -117 6,003,549.51 1,528,083.99 70' 25' 08.420" 150° 54' 54.516" 1306' 991' 7.3 13.1 CD3 -X18 6,003,544.88 1,528,064.44 70° 25' 08.372" 150° 54' 55.086" 1301' 1011' 7.3 12.8 CD3 -X19 6,003,540.17 1,528,044.86 70' 25' 08.322" 150° 54' 55.660" 1296' 1030' 7.3 12.8 CD3 -X20 6,003,535.95 1,528,025.39 70' 25' 08.278" 150° 54' 56.229" 1291' 1050' 7.3 12.6 CD3 -X21 , 6,003,531.41 1,528,006.04 70' 25' 08.230" 150° 54' 56.794" 1286' 1069' 7.3 12.5 CD3 -X22 6,003,527.00 1,527,986.67 70' 25' 08.184" , 150° 54' 57.360" 1282' 1088' 7.3 12.6 0D3 -X23 6,003,522.43 1,527,967.12 70° 25' 08.136" 150' 54' 57.932" 1277' 1108' 7.3 12.6 CD3 -X24 6,003,518.17 1,527,947.59 70' 25' 08.091" 150° 54' 58.502" 1272' 1127' 7.3 12.5 NOTES: 1. COORDINATES SHOWN HEREON ARE ALASKA STATE PLANE, ZONE 4, NAD 83. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL (B.P.M.S.L.) ALPINE MODULE: CD30 UNIT: CD Conoc.Phillips ALPINE PROJECT CD -3 WELL CONDUCTORS Alaska, Inc. AS -BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: req 05- 03- 03 -1A -2 3 -17 -05 , - 111 2 OF 3 7 REV DATE BY CK APP 1 DESCRIPTION REV DATE BY APP DESCRIPTION 4 4/8/07 AG DB C.A. ISSUED PER K07041ACS 5 4/13/09 AG DB C.A. UPDATED PER K090003ACS 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; CD3 -X98, CDX -99, CD3 -X19, CD3 -X20, CD3 -X21, CD3 -X22, CD3 -X23, CD3 -X24, 4/13/09, FB 2009.05 PGS. 70 -72. SURVEYOR'S CERT1FICATE . �������►��� I , I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED � •• .. �• AS-BUILT REPRESENTS TS OF ALASKA, THAT THIS SS- PRACTICE LAND BUIILT R A E SURVEY MADE BY OR UNDER MY DIRECT �� �,• �� ♦� SUPERVISION, THAT THE MONUMENTS SHOWN HEREON ACTUALLY EXIST i *: =• �� . •°•: *�♦ AS DESCRIBED, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE • 49th �� ♦ CORRECT. • • • % DATE: REGISTRATION NO. LS -5077 • • • A T Donald G. Bruce e o ♦�� s No. LS -5077 . k' �i`�F• °• ••.. .... ... KUUKPIK v*. PRoF I..CMF 730 E51etAw. • Anchorage, Alaska 99503 • (907)2 Alpine Office ( 90 7 ) 510-0]J9 Alpine Survey Office ALPINE MODULE: CD30 UNIT: CD C.noc.Phillips ALPINE PROJECT CD -3 WELL CONDUCTORS Alaska, Inc. AS -BUILT LOCATIONS CADD FILE NO. DRAWING NO: r ; PART: REV: 05-03-03-1A-3 3 -17 -05 CEa D. O 111 3 OF 3 5 Page 1 of 2 • Schwartz, Guy L (DOA) From: Winfree, Michael Alex (Jr.) [ Michael .A.Winfree @conocophillips.com] Sent: Thursday, January 07, 2010 7:24 AM To: Schwartz, Guy L (DOA) ( ) i cementing PTD 210 -001 Subject: RE: 7 intermediate ( 210-001) Guy, Below is the revised cement program for the 7" Intermediate casing. 7" Intermediate Casing run to 12,786' MD / 6,924' TVD First Stage: Cement the first 1000' from 12,786' — 11,700' MD with 15.8 ppg. Assume 40% excess annular volume. Tail Slurry: 230 sx Class G + 0.2% D046 antifoamer, + 1%S2, 0.2 %D46, 0.3 %D65 accelerator @ 15.8 PPG yielding 1.17 ft /sk Please let me know if you need additional information regarding the 7" cement job. Thanks, -Mike Mike A. Winfree 907 265.6820 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Wednesday, January 06, 2010 2:20 PM To: Winfree, Michael Alex (Jr.) Subject: RE: 7" intermediate cementing (PTD 210 -001) If it is just a depth typo you can email them to me and I can change the depths in my PTD copies. You don't have to reissue anything. Guy Schwartz Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Winfree, Michael Alex (Jr.) [mailto:Michael.A.Winfree @conocophillips.com] Sent: Wednesday, January 06, 2010 1:57 PM To: Schwartz, Guy L (DOA) Subject: RE: 7" intermediate cementing (PTD 210 -001) Guy, will address those typos in the cement section of the permit and get the corrections to you as soon as possible. 1/7/2010 Page 2 of 2 • Thanks, Mike A. Winfree 907 265. From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Wednesday, January 06, 2010 11:09 AM To: Winfree, Michael Alex (Jr.) Subject: 7" intermediate cementing (PTD 210 -001) Mike, On cementing program page regarding the 7" intermediate there appears to be a few typo's. Can you address this ?? I think you are planning on cementing the bottom 1000' of the 7" plus using the stage collar to cement the Qannuk. I think it is just a matter of some depths not being correctly listed. Guy Schwartz Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 1/7/2010 • • Page 1 of 1 Schwartz, Guy L (DOA) From: Winfree, Michael Alex (Jr.) [Michael.A.Winfree @conocophillips.com] Sent: Wednesday, January 06, 2010 1:57 PM To: Schwartz, Guy L (DOA) Subject: RE: CD3 -109 status / CD3 -106L1 (PTD 210 -002) Guy, The CD3 -109 well bore is suspected to have collapsed somewhere between 13,000'MD and 14,000'MD along the horizontal leaving - 3,300'MD of the lateral still producing. We plan to continue to produce out of the CD3 -109 well bore with CD3 -106L1 in place. Please let me know if you need additional information about the CD3 -109 wellbore collapse. Thanks, Mike A. Winfree 907.265.6820 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Wednesday, January 06, 2010 1:20 PM To: Winfree, Michael Alex (Jr.) Cc: Walker, Jack A Subject: CD3 -109 status / CD3 -106L1 (PTD 210 -002) Mike, I would assume that CD3 -106L1 is basically a replacement welibore for CD3 -109 .... Apparently the welibore is suspected to have collapsed in 109. Can you elaborate at all ?? What are the plans for CD3 -109 ... ?? Guy Schwartz Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 1/6/2010 • • TRANSMITTAL LETTER CHECKLIST WELL NAME Colville River Unit CD3 -106L1 PTD# 2100020 X Development Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: COLVILLE RIVER POOL: COLVILLE RIVER, FIORD OIL POOL 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 Colville River Unit CD3 -106, Permit No. 2100010, X (If last two digits in API No. 50- 103 - 20611- 00 -00. Production should continue to be API number are reported as a function of the original API number stated above. between 60 -69) PILOT HOLE In accordance with 20 AAC 25.005(0, all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. 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 program. Rev: 1/11/2008 .r.*.'1 Field & Pool COLVILLE RIVER, FIORD OIL - 120120 Well Name: COLVILLE RIV FIORD CD3 -106L1 Program DEV Well bore se PTD#: 2100020 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type DEV / PEND GeoArea 890 - -_ Unit 50360 On /Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA 12 Lease number appropriate Yes Lateral wellbore: top productive interval in ADL0364471; TD in ADL0364470 3 Unique well name and number Yes 4 Well located in a defined pool Yes COLVILLE RIVER, FIORD OIL - 120120, governed by CO 569. 1 5 Well located proper distance from drilling unit boundary Yes Conservation Order No. 569 contains no spacing restrictions with respect to drilling unit boundaries. 6 Well located proper distance from other wells Yes Conservation Order No. 569 has no interwell spacing restrictions. 7 Sufficient acreage available in drilling unit Yes Conservation Order No. 569 has no interwell spacing restrictions. Wellbore will be more than 500' from 8 If deviated, is wellbore plat included Yes external property line where ownership or landownership changes (-5,100' from external boundary of 9 Operator only affected party Yes the Colville River Unit). 10 Operator has appropriate bond in force Yes 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes SFD 1/5/2010 1113 Can permit be approved before 15 -day wait Yes 14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For NA Or 15 All wells within 1/4 mile area of review identified (For service well only) NA 1 16 Pre - produced injector: duration of pre - production less than 3 months (For service well only) NA 17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A -D) NA 18 Conductor string provided Yes Engineering 19 Surface casing protects all known USDWs NA No Aquifers in CRU area, AIO 30 Conclusion 3 20 CMT vol adequate to circulate on conductor & surf csg Yes 21 CMT vol adequate to tie -in long string to surf csg No 22 CMT will cover all known productive horizons Yes Qannik Zone to be cemented with 2nd stage during intermediate casing job. 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig equipped with steel tanks. All waste to approved disposal wells. 25 If a re- drill, has a 10 -403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes Proximity analysis performed. CD3 -109 is 135' away at 15500' md. 27 If diverter required, does it meet regulations NA Diverter waiver requested. No shallow gas issues in CRU 20 AAC 25.035(h)(2) Appr Date 1 28 Drilling fluid program schematic & equip list adequate Yes Max formation pressure= 3574 psi (9.9 ppg EMW) Will drill with 10 ppg mud GLS 1/6/2010 1 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP = 2886 psi Will test BOP to 3500 psi. 3 Ill 1 Choke manifold complies w /API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable No H2S not reported at CD3. Rig has sensors and alarms . 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures Yes None expected, but H2S and gas detectors will be used during drilling. Mitigation measures in Hazards Geology 36 Data presented on potential overpressure zones Yes Summary. Expected reservoir pressure is 10.0 ppg EMW; will be drilled with 10.0 ppg mud. Appr Date 37 Seismic analysis of shallow gas zones NA SFD 1/5/2010 1 38 Seabed condition survey (if off - shore) NA 39 Contact name /phone for weekly progress reports [exploratory only] NA Geologic Engineering b / Date Lateral production wellbore that will closely approach offset well CD3 -109, which reportedly has collapsed casing (see Well Commissioner: Date: Commissioner: Date ' omm Proximity Risks in drilling program. Well will comply with spacing requirements of CO 569. C*(4, 1 'i ' ii,_ , -8 -/0 • Well History File APPENDIX Info r ration 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. Sperry -Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Mar 25 06:58:51 2010 Reel Header Service name LISTPE Date 10/03/25 Origin STS Reel Name UNKNOWN Continuation Number 01 Previous Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Tape Header Service name LISTPE Date 10/03/25 Origin STS Tape Name UNKNOWN Continuation Number 01 Previous Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Colville River Unit MWD /MAD LOGS WELL NAME: CD3 -106L1 API NUMBER: 501032061160 OPERATOR: ConocoPhillips Alaska Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 25- MAR -10 JOB DATA MWD RUN 2 MWD RUN 3 MWD RUN 4 JOB NUMBER: -MW- 0006991490 -MW- 0006991490 -MW- 0006991490 LOGGING ENGINEER: P. WALKER P. ORTH P. ORTH QPERATOR WITNESS: D. LUTRICK L. HILL L. HILL MWD RUN 5 MWD RUN 6 JOB NUMBER: -MW- 0006991490 -MW- 0006991490 LOGGING ENGINEER: P. ORTH P. WALKER OPERATOR WITNESS: G. WHITLOCK G. WHITLOCK SURFACE LOCATION SECTION: 5 TOWNSHIP: 12N RANGE: 5E FNL: 3921 FSL: FEL: 777 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 41.40 GROUND LEVEL: 13.40 WELL CASING RECORD OPEN HOLE CASING DRILLERS Oc -- oba ��' G(g41 . . BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.750 9.625 2725.0 2ND STRING 6.125 7.000 12986.0 3RD STRING PRODUCTION STRING REMARKS: 1. THIS LATERAL IS A PLANNED OPENHOLE SIDETRACK, EXITING CD3 -106 AT 13,270'MD/6955'TVD. 2. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 3. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). ONLY INVERT /REVERT INTERVALS GREATER THAN 30' TVT ARE INCLUDED ON TVD PLOTS. 4. MWD RUN 1 COMPRISED DIRECTIONAL AND AT -BIT INCLINATION (ABI) WITH ELECTROMAGNETIC WAVE TELEMETRY (EM) - NO DATA ARE PRESENTED. 5. MWD RUNS 2 -6 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER - MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE -4 (EWR -P4), PRESSURE WHILE DRILLING (PWD), AND DRILLSTRING DYNAMICS SENSOR (DDSr). MWD RUNS 2,3 ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN) AND AZIMUTHAL LITHO- DENSITY (ALD). POROSITY CURVES ARE NOT INCLUDED IN THIS PRESENTATION - SEE CD3 -106 LOGS FOR POROSITY DATA. MWD RUNS 2,4 -6 ALSO INCLUDED GEOPILOT ROTARY - STEERABLE BHA (GP). 6. BECAUSE OF INTERMITTENT SPIKES, EWR DATA FROM FINAL TD TO 15659.5'MD/ 6873.7'TVD, ACQUIRED WHILE REAMING (ROTATING) OUT OF THE HOLE, WERE SUBSTITUTED FOR DRILLING DATA ON THE FINAL LOGS. DATA GAPS IN THIS INTERVAL ARE DUE TO THE EDITING -OUT OF NON- REPEATING, SPURIOUS SPIKES. DRILLING EWR DATA WITH INTERMITTENT SPIKING BETWEEN 15659.5'MD AND 15240'MD/6886.7'TVD +/- WERE NOT REPLACED BECAUSE NO USEABLE MAD DATA WERE ACQUIRED. DATA QUALITY IN SPIKEY INTERVALS IS SUSPECT. 7. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIRE- MENTS AT CONOCO - PHILLIPS /VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR THE DRILL SITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 20Q5. 8. MWD RUNS 1 -6 REPRESENT WELL CD3 -106 L1 WITH API #: 50 -103- 20611 -60. . . THIS WELL REACHED A TOTAL DEPTH (TD) OF 16,193'MD/6847'TVD. SROP = RATE OF PENETRATION WHILE DRILLING. SGRC = DUAL GAMMA RAY COMBINED. SEXP = EWR PHASE -4 9" 2 MHZ PHASE SHIFT RESISTIVITY. SESP = EWR PHASE -4 15" 2 MHZ PHASE SHIFT RESISTIVITY. SEMP = EWR PHASE -4 27" 2 MHZ PHASE SHIFT RESISTIVITY. SEDP = EWR PHASE -4 39" 1 MHZ PHASE SHIFT RESISTIVITY. SFXE = FORMATION EXPOSURE TIME EWR - PHASE -4. 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 SMOTHED WITH A 1.1 FT WINDOW. 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 10/03/25 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2701.0 16144.0 FET 2715.0 16151.0 RPX 2715.0 16151.0 RPM 2715.0 16151.0 RPD 2715.0 16151.0 RPS 2715.0 16151.0 ROP 2735.5 16193.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH MERGED DATA SOURCE PBU TOOL COPE BIT RUN NO MERGE TOP MERGE BASE MWD 2 2701.0 12855.0 MWD 3 12855.0 12997.0 MWD 4 12997.0 13270.0 MWD 5 13270.5 14131.0 MWD 6 14131.0 16193.0 $ REMARKS: MERGED MAIN PASS. # Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down 1 411 411 Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 ` RPX MWD OHMM 4 1 68 16 5 FET MWD HR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2701 16193 9447 26985 2701 16193 RPD MWD OHMM 0.06 2000 11.8541 26685 2715 16151 RPM MWD OHMM 0.1 1862.64 8.85831 26680 2715 16151 RPS MWD OHMM 0.12 1821.84 7.56712 26682 2715 16151 RPX MWD OHMM 0.13 1769.08 6.77717 26682 2715 16151 FET MWD HR 0.22 297.71 2.25124 26764 2715 16151 GR MWD API 19.39 382 100.129 26887 2701 16144 ROP MWD FPH 0.04 469.79 127.918 26916 2735.5 16193 First Reading For Entire File 2701 Last Reading For Entire File 16193 File Trailer Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/03/25 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.002 Physical EOF File Header Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/03/25 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 , FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH • 111 411 SGRC 2701.0 12850.5 SEDP • 2715.0 12804.0 SEMP 2715.0 12804.0 SEXP 2715.0 12804.0 SESP 2715.0 12804.0 SFXE 2715.0 12804.0 SROP 2735.5 12855.0 LOG HEADER DATA DATE LOGGED: 03- FEB -10 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88,20 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 12855.0 TOP LOG INTERVAL (FT): .2735.0 BOTTOM LOG INTERVAL (FT): 12855.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 56.3 MAXIMUM ANGLE: 80,8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132482 EWR4 ELECTROMAG. RESIS. 4 127479 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT): 2725.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB /G): 9.65 MUD VISCOSITY (S): 41.0 MUD PH: 9.9 MUD CHLORIDES (PPM): 750 FLUID LOSS (C3): 5.3 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 2.400 78.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.250 155.5 MUD FILTRATE AT MT: 2.200 78.0 MUD CAKE AT MT: 2.000 78.0 # --- NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: # I Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value - 999 Depth Units Datum Specification Block sub- type...0 I t • III Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2701 12855 7778 20309 2701 12855 RPD MWD020 OHMM 0.06 2000 9.61155 20179 2715 12804 RPM MWD020 OHMM 0.1 1862.64 6.93638 20179 2715 12804 RPS MWD020 OHMM 0.12 1821.84 5.89145 20179 2715 12804 RPX MWD020 OHMM 0.49 1769.08 5.69545 20179 2715 12804 FET MWD020 HR 0.22 98.7 1.15479 20179 2715 12804 GR MWD020 API 36.8 382 117.972 20300 2701 12850.5 ROP MWD020 FPH 0.19 469.79 145.119 20240 2735.5 12855 First Reading For Entire File 2701 Last Reading For Entire File 12855 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/03/25 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.003 Physical EOF File Header Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/03/25 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SFXE 12804.5 12932.0 SEXP 12804.5 12932.0 SEDP 12804.5 12932.0 SESP 12804.5 „,12932.0 SEMP 12804.5 12932.0 SGRC 12851.0 12948.5 SROP 12855.5 12997.0 ` i • $ LOG HEADER DATA DATE LOGGED: 06- FEB -10 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.20 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 12997.0 TOP LOG INTERVAL (FT): 12855.0 BOTTOM LOG INTERVAL (FT): 12997.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 81.5 MAXIMUM ANGLE: 84.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10718520 EWR4 ELECTROMAG. RESIS. 4 96540 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT): 2725.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB /G): 10.70 MUD VISCOSITY (S): 46.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 2000 FLUID LOSS (C3): 5.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.200 78.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.280 132.8 MUD FILTRATE AT MT: 1.600 78.0 MUD CAKE AT MT: 1.800 78.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 6,$ 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 111 411 FET MWD030 HR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12804.5 12997 12900.8 386 12804.5 12997 RPD MWD030 OHMM 6.66 31.07 14.6677 256 12804.5 12932 RPM MWD030 OHMM 6.17 31.96 13.943 256 12804.5 12932 . RPS MWD030 OHMM 4.68 31.53 13.2152 256 12804.5 12932 RPX MWD030 OHMM 4.01 29.75 12.733 256 12804.5 12932 ' FET MWD030 HR 1.28 88.54 27.3082 256 12804.5 12932 GR MWD030 API 35.84 88.3 50.8034 196 12851 12948.5 ROP MWD030 FPH 0.04 353.51 111.947 284 12855.5 12997 First Reading For Entire File 12804.5 Last Reading For Entire File 12997 File Trailer Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/03/25 Maximum Physical Record 65535 File Type LO Next File Name STSLIB4O04 Physical EOF File Header Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/03/25 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SEXP 12932.5 13270.0 SEMP 12932,5 13270.0 SESP 12932.5 13270.0 SEDP 12932.5 13270.0 SFXE 12932.5 13270.0 SGRC 12949.0 13270.0 SROP 12997.5 13270.0 $ LOG HEADER DATA DATE LOGGED: ,,; 18- FEB -10 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.20 r 411 411 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 13270.0 TOP LOG INTERVAL (FT): 12997.0 BOTTOM LOG INTERVAL (FT): 13270.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.0 MAXIMUM ANGLE: 95.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 151107 EWR4 Electromag Resis. 4 173235 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 12986.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB /G): 10.20 MUD VISCOSITY (S): 44.0 MUD PH: 8.8 MUD CHLORIDES (PPM): 97000 FLUID LOSS (C3): 2.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .120 85.0 MUD AT MAX CIRCULATING TERMPERATURE: .060 166.1 MUD FILTRATE AT MT: .070 85.0 MUD CAKE AT MT: .140 85.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12932.5 13270 13101.3 676 12932.5 13270 RPD MWD040 OHMM 0.21 2000 43.6979 567 12932.5 13270 RPM MWD040 OHMM 0.7 1463.3 19.7009 567 12932.5 13270 RPS MWD040 OHMM 0.15 1068.93 14.1698 567 12932.5 13270 RPX MWD040 OHMM 0.13 16.28 10.8053 567 12932.5 13270 FET MWD040 HR 0.41 157.05 11.975 567 12932.5 13270 GR MWD040 API 19.39 52.41 40.2104 643 12949 13270 ROP MWD040 FPH 7.23 347.95 93.3633 546 12997.5 13270 First Reading For Entire File 12932.5 Last Reading For Entire File 13270 File Trailer Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/03/25 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.005 Physical EOF File Header Service name STSLIB.005 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/03/25 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE - SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SEXP 13270.5 14090.0 SFXE 13270.5 14090.0 SESP 13270.5 14090.0 SEMP 13270.5 14090.0 SGRC 13270.5 14083.0 SEDP 13270.5 14090.0 SROP 13270.5 14131.0 LOG HEADER DATA DATE LOGGED: 27- FEB -10 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.20 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 14131.0 TOP LOG INTERVAL (FT): 13270.0 BOTTOM LOG INTERVAL (FT): 14131.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.6 R C 1 1 111 III • MAXIMUM ANGLE: 95.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 184054 EWR4 Electromag Resis. 4 141232 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 12986.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB /G): 10.50 MUD VISCOSITY (S): 48.0 MUD PH: 9.2 MUD CHLORIDES (PPM): 115000 FLUID LOSS (C3): 2.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .100 80.0 MUD AT MAX CIRCULATING TERMPERATURE: .050 159.1 MUD FILTRATE AT MT: .040 80.0 MUD CAKE AT MT: .120 80.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 � FET MWD050 HR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13270.5 14131 13700.8 1722 13270.5 14131 RPD MWD050 OHMM 6.95 18.68 13.432 1640 13270.5 14090 , RPM MWD050 OHMM 4.41 18,,,66 12.5449 1640 13270.5 14090 RPS MWD050 OHMM 2.77 18.1 11.6416 1640 13270.5 14090 RPX MWD050 OHMM 2.08 16.19 9.59358 1640 13270.5 14090 FET MWD050 HR 0.56 297.71 2.79173 1640 13270.5 14090 GR MWD050 API 34.03 60.37 47.7671 1626 13270.5 14083 ROP MWD050 FPH 0.06 220.97 67.1645 1722 13270.5 14131 First Reading For Entire File 13270.5 Last Reading For Entire File 14131 File Trailer Service name STSLIB.005 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/03/25 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.006 Physical EOF File Header Service name STSLIB.006 Service Sub Level Name Version Dumber - 1 0 0 Date of Generation 10/03/25 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SGRC 14083.5 16144.0 SEMP 14090.5 16151.0 SESP 14090.5 16151.0 SEDP 14090.5 16151.0 SFXE 14090.5 16151.0 SE-XP 14090.5 16151.0 SROP 14131.5 16193.0 LOG HEADER DATA DATE LOGGED; 02- MAR -10 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.20 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 16193.0 TOP LOG INTERVAL (FT): 14131.0 BOTTOM LOG INTERVAL (FT): 16193.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 90.1 MAXIMUM ANGLE: 96.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 151107 EWR4 Electromag Resis. 4 156404 $ M n 111 III # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 12986.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB /G): 10.55 MUD VISCOSITY (S): 51.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 95000 . FLUID LOSS (C3): 3.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) ` MUD AT MEASURED TEMPERATURE (MT): .080 76.0 MUD AT MAX CIRCULATING TERMPERATURE: .040 166.1 MUD FILTRATE AT MT: .020 76.0 MUD CAKE AT MT: .120 76.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS--MWD060 OHMM 4 1 68 12 4 RPX MWD060 OHMM 4 1 68 16 5 FET MWD060 HR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MWD060 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 14083.5 16193 15138.3 4220 14083.5 16193 RPD MWD060 OHMM 3.15 29.12 17.763 4043 14090.5 16151 RPM MWD060 OHMM 4.11 25.34 15.1206 4038 14090.5 16151 RPS MWD060 OHMM 2.17 27.4 12.9982 4040 14090.5 16151 RPX MWD060. OHMM 1.8 31.39 10.0941 4040 14090.5 16151 FET MWD060 HR 0.46 31.86 4.5101 4122 14090.5 16151 GR MWD060 API 32.6 55.92 44.6009 4122 14083.5 16144 ROP MWD060 FPH 0.2 273.19 74.5437 4124 14131.5 16193 First Reading For Entire File 14083.5 Last Reading For Entire File 16193 410 411 File Trailer Service name STSLIB.006 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/03/25 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.007 Physical EOF Tape Trailer Service name LISTPE Date 10/03/25 Origin STS Tape Name UNKNOWN Continuation Number 01 Next Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name LISTPE Date 10/03/25 Origin STS Reel Name UNKNOWN Continuation Number 01 Next Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
