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Home My WebLink About210-001 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 13, 2023 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Jessie Chmielowski: Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells were found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitors, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Brennen Green or Roger Mouser at 907-659-7506, if you have any questions. Sincerely, Brennen Green ConocoPhillips Well Integrity Field Supervisor Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927@conocophillips.com Reason: I am the author of this document Location: Date: 2023.04.13 11:34:18-08'00' Foxit PDF Editor Version: 12.0.1 Brennen Green ConocoPhillips Alaska Inc.Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-offReport of Sundry Operations (10-404)Alpine FieldWell Name API # PTD #Initial top of cementVol. of cement pumpedFinal top of cementCement top off date Corrosion inhibitorCorrosion inhibitor/ sealant dateft bbls in galCD3-106 5010320611-0000 210-001 N/APost Conductor Ext10.75" 4/5/2022 2 4/12/2023CD3-117 5010320596-0000 209-026 N/APost Conductor Ext13" 4/5/2022 3 4/12/2023CD3-127 5010320634-0000 211-005 18' 1.0 8" 4/9/2022 1 4/12/2023CD3-302A 5010320522-0100 210-035 N/APost Conductor Ext9" 4/5/2022 2 4/12/2023CD4-214 5010320537-0000 206-145 22' 8" 1.6 7" 4/9/2022 1.5 4/12/2023CD4-319 5010320516-0000 205-148 22' 3" 1.5 7" 4/9/2022 1.5 4/12/2023Date 04/13/2023CD3 & CD4 PadsCD3-1065010320611-0000210-001N/A10.75"4/5/202224/12/2023Post Conductor Ext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" # "$ %&$ ' () * +$! , *' -. !/ 0"!! 1. -. 23243,/3 5- / " * ' ,++6 ! +00+ ! ( ' ,++6 233+ +00+ +,76 8 7713#64439&437#,+4198' : +143#+1319&+1,#+00+9:' - ;&& / % :- *& / 2 <; * $ - / 7 < 4" % ' * " () * ' . * +" % = "'. ( ' = =$!>?.?= *!!5 () 8% !8% ; ( ( % @ 2+7#7,02 2 ! ! ( ( 3, 26,4 +166 +00+ +A 1+24A ,A ,+9 2+1+9 $ . 62129 4 ' ! 7234 5 ! % ! 21+9 6 -< 23243,3&243,&B24207/ 42+ = #8 ,37 ; ;! . '.7+66,3&7+66,&7,234 77,29#,++698' ,$* * *% !5 7+ 6 ?'7#3+ (.C .C$.!'=!( :$!88$$! 23#33 43#37#23+#33#33 >% D)337+3&&C11437 6" D"% 676 ' * $E ' 2022011 704 #D % 64A 210+ "$!>"= 7024 " #D ! 3, 2,24 ,++6 " 3#636 752323 " 73* By Samantha Carlisle at 9:38 pm, Feb 24, 2021 Mark Shulman Digitally signed by Mark Shulman Date: 2021.02.24 17:10:25 -09'00' DSR-2/25/21 RBDMS HEW 2/25/2021 Alpine Oil SFD 2/26/2021 SFD 2/26/2021VTL 3/3/21 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 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 210-001 50-103-20611-00-00 ADL 364470, 364471, 372105 CD3-106 None Colville River Field/Fiord Oil Pool 17664 6886 None None 17664 6886 12006 6734 Conductor 78' 16" 107 107 Surface 2696' 9.625" 2725 2475 Intermediate 12961' 7" 12986 6944 Liner 4292' 4.5" 17664 6886 13390 - 17659 6950 - 6886 see attached see attached see attached 13372' - 17664' 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 09:13:19 -09'00' DSR-11/10/2020 SFD 11/9/2020 VTL 2/24/21 RBDMS 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 VTL 4/10/20 DSR-4/9/2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS NOV 13 2019 1. Operations Abandon Plug Perforations Fracture Stimulate Ll Pull Tubing LJ P6VMs W twn 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 ❑ Exploratory ❑ Stratigraphic ❑ Service ❑ 210-001 3. Address: PO BOX 100360 6. API Number: Anchorage, AK 99510 50-103-20611-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 364470, 364471, 372105 CRU CD3 -106 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 17664 feet Plugs measured None feet true vertical 6886 feet Junk measured None feet Effective Depth measured 17664 feet Packer measured 12006 feet true vertical 6886 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 4292' 4.5" 17664' 6886' Perforation depth Measured depth Slotted liner from 13390' - 14550' and 15031' -176591 True Vertical depth 6950' - 6909' and 6917' - 6886' 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): 13372'-17664' 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 AAC 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations El Exploratory ❑ Development 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 Engineer Contact Email: Kaylie.B.Plunkett23cop com Authorized Signature: Date: 11-11-101 Contact Phone: 265-6450 V'TLf��/L///rro/! /7� Form 10-404 Revised 4/2017 A�LIi``"'(ld /l"/ RBDMS�`NOV 142019 Submit Original Only CD3 -106 and CD3 -106L1 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 bbls 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 -1061-1) C'gi'c 0,6 3-(C& Regg, James B (CED) P-6 Z-1 Occ I c From: NSK Prod Engr Specialist <n1139@conocophillips.com> Sent: Thursday, October 10, 2019 4:23 PM To: Regg, James B (CED) f� Cc: NSK Fieldwide Operations Supt; Brooks, Phoebe L (CED) Subject: FW: C133-106 Revised August SVS Test flow tubing pressure Attachments: SVS CRU CD3 08-22-19 MISC- Revised.xlsx Jim, as we discussed in talking with Alpine it appears that the operator recorded the FTP after he shut in the choke instead of before. The actual FTP should have been around 689 psi instead of 852. With the LPP Set PSI being 200 psi and the LPP Trip PSI being 199 psi this well would have passed its SVS test on 8/22/19. 1 have enclosed a corrected SVS report to update your records with. Please reference the graph below. Let me know if you need any further info regarding this matter Thanks, Darrell Humphrey 907-659-7535 From: Hume, Shane S <Samuel.S.Hume@conocophillips.com> Sent: Thursday, October 10, 2019 3:25 PM To: NSK Prod Engr Specialist <n1139@conocophillips.com> Subject: CD3 -106 e 0 N N itl Q B 0 rn E U 0 ro s c 3I a hla Y '> MMv nr lrF IIIL nl,uerY LR 9.19H -Id :II -uLz-v Irl If.��pl 1 1I130 B 11-I!tIY< 85T citor_ c1u v1- In n w:ef n. IInnr a IP ru 1.0 u1 '1- Fll S 6 IL LIS r19SY f.I OUR AM, PII 111 L L 1,1 LILUTPT I Wl' L] '1! Lli IRAL O UP C,LiNO dl1 PRF IUll IfNNIX _I_M1 1111Ni' )9. EBGGIIIW f I•,r ML STATU3 ufl .. ON too• —_.. ___i _. _ ____. _ _.__ ._.� into. OV%NASI I`," yP CU Al rnu, PACE TIN[ I. Rio OdWEPAL PUP.PC,SL O.RU � EVENT AT rlca TIMF x2Ro. CPFA[Y w i 1. AITMICALF LAR .IMTC AT PICA. TINY- ORIFICE A R� sn YxeF2E 0ET PROTECT ION Ni .l-AYI. 680 JJYL}' S0L 200, xeR o.BO i CRMTY sol. IF CREATL EPona0.92e' r2-Aua-lo BB;or o. ■ p0.92.R,.MIZE10110 �RiQ��en2 III �umtceN Puode.eTs ■�If n,,. Ir,. fff11Rl FIN. R r �''Ji'.1 1' IS-n. P,ll. YM .: dKi-f/ of l! ft 104 A f Ic MIIP.q'1 HOUR M INtiTANT T_t_eerl A M VNC:: 6.i1.. 761, A �NF 1.L FVCM`: �4F1.1. $YKIW IS �A'ARA[YIN .. PHCY/NE$i NYLL ■lee,l r �Wf SIINNARY __ MWEI1. HVTCR MTV:"1 'A,` ]TCB] `AROB NOTE- . 1GYINILF. TRLNB f. GC 03—(e-�, Re9g, James B (CED) f z10(1)lco From: NSK Prod Engr Specialist <n1139@conocophil1ips.com> Sent: Monday, October 7, 2019 5:01 PM + (b i G To: Regg, James B (CED) / II Subject: CD3 -106 Retest Trend l Attachments: CD3 -106 2019-10-07_16-47-20.png Mr. Regg It's trended with the choke position and a pick point for reference. Regards, Doug Doug McMullen /Darrell Humphrey Production Engineering Specialist ConocoPhillips Alaska Ph: 907.659.7535 � Pg: 924 1 Mail: NSK 69 1 UJLa — lg7/i9 w Env V H W n- 0 n ' < _ U: a n ki M U n. � C n F G7 P .a n nF a a � a Q � H 7 z W Z z:z Z w w F� cc a H H U m ,y m E V � N m A o V � � O G7 G37 n ki M a w w N r -i Z O w � o a F w w H a v: w a a � a Q � H 7 Z z:z Z w w cc a H H m ,y m E V � N m A a H O V W V � � O G7 Tx a Regg, James B (CED) From: NSK Prod Engr Specialist <nl l39@conocophiIIips.com> Sent: Monday, October 7, 2019 4:19 PM To: Regg, James B (CED) Subject: CD3 -106 Retest Attachments: SVS CRU CD3 10-06-19 Retestxls Mr. Regg Attached is the retest for CD3 -106 as requested. Regards, Doug Doug McMullen /Darrell Humphrey Production Engineering Specialist ConocoPhillips Alaska Ph: 907.659.7535 1 Pg: 924 1 Mail: NSK 69 417 i 3 \ \ ;}u / ) 7:3 k ] a 42ki j }j} § : 3 k ! ¥ 2 $ \\) Q J / \\\ )k\ &,A & 3 \ \ Regg, James B (CED) From: Sent: Regg, James B (CED) Friday, October 4, 2019 3:26 PM ��( qG� j0 I�I To: NSK Prod Engr Specialist j l Cc: Brooks, Phoebe L (CED); DOA AOGCC Prudhoe Bay Subject: SVS CD3 -106 8/22/2019 Attachments: SVS CRU CD3 08-22-19 MISC.xlsx Attached is a copy of the submitted test report for CRU CD3 -106. The LPS should have been shown as a Fail (Code 3 - Tripped Below Required Trip Pressure); reported trip was 199 psi; required trip was 213 psi (25% of Flowing Tubing Pressure). Retest required unless the reported pressures were incorrect. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such Information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907- 793-1236 or iim.reee@alaska.gov. u / &#a Pn ) a- )}� « k��~ }\ a {!) ,� .. & u Pn « k��~ }\ a ,� .. & <}f ! « }\ a o & STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS p 1. Operations Abandon LJ Plug Perforations LJ Fracture Stimulate Ll Pull Tubing Operations shutdown`Li 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 ❑ Exploratory ❑ Stratigraphic ❑ Service ❑ 210-001 3. Address: PO BOX 100360 6. API Number: Anchorage, AK 99510 50-103-20611-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 364470, 364471, 372105 CRU CD3 -106 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 17664 feet Plugs measured None feet true vertical 6886 feet Junk measured None feet Effective Depth measured 17664 feet Packer measured 12006 feet true vertical 6886 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 4292' 4.5" 17664' 6886' Perforation depth Measured depth Slotted liner from 13390'- 14550' and 15031' - 17659' True Vertical depth 6950' -6909' and 6917'-6886' 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: Cameo TRMAXX-5E, 2063' MD, 1995' TVD, locked out and WRDP installed 12. Stimulation or cement squeeze summary: Intervals treated (measured): 13372'-17664' 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 I Water -Bbl Casing Pressure I Tubing Pressure Prior to well operation: 1 365 2958 1 3063 1 1857 455 Subsequent to operation: Ino well test yet due to Test Separator maintenance 14. Attachments (required per 20 AAC 25.070, 25.071, s 25.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ i6. Well Status after work: Oil [2] 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: Kaylle.B.Plunkett0coo.com Authorized Signature: Ajr..`.V6 Date: 3-15- f Contact Phone: 265-6450 u VTL 31/91/`f Form 10-404 Revised 4/2017 �( 3/w /9' ROMS.L�NMAR 19 2019 Submit Original Only CD3 -106 and CD3 -3061.1 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 L1) • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSfON 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 El Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other:Scale Inhibitor Treatment D 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory ❑ 210-001 3.Address: Stratigraphic❑ Service ❑ 6.API Number: P.O. Box 100360, Anchorage,AK 99510 50-103-20611-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 364470, 364471, 373105 CRU CD3-106 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 17664 feet Plugs measured None feet true vertical 6886 feet Junk measured None feet Effective Depth measured 17664 feet Packer measured 12006 feet true vertical 6886 feet true vertical 6734 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 107' 107' Surface 2696' 9.625" 2725' 2475' RECEIVED Intermediate 12961' 7" 12986' 6944' Production Liner 4292' 4.5" 17664' 6886' MAR 0 9 2010 Perforation depth Measured Depth: Slotted liner from 13390'- 14550'and 15031'- 17659' AOGCC True Vertical Depth: 6950'-6909'and 6917'-6886' SCANNED 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): 13372'- 17664' 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 PAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El ExploratoryD DevelopmentD Service ❑ Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 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 /,A-n5 J Sp 7 Email Kaylie.B.PlunkettCc�cop.com Printed Name Kaylie Plunkett Title Production Engineer Signature 'i - Phone 265-6450 Date 3/-1. ix VTL ,3))4, /w � 0141/ RBnnIS 1,‘, �:a��° - 9 2r18 Form 10-404 Revised 5/2015 Submit Original Only • • 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) STATE OF ALASKA • A•KA OIL AND GAS CONSERVATION COMMISSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS DEC 1 9 2017 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ ii, O.,eGra,'on shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ ` ')r. -.;Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other:Scale Inhibitor Treatment 0 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ❑✓ Exploratory ❑ 210-001 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O. Box 100360,Anchorage,AK 99510 50-103-20611-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 364470, 364471, 373105 CRU CD3-106 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 17664 feet Plugs measured None feet true vertical 6886 feet Junk measured None feet Effective Depth measured 17664 feet Packer measured 12006 feet true vertical 6886 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 4292' 4.5" 17664' 6886' �tiEj I i+r ;, Perforation depth Measured Depth: Slotted liner from 13390'- 14550'and 15031'- 17659' True Vertical Depth: 6950'-6909'and 6917'-6886' 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): 13372'- 17664' 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 2 Exploratory❑ Development l] 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@cop.com Printed Name Kaylie PlunkettlupTitle Production Engineer ---riSignature .l".r'r.....r�... Phone 265-6450 Date 12-($-17 Vri 11 // s' Form 10-404 Revised 5/2015 =l8' Submit Original Only • • 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) • , WNS 9OD CD3-106 Conocof hillips 4 Well Attributes Max Angle&MD TD, Alaska,Inc, WellboreAPl/UW1 Field Name Wei!bore Status I nciPI M0111051 Act Ulm(ASS) C0111)C 'Ui0ips 501032061100 FIORD NECHELIK PROD I 95.43 16,077 06 17,664.0 kn Comment 1125(ppm) Date Annotation End Date KB.Grd(R) -Rig Release Date MULTIPLE LATERALS-CD310612/19/2017101952 NA SSSV.TROP Last WO: 28.00 3/6/2010 Venral achama9c(xlua!) Annotation Depth(ftKB) End Date Annotation ant Mod By End Date _ { Last Tag:SLM Rev Reason:GLV C/O,DRIFT TBG TO 12,450' pproven 3/162016 ........ d�'". IUNGER,zea l rf SLM(SEE NOTES) Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(MKS) Set Depth(TVD)...WULen IL..Grade Top Thread -i- CONDUCTOR 16 15.062 29.0 107.0 107.0 62.50 11-00 Welded Casing Description OD(id ID(in) Top(MB) Set Depth 011(B) Set Depth(SOD)...WULen It...Grade Top Thread :. SURFACE 95/8 8.835 29.4 2,725.4 2,475.1 40.00 L-80 BTC-Mod Casing Description OD(in) ID(in) Top(111(8) Set Depth IRKS) Set Depth(TVD)...WULen(I...Grade Top Thread 'taticcUA/4e t ,',t o'r'INTERMEDIATE 7 6.276 25.0 12,986.2 6,944.6 26.00 L-80 BTCM Casing Description OD(in) ID(In) Top(Hee) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread LINER(off L1) 4 1/2 3.958 13,372.1 17,664.0 6,886.2 12.60 L-80 SLHT I f Liner Details Nominal ID Top(ftKB) Top(TVD)(BOB) Top incl Fl Item Des Corn (in) CONDUCTOR;29.0-107.0 C 13,372.1 6,951.1 93.40 SLEEVE +BAKER HR SETTING SLEEVE 4410 Tubing Strings Tubing Description String Ma,,.ID tin) Top(ftKB) Set Depth-(H...Set Depth(TVD)(...WI Ob/R) Grade Top Connection TUBING 3112 2.992 22.0 12,1842 6,7942 9.30 L-80 EUEBrdMOD 4.5"x3.5"(Gil 112' Completion Details Safety Valve,2.0625 t.td,t Nominal ID Top((IKB) Top(NO)(ItKB) Tap Incl(') Item Des Com (in) 22.0 HANGER FMC 4 1/2"Tbg Hanger 4.500 112.5 112.5 0.09'XO Reducing XO 4.5'x3.5" 3.000 2,062.5 1,996.4 32.77 Safety Valve 3 1/2"Camco TRMAXX-5E SSSV 5,916"OD 2.812"ID 2.812 12,006.4 6,734.7 68.04 PACKER -Baker 3.5"X 7"Premier Packer 3.010 12,054.3 6,752.2 69.27 NIPPLE 3.5"HES"XN"Nipple 3.96"OD X 2.813"ID wl 2.75" 2.750 SURFACE;29.4-2,725.4--. 12,183.7 6,794.0 73.18 WLEG Wireline entry guide 2.990 Perforations&Slots GAS LIFT;4.079.5 s: Shot Dens ft Top(ND) Ulm(TVD) (shots/ Top(ftKB) Bim(KKB) MKS) (MB) Zone Date R) Type Corn 13,390.0 14,550.0 6,950.0 6,908.8 2/20/2010 32,0 SLOTS Slots 1/852.25",8 slots/row,4 rows/ft;no :. slots 3'from box/pin 15,031.2 17,659.4 6,916.6 6,886.4 2/20/2010 32.0 SLOTS Slots 1/8x2.26/,8 slots/row,4 rovrs/R;no slots 3'Iron,box/pin Mandrel Inserts St GAS LIFT,9,407.9 aL all on Top(TVD) Valve Latch Port Size TRO Run N Top(nOe) OMB) Make Model OD(in) Sec( Type Type (in) (psi) Run Date Com 1 4,679.5 3,418.3 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,935.0 3192010 2 9,487.9 5,589.7 CAMCO +KBMG 1 GAS LIFT GLV BK 0.188 1,951.0 3/9/2010 , 3 11,884.5 6,686.2 CAMCO KBMG 1 GAS LIFT OV BK 0.313 D.0 3/14/2016 GAS uFT;119045 if. _ 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) 3/20/2010 'NOTE:VIEW SCHEMATIC wlA(aska Schematic9.0 3/17/2013 NOTE:DRIFT TBG to 12,450'SLM 1 PACKER;12.006.4 0 e eel IF a NIPPLE.12,554.3 Ir d ' al WLEG.12,153.7 l ( I mtioss k k INTERMEDIATE;25,0-12906.2 SLOTS.12957.313.501 5-. .-I .- L1 LINER',12/95.2-191030 4i ✓so-.-- 44 SLOTS;13,390.0-14,550.0 SLOTS;15,031.2-17959 4 LINER(oft 91);13,3721- 17964 0 - 17664.0 STATE OF ALASKA AL OIL AND GAS CONSERVATION COMMOON ` REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon El Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing El Operations shutdown ❑ Performed: Suspend ❑ Perforate El Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool El Repair Well ❑ Re-enter Susp Well❑ Other:Scale Inhibitor Treatment 0 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development I] Exploratory ❑ 210-001 3.Address: Stratigraphic El Service El 6.API Number: P.O. Box 100360, Anchorage, AK 99510 50-103-20611-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 364470, 364471, 373105 CRU CD3-106 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 17664 feet Plugs measured None feet true vertical 6886 feet Junk measured None feet Effective Depth measured 17664 feet Packer measured 12006 feet true vertical 6886 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 RECEIVED Liner 4292' 4.5" 17664' 6886' .r t1 Perforation depth Measured Depth: Slotted liner from 13390'- 14550'and 15031'- 17659' MAR 2 8 2017 True Vertical Depth: 6950'-6909'and 6917'-6886' AOGGC 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: �s" Intervals treated(measured): 13372'- 17664' SC p� i'EO MAY , 5 11!' Treatment descriptions including volumes used and final pressure: d� 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 [ Exploratory❑ Development0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run El 16.Well Status after work: Oil I] Gas El WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ El WAG ❑ GINJ El SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact John Cookson Email John.Cooksoncop.com Printed Name / /yI)\1ohn Cookson Title Principal Production Engineer 5 [� Signature 1 Phone 265-6547 Date . �J//7 L/ rTL 577/ //? /01o�7 7 Form 10-404 Revised 5/2015 REDIV S w APR — 3 2u1 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) STATE OF ALASKA AKA OIL AND GAS CONSERVATION COMMSION - REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations El 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 ❑✓ Exploratory ❑ 210-001 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O. Box 100360, Anchorage,AK 99510 50-103-20611-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 364470, 364471, 373105 CRU CD3-106 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 17664 feet Plugs measured None feet true vertical 6886 feet Junk measured None feet Effective Depth measured 17664 feet Packer measured 12006 feet true vertical 6886 feet true vertical 6734 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 107' 107' Surface 2696' 9.625" 2725' 2475' SCANNED JUN 2 4 2016' Intermediate 12961' Ti 12986' 6944' Production Liner 4292' 4.5" 17664' 6886' RECEIVED Perforation depth Measured Depth: Slotted liner from 13390'- 14550'and 15031'- 17659' APR 2 1 2016 True Vertical Depth: 6950'-6909'and 6917'-6886' Tubing(size,grade,measured and true vertical depth) 4.5"x 3.5", L-80, 12184' MD, 6794'TVD ®GC 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): 13372'- 17664' 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 ❑✓ 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 KerryFreedman Title Principal Production Engineer Signature , q ,. Phone 265-6579 Date y hr.) 1 iL 7 V77- 5////6, RBDMS uV APR 2 1 2016 Form 10-404 Revised 5/2015 .I-- /%,‘ Submit Original Only s. • • CD3-106 and CD3-106L1 Scale Inhibition Treatment 3/21/16—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) , WNS PROD • CD3-106 ConocoPhillips Well Attributes Max angle&MD TD e Alaska inc. limtAlit,,:^" Wellbore API/UWI Field Name Wellbore Status Ind(°) MD(6K8) Act Btm(RKB) _„,,-,lea, 501032061100 FIORD NECHELIK PROD 95.43 16,077.06 17,664.0 ... Continent H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date MULTIPLE LATERALS-CD3-106,3/16/2016 12 33:57 PM SSSV:TRDP Last WO: 28.00 3/6/2010 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM Rev Reason:GLV C/O,DRIFT TBG TO 12,450' pproven 3/16/2016 HANGER;22.0- t �: SLM(SEE NOTES) Casing Strings Casing Description OD(in) ID(in) Top(RKB) Set Depth(ttKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread T q; CONDUCTOR 16 15.062 29.0 107.0 107.0 62.50 H-40 Welded �' Casing Description OD(in) ID(in) Top(RKB) 'Set Depth(RKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.835 29.4 2,725.4 2,475.1 40.00 L-80 BTC-Mod Casing Description OD(in) ID(in) Top(RKB) Set Depth(RKB) Set Depth)T/D)...Wt/Len(I...Grade Top Thread INTERMEDIATE 7 6.276 25.0 12,986.2 6,944.6 26.00 L-80 BTCM • Casing Description OD(in) ID(in) Top(RKB) Set Depth(RKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread LINER(off L1) 41/2 3.958 13,372.1 17,664.0 6,886.2 12.60 L-80 SLHT Liner Details '', Nominal ID 1141 _ ../ii, Top(ORB) Top(TVD)(RKB) Tap Incl(°) Item Des Com (in) 13,372.1 6,951.1 93.40 SLEEVE BAKER HR SETTING SLEEVE 4.410 CONDUCTOR;290-107.0 Tubing Strings Tubing Description String Ma...ID(in) Top(ttKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING 31/2 2.992 22.0 12,184.2 6,794.2 9.30 L-80 EUE8rdMOD ir- ( 4.553,5"@ 112' Completion Details Nominal ID Top(RKB) Top(ND)(RKB) Top Incl F) Item Des Com (in) Safety varve;2.0625 [' ' 22.0 HANGER FMC 4 1/2"Tbg Hanger 4.500 it112.5 112.5 0.09 XO Reducing X04.5'03.5" 3.000 I 2,062.5 1,996.4- 32.77 Safety Valve 3 1/2"Camco TRMAXX-5E SSSV 5.916"OD 2.812"ID 2.812 12,006.4 6,734.7 68.04 PACKER Baker 3.5"X 7"Premier Packer 3.010 12,054.3 6,752.2 69.27 NIPPLE 3.5"HES"XN"Nipple 3.96"OD X 2.813"ID w/2.75" 2.750 12,183.7 6,794.0 73.18 WLEG Wireline entry guide 2.990 SURFACE,29.4-2,725 4-+ r i Perforations&Slots Shot I Dens Top(ND) Btm(ND) (shots/f GAS LIFT,4,679.5 - Top(RKB) Btm(MKB) (RKB) (RKB) Zone Date t) Type Corn 13,390.0 14,550.0 6,950.0 fi,908.8 2/20/2010 32.0 SLOTS Slots 1/802.25",8 slots/row,4 rows/ft;no slots 3'from box/pin 15,031.2 17,659.4 6,916.6 6,886.4 2120/2010 32.0 SLOTS Slots 1/802.25",8 slots/row,4 rows/ft;no slots 3'from box/pin Mandrel Inserts St GAS LIFT;9.487 9 _ atl on Top(ND) Valve Latch Port Size TRO Run 15 N Top(RKB) (ttKB) Make Model OD(in) Sew Type Type (in) (psi) Run Date Com 1 4,679.5 3,418.3 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,935.0 3/9/2010 2 9,487.9 5,589.7 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,951.0 3/9/2010 ® 3 11,884.5 6,686,2 CAMCO KBMG 1 GAS LIFT OV BK 0.313 0.0 3/14/2016 GAS LIFT,11,884.5 _ 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) 111 3/20/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 1 3/17/2013 NOTE:DRIFT TBG to 12,450'SLM PACKER,12.0064 a s r ■ NIPPLE,12,054 3 al W LEG;12.183 7 1 1 aa' ill ll INTERMEDIATE,25.0-12,9862 SLOTS 12,987.9-13,501.5-.___-', ..-- L1 LINER;12,795.2-16,1830 .t ow- il 1 r SLOTS,13,3900-14,550.0 1 1 i It SLOTS;15 031.2-17,659.4 l 1 LINER(off L1),13,372.1I C 17,664 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 ❑ 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 El Exploratory ❑ 210-001 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O. Box 100360,Anchorage,AK 99510 50-103-20611-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 364470, 364471, 373105 CRU CD3-106 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 17664 feet Plugs measured None feet true vertical 6886 feet Junk measured None feet Effective Depth measured 17664 feet Packer measured 12006 feet true vertical 6886 feet true vertical 6734 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 107' 107' SCAMN 1.1 ,, 3 n;r, Surface 2696' 9.625" 2725' 2475' Intermediate 12961' 7" 12986' 6944' Production Liner 4292' 4.5" 17664' 6886' Perforation depth Measured Depth: Slotted liner from 13390'- 14550'and 15031'- 17659' RECEIVED True Vertical Depth: 6950'-6909'and 6917'-6886' MAR 10 2016 Tubing(size,grade,measured and true vertical depth) 4.5"x 3.5", L-80, 12184' MD, 6794'TVD . 0 GCC 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): 13372'- 17664' 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 0 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(a cop.com Printed Name Kerry FreedmannTitle Principal Production Engineer Signature / 7,.......L._ Phone 265-6579 Date 3 f 5 1 i C... I Form 10-404 Revised 5/2015 4 31116 RBDMS L,-MAR 1 1 1016 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) Ws • CD3-106 COnOCOPhilhip5 Well Attributes Max Angle&MD TD " 111C Wellbore API/UWI Field Name Well Status Incl I') MD(MB) Act BM(ftKB) 501032061100 FIORD NECHELIK PROD 95.43 16,077.06 17,664.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date Well Contg:MULTIPLE LATERALS-CD3- (dm 106,4/122t0334PM4 SSSV:TRDP Last WO: 28.00 3/6/2010 Schematic-Actual Annotation Depth(ftKB) End Date Annotation I Last Mod...End Date Last Tag: Rev Reason:WELL REVIEW I osborl 4/12/2012 HANGER,22 ' + Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)..Stony Wt..String...String Top Thrd CONDUCTOR 16 15.062 29.0 107.0 107.0 62.50 H-40 Welded i 7 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd SURFACE 9 5/8 8.835 29.4 2,725.4 2,474.9 40.00 L-80 BTC-Mod - ,:. Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd INTERMEDIATE 7 6.276 25.0 12,986.2 6,944.1 26.00 L-80 BTCM \: Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd 1, LINER(off L1) 41/2 3.958 13,372.1 17,664.0 6,886.2 12.60 L-80 SLHT Liner Details Top Depth (TVD) Top Incl :Nom! Top(ftKB) (ftKB) (°) Item Description Comment ID(in) CONDUCTOR, 13,372.1 6,951.1 93.40 SLEEVE BAKER HR SETTING SLEEVE 4.410 29-107 Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt..String.. String Top Thrd TUBING 31/2 2.992 22.0 12,184.2 6,793.7 9.30 L-80 EUE8rdMOD Ali 4 5"x3.5"@ 112 l Completion Details Safety Valve 1 '=". 1 I Top Depth 2.063 (TVD) Top Teel Nomi... Top(ftKB) (ftKB) ("1 Item Description Comment ID(in) -. 22.0 22.0 -0.01 HANGER FMC 4 12"Tbg Hanger 4.500 112.5 112.5 0.09 XO Reducing XO 4.5'x 3.5" 3.000 2,062.5 1,995.0 32.51 Safety Valve 3 1/2"Camco TRMAXX-5E SSSV 5.916"OD 2.812'ID 2.812 12,006.4 6,734.4 67.96 PACKER Baker 3.5"X T'Premier Packer 3.010 SURFACE, 12,054.3 6,750.0 68.70 NIPPLE 3.5"HES"XN"Nipple 3.96"OD X 2.813"ID w/2.75" 2.750 29-2.725 12,183.7 6,793.5 73.18 WLEG Wireline entry guide 2.990 Perforations&Slots GAS LIFT, Shot 4.600 Top(ND) Btm(TVD) Dens Top(ftKB) 13bn(ftKB) (ftKB) (ftKB) Zone Date (eh.- Type Comment 13,390.0 14,550.0 6,950.0 6,908.8 2/20/2010 32.0 SLOTS Slots 1/8x2.25",8 slots/row,4 rows/ft; no slots 3'from box/pin 15,031.2 17,659.4 6,916.6 6,886.4 2/20/2010 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 GAS LIFT, --5 9,488 k GAS LIFT, 11,885 r:-. PACKER, r7 12,ER, L� 2 NIPPLE,12.054 [: WLEG.12.184 Mandrel Details Top Depth Top Port NTERMEDIATE, (ND) Incl OD Valve Latch Size TRO Run 2512.986 12,98&13,502 , Stn Top(ftKB) (ftKB) (e) Make Model (in) sery Type Type (in) (poll Run Date Com... SLOTS. 1 4,679.5 3,418.5 65.24 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,935.0 3/9/2010 SLOTS, 13,34.550 2 9,487.9 5,589.7 62.21 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,951.0 3/9/2010 L1 LINER. L1 LINER' - BM3 11,884.5 6,685.3 64.99 CAMCO KBMG 1 GAS LIFT OV BK 0.313 0.0 3/9/2010 12,795-18,183 �__.-: UM SLOTS. 15,031-17,659 LINER(off L1). 13,372-17,664\ TD(CD3-106), \ 17,664 STATE OF ALASKA AL.._..A OIL AND GAS CONSERVATION COM..,,6SION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Performed Abandon r Repair well r Rug Perforations r Perforate rOther Scale Inhibition Alter Casing r Pull Tubing r Stimulate-Frac Waiver r Treatment r r Time Extension Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 Exploratory r 210-001 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-103-20611-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 364470,364471,373105 CRU CD3-106 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): RECEIVED none Colville River Field/Fiord Oil Pool 11.Present Well Condition Summary: APR O 7 2015 Total Depth measured 17664 feet Plugs(measured) none true vertical 6886 feet Junk(measured) none AOGCC Effective Depth measured 17664 feet Packer(measured) 12006 true vertical 6886 feet (true vertical) 6734 Casing Length Size MD ND Burst Collapse Conductor 78' 16" 107' 107' Surface 2696 9.625" 2725' 2475' Intermediate 12961 7" 12986' 6944' Liner 4292 4.5" 17664' 6886' Perforation depth: Measured depth: slotted liner from 13390-14550, 15031-17659 True Vertical Depth: 6950-6909,6917-6886 j 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 TVD SSSV-CAMCO TRMAXX-5E SSSV @ 2063 MD and 1995 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 13372'-17664' Treatment descriptions including volumes used and final pressure: one treatment for both laterals 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md 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 r 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(a�conocophillips.com Printed Name Kerry Freedman Title Principal Production Engineer Signature Phone:265-6579 Date /t4 i 6 / 2015— v'rL ,fl/v,`I -5— RBDMS APR - 7 2015 1 I/3/, 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: 13372'-17664' WNS CD3-106 ConocoPhillips :- Well Attributes Max Angle&MD TD Wellbore APIIUWI Field Name Well Status Incl(") MD(RKB) Act Btm(RKB) lUaska.Inc;. 501032061100 FIORD NECHELIK PROD 95.43 16,077.06 17,664.0 Co ocePhillgm Comment H2S(ppm) Date Annotation End Date KB-Ord(R) Rig Release Date Well 8onfig:MULTIPLE LATERALS-CD3.106,4/12/20121:0334 PM SSSV:TRDP Last WO: 28.00 3/6/2010 Schematic-Actual An Depth(MB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:WELL REVIEW osbori 4/12/2012 HANGER,22 Casing Strings Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd CONDUCTOR 16 15.062 29.0 107.0 107.0 62.50 H-40 Welded Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd SURFACE 95/8 8.835 29.4 2,725.4 2,474.9 40.00 L-80 BTC-Mod i ' Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String WE..String...String Top Thrd INTERMEDIATE 7 6.276 25.0 12,986.2 6,944.1 26.00 L-80 BTCM ?, Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd ds LINER(off L1) 4 1/2 3.958 13,372.1 17,664.0 6,886.2 12.60 L-80 SLHT Liner Details Top Depth Details Top Inc! Nomi... Top(ttKB) (RKB) (°) Rem DescriptionComment ID 6n1 CONDUCTOR, 13,372.1 6,951.1 93.40 SLEEVE BAKER HR SETTING SLEEVE 4.410 za107Imo Tubing Strings .. Tubing Description String 0... String ID...Top(ttKB) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd TUBING 31/2 2.992 22.0 12,184.2 6,793.7 9.30 L-80 EUE8rdMOD III 4.5"x3.5"@ 112' Completion Details Safety Valve, t Top Depth 2.063 I I (TVD) Top Incl Nomi... ITop(MB) MB) (") Item Description Comment ID(in) L.=�S 22.0 22.0 -0.01 HANGER FMC 41/2"Tbg Hanger 4.500 112.5 112.5 0.09 XO Redudng XO 4.5'x 3.5" '3.000 2,062.5 1,995.0 32.51 Safety Valve 312"Camco TRMAXX-5E SSSV 5.916"OD 2.812'ID 2.812 12,006.4 6,734.4 67.96 PACKER Baker 3.5"X 7"Premier Packer 3.010 SURFACE, .A L 12,054.3 6,750.0 68.70 NIPPLE 3.5"HES"XN"Nipple 3.96"OD X 2.813"ID w/2.75" 2.750 29-2,725 12,183.7 6,793.5 73.18 WLEG Wireline entry guide 2.990 rforations&Slots GAS LIFT. _ F"'-'4.- Shot 4.680 Top(TVD) Btm(ND) Dena 1 Top(RKB)Bhn(MB) MB) (RKB) Zone Date (oh-- Type Comment ---5 13,390.0 14,550.0 6,950.0 6,908.8 2202010 32.0 SLOTS Slots 1/8x2.25",8 slots/row,4 rows/k; no slots 3'from box/pin 15,031.2 17,659.4 6,916.6 6,886.4 2/20/2010 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 8 Drop off CD3-106L1(see attachment) 3/20/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 GASLFT _ I 9 488 GAS LIFT,_ 85 PA1R, 2 0 2R. 006 tlig , NIPPLE,12,054 )Ir MIk WLEG,12,184 J 1_. t-ii 1 Mandrel Details Top Depth Top Port NTERMEDIATE. (ND) Incl OD Valve Latch Size TRO Run 25.12.9861 Stn Top(RKB) MKS) ("1 Make _ Model lin) Sery Tyne TV. (in) (Pail Run Date Com... SLOTS, \ 12,988-13,502 ' A 1 4,679.5 3,418.5 65.24 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,935.0 3/9/2010 SLOTS, 13.39014,550 2 9,487.9 5,589.7 62.21 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,951.0 3/9/2010 L7 LINER, 12,796-16.183 }r�.';!Ir, 3 11,884.5 6,685.3 64.99 CAMCO KBMG 1 GAS LIFT OV BK 0.313 0.0 3/9/2010 SLOTS, 16031-1709 LINER(off LI), 13,372-17,64 TD(CD7 06), 17,864 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. J 0 - 0 D J Well History File Identifier Organizing (done) ❑ Two -sided III 111 I III III ❑ Rescan Needed 1 111111 11111 RES AN DIGITAL DATA OVERSIZED (Scannable) C for 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:: I C---- 61 P BY: Maria Date: 0- /s/ Project Proofing I BY: Maria Date: O i 511 is/ 1 P - Scanning Preparation W (0 x 30 = ` 1 0 + / = TOTAL PAGES 1 ` 6 g p ara „� g (Count does not include cover sheet) 44 _ BY: Maria Date: I l /s/ Scanning III I Production g Stage 1 Page Count from Scanned File: ' 9 7 (Count does include cov eet) Page Count Matches Number in Scanning Preparation: YES NO BY: -i Date: q /s/ 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. 1111111111M ReScanned III I 11111 BY: Maria Date: /s/ Comments about this file: Quality Checked 11111111111111111 10/6/2005 Well History File Cover Page.doc 6".1/�%`�a HEh e! cul a' 1 au �n STATE 1,� . . ,�._._ 1' �,L -,gin K.N. t __ , j 333 West Seventh AvenueeAlaska 99501 357 Anchora , ?_ � COVBRIvOI: SEAN ��AR�F.t I, g ° Main. 907.279.11/33 �D MAg 3r 6 2`�� MJ Loveland Sat* Well Integrity Project © �ConocoPhillips Alaska, Inc. aio — P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CD3-106 Sundry Number: 314-025 Dear Ms. Loveland: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, C/4 /a4trAte% Cathy P. oerster Chair inYiDATED this/dayof January, 2014. Encl. STATE OF ALASKA 941/�.i�� - AL ,CA OIL AND GAS CONSERVATION COMMISSION (V I•` APPLICATION FOR SUNDRY APPROVALS e 20 AAC 25.280 i/. 1 7 / 1.Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair well r Change App `�• ,I `� Suspend r Plug Perforations r Perforate r Pull Tubing r 7i sf6n r Operational r Re-enter Susp. r Stimulate r Alter casing r Other:Conductor Extension F 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Developmen F 210-001 3.Address: 6.API Number: Stratigraphi r Service P.O. Box 100360,Anchorage,Alaska 99510 50-103-20611-00- 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No F CD3-106 . 9.Property Designation(Lease Number): /l* 10.Field/Pool(s): 3(o yH 7.0 ADL 3644,364471,373-t03 37a/05- Colville River Field/Fiord Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 17664 . 6886 • Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 107' 107' SURFACE 2696 9 5/8 2725' 2475' INTERMEDIATE 12961 7 12986' 6944' LINER(OFF L1) 4292 4.5 17664' 6886' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 13,390-14,550, 15,031-17,659 • 6950-6908,6917-6886 3.5 L-80 12184 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER 3.5"X 7"PREMIER PACKER ' MD=12006 TVD=6735 TRMAXX-5E SSSS MD=,2233 TVD 1995 t'/'ll) 12.Attachments: Description Summary of Proposal F 13. Well Class after proposed work: Detailed Operations Program E BOP Sketch Exploratory (— Stratigraphic r' Development Service 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/1/2014 Oil F• Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Loveland/Martin Walters Email: n1878( coD.com Printed Name J 0 -Ia,.5' Title: Well Integrity Project Signature f Phone:659-7043 Date 1/11/14 Air Commission Use Only Sundry Number: 31 LI.ca 5 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: RBDMSAY U 9 2014 7 Spacing Exception Required? Yes 0 No Subsequent Form Required: /Q d APPROVED BY Approved by: ' • ,OVC• ••p is •.n is va � orl�l months from thTc Edat°c Otlapp oval. Date: ( - /7- / Form 10-403(Revised 10a/6 2012) ORIGINAL��'� Submit Form and Attachments in Duplicate VL-1' 1/ &/i / Y WNS CD3-106 Conoco P Iillips "� Well Attributes Max Angle&MD TO Alaska,Inc. Wellbore API/UWI Field Name Well Status Incl(°) MD(ftKB) Act Btm(ftKB) 501032061100 FIORD NECHELIK PROD 95.43 16,077.06 17,664.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date Well Conn8 MULTIPLE LATERALS-0 03-10 4 1/1312012 103.34 PM SSSV:TRDP Last WO: 28.00 3/6/2010 ScFsmalK•Adwl Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:WELL REVIEW osborl - HANGER,22 Casing Strings Casing Description String O... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR 16 15.062 29.0 107.0 107.0 62.50 H-40 Welded Casing Description String 0... String ID...Top(nKB) Set Depth(f...Set Depth(TVD)....String Wt..String...String Top Thrd I SURFACE 95/8 8.835 29.4 2,725.4 2,474.9 40.00 L-80 BTC-Mod i. Casing Description String 0... String ID...Top(ftKB) Set Depth(I...Set Depth(TVD)...String Wt..String...String Top Thrd INTERMEDIATE 7 6.276 25.0 12,986.2 6,944.1 26.00 L-80 BTCM Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd LINER(off L1) 4 1/2 3.958 13,372.1 17,664.0 6,886.2 12.60 L-80 SLHT Liner Details Top Depth (TVD) Top Incl Nomi... Top(ftKB) (ftKB) (°) Item Description Comment ID(in) CONDUCTOR, 13,372.1 6,951.1 93.40 SLEEVE BAKER HR SETTING SLEEVE 4.410 29-107 t 2 Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(I...Set Depth(ND)...String Wt...String... String Top Thrd TUBING 31/2 2.992 22.0 12,184.2 6,793.7 9.30 L-80 EUE8r4MOD 4.5"x3.5"@ 112' I Completion Details Safety Valve, - Top Depth 2.063 .......1 (ND) Top Incl Nomi... Top(ftKB) (nKB) 1°) Item Description Comment ID(in) 22.0 22.0 -0.01 HANGER FMC 41/2"Tbg Hanger 4.500 112.5 112.5 0.09 XO Reducing XO 4.5'x 3.5" 3.000 2,062.5 1,995.0 32.51 Safety Valve 312"Camco TRMAXX-5E SSSV 5.916"OD 2.81Z ID 2.812 12,006.4 6,734.4 67.96 PACKER Baker 3.5"X 7"Premier Packer 3.010 SURFACE,_ 12,054.3 6,750.0 68.70 NIPPLE 3.5"HES"XN"Nipple 3.96"OD X 2.813"ID w/2.75" 2.750 29-2,725 - -.... 12,183.7 6,793.5 73.18 WLEG Wireline entry guide 2.990 1.1 Perforations&Slots _ GAS LIFT, Shot 4,660 Top(TVD) Stem(TVD) Dens Top(ftKB)Btm MKS) (ftKB) (ftKB) Zone Date (eft- Type Comment 13,390.0 14,550.0 6,950.0 6,908.8 2/20/2010 32.0 SLOTS Slots 1/8x2.25",8 slots/row,4 rows/ft; no slots 3'from box/pin 15,031.2 17,659.4 6,916.6 6,886.4 2/20/2010 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 3202010 NOTE:CD3-1061.1 top in main wellbore,CD3-106 liner a Plop 8,Drop off CD3-106L1(see attachment) 320/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 GAS LIFT, _ 9.450 IIII GAS LIFT G 666 i,--‘_ I M PACKER. .._.- 12,006 V. NIPPLE,12,054- li I WLEG.12,184 - - J tri • Mandrel Details • , Top Depth Top Port NTERMEDIATE. (TVD) Incl OD Valve Latch Sine TRO Run 2512.986 Stn Top(ftKB) OMB) (°) Make Model (in) Seem Type Type (In) (psi) Run Date Com... SLOTS, • 1 4,679.5' 3,418.5 65.24 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,935.0 3/9/2010 12,989-13,5@t2,11-LOT02 9,487.9 5,589.7 62.21 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,951.0 3/9/2010 13,390.1 OTS,12,7L9S-1e1831. 3 11,884.5 6,685.3 64.99 CAMCO KBMG 1 GAS LIFT OV BK 0.313 0.0 3/9/2010 SLOTS, 15,031-17,659 LINER(off LI), 13,372-17,664 TD(CD3-106), 17,664 n- r. ConocoPhillips Alaska `y � 4L P.O. BOX 100360 !_t � Le .A" ANCHORAGE,ALASKA 99510-0360 January 10, 2014 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,AK 99501 Commissioner Foerster: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well CD3-106, PTD 210-001 conductor extension. Please contact Martin Walters or MJ Loveland at 659-7043 if you have any questions. Sincerely, ///..e/ MJ Lo land ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska,Inc. Alpine Well CD3-106(PTD 210-001) SUNDRY NOTICE 10-403 APPROVAL REQUEST January 10, 2014 This application for Sundry approval for Alpine well CD3-106 is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to SC. At some point during normal operations the conductor subsided about 7". With approval, the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Examine surface casing for any corrosion damage. 3. Extend the conductor to starter head and fill the void with cement and top off with sealant. 4. File 10-404 with the AOGCC post repair. NSK Well Integrity Projects Supervisor STATE OF ALASKA 4 , AL.A OIL AND GAS CONSERVATION CO SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon E Repair w ell F Rug Perforations j Perforate f Other j scale inhibition treatment Alter Casing E Pull Tubing E Stimulate - Frac Fl Waiver F Time Extension Change Approved Program j"'"" Operat. Shutdow n FW"' Stimulate - Other f"" Re -enter Suspended Well ("°°° 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F� Exploratory r 210 -001 — 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic j Service 50 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 364470, 364471, 373105 CD3 - 106 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 17664 feet Plugs (measured) none true vertical 6886 feet Junk (measured) none Effective Depth measured 17664 feet Packer (measured) 12006 true vertical 6886 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 RECEIVED Liner 4292' 4.5" 17664' 6886 MAY 1 3 2013 Perforation depth: Measured depth: slotted liner 13390'- 14550', 15031'- 17659' A `° G C "' True Vertical Depth: 6950' - 6909', 6917'-6886' ' C e 2.�1' SCAN JUL 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' 17664' 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 Subsequent to operation 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory Frn Development iW Service E Stratigraphic r 16. Well Status after work: Oil Fri Gas 1 — E Daily Report of Well Operations XXX GSTOR I- WINJ I" WAG E GINJ ;" — SUSP E SPLUG E 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Tim Nelson as 265 -6859 Email Tim.J.Nelson(a�cop.com Printed Name Tim Nelson Title Staff Production Engineer Signature Phone: 265 -6859 Date 5 1 RBDMS MAY 13 201 V 3 // 3 Form 10 -404 Revised 10/2012 d��ir, Submit Original Only . • • Scale Inhibition Treatment: CD3 -106 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. �,. i WNS • CD3 -106 onoco'hiilips W & Well Attributes Max Angle MD TD • IOC, Wellborn APYUWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) 501032061100 FIORD NECHELIK PROD 95.43 16,077.06 17,664.0 CanocoPhiMps Comment H2S (ppm) Date Annotation End Date KB -Ord (ft) Rig Release Date "" SSSV: TRDP Last WO: 2800 3/6/2010 Well conk,' MULTIPLE LATERALS - CD3 -706 4/12/2012 1:0334 PM Schematic - Actual Annotation Depth (ftK8) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason: WELL REVIEW osborl 4/12/2012 HANGER, 22 ±T Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String .. String Top Thrd CONDUCTOR 16 15.062 29.0 107.0 107.0 62.50 11-40 Welded C 7 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.835 29.4 2,725.4 2,474.9 40.00 L -80 BTC -Mod Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd iii INTERMEDIATE 7 6.276 25.0 12,986.2 6,944.1 26.00 L -80 BTCM I Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd LINER (off L1) 4 1/2 3.958 13,372.1 17,664.0 6,8862 12.60 L -80 SLHT Liner Details Top Depth (TVD) Topincl Nomi... Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) CONDUCTOR. 13,372.1 6,951.1 93.40 SLEEVE BAKER HR SETTING SLEEVE 4.410 29 -107 111166, Tubing Strings Illk Tubing Description String 0... String ID ... Top (ftK8) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 31/2 2.992 22.0 12,184.2 6,793.7 9.30 L -80 EUE8rdMOD 4.5 "x3.5" @ 117 - Completion Details Safely Valve. Top Depth 2,063 [ C'e I (TVD) Top lne! Noml... Top (ftKB) (ftK8) (°) Item Description Comment ID (In) 22.0 22.0 -0.01 HANGER FMC 4 1/7' Tbg Hanger 4.500 112.5 112.5 0.09 XO Reducing XO 4.5' x 3.5" 3.000 2,062.5 1,995.0 32.51 Safety Valve 3 1/2" Camco TRMAXX -5E SSSV 5.916" OD 2.817' ID 2.812 12,006.4 6,734.4 67.96 PACKER Baker 3.5" X 7" Premier Packer 3.010 SURFACE, JI l 12,054.3 6,750.0 68.70 NIPPLE 3.5" HES "XN "Nipple 3.96" OD X 2.813" ID w/ 2.75" 2.750 29 - 2,725 12,183.7 6,793.5 73.18 WLEG Wireline entry guide 2.9 IN Perforations & Slots GAS LIFT, Shot 4,680 - Top (TVD) Btm (TVD) Dens M I Top BOO) Btm OMB) (ftK8) (ftKB) Zone Date (eh•• Type Comment 13,390.0 14,550.0 6,950.0 6,908.8 2/20/2010 32.0 SLOTS Slots 1/8x2.25 ", 8 slots/row, 4 rows/ft; no slots 3' from box/pin 15,031.2 17,659.4 6,916.6 6,886.4 2/20/2010 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 k- -, 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 GAS LIFT, -> 9 ,486 ? GAS 71, 66 LIFT 5 _ r PACKER, 12,006 II III NIPPLE, 12,054 - IIII WLEG, 12,184 IN WI ®I E, Mandrel Details Top Depth Top Port NTERMEDIATE, (TVD) Inc! OD Valve Latch Size TRO Run 25- 12,986 \ Stn Top (ftKB) MB) ( °) Make Model (in) Sen. Type Type (in) (Pei) Run Date Com... SLOTS, 72,988 - 13,5502 02 1 4,679.5 3,418.5 65.24 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,935.0 3/9/2010 , S. SLOTS, 13,390 - 14,550 2 9,487.9 5,589.7 62.21 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,951.0 3/9/2010 L1 LINER, 12,795 - 18,783 � 3 11,884.5 6,685.3 64.99 CAMCO KBMG 1 GAS LIFT OV BK 0.313 0.0 3/9/2010 SLOTS, 15,031- 17,659 LINER (off 1.1), 13,372 - 77,884 • TO(CD3- 11x5), 77,664 RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APR 1 1 2012 REPORT OF ANNULAR DISPOSAL AOGCC 1 1. Operator: 4a. Well Class: Stratigraphic ❑ Service ❑ 6. Permit to Drill Number: 210 -001 ConocoPhillips Alaska, Inc. Development 0 Exploratory ❑ 7. Well Name: CD3 -106 2. Address: 4b. Well Status: Oil 0 Gas ❑ WAG ❑ 8. API Number: P. 0. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50 -103- 20611 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ❑ or Continuation ❑ or Final • 311 -021 2/1/2011 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: • cement - contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 493* 493 totals (bbls): 2011 / 1st 22913 100 0 23013 15 2/10/2011 2/27/2011 CD3 -127, CD3 -199 2011 / 2nd 7623 100 0 7723 8 4/10/2011 4/21/2011 CD3 -128 2011 / 3rd 0 0 0 0 0 2011 / 4th 0 0 0 0 0 2012 / 1st 0 0 4 4 0 • Total Ending Report is due on the 20th Volume 30536 200 497 31233 23 (bbls): of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ❑ Step Rate Test ❑ October 20 for the third quarter, and January 20 for the Other (Explain) ❑ fourth quarter. 12. Remarks and Approved Substances tD AP �1 �1 Description(s): *freeze protect volumes only I hereby certify that the foregoing is true and correct to the best of my knowledge. / Signature: A. 0 Date: 46000(L Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265 -6120 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ❑ Service ❑ 6. Permit to Drill Number: 210 -001 ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 7. Well Name: CD3 -106 2. Address: 4b. Well Status: Oil II Gas ❑ WAG ❑ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50 -103- 20611 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ❑ or Continuation El or Final ❑ 311 -021 2/1/2011 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement - contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred 51.AMED FEB 0 8 201• fluids, formation fluids and any necessary water added Previous 493* 493 totals (bbls): 2011 / 1st 22913 100 0 23013 15 2/10/2011 2/27/2011 CD3 -127, CD3 -199 2011 / 2nd 7623 100 0 7723 8 4/10/2011 4/21/2011 CD3 -128 2011 / 3rd 0 0 0 0 0 2011 / 4th 0 0 0 0 0 Total Ending Report is due on the 20th 0 Volume 30536 200 493 31229 23 (bbls): of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ❑ Step Rate Test ❑ October 20 for the third quarter, and January 20 for the Other (Explain) ❑ fourth quarter. 12. Remarks and Approved Substances Description(s): *freeze protect volumes only I hereby certify that the foregoing is tru nd correct to the best of my knowledge. C `'' Signature: ‘'_ Date: { t Gil° tL Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265 -6120 RSDMS JAN 0 9 2012 Oi " Form 10 -423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1 1. Operator: 4a. Well Class: Stratigraphic ❑ Service ❑ 6. Permit to Drill Number: 210 -001 ConocoPhillips Alaska, Inc. Development III Exploratory ❑ 7. Well Name: CD3 -106 2. Address: 4b. Well Status: Oil E Gas ❑ WAG ❑ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50 -103- 20611 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ❑ or Continuation • or Final ❑ 311 -021 2/1/2011 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement - contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 493* 493 III totals (bbls): 2011 / 1st 22913 100 0 23013 15 2/10/2011 2/27/2011 CD3 -127, CD3 -199 2011 /2nd 7623 100 0 7723 8 4/10/2011 4/21/2011 CD3 -128 2011 / 3rd 0 0 0 0 0 2011 / 4th Total Ending Report is due on the 20th Volume 30536 200 493 31229 23 (bbls): of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter,_ 11. Attach: Disposal Performance Data: Pressure vs. Time 111] Step Rate Test ❑ October 20 for the third quarter, and January 20 for the • Other (Explain) ❑ fourth quarter. 12. Remarks and Approved Substances ,,` . , } !)F_ s y y j 0 - Description(s): *freeze protect volumes only 1 hereby certify that the foregoing is true and correct to the best of my knowledge. \ 1 c I �(t:t{ Signature: f - l z "s.,_ Date: Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265 -6120 Form 10-423 Rev. 2/2004 RBDMS OCT 4 201070-41 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ❑ Service ❑ 6. Permit to Drill Number: 210 -001 ConocoPhillips Alaska, Inc. Development El Exploratory ❑ 7. Well Name: CD3 -106 2. Address: 4b. Well Status: Oil 0 Gas ❑ WAG ❑ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50 -103- 20611 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ❑ or Continuation 0 or Final ❑ 311 -021 2/1/2011 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement- contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 493* 493 totals (bbls): 2011 / 1st 22913 100 0 23013 15 2/10/2011 2/27/2011 CD3 -127, CD3 -199 2011 / 2nd 7623 100 0 7723 8 4/10/2011 4/21/2011 CD3 -128 2011 / 3rd 2011 / 4th Total Ending Report is due on the 20th PO Volume 30536 200 493 31229 23 i ll month f o f the monoown the final month of the quarter. Ex: (bbls): 9 q April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ❑ Step Rate Test ❑ October 20 for the third quarter, and January 20 for the Other (Explain) ❑ fourth quarter. 12. Remarks and Approved Substances Description(s): *freeze protect volumes only I hereby certify that the foregoing is true and correct to the best of my knowledge. . AL Signature: , ��- Date: 7 fic (L40 u Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265 -6120 Form 10 -423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate I STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ❑ Service ❑ 6. Permit to Drill Number: 210 -001 ConocoPhillips Alaska, Inc. Development El Exploratory ❑ 7. Well Name: CD3 -106 2. Address: 4b. Well Status: Oil IS Gas ❑ WAG ❑ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50 -103- 20611 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal E or Continuation ❑ or Final ❑ 311 -021 2/1/2011 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement- contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and IV any necessary water added Previous 493* 493 totals (bbls): 2011 / 1st 22913 100 0 23013 15 2/10/2011 2/27/2011 CD3 -127, CD3 -199 2011 / 2nd 2011 / 3rd 2011 / 4th Total Ending Report is due on the 20th SI Volume 22913 100 493 23506 15 (bbls): of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ❑ Step Rate Test ❑ October 20 for the third quarter, and January 20 for the Other (Explain) ❑ fourth quarter. 12. Remarks and Approved Substances l Description(s): *freeze protect volumes only I hereby certify that the foregoing is true and to the best of my knowledge. Signature: A W4 Date: 4(Lz(tO U` Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265 -6120 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate •' 1110 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 February 3, 2011 t 9j0 ' 0 0 I CV 3 Commissioner Dan Seamount :VerN frIr *•11 F ^ Alaska Oil & Gas Commission r `` 333 West 7 Avenue, Suite 100 FEB Q 4 2011 Anchorage, AK 99501 Gt Gi;l Cons. C: "' "':.,sion Commissioner Dan Seamount: kit t4,1; .,4a Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The corrosion inhibitor /sealant was pumped January 31, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907 - 659 -7043, if you have any questions. Sincerely, f// MJ Loveland ConocoPhillips Well Integrity Projects Supervisor 1 • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top Report of Sundry Operations (10 -404) Alpine Field Date 21312011 CD3 Pad Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date c> _, ft bbls ft gal CD3- 106 50103206110000 2100010 16" NA 16" NA 7.65 1/31/2011 CD3 -110 50103205090000 2050410 4" NA 6" NA 2.13 1/312011 CD3 -112 50103205270000 2060320 3" NA 16" NA 2.73 1/312011 CD3 - 114 50103205440000 2070330 5" NA 14" NA 2.55 1/312011 CD3 - 121 50103206150000 2100220 32" NA 32" NA 27.2 1/31/2011 _ CO3 - 122 50103206090000 2091530' 74" NA 74" NA 322 1/31/2011 CD3 - 124 50103206120000 2100080 17" NA 17" NA 5.1 1/31/2011 CD3 -301A 50103205430100 2060170 9" NA 15" NA 4.25 1/31/2011 CD3 -302A 50103205220100 2100350 5" NA 16" NA 3.83 1/31/2011 CO3 -304 50103205980000 2090280 18" NA 18" NA 5.9 1/31/2011 • • 11 0[F ALAsEA ffi �ffi SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COM HSSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD3 -106 Sundry Number: 311 -021 Dear Mr. Alvord: Enclosed is the approved Application for Sundry Approval relating to annular disposal of drilling wastes in the above - referenced well. Please note that any disposal into the surface /production casing annulus of a well approved for annular disposal must comply with the requirements and limitations of 20 AAC 25.080. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, / D. niel T. Seamount, Jr. Chair DATED this day of February, 2011 Encl. • IT ' �1lI' t STATE OF ALASKA 11 AN 2 0 ZUll ALASKA OIL AND GAS CONSERVATION COMMISSION ANNULAR DISPOSAL APPLICATION nlis ka Pit g Ciag Car+s.C1 is fission 20 AAC 25.080 An na'age 1. Operator 3. Permit to Drill Name: 2100010 ConocoPhillips Alaska 4. API Number: 50- 103- 20611 -00 -00 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD3 -106 6. Field: Colville River Field 7. Publicly recorded wells 8. Stratigraphic description: a) All wells within one - quarter mile: a) Interval exposed to open annulus: CD3 -316, CD3- 107/307, CD3 -112, CD3 -302, CD3 -109, CD3 -108, CD3 -110, Torok and Seabee formation, shale, siltstone and sandstone CD3 -301, CD3 -111, CD3 -112, CD3 -121, CD3 -122 b) Waste receiving zone: b) water wells within one mile: Sand layers below the C30 marker in the Seabee formation None c) Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Albian Torok Formation provide a lower barrier 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1250' MD / 1241' TVD None 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 13. Maximum anticipated pressure at shoe: None densities range from diesel to 12# /gal 2,188 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 35,000 bbls. Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement - contaminated drilling mud, completion fluids, diesel, formation fluids associated with the 16. Estimated start date: act of drilling a well, drill rig wash fluids, cement rinsate, domestic waste water, any 6 - Feb - 11 added water needed to facilitate pumping of drilling mud or drilling cuttings, and other substances that the commissioner determines on application are wastes associated with the act of drilling a well permited under 20 AAC 25.005. 17. Attachments: Well Schematic (Include MD and TVD) El Cement Bond Log (if required) 111 FIT Records w /LOT Graph 0 Surf. Casing Cementing Data 111 Other El previous authorization for new product cleanup fluids for CD1 and CD2 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: 4 Title: 14-&'tii ,... Printed Phone Name: Chip Alvord Number: 265 -6120 Date: i (11 (2'" Commission Use Only Conditions of approval: LOT review and approval: / Zp -4 Subsequent form required: / — { 2 S Approval number: 61 t 0 APPROVED BY Approved by: THE COMMISSION RB COMMISSIONER Date: DAAS FEB Op) � U R 1 G 1 NAL f Duplicate F orm 10 -403RD Rev. 6/2004 �'Z � { INSTRUCTIONS ON V SE n - l : z� • • ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 -0360 ConocoPhi I h ps Telephone 907 - 276 -1215 January 19 2010 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 -3539 Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on well CD3 -106 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD3 -106 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended to begin annular disposal operations on CD3 -106 approximately February 6th, 2010. Please find attached form 10 -403AD and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Summary of wells on Pad 4. Plan View of Adjacent Wells 5. Surface Casing Description 6. Surface Casing Cementing Report & Daily Drilling Report during cement job 7. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 8. Intermediate Casing Description 9. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 10. Formation LOT on 9 -5/8" x 7" casing annulus 11. List of wells on CD3 pad and the lateral distance from the surface casing shoe. 12. Information regarding wells within '/4 mile radius at AOGCC: CD3 -316, CD3- 107/307, CD3 -113, CD3 -302, CD3 -109, CD3 -108, CD3 -110, CD3 -301, CD3 -111 and CD3 -112. 13. Information regarding remaining wells within '/4 mile radius included in sundry package: CD3 -122 and CD3 - 121. 14. Copy of previous authorization (CD1 and CD2) for disposal of new product cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations The initial annular LOT (17.0 ppg) occurred at a lower equivalent mud weight than the casing shoe test (15.0 ppg LOT). Therefore we conclude that waste will not migrate above the confining zone provided we do not inject with sustained surface pressures that will cause pressures at the surface shoe to be in excess of the shoe FIT/LOT. If you have any questions or require further information, please contact Nina Anderson at 265 -6403 or Chip Alvord can also be reached by calling 265 -6120. Sincerely,. Nina Anderson Chip Alvord ATO -1570 Drilling Engineer Sharon Allsup -Drake ATO -1530 cc: CD3 -122 and CD3 -121 Well Files I S Annulus Disposal Transmittal Form - Well CD3 -106 AOGCC Regulations, 20 AAC 25.080 (b) 1 Designation of the well or wells to receive drilling wastes: CD3 -106 2 The depth to the base of freshwater aquifers and permafrost, if There are no USDW aquifers in the Colville River Unit. present. Estimated base of Permafrost = 1250' TVD (RKB) 3 A stratigraphic description of the interval exposed to the open The Schrader Bluff formation provides an upper barrier and annulus and other information sufficient to support a marine shales and claystones of the Albian Torok Formation commission fmding that the waste will be confined and will provide a lower barrier. Calculated water salinities of the not come to the surface or contaminate freshwater. Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/1. (Ref. AOGCC Conservation Order No. 443, March 15. 1999) 4 A list of all publicly recorded wells within one - quarter mile See attached map indicating wells within 1/4 mile. There are and all publicly recorded water wells within one mile of the no water wells within 1 mile. well to receive drilling waste. 5 Identify the types and maximum volume of waste to be Types of waste may be drilling mud, drilling cuttings, reserve disposed of and the estimated density of the waste slurry. pit fluids, cement - contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. Densities range from diesel to 12# /gal. Maximum volume to be pumped is 35,000 bbls. 6 A description of any waste sought to be determined as drilling Cement rinsate, mud plant rinse fluid generated by rinsing waste under (h)(3) of this section. tanks and equipment after producing drilling/completion fluid (see included note from CD1 &2 authorization). 7 An estimate of maximum anticipated pressure at the outer Maximum anticipated pressure at the outer casing shoe during casing shoe during annular disposal operations and disposal operations is 2,188 psi. See attached calculation calculations showing how this value was determined. page. 8 Details that show the shoe of the outer casing is set below the See attached: cementing reports, LOT / FIT reports and base of any freshwater aquifer and permafrost, if present, and casing reports. cemented with sufficient cement to provide zone isolation: 9 Details that show the inner and outer casing strings have See attached casing summary sheet and calculation pages. sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations: 10 The downhole pressure obtained during a formation integrity See attached LOT/FIT report. test conducted below the outer casing shoe. 11 Identification of the hydrocarbon zones, if any above the N/A depth to which the inner casing is cemented. 12 The duration of the disposal operation, not to exceed 90 days. N/A 13 Whether drilling waste has previously been disposed of in the N/A annular space of the well and, if so, a summary of the dates of the disposal operations, the volumes of waste disposed of, and the wells where the drilling waste was generated. 14 The well(s) where the drilling waste to be disposed of was or CD3 -199, CD3 -127, CD3 -128, CD3 -125, CD3 -198 will be generated. 15 If the operator proposes not to comply with a limitation N/A established in (d) of this section, an explanation of why compliance would be imprudent. 16 Any additional data required by the commission to confirm N/A containment of drilling waste. • Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) Version 1.0- Jan '05 Well CD3 -106 Assumptions Date 1/17/2011 Maximum injection pressure of 1,500 psi Maximum density of the injection fluid is 12.0 ppg Pore pressure at the 9 5/8" casing shoe is 0.434 psi /ft - Oil' Gas/Fluid Gradient in tubing/casing annulus 0.07 psi /ft Header Pressure (for wells on gas lift) 1,000 psi aQ Maximum Fluid Density to avoid Burst of Surface Casing U:! P P H + P -P r 85 drostahc A lied Formation bu st /o Y PP 9VIIIIII I r. 4,888 = ( 2,475 * 0.052 * MWmax ) + 1500 - ( 0.4337 * 2,475 ) to I1IIII'1 11 MWmax = 34.7 ppg 2,475 TVD • Surface Casing String , 1 ,11111 Size 9.625 in = Weight 40 ppf a 7 Grade L 80 pp CZ rburst100% 5,750 psi 11111111 Pburst85% 4,888 psi Depth of Shoe 2,475 ft FIT/LOT @ Shoe 17 ppg or 2,188 psi �I�� FIT/LOT for Annulus 15 ppg Max Surf. Pressure 1,500 psi TOC Est. @ 11,900' MD 6,693' TVD Maximum Fluid Density avoid Collapse of 2nd Casing String Pcollapse85% = PHydrostatic + PApplied - PGasGradient - PHeader 4,599 = ( 6,693 * 0.052 * MWmax ) + 1,500 - ( 0.0700 * 6,693 ) - 1,000 Z Z MWmax = 13.1 ppg - "Tubing 2nd Casing String Size 7 in 6,944 TVD Weight 26 ppf Grade L 80 rcollapse100% 5,410 psi Pcollapse85% 4,599 psi Top of Cement 6,693 ft Gas Gradient 0.07 psi /ft Max Surf. Pressure 1,500 psi Header Press 1,000 psi Maximum Anticipated Pressure at Surface Casing Shoe Pmax allowable = Shoe TVD Depth * .052 * Shoe FIT/LOT Pmax allowable = ( 2,475 * .052 * 17 ) Pmax allowable = 2,188 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe ". MINIM SURFACE CASING SHOE SEPARATION FROM CD3 -106 CD3 -106 x Y Surface Casing Shoe ASP 4 Coordinates NAD 27: 388447.6 6004482.6 uistance Ann. from Surface csg. Surface Details @ Disp. Object Shoe X Surface csg. Surf LOT casing TVD Annular Wells AOGCC Permit # Permit Date Source well Ann. Vol. ** Start Date End Date well* Coord. Shoe Y Coord. (ppg) (ft) LOT (ppg) Comments CD3 -1` ®:011'1'11 III 11 '1 IR 1 _ ,..u� 111111 !.. `. +umlaflm mtwRpRpl "gi 389300.3 6004"86.4 - 99 TA I 2431 0 911 sl., otforannulardis•osal Iql .uIIIIV , 10.IIIIIP CD3 -109 V CD3 110, CD3 -111, CD3-112, 306 -020 1 /20/2006 CD3-307, CD3 -302 64635 1/20/2006 3/4/2007 556 6004780.2 18 0 2414 16 0 Extended to 70000bb1 ex. 03/17/07 03.1(110 • N 1 tl' Y NNE V 1IN 6 . 1 - 1 Ilvual l . ! .�"I�Idluu a . rN+ lei _ 1, ;i 6004720.7 MINK NNIiti •'7 1 ^._ 2 99+.1 1 6 8 Law surfaee Mae to 3 N l , I�II�II II 44: u tlul . u11 CD3 -111 �' 307 -066 9 CD3 114, CD3 -301 26674 3/20/2007 4/20/2007 387821.0 6004710.6 2469 E13 IIIIIIIIII 00 'LL 1 .IIR +11 +>'' , +7 - 012° 1 111 1 :.111 1 2'; 77E93 CD 010 - r 3- 11111' 11 ++ ". ✓a. /+ 1 048 - .387 + 9,8 :000+ 33x2.13 -. 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'RIIIIIg -"-.- """"^'',, II I I IRI _ � ^ h l . : � " * „ ��; "IU 1 : u � , � ,::NIVVU�uWflIIRIINIII� 7�-T !i,1' V III : " � 5 u111, n " „." + 4. 6 1. �n. 8 2�i8� 1 ��N -_ _ m 1 .n.l�ul tl a�v�IflN�N� I .��I.NNN��NI .: ..: ® . _ o - . „ ::. .: - - � 388541 600 5510.5� ® ® � k Ir e .� � •,1 ",__ .1 � RIRI +, ,,,R,1 .tiu:�m � +:::1 + ” W m ,,,1,:11 31881 ,l1:RIR1 � �2� ® - IINIINN.•: •mow +� IIINI�INII� 1 ' � �. s . M .� .":�.�""9 1 11 �€a �IIIIIINIINIINIINIINN.:. " � r1.� .1.��INNNIINI _ << _. �q 1 ._- 1 I �, I� CD3 . •)�NNNNNNI9I NI�NNNIt ..f:1i NNN ,::.1 12/15/2008 C D ..,,,N „ C I, NN�N t, 1. NN � N CD3 -303 Y 308 26 12/15/2008 CD3 117 23833 2/14/2009 3/27/2009 1741 390091 0 6003906. 2488 ® ■. - -_, ,'r ^I::.:.�_a� : :.:.: -.�... lUVeu ... _- ,, .:Im - 1 r, � -... "1"W"'3'dz.:. t -- ":. a „ ': -:.: . - _ ,.. .: 11.x: - _�_ fl 1 _ ire 1 ' I 1 .��., � - � .. �4.. I Itl�V��NN11::�..: ,. a �.EINIIN� � ,�:. I ... 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NIINIINIINIINIINIINII s3 � 7 4 ._ �? .�,.�.�: :, �N1'INIINIINIINIIN I� SIN �I�1'1NI .gNNIIBIIIINII� CO3 -106 ©-- 388447.6 60044826® ++ ".. -_. _ - , • " :: q 1' ,. .: - _ : I mm s . _. - - - - -.... . __ . _ :: - . -,: , 111 ". _. hoodoo, :- �: ^: , m- ,. ,.,,. _ _. I ,: r ., ., -. �. 1 � : . + 1 1:� � . Ir. -:: +'fl " �� IINNI� N�NNNNNhn�'ul I�INNN�INI 1.'11,� " "� - -''� �NNN�ININNI :- =�1��IN�N NNN °:� !_Ii � ' I ^ 1!a �- r111;1I >- .• 11 , L!1• �� 3 87 ,• - 6 ++569.9 .�. " A, fl1111, -� 1 ::: NNN�NI �IIa� . CD3 -122 © — —. I 387238.8 6004125.0 2484 a -:: -,- a '4$ " I .0 .. : i M I _ -: r" 1 y :, _. . 1 P.• a CW.P 7^ °= :.Y+ ^1 vµ �.. 'f5.2 LIME $, Vd, h.- 'Id VI II!:r . 2 ', � 11'7F ., - a- ��,u�INNII�� ';:!ill N� � 1. NN NI� �� NNI III .�. IUNIINNNNN r�. ' �::I�NNNI�II IIII � 1�,� .r � .: III ��:: I 1 ^� M 1. �.�,. � . 17aa II 1 NNNNNNI�INI� L '�'�t + »8 #eStr CD3 -124 Y 310 -088 4/8/2010 382 2/1/2010 2687 386016.2 6003338.3 15.9 2472 14 60 Low surface shoe test CD3 - 125 ! 1876 386683 0 6003845.0 Planned Wells CD3 -127 2361 386211.8 6003723.6 Planned Wells CD3 -128 2111 386506.8 6003653.0 Planned Wells CD3 -198 174 388582.5 6004592.6 Planned Wells CD3 - 199 ! 589 387863.6 6004409.6 Planned Wells * Lateral distance in feet, between surface casing shoes, in the X -Y plane ** As of Nov 5, 2009 Note that this sheet is not the definitive record for annular disposal volumes • ) w D 1 O WELLBORE TARGET DETAILS (MAP CO- ORDINATES) X11 15, January 18 2011 (v_ Name TVDSS +N/ S +El -W Northing Easting ShapeNo wellbore target data is available Quarter Mile View � �% .? C D3.3 01 P � �O 1ag O`b o� 0'5' C D3Y - - 11111111, X11 r = � CD 111 C: �� • ' 0 i �� 1800 � — 1 -fir CO CD 3 ' 1o6° 1 r n v� 1350 C i 0 1 (09 0.4)5 �. 1 , / LO 900 — � / CD3_ 107L1-- i C p3 ry`9- ,- E�CO3 -3' 3 sOT O C� CD ? 450 �►•4 C OQ' 0 i 1 Iii' - r 0 0 I. Ail w ....v. 1s o rs 50 /' - ,li N`f' I S b '05 0 *. I In I kts -1800 -1350 -900 -450 0 450 900 1350 800 �� West( -) /East( +) (450 ft/in) • • TOM and Shannon, • You. have requeated tp dispose of "clew - product" clean up fluids from the routine mixing of• tud and cement .at Alpine as well as. the clean up fluids resulting from • cleaning out the tanks the mud plant in preparation for using .oil base anzd. The Commission had pre piously aapt;oved disposing of the new product' clean up • Cl«3.'ds via annular disposal at CD 1 pad. Due to the geological setting at Alpine, Class 1 and Class 2 disposal options are limited. • Phillips' prrd!cessor, AECO, had t bli thed the limitation of cit00pal options. to the Corun satisfaction end .annular disposal eras - approved as _. the practical and environmental alternative. Iii these requests the waste fluids are no diZferant than previously approved and . are the result of the.•ongoing develop ent activities at Alpine. The oomM ssioriers•have authors ed me to send you. thin mesaage. By copy of email, Phillips i 3 authorized to dispose of clean up fluids a.s described in your email_ Please Call with any guestior,s. Pon Maunder, PE Sr. Petroleum Engineer AOGCC • \. Al,P Env Coord wrote.; > Dear mr. Maunder, • > As noted in the - attached email, Tom Manson previously requested > Authorization to .dispose of new- product clean LID fluid8 such as cement > rinsate, and ru&..an&. brine pit rinses frog tniid.ng operations via annular. > injection in .permitted, wells at the Alpine CD2 Drill Bite. As rioted below, AOGCC approved ouch disposal at the CD1 Drill Site in. 1999, based on the • integral relationship of the mud mixing facility and the on -site drilling > operation. } Ph.Lllips would like to continuing pursni:nc this request. Significant. Olean > ottt of taxik at the :mud mixing facility must occur .i n ,preparation tot the s temporary use atoll based mud products at Alpine in. the coming months. • The availability of annular disposal. as-an option for tank. rinse fluids and > similar wastes would greatl.Y this process. (Typically, routine > rinses are beneficially reused, however, there is a concern about thin > potential quantity tit fluid that•c'ould be•gener ted during this large scale > clean up process.) > Tanks at the mud mixing facility may contain either new and used mud > products. Though rinses in contact with used products may be injected in > the permitted class. fl disposal well, (Ct719 i) ,• rinses ..of new products would > potentially be routed. to the class'. I disposal well (WD -02 , where there is > a difficulty managing solid6 content. 'The Plata I Well is a critical lifeline fbr facility infradLructure, being the. disposal location for all. > domestic effluent, and it is a priority to' prevent any compromise to this > disposal facility. Annular disposal Presents a preferred waste management > alternative in this case. x • • • > Thank you very Much for Your ConsideratiOn Of this reqUeSt. Please do net • s heaitatg to contac t bt nty alternate Via email or phone at (907) 670-4200 > if you have questions or need additional Lnformation. .> Shannon Donnelly 0 . > Jlpina Field.Envirehmental Coordinator > (907) 670-4200 Forwarded by'ALP Env Coord/PPC0 on 11/02/01 .1250 PM ----- . > > ALP Etv Coord 08/1/01 12;45 Pb TO: .t.o.i„jnaUnderge.dniin.state,ak.ua . SUbject: Request to Inject Cement Rinsate at CD 2• > > Dear Mt. maunder, • Injeftion of cement rinsate And cleAn-0 fluids from mud and brine nixing > operations - at the Alpine' mud plant facility into approved - annular disposal s operations was,granted by the Alaska Oil And Gas Conseryatioh Commission • (AOGCC). in the 17,• i999 letter from AOGCC tO.DOug'Chester of ARCO > Alaska, Inc., now Phillip e Alaska, Inc, {?AI). _The approval web gratted.te > PAl specifiCallyrfax Alpine Drill'SiteCD1 add autherized'VolumeS up to 35,000 barrels through the annular space. › > px,I request that this approval be.extended to drilling operations at Alpine. > Drill Site CD2. dement mixing operations fir setting surface conduCters > will be taking place.at the Grind and Inject facility which. is currently > attached to the drilling rig at.C)32 Upon cOmPletion of the cementing in > of the conduct:ore, the lines and mixing tank will have tb be rinsed and the > rinsate disposed of. PAT request approval to inject this rinsate, and > other clean-up from the mud and brine mixing operations, into the annual > space 'of approved Wells Located at Drill Site C1)2. > 1T you have any questions please contact me at 670-4200, > TO Manson > Alpine Field Environmental Compliance i lonurnaundenval • • • • • Casing OR Tubing OR Drilling Detail Well: CD3 -106 1 9 5/8" 40# L -80 BTC Csq Date: 1/23/2010 ConocoPhillips Rig: Doyion 141 Alaska, Inc. Depth Jt Number Joints Well Equipment Description and Comments Length Tops Page 1 l',c " Top of String or Top of Flange Doyon 141 RBK to LR 28.40 ', '' FMC fluted mandral hanger w/ pup jt 2.20 28.40 Jts 3 to 70 68 Jts 9 5/8" 40# L -80 BTCM casing 2612.70 30.60 Weatherford Float collar 1.56 2643.30 Jts 1 to 2 2 Jts 9 5/8" 40# L -80 BTCM casing 78.31 2644.86 Ray Oil Tools Silver Bullet float shoe 2.21 2723.17 2725.38 2725.38 2725.38 2725.38 2725.38 12 1/4" hole to 2735' MD 2481' TVD 2725.38 9 5/8" casing @ 2725' MD 2475' TVD 2725.38 2725.38 2725.38 Ran 40 bow spring centralizers 2725.38 1 cent. on first 12 jts 2725.38 Then 1 cent every other jt /f # 14 to # 68 2725.38 2725.38 2725.38 75 jts total in pipe shed 2725.38 70 jts to run 2725.38 Last 5 jts out 2725.38 2725.38 2725.38 2725.38 2725.38 2725.38 2725.38 2725.38 2725.38 2725.38 2725.38 2725.38 2725.38 Remarks: Average make up torque 11 K Up Wt 150K Dn Wt 90 K Block Wt 35 K ii �l�lil��l�llii • ID ; ._ � IiV ` `I ` Cement Detail Report CD3 -106 CotocoPhil l ip> String: Surface Casing Cement Job: DRILLING ORIGINAL, 1/20/2010 02:00 Cement Details Description Cementing Start Date Cementing End Date Welibore Name Surface Casing Cement 1/24/2010 10:03 1/24/2010 11:45 CD3 - 106 Comment Rig pumped 35 bbls 5 ppb nutplug / biozan spacer. Dropped bottom plug. Dowell tested lines to 2000 psi. Dowell pumped 50 bbls 10.5 ppb mud push, 327 bbls 10.7 ppg ASL and 48 bbls 15.8 ppg tail cement. Dropped top plug and pumped 20 bbls H2O. Rig displaced cement with 176 bbls 9.8 ppg mud. Bumped plug to 1000 psi. Check floats. OK. 100 bbls cement to surface. Cement Stages Stage # 1., Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? Surface Casing Cement Cement Surface 28.0 2,725.4 Yes 100.0 Yes Yes Q (start) (bbl /min) Q (end) (bbl /min) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 8 3 7 500.0 1,000.0 Yes 10.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Rig pumped 35 bbls 5 ppb nutplug / biozan spacer. Dropped bottom plug. Dowell tested lines to 2000 psi. Dowell pumped 50 bbls 10.5 ppb mud push, 327 bbls 10.7 ppg ASL and 48 bbls 15.8 ppg tail cement. Dropped top plug and pumped 20 bbls H2O. Rig displaced cement with 176 bbls 9.8 ppg mud. Bumped plug to 1000 psi. Check floats. OK. 100 bbls cement to surface. Cement Fluids &Additives - _ g - Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 0.0 2,246.0 410 327.0 Yield (ft'/sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 4.49 10.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 2,246.0 2,725.0 232 G 48.0 Yield (ftNsack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 15.80 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 1/19/2011 III Security Level: AK Development T �ul t 4IIy I I I� I iI I I I UI i l i l 5 I' il lij1l i ,, I u ► � l Daily Drilling Report , t III ` ' " �I�I CD3 -106 GQdnQCS}PtSltlfp Report Number: 4 Rig: DOYON 141 Report Date: 1/23/2010 ____ } AFE Type - - =NetworkllD # _ °` € Total AFE +Sup` _ ...,, 10272691 12,825,000.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3 - 106 Development FIORD NECHELIK 3.55 4.0 0.00 2,735.0 2,735.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 3,602.93 36, 540.56 191,282.51 883,114.80 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 1/20/2010 1/20/2010 36.03 32.83 3.20 2/21/2010 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) CONDUCTOR, 107.0ftKB Ops and Depth @ Morning Report 24hr Forecast Circulating preparing to cement Cement and nippled down . Nipple up and test BOPE. Pick up drill pipe Last 24hr Summary Finished wiper trip and pulled out of the hole. Rigged up and ran 9 - 5/8" surface casing to 1610' General Remarks Weather Head Count Calm, clear, -15F 46.0 Supervisor Titfe y. Donnie Lutrick, Rig Supervisor Rig Supervisor Don Mickey, Rig Supervisor Rig Supervisor Guy Whitlock, Rig Supervisor Rig Supervisor Mike Winfree Jr, Drilling Engineer Drilling Engineer Time Log p _ _ ' - Start End Dur £'' Time Depth rDepthEnd Time : ' : Time - '70elj phase Op Code _ _ i Activity Code P -T-X TrbtCode Trbl Class. ====tr (ftKBO=, - -= (ftKB) Operation . ` 00:00 02:45 2.75 SURFAC DRILL WPRT P 2,735.0 2,735.0 Continue running in the hole for wiper trip. Tag bridge at 1010' MD and CBU. Back ream out of the hole to top of HWDP. Run in the hole to 1010' and wash and ream to 1275'. Run in the hole to 1340' and wash through bridge. Run in the hole to 2660' with no problems. - 02:45 06:15 3.50 SURFAC DRILL CIRC P 2,735.0 2,735.0 Wash and ream from 2660' to 2735'. Stage pump up to 500 gpm and circulate two bottoms up. Back ream out of the hole to 2480' while conditioning mud. 06:15 09:00 2.75 SURFAC DRILL TRIP P 2,735.0 2,735.0 Monitor well at 2480'. P/U = 112k, S/0 = 88k. Pull out of the hole to 2110'. Back reamed to 1832'. 09:00 11:00 2.00 SURFAC DRILL TRIP P 2,735.0 2,735.0 Pull out of the hole to 157' 11:00 14:15 3.25 SURFAC DRILL PULD P 2,735.0 2,735.0 Lay down jars and NMDC. Drain motor and lay down same. Download MWD and lay down. 14:15 16:30 2.25 SURFAC CASING PULD P 2,735.0 2,735.0 Clear rig floor and bring casing equipment to floor 16:30 19:30 3.00 SURFAC CASING RURD P 2,735.0 2,735.0 Rig up casing equipment and make dummy run with casing hanger and landing joint. 19:30 00:00 4.50 SURFAC CASING RNCS P 2,735.0 2,735.0 Run casing per detail to 1610' Mud Check Data YP Calc Gel (10s) Gel (10m) Gel (30m) - t Filt Density`remp , Solids rr. Co Type Depth (ftKB) Dens (iblgat) Vies (s /qt) pV Cato (cp) - ={Ibff100ft) >'(Ibf /100f?) (Ibf/100t*) "'- (Itf1100fP) MBT (1b/bbt) _ _ (mtJSOm n) `pH " - ( ° F ) f Y :. Gel Mud 2,735.0 9.80 250 44.0 64.0 29.0 70.0 86.000 8.2 62.0 Gel Mud 2,735.0 9.80 260 45.0 58.0 28.0 78.0 93.000 8.3 67.0 injection Ftutd Fluid Source. : From Lease (bbl) - Destination Vendor Manifest Number Note *" - == -======,:m Drilling Mud WBM CD3 -106 290.0 CD3 -305 ASRC 237309 Drilling Mud WBM CD3 -106 130.0 CD3 -305 ASRC 237310 Drilling Mud WBM CD3 -106 100.0 CD3 -305 ASRC 237311 Latest BOP Test Data Page 1/2 Report Printed: 1/19/2011 11VII,I 0 • Security Level: AK Development , Ii i ,E , � Daily Drilling Report � II 11i I j� I III IiIiV I — II I III1,IV�IIIV1holllllllll„ CD3 -106 ryv I /M :04, .11ll ,I Milli _. -A- Report Number: 4 = lips PIT III�� +EJ" tIlQC41�t'411 Rig: DOYON 141 Report Date: 1/23/2010 Injection Fluid ,. =Fluid Source From Lease (bbi) Destination ,_, Vendor Manifest Number : " Nate Drilling Mud WBM CD3 -106 25.0 CD3 -305 ASRC 237312 Drib= Strings -. -BHA -No. 2 - y7600 Geo -Pilot /`Bit Run No. 2 -,_ 8 314in `SDBS FSFX463ZZ,11352163 - Depth In (ftKB) Depth Out (ftKB) TFA (incl Noz) (in') Nozzles (/32 ") IADC Bit Dull String Wt (1000Ibf) 2,735.0 12,855.0 1.04 15/15/15/15/15/15 3- 1- LT- N- X- 0 -ER -TQ 71 Drill String Components Jts Rem Description OD (in) ID (in)s Top Conn Sz'(in) Top=Thread Cum Len (ft) 1 7600 Geo -Pilot 7.6 1.920 4 1/2 IF 24.61 1 7600 Geoflex collar with DM - 6 3/4 1.920 4 1/2 IF 33.70 1 6 3/4" DGR 6 3/4 1.920 4 1/2 IF 40.22 1 PWD Smart Stab 6 3/4 1.920 4 1/2 IF 48.88 1 6 3/4" EWR / HCIM 6 3/4 1.920 4 1/2 IF 65.81 1 6 3/4'' SLD 6 3/4 1.920 4 1/2 IF 73.68 1 SLD Blade 6 3/4 1.920 4 1/2 IF 76.26 1 6 3/4" ACAL / CTN 6 3/4 1.920 4 1/2 IF 93.37 1 6 3/4" TM HOC 6 3/4 1.920 4 1/2 IF 103.38 1 IBS Stabilizer 6 3/4 2.813 4 1/2 IF 110.38 1 6 3/4" Non Mag Float sub 6 3/4 2.813 4 1/2 IF 112.88 3 6 3/4" Non Mag Flex Drill collar 6.66 2.813 4 1/2 IF 205.73 3 5" HWDP 5 3.000 4 1/2 IF 297.76 1 Drilling Jars Combo tool 6 1/4 2.750 4 1/2 IF 329.49 14 5" HWDP 5 3.000 4 1/2 IF 759.33 1 5" Drill Pipe 5 3.000 4 1/2 IF 790.26 1 8 3/4" Ghost Reamer 6 1/2 2.813 4 1/2 IF 795.89 33 5" DP 5 3.000 4 1/2 IF 1,815.60 1 8 3/4" Ghost Reamer 6 1/2 3.000 4 1/2 IF 1,822.51 2 5" DP 5 3.000 4 1/2 IF 1,884.35 Drilling Parameters, Flow Rate - Sl (gP = = - RPM ` PU Str Wt Drill Str Wt SO Str Wt Start (ftK8} -= End MKS) cum Depth (ft) - = Cum Drilt Time (hrs) Time (hrs) (gpm} woe (tbf) {tF?m) SPP (psi) (1000Jbf) (10001b4 ' (".1000 - :Ofr atm Tq Dri c - 2,735.0 3,070.0 335.00 2.46 45010,00... 60 900.0 115 115 95 5,000.0 8,000.0 Welibores Wellbore Name Wellbore API /UWI CD3 -106 501032061100 Section - - -'Size (in) Act-Top (ftKB) Act Btm (ftKB) Start Date _ End Date', COND 18 0.0 108.0 1/19/2010 SURFAC 12 1/4 108.0 2,735.0 1/20/2010 1/21/2010 INTRM1 8 3/4 2,735.0 12,997.0 1/26/2010 - 2/6/2010 PROD1 6 1/8 12,997.0 17,664.0 2/12/2010 2/18/2010 Page 2/2 Report Printed: 1/19/2011 Security Level: AK Development Daily Drilling Report r4 I, ra „� , „ ��'0i � CD3 -106 GertQesrPhttlips 040 Report Number: 5 Rig: DOYON 141 Report Date: 1/24/2010 AFE Type NetworkllD_ =# t Dial AFE +Sup - . 10272691 12,825,000.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3 - 106 Development FIORD NECHELIK 4.55 5.0 0.00 2,735.0 2,735.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 16,823.19 53,363.75 504,230.30 1,387,345.10 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 1/20/2010 1/20/2010 36.03 33.83 2.20 2/22/2010 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) SURFACE, 2,725.4ftKB Ops and Depth @ Morning Report 24hr Forecast Testing BOPE Finish testing BOPE. Make up cleanout BHA and pick up drill pipe Last 24hr Summary Finish running surface casing. Circulate and condition mud. Cement per program. CIP at 11:45 hrs 1/25/2010. Pressure test casing to 3500 psi for 30 minutes. Nipple down riser and nipple up wellhead. Test head to 1000 psi for 10 minutes. General Remarks Weather Head Count Calm, clear, -18F 46.0 Superva9or Fate Donnie Lutrick, Rig Supervisor Rig Supervisor Don Mickey, Rig Supervisor Rig Supervisor Guy Whitlock, Rig Supervisor Rig Supervisor Mike Winfree Jr, Drilling Engineer Drilling Engineer Time Log Start End Dur ___- Time Depth Start De End - (hrs) Phase- - Op Code _ Activity Code P T_X T€bl Code Trbl Class. in ) ( TtKS} _ Operation 00:00 00:30 0.50 SURFAC CASING CIRC P 2,735.0 2,735.0 Continue circulating two bottoms up. Increase rate to 6 bpm @ 350 psi. 00:30 03:30 3.00 SURFAC CASING RNCS T Hole Other 2,735.0 2,735.0 Work casing around curve from 1620' to Conditions 1645' 03:30 05:15 1.75 SURFAC CASING RNCS P 2,735.0 2,735.0 Coontinue running surface casing to 2725 P/U 140k, S/0 90k 05:15 06:30 1.25 SURFAC CEMENT RURD P 2,735.0 2,735.0 Rig down fill up tool and make up cement head. 06:30 09:15 2.75 SURFAC CEMENT CIRC P 2,735.0 2,735.0 Break circulation and stage rate up to 6 bpm at 470 psi. 09:15 12:00 2.75 SURFAC CEMENT PUCM P 2,735.0 2,735.0 Pre -job safety meeting. Pump cement per plan and bump plug at 11:45 hrs 1 -24 -2010 12:00 13:00 1.00 SURFAC CEMENT PRTS P 2,735.0 2,735.0 Pressure test casing to 3500 psi for 30 minutes. Flush riser and flow line. Drain riser and lines 13:00 15:45 2.75 SURFAC DRILL RURD P 2,735.0 2,735.0 Pre -job safety meeting, Rig down casing and cementing equipment. Lay down landing joint and riser. Clear rig floor. Change bails. 15:45 17:45 2.00 SURFAC WHDBOP NUND P 2,735.0 2,735.0 Nipple down 20" annular, adapter flange, and diverter spool. Clear cellar. 17:45 00:00 6.25 SURFAC WHDBOP PRTS P 2,735.0 2,735.0 Nipple up wellhead and test to 1000 psi for 10 minutes. Mud Check Data ` - . YP Gel (LOS) - -- Gel (10m) ,, Gei (36tH) KTHP Fitt , Density Temp S olids, Corr Type Depth (ftka) . Dens (lb /gal) Vis (skit) PV Celt_ (cp)- (tbff1 X ft9 - -. (lb€t1OOftt)- = pbf/1OOftx) (lbfttOOft ") MBT jibtbbt) (m1130rrUn ° pal ) Spud Mud 2,735.0 9.90 300 57.0 56.0 20.0 43.0 68.000 30.0 9.3 56.0 Injection Fluid Fluid "' Source From Lease (bogy' Destination Vendor Manifest,, Number Note _ Cement CD3 -106 220.0 CD3 -305 ASRC 237318 Cement Rinsate CD3 -106 250.0 CD3 -305 ASRC 237315 Cementing Fluids CD3 -106 100.0 CD3 -305 ASRC 237319 Drilling Mud OBM CD3 -106 275.0 CD3 -305 ASRC 237316 Latest BOP Test Data Date Comment = =`'' Page 1/2 Report Printed: 1/19/2011 II • Security Level: AK Development °'''` °'' ```� °" Daily Drilling Report 1 ilu it t tm ' ' - o. CD3 -106 C coPhillips Report Number: 5 Rig: DOYON 141 Report Date: 1/24/2010 Injection Fluid = _ Fluid = . ," ;- - -- Source From Lease (bbl) - - Destination . Vendor " Manifest Number Note Drilling Mud WBM CD3 -106 270.0 CD3 -305 ASRC 237320 Drilling Mud WBM CD3 -106 255.0 CD3 -305 ASRC 237414 Drilling Mud WBM CD3 -106 155.0 CD3 -305 ASRC 237313 Drilling Mud WBM CD3 -106 70.0 CD3 -305 ASRC 237317 Pit Rinsate CD3 -106 20.0 CD3 -305 ASRC 237323 Drill Strings:I - BHA No. 2 - =7600 Geo -Pilot 1 Bit Run No. ''2 - 8 3 /4in SDBS, FSFX463ZZ, 113521630= Depth In (ftKB) Depth Out (ftKB) TFA (inci Noz) (in') Nozzles (/32 ") IADC Bit Dull String Wt (1000Ibf) 2,735.0 12,855.0 1.04 15/15/15/15/15/15 3- 1- LT- N- X- 0 -ER -TQ 71 Drill String Components Jts - - Iten=Description OD (in) _ 'ID (in) Top Coon Sz (in) Top Thread Cum Len (ft) 1 7600 Geo -Pilot 7.6 1.920 4 1/2 IF 24.61 1 7600 Geoflex collar with DM 6 3/4 1.920 4 1/2 IF 33.70 1 6 3/4" DGR 6 3/4 1.920 4 1/2 IF 40.22 1 PWD Smart Stab 6 3/4 1.920 4 1/2 IF 48.88 1 6 3/4" EWR / HCIM 6 3/4 1.920 4 1/2 IF 65.81 1 6 3/4" SLD 6 3/4 1.920 4 1/2 IF 73.68 1 SLD Blade 6 3/4 1.920 4 1/2 IF 76.26 1 6 3/4" ACAL / CTN 6 3/4 1.920 4 1/2 IF 93.37 1 6 3/4" TM HOC 6 3/4 1.920 4 1/2 IF 103.38 1 IBS Stabilizer 6 3/4 2.813 4 1/2 IF 110.38 1 6 3/4" Non Mag Float sub 6 3/4 2.813 4 1/2 IF 112.88 3 6 3/4" Non Mag Flex Drill collar 6.66 2.813 4 1/2 IF 205.73 3 5" HWDP 5 3.000 4 1/2 IF 297.76 1 Drilling Jars Combo tool 6 1/4 2.750 4 1/2 IF 329.49 14 5" HWDP 5 3.000 4 1/2 IF 759.33 1 5" Drill Pipe 5 3.000 4 1/2 IF 790.26 1 8 3/4" Ghost Reamer 6 1/2 2.813 4 1/2 IF 795.89 33 5" DP 5 3.000 4 1/2 IF 1,815.60 1 8 3/4" Ghost Reamer 6 1/2 3.000 4 1/2 IF 1,822.51 2 5" DP 5 3.000 4 1/2 IF 1,884.35 Drilling Parameters FFow Rate Sliding ' _(9Pm) __ RPM _ PU Str VW Agrill Str Wt SO Stf' EWt' Start (ftKB), End (ftKB) Cum Depth (ft) Cum Drill Time (hrs) Time (hrs) (9Pm) ' WOB (lbf) (rPm) SPP (psi) (1000Ibf) _ = (1000Ibf) (1000Ib4 .0frkceaTo Orill Tq ° __ 2,735.0 3,070.0 335.00 2.46 450 10,00... 60 900.0 115 115 95 5,000.0 8,000.0 Welibores " Wellbore Name Wellbore API /UWI CD3 -106 501032061100 . - Section . . ` ' Size (in) _ 'r Act Too (ftKB) ` Act Btm (ftKB) . Start Date,'', End'; Date " == COND 18 0.0 108.0 1/19/2010 SURFAC 12 1/4 108.0 2,735.0 1/20/2010 1/21/2010 INTRM1 8 3/4 2,735.0 12,997.0 1/26/2010 2/6/2010 PROD1 6 1/8 12,997.0 17,664.0 2/12/2010 2/18/2010 .Cement _ _ 41F - Surface Casing Cement - Started i6 1/24/2010 Type Wellbore Cemented String Cement Evaluation Results casing CD3 - 106 SURFACE, 2,725.4ftKB Stg No. Description Top (ftKB) Bottom (ftKB) 0 (end) (bbl /... P (final) (psi) 1 Surface Casing Cement 28.0 2,725.4 3 500.0 - -- Fluid Class Amount (sacks) V (bbl) Density (tb /gal) _ -'Yield (ft'/sack) EstTop Est,Btm_(ftKB) Lead Cement 410 327.0 10.50 4.49 0.0 2,246.0 Tail Cement G 232 48.0 15.80 1.16 2,246.0 2,725.0 Page 2/2 Report Printed: 1/19/2011 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD3 -106 Rig: Doyon 141 Date: 1/24/2010 Volume Input Volume /Stroke Pum. Rate: Drilling Supervisor: D. Lutrick / M. Thornton Pump used: #2 Mud Pump Strokes O.1000 Bbls /strk 7.00 Strk/min Type of Test: Casing Shoe Test LOT /FIT ■ Pumping down annulus and DP. ■ Casing Test Pressure Integrity Test Hole Size: USE PICK LIST ■ Casing Shoe Depth Hole Depth Pumping Shut -in Pumping Shut -in RKB -CHF:, 28.OIFt 2725.OIFt -MDI 2475.OIFt -TVD 2755.OIFt -MD I2491.OIFt -TVD Strks psi Min psi Strks psi Min psi Casing Size and Description: 9 -5/8° 40 # /Ft L -80 BTC v 0 50 0 3550 0 0 0.00 1050 Casing Test Pressure IntegrityTest 2 175 1 3545 1 84 0.25 Mud Weight: 9.8 ppg Mud Weight: 9.7 ppg 4 350 21 3540 2 205 0.50 950 Mud 10 min Gel: 3.0 Lb /100 Ft2 Mud 10 min Gel: 15.0 Lb /100 Ft2 6 500 3 3540 3 377 1.00 925 Test Pressure: 3500.0 psi Rotating Weight: 115.0 Lbs 8 750 4 3535 4 420 1.50 910 a Rotating Weight: 110.0 Lbs Blocks/Top Drive Weight: 35.0 Lbs 10 925 5 3535 5 486 2.00 900 locks/Top Drive Weight 35.0 Lbs Desired PIT EMW: 18.0 ppg 12 1130 6 3530 6 562 2.50 890 Estimates for Test: 2.7 bbls Estimates for Test: 1068 psi 0.8 bbls 14 1350 7 3525 7 655 3.00 880 v ■ 16 1575 8 3525 8 691 3.50 870 EMW = Leak-off Pressure + Mud Weight = 934 PIT 15 Second 18 1790 9 3520 9 726 4.00 860 0.052 x TVD 0.052 x 2475 + 9 ' 7 Shut -in Pressure, psi 20 2000 10 3515 10 796 4.50 850 EMW at 2725 Ft -MD (2475 Ft -TVD) = 17.0 ppg Fill in FIT Columns ==> 22 2210 15 3510 11 845 5.00 830 4000 - Lost 50 psi during test, held 24 2450 20 3510 12 912 5.50 820 98.6% of test pressure. 26 2690 25 3505 13 934 6.00 820 3500 � If '�' �� '"��'�� 28 2910 30 3500 14 961 6.50 810 . . 111111111111111111111131 30 3180 15 1005 7.00 810 3000 ■■■INIVIIIi!INIIIMI 32 3450 16 1021 7.50 810 33 3550 17 1070 8.00 800 LLI 2500 8.50 800 9.00 800 2000 9.50 800 10.00 800 Illig 1500 -- -micas 1000 ��121111 iii - s s��s■■ mno ss� .n 500 0 , . 0 1 2 3 4 0 5 10 15 20 25 30 m Volume Volume Barrels h -In time, Minutes Volume Volume Sut t e "CASING TEST --LEAK -OFF TEST 0 PIT Point Pumped Bled Back Pumped Bled Back 3.3 Bbls IBbls 1.7 Bbls IBbls Comments: FIT Performed 1/26/10 CD3 -306 Surface FIT.xls Summary PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: I CD3-106 I Rig: Doyon 141 'Date: I 2/8/2010 I Volume Input Volume/Stroke I Pump Rate: Drilling Supervisor: I L. Hill,/ M. Thornton Pump used:7 #2 Mud Pump V Strokes .0:10,09 Bbls/Strk W :;'':7:: Strk/min ■ Type of Test: Annulus Leak Off Test for Disposal Adequacy ■ Pumping down annulus. ■ - , Casing Test Pressure Integrity Test Hole Size: USE PICK LIST " Casing Shoe Depth Hole Depth Pumping Shut-in Pumping Shut-in RKB-CHF: 28.0IFt 2725.0IFt-MDI 2475.OIFt 557 I 3801.0IFt-TVD Strks psi Min psi Strks psi Min psi Casinq Size and Description: 9 40#/Ft L BTC v :i:Hg; ;;;:;;;;;;;;; 0 .. 0 0.00 430 Changes for Annular Adequacy Test Pressure IntearitvTest :i:i:: ;;;;;;;;;;;;; 1 ;;;;;;;;;;;;;; 4 170 0.25 430 Enter outer casing shoe test results in comments Mud Weight: 10.6 ppg H:;i:::':.:.::: 2 H::H 8 180 0.50 430 Casing description references outer casing string. Inner casing OD: 7.0 In. ::::;:Hi:i::,::::: ,.: i ,. 12 210 1.00 35t .,.,. Hole Size is that drilled below outer casing. :;:;;;;;;,-',:„. ,::::::::!:1 4 ;:;:;:;:;:,;::: 16 230 1.50 350 Use estimated TOC for Hole Depth. ;;;;;;;;;;;;:;;;;;;:::,:i:i:i 5 ;:;:::::::::i: 20 260 2.00 340 Enter inner casing OD at right. Desired PIT EMW: 18.0 ppg :;:;:;:;:;;;;;;:::;;;;;;;;;:; 6 '' 24 270 2.50 330 Estimates for Test: 952 psi -0.2 bbls 7 ;:i:H::H; 28 300 3.00 320 v ■ ;;;;;;;;;;;;;;,:;;;;;:;:::- 8 H:;;;;;;;; 32 340 3.50 320 ..- -,--, EMW = Leak-off Pressure + Mud Weight = 570 PIT 15 Second :i;i:i:H:::H;;;;;;; 9 i:::::;:::;;;; 36 340 4.00 320 . 0.052 x TVD 0.052 x 2475 + 10 6 Shut-in Pressure, psi ;:::;:;::::i: :::::.::: 10 :::::::::;:;:; 40 350 4.50 320 ... - - , . ,; .. EMW at 2725 Ft-MD (2475 Ft-TVD) = 15.0 430 H:;;;;;;;;;;;;;;;;;H:;;;; 15 ::;:::;;;;:: 44 380 5.00 320 1000 / - - ;;;;;;;;;;:;:;:;;;;;; 20... 48 410 5.50 320 25 ;:;:;:;;;:;:::: 52 420 6.00 320 30 Z:;;:il 56 440 6.50 320 60 460 7.00 320 64 490 7.50 320 .............. ,...„,„..., 68 500 8.00 320 72 520 8.50 310 76 530 9.00 31. 0 500 ,,, :i 450 1 1?; 1 80 560 9.50 310 (n 1 84 570 10.00 310 , ce . 88 580 o_ „ t 15 bil::::............... ‘- 13.°19 92 560 .„ ..„. 96 480 100 430 104 430 108 420 116 420 o ,:, . , . ' ::..,.,. :::: 124 430 , 0 2 4 6 8 10 12 14 0 5 10 15 20 25 30 Barrels Shut-In time, Minutes Volume Volume Volume Volume Itlm'CASING TEST - Ell - LEAK - OFF TEST 0 PIT Point Pumped Bled Back Pumped Bled Back 0.0 Bbls _ .;;ii'ii;lBbls 12.4 Bbls ;;Iii;;;;i1Bbls Comments: Liu,)- 1 uo 1 .uu x u.oz5 Lk., 1 .m5 Summary CD3 -106 Intermediate Well: CO3 - 106 r 26 _tf L-80 BTC -m Casini Date: 217/2010 conoc4 '1ft!' Rig: Doyon Rig 141 Alaska, Inc. Depth Jt Number Joints Well Equipment and Comments Length Tops Page 1 ............................. ................... ... ........... ................. .............. ..... ... ............................. ....................... ........... ...... .......... .............. ......... ................. ........... ....................... ........... ..... .. ........ ....... .............. ...... .... ................. orTo: f Tlt IC.p ........ . .. RKB to Casing Flange (LLDS 25.02 �`�'` 11 1.1....:: : g 9 ( �} 25.02 .11$111,11 P,. ' 111NRI e FMC 7" Mandrel hanger .54 25.02 7 ", 26 #, L -80, BTC -m Casing Pup jt Pin x Pin 2.18 25.56 Jts 153 to 31E 166 Jts 7 ", 26 #, L - 80, BTC - Casing 6773.13 27.74 HES 7" Stage Collar 2.50 6800.87 Jts 4 to 152 149 Jts 7 ", 26 #, L - 80, BTC - Casing 6057.56 6803.37 HES Shut - off Baffle Collar 1.10 12860.93 Jts 3 to 3 1 Jts 7 ", 26 #, L - 80, BTC - Casing 39.91 12862.03 HES Sure Seal n Float Collar w/ By - Pass Baffle Adapter 1.00 12901.94 Jts 1 to 2 2 Jts 7 ", 26 #, L - 80, BTC - Casing 81.34 12902.94 Ray Oil Tools " Silver Bullet" Float Shoe 1.95 12984.28 12986.23 8 -3/4" Hole TD @ 12,997' MD / 6,945 ' TVD, Hole angle 84.56 deg 12986.23 7" Shoe @ 12,986.23' MD / 6944' TVD / Hole angle 84.56 deg 12986.23 Rathole 10.77' 12986.23 i ; : ; :::: ,, 12986.23 Total`af 29 S #raight: Made �ritrlirs �7:::�c &-�t8 );:.: 1 Bc wspr ing centralizer . stap 10: above sh -,fit, : k1::jt 12986.23 . ... ;:.:. - :::: .::::::::::::: 1 St atglat'Bl r t al r v�rl:stop ring 'I k : : : help Fiaet: l ar lf: # ::::::::::::::: 12 986.23 .'- 1:: Ott' a #gltzBlael:c+eritraizr c��ll.ar below:Baffle.Rdaptoc 12986.23 �lt. 12986.23 9 P I 1 9 Qannik top @ 6,248' , Base @ 6,304' 12986.23 Total of 122 Bt S 22 l lack E l it a eeiitr;alizers 7 ": 114 °.' . .' 12986.23 12986.23 1 Per;latrt.. firc�m Jt � # . �� afl 9 12986.23 " :: ��. 12986.23 Thal �f26 Straight:: Made �ritrali�rs : t7 :: x.� -3,i8 � :: ;;;; 1Watgtt Blacl ritralizars peri#`l~iii jts #;'1;53ta # 8 flpag ... , 1 12986.23 23 12986.23 lac C? ` e ' : . .. . ........... Total: of 74 t�6 B k 1 a 2�.� 1 � �±ald I�QS 1 � certti`�Ifs 12986.23 lz. . 1 Pe Jatrt fr�rri !t#�179 a #? .2. boat g 12986. 23 12986.23 Total cif 32 . Straight! Blade centralizers 7x6- : : : : : : : : : : : : :.. :; : : : : : : : :: : : : : : : : : : 12986.23 1:: Eve y :Otlher: t from Jt#253 to #3:16 (Bath #a10::0:#54%; FIf at€rE 12986.23 J. : { g 12986.23 Planned: 330 jts in pipe shed / 318 jts to run. 12986.23 12 joints left in the shed 12986.23 Remarks: Drifted w/ 6.151" plastic rabbit Up Wt 315 K Average MU torque= 8000 Ft Ibs Dn Wt 115 K Block Wt 35 K Ili 10 Cement Detail Report '' ,?! lll CD3 -106 ConocoPhill ips String: Intermediate Casing Cement Job: Dement. Detalfs Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 2/8/2010 11:00 2/8/2010 15:30 CD3 -106 Comment Turn over to Dowell, Pump First Stage w/ 5.0 bbls CW100 at rate of 5.0 bpm @ 370 psi, Test lines to 3600 psi - OK, Continue pumping to total of 39.3 bbls CW100 at rate of 5.0 bpm @ 450 psi, Mix & pump 30.5 bbls 12.0 ppg Mud PUSH mixed to 12.0 ppg at rate of 5.5 bpm @ 500 psi, Shut down, Drop bottom plug & Reload head with 2nd plug, Batch mix cement to 15.8 ppg, Pump total of 62.8 bbls (304 sacks) Class "G" cement w/ 0.2% D46, 0.3% D65, 0.11% B155, 0.4% D167 - 1.16 ft3 /sk Yield at rate of 5.0 bpm @ 500 psi, Drop top plug, Pump 20 bbls fresh water followed by 479.6 bbls 10.6 ppg mud at rate of 7 bpm @ 650 psi, Bump plug w/ 1200 psi, Check floats- OK, First Stage C.I.P @ 13:30 hrs 2/8/10, Calculated TOC @ 11,900', Worked casing 10' to 15' while cementing until last 4 bbls prior to bumping plug. Pressure up to 3200 psi to open Stage Collar © 6800', Load 3rd plug. Circ bottom's up at rate of 7.5 bpm @ 350 psi. Pump 29.1 bbls CW100 at rate of 4.5 bpm @ 250 psi followed by 35.9 bbls MudPUSH mixed at 12.0 ppg at rate of 4.5 bpm @ 250 psi, Batch mix cement & pump total of 56.1 bbls (271 sacks) Class "G" cement w/ 0.2% D46, 0.3% D65, 0.8% S2 - 1.16 ft3 /sk Yield at rate of 5.0 bpm © 300 psi, Drop closing plug, Pump 20 bbls fresh water followed by 243.6 bbls 10.6 ppg mud at rate of 7 bpm @ 400 psi, Bump plug w/ 900 psi, C.I.P @ 15:30 hrs 2/8/10, Calculated TOC @ 4,705. Cement Stages Stage `# 1 Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? Intermediate Casing Primary 11,900.0 12,986.0 Yes Yes Yes Cement Q (start) (bbl /min) Q (end) (bbl /min) Q (avg) (bbl /min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) Yes No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Turn over to Dowell, Pump First Stage w/ 5.0 bbls CW100 at rate of 5.0 bpm @ 370 psi, Test lines to 3600 psi - OK, Continue pumping to total of 39.3 bbls CW100 at rate of 5.0 bpm @ 450 psi, Mix & pump 30.5 bbls 12.0 ppg Mud PUSH mixed to 12.0 ppg at rate of 5.5 bpm © 500 psi, Shut down, Drop bottom plug & Reload head with 2nd plug, Batch mix cement to 15.8 ppg, Pump total of 62.8 bbls (304 sacks) Class "G" cement w/ 0.2% D46, 0.3% D65, 0.11% 8155, 0.4% D167 - 1.16 ft3 /sk Yield at rate of 5.0 bpm @ 500 psi, Drop top plug, Pump 20 bbls fresh water followed by 479.6 bbls 10.6 ppg mud at rate of 7 bpm @ 650 psi, Bump plug w/ 1200 psi, Check floats- OK, First Stage C.I.P @ 13:30 hrs 2/8/10, Calculated TOC @ 11,900', Worked casing 10' to 15' while cementing until last 4 bbls prior to bumping plug. Pressure up to 3200 psi to open Stage Collar @ 6800', Load 3rd plug. Circ bottom's up at rate of 7.5 bpm @ 350 psi. Pump 29.1 bbls CW100 at rate of 4.5 bpm © 250 psi followed by 35.9 bbls MudPUSH mixed at 12.0 ppg at rate of 4.5 bpm © 250 psi, Batch mix cement & pump total of 56.1 bbls (271 sacks) Class "G" cement w/ 0.2% D46, 0.3% D65, 0.8% S2 - 1.16 ft3 /sk Yield at rate of 5.0 bpm @ 300 psi, Drop closing plug, Pump 20 bbls fresh water followed by 243.6 bbls 10.6 ppg mud at rate of 7 bpm @ 400 psi, Bump plug w/ 900 psi, C.I.P @ 15:30 hrs 2/8/10, Calculated TOC @ 4,705'. Cement. Fluids & Additive§ fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Intermediate Cement 11,900.0 12,986.0 G Yield (fP /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Retarder 8155 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 %BWOC Additive Type Concentration Conc Unit label Antifoam D46 %BWOC Page 1/2 Report Printed: 1/19/2011 �llll9 • L Ali emu% Cement Detail Report CD3 -106 CeoPhillps String: Intermediate Casing Cement Job: Cement Stages = Stage # 2 -- Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? Intermediate Casing Secondary 5,571.0 6,800.0 Yes No Yes Cement Q (start) (bbl /min) Q (end) (bbl /min) Q (avg) (bbl /min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) No No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Turn over to Dowell, Pump First Stage w/ 5.0 bbls CW100 at rate of 5.0 bpm @ 370 psi, Test lines to 3600 psi - OK, Continue pumping to total of 39.3 bbls CW100 at rate of 5.0 bpm @ 450 psi, Mix & pump 30.5 bbls 12.0 ppg Mud PUSH mixed to 12.0 ppg at rate of 5.5 bpm @ 500 psi, Shut down, Drop bottom plug & Reload head with 2nd plug, Batch mix cement to 15.8 ppg, Pump total of 62.8 bbls (304 sacks) Class "G" cement w/ 0.2% D46, 0.3% D65, 0.11% 8155, 0.4% D167 - 1.16 ft3 /sk Yield at rate of 5.0 bpm @ 500 psi, Drop top plug, Pump 20 bbls fresh water followed by 479.6 bbls 10.6 ppg mud at rate of 7 bpm @ 650 psi, Bump plug w/ 1200 psi, Check floats- OK, First Stage C.I.P @ 13:30 hrs 2/8/10, Calculated TOC @ 11,900', Worked casing 10' to 15' while cementing until last 4 bbls prior to bumping plug. Pressure up to 3200 psi to open Stage Collar @ 6800', Load 3rd plug. Circ bottom's up at rate of 7.5 bpm @ 350 psi. Pump 29.1 bbls CW100 at rate of 4.5 bpm @ 250 psi followed by 35.9 bbls MudPUSH mixed at 12.0 ppg at rate of 4.5 bpm @ 250 psi, Batch mix cement & pump total of 56.1 bbls (271 sacks) Class "G" cement w/ 0.2% D46, 0.3% D65, 0.8% S2 - 1.16 ft3 /sk Yield at rate of 5.0 bpm @ 300 psi, Drop closing plug, Pump 20 bbls fresh water followed by 243.6 bbls 10.6 ppg mud at rate of 7 bpm @ 400 psi, Bump plug w/ 900 psi, C.I.P @ 15:30 hrs 2/8/10, Calculated TOC @ 4,705'. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Intermediate Cement 5,571.0 6,800.0 G Yield (ft' /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Antifoam D46 Additive Type Concentration Conc Unit label Dispersant D65 Additive Type Concentration Conc Unit label S2 Page 2/2 Report Printed: 1/19/2011 • • Security Level: AK Development Daily Drilling Report ►frill t I 61tt II I,I CD3 -106 ConocoPhillips Report Number: 19 Rig: DOYON 141 Report Date: 2/7/2010 "- AFE Type _ _ Network/(D # 'r at AFE +3up.. „ 10272691 12, 825, 000.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3 - 106 Development FIORD NECHELIK 18.55 19.0 0.00 12,997.0 12,997.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 4,406.81 492,146.08 188,222.81 4,840,614.28 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 1/20/2010 1/20/2010 36.03 36.52 -0.49 2/25/2010 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) SURFACE, 2,725.4ftKB Ops and Depth @ Morning Report 24hr Forecast Running 7" casing @ 12,136' Finish running 7" csg to 12986', Circ & cond. mud, Cmt 7" csg in 2 stages, Set 7" pack off, Change rams to 4 ", Rig & test BOP, UD 5" DP Last 24hr Summary POOH & stand back HWDP & Flex collars, Remove RA sources, Down load MWD, UD BHA, Pull wear bushing & Set test pulg, Change top pipe rams to 7 ", Test Rams & Hydril to 250 low & 3500 psi on Rams & 2500 psi on Hydril, Set thin wall wear bushing, Rig & run 7" csg to 2633', Circ pipe vol., Run 7" csg to 6102', Circ BTU, Run 7" csg to 8386'. General Remarks Weather Head Count No Accidents - No Spills Temp -27, WC -47, Ptly Cldy, Wind S @ 8 45.0 mph Supervisor Title Larry Hill, Rig Supervisor Rig Supervisor Mike Thornton, Rig Supervisor Rig Supervisor Mike Winfree Jr, Drilling Engineer Drilling Engineer Time Log Start End - _= Our !' Time 7 , Depth Start Depth End_ ; " ' Time Time__ (hrs) Phase 001 Code P T x - Trbt Code -Trbl Class. - (ftKB) (ftKB) .:1;1g; Operation - 00:00 01:00 1.00 INTRM1 DRILL TRIP P 2,706.0 761.0 Continue POOH from 2,706' to 761'. 01:00 02:00 1:00 INTRMI DRILL PULD P 761.0 85.0 Racked back 6 stands HWDP and laid down 2 jts. 02:00 06:30 4.50 INTRM1 DRILL PULD P 85.0 0.0 PJSM. Unloaded Nukes and downloaded MWD. Finished lay down BHA. 06:30 07:00 0.50 INTRM1 WHDBOP BOPE P 0.0 0.0 Pulled wear ring and set test plug. • 07:00 09:30 2.50 INTRM1 WHDBOP BOPE P 0.0 0.0 Changed rams to 7" and tested to 250/3500 psi. OK, Test Hydril to 250/2500 psi. OK. 09:30 10:30 1.00 INTRM1 WHDBOP BOPE P 0.0 0.0 Pulled test plug and set thin wear ring. Cleaned up Rig Floor. 10:30 12:15 1.75 INTRM1 CASING RURD P 0.0 0.0 Rigged up to run 7" casing. 12:15 12:30 0.25 INTRM1 CASING SFTY P 0.0 PJSM on running casing. 12:30 15:30 3.00 INTRM1 CASING RNCS P 0.0 2,633.0 Pick up & Make up 7 ", 26# Shoe track with Halliburton HES Baffle Adapter & Baffle Collar, RIH w/ 7" csg as per detail pick up all centralizers as detail to 2,633'. 15:30 16:15 0.75 INTRM1 CASING CIRC P 2,633.0 2,633.0 Circ 110 bbls casing volume at 5 bpm @ 400 psi. 16:15 19:30 3.25 INTRM1 CASING RNCS P 2,633.0 6,102.0 RIH w/ 7" casing following suggested running speed schedule to 6,102'. 19:30 20:30 1.00 INTRM1 CASING CIRC P 6,102.0 6,102.0 Circ bottom's up maintaining mud weight 10.6 ppg at rate of 5 bpm @ 500 psi. 20:30 00:00 3.50 INTRM1 CASING RNCS P 6,102.0 8,386.0 RIH w/ 7" casing following suggested running speed schedule to 8,386'. Mud Check Data YP Cate Gel (10s) Get (10m) Gel (30m) t(THP Fiat Density Temp Solids, Corr. Type Depth(t1103) Dens (Ib/gal) €Vis(s/gt) PVCele'(cp) (Ibftl00ft (Ibf /100ft') (lbfl100ft=) (ibf/1OOfN) MBTijb ))= (mt/30mut pH (F) (%) Inhibicol 12,997.0 10.70 48 10.0 17.0 5.0 7.0 9.000 22.5 6.6 9.5 95.0 15.0 Spike Latest BOP Test Data Page 1/2 Report Printed: 1/19/2011 • 0 Security Level: AK Development 4114 Daily Drilling Report CD3 -106 coe4phillips Report Number: 19 Rig: DOYON 141 Report Date: 2/7/2010 Mud Check Data_ `„ - - YP Dale ,Get (10s) > Gel (10m) Gel, (30m) HTHP File" ` Density Temp _Solids, Corr. Type „' Depth (ftKB) Dens (Ib /gal) Vie (s/qt) - _PV Cale (op) "(Ibf /100ft) (Ibff100ft r (1bf110Oft”) (Ibf/1 OOft) MST (iblbbl) _(mU3Omin) pH (F) _( %) Inhibicol 12,997.0 10.65 48 10.0 18.0 5.0 7.0 8.000 17.5 5.6 9.5 82.0 15.0 Spike Inhibicol 12,997.0 10.65 38 10.0 17.0 5.0 7.0 8.000 17.5 5.6 9.5 97.0 15.0 Spike Drill Strings: - BHA No. 3 - Steerable / Bit Run No. 3 - 8 3/41n, Hughes Christensen HCM605, 7101139 Depth In (ftKB) Depth Out (ftKB) TFA (incl Noz) (in') Nozzles (/32 ") IADC Bit Dull String Wt (1000Ibf) 12,855.0 12,997.0 0.98 16/16/16/16/16 0- 0- NO- A- X- 0 -NO -TD 50 Drill String Components Jts = Item Description OO (in) ID (in)',, Top Conn Sz' {in) Top Thread Cum Len (ft) Motor with Stabilizer 7 4.753 4 1/2 IF 26.29 1 Float Sub 6.56 2.813 4 1/2 IF 28.79 1 Stabilizer 6 3/4 2.813 4 1/2 IF 35.79 1 MWD DM HOC 6 3/4 1.920 4 1/2 IF 44.82 1 MWD DGR/PWD /EWR/HCIM 6 3/4 1.920 4 1/2 IF 76.92 1 MWD ALD /CTN 6 3/4 1.920 4 1/2 IF 104.40 1 MWD TM HOC 6 3/4 1.920 4 1/2 IF 114.41 3 Drill Collar 6 3/4 3.000 4 1/2 IF 207.26 1 HWDP 5 3.000 41/2 IF 299.29 1 Drilling Jars combo 5 2.750 4 1/2 IF 331.02 14 HWDP 5 3.000 4 1/2 IF 760.86 Wellbores : -: Wellbore Name Wellbore API /UWI CD3 -106 501032061100 Section - Size (in) Act Top (ftKB)=- Act Skit-MKS) +' Start Date __ ,_ End Date COND 18 0.0 108.0 1 /19/2010 SURFAC 12 1/4 108.0 2,735.0 1/20/2010 1/21/2010 INTRM1 8 3/4 2,735.0 12,997.0 1/26/2010 2/6/2010 PROD1 6 1/8 12,997.0 17,664.0 2/12/2010 2/18/2010 Page 2/2 Report Printed: 1/19/2011 • Security Level: AK Development k II a po Daily Drilling Report V l p it ` Art. i i h . Pulp) -1 CD3 -106 Report Number: 20 ConocoPhitIips ,, Rig: DOYON 141 Report Date: 2/8/2010 AFE Tyne Network/0# Total AFE +Sup` `- 10272691 12,825,000.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3 -106 Development FIORD NECHELIK 19.55 20.0 0.00 12,997.0 12,997.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 27,244.92 519,391.00 868,536.92 5,709,151.20 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 1/20/2010 1/20/2010 36.03 37.52 -1.49 2/26/2010 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) INTERMEDIATE, 12,986.2ftKB Ops and Depth @ Morning Report 24hr Forecast Rigging up to lay down 5" DP. Finish BOP test, UD 5" DP f/ DRK, P/U 4" & std in DRK, P/U 6 -1/8" BHA & Single in hole. Last 24hr Summary Finish running 7" csg to 12986', Circ & cond mud, Cement 7" w/ 2 stages, Set & test pack off, Clear floor of tools, Change upper & lower rams, LOT 7" x 9 -5/8" ann to 15.1 EMW, Flush ann w/ 85 bbls fresh water, Freeze protect ann w/ 60 bbls diesel to 2060' TVD, Begin BOP Test. General Remarks Weather Head Count No Accidents - No Spills Temp -35, WC -55, Mostly Cldy, Wind Calm 45.0 ' _Supervisor Title Larry Hill, Rig Supervisor Rig Supervisor Mike Thornton, Rig Supervisor Rig Supervisor Mike Winfree Jr, Drilling Engineer Drilling Engineer Time Log End Dur Agt Time Depth Start Depth End '41:1 ; Tune_ - Time (hrs) Phase OR Code= ---__- _= Activity =Code P -T-X Trial Code Trbl Ctass (ftKB) UM) Operation=_ 00:00 01:00 1.00 INTRM1 CASING RNCS P 8,386.0 9,196.0 RIH w/ 7" casing following suggested running speed schedule to 9,196'. 01:00 01:30 0.50 INTRM1 CASING CIRC P 9,196.0 9,196.0 Circ 100 bbls mud maintaining mud weight 10.6 ppg at rate of 5 bpm @ 500 psi. 01:30 04:30 3.00 INTRM1 CASING RNCS P 9,196.0 11,614.0 RIH w/ 7" casing following suggested running speed schedule to 11,614'. 04:30 05:00 0.50 INTRM1 CASING CIRC P 11,614.0 11,614.0 Circ 100 bbls mud maintaining mud weight 10.6 ppg at rate of 5 bpm @ 650 psi. 05:00 07:00 2.00 INTRM1 CASING RNCS P 11,614.0 12,960.0 RIH w/ 7" casing following suggested running speed schedule to 12,960', Up 315K, Dn 115K, Casing took correct displace going in hole. - No problems running casing. 07:00 07:15 0.25 INTRM1 CASING RNCS P 12,960.0 12,986.0 Make up Landing joint & Hanger, Land casing on depth @ 12,986'. 07:15 08:00 0.75 INTRM1 CEMENT PULD P 12,986.0 12,986.0 lay down Frank's Fill up tool, Make up Dowell cement head. 08:00 10:30 2.50 INTRM1 CEMENT CIRC P 12,986.0 12,986.0 Circ & Cond. Mud, Stage rate f/ 3 bpm © 510 psi to 7 bpm @ 900 psi, Up 265K, Dn 110K. 10:30 11:00 0.50 INTRM1 CEMENT SFTY P 12,986.0 12,986.0 PJSM with all crew members & Dowell on cementing 7" casing. Latest BOP Test Data Date Comment 2/8/2010 Tested Hydril to 250 & 2500 psi - all other components to 250 & 3500 psi - witness of test waived by Jeff Jones AOGCC Page 1/3 Report Printed: 1/19/2011 Security Level: AK Development Daily Drilling Report 10' CD3 -106 Report Number: 20 ConocoPhillips .ui Rig: DOYON 141 Report Date: 2/8/2010 Time Log Start End •>` Our Time Depth Start .Depth End Time Time (hrs) Phase Op Code Activity Code P-T-X Trbl' +Code Trbt Class. (ftKB) EZ== _ (MB) p Operation 11:00 15:30 4.50 INTRM1 CEMENT PUCM P 12,986.0 12,986.0 Turn over to Dowell, Pump First Stage w/ 5.0 bbls CW100 at rate of 5.0 bpm @ 370 psi, Test lines to 3600 psi - OK, Continue pumping to total of 39.3 bbls CW100 at rate of 5.0 bpm @ 450 psi, Mix & pump 30.5 bbls 12.0 ppg Mud PUSH mixed to 12.0 ppg at rate of 5.5 bpm @ 500 psi, Shut down, Drop bottom plug & Reload head with 2nd plug, Batch mix cement to 15.8 ppg, Pump total of 62.8 bbls (304 sacks) Class "G" cement w/ 0.2% D46, 0.3% D65, 0.11% B155, 0.4% D167 - 1.16 ft3 /sk Yield at rate of 5.0 bpm @ 500 psi, Drop top plug, Pump 20 bbls fresh water followed by 479.6 bbls 10.6 ppg mud at rate of 7 bpm @ 650 psi, Bump plug w/ 1200 psi, Check floats- OK, First Stage C.I.P © 13:30 hrs 2/8/10, Calculated TOC @ 11,900', Worked casing 10' to 15' while cementing until last 4 bbls prior to bumping plug. Pressure up to 3200 psi to open Stage Collar @ 6800', Load 3rd plug. Circ bottom's up at rate of 7.5 bpm @ 350 psi. Pump 29.1 bbls CW100 at rate of 4.5 bpm @ 250 psi followed by 35.9 bbls MudPUSH mixed at 12.0 ppg at rate of 4.5 bpm @ 250 psi, Batch mix cement & pump total of 56.1 bbls (271 sacks) Class "G" cement w/ 0.2% D46, 0.3% D65, 0.8% S2 - 1.16 ft3 /sk Yield at rate of 5.0 bpm @ 300 psi, Drop closing plug, Pump 20 bbls fresh water followed by 243.6 bbls 10.6 ppg mud at rate of 7 bpm @ 400 psi, Bump plug w/ 900 psi, C.I.P @ 15:30 hrs 2/8/10, Calculated TOC @ 4,705'. 15:30 16:30 1.00 INTRM1 CEMENT PULD P 12,986.0 12,986.0 Rig down Cement head, Clear Frank's fill up tool & Cement head from floor, Lay down janding jt. 16:30 18:00 1.50 INTRM1 WHDBOP OTHR P 12,986.0 12,986.0 Rig & Pull wear bushing, Install 7" x 9 -5/8" Pack off & test same- OK 18:00 21:30 3.50 INTRM1 WHDBOP BOPE P 12,986.0 12,986.0 PJSM, Change top rams to 3 -1/2" x 6" VBR's, Change btm rams to 4 ", Rig lines to 7" x 9 -5/8" annulas, Perform LOT of 15.1 EMW, Flush annulas to a total of 85bbls (110 %) 21:30 23:00 1.50 INTRM1 WHDBOP BOPE P 12,986.0 12,986.0 Clear rig floor of Casing slips, Elevators, Tongs, Bails & 5" subs, Pick up 4" subs & floor valves, Short bails & install same. Rig Little Red & freeze protect 7" x 9 -5/8" annulas w/ 60 bbls diesel to 2125' MD / 2060' TVD. Page 2/3 Report Printed: 1/19/2011 116 °ui,? 1 • Security Level: AK Development I ., ,' "i � "" Daily Drilling Report ,,,hilt !; a,N1 i V k CD3 -106 4` " i lq�146i' �i 11 p l�� .. ConocoPhillips llli Report Number: Rig: DOYON 141 Report Date: 2/8/2010 - Time Log = Start - - =End = Dur Time - Depth Start . „Depth:End . Time Time (hrs) Phase Op Code. Activity Code ; P - T - X Trbl Code '- Trbl Class. (ftKB) " (ftKB) Operation, 23:00 00:00 1.00 INTRM1 WHDBOP BOPE P 12,986.0 0.0 Install test plug, Rig to test BOPE, Fill stack with water & get air out of system. Mud Check'Data = YP Catc Gel (1Os) Gel (10m): = Gel: (30m) - HTHP Fitt Density Temp Solids _Corr. Type- Depth (ftKB) Dens (Ib /gal) Vis (s /qt) PV Calc (cp) - = - (Ibf /1DOft°) (Ibf /100ft) -- (Ibf /100ft') - -- (Ibfll,OdfP) ` MBT (1b/bbl) - (mtnamin), pl{=_> ( °F) m) Inhibicol 13,809.0 10.60 44 10.0 14.0 4.0 6.0 7.000 140.2 6.0 9.3 75.0 14.0 Spike . Inhibicol 12,997.0 10.60 40 14.0 16.0 6.0 8.0 9.000 140.2 5.9 9.3 80.0 14.0 Spike Inhibicol 12,997.0 10.65 46 13.0 12.0 4.0 6.0 7.000 122.7 6.3 9.5 85.0 15.0 Spike Injection Fluid - Fluid , --= Source From, Lease (bbl) Destination Vendor Manifest Number Note ? Cement Rinsate CD3 -106 100.0 CD1 -19 ASRC 308296 Cuttings CD3 -106 2.0 CD3 -304 ASRC 308292 Cuttings CD3 -106 2.0 CD3 -304 ASRC 308393 Cuttings CD3 -106 2.0 CD3 -304 ASRC 308394 Drilling Mud WBM CD3 -106 275.0 CD3 -304 ASRC 308395 Drilling Mud WBM CD3 -106 180.0 CD3 -304 ASRC 308291 Pit Rinsate CD3 -106 275.0 CD3 -304 ASRC 308299 Pit Rinsate CD3 -106 275.0 CD3 -304 ASRC 308298 Truck Rinsate CD3 -106 100.0 CD1 -19 ASRC 308297 Welibores , -_ Wellbore Name Wellbore API /UWI CD3 -106 501032061100 Section Size (in) Act Top (FMB) Act Btrn (ftlKB} Start Date End Date COND 18 0.0 108.0 1/19/2010 SURFAC 12 1/4 108.0 2,735.0 1/20/2010 1/21/2010 INTRM1 8 3/4 2,735.0 12,997.0 1/26/2010 2/6/2010 PROD1 6 1/8 12,997.0 17,664.0 2/12/2010 2/18/2010 Cement Intermediate Casing Cement - Started A 2/8 /2010 Type Wellbore Cemented String Cement Evaluation Results casing CD3-1 06 Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl /... P (final) (psi) 1 Intermediate Casing Cement 11,900.0 12,986.0 Fluid „,r Class Amount (sacks) , . - V (bbl) - Density (Ibigal) -__° Yield (ft' /sack) 4.ggskTop - (ftKB)= -- : Est Btrn, Intermediate Cement G 11,900.0 12,986.0 Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl /... P (final) (psi) 2 Intermediate Casing Cement 5,571.0 6,800.0 ,- -,,-,- _ =Fluid _ - Class Amount (sacks) i; V (bbl) Density(Iblgat) Yield (f Msack) Est Top (ftKB) Est Bttn (ftKB)> - Intermediate Cement G 5,571.0 6,800.0 Page 3/3 Report Printed: 1/19/2011 i • CD3 -121 • I! CD3 -121 Surface Casing Well: CD3 - 121 r ,,, 9-5/8" 40 € L=8 BT sr Casing Date: 3/1312010 Cono4 fillips Rig: Doyon 19 Alaska, Inc. Depth Jt Number Joints Well Equipment Description and Comments Length Tops Page 1 Doyon 19 RKB to top of landing Ring 36.00 FMC Gen V 9-518" Fluted Hanger (15 -1/4" OD) .22 36.00 9 -5/8" 40 ppf L -80 BTC -m casing pup P x P 2.42 36.22 Jts 3 to 71 69 Jts 9 - 5/8" 40 ppf L - BTC - casing 2601.14 38.64 Halliburton 9 -5/8" "Sure Seal ll" Float collar (10.70" OD) 1.21 2639.78 Jts 2 to 2 1 Jts 9 -5/8" 40 ppf L -80 BTC -m casing- Thread lock joint 37.44 2640.99 Jts 1 to 1 1 Jts 9 - 5/8" 36 ppf K - BTC casing 42.24 2678.43 Rays Oil Tools 9 -5/8" "Silver Bullet" Float Shoe (10.70" OD) 2.58 2720.67 Bottom of shoe »> 2723.25 2723.25 12 -1/4" TD @ 2733' MD / 2465' TVD 2723.25 9-5/8" Casing Shoe cr? 2723.25' MD / 2457.24' TVD 2723.25 Rat hole 9.75'. 2723.25 2723.25 76 Joints in Pipe Shed - Run 71 / Last 5 jts. out 2723.25 2723.25 One bowspring on stop 10' above shoe and on collar of jt #1. 2723.25 One bowspring on stop 10' below collar of jt #2. 2723.25 One Bowspring Centralizer per Joint 3 -13, then Every Other Joint 15 -69 2723.25 Total 42 Bowsprings - Two Stop Collars 2723.25 2723.25 2723.25 2723.25 2723.25 2723.25 2723.25 2723.25 2723.25 2723.25 2723.25 2723.25 2723.25 2723.25 2723.25 2723.25 Remarks: Drifted w/ teflon drift 8.76 ". Up Wt 165 K Used Run -N -Seal dope. Dn Wt 125 K Average MU torque= 8000 Ft lbs. Block Wt 80 K Supervisors: Dave Burley/ Granville Rizek • • Cement Detail Report ti Ii,� CD3 -121 CanocoPhillips String: Surface Casing Cement Job: DRILLING ORIGINAL, 3/9/2010 21:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 3/13/2010 00:30 3/13/2010 02:48 CD3 -121 Comment Rig up Dowell cement head, connect lines. Circulate and condition mud and hole for cement job. Reciprocate pipe f/ 2723' to 2688' (35'). Initial pump rate 5 bpm w/ 320 psi, after 35 bbls 6 bpm w/ 380 psi 28 %, after 90 bbls 7 bpm w/ 420 psi 32 -34% Totco flow out. Total of 857 bbls pumped at midnight. PV/YP in 23/18, 63 funnel vis. Held PJSM f/ cementing while circulating. Con't to circ & cond mud and hole for cement job. Recip pipe f/ 2723' to 2688' (35'). Pumping 7 bpm w/ 300 psi. Circ a total of 962 bbls (PV/YP 23/18, vis 63 in, PV/YP 25/19 out. Rig mixed & pump 50 bbls of 9.7 ppg mud w/ nut plug marker (5ppb), followed w/ 36.5 bbls of viscosified water w/ nut plug (5ppb). Pump @ 7 bpm w/ 280 to 220 psi. PU wt 170k, SO wt 150k. Dowell press test to 3500 psi. Drop bottom plug. Dowell pump 49.6 bbls of MudPush II (10.5 ppg). Pump 5.8 bpm w/ final press of 210 psi. Dowell mixed and pumped a total of 308.3 bbls (384 sx) of 10.7 ppg ArcticSet Lite 3 cement (Yield 4.51 cuft/sx) (21.23 gal /sx mix water). Avg pump rate of 7.5 bpm w/ initial press of 210 and final of 273 psi. Dowell mixed & pumped 53.2 bbls (257 sx) of 15.8 ppg LiteCrete tail cement ( Yield 1.16 cuft/sx) (21.23 gal /sx mix water). Avg pumping rate of 4.8 bpm w/ final of 136 psi. Drop top plug. Dowell displace and wash up through the tub, pumping 20.1 bbls of water @ 6 bpm w/ 100 psi. Reciprocate pipe f/ 2723' to 2688' (35'). Rig displaced cement w/ 9.7 ppg mud. Pumping the first 170 bbls @ 7.5 bpm w/ 250 psi initial and 600 psi final, then slowed rate for the last 10 bbls to 4 bpm w/ 480 psi. Bumped plugs w/ 500 psi over - -1000 psi © 0248 hrs 3/13/2010, held f/ 5 minutes. Note: Reciprocated pipe f/ 2723' to 2703' (20') while displacing cement, set on hanger 30 bbls prior to bumping plug. Had 35 bbls of good 10.7 ppg cement to surface. SO wt 125k. Note: Cement in place @ 0248 hrs 3 -13 -2010. Bled off pressure to check floats , floats held. PJSM,rig down cement and casing equip. Cement Stages Stage # 1 Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtm (... Top Plug? Btm Plug? Surface Casing Cement Cement surface casing 36.0 2,723.3 Yes Yes Yes Q (start) (bbl /min) Q (end) (bbl /min) Q (avg) (bbl /min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 7 4 7 480.0 1,000.0 Yes 20.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Rig up Dowell cement head, connect lines. Circulate and condition mud and hole for cement job. Reciprocate pipe f/ 2723' to 2688' (35'). Initial pump rate 5 bpm w/ 320 psi, after 35 bbls 6 bpm w/ 380 psi 28 %, after 90 bbls 7 bpm w/ 420 psi 32 -34% Totco flow out. Total of 857 bbls pumped at midnight. PV/YP in 23/18, 63 funnel vis. Held PJSM f/ cementing while circulating. Con't to circ & cond mud and hole for cement job. Recip pipe f/ 2723' to 2688' (35'). Pumping 7 bpm w/ 300 psi. Circ a total of 962 bbls (PV/YP 23/18, vis 63 in, PV/YP 25/19 out. Rig mixed & pump 50 bbls of 9.7 ppg mud w/ nut plug marker (5ppb), followed w/ 36.5 bbls of viscosified water w/ nut plug (5ppb). Pump © 7 bpm w/ 280 to 220 psi. PU wt 170k, SO wt 150k. Dowell press test to 3500 psi. Drop bottom plug. Dowell pump 49.6 bbls of MudPush II (10.5 ppg). Pump 5.8 bpm w/ final press of 210 psi. Dowell mixed and pumped a total of 308.3 bbls (384 sx) of 10.7 ppg ArcticSet Lite 3 cement (Yield 4.51 cuft/sx) (21.23 gal /sx mix water). Avg pump rate of 7.5 bpm w/ initial press of 210 and final of 273 psi. Dowell mixed & pumped 53.2 bbls (257 sx) of 15.8 ppg LiteCrete tail cement ( Yield 1.16 cufUsx) (21.23 gal /sx mix water). Avg pumping rate of 4.8 bpm w/ final of 136 psi. Drop top plug. Dowell displace and wash up through the tub, pumping 20.1 bbls of water @ 6 bpm w/ 100 psi. Reciprocate pipe f/ 2723' to 2688' (35'). Rig displaced cement w/ 9.7 ppg mud. Pumping the first 170 bbls @ 7.5 bpm w/ 250 psi initial and 600 psi final, then slowed rate for the last 10 bbls to 4 bpm w/ 480 psi. Bumped plugs w/ 500 psi over - -1000 psi @ 0248 hrs 3/13/2010, held f/ 5 minutes. Note: Reciprocated pipe f/ 2723' to 2703' (20') while displacing cement, set on hanger 30 bbls prior to bumping plug. Had 35 bbls of good 10.7 ppg cement to surface. SO wt 125k. Note: Cement in place @ 0248 hrs 3 -13 -2010. Bled off pressure to check floats , floats held. PJSM,rig down cement and casing equip. Cement Fluids i & Additives` Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Mud w/ nut plug 50.0 Yield (fN/sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 9.70 Additives Additive Type Concentration Conc Unit label :Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Viscosified Water w/ 36.5 nut plug Yield (ft' /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 8.50 Page 1/2 Report Printed: 1/19/2011 ��llllllril�t • • i �� "'',II Cement Detail Report I� I I K..� i __ � � I4lPllaglt CD3 -121 ConocoPhillips String: Surface Casing Cement Job: DRILLING ORIGINAL, 3/9/2010 21:00 Additives Additive Type Concentration Conc Unit label Cement Fluids & Additives - - Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) MudPush II 49.6 Yield (t/sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 10.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Arctic Set Lite 3 36.0 2,223.0 384 G 308.3 Yield (ft/sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 4.51 21.23 10.70 Additives Additive Type Concentration Conc Unit label S001 Accelerator 1.5 %BWOC Additive Type Concentration Conc Unit label D046 AntiFoam 0.6 %BWOC Additive Type Concentration Conc Unit label D079 Extender 1.5 %BWOC Additive Type Concentration Conc Unit label D124 Extender 50.0 %BWOC Additive Type Concentration Conc Unit label D044 Freeze Suppressant 9.0 %BWOC Additive Type Concentration Conc Unit label D053 Thixotropic 30.0 %BWOC Fluid _ = - Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Alpine Surface Tail 2,223.0 2,723.0 257 G 53.1 Yield (t/sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (Ib /gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 5.11 15.80 Additives Additive Type Concentration Conc Unit label S001 Accelerator 1.0 %BWOC Additive Type Concentration Conc Unit label D046 Antifoam 0.2 %BWOC Additive Type Concentration Conc Unit label D065 Dispersant 0.3 %BWOC Page 2/2 Report Printed: 1/19/2011 • Security Level: AK Development Daily Drilling Report CD3 -121 ieu Report Number: 4 ConocoPhiiitps Rig: DOYON 19 Report Date: 3/12/2010 - - - AFE Typa, "'' Network/10 # ` _ TotarAFE +Sup 10277784 9,625,000.00 Welibore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3 - 121 Development FIORD NECHELIK 367.42 4.0 0.00 2,733.0 2,733.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 6,463.95 36,432.43 208,295.95 983,486.43 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 3/9/2010 3/10/2010 27.00 24.58 2.42 4/3/2010 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) CONDUCTOR 24" Insulated, 114.0ftKB Ops and Depth @ Morning Report 24hr Forecast Nipple down Riser and FMC Quick connect. Cement 9 -5/8 ", Rig down, Nipple down, Nipple up BOP stack, test BOPE, PU 5" DP. Last 24hr Summary Circ BU at TD (2733'), backream to 812', trip in the hole to 2733', tag bottom- no fill, circ and condition hole for 9 -5/8" casing. POOH on the trip tank from 2733' to 905'. Observe well for flow @ HWDP (905')- static. Con't to pull out of the hole on the trip tank. PJSM on laying down BHA #1. Lay down BHA #1. Clean & clear rig floor. RU to run 9 -5/8" 40 ppf L -80 BTC -m surface casing. PJSM. Run 9 -5/8" 40 ppf L -80 BTC -m surface casing. Make up Ray Oil Tool Silver bullet w/ 36 ppf K -55 BTC jt (one centralizer 10' above shoe on stop and on collar of jt #1). All other joints are 40 ppf L -80 BTC -m casing. Make up jt #2 (Thread lock joint) (stop 10' below box w/ bow spring centralizer), make up Jt #3 w/ Halliburton Sure Seal II Float collar on bottom. Make up jt #4 (baker locked pin). Stab Frank's fillup tool and circulate w/ shoe above conductor shoe. Continue to run casing using Run -N- Seal dope. Centralizers are on box of first 13 joints then every other jt. Run in jt # 31 to 1170', lost 10k to 105k SO wt. Pick up to 1145', stab Frank's fillup tool. Estab circulation pumping 4 bpm w/ 200 psi- 28% Totco flow out. Increase pump rate to 5 bpm w/ 270 psi, wash in the hole from 1145' to jt # 40 in the hole -- 1515'. Worked through numerous areas from 117.0' to 1515' which we saw a reduction in slack off wt, so washed casing string in the hole. Con't to run casing w/o pumping from 1515' to 1670' (jt # 41 thru jt # 44). Circulate 1.5 BU (150 bbls) while recip from 1670' to 1705' (Jt # 45 in the hole). Con't to run 9 -5/8" 40 ppf L -80 BTC -m surface casing f/ 1705' to 2680' (jt #71). ' Make up FMC hanger and landing joint. Run in hole and land on hanger w/ shoe @ 2723.25'. PU wt 175k, SO wt 140k. Rig down Frank's fill up tool. Blow down the top drive. RU Dowell cement head & lines. Circ and condition mud and hole for cement job. Reciprocate pipe f/ 2723' to 2688' (35'). Initial pump rate 5 bpm w/ 320 psi, 6 bpm w/ 380 psi, final 7 bpm w/ 420 psi. Circ a total of 857 bbls @ midnight. General Remarks Weather Head Count No Spills / No Accidents. on Hi -line w/ one engine running. -26 °, WC -48 °, Wind SW @ 10 Mph, 10 mile 50.0 vis Supervisor Titie -- Dave Burley, Rig Supervisor Rig Supervisor Granville Rizek, Rig Supervisor Rig Supervisor Patrick Reilly, Drilling Engineer Drilling Engineer Jeremy Sadleir, DSD Engineer DSD Engineer Time Log Start End _ Dur -: _ Tine Depth Start Depth End Time Time_ (hrs) Phase Op Cede Ac ivvity Code °' . P-T X Trbl Code Trbi Class: = (td(B) (ftKB) Operation 00:00 00:15 0.25 SURFAC DRILL CIRC P 2,733.0 2,733.0 Circulate bottom's up, pumping 600 gpm w/ 1600 si. Reciprocate from 2733' to P P 2708'. Rotate 80 rpm w/ 8k ft/lbs of torque. PU wt 150k, SO wt 140k, Rot wt 148k. 00:15 05:15 5.00 SURFAC DRILL REAM P 2,733.0 812.0 Backream out of the hole from 2733' to 1560', pumping 600 gpm w/ 1 580 to 1800 psi, rotate 80 rpm w/ 6.5k ft lbs of torque. Continue to backream out of the hole from the base of the permafrost © 1560' to 812', pumping 500 gpm w/ 1200 to1100 psi, rotate 80 rpm w/ 6.5 to 3.5k ft lbs of torque. 05:15 06:15 1.00 SURFAC DRILL TRIP P 812.0 2,710.0 Trip in the hole f/ 812' to 2710'. Slack off weight 120k. Tight spots on trip in the hole @ 852', 1194', 1247', 1297' and 2277'. 06:15 06:30 0.25 SURFAC DRILL TRIP P 2,710.0 2,733.0 Break circulation, tag bottom at 2733' w/ no fill. Latest BOP Test Data Date Comment Page 1/3 Report Printed: 1/19/2011 • • Security Level: AK Development 0 4 h * Daily Drilling Report u 1 4 1i �1111llu� E �i9 CD3 -121 �onacsPhitlips Report Number: 4 Rig: DOYON 19 Report Date: 3/12/2010 Time Log 9 = Start End Dur _' Time Depth Start Depth End . Time Time _ _ (hrs) Phase Op Code Activity Code P -T -X Trbi Code - - - Tcbl Class. -_ -__ (I) (ftKB)=� - Operation 06:30 07:30 1.00 SURFAC DRILL CIRC P 2,733.0 2,733.0 Circulate and condition mud and hole f/ 9 -5/8" surface casing. Initial 500 gpm w/ 1150 psi, final 6650 gpm w/ 1850 psi. Rotate 60 rpm w/ 6k ft Ibs of torque. 07:30 07:45 0.25 SURFAC DRILL OWFF P 2,733.0 2,733.0 Observe well for flow- static. 07:45 09:15 1.50 SURFAC DRILL TRIP P 2,733.0 905.0 Pull out of the hole on the trip tank from 2733' to 905'. At 905' : PU wt 115k, SO wt 110k. 09:15 09:30 0.25 SURFAC DRILL OWFF P 905.0 905.0 Observe well for flow @ HWDP (905') - static. 09:30 10:15 0.75 SURFAC DRILL TRIP P 905.0 168.0 Continue to pull out of the hole on the trip tank. 10:15 10:30 0.25 SURFAC DRILL SFTY P 168.0 168.0 Pre job safety meeting on laying down BHA #1. 10:30 11:45 1.25 SURFAC DRILL PULD P 168.0 0.0 Lay down BHA #1. 11:45 12:30 0.75 SURFAC DRILL OTHR P 0.0 0.0 Clean and clear rig floor. 12:30 12:45 0.25 SURFAC CASING SFTY P 0.0 Pre job safety meeting on rig up to run casing. 12:45 14:00 1.25 SURFAC CASING RUNL P 0.0 0.0 Rig up to run 9 -5/8" 40 ppf L -80 BTC -m surface casing. 14:00 14:15 0.25 SURFAC CASING SFTY P 0.0 0.0 Pre job safety meeting on run casing. 14:15 17:00 2.75 SURFAC CASING RNCS P 0.0 1,170.0 Run 9 -5/8" 40 ppf L -80 BTC -m surface casing. Make up Ray Oil Tool Silver bullet w/ 36 ppf K -55 BTC jt (one centralizer 10' above shoe on stop and on collar of jt #1). All other joints are 40 ppf L -80 BTC -m casing. Make up jt #2 (Thread lock joint) (stop 10' below box w/ bow spring centralizer), make up Jt #3 w/ Halliburton Sure Seal II Float collar on bottom. Make up jt #4 (baker locked pin). Stab Frank's fillup tool and circulate w/ shoe above conductor shoe. Continue to run casing using Run -N- Seal dope. Centralizers are on box of first 13 joints then every other jt. Run in jt # 31 to 1170', lost 10k to 105k SO wt. 17:00 19:00 2.00 SURFAC CASING RNCS P 1,170.0 1,515.0 Pick up to 1145', stab Frank's fillup tool. Establish circulation pumping 4 bpm w/ 200 psi- 28% Totco flow out. Increase pump rate to 5 bpm w/ 270 psi, wash in the hole from 1145' to jt # 40 in the hole -- 1515'. Worked through numerous areas from 1170' to 1515' which we saw a reduction in slack off wt, so washed casing string in the hole. 19:00 19:15 0.25 SURFAC CASING RNCS P 1,515.0 1,710.0 Continue to run casing without pumping in the hole from 1515' to 1670' (jt # 41 thru jt # 44). 19:15 19:45 0.50 SURFAC CASING CIRC P 1,670.0 1,705.0 Circulate 1.5 BU (150 bbls) while recip from 1670' to 1705'. Wash Jt # 45 in the hole. 19:45 21:15 1.50 SURFAC CASING RNCS P 1,705.0 2,680.0 Continue to run 9 -5/8" 40 ppf L -80 BTC -m surface casing f/ 1705' to 2680' Page 2/3 Report Printed: 1/19/2011 p, p,,,,i,',, • • Security Level: AK Development "''''' Daily Drilling Report .l CD3 -121 wconcacvPtt illi Report Number: 4 Rig: DOYON 19 Report Date: 3/12/2010 Time Log Start End Dur = . Time ` _- Depth Start Depth End - Time Time = i(firsr " Phase Op Code ` Activity-Code P -T -X Trbl Code Trbl Class -= _ (ftKB)_i__- (11KB) Operation 21:15 21:30 0.25 SURFAC CASING RNCS P 2,680.0 2,723.0 Make up FMC hanger and landing joint. Run in hole and land on hanger w/ shoe @ 2723.26. 21:30 21:45 0.25 SURFAC CASING RURD P 2,723.0 2,723.0 Rig down Frank's fill up tool. Blow down the top drive. 21:45 22:00 0.25 SURFAC CEMENT RURD P 2,723.0 2,723.0 Rig up Dowell cement head, connect lines. 22:00 00:00 2.00 SURFAC CEMENT CIRC P 2,723.0 2,723.0 Circulate and condition mud and hole for cement job. Reciprocate pipe f/ 2723' to 2688' (35'). Initial pump rate 5 bpm w/ 320 psi, after 35 bbls 6 bpm w/ 380 psi 28 %, after 90 bbls 7 bpm w/ 420 psi 32 -34% Totco flow out. Total of 857 bbls pumped at midnight. PV/YP in 23/18, 63 funnel vis. Held PJSM f/ cementing while circulating. Mud _Check =Data YP Cale Gel (10s) -_ Gel 10m Gel _(301n) HTHP Fist l Density Temp _Solids, Corr. Type Depth (ftKB) Dens (lb/gat)- Vis (slgt), PV Calc (cp) (I14/100rt (tbf /1=00f) r- (lbf/100ft 2 ), (1b000fe)', . MBT (Ibibbl) (m min) p 1 (`F) ' ( %) Spud Mud 2,733.0 9.80 300 18.0 82.0 65.0 70.0 75.000 30.0 8.5 8.0 Spud Mud 2,733.0 9.80 300 15.0 91.0 67.0 71.0 74.000 30.0 8.5 8.0 injection Fluid Source From Lease (bbi) -- Destination- Vendor Manifest Number -- Note Cuttings 261.0 CD3 -114 Diesel 35.0 CD3 -114 Water 150.0 CD3 -114 Welibores Wellbore Name Wellbore API /UWI CD3 -121 501032061500 Section Size (irrl =_ Act Top (ftKB) _ Act Btm (ftKB) Start Date End Date COND1 18 36.0 114.0 4/10/2009 4/10/2009 SURFAC 12 1/4 114.0 2,733.0 3/10/2010 3/12/2010 INTRM1 8 3/4 2,733.0 8,888.0 3/14/2010 3/19/2010 PROD1 6 3/4 8,888.0 15,081.0 3/24/2010 3/28/2010 Page 3/3 Report Printed : 1/19/2011 9 0 11 • • Security Level: AK Development Daily Drilling Report ,iu ,, CD3 -121 Cnc�coPhitli� l,�,iaf Report Number: 5 Rig: DOYON 19 Report Date: 3/13/2010 ` AFE Type " Netwock/ID # - . _ Total AFE +Sup. ". 10277784 9,625,000.00 Welibore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3 - 121 Development FIORD NECHELIK 368.42 5.0 0.00 2,733.0 2,733.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 4,454.53 40,886.96 218,870.53 1,202,356.96 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 3/9/2010 3/10/2010 27.00 25.58 1.42 4/4/2010 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) SURFACE, 2,723.3ftKB Ops and Depth @ Morning Report 24hr Forecast Testing 9 -5/8" casing MU BHA #2, Run 57 jts of 5" f/ shed, test casing to 3500 psi, drill cement & 20' new hole, LOT, drill 8 -3/4" hole. Last 24hr Summary Con't to circ & cond mud & hole for cement job. Recip pipe f/ 2723' to 2688' (35'). Pump 7 bpm w/ 300 psi. Circ a total of 962 bbls ( PV/YP 23/18, vis 63 in, PV/YP 25/19 out. Rig mixed & pump 50 bbls of 9.7 ppg mud w/ nut plug marker (5ppb), follow w/ 36.5 bbls of vis water w/ nut plug (5ppb). Pump @ 7 bpm w/ 280 to 220 psi. PU wt 170k, SO wt 150k. Dowell press test to 3500 psi. Drop bottom plug. Dowell pump 49.6 bbls of MudPush II (10.5 ppg). Pump 5.8 bpm w/ final press of 210 psi. Dowell mixed and pumped a total of 308.3 bbls (384 sx) of 10.7 ppg ArcticSet Lite 3 cement (Yield 4.51 cuft/sx) (21.23 gal /sx mix water). Avg pump rate of 7.5 bpm w/ initial press of 210 and final of 273 psi. Dowell mixed & pumped 53.2 bbls (257 sx) of 15.8 ppg LiteCrete tail cement ( Yield 1.16 cuft/sx) (21.23 gal /sx mix water). Avg pumping rate of 4.8 bpm w/ final of 136 psi. Drop top plug. Dowell displace & wash up through the tub, pumping 20.1 bbls of water © 6 bpm w/ 100 psi. Recip pipe f/ 2723' to 2688' (35'). Rig displaced cement w/ 9.7 ppg mud. Pumping the first 170 bbls @ 7.5 bpm w/ 250 psi initial and 600 psi final, then slowed rate for the last 10 bbls to 4 bpm w/ 480 psi. Bumped plugs w/ 500 psi over - -1000 psi @ 0248 hrs 3/13/2010, held f/ 5 minutes. Note: Recip pipe f/ 2723' to 2703' (20') while displacing cement, set on hanger 30 bbls prior to bumping plug. Had 35 bbls of good 10.7 ppg cement to surface. Note: Cement in place © 0248 hrs 3 -13 -2010. Bled off press - floats held. PJSM, R/D cement equip. Monitor ann, dropping slightly. 2 bbls of cement allowed to replace itself in the cond. Flush stack. L/D FMC landing joint. PJSM, N/D riser & FMC quick connect. Install FMC Gen II Wellhead. Orient. Measure RKB to lockdown screws. Test metal to metal seal to 1000 psi for 10 minutes. PJSM, Nipple up 13 -5/8" BOPE. RU -Test BOPE, witness of test waived by AOGCC inspector Lou Grimaldi. Set wear bushing, LJD 2 8" DC w/ jars, PU 48 stands 5" dp, slip and cut 60' drill line, PU BHA #2 General Remarks Weather Head Count No Spills / No Accidents. on Hi -line w/ one engine running. -38 °, WC -61°, Wind S @ 9 Mph, 10 mile vis 49.0 Supervisor :. - Tale -_, Dave Burley, Rig Supervisor Rig Supervisor Granville Rizek, Rig Supervisor Rig Supervisor Patrick Reilly, Drilling Engineer Drilling Engineer Jeremy Sadleir, DSD Engineer DSD Engineer Time L Start End -_ - Dur Time °_ - Depth Sit_ Depth End - Time Time (hrs) Phase Op Code =3igritiotivity Cede P T X MTrbt Code = Trbl Class.. (ftKB _ - (ftKB) Operation 00:00 00:30 0.50 SURFAC CEMENT CIRC P 2,723.0 2,723.0 Continue to circ and condition mud and hole for cement job. Reciprocate pipe f/ 2723' to 2688' (35'). Pumping 7 bpm w/ 300 psi. Circ a total of 962 bbls. Final mud properties: MW in 9.6+ ppg, PV/YP = 23/18, vis 63. MW out 9.7 ppg, PV/YP 25/19. 00:30 01:00 0.50 SURFAC CEMENT CMNT P 2,723.0 2,723.0 Rig mixed and pumped 50 bbls of 9.8 ppg mud w/ nut plug marker (5ppb), followed w/ 36.5 bbls of viscosified water w/ nut plug (5ppb). Reciprocate pipe f/ 2723' to 2688' (35'). Pumped @ 7 bpm w% 280 to 220 psi. PU wt 170k, SO wt 150k. 01:00 01:11 0.19 SURFAC CEMENT PRTS P 2,723.0 2,723.0 Dowell pressure test lines to 3500 psi. Rig changed pressure sensor. Dowell trouble shoot display screen in the dog house. Drop bottom plug after testing. 01:11 01:21 0.16 SURFAC CEMENT CMNT P 2,723.0 2,723.0 Dowell pumped 49.6 bbls of MudPush II (10.5 ppg). Pumping 5.8 bpm w/ final pressure of 210 psi. Reciprocate pipe f/ 2723' to 2688' (35'). Latest BOP Test Data Date -, Comment x 3/13/2010 Witness of test waived by AOGCC inspector Lou Grimaldi. Page 1/5 Report Printed: 1/19/2011 • • Security Level: AK Development Daily Drilling Report 110 P'14 i n!,,1,�;�{ CD3 -121 csnoc Il tllt Report Number: 5 Rig: DOYON 19 Report Date: 3/13/2010 Time Log Start End D4r Time " Depth Start, Depth,End Time Time , (hrs) = Phase " Op Code Activity Code P-T-X Trbl Code TrbI Class.!„ (ftX: MO) Operation 01:21 02:04 0.72 SURFAC CEMENT PUCM P 2,723.0 2,723.0 Dowell mixed and pumped a total of 308.3 bbls (384 sx) of 10.7 ppg ArcticSet Lite 3 cement (Yield 4.51 cuft/sx) (21.23 gal /sx mix water). Average pumping rate of 7.5 bpm w/ initial pressure of 210 and final of 273 psi. Reciprocate pipe f/ 2723' to 2688' (35'). 02:04 02:16 0.20 SURFAC CEMENT PUCM P 2,723.0 2,723.0 Dowell mixed and pumped 53.2 bbls (257 sx) of 15.8 ppg LiteCrete tail cement ( Yield 1.16 cuft/sx) (21.23 gal /sx mix water). Average pumping rate of 4.8 bpm w/ final of 136 psi. Reciprocate pipe f/ 2723' to 2688' (35'). 02:16 02:18 0.03 SURFAC CEMENT OTHR P 2,723.0 2,723.0 Drop top plug. 02:18 02:22 0.07 SURFAC CEMENT DISP P 2,723.0 2,723.0 Dowell displace and wash up through the tub, pumping 20.1 bbls of water @ 6 bpm w/ 100 psi. Reciprocate pipe f/ 2723' to 2688' (35'). 02:22 02:55 0.55 SURFAC CEMENT DISP P 2,723.0 2,723.0 Rig displaced cement w/ 9.7 ppg mud. Pumping the first 170 bbls @ 7.5 bpm w/ 250 psi initial and 600 psi final, then slowed rate for the last 10 bbls to 4 bpm w/ 480 psi. Bumped plugs w/ 500 psi over - -1000 psi @ 0248 hrs 3/13/2010, held f/ 5 minutes. Note: Reciprocated pipe f/ 2723' to 2703' (20') while displacing cement, set on hanger 30 bbls prior to bumping plug. Had 35 bbls of good 10.7 ppg cement to surface. Note: Cement in place @ 0248 hrs 3 -13 -2010. 02:55 03:00 0.08 SURFAC CEMENT OTHR P 2,723.0 2,723.0 Bled off pressure to check floats , floats held. 03:00 03:15 0.25 SURFAC CEMENT SFTY P 2,723.0 2,723.0 Pre job safety meeting on rigging down cementing and casing equipment. 03:15 03:45 0.50 SURFAC CEMENT RURD P 2,723.0 2,723.0 Rig down Dowell cement head. Blow down cementing line. 03:45 04:30 0.75 SURFAC DRILL OWFF P 2,723.0 2,723.0 Monitor annulus while rigging down equipment and lay down mouse hole. Annulus dropping slightly. Final drop of 15' below the flow line - -2 bbls of cement allowed to replace itself in the conductor. 04:30 05:15 0.75 SURFAC DRILL RURD P 2,723.0 0.0 Flush stack w/ black water. Back out and lay down FMC landing joint. 05:15 05:30 0.25 SURFAC WHDBOP SFTY P Pre job safety meeting on nippling down riser and FMC quick connect. 05:30 06:15 0.75 SURFAC WHDBOP NUND P Nipple down surface riser. Disconnect turnbuckles and flow line. 06:15 06:30 0.25 SURFAC WHDBOP NUND P Remove FMC quick connect 06:30 06:56 0.44 SURFAC WHDBOP NUND P Install FMC Gen II Wellhead. Orient to flow lines. Measure RKB to lockdown screws. Page 2/5 Report Printed: 1/19/2011 • • Security Level: AK Development f ��III�P; i41''I,I Daily Drilling Report i�lf' 911 'u l l' I , ;hi dlgl CD3 -121 lil Report Number: 5 ICoriocoPhiilps Rig: DOYON 19 Report Date: 3/13/2010 Time Log - Start End Dur Time- Depth Start Depth End Time Time (hrs)- Phase Op Code Activity Code ,,, P-T-X TrblCode` Trbl Class. MKS) !== (ftKS) _ Operation 06:56 07:00 0.06 SURFAC WHDBOP PRTS P Test metal to metal seal to 1000 psi for 10 minutes- good test. 07:00 07:15 0.25 SURFAC WHDBOP SFTY P Pre job safety meeting on nippling up BOPE. 07:15 08:30 1.25 SURFAC WHDBOP NUND P Nipple up 13-5/8" BOPE. 08:30 09:30 1.00 SURFAC WHDBOP RURD P Rig up to test BOPE. Pick up 5" test joint. Set FMC lower test plug. Fill lines with water. 09:30 09:45 0.25 SURFAC WHDBOP SFTY P Pre job safety meeting on testing BOPE. 09:45 14:30 4.75 SURFAC WHDBOP BOPE P Test BOPE. Witness of test waived by AOGCC inspector Lou Grimaldi. Electrician tested gas alarms. Tested pad evacuation alarm at noon, as today is Saturday. Performed Koomey recovery test. All tests were charted. All tests were held 5 minutes. All tests with 5" test joint. Tested annular to 250 psi low and 2500 psi high. Test upper and lower pipe rams, blinds, kill and choke line valves, choke manifold, mud valve in mezzanine, top drive IBOP valves and floor safety valves to 250 psi low and 3500 psi high. 14:30 15:00 0.50 SURFAC WHDBOP OTHR P Blow down choke line, kill line, and choke manifold. Pull test 5" test joint w/ FMC lower test plug. 15:00 15:15 0.25 SURFAC WHDBOP OTHR P Set FMC long (4.33') wear bushing (10 -3/4" OD x 10" ID). 15:15 15:30 0.25 SURFAC DRILL RURD P Pick up drilling bales and 5" elevators. 15:30 16:00 0.50 SURFAC DRILL PULD P Lay down 8" NMDC w/ jars from the derrick. 16:00 16:15 0.25 SURFAC DRILL SFTY P Pre job safety meeting on picking up/ standing back 5" drill pipe in the derrick via the mouse hole. 16:15 22:00 5.75 SURFAC DRILL PULD P Pick up/ standi back 48 stands of 5" drill pipe in the derrick via the mouse hole. 22:00 22:15 0.25 SURFAC RIGMNT SFTY P Pre job safety meeting on slip and cut drilling line. 22:15 23:15 1.00 SURFAC RIGMNT SVRG P Slip and cut 60' of 1 -3/8" drilling line. 23:15 23:30 0.25 SURFAC DRILL SFTY P Pre job safety meeting on picking up BHA #2. 23:30 00:00 0.50 SURFAC DRILL PULD P 0.0 43.0 Pick up/ Make up BHA #2. Hughes 8 -3/4" PDC 605z bit, SperryDrill 7" motor 7/8 6 stage motor, nm float sub, internal blade stabilizer, 6 -3/4" NM DM to 43'. Mud Check Data YP Cate _ Ge1(10s) r , ,Gel (10m) Gei (30m) - HTHP Filt = Density Temp _ _Sodds, Corr. Type Depth (ftKB) Dens (lb/gat)` Vis (stet) PVCalc (op) rfibfflOOff) (lbt_I1 Dory) (Ibf /100ft') !, (Ibf_flOOft"k MST abnao (mU3Omin) =Trim (F) (%) Spud Mud 2,733.0 9.65 59 16.0 18.0 8.0 14.0 19.000 28.0 9.1 7.0 injection Fiuid , Fluid __ Source From Lease (bbl) Destination Vendor ;- Manifest Number Note Diesel 20.0 CD3 -114 Drilling Mud WBM CD3 -121 1317.0 CD3 -114 Drilling Mud WBM CD3 -121 342.0 CD3 -114 Contaminated Mud w/ cement Water 190.0 CD3 -114 Page 3/5 Report Printed: 1/19/2011 • • Security Level: AK Development Daily Drilling Report ryll o,I�'�� F CD3 -121 Report Number: 5 ConocoPhittips Rig: DOYON 19 Report Date: 3/13/2010 Injection'Flwd Fluid-_ Source F rom Lease (bbl) Destination Vendor Manifest Number Note_ Water Based Mud CD3 -121 600.0 CD3 -114 Wetlbores Wellbore Name Wellbore API/DWI CD3 -121 501032061500 Section . " (in) Act f€tKB) Act Btm „(ftKS) S tart Date ,End Date COND1 18 36.0 114.0 4/10/2009 4/10/2009 SURFAC 12 1/4 114.0 2,733.0 3/10/2010 3/12/2010 INTRM1 8 3/4 2,733.0 8,888.0 3/14/2010 3/19/2010 PROD1 6 3/4 8,888.0 15,081.0 3/24/2010 3/28/2010 Casing Strings String OD String;Wt Casing Description Run Date (In) (Ibstft) String Grade ” Set Depth (ftKB) Comment SURFACE 3/13/2010 9 5/8 40.00 L -80 2,723.3 Run 9 -5/8" 40 ppf L -80 BTC -m surface casing. Make up Ray Oil Tool Silver bullet w/ 36 ppf K -55 BTC jt (one centralizer 10' above shoe on stop and on collar of jt #1). All other joints are 40 ppf L -80 BTC -m casing. Make up jt #2 (Thread lock joint) (stop 10' below box w/ bow spring centralizer), make up Jt #3 w/ Halliburton Sure Seal II Float collar on bottom. Make up jt #4 (baker locked pin). Stab Frank's fillup tool and circulate w/ shoe above conductor shoe. Continue to run casing using Run -N- Seal dope. Centralizers are on box of first 13 joints then every other jt. Run in jt # 31 to 1170', lost 10k to 105k SO wt. Pick up to 1145', stab Frank's fillup tool. Estab circulation pumping 4 bpm w/ 200 psi- 28% Totco flow out. Increase pump rate to 5 bpm w/ 270 psi, wash in the hole from 1145' to jt # 40 in the hole -- 1515. Worked through numerous areas from 1170' to 1515' which we saw a reduction in slack off wt, so washed casing string in the hole. Con't to run casing w/o pumping from 1515' to 1670' (jt # 41 thru jt # 44). Circulate 1.5 BU (150 bbls) while recip from 1670' to 1705' (Jt # 45 in the hole). Con't to run 9 -5/8" 40 ppf L -80 BTC -m surface casing f/ 1705' to 2680' (jt #71). Make up FMC hanger and landing joint. Run in hole and land on hanger w/ shoe @ 2723.25'. PU wt 175k, SO wt 140k. Rig down Frank's fill up tool. Blow down the top drive. RU Dowell cement head & lines. Circ and condition mud and hole for cement job. Reciprocate pipe f/ 2723' to 2688' (35). Initial pump rate 5 bpm w/ 320 psi, 6 bpm w/ 380 psi, final 7 bpm w/ 420 psi. Circ a total of 962 bbls bbls. Prior to pumping 50 bbls of 9.7 ppg mud w/ nut plug, then 36.5 bbls of viscosified water w/ nut plug for the cement job. Cement - Surface Casing Cement - Started @ 3/13/2010 Type Wellbore Cemented String Cement Evaluation Results casing CD3 - 121 SURFACE, 2,723.3ftKB Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl /... P (final) (psi) 1 Surface Casing Cement 36.0 2,723.3 4 480.0 Fluid , Glass „ Amount (sacks) V (bbtj _- 4=5 Density (tbfgal) Yield +EstTop ftKB) EstBtm (ItKB) - - Mud w/ nut plug 50.0 9.70 Viscosified Water w/ nut plug 36.5 8.50 MudPush II 49.6 10.50 Arctic Set Lite 3 G 384 308.3 10.70 4.51 36.0 2,223.0 Page 4/5 Report Printed: 1/19/2011 F • • Security Level: AK Development 1 ri (IIiiV,ll, dill ill l u.. V I II Daily Drilling Report At J.. l it CD3 -121 Ml, lll�, Report Number: 5 ConocoPhill ips Rig: DOYON 19 Report Date: 3/13/2010 Fluid Class Amount (sacks) V (bbl) Density (lblgal) Yield (IP /sack) Est Top (itKB) Est atm, (ftKB) Alpine Surface Tail G 257 53.1 15.80 1.16 2,223.0 2,723.0 I Page 5/5 Report Printed: 1/19/2011 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: I CD3-121 I Rig: Delon 19 Dath: I 3114/2010 I Volume Input Volume/Stroke Pump Rate: Drilling Supervisor: I Dave Burley/ Granville Rizek 'Pump used: #2 Mud Pump ■ Strokes 01 005 Bbls/Strk ::::53)(1 Strk/min Ir Type of Test: Casing Shoe Test LOT/FIT V Pumping down annulus and DP. • - - - Casing Test Pressure Integrity Test Hole Size: 8-3/4" • Casing Shoe Depth Hole Depth Pumping Shut-in Pumping Shut-in RKB-CHF: 36.OIFt 2723.3IFt-MDI 2457.OIFt _ 2753.OIFt 12480.9IFt-TVD Strks psi Min psi Strks , psi Min psi Casinq Size and Description: - 19-5/8" 40#/Ft L-80 BTC v 0 0 0 3550 0 0 0.00 1100 Casinq Test Pressure IntearitvTest 2 175 1 3550 1 40 0.25 900 Mud Weight: 9.7 ppg Mud Weight: 9.6 ppg 4 320 2 3550 2 90 0.50 880 Mud 10 min Gel: 16.0 Lb/100 Ft2 Mud 10 min Gel: 50.0 Lb/100 Ft2 6 575 3 3550 3 190 1.00 84411 Test Pressure: 3500.0 psi Rotating Weight: *MIAMI* Lbs 8 800 4 3550 4 300 1.50 790 Rotating Weight: #####ff Lbs Blocks/Top Drive Weight: 74000.0 Lbs 10 975 5 3545 5 400 2.00 780 Blocks/Top Drive Weight: 74000.0 Lbs Desired PIT EMW: 18.0 ppg 12 1140 6 3545 6 510 2.50 770 Estimates for Test: 2.4 bbls Estimates for Test: 1073 psi 0.7 bbls 14 1310 7 3545 7 600 3.00 760 . w 16 1550 8 3545 8 710 3.50 760 EMW = Leak-off Pressure + Mud Weight = 860 + 96 PIT 15 Second 18 1750 9 3540 9 800 4.00 760 . 0.052 x TVD - 0.052 x 2457 Shut-in Pressure, psi 20 2000 10 3535 10 860 4.50 755 EMW at 2723.25 Ft-MD (2457 Ft-TVD) = 16.3 ppg 900 22 2225 15 3530 11 910 5.00 755 4000 [ Lost 60 psi during test, held - L - 24 2475 20 3505 12 970 5.50 750 98.3% of test pressure. 26 2725 25 3495 13 1040 6.00 750 3500 Alogasil.T44-0,14,1,_ip-„....,_j6 28 2975 30 3490 14 1100 6.50 750 'i 30 3275 3485 :;:::;:;:;:;:;:ii:::::.:: 7.00 750 3000 ,. 32 3550 :;:;:;:;:;:;;;:::;;;;;;;;;H:H 7.50 750 8.00 745 W 2500 ,:i 8.50 745 , 9.00 745, m ' O 2000 ,. ::::!;: 9.50 74 u) 10.00 745 O. • 1500 1000 500 0 - '' . . . . 0 1 2 3 4 0 5 10 15 20 25 30 Barrels Shut-In time, Minutes Volume Volume Volume Volume imlitm'CASING TEST -0-LEAK-OFF TEST 0 PIT Point Pumped Bled Back Pumped Bled Back Comments: l-.1-1,1-1Z I Huai out IdeC t...sg rlT.xls Summary CD3 -121 Intermediate Well: 003 -121 BTO-ni Casing Date: 3/2012010 Con04111llips Rig: Cioyon g 19 Aiask, Inc. Depth Jt Number Joints Well Equipm "t 'es cription and Comments Length Tops Page 1 RKB to Casing Flange (Load shoulder 34.61') (LLDS 33.69') 33.69 EINNUEL ............... FMC 7" Mandrel hanger 1.08 33.69 7 ", 26 #, L -80, BTC -m Casing Pup jt Pin x Pin 2.26 34.77 Jts 88 to 216 129 Jts 7 ", 26 #, L - 80, BTC - Casing 5277.97 37.03 HES 7 " Stage Collar 2.43 5315.00 Jts 4 to 87 84 Jts 7 ", 26 #, L - 80, BTC - Casing 3427.72 5317.43 HES Shut - off Baffle Collar 1.01 8745.15 Jts 3 to 3 1 Jts 7 ", 26 #, L - 80, BTC - Casing 43.05 8746.16 HES Sure Seal II Float Collar w/ By - Pass Baffle Adapter 1.01 8789.21 Jts 1 to 2 2 Jts 7 ", 26 #, L - 80, BTC - Casing 85.80 8790.22 Ray Oil Tools " Silver Bullet" Float Shoe 2.12 8876.02 Bottom of shoe >> 8878.14 8 -3/4" Hole TD @ 8888' MD / 6946 'TVD, Hole angle 83.25 deg 8878.14 • 7" Shoe @ 8878.14' MD / 6945' TVD/ Hole angle 83 deg 8878.14 Rat hole 9.86'. 8878.14 Total of 91 Straight Blade centralizers (7" x 8 -3/8 ") - 5 Stop Collars 8878.14 1 Staight Blade centralizer w/ stop 10' above shoe -Jt. #1 8878.14 1 Straight Blade centralizer w/ stop ring 10' below Float Collar jt. #2 8878.14 1 Straight Blade centralizer w/ stop collar 10' below Baffle Adaptor Jt. #3 8878.14 1 Straight Blade centralizer per jt on jts # 4 - #30 floating 8878.14 8878.14 1 Straight Blade centralizer w/ stop ring 10' below Stage Collar jt. #87 8878.14 1 Staight Blade centralizer w/ stop 10' above Stage Collar -Jt. #88 8878.14 1 Straight Blade centralizer per joint floating # 89 thru #114 8878.14 8878.14 1 on 3 jts Across Shoe jts # 152, #153 & 154 8878.14 then 1 every other jt # 156 to # 214 8878.14 8878.14 8878.14 8878.14 8878.14 Planned: 230 jts in pipe shed / 216 jts to run. 8878.14 14 joints left in the shed 8878.14 8878.14 8878.14 Remarks: Drifted w/ 6.151" plastic rabbit Up Wt 270 K Average MU torque= 8000 Ft lbs Dn Wt 180 K Used Run -N -Seal dope Block Wt 80 K While running pipe last: PU wt 300k, SO wt 185k numbers to the right are final while cementing. Supervisors: Fred Herbert / Granville Rizek I • 1 Cement Detail Report w pl CD3 -121 ConocoPMhil l ips String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 3/9/2010 21:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 3/20/2010 22:38 3/21/2010 08:55 CD3 - 121 Comment Circ 632 bbls prior to cementing. Final PU wt while circulating 270k, SO wt 180k. Note: Held ob job safety ppg, PV/YP= 12/19. Dowell pump 3 bbl of CW 100, shut down, PT to 3500 P Y meetin 9 on cement job while circ. Final mud weight 9 10 PP9 psi, con't to pump 37 more bbls of CW 100 (Total of 40 bbls CW 100). Crosssover on the landing joint was leaking. Shut down and tightened the cement crossover while Dowell mixed Mudpush II to 11.5 ppg. Pumped 35 bbls MudPush II (11.5 ppg) at 4 bpm w/ 400 to 350 psi. Shut down load and kick out bottom plug w/ 5 bbls of MudPush II (Total of 40 bbls MudPush II). Shut down and load Halliburton shut -off plug, while Dowell mix Alpine tail cement (15.8 ppg, 1.16 cuft/sx, 5.08 gal /sx water). Dowell pump 46.4 bbls (225 sx) of Alpine tail cement (15.8 ppg)(1.16 cu ft/sx) 5.076 gal /sx) (5.34 hrs thickening time). Pumping 4.3 bpm w/ 350 psi initial & 100 psi final. Drop Halliburton shut -off plug. Dowell displace 20 bbls of water behind plug. Pumping 4.3 bpm w/ 50 psi. Rig displace cement w/ 10 ppg mud. Did not bump plug at max strokes. WOC 5.42 hrs. Start pumping 3 bpm, press up to 900 psi (28 strokes to attain 900 psi). Hold 900 psi f/ 5 minutes. Con't to pressure up to open Halliburton cementer @ 5315'. Cementer opened at 3500 psi. Circulate and condition mud for second stage cement job. Circ 4 to 5 bpm w/ 260 to 300 psi. PJSM on 2nd stage cement job. Dowell pump 30 bbls CW 100, pumping 5 bpm w/ 340 to 380 psi.. Mix and pump 30 bbls mud push spacer (11.5 ppg), pumping 4.3 bpm w/ 350 to 290 psi. Dowell mix then pump 39.5 bbls (191.2 sx) cement, pumping 4.3 bpm w/ 300 to 116 psi. Shut down, drop Halliburton top plug. Dowell kick out plug w/ 20 bbls of water, pumping 4.7 bpm w/ 87 psi. Rig displace cement w/ 183.1 ppg mud (1822 strokes). Pumping 5 bpm w/ initial 100 psi. Final rate of 3 bpm w/ 375 psi. Bump plug w/ 200 psi over to 600 psi. Increase pressure to 1500 psi to shift cementer sleave closed. Hold f/ 5 minutes. CIP 0855 hrs 3 -21- 2010. Cement Stages Stage t ;= Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtm (... Top Plug? Btm Plug? Intermediate Casing cement intermediate 7,797.0 8,888.0 Yes Yes Yes Cement shoe Q (start) (bbl /min) Q (end) (bbl /min) Q (avg) (bbl /min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 3 3 6 450.0 900.0 Yes 20.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Drill Bit 6 1/4 Comment Circ & Cond Mud Prior to First Stage Cement. Circ a total of 632 bbls prior to cementing. Stagged pumps up from 3.5 bpm w/ 420 psi, final 6 bpm w/ 600 to 650 psi. Reciprocated 25' stroke f/ 8878' to 8858'. Final PU wt while circulating 270k, SO wt 180k. Note: Held pre job safety meeting on cement job while circulating. Final mud weight 10 ppg, PV/YP= 12/19. Dowell pump 3 bbl of CW 100, shut down, PT to 3500 psi, con't to pump 37 more bbls of CW 100 (Total of 40 bbls CW 100). Crosssover on the landing joint was leaking. Shut down and tightened the cement crossover while Dowell mixed Mudpush II to 11.5 ppg. Pumped 35 bbls MudPush II (11.5 ppg) at 4 bpm w/ 400 to 350 psi. Shut down load and kick out bottom plug w/ 5 bbls of MudPush II (Total of 40 bbls MudPush II). Shut down and load Halliburton shut -off plug, while Dowell mix Alpine tail cement (15.8 ppg, 1.16 cuft/sx, 5.08 gal /sx water). Dowell pump 46.4 bbls (225 sx) of Alpine tail cement (15.8 ppg)(1.16 cu ft/sx) 5.076 gal /sx) (5.34 hrs thickening time). Pumping 4.3 bpm w/ 350 psi initial & 100 psi final. Drop Halliburton shut -off plug. Dowell displace 20 bbls of water behind plug. Pumping 4.3 bpm w/ 50 psi. Rig displace cement w/ 10 ppg mud. Pumping 7 bpm w/ initial 350 psi. Slowed rate to 4 bpm w/ 80 psi while bottom plug went through the cementer, increased rate back to 7 bpm w/ 360 to 390 psi, then slowed to 4 bpm w/ 40 to 70 psi while top plug went through cementer. Increased rate back to 7 bpm w/ 300 psi & a final of 630 psi before slowing down last 10 bbls to 3 bpm w/ initial 320, final of 450 psi prior to pumping maximum strokes (3158 strokes) (317.4 bbls). Set casing on hanger during last 10 bbls pumped. Did not bump plug. Refigure pump volume using .1 bps instead of .1005 bps, then pumped to 3174 strokes (317.4 bbls). Still did not bump plug. Pumped 2 more bbls (4 of 5 bbls in shoe track). Did not bump plug. Town engineer was contacted and decision to WOC before trying to open cementer for second stage Cement, Fluids & Additives Fluid - Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) CW100 5,665.0 6,731.0 40.0 Yield (ft' /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb /gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 8.50 Additives Additive Type Concentration Conc Unit label D046 Antifoam 0.2 %BWOC Additive Type Concentration Conc Unit label D065 Dispersant 0.25 %BWOC Additive Type Concentration Conc Unit label D167 Fluid loss 0.18 %BWOC Additive Type Concentration Conc Unit label D800 Retarder 0.25 %BWOC Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) MudPushll 6,731.0 7,797.0 40.0 Yield (ft' /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb /gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 11.50 Page 1/2 Report Printed: 1/19/2011 0 1 Cement Detail Report CD3 -121 CoinocoPhil lips String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 3/9/2010 21:00 Additives Additive Type Concentration Conc Unit label Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail 7,797.0 8,888.0 225 G 46.4 Yield (ft' /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb /gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 5.08 15.80 5.34 Additives Additive Type Concentration Conc Unit label S002 Accelerator 0.8 %BWOC Additive Type Concentration Conc Unit label D046 Antifoam 0.2 %BWOC Additive Type Concentration Conc Unit label D065 Dispersant 0.3 %BWOC Cement Stages - Stage # 2 Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtm (... Top Plug? Btm Plug? Intermediate Casing Isolate Quannik 4,262.0 5,315.0 No Yes No Cement Formation Q (start) (bbl /min) Q (end) (bbl /min) Q (avg) (bbl /min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 5 3 5 375.0 600.0 No No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) 5,308.0 Drill Bit 6 1/4 Comment Did not bump plug on first stage. Wait on cement 5.42 hrs. Start pumping 3 bpm, press up to 900 psi (28 strokes to attain 900 psi). Hold 900 psi for 5 minutes. Continue to pressure up to open Halliburton cementer @ 5315'. Cementer opened at 3500 psi. Circulate and condition mud for second stage cement job. Circulate 4 to 5 bpm w/ 260 to 300 psi. Pre job safety meeting on 2nd stage cement job. Dowell pump 30 bbls CW 100, pumping 5 bpm w/ 340 to 380 psi.. Mix and pump 30 bbls mud push spacer (11.5 ppg), pumping 4.3 bpm w/ 350 to 290 psi. Dowell mix then pump 39.5 bbls (191.2 sx) cement, pumping 4.3 bpm w/ 300 to 116 psi. Shut down, drop Halliburton top plug. Dowell kick out the plug with 20 bbls of water, pumping 4.7 bpm w/ 87 psi. Rig displace cement w/ 183.1 ppg mud (1822 strokes). Pumping 5 bpm w/ initial 100 psi. , 21% flow out. Final rate of 3 bpm w/ 375 psi. Bump plug w/ 200 psi over to 600 psi. Increase pressure to 1500 psi to shift cementer sleave closed. Hold f/ 5 minutes, bled off to check floats- OK. CIP at 0855 hrs. Rig down cementing equipment. Lay down 7" landing joint. Cement Fluids & Additives Fluid - - - Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) CW100 2,662.0 3,462.0 30.0 Yield (ft' /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb /gal) `Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 8.40 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) MudPushll 3,462.0 4,262.0 30.0 Yield (ft' /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb /gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 11.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Intermediate Cement 4,262.0 5,315.0 191 G 39.5 Yield (ft' /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb /gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 5.11 15.80 5.34 Additives Additive Type Concentration Conc Unit label S002 Accelerator 1.0 %BWOC Additive Type Concentration Conc Unit label D046 Antifoam 0.2 %BWOC Additive Type Concentration Conc Unit label D065 Dispersant 0.3 %BWOC Page 2/2 Report Printed: 1/19/2011 • • Security Level: AK Development Daily Drilling Report 477900L a CD3 -121 ccvcQt)tvtli Report Number: 12 s Rig: DOYON 19 Report Date: 3/20/2010 ,,, AFE Type "" Network/ID # 't'otatAEO=Sup 10277784 9,625,000.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3 - 121 Development FIORD NECHELIK 375.42 12.0 0.00 8,888.0 8,888.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 9,572.07 326,092.93 227,199.07 3,197,915.93 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 3/9/2010 3/10/2010 27.00 22.63 4.37 4/1/2010 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) INTERMEDIATE, 8,878.1ftKB Ops and Depth c Morning Report 24hr Forecast Wait on cement- 1st stage cement job. Finish 1st stage 7" cement job, open cementer, perform 2nd stage cement job, rig down casing and cementing equipment, pull wear bushing, install and test packoff, change rams to 3 -1/2" x 6 ", test BOPE, lay down drill pipe. Last 24hr Summary Pull wear bushing, change top rams to 7 ", test to 250/3500 psi. Pull test plug, set casing running wear bushing. RU to run 7" csg. PJSM, Run 7" 26 ppf L -80 BTC -m csg per detail. Circ w/ Frank's fillup tool after 4 joints, check floats- OK. Con't to run csg to 2702' (66 jts), circ 2+ BU (150 bbls) stage up to 6 bpm w/ 410 psi. Con't to run csg to 4704' (115 jts), circ +/- 2 BU (240 bbls) stage up to 6 bpm w/ 510 psi. Con't to run csg to 6745' (165 jts), circ 2 BU (363 bbls) stage up to 6 bpm w/ 550 psi. Con't to run csg to 7765' (190 jts), circ 1.5+ BU (342 bbls) stage up to 6 bpm w/ 640 psi. Con't to run csg to 8841' (216 jts) PU wt 300k, SO wt 185k. Make up FMC 7" csg hanger w/ landing joint. RIH /land on hanger w/ shoe @ 8878.14' Final PU wt 300k, SO wt 180k. L/D FU Tool - BD Top Drive & M/U Dowell cement head. Circ & Cond mud prior to First Stage Cement. Circ a total of 632 bbls prior to cementing. Stage pumps up from 3.5 bpm w/ 420 psi, final 6 bpm w/ 600 to 650 psi, totco 21 to 25% flow out. Recip 25' stroke f/ 8878' to 8858'. Final PU wt while circulating 270k, SO wt 180k. Note: Held pre job safety meeting on cement job while circ. Final mud weight 10 ppg, PV/YP= 12/19. Dowell pump 3 bbl of CW 100, shut down, pressure test lines to 3500 psi, con't to pump 37 more bbls of CW 100 (Total of 40 bbls CW 100). Crosssover on the landing joint was leaking. Shut down and tightened the cement crossover while Dowell mixed Mudpush II to 11.5 ppg. Pumped 35 bbls MudPush II (11.5 ppg) at 4 bpm w/ 400 -350 psi. Shut down load and kick out bottom plug w/ 5 bbls of MudPush II (Total of 40 bbls MudPush II). Shut down & load shut -off plug, while Dowell mix Alpine tail cement. Dowell pump 46.4 bbls (225 sx) of Alpine tail cement (15.8 ppg)(1.16 cu ft/sx) 5.076 gal /sx) (5.34 hrs thickening time). Pumping 4.3 bpm w/ 350 psi initial -100 psi final. Drop Halliburton shut -off plug. Dowell displace 20 bbls of water. Rig displace cement w/ 10 ppg mud. Pumping 7 bpm w/ initial 350 psi. General Remarks Weather Head Count No Spills / No Accidents. on Hi -line w/ one engine running. -15 °, WC -41°, Wind NE @ 18 Mph, 10 mile 49.0 vis Supervisor Title Fred Herbert, Rig Supervisor Rig Supervisor Granville Rizek, Rig Supervisor Rig Supervisor Dave Egedahl, Rig Engineer Rig Engineer Time=i,.og Start Endr Dur Time Depth, Start , Depth End Time Time `(hrs) - Phase ©p Code- _ - Activity Cook __ P-T-X __ Trb[ Code Trbi Crass. (ftKB) ' (ftKB)- Operation 00:00'01:15 1.25 INTRM1 WHDBOP OTHR P Pull FMC long wear bushing (10" ID). Used air hoist- no go. Used blocks up to 15k overpull- no go. Steamed body of wellhead, rechecked all lockdown screws were backed out. Pulled wear bushing w/ blocks and 19k overpull. 01:15 01:30 0.25 INTRM1 WHDBOP SFTY P Pre job safety meeting on changing top pipe rams. 01:30 03:15 1.75 INTRM1 WHDBOP NUND P Change top pipe rams from 3 -1/2" x 6" variables to 7" solid body w/ blind rams shut. Rigging up casing equipment on floor (long bales, elevators and Frank's fillup tool). 03:15 03:45 0.50 INTRM1 WHDBOP BOPE P Set FMC test plug. Fill hole with water. Lower annulus open. 03:45 04:00 0.25 INTRM1 WHDBOP BOPE P Test top pipe rams to 250 psi low and 3500 psi high. Hold test f/ 5 minutes each. Chart test. Latest BOP Test Data r Date 3/20/2010 7" top pipe rams Page 1/5 Report Printed: 1/19/2011 1 Security Level: AK Development Daily Drilling Report CD3 -121 CcaNhiilips Report Number: 12 Rig: DOYON 19 Report Date: 3/20/2010 Time Log Start End Dur Time Depth Stark Depth End Time Time (bra) Phase Op Code Aotivity=Code P-T -X °' Trbl Code Trbl Class. 0#931 (ftKS) Operation 04:00 04:30 0.50 INTRM1 WHDBOP RURD P Rig down test equipment. Set FMC thin wall casing running wear bushing ( 1.53' long x 10 -7/8" OD x 10 -3/8" ID). Lay down running tool and test joint. 04:30 05:30 1.00 INTRM1 CASING RURD P Finish rigging up to run 7" casing. 05:30 05:45 0.25 INTRM1 CASING SFTY P Pre job safety meeting on running 7" 26 ppf L -80 BTC -m casing. 05:45 06:45 1.00 INTRM1 CASING RNCS P 0.0 130.0 Run 7" casing: Pick up jt #1: Ray Oil tool 7 -5/8" eccentric shoe joint w/ Ray Oil Tool aluminum centralizer (7 "" x 8- 5/16 ") floating f/ shoe to 10' above the shoe with stop ring. Thread lock joint #2 w/ 7" x 8- 5/16" aluminum centralizer between box and 10' below box with stop ring. Baker lock Halliburton Sure Seal II Float Collar w/ baffle adapter installed. Thread lock jt #3 w /Ray Oil Tool aluminum centralizer (7 "" x 8- 5/16 ") floating f/ pin to 10' above pin with stop ring. Baker lock Halliburton Baffle adapter, then Baker lock pin of Jt #4 with centralizer floating the full joint. Four connections were baker - locked. 06:45 07:00 0.25 INTRM1 CASING CIRC P 130.0 130.0 Stab Frank's fillup tool, then circulate 20 bbls of mud to check floats. Pumping 4.5 bpm w/ 180 psi. 07:00 09:30 2.50 INTRM1 CASING RNCS P 130.0 2,702.0 Continue to run 7" 26 ppf L -80 BTC -m casing f/ 130' to 2702' (66 jts in the hole). PU 133k, SO 123k. Obtain PU & SO wt's per rig engineer. 09:30 10:00 0.50 INTRM1 CASING CIRC P 2,702.0 2,702.0 Circulate 2+ BU 150 bbls. Stage up f/ 3.5 bpm w/ 260 psi to 6 bpm w/ 410 psi, 23 to 25% Totco flow meter. 10:00 12:00 2.00 INTRM1 CASING RNCS P 2,702.0 4,704.0 Continue to run 7" 26 ppf L -80 BTC -m casing f/ 2702' to 4704' (115 jts in the hole). PU wt 175k, SO wt 150k. Obtain PU & SO wt's per rig engineer. 12:00 13:00 1.00 INTRM1 CASING CIRC P 4,704.0 4,704.0 Circulate 2 +/- bottom's up, 240 bbls. Stage up f/ 3.5 bpm w/ 380 psi to 6 bpm w/ 510 psi, 25% Totco flow meter. PU wt 170k, SO wt 145k. 13:00 15:00 2.00 INTRM1 CASING RNCS P 4,704.0 6,745.0 Continue to run 7" 26 ppf L -80 BTC -m casing f/ 4704' to 6745' (165 jts in the hole). PU wt 237k, SO wt 170k. Obtain PU & SO wt's per rig engineer. 15:00 16:15 1.25 INTRM1 CASING CIRC P 6,745.0 6,745.0 Circulate 2- bottom's up, 362 bbls. Stage up f/ 3.5 bpm w/ 410 psi to 6 bpm w/ 550 psi, 25 to 27% Totco flow out. PU wt 220k, SO wt 174k. 16:15 17:15 1.00 INTRM1 CASING RNCS P 6,745.0 7,765.0 Continue to run 7" 26 ppf L -80 BTC -m casing f/ 6745' to 7765' (190 jts in the hole). PU wt 265k, SO wt 184k. Obtain PU & SO M's per rig engineer. Page 2/5 Report Printed: 1/19/2011 • ,lg n Security Level: AK Development Daily Drilling Report *, 1 �'uikN CD3 -121 Report Number: 12 ConocoPhillips Rig: DOYON 19 Report Date: 3/20/2010 Time Log Start End _- Dur - Time Depth Start Depth End' Time Time =` lhrs) - Phase= Op Code , Activity Code P -T -X . Trbl Code Trbi Class. _ EftKB) ;, (ftKB) - Operation 17:15 18:30 1.25 INTRM1 CASING CIRC P 7,765.0 7,765.0 Circulate 1.5+ bottom's up, 342 bbls. Stage up f/ 3.5 bpm w/ 410 psi to 6 bpm w/ 640 psi, 23 to 25% Totco flow out. 18:30 19:45 1.25 INTRM1 CASING RNCS P 7,765.0 8,841.0 Continue to run 7" 26 ppf L -80 BTC -m casing f/ 7765' to 8841' (216 jts in the hole). PU wt 300k, SO wt 185k. Final PU wt 300k, SO wt 180k. Obtain PU & SO wt's per rig engineer. 19:45 20:00 0.25 INTRM1 CASING RNCS P 8,841.0 8,878.0 Make up FMC 7" casing hanger w/ landing joint. RIH and land on hanger w/ shoe @ 8878.14' Final PU wt 300k, SO wt 180k. 20:00 20:30 0.50 INTRM1 CEMENT PULD P 8,878.0 8,878.0 L/D Franks Fill -Up Tool - Blow Down the Top Drive & M/U Dowell cement head and lines. 20:30 22:30 2.00 INTRM1 CEMENT CIRC P 8,878.0 8,878.0 Circ & Condition Mud Prior to First Stage Cement. Circulated a total of 632 bbls prior to cementing. Stagged pumps up from 3.5 bpm w/ 420 psi, after 20 bbls 4 bpm w/ 480 psi, after 50 bbls pumped 5 bpm w/ 510 psi, after 100 bbls pumped, went to 6 bpm w/ 600 to 650 psi, totco 21 to 25% flow out. Reciprocated 25' stroke f/ 8878' to 8858'. Final PU wt while circulating 270k, SO wt 180k. Note: Held pre job safety meeting on cement job while circulating. Final mud weight 10 ppg, PV/YP= 12/19. 22:30 23:15 0.75 INTRM1 CEMENT PUCM P 8,878.0 8,878.0 Dowell pump 3 bbl of CW 100, shut down, pressure test lines to 3500 psi, continue to pump 37 more bbls of CW 100 (Total of 40 bbls CW 100). Crosssover on the landing joint was leaking. Shut down and tightened the cement crossover while Dowell mixed Mudpush II to 11.5 ppg. Pumped 35 bbls MudPush 11 (11.5 ppg) at 4 bpm w/ 400 to 350 psi. Shut down load and kick out bottom plug w/ 5 bbls of MudPush II (Total of 40 bbls MudPush II). Shut down and load Halliburton shut -off plug, while Dowell mix Alpine tail cement (15.8 ppg, 1.16 cuft/sx, 5.08 gal /sx water). 23:15 23:30 0.25 INTRM1 CEMENT PUCM P 8,878.0 Dowell pump 46.4 bbls (225 sx) of Alpine tail cement (15.8 ppg)(1.16 cu ft/sx) 5.076 gal /sx) (5.34 hrs thickening time). Pumping 4.3 bpm w/ 350 psi initial and 100 psi final. 23:30 23:45 0.25 INTRM1 CEMENT DISP P 8,878.0 8,878.0 Drop Halliburton shut -off plug. Dowell displace 20 bbls of water behind plug. Pumping 4.3 bpm w/ 50 psi. Page 3/5 Report Printed: 1/19/2011 Security Level: AK Development n a tY p otie Daily Drilling Report r CD3 -121 csrtQCaPhttlip Report Number: 12 Rig: DOYON 19 Report Date: 3/20/2010 Time Log _ ;,Start End's Dur Time p 4epth Start Depth End Time Time (firs) Phas } - Op Code Activity Code = P -T -X - °°-Trbl Code Trht Class. (ftKB) (ftKB) Operation 23:45 00:00 0.25 INTRM1 CEMENT DISP P 8,878.0 8,878.0 Rig displace cement w/ 10 ppg mud. Pumping 7 bp w/ initial 350 psi. At P 9 m midnight 100 bbls of mud had been displaced, pumping 7 bpm w/ 390 psi, 26% flow out. PU wt 270k, SO wt 190K. Reciprocating 13' from 8878' to 8865'. Mud Check Data - YP Catc= Get (10s) Gel (10/4 - - Gel (30m) t•fTHP Flit ! Density Temp `- Solids, Corr._ Type Depth MKS) Dens (11441) Vis (s /qt) PV Cat PCa(cp) (lbf /100fti (Ibf/100W), (Ibf/10Dft) (lbf/100fr) MET(Ibtbbl) __(mlP3Omin)' p Fi (°F} ( %) _ - LSND 8,888.0 10.00 45 12.0 19.0 8.0 13.0 15.000 17.0 9.4 11.0 w /Glydril GP LSND 8,888.0 10.00 45 12.0 19.0 8.0 14.0 15.000 17.0 8.5 9.4 11.0 w /Glydril GP Injection Fluid Source From, bbi Vendor Destination Manifest Number Note . Fluid ( ) Diesel 20.0 CD3 -114 YVell bares Wellbore Name Wellbore API /UWI CD3 -121 501032061500 Section Size (in) °- Act Top (ftKB) Act Btm (MKS) Startate End Date ,k.„; CONDI 18 36.0 114.0 4/10/2009 4/10/2009 SURFAC 12 1/4 114.0 2,733.0 3/10/2010 3/12/2010 INTRM1 8 3/4 2,733.0 8,888.0 3/14/2010 3/19/2010 PROD1 6 3/4 8,888.0 15,081.0 3/24/2010 3/28/2010 Casing Strings Stringf)0= _ String =wt _ Esige Casing Description = Run Date - (in) (lbsItt) String Grade Set Depth (ftKB) - Comment _ INTERMEDIATE 3/20/2010 7 26.00 L -80 8,878.1 RU to run 7" csg. PJSM, Run 7" 26 ppf L -80 BTC -m csg per detail. Circ w/ Frank's fillup tool after 4 joints, check floats- OK. Con't to run csg to 2702' (66 jts), circ 2+ BU (150 bbls) stage up to 6 bpm w/ 410 psi. Con't to run csg to 4704' (115 jts), circ +/- 2 BU (240 bbls) stage up to 6 bpm w/ 510 psi. Con't to run csg to 6745' (165 jts), circ 2 BU (363 bbls) stage up to 6 bpm w/ 550 psi. Con't to run csg to 7765' (190 jts), circ 1.5+ BU (342 bbls) stage up to 6 bpm w/ 640 psi. Con't to run csg to 8841' (216 jts) PU wt 300k, SO wt 185k. Make up FMC 7" csg hanger w/ landing joint. RIH /land on hanger w/ shoe @ 8878.14' Final PU wt 300k, SO wt 180k. UD FU Tool - BD Top Drive & M/U Dowell cement head. Circ & Cond mud prior to First Stage Cement. Circ a total of 632 bbls prior to cementing. Stage pumps up from 3.5 bpm w/ 420 psi, final 6 bpm w/ 600 to 650 psi, totco 21 to 25% flow out. Recip 25' stroke f/ 8878' to 8858'. Final PU wt while circulating 270k, SO wt 180k. Cement Intermediate Casing Cement - Started @ 3/20/2010 Type Wellbore Cemented String Cement Evaluation Results casing CD3 - 121 INTERMEDIATE, 8,878.1ftKB Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl /... P (final) (psi) 1 Intermediate Casing Cement 7,797.0 8,888.0 3 450.0 Fluid Class Amount (sacks) V (bbi) Density (tb/galk=_ Yield.( (sack) Est Top (ftKB)' Est Bkn_(ftKB) CW100 40.0 8.50 5,665.0 6,731.0 MudPushll 40.0 11.50 6,731.0 7,797.0 Page 4/5 Report Printed: 1/19/2011 0 • Security Level: AK Development ,up11 t4 11,1 Daily Drilling Report r - CD3 -121 i ry Report Number: 12 ConocoPhil l ips Rig: DOYON 19 Report Date: 3/20/2010 Fluid Class ' Amount (Sacks) V (bbl) Density (lb /gal) _ Yield (ft' /sack) Est Top (ftKB) Est Btm_(ftKS) Tail G 225 46.4 15.80 1.16 7,797.0 8,888.0 Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl /... P (final) (psi) 2 Intermediate Casing Cement 4,262.0 5,315.0 3 375.0 Fluid Class Amount (sacks) V (bbl) Density (lb/gal) Yield (ft' /sack) " Est Top (ftK&). , , Eat Btm (ftKB) CW1 30.0 8.40 2,662.0 3,462.0 MudPushll 30.0 11.50 3,462.0 4,262.0 Intermediate Cement G 191 39.5 15.80 1.16 4,262.0 5,315.0 Page 5/5 Report Printed: 1/19/2011 110 • Security Level: AK Development j Daily Drilling Report p1 110 , 1,111llppii CD3 -121 Report Number: 13 ConocoPhif ips ° jIIV''' Rig: DOYON 19 Report Date: 3/21/2010 AFE Type < --- Network/ID # " ^ Total AFE+Sup . 10277784 9,625,000.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3 - 121 Development FIORD NECHELIK 376.42 13.0 0.00 8,888.0 8,888.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 3,427.33 329,520.26 631,465.33 3,829,381.26 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 3/9/2010 3/10/2010 27.00 23.63 3.37 4/2/2010 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) INTERMEDIATE, 8,878.1ftKB Ops and Depth @ Morning Report 24hr Forecast Trip in hole @ approx 5000' w/ BHA #4. Finish laying down 5" dp f/ derrick, Change heads in iron roughneck, PU /MU BHA # 4, RIH, drill stage collar, POOH, test BOPE, PU /MU BHA #5, single in the hole w/ 5" dp. Last 24hr Summary Rig con't to displ cmt w/ 10 ppg mud. PU wt 270k, SO wt 190K. Recip 13' from 8878' to 8865'. Slow rate to 4 bpm w/ 80 psi while bottom plug went through the cementer, increased rate back to 7 bpm w/ 360 to 390 psi, then slowed to 4 bpm w/ 40 to 70 psi while top plug went through cementer. Increased rate back to 7 bpm w/ 300 psi & final of 630 psi before slowing down last 10 bbls to 3 bpm w/ initial 320, final of 450 psi prior to pumping max strokes (3158 strokes) (317.4 bbls). Set casing on hanger during last 10 bbls pumped. Did not bump plug. Refigure pump volume using .1 bps instead of .1005 bps, then pumped to 3174 strokes (317.4 bbls). Still did not bump plug. Pumped 2 more bbls (4 of 5 bbls in shoe track). Did not bump plug. Town engineer was contacted and decision to WOC before trying to open cementer for second stage. CIP @ 0055 hrs 3/21/2010. WOC 5.42 hrs. Pumping 3 bpm, press up to 900 psi (28 strokes to attain 900 psi). Hold 900 psi for 5 minutes. Con't to press up to open Halliburton cementer @ 5315'. Cementer opened at 3500 psi. Circ & cond mud for 2nd stage job. Circ 4 to 5 bpm w/ 260 to 300 psi. PJSM. Dowell pump 30 bbls CW 100, pump 5 bpm w/ 340 to 380 psi.. Mix & pump 30 bbls mud push spacer (11.5 ppg), pumping 4.3 bpm w/ 350 to 290 psi. Dowell mix/pump 39.5 bbls (191.2 sx) cement, pumping 4.3 bpm w/ 300 to 116 psi. Shut down, drop Halliburton top plug. Dowell kick out the plug with 20 bbls of water, pumping 4.7 bpm w/ 87 psi. Rig displace cement w/ 183.1 ppg mud (1822 strokes). Pumping 5 bpm w/ initial 100 psi. , 21% flow out. Final rate of 3 bpm w/ 375 psi. Bump plug w/ 200 psi over to 600 psi. Increase pressure to 1500 psi to shift cementer sleave closed. Hold f/ 5 minutes, bled off to check floats- OK. CIP at 0855 hrs.R/D cmt equip, Pull wear bush, install 7" packoff, test to 5000 psi f/ 10 min -ok, change top pipe rams to 3 -1/2x 6 ", test upper & lower rams w/ 4" test joint, test annular. R/D, set wear bushing, PJSM, L/D 5" dp f/ derrick (8+ 80) General Remarks Weather Head Count No Spills / No Accidents. on Hi -line w/ one engine running. -15 °, WC -36 °, Wind NE @ 10 Mph, 10 mile 47.0 Dowell perform injectivity test 9 -5/8" x 7" ann to 14.9 ppg EMW. Flush & freeze protect. vis Title .,, Fred Herbert, Rig Supervisor Rig Supervisor Granville Rizek, Rig Supervisor Rig Supervisor Dave Egedahl, Rig Engineer Rig Engineer Latest BOP Test Data Date = Comment 3/21/2010 3 -1/2" x 6" w/ 4" test joint Page 1/4 Report Printed: 1/19/2011 1 Security Level: AK Development Nvto Lk*, Daily Drilling Report 'hi CD3 -121 101 Con�o�cof'tfillips Report Number: 13 Rig: DOYON 19 Report Date: 3/21/2010 Time Log Start End Dur Time Depth Start Depth End Time Time (hrs) Phase Op Code Activity Code � P -T -X Trbl Code Trbl Class (ftKB} - _- (ftXB) _ Operation 00:00 00:45 0.75 INTRM1 CEMENT DISP P 8,878.0 8,878.0 Rig continue to displace cement w/ 10 ppg mud. 100 bbls had been pumped prior to midnight Pumping 7 bpm w/ initial 390 psi. PU wt 270k, SO wt 190K. Reciprocating 13' from 8878' to 8865'. Slowed rate to 4 bpm w/ 80 psi while bottom plug went through the cementer, increased rate back to 7 bpm w/ 360 to 390 psi, then slowed to 4 bpm w/ 40 to 70 psi while top plug went through cementer. Increased rate back to 7 bpm w/ 300 psi and a final of 630 psi before slowing down last 10 bbls to 3 bpm w/ initial 320, final of 450 psi prior to pumping maximum strokes (3158 strokes) (317.4 bbls). Set casing on hanger during last 10 bbls pumped. Did not bump plug. Refigure pump volume using .1 bps instead of .1005 bps, then pumped to 3174 strokes (317.4 bbls). Still did not bump plug. Pumped 2 more bbls (4 of 5 bbls in shoe track). Did not bump plug. Town engineer was contacted and decision to WOC before trying to open cementer for second stage. CIP @ 0055 hrs 3/21/2010. 00:45 06:00 5.25 INTRM1 CEMENT WOC T Cement - Other 8,878.0 8,878.0 WOC. While waiting on cement to cure: Primary Prepare as much as possible to lay down 5" drill pipe. Rig crew work on work orders, perform derrick inspection. Service and inspect the top drive. Prepare to change out upper pipe rams. Prepare for upcoming BOPE test. 06:00 06:15 0.25 INTRM1 CEMENT PRTS T Cement - Other 8,878.0 8,878.0 Pumping 3 bpm, press up to 900 psi (28 Primary strokes to attain 900 psi). 06:15 06:30 0.25 INTRM1 CEMENT PRTS P 8,878.0 8,878.0 Hold 900 psi for 5 minutes. Continue to pressure up to open Halliburton cementer @ 5315'. Cementer opened at 3500 psi. 06:30 07:30 1.00 INTRM1 CEMENT CIRC P 8,878.0 8,878.0 Circulate and condition mud for second stage cement job. Circulate 4 to 5 bpm w/ 260 to 300 psi. 07:30 07:45 0.25 INTRM1 CEMENT SFTY P 8,878.0 8,878.0 Pre job safety meeting on 2nd stage cement job. 07:45 08:00 0.25 INTRM1 CEMENT CMNT P 8,878.0 8,878.0 Dowell pump 30 bbls CW 100, pumping 5 bpm w/ 340 to 380 psi.. Mix and pump 30 bbls mud push spacer (11.5 ppg), pumping 4.3 bpm w/ 350 to 290 psi. 08:00 08:15 0.25 INTRM1 CEMENT PUCM P 8,878.0 8,878.0 Dowell mix then pump 39.5 bbls (191.2 sx) cement, pumping 4.3 bpm w/ 300 to 116 psi. 08:15 08:30 0.25 INTRM1 CEMENT CMNT P 8,878.0 8,878.0 Shut down, drop Halliburton top plug. 08:30 08:45 0.25 INTRM1 CEMENT DISP P 8,878.0 8,878.0 Dowell kick out the plug with 20 bbls of water, pumping 4.7 bpm w/ 87 psi. Page 2/4 Report Printed: 1/19/2011 • • Security Level: AK Development Daily Drilling Report CD3 -121 Report Number: 13 ConocoPhillips Rig: DOYON 19 Report Date: 3/21/2010 Time Log Start End u, Dur Time Depth Start = Depth Time Iime (hrs) Phase-` Op Code - Activity= Code P T X Trbl Code Tibl Class - _ (ftKB) (ftKB) Operation 08:45 09:00 0.25 INTRM1 CEMENT DISP P 8,878.0 8,878.0 Rig displace cement w/ 183.1 ppg mud (1822 strokes). Pumping 5 bpm w/ initial 100 psi. , 21% flow out. Final rate of 3 bpm w/ 375 psi. Bump plug w/ 200 psi over to 600 psi. Increase pressure to 1500 psi to shift cementer sleave closed. Hold f/ 5 minutes, bled off to check floats- OK. CIP at 0855 hrs. 09:00 10:00 1.00 INTRM1 CEMENT RURD P 8,878.0 0.0 Rig down cementing equipment. Lay down 7" landing joint. 10:00 10:30 0.50 INTRM1 WHDBOP OTHR P Pull FMC thin wall ( 1.53' long x 10 -7/8" OD x 10 -3/8" ID) casing running wear bushing. 10:30 11:00 0.50 INTRM1 WHDBOP OTHR P Install FMC 7" packoff. Run in lock down screws. 11:00 11:15 0.25 INTRM1 WHDBOP PRTS P Test FMC packoff to 5000 psi for 10 minutes. Good test. 11:15 11:30 0.25 INTRM1 WHDBOP PULD P Lay down casing equipment. 11:30 13:15 1.75 INTRM1 WHDBOP NUND P Change out upper pipe rams from 7" to 3 -1/2" x 6" variables. Change out the saver sub on the top drive to 4" XT39. Change heads in grabber f/ top drive to 4 ". Pick up short bales (Drilling bales), install elevators. 13:15 13:30 0.25 INTRM1 WHDBOP RURD P Pick up 4" test joint, make up FMC upper test plug. Set test plug. Fill stack with water. Rig up to test. 13:30 14:30 1.00 INTRM1 WHDBOP BOPE P Test annular to 250 psi low and 2500 psi high. Test upper and lower pipe rams to 250 psi low and 3500 psi high. Hold each test f/ 5 minutes. Chart tests. 14:30 14:45 0.25 INTRM1 WHDBOP RURD P Rig down testing equipment, pull 4" test joint w/ FMC test plug. Break and lay down test plug. 14:45 15:15 0.50 INTRM1 WHDBOP OTHR P Set FMC upper wear bushing. Run in lock down screws. 15:15 15:30 0.25 INTRM1 DRILL SFTY P Pre job safety meeting on laying down 5" drill pipe from the derrick. 15:30 00:00 8.50 INTRM1 DRILL PULD P Lay down 8 stands of 5" HWDP from the derrick via the mousehole. Then laying down a total of 90 stands of 5" G -105 drill pipe from the derrick. 80of 90 layed down at midnight. Note: Dowell performed injectivity on 9 -5/8" x 7" to 14.9 ppg EMW. Then pumped 300 bbls water, followed w/ 50 bbls of Diesel freeze protection for initial annular injection on CD3 -121. .Mud Check Data = VP Cab Gel (105) Get (10m) - !!!!!!! (30m HTHP Fill Density Temp Solids Corr _, Type Depth (ftKS) Dens (Ibtpal) Vas fslgt) PV Caic( (Ibf /100ft") (Ibf /100ft') - (1bfIlOOft }, -- (Ibf /lOOft MBT (lbibbl) = [mtJ3Omin) or ( ° P) ill -- LSND 8,888.0 10.00 50 14.0 20.0 11.0 14.0 17.000 126.2 10.1 11.0 w /Glydril GP Page 3/4 Report Printed: 1/19/2011 • • Security Level: AK Development W10 Daily Drilling Report k ��W�i�'�Iu'iuu��, �e CD3 -121 iC coPhillips 101: Report Number: 13 Rig: DOYON 19 Report Date: 3/21/2010 Injection Fluid = . Fluid = __ " Source From Lease (bbl) -'_ Destination == Vendor Manifest Number Note' Diesel CD3 -121 50.0 CD3 -121 initial Freeze Protect CD3 -121 Diesel 30.0 CD3 -114 Freeze protect Diesel 5.0 CD3 -114 Injectivity Water CD3 -121 300.0 CD3 -121 initial flush CD3 -121 Water 150.0 CD3 -114 Water Based Mud 445.0 CD3 -114 Water Based Mud CD3 -121 8.0 CD3 -121 to perform LOT Weilbores - Wellbore Name Welibore API /UWI CD3 -121 501032061500 Section i, Size (in) _ - - ' Act Top (ttKB) Aet Btm (ftKBJ Start Date End Date COND1 18 36.0 114.0 4/10/2009 4/10/2009 SURFAC 12 1/4 114.0 2,733.0 3/10/2010 3/12/2010 ' INTRM1 8 3/4 2,733.0 8,888.0 3/14/2010 3/19/2010 PROD1 6 3/4 8,888.0 15,081.0 3/24/2010 3/28/2010 Leak`Off and Formation Integrity Tests - Leak r -. =_'_= Dens Fluid LO' Fluid Den, oft? Last Casing String Run = 13epth (ftKS) (lb/gai)'= Fluid P (Surf) (psi) Pb/gal) P (Lon:isi) No INTERMEDIATE, 8,878.1ftKB 4,298.0 10.00 WBM 633.0 13.30 2,553.8 Page 4/4 Report Printed: 1/19/2011 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD3-121 Rig:I Doyon 19 Date: I 3/2112010 I Volume Input I Pump Rate: Drilling Supervisor: I Fred Herbert! Granville Rizek 'Pump used: Cement Unit v Barrels NIP '':i:':::: Bbls/Strk '':;':"P'.g) Bbl/min ■ Type of Test: Annulus Leak Off Test for Disposal Adequacy ■ Pumping down annulus. Ilr - - j]H Casing Test Pressure Integrity Test Hole Size: 8-3/4" w Casing Shoe Depth Hole Depth Pumping Shut Pumping Shut RKB 36.OIFt 2723.0IFt-MDI 2465.OIFt 4298.OIFt I 3698.0IFt-TVD Bbls psi Min psi Bbls psi Min psi Casing Size and Description: 7 7-5/8" 29.7#/Ft L-80 BTC-MOD V 0 ;;;;::;;;;;;;; 0 0 0.00 607 Changes for Annular Adequacy Test Pressure IntegrityTest ;;;;;;;;;;;;;::;i;i:i:1:::::: 1 ;:::H;;;;;;; 0.5 90 0.25 565 Enter outer casing shoe test results in comments Mud Weight: 10.0 ppg 2 ..::::::::::; 1 180 0.50 561 Casing description references outer casing string. Inner casing OD: 7.0 In :i::::::::;:;,:;:;:::::::::;: 3 :::H:;::: 1_5 280 ----- flp5 Hole Size is that drilled below outer casing. ';:ii!::H:;:;ILI:;:;:; 4 ;:;:::::::::;. 2 350 1.50 550 Use estimated TOC for Hole Depth. '.!ii:i:i:;:::;:;:;:;:;:;:; 5 ;:;:i:H:;:;: 2.5 440 2.00 550 Enter inner casing OD at right. Desired PIT EMW::;::::i:i:;.:::::::: ppg ,;, 6 3 530 2.50 545 Estimates for Test: - 1282 psi - 0.2 bbls ;:;::::::::::::: :::.::::: :.:.:: 7 :::::::::::::: 3.5 620 3.00 545 ...„_.,_ V v :,:::;;;;;;;;;;;;; 8 ;;;H;H: 4 680 3.50 540 EMW = Leak-off Pressure + Mud Weight = 633 + 10 PIT 15 Second ;i:i:i:H:' .:;;;;;;;;;;:; 9 ;;;:;:;;;;;;;; 4.5 735 4.00 540 0.052 x TVD 0.052 x 2465 Shut-in Pressure, psi ;:::::::::::;:, ,:,.:.'.:::.H. 10 ::::;:;:;:;:; 4.7 754 4.50 540 EMW at 2723 Ft-MD (2465 Ft-TVD) = 14.9 565 :H;;:;;;;;;;;;;;;;;;;;;; 15 . .. 650 5.00 540 1000 - - I ;;;; ;;;;;;;;;;;;; 20 ;;;;;;;;;;;H 5.5 635 5.50 535 25 '1i;:;i:LL 6 650 6.00 535 . ,11;]H:;:::::':;::::::::;:;:;, 30 . 635 6.50 535 7 640 7.00 535 7.5 640 7.50 535 8 620 8.00 535 8.50 530 eG i ;:;:i:H 9.00 530 ,, .,...,. Ci 500 :: 9.50 530 o 10.00 530 W 1141 Ill.... 0 . o ,,,, , . , . . . ,;;;;;;;;;;;;„;;;;;;;;;;;; 0 1 2 3 4 5 6 7 8 9 0 5 10 15 20 25 30 '•• ,','''' ," ' ''AL':' Barrels Shut time, Minutes Volume Volume Volume Volume imitm'CASING TEST -El-LEAK-OFF TEST 0 PIT Point Pumped Bled Back Pumped Bled Back 0.0 Bbls ::g: _ 8.0 Bbls :;;;i; Comments: Flushed Annulus with 300 bbls H20 and freeze protected it with 50 bbls diesel, I z I itgeudvny i est. usp-c t-lu.xls Summary zz i- :a a • • • • CD3 -122 Surface Casing Well: CD3 x.625. 40 /` . L- 0 , TC -. cas o 20 I - . Date 11 i5F��10 ConocoPhillips Rig: Doyon 1 Alaska, Inc. Depth Jt Number Joints Well Equipment Description and Comments Length Tops Page 1 Doyon 19 RKB to landing Ring 36.10 '!,.in� " 41 P � FMC Gen V 9-5/8" Fluted Hanger (15 -114" OD) (pxp pup 2.43') 2.47 36.10 Jts 3 to 69 67 Jts 9 - 5/8" 40 ppf L - BTC - casing 2565.24 38.57 Halliburton 9 -5/8" "Sure Seal II" Float collar (10.67" OD) 1.24 2603.81 Jts 1 to 2 2 Jts 9 - 5/8" 40 ppf L - BTC - casing 77.80 2605.05 Rays Oil Tools 9 - 5/8" "Silver Bullet" Float Shoe (10.67" OD) 2.20 2682.85 2685.05 2685.05 2685.05 12 -1/4" TD @ 2695' MD / 2492.6' TVD 2685.05 9 -5/8" Casing Shoe rx7 2685.05' MD / 2484.78' TVD 2685.05 2685.05 2685.05 75 Joints in Pipe Shed - Run 69 / Last 6 jts. out 2685.05 2685.05 One bowspring on stop 10' above shoe and on collar of jt #1. 2685.05 One bowspring on stop 10' below collar of jt #2. 2685.05 One Bowspring Centralizer per Joint 3 -13, then Every Other Joint 15 -67 2685.05 Total 41 Bowsprings - Two Stop Collars 2685.05 2685.05 26$5.05 2685.05 2685.05 2685.05 2685.05 2685.05 2685.05 2685.05 2685.05 2685.05 2685.05 2685.05 2685.05 2685.05 2685.05 Remarks: Average MU torque = 9500 ft lbs Up Wt 175 K Drifted pipe w/ plastic rabbit 8.76" OD Dn Wt 145 K Used Run N Seal dope. Block Wt 74 K Supervisors: David Burley / Granville Rizek • 6 1 ►� Cement Detail Report ��d li�lll lu �lil i� „ .-444401 , CD3 -122 ConocoPhillips String: Surface Casing Cement Job: DRILLING ORIGINAL, 1/10/2010 13:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 1/15/2010 07:45 1/15/2010 10:15 CD3 - 122 Comment Pre job safety meeting on cementing 9 -5/8" casing. While continuing to circulate. Final mud properties 9.9 ppg, vis 60 to 70. Cemented 9 5/8" casing as follows: Rig pumped 80 bbls of 9.9 ppg mud with nut plug marker followed with 35 bbls of Biozan as pre flush w/ nut plug marker. Line up to Dowell and pumped 3 bbls of FW, tested lines to 3500 psi . Dropped bottom plug. Mixed & pumped 50 bbls of 10.5 ppg MudPUSH II spacer, ave. 6 bpm at 180 psi. Mixed & pumped 360 sxs of 10.7 ppg lead slurry (4.57 cf /sx yield) (ASL) ave. 5.0 bpm at 189 - 152 psi. Observed nut plug marker at shakers w/ 278 bbls lead slurry pumped (pumped down surge can, 293 bbls total) Switched to tail slurry and pumped 240 sxs of 15.8 ppg tail cmt (1.17 cf /sx) 50 bbls (Class G w/ additives) ave.4.5 bpm at 110 psi. Dropped top plug displaced w/ 20 bbls fresh water f/ Dowell, Switched to rig pumps & displaced cement w/ 177 bbls of 9.9 ppg mud ave. 7.0 bpm, ICP 320, FCP 650 psi, slowed pump to 4 bpm at 490 psi (for the last 7.5 bbls of displacement) Bumped plug to 1050 psi. Checked floats OK, CIP @ 1015 hrs. Had full returns throughout job w/ 58 bbls of 10.7 ppg cement returns to surface. Reciprocated pipe until last 47 bbls of displacement. cement Stages. Stage # 1 ., Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? Surface Casing Cement Primary 36.0 2,685.0 Yes 58.0 Yes Yes Q (start) (bbl /min) Q (end) (bbl /min) Q (avg) (bbl /min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 5 4 5 490.0 1,050.0 Yes 25.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) 8 3/4 Comment Cemented 9 5/8" casing as follows: Rig pumped 80 bbls of 9.9 ppg mud with nut plug marker followed with 35 bbls of Biozan as pre flush w/ nut plug marker. Line up to Dowell and pumped 3 bbls of FW, tested lines to 3500 psi . Dropped bottom plug. Mixed & pumped 50 bbls of 10.5 ppg MudPUSH II spacer, ave. 6 bpm at 180 psi. Mixed & pumped 360 sxs of 10.7 ppg lead slurry (4.57 cf /sx yield) (ASL) ave. 5.0 bpm at 189 - 152 psi. Observed nut plug marker at shakers w/ 278 bbls lead slurry pumped (pumped down surge can, 293 bbls total) Switched to tail slurry and pumped 240 sxs of 15.8 ppg tail cmt (1.17 cf /sx) 50 bbls (Class G w/ additives) ave.4.5 bpm at 110 psi. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Viscosified Water 35.0 Yield (ft' /sack) Mix 1120 Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 8.40 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) MudPush II 50.0 Yield (ft' /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb /gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 10.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) ArcticSet Lite 36.1 360 293.0 Yield (ft' /sack) Mix 1120 Ratio (gal /sa... Free Water ( %) Density (lb /gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) . 4.57 21.23 10.70 Additives Additive Type Concentration Conc Unit label S001 Accelerator 1.5 %BWOC Additive Type Concentration Conc Unit label D046 antifoam 0.6 %BWOC Additive Type Concentration Conc Unit label D079 extender 1.5 %BWOC Additive Type Concentration Conc Unit label D124 extender 50.0 %BWOC Additive Type Concentration Conc Unit label D044 Freeze suppressant 9.0 %BWOW Additive Type Concentration Conc Unit label D053 Thixotropic 30.0 %BWOC Page 1/2 Report Printed: 1/19/2011 • 1' I"'' Cement Detail Report R F irf � CD3 -122 C coPhillips { {° i .r. String: Surface Casing Cement Job: DRILLING ORIGINAL, 1/10/2010 13:00 Cement Flu & Add Fluid- ' ° m Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bb Alpine Surf Tail 2,185.0 2,685.0 140 50.0 Yield (ft' /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb /gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.17 5.10 15.80 Additives Additive Type Concentration Conc Unit label S001 Accelerator 1.0 %BWOC Additive Type Concentration Conc Unit label D046 Antifoam 0.2 %BWOC Additive Type Concentration Conc Unit label D065 Dispersant 0.3 %BWOC Page 2/2 Report Printed: 1/19/2011 il h, • 1110 Security Level: AK Development Oh Mang. Daily Drilling Report CD3 -122 Ca�tc�ctsPtritlips Report Number: 6 Rig: DOYON 19 Report Date: 1/15/2010 AFEType Netwo rkllD # 10271110 11,115,000.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3 - 122 Development FIORD NECHELIK 3.02 6.0 0.00 2,695.0 2,695.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 9,668.51 52,169.12 469,952.51 1,780,090.12 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 1/10/2010 1/12/2010 28.90 27.30 1.60 2/6/2010 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) SURFACE, 2,685.1ftKB Ops and Depth @ Morning Report 24hr Forecast MU BHA #2, depth approx 733'. Pick up/ Make up/ Stand back 5" drill pipe, MU BHA #2, single in w/ 5" f/ pipe shed, test csg to 3500 psi, drill shoe track and 20' new, perform FIT to 18 ppg, drill ahead 8 -3/4" intermediate Last 24hr Summary Continue to run 9 - 5/8" 40 ppf L - 80 BTC - casing to 1620' circulate bottom's up, continue to run casing to land on hanger w/ shoe @ 2685'. PJSM, rig down casing equipment, rig up Dowell cement head and lines, circulate and condition mud and hole f/ cement, Dowell cement 9 -5/8" casing, rig displace w/ 9.9 ppg mud, bump plug w/ 58 bbls of good 10.7 ppg cement to surface. Rig down cementing and casing running tools.Lay down landing joint. PJSM, nipple down, nipple up wellhead, test metal to metal seal to 1000 psi f/ 10 minutes, PJSM, nipple up BOPE, rig up to test, test BOPE w/ 5" test joint. Witness of test waived by AOGCC inspector Jeff Jones. Pull test joint and test plug, install FMC wear bushing, rig up drilling bales and 5" drill pipe elevators, PJSM, pick up, make up/ stand back 5" drill pipe in the derrick. General Remarks Weather Head Count No Accidents / No Spills -31°, WC -53 ° , Wind SW © 17 Mph, 4 mile 49.0 vis Supervisor = Title Dave Burley, Rig Supervisor Rig Supervisor Granville Rizek, Rig Supervisor Rig Supervisor Dave Egedahl, Rig Engineer Rig Engineer Time Log- - AStart-E,A Afnd Our - Time Depth start Dept mid - ' Tm e `_Time (hrs)' ___ Phase Op Code Activity Code P-T-X X - Trbr Code_ TrbI Class. (ftKB) ‘ Operation 00:00 02:45 2.75 SURFAC CASING RNCS P 121.0 1,620.0 Baker lock pin of joint #4, continue to run 9 -5/8" 40 ppf L -80 BTC -m casing to joint # 42 (1620'). Note: Ran centralizers one per joint up to jt # 13, then every other joint. 02:45 03:15 0.50 SURFAC CASING CIRC P 1,620.0 1,620.0 Circulate w/ Frank's fillup tool w/ casing below the base of the permafrost (Permafrost @ 1526'). Stage pumps up f/ 3 bpm to 6 bpm w/ 330 psi. PU wt 126k, SO wt 123k. 03:15 04:45 1.50 SURFAC CASING RNCS P 1,620.0 2,685.0 Continue to run 9 -5/8" 40 ppf L -80 BTC -m casing to jt # 69, then makeup FMC fluted hanger, run in and land on hanger w/ shoe at 2685'. PU wt 175k, SO wt 145k. Continue to install bow spring centralizers over collars to joint # 67. 04:45 05:00 0.25 SURFAC CASING SFTY P 2,685.0 2,685.0 Pre job safety meeting on rigging down casing tools and rigging up to cement. 05:00 05:15 0.25 SURFAC CASING RURD P 2,685.0 2,685.0 Rig down casing running equip (Frank's fillup tool) 05:15 05:30 0.25 SURFAC CEMENT RURD P 2,685.0 2,685.0 Rig up Dowell cementing head, make up 2" cementing line. 05:30 07:15 1.75 SURFAC CEMENT CIRC P 2,685.0 2,685.0 Circulate and condition mud and hole f/ cement. Reciprocate and stage rate up f/ 3 bpm to 7 bpm. FCP= 310 psi PUW 163K SOW 149K 640 bbls pumped Latest BOP Test Data Date Comment 1/15/2010 Witness of test waived by AOGCC inspector Jeff Jones. Page 1/4 Report Printed: 1/19/2011 • Security Level: AK Development AO Daily Drilling Report vok 0,11 � - CD3 -122 Conc)cQPltitlips Report Number: 6 Rig: DOYON 19 Report Date: 1/15/2010 Time Log _ Start" " End Dur Time Depth Start De th End P Time Time _- _ (hrs) Phase _ Op Code Activity Code P -T -X Trbl Code Trbl Class. _ (ttKO)',,, (ftKaI= Operation 07:15 07:45 0.50 SURFAC CEMENT SFTY P 2,685.0 2,685.0 Pre job safety meeting on cementing 9 -5/8" casing. While continuing to circulate. Final mud properties 9.9 ppg, vis 60 to 70. 07:45 09:45 2.00 SURFAC CEMENT PUCM P 2,685.0 2,685.0 Cemented 9 5/8" casing as follows: Rig pumped 80 bbls of 9.9 ppg mud with nut plug marker followed with 35 bbls of Biozan as pre flush w/ nut plug marker. Line up to Dowell and pumped 3 bbls of FW, tested lines to 3500 psi . Dropped bottom plug. Mixed & pumped 50 bbls of 10.5 ppg MudPUSH II spacer, ave. 6 bpm at 180 psi. Mixed & pumped 360 sxs of 10.7 ppg lead slurry (4.57 cf /sx yield) (ASL) ave. 5.0 bpm at 189 - 152 psi. Observed nut plug marker at shakers w/ 278 bbls lead slurry pumped (pumped down surge can, 293 bbls total) Switched to tail slurry and pumped 240 sxs of 15.8 ppg tail cmt (1.17 cf /sx) 50 bbls (Class G w/ additives) ave.4.5 bpm at 110 psi. 09:45 10:15 0.50 SURFAC CEMENT DISP P 2,685.0 2,685.0 Dropped top plug displaced w/ 20 bbls fresh water f/ Dowell, Switched to rig pumps & displaced cement w/ 177 bbls of 9.9 ppg mud ave. 7.0 bpm, ICP 320, FCP 650 psi, slowed pump to 4 bpm at 490 psi (for the last 7.5 bbls of displacement) Bumped plug to 1050 psi. Checked floats OK, CIP @ 1015 hrs. Had full returns throughout job w/ 58 bbls of 10.7 ppg cement returns to surface. Reciprocated pipe until last 47 bbls of displacement. 10:15 10:30 0.25 SURFAC CEMENT SFTY P 2,685.0 2,685.0 Pre job safety meeting on rigging down cement equipment. 10:30 11:15 0.75 SURFAC CEMENT RURD P 2,685.0 2,685.0 Rig down cementing equipment. 11:15 11:30 0.25 SURFAC DRILL PULD P 2,685.0 0.0 Back out FMC landing joint w/ 10.75 4SAM2 -Left hand threads. Lay down the landing joint. 11:30 11:45 0.25 SURFAC DRILL PULD P 0.0 0.0 Lay down the mouse hole. Clean and clear rig floor of tools. 11:45 12:00 0.25 SURFAC WHDBOP SFTY P 0.0 0.0 Pre job safety meeting on nippling down surface riser. 12:00 13:15 1.25 SURFAC WHDBOP NUND P 0.0 0.0 Nipple down surface riser. 13:15 14:00 0.75 SURFAC WHDBOP NUND P 0.0 0.0 Remove FMC starting head. Install FMC wellhead. 14:00 14:15 0.25 SURFAC WHDBOP DHEQ P 0.0 0.0 Install FMC wellhead. Test FMC metal to metal seal to 1000 psi, hold for 10 minutes. Good test. 14:15 14:30 0.25 SURFAC WHDBOP SFTY P 0.0 0.0 Pre job safety meeting on nippling up BOP equipment. 14:30 16:45 2.25 SURFAC WHDBOP NUND P 0.0 0.0 Nipple up 13 -5/8" 5m BOP stack. 16:45 17:00 0.25 SURFAC WHDBOP SFTY P 0.0 0.0 Pre job safety meeting on testing BOPE. Page 2/4 Report Printed: 1/19/2011 • Security Level: AK Development Daily Drilling Report " CD3 -122 p6, Report Number: 6 ConocoPhitlu`ps Rig: DOYON 19 Report Date: 1/15/2010 Time Log - "' Start End= - Dur Time Depth Start Depth End = Time Time (hrs) Phase Op Code r -- Activity Code =_ €'P T -X Trbl Code Trbl Class:' (ftKB) (ftKB)- Operation 17:00 18:00 1.00 SURFAC WHDBOP BOPE P 0.0 0.0 Rig up to test BOPE. Set FMC lower test plug. Fill stack and choke manifold with water. 18:00 21:30 3.50 SURFAC WHDBOP BOPE P 0.0 0.0 Test BOPE. Witness of test waived by AOGCC inspector Jeff Jones. All tests were charted. Tests held f/ 5 minutes each low and high. Tested annular to 250 psi and 2500 psi. All valves in the • choke manifold, kill line and choke line valves, 4" demco valve on mud line, floor safety and IBOP valve, top drive automatic and manual IBOP valves, upper pipe rams (3 -1/2" x 6" variable bore), blind rams, lower pipe rams (3 -1/2" x 6" variables) were tested to 250 psi and 3500 psi. Pipe rams and annular tested with 5" test joint. Accumulator test performed: initial pressure 3000 psi, 1550 psi after operating. Recovery time test of 33 seconds for 200 psi build up and 2 minutes 55 seconds for full charge. Nitrogen bottles average 1650 psi. 21:30 21:45 0.25 SURFAC WHDBOP OTHR P 0.0 0.0 Pull test joint and test plug, blow down kill and choke lines. 21:45 22:00 0.25 SURFAC WHDBOP OTHR P 0.0 0.0 Install FMC long wear bushing. 22:00 22:15 0.25 SURFAC DRILL RURD P 0.0 0.0 Pickup short drilling bales, attach to the top drive. Install 5" drill pipe elevators. 22:15 22:30 0.25 SURFAC DRILL SFTY P 0.0 0.0 Pre job safety meeting on picking up and standing back 5" drilllpipe. 22:30 00:00 1.50 SURFAC DRILL PULD P 0.0 0.0 Pickup/ makeup/ standback in the derrick 5" drill pipe. 8 stands picked up. Mud Check =Data VP' Cale Get (10s) = Get110m) Gel (30m) "HTHP Or Density Temp - Soliids, Corr: Type Depth (ftKB) Dens (lb/gal) Vis (skit) PV Catc (cp) ,'•'(Ibf/100fe) (Ibf /100ft _' (lbff100ffs)4 ° (Ibfiloctt") AMT (Ib /bbl) (mu30min) pH (F) ( %) Spud Mud 2,685.0 9.60 61 8.0 15.0 4.0 5.0 5.000 30.0 9.0 9.0 Injectiotr Fluid = - Fluid Source From Lease (bbl) . Destination -_ Vendor Manifest Number - Diesel 10.0 CD3 -305 Water 40.0 CD3 -305 Water Based Mud CD3 -122 1335.0 CD3 -305 Water Based Mud CD3 -122 311.0 CD3 -305 cement contaminated mud Water Based Mud CD3 -122 58.0 CD3 -305 cement contaminated mud Weitbores' Wellbore Name Wellbore API /UWI CD3 -122 501032060900 ;Section iggEize (in) ' - , •:Act, Top (ftKB) Act Btm (lKE) >; Start Date End Date COND1 18 37.0 114.0 SURFAC 12 1/4 114.0 2,695.0 1/12/2010 1/14/2010 INTRM1 8 3/4 2,695.0 9,140.0 1/16/2010 1/20/2010 PROD1 6 1/8 9,140.0 15,409.0 1/25/2010 1/31/2010 Page 3/4 Report Printed: 1/19/2011 • Security Level: AK Development , i Daily Drilling Report ui ,li4g4i F V[il1pi,lj CD3 -122 ConocoPhltlips Report Number: 6 Rig: DOYON 19 Report Date: 1/15/2010 Casing_ Strings String OD g Casing Description Run Date (in) (IbStnn s/f Wt t) String Grade Set Depth (ftKS) Comment SURFACE 1/15/2010 9 5/8 40.00 L -80 2,685.1 Make up Ray Oil tool 9 -5/8" eccentric shoe joint w/ centralizer 10' above the shoe over a stop ring and over collar of jt #1, thread lock joint w/ centralizer over stop 10' below box, Float collar joint. All connections w/ baker lock. Attempt to fill pipe and check floats using Frank's fillup tool. Break fill up tool from top drive. Blow down the top drive. Use steam to thaw out Frank's fillup tool. Make up tool to the top drive. Fill three joints of casing, circulate surface to surface. Float equipment works fine. Baker lock pin of joint #4, continue to run 9 -5/8" 40 ppf L -80 BTC -m casing to joint # 42 (1620'). Circulate w/ Frank's fillup tool w/ casing below the base of the permafrost (Permafrost @ 1526'). Stage pumps up f/ 3 bpm to 6 bpm w/ 330 psi. PU wt 126k, SO wt 123k. Continue to run 9 -5/8" 40 ppf L -80 BTC -m casing to jt # 69, then makeup FMC fluted hanger, run in and land on hanger w/ shoe at 2685'. PU wt 175k, SO wt 145k. Pre job safety meeting on rigging down casing tools and rigging up to cement. Rig down casing running equip (Frank's fillup tool/ slips). Rig up Dowell cementing head, Make up 2" cementing line. Circulate and condition mud and hole f/ cement, final mud properties: MW 9.9 ppg, vis 60 to 70. Reciprocate and stage rate up f/ 3 bpm to 7 bpm. Circulated 685 bbls prior to cementing. Note: Centralizers: 10' above shoe over a stop, one on collar of jt #1, 10' below float collar on jt #2, then one per joint up to jt # 13, then every other joint to jt # 67 for a total of 41 bow centralizers and 2 stop rings. Cement Surface Casing Cement - Started @ 1/15/2010 Type Wellbore Cemented String Cement Evaluation Results casing CD3 - 122 SURFACE, 2,685.1ftKB Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl /... P (final) (psi) 1 Surface Casing Cement 36.0 2,685.0 4 490.0 fluid -- - Class Amount (sacks) V (bbl) Density(tbigal) - Yield',(fWsack)_ Top (ftKB) - =- EstBtm(itt t;' = - -- _ Viscosified Water 35.0 8.40 MudPush II 50.0 10.50 ArcticSet Lite 360 293.0 10.70 4.57 36.1 Alpine Surf Tail 140 50.0 15.80 1.17 2,185.0 2,685.0 Page 4/4 Report Printed: 1/19/2011 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. • Well Name: I CD3-122 I Rig:I Doyort 19 Date: I 1/16/2010 1 Volume Input Volume/Stroke 1 Pump Rate: Drilling Supervisor: I D. Burley/ G. Rizek ]Pump used: #2 Mud Pump liv Strokes 010 Bbls/Strk :'':7'AKI Strk/min ■ Type of Test: Casing Shoe Test LOT/FIT I/ Pumping down annulus and DP. • - Casing Test Pressure Integrity Test Hole Size: 8-3/4" • Casing Shoe Depth Hole Depth Pumping Shut-in Pumping Shut-in RKB-CHF: 33.6IFt 2685.0 I Ft-MDI 2484.0IFt-TVD 2 I 2508.0IFt-TVD Strks psi Min psi Strks psi Min psi Casino Size and Description: 9-5/8" 40#/Ft L-80 BTC v 0 70 0 3630 0 10 0.00 1060 Casing Test Pressure IntearitvTest 2 180 1 3630 1 40 0.25 870 Mud Weight: 9.6 ppg Mud Weight: 9.6 ppg 4 320 2 3630 2 90 0.50 750 Mud 10 min Gel: 40,0 Lb/100 Ft2 Mud 10 min Gel: 40.0 Lb/100 Ft2 6 540 3 3630 3 180 1.00 70: Test Pressure: 3500.0 psi Rotating Weight: ####### Lbs 8 760 4 3620 4 280 1.50 680 Rotating Weight: Ififtlifilt Lbs Blocks/Top Drive Weight: 75000.0 Lbs 10 910 5 3620 5 400 2.00 660 Blocks/Top Drive•Weight: 75000.0 Lbs Desired PIT EMW: 18.0 ppg 12 1070 6 3620 6 500 2.50 660 Estimates for Test: 2.4 bbls Estimates for Test: ' 1085 psi 0.7 bbls 14 1280 7 3620 7 590 3.00 650 v v 16 1470 8 3620 8 670 3.50 640 EMW = Leak-off Pressure + Mud Weight = 870 + 9 6 PIT 15 Second 18 1660 9 3610 9 740 4.00 640 . 0.052 x TVD 0.052 x 2484 Shut-in Pressure, psi 20 1860 10 3610 10 820 4.50 630 EMW at 2685 Ft-MD (2484 Ft-TVD) = 16.3 ppg 870 22 2090 15 3610 11 870 5.00 630 4000 - E Lost 30 psi during test, held 24 2330 20 3600 12 900 5.50 620 L 99.2% of test pressure. 26 2590 25 3600 13 940 6.00 620 3500 ImIIIIIIIIIIIIIIIIIINIIINNIN■■ 28 2830 30 3600 14 990 6.50 610 ■■■■■•■ 30 3100 15 1030 7.00 600 ■■■■■•■••1 ' ■11■■•IIMMINIIIMIIIIMIIIIIIIIIIIIII 32 3370 16 1070 7.50 600 3000 mismiiimini■Nimmi■s■ ■■■■■■ MIMI MIIIIIMINIIIIIMINEMI1111111111 MIMI. 34 3630 17 1100 8.00 600 ■■■■■■ ,, : : : : : : ,, , - . „ . •■■•••■■=1......... ::::::::::::::: ::.::: ; ;::; ;:J;J:0i':i::i0 8 50 600 Ill 2500 ■immii■I■11■■ , " • „ ,:.,..:• ,,, •;,::: : :, • 9.00 60 ■■■■■•■ :;:;:;,,,,::::: :;:::::::::::: m ■■■■■■• .:::::::::::::: :::::::::::::: „ (4 2000 IIIIIIINimimmiiiiiimm•IININININIII :::::::::::;::: :::::::::::::: i:;::;::::::1 :i::: :: 9.50 59" u) =111011•111=11=1•111111111•111111■1■111• : : : ; . ; ; : . : ; ; ; ; : : : ■■■■■■ : :::;:, ; i I:, H::: ::;:;:;::; 10.00 590 tu ..1=••■•■••■■=.1. " : ; • W .•■■■•■•■•■ :::::;:;::::::: ::;; :; ; 1.......................m.. ::: ------ ;i0::::::::: :: : : :: O. 1500 , ,:::,:•: :•: ■■■■■■ ::::::::::::::, ::::: ::: ::: MIMI IIIIIIIIIIIIIIIIIIIMI MN= MEM MUM ■■■■■ !!!!!!! ! ! ! 1000 •• • ■•■•■•■••■ :•:•::::::::::: :::::::::::::: ■■■■■ 14,714,7!7.7.!.7t7!•,:,:::::::::, 1111 1,1,1,-. I, --- 500 ■■wilmmlommimomm■ Iiiiiiiimmi■■•■■■■ ::::::::::::::: :::::::::::::, IIIIIIIIIIIIII•meiimi■■■ , ■■ : :, ----- :,,,, , ■■■■■■=s • " " " 0 0 i Barrels Shut-In time, Minutes Volume Volume Volume Volume Back Pumped imitr•CASING TEST -0- LEAK-OFF TEST 0 PIT Point Pumped Bled Bled Back 3.4 Bbls :iii;ABbls 1.7 Bbls ini;;;;HBbls Comments: sur ubg rIT Illicti.xls Summary 1 • CD3-122 Intermediate Well: CD3-122 7" 26 pof L-80 BTC-m Casing Date: 112212010 c01;i1 Cono ips Rig: Doyon Rig 19 Alaska, Inc, Depth Jt Number Joints Well Equipment Description and Comments • Length Tops 111 Page 1 . . • • • • • 1 1 . .1 ..• I: • • • • • • • • • • • • • • • • - :•:•:•:•:•:•:•:•:•:•:•:•:•:•::•:•:...: ....................... .•.-.•.•.......•.•.•.•.•.•.•.•.• •:•:•:•:•:•:•:•:•:•:•:•:•:•:• •:•:•:•:•:•:•:•:•: RKB to Casing Flange (Load shoulder 34.53') (LLDS 33.61') 33.61 FMC 7" Mandrel hanger 1.29 33.61 7", 26#, L-80, BTC-m Casing Pup jt Pin x Pin 1.27 34.90 Jts 98 to 224 127 Jts 7 ", 26#, L BTC Casing 5156.50 36.17 HES 7" Stage Collar 2.43 5192.67 Jts 4 to 97 94 Jts 7", 26#, L BTC Casing 3802.83 5195.10 HES Shut Baffle Collar 1.01 8997.93 Jts 3 to 3 1 Jts 7", 26#, L BTC Casing 43.44 8998.94 HES Sure Seal H Float Collar w/ By Baffle Adapter 1.00 9042.38 Jts 1 to 2 2 Jts 7", 26#, L BTC Casing 84.52 9043.38 Ray Oil Tools " Silver Bullet" Float Shoe 2.12 9127.90 9130.02 8-3/4" Hole TD @ 9140' MD / 6958.9 ' TVD, Hole angle 86.28 deg 9130.02 7" Shoe @ 9130.02' MD / 6958.3' TVD/ Hole angle 86.28 deg 9130.02 9130.02 Total of 91 Straight Blade centralizers (7" x 8-3/8") - 5 Stop Collars 9130.02 1 Staight Blade centralizer w/ stop 10' above shoe -Jt. #1 9130.02 1 Straight Blade centralizer w/ stop ring 10' below Float Collar jt. #2 9130.02 1 Straight Blade centralizer w/ stop collar 10' below Baffle Adaptor Jt. #3 9130.02 1 Straight Blade centralizer per jt on jts # 4430 floating 9130.02 9130.02 1 Straight Blade centralizer w/ stop ring 10' below Stage Collar jt. #97 9130.02 1 Staight Blade centralizer w/ stop 10' Stage Collar -Jt. #98 9130.02 1 Straight Blade centralizer per joint floating # 99 thru #123 9130.02 9130.02 1 on 3 jts Across Shoe jts # 159, #160 & 161 9130.02 then 1 every other jt # 163 to # 223 9130.02 9130.02 9130.02 9130.02 9130.02 Planned: 230 jts in pipe shed / 224 jts to run. 9130.02 6 joints left in the shed 9130.02 9'1 9130.02 Remarks: Drifted w/ 6.17 plastic rabbit Up Wt 285 K Average MU torque= 8000 Ft Ibs Dn Wt 180 K Block Wt 74 K Supervisors: Fred Herbert / Granville Rizek 1 • 4 1 °``j'I Cement Detail Report 9 Vlf i.� IlIhI � „ 1, V CD3 -122 wiTP ConecoPhil lips String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 1/10/2010 13:00 `Dement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 1/22/2010 21:50 1/23/2010 02:15 CD3 -122 Comment RU cmt head & cmt hose. Circ, stage up f/ 3 bpm w/ 400 psi to 5 bpm w/ 370 psi. PJSM w/ circ. Circ a total of 693 bbls. Final mud properties : PV/YP= 9/16. MW 9.8 ppg. Dowell pump 2 bbl of CW 100, test to 3600 psi, pump another 38 bbls © 4 bpm w/ 300 psi, mix and pump 35 bbls 11.5 ppg mudPushll @ 5.1 bpm w/ 395 initial -190 psi final. Shut down, load bottom plug. Pump another 5 bbls of mudPushll. Shut down and load shut off plug. Dowell mix and pump 56.7 bbls Alpine tail cement (15.8 ppg) ( 273 sx)(1.16 cuft/sx yield) (5.076 gal /sx water) (5.34 hrs thickening time). Pump at 5.2 bpm avg w/ 400 psi initial -140 psi final pressure. Drop Halliburton shut off plug, chase w/ 20 bbl of water, pump 4.5 to 5.3 bpm w/ 44 psi to -17 psi. Rig displ cement w/ 9.8 ppg mud. Pump 7 bpm. Slowed to 3 bpm when plugs went through Baffle adapter. Recip f/ 9130' to 9120' until 15.8 bbls before bumping plug. PU wt 280 to 285k, SO wt 180k. Bumped plug @ 2341 hrs 1 -22 -2010. Landed on FMC hanger @ 2336 hrs 1 -22 -2010. Held press 4 min, bled off press - floats held. Load Halliburton closing plug f/ 2nd stage. Press up to 3425 psi to open Halliburton type HES cementer. Estab circ -stage tool at 5192.67'. Pump 6 bpm w/ 270 psi - 250 psi final. PJSM. Circ a total of 332 bbls. No CW100 or mudpush at the shakers. Dowell pump 2 bbl of CW 100, test to 3600 psi, pump another 28.12 bbls © 4 bpm w/ 225 psi, mix and pump 31.6 bbls 11.5 ppg mudPushll @ 5.2 bpm w/ 262 psi initial -220 psi final. Shut down. Dowell mix & pump 39.24 bbls (187sx) Alpine surf tail cmt (15.8 ppg)(1.17 cuft/sx yield) (5.105 gal /sx water). Pump @ 5.2 bpm avg w/ 260 psi initial -150 psi final. Drop Halliburton closing plug, then chase w/ 20 bbl of water, pump 5.2 bpm w/ 70 psi. Rig displ cmt w/ 9.8 ppg mud. Pump 7 bpm w/ 140 psi initial until mudpush @ stage tool, then slow to 5 bpm w/ 70 psi, w/ cmt at tool, pump 6 bpm w/ 90 psi initial- 270 psi final, pump 2 bpm last 15 bbls w 260 psi prior shut tool w/ 1425 psi @ 0215 hrs 1/23/2010 Cement Stages ` ' = I Stage-It 1 Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtm (... Top Plug? Btm Plug? Intermediate Casing Cement 7" intermediate 7,786.0 9,140.0 Yes 0.0 Yes Yes Cement Q (start) (bbl /min) Q (end) (bbl /min) Q (avg) (bbl /min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 4 3 6 410.0 930.0 Yes 10.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment RU cmt head & cmt hose. Circ, stage up f/ 3 bpm w/ 400 psi to 5 bpm w/ 370 psi. PJSM w/ circ. Circ a total of 693 bbls. Final mud properties : PV/YP= 9/16. MW 9.8 ppg. Dowell pump 2 bbl of CW 100, test to 3600 psi, pump another 38 bbls © 4 bpm w/ 300 psi, mix and pump 35 bbls 11.5 ppg mudPushll @ 5.1 bpm w/ 395 initial -190 psi final. Shut down, load bottom plug. Pump another 5 bbls of mudPushll. Shut down and load shut off plug. Dowell mix and pump 56.7 bbls Alpine tail cement (15.8 ppg) ( 273 sx)(1.16 cuft/sx yield) (5.076 gal /sx water) (5.34 hrs thickening time). Pump at 5.2 bpm avg w/ 400 psi initial -140 psi final pressure. Drop Halliburton shut off plug, chase w/ 20 bbl of water, pump 4.5 to 5.3 bpm w/ 44 psi to -17 psi. Rig displ cement w/ 9.8 ppg mud. Pump 7 bpm. Slowed to 3 bpm when plugs went through Baffle adapter. Recip f/ 9130' to 9120' until 15.8 bbls before bumping plug. PU wt 280 to 285k, SO wt 180k. Bumped plug @ 2341 hrs 1 -22 -2010. Landed on FMC hanger © 2336 hrs 1 -22 -2010. Held press 4 min, bled off press -floats held. Load Halliburton closing plug f/ 2nd stage. Cemen t Fluids & Additives '+ Fluid _ Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) CW100 5,652.0 6,719.0 40.0 Yield (ft /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 8.40 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) MudPush II 6,719.0 7,786.0 40.0 Yield (ft /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 11.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Alpine Intermediate 7,786.0 9,140.0 273 56.7 Tail Yield (ft' /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 5.08 15.80 5.34 Additives Additive Type Concentration Conc Unit label S002 Accelerator 0.8 %BWOC Page 1/2 Report Printed: 1/19/2011 1 • u� s III0 Tilb A 11 , Iu ,{ u � Cement Detail Report A £ _ CD3 -122 ConacoPhillips String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 1/10/2010 13:00 Additives Additive Type Concentration Conc Unit label D046 anifoam 0.2 %BWOC Additive Type Concentration Conc Unit label D065 disperssant 0.3 %BWOC Cement Stages Stage # 2 Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? Intermediate Casing Isolate Quannik 4,167.0 5,193.0 Yes Yes No Cement formation Q (start) (bbl /min) Q (end) (bbl /min) Q (avg) (bbl /min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 4 2 6 270.0 1,425.0 No No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Load Halliburton closing plug f/ 2nd stage after checking floats on first stage. Press up to 3425 psi to open Halliburton type HES cementer. Estab circ -stage tool at 5192.67'. Pump 6 bpm w/ 270 psi - 250 psi final. PJSM. Circ a total of 332 bbls. No CW100 or mudpush at the shakers. Dowell pump 2 bbl of CW 100, test to 3600 psi, pump another 28.12 bbls @ 4 bpm w/ 225 psi, mix and pump 31.6 bbls 11.5 ppg mudPushll @ 5.2 bpm w/ 262 psi initial -220 psi final. Shut down. Dowell mix & pump 39.24 bbls (187sx) Alpine surf tail cmt (15.8 ppg)(1.17 cuft/sx yield) (5.105 gal /sx water). Pump © 5.2 bpm avg w/ 260 psi initial -150 psi final. Drop Halliburton closing plug, then chase w/ 20 bbl of water, pump 5.2 bpm w/ 70 psi. Rig displ cmt w/ 9.8 ppg mud. Pump 7 bpm w/ 140 psi initial until mudpush © stage tool, then slow to 5 bpm w/ 70 psi, w/ cmt at tool, pump 6 bpm w/ 90 psi initial- 270 psi final, pump 2 bpm last 15 bbls w 260 psi prior shut tool w/ 1425 psi @ 0215 hrs 1/23/2010 Cement Fluids &Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) CW100 2,500.0 3,303.7 30.1 Yield (ft /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 8.40 Additives Additive Type Concentration Conc Unit label Fluid - __ - ° Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) MudPush II 3,303.7 4,146.7 31.6 Yield (fP /sack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 11.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Alpine Surface Tail 4,146.7 5,192.7 187 39.2 Yield (ftnsack) Mix H2O Ratio (gal /sa... Free Water ( %) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.17 5.10 15.80 5.34 Additives Additive Type Concentration Conc Unit label S002 accelerator 1.0 %BWOC Additive Type Concentration Conc Unit label D046 anti foam 0.2 %BWOC Additive Type Concentration Conc Unit label D065 dispperssant 0.3 %BWOC Page 2/2 Report Printed: 1/19/2011 • Security Level: AK Development Daily Drilling Report 6.441 CD3 -122 Idoe Report Number: 13 ConocoPhtllips Rig: DOYON 19 Report Date: 1/22/2010 AFE Type ;- _ - Network/ID # Totai AFE +Sup 10271110 11,115,000.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3 -122 Development FIORD NECHELIK 10.02 13.0 0.00 8,625.0 8,625.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 5,375.22 310,814.69 769,563.22 4,064,324.69 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 1/10/2010 1/12/2010 28.90 25.79 3.11 2/5/2010 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) INTERMEDIATE, 9,130.OftKB Ops and Depth @ Morning Report 24hr Forecast Changing top pipe rams to 3 -1/2" x 7 ". Circulate, cement through stage collar, R/D cementing and casing tools, pull wear bushing, install packoff, test packoff, change upper pipe rams, lay down 5" DP, PU 4" DP, test BOPE. Last 24hr Summary Change top pipe rams to 7 ", PJSM, RU, test to 250 psi and 3500 psi, R/D test equip, install FMC thin wear bushing, PJSM, RU, PJSM, Run 7" csg: MU fist 4 jts, fill pipe w/ Frank's fillup tool, circ 20 bbls, check floats- OK. Con't to run 7 ". Avg MU torque 8000 ft lbs. The first 30 joints have Ray Oil Tool 7" x 8 -3/8" Aluminum straight blade centralizers. Con't to run 7" csg f/ 1200' to 2630'. Circ & cond mud @ 2630'. Con't to run 7" f/ 2630' to 5065'. Between jt # 97 and # 98 is the Halliburton Type HES 7" stage collar (Baker locked). Centralizer floating on Jt # 97 & # 98 between a stop, 10' above and below cementer. Circ & cond mud @ 5065'. Con't to run 7" f/ 5065' to 7507'. Centralizers floating on Jt # 159, # 160, # 161, then every other jt f/ # 163. Last centralizer will be on jt # 223. Circ & cond mud @ 7507'. Con't to run 7" f/ 7507' to 9130'. PU wt 300k, SO wt 175k. R/D Frank's FU tool. RU Dowell cement head & cementing hose. Circ a total of 693 bbls, PJSM. Final mud properties : PV/YP= 9/16. MW 9.8 ppg. Dowell pump 2 bbl of CW 100, test lines to 3600 psi, pump another 38 bbls @ 4 bpm w/ 300 psi, mix and pump 35 bbls 11.5 ppg mudPushll, Shut down, load bottom plug. Pump another 5 bbls of mudPushll @ 11.5 ppg. Shut down, load shut off plug. Mix & pump 56.7 bbls 15.8 ppg(273 sx) (1.16 cuft/sx) 5.076 gal /sx) cement © 5.2 bpm avg w/ 400 psi initial and 140 psi final. Drop Halliburton shut off plug, chase w/ 20 bbls water pumping 5.3 bpm w/ 44 psi initial and -17 psi final pressure. Rig displace cement w/ 9.8 ppg mud. Pumping 7 bpm. Slowed down to 3 bpm when plugs went through Baffle adapter. Recip until 15.8 bbls before bumping plug, final rate 3 bpm, landed on FMC hanger. PU wt 280 to 285k, SO wt 180k. Bumped plug @ 2341 hrs 1 -22 -2010. Landed on hanger 2336 hrs 1 -22 -2010. Held pressure 4 minutes, bled off pressure and floats held. Load Halliburton closing plug f/ 2nd stage cement job. Pressure up to open Halliburton type HES cementer. Opened at 3425 psi. General Remarks Weather Head Count No Accidents / No Spills -24 °, Wind E © 14 Mph, 10 mile vis 51.0 Supervisor _ Titles ____ Fred Herbert, Rig Supervisor Rig Supervisor Granville Rizek, Rig Supervisor Rig Supervisor Dave Egedahl, Rig Engineer Rig Engineer Time Log < < INAVEDIPIESE Start End Dur r Time Depth Start Depth End `- Time Time _-- (hrs) Phase Op, Code`, Activity Code P-T-X _ Trbt Code Tut)] Class. (ftkB) _, {fttKB r`?. Oper'aeon'' 00:00 00:30 0.50 INTRM1 WHDBOP NUND P 0.0 0.0 Continue to change upper pipe rams (3 -1/2" x 6 ") to 7 ". Blind rams are closed. 00:30 00:45 0.25 INTRM1 WHDBOP BOPE P 0.0 0.0 Pre job safety meeting on rigging up to test 7" rams. 00:45 01:00 0.25 INTRM1 WHDBOP BOPE P 0.0 0.0 Rig up to test 7" rams. 01:00 01:15 0.25 INTRM1 WHDBOP BOPE P 0.0 0.0 Test 7" upper pipe rams to 250 psi low and 3500 psi high. Hold each test 5 minutes. Chart test. 01:15 01:30 0.25 INTRM1 WHDBOP BOPE P 0.0 0.0 Blow down testing lines. Rig down. 01:30 02:00 0.50 INTRM1 CASING PULD P 0.0 0.0 Install FMC thin wear bushing (10.75" ID). Lay down the 7" test joint. 02:00 02:15 0.25 INTRM1 CASING SFTY P 0.0 0.0 PJSM on rigging up casing running equipment. 02:15 02:45 0.50 INTRM1 CASING RURD P 0.0 0.0 Rig up to run 7" 26 ppf L -80 BTC -m casing. 02:45 03:00 0.25 INTRM1 CASING SFTY P 0.0 0.0 PJSM on running 7" 26 ppf L -80 BTC -m casing. Latest BOP Test Data Date Comment 1/15/2010 Witness of test waived by AOGCC inspector Jeff Jones. Page 1/5 Report Printed: 1/19/2011 • 11111 Security Level: AK Development iit a I��iJpllj'ilii� a u9ViihlVl,l�i�J !PII, a Daily Drilling Report CD3 -122 Ccx,cac+Phittrps Report Number: 13 Rig: DOYON 19 Report Date: 1/22/2010 Time Log Start End Dur Time Depth Start ! Depth End Time Time Mrs) ` _ Phase =(Dp Code Activity Code P - T - X Trbt Code Trbl Class. + «tKB) -_` CrtKB) <- Operation -_ 03:00 04:00 1.00 INTRM1 CASING RNCS P 0.0 172.0 Run 7" casing: Pick up jt #1: Ray Oil tool 7" eccentric shoe joint w/ Ray Oil Tool aluminum centralizer (7" x 8 -3/8 ") floating f/ shoe to 10' above the shoe with stop ring. Thread lock joint #2 w/ centralizer between box and 10' below box with stop ring. Baker lock Halliburton Sure Seal II Float Collar w/ baffle adapter installed. Baker lock pin of Jt #4 with centralizer floating the full joint. Four connections were bakerlocked. 04:00 04:15 0.25 INTRM1 CASING CIRC P 172.0 172.0 Fill pipe w/ Frank's fillup tool, circulate 20 bbls, check floats- OK. 04:15 06:00 1.75 INTRM1 CASING RNCS P 172.0 1,200.0 Continue to run 7" 26 ppf L -80 BTCM casing. Average make up torque 8000 ft Ibs of torque. 30 jts in the hole. The first 30 joints all have Ray Oil Tool 7" x 8 -3/8" Aluminum straight blade centralizers. 06:00 07:30 1.50 INTRM1 CASING RNCS P 1,200.0 2,630.0 Continue to run 7" 26 ppf L -80 BTCM casing from 1200' to 2630' (Jt # 30 to jt # 65). 07:30 08:15 0.75 INTRM1 CASING CIRC P 2,630.0 2,630.0 Circulate and condition mud @ 2630', prior to exiting surface casing shoe. Stage pumps up to 6 bpm w/ 400 psi. PU wt 131k, SO wt 124k. 08:15 11:00 2.75 INTRM1 CASING RNCS P 2,630.0 5,065.0 Continue to run 7" 26 ppf L -80 BTCM casing from 2630' to 5065' (Jt # 65 to jt # 125). PU wt 193k, SO wt 150k. Between joint # 97 and # 98 is the 7" Halliburton Type HES cement stage tool. Ray Oil tool straight blade 7" x 8 -3/8" aluminum centralizer floating on Jt # 97 between a stop ring 10' below the box and the box. A centralizer floating between the pin and 10' above the pin of joint # 98. Then centralizers were installed floating on jt # 99 to # 123. 11:00 12:00 1.00 INTRM1 CASING CIRC P 5,065.0 5,065.0 Circulate and condition mud @ 5065'. Stage pumps up f/ 2.5 bpm w/ 450 psi to 5 bpm w/ 350 psi. PU wt 190k, SO wt 150k. 12:00 15:00 3.00 INTRM1 CASING RNCS P 5,065.0 7,507.0 Continue to run 7" 26 ppf L -80 BTCM casing from 5065' to 7507' (Jt # 125 to jt # 185). PU wt 260k, SO wt 180k. Straight blade centralizers floating on Jt # 159, # 160, # 161, then every other jt f/ # 163. Last centralizer will be on jt # 223. 15:00 16:30 1.50 INTRM1 CASING CIRC P 7,507.0 7,507.0 Circulate and condition mud @ 7507'. Stage pumps up f/ 3.5 bpm w/ 450 psi to 5 bpm w/ 450 psi. PU wt 253k, SO wt 185k. Page 2/5 Report Printed: 1/19/2011 Security Level: AK Development e`' i' Daily Drilling Report tat � ipui��l�u° CD3 -122 Report Number: 13 ConocoPhiilips Rig: DOYON 19 Report Date: 1/22/2010 Time log Start End Our Time Depth Start Depth End Time = °Time (hrs) Phase; ' Op Code ActiuityCode ` P -T-X __- Trbi Code Trbl Class. ((tKB)= (ftKB) Operation _ 16:30 19:00 2.50 INTRM1 CASING RNCS P 7,507.0 9,130.0 Continue to run 7" 26 ppf L -80 BTCM casing from 7507 to 9130' (Jt # 185 to jt # 124 + FMC hanger and landing joint). PU wt 300k, SO wt 175k. Required 315K PU wt to break over. Landed on hanger @ 1900 hrs. 19:00 19:15 0.25 INTRM1 CASING RURD P 9,130.0 9,130.0 Rig down Frank's fill up tool, blow down the top drive. 19:15 19:30 0.25 INTRM1 CEMENT RURD P 9,130.0 9,130.0 Rig up Dowell cement head and cementing hose. 19:30 21:45 2.25 INTRM1 CEMENT CIRC P 9,130.0 9,130.0 Circulate, staging pumps f/ 3 bpm w/ 400 psi to 5 bpm w/ 370 psi. Pre job safety meeting while circulating. Circulated a total of 693 bbls. Final mud properties : PV/YP= 9/16. MW 9.8 ppg 21:45 22:30 0.75 INTRM1 CEMENT PUCM P 9,130.0 9,130.0 Dowell pump 2 bbl of CW 100, test lines to 3600 psi, pump another 38 bbls @ 4 bpm w/ 300 psi, mix and pump 35 bbls 11.5 ppg mudPushll @ 5.1 bpm w/ 395 initial to 190 psi final. Shut down, then load bottom plug. Pump another 5 bbls of 11.5 ppg mudPushll. Shut down and load shut off plug. 22:30 22:45 0.25 INTRM1 CEMENT PUCM P 9,130.0 9,130.0 Dowell mix and pump 56.7 bbls (273 sx) Alpine tail cement (15.8 ppg) (1.16 cuft/sx yield) (5.076 gal /sx water) (5.34 hrs thickening time). Pump at 5.2 bpm average w/ 400 psi initial and 140 psi final pressure. Drop Halliburton shut off plug, chase w/ 20 bbl of water, pumping 4.5 to 5.3 bpm w/ 44 psi to -17 psi. 22:45 23:45 1.00 INTRM1 CEMENT DISP P 9,130.0 9,130.0 Rig displace cement w/ 9.8 ppg mud. Pumping 7 bpm. Slowed down to 3 bpm when plugs went through Baffle adapter. Reciprocated f/ 9130' to 9120' until 15.8 bbls before bumping plug, landed on FMC hanger. Slowed to 3 bpm for the last 20 bbls pumped. PU wt 280 to 285k, SO wt 180k. Bumped plug @ 2341 hrs 1 -22 -2010. Landed on hanger 2336 hrs 1 -22 -2010. 23:45 00:00 0.25 INTRM1 CEMENT OTHR P 9,130.0 9,130.0 Held pressure 4 minutes, bled off pressure and floats held. Load Halliburton closing plug f/ 2nd stage cement job. Pressure up to open Halliburton type HES cementer. Opened at 3425 psi. Injection Fluid Fluid Source From Lease (bbit ,, Destination Vendor, " " Manifest "Number Note Diesel 35.0 CD3 -305 Water Based Mud CD3 -122 40.0 CD3 -305 Welibores Wellbore Name Wellbore API/UWI CD3 -122 501032060900 Section Size (in) Act Top (ftKB) Act Btm, (ftKB) t StartBata`` = End pate COND1 18 37.0 114.0 Page 3/5 Report Printed: 1/19/2011 • 40 Security Level: AK Development Daily Drilling Report -- 2 mm ,iu CD3 -122 ConocoPhillips Report Number: 13 Rig: Report Date: 1/22/2010 • D OYON 19 p Section _, _ _= Size (in) -- Act Top (ftka) Act Btm (ftKB), =- - Start Date - _ End Date SURFAC 12 1/4 114.0 2,695.0 1/12/2010 1/14/2010 INTRM1 8 3/4 2,695.0 9,140.0 1/16/2010 1/20/2010 PROD1 6 1/8 9,140.0 15,409.0 1/25/2010 1/31/2010 Casing Strings String 00 String Wt Casing Description Run Date (in) (Ibstft) String Grade Set Depth (ftKS) Comment INTERMEDIATE 1/22/2010 7 26.00 L -80 9,130.0 PJSM on running 7" 26 ppf L -80 BTC -m csg. Run 7" cg: Pick up jt #1: Ray Oil tool 7" eccentric shoe joint w/ Ray Oil Tool aluminum centralizer (7" x 8 -3/8 ") floating f/ shoe to 10' above the shoe with stop ring. Thread lock joint #2 w/ centralizer between box and 10' below box with stop ring. Baker lock Halliburton Sure Seal II Float Collar w/ baffle adapter installed. Baker lock pin of Jt #4 with centralizer floating the full joint. 4 jts w/ baker lock. Fill pipe w/ Frank's FU tool, circ 20 bbls, check floats- OK. Con't to run 7" 26 ppf L -80 BTCM csg. Avg make up torque 8000 ft lbs. The first 30 jts all have Ray Oil Tool 7" x 8 -3/8" Aluminum straight blade centralizers. Con't to run 7" csg from 1200' to 2630' (Jt # 30 to jt # 65). Circ and condition mud @ 2630', prior to exiting surface csg shoe. Stage pumps up to 6 bpm w/ 400 psi. PU wt 131k, SO wt 124k. Con't to run 7" csg from 2630' to 5065' (Jt # 65 to jt # 125). PU wt 193k, SO wt 150k. Between joint # 97 and # 98 is the Halliburton Type HES 7" stage collar. Ray Oil tool straight blade 7" x 8 -3/8" aluminum centralizer floating on Jt # 97 between a stop ring 10' below the box and the box. A centralizer floating between the pin and 10' above the pin of jt # 98. Then centralizers installed floating on jt # 99 to # 123. Circ and condition mud @ 5065'. Stage pumps up f/ 2.5 bpm w/ 450 psi to 5 bpm w/ 350 psi. PU wt 190k, SO wt 150k. Con't to run 7" csg from 5065' to 7507' (Jt # 125 to jt # 185). PU wt 260k, SO wt 180k. Straight blade centralizers floating on Jt # 159, # 160, # 161, then every other jt f/ # 163 to # 223. Circulate and condition mud @ 7507'. Stage pumps up f/ 3.5 bpm w/ 450 psi to 5 bpm w/ 450 psi. PU wt 253k, SO wt 185k. Con't to run 7" 26 ppf L -80 BTCM casing from 7507' to 9130' (Jt # 185 to jt # 124 + FMC hanger and landing joint). PU wt 300k, SO wt 175k. Required 315K to break over. Landed on hanger @ 1900 hrs. Quit recip 2336 hrs 1/22/2010 during cement job. Final PU 285k, SO 180K. Cement Intermediate Casing Cement - Started @ 1/22/2010 Type Wellbore Cemented String Cement Evaluation Results casing CD3 -122 INTERMEDIATE, 9,130.0ftKB Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl /... P (final) (psi) 1 Intermediate Casing Cement 7,786.0 9,140.0 3 410.0 Fluid Class Amount, (sacks) -° V (bbl) ___ Density(Ib/gal) Yield (R' /sack) __- - °-- Est Top (ftKB) = EstBtnt''l(ftKB) ., CW100 40.0 8.40 5,652.0 6,719.0 MudPush II 40.0 11.50 6,719.0 7,786.0 Page 4/5 Report Printed: 1/19/2011 1 • ' Security Level: AK Development 'h',,,,,, Daily Drilling Report i s l �i4, �_ CD3 -122 w Report Number: 13 ConocoPhill ps Rig: DOYON 19 Report Date: 1/22/2010 Fluid Class Amount (sacks) V (bbl) Density (lb/gag __= = Yield (ft'lsack) - Est Top (ftKB }_ =- Est Btm (ftKB} Alpine Intermediate Tail 273 56.7 15 .80 1.16 7,786.0 9,140.0 Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl /... P (final) (psi) 2 Intermediate Casing Cement 4,167.0 5,193.0 2 270.0 Fluid Class Amount (sacks } V (bbt} -- = Density (Iblgaq Yield (ft'lsaek) Est Top (ftKB) Est Btm (ftKB) 7 CW100 30.1 8.40 2,500.0 3 . MudPush II 31.6 11.50 3,303.7 4,146.7 Alpine Surface Tail 187 39.2 15.80 1.17 4,146.7 5,192.7 Page 5/5 Report Printed: 1/19/2011 { Security Level: AK Development rov Daily Drilling Report . CD3-122 C tcoltrtllrs Report Number: 14 Rig: DOYON 19 Report Date: 1/23/2010 AFE Type `` Network/ID # Total -AFE +Sup _ . " 10271110 11,115,000.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3 - 122 Development FIORD NECHELIK 11.02 14.0 0.00 8,625.0 8,625.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 3,708.41 314,523.10 222,713.41 4,287,038.10 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 1/10/2010 1/12/2010 28.90 26.79 2.11 2/6/2010 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) INTERMEDIATE, 9,130.0ftKB Ops and Depth @ Morning Report 24hr Forecast PU /MU /RIH w/ 4" Dp w/ BHA #3, depth approx 5000' PU /MU BHA #3 to clean out cement in 7 ", RIH, test csg to 1000 psi above stage collar, drillout stage collar, test to 1000 psi, con't to PU /MU /RIH w/ 4" dp, test to 3500 psi above baffle collar, drill cement to 9120', circ, POOH f/ BHA #4, PU /MU /RIH w/ BHA Last 24hr Summary Estab circ thru Halliburton 7" HES stage tool at 5192.67'. Pump 6 bpm w/ 270 psi. PJSM on 2nd stage cement job while circ 6 bpm w/ 250 psi final. Dowell pump 2 bbl of CW 100, test lines to 3600 psi, pump another 28.12 bbls @ 4 bpm w/ 225 psi, mix and pump 31.6 bbls 11.5 ppg mudPushll @ 5.2 bpm w/ 262 psi initial - 220 psi final. Shut down. Dowell mix and pump 39.24 bbls (187 sx) Alpine surface tail cement (15.8 ppg) (1.17 cuft/sx yield) (5.105 gal /sx water) (5.34 hrs thickening time). Pump 5.2 bpm average w/ 260 psi initial -150 psi final pressure. Drop Halliburton closing plug, chase w/ 20 bbl of water, pump 5.2 bpm w/ 70 psi. Rig displace cement w/ 9.8 ppg mud. Pump 7 bpm w/ 140 psi initial until mud push was at stage tool, then slowed to 5 bpm w/ 70 psi, once cement was at the tool, increased rate to 6 bpm w/ 90 psi initial- 270 psi final. While pumping the last 15 bbls, slowed down to 2 bpm w/ 260 psi final, bumped plug at calculated strokes (1779 strokes). Pressure to 1100 psi, bled off pressure, tool not shut. Re- pressure to 1500 psi, tool shut at 1425 psi. Bumped plug @ 0209 hrs 1 -23 -2010. Held pressure 4 minutes, bled off pressure. R/D cement head and hose. UD 7" landing joint. PU/ MU wear ring pulling tool, remove FMC thin wear bushing (10.75" ID). Run in the FMC 7" packoff. UD running tool. Torque lockdown screws to 450 ft lbs. Test 7" packoff to 5000 psi for 10 min. UD 7" csg equip. PJSM,change top pipe rams to 3 -1/2" x 6, change saver sub to 4" XT 39. PJSM, RU to test, Test BOPE: Everything to 250 psi low, annular to 2500 psi high, all other components to 3500 psi high, chart all tests. Hold each test 5 minutes. Tested accumulator. Witness of test waived by AOGCC inspector Chuck Scheve. Tested BOPE w/ 3 -1/2 ", 4 ", and 4 -1/2" test joint. Pull 4 -1/2" test joint and test plug, blow down kill and choke lines, blow choke manifold, install FMC (7 -1/8" ID) wear bushing, PJSM, Pick up/ stand back 4" drill pipe in the derrick, via the mousehole. General Remarks Weather Head Count No Accidents / No Spills. Rig off highline @ 1300 hrs, back on @ 1415 hrs. Moved cable to -7 °, Wind SW @ 8 Mph, 10 mile vis 50.0 the rig. Supervisor : . , Ttla >_ Fred Herbert, Rig Supervisor Rig Supervisor Granville Rizek, Rig Supervisor Rig Supervisor Dave Egedahl, Rig Engineer Rig Engineer Time Log -- = Start __ End- Dur - Time:, -_- Depth Start Depth End Time -. Time (hrs) Phase Op Gode Activity Code = _ x Trbt Code= Trbl Class. (ftKBi _' (fKB)s Operation 00:00 00:30 0.50 INTRM1 CEMENT CIRC P 9,130.0 9,130.0 Establish circulation through the Halliburton 7" HES stage tool at 5192.67'. Pumping 6 bpm w/ 270 psi. 00:30 00:45 0.25 INTRM1 CEMENT SFTY P 9,130.0 9,130.0 Pre job safety meeting on 2nd stage cement job while continuing to circulate. 00:45 01:00 0.25 INTRM1 CEMENT CIRC P 9,130.0 9,130.0 Circulate, pumping 6 bpm w/ 250 psi final. Circulated a total of 332 bbls. No indication of CW100 or mud push at the shakers. 01:00 01:15 0.25 INTRM1 CEMENT PUCM P 9,130.0 9,130.0 Dowell pump 2 bbl of CW 100, test lines to 3600 psi, pump another 28.12 bbls @ 4 bpm w/ 225 psi, mix and pump 31.6 bbls 11.5 ppg mudPushll @ 5.2 bpm w/ 262 psi initial and 220 psi final. Shut down. Latest BOP Test Data D_a__te _ Comment 1/23/2010 Witness of test waived by AOGCC inspector Chuck Scheve. Page 1/4 Report Printed: 1/19/2011 1 Security Level: AK Development Daily Drilling Report z ira CD3 -122 CtCCri'htlli�ts Report Number: 14 Rig: DOYON 19 Report Date: 1/23/2010 Time Log Star€ _ End Dur Time Depth Start Depth_End Time Time (hrs) Phase Op Code Activity Code P -T -X Trbl Code Trial Class __ (ftKB) (ftKB) Operation 01:15 01:30 0.25 INTRM1 CEMENT PUCM P 9,130.0 9,130.0 Dowell mix and pump 39.24 bbls (187 sx) Alpine surface tail cement (15.8 ppg)(1.17 cuft/sx yield) (5.105 gal /sx water) (5.34 hrs thickening time). Pump at 5.2 bpm average w/ 260 psi initial and 150 psi final pressure. Drop Halliburton closing plug, then chase w/ 20 bbl of water, pumping 5.2 bpm w/ 70 psi. 01:30 02:15 0.75 INTRM1 CEMENT DISP P 9,130.0 9,130.0 Rig displace cement w/ 9.8 ppg mud. Pumping 7 bpm w/ 140 psi initial until mud push was at stage tool, then slowed to 5 bpm w/ 70 psi, once cement was at the tool, increased rate to 6 bpm w/ 90 psi initial- 270 psi final. While pumping the last 15 bbls, slowed down to 2 bpm w/ 260 psi final prior to bumping plug at calculated strokes (1779 strokes). Pressured to 1100 psi, bled off pressure, tool not shut. Re- presure to 1500 psi, tool shut at 1425 psi. Bumped plug @ 0209 hrs 1 -23 -2010. Held pressure 4 minutes, bled off pressure. 02:15 03:30 1.25 INTRM1 CEMENT RURD P 9,130.0 0.0 Rig down cement head and hose. Lay down 7" landing joint. 03:30 04:15 0.75 INTRM1 DRILL OTHR P 0.0 0.0 Pick up/ make up wear rig pulling tool, remove FMC thin wear bushing (10.75" ID). Run in the FMC 7" packoff. Lay down the running tool. Torque the lower lockdown screws to 450 ft Ibs of torque. 04:15 04:30 0.25 INTRM1 DRILL PRTS P 0.0 0.0 Test the 7" packoff to 5000 psi for 10 minutes. Witness of test by FMC Bobby and Rig Supervisor. 04:30 05:00 0.50 INTRM1 DRILL PULD P 0.0 0.0 Lay down 7" casing equipment. 05:00 05:15 0.25 INTRM1 WHDBOP SFTY P 0.0 0.0 Pre job safety meeting on changing top pipe rams from 7" to 3 -1/2" x 6" variables. 05:15 06:30 1.25 INTRM1 WHDBOP NUND P 0.0 0.0 With blinds shut. Change upper pipe rams to 3 -1/2" x 6" variables. Also changing saver sub on the top drive from 4 -1/2" IF to 4" XT 39 06:30 06:45 0.25 INTRM1 DRILL SFTY P 0.0 0.0 Pre job safety meeting on rig up to lay down 5" drill pipe f/ derrick. 06:45 07:15 0.50 INTRM1 DRILL RURD P 0.0 0.0 Install drilling bales on the top drive. Install 5" elevators. 07:15 12:30 5.25 INTRM1 DRILL PULD P 0.0 0.0 Lay down 5" drill pipe from the derrick via the mouse hole. A total of 59 stands were layed down, leaving 30 stands of 5" in the derrick for the next hole. 12:30 13:00 0.50 INTRM1 DRILL PULD P 0.0 0.0 Lay down 5" drilling tools, pick up 4" drilling tools. 13:00 13:15 0.25 INTRM1 DRILL SFTY P 0.0 0.0 Pre job safety meeting on moving hi -line cable to the rig. Page 2/4 Report Printed: 1/19/2011 • ' 1 Security Level: AK Development i Daily Drilling Report 11,0,1hl0 1 1 1 1'1 d v CD3 -122 Cof�ocoPhitlips Report Number: 14 Rig: DOYON 19 Report Date: 1/23/2010 Time Log Start , , End Dur _ Time ;- Depth__Start Depth'End Time Time (hrs) __ - -__- Phase Op Code Activity Code P -T -X T rbl Code Trbl Class. (ftKBf ` -- (ftK8) _Operation 13:15 13:45 0.50 INTRM1 DRILL RURD P 0.0 0.0 Rig went off hi -line at 1300 hrs, back on at 1415 hrs. Disconnect Hi -line cable, re -route cable due to construction activities on pad. 13:45 14:00 0.25 INTRM1 DRILL SFTY P 0.0 0.0 Pre job safety meeting on slip and cut drilling line. 14:00 15:15 1.25 INTRM1 RIGMNT SVRG P 0.0 0.0 Hang blocks. Slip and cut 60' of 1 -3/8" drilling line. Service the top drive. 15:15 15:45 0.50 INTRM1 RIGMNT SVRG P Change the 5" die blocks on the iron roughneck to 4 ". Adjust air pressure on the top drive. 15:45 17:15 1.50 INTRM1 WHDBOP RURD P 0.0 0.0 Set FMC upper test plug. Rig up to test BOPE. 17:15 22:30 5.25 INTRM1 WHDBOP BOPE P 0.0 0.0 Test BOPE. Witness of test waived by AOGCC inspector Chuck Scheve. Rig electrician tested floor methane alarm and pit H2S alarm- good. All tests were charted. Tests held f/ 5 minutes each low and high. Tested annular to 250 psi and 2500 psi. All valves in the choke manifold, kill line and choke line valves, 4" demco valve on mud line, floor safety and IBOP valve, top drive automatic and manual IBOP valves, upper pipe rams (3 -1/2" x 6" variable bore), blind rams, lower pipe rams (3 -1/2" x 6" variables) were tested to 250 psi and 3500 psi. Pipe rams and annular tested with 3 -1/2 ", 4" and 4 -1/2" test joint. Accumulator test performed: initial pressure 3000 psi, 1650 psi after operating. Recovery time test of 34 seconds for 200 psi build up and 2 minutes 43 seconds for full charge. Nitrogen bottles average 1675 psi. 22:30 23:00 0.50 INTRM1 WHDBOP OTHR P 0.0 0.0 Remove FMC upper test plug. Blow down kill and choke lines, blow down chioke manifold. Set FMC 7 -1/8" ID wear bushing. 23:00 23:15 0.25 INTRM1 DRILL SFTY P 0.0 0.0 Pre job safety meeting on picking up and standing back in the derrick 10 stands of 4" drill pipe. 23:15 00:00 0.75 INTRM1 DRILL PULD P 0.0 0.0 Pick up/ make up/ stand back 4" drill pipe in the derrick, via the mouse hole. Note: Performed injectivity test, flush and freeze protected 9 -5/8" x7" annulus on CD3 -122 with dowel) on 1 -23 -2010. Injectivity test 7 bbls 9.8 ppg mud, 300 bbls water, 50 bbls diesel. Mud Check Data ggi=- YP Calc !%-= Gel (10s) Gel (10m) Gel (30m) HTHP Fitt Density Temp Solids Corr'- Type __ -- Depth. (11K8) Dens (Ib /gal), Vis (s/qt) = - PVCaid(cp) (IbfriPPfe- _- (Ibf /100ft) (Ibf /100W - - - (Ibf /100fP) ' MBT (Ib/bbl) (mL/30min) pH ( ".F) Mgr LSND 9,140.0 9.80 35 9.0 17.0 6.0 8.0 10.000 140.2 9.6 10.0 w /Inhibycol Page 3/4 Report Printed: 1/19/2011 1 • Security Level: AK Development Daily Drilling Report 7F Z3 i 1400:.; CD3 -122 . �& ',01, IGonocoPhitlips Report Number: 14 Rig: DOYON 19 Report Date: 1/23/2010 Injection Fluid Fluid , - - -- -- Source From Lease (bbl)- = Destination Vendor Manifest- Number Note Diesel 50.0 CD3 -122 Freeze protect 9 -5/8" x 7 Diesel 25.0 CD3 -305 Pit Rinsate CD3 -122 217.0 CD3 -305 ASRC 334751 Water 300.0 CD3 -122 Flush 9 -5/8" x 7" Water 150.0 CD3 -305 Water Based Mud CD3 -122 1214.0 CD3 -305 Water Based Mud CD3 -122 280.0 CD3 -305 ASRC 334753 Water Based Mud CD3 -122 220.0 CD3 -305 ASRC 334752 Water Based Mud CD3 -122 7.0 CD3 -122 Initial injectivity 9 -5/8" x 7" Welibores Welibore Name Wellbore API /UWI CD3 -122 501032060900 Section Size (in) - __ Act Top (ftKS) _ > - - Act Btm (ftKB) = Start Date End Date COND1 18 37.0 114.0 SURFAC 12 1/4 114.0 2,695.0 1/12/2010 1/14/2010 INTRM1 8 3/4 2,695.0 9,140.0 1/16/2010 1/20/2010 PROD1 6 1/8 9,140.0 15,409.0 1/25/2010 1/31/2010 Leak Off and Formation Integrity Tests Leak _ Dens Fluid - - _- LO Eq Fluid Den == off? Last Casing String Run =__ _ _ ,E=-_ Depth (ftKB) -- (Ib/gal) Fluid P (SUM (psis _ '- (Iblgal) P (LQ)(psE -°' -- Yes ' INTERMEDIATE, 9,130.0ftKB 4,172.0 9.80 Water 648.0 13.21 2,509.3 Page 4/4 Report Printed: 1/19/2011 ,-, PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: I CD3-122 Rig: Doyon 19 'Date: 1/23/2010 _ Volume Input 1 Pump Rate: Drilling Supervisor: Fred Herbert / Granville Rizek ]Pump used Cement Unit v Barrels -,:;;;;;;;;;:;:i Bbls/Strk V ::::::.:04$0 Bbl/min ■ Type of Test: Annulus Leak Off Test for Disposal Adequacy ■ Pumping down annulus. ■ - . - Casing Test Pressure Integrity Test Hole Size: 8 v Casing Shoe Depth Hole Depth Pumping Shut-in Pumping Shut-in RKB-CHF:_ 34.2IFt 2801.0IFt-MDI 2484.OlFt 4 1 7 2.OIFt - MD I 3656.0IFt-TVD Bbls psi Min psi Bbls psi Min psi Casino Size and Description: 9 40#/Ft L BTC v :;i:i:i;;:i;i ::':::i;I:;;;;; 0 ;;;;;;;;;;;;: 0 39 0.00 599 Chanaes for Annular Adequacy Test Pressure IntearitvTest ;;;;;;;;;;;;;;:;;;;;;;;;;;;;; 1 ;;;:;;;;;;;;; 0.5 144 0.25 547 Enter outer casing shoe test results in comments Mud Weight: 9.8 ppg ;:;:;:;:::;:::;E;HH;: 2 ;;*:;:;H; 1 247 0.50 542 Casing description references outer casing string. Inner casing OD: 7.0 In ;:;:;: ;:::;:;:;:;:;: 3 1.5 349 1.00 53. Hole Size is that drilled below outer casing. 4 ::,,:,:, 2 437 1.50 537 Use estimated TOC for Hole Depth. :::H::H:1:1H 5 ;:;.:;:::::::;: 2.5 516 2.00 535 Enter inner casing OD at right. Desired PIT EMW: 15.0 ppg ;;; 6 ;;;;;:::;:;;;: 3 579 2.50 531 Estimates for Test: 672 psi 03 bbls ;;;;;;;;;;;H: !:i:'i;H: 7 3.5 633 3.00 530 , .,,,.,s,...... 8 :;:.:;;;:;:: 3.75 648 3.50 529 EMW = Leak-off Pressure + Mud Weight = 579 + 9 8 PIT 15 Second ;;;;;;;';;;;;;;;;;;;;;;;;;:::: 9 :;;;:;:::::; 4 622 4.00 528 . 0.052 x TVD 0.052 x 2484 Shut-in Pressure, psi ;:;:;:;:;:;:;:: i:::;:;:i: 10 p:::::;:j! 4.5 617 4.50 527 EMW at 2801 Ft-MD (2484 Ft-TVD) = 14.3 547 '::,:.:'''''.:'';'.:':!;.::::: 15 ;i;;;:;:;:;:;': 5 613 5.00 526 1000 - - 1 .,-:;;.;;,,,;:' ]. :;';''::H 20 H 5.5 602 5.50 525 25 6 602 6.00 524 30 2;;,;:;:::: 6.5 602 6.50 524 7 599 7.00 523 7.50 521 8.00 520 tu ..Mk- 8.50 520 9.00 51 en 500 :.;;;;;;;i:: ;;; 9.50 518W 0 ;:;::::HH;;; 10.00 517 re , 1 ,II. ".. „-111'1 'A.,{..--• {4" , 0 0 1 2 3 4 5 6 7 8 0 5 10 15 20 25 30 V olume Barrels Shut-In time, Minutes Volume Volume Volume Volume wwtr'iCASING TEST - El - LEAK - OFF TEST 0 PIT Point Pumped Bled Back Pumped Bled Back 0.0 Bbls ;;;;H;ABbls 7.0 Bbls ;;iiiiiilBbls Comments: Surface Casing FIT C 18.1 PPG EMW - - 7" Casing Shoe @ 9130 MD (6958' TVD) L.va I cc vrA Lv i u I i u .xlb Summary • • Note to File CD3 -106 (210 -001 311 -021) Colville River Unit (Qannik) ConocoPhillips Alaska, Inc ConocoPhillips has made application to authorize annular disposal in the subject well. This document examines the pertinent information for the well and recommends approval of ConocoPhillips' request. -- No unusual events were reported while drilling the surface hole of the well (CD3 -106). -- 9 5/8" Surface casing was cemented to surface successfully. No problems were reported. Approximately 100 bbls of cement was circulated to surface. The net cement remaining in the surface hole was 80% XS of the calculated hole volume. -- On the initial leak off test (LOT) for the surface casing shoe dated 1/24/10 , the pressure slope rises smoothly to —15.5 EMW and continues at a slightly shallower slope to 17.0 EMW. Minimal fluid was pumped in. The pressure declined slightly during the observation period to about 15.2 ppg EMW. The initial leak off indicates that the surface casing shoe is well cemented. - -No problems are reported drilling the intermediate hole. The 7 -5/8" casing was run and successfully cemented. Full returns were noted and the casing was reciprocated. Qannik zone was covered in the second stage of the cement job. - -An injectivity test down 10 -3/4" x 7 -5/8" annulus was conducted on 2/8/10. Pressure steadily increases until the break at 15.0 EMW. The pressure declined with additional pumping to 13.9 ppg EMW. During the observation period, the pressure declined to 13.0 ppg EMW. The lower EMW of the pump in test indicates that the planned disposal should be conducted at EMWs below that of the shoe integrity. - -There are several wells within % mile radius of CD3 -106. The surface shoe of CD3 -110 is closest, about 265' distant. CD3 -302 is 370' and CD3 -109 is 556' distant. AD was approved for CD3 -109 and CD3 -302 in 2006 and 2008 respectively. There are no identified issues with any of the proximal wells. Based on examination of the submitted information, I recommend approval of ConocoPhillips' request for the subject well. Guy wartz Sr. roleum Engineer AOGCC January 28, 2011 G:\AOGCC\ Common \tommaunder \Well Information\By Subject \Annular Disposal\ 110128_CD3- 106.doc ♦ • Note to File CRU CD3 -106 (PTD 2100010) January 26, 2010 Re: ConocoPhillips' Application for Sundry Approval for Annular Disposal of Drilling Wastes within Well CD3 -106 Request ConocoPhillips requests approval to dispose of waste fluids generated through drilling operations by injection into the 9 -5/8" x 7" annulus within well CD3 -106. Recommendation Approve ConocoPhillips' request. Conclusions 1. The 9 -5/8" surface casing shoe is set in this well at about 2,725' (- 2,425' true vertical depth subsea, or "TVDSS "), near the base of a 450 -foot thick mudstone and siltstone interval that persists throughout the area. This interval will provide confinement to prevent upward migration of injected waste. 2. There appears to be a sufficient volume of silty sandstone and sandy siltstone open to the annulus surrounding the 7" casing within this well to accept the proposed injected fluids. 3. The lower confining mudstone strata are sufficiently thick and laterally persistent to ensure injected materials remain within the target disposal interval. 4. There are no potential USDWs in this area. 5. Correlative rights will be protected. 6. The proposed disposal injection operations will not affect potential oil or gas reservoirs. 7. The area most strongly impacted by the proposed annular disposal activities will be limited to a radius of less than 120' from the wellbore. Discussion CPAI's application was reviewed along with well logs from Colville River Unit (CRU) wells CD3 -108, CD3 -111, CD3 -114, and the Nechelik 1 exploratory well. The mud log from CRU CD3 -114 was also reviewed. An index map is provided in Figure 1, below. The CD3 -106 development well was drilled to the Fiord Oil Pool within the CRU. ConocoPhillips, the operator, intends to dispose of drilling wastes utilizing an open annulus within CD3 -106 that extends downward from the 9 -5/8" surface casing shoe, which is set at about 2,725' (- 2,425' TVDSS), to the top of cement for the 7" casing string, which is estimated to lie at about 11,180' ( -6,310 TVDSS). This annulus lies within Section 5 of T12N, R5E, Umiat Meridian (UM) and Section 32 of T13N, R5E, UM (see Figure 1, below). The annulus is located more than 1 -3/4 miles from the current boundary of the CRU. The section of annulus in CD3 -106 that will most likely accept the injected waste fluids (most likely receptor interval) is a portion of the Seabee formation that extends from about 2,845 to 2,885' 1 All depths herein represent measured depths unless otherwise specified. 2 All thicknesses represent true vertical thicknesses unless otherwise specified. 3 Top of cement estimate determined by G. Schwartz, AOGCC. . • CD3 -106 January 26, 2011 Note to File Page 2 of 5 (- 2,492' and - 2,514' TVDSS; see Figure 2, below). This 25 -foot thick interval consists of sandy siltstone and silty sandstone with thin interbeds of siltstone, mudstone and shale. The aggregate stratigraphic thickness of the sandy siltstone and silty sandstone beds exposed to the annulus is about 18 feet. - l_" \ 0 CD3 -111 L1 `, } CD3 -301 \ CD3 - 1 06 CD3-301A r / CD3 -107L1 CD3 -111 1 1 , I . CD3-107 CD3 -112 \ f A/ ,-9 -F10 5 QCD3 -113 \ ■ 1\ 03.114 \ ' .• CRU CD3 -106 \ ,, . 'y Annu1u \ \ gar . \ \ ✓ j CD3307 \ \ Area of Review f I CD3 - 4 (shaded blue) ' I �� \ 1 .. =3 \ \ , ii , \ \ �``�- 4 ,: Most Likely Receptor Interval : L. — 1".. , - � (highlighted with red rectangle) Cement op 00.----- \ ---„,1 Figure 1. Index Map (The path of the cross - section shown on Figure 3 is highlighted with a purple line) The 9 -5/8" surface casing shoe lies near the base of a 450 -foot thick interval that is dominated by mudstone and siltstone. This interval is continuous throughout the area, and it will provide upper confinement for the disposed fluids. Beneath the most likely receptor interval is a 50 -foot thick siltstone interval that is also continuous throughout the area. This interval, which lies between about 3,155' and 3,250' (- 2,662' and - 2,715' TVDSS), and two similar, thinner, underlying mudstone intervals will provide additional lower confinement for injected wastes (see Figure 3, below). In vicinity of Drill Site CD3, the base of permafrost occurs at about - 1,250' TVDSS, which is about 1,250' shallower than the top of the likely receptor interval. Conclusion 3 of Area Injection Order 30, which governs the Fiord Oil Pool, states that there are no USDWs beneath the proposed affected area. CD3 -114 is the only well that was mud logged on Drill Site CD3. In CD3 -114, methane was first encountered at about 1,115' (- 1,050' TVDSS). So, the entire proposed disposal interval likely contains some amount of methane gas. • • CD3 -106 January 26, 2011 Note to File Page 3 of 5 Correlation Depth Resis Porosity 1 OR <MD ResD(RPD) RHOB -10 API 240 12 OHMM 200M .65 G/CC 2.65 and - Si - Shale TVDSS > ResM(RPM) ow Pot. 12 OHMM 200 SP(N /A) TVD ResS(RPS) NPOR 100 100 3.2 OHMM 200 30 0 Upp <MD Confining = Strata —♦ Most likely 2844 Receptor Interval for - { e, . . . Disposed 2900 °_ Fluids 7600 -2550 3000 2650 -2600 3100 1 2700 -2650 { 3200 '---jir 2750 -2700 Lower " Confining 3300 ? )00 - 2750 Strata 3400 2 850 -2800 .- 3500 ^yoa -2850 7950 3600 7a -2300 Ai 3700 1000 -2550 i Figure 2. CD3 -106 Well Log Displaying Affected Intervals The shallowest oil show encountered in well CD3-114 was observed at 6,050' (- 4,413' TVDSS), about 1,900' stratigraphically below the most likely receptor beds for the injected material. This show consisted only of 10% dull yellow sample fluorescence and a slow pale yellow sample cut in solvent, and the mud logging geologist rated this show as being of "trace" quality. This instance is judged to represent only small amounts of residual (non - mobile) oil. So, at Drill Site CD3 the likely disposal interval does not contain potentially commercial quantities of oil or gas. i • CD3 -106 January 26, 2011 Note to File Page 4 of 5 S W 1811490 2060300 2100010 2050330 NE V V 501032002000 12840 ft 501032052600 468 ft 501032061100 fl 501032050700 388 - - 4 -- __ - 0. 4 — ■ 4 — SOHIO CONOCOPHILLIPS ALASK CONOCOPHILLIPS ALASK CONOCOPHILLIPS ALASK NECHELIK 1 COLVILLE RIV UNIT CD3 -111 COLVILLE RIV UNIT CD3 -106 COLVILLE RIV UNIT CD3 -108 2340 FSL 814 FWL 1334 FSL, 875 FEL 3921 FNL 777 FEL 1349 FSL 816 FEL TWP:12 N- Range:5 E- Sec.18 TWP:12 N- Range:5 E - Sec .5 TWP:12 N- Range:5 E -Sec.5 TWP:12 N- Range:5 E - Sec .5 ,„, ,-=-- :7 ;.-- ---- *.7;:.- ---- •Ii.. , - . L —.- *— ' ' Upper m I ? Confining j St 2 - I m ¶# 9 -5/8" Casing Shoe ). i, i k, Lik l e � y _ Recep ;� _ _ . ( Interval r 1 Lower y► : _ t '� L ;� Confining l Strata : - s= y m ry __ i .„ TD=10018 TD =15073 TD =17864 TD =18915 Figure 3. Structural Cross - section from Nechelik 1 TO CRU CD3 -108 The chart presented in Figure 4, below, provides an estimate of the subsurface volume around CD3 -106 that will be affected by the proposed annular disposal operations. There are about 18' of porous sandy siltstone and silty sandstone beds within the likely waste receptor interval, according to a count using the gamma ray curve from CD3 -106. Neutron and density porosity well logs were run across the proposed disposal interval in well CD3 -106. Inspection of these well logs suggests an average porosity of about 30% for the sandy siltstone and silty sandstone within the likely receptor interval. Based on these values, the proposed annular injection activities will directly affect the receptor beds only to a radius of less than 120' from the wellbore, as indicated in the chart below. Summary The limited volume of rock that will be affected by this proposed disposal injection program likely contains some gas, is situated beneath about 1,250' of permafrost, and is bounded above and below by continuous confining layers. There are no freshwater aquifers present, nor are there any potentially commercial hydrocarbons within the proposed injection interval beneath Drill Site CD3. The open annulus that will be used for disposal injection lies inside the CRU, well away from any external property lines, so correlative rights are not a concern. • • CD3 -106 January 26, 2011 Note to File Page 5 of 5 Injected Fluid vs Affected Radial Distance CD3 -106 Wellbore (assumes 18' aggregate injection zone thickness and 30% porosity) 300 — — - - - 250 - d 0 .0 0 200 E 0 m m • 150 N_ f0 c* 100 Q • 50 0 0 5,000 10,000 15,000 20,000 25,000 30,000 35,000 Amount of Injected Fluid (barrels) Figure 4. Radial Distance Potentially Impacted by CD3 -106 Annular Disposal Recommendation I rec. - end approval of this annular disposal project. Steve Davies Senior Petroleum Geologist Co, cv/'. i�� 064' ConocoPhillips(Alaska) Inc. Western North Slope CD3 Fiord Pad CD3 -106 501032061100 Sperry Drilling Services Definitive Survey Report 09 March, 2010 I I I J 1 HALLIBURTDN Sperry Drilling Services I 9104A)1 • • 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 Welibore: CD3 - 106 Survey Calculation Method: Minimum Curvature Design: CD3 -106 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 +N/-5 0.00 ft Northing: 6,003,852.22ft Latitude: 70° 25 10.108 N +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 Welibore CD3 - 106 Magnetics Model Name Sample Date Declination Dip Angle Field Strength ( ( - (nT) BGGM2007 1/6/2010 21.28 80.78 57,638 Design CD3 - 106 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 28.00 Vertical Section: Depth From (ND) +NI -S +E / -W Direction (ft) (ft) (ft) ( 28.00 0.00 0.00 336.00 Survey Program Date From To (ft) (ft) Survey (Welibore) ' 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 t 2,778.23 12,785.08 CD3 -106 MWD (CD3 -106) MWD +IFR- AK- CAZ -SC MWD +IFR AK CAZ SCC 1/26/2010 t 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 17,597.41 CD3 -106 MWD (CD3 -106) MWD +IFR- AK- CAZ -SC MWD +IFR AK CAZ SCC 2/12/2010 1: Survey Map Map Vertical MD Inc Azi ND TVDSS +NI -S +E / -W Northing Easting DLS Section (ft) ( ( (ft) (ft) (ft) (ft) (ft) (ft) (° /100') (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 -11.19 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 -22.57 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 -33.84 CB- GYRO -SS (1) 750.00 11.24 132.10 746.88 705.48 -33.62 29.25 6,003,818.17 388,295.20 0.76 -42.61 CB- GYRO -SS (1) 3/9/2010 12:57:05PM Page 2 COMPASS 2003.16 Build 69 i ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co 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: . .CD3-106 Survey Calculation Method: Minimum Curvature Design: CD3 - 106 Database: CPAI EDM Production Survey . Map Map Vertical • MD Inc Azi TVD TVDSS • +N/ -S :. +El -W Northing: . Easting DLS Section (ft} - (°) (") (ft) (ft) . - (ft) (ft) (ft) (ft) C1100') (ft) Survey Tool Name 817.00 11.73 130.07 812.54 771.14 -42.38 39.31 6,003,809.26 388,305.13 0.95 -54.71 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 -62.07 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 -77.85 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 -91.84 MWD +IFR -AK- CAZ -SC (2) 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 - 102.78 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 - 110.81 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 - 114.04 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 - 109.40 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 -96.15 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 -76.40 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 -52.87 MWD +IFR -AK- CAZ -SC (2) 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 -24.41 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 9.27 MWD +IFR -AK- CAZ -SC (2) 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 49.94 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 93.39 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 3.02 139.34 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 3.36 190.80 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 4.13 244.22 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 1.13 301.11 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 3.84 362.58 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 4.66 427.63 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 4.59 481.02 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 2.45 549.56 MWD +IFR -AK- CAZ -SC (3) 7 4.56 162.13 6,004,604.21 388 439.85 0.69 623.39 MWD +IFR -AK- CAZ -SC 3 2,872.19 56.43 354.92 2,556.99 2,515 59 5 ( ) 2,963.08 56.94 355.77 2,606.91 2,565.51 830.27 155.96 6,004,679.99 388,434.82 0.96 695.05 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 0.13 770.31 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 0.89 842.60 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 0.37 914.58 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 0.70 987.67 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 1,060.18 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 1,134.60 MWD +IFR -AK- CAZ -SC (3) 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 1,209.39 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 1,286.74 MWD +IFR -AK- CAZ -SC (3) 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 1,363.98 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 1,442.22 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 1,520.73 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 1,599.02 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 1,678.46 MWD +IFR -AK- CAZ -SC (3) 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 1,757.27 MWD +IFR -AK- CAZ -SC (3) 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 1,835.51 MWD +IFR -AK- CAZ -SC (3) 3/9/2010 12:57:05PM 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 Wellbore: CD3 - 106 Survey Calculation Method: Minimum Curvature Design: CD3 - 106 Database: CPAI EDM Production Survey . • Map Map Vertical MD Inc Azi TVD TVDSS +N / -3 +E/-W Northing Easting DLS Section (ft) ( °) ( (ft) (ft) (ft) (ft) (ft) (ft) ( (ft) Survey Tool Name • 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 1,915.33 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 1,993.45 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 2,072.55 MWD +IFR- AK -CAZSC (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 2,151.16 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 2,228.25 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 2,307.39 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 2,386.06 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 2,464.87 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 2,544.81 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 2,620.79 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 2,702.70 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 2,777.34 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 2,860.79 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 2,940.04 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 3,019.86 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 3,097.72 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 3,176.81 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 3,254.14 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 3,332.24 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 3,409.20 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 3,488.62 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 3,564.96 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 3,644.79 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 3,723.69 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 3,802.04 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 3,880.22 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 3,958.07 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 4,035.56 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 4,117.02 MWD+ I FR-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 4,188.52 MWD+ I FR-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 4,267.91 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 4,346.14 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 4,423.43 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 4,499.23 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 4,578.56 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 4,655.84 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 4,733.19 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 4,810.31 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 4,887.68 MWD +IFR -AK- CAZ -SC (3) 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 4,965.02 MWD +IFR -AK- CAZ -SC (3) 3/9/2010 12:57:05PM 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 - 106 Survey Calculation Method: Minimum Curvature Design: CD3 - 106 Database: CPAI EDM Production Survey Map Map Vertical MD Inc . __ Azi TVD TVDSS +N / -S +E / -W Northing: Easting DLS Section (ft) ( °) ( (ft) (ft) (ft) (ft) (ft) (ft) ( °I100') (ft) Survey Tool Name 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 5,042.81 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 5,120.15 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 5,197.68 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 5,274.80 MWD+ IF R-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 5,352.74 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 5,427.42 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 5,507.92 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 5,584.98 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 5,663.43 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 5,741.59 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 5,818.50 MWD +IFR -AK -CAZSC (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 5,894.72 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 5,975.62 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 6,054.43 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 6,129.77 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 6,205.89 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 6,282.65 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 6,361.05 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 6,437.03 MWD +IFR -AK -CAZSC (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 6,515.75 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 6,594.07 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 6,672.22 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 6,750.14 MWD +IFR -AK -CAZSC (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 6,827.71 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 6,905.09 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 6,983.98 MWD+ I FR-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 7,060.36 MWD+ IF R-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 7,135.12 MWD+ I FR-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 7,215.63 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 7,293.36 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 7,371.70 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 7,449.87 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 7,527.77 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 7,605.06 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 7,684.48 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 7,761.18 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 7,838.96 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 7,914.59 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 7,990.55 MWD +IFR -AK- CAZ -SC (3) 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 8,068.55 MWD +IFR -AK- CAZ -SC (3) 3/9/2010 12:57:05PM 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 ND 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 Welibore: CD3 -106 Survey Calculation Method: Minimum Curvature Design: . CD3 -106 Database: CPAI EDM Production ! Survey. Map Map Vertical MD Inc Az[.:. ND TVDSS +N / -S +E/ -W Northing Easting DLS Section (ft) (°) (°) ' (ft) (ft) (ft) (ft) (ft) (ft) ( °H00') (ft) Survey Tool Name 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 8,147.85 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 8,226.73 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 8,308.01 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 8,392.00 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 8,476.69 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 8,564.53 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 8,654.65 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 8,742.52 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 8,833.92 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 8,927.03 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 9,018.41 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 9,082.83 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 9,176.28 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 9,202.50 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 9,295.16 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 9,387.19 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 9,480.33 MWD +IFR -AK- CAZ -SC (5) 13,348.85 93.39 328.17 6,952.45 6,911.05 10,045.97 - 976.55 6,013,910.81 387,440.46 3.41 9,574.65 MWD +IFR -AK- CAZ -SC (5) 13,443.26 93.45 324.29 6,946.81 6,905.41 10,124.29 - 1,028.92 6,013,989.91 387,389.27 4.10 9,667.50 MWD +IFR -AK- CAZ -SC (5) 13,537.98 93.51 318.89 6,941.06 6,899.66 10,198.35 - 1,087.64 6,014,064.83 387,331.67 5.69 9,759.04 MWD +IFR -AK- CAZ -SC (5) 13,632.09 93.33 314.66 6,935.44 6,894.04 10,266.79 - 1,151.96 6,014,134.22 387,268.38 4.49 9,847.72 MWD +IFR -AK- CAZ -SC (5) 13,730.12 91.35 312.29 6,931.44 6,890.04 10,334.17 - 1,223.03 6,014,202.65 387,198.34 3.15 9,938.19 MWD +IFR -AK- CAZ -SC (5) 13,819.78 91.35 312.38 6,929.33 6,887.93 10,394.54 - 1,289.29 6,014,263.99 387,132.99 0.10 10,020.28 MWD +IFR -AK- CAZ -SC (5) 13,912.20 92.83 310.46 6,925.96 6,884.56 10,455.63 - 1,358.55 6,014,326.12 387,064.67 2.62 10,104.27 MWD +IFR -AK- CAZ -SC (5) 6 921.87 6 880.47 10 515.39 -1 431.09 6,014,386.95 386,993.03 2.20 10,188.36 MWD +IFR -AK- CAZ -SC 5 14,006.28 92.15 308.50 ( ) 14,101.10 92.83 305.35 6,917.75 6,876.35 10,572.30 - 1,506.81 6,014,444.97 386,918.18 3.40 10,271.15 MWD +IFR -AK- CAZ -SC (5) 14,195.10 91.54 300.94 6,914.16 6,872.76 10,623.64 - 1,585.44 6,014,497.48 386,840.34 4.88 10,350.03 MWD +IFR -AK- CAZ -SC (5) 14,289.19 89.87 299.27 6,913.01 6,871.61 10,670.83 - 1,666.82 6,014,545.88 386,759.67 2.51 10,426.24 MWD +IFR -AK- CAZ-SC (5) 14,383.89 91.22 300.53 6,912.11 6,870.71 10,718.03 - 1,748.91 6,014,594.30 386,678.31 1.95 10,502.75 MWD +IFR -AK- CAZ -SC (5) 14,478.57 91.23 301.20 6,910.08 6,868.68 10,766.59 - 1,830.16 6,014,644.07 386,597.80 0.71 10,580.16 MWD +IFR -AK- CAZ -SC (5) 14,567.71 90.67 301.96 6,908.60 6,867.20 10,813.26 - 1,906.09 6,014,691.87 386,522.58 1.06 10,653.68 MWD +IFR -AK- CAZ -SC (5) 14,662.34 90.55 302.41 6,907.60 6,866.20 10,863.67 - 1,986.17 6,014,743.46 386,443.27 0.49 10,732.30 MWD +IFR -AK- CAZ -SC (5) 14,756.75 89.62 303.10 6,907.46 6,866.06 10,914.75 - 2,065.57 6,014,795.72 386,364.65 1.23 10,811.26 MWD +IFR -AK- CAZ -SC (5) 14,855.35 88.88 304.86 6,908.75 6,867.35 10,969.85 - 2,147.32 6,014,852.03 386,283.74 1.94 10,894.85 MWD +IFR -AK- CAZ -SC (5) 14,949.91 87.58 309.74 6,911.67 6,870.27 11,027.10 - 2,222.48 6,014,910.40 386,209.46 5.34 10,977.72 MWD +IFR -AK- CAZ -SC (5) 15,039.69 85.23 311.63 6,917.30 6,875.90 11,085.51 - 2,290.42 6,014,969.81 386,142.40 3.36 11,058.71 MWD +IFR -AK- CAZ -SC (5) 15,135.18 87.83 316.56 6,923.08 6,881.68 11,151.81 - 2,358.84 6,015,037.12 386,074.99 5.83 11,147.11 MWD +IFR -AK- CAZ -SC (5) 15,228.01 89.25 320.45 6,925.45 6,884.05 11,221.30 - 2,420.32 6,015,107.52 386,014.57 4.46 11,235.60 MWD +IFR -AK- CAZ -SC (5) 15,324.05 90.30 323.89 6,925.82 6,884.42 11,297.14 - 2,479.21 6,015,184.23 385,956.82 3.74 11,328.84 MWD +IFR -AK- CAZ -SC (5) 15,416.08 89.68 325.09 6,925.84 6,884.44 11,372.06 - 2,532.66 6,015,259.93 385,904.50 1.47 11,419.02 MWD +IFR -AK- CAZ -SC (5) 3/9/2010 12:57:05PM 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 ND 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 - 106 Survey Calculation Method: Minimum Curvature Design: CD3 - 106 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi ND TVDSS +N / -S +E/ -W Northing Easting DLS Section (ft) (°) ( . (ft) (ft) (ft) (ft) (ft) (ft) ( °1100') (ft) Survey Toot Name 15,512.91 90.18 327.39 6,925.96 6,884.56 11,452.55 - 2,586.47 6,015,341.22 385,851.91 2.43 11,514.44 MWD +IFR -AK- CAZ -SC (5) 15,605.85 91.16 329.57 6,924.87 6,883.47 11,531.77 - 2,635.05 6,015,421.14 385,804.52 2.57 11,606.57 MWD +IFR -AK- CAZ -SC (5) 15,701.69 93.58 333.32 6,920.91 6,879.51 11,615.86 - 2,680.81 6,015,505.90 385,760.03 4.65 11,702.00 MWD +IFR -AK- CAZ -SC (5) 15,795.14 92.34 333.76 6,916.08 6,874.68 11,699.40 - 2,722.40 6,015,590.05 385,719.70 1.41 11,795.24 MWD +IFR -AK- CAZ -SC (5) 15,889.21 94.01 334.16 6,910.87 6,869.47 11,783.79 - 2,763.63 6,015,675.04 385,679.74 1.83 11,889.10 MWD +IFR -AK- CAZ -SC (5) 15,982.70 93.20 334.40 6,904.99 6,863.59 11,867.85 - 2,804.12 6,015,759.69 385,640.52 0.90 11,982.36 MWD +IFR -AK- CAZ -SC (5) 16,077.06 95.43 333.49 6,897.89 6,856.49 11,952.38 - 2,845.44 6,015,844.82 385,600.46 2.55 12,076.38 MWD +IFR -AK- CAZ -SC (5) 16,170.99 91.60 331.67 6,892.14 6,850.74 12,035.58 - 2,888.61 6,015,928.65 385,558.55 4.51 12,169.95 MWD +IFR -AK- CAZ -SC (5) 16,264.57 90.30 332.09 6,890.58 6,849.18 12,118.10 - 2,932.71 6,016,011.81 385,515.70 1.46 12,263.27 MWD +IFR -AK- CAZ -SC (5) 16,355.57 91.10 337.12 6,889.47 6,848.07 12,200.27 - 2,971.72 6,016,094.55 385,477.92 5.60 12,354.21 MWD +IFR -AK- CAZ -SC (5) 16,450.47 91.16 336.63 6,887.60 6,846.20 12,287.53 - 3,008.98 6,016,182.35 385,441.97 0.52 12,449.08 MWD +IFR -AK- CAZ -SC (5) 16,540.20 91.41 331.71 6,885.59 6,844.19 12,368.25 - 3,048.06 6,016,263.64 385,404.11 5.49 12,538.71 MWD +IFR -AK- CAZ -SC (5) 16,637.24 90.61 330.10 6,883.88 6,842.48 12,453.03 - 3,095.24 6,016,349.11 385,358.22 1.85 12,635.35 MWD +IFR -AK- CAZ -SC (5) 16,732.36 87.89 328.01 6,885.12 6,843.72 12,534.59 - 3,144.14 6,016,431.38 385,310.55 3.61 12,729.75 MWD +IFR -AK- CAZ -SC (5) 16,823.12 86.59 329.21 6,889.49 6,848.09 12,611.97 - 3,191.35 6,016,509.46 385,264.50 1.95 12,819.65 MWD +IFR -AK- CAZ -SC (5) 16,920.65 87.15 333.71 6,894.82 6,853.42 12,697.50 - 3,237.87 6,016,595.67 385,219.27 4.64 12,916.70 MWD +IFR -AK- CAZ -SC (5) 17,014.98 86.78 335.43 6,899.81 6,858.41 12,782.57 - 3,278.31 6,016,681.32 385,180.10 1.86 13,010.87 MWD +IFR -AK- CAZ -SC (5) 17,109.78 89.06 338.54 6,903.26 6,861.86 12,869.75 - 3,315.35 6,016,769.04 385,144.39 4.07 13,105.57 MWD +IFR -AK- CAZ -SC (5) 17,202.21 92.22 340.54 6,902.22 6,860.82 12,956.33 - 3,347.65 6,016,856.08 385,113.39 4.05 13,197.80 MWD +IFR -AK- CAZ -SC (5) 17,298.21 94.07 339.73 6,896.96 6,855.56 13,046.47 - 3,380.22 6,016,946.70 385,082.17 2.10 13,293.41 MWD +IFR -AK- CAZ -SC (5) 17,392.50 92.03 335.01 6,891.94 6,850.54 13,133.35 - 3,416.44 6,017,034.10 385,047.26 5.45 13,387.50 MWD +IFR -AK- CAZ -SC (5) 17,487.08 90.49 331.22 6,889.86 6,848.46 13,217.67 - 3,459.19 6,017,119.04 385,005.78 4.32 13,481.92 MWD +IFR -AK- CAZ -SC (5) 17,550.69 90.11 327.74 6,889.52 6,848.12 13,272.46 - 3,491.49 6,017,174.30 384,974.31 5.50 13,545.11 MWD +IFR -AK- CAZ -SC (5) 17,597.41 92.09 327.97 6,888.63 6,847.23 13,312.01 - 3,516.34 6,017,214.22 384,950.05 4.27 13,591.35 MWD +IFR -AK- CAZ -SC (5) 17,664.00 92.09 327.97 6,886.20 6,844.80 13,368.42 - 3,551.63 6,017,271.15 384,915.61 0.00 13,657.24 PROJECTED to TD 3/9/2010 12 :57:05PM Page 7 COMPASS 2003.16 Build 69 (77 210 -00 r . ry Cement Detail Report CD3 -106 conoco String: Surface Casing Cement Job: DRILLING ORIGINAL, 1/20/2010 02:00 Cement Details Description Cementing Start Date Cementing End Date Welibore Name /Edit Surface Casing Cement 1/24/2010 1 0:03 1/24/2010 11:45 003 - 106 Comment Rig pumped 35 bbls 5 ppb nutplug 1 biozan spacer. Dropped bottom plug. Dowell tested lines to 2000 psi. Dowell pumped 50 bbls 10.5 ppb mud push, 327 bbls 10.7 ppg ASL and 48 bbls 15.8 ppg tail cement. Dropped top plug and pumped 20 bbls H20. Rig displaced cement with 176 bbls 9.8 ppg mud. Bumped plug to 1000 psi. Check floats. OK. 100 bbls cement to surface. Cement Stages Stage # 1 'Edit Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn ... Top Plug? Btm Plug? Surface Casing Cement Cement Surface 28.0 2,725.4 Yes 100.0 Yes Yes Q (start) (bbl /min) Q (end) (bbllmin) Q (aug) (bblimin) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 8 3 7 500.0 1,000.0 Yes 10.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Rig pumped 35 bbls 5 ppb nutplug I biozan spacer. Dropped bottom plug. Dowell tested lines to 2000 psi. Dowell pumped 50 bbls 10.5 ppb mud push, 327 bbls 10.7 ppg ASL and 48 bbls 15.8 ppg tail cement. Dropped top plug and pumped 20 bbls H20. Rig displaced cement with 176 bbls 9.8 ppg mud. Bumped plug to 1000 psi. Check floats. OK. 100 bbls cement to surface. Cement Fluids & Additives • Fluid (Edit Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 0.0 2,246.0 410 327.0 Yield (ftslsack) Mix H2O Ratio (galisa... Free Water (%) Density (Ibigal) Plastic Viscosity (cp) Thick Time (hrs) CmprStr 1 (psi) 4.49 10.50 Additives Additive Type Concentration Conc Unit label 'Edit Fluid JEdit Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 2,246.0 2,725.0 232 0 48.0 Yield (W/sack) Mix H2O Ratio (gallsa... Free Water (%) Density (Ibigal) Plastic Viscosity (cp) Thick Time (hrs) 'CmprStr 1 (psi) 1.16 15.80 Additives Additive Type Concentration Conc Unit label jEdit RECEIVED 0 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 2 5 '2010 WELL COMPLETION OR RECOMPLETION REPORT 411;41 la. Well Status: Oil Q Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 1b. Well Class: e 20AAC 25.105 20AAC 25.110 Development o A ator y ❑ 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. or Aband.: March 5, 2010 210 - 0010 / 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 January 20, 2010 50 103 - 20611 - 00 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 February 18, 2010 CD3 - 106 Top of Productive Horizon: 8. KB (ft above MSL): 41.4' RKB 15. field /Pool(s): 412' FSL, 1186' FWL, Sec. 29, T13N, R5E, UM GL (ft above MSL): 13.4' AMSL Colville River Field Total Depth: 9. Plug Back Depth (MD + TVD): 1113' FNL, 1649' FEL, Sec. 30, T13N, R5E, UM 17664' MD / 6886' 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 17664' MD / 6886' TVD ADL 364470, 364471, 372105 TPI: x - 387706 y - 6013474 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 384916 y - 6017271 Zone 4 2062' MD / 1996' TVD 380077 18. Directional Survey: Yes Q 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 - r ULLED 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 13375' 17664' 6951' 6886' 6.125" slotted / blank liner 24. Open to production or injection? Yes 0 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 17659'- 15031' MD 6887' -6916' TVD 14550' 13390' MD 6909' - 6950' 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 _ (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. GOMFLEI10 ^ t NONE f Form 10 -407 Revised 12 /2F113 MAR 2 5 2010 V / I' TINUED ON REVERSE Submit original only 2i. T . (C)/ 28. GEOLOGIC MARKERS (List all formations and marker3"�ncountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes al 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 12132' 6779' Kuparuk 12266' 6816' Kuparuk C 12453' 6861' Nechelik 12836' 6927' N/A Formation at total depth: Nechelik 30. LIST OF ATTACHMENTS ' Summary of Daily Operations, Final directional survey, schematic 5123 [ato 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Winfree @ 265 - 6820 Printed Name /� G. L. Alvord Title: Alaska Drilling Manager r J Signature 1 1 6-0& Phone 265 - 6120 Date 31z4-1z0(. 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 f .. ,. ._ -9 WNS CD3 -106 ConocoPhillips s , ; WgII- Attributes Max I Angle & MD TD APN'6 Irk, _ Wellbore APWWI Feld Name Well Status I Intl (°) MD (ftK8) Act Bhe (ftK6) 9amcU'tuMm 501032061100 FIORD NE( 1PROD 1 95 43 16,07706 17.664.0 Comment H25 (ppm) Date I Annotation '.End Date KB - Grd (ft) Rig Release Date "' _ 3/6/2010 weu config: MULTIPLE LATERALS em - Ac 37 D 10 .`+6:P5AM E to A on Depth (968) End Date Annotation Reason' GLV C /O Pull RHC, Ball /Rod Last Mod ... !End Date or 1 3/20/2010 HANGER zz__ sue. Casing_Strings e Casing Description String O String ID .. Top (ftK8) Set Depth (f... Set Depth (TVD) .. String Wt... String . )String Top Thrd CONDUCTOR 16 ' 1 062 29.0 107.0 107.0 62.50 H Welded \ Y ; Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) .. String Wt... String String Top Thrd SURFACE 9 5/8 3.835 29.4 2,725.4 2.474 9 40.00 L I BTC - Mod Casing Description String 0... String ID ._ Top (ftK6) Set Depth (f... Depth (TVD) ... String Wt... String .!String Top Thrd AMP INTERMEDIATE 7 6 216 25 0 12,986.2 6,944.1 26.00 L I BTCM . ., I Casing Description pth String 0... Str g ID ... Top (ftK6) Set Depth (f.,. Set Depth (TVD) ... Strng Wt String . String Top Thrd LINER (off L1) 4 1/2 365E 13,3721 176640 6 88 12.60 L -80 SLHT -1114 rier Details (TVD) Top Intl Top De Top (ftK6) ( 1/KB ) O Item 0 1 tion Comment ID (in) CONOUcTOR, 13372.1 6,951.1! 9340!Settii1l lee Baker HR settng sleeve assemhly 4410 '' Tubing Strings Tubing Des pt o i St g 0 Sl r ID . Top (ftK8) Set Depth ((.. Set Depth (TVD) . St g Wt. .. Str g String Top Thrd TUBING 4 5 x 3 5" 1 12 22 12,184.2 6,793 3 [ EUESrdMOD Com r Ietion Details - _ Top Depth Safety Valve, (TVD) Top Intl Nonff ... 2063 '°: Top (ftK8) (ftK ( °) Item D cription Comment ID(in) 22 -0 22.0 -0.01 HANGER FMC 4 1/2" Tbg Hanger 4.500 112.5 112.5 0.09 X0 Reducing X0 4.5' x 3.5" 3.000 2,062.5 1,995,0 32.51 Safety Valve 3 1/2" Camco TRMAXX -5E SSSV 5.916" OD 2.812" ID 2.812 12,006. 6,734.4 67.96 PACKER Baker 3 -5" X 7" Premier Packer 3.010 , L , . 12,054.3 6,750.0 68.70 NIPPLE 3.5" HES "XN" Nipple 3 96" OD X 2.813" ID w/ 2.75" 2.750 SURFACE ■ 12,183. 6,793.5 73.18I WLEG W reline entry guide 2.990 292,725 ) I Perforations & Slots Shot GAS LIFT, Top(TVD) Btrn (TVDm Dens 4,660 Top (ftKB), Rho(ftKIfil (968) 18166) Zone Date (s Type Comment 13,390 14,550 6,950 -0 666,908 8 2'20/2010 32 0 SLOTS Slots 1/8x2 25 ", 8 slots/row, 4 rows/ft; no slots 3' from box/pin r.' 15,031 17,659 6,916.6 6,8864 2'20'2/110 3 SLOTS Slots 1/8x2.25", 8 slots/row, 4 rows/ft; no slots 3' from box/pin Notes: Generale Safety _. ,� ,.� End Date Annotation ,f 3/20/2010 'NOTE. CD3 -10611 reoi■ I 1 main wellbore, CD3 -106 ner a Plop 8 Drop off CD3 -106L1 (see attachment) _- ...__. 3/20/2010 NOTE: VIEW SCHEMA IC w /Alaska Schematic9.0 GAS LIFT 9488 .. GAS LIFT. '1885 1 FEIV- i I PACKER, 12,006 NIPPLE, 12,054 ' '', WLEG, 12,184 - V Mandrel Details a .,, x ,�.,,,. .,,�, Top Depih Top Port ,• .•^ NTERMEDIATE,_ (100) Intl OD Valve Latch San TRO Run 25- 12,986 StnT��ftKB) (ftK6) (°) Make Model (in) Sere Type Type (in) (Psi) Run Date Com... SLOTS, 12988 113,502 3,502 1 4 3418 6524 CAMCO KBMG 1 GAS LIFT GLV IBK 0 - 188 1935.0 3/9/2010 SLOTS, - 13390 - 2 9,487.9 5,589.7 CAMCO KBMG 1 GAS LIFT GLV 1OK 0.188 1,951 0 3/9/2010 L1 LINER' = = 3 11,884.5 6,685.3 64.99 CAMCO KBMG 1 GAS LIFT OV BK 0.3131 0.0 3/9/2010 12795 - 16783 SLOTS, _ 1 15,031- 17,659 LINER R - 17,66 , 1N,E ( ff L6 TD (CD , 17,664 Conoc ©Phitlips Time Log & Summary Welfwew Web Reporting Report Well Name: CD3 - 106 Rig Name: DOYON 141 Job Type: DRILLING ORIGINAL Rig Accept: 1/20/2010 2:00:00 AM Rig Release: 3/6/2010 8:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01/20/2010 24 hr summary Accept rig at 02:00 hrs 01/20/2010. Pick up 90 joints of 5" drill pipe and 21 joints of 5" HWDP and rack in the derrick. Make up cleanout BHA and tag ice plug in conductor at 47' MD. Cleanout to 107'. Pull out of the hole and make up directional BHA. Trouble shoot electrical problem in rock washer. Rig went of highline at 19:15 hrs. Drill from 107' MD to 165' MD. 02:00 07:00 5.00 0 0 MIRU DRILL PULD P Accept rig at 02:00 hrs 01 -20 -2010. Pick up 90 joints of 5" drill pipe and 7 stands of HWDP and stand back in the derrrick. Tag ice plug at 47' MD in conductor. 07:00 07:30 0.50 0 0 MIRU DRILL OTHR P Pre -job safety meeting and bring directional and gyro tools to the rig floor 07:30 11:00 3.50 0 0 MIRU DRILL OTHR P Calibrate PVT equipment and MWD tools 11:00 13:45 2.75 0 0 MIRU DRILL WASH P Make up cleanout BHA. Flood conductor and check for leaks. Test Pressure test circulating system to 3500 psi. Clean out conductor from 47' to 107' at 450 gpm and 450 psi. 13:45 15:45 2.00 0 0 MIRU DRILL PULD P Blow down top drive and pick up 2 flex collars and jars. Rack back in derrick. 15:45 19:00 3.25 0 0 SURFA( DRILL PULD P Pre -job safety meeting. Make up directional drilling BHA. Orient and upload MWD. 19:00 22:00 3.00 0 0 SURFA( RIGMNT RGRP T Trace electrical problem in rock washer. Off highline at 19:15 hrs. Attempt to go back on highline at 21:15 hrs without success. 22:00 22:45 0.75 0 0 SURFA( DRILL SFTY P Prejob safety meeting. Circulate and check circulating system 22:45 00:00 1.25 0 165 SURFA( DRILL DDRL P Drill from 0' to 165' MD, 165' TVD. ADT =.5 hrs, ART =.5 hrs. 400 gpm, 650 psi, 50 rpm, P/U 50k, S/O 50k, Rot 50k, Jars .5 hr 01/21/2010 Drill from 165' MD to 1808' MD. 00:00 12:00 12.00 165 905 SURFA( DRILL DDRL P Drill from 165' MD to 905' MD (896' TVD). AST =1.91 hrs, ART =2.81 hrs, ADT =5.22 hrs. P /U =75k, S/O =75k, Rot =75k, Torque on =5k ft-Ibs, Torque off =3k ft-Ibs, max gas =0 units, Jars =5.22 hrs. 12:00 00:00 12.00 905 1,808 SURFA( DRILL DDRL P Drill from 905' MD to 1808' MD (1775' TVD). ART =2.0 hrs, AST =4.23 hrs, ADT =11.45 hrs. P/U = 100k, S/O = 95k, ROT = 100k, Torque on = 5k ft-Ibs, Torque off = 4k ft-Ibs, Page 1 of 32 410 1111 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01/22/2010 24 hr Summary Drilled from 1808' to 2735 MD. Circulate bottoms up two times and make wiper trip 00:00 05:00 5.00 1,808 2,200 SURFA( DRILL DDRL P Drill from 1808' MD to 2200' MD (2109' TVD) 05:00 06:30 1.50 2,200 2,200 SURFA( DRILL CIRC P Circulate and condition mud for weight up at 300 gpm -550 psi -50 rpm 06:30 08:45 2.25 2,200 2,200 SURFA( DRILL CIRC P Rack one stand back and continue circulating at 300 gpm -550 psi while waiting on spike fluid. 08:45 12:00 3.25 2,200 2,385 SURFA( DRILL DDRL P Drill from 2200' to 2385' MD (2250' TVD) ART = 2.2, AST = 1.79, ADT = 3.99, P/U = 104k, S/O = 90k, ROT = 98k, Torque on = 5k, Torque off = 4k, 5 12:00 17:30 5.50 2,385 2,735 SURFA( DRILL DDRL P Drill from 2385' to 2735' MD (2481' TVD). ART = 1.67. AST = 2.39, ADT = 4.06, P/U = 106k , S/O = 90k, ROT = 99k, Torque on = 6k ft -Ibs, Torque off = 4k ft-Ibs, 17:30 19:00 1.50 2,735 2,735 SURFA( DRILL CIRC P Circulate two bottoms up at 600 gpm, 1800 psi, 80 rpm, 19:00 23:30 4.50 2,735 2,735 SURFA( DRILL WPRT P Back ream out of the hole from 2735' to 813' at 500 gpm, 1380 psi, 50 rpm. Slowed pump rate to 400 gpm at 800 psi through the permafrost. Hole unloaded cuttings at 2100' and 1550' MD. 23:30 00:00 0.50 2,735 2,735 SURFA( DRILL WPRT P Run back in the hole from 813' to 835'. Wash through bridge to 845'. Blowdown top drive and run in the hole to 995' MD. P/U = 72k, S/O = 75k 01/23/2010 Finished wiper trip and pulled out of the hole. Rigged up and ran 9 -5/8" surface casing to 1610' 00:00 02:45 2.75 2,735 2,735 SURFA( DRILL WPRT P Continue running in the hole for wiper trip. Tag bridge at 1010' MD and CBU. Back ream out of the hole to top of HWDP. Run in the hole to 1010' and wash and ream to 1275'. Run in the hole to 1340' and wash through bridge. Run in the hole to 2660' with no problems. 02:45 06:15 3.50 2,735 2,735 SURFA( DRILL CIRC P Wash and ream from 2660' to 2735'. Stage pump up to 500 gpm and circulate two bottoms up. Back ream out of the hole to 2480' while conditioning mud. 06:15 09:00 2.75 2,735 2,735 SURFA( DRILL TRIP P Monitor well at 2480'. P/U = 112k, S/O = 88k. Pull out of the hole to 2110'. Back reamed to 1832'. 09:00 11:00 2.00 2,735 2,735 SURFA( DRILL TRIP P Pull out of the hole to 157' 11:00 14:15 3.25 2,735 2,735 SURFA( DRILL PULD P Lay down jars and NMDC. Drain motor and lay down same. Download MWD and lay down. 14:15 16:30 2.25 2,735 2,735 SURFA( CASING PULD P Clear rig floor and bring casing equipment to floor Page 2 of 32 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:30 19:30 3.00 2,735 2,735 SURFA( CASING RURD P Rig up casing equipment and make dummy run with casing hanger and landing joint. 19:30 00:00 4.50 2,735 2,735 SURFA( CASING RNCS P Run casing per detail to 1610' 01/24/2010 Finish running surface casing. Circulate and condition mud. Cement per program. CIP at 11:45 hrs 1/25/2010. Pressure test casing to 3500 psi for 30 minutes. Nipple down riser and nipple up wellhead. Test head to 1000 psi for 10 minutes. 00:00 00:30 0.50 2,735 2,735 SURFA( CASING CIRC P Continue circulating two bottoms up. Increase rate to 6 bpm @ 350 psi. 00:30 03:30 3.00 2,735 2,735 SURFA( CASING RNCS T Work casing around curve from 1620' to 1645' 03:30 05:15 1.75 2,735 2,735 SURFA( CASING RNCS P Coontinue running surface casing to 2725' P/U 140k, S/O 90k 05:15 06:30 1.25 2,735 2,735 SURFA( CEMEN' RURD P Rig down fill up tool and make up cement head. 06:30 09:15 2.75 2,735 2,735 SURFA( CEMEN" CIRC P Break circulation and stage rate up to 6 bpm at 470 psi. 09:15 12:00 2.75 2,735 2,735 SURFA( CEMEN" PUCM P Pre -job safety meeting. Pump 1 cement per plan and bum plus at` 11:45 hrs 1 -24 -2010 12:00 13:00 1.00 2,735 2,735 SURFA( CEMEN PRTS P Pressure test casing to 3500 psi for 30 minutes. Flush riser and flow line. Drain riser and lines 13:00 15:45 2.75 2,735 2,735 SURFA( DRILL RURD P Pre -job safety meeting, Rig down casing and cementing equipment. Lay down landing joint and riser. Clear rig floor. Change bails. 15:45 17:45 2.00 2,735 2,735 SURFA( WHDBO NUND P Nipple down 20" annular, adapter flange, and diverter spool. Clear cellar. 17:45 00:00 6.25 2,735 2,735 SURFA( WHDBO PRTS P Nipple up wellhead and test to 1000 psi for 10 minutes. 01/25/2010 Finished testing BOPE to 25/3500 psi. Test witnessed by Chuck Scheve, AOGCC. Cleared floor. Rigged up Geo -span unit. Picked up 5" drillpipe. 00:00 01:45 1.75 2,735 2,735 SURFA( WHDBO BOPE P Rig up BOP test equipment 01:45 06:30 4.75 2,735 2,735 SURFA( WHDBO BOPE P Test BOPE. Test all components to 250 psi /3500 psi. Test accumulator. All tests witnessed by Chuck Scheve, AOGCC 06:30 07:30 1.00 2,735 2,735 SURFA( WHDBO RURD P Rig down BOP test equipment. Set wear bushing (9.25" i.d.) 07:30 08:00 0.50 2,735 2,735 SURFA( DRILL RURD P Install short bales and elevators 08:00 10:30 2.50 2,735 2,735 SURFA( DRILL RURD P Prejob safety meeting. Remove sub rack. Pick up and install Geo -span unit. 10:30 14:45 4.25 2,735 2,735 SURFA( DRILL PULD P Pick up 81 jts of 5" drillpipe and run in the hole. POOH and SLM 14:45 15:15 0.50 2,735 2,735 SURFA( DRILL PULD P Pick up tools and plumb Geo -span unit 15:15 23:30 8.25 2,735 2,735 SURFA( DRILL PULD P Pick up up 180 jts of 5" drillpipe, rack in the derrick and SLM. 23:30 00:00 0.50 2,735 2,735 SURFA( DRILL OTHR P Clear rig floor Page 3 of 32 1111 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01/26/2010 24 hr Summary Pick up rotary steerable BHA and run in the hole picking up singles. Drill shoe track and twenty feet of new hole to 2755'. CBU and perform FIT to 18.0 ppg EMW. Displace hole with new LSND mud. Drill from 2755' to 3070' (2667' TVD) 00:00 01:00 1.00 2,735 2,735 SURFA( DRILL PRTS P Pressure test Geo -span unit and hardline 01:00 04:15 3.25 2,735 2,735 SURFA( DRILL PULD P Make up rotary steerable BHA and upload MWD 04:15 05:30 1.25 2,735 2,735 SURFA( DRILL PULD P Continue making up BHA 05:30 06:30 1.00 2,735 2,735 SURFA( DRILL PULD P Load nuclear sources in MWD tools 06:30 07:30 1.00 2,735 2,735 SURFA( DRILL PULD P Continue making up BHA. Break in seals on Geo - pilot. Down link Geo -pilot 07:30 10:00 2.50 2,735 2,735 SURFA( DRILL TRIP P Run in the hole with BHA. Lay down 4 joints 5" HWDP. Run in hole picking up singles from the pipe shed. 10:00 12:15 2.25 2,735 2,735 SURFA( DRILL SVRG P Pre -job safety meeting. Cut and slip drilling line. Service drawworks and top drive 12:15 13:15 1.00 2,735 2,735 SURFA( CEMEN" COCF P Run in the hole from 2440' to 2532'. Wash and ream to top of cement at 2615'. Drill green cement and tag plugs at 2640'. 13:15 16:45 3.50 2,735 2,735 SURFA( CEMEN" COCF P Drill wiper plugs from 2640' to 2721'. Clean out rat hole to 2735'. 16:45 17:00 0.25 2,735 2,755 SURFA( DRILL DDRL P Drill from 2735' to 2755'. 550 gpm, 1600 psi, P/U 97k, S/O 90k 17:00 17:45 0.75 2,755 2,755 SURFA( DRILL CIRC P Circulate bottoms up, rack one stand back. Blow down top drive. Rig up for FIT 17:45 18:45 1.00 2,755 2,755 SURFA( DRILL FIT P Perform FIT to 18.0 ppg EMW, w/ 9.7 ppg mud, 1070 psi, 2475' TVD 18:45 19:15 0.50 2,755 2,755 INTRM1 DRILL CIRC P Displace well with clean LSND 19:15 00:00 4.75 2,755 3,070 INTRM1 DRILL DDRL P Directional drill from 2755' to 3070' MD (2667 TVD) ADT =2.46 P/U = 115k, S/O = 95k, ROT = 98k, Torque on = 8k, Torque off = 5k 01/27/2010 Drill from 3070' to 4875' MD (3502' TVD) 00:00 12:00 12.00 3,070 3,845 INTRM1 DRILL DDRL P Drill from 3070' to 3845' MD (3060' TVD). ADT = 7.36 hrs, Pumped 3 -35 bbl nutplug sweeps. P/U = 108k, S/O = 96k, ROT = 104k, Torque on = 5k, Torque off = 3k, ECD = 10.8 ppg EMW, Max connection gas = 418 units, 12:00 00:00 12.00 3,845 4,875 INTRM1 DRILL DDRL P Drill from 3845' to 4875' MD (3502' TVD) ADT = 7.63 hrs, P/U + 116k, S/O = 99k, ROT = 108k, Torque on = 8 k, Torque off = 6k, Max connection gas 136 units, ECD = 11.0 ppg EMW 01/28/2010 Drill from 4875' to 5010'. change saver sub. Drill from 5010' to 6513'. Page 4 of 32 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 4,875 5,010 INTRMI DRILL DDRL P Drill from 4875' to 5010' MD (3560' TVD) ADT = .75 01:00 02:30 1.50 5,010 5,010 INTRMI RIGMNT SVRG P Back ream one sand and stand back in derrick. Change saver sub in top drive and work on DC module in #3 SCR. 02:30 12:00 9.50 5,010 5,560 INTRMI DRILL DDRL P Drill from 5010' to 5560' MD (3796' TVD) ART = 6.71 P/U = 126k, S/O = 103k, ROT = 113k, Torque = 8k ft-Ibs, Torque off = 9k, Max trip gas on bottoms up = 2042 units, ECD = 11.4 ppg EMW, Pumped 3 - 30 bbl SAPP - Nutplug sweeps 12:00 00:00 12.00 5,560 6,513 INTRMI DRILL DDRL P Drill from 5560' to 6513' MD (4231' TVD) ADT = 6.96 hrs, P/U 160k, S/O 100k, ROT = 120k, Torque on = 10k ft-Ibs, Torque off = 10k ft -Ibs, Max connection gas = 369 units. ECD = 10.6 units, 01/29/2010 Drill from 6513' to 6975'. Circulate, back ream and stand a stand back /hr while waiting on phase 3 weather. Run in the hole and drill from 6975' to 7716'. 00:00 05:00 5.00 6,513 6,975 INTRMI DRILL DDRL P Drill from 6513' to 6975' MD (4455' TVD) ART = 3.72 hrs. P/U = 147k, S/O = 113k, ROT = 127k, Torque on = 8k ft-Ibs, Torque off = 6k ft-Ibs, ECD = 10.5 ppg Max connection gas = 194 units 05:00 15:00 10.00 6,975 6,975 INTRMI DRILL CIRC T Circulate and back ream out of the hole. Rack back one stand every hr from 6975' to 6052' at 430 gpm, 1000 psi, 70 rpm, 15:00 15:45 0.75 6,975 6,975 INTRMI DRILL TRIP T Trip in the hole to 6883'. Wash and ream to 6975' 15:45 23:00 7.25 6,975 7,716 INTRMI DRILL DDRL P Drill from 6975' to 7716' MD (4783' TVD). ADT = 4.43, P/U = 148k, S/O = 116k, ROT = 132k, Torque on = 10k ft-Ibs, Torque off = 7k ft -Ibs, Max trip gas 97 units ECD = 10.9 ppg EMW, 23:00 00:00 1.00 7,716 7,716 INTRMI DRILL RGRP T Tripped high line breaker. Increased amps and re- energized 01/30/2010 Drill from 7715' to 9845' (5752' TVD) 00:00 12:00 12.00 7,716 8,690 INTRMI DRILL DDRL P Drill from 7716' to 8690' MD (5526' TVD) ART = 7.57, P/U + 160k, S/O = 124k, ROT = 140k, Torque on = 10k ft-Ibs, Torque off = 9k ft-Ibs, ECD = 10.t ppg EMW, Max gas = 91 units, 12:00 00:00 12.00 8,690 9,845 INTRM1 DRILL DDRL P Drill from 8690' to 9845' MD (5752' TVD) ART = 8.16, P/U = 175k, S/O = 130k, ROT = 150k, Torque on = 15k ft-Ibs, Torque off = 15k ft-Ibs, ECD = 10.9, Max gas = 117 units, 01/31/2010 Drill from 9845' to 11420'. Had to work on Top Drive breaker Page 5 of 32 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:00 2.00 9,845 10,015 INTRM1 DRILL DDRL P Drill from 9845' to 10015' MD (TVD = 5827') 02:00 04:00 2.00 10,015 10,015 INTRM1 DRILL RGRP T Reset breakers on Top Drive. Adjust voltage 04:00 12:00 8.00 10,015 10,450 INTRM1 DRILL DDRL P Drill from 10015' to 10450' MD (6024' TVD) ART = 5.79 hrs, P/U = 185k, S/O = 173k, ROT = 155k, Torque on = 15k, Torque off = 16k, ECD =10.5 ppg EMW, Max gas = 121 units 12:00 14:45 2.75 10,450 10,736 INTRMI DRILL DDRL P Drill from 10450' to 10736' MD 14:45 15:15 0.50 10,736 10,736 INTRMI DRILL CIRC T Circulate and trouble shoot MWD 15:15 20:30 5.25 10,736 11,238 INTRM1 DRILL DDRL P Drill from 10736' to 11238 MD Mud returns cut to 8.8 ppg. Connection gas increased to 1757 units 20:30 21:30 1.00 11,238 11,238 INTRM1 DRILL CIRC P Circulate and increase mud weigh to 9.9 ppg. 21:30 00:00 2.50 11,238 11,420 INTRM1 DRILL DDRL P Drill from 11238' to 11420' MD (6470' TVD) ART = 6.83 hrs, P/U = 200k, S/O = 135k, ROT = 160k, Torque on = 15k, Torque off = 19k, ECD = 10.7 ppg EMW, Max gas = 1757 units 02/01/2010 Drill from 11420' to 12600'. Had increase in flow corresponding to increase in gas. Shut well in (SIDPP = 140 psi, SICP = 100 psi) Circulate gas out on choke with 710 psi at 40 spm. Open well- static. Drill pipe stuck and worked it free. Circulate and condition mud. Increase mud weight to 10.6 ppg. 00:00 01:30 1.50 11,420 11,606 INTRM1 DRILL DDRL P Drill from 11420' to 11606' MD (6558' TVD) 01:30 03:30 2.00 11,606 11,606 INTRM1 DRILL CIRC P Circulate 3 bottoms up while swapping mud to black products. Back ream out of the hole to 11420'. Wash and ream back to 11606' 03:30 12:00 8.50 11,606 12,200 INTRMI DRILL DDRL P Drill from 11606' to 12200' (6799' TVD) ART = 6.7 hrs, P/U = 217k, S/O = 137k, ROT = 166k, Torque on = 19k, Torque off = 18k, ECD = 11.1 ppg EMW, Max gas = 380 units, 12:00 16:30 4.50 12,200 12,600 INTRMI DRILL DDRL P Drill from 12200' to 12600' (6889 TVD) ART = 2.98 hrs, P/U = 230k, S/O = 125k, ROT = 167k, Torque on = 20k, Torque off = 22k, ECD = 11.0 ppg EMW, Max gas = 380 units, 16:30 21:30 5.00 12,600 12,600 INTRM1 DRILL CIRC T After drilling through Kuparuk Formation at 12445' made connection at 12533'. Slight flow while making connection.. Drilled ahead and watched bottoms up -peak gas 4953 units and dropping with no increase in flow. Gas spiked again at 4052 units with flow increase. Shut well in -- SIDPP =140 psi, SICP = 100 psi. Circulate through choke at 40 spm w/ 710 psi. Open well- static. Rotated pipe through annular at 10 rpm every hour while circulating through choke. 21:30 21:45 0.25 12,600 12,600 INTRM1 DRILL CIRC T Drill pipe stuck. Worked pipe free Page 6 of 32 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:45 00:00 2.25 12,600 12,600 INTRMI DRILL CIRC P Circulate and condition mud. Increase rate to 613 gpm at 2650 psi. 02/02/2010 Circ at 12,600' while increase mud weight f/ 10.3 ppg to 10.6 ppg, Monitor well - Static, CBU - No noticeable gas increase on CBU, Drill f/ 12,600' to 12,817' MD / 6,924' TVD, Circ & wait on weather due to phase 3 weather. 00:00 03:45 3.75 12,600 12,600 INTRM1 DRILL CIRC P Increase mud wt to 10.6 ppg. Reduce pump rates from 612 gpm to 550 gpm due to ECD. Max ECD - 11.4 ppg. Reciprocate pipe from 12,590' to 12,533'. 03:45 05:00 1.25 12,600 12,600 INTRMI DRILL CIRC P Monitor well. Static. CBU at 550 gpm - 2200 psi - 120 rpm. No influx or gas increase at bottoms up. 05:00 11:00 6.00 12,600 12,817 INTRMI DRILL DDRL P Drill from 12,600' to 12,817' (6924 TVD) ART = 3.14 hrs, P/U = 232k, S/O = 117k, ROT = 162k, Torque on = 18k, Torque off = 16k, ECD = 11.4 ppg EMW, Max gas = 650 units, 11:00 12:00 1.00 12,817 12,722 INTRMI DRILL CIRC T Back ream out of hole slow while waiting on weather to clear. 12:00 18:30 6.50 12,722 12,258 INTRM1 DRILL CIRC T Back ream out of hole slow while waiting on weather to clear. 550 gpm @ 2400 psi, 140 RPM w/ 15 to 17K Tq. 18:30 00:00 5.50 12,258 12,350 INTRM1 DRILL CIRC T While still waiting on weather "Lost Top Drive Rotation on Top Drive Due to electrical problem ". Continue to circ at rate of 550 gpm @ 2400 psi w/ no rotation. Gas 60 units. Work pipe f/ 12,350' to 12,318'. Trouble shooting top drive problem. 02/03/2010 Finish waiting on weather and repairing top drive, RIH to 12,817' Drill to 12,855' with excess torque (Possible out of cuage bit), POOH & Back ream out to 12,443'. 00:00 05:00 5.00 12,350 12,350 INTRM1 DRILL CIRC T While still waiting on weather "Lost Top Drive Rotation on Top Drive Due to electrical problem ". Continue to circ at rate of 550 gpm @ 2400 psi w/ no rotation. Gas 90 units. Work pipe f/ 12,350' to 12,254'. Trouble shooting top drive problem. 05:00 16:30 11.50 12,350 12,350 INTRM1 DRILL CIRC T Weather improved to Phase 2 but Top Drive Still unable to rotate. Continue to reciprocate pipe f/ 12,350' to 12,254' & circ at rate of 550 gpm @ 2400 psi while trouble shoot top drive. Rig on down time. 16:30 17:15 0.75 12,350 12,350 INTRM1 DRILL REAM T Monitor well, Precautionary ream f/ 12,350' to 12,254' at rate of 550 gpm @ 2400 psi, 150 RPM w/ 23K tq. 17:15 18:30 1.25 12,350 12,817 INTRM1 DRILL TRIP T RIH to 12,814', Attempt to survey and hole packing off and torqueing up, Stand back 1 stand and clean hole up, Stage pumps back up to 510 gpm w/ 150 RPM w/ 23 to 25K Tq., Had 3' fill on btm. Page 7 of 32 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 22:30 4.00 12,817 12,855 INTRM1 DRILL DDRL P Direction Drill f/ 12,817' to 12,855' MD / 6930' TVD, Up 225K, Dn 125K, Rot 155K, 150 RPM w/ 25K Tq, Ave. ECD's 11.3 ppg, Max Gas 347 Units, ART= 1.71 hrs. Note; Torue off btm normal 20K, Torque attempting to drill 25K and stalling rotary with no improvement. Decision made to check for out of guage bit. 22:30 00:00 1.50 12,855 12,443 INTRMI DRILL REAM T Monitor well - Static, Back Ream out of hole to above HRZ at rate of 550 gpm @ 2200 psi, 110 RPM 02/04/2010 Continue to POOH, Back ream f/ 12443' to 11600', Monitor well - OK, CBU - no gas, POOH to 10315', Back ream to 9941', POOH to 7905', Back ream to 7719, POOH to 7164', Back ream to 4199', POOH to 2717', Monitor well - OK, CBU 3 times, POOH & LID Ghost reamer ©1834' 00:00 03:00 3.00 12,443 11,600 INTRMI DRILL REAM T POOH to Check Bit due to excessive toque while drilling, Back ream out of the hole f/ 12,443' to 11,600' at rate of 550 gpm @ 2200 psi, torque ranging f/ 20K to 25K 03:00 03:15 0.25 11,600 11,600 INTRMI DRILL OWFF T Monitor well 15 min. - Static. 03:15 04:15 1.00 11,600 11,423 INTRM1 DRILL CIRC T Circ bottom's up to check gas while slowly back reaming f/ 11,600' to 11,423' at rate of 550 gpm @ 2200 psi w/ 110 rpm - No gas increase. 04:15 06:30 2.25 11,423 10,315 INTRMI DRILL TRIP T POOH on elevators f/ 11,423' to 10,315' (Tight - 40K over pull) 06:30 07:45 1.25 10,315 9,941 INTRM1 DRILL REAM T Back ream out of the hole f/ 10,315' to 9,941' at rate of 550 gpm @ 2100 psi. 07:45 10:45 3.00 9,941 7,905 INTRM1 DRILL TRIP T POOH on elevators f/ 9,941' to 7,905' (Started pulling tight) 10:45 11:30 0.75 7,905 7,719 INTRMI DRILL REAM T Back ream out of the hole f/ 7,905' to 7,719' at rate of 550 gpm @ 1800 psi. 11:30 12:00 0.50 7,719 7,119 INTRMI DRILL TRIP T POOH on elevators f/ 7,719' to 7,164' (Started pulling tight - 60K over) 12:00 20:30 8.50 7,119 4,199 INTRMI DRILL REAM T Back ream out of the hole f/ 7,164' to 4,199' at rate of 550 gpm @ 1800 psi, 120 rpm (Mild packing off) Slowed pulling rate down periodically to let hole clean up and to condition mud, ECD's as high as 11.9 ppg. 20:30 21:30 1.00 4,199 2,717 INTRM1 DRILL TRIP T POOH on elevators f/ 4,199' to 2,717' (Shoe at 2,725'). 21:30 22 :00 0.50 2,717 2,717 INTRM1 DRILL CIRC T Monitor well - Static, Circ casing clean with 3 time bottom's up at rate of 550 gpm @ 1800 psi & 120 rpm. 22:00 00:00 2.00 2,717 1,834 INTRM1 DRILL TRIP T POOH on elevators f/ 2,717' to 1,834', Lay down Ghost Reamer. 02/05/2010 POOH, Stand back & UD BHA, Check bit- OK, Pull W.B., Set test plug & Test Hydril to 250 low & 2500 psi high, M/U BHA #3, RIH to 2706', Slip & cut drlg line 110', Service rig & check top drive torque (8K off- adjust same), RIH to 8079', C & C mud to balance mud wt., RIH to 12711', Wash to 12803' & C & C mud to balance mud wt. Page 8 of 32 • Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 00:00 00:30 0.50 1,834 759 INTRMI DRILL TRIP T POOH on elevators f/ 1,834' to 759', Monitor well - Static. 00:30 02:00 1.50 759 95 INTRM1 DRILL TRIP T Stand back HWDP, PJSM on removing RA Source, Stand back Flex Collars, Remove RA source. 02:00 05:00 3.00 95 0 INTRMI DRILL PULD T Down load MWD, Check bit - OK, Lay down BHA, Change out probe in TM collar. 05:00 07:30 2.50 0 0 INTRM1 WHDBO BOPE P Pull wear bushing, Set test plug w/ 5" DP, Rig & test Hydril to 250 psi low & 2500 psi high due that it was used to kill well on 2/1/10. 07:30 11:00 3.50 0 95 INTRM1 DRILL PULD T Pick up Mud motor & Change setting to 1.22 deg., Make up BHA #3 & orient same. 11:00 14:30 3.50 95 2,706 INTRM1 DRILL TRIP T RIH to 853' & Shallow test MWD - OK, RIH to 2,706', Fill pipe, Blow down top drive. 14:30 17:00 2.50 2,706 2,706 INTRM1 RIGMNT SLPC P Cut & slip drilling 110', Service top drive & drawworks, Check torque on top drive & forund torque reading 8,000 ft/Ibs high, Adjust same. 17:00 20:00 3.00 2,706 8,079 INTRM1 DRILL TRIP T RIH to 8,079' (No problems - hole in good shape), Fill pipe © 4,373' & 6,226'. 20:00 21:00 1.00 8,079 8,079 INTRM1 DRILL CIRC T Fill pipe, Circ and Cond mud & balance mud weight to 10.6+ ppg (Mud weight coming out as high as 10.9+ ppg in spots) 21:00 23:00 2.00 8,079 12,711 INTRMI DRILL TRIP T RIH to 12,711' (No problems - hole in good shape), Fill pipe @ 10,023'. 23:00 00:00 1.00 12,711 12,803 INTRM1 DRILL CIRC P Break circ, Stage pumps up to 400 gpm @ 1800 psi, Wash & ream f/ 12,711' to 12,803', Continue to circ bottom's up to balance mud weight to 10.6 ppg due to ECD's 11.6 ppg prior to increasing pump rate. 02/06/2010 CBU © 12803', Wash to 12855' & CBU, Drill f/ 12855' to 12997' (7" csg TD), Circ hole clean, Wipe hole to 11598', Circ hole clean, Spot csg lube pill & pump out to 11598', POOH on elevators to 2706' (Hole in good shape) 00:00 01:00 1.00 12,803 12,803 INTRMI DRILL CIRC T CBU @ 12,803' 450 GPM 2100 psi 100 RPM Torq 10K 01:00 02:00 1.00 12,803 12,855 INTRM1 DRILL REAM T Washed and reamed 12,803' to 12,855" 550 gpm 2500psi 100 rpm Torq 12K 02:00 07:30 5.50 12,855 12,997 INTRM1 DRILL DDRL P Direction Drill f/ 12,855' to 12,997' MD / 6945' TVD, Up 220 K, Dn 122 K, Rot 160 K, 550 gpm © 2700 psi, 100 RPM w/ 17 K Tq,on 15 K off Ave. ECD's 11.3 ppg, Max Gas 57 Units, ART= .61 hrs. AST= 1.52 ADT = 2.13 hrs 07:30 10:30 3.00 12,997 12,525 INTRM1 DRILL CIRC P CBU X 3 @ 12,997' to 12,525' @ 550 GPM 2600 psi 100 RPM Torq 15 K Set back 1 stand each 1/2 Hr. Page 9 of 32 . . Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:30 12:30 2.00 12,525 11,598 INTRMI DRILL WPRT P POOH backreaming from 12,525' to 11,598' 550 gpm 2600 psi, 100 rpm w/ 14K Tq, Pulling rate 25/30 fph. 12:30 13:30 1.00 11,598 12,997 INTRM1 DRILL WPRT P RIH f/ 11,598' to 12,997' - No problems. 13:30 16:00 2.50 12,997 12,997 INTRM1 DRILL CIRC P Circ hole clean f/ 7" casing w/ 2+ times bottom's up at rate of 550 gpm @ 2600 psi, 100 rpm w/ 15K Tq, ECD's 11.27 ppg, Spot casing lube pill at bit. 16:00 17:45 1.75 12,997 11,598 INTRMI DRILL TRIP P POOH while pumping 2.5 bpm - 3 min. /stand while spotting lube pill on bottom f/ 12,997' to 11,598', Up 210K, Dn 125K, Rot 165K. 17:45 18:00 0.25 11,598 11,598 INTRM1 DRILL TRIP P Monitor well- Static, Blow down top _ drive. 18:00 00:00 6.00 11,598 2,706 INTRMI DRILL TRIP P POOH on elevators f/ 11,598' to 2,706' (No tight hole - Hole in very good shape), Monitor well - Static. 02/07/2010 POOH & stand back HWDP & Flex collars, Remove RA sources, Down load MWD, L/D BHA, Pull wear bushing & Set test pulg, Change top pipe rams to 7 ", Test Rams & Hydril to 250 low & 3500 psi on Rams & 2500 psi on Hydril, Set thin wall wear bushing, Rig & run 7" csg to 2633', Circ pipe vol., Run 7" csg to 6102', Circ BTU, Run 7" csg to 8386'. 00:00 01:00 1.00 2,706 761 INTRMI DRILL TRIP P Continue POOH from 2,706' to 761'. 01:00 02:00 1.00 761 85 INTRMI DRILL PULD P Racked back 6 stands HWDP and laid down 2 jts. 02:00 06:30 4.50 85 0 INTRM1 DRILL PULD P PJSM. Unloaded Nukes and downloaded MWD. Finished lay down BHA. 06:30 07:00 0.50 0 0 INTRM1 WHDBO BOPE P Pulled wear ring and set test plug. 07:00 09:30 2.50 0 0 INTRMI WHDBO BOPE P Changed rams to 7" and tested to _ 250/3500 psi. OK, Test Hydril to 250/2500 psi. OK. 09:30 10:30 1.00 0 0 INTRM1 WHDBO BOPE P Pulled test plug and set thin wear ring. Cleaned up Rig Floor. 10:30 12:15 1.75 0 0 INTRM1 CASING RURD P Rigged up to run 7" casing. 12:15 12:30 0.25 0 INTRM1 CASING SFTY P PJSM on running casing. 12:30 15:30 3.00 0 2,633 INTRM1 CASING RNCS P Pick up & Make up 7 ", 26# Shoe track with Halliburton HES Baffle Adapter & Baffle Collar, RIH w/ 7" csg as per detail pick up all centralizers as detail to 2,633'. 15:30 16:15 0.75 2,633 2,633 INTRM1 CASING CIRC P Circ 110 bbls casing volume at 5 bpm @ 400 psi. 16:15 19:30 3.25 2,633 6,102 INTRM1 CASING RNCS P RIH w/ 7" casing following suggested running speed schedule to 6,102'. 19:30 20:30 1.00 6,102 6,102 INTRMI CASING CIRC P Circ bottom's up maintaining mud weight 10.6 ppg at rate of 5 bpm @ 500 psi. 20:30 00:00 3.50 6,102 8,386 INTRMI CASING RNCS P RIH w/ 7" casing following suggested running speed schedule to 8,386'. 02/08/2010 Finish running 7" csg to 12986', Circ & cond mud, Cement 7" w/ 2 stages, Set & test pack off, Clear floor of tools, Change upper & lower rams, LOT 7" x 9 -5/8" ann to 15.1 EMW, Flush ann w/ 85 bbls fresh water, Freeze protect ann w/ 60 bbls diesel to 2060' TVD, Begin BOP Test. Page 10 of 32 . • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 8,386 9,196 INTRM1 CASING RNCS P RIH w/ 7" casing following suggested running speed schedule to 9,196'. 01:00 01:30 0.50 9,196 9,196 INTRM1 CASING CIRC P Circ 100 bbls mud maintaining mud weight 10.6 ppg at rate of 5 bpm @ 500 psi. 01:30 04:30 3.00 9,196 11,614 INTRMI CASING RNCS P RIH w/ 7" casing following suggested running speed schedule to 11,614'. 04:30 05:00 0.50 11,614 11,614 INTRMI CASING CIRC P Circ 100 bbls mud maintaining mud weight 10.6 ppg at rate of 5 bpm @ 650 psi. 05:00 07:00 2.00 11,614 12,960 INTRMI CASING RNCS P RIH w/ 7" casing following suggested running speed schedule to 12,960', Up 315K, Dn 115K, Casing took correct displace going in hole. - No problems running casing. 07:00 07:15 0.25 12,960 12,986 INTRMI CASING RNCS P Make up Landing joint & Hanger, Land casing on depth @ 12,986'. 07:15 08:00 0.75 12,986 12,986 INTRM1 CEMEN" PULD P lay down Frank's Fill up tool, Make up Dowell cement head. 08:00 10:30 2.50 12,986 12,986 INTRM1 CEMEN" CIRC P Circ & Cond. Mud, Stage rate f/ 3 bpm @ 510 psi to 7 bpm @ 900 psi, Up 265K, Dn 110K. 10:30 11:00 0.50 12,986 12,986 INTRMI CEMEN" SFTY P PJSM with all crew members & Dowell on cementing 7" casing. Page 11 of 32 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 15:30 4.50 12,986 12,986 INTRMI CEMEN" PUCM P Turn over to Dowell, Pump First Stage w/ 5.0 bbls CW100 at rate of 5.0 bpm © 370 psi, Test lines to 3600 psi - OK, Continue pumping to total of 39.3 bbls CW100 at rate of 5.0 bpm © 450 psi, Mix & pump 30.5 bbls 12.0 ppg Mud PUSH mixed to 12.0 ppg at rate of 5.5 bpm @ 500 '7 psi, Shut down, Drop bottom plug & Reload head with 2nd plug, Batch mix cement to 15.8 ppg, Pump total >• of 62.8 bbls (304 sacks) Class "G" cement w/ 0.2% D46, 0.3% D65, ' C 0.11 %B155,0.4 %D167 -1.16 ft3 /sk Yield at rate of 5.0 bpm @ 500 psi, Drop top plug, Pump 20 bbls fresh water followed by 479.6 bbls 10.6 ppg mud at rate of 7 bpm @ 650 psi, Bump plug w/ 1200 psi, Check floats- OK, First Stage C.I.P © 13:30 hrs 2/8/10, Calculated TOC @ 11,900', Worked casing 10' to 15' while cementing until last 4 bbls prior to bumping plug. Pressure up to 3200 psi to open Stage Collar © 6800', Load 3rd plug. Circ bottom's up at rate of 7.5 bpm © 350 psi. Pump 29.1 bbls CW100 at rate of 4.5 / Z bpm @ 250 psi followed by 35.9 bbls MudPUSH mixed at 12.0 ppg at rate 9-11 of 4.5 bpm @ 250 psi, Batch mix cement & pump total of 56.1 bbls (271 sacks) Class "G" cement w/ 0.2% D46, 0.3% D65, 0.8% S2 - 1.16 ft3 /sk Yield at rate of 5.0 bpm @ 300 psi, Drop closing plug, Pump 20 bbls fresh water followed by 243.6 bbls 10.6 ppg mud at rate of 7 bpm @ 400 psi, Bump plug w/ 900 psi, C.I.P @ 15:30 hrs 2/8/10, Calculated TOC @ 4,705'. 15:30 16:30 1.00 12,986 12,986 INTRMI CEMEN" PULD P Rig down Cement head, Clear Frank's fill up tool & Cement head from floor, Lay down janding jt. 16:30 18:00 1.50 12,986 12,986 INTRM1 WHDBO OTHR P Rig & Pull wear bushing, Install 7" x 9 -5/8" Pack off & test same- OK 18:00 21:30 3.50 12,986 12,986 INTRM1 WHDBO BOPE P PJSM, Change top rams to 3 -1/2" x 6" VBR's, Change btm rams to 4 " Rig lines to 7" x 9 -5/8" annulas, Perform LOT of 15.1 EMW, Flush annulas to a total of 85bbls (110 %) tlA LoT Page 12 of 32 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:30 23:00 1.50 12,986 12,986 INTRMI WHDBO BOPE P Clear rig floor of Casing slips, Elevators, Tongs, Bails & 5" subs, Pick up 4" subs & floor valves, Short bails & install same. Rig Little Red & freeze protect 7" x 9 -5/8" annulas w/ 60 bbls diesel to 2125' MD / 2060' TVD. 23:00 00:00 1.00 12,986 0 INTRMI WHDBO BOPE P Install test plug, Rig to test BOPE, Fill stack with water & get air out of system. 02/09/2010 Finish testing BOPE - LD 5" DP - PU 18 jts 4" DP & Std back - MU clean out assembly - RIH w/ CO assembly picking up 4" DP to 741' 00:00 05:00 5.00 0 0 INTRMI WHDBO BOPE P Test BOPE. Test all components & Rams to 250 psi /3500 psi. Test Bag 250/2500 psi Test accumulator. Pulled test plug and ran Wear Bushing. Witness waived by Jeff Jones, AOGCC. 05:00 06:00 1.00 0 0 INTRMI WHDBO RURD P Blew down lines and choke manifold. Set Mousehole and RU to lay down 5" DP. 06:00 11:30 5.50 0 0 INTRMI DRILL PULD P Laid down 5" Drillpipe from Derrick via Mousehole. 11:30 12:00 0.50 0 0 INTRMI DRILL PULD P PU bit - XO & tools for BHA # 4 12:00 16:00 4.00 0 0 INTRMI DRILL PULD P Finish LD 5" DP 16:00 16:30 0.50 0 0 INTRM1 DRILL PULD P LD mouse hole -Re dres iron roughneck for 4" DP 16:30 16:45 0.25 0 0 INTRMI DRILL SFTY P PJSm on changing out saver sub 16:45 18:45 2.00 0 0 INTRM1 RIGMNT SVRG P Change TD saver sub f/ 4 1/2" IF to 4" XT -39 18:45 20:30 1.75 0 0 INTRM1 DRILL PULD P PU 18 jts. 4" DP f/ pipe shed & std back in derrick 20:30 23:00 2.50 0 303 INTRM1 DRILL PULD P MU clean out assembly ( bit - bit sub - stab - float sub - (3) non mag flex DC's - XO - jars - DC - bumper sub - (4) DC's to 303' 23:00 00:00 1.00 303 741 INTRM1 DRILL PULD P RIH w/ CO assembly - picking up 4" DP f/ pipe shed to741' 02/10/2010 Cont. RIH to 6748' - test csg to 1000 psi for 10 mins.- Wash down to stage collar @ 6800' - drill out SC & wash down to 7086' - test csg to 1000 psi - Cont. RIH to 12,773' (top of cmt) Circ & test csg to 3500 psi for 30 mins.- clean out shoe track & drill 20' new hole to 13,017' - Circ & perform FIT to 12.5 ppg EMW - POOH to 12,491' - string pulling 20 - 35 k over - Circ btms up 00 :00 05:30 5.50 741 6,748 INTRM1 DRILL PULD P RIH picking up 4" DP to 6,748' Tagged cement stringer. Tested casing to 1000 psi for 10 min. 05:30 10:00 4.50 6,748 7,086 INTRM1 CEMEN" COCF P Cleaned out down to Stage Collar @ 6,800'. Drilled out stage Collar and cleaned out to 7,086'. 260 gpm 860 psi 100 rpm wob 5 K. Tested casing 1000 psi for 10 min. OK. 10:00 10:30 0.50 7,086 6,748 INTRMI DRILL TRIP P POOH and stood back stands to 6,748'. 10:30 12:00 1.50 6,748 8,352 INTRM1 DRILL PULD P RIH picking up 4" DP from 6,748' to 8,352'. Page 13 of 32 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 15:45 3.75 8,352 12,773 INTRMI DRILL PULD P Cont. RIH w/ CO assembly picking up 4" DP f/ pipe shed f/ 8352' to 12,773' ( tagged top of cmt ) 15:45 16:30 0.75 12,773 12,773 INTRM1 DRILL CIRC P Establish circ & circ for 15 mins - Blow down TD - RU to test casing - Circ 16:30 17:45 1.25 12,773 12,773 INTRMI DRILL PRTS P Test 7" casino to 3500 psi for 30 , mins. ( Good Test) - RD test equipment - Blow down kill line 17:45 19:45 2.00 12,773 12,997 INTRMI CEMEN" DRLG P Clean out cmt f/ 12,773' to top of baffle collar @ 12,860' - Drill out baffle collar & clean out cmt to top of float collar @ 12,902' - Drill out float collar & clean out cmt to top of float shoe @ 12,894' - Drill out float shoe & clean out rat hole to 12.997' 19:45 20:30 0.75 12,997 13,017 INTRM1 DRILL DDRL P Drill 20' new hole from 12,997' to 13,017' - 250 gpm @ 1550 psi w/ 100 rpm ADT .58 hrs. 20:30 22:00 1.50 13,017 13,017 INTRM1 DRILL FIT P Circ btms up & condition mud for FIT y! - Blow down TD - RU for FIT - perform FIT to 12.5 ppq EMW w/ 10.35 ppq, mud w/ 780 psi applied pressure @ 6945' TVD - RD test equipment 22:00 00:00 2.00 13,017 13,017 PROD1 DRILL TRIP P Flow ck well (Static) POOH f/ 12,964' to 12,491' - hole took correct fill but pulling 20 - 35 k over - PU wt. 190 SO wt 135 - Assummed possible pieces of rubber f/ drilling wiper plugs - Circ btms up & rotate & recip pipe _ to try & clean up wellbore 02/11/2010 Cont. to circ to clean up possible rubber or junk around bit or stab - Attempt to POOH to 12,302' - improper hole fill - POOH w/ pump to 11,270' - flow ck slight flow - RIH to 12,894' - Circ btms up (no gas @ btms up - flow ck (static) POOH w/ pump to 11,551' - Attempt to POOH on elevators to 11,270' - improper hole fill - RIH to 12,984' - wash to 13,017' - Circ & cond. mud added lubes - POOH w/ pump & wo/ pump f/ 13,017' to 303' top of BHA) made several attempts to pull out on elevators with improper hole fill - Monitored well @ BHA for 30 mins. Static 00:00 00:30 0.50 12,491 12,149 PROD1 DRILL CIRC P CBU working pipe to get rid of debris alongside. 6 BPM @ 1200psi. PU Wt 225 SOW 135 K. 00:30 01:30 1.00 12,149 11,270 PROD1 DRILL TRIP P POOH with pump from 12,149' to 11,270' 3 BPM 500 psi. 01:30 02:30 1.00 11,270 12,964 PROD1 DRILL TRIP T Observed well slight flow. RIH to 12,964'. 02:30 03:30 1.00 12,964 12,964 PROD1 DRILL CIRC T CBU 8BPM @ 2500 psi. Gas 30 units. 03:30 05:30 2.00 12,964 11,551 PROD1 DRILL TRIP T POOH with pump from 12,964' to 11,551' 3 BPM 200 psi. 05:30 06:30 1.00 11,551 11,551 PROD1 DRILL TRIP T POOH on TT from 11,551' to 11,270'. Incorrect hole fill. RIH to 11,551'. 06:30 08:00 1.50 11,551 11,551 PROD1 DRILL CIRC T CBU 260gpm 1500 psi. 30 rpm w 10,000 FP torque. Rot torque was only 5 K when Shoe Track was drilled. 08:00 08:30 0.50 11,551 13,017 PROD1 DRILL TRIP T Continue RIH to TD to check for junk or gas. Page 14 of 32 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 10:00 1.50 13,017 13,017 PROD1 DRILL CIRC T Circulated and conditioned mud PH was 12 lowered to 10 added lube, worked pipe 260 gpm 1600 psi 40 - 70 rpm. Max gas 46 units. Flowcheck well static. 10:00 12:00 2.00 12,984 11,663 PROD1 DRILL TRIP T Pull up to 12,984' monitor well (static) POOH with pump 2 bbls /min @ 350 psi - PU wt. 200 k SO wt. 80 k from 12,984' to 11,643' - hole took correct fill 12:00 19:00 7.00 11,663 3,669 PROD1 DRILL TRIP T Cont. POOH w/ pump f/ 11,643' to 11,364' on elevators (hole fill short) POOH w/ pump f/ 11,364' to 7692' - POOH on elevators f/ 7692' to 7409' (hole fill short) POOH w/ pump f/ 7409' to 3669' pump rate 3 bbls /min @ 450 psi 19:00 19:45 0.75 3,669 3,669 PROD1 DRILL OWFF T Monitor well slight flow - well went static after 30 mins. - mud aired up again 19:45 23:30 3.75 3,669 303 PROD1 DRILL TRIP T Cont. to POOH w/ pump f/ 3669' to 303' @ 3 bbls /min @ 450 psi 23:30 00:00 0.50 303 303 PROD1 DRILL OWFF T Monitor well for 30 mins. Well static 02/12/2010 LD BHA # 4 - Flush stack - MU BHA # 5 - RIH to 5060' w/ pipe f/ pipe shed - RIH to 12,947' w/ pipe f/ derrick - Cut & Sllip drill line - Wash down to 13,017' - Change over to 9.3 ppg Flo Thru - Drilled 6 1/8" hole W/ GP to 13,262' - Took kick shut in well - Monitor pressure - Prep to circ out kick 00:00 01:30 1.50 303 0 PROD1 DRILL PULD P Laid down BHA and cleaned Rig Floor. 01:30 02:30 1.00 0 0 PROD1 DRILL OTHR P Picked up stack washer and washed ram cavities. Function tested rams. 02:30 06:30 4.00 0 382 PROD1 DRILL PULD P MU BHA # 5 (Geopilot) Uploaded MWD.Shallow test tools 06:30 10:00 3.50 382 5,060 PROD1 DRILL TRIP P RIH w/ BHA # 5 picking up remaining 4" DP f/ pipe shed to 5060'. Filled pip every 60 jts. 10:00 14:45 4.75 5,060 12,942 PROD1 DRILL TRIP P Cont. RIH w/ BHA # 5 w/ DP f/ derrick f/ 5060' to 12,942' ' - Filled pipe every 20 stds. 14:45 16:15 1.50 12,942 12,942 PROD1 RIGMNT SLPC P Cut & slip drill line - Service top drive 16:15 16:45 0.50 12,942 13,017 PROD1 DRILL WASH P Washed down f/ 12,942' to 13,017' 16:45 18:30 1.75 13,107 13,017 PROD1 DRILL CIRC P Change well over f/ 10.4 ppg LSND to 9.3 ppg Flo Thru @ 230 gpm © 1680 psi w/ 80 rpm's - PU wt. 163 SO wt. 92 Rot wt. 120 - Torque off btm 6 -7 k ft/Ibs - 18:30 19:00 0.50 13,017 13,017 PROD1 DRILL OWFF P Flow ck well while cleaning up under shakers - Observed slight flow Page 15 of 32 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 23:45 4.75 13,017 13,262 PROD1 DRILL DDRL P Drilled 6 1/8" hole w/ GP f/ 13,017' to 13,262' MD 6955' TVD ADT - 2.97 hrs ECD - 10.44 ppg Max gas - 55 units WOB 10/15 k RPM 120 GPM 230 @ 1750 psi String wt - PU 151 SO 104 Rot 129 Torque on /off btm. 5,500 / 3000 ft/Ibs Flow ck on connections - Observed slight flow @ 13,040' - 13,134' - 13,227' @ 13,227' Observed slight amount of oil - Began to weight up to 9.5 ppg Took Cassandra check shot surveys @ 13,243' & 13,263' 23:45 00:00 0.25 13,262 13,262 PROD1 WELCTL KLWL T Flow ck well - flowing w/ gas breaking out © surface - Shut - in well @ 2350 hrs. SIDPP - 20 psi SICP - 10 psi - Monitor pressures 10 mins. DPP - 20 psi CP - 20 psi 02/13/2010 Monitored shut -in pressures - open choke & pumped 12 bbls @ 1 bbl /min to fill gas buster - Shut down & close choke - bring on pump & open choke - Circ out influx using drillers method holding 560 psi on DP until 9.5 ppg mud in & out - Shut down & close choke - Bleed off pressure & opened Hydril - Circ & rsied mud wt. to 10.0 ppg - Drilled 6 1/8" hole f/ 13,262' to 13,794' - MWD computer crashed - Circ & work pipe while trouble shooting MWD computer problem 00:00 01:00 1.00 13,262 13,262 PROD1 WELCTL KLWL T Well shut in observing pressure build and weighting up mud to 9.5 PPG. 15 min SIDPP 80 psi SICP 100 psi. - Pumped 12 bbl mud @ 1 bbl /min @ 270 psi to fill gas buster - Shut down pump & close choke SIDPP 90 psi SICP 120 psi monitored for 15 mins - DPP 210 CP 240 01:00 05:30 4.50 13,262 13,262 PROD1 WELCTL KLWL T Bring on pump to 20 spm holding casing pressure constant until pump up to speed - Held DP prerssure of 560 psi & circulated influx out w/ 9.5 PPG mud following driller's method 05:30 06:30 1.00 13,262 13,262 PROD1 WELCTL KLWL T Well shut in observing pressure build and weighting up mud to 9.7 PPG. 15 min SIDPP 100 psi SICP 100 psi. -- final DPP 210 CP 230 06:30 12:00 5.50 13,262 13,262 PROD1 WELCTL KLWL T Bleed off pressure & opened Hydril - fluid level below top of Hydril - took 5 bbls to fill hole - Circ & weight up to 10.0 ppg @ 5 bbls /min @ 1600 psi rotate & recip pipe - 100 rpm - string wt. PU 153 SO 110 ROT 129 Page 16 of 32 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 21:00 9.00 13,262 13,794 PROD1 DRILL DDRL P Drilled 6 1/8" hole w/ GP f/ 13,262' to 13,794' MD 6931' TVD ADT 6.13 hrs. ECD 11.36 Max gas - 47 units WOB 10 -15 k RPM 120 GPM 230 @ 1825 psi String wt. PU 156 SO 94 ROT 127 Torque on /off btm.- 10,000/7,000 ft/Ibs Weighting up system to 10.2 ppg while drilling Connection @ 13,794' was static 21:00 00:00 3.00 13,764 13,764 PROD1 DRILL CIRC T MWD computer went down - trouble shoot problem - stood back 1 std to 13,764' - Circ & work pipe f/ 13,697' to 13,764' @ 230 gpm @ 1700 psi w /80 rpm - PUwt124 SOwt115 - torque8k 02/14/2010 Drilled 6 1/8' hole f/ 13,794' to 14,646' Lost returns crossed faults 14,593' & 14.643' - Slowed pumps & spotted LCM pill - regaing partial returns - Drilled 6 1/8" hole f/ 14,646' to 14,790' w/ losses & well breathing on connections - Lost returns @ 14,790' - Crossed faults @ 14,760' & 14,785' - slowed pumps & spotted LCM pill - regained returns - Drilled 6 1/8" hole f/ 14,785' to 14,876' w/ losses & well breathing on connections 00:00 12:00 12.00 13,794 14,470 PROD1 DRILL DDRL P Drilled 6 1/8" hole w/ GP f/ 13,794' to 14,470' MD 6914' TVD ADT 10.77 hrs. ECD 11.6 Max gas - 2104 units WOB 10 -15 k RPM 120 GPM 200 @ 1800 psi String wt. PU 160 SO 94 ROT 125 Torque on /off btm.- 12,000/8,000 ft/Ibs 12:00 14:15 2.25 14,470 14,646 PROD1 DRILL DDRL P Drilled 6 1/8" hole w/ GP f/ 14,470' to 14,646' MD 6908' TVD ADT - 2.29 hrs ECD - 11.6 Max 482 units WOB 10 -15 k RPM 120 GPM 205 @ 1800 psi String wt. PU 161 SO 88 ROT 126 Torque on /off btm.- 11,500 / 8,000 ft/Ibs 14:15 16:45 2.50 14,646 14,646 PROD1 DRILL CIRC T Lost returns @ 14,646' - Slowed pump to 2 bbl /min - Pumped LCM pill - Observed partial returns @ flow line Inital loss rate 120 bbls/ hr - w/ LCM pill @ BHA increased pump rate to 4 bbls /min Crossed faults @ 14,593' & 14,643' Page 17 of 32 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:45 18:45 2.00 14,646 14,790 PROD1 DRILL DDRL P Drilled 6 1/8" hole w/ GP f/ 14,646' to 14,790' MD 6909' TVD ADT - 1.82 hrs ECD - 11.5 Max Gas 475 units WOB 10 - 15 k RPM 120 GPM 180 @ 1550 psi String wt. PU 161 SO 88 ROT 126 Torque on /off btm.- 11,500/8,000 Well breathing on connections & taking fluid @ 82 bbls/ hr (average) Pumped 35 bbl LCM pill Adding 10 sks/ hr Dyanred 18:45 21:15 2.50 14,790 14,790 PROD1 DRILL CIRC T Lost returns @ 14,785' - lost approx. 120 bbls - slowed pump to 2 bbl /min - Mixed & pumped LCM pill - Slowed pump to 1.5 bbl /min - running very low on mud - take on mud - Increased pump to 4 bbls /min as pill reached BHA Crossed Faults @ 14,760' & 14,785' 21:15 00:00 2.75 14,790 14,876 PROD1 DRILL DDRL P Drilled 6 1/8" hole w/ GP f/ 14,790' to 14,876' MD 6909' TVD ATD - 2.44 hrs ECD 11.6 Max gas 1345 WOB 10/15 k RPM 120 GPM 180 @ 1680 psi String wt. PU 160 SO 89 ROT 123 Torque on /off btm.- 11,000 / 8,000 ft/Ibs well breathing on connections & hole taking fluid © 54 bbls /hrs ( average) Adding Dynared med. @ 10 sks / hr. Lost 580 bbls 10.2 ppg Flo Thru to well last 12 hrs 02/15/2010 Drilled 6 1/8" hole w/ GP f/ 14,876' to 14,945' w/ 70% deflection in GP trying to drop to 84° - Service top drive - Drilled 6 1/8" hole w/ GP f/ 14,945' to 14,966' w/ 70 % deflection in GP trying to drop to 84° Lost 682 bbls 10.2 ppg FloThru last 24 hrs.- 1262 bbls FloThru total Average loss rate 24 bbls /hr Page 18 of 32 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 14,876 14,920 PROD1 DRILL DDRL P Drilled 6 1/8" hole w/ GP f/ 14,876' to 14,920' MD 6910' TVD ADT - 7.63 hrs ECD 11.6 Max gas 1345 WOB 10/15 k RPM 120 GPM 180 @ 1680 psi String wt. PU 160 SO 90 ROT 123 Torque on /off btm.- 12,000 / 8,000 ft/Ibs well breathing on connections & hole taking fluid @ 40 bbls /hrs ( average) 12:00 18:15 6.25 14,920 14,945 PROD1 DRILL DDRL P Drill 6 1/8" hole w/ GP w/ 70 % deflection down f/ 14,920' to 14,945' MD 6911' TVD ADT - 5.24 hrs. ECD - 11.19 Max gas 80 units WOB 10/25k RPM 70 - 130 GPM 175 @ 1500 psi String wt. PU 158 So 90 Rot 125 Torque on /off btm. 11.5 k/8 k ft/Ibs 18:15 19:15 1.00 14,945 14,945 PROD1 DRILL SVRG P Service top drive 19:15 00:00 4.75 14,945 14,966 PROD1 DRILL DDRL P Drilled 6 1/8" hole w/ GP @ 70 % deflection down f/ 14,945' to 14,966' MD 6911' TVD ADT 4.46 hrs. ECD- 11.19 Max gas 40 WOB 10 - 25 k RPM 70 - 130 GPM 175 @ 1500 psi Torque on /off btm.- 11.5 k / 8 k ft/Ibs Lost 682 bbls 10.2 ppg FloThru past 24 hrs - total losses 1262 bbls Average loss rate 24 bbls /hr 02/16/2010 Drilled 6 1/8" hole w/ GP f/ 14,966' to 15,676' 00:00 12:00 12.00 14,966 15,015 PROD1 DRILL DDRL P Drilled 6 1/8" hole w/ GP @ 70 - 90 % deflection to drop f/ 14,966' to 15015' MD 6914' TVD ADT 9.10 hrs ECD 11.4 Max gas 61 WOB 10 RPM 120 GPM 173 @ 1500 psi String wt. PU 163 SO 90 Rot 123 Torque on /off btm.- 11,000/8,000 ft/Ibs Broke out of hard drilling back into sand @ 15,005' Well still taking fluid @ 22 bbls /hr average & breathing on connections Lost 267 bbls last 12 hrs. Page 19 of 32 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 15,015 15,676 PROD1 DRILL DDRL P Drilled 6 1/8" hole w/ GP f/ 15015' to 15,676' MD 6922' TVD ADT 8.29 hrs ECD 11.48 Max gas 4200 WOB 10 -15 k RPM 120 GPM 175 @ 1450 psi String wt. PU 165 SO 86 Rot 122 Well still taking fluid @ 28 bbls /hr average & breathing on connections Lost 334 bbls last 12 hrs Total losses 601 bbls last 24 hrs - total to date - 1863 bbls 02/17/2010 Drilled 6 1/8" hole w/ GP f/ 15,676' to 16,925' 00:00 12:00 12.00 15,676 16,285 PROD1 DRILL DDRL P Drilled 6 1/8" hole w/ GP f/ 15,676' to 16,285' MD 6893' TVD ADT 7.89hrs ECD -11.5 WOB 10 - 15 k RPM 120 GPM 180 @ 1600 psi String wt. PU 164 SO 86 ROT 123 Torque on /off btm.- 12,000/8,000 ft/Ibs Hole still taking fliud & breathing on connections Lost 387 bbls last 12 hrs. 12:00 00:00 12.00 16,285 16,925 PROD1 DRILL DDRL P Drilled 6 1/8" hole w/ GP f/ 16,285' to 16,925' MD 6896' TVD ADT 9 hers. ECD - 11.64 WOB 10 - 15 k RPM 130 GPM 180 @ 1600 psi String wt. PU 170 SO 85 ROT 121 Torque on /off btm.- 13000/9000 ft/Ibs Hole still taking fluid & breathing on connections Lost 504 bbl last 12 hrs.- total to date - 2754 bbls 02/18/2010 Drilled 6 1/8" hole w/ GP f/ 16,925' to 17,664' (TD) - Circ 3 X btms up std back 1 std DP every hr. 00:00 12:00 12.00 16,925 17,422 PROD1 DRILL DDRL P Drilled 6 1/8" hole w/ GP f/ 16,925' to 17,422' MD 6891' TVD ADT 7.75 hrs. ECD 11.9 ppg WOB 10 /15 k RPM 130 GPM 180 @ 1600 psi String wt. PU 170 SO 84 ROT 123 Torque on /off btm.- 14,000/12,000 ft/lbs Hole taking fluid & breathing on connections Page 20 of 32 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 20:15 8.25 17,422 17,664 PROD1 DRILL DDRL P Drilled 6 1/8" hole w/ GP f/ 17,422' to 17,664' MD 6889' (TD of Prod.1) WOB 8/30 k RPM 90/130 GPM 180 @ 1750 psi String wt. PU 180 SO 65 ROT 125 Torque on /off btm.- 18,000/11,500 ft/lbs Hole taking fluid & breathing on connections 20:15 00:00 3.75 17,664 17,330 PROD1 DRILL CIRC P Circ 3 X btms up @ 180 gpm @ 1750 psi - 120 rpm - torque 12,000 PU wt. 115 SO wt 110 - Std back 1 std every hr. f/ 17664' to 17,330' Lost 874 bbs last 24 hrs. Total losses to date 3688 bbls 02/19/2010 Finish circ 3 X btms up - BROOH to 12,942' - Circ 2 X btms up - Perform exhale test - Circ & wt. up to 10.5 ppg - RIH to 14987' Took wt. wash down to 15,112' - RIH f/ 15,112' 00:00 02:30 2.50 17,330 17,084 PROD1 DRILL CIRC P Cont. Circ 3 X btms up @ 3.5 bbls /min @ 1375 psi w/ 120 rpm @ 14 k torque - std back last jt to 17084' 02:30 10:00 7.50 17,084 12,942 PROD1 DRILL TRIP P Monitor well 15 mins. slight flow (breathing) BROOH f/ 17,084' to 12,942' w/ 3 bbls /min @ 900 psi w/ 100 rpm 14 k torque @ 20 -30 ft/min - Increased pump rate to 4 bbls /min @ 14,100' PU wt. 174 SO 80 ROT 123 - Calc fill 27 bbls - actual 79 bbls * Dropped 2' hallow drift w/ 100' slick line © 13,794' 10:00 12:30 2.50 12,942 12,942 PROD1 DRILL CIRC P Circ 2 X btms up @ 1.9 bbls /min @ 1350 psi w/ 100 rpm - 9 k torque PUwt.120 SOwt115 Blow down top drive & rig up to perform exhale test Page 21 of 32 • . Time Logs Date From To Dur S.•Depth E. Depth Phase Code Subcode T Comment 12:30 14:15 1.75 12,942 12,942 PROD1 DRILL OWFF P Perform exhale test as follows- Shut in well monitor pressure - ISIDP 70 psi ISICP 0 psi - after 10 mins. SIDP 100 psi SICP 120 psi - Opened well & flow thur choke to trip tank for 10 mins 4 bbls flow back - Shut in well ISIDP 80 psi ISIC 100 psi - after 10 mins. SIDP 100 psi SIC 120 psi - Opened well & flow thru chkoe to trip tank for 10 mins. 4.76 bbls flow back - Shut in well ISIDP 80 psi ISIC 110 psi after 10 mins SIDP 80 psi SIC 120 psi - Opened well for final flow 10 mins - flowed back 5.4 bbls - Flow back volume increasing with each flow back period, but pressures building back to nearly the same each time. Weighting up suction pit to 10.5 ppg while performing test 14:15 21:15 7.00 12,942 12,942 PROD1 DRILL CIRC P Circ btms up thru choke © 2.5 to 3 bbl /min @ 600 -700 psi - Observed 9.9 ppg mud wt. @ btms up - No gas or oil shows - Shut down pump - Opened well & flow ck. slight flow - RD equipment f/ exhale test - Circ & weight up to 10.5 ppg @ 2.5 bbls /min @ 850 psi w/ 80 rpm - 7 -9 k torque - Shut down & flow ck very slight flow - Blow down TD 21:15 00:00 2.75 12,942 15,112 PROD1 DRILL TRIP P RIH f/ 12942' to 14,987' - String took wt.- log showed area where the well transitioned f/ shale back to sand) PU & rotated thru spot @ 14,987 top 15,018' - Filled pipe & washed down f/ 15,018' to 15,112' - Hole trying to pack off f/ 14,987' to 15, 018' - RIH f/ 15,112' Lost 448 bbls last 24 hrs. Total to date 4146 bbls 02/20/2010 RIH / 15112' to 17,555' - Wash down to 17,664' -Circ & weight up to 10.5 ppg - BROOH f/ 17,664' to 12,945' - Perform exhale test 00:00 01:00 1.00 15,112 17,555 PROD1 DRILL TRIP P RIH f/ 15,112' to 17,555' - Hole in good condition 01:00 01:30 0.50 17,555 17,664 PROD1 DRILL WASH P Break circ & wash & ream down f/ 17,555' to 17,664' 2.7 bbls /min @ 1100 psi - 80 rpm - torque 13 k 01:30 09:30 8.00 17,664 17,664 PROD1 DRILL CIRC P Circ & cond. mud - weight up to 10.5 ppg @ 3 bbls /min @ 1300 psi 90 rpm - torque 15 k 09:30 10:00 0.50 17,664 17,664 PROD1 DRILL OWFF P Take on mud in pit # 6 - Obtain SPR - LD 1 single of DP - Monitor well - Observed slight flow Page 22 of 32 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 19:30 9.50 17,664 12,945 PROD1 DRILL TRIP P BROOH f/ 17664' to 12,945' - 3 bbls /min @ 1400 to 1200 psi - 90 - 100 rpm - torque 12- 13 k 19:30 21:30 2.00 12,945 12,945 PROD1 DRILL CIRC P Circ btms up @ 3 bbls /min @ 1200 psi - String wt. PU 119 SO 115 - • blow down top drive - RU for exhale test 21:30 00:00 2.50 12,945 19,945 PROD1 DRILL OTHR P Performed exhale test as follows - Shut in well DPP 0 CP 0 - after 15 mins. DPP 105 CP 70 (had trapped pressure on DP bleed down - new DP 65 psi ) Opened choke and flowed for 10 mins to trip tank - 1 bbl in 10 mins. - Shut in DPP 50 CP 0 - after 20 mins. DPP 60 CP 50 - opened choke to flow well for 10 mins - 1/2 bbl in 10 mins - Shut in well DDP 50 CP 0 after 25 mins. DDP 30 CP 30 - opened choke to flow well for 10 mins. - 4 gals. in 10 mins. - Shut in DPP 25 CP 0 after 25 mins. DPP 20 CP 10 - Opened choke to monitor well for 30 mins. * Note - emailed results of exhale test to drilling engineer Lost 618 bbls last 24 hrs. - Total to date - 4764 bbls 02/21/2010 Finish Exhale test - POOH f/ 12,945' to 308' (had to pump to BHA) Flow ck @ 308' for 15 mins. Well Static - Pull & std back HWDP,Jars, & NM flex DC's - Down load MWD - LD MWD - Geopilot & bit 00:00 01:00 1.00 12,945 12,945 PROD1 DRILL OTHR P Finish exhale test - final DDP 20 CP 10 - Open choke & monitor on trip tank for 30 mins.- gained 21 gals.- Open well - flow ck (static) - blow down choke & kill lines 01:00 19:00 18.00 12,945 92 PROD1 DRILL TRIP P POOH f/ 12,945' to 380' (top of BHA) w/ pump - made several attempts to pull on elevators - well would swab - Pumped @ 1 bbl /min @ 300 psi - Monitored well @ top of BHA for 15 mins. - Well static - Blow down TD - Pulled BHA out on elevators - Stood back HWDP, jars & NM flex DC' s 19:00 22:15 3.25 92 0 PROD1 DRILL PULD P Down load MWD - LD MWD - Geopilot & bit 22:15 00:00 1.75 0 0 PROD1 WHDBO BOPE P Clean & clear rig floor - Pull wear bushing - Set test plug -RU & test annular preventer to 250 & 2500 psi - RD test euqipment - Pull test plug - Set wear bushing ( Test of Hydril for use after well control on 2/12/2010) Lost 117 bbls last 24 hrs. - Total to date - 4881 bbls Page 23 of 32 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/22/2010 24 hr Summa RU & Ran 4 1/2" SLHT liner w/ shoe @ 17,664 & top @ 13,375' - Release f/ liner - Circ btms up - Flow ck very slight flow - Attempt to POOH on elevators - well swabbing - POOH w/ pump 00:00 00:45 0.75 0 0 COMPZ CASING RURD P Rig up to run 4 1/2" liner 00:45 01:00 0.25 0 0 COMPZ CASING SFTY P Held PJSM w/ crew on running 4 1/2" liner 01:00 05:45 4.75 0 4,288 COMPZ CASING RUNL P Ran 4 1/2" liner as follows: MU liner shoe - 4 1/2" 12.6# L -80 SLHT pup jt w/ orange peel btm.(4.59' ) - 66 jts.(2628.16') 4 1/2" 12.6# L -80 SLHT slotted liner - 12 jts (481.20') 4 1/2" 12.6# L -80 SLHT blank liner - 29 jts (1159.93') 4 1/2" 12.6# L -80 SLHT slotted liner - MU Baker HR setting sleeve assmebly ( 14.84') - total liner - 4,288.72' - RD casing tongs 05:45 13:00 7.25 4,288 12,914 COMPZ CASING RUNL P RIH w/ 4 1/2" liner on 4" DP f/ 4288' to 12,914' - Obtain PU & So wt. every 10 stds & rot torque every 20 stds - @ 12,914' - Establish circ & circ drill pipe volume @ 2 bbls /min @ 450 psi - PUwt168 SOwt77 Rot. 117 - Torque 9,000 ft/lbs 13:00 14:15 1.25 12,914 12,914 COMPZ RIGMNT SVRG P PJMS on changing saver sub - Changed out saver sub in top drive 14:15 17:00 2.75 12,914 17,668 COMPZ CASING RUNL P RIH w/ liner f/ 12,914' to 17, 668' - String wt. PU 195 SO 65 17:00 20:00 3.00 17,668 13,317 COMPZ CASING CIRC P Pick up & tagged btm on depth - Dropped ball - Pumped ball down @ 2 bbls /min @ 600 psi - slowed pump to 1 bbl /min @ 450 psi - Ball on seat - Pressure up to 3000 psi to release running tool - Top of liner @ 13,375' - PU & observed 25,000 loss in string wt.- PU to clear running tool f/ liner top - Pressure up to 4200 psi to shear ball seat - PU to 13,317' 20:00 23:00 3.00 13,317 13,317 COMPZ CASING CIRC P Circ btms up @ 3 bbls /min @ 800 psi - Monitor well for 30 mins. very slight flow after 30 mins. 23:00 00:00 1.00 13,317 13,035 COMPZ CASING TRIP P Attempt to pull on elevators - well swabbing - POOH w/ pump f/ 13,317' to 13,035' @ 1.5 bbls /min @ 425' Lost 82 bbls last 24 hrs. - Total to date - 4963 bbls 02/23/2010 Pump out of hole to 6,732', Slip & Cut Drlg line 91', Service rig, Pump out to 3,366', POOH & UD running tool, UD 2 std's 4" DP f/ drk, Rig & test BOPE waived by AOGCC Lou Grimaldi 00:00 08:30 8.50 13,035 6,732 COMPZ CASING TRIP P Pump out of hole at rate of 1 bpm @ 300 psi f/ 13,035' to 6,732'. 08:30 10:30 2.00 6,732 6,732 COMPZ RIGMNT SLPC P Monitor well on trip tank, PJSM, Slip & cut drilling line 91', Service rig, Calibrate block height. Page 24 of 32 • 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 00:00 04:15 4.25 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. 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 15:15 16:00 0.75 13,037 13,037 PROD2 RIGMNISVRG 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/ /0 to LI 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 1 711) FLOTHRU w/ micronised barite 00'- 19:15 21:45 2.50 13,229 13,270 PROD2 DRILL REAM P PU and Cutting trough f/ L1°- 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 TQ 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/ 11k 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- 120gpm - Drilling losses for tour = 52 bbls - Tripping 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 i • 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, 11ktq 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 Su mmary 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 - PUW162k- SOW83k -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 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, 11kTQ - 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/ 8k TQ - 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 jt. - 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 (84jts) 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 1 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 bbls - Actual fill = 37 bbls 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 bbls 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 bbls 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 per 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 bbls 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 SSSV w/ 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, LAD 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 • • ConocoPhillips(Alaska) Inc. Western North Slope CD3 Fiord Pad CD3 -106 501032061100 Sperry Drilling Services Definitive Survey Report 09 March, 2010 HALLIBURTON ° Sperry Drilling Services • • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well CD3 -106 1 Project: Westem 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 - 106 Survey Calculation Method: Minimum Curvature Design: CD3 -106 Database: CPAI EDM Production Project Westem North Slope Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor ! Well CD3 - 106 Well Position +N /-S 0.00 ft Northing: 6,003,852.22ft Latitude: 70° 25' 10.108 N +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 - 106 Magnetics Model Name Sample Date Declination Dip Angie Field Strength r) ( (nT) BGGM2007 1/6/2010 21.28 80.78 57,638 Design CD3 -106 Audit Notes: 1 Version: 1.0 Phase: ACTUAL Tie On Depth: 28.00 Vertical Section: Depth From (TVD) +W-S +E/ -W Direction i (ft) (ft) (ft) r) 28.00 0.00 0.00 336.00 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 17,597.41 CD3 -106 MWD (CD3 -106) MWD +IFR- AK- CAZ -SC MWD +IFR AK CAZ SCC 2/12/2010 1: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/S +E/ W Northing Easting DLS Section (ft) (') (°) (ft) (ft) (ft) (ft) (ft) (ft) ( °1100') (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 -11.19 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 -22.57 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 -33.84 CB- GYRO -SS (1) 750.00 11.24 132.10 746.88 705.48 -33.62 29.25 6,003,818.17 388,295.20 0.76 -42.61 CB- GYRO -SS (1) 3/9/2010 12:57:05PM Page 2 COMPASS 2003.16 Build 69 • • ConocoPhillips (Alaska) Inc. Definitive Survey Report - Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well CD3 -106 Project Westem 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 - 106 Survey Calculation Method: Minimum Curvature Design: CD3 - 106 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 817.00 11.73 130.07 812.54 771.14 -42.38 39.31 6,003,809.26 388,305.13 0.95 -54.71 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 -62.07 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 -77.85 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 -91.84 MWD +IFR -AK- CAZ -SC (2) 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 - 102.78 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 - 110.81 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 - 114.04 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 - 109.40 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 -96.15 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 -76.40 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 -52.87 MWD +IFR -AK- CAZ -SC (2) 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 -24.41 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 9.27 MWD +IFR -AK- CAZ -SC (2) 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 49.94 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 93.39 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 3.02 139.34 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 3.36 190.80 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 4.13 244.22 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 1.13 301.11 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 3.84 362.58 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 4.66 427.63 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 4.59 481.02 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 2.45 549.56 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 0.69 623.39 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 0.96 695.05 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 0.13 770.31 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 0.89 842.60 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 0.37 914.58 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 0.70 987.67 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 1,060.18 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 1,134.60 MWD +IFR -AK- CAZ -SC (3) 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 1,209.39 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 1,286.74 MWD +IFR -AK- CAZ -SC (3) 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 1,363.98 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 1,442.22 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 1,520.73 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 1,599.02 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 1,678.46 MWD +IFR -AK- CAZ -SC (3) 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 1,757.27 MWD +IFR -AK- CAZ -SC (3) 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 1,835.51 MWD +IFR -AK- CAZ -SC (3) 3/9/2010 12 :57 :05PM 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: Westem 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 - 106 Survey Calculation Method: Minimum Curvature Design: CD3 - 106 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Az! TVD TVDSS +N/-S +EI -W Northing Easting DLS Section (ft) r) (°1 (ft) (n) (n) (ft) (ft) (ft) ( °1100') (g) Survey Tool Name 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 1,915.33 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 1,993.45 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 2,072.55 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 2,151.16 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 2,228.25 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 2,307.39 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 2,386.06 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 2,464.87 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 2,544.81 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 2,620.79 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 2,702.70 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 2,777.34 MWD +IFR -AK- CAZ -SC (3) j 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 2,860.79 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 2,940.04 MWD +IFR -AK- CAZ -SC (3) J 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 3,019.86 MWD +IFR -AK- CAZ -SC (3) i 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 3,097.72 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 3,176.81 MWD +IFR -AK- CAZ -SC (3) j 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 3,254.14 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 3,332.24 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 3,409.20 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 3,488.62 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 3,564.96 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 3,644.79 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 3,723.69 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 3,802.04 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 3,880.22 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 3,958.07 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 4,035.56 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 4,117.02 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 4,188.52 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 4,267.91 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 4,346.14 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 4,423.43 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 4,499.23 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 4,578.56 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 4,655.84 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 4,733.19 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 4,810.31 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 4,887.68 MWD +IFR -AK- CAZ -SC (3) 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 4,965.02 MWD +IFR -AK- CAZ -SC (3) 3/9/2010 12:57:05PM 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 Westem 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 Welibore: CD3 - 106 Survey Calculation Method: Minimum Curvature Design: CD3 - 106 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/S +E/ -W Northing Easting DLS Section (ft) (°) (') (ft) (ft) (ft) (ft) (ft) (ft) ( °N00') (ft) Survey Tool Name 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 5,042.81 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 5,120.15 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 5,197.68 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 5,274.80 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 5,352.74 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 5,427.42 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 5,507.92 MWD +IFR -AK- CAZ -SC (3) D +IF - 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 5,584.98 MW R 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 5,663.43 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 5,741.59 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 5,818.50 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 5,894.72 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 5,975.62 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 6,054.43 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 6,129.77 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 6,205.89 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 6,282.65 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 6,361.05 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 6,437.03 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 6,515.75 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 6,594.07 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 6,672.22 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 6,750.14 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 6,827.71 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 6,905.09 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 6,983.98 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 7,060.36 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 7,135.12 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 7,215.63 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 7,293.36 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 7,371.70 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 7,449.87 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 7,527.77 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 7,605.06 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 7,684.48 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 7,761.18 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 7,838.96 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 7,914.59 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 7,990.55 MWD +IFR -AK- CAZ -SC (3) 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 8,068.55 MWD +IFR -AK- CAZ -SC (3) 3/9/2010 12:57:05PM 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 Westem 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 - 106 Survey Calculation Method: Minimum Curvature Design: CD3 - 106 Database: CPAI EDM Production Survey Map Map Vertical G MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) ( ° (ft) Survey Tool Name 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 8,147.85 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 8,226.73 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 8,308.01 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 8,392.00 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 8,476.69 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 8,564.53 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 8,654.65 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 8,742.52 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 8,833.92 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 8,927.03 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 9,018.41 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 9,082.83 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 9,176.28 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 9,202.50 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 9,295.16 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 9,387.19 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 9,480.33 MWD +IFR -AK- CAZ -SC (5) 13,348.85 93.39 328.17 6,952.45 6,911.05 10,045.97 - 976.55 6,013,910.81 387,440.46 3.41 9,574.65 MWD +IFR -AK- CAZ -SC (5) 13,443.26 93.45 324.29 6,946.81 6,905.41 10,124.29 - 1,028.92 6,013,989.91 387,389.27 4.10 9,667.50 MWD +IFR -AK- CAZ -SC (5) 13,537.98 93.51 318.89 6,941.06 6,899.66 10,198.35 - 1,087.64 6,014,064.83 387,331.67 5.69 9,759.04 MWD +IFR -AK- CAZ -SC (5) 13,632.09 93.33 314.66 6,935.44 6,894.04 10,266.79 - 1,151.96 6,014,134.22 387,268.38 4.49 9,847.72 MWD +IFR -AK- CAZ -SC (5) 13,730.12 91.35 312.29 6,931.44 6,890.04 10,334.17 - 1,223.03 6,014,202.65 387,198.34 3.15 9,938.19 MWD +IFR -AK- CAZ -SC (5) 13,819.78 91.35 312.38 6,929.33 6,887.93 10,394.54 - 1,289.29 6,014,263.99 387,132.99 0.10 10,020.28 MWD +IFR -AK- CAZ -SC (5) 13,912.20 92.83 310.46 6,925.96 6,884.56 10,455.63 - 1,358.55 6,014,326.12 387,064.67 2.62 10,104.27 MWD +IFR -AK- CAZ -SC (5) 14,006.28 92.15 308.50 6,921.87 6,880.47 10,515.39 - 1,431.09 6,014,386.95 386,993.03 2.20 10,188.36 MWD +IFR -AK- CAZ -SC (5) 14,101.10 92.83 305.35 6,917.75 6,876.35 10,572.30 - 1,506.81 6,014,444.97 386,918.18 3.40 10,271.15 MWD +IFR -AK- CAZ -SC (5) 14,195.10 91.54 300.94 6,914.16 6,872.76 10,623.64 - 1,585.44 6,014,497.48 386,840.34 4.88 10,350.03 MWD +IFR -AK- CAZ -SC (5) 14,289.19 89.87 299.27 6,913.01 6,871.61 10,670.83 - 1,666.82 6,014,545.88 386,759.67 2.51 10,426.24 MWD +IFR -AK- CAZ -SC (5) 14,383.89 91.22 300.53 6,912.11 6,870.71 10,718.03 - 1,748.91 6,014,594.30 386,678.31 1.95 10,502.75 MWD +IFR -AK- CAZ -SC (5) 14,478.57 91.23 301.20 6,910.08 6,868.68 10,766.59 - 1,830.16 6,014,644.07 386,597.80 0.71 10,580.16 MWD +IFR -AK- CAZ -SC (5) 14,567.71 90.67 301.96 6,908.60 6,867.20 10,813.26 - 1,906.09 6,014,691.87 386,522.58 1.06 10,653.68 MWD +IFR -AK- CAZ -SC (5) 14,662.34 90.55 302.41 6,907.60 6,866.20 10,863.67 - 1,986.17 6,014,743.46 386,443.27 0.49 10,732.30 MWD +IFR -AK- CAZ -SC (5) 14,756.75 89.62 303.10 6,907.46 6,866.06 10,914.75 - 2,065.57 6,014,795.72 386,364.65 1.23 10,811.26 MWD +IFR -AK- CAZ -SC (5) 14,855.35 88.88 304.86 6,908.75 6,867.35 10,969.85 - 2,147.32 6,014,852.03 386,283.74 1.94 10,894.85 MWD +IFR -AK- CAZ -SC (5) 14,949.91 87.58 309.74 6,911.67 6,870.27 11,027.10 - 2,222.48 6,014,910.40 386,209.46 5.34 10,977.72 MWD +IFR -AK- CAZ -SC (5) 15,039.69 85.23 311.63 6,917.30 6,875.90 11,085.51 - 2,290.42 6,014,969.81 386,142.40 3.36 11,058.71 MWD +IFR -AK- CAZ -SC (5) 15,135.18 87.83 316.56 6,923.08 6,881.68 11,151.81 - 2,358.84 6,015,037.12 386,074.99 5.83 11,147.11 MWD +IFR -AK- CAZ -SC (5) 15,228.01 89.25 320.45 6,925.45 6,884.05 11,221.30 - 2,420.32 6,015,107.52 386,014.57 4.46 11,235.60 MWD +IFR -AK- CAZ -SC (5) 15,324.05 90.30 323.89 6,925.82 6,884.42 11,297.14 - 2,479.21 6,015,184.23 385,956.82 3.74 11,328.84 MWD +IFR -AK- CAZ -SC (5) 15,416.08 89.68 325.09 6,925.84 6,884.44 11,372.06 - 2,532.66 6,015,259.93 385,904.50 1.47 11,419.02 MWD +IFR -AK- CAZ -SC (5) 3/9/2010 12:57:05PM 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 Westem 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) Weti: CD3 - 106 North Reference: True Welibore: CD3 - 106 Survey Calculation Method: Minimum Curvature Design: CD3 - 106 Database: CPAI EDM Production Survey Map Map Ma Vertical MD Inc At TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) ( °) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°IjOO (ft) Survey Tool Name 15,512.91 90.18 327.39 6,925.96 6,884.56 11,452.55 - 2,586.47 6,015,341.22 385,851.91 2.43 11,514.44 MWD +IFR -AK- CAZ -SC (5) 15,605.85 91.16 329.57 6,924.87 6,883.47 11,531.77 - 2,635.05 6,015,421.14 385,804.52 2.57 11,606.57 MWD +IFR -AK- CAZ -SC (5) 15,701.69 93.58 333.32 6,920.91 6,879.51 11,615.86 - 2,680.81 6,015,505.90 385,760.03 4.65 11,702.00 MWD +IFR -AK- CAZ -SC (5) 15,795.14 92.34 333.76 6,916.08 6,874.68 11,699.40 - 2,722.40 6,015,590.05 385,719.70 1.41 11,795.24 MWD +IFR -AK- CAZ -SC (5) 15,889.21 94.01 334.16 6,910.87 6,869.47 11,783.79 - 2,763.63 6,015,675.04 385,679.74 1.83 11,889.10 MWD +IFR -AK- CAZ -SC (5) 15,982.70 93.20 334.40 6,904.99 6,863.59 11,867.85 - 2,804.12 6,015,759.69 385,640.52 0.90 11,982.36 MWD +IFR -AK- CAZ -SC (5) 16,077.06 95.43 333.49 6,897.89 6,856.49 11,952.38 - 2,845.44 6,015,844.82 385,600.46 2.55 12,076.38 MWD +IFR -AK- CAZ -SC (5) 16,170.99 91.60 331.67 6,892.14 6,850.74 12,035.58 - 2,888.61 6,015,928.65 385,558.55 4.51 12,169.95 MWD +IFR -AK- CAZ -SC (5) 16,264.57 90.30 332.09 6,890.58 6,849.18 12,118.10 - 2,932.71 6,016,011.81 385,515.70 1.46 12,263.27 MWD +IFR -AK- CAZ -SC (5) 16,355.57 91.10 337.12 6,889.47 6,848.07 12,200.27 - 2,971.72 6,016,094.55 385,477.92 5.60 12,354.21 MWD +IFR -AK- CAZ -SC (5) 16,450.47 91.16 336.63 6,887.60 6,846.20 12,287.53 - 3,008.98 6,016,182.35 385,441.97 0.52 12,449.08 MWD +IFR -AK- CAZ -SC (5) 16,540.20 91.41 331.71 6,885.59 6,844.19 12,368.25 - 3,048.06 6,016,263.64 385,404.11 5.49 12,538.71 MWD +IFR -AK- CAZ -SC (5) 16,637.24 90.61 330.10 6,883.88 6,842.48 12,453.03 - 3,095.24 6,016,349.11 385,358.22 1.85 12,635.35 MWD +IFR -AK- CAZ -SC (5) 16,732.36 87.89 328.01 6,885.12 6,843.72 12,534.59 - 3,144.14 6,016,431.38 385,310.55 3.61 12,729.75 MWD +IFR -AK- CAZ -SC (5) 16,823.12 86.59 329.21 6,889.49 6,848.09 12,611.97 - 3,191.35 6,016,509.46 385,264.50 1.95 12,819.65 MWD +IFR -AK- CAZ -SC (5) 16,920.65 87.15 333.71 6,894.82 6,853.42 12,697.50 - 3,237.87 6,016,595.67 385,219.27 4.64 12,916.70 MWD +IFR -AK- CAZ -SC (5) 17,014.98 86.78 335.43 6,899.81 6,858.41 12,782.57 - 3,278.31 6,016,681.32 385,180.10 1.86 13,010.87 MWD +IFR -AK- CAZ -SC (5) 17,109.78 89.06 338.54 6,903.26 6,861.86 12,869.75 - 3,315.35 6,016,769.04 385,144.39 4.07 13,105.57 MWD +IFR -AK- CAZ -SC (5) 17,202.21 92.22 340.54 6,902.22 6,860.82 12,956.33 - 3,347.65 6,016,856.08 385,113.39 4.05 13,197.80 MWD +IFR -AK- CAZ -SC (5) 17,298.21 94.07 339.73 6,896.96 6,855.56 13,046.47 - 3,380.22 6,016,946.70 385,082.17 2.10 13,293.41 MWD +IFR -AK- CAZ -SC (5) 17,392.50 92.03 335.01 6,891.94 6,850.54 13,133.35 - 3,416.44 6,017,034.10 385,047.26 5.45 13,387.50 MWD +IFR -AK- CAZ -SC (5) 17,487.08 90.49 331.22 6,889.86 6,848.46 13,217.67 - 3,459.19 6,017,119.04 385,005.78 4.32 13,481.92 MWD +IFR -AK- CAZ -SC (5) 17,550.69 90.11 327.74 6,889.52 6,848.12 13,272.46 - 3,491.49 6,017,174.30 384,974.31 5.50 13,545.11 MWD +IFR -AK- CAZ -SC (5) 17,597.41 92.09 327.97 6,888.63 6,847.23 13,312.01 - 3,516.34 6,017,214.22 384,950.05 4.27 13,591.35 MWD +IFR -AK- CAZ -SC (5) 17,664.00 92.09 327.97 6,886.20 6,844.80 13,368.42 - 3,551.63 6,017,271.15 384,915.61 0.00 13,657.24 PROJECTED to TD 3/9/2010 12:57:05PM Page 7 COMPASS 2003.16 Build 69 • fli WELL LOG TRANSMITTAL To: State of Alaska March 25, 2010 Alaska Oil and Gas Conservation Commission Attn.: Christine Mahnken 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 -3539 RE: MWD Formation Evaluation Logs: CD3- 106 +L1 AK -MW- 0006991490 CD3 -106 2" x 5" MD TRIPLE COMBO Logs: 1 Color Log 50 -103- 20611 -00 2" x 5" TVD TRIPLE COMBO Logs: 1 Color Log 50- 103 - 20611 -00 Digital Log Images & LWDG- formatted LIS Data w /verification listing; 1 CD Rom 50 -103- 20611 -00 CD3 -106 LI 2" x 5" MD Gamma Ray/Resistivity Logs: 1 Color Log 50 -103- 20611 -60 2" x 5" TVD Gamma Ray/Resistivity Logs: 1 Color Log 50 -103- 20611 -60 Digital Log Images & LWDG- formatted LIS Data w /verification listing; 1 CD Rom 50 -103- 20611 -60 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3536 Fax: 907 - 273 -3535 Bryan.Burinda halliburt / RECEIVtL3 f Date: AR 3 1 Z Signed: Ccrnitsitra 0/0 l9g93 is 11) SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMAIISSION 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 -106 ConocoPhillips Alaska Inc. Permit No: 210 -001 Surface Location: 3921' FNL, 777' FEL, SEC. 5, T12N, R5E Bottomhole Location: 931' FNL, 1705' FEL, SEC. 30, T12N, R5E Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). Sincerely, 0 or Daniel T. Seamount, Jr. 44 Chair DATED this 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) 1 ConocoPhillips Alaska, Inc Post Office Box 100360 ~� Anchorage, Alaska 99510 -0360 ConocoPhillips Telephone 907 - 276 -1215 ; January 4, 2010 ar i j A18Sk Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 Re:Application for Permit to Drill, Nechelik Producer, CD3 -106 and CD3 -106L1 Dear Commissioner Seamount, ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for a single zone multilateral onshore oil production well from the CD3 drilling pad. The main bore of the well will be designated CD3 -106 and the lateral bore of the well will be designated as CD3- 106L1. The intended spud date for this well is 01/15/09. It is intended that Doyon Rig 141 be used to drill the well. After setting 7" intermediate casing, the CD3 -106 main bore horizontal section will be drilled and the well completed with slotted /blank liner. The CD3 -106L1 lateral will be kicked off below the 7" casing shoe, in zone, and also completed with slotted /blank liner. If the laterals are drilled in zone over the entire lengths, the wells will not be cased with the slotted /blank liners and left with open hole completions. It is expected that the K2 (Qannik) sand will be considered a significant hydrocarbon bearing zone. After running 7" casing, it is planned to pump lead cement, then open a stage tool and pump a second cement job to isolate the K2 with 500' of cement above and below the interval. This will leave a mud gap between the two stages. It is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. At CD3, there has not been a significant show of shallow gas or gas hydrates through the surface hole " interval. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10 -401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. A proposed drilling program. 3. A proposed completion diagram. 4. A drilling fluids program summary. 5. Pressure information as required by 20 ACC 25.035 (d)(2). 6. Directional drilling /collision avoidance information as required by 20 ACC 25.050(b). 0 0 Information pertinent to the application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Riser setup If you have any questions or require further information, please contact Mike A. Winfree, 265 -6820, or Mark Chambers at 265 -1319. * tii Sincer- 1 Mike A. , infree Drilling E gineer Attachments cc: CD4 -25 Well File / Sharon Allsup Drake ATO 1530 Mark Chambers ATO 1566 Nina Anderson ATO 1706 Liz Galiunas ATO 1706 Ryan Robertson ATO 1708 Tim Schnieder ATO 1768 Lanston Chin Kuukpik Corporation STATE OF ALASKA r t ALA" OIL AND GAS CONSERVATION COMMIDON PERMIT TO DRILL j;:,, 0 , . .;z 20 AAC 25.005 la. Type of Work: 1b. Proposed Well Class: Development - Oil S , Service - Winj ❑ Single Zone AIRS14.WAifF.64478;18;Prclii0P.41Dr . Drill 0 , Redrill ❑ Stratigraphic Test ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Coalbed 088 •.68s 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 -106 ' 3. Address: 6. Proposed Depth: 12. Field /PooI(s): P.O. Box 100360 Anchorage, AK 99510 -0360 MD: 17,843' ' TVD: 6,874' ' Colville River Field 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): AP.. Fiord Oil Pool Surface: 3921FNL, 777FEL, Sec 5, T12N, R5E • ADL 364470 ADL 364471 3 7Z &.,S Top of Productive Horizon: 8. Land Use Permit: /W- 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: 931FNL, 1705FEL, Sec30, T12N, R5E 2560 e 0.7 miles to AVCG boundary . 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: yq 7 .4`r . feet 15. Distance to Nearest Well Open Surface: x- 1 ' / y- 60 _ Zone- 4 GL Elevation above MSL: 13.4 ' feet to Same Pool: 110' to CD3 -109 . •_ S 2L,4' , T' 4,,, Z)'5, 06; ,::=.2..:z_ b i 5%A) at 12,850'MD 16. Deviated wells: Ai'' ;. , 1) Kickoff depth: 250 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 91 degrees Downhole: 3,574 - Surface: 2,886 • 18. Casing Program: Specifications 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 5343 12500 6876 17843 6874 . 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 - Intermediate Production &:::' , _ Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program El Time v. Depth Plot ❑ Shallow Hazard Analysis 0 Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program IO 20 AAC 25.050 requirements Its 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Printed Name G.L. Alvord Title CPAI Drilling Manager Signature /4 �. Phone 265 -6120 Date 1/4/2010 // Commission Use Only Permit to Drill 1 z- API Number: . Permit App o See cover letter for other Number: f� 50- /L)oj` 2-(_,- ' -a Date: / t✓ requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produc coalbed methane, gas hydrates, or gas contained in shales: Z' Other: it 3 5 Op PSG Bo ) (( /e5 -L- Samples req'd: Yes ❑ No 7( Mud log req'd: Yes ❑ No [r 25c0 p- " /'I n w wt 0.r �s ( ,,. �)2S measures: Yes 111 No 2' j Directional svy req'd: Yes ' No 111 it4 L i ver'&r- L J . I L/ d 2c A AC 2 S. o 35 (A) ( dp , _ APPROVED BY THE COMMISSION / AP DATE: V , COMMISSIONER Form 10 - 401 (Revised 7/2009) This permit is valid 2inti 1NAtL approval (20 AAC 25.005( ) Submi in Duplicate • Procedure 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 not covered in this permit but are shown here for convenience: 19. PU 6 -1/8" Drilling BHA and RIH to CD3106L1 KOP. pf o 20. Low side open hole sidetrack at 13,326' MD and drill to CD3 -106L1 TD. alp - O02 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 -%2, 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. 23. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. ORIGINAL • 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. ORIGINAL ! i 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 TVD 1) Tubing Hanger 24' 24' - ss� 2) 4 -1/2 ", 12.6 # /ft, IBT -Mod Tubing (2 jts) 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" 40 ppf L -80 BTC 5) 3-1/2", 9.3 # /ft, EUE -Mod Tubing S Casing MI at 2,739' ' MD MD / 2,500' TVD 6) 3 -1/2" Camco KBMG -GLM w/ DV 4,678' 3,400' / Cementedtosurface 7) 3 -1/2 ", 9.3 # /ft, EUE -Mod Tubing 8) 3 -1/2" Camco KBMG -GLM w/ DV 9,497' 5,600' GL J 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" 93ppfL -80EUE Tubing 12 ) 3-1/2", "XN" Nipple "" le 12,460' 6,867' 13) 3 -'W' Baker Casing Seal Assembly TOC = 5,700 Lower Completion MD TVD Qannik Interval Top +/- 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 " SLHT In 6.800' MD / 4,368' TVD XO Sub 5" BTC box by 4 -'Yz p '- •' =� ' 2) 4-W 12.6 #, L -80, SLHT, Blank/Slotted Liner GL CD3 -106 7" 26 ppf L -80 BTC -M Production Casing �� 6,874' TVD 4 at 12,786' = 6,924' TVD @ +!- 83.0° i i/ ' ♦ 4 -%" 12.6 6, L -80, SLHT, Slotted Liner TOC © +!- 11,700' MD / 6,762' TVD ' CD3-106L1 Top of Nechelik - 12,876' MD ! 6,934' TVD 6,809' TVD L1 Kick OR Depth: 13,326' MD 6,954' TVD 1\IGIR. L �r� • DRILLING FLUID PROGRAM SPUD to Intermediate hole to production Hole 9 -5/8 "surface casing 7" casing point — Section — 6 1/8" point — 12 -1/4" hole 8 -3/4" hole Density 8.8 — 9.6 ppg 9.6 — 9.8 ppg • 10 ppg PV 10 -16 10 -15 YP 20 -60 13 -25 25 -30 Funnel Viscosity 100 — 300 Initial Gels 8 — 10 10 — 15 10 minute gels <20 12 - 20 API Filtrate NC — 10 cc / 30 min 5 — 12 cc /30 min (drilling) HPHT Fluid Loss at 160 12 - 14 cc /30 min PH 8.5 -9.0 9.0 -10.0 9.0 -9.5 KCL 6 % Surface Hole: A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep flow line viscosity at ± 200 sec /qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel / polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the Nechelik is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be • important in maintaining wellbore stability. 9 . Y Production Hole Section : The 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. • 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) (lbs. / 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 17,843 / 6,874 16.0 3,574 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) = 3,574 — (0.1 x 6,924') = 2,886 psi r • 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 110' well to well separation at 12,850' 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 -106 will be injected into a permitted annulus on . CD3, or the class 1 disposal well on CD1 pad. The CD3 -106 surface /intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The only significant hydrocarbon zone is the Qannik reservoir and there will be ;, 500' of cement fill above the top of the Qannik as per regulations. Upon completion of CD3 -106, 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 ORIGINAL • • Cementing Program: 9 -5/8" Surface Casing run to2,739' MD / 2,500' TVD. Cement from 2,739' MD to 2,239' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2400' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (1,295' MD). Lead slurry: 480 sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.45 ft /sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% S001 accelerator, 50% D124 extender and 9% BWOW D044 freeze suppressant Tail slurry: 240 sx Class G + 0.2% D046 antifoamer, + 1 %S2, 0.2 %D46, 0.3 %D65 accelerator @ 15.8 PPG yielding 1.17 ft /sk s .1....9 / L 7" Intermediate Casing run to 12,786' MD / 6,924' TVD 12 4 71e 1 1 , 76) /0 /- 7• /o First Stage: Cement the first 1000' from 11MD with : • • • • . =' - witMt- 6iteGFett 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 Second Stage: Cement from ports in a Stage tool set 500' below the K2 interval to +/- 500' above the K2 interval with Class G + additives @ 15.8 ppg. Assume 40% excess annular volume Lead: 290 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1` S002 accelerator @ 15.8 PPG yielding 1.17 ft /sk 1 By Weight Of mix Water, all other additives are\BrlAI (C ? t • [ t k S [ if. k 7 '`... € Al N../ LL t E 4 1 L.. • CD3 -106 Drilling Hazards Summary (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12 -1/4" Hole / 9 -5/8" Casing Interval, Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low Gyro single shots, traveling cylinder diagrams Monitor well at base of permafrost, increased mud Gas Hydrates Low weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud temperatures Running Sands and Gravel Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of low density cement slurries 8 -3/4" Hole / 7" Casing Interval Event Risk Level Mitigation Strategy Abnormal Pressure in BOPE drills, Keep mud weight above 9.6 ppg. Surface Formations Low Check for flow during connections and if needed, >2000' TVD increase mud weight. Reduced pump rates, reduced trip speeds, real time Lost Circulation Low equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Reduced trip speeds, mud properties, proper hole Hole Swabbing on Trips Moderate filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. Abnormal Reservoir Well control drills, increased mud weight. No Pressure Low , mapped faults occur within 700' of the planned wellbore. Hydrogen Sulfide Gas Low / H drills, detection systems, alarms, standard well / control practices, mud scavengers 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 fl i t 0 1 k Y Y i +w a 1 V t{ c L.. • • ConocoPhillips(Alaska) Inc. Western North Slope CD3 Fjord Pad Plan: CD3 -106 Plan: CD3 -106 Plan: CD3- 106wp09 Standard Proposal Report [ D 2 7J 04 January, 2010 Permit PACK HALLIBURTON 111=111 4■11111■M Mb NMI MIK Sperry Drilling Services ORIGINAL Project: Western North Slope CD3 +) (3500 Win) W Plan: ConocoPhillips Wellboeee PIan: Fiord CD3 Pad Ofi `I `7 T �� I i 1 1 -3500 0 350D I I I Al aska DDI .4 no Relatively short, simple wale or simple profiles w91 low tororosry 00160 -64' Shorter wells with high tortuosity or lager wells with low tortuosity tortuosity 1 4ggg - CO3 DDI = 6.889 106wp0 - �� _ _ 4 - 1/2 "x6 - 1/8" -14000 DDI 6.4 - 6.8 . Long wells with relativdy tortuous pro1l06 C01 > 68. Lag, tortuous piles wen a high degree of df6wlty - - - _ _ _ - HALLIBLIRTON REFERENCE INFORMATION Surface Location \ lOOO - Co- or4n4e (N/E) Reference Well Play. CD3-108, True North Northing 6003599.43 - ICD3- 109_RedrillwpXX We Tee - Vertical (TVD) Reference Plan: CD3-306 (36 3.13.4) @ 49 700 (Duyon 19) Fasting 152829837 Sperry 06 filling c t ai Ma Reference, m a � a ) Ground Latitude 70 °258.942 N - 4, - Geodetic Zone: Alaska Zone LosS/ode 150 °54 W Start DLS 0.00 TFO 21.09 - - . O 13:36, December 29 2009 Geodetic Datum: Nora, Amaasa, Datum 1983 y 0 o 0 s o - CASING DETAILS SURVEY PROGRAM Start DLS 3.00 TFO 88.73 -- - - ^7' i ND TVOSS MD Name Sae 250000 245030 2739.79 95/8 95/8'x12 -1 /4" 36.30 1000.00 CD3- 106wp09 (Plan, CD3 -106) CS-GYRO-SS 10500- -10500 692470 8875.00 12786.16 7 7'x8 -3/4' 1000.00 17843.12 CD3-106wp09 (Plan: CD3 -106) kIWDelFR- AKLAZ -SC 6874.70 682600 17843.12 4 -1/2 4-1/2' x6-1/8' Start DLS 3.00 TFO -90.00 _..411.v!.....,... _ _ - - - - Start Drop -100 Start Build 3.00 Target, ICD3- 106wp09 Top Nechek - Nine TVDSS +00-5 .1.6/-W Nprthlrg Fasting Shape 12000 CO3 -106 rt T o NIX Wad Tae 882500 1355005 -360959 6017201.00 152489300 GMe(Raalus: 100.00) Start DLS 2.69 TFO - 58.46 00 003.1067.03 09 Top NechdF 6875.00 956037 -71239 601316880 152772970 Cede (Radius: 10.00) O - - el - 1100 - SECTION DETAILS V Start DLS 2.50 TFO - 45.93 Sac MD Inc Asl TVD TVDSS 4004 °E/-W Northing Fasting DLeg TFace VSec Target 0 1 36.30 0.00 0.00 36.30 -13.40 0.00 0.00 6003599.43 1528298.37 0.00 0.00 0.00 1 7000- 10000 - 7000 5 2 250.00 0.00 0.00 250.00 200.30 0.00 0.00 6003592.28 1528302.37 0.00 0.00 0.00 Z 3 504.58 2.49 150.00 500.00 850.30 -0.09 4.10 6003548.21 1528332.86 1.50 150.00 5.47 > 4 90800 12.49 135.84 900.00 850.30 831.41 41.25 6004428.55 1528451.58 220 -43.40 -62.47 t - - 5 2681.39 62.84 355.62 66025.38 2575.63 831.40 140.75 6004428.55 1527475.11 3.50 - 140.00 702.27 9000 6 11796.16 6280 335.23 6622.70 6553.18 9560.37 412.39 6013168.60 1527729.70 000 0.00 8023.54 0 ° o 7 12786.16 83.00 336.23 6924.70 6875.00 9560.37 - 713.39 6013168.60 1527729.70 2.50 45.93 9023.59 CD3- 1060p09 Top NecMlik 0 - - ,4 � 8 13276.31 90.00 325.00 6954.70 6905.00 9985.62 - 952.07 6013597.37 1527496.46 2.69 -58.46 9509.56 CO S V 9 13376.31 9300 325.50 6952.08 6902.38 10067.50 - 1009.40 6013680.09 1527440.37 3.00 0.00 9607.68 - 8009 - 10 13456.31 90.60 325.00 6949.57 6899.87 10132.99 - 1055.26 6013746.26 1527395.50 3.00 180.00 9686.16 11 14456.26 90.52 295.00 6939.57 6889.87 10768.40 - 1812.51 6014392.91 1526647.94 3.00 -90.00 10574.64 12 15783.63 91.21 334.82 6915.66 6868.96 11686.62 - 2733.68 6015324.79 1525740.75 3.00 88.73 11788.15 356 13 17843.12 91.23 334.83 6874.70 6825.00 13550.05 . 3609.59 6017201.00 1524893.00 0.00 21.09 13846.74 CO3.109_RedrillwpXx Was Toe - 1000 _ w° ,. ■ 3500- 6000 -3500 ' 5000 0■1 0 2500 5000 7500 _ I ! 1 I I t I I I I I i I I I I I I I I I I I I I I 4000 - Start 8713.40 hold at 2981.00 M 9 -5/8" x 12 -1 /4" 1- Start Build 1.50 _ Start DLS 3.50 TFO - 143.40 l, 3000 - _ t - - - S tart DLS 2.20 TFO -20.00 0 - Start DLS 2.20 TFO -20,00 - - - - - • 000 -5 - Base Permafrost 1D °- -Start DLS 150 TFO - 143.40 - Start Build 1.50 - 1000 - I I I I I I I I I 1 I I I I I I 1 I I I I I C - • - 7000 - 3500 0 3500 9-5/8" x 12 -1/4" West( -) /East( +) (3500 Win) C -30 - ' o , - Ng: d Start 8713.40 hold at 2981.00 MD _� O 2500 D - - - - 15 ANNOTATIONS O O - M. , C - TVD TVDSS MD Annotation P p d 25 0 .et t 0 . 00 50000 00 45030 20030 250.00 90459 Start DLS St DL5220 Builtl 5 TFO -20.00 d h Start DLS 2.69 TFO - 58.46 C) 90000 85030 90459 350 TFO -14340 O - K - Start Build 3.00 - 2625.33 2575.63 2991.00 Stag 8713.40 250 hdd TFO 45 MD 6802.88 . 1188439 S K - Basal 6875.00 Ia1GL250TFO -7593 692470 68]5.00 12786.16 Start DLS 269 TFO -58.46 SI K - B K - Oannik 0 � Sta DLS 2.50 TFO - 45.93 6954.70 690500 132]6.31 stet 0L S 3,00 TFO -90.00 _ _ i Start Drop - 3.00 - N 6952.08 6902 38 1337931 Slat Drop-3 00 1: I O 694957 6899 87 13456 31 Sta1DLS3.00 C� 693957 6889 87 1445626 Start TFO 8813 0� p I Start DLS 3.00 TFO - 90.00 - 691866 6868 96 15783.63 Merl DLS 0.00 TFO 2109 ■ 05 ( ) 7" x 8 i 6874.70 6825.00 17843.12 TD et 17843.12 " I- 5000 _ O o ° I i Start DL 3.00 TFO 88.73 -5000 5 DJ O \ F ORMATION TOP DETAILS - Albian 97 Albian 96 °o I \ St DLS 0 TFO 21 - O I \ I h TVDssPI MDPdh Formation 1249 70 1200.00 232970 225000 1258.74 base Perm 0-40 _�- - - OQ \ / - 1249 7 2470 99 C -40 1 \ I 4 - 1/2" X 6 249970 245000 2739 27 0-30 ' \ 0 0 \ ° - 288970 284000 356015 0-20 3934.70 3885.00 5849.37 K -3 - Top HRZ Base - - I ro h o 4094.70 4045.00 6199 87 K-3 Basal Top KUpafuk D - r, $ Wo b / ., ' - 412470 407500 6265.59 K -2 (oalnik) . 4229 70 4180 00 6495 61 K-2 nasal . .. �, _ -_ - _ _ - _ _. -� _ 668970 5000 969395 NNan - _ _ _ 61 q CD3 106wp0B - 6014.70 5965.00 10405.91 Naal96 _ - _ ° 666470 661500 1183583 Top FIRZ To Ku arukC ° 0 0 W 8694.70 664500 1190954 Base NRZ th 7500 Top Neellk LCU p p ik o ° ° ° - 7500 6774.70 672500 12129.14 K - 1 ICD3 106wp09 Top Nechel CD3 - 109 RedrillwpXX West Ti), 8809.70 6760.00 1224037 Top KUpaukO I I 1 I I 1 1 1 1 I I I 1 I 1 I I I I I I I I I I I 1 1 1 1 I I I I 1 I i i 1 1 1 1 I 684970 6800.00 1238591 Top Kuparuk C 6857 70 6808.00 12418 33 LCU 0 2600 5000 7500 10000 12500 15000 6934.70 6885,00 1287640 Tap Neche& Vertical Section at 336.00 °(2500 ft/in) / I • Project: Western North Slope West( -) /East( +) (3500 Win) ConocoPhillips Well Flan: FCD3 CD3 106wp09 -7000 4500 0 3500 I I I Al aska Dw <6.0: Relatively short, simple wells or simple profiles with low tortuosity u 000- CD3.106w 4.1/2 "x6 - 118" DDI 80 -64• Shah tortuosity with high tortuos or longer watts with by tortuosity DDI = 6.889 _ ___ p 0 9 3 14606 DDI 64- 68' Lap walls with relatively tortuous ales -- J COI > 6.8: Long, tortuous profiles with a high degree of dMalty 1 CD3.109_RedrlllwpXX West Tee _ I-IALLIBURTON REFERENCE INFORMATION SurfaceLocasorl 0 Northing 6003599.43 - 1 I _- I Coordnale(NIE) Reference WM Flan: CO3 -106, True North Easling 1528298 37 - Vertical (N en D) Reference Ps: CD3 -306 (36 3+114) Q 49 70ft (Doyon 19) Ground Level 1140 Sperry Drilling C Curvature WE) L3ltude 70 °258942N 16 alculabon Geodetic zone: Alaska Zone Langiwde 150'54' 48252 W Start DLS 0.00 TFO 21.09 - - ,,Sgt 50 03:40, December 29 2009 Geodetic Datum North American Datum 1983 y 0 CASING DETAILS SURVEY PROGRAM . ^ •y 000 - Start DLS 3.00 TFO 88.73 - ea ND TVDSS MD Name Sae 2500.00 245030 273979 9-5/8 9.5/8 +12.1/4° 36.30 1000.00 CO3- 106w409 (Plan: CO3 -106) CB- GYRO -SS 10500- - 10500 692470 687500 1278616 7 7'x8-3/4° 1000.00 17843.12 CD3- 106wp09 (Pram CO3 -106) MWO +IFR- AK-CAZ -SC . 687470 8825.00 17843.12 4 41/2'x6 - /8• Start DLS 3,00 TFO - 90.00 _ - - -5. / a +r•- - - Start Drop -3.00 -- - Start Build 3.00 - - -•� - -____ Targets - - - - 1 CD3.106wp09 Top Neche$ik - Name TVDSS +W -6 +El -W Northing Eacerp Shape C 120 CD3109 Reaathg9 West Ton 8825.00 1365005 -360959 601720100 152489300 Circle (Radius: 100.00) Start DLS 2.69 TFO - 58.46 6n CD3- 106;p09 Top N6 delr 11876.00 956037 -71139 6013188 60 152]]2970 Ckda(Radius: 10.00) _ - p O el 110 SECTION DETAILS - - - Start DLS 2.50 TFO - 45.93 0 Sec MD Inc Aal TVD TVDSS +14/4 +E/.M Northing EeatIng DLag TFece VSS6 Target 7000- 10000 - - 7000 0 1 36.30 0.00 0.00 36.30 -13.40 0.00 0.00 6003599.43 1528298.37 0.00 0.00 0.00 O 2 250.00 0.00 000 25000 200.30 0.00 0.00 6003599.43 152829037 0.00 000 000 Z 3 500.18 3.75 150.00 500,00 450.30 .7.09 4.10 6003592.28 1528302.36 1.50 160.00 4.15 Z. 4 904.59 12.49 135.84 90000 85010 -50.01 41.25 6003548.81 1528338.86 220 30.00 -62.47 - - 5 2981.00 62.84 355.62 2625.33 2575.63 831.40 140.75 6004128.55 1528451.58 3.50 - 143.40 702.27 .5. 9000 6 11694.39 62.84 355.62 6602.88 6553.18 8561.29 -451.93 6012165.80 1527975.11 0.00 0.00 800494 O 0 7 12786.16 83.00 336.23 6924.70 6875.00 9560.37 - 712.39 6013168.60 1527729.70 2.50 -45.93 902159 CO3- 106w309 Top Nechelik N - - 8 13276.31 90.00 325.00 6954.70 6905.00 9985.62 . 952.07 6013597.37 1527496.46 2.69 -58.46 9509.56 8000 9 13376.31 93.00 325.00 6952.08 6902.38 10067.50 - 1009.40 6013600.09 1527440.37 3.00 0.00 960768 10 13456.31 9060 325.00 6949.57 6869.87 10132.99 . 105526 6013746.26 152739560 3.00 180.00 9686.16 11 14458.26 90.52 295.00 6939.57 6889.87 10768.40 - 1812.51 6014392.91 1526647.94 3.00 -90.00 10574.64 - - 12 15783.63 91.21 334.82 691066 6868.96 11686.62 . 273168 6015324.79 1525740.75 100 88.73 11786.15 356 13 17843.12 91.23 334.83 687470 6825.00 13550.05 - 3609.59 6017201.00 1524893.00 0.00 21.09 13846.74 003 -109 Redriliwpxx West Toe 7000 _ 3300- 600 - - 3500 . (Jr _ - -. - _ 5000 -_ eromm+aa 0 2500 5000 7500 - I I I I I I I I I I I I I I I I I 1 I 1 I I I _I I 1 - 4000 Start 8713.40 hold at 2981.00 MD 9 -5/8" x 12 -114" o- Start Build 1.50 - Start DLS 3.50 TFO - 143.40 $. 3000 - -. ° - -Start DLS 2.20 TFO -20.00 a - Start DLS 2.20 TFO - 20.00 - -- - o 00 -0 5 - Base Permafrost 1D °- -Start DLS 3.50 TFO - 143.40 _ Start Build 1.50 e 1 000 I I I I - I 1 I I I I I I I I I I i I I _ C ° - 7000 - 3500 0 3500 9-5/8 "x12 -1/4" West( -) /East( +) (3500 ft/in) C -30 0 1500 °° Start 8713.40 hold at 2981.00 MD - 2500 O - - _ 0 0 01 ANNOTATIONS N M. 1j ND 20030 MD Annotation Build L C - 0 00 - N 500.00 45030 50010 Start DL 50 d1 O -20.00 030 90459 Start OLS 3 50 TFO b o Start DLS 2.69 TFO - 58.46 0 2325 33 2575 63 2981.00 Start 8713.40 hold at 2 2981.00 MD CD Cl K - K - Basal o o ° S tart Build 3.00 _ - O 660288 6553181169439 Start DLS 250 TFO -45.93 �- 692470 687500 12786.16 Start DLS 2.69 TFO -58.46 U - - 0 I 6954 70 6905 00 13276 31 Start Build 3.00 CS . DLS 2.50 TFO -45.93 ' 1 Start Drop - 3.00 - N3 6952 08 6902 38 13376 31 Scat Drop -3.00 -\ - 7 43 O 694957 689987 13456.31 Start DLS 800 TFO -9000 O I O 6939 57 630987 14458.28 Slat DLS 300 TFO 8873 o Start DLS 3.00 TFO - 90.00 --nn 691866 6868 96 1678163 Start DLS 000TFO 2109 N - K -2 Basal K -2 (gan0lk) 00 7° x 8 -3/4" _ 6874.70 6825.00 17843.12 70317843.12 I- 5000- 000 I S OL 3.00 TFO 88.73 • m oo r3 0 1 FORMATION TOP DETAILS - Albian 97 Albian 96 0 0 1 i Start DLS 0 TFO 21.09 ^ O 1 TVDPat0 N0 00 MDPath Formation i - - - - 04 I _ 1249.70 82 1200 0 00 125874 Bone Perm 0-40 2329 70 228000 1 I 4 - 1/2" x 6 - 1/8" 2499.70 245000 273927 C -30 - '" n i e 0 I I _ 2889 70 284000 3560.15 0-20 - TOP HRZ Base HRZ 4) $ \ i p I . 4. - 3934.70 3885.00 5849.37 K -3 t °O 4094.70 454500 619987 K -3 Basel - , - _ _ - K_1 Top Kuparuk D ` 1 ' u» b _ 4124 70 4075,00 c165.50 K3 (Donor) - - - - - - _ _ _. _. _. m- rn. - _ - - - _ - -- 4229 70 4180.00 6495 61 K -2 Basal -. ._ _ _ .- - -� _ 568970 5134000 969395 AINan 97 - -- - - _ ' 03 m CD3- t O6wp0� - 501 596500 10405 TNan96 _ �y O 686470 6615 00 1183583 Top HR] Nechelik LCU Top Kuparuk C 0 0 ° o ° o o 6669470 6645 o n o 18 8 C 09,54 Bye Ii H 7500- Top � P CD3 106wp09 Top Nechelik RedriltwpXX West To - 7500 e 680970 676000 1224037 Top KuparukD 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 1 I I I I I 1 I 1 I 6849.70 8800.00 12385 91 Top Kuparuk C 6857 70 6808 00 12418 33 LCU 0 2500 5000 7500 10000 12500 15000 693470 688600 1187640 Top 5e06tli81 Vertical Section at 336.00 °(2500 ft/in) • • ConocoPhillips HALLIBURTQN 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 15 Project: Western North Slope MD Reference: Plan: CD3 -306 (36.3 +13.4) © 49.70ft (Doyon 19 Site: CD3 Fjord Pad North Reference: True Weil: Plan: CD3 -106 Survey Calculation Method: Minimum Curvature Wel!bore: Plan: CD3 -106 Design: CD3 106wp09 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 ft ✓ Latitude: 70° 25' 10.108 N +E / -W 0.00 ft Easting: 388,266.46 ft ✓ Longitude: 150° 54' 36.875 W Uncertainty 0.00ft Wellhead Elevation: ft Ground Level: 13.40ft Welibore Plan: CD3 -106 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) ( (nT) BGGM2007 12/28/2009 16.37 79.70 57,320 Design CD3- 106wp09 Audit Notes: Version: Phase: PLAN Tie On Depth: 36.30 Vertical Section: Depth From (TVD) +N /-S +E/ -W Direction I (ft) (ft) (ft) ( 36.30 0.00 0.00 336.00 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/.W Rate Rate Rate Tool Face (ft) (°) (°) (ft) ft (ft) (ft (°t100ft) ( °il00ft) ( °1100ft) (1 36.30 0.00 0.00 36.30 -13.40 0.00 0.00 0.00 0.00 0.00 0.00 250.00 0.00 0.00 250.00 200.30 0.00 0.00 0.00 0.00 0.00 0.00 500.18 3.75 150.00 500.00 450.30 -7.09 4.10 1.50 1.50 0.00 150.00 904.59 12.49 135.84 900.00 850.30 -50.01 41.25 2.20 2.16 -3.50 -20.00 2,980.98 62.84 355.62 2,625.31 2,575.61 831.40 140.84 3.50 2.42 -6.75 - 143.39 11,694.32 62.84 355.62 6,602.84 6,553.14 8,561.27 - 451.21 0.00 0.00 0.00 0.00 12,786.20 83.00 336.23 6,924.70 6,875.00 9,560.47 - 711.66 2.50 1.85 -1.78 -45.93 13,276.35 90.00 325.00 6,954.70 6,905.00 9,985.73 - 951.33 2.69 1.43 -2.29 -58.46 13,376.35 93.00 325.00 6,952.08 6,902.38 10,067.60 - 1,008.67 3.00 3.00 0.00 0.00 13,456.35 90.60 325.00 6,949.57 6,899.87 10,133.10 - 1,054.53 3.00 -3.00 0.00 180.00 14,456.30 90.52 295.00 6,939.57 6,889.87 10,768.51 - 1,811.78 3.00 -0.01 -3.00 -90.00 15,783.67 91.21 334.82 6,918.66 6,868.96 11,686.73 - 2,732.95 3.00 0.05 3.00 88.73 17,843.29 91.23 334.85 6,874.70 6,825.00 13,550.44 - 3,608.54 0.00 0.00 0.00 55.50 1/4/2010 8 :54 :01AM Page 2 COMPASS 2003.16 Build 69 „....,.. , t , , ,. ConocoPhillips HALL!BURTON 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 Wellbore: Plan: CD3 -106 Design: CD3- 106wp09 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) -13.40 36.30 0.00 0.00 36.30 -13.40 0.00 0.00 6,003,852.22 388,266.46 0.00 0.00 100.00 0.00 0.00 100.00 50.30 0.00 0.00 6,003,852.22 388,266.46 0.00 0.00 1 200.00 0.00 0.00 200.00 150.30 0.00 0.00 6,003,852.22 388,266.46 0.00 0.00 250.00 0.00 0.00 250.00 200.30 0.00 0.00 6,003,852.22 388,266.46 0.00 0.00 Start Build 1.50 300.00 0.75 150.00 300.00 250.30 -0.28 0.16 6,003,851.93 388,266.62 1.50 -0.33 400.00 2.25 150.00 399.96 350.26 -2.55 1.47 6,003,849.65 388,267.89 1.50 -2.93 500.00 3.75 150.00 499.82 450.12 -7.08 4.09 6,003,845.08 388,270.44 1.50 -8.13 500.18 3.75 150.00 500.00 450.30 -7.09 4.10 6,003,845.07 388,270.45 1.50 -8.15 Start DLS 2.20 TFO - 20.00 600.00 5.86 142.63 599.47 549.77 -13.98 8.82 6,003,838.11 388,275.07 2.20 -16.36 700.00 8.03 139.18 698.73 649.03 -23.32 16.49 6,003,828.66 388,282.60 2.20 -28.01 800.00 10.20 137.19 797.46 747.76 -35.10 27.07 6,003,816.72 388,293.00 2.20 -43.08 900.00 12.39 135.89 895.51 845.81 -49.30 40.56 6,003,802.32 388,306.27 2.20 -61.54 904.59 12.49 135.84 900.00 850.30 -50.01 41.25 6,003,801.60 388,306.95 2.20 -62.47 Start DLS 3.50 TFO - 143.40 1,000.00 10.01 124.31 993.58 943.88 -62.09 55.29 6,003,789.32 388,320.81 3.50 -79.21 1,100.00 8.08 105.51 1,092.35 1,042.65 -68.87 69.24 6,003,782.33 388,334.66 3.50 -91.08 1,200.00 7.41 79.80 1,191.47 1,141.77 -69.60 82.37 6,003,781.39 388,347.77 3.50 -97.09 1,258.74 7.76 64.40 1,249.70 1,200.00 -67.22 89.68 6,003,783.67 388,355.11 3.50 -97.88 Base Permafrost 1,300.00 8.30 54.81 1,290.56 1,240.86 -64.30 94.63 6,003,786.52 388,360.10 3.50 -97.23 1,400.00 10.36 37.16 1,389.25 1,339.55 -52.97 105.96 6,003,797.67 388,371.60 3.50 -91.49 1,500.00 13.04 25.96 1,487.18 1,437.48 -35.66 116.33 6,003,814.82 388,382.23 3.50 -79.89 1,600.00 16.03 18.70 1,583.97 1,534.27 -12.43 125.70 6,003,837.91 388,391.95 3.50 -62.48 1,700.00 19.20 13.73 1,679.28 1,629.58 16.63 134.03 6,003,866.84 388,400.71 3.50 -39.33 1,800.00 22.45 10.13 1,772.74 1,723.04 51.41 141.29 6,003,901.50 388,408.49 3.50 - 10.51 1,900.00 25.78 7.42 1,864.00 1,814.30 91.78 147.46 6,003,941.77 388,415.27 3.50 23.87 2,000.00 29.13 5.29 1,952.73 1,903.03 137.59 152.51 6,003,987.50 388,421.00 3.50 63.67 2,100.00 32.52 3.56 2,038.59 1,988.89 188.68 156.43 6,004,038.52 388,425.68 3.50 108.74 2,200.00 35.93 2.13 2,121.26 2,071.56 244.84 159.19 6,004,094.63 388,429.28 3.50 158.93 2,300.00 39.35 0.92 2,200.43 2,150.73 305.88 160.79 6,004,155.63 388,431.80 3.50 214.03 2,400.00 42.78 359.87 2,275.82 2,226.12 371.56 161.23 6,004,221.29 388,433.22 3.50 273.86 2,475.00 45.36 359.17 2,329.70 2,280.00 423.72 160.79 6,004,273.44 388,433.55 3.50 321.69 C-40 2,500.00 46.22 358.95 2,347.13 2,297.43 441.64 160.49 6,004,291.36 388,433.53 3.50 338.18 2,600.00 49.67 358.13 2,414.11 2,364.41 515.85 158.59 6,004,365.59 388,432.74 3.50 406.75 2,700.00 53.12 357.39 2,476.50 2,426.80 593.92 155.53 6,004,443.69 388,430.85 3.50 479.31 2,739.29 54.48 357.12 2,499.70 2,450.00 625.59 154.01 6,004,475.38 388,429.80 3.50 508.86 C - 30 2,739.80 54.50 357.12 2,500.00 2,450.30 626.01 153.99 6,004,475.80 388,429.79 3.50 509.25 9 - 5/8" x 12 - 1/4" 2,800.00 56.58 356.72 2,534.06 2,484.36 675.56 151.32 6,004,525.38 388,427.86 3.50 555.61 2,900.00 60.04 356.09 2,586.59 2,536.89 760.47 145.98 6,004,610.35 388,423.79 3.50 635.35 2,980.98 62.84 355.62 2,625.31 2,575.61 831.40 140.84 6,004,681.34 388,419.71 3.50 702.23 1/4/2010 8:54 :01AM Page 3 COMPASS 2003.16 Build 69 ORIGINAL 0 ConocoPhillips HALLIBURT ®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 Wellbore: Plan: CD3 -106 Design: CD3- 106wp09 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +WS +E/ -W Northing Easting DLS Vert Section (ft) ( ( (ft) ft (ft) (ft) (ft) (ft) 2,575.61 2,981.00 62.84 355.62 2,625.31 2,575.61 831.41 140.84 6,004,681.36 388,419.71 0.00 702.25 Start 8713.40 hold at 2981.00 MD 3,000.00 62.84 355.62 2,633.99 2,584.29 848.27 139.55 6,004,698.23 388,418.67 0.00 718.18 3,100.00 62.84 355.62 2,679.64 2,629.94 936.99 132.75 6,004,787.03 388,413.21 0.00 801.98 3,200.00 62.84 355.62 2,725.29 2,675.59 1,025.70 125.96 6,004,875.83 388,407.74 0.00 885.79 3,300.00 62.84 355.62 2,770.94 2,721.24 1,114.41 119.16 6,004,964.63 388,402.28 0.00 969.60 3,400.00 62.84 355.62 2,816.58 2,766.88 1,203.12 112.37 6,005,053.42 388,396.81 0.00 1,053.41 3,500.00 62.84 355.62 2,862.23 2,812.53 1,291.84 105.57 6,005,142.22 388,391.34 0.00 1,137.21 3,560.17 62.84 355.62 2,889.70 2,840.00 1,345.22 101.48 6,005,195.65 388,388.06 0.00 1,187.64 C - 20 3,600.00 62.84 355.62 2,907.88 2,858.18 1,380.55 98.78 6,005,231.02 388,385.88 0.00 1,221.02 3,700.00 62.84 355.62 2,953.53 2,903.83 1,469.26 91.98 6,005,319.81 388,380.41 0.00 1,304.83 3,800.00 62.84 355.62 2,999.18 2,949.48 1,557.98 85.19 6,005,408.61 388,374.95 0.00 1,388.63 3,900.00 62.84 355.62 3,044.83 2,995.13 1,646.69 78.39 6,005,497.41 388,369.48 0.00 1,472.44 4,000.00 62.84 355.62 3,090.48 3,040.78 1,735.40 71.60 6,005,586.21 388,364.02 0.00 1,556.25 I 4,100.00 62.84 355.62 3,136.13 3,086.43 1,824.12 64.80 6,005,675.00 388,358.55 0.00 1,640.06 4,200.00 62.84 355.62 3,181.77 3,132.07 1,912.83 58.01 6,005,763.80 388,353.09 0.00 1,723.86 4,300.00 62.84 355.62 3,227.42 3,177.72 2,001.54 51.21 6,005,852.60 388,347.62 0.00 1,807.67 4,400.00 62.84 355.62 3,273.07 3,223.37 2,090.26 44.42 6,005,941.40 388,342.15 0.00 1,891.48 4,500.00 62.84 355.62 3,318.72 3,269.02 2,178.97 37.62 6,006,030.19 388,336.69 0.00 1,975.28 4,600.00 62.84 355.62 3,364.37 3,314.67 2,267.68 30.83 6,006,118.99 388,331.22 0.00 2,059.09 4,700.00 62.84 355.62 3,410.02 3,360.32 2,356.40 24.04 6,006,207.79 388,325.76 0.00 2,142.90 4,800.00 62.84 355.62 3,455.67 3,405.97 2,445.11 17.24 6,006,296.58 388,320.29 0.00 2,226.71 4,900.00 62.84 355.62 3,501.32 3,451.62 2,533.82 10.45 6,006,385.38 388,314.83 0.00 2,310.51 5,000.00 62.84 355.62 3,546.96 3,497.26 2,622.53 3.65 6,006,474.18 388,309.36 0.00 2,394.32 5,100.00 62.84 355.62 3,592.61 3,542.91 2,711.25 -3.14 6,006,562.98 388,303.89 0.00 2,478.13 5,200.00 62.84 355.62 3,638.26 3,588.56 2,799.96 -9.94 6,006,651.77 388,298.43 0.00 2,561.93 5,300.00 62.84 355.62 3,683.91 3,634.21 2,888.67 -16.73 6,006,740.57 388,292.96 0.00 2,645.74 5,400.00 62.84 355.62 3,729.56 3,679.86 2,977.39 -23.53 6,006,829.37 388,287.50 0.00 2,729.55 5,500.00 62.84 355.62 3,775.21 3,725.51 3,066.10 -30.32 6,006,918.17 388,282.03 0.00 2,813.36 5,600.00 62.84 355.62 3,820.86 3,771.16 3,154.81 -37.12 6,007,006.96 388,276.57 0.00 2,897.16 5,700.00 62.84 355.62 3,866.51 3,816.81 3,243.53 -43.91 6,007,095.76 388,271.10 0.00 2,980.97 5,800.00 62.84 355.62 3,912.16 3,862.46 3,332.24 -50.71 6,007,184.56 388,265.64 0.00 3,064.78 5,849.39 62.84 355.62 3,934.70 3,885.00 3,376.05 -54.06 6,007,228.41 388,262.94 0.00 3,106.17 K - 3 5,900.00 62.84 355.62 3,957.80 3,908.10 3,420.95 -57.50 6,007,273.35 388,260.17 0.00 3,148.58 6,000.00 62.84 355.62 4,003.45 3,953.75 3,509.67 -64.30 6,007,362.15 388,254.70 0.00 3,232.39 I 6,100.00 62.84 355.62 4,049.10 3,999.40 3,598.38 -71.09 6,007,450.95 388,249.24 0.00 3,316.20 6,199.89 62.84 355.62 4,094.70 4,045.00 3,686.99 -77.88 6,007,539.65 388,243.78 0.00 3,399.91 K - 3 Basal 6,200.00 62.84 355.62 4,094.75 4,045.05 3,687.09 -77.88 6,007,539.75 388,243.77 0.00 3,400.01 6,265.61 62.84 355.62 4,124.70 4,075.00 3,745.30 -82.34 6,007,598.01 388,240.19 0.00 3,454.99 K - 2 (Qannik) 6,300.00 62.84 355.62 4,140.40 4,090.70 3,775.81 -84.68 6,007,628.54 388,238.31 0.00 3,483.81 I 6,400.00 62.84 355.62 4,186.05 4,136.35 3,864.52 -91.47 6,007,717.34 388,232.84 0.00 3,567.62 1/4/2010 8:54:01AM Page 4 COMPASS 2003.16 Build 69 fp! 'It • ConocoPhillips HALL1BURT ®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 15 Site: CD3 Fjord Pad North Reference: True Welk Plan: CD3 - 106 Survey Calculation Method: Minimum Curvature Welibore: Plan: CD3 -106 Design: CD3- 106wp09 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NIS +0-W Northing Fasting DLS Vert Section (ft) t ( (ft) ft (ft) (ft) (ft) (ft) 4,180.00 6,495.63 62.84 355.62 4,229.70 4,180.00 3,949.35 - 97.97 6,007,802.25 388,227.62 0.00 3,647.76 K - 2 Basal 6,500.00 62.84 355.62 4,231.70 4,182.00 3,953.23 -98.27 6,007,806.14 388,227.38 0.00 3,651.43 i 6,600.00 62.84 355.62 4,277.35 4,227.65 4,041.94 - 105.06 6,007,894.94 388,221.91 0.00 3,735.23 6,700.00 62.84 355.62 4,322.99 4,273.29 4,130.66 - 111.86 6,007,983.73 388,216.44 0.00 3,819.04 6,800.00 62.84 355.62 4,368.64 4,318.94 4,219.37 - 118.65 6,008,072.53 388,210.98 0.00 3,902.85 6,900.00 62.84 355.62 4,414.29 4,364.59 4,308.08 - 125.45 6,008,161.33 388,205.51 0.00 3,986.66 7,000.00 62.84 355.62 4,459.94 4,410.24 4,396.80 - 132.24 6,008,250.13 388,200.05 0.00 4,070.46 7,100.00 62.84 355.62 4,505.59 4,455.89 4,485.51 - 139.04 6,008,338.92 388,194.58 0.00 4,154.27 7,200.00 62,84 355.62 4,551.24 4,501.54 4,574.22 - 145.83 6,008,427.72 388,189.12 0.00 4,238.08 7,300.00 62.84 355.62 4,596.89 4,547.19 4,662.94 - 152.63 6,008,516.52 388,183.65 0.00 4,321.88 7,400.00 62.84 355.62 4,642.54 4,592.84 4,751.65 - 159.42 6,008,605.31 388,178.19 0.00 4,405.69 7,500.00 62.84 355.62 4,688.18 4,638.48 4,840.36 - 166.22 6,008,694.11 388,172.72 0.00 4,489.50 I 7,600.00 62.84 355.62 4,733.83 4,684.13 4,929.08 - 173.01 6,008,782.91 388,167.25 0.00 4,573.30 7,700.00 62.84 355.62 4,779.48 4,729.78 5,017.79 - 179.81 6,008,871.71 388,161.79 0.00 4,657.11 7,800.00 62.84 355.62 4,825.13 4,775.43 5,106.50 - 186.60 6,008,960.50 388,156.32 0.00 4,740.92 7,900.00 62.84 355.62 4,870.78 4,821.08 5,195.22 - 193.39 6,009,049.30 388,150.86 0.00 4,824.73 8,000.00 62.84 355.62 4,916.43 4,866.73 5,283.93 - 200.19 6,009,138.10 388,145.39 0.00 4,908.53 8,100.00 62.84 355.62 4,962.08 4,912.38 5,372.64 - 206.98 6,009,226.90 388,139.93 0.00 4,992.34 8,200.00 62.84 355.62 5,007.73 4,958.03 5,461.36 - 213.78 6,009,315.69 388,134.46 0.00 5,076.15 8,300.00 62.84 355.62 5,053.37 5,003.67 5,550.07 - 220.57 6,009,404.49 388,129.00 0.00 5,159.95 8,400.00 62.84 355.62 5,099.02 5,049.32 5,638.78 - 227.37 6,009,493.29 388,123.53 0.00 5,243.76 8,500.00 62.84 355.62 5,144.67 5,094.97 5,727.49 - 234.16 6,009,582.08 388,118.06 0.00 5,327.57 8,600.00 62.84 355.62 5,190.32 5,140.62 5,816.21 - 240.96 6,009,670.88 388,112.60 0.00 5,411.38 8,700.00 62.84 355.62 5,235.97 5,186.27 5,904.92 - 247.75 6,009,759.68 388,107.13 0.00 5,495.18 8,800.00 62.84 355.62 5,281.62 5,231.92 5,993.63 - 254.55 6,009,848.48 388,101.67 0.00 5,578.99 8,900.00 62.84 355.62 5,327.27 5,277.57 6,082.35 - 261.34 6,009,937.27 388,096.20 0.00 5,662.80 9,000.00 62.84 355.62 5,372.92 5,323.22 6,171.06 - 268.14 6,010,026.07 388,090.74 0.00 5,746.60 9,100.00 62.84 355.62 5,418.57 5,368.87 6,259.77 - 274.93 6,010,114.87 388,085.27 0.00 5,830.41 9,200.00 62.84 355.62 5,464.21 5,414.51 6,348.49 - 281.73 6,010,203.67 388,079.80 0.00 5,914.22 9,300.00 62.84 355.62 5,509.86 5,460.16 6,437.20 - 288.52 6,010,292.46 388,074.34 0.00 5,998.03 9,400.00 62.84 355.62 5,555.51 5,505.81 6,525.91 - 295.31 6,010,381.26 388,068.87 0.00 6,081.83 9,500.00 62.84 355.62 5,601.16 5,551.46 6,614.63 - 302.11 6,010,470.06 388,063.41 0.00 6,165.64 9,600.00 62.84 355.62 5,646.81 5,597.11 6,703.34 - 308.90 6,010,558.85 388,057.94 0.00 6,249.45 9,693.96 62.84 355.62 5,689.70 5,640.00 6,786.69 - 315.29 6,010,642.29 388,052.81 0.00 6,328.19 Albian 97 9,700.00 62.84 355.62 5,692.46 5,642.76 6,792.05 - 315.70 6,010,647.65 388,052.48 0.00 6,333.25 9,800.00 62.84 355.62 5,738.11 5,688.41 6,880.77 - 322.49 6,010,736.45 388,047.01 0.00 6,417.06 9,900.00 62.84 355.62 5,783.76 5,734.06 6,969.48 - 329.29 6,010,825.25 388,041.55 0.00 6,500.87 10,000.00 62.84 355.62 5,829.40 5,779.70 7,058.19 - 336.08 6,010,914.04 388,036.08 0.00 6,584.68 10,100.00 62.84 355.62 5,875.05 5,825.35 7,146.90 - 342.88 6,011,002.84 388,030.61 0.00 6,668.48 10,200.00 62.84 355.62 5,920.70 5,871.00 7,235.62 - 349.67 6,011,091.64 388,025.15 0.00 6,752.29 10,300.00 62.84 355.62 5,966.35 5,916.65 7,324.33 - 356.47 6,011,180.44 388,019.68 0.00 6,836.10 10,400.00 62.84 355.62 6,012.00 5,962.30 7,413.04 - 363.26 6,011,269.23 388,014.22 0.00 6,919.90 1/4/2010 8:54:01AM Page 5 COMPASS 2003.16 Build 69 n rlto li III ConocoPhillips HALL1BURTO SJ 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 18 Site: CD3 Fjord Pad North Reference: True Welty Plan: CD3 - 106 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD3 -106 Design: CD3- 106wp09 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVOss +N /-S +E/-W Northing Easting DLS Vert Section (ft) ( °) ( (ft) ft (ft) (ft) (ft) (ft) 5,965.00 10,405.92 62.84 355.62 6,014.70 5,965.00 7,418.29 - 363.66 6,011,274.49 388,013.89 0.00 6,924.86 Albian 96 10,500.00 62.84 355.62 6,057.65 6,007.95 7,501.76 - 370.06 6,011,358.03 388,008.75 0.00 7,003.71 10,600.00 62.84 355.62 6,103.30 6,053.60 7,590.47 - 376.85 6,011,446.83 388,003.29 0.00 7,087.52 10,700.00 62.84 355.62 6,148.95 6,099.25 7,679.18 - 383.65 6,011,535.62 387,997.82 0.00 7,171.33 10,800.00 62.84 355.62 6,194.59 6,144.89 7,767.90 - 390.44 6,011,624.42 387,992.35 0.00 7,255.13 10,900.00 62.84 355.62 6,240.24 6,190.54 7,856.61 - 397.24 6,011,713.22 387,986.89 0.00 7,338.94 ■ 11,000.00 62.84 355.62 6,285.89 6,236.19 7,945.32 - 404.03 6,011,802.02 387,981.42 0.00 7,422.75 11,100.00 62.84 355.62 6,331.54 6,281.84 8,034.04 - 410.82 6,011,890.81 387,975.96 0.00 7,506.55 11,200.00 62.84 355.62 6,377.19 6,327.49 8,122.75 - 417.62 6,011,979.61 387,970.49 0.00 7,590.36 11,300.00 62.84 355.62 6,422.84 6,373.14 8,211.46 - 424.41 6,012,068.41 387,965.03 0.00 7,674.17 11,400.00 62.84 355.62 6,468.49 6,418.79 8,300.18 - 431.21 6,012,157.21 387,959.56 0.00 7,757.98 11,500.00 62.84 355.62 6,514.14 6,464.44 8,388.89 - 438.00 6,012,246.00 387,954.10 0.00 7,841.78 11,600.00 62.84 355.62 6,559.78 6,510.08 8,477.60 - 444.80 6,012,334.80 387,948.63 0.00 7,925.59 11,694.32 62.84 355.62 6,602.84 6,553.14 8,561.27 - 451.21 6,012,418.55 387,943.47 0.00 8,004.63 11,694.39 62.84 355.62 6,602.87 6,553.17 8,561.34 - 451.21 6,012,418.62 387,943.47 0.00 8,004.70 Start DLS 2.50 TFO - 45.93 11,700.00 62.94 355.51 6,605.43 6,555.73 8,566.32 - 451.60 6,012,423.60 387,943.16 2.53 8,009.40 1 11,800.00 64.69 353.52 6,649.56 6,599.86 8,655.63 - 460.19 6,012,513.03 387,935.91 2.50 8,094.49 11,835.84 65.33 352.82 6,664.70 6,615.00 8,687.89 - 464.05 6,012,545.33 387,932.53 2.50 8,125.53 Top HRZ 11,900.00 66.47 351.59 6,690.90 6,641.20 8,745.91 - 472.00 6,012,603.46 387,925.45 2.50 8,181.76 11,909.56 66.64 351.41 6,694.70 6,645.00 8,754.58 - 473.29 6,012,612.15 387,924.29 2.50 8,190.21 Base HRZ 12,000.00 68.28 349.72 6,729.37 6,679.67 8,836.98 - 486.99 6,012,694.74 387,911.82 2.50 8,271.06 12,100.00 70.10 347.89 6,764.90 6,715.20 8,928.66 - 505.15 6,012,786.67 387,895.04 2.50 8,362.20 12,129.16 70.63 347.36 6,774.70 6,725.00 8,955.49 - 511.04 6,012,813.58 387,889.55 2.50 8,389.10 I K -1 12,200.00 71.94 346.10 6,797.43 6,747.73 9,020.79 - 526.44 6,012,879.10 387,875.13 2.50 8,455.02 12,240.40 72.69 345.39 6,809.70 6,760.00 9,058.10 - 535.92 6,012,916.54 387,866.21 2.50 8,492.96 Top Kuparuk D 12,300.00 73.80 344.35 6,826.88 6,777.18 9,113.18 - 550.82 6,012,971.84 387,852.14 2.50 8,549.35 12,385.95 75.41 342.87 6,849.70 6,800.00 9,192.67 - 574.20 6,013,051.67 387,829.95 2.50 8,631.47 Top Kuparuk C 12,400.00 75.67 342.63 6,853.21 6,803.51 9,205.67 - 578.24 6,013,064.72 387,826.11 2.50 8,644.99 12,418.36 76.02 342.32 6,857.70 6,808.00 9,222.65 - 583.60 6,013,081.77 387,821.01 2.50 8,662.68 LCU 12,500.00 77.56 340.94 6,876.36 6,826.66 9,298.07 - 608.65 6,013,157.56 387,797.09 2.50 8,741.77 12,600.00 79.45 339.28 6,896.29 6,846.59 9,390.21 - 641.99 6,013,250.18 387,765.14 2.50 8,839.50 12,700.00 81.35 337.63 6,912.97 6,863.27 9,481.91 - 678.20 6,013,342.40 387,730.31 2.50 8,938.00 12,786.16 83.00 336.23 6,924.69 6,874.99 9,560.44 - 711.64 6,013,421.41 387,698.05 2.50 9,023.34 Start DLS 2.69 TFO - 58.46 - 7" x 8 12,786.20 83.00 336.23 6,924.70 6,875.00 9,560.47 - 711.66 6,013,421.45 387,698.03 2.50 9,023.39 CD3 106wp09 Top Nechelik 12,800.00 83.19 335.91 6,926.36 6,876.66 9,573.00 - 717.21 6,013,434.05 387,692.66 2.69 9,037.08 1/4/2010 8:54:01AM ` r R ! P4aels i' 1 ft, I COMPASS 2003.16 Build 69 • • ConocoPhillips HALL18URTOlti1 Standard Proposal Report Database: EDM v16 Prod Local Co- ordinate Reference: Well Plan: CD3 - 106 Company: ConocoPhillips(Aiaska) Inc. 1VD 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 19 Site: CD3 Fjord Pad North Reference: True Well: Plan: CD3 - 106 Survey Calculation Method: Minimum Curvature Weilbore: Plan: CD3 -106 Design: CD3- 106wp09 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NIS +E1.W Northing Easting DLS Vert Section (ft) (°) ( °) (ft) ft (ft) (ft) (ft) (ft) 8,885.00 12,876.44 84.28 334.15 6,934.70 6,885.00 9,641.87 - 749.29 6,013,503.40 387,661.62 2.69 9,113.05 Top Nechelik 12,900.00 84.61 333.61 6,936.98 6,887.28 9,662.93 - 759.62 6,013,524.60 387,651.62 2.69 9,136.48 13,000.00 86.04 331.31 6,945.13 6,895.43 9,751.29 - 805.70 6,013,613.64 387,606.86 2.69 9,235.95 13,100.00 87.47 329.02 6,950.80 6,901.10 9,837.89 - 855.36 6,013,700.96 387,558.50 2.69 9,335.27 13,200.00 88.90 326.74 6,953.97 6,904.27 9,922.53 - 908.50 6,013,786.38 387,506.64 2.69 9,434.20 13,276.31 90.00 325.00 6,954.70 6,905.00 9,985.69 - 951.31 6,013,850.17 387,464.79 2.69 9,509.31 Start Build 3.00 13,276.35 90.00 325.00 6,954.70 6,905.00 9,985.73 - 951.33 6,013,850.21 387,464.77 2.69 9,509.36 13,300.00 90.71 325.00 6,954.55 6,904.85 10,005.10 - 964.90 6,013,869.78 387,451.49 3.00 9,532.57 13,376.31 93.00 325.00 6,952.08 6,902.38 10,067.57 - 1,008.64 6,013,932.89 387,408.70 3.00 9,607.43 Start Drop - 3.00 13,376.35 93.00 325.00 6,952.08 6,902.38 10,067.60 - 1,008.67 6,013,932.93 387,408.67 3.00 9,607.47 13,400.00 92.29 325.00 6,950.99 6,901.29 10,086.96 - 1,022.22 6,013,952.48 387,395.41 3.00 9,630.66 13,456.31 90.60 325.00 6,949.57 6,899.87 10,133.06 - 1,054.50 6,013,999.06 387,363.83 3.00 9,685.92 Start DLS 3.00 TFO - 90.00 13,456.35 90.60 325.00 6,949.57 6,899.87 10,133.10 - 1,054.53 6,013,999.09 387,363.80 3.00 9,685.96 13,500.00 90.60 323.69 6,949.11 6,899.41 10,168.56 - 1,079.97 6,014,034.93 387,338.89 3.00 9,728.71 13,600.00 90.60 320.69 6,948.07 6,898.37 10,247.55 - 1,141.26 6,014,114.83 387,278.80 3.00 9,825.80 13,700.00 90.60 317.69 6,947.03 6,897.33 10,323.23 - 1,206.60 6,014,191.47 387,214.60 3.00 9,921.51 13,800.00 90.59 314.69 6,945.99 6,896.29 10,395.38 - 1,275.82 6,014,264.64 387,146.48 3.00 10,015.58 13,900.00 90.58 311.69 6,944.97 6,895.27 10,463.81 - 1,348.72 6,014,334.15 387,074.62 3.00 10,107.74 14,000.00 90.58 308.69 6,943.95 6,894.25 10,528.33 - 1,425.10 6,014,399.80 386,999.22 3.00 10,197.75 14,100.00 90.57 305.69 6,942.96 6,893.26 10,588.77 - 1,504.75 6,014,461.41 386,920.49 3.00 10,285.36 14,200.00 90.56 302.69 6,941.98 6,892.28 10,644.95 - 1,587.45 6,014,518.82 386,838.64 3.00 10,370.32 14,300.00 90.54 299.69 6,941.02 6,891.32 10,696.73 - 1,672.98 6,014,571.87 386,753.90 3.00 10,452.41 14,400.00 90.53 296.69 6,940.09 6,890.39 10,743.96 - 1,761.11 6,014,620.41 386,666.50 3.00 10,531.41 14,456.26 90.52 295.00 6,939.57 6,889.87 10,768.49 - 1,811.74 6,014,645.69 386,616.25 3.00 10,574.40 Start DLS 3.00 TFO 88.73 14,456.30 90.52 295.00 6,939.57 6,889.87 10,768.51 - 1,811.78 6,014,645.71 386,616.21 3.00 10,574.44 14,500.00 90.55 296.31 6,939.16 6,889.46 10,787.42 - 1,851.16 6,014,665.21 386,577.11 3.00 10,607.74 14,600.00 90.61 299.31 6,938.15 6,888.45 10,834.07 - 1,939.60 6,014,713.17 386,489.39 3.00 10,686.32 14,700.00 90.68 302.31 6,937.02 6,887.32 10,885.28 - 2,025.47 6,014,765.66 386,404.31 3.00 10,768.03 14,800.00 90.74 305.31 6,935.79 6,886.09 10,940.91 - 2,108.54 6,014,822.52 386,322.08 3.00 10,852.64 14,900.00 90.80 308.31 6,934.45 6,884.75 11,000.82 - 2,188.59 6,014,883.61 386,242.95 3.00 10,939.92 15,000.00 90.86 311.31 6,933.00 6,883.30 11,064.82 - 2,265.39 6,014,948.76 386,167.12 3.00 11,029.64 15,100.00 90.91 314.31 6,931.46 6,881.76 11,132.76 - 2,338.74 6,015,017.78 386,094.80 3.00 11,121.54 15,200.00 90.96 317.31 6,929.83 6,880.13 11,204.45 - 2,408.43 6,015,090.49 386,026.20 3.00 11,215.37 15,300.00 91.01 320.31 6,928.10 6,878.40 11,279.68 - 2,474.27 6,015,166.70 385,961.50 3.00 11,310.87 15,400.00 91.06 323.31 6,926.29 6,876.59 11,358.25 - 2,536.08 6,015,246.18 385,900.88 3.00 11,407.80 15,500.00 91.10 326.31 6,924.40 6,874.70 11,439.95 - 2,593.69 6,015,328.72 385,844.50 3.00 11,505.86 15,600.00 91.15 329.31 6,922.44 6,872.74 11,524.55 - 2,646.95 6,015,414.11 385,792.51 3.00 11,604.81 15,700.00 91.18 332.31 6,920.41 6,870.71 11,611.82 - 2,695.71 6,015,502.09 385,745.07 3.00 11,704.37 15,783.63 91.21 334.82 6,918.66 6,868.96 11,686.69 - 2,732.93 6,015,577.49 385,708.98 3.00 11,787.90 Start DLS 0.00 TFO 21.09 1/4/2010 8:54:01AM COMPASS 2003.16 Build 69 III ConocoPhillips HALL1BURTON 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 1.9 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 Wellbore: Plan: CD3 -106 Design: CD3- 106wp09 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), Oft (ft) 6,868.96 15,783.67 91.21 334.82 6,918.66 6,868.96 11,686.73 - 2,732.95 6,015,577.53 385,708.96 3.00 11,787.94 15,800.00 91.21 334.82 6,918.32 6,868.62 11,701.50 - 2,739.89 6,015,592.41 385,702.24 0.00 11,804.26 15,900.00 91.21 334.82 6,916.20 6,866.50 11,791.98 - 2,782.43 6,015,683.50 385,661.07 0.00 11,904.22 ' 16,000.00 91.21 334.82 6,914.08 6,864.38 11,882.45 - 2,824.96 6,015,774.60 385,619.90 0.00 12,004.18 16,100.00 91.22 334.82 6,911.96 6,862.26 11,972.94 - 2,867.49 6,015,865.70 385,578.73 0.00 12,104.13 16,200.00 91.22 334.83 6,909.84 6,860.14 12,063.42 - 2,910.02 6,015,956.80 385,537.56 0.00 12,204.09 16,300.00 91.22 334.83 6,907.71 6,858.01 12,153.90 - 2,952.54 6,016,047.90 385,496.40 0.00 12,304.05 16,400.00 91.22 334.83 6,905.59 6,855.89 12,244.38 - 2,995.07 6,016,139.00 385,455.24 0.00 12,404.00 16,500.00 91.22 334.83 6,903.46 6,853.76 12,334.87 - 3,037.59 6,016,230.11 385,414.08 0.00 12,503.96 16,600.00 91.22 334.83 6,901.33 6,851.63 12,425.35 - 3,080.11 6,016,321.21 385,372.93 0.00 12,603.92 16,700.00 91.22 334.83 6,899.20 6,849.50 12,515.84 - 3,122.62 6,016,412.32 385,331.77 0.00 12,703.87 16,800.00 91.22 334.84 6,897.06 6,847.36 12,606.33 - 3,165.14 6,016,503.42 385,290.62 0.00 12,803.83 16,900.00 91.22 334.84 6,894.93 6,845.23 12,696.82 - 3,207.65 6,016,594.53 385,249.47 0.00 12,903.79 17,000.00 91.22 334.84 6,892.79 6,843.09 12,787.31 - 3,250.16 6,016,685.64 385,208.33 0.00 13,003.74 17,100.00 91.23 334.84 6,890.65 6,840.95 12,877.80 - 3,292.66 6,016,776.75 385,167.18 0.00 13,103.70 17,200.00 91.23 334.84 6,888.51 6,838.81 12,968.29 - 3,335.17 6,016,867.86 385,126.04 0.00 13,203.66 17,300.00 91.23 334.84 6,886.37 6,836.67 13,058.78 - 3,377.67 6,016,958.97 385,084.90 0.00 13,303.61 , 17,400.00 91.23 334.84 6,884.23 6,834.53 13,149.28 - 3,420.17 6,017,050.08 385,043.77 0.00 13,403.57 17,500.00 91.23 334.85 6,882.08 6,832.38 13,239.77 - 3,462.67 6,017,141.19 385,002.63 0.00 13,503.53 17,600.00 91.23 334.85 6,879.93 6,830.23 13,330.27 - 3,505.16 6,017,232.31 384,961.50 0.00 13,603.48 17,700.00 91.23 334.85 6,877.78 6,828.08 13,420.77 - 3,547.65 6,017,323.42 384,920.37 0.00 13,703.44 17,800.00 91.23 334.85 6,875.63 6,825.93 13,511.26 - 3,590.14 6,017,414.54 384,879.24 0.00 13,803.40 17,843.12 91.23 334.85 6,874.70 6,825.00 13,550.29 - 3,608.46 6,017,453.83 384,861.51 0.00 13,846.50 TD at 17843.12 - 4 112" x 6 - 118" .- 17,843.29 91.23 334.85 6,874.70 ,' 6,825.00 13,550.44 - 3,608.54 6,017,453.99 384,861.44 0.46 13,846.67 CD3- 109_RedrillwpXX West 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- 106wp09 Top Nechelik 0.00 0.00 6,924.70 9,560.47 - 711.66 6,013,421.45 387,698.03 - plan hits target center - Circle (radius 10.00) CD3- 109_RedrillwpXX West Toe 0.00 0.00 6,874.70 13,550.44 - 3,608.54 6,017,453.99 384,861.44 - plan hits target center - Circle (radius 100.00) 1/4/2010 8:54:01AM COMPASS 2003.16 Build 69 ., 0 ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan: CD3 - 106 Company: ConocoPhillips(Alaska) Inc. 7VD Reference: Plan: CD3 -306 (36.3 +13.4) © 49.70ft (Doyon 1G Project: Western North Slope MD Reference: Plan: CD3 -306 (36.3 +13.4) @ 49.70ft (Doyon 1S Site: CD3 Fjord Pad North Reference: True Welk Plan: CD3 - 106 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD3 -106 Design: CD3- 106wp09 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name r) ( ") 2,739.80 2,500.00 9 -5/8" x 12 -1/4" 9 -5/8 12 -1/4 12,786.16 6,924.69 7" x 8 -3/4" 7 8 -3/4 17,843.12 6,874.70 4 -1/2" x 6 -1/8" 4 -1/2 6 -1/8 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (°) (') 6,265.61 4,124.70 K -2 (Qannik) 11,835.84 6,664.70 Top HRZ 5,849.39 3,934.70 K -3 6,495.63 4,229.70 K -2 Basal 9,693.96 5,689.70 Albian 97 6,199.89 4,094.70 K -3 Basal 3,560.17 2,889.70 C -20 2,739.29 2,499.70 C -30 11,909.56 6,694.70 Base HRZ 12,385.95 6,849.70 Top Kuparuk C 2,475.00 2,329.70 C -40 12,876.44 6,934.70 Top Nechelik 1,258.74 1,249.70 Base Permafrost 10,405.92 6,014.70 Albian 96 12,129.16 6,774.70 K -1 12,418.36 6,857.70 LCU 12,240.40 6,809.70 Top Kuparuk D L. Plan Annotations Measured Vertical Local Coordinates Depth Depth +NI$ +FJ-W (ft) (ft) (ft) (ft) Comment 250.00 250.00 0.00 0.00 Start Build 1.50 500.18 500.00 -7.09 4.10 Start DLS 2.20 TFO -20.00 904.59 900.00 -50.01 41.25 Start DLS 3.50 TFO - 143.40 2,981.00 2,625.31 831.41 140.84 Start 8713.40 hold at 2981.00 MD 11,694.39 6,602.87 8,561.34 - 451.21 Start DLS 2.50 TFO -45.93 12,786.16 6,924.69 9,560.43 - 711.64 Start DLS 2.69 TFO -58.46 13,276.31 6,954.70 9,985.69 - 951.31 Start Build 3.00 i 13,376.31 6,952.08 10,067.57 - 1,008.64 Start Drop -3.00 13,456.31 6,949.57 10,133.06 - 1,054.50 Start DLS 3.00 TFO -90.00 14,456.26 6,939.57 10,768.49 - 1,811.74 Start DLS 3.00 TFO 88.73 15,783.63 6,918.66 11,686.69 - 2,732.93 Start DLS 0.00 TFO 21.09 17,843.12 6,874.70 13,550.29 - 3,608.46 TD at 17843.12 1/4/2010 8:54:01AM ' � a P�� '+ '-' ''''' COMPASS 2003.16 Build 69 , I ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD3 Fiord Pad Plan: CD3 -106 Plan: CD3 -106 CD3- 106wp09 • CD 1 Sperry Dr Services ; #o 1 0 1 1 1 II Clearance Summary Major Risk Anticollision Report TMrequired 28 December, 2009 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad - Plan: CD3 -106 - Plan: CD3 -106 - CD3- 106wp09 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: 0.00 to 17,843.12 ft. Measured Depth. Scan Radius is 1,980.68 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited it Geodetic Scale Factor Applied I Version: 2003.16 Build: 69 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 m. HALLIBURTON .M. Sperry Drilling Services ' It Easting (3500 ft/in) J 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 1 1 1 1 1 1, 1 1 1 1 1 1 I 1 1 1 1 1 1 1 1 I 1 l 1, 1 1 1 1 1 1 1 1 1 1 1 1 1 I 1 1 1 1 1 1 1 1 t l i i 1 1 1 1 1 1 1 1 1 1 1 1 1 i i - ConocoPhillips(Alaska) Inc. -WNS Date prepared: Western North Slope 13:25, December 28 2009 CD3 Fiord Pad CD3 -109 - CD3- 126wp02 - CD3- 125w.02 CD3- 106wp09 :, GD'3- .. - \ " CD3 -108 - - CD3- 10 CD3- 01Awp07 (wo in progres ...) - CD3 -1 L1 Cla c • t L 1 CD3 -1 1 - • CD3-111 )1,1r, CD3 -1 b -- CD3 -11 D3 30' ' wp13 D3 -301 P: wp.6 CD i v - CD3 -1 4 - Z -- 7 CD3 -30 \ % - a a - CD3 -1 5 ��" . CD3 -307 - f M f 12PB f -302' :1 - ° CD3 -117 o _5 �� 4 -CD3 -303 � ''' "° CD 316 C I — 16 wp01 - • CD3- 199wp01 - .93-119w61 _ CD3 =304 - CD3- 305PB1 - CD3-305 - 11 1 1 1 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 T, I 1 1 1 1 1 1 I T I I I I I I I „ I I I I I 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 1 1 1 1 1 1 1 1 I 1 Easting (3500 ft/in) ConocoPhillips(Alaska) Inc. -WNS HALLIBURTON Western North Slope Anticollision Report for Plan: CD3 -106 - CD3- 106wp09 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad - Plan: CD3 -106 - Plan: CD3 -106 - CD3- 106wp09 Scan Range: 0.00 to 17,843.12 ft. Measured Depth. Scan Radius is 1,980.68 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 • 1 CD3 -107 - CD3 -107 - CD3 -107 549.66 15.82 549.66 4.60 550.00 1.410 Centre Distance Pass - Major Risk CD3 -107 - CD3 -107 - CD3 -107 648.89 16.54 648.89 3.71 650.00 1.289 Clearance Factor Pass - Major Risk CD3 -107 - CD3 -107L1 - CD3 -107L1 549.45 15.83 549.45 4.61 550.00 1.411 Centre Distance Pass - Major Risk e „..... CD3 -107 - CD3 -107L1 - CD3 -107L1 648.68 16.53 648.68 3.71 650.00 1.289 Clearance Factor Pass - Major Risk 4..._ CD3 -107 - CD3 -307 - CD3 -307 549.51 15.83 549.51 4.61 550.00 1.411 Centre Distance Pass - Major Risk 3 CD3 -107 - CD3 -307 - CD3 -307 648.74 16.53 648.74 3.71 650.00 1.289 Clearance Factor Pass - Major Risk -"'° CD3 -108 - CD3 -108 - CD3 -108 497.17 35.23 497.17 26.00 500.00 3.814 Centre Distance Pass - Major Risk CD3 -108 - CD3 -108 - CD3 -108 521.74 35.43 521.74 25.73 525.00 3.653 Clearance Factor Pass - Major Risk ---- CD3 -109 - CD3 -109 - CD3 -109 669.61 56.37 669.61 42.71 675.00 4.126 Centre Distance Pass - Major Risk CD3 -109 - CD3 -109 - CD3 -109 12,937.89 1 11. I< 4, CD3 -110 - CD3 -110 - CD3 -110 522.39 75.81 522.39 64.99 525.00 7.004 Centre Distance Pass - Major Risk .y°" CD3 -110 - CD3 -110 - CD3 -110 570.81 76.09 570.81 64.37 575.00 6.492 Clearance Factor Pass - Major Risk CD3 -111 - CD3 -111 - CD3 -111 36.40 100.05 36.40 99.14 36.10 109.554 Centre Distance Pass - Major Risk CD3 -111 - CD3 -111 - CD3 -111 349.56 103.41 349.56 96.01 350.00 13.978 Clearance Factor Pass - Major Risk CD3 -111 - CD3-111L1 - CD3-111L1 36.40 100.05 36.40 99.14 36.10 109.554 Centre Distance Pass - Major Risk CD3 -111 - CD3-111L1 - CD3-111L1 349.56 103.41 349.56 96.01 350.00 13.978 Clearance Factor Pass - Major Risk CD3 -112 - CD3 -112 - CD3 -112 225.39 119.29 225.39 114.60 225.00 25.394 Centre Distance Pass - Major Risk • CD3 -112 - CD3 -112 - CD3 -112 300.00 119.97 300.00 113.65 300.00 18.985 Clearance Factor Pass - Major Risk CD3 -113 - CD3 -113 - CD3 -113 36.60 140.65 36.60 139.73 36.80 153.570 Centre Distance Pass - Major Risk CD3 -113 - CD3 -113 - CD3 -113 545.73 142.85 545.73 131.15 550.00 12.217 Clearance Factor Pass - Major Risk CD3 -114 - CD3 -114 - CD3 -114 36.40 160.36 36.40 159.44 36.75 175.585 Centre Distance Pass - Major Risk CD3 -114 - CD3 -114 - CD3 -114 471.73 162.75 471.73 152.67 475.00 16.155 Clearance Factor Pass - Major Risk CD3 -115 - CD3 -115 - CD3 -115 274.38 180.25 274.38 174.48 275.00 31.253 Centre Distance Pass - Major Risk CD3 -115 - CD3 -115 - CD3 -115 422.32 181.82 422.32 172.83 425.00 20.219 Clearance Factor Pass - Major Risk CD3 -117 - CD3 -117 - CD3 -117 348.98 217.63 348.98 210.24 350.00 29.452 Centre Distance Pass - Major Risk CD3 -117 - CD3 -117 - CD3 -117 398.16 218.10 398.16 209.64 400.00 25.776 Clearance Factor Pass - Major Risk CD3 -301 - CD3 -301 - CD3 -301 149.48 99.64 149.48 96.57 150.00 32.512 Centre Distance Pass - Major Risk CD3 -301 - CD3 -301 - CD3 -301 450.04 102.43 450.04 92.82 450.00 10.668 Clearance Factor Pass - Major Risk 28 December, 2009 - 13:12 Page 2 of 6 COMPASS ConocoPhillips(Alaska) Inc. -WNS HALLIBURTON Western North Slope Anticollision Report for Plan: CD3 -106 - CD3- 106wp09 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad - Plan: CD3 -106 - Plan: CD3 -106 - CD3- 106wp09 Scan Range: 0.00 to 17,843.12 ft. Measured Depth. Scan Radius is 1,980.68 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Welibore Name - Design (ft) (ft) (ft) (ft) ft CD3 -301 - CD3 -301 PB1 - CD3 -301 PB1 149.48 99.64 149.48 96.57 150.00 32.512 Centre Distance Pass - Major Risk CD3 -301 - CD3 -301 PB1 - CD3 -301 PB1 450.04 102.43 450.04 92.82 450.00 10.668 Clearance Factor Pass - Major Risk • CD3 -301 - Plan: CD3 -301A - CD3- 301Awp07 (work in 149.48 99.64 149.48 96.57 150.00 32.512 Centre Distance Pass - Major Risk CD3 - 301 - Plan: CD3 - 301A - CD3 301Awp07 (work in 12,575.30 305.56 12,575.30 25.14 12,850.00 1.090 Clearance Factor Pass - Major Risk CD3 -301 - Plan: CD3- 301APB1 - CD3- 301APB1wp06 149.48 99.64 149.48 96.57 150.00 32.512 Centre Distance Pass - Major Risk CD3 -301 - Plan: CD3- 301APB1 - CD3- 301APB1wp06 450.04 102.43 450.04 92.82 450.00 10.668 Clearance Factor Pass - Major Risk CD3 -302 - CD3 -302 - CD3 -302 174.70 79.72 174.70 76.12 175.00 22.122 Centre Distance Pass - Major Risk CD3 -302 - CD3 -302 - CD3 -302 274.84 80.84 274.84 75.12 275.00 14.116 Clearance Factor Pass - Major Risk r --. 1 CD3-302 - CD3- 302PB1 - CD3- 302PB1 174.30 79.72 174.30 76.13 175.00 22.175 Centre Distance Pass - Major Risk CD3 -302 - CD3- 302PB1 - CD3- 302PB1 274.44 80.83 274.44 75.12 275.00 14.134 Clearance Factor Pass - Major Risk CD3 -302 - CD3- 302PB2 - CD3- 302PB2 174.30 79.72 174.30 76.13 175.00 22.175 Centre Distance Pass - Major Risk e CD3 -302 - CD3- 302PB2 - CD3- 302PB2 274.44 80.83 274.44 75.12 275.00 14.134 Clearance Factor Pass - Major Risk ` "`" CD3 -302 - CD3- 302PB3 - CD3- 302PB3 174.70 79.72 174.70 76.12 175.00 22.122 Centre Distance Pass - Major Risk r- CD3 -302 - CD3- 302PB3 - CD3- 302PB3 274.84 80.84 274.84 75.12 275.00 14.116 Clearance Factor Pass - Major Risk CD3 -302 - Plan: CD3 -302A - CD3- 302Awp13 174.70 79.72 174.70 76.12 175.00 22.122 Centre Distance Pass - Major Risk CD3 -302 - Plan: CD3 -302A - CD3- 302Awp13 274.84 80.84 274.84 75.12 275.00 14.116 Clearance Factor Pass - Major Risk CD3 -303 - CD3 -303 - CD3 -303 36.40 59.81 36.40 58.89 36.35 65.487 Centre Distance Pass - Major Risk CD3 -303 - CD3 -303 - CD3 -303 400.57 60.75 400.57 52.25 400.00 7.148 Clearance Factor Pass - Major Risk CD3 -304 - CD3 -304 - CD3 -304 274.92 39.08 274.92 33.29 275.00 6.747 Centre Distance Pass - Major Risk III CD3 -304 - CD3 -304 - CD3 -304 400.24 39.89 400.24 31.37 400.00 4.686 Clearance Factor Pass - Major Risk CD3 -305 - CD3 -305 - CD3 -305 36.30 19.62 36.30 18.70 36.80 21.509 Centre Distance Pass - Major Risk CD3 - 305 - CD3 - 305 - CD3 - 305 499.27 21.54 499.27 11.87 500.00 2.227 Clearance Factor Pass - Major Risk CD3 - 305 - CD3 305PB1 - CD3 305PB1 36.30 19.62 36.30 18.70 36.80 21.509 Centre Distance Pass - Major Risk CD3 - 305 - CD3 305PB1 - CD3 305PB1 499.27 21.54 499.27 11.87 500.00 2.227 Clearance Factor Pass - Major Risk CD3 -316 - CD3 -316 - CD3 -316 250.00 198.62 250.00 193.39 250.00 37.954 Centre Distance Pass - Major Risk CD3 -316 - CD3 -316 - CD3 -316 348.77 199.75 348.77 192.36 350.00 27.048 Clearance Factor Pass - Major Risk CD3 -316 - CD3 -316A - CD3 -316A 250.00 198.62 250.00 193.39 250.00 37.954 Centre Distance Pass - Major Risk CD3 -316 - CD3 -316A - CD3 -316A 348.77 199.75 348.77 192.36 350.00 27.048 Clearance Factor Pass - Major Risk CD3 -316 - CD3- 316APB1 - CD3- 316APB1 250.00 198.62 250.00 193.39 250.00 37.954 Centre Distance Pass - Major Risk CD3 -316 - CD3- 316APB1 - CD3- 316APB1 348.77 199.75 348.77 192.36 350.00 27.048 Clearance Factor Pass - Major Risk 28 December, 2009 - 13:12 Page 3 of 6 COMPASS ConocoPhillips(Alaska) Inc. -WNS HALLIBURTON Western North Slope Anticollision Report for Plan: CD3 -106 - CD3- 106wp09 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad - Plan: CD3 -106 - Plan: CD3 -106 - CD3- 106wp09 Scan Range: 0.00 to 17,843.12 ft. Measured Depth. Scan Radius is 1,980.68 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 Plan: CD3 -106 - Plan: CD3 -106L1 - CD3- 106L1wp10 13,350.00 0.30 13,350.00 -0.52 13,3500 0.368 Clearance Factor FAIL - Major Risk Plan: CD3 -119 - Plan: CD3 -119 - CD3- 119wp02 3,294.20 171.07 3,294.20 105.75 3,125.00 2.619 Clearance Factor Pass - Major Risk • Plan: CD3 -125 - Plan: CD3 -125 - CD3- 125wp02 1,724.20 287.52 1,724.20 256.04 1,875.00 9.132 Clearance Factor Pass - Major Risk Plan: CD3 -126 - Plan: CD3 -126 - CD3- 126wp02 1,752.90 347.82 1,752.90 315.83 1,925.00 10.871 Clearance Factor Pass - Major Risk Plan: CD3 -198 - Plan: CD3 -198 - CD3- 198wp01 401.48 139.19 401.48 130.73 400.00 16.457 Centre Distance Pass - Major Risk Plan: CD3 -198 - Plan: CD3 -198 - CD3- 198wp01 502.28 140.46 502.28 129.81 500.04 13.192 Clearance Factor Pass - Major Risk C"°J Plan: CD3 -199 - Plan: CD3 -199 - CD3- 199wp01 249.90 119.67 249.90 114.49 250.00 23.120 Centre Distance Pass - Major Risk Plan: CD3 -199 - Plan: CD3 -199 - CD3- 199wp01 426.17 121.29 426.17 112.29 425.00 13.479 Clearance Factor Pass - Major Risk G) Survey tool program From To Survey /Plan Survey Tool r-':.. (ft) (ft) 36.30 1,000.00 CD3- 106wp09 CB- GYRO -SS 1,000.00 17,843.12 CD3- 106wp09 MWD +IFR- AK- CAZ -SC Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. III 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. 28 December, 2009 - 13:12 Page 4 of 6 COMPASS ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD3 Fiord Pad Plan: CD3 -106 Plan: CD3 -106 CD3- 106wp09 • . . perry �_ rBrr Drilling l l �r� Se�rv� �# 4nti visia Clearance Summa ry Minor Risk Anticollision Report 28 December, 2009 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad - Plan: CD3 -106 - Plan: CD3 -106 - CD3- 106wp09 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: 0.00 to 17,843.12 ft. Measured Depth. Scan Radius is 1,980.68 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 GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 13:30, December 28 2009 CD3- 106wp09 Ellipsoid Color 36.30 To 17843.12 CD3 - 30' Cp3- 301Awp07 (work in progress...) CD3- 301APB1wp05 - CD3- 301 36 250 1750 2000 5000 — 6000 14000 1600C 250 500 2000 2500 6000 7000 16000 1800C CD3 -108 500 750 2500 3000 7000 8000 18000 2000C 0 / 360 CD3 199wp0$ 750 1000 3000 3500 8000 9000 20000 2500C '4 � �i 1000 -- 1250 3500 4000 9000 10000 �� /� /� /aj y - ,, - 1250 1500 4000 4500 10000 12000 " 30 / 330 � � r �� ,/�%/��//�i��]� � �� : �.a ,, ♦ r / /l)I 1 . : Ga.- D3 -10 1500 1750 4500 5000 12000 14000 CD3 -11' r ♦,I ■ ,;16,q '�hltl e j ♦ v . / �‘■ � ♦ �� ll� l l a i i //I il� l tl hr 'A�i !y � Ir i,,=---.....-141.0.- �:r= CD3- 198wp0� �.D3 -107L� ♦.►. ull r ' 4∎A,, 41 ' Vii' �� . - CD3 307 CD3 -30° CD3- 305P8' • CD3 -111Lt / lsi, 1 ral. . iiiii 'f l l ��l�l f a '�� .)14 Rr d ' ',, j CD3 - 107 41•41.6k v .1 nU; r 1 m 01.0 ♦� a a • l �I�l�aplir . N I l 2n 4 • 1 ,. r 11 1 .\. � * .• m , '- t ti 4 CD3 302Awp13 � Ir 1` 11■•A e . �'�� 1 � 1 • � '� ° 11 . ♦ '• 1 ♦ ♦ ' �� r� � n r�� i w� ` -60 / 300 i t•�� , , i11 . N �1a4. • I 60 �� I �1 1 ' 4AN r � i ♦ � ♦��c� ql I Iii C D3- 302PB3 0 / 360 viii CP1� 0 11 ; iolr / /, N � 0 � . � - . i► ,r /ia► " D3 -11� ) . ,1y.-ia ,-.71411. 1 ; n,444�N�� ., ': i /•- � _ _CD3 -302P6 2 q r • �• c!:� i w r��r t• A 1..∎�,%,∎∎• i ; -- O - _ _ 30 / 330 ,/�� 1/1 ,� 1 \� � q ` 1 4 \ \ItO� � *-4,2-;104,11..t..4 , 44 , 41, ��Ie!/�� ♦ .� �� ► ' o i 14� l;i: :'�: ' f� q / " � i CD3 302PB 1 4'�� -, .4 • '„ 011 40,14 / 1 t . �; \I . .` iii / p '�4 CD3- 108 ( ♦, _ ®i 1 � � � ;\ � � 7�a�� 1 1 � ``. : —��1a►- • '1. i•► > ° /rsi i3 D3-30� •�� ,♦,�_��1i ►�� •o wilr �/� 1 v . •i ♦ . � . it , a �' �i•�� %t c . ` 4 i ' . ?� QQ 1 \ 1I_� Ii � � X 44 I'1 �. a r i >i a . � 4/ g )%:,44 �1 � ��' -114 i� �� \Vii �0 Vi a►• � � i I � ii �. ` • '' �.c9 .4i 44, }, D3-30 /�` � � .cam �y�iiv \ \ \�1 . •. � O•: ' : � ., iii• s o�j� � �,: pro nl� Y 60 / 300 �-_ �'� � e i ; :..4 44 M� � - 60 o _ r M rp � •r ,.•. . .°.' - - v I i d/ r►1," t.� % .y \aa•a 11. 1 tl i _ 0iv I s 3 .15/- c 1 • r .. i r- : 0 /i - A G 4 CD3 -30 1�� i �y'. ,, . 1 �� . �� CD3- 304 90 / 270 • . i 1 ' r � �ro %/'if '; 90 ��ti0 � s \1 ji %i i ,, � ` )" - �� . i / i CD3 - 107-.7 11 iii t o ! �� ' ' yov /� 1� ill) i i • ��t i• i, I�� •,.- A d f i � , �� y i �` ®��' ♦� ��iiii / /_ 1 �� \ r' Q '�1 ∎1► ..: i w ,, , 40-1.....1t1 � ♦ r, t` •iiy \ i � �j. \ �Y ai �:�7 -10 ♦I �. ' :% � Z�14 S ! a 1 G //j� :�� !� �� SIB �� a/ �►'� D3 -30� 9 0 / 270 � � } v ,,, I ��\1�i 90 Atiaz.vp .,D -11 t/•1 Y� a %1 \- �� n `.100 rai n i t r: - a • �/ 3D3 -11( �v; ��,� , N � 7 '% - ,' ch ile.1,. .fir . y r ,, �!�, �i•� 1. � .� 1 :j * :�t;: H CD3- 305PB1 120 / 240 �� i� \ �� t t+ ' ♦47 120- '"D3 -30` \1 .�..�`.. --- Nb■ � ,� � � 120 / 240 120 ? J 200 3D3-314 - - -,, �� j 150 / 210 150 50 PD3 -316 . -150 / 210 �,, '. - I 150 180 / 180 �� CD3- 316APB1 - 1 7 Illkr =- CD3- 119wp02 180 / 180 CD3- 125wp02 Travelling Cylinder Azimuth (TFO +AZI) [ °] vs Centre to Centre Separation [25 ft/in] ConocoPhillips(Alaska) Inc. -WNS HALLIBURTON Western North Slope Anticollision Report for Plan: CD3 -106 - CD3- 106wp09 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad - Plan: CD3 -106 - Plan: CD3 -106 - CD3- 106wp09 Scan Range: 0.00 to 17,843.12 ft. Measured Depth. Scan Radius is 1,980.68 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft CD3 Fiord Pad • CD3 -107 - CD3 -107 - CD3 - 107 549.66 15.82 549.66 4.60 550.00 1.410 Centre Distance Pass - Major Risk CD3 -107 - CD3 -107 - CD3 - 107 648.89 16.54 648.89 3.71 650.00 1.289 Clearance Factor Pass - Major Risk CD3 -107 - CD3 -107L1 - CD3 -107L1 549.45 15.83 549.45 4.61 550.00 1.411 Centre Distance Pass - Major Risk CD3 -107 - CD3 -107L1 - CD3 -107L1 648.68 16.53 648.68 3.71 650.00 1.289 Clearance Factor Pass - Major Risk CD3 -107 - CD3 -307 - CD3 - 307 549.51 15.83 549.51 4.61 550.00 1.411 Centre Distance Pass - Major Risk ` -.. CD3 -107 - CD3 -307 - CD3 - 307 648.74 16.53 648.74 3.71 650.00 1.289 Clearance Factor Pass - Major Risk ,,.. i CD3 - 108 - CD3 - 108 - CD3 - 108 497.17 35.23 497.17 26.00 500.00 3.814 Centre Distance Pass - Major Risk - - CD3 -108 - CD3 -108 - CD3 -108 521.74 35.43 521.74 25.73 525.00 3.653 Clearance Factor Pass - Major Risk -T) CD3 - 109 - CD3 - 109 - CD3 - 109 669.61 56.37 669.61 50.64 675.00 9.836 Clearance Factor Pass - Minor 1/100 CD3 - 110 - CD3 - 110 - CD3 -110 522.39 75.81 522.39 64.99 525.00 7.004 Centre Distance Pass - Major Risk •--,e' CD3 -110 - CD3 -110 - CD3 -110 570.81 76.09 570.81 64.37 575.00 6.492 Clearance Factor Pass - Major Risk ,,,,,,, CD3 -111 - CD3 -111 - CD3 -111 36.40 100.05 36.40 99.14 36.10 109.554 Centre Distance Pass - Major Risk CD3 -111 - CD3 -111 - CD3 -111 349.56 103.41 349.56 96.01 350.00 13.978 Clearance Factor Pass - Major Risk y ,H- CD3 -111 - CD3-111L1 - CD3-111L1 36.40 100.05 36.40 99.14 36.10 109.554 Centre Distance Pass - Major Risk CD3 -111 - CD3-111L1 - CD3-111L1 349.56 103.41 349.56 96.01 350.00 13.978 Clearance Factor Pass - Major Risk CD3 -112 - CD3 -112 - CD3 -112 225.39 119.29 225.39 114.60 225.00 25.394 Centre Distance Pass - Major Risk CD3 -112 - CD3 -112 - CD3 -112 300.00 119.97 300.00 113.65 300.00 18.985 Clearance Factor Pass - Major Risk CD3 - 113 - CD3 - 113 - CD3 - 113 36.60 140.65 36.60 139.73 36.80 153.570 Centre Distance Pass - Major Risk CD3 -113 - CD3 -113 - CD3 -113 545.73 142.85 545.73 131.15 550.00 12.217 Clearance Factor Pass - Major Risk CD3 -114 - CD3 -114 - CD3 -114 36.40 160.36 36.40 159.44 36.75 175.585 Centre Distance Pass - Major Risk CD3 -114 - CD3 -114 - CD3 -114 471.73 162.75 471.73 152.67 475.00 16.155 Clearance Factor Pass - Major Risk CD3 -115 - CD3 -115 - CD3 -115 274.38 180.25 274.38 174.48 275.00 31.253 Centre Distance Pass - Major Risk CD3 -115 - CD3 -115 - CD3 -115 422.32 181.82 422.32 172.83 425.00 20.219 Clearance Factor Pass - Major Risk CD3 -117 - CD3 -117 - CD3 -117 348.98 217.63 348.98 210.24 350.00 29.452 Centre Distance Pass - Major Risk CD3 -117 - CD3 -117 - CD3 -117 398.16 218.10 398.16 209.64 400.00 25.776 Clearance Factor Pass - Major Risk CD3 -301 - CD3 -301 - CD3 -301 149.48 99.64 149.48 96.57 150.00 32.512 Centre Distance Pass - Major Risk CD3 -301 - CD3 -301 - CD3 -301 450.04 102.43 450.04 92.82 450.00 10.668 Clearance Factor Pass - Major Risk CD3 -301 - CD3 -301 PB1 - CD3 -301 PB1 149.48 99.64 149.48 96.57 150.00 32.512 Centre Distance Pass - Major Risk 28 December, 2009 - 13:37 Page 2 of 6 COMPASS ConocoPhillips(Alaska) Inc. -WNS HALLIBURTON Western North Slope Anticollision Report for Plan: CD3 -106 - CD3- 106wp09 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad - Plan: CD3 -106 - Plan: CD3 -106 - CD3- 106wp09 Scan Range: 0.00 to 17,843.12 ft. Measured Depth. Scan Radius is 1,980.68 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 -301 - CD3 -301 PB1 - CD3 -301 PB1 450.04 102.43 450.04 92.82 450.00 10.668 Clearance Factor Pass - Major Risk CD3 -301 - Plan: CD3 -301A - CD3- 301Awp07 (work in 149.48 99.64 149.48 96.57 150.00 32.512 Centre Distance Pass - Major Risk CD3 -301 - Plan: CD3 -301A - CD3- 301Awp07 (work in 12,575.30 305.56 12,575.30 25.14 12,850.00 1.090 Clearance Factor Pass - Major Risk III CD3 -301 - Plan: CD3- 301APB1 - CD3- 301APB1wp06 149.48 99.64 149.48 96.57 150.00 32.512 Centre Distance Pass - Major Risk CD3 -301 - Plan: CD3- 301APB1 - CD3- 301APB1wp06 450.04 102.43 450.04 92.82 450.00 10.668 Clearance Factor Pass - Major Risk CD3 -302 - CD3 -302 - CD3 -302 174.70 79.72 174.70 76.12 175.00 22.122 Centre Distance Pass - Major Risk CD3 -302 - CD3 -302 - CD3 -302 274.84 80.84 274.84 75.12 275.00 14.116 Clearance Factor Pass - Major Risk CD3 -302 - CD3- 302PB1 - CD3- 302PB1 174.30 79.72 174.30 76.13 175.00 22.175 Centre Distance Pass - Major Risk CD 274 CD3 302 - CD3- 302PB1 - CD3- 302PB1 .44 80.83 274.44 75.12 275.00 14.134 Clearance Factor Pass - Major Risk CD3 -302 - CD3- 302PB2 - CD3- 302PB2 174.30 79.72 174.30 76.13 175.00 22.175 Centre Distance Pass - Major Risk ,�,,,OMD CD3 -302 - CD3- 302PB2 - CD3- 302PB2 274.44 80.83 274.44 75.12 275.00 14.134 Clearance Factor Pass - Major Risk CD3 -302 - CD3- 302PB3 - CD3- 302PB3 174.70 79.72 174.70 76.12 175.00 22.122 Centre Distance Pass - Major Risk """" CD3 -302 - CD3- 302PB3 - CD3- 302PB3 274.84 80.84 274.84 75.12 275.00 14.116 Clearance Factor Pass - Major Risk -y . CD3 -302 - Plan: CD3 -302A - CD3- 302Awp13 174.70 79.72 174.70 76.12 175.00 22.122 Centre Distance Pass - Major Risk CD3 -302 - Plan: CD3 -302A - CD3- 302Awp13 274.84 80.84 274.84 75.12 275.00 14.116 Clearance Factor Pass - Major Risk CD3 -303 - CD3 -303 - CD3 -303 36.40 59.81 36.40 58.89 36.35 65.487 Centre Distance Pass - Major Risk �r CD3 -303 - CD3 -303 - CD3 -303 400.57 60.75 400.57 52.25 400.00 7.148 Clearance Factor Pass - Major Risk CD3 -304 - CD3 -304 - CD3 -304 274.92 39.08 274.92 33.29 275.00 6.747 Centre Distance Pass - Major Risk CD3 -304 - CD3 -304 - CD3 -304 400.24 39.89 400.24 31.37 400.00 4.686 Clearance Factor Pass - Major Risk • CD3 -305 - CD3 -305 - CD3 -305 36.30 19.62 36.30 18.70 36.80 21.509 Centre Distance Pass - Major Risk CD3 -305 - CD3 -305 - CD3 -305 499.27 21.54 499.27 11.87 500.00 2.227 Clearance Factor Pass - Major Risk CD3 -305 - CD3- 305PB1 - CD3- 305PB1 36.30 19.62 36.30 18.70 36.80 21.509 Centre Distance Pass - Major Risk CD3 -305 - CD3- 305PB1 - CD3- 305PB1 499.27 21.54 499.27 11.87 500.00 2.227 Clearance Factor Pass - Major Risk CD3 -316 - CD3 -316 - CD3 -316 250.00 198.62 250.00 193.39 250.00 37.954 Centre Distance Pass - Major Risk CD3 -316 - CD3 -316 - CD3 -316 348.77 199.75 348.77 192.36 350.00 27.048 Clearance Factor Pass - Major Risk CD3 -316 - CD3 -316A - CD3 -316A 250.00 198.62 250.00 193.39 250.00 37.954 Centre Distance Pass - Major Risk CD3 -316 - CD3 -316A - CD3 -316A 348.77 199.75 348.77 192.36 350.00 27.048 Clearance Factor Pass - Major Risk CD3 -316 - CD3- 316APB1 - CD3- 316APB1 250.00 198.62 250.00 193.39 250.00 37.954 Centre Distance Pass - Major Risk CD3 -316 - CD3- 316APB1 - CD3- 316APB1 348.77 199.75 348.77 192.36 350.00 27.048 Clearance Factor Pass - Major Risk Plan: CD3 -106 - Plan: CD3 -106L1 - CD3- 106L1wp10 28 December, 2009 - 13:37 Page 3 of 6 COMPASS ConocoPhillips(Alaska) Inc. -WNS HALLI BURTON Western North Slope Anticollision Report for Plan: CD3 -106 - CD3- 106wp09 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad - Plan: CD3 -106 - Plan: CD3 -106 - CD3- 106wp09 Scan Range: 0.00 to 17,843.12 ft. Measured Depth. Scan Radius is 1,980.68 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 Plan: CD3 - 119 - Plan CD3 - 119 - CD3 119wp02 3,294.20 171.07 3,294.20 105.75 3,125.00 2.619 Carte Factor Pass - Major Risk Plan: CD3 -125 - Plan: CD3 -125 - CD3- 125wp02 1,724.20 287.52 1,724.20 256.04 1,875.00 9.132 Clearance Factor Pass - Major Risk Plan: CD3 -126 - Plan: CD3 -126 - CD3- 126wp02 1,752.90 347.82 1,752.90 315.83 1,925.00 10.871 Clearance Factor Pass - Major Risk Plan: CD3 -198 - Plan: CD3 -198 - CD3- 198wp01 401.48 139.19 401.48 130.73 400.00 16.457 Centre Distance Pass - Major Risk Plan: CD3 -198 - Plan: CD3 -198 - CD3- 198wp01 502.28 140.46 502.28 129.81 500.04 13.192 Clearance Factor Pass - Major Risk Plan: CD3 -199 - Plan: CD3 -199 - CD3- 199wp01 249.90 119.67 249.90 114.49 250.00 23.120 Centre Distance Pass - Major Risk Plan: CD3 -199 - Plan: CD3 -199 - CD3- 199wp01 426.17 121.29 426.17 112.29 425.00 13.479 Clearance Factor Pass - Major Risk i .4, d Survey tool program From To Survey /Plan Survey Tool (ft) (ft) 36.30 1,000.00 CD3- 106wp09 CB- GYRO -SS g 1,000.00 17,843.12 CD3- 106wp09 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. III 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. 28 December, 2009 - 13:37 Page 4 of 6 COMPASS ConocoPhillips(Alaska) Inc. -WNS HALLIBURTON Western North Slope Anticollision Report for Plan: CD3 -106 - CD3- 106wp09 Direction and Coordinates are relative to True North Reference. Vertical De Plan: CD3 -106. Depths are relative to Plan: CD3 306 (36.3+13.4) 49.70ft Do on 19 . Northing and Easting are relative to a P @ (Doyon ) 9 9 Coordinate System is US State Plane 1983, Alaska Zone 4. Central Meridian is - 150.00 °, Grid Convergence at Surface is: -0.86 °. - 54UJ -141 ,10IJJ - J41 ,41.......01.. I VT -X- CO3.108,CO3- 108,CO3.108V14 Ladder 003-109,CD3- 109,CD3 -109V5 Plat -8- CO3.110,CD3- 110,CO3 -110 V12 1 I a l CD3- 111,CD3 -111 ,CD3 -111 V7 • I I 1 ■ I 1 I 1 1 1 I - X - CD3 -111 ,CD3.111 L1 ,CD3 -11 1 L1 V1 . II , 1 +I x' 41 � J I II I _ —I— CD3.112,CO3- 112,003.112 V3 1800 I . .tt i�� •ii . 4t N _ + R � r � l n � r I CD3- 113.003- 113.003.113 VB O i ; f i 11 i�j I 1a1- i -- CD3- 114,CD3- 114,CD3.114V14 i f s I ∎ 1 ' _. FI I ` 1I I 1 '.�..� CO "RN � i i 1 Al I I I -$- 003- 115,CD3- 115,CD3- 115V1a 11 i �"`^'�j z � 14 .' I !• if '1 E it 1 - CO3.117,CD3- 117,CD3 -117 VD p i ll t 11:::, I I i $ CD3 - 301,003- 301,CD3. 3011+x# • •j a F41 i�1 I I G) (� i v ri I I I -- CD3- 301,CO3.301PB1,CD3.301PB1 V1 CO 1200 I„ ii 'ii+ � 1 +1 :-�� 1 1 ft � 1 $ 003- 301,PIan: CD3 -30 1A ,CD3- 301Awp07 (work in progress..., 47 '�I� } +• �� I I1 rI rY r -A- CC -3D1, Plan: 0Er3- 301APB1,003- 301APB1wpD6V13 G j' .,1 f� a M1 I F I A 1 ♦ r {i lil r i. I k i r I f I I —I— CD3- 302,CD3- 302,003 -302V3 X' 1 1 i: !H !!" ~� 1 -a- CO3- 302,CO3.302PB1,CE4.302PB1 V11 r -- C �, 1 f, a � 5,...i." @ ' , I ..r r. : � i FU ry . � - I I i CO3.302,CD3- 302PB2,CD3- 302PB2V6 a I J .I� , y :- I l ,, 1 . � . q .l;i • + 7n ,�,`- � _ 41 � _ 1 1 $ CD3 .302,CD3- 302 302pB3V'2 O j 1 77:WP: ; ! y '' 1 • 1 CD3 -302, Plan: CD3- 302A,CD3- 302Awp13 VO r> ei:, �y +,; :'F I 1a] I I CD3- 303,CD3- 303,003 -303V0 III +-+ - - , r I ... I ' k1 9 I 1 3 I''� a i r i 1 i ',•.'`. 1 I i CO3 -304, CD3- 304, CO3.304Vti7 �' y . a ■ (Irr I I ', Y.c / 1 I (0 "°''° . L� r i i �. I i mfr 0D3- 3D5,CO3- 3D5,003.305VT1 • 15 " I I I i i --A- 003- 3D5,CD3.3D5PB1,CD3.305PB1V13 0 1 I I 1 + I 1 -a- CD3- 316,CD3.316,CD3- 316V0 1 0 3500 7000 10500 14000 17500 $ CD3 - 316,003- 316A,CO3- 316AV1 -" Measured Depth (3500ftfin) CD3- 316,CD3.316APB1,CO3.316AP81 VD Plan: CD3 - 106 ,PIan:CO3- 106L1,CD3.1D6L1wp10 Vt) - Plan•r.111 -11A Pln•r.rn -1151 r.rn- iininnro\in 28 December, 2009 - 13:37 Page 5 of 6 COMPASS ConocoPhillips(Alaska) Inc. -WNS HALLIBURTON Western North Slope Anticollision Report for Plan: CD3 -106 - CD3- 106wp09 Clearance Factor Plot: Measured Depth versus Separation(Clearance) Factor liI t is i ' i 111 � CD3.108,CD3.108,CD3.108V14 CD3 -109, CD3 -109, CO3 -109 V5 lla 1000 „ i. Y � 1 CO3 -110, CO3.110,CD3- 110V12 - r,�I nri , 1 ' ,.�� CO3.111,CD3.111,CD3 -111V7 111 j 1 l CD3- 111,CD3 -111 L1,CD3.111L1 V1 • „5 ;, , '�. � Il CD3 -112, CD3 -112, CO3 -112 V3 - 1 i Ai : i �� ?� • CD3 -113, CD3.113, CD3 -113 V6 :- :t C 03-114, CD3- 114,CO3- 114V14 LI . ga l] iI� 3 yr ` : �� '. ? ' + �+ _ �1 J r �N • CD3 -115, CD3 -115, cD3 -115 VD li . _ ;? VI �' kl k l l :+ fl CD3 -117, CD3 -117, CD3 -117 VO of PA ' F , CD3 -301, CD3.301,CO3 -301 V4 s o pit '� R r �` �_ I ; CD3.301,CO3- 301PB1,CO3- 301PB1 V1 ` • _ 1 1 1 � `. I 1 1 g CD3- 301 ,Plan : CD3. 301A ,CD3.301Awp07 (work inprogress...y , V„ !a v _ W. CD3.301, Plan :CD3.301AP 81, CD3- 301APB1wpD6VD '� �, C a 000 X 57 t` .,.... - __ i 1 I a CD3 -302, CD3.302, CD3 -302 V3 • -. II k% 1i ` �i NI CD3 -302, CD3- 302 PB1,CD3- 302P81 V11 7o yam . CO3.302,CD3.302P82,CD3- 302PB2 V6 • IF F•Y•• ;i..; +:„ - :il•• .."!. CD3-302,CO3-302 P B3 , C 03-302P B3 V2 � .1 1 -+°" = 6 I � � � � � CD3. 302, Plan :CD3.3D2A,CD3- 3D2Awp13V0 - .Bp f ____ ----- _ ----- ._ C 03.303, CO3 -303, CD3 -303 VD Illni CD3 -304, CD3 -304, CD3.304 VO • II � CO3 -305, CD3 -305, CO3 -305 Vn ► �: : � i t CO3-305 ,CD3 305PB1,CO3-306P B1 VD - I W . C 03-316, CD3.316, CD3 -316 VD = I I 1 ., CD3 -316, CD3- 316A,CO3- 316AV0 06] I I I ! I I I + + ti 1 ii I I 1 ii I I i 1 1 1 1 1 i I i I I I I I! 11 1 1 i' I I I I j 1 1 1 1 i 1 I 1 1 I I o 10"00 300 4,000 dr ;a"C0 .10o logo 13300 I. Ic00 16500 Ia:CG CD3 -316, CD3 -316AP B 1, CD3 -316AP B 1 V1] Measured Deptll goo ft1in] • Plan: CD3.106, Plan: CD3 -106 L1,CO3 -106 L1wp10VO $ Plan: CD3.119, Plan: CD3 -119, CD3- 119wp02 VO 28 December, 2009 - 13 :37 Page 6 of 6 COMPASS Project: Western North Slope ConocoPhillips Date prepared: Site: CD3 Fiord Pad CD3 -1 O6wp09 �� ' }4 Well: Plan: CD3 -106 2'2 Wel lbore: Plan: CD3 -106 - - - T - - ''' Quarter Mile View HALLIBURTON CD3- 106wp09 Sperry Drilling - -- - -- 16000 106 *IC 1 O9 I • 1 09' 4 14000 Ill c oti C�� CD -S2000 r+- n� c w � V + iao �i ■ � I> CD3 -107L O 0000 11 1 III O GOB 8000 6000 �,�� L. IA . .� -8000 -6000 -4000 -2000 0 2000 4000 6000 8000 West( -) /East( +) (2000 ft/in) Operdor: CmsCOPNIIps(Almkd Inc.-VMS God<oe redlm. -0.86 ° JobNO'. tlN /A Reid Western Norm Slope NiowetC 0 ecindlm - . 2129 A(E No. RN /A W4! CD3.106wp09 Dp: 80.78 ° APINO: RN /A Rig MN /A 0oglegper 100 It System(IVO) Releence Mem Se.le2N SRrlx.60cdl05 Original VS Plane: 336.00 • P9ren1 Wee Nal:CDS -106 X' 152829833 q View VS Plane: 336.00 • re NNW: 49.30 9 Y. 0003599A3 It UM System: AP18®ed /WS Sedian (VS) 5040.00,: Slot Comments: POOL: P$dn vit1r $ 1 8 o o ° g 8 2 CD3- 106wp09 Plan: 12786' to 17843.12' MD - — 60,9800 CD3 -109: 9775' to 20321' MD CD3 -110: 8735' to 17991' MD 6018800 --- ------ --- — --- -- -------- - - ---- ' 6017800 V--'' �, r _._.___ .___ _ __ 6016800 • 0 m - - -- -- - -- - - - - -- -- - 6015800 0 z _ — - -- 6014800 L Co ,/�'� -- — Al 'PO 6013800 Section View —.— CD3- 106wp09 Plan •CD3 -109 CD3 -110 —.--- - CD3-301 1 — -- %hi. — 6012800 1 )111 - -___ —_ 6011800 --- - - 6010800 a."71. \ -- 6009800 r 6008800 .c $ East ( +) / West ( -) T T. CI a) • U a o2 a) \ m \ C m 1 co .. _ - - • - 8 8 8 8 8 8 8 8 a0 P O V Vert icd Section tong Mew VS Plone' Combo Preview Page 1 of 1 (CD3-106wp09 Toolbox)ds) 12/29/2009 2:13 PM I Closest in POOL Closest Approach: Reference Well: CD3- 106wp09 Plan Offset Well: CD3 -109 • Coords. - Coords. - ASP ASP 3 -O ctr -ctr Meas. Incl. TRUE Subsea N( +) /S( -) View VS Meas. Incl. TRUE Subsea N( +) /S( -) View VS Distance. Depth Angle Azi. TVD E( +) /W(- (336) Comments Depth Angle Azi. TVD E( +) /W(- (336) Comments POOL Min POOL Min Distance (110 49 ft) Distance (110.49 ft) .. in POOL (12786 - in POOL (12786 - ,,-- 17843.12 MD) to 17843.12 MD) to CD3 -109 (9775 - CD3- 106wp09 Plan 110.49 12850 83.91 334.76 6882.19 6013228 1527705 9086.83 20321 MD) 15481.99 89.12 336.52 6920.98 6013266 1527801 9074.98 (9775 - 20321 MD) r ' P Closest Approach: Reference Well: CD3- 106wp09 Plan Offset Well: CD3 -110 Coords. - Coords. - - °' ASP ASP =� 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(- (336) Comments Depth Angle Azi. TVD E( +) /W(- (336) Comments POOL Min POOL Min --. Distance (1621.28 Distance (1621.28 ft) in POOL (12786 ft) in POOL (12786 - 17843.12 MD) to - 17843.12 MD) to CD3 -110 (8735 - CD3- 106wp09 Plan • 1621.3 15300 91.01 320.31 6878.276 6014915 1525994 11310.95 17991 MD) 15941.65 94.1 320.36 6843.48 6013898 1524731 10858.5 (8735 - 17991 MD) PoolSummaryl 12/29/2009 2:19 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 VIIIILW4TrriAlliffraf I t )di ej , ., rind fi mi ma "1-4 Ai= 0-b Li . � �! I ! a / M LOCATION OF i tat - � , � � THIS SURVEY Mallailk eiril ALPINE SATELLITE DEVELOPMENT IMEIV VICINITY MAP NOT TO SCALE P ND DES\GN SHO ULDER OF C D — 3 PAD a, a M 9,x G HE MIGP\ - N` o o0 1 ; `i , u � 8' Tt.0o0 ,,,, rn o cis i _ 0 00 o U s o p S - .�: '.::: �i�i� :�'11 MOD ULE . i� • USE ` jam ��••• PRO . ,-c g : M GGIN G 1 FUEL- �!� 00O )° E 100G KID . .S WAREHOUSE S PLANT 11�. ASPC O VPRTERS N 13.00'00" 4i ili U)Lc) LCUF LEGEND: ° o 0 z Z O PROPOSED CONDUCTOR - v �° N N • EXISTING CONDUCTOR ° T-- `N9 � 0 A N 1ri sr O Z ➢ O A �o 00 KUUKPIK w W - LCMF 13E1E51rAve. -Mtla e, Make 99503- (987)2734830 Alpine Oelce ices) 670 -4739 Alpine Survey Office ALPINE MODULE: CD30 UNIT: CD ConocePhillips CD -3 L WELL CONDUCTORS Alaska, Inc. AS -BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 05 03 - 03 - 1A 11/3/05 . "_;, ia 1 f N 13Q -111 1 OF 3 6 REV DATE BY CK APP • DESCRIPTION REV DATE BY APP DESCRIPTION 6 4/8/07 AG DB C.A. ISSUED PER KO7041ACS 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. t � t -5 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 r 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 CD3 -112 6,003,572.43 1,528,181.20 70' 25' 08.660" 150° 54' 51.676" 1330' 894' 7.3 13.1 003 -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 CO3 -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 C.noc.Phillips ALPINE PROJECT CD -3 WELL CONDUCTORS Alaska, Inc. AS -BUILT LOCATIONS CADD FILE NO. DRAWING NO: 111 PART: REV: 05- 03- 03 -1A -2 3 -17 -05 l *� 2 OF 3 7 777,777 BY CK APP DESCRIP REV DA TE 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 CERTIFICATE 11 I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED 4 • OF ' L A �♦ TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA, THAT THIS • �P •• • ... ♦ AS -BUILT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT �,•' •• '. 9 SUPERVISION, THAT THE MONUMENTS SHOWN HEREON ACTUALLY EXIST = *:•° * � . AS DESCRIBED, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE • 49th �� CORRECT. • / DATE: REGISTRATION NO. LS -5077 • 0 A Donald G. Bruce : o • •�� s % No. LS -5077 .•' FO ''• • •• ............... ••�o KUUKPIK v 44, -/P °rEssioli Pk. 133 E51.t AVa. • Mdgtep ,Nrke %503 (9C7273 1330 Alpha Office (90 7 ) 67&.4739 Alpine Surve Office IPPYV ALPINE MODULE: CD30 UNIT: CD C.noc.Phillips ALPINE PROJECT CD -3 WELL CONDUCTORS Alaska, Inc. AS -BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 05- 03- 03 -1A -3 3 -17 -05 CE -01310 - 111 3 OF 3 5 9 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) Subject: RE: 7" intermediate cementing (PTD 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, I 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, 6620 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 welibore collapse. Thanks, Mike A. Winfree 907 265 6820 From: Schwartz, Guy L (DOA) [ maiito:guy.schwartz @alaska.govj 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 CD3 -106 . � 210 00) Well control event Chuck Seheve (AOGCC) The following is a summary of the well control event that occurred at Do on 141 ry Doyon well CD3 -106 at Alpine. The well was changed over f/ 10.4 ppg LSND to 9.3 ppg Flo Thru with the drill string on bottom at 13,017' After the new mud was to surface, a flow check was made and a slight flow was observed. Drilling began and flow checks very made on connections. A slight flow was observed. We began weighting up the system to 9.5 ppg while drilling ahea The pumps were shut down for a time while some survey data was obtained at 13,243' & 13,262'. When the pumps were brought on line the driller observed gas breaking out of the mud at the flow line and an increase in flow. The well was shut in with the annular preventer at 2350 hrs. The initial shut in pressures were SIDP 20 psi SIC 10 psi the pressures were monitored for 40 minutes with the DP 80 psi and the casing 100 psi. The mud in the pits was being weighted up to 9.5 ppg The choke was opened and 12 bbls of mud was pumped @ 1 bbl / min 270 psi to fill the poor boy degasser and to insure that we had not froze up the stand pipe. The pump was shut down and the choke closed. SIDP 90 psi SIC 120 psi. The pressures were monitored for 15 minutes with the DP rising to 210 psi and the casing to 240 psi. The pump was brought on line to 20 spm while holding casing pressure then switching over to the drill pipe and holding 560 psi while circulating the influx out and obtaining 9.5 ppg mud weight in and out. The pumps were shut down and the choke closed with SIDP 100 psi and SIC 100 psi. The pressures were bleed off and the annular preventer opened. The well was then circulated and the mud weight brought up to 10.0 ppg and we went back to drilling. Don Mickey — night drilling supervisor • • TRANSMITTAL LETTER CHECKLIST WELL NAME Colville River Unit CD3 -106 PTD# 2100010 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 , Permit No. (If last two digits in API No. . 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 '"" ! Field & Pool COLVI RIVER, FIORD OIL - 120120 �� Well Name: COLVILLE RIV FIORD CD3 -106 —__ Program DEV Well bore seg ❑ PTD#: 2100010 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 2 Lease number appropriate Yes Surface location in ADL0372105; 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. 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. 17 Sufficient acreage available in drilling unit Yes Conservation Order No. 569 has no interwell spacing restrictions. Wellbore will be more than 500' from 18 If deviated, is wellbore plat included Yes external property line where ownership or landownership changes (- 3,550' from external boundary of 9 Operator only affected party Yes the Colville River Unit). 10 Operator has appropriate bond in force Yes 111 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes 13 Can permit be approved before 15 -day wait Yes SFD 1/5/2010 1 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For NA 1 15 All wells within 1/4 mile area of review identified (For service well only) NA 16 Pre - produced injector: duration of pre production less than 3 months (For service well only) NA 1 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 1 22 CMT will cover all known productive horizons Yes Qannik zone to be cemented with 2nd stage job_ 1 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 110' away at and of 12850'. 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 28 Drilling fluid program schematic & equip list adequate Yes Maximum formation pressure = 3574 psi (9.9ppg EMW) Will drill with 10 ppg mud GLS 1/6/2010 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 • 31 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. 1 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 as detectors will be used during drilling. Mitigation measures in Hazards Geology 1 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 38 Seabed condition survey (if off - shore) NA 39 Contact name /phone for weekly progress reports [exploratory only] NA Geologic Engineering blic Date Main wellbore of multilateral producer. Closely approaches offset well CD3 -109, which reportedly has collapsed casing (see Well Commissioner: Date: Comm_ issioner Date Co ioner Proximity Risks in drilling program. Well will comply with spacing requirements of CO 569. • • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically • organize this category of information. • Sperry -Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Mar 08 13:45:36 2010 Reel Header Service name LISTPE Date 10/03/08 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 10/03/08 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 -106 API NUMBER: 501032061100 OPERATOR: ConocoPhillips Alaska, Inc LOGGING COMPANY: Sperry Drilling TAPE CREATION DATE: 08- 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 OPERATOR WITNESS: D. LUTRICK L. HILL L. HILL 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 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 c� r0 -00 i 19q'33 REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). ONLY INVERT /REVERT INTERVALS GREATER THAN 30' TVT ARE INCLUDED ON TVD PLOTS. 3. MWD RUN 1 COMPRISED DIRECTIONAL AND AT -BIT INCLINATION (ABI) WITH ELECTROMAGNETIC WAVE TELEMETRY (EM) - NO DATA ARE PRESENTED. 4. MWD RUNS 2 -4 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). MWD RUNS 2,4 ALSO INCLUDED GEOPILOT ROTARY - STEERABLE BHA (GP). 5. 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 2005. 6. MWD RUNS 1 -4 REPRESENT WELL CD3 -106 WITH API #: 50- 103 - 20611 -00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 17, 664'MD/6886'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. TNPS = THERMAL NEUTRON POROSITY (SANDSTONE MATRIX). CTFA = AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = BULK DENSITY - COMPENSATED (RAPID SAMPLE), LOW -COUNT BIN. SCO2 = STANDOFF CORRECTION (RAPID SAMPLE), LOW -COUNT BIN. SNP2 = NEAR DETECTOR PE FACTOR (RAPID SAMPLE), LOW -COUNT BIN. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 8.75" BIT FIXED HOLE SIZE MUD WEIGHT: 9.6 - 10.7 PPG MUD SALINITY: 500 - 4000 PPM CHLORIDES FORMATION WATER SALINITY: 23,000 PPM CHLORIDES FLUID DENSITY: 1.0 G /CC MATRIX DENSITY: 2.65 G /CC LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR SROP AND SGRC. THESE CURVES ARE SMOOTHED 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 10/03/08 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 17615.0 NPHI 2715.0 12897.0 FCNT 2715.0 12897.0 NCNT 2715.0 12897.0 DRHO 2715.0 12910.5 PEF 2715.0 12910.5 RPM 2715.0 17622.0 RPS 2715.0 17622.0 FET 2715.0 17622.0 RPX 2715.0 17622.0 RPD 2715.0 17622.0 RHOB 2715.0 12910.5 ROP 2735.5 17664.0 GR 3280.5 12850.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 2701.0 12855.0 MWD 3 12855.0 12997.0 MWD 4 12997.0 17664.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub- type...0 • i Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD API 4 1 68 4 2 FCNT MWD CP30 4 1 68 8 3 NCNT MWD CP30 4 1 68 12 4 RHOB MWD G /CC 4 1 68 16 5 DRHO MWD G /CC 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 RPM MWD OHMM 4 1 68 28 8 RPS MWD OHMM 4 1 68 32 9 RPX MWD OHMM 4 1 68 36 10 FET MWD HR 4 1 68 40 11 GR MWD API 4 1 68 44 12 I PEF MWD B/E 4 1 68 48 13 ROP MWD FPH 4 1 68 52 14 NPHI MWD PU 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2701 17664 10182.5 29927 2701 17664 GR MWD API 32 422.71 118.33 19141 3280.5 12850.5 FCNT MWD CP30 460.6 2314.43 857.289 20365 2715 12897 NCNT MWD CP30 103039 177845 131529 20365 2715 12897 RHOB MWD G /CC 1.047 3.254 2.41339 20392 2715 12910.5 DRHO MWD G /CC -4.001 0.299 0.0420842 20392 2715 12910.5 RPD MWD OHMM 0.06 2000 12.3375 29706 2715 17622 RPM MWD OHMM 0.1 1862.64 9.63918 29706 2715 17622 RPS MWD OHMM 0.12 1821.84 8.49306 29706 2715 17622 RPX MWD OHMM 0.13 1769.08 7.59623 29706 2715 17622 FET MWD HR 0.22 157.05 1.60524 29706 2715 17622 GR MWD API 19.39 382 94.109 29829 2701 17615 PEF MWD B/E 1.84 48.64 3.02231 20392 2715 12910.5 ROP MWD FPH 0.04 469.79 123.93 29858 2735.5 17664 NPHI MWD PU 15.03 71.72 35.5459 20365 2715 12897 First Reading For Entire File 2701 Last Reading For Entire File 17664 File Trailer Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/03/08 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 10/03/08 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 SGRC 2701.0 12850.5 SNP2 2715.0 12783.0 SFXE 2715.0 12804.0 SEXP 2715.0 12804.0 TNPS 2715.0 12769.0 SCO2 2715.0 12783.0 CTFA 2715.0 12769.0 CTNA 2715.0 12769.0 SBD2 2715.0 12783.0 SEDP 2715.0 12804.0 SEMP 2715.0 12804.0 SESP 2715.0 12804.0 SROP 2735.5 12855.0 ABGT 3280.5 12850.5 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 CTN COMP THERMAL NEUTRON 181187 ALD Azimuthal Litho -Dens 144855 ABGT At -Bit Dual GR 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): • 1 • 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 GR MWD020 API 4 1 68 4 2 FCNT MWD020 CP30 4 1 68 8 3 NCNT MWD020 CP30 4 1 68 12 4 RHOB MWD020 G /CC 4 1 68 16 5 DRHO MWD020 G /CC 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 RPM MWD020 OHMM 4 1 68 28 8 RPS MWD020 OHMM 4 1 68 32 9 RPX MWD020 OHMM 4 1 68 36 10 FET MWD020 HR 4 1 68 40 11 GR MWD020 API 4 1 68 44 12 PEF MWD020 B/E 4 1 68 48 13 ROP MWD020 FPH 4 1 68 52 14 NPHI MWD020 PU 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2701 12855 7778 20309 2701 12855 GR MWD020 API 32 422.71 118.33 19141 3280.5 12850.5 FCNT MWD020 CP30 460.6 2314.43 852.868 20109 2715 12769 NCNT MWD020 CP30 103039 172785 131367 20109 2715 12769 RHOB MWD020 G /CC 1.047 3.254 2.41283 20137 2715 12783 DRHO MWD020 G /CC -4.001 0.263 0.0419845 20137 2715 12783 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 PEF MWD020 B/E 1.85 48.64 3.01876 20137 2715 12783 ROP MWD020 FPH 0.19 469.79 145.119 20240 2735.5 12855 NPHI MWD020 PU 15.03 71.72 35.6233 20109 2715 12769 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 10/03/08 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 10/03/08 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 TNPS 12769.5 12897.0 CTNA 12769.5 12897.0 CTFA 12769.5 12897.0 S002 12783.5 12910.5 SBD2 12783.5 12910.5 SNP2 12783.5 12910.5 SEXP 12804.5 12932.0 SEMP 12804.5 12932.0 SEDP 12804.5 12932.0 SFXE 12804.5 12932.0 SESP 12804.5 12932.0 SGRC 12851.0 12948.5 SROP 12855.5 12997.0 LOG HEADER DATA DATE LOGGED: 06- FEB -l0 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 CTN COMP THERMAL NEUTRON 244601 ALD Azimuthal Litho -Dens 105252 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 • w 410 III 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 FCNT MWD030 CP30 4 1 68 4 2 NCNT MWD030 CP30 4 1 68 8 3 RHOB MWD030 G /CC 4 1 68 12 4 DRHO MWD030 G /CC 4 1 68 16 5 RPD MWD030 OHMM 4 1 68 20 6 RPM MWD030 OHMM 4 1 68 24 7 RPS MWD030 OHMM 4 1 68 28 8 RPX MWD030 OHMM 4 1 68 32 9 FET MWD030 HR 4 1 68 36 10 GR MWD030 API 4 1 68 40 11 PEF MWD030 B/E 4 1 68 44 12 ROP MWD030 FPH 4 1 68 48 13 NPHI MWD030 PU 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12769.5 12997 12883.3 456 12769.5 12997 FCNT MWD030 CP30 579.15 1994.9 1204.57 256 12769.5 12897 NCNT MWD030 CP30 112517 177845 144279 256 12769.5 12897 RHOB MWD030 0/00 2.227 3.064 2.45716 255 12783.5 12910.5 DRHO MWD030 G /CC -0.074 0.299 0.0499529 255 12783.5 12910.5 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 PEF MWD030 B/E 1.84 9.86 3.30314 255 12783.5 12910.5 ROP MWD030 FPH 0.04 353.51 111.947 284 12855.5 12997 NPHI MWD030 PU 17.33 54.23 29.4614 256 12769.5 12897 ■ ■ • First Reading For Entire File 12769.5 Last Reading For Entire File 12997 File Trailer Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/03/08 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.004 Physical EOF File Header Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/03/08 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 SEMP 12932.5 17622.0 SEXP 12932.5 17622.0 SEDP 12932.5 17622.0 SFXE 12932.5 17622.0 SESP 12932.5 17622.0 SGRC 12949.0 17615.0 SROP 12997.5 17664.0 LOG HEADER DATA DATE LOGGED: 18- FEB -10 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.20 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 17664.0 TOP LOG INTERVAL (FT): 12997.0 BOTTOM LOG INTERVAL (FT): 17664.0 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 III 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 17664 15298.3 9464 12932.5 17664 RPD MWD040 OHMM 0.21 2000 18.2063 9271 12932.5 17622 RPM MWD040 OHMM 0.7 1463.3 15.4032 9271 12932.5 17622 RPS MWD040 OHMM 0.15 1068.93 14.0253 9271 12932.5 17622 RPX MWD040 OHMM 0.13 28.98 11.5916 9271 12932.5 17622 FET MWD040 HR 0.41 157.05 1.87595 9271 12932.5 17622 GR MWD040 API 19.39 119.73 43.1139 9333 12949 17615 ROP MWD040 FPH 0.06 347.95 78.3488 9334 12997.5 17664 First Reading For Entire File 12932.5 Last Reading For Entire File 17664 File Trailer Service name $TSLIB.004 1 1 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/03/08 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.005 Physical EOF Tape Trailer Service name LISTPE Date 10/03/08 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 10/03/08 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