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Home My WebLink About210-042 2\D- o V- 0 • 2G'55G, WELL LOG TRANSMITTAL#902723128 To: Alaska Oil and Gas Conservation Comm. October 9, 2015 Attn.: Makana Bender DATA LOGGED 333 West 7th Avenue, Suite 100 /2.N/2015 K.BENDER Anchorage, Alaska 99501 RE .. .C E D OC1 14 2015 RE: Multi Finger Caliper(MFC): 3K-09B AOGCC Run Date: 9/3/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3K-09B Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-21656-02 SCALE PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: ,4-7 - . ,�;,k" '"_C EWED R . STATE OF ALASKA • SEP 2 2 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon RugPerforationsPull Tubing r Operations shutdow n r Fracture Stimulate r ,� r- Performed: Suspend r Perforate r Other Stimulate ry'`t Alter Casing r Change Approved Rrogram r Rug for Redrill r Perforate New Pool r Repair Well I ' Re-enter Susp Well Other:Patch wbinci 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: V'lls ConocoPhillips Alaska, Inc. Development F Exploratory r 210-042-0 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-029-21656-02 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025519 WitU 3K-09B 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 9610 feet Plugs(measured) None true vertical 6648 feet Junk(measured) None Effective Depth measured NA feet Packer(measured) 493,6798,6877,6935, 6936 true vertical NA feet (true vertical) 493,6314,6380,6430,6431 Casing Length Size MD TVD Burst Collapse CONDUCTOR 72 16 110 SURFACE 3135 12 3172 PRODUCTION 7226 7 7261 Perforation depth: Measured depth: 8066-8095', 8123'-9509' True Vertical Depth: 6728'-6727',6727'-6646' SEANCE' Nov I 2015 Tubing(size,grade,MD,and ND) 2.875,J-55,7128 MD,6595 TVD Packers&SSSV(type,MD,and TVD) NIPPLE-CAMCO DS NIPPLE @ 493 MD and 493 ND PATCH-STATEWIDE PARAGON II PACKER'S WITH 34.5'SPACER PIPE @ 6798 MD and 6314 ND NIPPLE-CAMCO DS NIPPLE @ 6877 MD and 6380 ND SEAL ASSY-BAKER KBH-22 ANCHOR SEAL ASSEMBLY (3.5"EUE 8RD BOX UP)@ 6935 MD and 643( PACKER-BAKER 7"X 4.5"SAB3 RETAINER PRODUCTION PACKER(LTC BOX DOWN)@ 6936 MD anc 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Daily Report of Well Operations 400 Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Copies of Logs and Surveys Run Prior to well operation Subsequent to operation 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Exploratory r Development r.. Service r Stratigraphic r 16.Well Status after work: Oil Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r 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: N/A Contact Jan/Dusty Email N1617(p conocophillips.com Printed Name an Byrne Title Problem Wells Supervisor —Signature Phone-659-7-126 Date 6,720//..5 VTL e/Zy/l5 Form 10-404 Revised 5/20154 f* RBDMS SEP 2 5 2015 Submit Original Only RECEIVED SEP 2 2 2015 ConocoPhillips AOGCC Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 September 20th, 2015 Ms. Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Foerster, Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well 3K-09B PTD 210-042-0 tubing patch repair. Please call Dusty Freeborn or myself at 659-7126 or Brent Rogers/Kelly Lyons at 659- 7224 if you have any questions. Sincerely, Jan Byrn; Problem Wells Supervisor Attachments • • Name of Recipient Page 2 of 2 09/20/15 Delete the section break above to remove the second page • 3K-09B DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary A tubing patch was installed in gas lifted producer 3K-09B to regain tubing integrity. The following information is the work performed from leak location to integrity testing post patch installation. 08/17/15 PULLED CATCHER SUB @ 6,903' SLM BRUSH AND FLUSH TBG AND DS NIPPLE @ 6,877' RKB SET 2.81" CS-A2 PLUG @ 6,877' RKB RAN LEAK DETECT LOG, IDENTIFIED LEAK BETWEEN 6,827' RKB AND 6,828' RKB. LEAK IS AT THE TOP OF THE 10' PUP BELOW STA.#6 MANDREL 08/23/14 CIRC OUT PUMP'D 170 BBLS CORRISION INHIBITED S/W FOLLOWED BY 70 BBLS DIESEL( FREEZE PROTECT) U-TUBE UNTIL FLUIDS HAVE EQUALIZED PERFORM CMIT T x IA TO 2500 PSI JOB COMPLETE CMIT TxIA: Pre TIO: 50/25/680. Initial TIO: 2550/2600/720. 15 min TIO: 2510/2550/720. 30 min TIO: 2500/2525/720. 09/03/15 LOG 24 ARM CALIPER FROM 6937'TO SURFACE. JOB COMPLETE 09/10/15 BRUSH AND FLUSH RESTRICTIONS FROM SURFACE TO 600' SLM BRUSH AND FLUSH INTERVAL FOR PATCH FROM 8,700' SLM TO 8,450' SLM 09/12/15 DRIFT 2.72" DUMMY PATCH TO 6,850' SLM SET STATEWIDE 2.72" PARAGON II PACKER @ 6,841' RKB MIDDLE ELEMENT SET TTS TEST TOOL IN PARAGON II PACKER @ 6,787' SLM LRS PERFORMED PASSING CMIT TxIA TO 2,500 PSI. Pre TIO: 1250/1050/580. Initial TIO: 2500/2350/580. 15 min TIO: 2500/2350/580. 30 min TIO: 2500/2350/580. PULLED TTS TEST TOOL @ 6,787' SLM 09/13/15 SET PARAGON II PACKER AND 34.5' SPACER PIPE @ 6,802' RKB MIDDLE ELEMENT SET TTS TEST TOOL IN UPPER PARAGON II PACKER @ 6,753' SLM LRS PERFORMED PASSING MIT-T TO 3,000 PSI LRS PERFORMED PASSING MIT-IA TO 2,500 PSI PULLED TTS TEST TOOL @ 6,753' SLM MIT-T pre TIO: 1200/1150/580. Initial TIO: 3000/1150/580. 15 min TIO: 2950/1150/580. 30 min TIO: 2950/1150/580. MIT-IA pre TIO: 2900/1150/580. Initial TIO: 3025/2500/580. 15 min TIO: 3025/2500/580. 30 min TIO: 3025/2500/580. • • 3K-09B DESCRIPTION OF WORK COMPLETED SUMMARY °1,, KUP PROD • 3K-09B ConocoPhillips r`` Well Attributes Max Angie&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Btm(ftKB) [rnarnAvllgw 500292165602 KUPARUK RIVER UNIT PROD 103.66 8,400.33 9,610.0 -.- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3K-09B,9/19/2015 4.33.02 PM SSSV:NIPPLE 95 12/20/2014 Last WO: 10/31/2013 39.90 10/17/1986 Vertical tchem t (actual) .... Annotation I Depth(ftKB) !End Date Annotation (Last Mod By 'End Date --- Last Tag:SLM 6,937.0 11/11/2014 Rev Reason:Patch I pproven 9/16/2015 HWGER,35A II Casing Strings �° (", (las,C sing Description OD(in) ID(in) Top)ftKB) Set Depth(ftKB) Set Depth(ND)... WtlLen(I...Grade Top Thread I fI11JJ CONDUCTOR 16 15.062 38.0 110.0 110.0 62.50 H-40 WELDED(ftK Casing Description OD(in) ID(in) Top(ftKB) Set Depth B) Set Depth(TVD)... Wt/Len(I...Grade Top Thread s SURFACE 103/4 9.950 37.0 3,171.7 3,169.1 45.50 K-55 BTC CONDUCTOR;38.0-110.0 - Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread Window BL2-01 _ 8 3.625 7,140.0 7,150.0 6,613.5 NIPPLE 492.5 to Casin Oestri tion OD(in) ID in TopftKB Set Depth(ftKB) Set Depth(ND)...Wt/Len I...Grade TopThread I 9 p ( ) I I ( Window BL1-01 8 2.375 7,191.0 7201.0 6,657.0 GAS LIFT;2,594.8 a Casing Description OD(in) ID(in) Top(ftKB) Set Depth(MB) Set Depth)T/D)...WtlLen(I...Grade Top Thread I PRODUCTION 7 6.276 35.0 7,261.3 6,702.1 26.00 J-55 BTC Post S/T Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread BL2-01 LINER 23/8 1.995 8,055.6 9,510.0 6,645.9 4.60 L-80 STL SURFACE:37.0.3,171.7 a Liner Details . - GAS LIFT;3.751.2 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 8,055.6 6,727.7 89.99 BILLET ALUMINUM BILLET 1.000 GAS LIFT:4,813.8 81222 6,726.9 91.11 DEPLOY DEPLOYMENT SLEEVE 1.000 GAS LIFT;5,695.0 lcTubing Strings Tubing Oestripion (String Ma,..I1S(in) (Top(ftKB) (Set Depth(It Set Depth(ND)(...I Wt(lb/ft) (Grade (Top Connection GAS LIFT;6,362.2 _ TUBING WO 31211 2997_ 350 6.92701 6,4232 9.30 L-80 EUE8rd e. Completion Details UPPER PACKER;6,801.7 ?� Nominal ID - 5.F1.3 - Top(ftKB) Top(ND)(ftKB) Top Incl C) Item Des Com (in) GAS LIFT;6,816.8-, 35.0 35.0 0 00 HANGER CAMERON GEN IV HANGER 2.992 PATCH;6,805.4 kk 492.5 492.4 0.54 NIPPLE CAMCO DS NIPPLE 2.875 �j LOWER PACKER;6,841 0 6,876.5 6,380.2 31.39 NIPPLE CAMCO DS NIPPLE 2.812 6,924.5 6,421.1 31.80 LOCATOR BAKER LOCATOR SUB 2.990 NIPPLE;6,8765 s 6,925.4 6,421.9 31.79 SEAL ASSY GBH 80/40 BAKER SEAL ASSEMBLY 11.85'LONG 2.990 - Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING Packer Assy 3 1/2 2.992 6,921.6 7,050 0 6,528.2 9.30 L-80 EUE 8rd LOCATOR,6,924.5 /11 Completion Details °... SEAL ASSY,6.925.4 PBR.6,921.6 Nominal ID _ Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) SEAL ASSY;6,935.0 6,921.6 6,418.7 31.78 PBR Baker PBR Polish Bore Receptacle(6 Pins 40,000 lb 4.000 ..... Shear) PACKER;6.935.9 6,935.0 6,430.0 31.60 SEAL ASSY Baker KBH-22 Anchor Seal Assembly(3.5"EUE 8rd Box 3.000 Up) XD-Reducing;6.946.4 - Ii• 6,935.9 6,430.8 31.58 PACKER Baker 7"x 4.5"SAB3 Retainer Production Packer(LTC 3.250 . Box Down) 6,946.4 6,439.7 31.36 XO-Reducing Crossover 4.5"LTC Box x 3.5"EUE 8rd Pin 3.500 6,983.8 6,471.7 31.35 NIPPLE 2.813"'XN'Nipple-Milled to 2.804/22/2010 2.800 7,049.1 6,527.4 31.58'WLEG Wireline Entry Guide 4.18"0 D 2 992 NIPPLE;6,983.8 er In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) I Top(ND) Top Incl ''" ■f Top(ftKB) (ftKB) ("I Des Com Run Date ID(in) TBG PUNCHES;7,035.0 6,801.7 6,316.7 31.87 UPPER 3.5"PARAGON II UPPER PACKER 9/13/2015 1.630 PACKER WLEG;7.049.1-. Ilis 6,805.4 6,319.8 31.90 PATCH 35.65'SPACER PIPE PATCH 9/13/2015 1.630 SLOTS;6,969.47,164.0-- PILOT HOLE;7,033.0 `rt 6,841.0 6,350.0 31.98 LOWER 3.5"PARAGON II SEAL BORE LOWER PACKER 9/13/2015 1.630 PACKER WHIPSTOCK;7,145.0 ' III Window BL2-01;7,140.0- 7,033.0 6,513.7 31.61 PILOT HOLE PILOT HOLE FOR SIDETRACKS 5/25/2010 7'150.0 "'� 7,145.0 6,609.2 31.42 WHIPSTOCK OPEN HOLE ANCHOR/WHIPSTOCK BL2-01 6/5/2010 1 7,196.0 6,652.7 31.56 WHIPSTOCK OPEN HOLE ANCHOR/WHIPSTOCK BL101 5/26/2010 Perforations&Slots Shot Dens Top(TVD) Btm(ND) (shots/f WHIPSTOCK;7,196.01 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn Window BL1-01;7,191.0- 8,066.0 8,095.0 6,727.7 6,727.4 A-3,3K-09B 5/27/2010 6.0 SLOTS Alternating solid/slotted 7,201.0 pipe-0.125"x2.5"@4 circumferential adjacent PRODUCTION Post I, rows,3"centers src;35.0-7,201.3 staggered 18 deg,3'non -slotted ends SLOTS,7,320.0-8,954.0 8,123.0 9,509.0 6,726.8 6,646.0 A-3,A-1,A-3, 5/27/2010 6.0 SLOTS Alternating solid/slotted SLOTS 7,297.47,953 0 A-2,A-4,A-5, pipe-0.125"x2.5"@ 4 BL2-01 LINER;6,962.5-8,955.0 3K-09B circumferential adjacent BL1-01 LINER;7,193.3-8,897.0 rows,3"centers staggered 18 deg,3'non i - - -slotted ends Cement Squeezes SLOTS,7,872.0.10,030.0 Top(ND) Btm(ND) BL1 LINER;7,863.4-10,031.0 Top(fIKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com 7,033.0 7,201.0 6,513.7 6,657.0 Cement SQZ 4/24/2010 Pre-CTD work ir SLOTS;8,066.0-8.095.0 Mandrel Inserts St ati on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1' 2,594.8 2,594.4 CAMCO MMG 11/2 GAS LIFT GLV -RK 0.188 1,247.0 11/15/2013 9:00 2 3,751.2 3,737.4 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,251.0 11/15/2013 10:30 SLOTS;8,123 0-E509.0 3 4,813.8 4,676.0 CAMCO MMG 11/2 GAS LIFT GLV RK 0.188 1,253.0 11/15/2013 6:30 • 4 5,695.0 5,394.6 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,252.0 701/2014 3:30 5 6,362.2 5,946.2 CAMCO ,MMG 1 1/2 GAS LIFT GLV RK 0.188 1,244.0 7/31/2014 1:00 BL2-01 LINER,8,055 5-9 510 0 -ifsmsz• PROD S 3K-09B ConocoPhillips . Alaska,Inc. ConucciRldfips 3K-09B,9/19/2015 4'.33'04 PM Vertical schematic(actual) HANGER,35.0 Mandrel Inserts 22St It, o Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftK8) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com CONDUCTOR;38.0-110.0 6" 6816.9 6,329.6 CAMCO MMG 1112 GAS LIFT DMY RK 0-000 0.0 8/16/2015 12.00 NIPPLE;4925 Notes:General&Safety End Date Annotation GAS LIFT;2,59a.8 6/12/2010 NOTE:SIDETRACKED TO'B',BL1,BL1-01(off main wellbore)BL1-02,BL2,BL2-01(off main wellbore) 6/17/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0.See Attached Visio Drawing SURFACE;37.03,171.7 w GAS LIFT;3,751.2 11. GAS LIFT;4,813.8 t GAS LIFT;5,695.0r GAS LIFT,6362 2 UPPER PACKER;6,801 7 GAS LIFT',6,816.8_s PATCH;6,8054 LOWER PACKER,6,841 0 NIPPLE;6,8765 p!p■ LOCATOR,6,924.57 SEAL ASSY;6.925.4– PBR;6,921 6 SEAL ASSY;6,935.0 PACKER;6,935.9 XO-Reducing;6,946.4 — p1 j■jj NIPPLE;6.9838 TBG PUNCHES;7,035.0 till 611 WLEG;7,049.1 ! SLOTS;6,969.0-7,164.0 PILOT HOLE;7,033.0 r WHIPSTOCK;7,1450 Window BL2-01;7,140.0- 7,150.0 WHIPSTOCK;7,1960 Window BL1-01;7,191.0 .11 - 7,201 0 PRODUCTION Post SR;35 07,261.3 SLOTS;7,320.0-8,954.0 SLOTS;7,297.0.7,953.0 BL2-01 LINER,6,962.5-8,955.0 BL1-01 LINER;7,193.3-8,897.0 SLOTS,7,872.0-10,030.0 BL1 LINER,7,863.4-10,031.0 SLOTS;8,066.0-8,0950 SLOTS,8,123.0-9,509.0 BL2-01 LINER;8,055.5-9,510.0 1 • • 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 la Well History File Identifier Organizing (done) ❑ Two -sided III 11111111 I III ❑ Rescan Needed II 111111 1 III RESCAN DIGITAL DATA OVERSIZED (Scannable) olor Items: ❑ Diskettes, No. ❑ Maps: reyscale Items: + ther, No/Type: CP r JO. ❑Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: r l Li Other :: BY: Maria � Date: C la ! a. ,s, till:1) Project Proofing I .1I1111111111 ro�ect g BY: Maria Date: a S/1 a.., /s/ (V, p Scanning Preparation _ d. x 30 = (P0 + 5 = TOTAL PAGES OS /ag (Count does not include cover sheet) BY: A -- Date: / I /s/ Production Scanning 111111111111111111 Stage 1 Page Count from Scanned File: (Count does include cover eet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: V l d -- /s/ ro P Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. I I (111 ReScanned 11111111111111 BY: Maria Date: /s/ Comments about this file: Quality Checked 11111111111 MEI 12/22/2011 Well History File Cover Page.doc ' ' . ' STATE OF ALASKA RECEIVED ALAI,OIL AND GAS CONSERVATION COM•ION REPORT OF SUNDRY WELL OPERATIONS DEC 0 3 2013 1.Operations Performed: Abandon r Repair w ell - Aug Perforations r Perforate [ Other Alter Casing r Pull Tubing P"• Stimulate-Frac r Waiver r Time Extension GCC 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 Exploratory r 210-042 ' 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic "°' Service 50-029-21656-02 ' 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25519 • 3K-09B • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool • 11.Present Well Condition Summary: Total Depth measured 9610 feet Plugs(measured) None true vertical 6648 feet Junk(measured) None Effective Depth measured 9510 feet Packer(measured) 6936 true vertical 6646 feet (true vertical) 6431 Casing Length Size MD TVD Burst Collapse CONDUCTOR 72 16 110 110 SURFACE 3135 10.75 3172 3169 PRODUCTION 7226 7 7261 6702 B LINER 1455 2.375 9510 6646' Perforation depth: Measured depth: slotted liner from 8066-8095,8123-9509 SCAN�E� I) 4:- I I True Vertical Depth: 6728-6728,6727-6646' Tubing(size,grade,MD,and TVD) 3.5, L-80,6927 MD,6423 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER 7"X 4.5"SAB3 RETAINER PRODUCTION PACKER @ 6936 MD and 6431 ND NIPPLE-CAMCO DS NIPPLE @ 493 MD and 492 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development - Service r Stratigraphic r 16.Well Status after work: Oil W . 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 Ian Toomey lq'a 263-4773 Email Ian.A.Toomey(a�conocophillips.com Printed Name Ian Toomey Title Wells Engineer Signature �--- ____.--- Phone:263-4773 Date /a -2 - / 3 SDMS DEC 13 79 VF 10? I13 Form 10-404 Revised 10/2012 Submit Original Only i KUP PROD • 3K-09B ConocoPhillips - Well Attributes Max Angle&MD TD AL-1;.,,.1.,., Wellbore API/UWI Field Name Wellbore Status ncl)°) MD(ftKB) Act Btm(ftKB) comairrrM4 500292165602 I KUPARUK RIVER UNIT (PROD 103.661 8,400.33 9,610.0 ••• Comment 1H2S(ppm) Date Annotation 'Entl Date KB1xd(ft) Rig Release Date 3K-095,12/2201310:59:38 AM SSSV:TRDP 80 12/23/2012 Last WO: 10/31/2013 39.90 10/17/1986 Vertical schematic(actual) Annotation I Depth(ftKB) I End Date Annotation Last Mod By End Date --- ---- --- - ----Last Tag: 6117/2010 Rev Reason:WORKOVER,GLV CIO,PULL haggea 12/2/2013 CATCHER/PLUG HANGER;350 v C d ing Strings i ll Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I..Grade Top Thread , 1 1 CONDUCTOR 16 15.062 38.0 110.0 110.0 62.50 H-40 WELDED H PI Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)ND)...Wt/Len(I...Grade Top Thread SURFACE 103/4 9.950 37.0 3,171.7 3,169.1 45.50 K-55 BTC ..11 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONDUCTOR;360-110.0 Ill_ Window BL2-01 8 3.625 7,140.0 7,150.0 6,613.5 NIPPLE;492.5 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread Window BL1-01 8 2.375 7,191.0 7,201.0 6,657.0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread ISO SLEEVE;2,183.3 PRODUCTION 7 6.276 35.0 7,261.3 6,702.1 26.00 J-55 BTC Post S/T GAS LIFT;2.594.8 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)ND)...Wt/Len(I...Grade Top Thread B LINER 2 3/8 1.995 8,055.5 9,510.0 6,645.9 4.60 L-80 STL 1 I Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Inc!(°) Item Des Com (in) 8,055.5 6,727.7 89.99 BILLET 'ALUMINUM BILLET 1.000 SURFACE;37.03,171.7 8,1222 6,726.9 91.11 DEPLOY 'DEPLOYMENT SLEEVE 1.000 Tubing Strings GAS LIFT;3,751.2 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection . TUBING WO 31/2 2.992 35.0 6,927.0 6,423.2 9.30 L-80 EUE8rd GAS LIFT;4,813.8 Completion Details � GAS LIFT;5,695.0 � Item Des F® 35.0 35.0 0.00 HANGER CAMERON GEN IV HANGER 2.992 GAS LIFT;6,362.2 . 492.5 492.4 0.54 NIPPLE CAMCO DS NIPPLE 2.875 ® 6,876.5 6,380.2 31.39 NIPPLE CAMCO DS NIPPLE 2.812 GAS LIFT;6,916 a 6,924.5 6,421.1 31.80 LOCATOR BAKER LOCATOR SUB 2.990 NIPPLE;6,8760 R 6,925.4 6,421.9 31.79 SEAL ASSY GBH 80/40 BAKER SEAL ASSEMBLY 11.85'LONG 2.990 ® Tubing Description String Ma...ID(in) 'Top(ftKB) Set Depth(ft../Set Depth(ND)(...'Wt(lb/ft) 'Grade Top Connection TUBING Packer Assy 31/2 2.992 6,921.6 7,0500 6,528.2 9.30 L-80 EUE 8rd LOCATOR;6,924.5 r 1 Completion Details SEAL ASSY;6,925.4 It ..1 Nominal ID PBR;6,921.6 ilM Top(ftKB) Top(ND)(ftKB) Top Ind(°) Item Des Com (in)6,921.6 6,418.7 31.78 PBR Baker PBR Polish Bore Receptacle(6 Pins 40,000 lb 4.000 SEAL ASSY;6,935.0 iiAL Shear) PACKER;6,935.9 6,935.0 6,430.0 31.60 SEAL ASSY Baker KBH-22 Anchor Seal Assembly(3.5"EUE 8rd Box 3.000 Up) X0-Reducing;6,9464 -' 6,935.9 6,430.8 31.58 PACKER Baker 7"x 4.5"SAB3 Retainer Production Packer(LTC 3.250 Box Down) 6,946.4 6,439.7 31.36 XO-Reducing Crossover 4.5"LTC Box x 3.5"EUE 8rd Pin 3.500 6,983.8 6,471.7 31.35 NIPPLE 2.873"'XN'Nipple-Milled to 2.804/22/2010 2.800 ( 1 I 7,049.1 6,527.4 31.58 WLEG Wireline Entry Guide 4.18"O.D. 2.992 NIPPLE:6,983.8.---14,7 I l I Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Inc' -:1 Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) TBG PUNCHES;7,035.0 J.. .‘,..1 2,183.3 2,183.2 1.24 ISO SLEEVE 2.85"ISOLATION SLEEVE SET IN SAFETY VLV 10/15/2013 2.310 WLEG;7,049.1 AI:411::";, 7,033.0 6,513.7 31.61 PILOT HOLE PILOT HOLE FOR SIDETRACKS 5/25/2010 SLOTS;619:/9 7,164.0 PILOT HOLE;7,033.0 L J✓ 7,145.0 6,609.2 31.42 WHIPSTOCK OPEN HOLE ANCHOR/WHIPSTOCK BL2-01 6/5/2010 Cement S02;7633.0 ,-, C✓. WHIPSTOCK 7,1456 7,196.0 6,652.7 31.56 WHIPSTOCK OPEN HOLE ANCHOR/WHIPSTOCK BL1-01 5/26/2010 Window 812-01;7,140.0- �' 7,150.0 ;i' Perforations&Slots `r:■ ■ Shot i,, •1: Top(ND) Btm(ND) (shets/f Top(ftKB) Btm(MB) (ftKB) (ftKB) Zone Date t) Type Com L, 8,066.0 8,095.0 6,727.7 6,727.4 A-3,3K-09B 5/27/2010 6.0 SLOTS Alternating solid/slotted pipe-0.125"x2.5"@ 4 I ? circumferential adjacent WHIPSTOCK;7,196.0 rows,3"centers Window BL1-01;7.1916- staggered 18 deg,3'non 7201 0 -slotted ends 8,123.0 9,509.0 6,726.8 6,646.0 A-3,A-1,A-3, 5/27/2010 6.0 SLOTS Alternating solid/slotted PRODUCTION Post A-2,A-4,A-5, pipe-0.125"x2.5"@ 4 VT;360-7,261.3 3K-09B circumferential adjacent rows,3"centers staggered 18 deg,3'non -slotted ends SLOTS;7,320.0-695401 SLOTS;7,297.0-7,953.00- 11 CementS Squeezes a 012-01 LINER;6,962.5-8,9556 t Q BL1-01 LINER;7,193.30,897.0 Top(ND) Btm(ND) L Top(ftKB) Btm(ftKB) (ftKB) )ftKB) Des Start Date Com 7,033.0 7,201.0 6,513.7 6,657.0 Cement SQZ 4/24/2010 Pre-CTD work 4- Mandrel Inserts SLOTS;7,872.0-10,030.0 4, St 0-i C BL1 LINER;7,863.4-10,031.0 ' o Top)ND) Valve Latch Port Size TRO Run Na Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date m SLOTS;8,0666-86960 I 1 2,594.8 2,594.4 CAMCO MMG 11/2 GAS LIFT GLV RK 0.188 1,247.0 11/15/2013 j 2 3,751.2 3,737.4 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,251.0 11/15/2013 3 4,813.8 4,676.0 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,253.0 11/15/2013 4 5,695.0 5,394.6 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.250 0.0 11/15/2013 5 6,362.2 5,946.2 CAMCO MMG 1 1/2 GAS LIFT SOV RKP 0.000 0.0 11/5/2013 6 6,816.9 6,329.6 CAMCO MMG 1 1/2 GAS LIFT DMY RK DCR-1 0.000 0.0 11/5/2013 SLOTS;8,123.0-9.5060 Notes:General&Safety 1. End Date Annotation i 6/12/2010 NOTE:SIDETRACKED TO'B',BL1,BL1-01(off main wellbore)BL1-02,BL2,BL2-01(off main wellbore) B LINER;0,056S-9.510.0 I 6/17/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0.See Attached Visio Drawing •3K-09 Pre and Post Rig Well Work Sum. Pre-Rig Well Work DATE SUMMARY 5/8/2013 (AC EVAL) : TIFL FAILED (INFLOWED 3435'). 5/16/2013 GAUGED TBG TO 2.78"TO LINER @ 6962' RKB. TBG TEST PASSED WITH HOLE FINDER SET @ 6264' SLM, ABOVE OV. IN PROGRESS. 5/17/2013 SET CATCHER @ 6345' SLM. PULLED/SET NEW 1/4 PORT OV @ 6307' RKB. TESTED TBG, PASSED. BAILED W/2.5" PUMP BAILER TO 6342'SLM. IN PROGRESS. 5/18/2013 BAILED SCALE FROM 6336'TO 6343' SLM WITH 2.5" PUMP BAILER. EST. 2'ABOVE CATCHER. IN PROGRESS. 5/29/2013 BAIL FILL & PULLED CATCHER @ 6343' SLM. JOB COMPLETE. 6/29/2013 (AC) :TIFL POST SL. FAILED WITH AN INFLOW OF (3555'). 7/13/2013 RAN LEAK DETECT LOG, MADE SEVERAL PASSES FROM 6950' RKB TO 6150' RKB, FOUND LEAK IN TUBING @—6620' RKB, DIFFICUILT TO SEE DUE TO SCALE BUILD UP, SAW INDICATIONS OF POSSIBLY ANOTHER LEAK BUT WAS UNABLE TO SEE IT, IN PROGRESS. 7/13/2013 ASSIST DIGITAL SLICK LINE 7/14/2013 BRUSH @ FLUSHED TUBING DOWN TO MILLED OUT XN NIP @ 6923'SLM/6984' RKB, RAN PDS 24arm CALIPER FROM 6920' SLM TO SURFACE, LDL JOB COMPLETE. 8/14/2013 GAUGE 2.78"TO 6932' SLM, ATTEMPT TO SET 2.81"XX PLUG w/GAUGES UNABLE TO SET IN X PROFILE @ 6888' RKB, FALLS PAST NIPPLE, IN PROGRESS. 8/15/2013 BRUSH & FLUSH TBG TO 6932' SLM, SET 2.81"XX PLUG w/GAUGES @ 6888' RKB, SET CATCHER ©6839' RKB PULLED DV @ 6839' RKB, LEFT LRS TO CIRC OUT, IN PROGRESS 8/16/2013 UNABLE TO GET PASSING MITTx IA COMBO. FAIL AT 0.3 BPM @ 2500 PSI. RAN D&D TT TO TOP OF PLUG @ 6888' RKB. TEST TO 2500, FAIL. PULLED OV @ 6307', GLV @ 5586' RKB, SET DV @ 6307' RKB, IN PROGRESS 8/17/2013 PULLED GLVs @ 4606, 3532, 2396' RKB, SET DVs @ 5586', 4606', 3532, 2396' RKB, HAD TROUBLE SETTING DV @ 5586' RKB, ATTEMPT TO PULL CATCHER @ 6888' RKB, POSSIBLE VALVE IN CATCHER, IN PROGRESS. 8/18/2013 BAIL FILL OFF CATCHER f/6836'SLM TO 6846' SLM, HAD MARKS ON JD BAILER BOTTOM, IN PROGRESS. 8/19/2013 BAIL FILL OFF CATCHER @ 6845'SLM, PULLED CATCHER @ 6845' SLM, ALL GLMs HAVE DVs IN THEM, STA#6 "OPEN" @ 6839' RKB, BAIL SCALE OFF PLUG @ 6888' RKB, RAN EQ-PRONG TO PLUG, UNABLE TO EQUALIZE, RAN 2" PUMP BAILER INTO XX PLUG TO GET TO X EQUALIZING DEVICE, HAD MARKS ON BAILER TIP INDICATING GETTING INSIDE X PLUG, LDFN DUE TO RIG MOVE, IN PROGRESS. 8/20/2013 BAIL FILL& PULLED 2.81"XX PLUG w/DUAL SPARTEK GAUGES @ 6888' RKB. TURN OVER TO E-LINE FOR WRP. 8/22/2013 (PRE-RWO): FT LDS (ALL FUNCTION). IC-POT PASSED. IC-PPPOT PASSED. RE-ENERGIZED IC-PO. MIT-OA PASSED TO 1800 PSI. 9/1/2013 SET 2.78"WEATHERFORD 3 1/2 WRP AT 6958'. CCL TO MID ELEMENT= 10.8'. CCL STOP DEPTH = 6947.2'. JOB COMPLETE 9/4/2013 (PRE-RWO) : T-POT(PASSED), CMITTx IA(FAILED), LLR OF 9.1 GALS PER MIN @ 1650 psi. 9/8/2013 RAN LEAK DETECT LOG, WRP @ 6958' RKB IS NOT HOLDING, EQUALIZE & PULL 2.78"WRP FROM 6958' RKB, BRUSH & FLUSH TUBING W/65bbls DIESEL&3-1/2" BRUSH W/2.70"GAUGE RING, IN PROGRESS 9/9/2013 SET 2.78"WFD WRP @ 6955' RKB (MID ELEMENT), LRS PERFORM PASSING CMIT-TxIA @ 2500psi, JOB COMPLETE 9/10/2013 T x IA DDT(PASSED). 9/11/2013 REPLACE T LDS, T PPPOT(PASSED). 10/15/2013 SET LONG CATCHER (OAL= 87") ON WRP @ 9651' RKB, SET 2.31" ID ISO SLEEVE IN SSSV @ 2183' RKB, READY FOR BPV. COMPLETE. • _ • Conoco hiIIips Time Log & Summary Wellview Web Reporting Report Well Name: 3K-09 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 10/31/2013 9:00:00 PM Rig Release: 11/6/2013 3:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10/31/2013 24 hr Summary Rig accept @ 21:00 Hrs. Spot rig, rig up hard lines, kill tank and cuttings tank. Pull BPV. 21:00 00:00 3.00 MIRU MOVE RURD P Spot rig, spot kill tank and cuttings tank. Begin riggin up hard line. Rig up and test lubricator-Pull BPV. 11/01/2013 Kill well with total of 311 bbls of 8.6#brine. Set and test BPV, ND tree, NU BOPE. Body test-LDS leaking. NPT 3 hours changing out LDS and packing. Continue with BOPE test 250/3000 psi. one failure Valve#9. Rebuild. good test. M/U landing joint, BOLDS, pull on tubing, Tubing hanger came free 145K, Continue to work string .would not pull free, max pull 200K(165K string). Call for E-line. String came free. Held 200K while circulating 3 bpm. Cancel E-line. State test waived by Jim Regg. 00:00 02:00 2.00 MIRU WELCTL RURD P Complete rigging up hard lines, pressure test to 2500 psi. Load fluid in pits. 02:00 02:30 0.50 MIRU WELCTL SFTY P Pre Spud with Cody crew-PJSM killing the well. 02:30 05:00 2.50 MIRU WELCTL KLWL P Check well pressure Tubing 10 psi IA 10 psi. Begin killing the well. Reverse 60 bbls of 8.6#brine to circ out diesel from tubing string. Start pumping down tubing string for well kill.4 bpm @ 320 psi, choke pressure 180 psi. 251 bbls. Total of 311 bbls pumped, clean Brine to surface. Stop and monitor well for 30 _minutes. 05:00 06:30 1.50 MIRU WHDBO MPSP P Remove tree cap&flange, Set BPV- test 1000 psi. 06:30 08:30 2.00 MIRU WHDBO NUND P PJSM ND tree and adaptor. 08:30 11:00 2.50 MIRU WHDBO NUND P NU BOPE and hook up lines. Body test,tighten grey locks and LDS. 11:00 14:00 3.00 MIRU WHDBO WWSP T Stems and LDS leaking. Replace two stems, repack additional 2 stems due to leaks. Total of 3 hrs removed from BOPE test time due to wellhead equipment. 14:00 18:00 4.00 MIRU WHDBO BOPE P Test to 250/3000 psi. (1) Bilnds, Kill Hard line,TD HCR 3.5 IF dart, Choke 4,11,12. pass. (2) Blinds, Killl HCR, TD Man, 3.5 IF FOSV,Choke 3,7,9,10.failed geased choke. Failed. 9(3) Blds, kill HCR,TD man, 3.5 IF FOSV, Choke 3,7,8, Pass(4) 3.5 TJ LPR, 3.5"8rd FOSV, Choke 2,5,6, ,, ! of f, Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 21:30 3.50 MIRU WHDBO BOPE P Crew change-repack Valve#9. re-test good. Move onto test#5 3.5" test joint annular and manual kill, tighten gland nuts-small weap. Pass. Test 6 UPR's, Man Kill, Choke HCR. Test 7, UPR's, Man Kill, Man Choke. Test 8 UPR's, man kill, Choke, 1,2,5,6. Draw down test. 21:30 22:30 1.00 MIRU WHDBO MPSP P PJSM suck out stack, pull test dart (PBV) 22:30 00:00 1.50 COMPZ RPCOM PULL P PJSM-Make up landing joint, BOLDS. Unland hanger 145K. Attempt to pull tubing, max pull 200K.Worked string multiple times, circulated B/U.work string again with very little movement.Attempt to free seals from pbr with 1500 psi. No luck. Call out E-line. Keep 200K pulled into string circulating 3 bpm @ 130 psi. 11/02/2013 Circ 1.5 B/U,TOOH with decompletion string. Pinholes in tubing found from joint#203 to 211. P/U new 3.5" completion string.TIH down to PBR @ 6919'. Difficult time trying to get seal assembly into PBR due to fill. Reverse circ Hi-visc sweep from top of PBR, frac sand&scale over shakers. Made additional 3ft into PBR with seal assembly down to 6922'. 00:00 01:00 1.00 COMPZIRPCOM PULL P While calling out Eline for chemical cut, held 200K on string pumping 3 bpm. String popped free-new P/U weight 105K. Bring tubing hanger to rig floor. 01:00 02:00 1.00 COMPZ RPCOM CIRC P Circulate 1.5 X hole volume @ 8bpm /810 psi. No-flow check for 30 minutes. Lay down tubing hanger, blow down Top drive, Rig up SLB spooler to control line. 02:00 05:30 3.50 6,936 4,753 COMPZ RPCOM PULL P PJSM begin Pulling pipe&spooling control line. P/U weight 95K. Total of 71 SSSV bands recovered. Rig down spooling equipment and Norm control line. 05:30 12:30 7.00 4,153 0 COMPZ RPCOM PULL P Continue TOOH with decompletion string. Found pitting on jt#111, holes in jt 203, 205,6,7,8,9,10,11, photo's taken 12:30 15:30 3.00 0 COMPZ RPCOM PULD T Wait on seal assembly from Baker. truck stopped do to camp move on the other side of the river 15:30 22:00 6.50 0 6,910 COMPZ RPCOM PULD P Picked up new seal assembly&RIH with completion equipment. P/U weight off bottom 93K, down weight I '90K. ... __. Page 2 of 5 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:00 00:00 2.00 6,910 6,918 COMPZ RPCOM CIRC P Slowly roll pumps while stinging into seal assembly. Engange PBR 6918', hard time sliding down. P/U weight break over 105K, try again, no luck. Circulate B/U-lots of sand, scale over shakers. Make another attempt made additional 3ft down to 6922'. Mix up HI-visc pill. Reverse Circ Hi-visc sweep @ 7 bpm. 11/03/2013 TIH and clean out PBR from 6915' to 6933'. Circualte well clean, 30 minute flow check,TOOH standing back 3.5"completion string. Lay down clean out assembly,jet BOPE stack. Replace 2"hydraulic hose to top drive. P/U completion assembly RIH with 3.5"completion string. 00:00 01:30 1.50 6,918 6,923 COMPZ RPCOM CIRC P Continue with reverse circulating Hi-visc sweep from top of PBR to surface. Good frac sand returns over shaker, pump until returns cleaned up. 280 bbls pumped. RIH with seal assembly, made additional 1.5'down to 6923'. Estimated 8 ft short to no-go. Flow check. Blow down top drive. 01:30 05:30 4.00 6,923 0 COMPZ RPCOM TRIP T TOOH standing back completion string. Inspect seal assembly at surface. Hot shot it back to BOT to replace the seals. 05:30 10:30 5.00 0 6,926 COMPZ RPCOM TRIP T P/U 2-7/8"Mule shoe stinger. RIH with completion string fro cleanout. 10:30 12:30 2.00 6,926 9,633 COMPZ RPCOM CIRC T Est. convetional circulation.ICP=450 PSI @ 6 BPM. @ 6915.cleaned out to 6933'pumped 30 BBL hi-vis sweep. 12:30 13:00 0.50 COMPZ RPCOM OWFF T monitor well for flow 30 min's. 13:00 17:00 4.00 6,933 0 COMPZ RPCOM TRIP T Pooh with BHA#1 2 7/8 mule shoe 17:00 19:30 2.50 0 0 COMPZ RPCOM CIRC T Jet the stack. Crew change. 19:30 22:30 3.00 0 0 COMPZ RPCOM RGRP T While installing elevators a 2" Hydraulic hose sprung a leak on the rig floor. PJSM-Shut down and replace the 2"hose, to the top drive, circualte the hydraulic system and test the connections. 22:30 00:00 1.50 0 1,800 COMPZ RPCOM TRIP T PJSM-running completion equipment with new seals on seal assembly. TIH with 3.5"Completion string as per program. 11/04/2013 TIH with completion string, locate PBR,space out 1ft. P/U tubing hanger, pump 175 bbls corrosion inhibited fluid. Drain stack, Land tubing hanger, RILDS, test tubing 3500 psi-good test.Test IA-3000 psi held briefly then leaked off to 2000psi. Changed surface valves-retest cannot get over 2500 psi on IA-no flow/leak on tubing. TOOH for test packer. RIH with test packer-Test IA 2500',4000',6580'Good tests. -test full wellbore to 3000 psi-good test, chart 15 minutes. 00:00 03:00 3.00 1,800 6,919 COMPZ RPCOM TRIP T Continue TIH with completion string. Page 3 of 5 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 04:00 1.00 6,920 6,932 COMPZ RPCOM PUTB P Slowly roll pump while locating seal assembly into PBR 6919.5. Bleed pressure-tag no-go 6932'. Mark pipe, P/U for 1ft space out. Make up 16.5'pups and tubing hanger. 04:00 05:00 1.00 6,915 6,915 COMPZ RPCOM CIRC P Pump 5 bpm, 175 bbls corrosion inhibitor into well, bottom of string @ 6915'. Chase with 30 bbls. Drain stack, blow down lines. 05:00 09:30 4.50 6,915 6,932 COMPZ RPCOM PRTS P Land tubing hanger, RILDS. Pressure test tubing 3500/30 minutes, bleed down to 2000psi, Pressure test IA 3000. IA held for 4min's. and bled down to 2200 psi. Isolated IA from rig equipment. retested IA to 3000 psi. test dropped off to 2000 psi in 4 mins and held steady @ 1950 psi. Beld off pressure RD test equipment. 09:30 10:00 0.50 6,932 COMPZ RPCOM BOPE T Shell test BOPE and lines. 250/ 3000 psi. 10:00 18:00 8.00 6,932 0 COMPZ RPCOM TRIP T BOLDS pulled hanger and removed. Crew change @ noon, Trip out of hole with completion equipment. 18:00 00:00 6.00 0 6,580 COMPZ RPCOM TRIP T P/U test packer-TIH down to 2400' set and test IA to 3000 psi-good test,TIH to 6580'-Prior to P/U singles. Set packer and test IA-3000 psi- good test.Test down tubing-good test. Release packer-Move pipe 15ft. Close rams-test wellbore to 3000 psi-good test-chart for 15 minutes. No casing leaks detected. 11/05/2013 Slip&cut drilline.TOOH with test packer, P/U 80/40 seal assembly. RIH-Tag No-go @ 6931' Up weight 90K, Down weight 87K,space out 2ft. Land tubing hanger, RILDS,test tubing 3500psi/30 minutes, IA 3500 psi/30 minutes-good. Shear SOV @ 1000psi,set BPV,test 1000 psi, RDBOPE, RU tree, 250/5000 psi test. Freeze protect well and set BPV. 00:00 02:30 2.50 6,580 6,580 COMPZ RPCOM RGRP P Slip and cut drill line. 02:30 05:00 2.50 6,580 800 COMPZ RPCOM TRIP T TOOH with test packer. 800'from surface, Stop. P/U tubing hanger with 2 way check. Land tubing hanger, close blind rams and test tubing hanger from surface to ensure the bowl is not leaking. 05:00 07:00 2.00 800 0 COMPZ RPCOM TRIP T Continue TOOH. Lay down test packer. 07:00 07:30 0.50 0 0 COMPZ RPCOM PRTS T PT IA to 3000 psi for 10 min's.good test. 07:30 13:30 6.00 0 6,931 COMPZ RPCOM TRIP T Pu 80/40 seal assembly&RIH with completion. 6911'-P/U weight 90K, Down 87K. Space out PBR. Tag No-go-6931'. P/U and lay down 3 joints, P/U space out pups and tubing hanger. Page 4 of 5 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 16:00 2.50 6,931 ' 6,928 COMPZ RPCOM PRTS P Land Hanger, RILDS test tubing 3500 psi/30 minutes-good,Test IA 3500 psi/30 minutes-good. Bleed down and pressure up on SOV-sheared 1000psi. 16:00 17:00 1.00 6,928 0 COMPZ RPCOM MPSP P Install BPV-test 1000psi. 17:00 20:00 3.00 MIRU WHDBO NUND P NDBOPE-inspect ram cavitites. 20:00 22:00 2.00 MIRU WHDBO WWSP P Install tree-test 250/5000 psi. 22:00 00:00 2.00 MIRU WHDBO FRZP P R/U LRS and freeze protect well with 100bbis of deisel. 11/06/2013 Rig release 03:00 hrs. 00:00 02:00 2.00 0 0 MIRU WHDBO MPSP P Let the well swap out and equalize. Set 3" BPV. 02:00 03:00 1.00 0 0 MIRU MOVE MOB P Pull rig off well Rig Release 03:00 hrs Page 5 of 5 3K-09 Post Rig Well Work Summary DATE SUMMARY 11/13/2013 TAG FILL ON CATCHER @ 6900'SLM; PULLED SOV&SET DV @ 6362' RKB; PULLED DV @ 5694' RKB. IN PROGRESS. 11/15/2013 SET OV @ 5694' RKB; PULLED DV's @ 4813' , 3751', 2595' RKB, &SET GLV'S; BAILED-- 1'OF FILL FRAC SAND, MUD, & METAL FROM TOP OF CATCHER. IN PROGRESS. 11/16/2013 BAIL FRAC SAND; PULLED CATCHER SUB ON WRP @ 6955' RKB &ATTEMPT TO PULL WRP @ SAME. IN PROGRESS. 11/17/2013 BAILED— 1 gal. OF FILL; ATTEMPT TO PULL WRP @ 6955' RKB. IN PROGRESS. 11/18/2013 BAILED—2 gal. OF FILL; ATTEMPT TO PULL WRP @ 6955' RKB. IN PROGRESS. 11/20/2013 BAIL FILL& EQUALIZED WRP @ 6955' RKB; MADE SEVERAL ATTEMPTS TO PULL WRP @ SAME. IN PROGRESS. 11/21/2013 LATCHED WRP @ 6955' RKB W/BAITED 2.5"MODIFIED JD &JARRED UP FOR 1.5 HOURS. IN PROGRESS. 11/23/2013 PULLED BAITED WRP FROM 6955' RKB. JOB COMPLETE. DATA SUBMITTAL COMPLIANCE REPORT 6/18/2012 Permit to Drill 2100420 Well Name /No. KUPARUK RIV UNIT 3K -09B Operator CONOCOPHILLIPS ALASKA INC API No. 50- 029 - 21656 -02 -00 MD 9610 TVD 6648 Completion Date 6/12/2010 Completion Status 1 -OIL Current Status 1 -OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Sury y Yes DATA INFORMATION Types Electric or Other Logs Run: GR / RES (data taken from Logs Portion of Master Well Data Maint Well Log Information: ID Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med /Frmt Number Name Scale Media No Start Stop CH Received Comments ED ✓C . Jas t„ CS 19904 Gamma Ray 6529 9610 Case 7/27/2010 GR, ROP, Res, Log fi Induction /Resistivity 2 Col 7201 9610 Open 7/27/2010 MD MPR, GR Log — Induction /Resistivity 5 Col 7201 9610 Open 7/27/2010 MD MPR, GR Log ./. Induction /Resistivity 5 Col 7201 9610 Case 7/27/2010 TVD MPR, GR ED (/C - Directional Survey 7200 9610 Open Rpt Directional Survey 7200 9610 Open Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION • Well Cored? Y Daily History Received? Y N Chips Received? 1f1 Formation Tops Y N Analysis YTN Received? Comments: '„...L.,,c:) ( ) Compliance Reviewed By: Date: I g k �'V— ( ■ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil Q Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: June 12, 2010 210 - 0420 / 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 May 21, 2010 50 029 - 21656 - 02 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1234' FSL, 317' FWL, Sec. 35, T13N, R9E, UM May 25, 2010 3K - 09B Top of Productive Horizon: 8. KB (ft above MSL): 69' RKB 15. Field /Pool(s): 1278' FSL, 2319' FWL, Sec. 35, T13N, R9E, UM GL (ft above MSL): 30' Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 2074' FNL, 2207' FEL, Sec. 35, T13N, R9E, UM 9510' MD / 6646' TVD Kuparuk River Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 529306 y 6008229 Zone 4 9610' MD / 6648' TVD ADL 25519 TPI: x - 531308 y - 6008280 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 532051 y 6010211 Zone 4 2183' MD / 2183' TVD 2555 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) 1700' MD / 1700' 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 7201' MD / 6656' TVD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 Surf. 110' Surf. 110' 24" 1540# Poleset 10.75" 45.5# K -55 Surf. 3172' Surf. 3169' 13.5" 1400 sx AS IV, 125 sx Class G 7" 26# J -55 Surf. 7559' Surf. 6962' 8.5" 910 sx Class G, 175 sx AS I 2.375" 4.7# L -80 8059' 9510' 6727' 6646' 3" solid /slotted liner 24. Open to production or injection? Yes MI 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" 7050' 6936' MD / 6431' TVD alternating solid / slotted liner from: 8066-8095' MD 6728' -6728' TVD COMPLETION 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8123' - 9509' MD 6727' - 6646' TVD , DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED _ t . i 033' 17 ppg cement " 4, 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) June 24, 2010 Gas Lift Oil Date of Test Hours Tested Production for OIL - BBL GAS - MCF WATER - BBL CHOKE SIZE GAS - OIL RATIO 6/28/2010 20 hours Test Period - -> 1192 363 50 5 Bean 388 Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. 515 psi 30.5 24 -Hour Rate -> 1313 510 59 21.5 deg. 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 25.07 P E1VED NONE ,!HL 1 3 2010 RBDMS JUL 0 3 20 rciska Oil & Gas GeN. Commission A charage Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit original only 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes El 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 1700' 1700' needed, and submit detailed test information per 20 AAC 25.071. Top B 7215' 6668' Top A 7267' 6705' Top Miluveach 8242' 6717' N/A Formation at total depth: Kuparuk A4 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic, final directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: James Ohlinger @ 265 - 1102 Printed Na V. wv Title: Alaska Wells Manager Signature Phone 265 - 6306 Date — 7/r 1 /7C 1 4 6 Z 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 1a: Classification of Service wells: Gas injection, water injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 3K -09B + Completed CTD Sidetrack 3 -1/2" TRMAXX -5E SCSSV @ 2,183' MD ID = 2.812" 3 -1/2" 9.3# L -80 EUE 8rd Tubing to surface ID = 2.992" 3 -1/2" Camco MMG gas lift mandrels © 2396' 3533' 16" 62# H -40 shoe 4607' @ 110' MD 5586' _-llgilli _■.- 6307' 6839' 10 -3/4" 45.5# K -55 shoe @ 3172' MD • 3 -1/2" X Nipple @ 6888' MD (2.813" profile) 1 r' 4 Baker PBR @ 6922' MD (4" ID) Top of liner 6965' Baker KBH -22 Anchor Seal Assembly @ 6935' MD (3.0" ID) Baker SAB3 Packer © 6936' MD (4.0" ID) 2.813 "'XN' Nipple © 6984' MD (milled out to 2.80" min ID) 1 4 _= Perfs for Cement •- ----- 4� 7033' - 7035' WLEG @ 7049' MD ' F:\, ,,\\ \ \ \\\\ Tubing Tail @ 7050' MD 2 -5/8" Openhole anchor /whipstock @ 7150' Top of liner 7193' \\ South Laterals T • op of Billet - 7749'1 3K- 09BL2 -01: 8955' 2 -5/8" Openhole anchor /whipstock @ 7201' j - - - -- ' 7250' - Bottom of Pilot Hole North Laterals A3 - sand perfs 7279' 3K -096L2 8879' - 7297' MD Top of Billet - 7863' _ ( 1 A2 - sand pads 7310' IIII -- ,. \ --- I �K- 09BL1: 10,034' 7326' MD ` - -- - -- 7333' 7339' \ of Billet - 8059' t t�� op ' 3K -09B: TD - 9610' 7348' -7352' t\ �)' BOL -9510' ' 7359' - 7363' - ... 7" 26# J -55 shoe @ 11,2L u,J - I 3K- 09BL1 -01 8897' ' 7559' MD -�� ` f jI t . KUP • 3K -09B Com :Phillips g \ Well Attributes Max Angle & MD TD A)F(1l(S, Wellbore APUUWI Field Name Well Status Inc! ( °) 1MD (ftKB) Act Btm (8K8) ' Corme64vUpt 500292165602 I KUPARUK RIVER UNIT PROD Comment H25 (ppm) Date Annotation End Dab KB (fa Rig Release Date r �S �_� I TfTi(T'rT'3rr SSSV: TRDP ■ 120 2/23/2009 Last WO: 6/17/2010 39.90 10/17/1986 .. s. A otat,on Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: 1 6/17/2010 Rev Reason: SIDETRACK, GLV C/O Imosbor 6/17/2010 Casing Strings Casing Description String O. String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 38.0 110.0 62.50 H HANGER, 35 Casing Description String 0... String ID... Top (88(8) Set Depth (f... Set Depth (TVD) ... String Wt... String... String Top Thrd t;^, r '.. SURFACE 103/4 9.794 37.0 3,171.7 45.50 K - 55 BTC 1 ; - ;r ' casing Description I String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String -- String Top Thrd 19ttillillir '' - i d B 8 3.625 7,150.0 ICasin Description '1Str 0...... St ring ID... Top (kK Set Depth ( Depth (TVD)".. ND) ... ... N Window ow BL1 - 01 L2 -01 8 2.375 7,191.0 7,140.0 7,201 0 L ' � Casing Description String S tn g ID ... Top ( kKB) Set Depth (i Set Depth (ND) .. String Wt... String Wt... String String ... String Tap Th String Top Thrd CONDUCTOR, PRODUCTION 7 6.151 350 7,558.6 26.00 J55 BTC t_ 38 - 110 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) .. String Wt... String .. String Top Thrd 8 LINER 23/8 1.995 8,055.6 9,510.0 4.60 L - 80 STL Safely Vat., ' _.. __. - - - -- - -. _ - -- 2,183 Li D etails — Tap Depth (TVD) Top Inc! Norni... GAS L,39IFT6 , " ..e � Top (�8) (ftKB) (1 Item Description Comment ID (in) 2 8,055.6 Whipstock Whipstock/Aluminum Billet 1.000 II 8,122.2 DEPLOY Deployment Sleeve 1.000 i BILLET SUR FACE , i Tubin s_ Strin _ 3 7- 3,172 A 3,172 2 Tubing Description String 0 String ID... Top (998) Set Depth (i Set Depth (ND) .. String Wt... String String Top Thrd TD (3K TUBING 3 1/2 2 992 I 35 0 I 6,940 4 I - -_ I_ 930 . _ .. __ L-80 _ -_ EUE 8rd Completion Details GAS LIFT,_ __.- Top Depth ill i 3,533 (TID Top Intl N i... Top (kKB(_ (�) C) Item Description Comment ID (n) GAS LIFT, . 35.0 HANGER 3.5" Gen V Tubing Hanger EUE 8rd Mod (Pupjt3.66') 3.500 6,807 1 I 2,183 -3 Safety Valve 3.5" TRMAXX-5E SCSSV w/ 2212" X Profile EUE 8rd Mod 2.812 GASUFT, - -___ _ 6,888.0 NIPPLE 3.5" X Nipple w/ 2.813" profile 2.813 5 ' '` '° 6,927 6 LOCATOR Baker 3 5" Locator 0.0. 4.54 I D 3.99" 3.030 I �� 6,927.9 SEAL ASSY Baker 80-40 PBR w /Seal Assembly O.D 4.01" I.D. 2.99 2.990 GAS LIFT. 6,307 Tubing Description String 0... String ID .. Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt . Str g String Top Thrd TUBING Packer Assy 3 1/2 2 992 ..I Top 6,921.6 I 7,050.0 19 30 LL -80 EUE 8rd GAS LIFT, ___ ' -= Completion Details 6,839 Top Depth— _ (TVD) Top Inc' Nomi... Top(ftKB) ( ftK8 ) el lam Description Comment ID (!n) NIPPLE, 6,888 3 6,921.6 PBR Baker PBR Polish Bore Receptacle (6 Pins 40,000 lb Shear) 4.000 6,935.0 SEAL ASSY Baker KBH -22 Anchor Seal Assembly (3.5" EUE 8rd Box Up) 3.000 6,935.9 PACKER Baker 7" x 4.5" SAB3 Retainer Production Packer (LTC Box Down) 3.250 LOCATOR, 6,928� 6,946.4 XO Reducing Crossover 4.5" LTC Box x 3 - 5" EUE 8rd Pin 3.500 PBR, 6,922 — - — - . - — - — SEAL ASSY, 1 6,983.8 _ — NIPPLE 2.813"'XN' Nipple - Milled to 2.80 4/2212010 2.800 6,928\ _ - SEAL ASSY, 7,049.1 WLEG Wireline Entry Guide 418" O D 2.992 6,9% } PACKER, 6,936 — Perforations & Slots __ ` _ _ —__ __ Shot Top (TVD) Btm (TVD) Dens Top (91(8) Mtn (8103) (ftKB) (ftKB) Zone Dab (sh... Type Comment 8,066 8,095 5/27/2010 SLOT ARemating solid/slotted pipe - xO Reduang, 0.125 "x2.5" @4 circumferential 6,946 adjacent rows, 3" centers staggered 18 deg, 3' non - slotted ends 8,123 9,509 5/27/2010 SLOT Alternating solid/slotted pipe - NIPPLE, 6,986 1 0.125 "x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 1 1 18 deg, 3' non - slotted ends I Notes: General & Safety WLEG, 7,049 - End Date Annotation 6!12/2010 NOTE WELL SIDEiHACKED s 6117/2010 NOTE- VIEW SCHEMATIC w /Alaska Schematic9.0. See Attached Visio Drawing w1aow 7,140.7,150 Cement SOZ, 7,033 Window BL1U1,- 7,191.7,201 PRODUCTION, i 1 35 -7,559 Mandrel Details Top Depth Top Port SLOT, . (TVD) Inc! OD Valve latch Size TRO Run 8,066 -8,095 ..ar,M, Stn Top 011(8) (8K8) (°) Mak. Model lint Senr TYp• TYPE (in) (PO Run Date Com... V..". I 1 2,396.3 CAMCO MMG 1 1/2 GAS LIFT GLV R -20 0.188 1,339.0 6/16/2010 I I 2 3,532.7 CAMCO MMG 1 12 GAS LIFT GLV R -20 0.188 1,320.0 6/16/2010 3 4,606.5 CAMCO MMG 1 1/2 GAS LIFT GLV R -20 0.188 1,302.0 6/16/2010 4 5,586.4 CAMCO MMG 1 1/2 GAS LIFT OV do-20 0.250 0.0 6/16/2010 ______14 5 6,307.0 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/2/2008 6 6,839.0 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/13/2010 8 H 3K -09B Well Events Summary DATE SUMMARY 4/11/10 TAG @ 7398' SLM w /10'x 2" DD BAILER, SAMPLE OF FRAC SAND. PERFORM 30 MIN SBHP @ 7340' RKB =3089 PSI, 162 DEG F; 15 MIN GRADIENT STOP @ 7222' = 3053 PSI. SET 2.81" CAT SV @ 6983' RKB, PULL OV @ 6839' RKB & GLVs @ 5586' & 3532' RKB, IN PROGRESS. 4/12/10 PULL GLV @ 2396' RKB, SET DVs @ 2396', 3532' & 5586' RKB, CIRC. 243 BBLS DIESEL DOWN TBG UP IA, ATTEMPT 2500PSI CMIT, FAILED, IN PROGRESS, 4/13/10 CMIT TO 2500 PSI; PASSED. SET DV @ 6839' RKB; MITT TO 2500 PSI, PASSED. PULL SV @ 6972' RKB. COMPLETE. 4/15/10 PERFORMED PERFORATIONS- MIDDLE OF FIRST FULL JOINT ABOVE TUBING TAIL. CORRELATED TO K1 MARKER ON SCHLUMBERGER CBL LOG DATED 14- NOV -86. PERFORATED 7035' - 7037'; 2 -INCH BH HSD GUNS, 6SPF, 60 DEG. 4/17/10 (PRE -CTD) T- POT - PASSED; T- PPPOT- FAILED; IC- POT - PASSED; IC PPPOT- PASSED; MITOA- PASSED; - PT SV- PASSED; MV- PASSED; SSV- PASSED; DD TEST SV- PASSED; MV- PASSED; SSV-PASSED; SSSV - PASSED 4/19/10 TAGGED @ 7390' SLM. LOG CALIPER f/ 7380' - 6300' SLM. DATA NOT GOOD, CALIPER ARMS STUCK IN DUE TO VISCOUS / TAR -LIKE COATING. 4/20/10 MIRU; RD FOR SAFETY STAND DOWN. IN PROGRESS. 4/21/10 BRUSHED & FLUSHED TBG f/ 6500' - 7370' SLM. LOGGED CALIPER SURVEY f/ 7360' - 6500' SLM. RECOVERED DATA GOOD. COMPLETE. 4/22/10 __ MILL2 75" XN NIPPLE cc� 6983' RKB TO 2.80". WELL READY FOR SLICKLINE TO DRIFT NIPPLE & SET FRAC SLEEVE. IN PROGRESS. 4/23/10 GAUGED TBG TO 2.79" THRU XN TO 7100' SLM. ATTMEPTED DRIFT FOR FRAC SLEEVE; TIGHT COLLAR @ 41' SLM. RD FOR CTU. 4/23/10 MILL TIGHT COLLAR @ 57' CTMD W/ 2.87" JUNK MILL. DRIFT DRY TO SSSV @ 2183' RKB. TURN WELL OVER TO SLICKLINE, IN PROGRESS. 4/23/10 GAUGED TBG TO 2.86" TO SSSV. SET 3.5" TRMAXX -5E FRAC SLEEVE IN SSSV © 2183' RKB (OAL =80 ", MIN ID= 2.30 "). COMPLETE. 4/24/10 LOAD WELL WITH HEATED SEAWATER. LAY IN 25 BBLS OF 17 PPG CEMENT & PERFORM HESITATION SQZ UP TO 2000 PSI, HELD FOR 1 HOUR. CLEAN OUT CEMENT W/ BIOZAN & SEAWATER TO TOC @ 7033' RKB. WELL FREEZE PROTECTED W/ DIESEL TO 2500' RKB. ALLOW 72 HOURS FOR CEMENT TO ere. gi5 CURE PRIOR TO TAG & PT. IN PROGRESS. t �I 4/27/10 MIT TBG 1635 PSI, GOOD TEST. TAGGED CEMENT @ 7010' SLM. PULLED FRAC SLEEVE @ 2153' SLM - 2183' RKB. COMPLETE. 6/15/10 GAUGED TBG TO 2.74" TO 2 -3/8" LINER TOP @ 6957' RKB. MEASURED BHP @ 6957' RKB: 4274 PSI. SET CATCHER @ 5695' SLM. REPLACED DV @ 5586' RKB WITH OV. PULLED DV @ 4606' RKB. IN PROGRESS. 6/16/10 SET GLV @ 4606' RKB. REPLACED DVs @ 3533' & 2396' RKB WITH GLVs. PULLED CATCHER @ 5695' fc'Sfi SLM. COMPLETE. 9 • • Conoco Phillips Time Log & Summary Wellvlew Web Reporting Report Well Name: 3K -09 Rig Name: NABORS CDR2 -AC Job Type: DRILLING SIDETRACK Rig Accept: 5/15/2010 6:00:00 PM Rig Release: 6/12/2010 10:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/15/2010 24 hr Summary Swapping Reel & Injector on 1Q-pad. * * *Excempt move due to phase conditions * ** 18:00 00:00 6.00 MIRU MOVE CTOP P Spot Bed truck & discuss reel lowering procedure. Remove old reel from rig. Exchange reels on 1 -PAD 05/16/2010 Complete reel & injector swap. Move rig from 1Q to 3K - 09. Spot rig & equipment.. 00:00 10:00 10.00 MIRU MOVE CTOP P Completed swapping reels & injector. Start hooking up line to injector head while prepping pad & equipment for rig move. 10:00 20:00 10.00 MIRU MOVE MOB P Start moving rig off 1Q -pad. Walk around with pad operator and everything looked good. Hard time moving down road due to icey road conditions and blowing snow. Blower & grader leading the move. 20:00 00:00 4.00 MIRU MOVE MOB P Arrive on 3K - pad, DSO Shut in 3K -27 while spotting the rig. Spot rig & mud module. 05/17/2010 Spotted Rig & Equipment. Function Tested Injector. 6 hr Weather Hold ( Phase 3 Condition) Rigged Inner Reel Iron. Stab Pipe in Injector, Rebuilt Stuffing Box. 00:00 06:00 6.00 MIRU MOVE NUND P Rig spotted over well, start rigging up hard line. Rolled injector, tested all skate rams, stripper, in /out of hole. Aligned gooseneck. 06:00 09:00 3.00 MIRU WHDBO NUND P Crew change, rig up hard line in cellar, set down containment, hooked up hoses and & pumped open SSV, installed fusable. 09:00 15:00 6.00 MIRU WHDBO NUND T ** *Phase 3 conditions ** Limit work duties on rig. Clean up rig floor, prep fro stabbing pipe, finish making up hoses. Had pre -spud meeting with town Engineers & rig crews. 15:00 17:00 2.00 MIRU WHDBO CTOP P Back at Phase 2 and getting better. Get ready to Stab CT. Run straight bar for alignment. Crew Change. 17:00 21:00 4.00 MIRU WHDBO CTOP P Done Stabbing Pipe In Injector. Check Alignment on Injector. 21:00 23:00 2.00 MIRU WHDBO CTOP P Start Rigging Up Inner Reel Iron. Grease crew on location. 23:00 00:00 1.00 MIRU WHDBO NUND P Done With Reel Iron. Remove Cable & CTC from Coil. Grease Crew Done Servicing Tree Valve. Done Installing Second Block Valve On OA. 05/18/2010 Complete BOPE Test, Performed slack Mgmt. M/U BHA, RIH to mill pilot hole Page 1 of 26 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 MIRU WHDBO CTOP P Made Goose Neck Alignment. Install Packoff. Start Valve Alignment. PJSM. * ** Rig Accept @ midnight *** 01:00 02:00 1.00 MIRU WHDBOCIRC P Start filling BOP stack, body test. Small drip from WH Valve (MP line) was loose during Shell Test of BOPE. Re- tighten flange bolts on tree. 02:00 06:00 4.00 MIRU WHDBO BOPE P * ** *Start BOP testing ** *,State Test waived by Bob Noble 06:00 11:00 5.00 MIRU WHDBO BOPE P Crew change - valve checklist. Continue with BOP testing. * ** *BOP test completed * * ** 250 low / 5000 psi high. tested all gas alarms on rig. 11:00 13:00 2.00 MIRU WHDBO MPSP P P/U FMC lubricator to pull BPV - no information indicating current well pressure. 300 psi below BPV when pulled. Attached ESD remote panel line to 3K -27. 13:00 15:00 2.00 SURPRI WELLPF PRTS P Rig up CTU on Well and start filling the CT string with water. Pump slack back. 15:00 16:00 1.00 SURPRI WELLPF PRTS P Test inner reel valve and stripper. 250 / 5000 psi. Good test 16:00 18:00 2.00 SURPRI WELLPF SLPC P Cut coil to find wire, Cut 20' coil, M/U CTC 18:00 19:00 1.00 SURPRI WELLPF SLPC P Pull test connector to 40K, Head up E -line 19:00 20:00 1.00 SURPRI WELLPF PRTS P PT tiger tank line, PT CTC to 4K 20:00 21:00 1.00 0 0 PROD1 WHPST PULD P PJSM, M/U Coil track BHA to mill pilot hole, Surface test tool 21:00 23:45 2.75 0 6,850 PROD1 WHPST TRIP P RIH With BHA #1..9 degree motor. 2.80 Diamond speed mill_ Check injector alignment, Pull up hole every —1000' check coil for marks 23:45 00:00 0.25 6,850 6,870 PROD1 WHPST DLOG P Gamma tie into formation 05/19/2010 Complete Pilot hole to 7250, Run_Dummy WS to 7240 00:00 01:30 1.50 6,870 6,642 PROD1 WHPST DLOG P Still tying in. No clear tie in PUH 6535 and resume logging to 6642 got a +20' correction, RIH to log 6860 and log into second marker 01:30 01:42 0.20 6,642 6,680 PROD1 WHPST TRIP P RIH to tie into 6860 01:42 01:48 0.10 6,680 6,872 PROD1 WHPST DLOG P 6860 Tie into second marker, No Correction, RIH to Mill 01:48 01:54 0.10 6,872 7,030 PROD1 WHPST TRIP P 7030', dry tag cement, POOH and start pilot hole 01:54 04:54 3.00 7,030 7,083 PROD1 WHPST MILL P 7030, Mill Cement Pilot hole . 1.45 BPM @ 2923 PSI FS 16.5 FPH @ 1800 Lbs WOB 04:54 06:54 2.00 7,083 7,110 PROD1 WHPST MILL P 7083, stalled, come down on pumps and picked up. Possible caseing wall. Resume milling Page 2 of 26 • 411 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:54 08:24 1.50 7,110 7,145 PROD1 WHPST MILL P Continue milling Cement 15R. 1.40 BPM, 3600 psi, BHP 3890, ROP 20, WOB 2.5, No steel on magnets and good cement over shakers. Stall @ 7145' Getting very light trace of metal /scale in samples, along with cement. 08:24 09:24 1.00 7,145 7,165 PROD1 WHPST MILL P Milling - 1.40 bpm, 3600psi, BHP 3914, WOB 2.2K, ROP 17, CTweight 2K. Injector starting to make a clunking noise on bottom drilling (7150'). P/U pipe looks good, 28K up weight, 11K RIH weight. Injector sounds good. Increase chain tension (snubbing), on bottom. CT weight 8K. sound is gone. 09:24 13:24 4.00 7,165 7,230 PROD1 WHPST MILL P Milling ahead - 1.40 bpm, 3570, BHP 3930, WOB 2K, ROP 17, Ct weight 8K. Good cement returns to surface. 13:24 15:24 2.00 7,230 7,250 PROD1 WHPST MILL P Stall @ 7230 & 7233'- P/U 29K Had -3K overpull on BHA - wipe up 100 ft and work back down. Continue milling. 15:24 16:24 1.00 7,250 7,250 PROD1 WHPST WPRT P P/U weight - 26K off bottom. Wipe up through cement pilot. Circulate B/U - Stop pumping RIH & dry run cement pilot. Inspect pipe no marks off bottom. Clean no issues. 16:24 18:39 2.25 7,250 0 PROD1 WHPST TRIP P Perform flow test 15 minutes. No -flow Static BHP = 3382', POOH pumping to surface. 18:39 19:30 0.85 0 0 PROD1 WHPST PULD P PJSM / No Flo Test Lay down BHA #1 Pilot hole milling run 2.80 go but tight, 2.79 NoGo on mill 19:30 20:00 0.50 0 0 PROD1 RPEQPI PRTS P Pressure test PDL's to 4K 20:00 20:36 0.60 0 0 PROD1 RPEQPI PULD P PJSM, P/U BHA #2 Dummy whipstock Bump up and test tool, set depths 20:36 22:36 2.00 0 6,700 PROD1 RPEQP1TRIP P Trip in with dummy whipstock 22:36 22:51 0.25 6,700 6,719 PROD1 RPEQPI DLOG P 6700, Gamma tie in, +16, trip in well 22:51 00:00 1.15 6,719 7,240 PROD1 RPEQP1TRIP P Run to 7240, No setdowns. Good clean trip 05/20/2010 Completed dummy run, set whipstock @7200, Milled window TOW =7201, BOW= 7206.5 00:00 00:45 0.75 7,240 0 PROD1 RPEQP1TRIP P Continue out of well with dummy whipstock 00:45 01:30 0.75 0 0 PROD1 RPEQPI PULD P PJSM, Flow check well, Unstab and lay down dummy 01:30 02:00 0.50 0 0 PROD1 RPEQPI PULD T BOT trapped behind vac truck stuck in road Page 3 of 26 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 03:00 1.00 0 0 PROD1 RPEQP1 PULD P PJSM, M/U Whipstock and coiltrack, surface test tool. Bump up and set counters / Open EDC 03:00 04:45 1.75 0 6,700 PROD1 RPEQP1TRIP P RIH 04:45 04:51 0.10 6,700 6,719 PROD1 RPEQP1 DLOG P Gamma tie in for +21' correction, Trip into run CCL 04:51 05:21 0.50 6,719 7,229 PROD1 RPEQP1DLOG P 7000 Run CCL log, locate 7" collars 05:21 05:36 0.25 7,229 7,210 PROD1 RPEQP1WPST P PUH to 7209.64, TOW @ 7 Shut EDC, Pumps on Good indication of set @ 4300PSI, Set down cofirm set 05:36 07:36 2.00 7,209 0 PROD1 RPEQP1TRIP P POOH, PUW =24K -CT @ surface. Flow -check 07:36 09:06 1.50 0 73 PROD1 WHPST PULD P Lay down WS setting BHA - looked good, clean setting tool. P/U .6 AKO, 2.80" Window milling BHA. Service injector. 09:06 11:06 2.00 73 7,201 PROD1 WHPST TRIP P RIH Tie in + 20 ft correction. Dry tag WS @ 7201' IA = 30 psi, OA = 250 psi 11:06 13:06 2.00 7,201 7,202 PROD1 WHPST MILL P P/U and slowly RIH pumping - stall @ 7200.8', P/U and start milling 7200.7' " - 1.65 bpm, 3700 psi, BHP (1' 3950', WOB .3, CT weight 16K. ROP 1.1 fph. "Auto -drill .02" Good motor work @ 7200.9' 13:06 16:06 3.00 7,202 7,205 PROD1 WHPST MILL P Getting light metal shavings over shakers. ROP 1 fph, 1.65 bpm, 3800 psi, BHP 3955, WOB 1.6K, CT weight 13K. 16:06 18:51 2.75 7,205 7,207 PROD1 WHPST MILL P Good medal cutting over shakers, roughly half way through 7" 18:51 20:51 2.00 7,207 7,209 PROD1 WHPST MILL P 7206.5, Pressure spike calling bottom of window Start milling 1 FPH for string reamer to work area 1.65BPM @ 3950 FS, Getting formation in returns 20:51 00:00 3.15 7,209 7,215 PROD1 WHPST MILL P 7208.5, Start milling 10' formation, Midnight Depth 7215 05/21/2010 Complete Window, Drill Build from 7215 to 7385, RIH with lateral BHA, Tool Failure, POOH 00:00 00:15 0.25 7,215 7,216 PROD1 WHPST MILL P 7215, Milling formation 00:15 01:30 1.25 7,216 7,216 PROD1 WHPST REAM P Ream, Backream window area 3 complete passes, dry pass @ 5FPM Looks good 01:30 02:00 0.50 7,216 7,210 PROD1 WHPST CIRC P 7010, POOH above TOC, Open EDC, Circulate new 10.0 Lbs Flo Pro in well 02:00 03:45 1.75 7,210 500 PROD1 WHPST TRIP P New 10 PPG Flow Pro around, POOH 03:45 04:00 0.25 500 0 PROD1 WHPST SFTY P PJSM to swap out milling Bha #4 to Build section BHA #5 Continuing to surface Page 4 of 26 • Time Logs Date _ From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 04:30 0.50 0 0 PROD1 WHPST PULD P Tag up, Swap BHA's 2.80 No go on Mill, 2.79 No Go on string mill 04:30 05:15 0.75 0 0 PROD1 DRILL PULD P P/U Build section BHA with 2.4 degree motor and Bi- Center Surface test tool 05:15 07:15 2.00 0 7,215 PROD1 DRILL TRIP P RIH - tie in +21 ft correction, close EDC and drift through window. No problems. HS 07:15 08:15 1.00 7,216 7,225 PROD1 DRILL DRLG P Start drilling build section - 1.40 bpm, 3800psi, BHP 4170, ECD 12.2, WOB 1.4, CT weight 15K, ROP 18. Had to P/U a couple fo times off bottom for TF and weight transfer. Lower pump rate to 1.25bpm to ease the BHA stress. 08:15 10:45 2.50 7,225 7,308 PROD1 DRILL DRLG P Better weight transfer and TF orientation - continue drilling ahead. 1.25 bpm, 3600psi, BHP 4150, ECD 12.1, ROP 42, WOB 1.8K, CT weight 14K. Clays, shale & siltstone in samples. 10:45 13:45 3.00 7,308 7,385 PROD1 DRILL DRLG P Slow ROP due to ankerite. Broke through @ 7321'. Complete build section. P/U weight 25K 13:45 15:45 2.00 7,385 71 PROD1 DRILL TRIP P Wiper to Window, come up through window to TOC pumping .2 bpm, no weight bobbles. Stop POOH - Open EDC. POOh following MP schedule. 15:45 16:15 0.50 71 0 PROD1 DRILL PRTS P CT @ surface. Close EDC, Hold pre-job. Plan on dumping WH & close SSSV @ same tme to test SSSV. Close choke back in, bleed CT pressure. Pressure on BHA 26 psi. 15 minute flo- check. Final 27.5 psi- good test. Open choke and watch for flow 16:15 17:00 0.75 0 0 PROD1 DRILL PULD P Unstab injector, Lay down BHA #5 17:00 18:00 1.00 0 0 PROD1 DRILL PULD P M/U motor and bit, Lower MWD and Scribe, open swabs. P/U top section of Coil Track, set in well, Stab on and surface test tool, Open ECD 18:00 19:30 1.50 0 6,698 PROD1 DRILL TRIP P Pump up well to 625, Pump open SSSV, RIH 19:30 19:45 0.25 6,698 6,722 PROD1 DRILL DLOG P 6698' Gamma Tie In +19, Shut EDC, Trip into log RA 19:45 20:00 0.25 6,722 7,150 PROD1 DRILL TRIP P Trip in to log RA marker on whipstock 20:00 22:00 2.00 7,150 0 PROD1 DRILL TRIP T BHA Failure, Unable to move orienter. Tag up and drop 1.9' to deployment depth BHI Downtime Starts 22:00 00:00 2.00 0 0 PROD1 DRILL PULD T Undeploy BHA #6 / Deploy BHA #7 1 degree motor, New Razor bit Page 5 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/22/2010 24 hr Summary RIH with BHA #7 Drill Ahead to 8150, Lost 28BBIs to hole 00:00 01:24 1.40 0 0 PROD1 DRILL PULD T Pressure Deploy BHA #7, Surface test 01:24 02:30 1.10 0 6,698 PROD1 DRILL TRIP T Trip in well with BHA #7 1 Degree motor, razor cutters, resistivity, EDC open 02:30 02:42 0.20 6,698 6,714 PROD1 DRILL DLOG P Log Gamma Tie In +21' correction, Close EDC End of BHI Downtime 02:42 02:51 0.15 6,714 7,225 PROD1 DRILL TRIP P Trip in to log RA Marker 02:51 03:00 0.15 7,225 7,240 PROD1 DRILL DLOG P Log across RA Marker, RA Marker at 7206 TOW @ 7200.65 BOW @ 7206.15 RIH to drill, Did not see anything passing through window 03:00 03:06 0.10 7,240 7,385 PROD1 DRILL TRIP P Trip in hole to drill 03:06 05:06 2.00 7,385 7,485 PROD1 DRILL DRLG P 7385' Drill Ahead 1.36 BPM @ 3800FS RIW =10K BHP =4240, one stall getting going 05:06 07:36 2.50 7,485 7,535 PROD1 DRILL DRLG P 7485', Back in Anchorite ROP <10 FPH WOB =3kBOP =4250 Stall @ 7512' when got out Ankerite. P/U and continued drilling ahead. Rate out dropped slightly but is slowly coming back to normal. 07:36 09:36 2.00 7,535 7,535 PROD1 DRILL DLOG P Wiper trip with MAD Pass, slow pump rates. P/U weight P/U weight 23K, BHP 4200 psi, ECD 12.3. 09:36 11:36 2.00 7,535 7,685 PROD1 DRILL DRLG P Drilling ahead - 1.35 bpm, 3900 psi, BHP 4240, ECD 12.3, ROP 65, WOB 2K, CT weight 11 K. Very good sand in samples, nice formation. 11:36 12:36 1.00 7,685 7,685 PROD1 DRILL WPRT P Wiper trip 24K off bottom. 12:36 15:06 2.50 7,685 7,835 PROD1 DRILL DRLG P Drilling ahead - 1.40 bpm, 3900, BHP 4250, ECD 12.2, ROP 50, WOB 1.6K, Ct weight 12K. 15:06 16:36 1.50 7,835 7,835 PROD1 DRILL WPRT P Wiper trip P/U weight 23K Tie in with -2 ft. correction. 16:36 19:00 2.40 7,835 7,985 PROD1 DRILL DRLG P Drilling ahead - 1.40 bpm, 3840psi, BHP 4250, ECD 12.3, ROP 55, WOB 1.7, CT weight 13K. 19:00 20:00 1.00 7,985 7,985 PROD1 DRILL WPRT P 7985', Wiper to window 1.38 BPM @ 3850 FS PUW =23K, BHP =4290 20:00 21:45 1.75 7,985 8,135 PROD1 DRILL DRLG P 7985', Drill Ahead 1.36 BPM @3945FS RIW =11 K, BHP =4290 21:45 22:45 1.00 8,135 8,135 PROD1 DRILL WPRT P 8135' Wiper to window, PUW =22.5 K 1.38 BPM @ 3945 BHP =4290, No overpulls or setdowns Page 6 of 26 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:45 00:00 1.25 8,135 8,150 PROD1 DRILL DRLG P 8135', Drill Ahead 1.36 BPM @ 3940 PSI FS Lost 28 BBIs to Hole last 24 Hours, LSRV @36K, .4% Drill Solids 10 PPG BHP =4320 Midnight Depth =8150 05/23/2010 Drilled 8150 to 8760, Swapped Mud, Lost 47 BBIs to formation 00:00 03:00 3.00 8,150 8,190 PROD1 DRILL DRLG P 8150', Drill Ahead 1.36BPM @3940FS RIW =6K WOB =3k ROP =I5FPH BHP =4320 03:00 04:00 1.00 8,190 8,210 PROD1 DRILL DRLG P Sample @ 8150 shows clays, Tried BHA wipers, ROP was up to 30 FPH briefly, now down to 9 FPH. Send 10 BBI pill of drillzone to clear bit if balled up 04:00 04:45 0.75 8,210 8,218 PROD1 DRILL DRLG P 8210, Drill zone pill had no effect, Still in clays /shales ROP =10 to 15 FPH. WOB =2.8K RIW =7.7K BHP =4340 04:45 06:45 2.00 8,218 8,240 PROD1 DRILL DRLG P 8218, performed BHA wiper up to 8110 PUW =23K, Not sticky at all, went right back to drilling 06:45 08:00 1.25 8,240 8,290 PROD1 DRILL DRLG P ROP increased to 40, get set up for mud swap during wiper trip. Continue drilling ahead. Weight check 27K off bottom. 08:00 09:30 1.50 8,290 8,290 PROD1 DRILL WPRT P Wiper trip 27K off bottom, weight cleaning up 40' into wiper to 22K. Tie in with - 5 ft correction. Mud swap with 1080' ft on old system. Two small weight bobbles @ 8183' TF change. Quick weight check on bottom 24K. 09:30 14:00 4.50 8,290 8,440 PROD1 DRILL DRLG P Drilling ahead new mud at bit - 1.4 bpm, 3850 psi, BHP 4230, ECD 12.3, ROP 18, WOB 2.5K, Still steering up to find formation. 8316' - weight check 24K. Continue drilling slow ROP. 14:00 14:30 0.50 8,440 8,460 PROD1 DRILL DRLG P BHA wiper P/U weight 24K - Geo's have am idea of throw but would like additional 20ft. to confirm. 14:30 15:30 1.00 8,460 7,000 PROD1 DRILL WPRT P Planned Wiper trip - Pull up through window - clean. Stop CT above cement @ 7000', hold 4100 at window. Discuss formation options with town & lock out reel to tighten reel flange bolts. 15:30 16:30 1.00 7,000 8,460 PROD1 DRILL WPRT P RIH - to continue drilling ahead. 1.35 bpm 3750 free spin. Page 7of26 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:30 17:00 0.50 8,460 8,480 PROD1 DRILL DRLG P Drilling ahead - 1.35 bpm, 3800 psi, BHP 4290, ECD 12.4, ROP 75, WOB 1.5K, CT weight 12K. At 8499' Gas /Oil returns starting coming to surface, take out to TT. BHP has been constant the whole time. BHP has increased to 4400 psi. 17:00 19:15 2.25 8,480 8,610 PROD1 DRILL DRLG P P/U weights clean, start holding about 100 psi on choke & work out gas bubble. 19:15 20:51 1.60 8,610 8,610 PROD1 DRILL WPRT P i r trip window, 8610, Wpe t p to , PUW =21.5 Good trip in and out, No over pulls or set downs 20:51 22:51 2.00 8,610 8,760 PROD1 DRILL DRLG P 8610', Drill Ahead 1.36 BPM @ 3930 FS RIW =9k, WOB =1.1k BHP =4450 Saw no gas / oil shows during drilling interval, Holding 125 on choke 22:51 23:51 1.00 8,760 7,225 PROD1 DRILL WPRT P Wiper trip to window with tie in 1.3 BPM @ 3800FS PUW =22k BHP =4470 23:51 00:00 0.15 7,225 PROD1 DRILL DLOG P Tie into RA Marker 05/24/2010 Drilled 8760 to 9412, Lost 8 BBIs to formation 00:00 00:15 0.25 7,225 7,243 PROD1 DRILL DLOG P Tie into RA marker, -9' correction RIH to drill 00:15 01:00 0.75 7,243 8,760 PROD1 DRILL WPRT P Continue wiper trip No overpulls or set downs Hole in good shape 01:00 01:18 0.30 8,760 8,765 PROD1 DRILL DRLG P 8755', Drill ahead 1.28 BPM @ 3750 FS RIW =11 K, WOB =1.04K BHP =4420 01:18 01:33 0.25 8,765 8,770 PROD1 DRILL DRLG P Divert gassy / oily returns to tiger tank 01:33 04:03 2.50 8,770 8,775 PROD1 DRILL DRLG P Density back up, Bring returns back inside. Continue drilling ahead 04:03 06:03 2.00 8,775 8,910 PROD1 DRILL WPRT P 8910, Wiper trip to window PUW =23K, BHP =4424 06:03 09:03 3.00 8,910 9,060 PROD1 DRILL DRLG P back on bottom - diverted 19 bbls outside due to wiper influx. Drilling ahead - 1.35 bpm, 4200 psi, BHP 4540, CTES WHP 170 psi, ECD 13.3, WOB 2.3, Ct weight 7K, ROP 60 09:03 11:03 2.00 9,060 9,060 PROD1 DRILL WPRT P Wiper trip - P/U weight 22K, Hold additional 40 psi on WHP for wiper. CTES WHP - 225 psi. No kick's when got back to bottom. 11:03 13:33 2.50 9,060 9,210 PROD1 DRILL DRLG P Drilling ahead - 1.40 bpm, 4200 psi, BHP 4529, WHP 185, ECD 13.2, ROP 60, WOB 2K, Ct weight 8K. 13:33 16:03 2.50 9,210 9,210 PROD1 DRILL WPRT P Wiper trip - 23K off bottom WHP 220 on wiper. Had a small weight spike @ 8210' when POOH. Tie in - 12ft correction. No influx during wiper trip. Page 8 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:03 18:03 2.00 9,210 9,306 PROD1 DRILL DRLG P Tag bottom early due to correction - drilling ahead from 9198' 18:03 19:33 1.50 9,306 9,306 PROD1 DRILL WPRT P Geo Wiper, Hot gamma, consult town, wipe to 7230 Clean trip up, Set down @9265, 72, 83, Shaley area Bakream up from 9300 180 degree out from as drilled, High Gamma 9240 to 9270 Back down few bobbles no setdowns at full pump rate 19:33 23:33 4.00 9,306 9,370 PROD1 DRILL DRLG P 9306, Drill ahead 1.3 BPM @ 3800 FS, RIW =8.5 BHP =4570 23:33 23:39 0.10 9,370 9,412 PROD1 DRILL DRLG P Drilling break, ROP 80FPH, out of hot gamma, Res indicating less water, Near bit 96 to 97 degrees 1.3 BPM @ 3800 FS BHP =4570 23:39 00:00 0.35 9,412 9,412 PROD1 DRILL DRLG P Drilling ahead Midnight depth 9412 10.0 ppg 47 vis SF FloPro LSRV - 29000 Drilled Solids- 0.7 05/25/2010 TD 3K -09B lateral 9610'. POOH lay in liner pill. Unable to get good test on SSSV. RIH for cleanout run 00:00 00:30 0.50 9,412 9,460 PROD1 DRILL DRLG P 9412, Drill Ahead 1.3 BPM ©3800 FS BHP =4630, Still holding 100 PSI on choke BHP has come up since 9370' 00:30 03:15 2.75 9,460 9,460 PROD1 DRILL WPRT P 9460, Wipe to window , goto 120 PSI on choke PUW =22K Clean trip up Set downs @9290, 9284, 9285 Ratty through shale sections 9240 -9310 and 9340- 9360 03:15 05:15 2.00 9,460 9,610 PROD1 DRILL DRLG P 9460', Drill ahead 1.3 BPM @ 3800 FS BHP =4630, Holding 100 PSI on choke 05:15 07:45 2.50 9,610 8,175 PROD1 DRILL WPRT P Wiper trip - P/U weight 23K off bottom.Mud swap. Tie in @ window - 16 ft correction. RIH and stacked out @ 8175' due to TF change. Heavier P/U 5K over. Ran through then wiped up pass to ensure clean. - Pulling heavy 35K @ 8150' 07:45 09:15 1.50 8,175 8,150 PROD1 DRILL WPRT T Worked pipe @ 8150' for 15 minutes (BHA stuck with partial to no returns). Worked free, full returns. Wiper to window to clean up hole and let new mud get around. Page 9 of 26 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:15 10:27 1.20 8,150 8,200 PROD1 DRILL WPRT T RIH - slow down to 15 fpm, pump rate 1.2 bpm, BHP 4350, WHP 225. TF started to rotate © 8159', P/U 100' clean up, RIH down to 8200' P/U 23K, light overpull @ 8157', cleaned up. RIH TF rolled again @ 8158', P/U clean, RIH no more problems. Weight check @ 4200' 22K. 10:27 11:27 1.00 8,200 8,780 PROD1 DRILL WPRT P Continue RIH pumping new mud to spot liner pill. 8780' Fitting leaking on injector head. Have to work out gas bubble that was behind shale while RIH. 11:27 12:12 0.75 8,780 7,000 PROD1 DRILL WPRT T POOH slowly to inspect Injector. Skate hose fitting leaking. Working out gas kick as POOH. BHP 4400 P/U to 8050' - Above bad shale. Slow pump rate and increase WHP to 500 psi. Need to POOH into cased hole and fix injector hose problem. 25 bbls total to TT. * ** Nabor down time * ** 12:12 12:30 0.30 7,000 7,000 PROD1 DRILL TRIP T Stop in cased hole above Cement @ 7000'. Slow pump rate to .4 bpm and trap 800 psi on WH. Shut down pump. BHP bled down to 4300 psi. Review procedure for closing upper 2" rams. Pack up Stripper, close 2" rams - push pull test - good. Lower traction and reel pressure. Isolate hyd. from injector head. 12:30 13:30 1.00 7,000 8,780 PROD1 DRILL TRIP T BHP 4280 psi with 800 WHP after 10 minutes with injector repairs. Apply traction, P/U string weight - open rams. POOH 100 ft to inspect pipe. Looks good - RIH, Tie in to RA. ** *End Nabors down time, 2 Hours code 8 * ** 13:30 14:06 0.60 8,780 9,262 PROD1 DRILL TRIP P Continue to RIH 14:06 14:30 0.40 9,262 9,240 PROD1 DRILL TRIP T Stacking weight and motor work at 9262', PU clean and then stack out at 9253 and 9249'. Drop pump rate to .2 BPM and try again. 14:30 15:00 0.50 9,240 9,000 PROD1 DRILL TRIP T Before getting down to trouble area started getting gas in returns. Divert to tiger tank and circulate out gas, total of 42 Bbls. to TT Page 10 of 26 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 15:30 0.50 9,000 9,000 PROD1 DRILL TRIP T Returns cleaned up, run back inhole, stack weight at 9260', PUH and shut down pump. RIH and see weight stacking at 9249', 9262', 9280'. Got down to 9300', brought pump online and stalled, pulled 8K over, lots of differential pressure at the BHA. continue PUH seeing 15K overpulls up to 9240', clean PU from there. CBU 15:30 16:30 1.00 9,000 9,250 PROD1 DRILL DISP P Consulted with town eng, decide to precede to liner operations. Pump 5 low /5 high sweeps, followed by mud spacer then liner running pill 16:30 18:00 1.50 9,250 7,771 PROD1 DRILL TRIP P POOH, laying in liner running pill. 18:00 19:00 1.00 7,771 5,771 PROD1 DRILL TRIP P Paint EOP flag, continue POOH 19:00 20:00 1.00 5,771 0 PROD1 DRILL TRIP P Paint EOP flag, continue POOH 20:00 21:42 1.70 0 0 PROD1 DRILL SIPB P At surface, close EDC. Bleed psi off SSSV. Wait 5 minutes. Try to bleed WHP. Unable to bleed WHP. Cycle SSSV attempting to close SSSV. Unsuccessful. Call DSO for assistance. Psi up SSSV with DSO pump attempting to close SSSV. Unsuccessful. 21:42 22:42 1.00 0 3,000 PROD1 DRILL TRIP P Open EDC, RIH to kill well 22:42 23:21 0.65 3,000 6,700 PROD1 DRILL TRIP P Crude /gas in returns. Send returns to TT. Continue RIH 23:21 00:00 0.65 6,700 7,000 PROD1 DRILL DLOG P Tie in depth to gamma + 19', Increase rate 1.3 BPM circulating bottoms up 05/26/2010 Perform cleanout run to TD, Laying in liner pill. Displace well with KWF (Formate). POOH, PU liner, RIH setting liner at 9510', TOL 8125'. POOH, PU OH anchor billet with proper spaceout with liner pup joints setting on depth 8125' TOB 8055'. POOH 00:00 00:12 0.20 7,000 7,000 PROD1 DRILL CIRC P Start taking returns back inside. 00:12 00:30 0.30 7,000 8,180 PROD1 DRILL TRIP P RIH to TD cleaning hole. 00:30 02:00 1.50 8,180 9,250 PROD1 DRILL TRIP P Tag up work passed tight spot, pumps minimum rate 02:00 04:00 2.00 9,250 7,350 PROD1 DRILL TRIP P POOH laying in Liner pill 04:00 06:00 2.00 7,350 0 PROD1 DRILL TRIP P POOH laying in Formate 06:00 06:42 0.70 0 0 PROD1 DRILL PULD P At surface, flow check, no flow. Lay down drilling BHA 06:42 10:00 3.30 0 1,432 COMPZ CASING PUTB P Rig up floor for running liner. PU 43 joints of liner, liner running BHA. 10:00 12:00 2.00 1,432 7,132 COMPZ CASING RUNL P RIH 12:00 12:30 0.50 7,132 7,104 COMPZ CASING DLOG P Correct depth at flag, +39'? PUH to 5618 EOP depth and log down. -10' correction. 18K RIW, 24K PUW Page 11 of 26 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:30 14:00 1.50 7,104 9,510 COMPZ CASING RUNL P Continue RIH. Stacked weight at 7320', 5K over pull, down clean. 9271' Stacked weight, did not PU, Got weight back. 14:00 15:00 1.00 9,510 6,690 COMPZ CASING RUNL P 28K PUW, Release liner at 9510',_ 1.2 BPM, 4000 psi, 23K PUW. Pump down backside while pulling out of open hole. Take out liner length from bit depth, - 1387.8. 15:00 15:18 0.30 6,690 6,720 COMPZ CASING DLOG P Log cased hole tie in, 0 correction. 15:18 16:36 1.30 6,720 0 COMPZ CASING RUNL P POOH 16:36 16:54 0.30 0 0 COMPZ CASING PUTB P Confirm no flow and lay down BHA a 16:54 17:18 0.40 0 0 COMPZ CASING BOPE P Function test BOP, change stripper 17:18 18:03 0.75 0 0 COMPZ CASING PUTB P PU indexing guide shoe, 1 jt. slotted liner, 3 solid liner pups and anchored billet 18:03 18:33 0.50 0 0 COMPZ CASING SFTY P Crew change PJSM 18:33 19:03 0.50 0 0 COMPZ CASING PUTB P MU BHA to injector head 19:03 20:33 1.50 0 6,800 COMPZ CASING TRIP P RIH 20:33 22:03 1.50 6,800 7,320 COMPZ CASING DLOG P Tie in depth with gamma, +37' correction, Unsure of correction, RIH through window at 5 FPM to tie into RA marker 22:03 22:33 0.50 7,320 7,320 COMPZ CASING DLOG P Correct -5' tieing into RA marker, Overall correction +32' 22:33 22:48 0.25 7,320 8,125 COMPZ CASING TRIP P RIH to setting depth EDC closed, before running OH 22:48 23:03 0.25 8,125 8,125 COMPZ CASING WPST P Tag TOL 8125.1'. PU string weight 22K, 1K DHWOB. Online with pumps setting Anchor. .5 BPM, 3750 psi anchor set, 3.6K DHWOB. Line up pumps pumping across top displacing KWF keeping hole full. 23:03 23:18 0.25 8,125 7,350 COMPZ CASING TRIP P PUH to window 24.5K PUW. 23:18 00:00 0.70 7,350 COMPZ CASING TRIP P Line up pumping back down CT, POOH 05/27/2010 RIH with Coil Track drilling assembly 1.3AKO, Reed Hycalog Razor Bi- center, Displace well to Flo -Pro at window. Sidetrack for BL1 lateral off Alluminum Billet at 8059'. Drill BL1 Lateral 8059'- 8530'. Perform mud swap at 21:00 hours. 00:00 01:00 1.00 7,350 0 COMPZ CASING TRIP P POOH 01:00 02:00 1.00 0 0 COMPZ CASING PUTB P At surface, monitor well for flow, PJSM, LD BHA 9 02:00 03:18 1.30 0 0 PROD2 STK PULD P PU /MU BHA 10, Service injector head, clean gripper blocks, inspect BHI counter 03:18 04:48 1.50 0 6,750 PROD2 STK TRIP P RIH 04:48 05:42 0.90 6,750 7,300 PROD2 STK DLOG P Tie in depth with Gamma, Unable to get accurate tie in with gamma, RIH 50' above window, RIH 5 FPM tieing into RA marker. Tie in to RA, +32'. Page 12 of 26 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:42 07:12 1.50 7,300 7,300 PROD2 STK DISP P Displace KWF 07:12 08:00 0.80 7,300 8,059 PROD2 STK TRIP P RIH 08:00 11:42 3.70 8,059 8,072 PROD2 STK KOST P Tagged billet at 8059', start time milling at 1 FPH. 1.3 BPM, 3950 CTP, 250 WHP to maintain 4450 BHP, 24K PUW, 14K RIW. Some stick/slip. Increased to 2 FPH after 1 foot, then 3 FPH. increased to 10 B y FPH for 10'. 11:42 12:42 1.00 8,072 8,100 PROD2 DRILL DRLG P Drilling ahead, 1.3 BPM, 3990 CTP, 4460 BHP with 250 WHP. 11K surface weight with 2K WOB 12:42 12:54 0.20 8,100 8,100 PROD2 DRILL DRLG P Pick up and drift billet kick off. Up at .3 BPM, down with pump off. Clean both ways. 24K PUW, 14K RIW 12:54 16:06 3.20 8,100 8,230 PROD2 DRILL DRLG P Continue drilling, 1.3 BPM, 4000 CTP, 4475 BHP with 250 WHP. 11K surface weight with 2K WOB 16:06 17:18 1.20 8,230 8,230 PROD2 DRILL WPRT P Wiper trip to the window, 24K PUW, 13K RIW 17:18 19:39 2.35 8,230 8,380 PROD2 DRILL DRLG P Continue drilling, 1.3 BPM, 4050 CTP, 4485 BHP with 230 WHP. 11K surface weight with 2K WOB 19:39 20:39 1.00 8,380 8,380 PROD2 DRILL WPRT P Wiper trip back to window, 22K PUW, 13K RIW 20:39 22:09 1.50 8,380 8,530 PROD2 DRILL DRLG P Continue drilling, 1.4 BPM, 4350 CTP, 4485 BHP with 325 WHP. 7K surface weight with 1 -2K WOB Mud swap 22:09 23:09 1.00 8,530 8,530 PROD2 DRILL WPRT P Wiper trip back to window, 22.8K PUW, 11K RIW 23:09 23:18 0.15 7,230 7,225 PROD2 DRILL DLOG P Tie into RA marker -5' correction 23:18 23:48 0.50 8,225 8,155 PROD2 DRILL WPRT P RIH 14K RIW 23:48 00:00 0.20 8,155 8,500 PROD2 DRILL WPRT P Set down at 8155', PUH 21.2K PUW, clean PU to 8130'. RIH, Slide through no pumps. Wipe back through area 8170 - 8130', Al shale area 8136- 8150'. Reduce pump rate 1 BPM RIH through shales on second run. Slide through. RIH to bottom 05/28/2010 Drill BL1 Lateral 8530'- 943Q'. Low Level H2S Alarm at 430am. (Sensor #2 Cellar, False Alarm). 00:00 00:12 0.20 8,500 8,530 PROD2 DRILL WPRT P Continue RIH 00:12 01:27 1.25 8,530 8,680 PROD2 DRILL DRLG P Continue drilling, 1.3 BPM, 4150 CTP, 4520 BHP with 350 WHP. 6 -7K surface weight with 1.5K -2K WOB 01:27 01:42 0.25 8,680 8,680 PROD2 DRILL WPRT P Wiper Trip back to window, 22.2K PUW 01:42 02:24 0.70 8,680 8,680 PROD2 DRILL DLOG P Perform MAD pass as per GEO, 8290'- 8130', at 4 FPM 02:24 03:30 1.10 8,680 8,680 PROD2 DRILL WPRT P Continue wiper trip Page 13 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 04:30 1.00 8,680 8,750 PROD2 DRILL DRLG P Continue drilling, 1.38 BPM, 4150 CTP, 4520 BHP with 350 WHP. 6 -7K surface weight with 1.5K -2K WOB 04:30 05:00 0.50 8,750 8,750 PROD2 DRILL SFTY P PUH, Low level H2S alarm, muster rig. Notify security and Nordic 3. False Alarm, faulty sensor. RIH 05:00 07:00 2.00 8,750 8,830 PROD2 DRILL DRLG P Continue drilling, 1.38 BPM, 4150 CTP, 4520 BHP with 350 WHP. 6 -7K surface weight with 1.5K -2K WOB 07:00 09:12 2.20 8,830 8,830 PROD2 DRILL WPRT P Wiper to window, 24K PUW, clean run in hole 09:12 12:36 3.40 8,830 8,980 PROD2 DRILL DRLG P Continue drilling, 1.35 BPM, 4100 CTP, 4550 BHP with 350 WHP. 6K surface weight with 1.5K -2K WOB 12:36 13:42 1.10 8,980 7,225 PROD2 DRILL WPRT P Wiper to window, 25K PUW 13:42 13:54 0.20 7,225 7,250 PROD2 DRILL DLOG P Tie in at RA, -5' 13:54 14:48 0.90 7,250 8,977 PROD2 DRILL WPRT P Wiper back in hole, set down at 8818', PU and then run by clean 14:48 16:39 1.85 8,980 9,130 PROD2 DRILL DRLG P Continue drilling, 1.3 BPM, 4150 CTP, 4600 BHP with 280 WHP. 6 -7K surface weight with 1.5K -2K WOB 16:39 18:54 2.25 9,130 9,130 PROD2 DRILL WPRT P Wiper trip to window, 23K PUW 18:54 20:24 1.50 9,130 9,280 PROD2 DRILL DRLG P Continue drilling, 1.3 BPM, 4150 CTP, 4600 BHP with 280 WHP. 6 -7K surface weight with 1.5K -2K WOB 20:24 22:54 2.50 9,280 9,280 PROD2 DRILL WPRT P Wiper trip to window, 22.8K PUW 22:54 00:00 1.10 9,280 9,384 PROD2 DRILL DRLG P Continue drilling, 1.3 BPM, 4150 CTP, 4630 BHP with 260 WHP. 6 -7K surface weight with 1.5K -2K WOB 05/29/2010 frill RI 1 I ateral. TD'd Lateral 10018' 00:00 00:30 0.50 9,384 9,530 PROD2 DRILL DRLG P Continue drilling, 1.3 BPM, 4150 CTP, 4620 BHP with 240 WHP. 6 -7K surface weight with 1.5K -2K WOB 00:30 02:00 1.50 9,530 7,230 PROD2 DRILL WPRT P Wiper trip back to window, 23K PUW 02:00 02:12 0.20 7,230 7,230 PROD2 DRILL DLOG P Tie into RA marker, -7' 02:12 03:12 1.00 7,230 9,530 PROD2 DRILL WPRT P RIH 03:12 05:12 2.00 9,530 9,580 PROD2 DRILL DRLG P Continue drilling, 1.3 BPM, 4150 CTP, 4620 BHP with 240 WHP. 6 -7K surface weight with 1.5K -2K WOB 05:12 08:00 2.80 9,580 9,580 PROD2 DRILL WPRT P Wiper to window, 23K PUW. 13K RIW, clean trip both ways. 08:00 10:18 2.30 9,580 9,730 PROD2 DRILL DRLG P Continue drilling, 1.3 BPM, 4100 CTP, 4640 BHP with 250 WHP. 6 -7K surface weight with 1.5K -2K WOB Page 14 of 26 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:18 12:00 1.70 9,730 7,218 PROD2 DRILL WPRT P Wiper to window, 23K PUW 12:00 12:12 0.20 7,218 7,240 PROD2 DRILL DLOG P Tie in at RA, -6' correction 12:12 13:30 1.30 7,240 9,730 PROD2 DRILL WPRT P Wiper in hole, 14K RIW 13:30 15:06 1.60 9,730 9,880 PROD2 DRILL DRLG P Continue drilling, 1.3 BPM, 4100 CTP, 4700 BHP with 150 WHP. 7K surface weight with 1.5K -2K WOB 15:06 17:00 1.90 9,880 7,220 PROD2 DRILL WPRT P Wiper trip to window, Start mud swap. Over pull at 8145'. 17:00 17:12 0.20 7,220 7,240 PROD2 DRILL DLOG P Tie in , -4' correction 17:12 18:27 1.25 7,240 9,880 PROD2 DRILL WPRT P Wiper in hole 18:27 20:42 2.25 9,880 10,018 PROD2 DRILL DRLG P Continue drilling, 1.3 BPM, 4100 CTP, 4700 BHP with 400 WHP. 7K surface weight with 1.5K -2K WOB 20:42 22:42 2.00 10,018 10,018 PROD2 DRILL WPRT P Pump 5bbrl low/ 10bbrl high vis sweeps. TD BL1 Lateral. Wiper trip back to window chasing sweeps. 24.5K PUW Pull heavy 8940 - 8820'. Continue POOH not wanting to irratate shales 22:42 22:57 0.25 10,018 7,230 PROD2 DRILL DLOG P Tie into RA marker, -3' correction 22:57 23:27 0.50 7,230 8,230 PROD2 DRILL WPRT P RIH to TD, Large amounts of shale in returns plugging Choke "B ". Swap to choke "A ". Blow back choke "B" and MM, good amount of shale when blown back. 23:27 00:00 0.55 8,230 8,230 PROD2 DRILL WPRT P Continue RIH, pump minimum rate through shale areas, Keep MM bypassed until reach TD to keep MM clean of shale, to use MM on displacing liner running pill. 05/30/2010 Lay in liner running pill, POOH displacing well to KWF, PU 66jnts with Liner top Billet. RIH setting on bottom. POOH keeping_ well displaced of KWF. Start BOP testing 7PM 00:00 00:30 0.50 9,500 10,018 PROD2 DRILL WPRT P Tag TD 10018' 00:30 01:00 0.50 10,018 8,400 PROD2 DRILL WPRT P POOH laying in Liner Pill 1 for 1, chasing with flo -pro. 01:00 01:30 0.50 8,400 7,771 PROD2 DRILL WPRT P Confirmed able to pass bad area 8940 - 8820'. Start pumping KWF (formate). Continue POOH laying in Liner pill 01:30 01:45 0.25 7,771 7,250 PROD2 DRILL WPRT P Paint EOP flag 7700. 7771 CTMD, Continue POOH 01:45 02:03 0.30 7,250 7,350 PROD2 DRILL CIRC P RIH to spot KWF 7350' 02:03 02:45 0.70 7,350 4,971 PROD2 DRILL TRIP P POOH displacing well to KWF 02:45 04:15 1.50 4,971 0 PROD2 DRILL TRIP P Paint EOP flag 4900'. 4971' CTMD, POOH 04:15 04:30 0.25 0 0 PROD2 DRILL OWFF P PJSM, flow check well 04:30 05:42 1.20 0 0 PROD2 DRILL PULD P LD BHA 10 05:42 06:00 0.30 0 0 COMPZ CASING SFTY P PJSM for liner operations Page 15 of 26 ! • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 10:00 4.00 0 2,211 COMPZ CASING PUTB P Rig up and run 66 joints slotted liner, aluminum billet and Inteq BHA 10:00 11:18 1.30 2,211 7,111 COMPZ CASING RUNL P RIH 11:18 12:30 1.20 7,111 10,044 COMPZ CASING RUNL P Correct at EOP flag, +40', 25K PUW, 15K RIW 12:30 12:54 0.40 10,044 7,220 COMPZ CASING TRIP P Stack weight at 10044'. Release from liner, 1.3 BPM, 4300 CTP. Continue PUH pumping down backside. 12:54 13:06 0.20 7,190 7,216 COMPZ CASING DLOG P Tie in to RA, -10' correction 13:06 14:36 1.50 7,216 0 COMPZ CASING TRIP P POOH, pumping down coil. 14:36 15:18 0.70 0 0 COMPZ CASING PUTB P At surface, flow check, lay down BHA 15:18 17:18 2.00 0 0 PROD3 DRILL CIRC P Stab back onto well and displace CT to fresh water, jeting stack and flushing surface lines. 17:18 17:48 0.50 0 0 PROD3 DRILL SFTY P Crew Change, PJSM 17:48 19:00 1.20 0 0 PROD3 DRILL SVRG P Grease Tree, and Choke Valves 19:00 00:00 5.00 0 0 PROD3 DRILL BOPE P Start BOP Testing_ State Witnessed: Chuck Scheve 05/31/2010 Complete BOP testing (10 hrs), PU /MU BHA 11, RIH, displace well back to flo -pro. Tag alluminum top billet 7863'. Sidetrack, drill ahead BL1 -01 lateral 7863'- 8310'. 00:00 05:00 5.00 0 0 PROD3 DRILL BOPE P BOP testing BOP testing complete 05:00 07:30 2.50 0 0 PROD3 STK PULD P Install check valves, Displace CT to KWF, MU Drilling BHA with res 07:30 09:30 2.00 0 6,700 PROD3 STK TRIP P RIH 09:30 10:00 0.50 6,700 6,750 PROD3 STK DLOG P Tie -in, +29' correction 10:00 11:30 1.50 6,750 7,200 PROD3 STK TRIP P Continue RIH, stop at window and circulate out KWF, 0.5 BPM at 4675 BHP 11:30 12:00 0.50 7,200 7,863 PROD3 STK TRIP P RIH and tag top of billet at 7863.4 with pump down. 24K PUW, 11K RIW 12:00 14:24 2.40 7,863 7,890 PROD3 STK KOST P Mill off billet. 1.4 BPM, 4060 CTP, 4450 BHP, 360 WHP. 1 FPH for one foot, 2 FPH for 1 foot, 3 FPH for 1 V foot then 10 FPH, then 30 FPH 14:24 14:36 0.20 7,890 7,890 PROD3 STK KOST P PUH past billet then dry drift. Clean 00-01 up and down. 14:36 16:00 1.40 7,890 8,010 PROD3 DRILL DRLG P Drilling ahead, 1.3 BPM, 4000 CTP, 4460 BHP, 360 WHP. 1 - 2K WOB, 200 -300 psi motor work for 100 -150 ROP 16:00 17:00 1.00 8,010 8,010 PROD3 DRILL WPRT P Wiper to window, 24K PUW Page 16 of 26 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 20:30 3.50 8,010 8,160 PROD3 DRILL DRLG P Drilling ahead, 1.3 BPM, 4000 CTP, 4460 BHP, 360 WHP. 1 - 2K WOB, 200 -300 psi motor work for 100 -150 ROP 30 -60 FPH 2 -3K WOB, drilling through B formation 20:30 21:30 1.00 8,160 8,160 PROD3 DRILL WPRT P Wiper trip to window, 23K PUW 21:30 23:30 2.00 8,160 8,310 PROD3 DRILL DRLG P Drilling ahead, 1.3 BPM, 4000 CTP, 4460 BHP, 360 WHP. 1 - 2K WOB, 200 -300 psi motor work for 100 -150 ROP 40 -80 FPH 2 -3K WOB, drilling through B formation 23:30 00:00 0.50 8,310 8,310 PROD3 DRILL WPRT P Wiper trip to window, 23K PUW 06/01/2010 TD BL1 -01 Lateral, 8903'. Lay in liner running pill, POOH killing well. PU/MU BL1 -01 liner. RIH 00:00 00:12 0.20 8,310 7,230 PROD3 DRILL DLOG P Tie in depth with RA marker. 0 correction. 00:12 00:42 0.50 7,230 8,310 PROD3 DRILL WPRT P RIH 11K RIW. 00:42 02:12 1.50 8,310 8,460 PROD3 DRILL DRLG P Drilling ahead, 1.3 BPM, 4000 CTP, 4500 BHP, 280 WHP. 1 - 2K WOB, 200 -300 psi motor work for 80 -100 ROP 02:12 03:36 1.40 8,460 8,460 PROD3 DRILL WPRT P Wiper trip to window, 23K PUW 03:36 05:06 1.50 8,460 8,610 PROD3 DRILL DRLG P Drilling ahead, 1.36 BPM, 4000 CTP, 4500 BHP, 230 WHP. 1 - 2K WOB, 200 -300 psi motor work for 80 -125 ROP 05:06 06:06 1.00 8,610 7,280 PROD3 DRILL WPRT P Wiper trip to window, 23K PUW 06:06 07:00 0.90 7,280 8,610 PROD3 DRILL WPRT P While RIH for wiper stacked weight at 7280' at .25 BPM. Shut down pump and ran by to 7350'. PUH at full pump rate. RBIH at .25 BPM and stack weight again. Able to get down with pump down. Continue wiper 07:00 08:18 1.30 8,610 8,760 PROD3 DRILL DRLG P Drilling ahead, 1.36 BPM, 4050 CTP, 4560 BHP, 250 WHP. 1 - 2K WOB, 200 -300 psi motor work 08:18 09:18 1.00 8,760 7,230 PROD3 DRILL WPRT P Wiper to window, 24K PUW 09:18 09:30 0.20 7,230 7,250 PROD3 DRILL DLOG P Tie in at RA, -3.5' 09:30 10:18 0.80 7,250 8,760 PROD3 DRILL WPRT P Wiper back in hole, Shut pump down through build. 10:18 11:30 1.20 8,760 8,902 PROD3 DRILL DRLG P Drilling ahead, 1.36 BPM, 4050 CTP, 4560 BHP, 250 WHP. 1 - 2K WOB, 200 -300 psi motor work 11:30 13:06 1.60 8,902 7,230 PROD3 DRILL WPRT P TD. Pump low/high yjs sweeps. PUH for final tie -in 13:06 13:18 0.20 7,230 7,250 PROD3 DRILL DLOG P Tie in to RA, -1' correction 13:18 15:18 2.00 7,250 8,903 PROD3 DRILL WPRT P Wiper back to TD Page 17 of 26 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:18 16:03 0.75 8,903 7,350 PROD3 DRILL DISP P Tag TD at 8903'. Lay in liner running pill with alpine beads. Lay in KWF. Paint white flag at 7000' EOP and paint yellow flag at 5300' EOP 16:03 17:33 1.50 7,350 0 PROD3 DRILL TRIP P POOH Displacing well to KWF 17:33 18:03 0.50 0 0 PROD3 DRILL OWFF P At surface, perform flow check 18:03 18:33 0.50 0 0 PROD3 DRILL SFTY P Crew change, PJSM 18:33 19:03 0.50 0 0 PROD3 DRILL PULD P LD BHA 12 19:03 19:33 0.50 0 0 COMPZ CASING PUTB P Prep floor to run liner 19:33 19:48 0.25 0 0 COMPZ CASING PUTB P Start running Liner 19:48 20:03 0.25 0 0 COMPZ CASING SFTY P BOP drill, Shut down, talk about drill. 20:03 23:03 3.00 0 0 COMPZ CASING PUTB P Continue running liner 23:03 23:48 0.75 0 0 COMPZ CASING PUTB P MU Coil Track to liner and CT 23:48 00:00 0.20 0 COMPZ CASING RUNL P RIH 06/02/2010 RIH with BL1 -01 liner releasing liner at 8904' BOL, 7200' TOL. PUH tie in depth with -7' correction. Correct liner depths 8897' BOL, 7193' TOL. POOH displacing KWF. PU WS setting on depth 7150' TOWS. POOH displacing KWF. PU milling BHA, RIH, displace well to milling fluid. Start milling window #2 at 7150.5'. 00:00 00:45 0.75 2,000 7,047 COMPZ CASING RUNL P RIH with liner 00:45 01:00 0.25 7,047 7,047 COMPZ CASING RUNL P Correct depth to EOP flag, +34'. Record up and down weights 22K PUW, 15K RIW 01:00 01:30 0.50 7,047 8,904 COMPZ CASING RUNL P RIH, stop at 8904' CTMD. 3.5K WOB 01:30 01:45 0.25 8,904 6,698 COMPZ CASING RUNL P Release off liner 3800psi, 21K PUW, POOH, keeping well dead Remove liner length from CTM D= 1703.73' 01:45 02:00 0.25 6,698 6,691 COMPZ CASING DLOG P Tie in depth with gamma -7'. correction 02:00 03:30 1.50 6,691 0 COMPZ CASING RUNL P POOH Correct depth's to tie in. BOL= 8897', TOL 7193'. 03:30 03:45 0.25 0 0 COMPZ CASING OWFF P At surface. Monitor well for flow, PJSM 03:45 04:45 1.00 0 0 COMPZ CASING PUTB P LD BHA 13 04:45 05:30 0.75 0 0 PROD4 WHPST PULD P PU BHA 14 05:30 07:00 1.50 0 6,700 PROD4 WHPST TRIP P RIH 07:00 07:18 0.30 6,700 6,770 PROD4 WHPST DLOG P Tie in to formation, +28' correction 07:18 07:30 0.20 6,770 6,760 PROD4 WHPST WPST P RIH to 7170', 11K riw, PUH to setting 61) depth at 7159.7', Top of whipstock at � 7150', oriented HS. Pressure up at .5 BPM, set at 3900 CTP, stack down to 4K WOB. 07:30 09:06 1.60 6,760 0 PROD4 WHPST TRIP P POOH Page 18 of 26 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:06 09:24 0.30 0 0 PROD4 WHPST SFTY P PJSM 09:24 10:36 1.20 0 0 PROD4 WHPST PULD P lay down BHA #14, PU BHA # 15. Service injector and check P'offs 10:36 12:24 1.80 0 6,700 PROD4 WHPST TRIP P RIH 12:24 12:42 0.30 6,700 6,760 PROD4 WHPST DLOG P Tie in, +28' 12:42 14:12 1.50 6,760 7,151 PROD4 WHPST DISP P Dry tag WS at 7151', Circulate out KWF 14:12 18:12 4.00 7,151 7,154 PROD4 WHPST MILL P 11K RIW, 24K PUW, 1.35 BPM, 3900 CTP, 4300 BHP, 215 WHP. Start window milling from 7150.5 18:12 20:42 2.50 7,154 7,155 PROD4 WHPST MILL P 350 psi pressure increase. No stall, continue milling. 20:42 21:12 0.50 7,155 7,147 PROD4 WHPST TRIP P WOB and surface weight stacking without motor work, PUH, 21 K PUW, Reset WOB sensor of bottom, RIH 2FPM. Depths =bit to bend wear plate at top of WS 21:12 22:27 1.25 7,154 7,156 PROD4 WHPST MILL P Set auto driller to .5 FPH, off bottom 3950 CTP, 4325 BHP, 215 WHP 22:27 22:57 0.50 7,156 7,156 PROD4 WHPST MILL P Pop by wear band, 170psi motor work increase. Cont. milling .5 FPH 4070 CTP, 7K CTP, 4325 WHP, 1.3 BPM, 22 :57 00:00 1.05 7,156 7,157 PROD4 WHPST MILL P WOB drop to .5K. 4000 CTP, Continue milling .8 FPH 06/03/2010 Complete window #2, TOWS 7151', BOW 7156'. POOH PU 2.3 AKO with hughes bit. Drill build section, landinE at 7510', POOH 00:00 00:15 0.25 7,157 7,162 PROD4 WHPST MILL P Increase ROP to 2 FPM 00:15 02:00 1.75 7,162 7,166 PROD4 WHPST MILL P Increase ROP 4 FPH, 1 -1.5K WOB drilling rat hole 02:00 03:06 1.10 7,166 7,150 PROD4 WHPST TRIP P PUH 1 FPM through window. 7150'. 03:06 03:21 0.25 7,150 7,166 PROD4 WHPST TRIP P RIH drifting window pumps on 03:21 03:36 0.25 7,166 7,150 PROD4 WHPST TRIP P POOH drifting window pumps on. 03:36 04:06 0.50 7,150 7,166 PROD4 WHPST TRIP P RIH drifting window, no pumps X2, Looks good. 04:06 06:00 1.90 7,166 0 PROD4 WHPST TRIP P POOH following MP schedule 06:00 06:30 0.50 0 0 PROD4 WHPST TRIP P Crew change out, walk arounds and start of tour checklists. PJSM 06:30 07:48 1.30 0 0 PROD4 WHPST PULD P Un- deploy milling BHA. 2.80 go / 2.79 no -go on mill and string reamer 07:48 08:18 0.50 0 0 PROD4 DRILL PULD P Adjusting motor to 2.3+ 08:18 09:48 1.50 0 0 PROD4 DRILL PULD P Deploy BHA # 16 for build 09:48 11:12 1.40 0 6,698 PROD4 DRILL TRIP P RIH with open EDC following MPD tripping schedule 11:12 11:24 0.20 6,698 6,740 PROD4 DRILL DLOG P Tie in , + 26' correction. Page 19 of 26 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:24 11:36 0.20 6,740 7,166 PROD4 DRILL TRIP P Continue RIH. 11K RIW Close EDC above window and drift through window HS, clean. 11:36 14:48 3.20 7,166 7,288 PROD4 DRILL DRLG P Drilling ahead, 1.3 BPM, 4100 CTP, 4300 BHP, 150 WHP, 1 - 2K WOB, 150 -300 PSI motor work. Saw RA at 7156' while drilling 14:48 15:00 0.20 7,288 7,288 PROD4 DRILL WPRT P Wiper to window, 21K PUW, started getting gas and crude cut returns, divert to TT 15:00 21:00 6.00 7,288 7,440 PROD4 DRILL DRLG P Drilling ahead, 1.3 BPM, 4100 CTP, 4300 BHP, 250 WHP, 1 - 2K WOB, 150 -300 PSI motor work. Swap Mud. 21:00 21:15 0.25 7,440 7,440 PROD4 DRILL WPRT P Wiper trip to window, 21 K PUW. Some more gas and crude cut mud, sent 38 Bbls to TT, start holding 50 - 75 psi extra on BHP 21:15 22:30 1.25 7,440 7,510 PROD4 DRILL DRLG P Drilling ahead, 1.3 BPM, 4100 CTP, 4450 BHP, 250 WHP, 1 - 2K WOB, 150 -300 PSI motor work. 22:30 00:00 1.50 7,510 0 PROD4 DRILL TRIP P Land build section. POOH 06/04/2010 Undeploy BHA 16, Deploy BHA 17, RIH, Drill BL2 Lateral, 7510'- 8260'. 00:00 01:00 1.00 0 0 PROD4 DRILL TRIP P At surface 01:00 01:15 0.25 0 0 PROD4 DRILL SFTY P PJSM 01:15 02:45 1.50 0 0 PROD4 DRILL PULD P Undeploy BHA 16 02:45 04:30 1.75 0 0 PROD4 DRILL PULD P Deploy BHA 17 04:30 06:12 1.70 0 6,800 PROD4 DRILL TRIP P RIH 06:12 07:12 1.00 6,800 7,200 PROD4 DRILL DLOG P Tie -in, tried to find the K1 marker without success. PUH to 6690. +26' correction. RIH, close EDC and log RA at 7155' 07:12 07:30 0.30 7,200 7,510 PROD4 DRILL TRIP P Continue RIH 07:30 09:30 2.00 7,510 7,660 PROD4 DRILL DRLG P Drill ahead, 4100 CTP, 4430 BHP, 300 WHP, 11K RIW. Starting to get some crude cut mud to the shaker, divert to TT, sent 40 Bbls. to TT. 09:30 10:42 1.20 7,660 7,200 PROD4 DRILL DLOG P MAD pass from 7550 to 7160', 22K PUW 10:42 11:00 0.30 7,200 7,660 PROD4 DRILL WPRT P RBIH, 12K RIW 11:00 12:48 1.80 7,660 7,810 PROD4 DRILL DRLG P Drilling ahead, 1.3 BPM, 4100 CTP, 4490 BHP, 310 WHP, 1 - 2K WOB, 200 -300 Motor work 12:48 13:30 0.70 7,810 7,810 PROD4 DRILL WPRT P Wiper trip to window, 22K PUW, 12K RIW. Clean trip. 13:30 16:12 2.70 7,810 7,960 PROD4 DRILL DRLG P Drilling ahead, 1.3 BPM, 4100 CTP, 4520 BHP, 350 WHP, 1 - 3K WOB, 200 -300 Motor work 16:12 16:42 0.50 7,960 7,175 PROD4 DRILL WPRT P Wiper to window, 22K PUW 16:42 16:54 0.20 7,175 7,195 PROD4 DRILL DLOG P Tie in, -0.5' Page 20 of 26 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:54 17:18 0.40 7,195 7,960 PROD4 DRILL WPRT P Wiper back in hole, 13K RIW 17:18 19:18 2.00 7,960 8,110 PROD4 DRILL DRLG P Drilling ahead, 1.3 BPM, 3950 CTP, 4590 BHP, 200 WHP, 1 - 3K WOB, 200 -300 Motor work 19:18 20:48 1.50 8,110 8,110 PROD4 DRILL WPRT P Wiper trip back to window 20:48 22:48 2.00 8,110 8,260 PROD4 DRILL DRLG P Drilling ahead, 1.3 BPM, 3950 CTP, 4595 BHP, 200 WHP, 1 - 3K WOB, 200 -300 Motor work 22:48 00:00 1.20 8,260 8,260 PROD4 DRILL WPRT P Wiper trip back to window, 23K PUW 06/05/2010 Drill_ BL2 Lateral 8260' - 8880'. Lay in liner running pill, POOH displacing well to KWF. PU /MU Liner. 00:00 02:15 2.25 8,260 8,410 PROD4 DRILL DRLG P Drilling ahead, 1.3 BPM, 4150 CTP on bottom, 3950 of bottom 4590 BHP, 200 WHP, 1 - 3K WOB, 200 -300 Motor work 02:15 03:03 0.80 7,180 7,180 PROD4 DRILL WPRT P Wiper trip to window, 23K PUW 03:03 03:18 0.25 7,180 7,180 PROD4 DRILL DLOG P Correct -3' correction 03:18 04:00 0.70 7,180 8,410 PROD4 DRILL WPRT P RIH 04:00 06:48 2.80 8,410 8,560 PROD4 DRILL DRLG P Drilling ahead, 1.3 BPM, 4175 CTP on bottom, 4000 of bottom 4610 BHP, 200 WHP, 1 - 3K WOB, 200 -300 Motor work 06:48 08:24 1.60 8,560 8,560 PROD4 DRILL WPRT P Wiper to window, 22K PUW, 11K RIW. Clean trip 08:24 10:18 1.90 8,560 8,710 PROD4 DRILL DRLG P Drilling ahead, 1.3 BPM, 4100 CTP, 4630 BHP, 240 WHP, 1 - 3K WOB, 200 -300 Motor work. Losing about 1 Bbl /Hr. 10:18 12:06 1.80 8,710 8,710 PROD4 DRILL WPRT P Wiper to window, 22K PUW, 12K RIW, 12:06 15:06 3.00 8,710 8,880 PROD4 DRILL DRLG P Drilling ahead, 1.3 BPM, 4100 CTP, 4620 BHP, 240 WHP, 1 - 3K WOB, _20Q=306-Mntor Work TD 15:06 16:36 1.50 8,880 7,165 PROD4 DRILL WPRT P Pump 6 low/ 10 high vis sweeps and wiper to window. 20K PUW 16:36 16:48 0.20 7,165 7,185 PROD4 DRILL DLOG P Tie in to RA, -3'. 16:48 17:48 1.00 7,185 8,879 PROD4 DRILL WPRT P Wiper back in hole, 11K RIW 17:48 18:48 1.00 8,879 5,900 PROD4 DRILL DISP P Tag TD at 8879', PUH laying in liner running pill. 23K PUW. Paint flag at 7600 EOP. Lay in KWF from 7400'. 18:48 20:18 1.50 5,971 0 PROD4 DRILL TRIP P Paint EOP flag 5900', Continue POOH 20:18 20:33 0.25 0 0 PROD4 DRILL SFTY P At surface, PJSM, Monitor well for flow 20:33 21:18 0.75 0 0 PROD4 DRILL PULD P LD BHA 17 21:18 22:03 0.75 0 0 COMPZ CASING SVRG P Prep floor to run liner 22:03 22:18 0.25 0 0 COMPZ CASING SFTY P PJSM, running liner 22:18 00:00 1.70 0 0 COMPZ CASING PUTB P Run liner Page 21 of 26 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/06/2010 24 hr summary RIH setting liner on bottom 8880', TOL 7749'. POOH displacing KWF. At surface perform function test on BOP's. PU drilling BHA (1.1 AKO, Hughes bit). RIH displace well to Flo -Pro. Sidetrack BL2 -01 Lateral at 7749'. Drill BL2 -01 Lateral 7749'- 8130'. 00:00 00:30 0.50 0 0 COMPZ CASING PUTB P Continue running liner 00:30 01:45 1.25 0 7,044 COMPZ CASING RUNL P RIH 01:45 02:00 0.25 7,044 7,077 COMPZ CASING DLOG P Tie in depth to EOP flag, Close EDC, Record up and down weights. correct +32', 23K PUW, 02:00 02:15 0.25 7,076 8,886 COMPZ CASING RUNL P Continue RIH, EOP flag on depth 02:15 02:45 0.50 8,886 7,170 COMPZ CASING RUNL P Liner on bottom, pump off liner 02:45 03:15 0.50 7,170 7,170 COMPZ CASING DLOG P Tie in depth to RA marker -4.5' correction Liner Depths: BOL= 8881.5', TOL= 7749.5' 03:15 04:45 1.50 7,170 0 COMPZ CASING RUNL P POOH, circulating KWF 04:45 05:00 0.25 0 0 COMPZ CASING SFTY P At surface, PJSM, Monitor well for flow 05:00 06:00 1.00 0 0 COMPZ CASING PUTB P LD BHA 18 Function test BOP's 06:00 07:18 1.30 0 0 PROD5 STK PULD P PU BHA # 19. 07:18 08:54 1.60 0 6,700 PROD5 STK TRIP P RIH 08:54 09:12 0.30 6,700 6,747 PROD5 STK DLOG P Tie in at RA, +28'. close EDC 09:12 11:12 2.00 6,747 7,030 PROD5 STK DISP P Continue RIH to 7400', circulate out the KWF pulling up above window 11:12 11:42 0.50 7,030 7,749 PROD5 STK TRIP P RIH and dry tag billet at 7748.7' 11:42 14:06 2.40 7,749 7,770 PROD5 STK KOST P Start time milling at 1 FPH for 1' from I 7748.7' (a7 1.3 BPM, 3900 CTP, 4550 I', BHP, 400 WHP, 11K RIW. Increase P)0'6 to 2 FPH for 1'. Increase to 3 FPH for 1', increase to 15FPH 14:06 16:54 2.80 7,770 7,910 PROD5 DRILL DRLG P PU at 22K PUW and ream past billet then drift with pump down. Looks good. Driling ahead, 1.3 BPM, 4000 CTP, 4520 BHP, 390 WHP, 11K RIW, 1 -3K WOB, 200 -300 PSI motor work 16:54 17:54 1.00 7,910 7,910 PROD5 DRILL WPRT P Wiper trip, 22K PUW 17:54 19:06 1.20 7,910 7,991 PROD5 DRILL DRLG P Driling ahead, 1.3 BPM, 4000 CTP, 4520 BHP, 390 WHP, 11K RIW, 1 -3K WOB, 200 -300 PSI motor work 19:06 19:51 0.75 7,991 7,991 PROD5 DRILL WPRT P Goe wiper 22K PUW 19:51 21:06 1.25 7,991 8,055 PROD5 DRILL DRLG P Driling ahead, 1.3 BPM, 4125 CTP, 4520 BHP, 280 WHP, 11K RIW, 1 -3K WOB, 200 -300 PSI motor work 21:06 22:36 1.50 8,055 8,055 PROD5 DRILL WPRT P Wiper trip, 22K PUW 22:36 00:00 1.40 8,055 8,130 PROD5 DRILL DRLG P Driling ahead, 1.3 BPM, 4200 CTP, 4520 BHP, 270 WHP, 11K RIW, 1 -3K WOB, 200 -300 PSI motor work Page 22 of 26 • Time Logs Date From . To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/07/2010 24 hr summary Drill BL2 Lateral 8130'- 8647', Encountering ankerite for slow ROP's 00:00 01:00 1.00 8,130 8,205 PROD5 DRILL DRLG P Driling ahead, 1.3 BPM, 4300 CTP, 4550 BHP, 390 WHP, 11K RIW, 1 -3K WOB, 200 -300 PSI motor work 01:00 01:45 0.75 8,205 8,205 PROD5 DRILL WPRT P Wiper trip, 22K PUW 01:45 01:51 0.10 7,170 7,180 PROD5 DRILL DLOG P Tie in Depth -4' Correction 01:51 02:36 0.75 7,180 8,205 PROD5 DRILL TRIP P RIH 02:36 04:06 1.50 8,205 8,355 PROD5 DRILL DRLG P Driling ahead, 1.3 BPM, 4300 CTP, 4550 BHP, 280 WHP, 11K RIW, 1 -3K WOB, 200 -300 PSI motor work 04:06 06:06 2.00 8,355 8,355 PROD5 DRILL WPRT P Wiper trip back to window, 23K PUW 06:06 16:06 10.00 8,355 8,505 PROD5 DRILL DRLG P Driling ahead, 1.3 BPM, 4100 CTP, 4620 BHP, 350 WHP, 11K RIW, 1 -3K WOB, 200 -300 PSI motor work 16:06 18:06 2.00 8,505 8,505 PROD5 DRILL WPRT P Wiper to window, 21K PUW 18:06 00:00 5.90 8,505 8,647 PROD5 DRILL DRLG P Driling ahead, 1.3 BPM, 4100 CTP, 4620 BHP, 350 WHP, 11K RIW, 1 -3K WOB, 200 -300 PSI motor work 06/08/2010 , 0 1 TD BL2 Lateral @ 8955, Lay in liner pill & KWF. Start Skate repairs 00:00 02:00 2.00 8,647 8,655 PROD5 DRILL DRLG P Driling ahead, 1.3 BPM, 4100 CTP, 4620 BHP, 350 WHP, 11K RIW, 1 -3K WOB, 200 -300 PSI motor work 02:00 03:00 1.00 8,655 7,170 PROD5 DRILL WPRT P Wiper Trip to window, 22K PUW 03:00 03:15 0.25 7,170 7,170 PROD5 DRILL DLOG P Tie into RA marker, -4.5' correction 03:15 04:00 0.75 7,170 8,655 PROD5 DRILL WPRT P RIH 04:00 10:00 6.00 8,655 8,805 PROD5 DRILL DRLG P Driling ahead, 1.3 BPM, 4100 CTP, • 4620 BHP, 350 WHP, 11K RIW, 1 -3K WOB, 200 -300 PSI motor work 10:00 11:00 1.00 8,805 7,035 PROD5 DRILL WPRT P Wiper to window, 22K PUW 11:00 11:12 0.20 7,035 7,055 PROD5 DRILL DLOG P Tie in, zero correction 11:12 12:00 0.80 7,055 8,805 PROD5 DRILL WPRT - P Continue wiper in hole, 13K RIW 12:00 14:12 2.20 8,805 8,955 PROD5 DRILL DRLG P Driling ahead, 1.3 BPM, 4200 CTP, 4640 BHP, 250 WHP, 11K RIW, 1 -3K WOB, 200 -300 PSI motor work �A 14:12 16:00 1.80 8,955 7,175 PROD5 DRILL WPRT P TD well, recip to get low /high vis sweeps around then wiper to window 16:00 16:18 0.30 7,175 7,195 PROD5 DRILL DLOG P Tie in, -1' 16:18 17:00 0.70 7,195 8,955 PROD5 DRILL WPRT P RBIH, tag TD at 8955' 17:00 19:45 2.75 8,955 0 PROD5 DRILL TRIP P POOH, laying in liner running pill, Paint 6800, 5000' EOP Flag Stop and check injector, Making noises. Stop and check reel 19:45 21:00 1.25 0 0 PROD5 DRILL PULD P At surface, PJSM while performing No -Flo test Good test, Lay down BHA #19. Bearing rollers and Race pieces in sump Page 23 of 26 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 23:00 2.00 0 0 PROD5 DRILL RGRP T Circulate KWF out of coil. Unstab and remove UQC. Seal end of E -Line. Blow back coil with 350PSI Air compressor Bleed off air, Unstab. ** *Nabors Downtime Starts * ** 23:00 00:00 1.00 0 0 PROD5 DRILL RGRP T PJSM, Rig up to unstab coil from Injector 06/09/2010 Complete Injector repairs, Perform slack Mgmt. Start BL2 -01 Liner pick up 00:00 16:00 16.00 0 0 PROD5 DRILL RGRP T Nabors Downtime. Continue to prep for skate removal: unstab coil, lay down stripper, Break chains, remove skates, install skates, MU Chains, Check chains and gripper blocks, MU stripper, Stab coil, Cut off grapple. * ** Nabors Downtime ends * ** 3 Hours for the 8th, 16 Hours for the 9th. 16:00 18:00 2.00 0 0 COMPZ CASING SLPC P Seal end of E -line, stab onto well and pump slack, cut off 50' to find wire 18:00 21:00 3.00 0 0 COMPZ CASING CTOP P PJSM, Dress coil and install CTC, Pull test to 35K Test E -Line, Make up Upper quick connect Run Valve checklist, Fill coil and PT connector to 4K 21:00 22:45 1.75 0 0 COMPZ CASING CTOP P Replace Packoffs, Roll coil to KWF. PT lubricator and packoff to 4K. Open swabs, Fill hole monitor for flow 22:45 00:00 1.25 0 0 COMPZ CASING PUTB P PJSM, Make up BL2 -01 Liner Perform safety joint drill 06/10/2010 Make up Liner / RIH, Unable to get past 7420, POOH, P/U Mill, unable to get to past 7406. POOH Revise BHA 00:00 02:42 2.70 0 2,036 COMPZ CASING PUTB P Continue to Make up BL2 -01 Liner Make up coil track to liner, Surface test, Open EDC 02:42 04:12 1.50 2,036 6,955 COMPZ CASING RUNL P Trip in with Liner 04:12 04:24 0.20 6,955 7,419 COMPZ CASING RUNL P 6955, Correct to EOP Flag +31' (last liner correction +32) PUW =24k, Continue in well, RIW =16K 04:24 06:18 1.90 7,419 7,419 COMPZ CASING RUNL T Unable to work past 7419'. Tried different speeds and different operators with no luck. 06:18 07:48 1.50 7,419 0 COMPZ CASING RUNL T POOH, KWF down backside. Page 24 of 26 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:48 12:24 4.60 0 0 COMPZ CASING PUTB T Lay down liner running BHA. RU and lay down liner string. Shoe had hard packed salt on the nose. It tumed and moved up and down normally. RD liner running equipment 12:24 12:36 0.20 0 0 COMPZ CASING SFTY T PJSM 12:36 13:18 0.70 0 0 COMPZ CASING PULD T PU cleanout BHA, 1.1 Deg. motor and used bicenter bit. 13:18 15:06 1.80 0 6,670 COMPZ CASING TRIP T RIH circulating KWF at .3 BPM 15:06 15:18 0.20 6,670 6,700 COMPZ CASING DLOG T Tie in, +24' 15:18 16:18 1.00 6,700 7,400 COMPZ CASING TRIP T Continue RIH, Displace KWF from 7400' 16:18 17:33 1.25 7,400 7,408 COMPZ CASING TRIP T RIH and bring rate up. Tag and stall at 7408'. PU clean, RIH at .3 BPM and tag in same place. Try at .8 BPM and RIH at 30 FPM, tag same. 17:33 19:33 2.00 7,408 0 COMPZ CASING TRIP T POOH to revise BHA 19:33 21:03 1.50 0 0 COMPZ CASING PULD T PJSM, Undeploy BHA # 21 21:03 21:48 0.75 0 0 COMPZ CASING PULD T Reset motor AKO, service FVS. Load PDL 21:48 23:18 1.50 0 0 COMPZ CASING PULD T PJSM, Deploy BHA #22, Surface test tool, Strip on and bump up 23:18 00:00 0.70 0 1,875 COMPZ CASING TRIP T RIH with BHA #22. 2.3 degree motor and 2.74 Mill 06/11/2010 Cleanout wellbore to TD, Run liner to TD BOL =8957 TOL =6965 00:00 01:00 1.00 1,875 6,680 COMPZ CASING TRIP T Continue in well 01:00 01:06 0.10 6,680 6,737 COMPZ CASING DLOG T 6680, Log tie in for +23' correction 01:06 01:48 0.70 6,737 7,408 COMPZ CASING TRIP T Continue in well. Started 10 BBI KCL +Claystop pill down coil after passing window. Tagged up @ 7408 PUH and wait for pill to get to mill 01:48 02:00 0.20 7,408 7,510 COMPZ CASING MILL T Mill at 7402 pill at mill. RIH @ 3fpm 1.30BPM@ 3908 PSI Free spin 7415 to 5 FPM, 7425 to 10 FPM to 7510 Bottom of build 02:00 04:15 2.25 7,510 0 COMPZ CASING TRIP T Clean trip to 7510, POOH following MP Schedule. Stop and open EDC 04:15 06:00 1.75 0 0 COMPZ CASING PULD T PJSM, Undeploy BHA #22 06:00 06:24 0.40 0 0 COMPZ CASING SFTY T PJSM, crew change 06:24 07:54 1.50 0 0 COMPZ CASING PULD T Deploy BHA # 23 07:54 09:24 1.50 0 6,880 COMPZ CASING TRIP T RIH following MPD tripping schedule 09:24 09:36 0.20 6,880 6,738 COMPZ CASING DLOG T Tie in, +23' correction. Close EDC 09:36 11:06 1.50 6,738 8,955 COMPZ CASING TRIP T Continue RIH 11:06 12:06 1.00 8,955 7,400 COMPZ CASING DISP T Tag bottom at 8955'. Lay in liner running pill 12:06 14:06 2.00 7,400 0 COMPZ CASING DISP T Lay in KWF, Flag pipe at 6800' EOP and 5000' EOP Page 25 of 26 • • Time Logs Date From _ To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:06 15:06 1.00 0 0 COMPZ CASING PULD T Lay down cleanout BHA 15:06 15:24 0.30 0 0 COMPZ CASING SFTY T PJSM for liner ops 15:24 19:00 3.60 0 0 COMPZ CASING PUTB T Run liner 19:00 20:30 1.50 0 7,006 COMPZ CASING RUNL T RIH with Liner 20:30 21:30 1.00 7,006 8,962 COMPZ CASING RUNL T Correct @ Flag +30.5' correction PUW =23K 21:30 21:36 0.10 8,962 8,945 COMPZ CASING RUNL T 8969, Set down with liner. P/U and confirm bottom, Neutral weight depth 8962. Pump off liner 1 BPM @ 4620, PUW 23K 21:36 22:24 0.80 8,945 8,945 COMPZ CASING CIRC P Circulate Spacer then seawater down coil 22:24 22:42 0.30 8,945 6,670 COMPZ CASING DLOG P Pull up hole to Tie In, Reset depth to . remove liner length, Log GR Tie in for -6' correction BOL =8957, TOL =6965' Corrected 22:42 00:00 1.30 6,670 3,480 COMPZ CASING RUNL P POOH. Load coil with Diesel 06/12/2010 Swap well to SW and FP from 2500' with diesel. RDMO 00:00 01:00 1.00 3,480 0 COMPZ CASING RUNL P continue out of well 01:00 03:00 2.00 0 0 COMPZ CASING PUTB P PJSM, At surface, Pressure undeploy BHA #24 Blow down tools and lay down Final SITP =1650 IA =37, OA =150 03:00 04:15 1.25 0 0 DEMOB WHDBO NUND P PJSM, Get FMC equipment to rig floor to set BPV 04:15 05:00 0.75 0 0 DEMOB WHDBO NUND P PT Lubricator to 3K, RI with BPV 05:00 06:12 1.20 0 0 DEMOB WHDBO NUND P Stab back on well to flush rig 06:12 08:06 1.90 0 0 DEMOB WHDBO NUND P Start blowing down rig 08:06 10:00 1.90 0 0 DEMOB WHDBO NUND P ND BOP stack and RD ops. Release rig at 10:00, start rig move charges on 1 R -06. Exception rig move. Page 26 of 26 ConochiIIips Alaska • ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3K Pad 3K -09B 50- 029 - 21656 -02 Baker Hughes INTEQ • Definitive Survey Report BAKER p HUGHES 22 June, 2010 ConocoPhillips CCt11t CC P�"i1 Ip5 Definitive Survey Report HUGHES Alaska Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 3 K - 09 Project: Kuparuk River Unit TVD Reference: 3K -09 @ 69.00ft (3K -09) Site: Kuparuk 3K Pad MD Reference: 3K -09 @ 69.00ft (3K -09) Well: 3K - 09 North Reference: TRUE 1 Welibore: 3K - 09 Survey Calculation Method: Minimum Curvature 1 Design: 3K -09 Database: EDM Alaska Prod v16 1 Project Kuparuk River Unit Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point 1 Map Zone: Alaska Zone 04 Using geodetic scale factor • — Well 3K- 09 Well Position +N /S 0.00 ft Northing: 6,008,228.65ft Latitude: 70° 26' 0.812 N +E / - 0.00 ft Easting: 529,305.92ft Longitude: 149° 45' 39.960 W Position Uncertainty 0_00 ft Wellhead Elevation: ft Ground Level: 0.00 ft Welibore 3K - 09B Magnetics Model Name Sample Date Declination Dip Angle Field Strength ( ( (nT) BGGM2009 7/15/2010 17.14 79.87 57,394 { Design 3K - 096 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,200.00 Vertical Section: Depth From (TVD) +N /-S +E/ -W Direction • (ft) (ft) (ft) ( 69.00 0.00 0.00 54.40 Survey Program Date From To Survey Survey (ft) (ft) Survey (Welibore) Tool Name Description Start Date End Date 100.00 7,200.00 3K -09A GyroData (3K -09A) GYD -CT -CMS Gyrodata cont.casing m/s 3/9/2009 7,230.27 9,570.23 3K -09B (3K -09B) MWD MWD - Standard 5/21/2010 5/25/2010 6/22/2010 8:14 :22AM Page 2 COMPASS 2003.16 Build 69 1 °»- ConocoPhillips H' ConocoPhillips Definitive Survey Report BAKER Alaska i Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 3K - 09 I Project: Kuparuk River Unit TVD Reference: 3K -09 © 69.00ft (3K -09) i Site: Kuparuk 3K Pad MD Reference: 3K -09 @ 69.00ft (3K -09) I Well: 3K - 09 North Reference: TRUE Wellbore: 3K - 09 Survey Calculation Method: Minimum Curvature I Design: 3K - 09 Database: EDM Alaska Prod v16 Survey g Vertical Section io MD Inc Az! TVD TVDSS +N/-S +E/-W Northing East n DLS Survey Tool Name Annotation (ft) ( °) ( °) (ft) (ft) (ft) (ft) (ft) (ft) C/100') (ft) • 7,200.00 31.59 90.32 6,656.12 6,587.12 32.93 1,940.66 6,008,269.20 531,246.24 0.78 1,597.03 GYD -CT -CMS (1) TIP 3K - 09A 7,230.27 39.26 85.70 6,680.77 6,611.77 33.61 1,958.17 6,008,269.94 531,263.75 26.82 1,611.66 MWD (2) Interpolated AZI 7,260.29 53.36 79.00 6,701.47 6,632.47 36.63 1,979.59 6,008,273.06 531,285.15 49.61 1,630.83 MWD (2) Interpolated AZI 7,292.83 63.04 67.52 6,718.63 6,649.63 44.71 2,005.93 6,008,281.23 531,311.46 42.17 1,656.95 MWD (2) 7,320.46 70.87 56.22 6,729.47 6,660.47 56.72 2,028.25 6,008,293.34 531,333.73 47.07 1,682.09 MWD (2) 7,350.46 80.04 49.06 6,737.01 6,668.01 74.34 2,051.27 6,008,311.04 531,356.67 38.30 1,711.06 MWD (2) 7,380.76 92.49 46.43 6,738.98 6,669.98 94.64 2,073.60 6,008,331.42 531,378.92 41.99 1,741.03 MWD (2) 7,410.67 95.01 43.80 6,737.02 6,668.02 115.70 2,094.74 6,008,352.56 531,399.98 12.16 1,770.48 MWD (2) 7,442.09 96.61 41.66 6,733.84 6,664.84 138.65 2,115.95 6,008,375.60 531,421.10 8.48 1,801.10 MWD (2) 7,473.06 95.25 39.56 6,730.64 6,661.64 162.04 2,136.00 6,008,399.06 531,441.05 8.05 1,831.01 MWD (2) 7,500.29 93.35 37.76 6,728.60 6,659.60 183.24 2,152.96 6,008,420.33 531,457.93 9.60 1,857.14 MWD (2) 7,530.42 93.62 35.41 6,726.77 6,657.77 207.39 2,170.88 6,008,444.54 531,475.75 7.84 1,885.77 MWD (2) 7,560.30 93.90 33.50 6,724.81 6,655.81 231.97 2,187.75 6,008,469.19 531,492.52 6.45 1,913.80 MWD (2) 7,590.33 93.41 30.15 6,722.89 6,653.89 257.43 2,203.55 6,008,494.71 531,508.22 11.25 1,941.47 MWD (2) 7,620.34 91.87 31.54 6,721.51 6,652.51 283.17 2,218.92 6,008,520.50 531,523.49 6.91 1,968.95 MWD (2) 7,655.29 89.69 33.11 6,721.03 6,652.03 312.69 2,237.60 6,008,550.10 531,542.06 7.69 2,001.33 MWD (2) 7,680.36 88.56 35.51 6,721.42 6,652.42 333.40 2,251.73 6,008,570.86 531,556.10 10.58 2,024.67 MWD (2) • 7,710.43 87.54 38.24 6,722.44 6,653.44 357.44 2,269.76 6,008,594.96 531,574.04 9.69 2,053.53 MWD (2) 7,740.39 88.19 41.11 6,723.56 6,654.56 380.48 2,288.88 6,008,618.08 531,593.06 9.82 2,082.48 MWD (2) 7,770.23 89.20 43.86 6,724.24 6,655.24 402.47 2,309.02 6,008,640.15 531,613.12 9.82 2,111.67 MWD (2) 7,800.16 88.68 46.70 6,724.79 6,655.79 423.53 2,330.28 6,008,661.29 531,634.29 9.64 2,141.21 MWD (2) 7,830.39 88.90 49.16 6,725.43 6,656.43 443.78 2,352.72 6,008,681.62 531,656.64 8.17 2,171.24 MWD (2) 7,860.44 86.04 51.53 6,726.23 6,657.23 462.95 2,375.84 6,008,700.88 531,679.69 8.39 2,201.20 MWD (2) 7,890.40 87.54 53.77 6,727.39 6,658.39 481.11 2,399.64 6,008,719.13 531,703.41 7.66 2,231.13 MWD (2) { 7,920.36 88.28 58.04 6,728.48 6,659.48 497.89 2,424.43 6,008,736.01 531,728.13 14.46 2,261.05 MWD (2) 7,950.52 89.97 60.60 6,728.94 6,659.94 513.27 2,450.36 6,008,751.49 531,754.00 10.17 2,291.09 MWD (2) 7,980.49 91.69 61.77 6,728.51 6,659.51 527.72 2,476.62 6,008,766.04 531,780.20 6.94 2,320.84 MWD (2) 8,010.51 90.92 59.71 6,727.82 6,658.82 542.38 2,502.80 6,008,780.81 531,806.32 7.32 2,350.67 MWD (2) 8,040.46 89.88 56.94 6,727.61 6,658.61 558.11 2,528.28 6,008,796.63 531,831.74 9.88 2,380.55 MWD (2) ! 8,070.63 90.09 54.48 6,727.62 6,658.62 575.10 2,553.21 6,008,813.72 531,856.59 8.18 2,410.71 MWD (2) 6/22/2010 8:14:22AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips ConocoPhillips Definitive Survey Report S AES Alaska Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 3K -09 Project: Kuparuk River Unit TVD Reference: 3K -09 @ 69.00ft (3K -09) I Site: Kuparuk 3K Pad MD Reference: 3K -09 @ 69.00ft (3K -09) i Well: 3K -09 North Reference: TRUE Welibore: 3K -09 Survey Calculation Method: Minimum Curvature Design: 3K -09 Database: EDM Alaska Prod v16 I S .. , Survey r MD Inc AzI TVD TVDSS +14/-S LW +E Northing Easting DLS Section Survey Tool Name Annotation • I (ft) ( °) (1 (ft) (ft) (ft) (ft) (ft) (ft) mow) (ft) 8,100.44 91.23 52.14 6,727.28 6,658.28 592.91 2,577.11 6,008,831.62 531,880.42 8.73 2,440.51 MWD (2) 8,130.04 91.07 50.02 6,726.68 6,657.68 611.50 2,600.13 6,008,850.30 531,903.37 7.18 2,470.05 MWD (2) 8,160.01 91.99 47.05 6,725.88 6,656.88 631.34 2,622.58 6,008,870.22 531,925.74 10.37 2,499.85 MWD (2) 8,190.27 94.92 46.94 6,724.06 6,655.06 651.94 2,644.66 6,008,890.91 531,947.74 9.69 2,529.80 MWD (2) 8,220.32 98.44 45.73 6,720.56 6,651.56 672.54 2,666.25 6,008,911.59 531,969.25 12.38 2,559.35 MWD (2) 8,250.22 100.87 43.89 6,715.55 6,646.55 693.45 2,687.02 6,008,932.58 531,989.93 10.14 2,588.41 MWD (2) 8,280.33 101.84 40.32 6,709.62 6,640.62 715.35 2,706.81 6,008,954.55 532,009.64 12.06 2,617.25 MWD (2) 8,310.24 102.31 37.62 6,703.36 6,634.36 738.08 2,725.21 6,008,977.36 532,027.94 8.97 2,645.44 MWD (2) 8,340.35 102.94 35.33 6,696.78 6,627.78 761.71 2,742.67 6,009,001.05 532,045.31 7.71 2,673.39 MWD (2) 8,370.28 103.44 32.83 6,689.95 6,620.95 785.84 2,759.00 6,009,025.24 532,061.54 8.30 2,700.72 MWD (2) 8,400.32 103.66 30.65 6,682.91 6,613.91 810.67 2,774.36 6,009,050.14 532,076.80 7.09 2,727.67 MWD (2) 8,430.40 103.56 29.05 6,675.83 6,606.83 836.03 2,788.91 6,009,075.55 532,091.25 5.18 2,754.26 MWD (2) 8,460.67 102.41 26.24 6,669.03 6,600.03 862.16 2,802.60 6,009,101.72 532,104.83 9.81 2,780.59 MWD (2) 8,490.28 99.47 24.27 6,663.41 6,594.41 888.45 2,815.00 6,009,128.06 532,117.13 11.88 2,805.98 MWD (2) 8,520.24 96.83 22.21 6,659.16 6,590.16 915.69 2,826.70 6,009,155.35 532,128.72 11.13 2,831.36 MWD (2) 8,550.29 95.75 20.08 6,655.87 6,586.87 943.55 2,837.47 6,009,183.25 532,139.38 7.91 2,856.33 MWD (2) 8,580.49 94.43 19.04 6,653.19 6,584.19 971.89 2,847.54 6,009,211.63 532,149.34 5.56 2,881.02 MWD (2) • 8,610.49 91.96 17.51 6,651.52 6,582.52 1,000.33 2,856.93 6,009,240.10 532,158.62 9.68 2,905.22 MWD (2) 8,640.43 93.90 15.06 6,649.99 6,580.99 1,029.03 2,865.31 6,009,268.83 532,166.89 10.43 2,928.74 MWD (2) 8,670.51 95.93 13.40 6,647.41 6,578.41 1,058.08 2,872.68 6,009,297.90 532,174.14 8.70 2,951.64 MWD (2) 8,700.64 94.40 11.69 6,644.70 6,575.70 1,087.37 2,879.20 6,009,327.21 532,180.54 7.60 2,973.99 MWD (2) 8,730.35 91.14 9.00 6,643.26 6,574.26 1,116.55 2,884.53 6,009,356.42 532,185.75 14.22 2,995.31 MWD (2) 8,760.38 90.15 6.35 6,642.92 6,573.92 1,146.31 2,888.54 6,009,386.19 532,189.64 9.42 3,015.90 MWD (2) 8,790.30 87.76 5.60 6,643.47 6,574.47 1,176.06 2,891.65 6,009,415.94 532,192.64 8.37 3,035.75 MWD (2) 8,820.42 85.33 3.45 6,645.28 6,576.29 1,206.03 2,894.02 6,009,445.92 532,194.89 10.76 3,055.13 MWD (2) I 8,850.36 85.02 1.84 6,647.80 6,578.80 1,235.83 2,895.40 6,009,475.72 532,196.15 5.46 3,073.60 MWD (2) 8,880.30 82.70 0.90 6,651.01 6,582.01 1,265.59 2,896.11 6,009,505.48 532,196.75 8.35 3,091.50 MWD (2) 8,910.23 81.50 358.44 6,655.12 6,586.12 1,295.23 2,895.94 6,009,535.12 532,196.46 9.07 3,108.62 MWD (2) 8,942.24 81.39 354.41 6,659.88 6,590.88 1,326.81 2,893.97 6,009,566.69 532,194.37 12.45 3,125.40 MWD (2) 8,970.31 81.32 350.69 6,664.10 6,595.10 1,354.33 2,890.37 6,009,594.19 532,190.66 13.10 3,138.50 MWD (2) 9,000.35 84.16 349.57 6,667.90 6,598.90 1,383.68 2,885.26 6,009,623.52 532,185.44 10.15 3,151.43 MWD (2) 6/22/2010 8 :14 :22AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips VAS ConocoPhillips Definitive Survey Report KE HUGHES Alaska Company: ConocoPhillips(Alaska) Inc. � Local Co- ordinate Reference: 3K - 09 ___u Project: Kuparuk River Unit TVD Reference: 3K -09 © 69.00ft (3K -09) Site: Kuparuk 3K Pad MD Reference: 3K -09 @ 69.00ft (3K -09) I Well: 3K - 09 North Reference: TRUE i Wellbore: 3K - 09 Survey Calculation Method: Minimum Curvature 1 Design: 3K - 09 Database: EDM Alaska Prod v16 Survey Man r- Vertical MD Inc Azi TVD TVDSS +N/-S +EI -W Northing East ng DLS Section Survey Tool Name Annotation (ft) ( °) (*) (ft) (ft) (ft) (ft) (ft) (ft) r/100.) (ft) • 9,030.40 86.77 348.54 6,670.28 6,601.28 1,413.09 2,879.57 6,009,652.90 532,179.64 9.33 3,163.93 MWD (2) 9,060.36 88.16 346.31 6,671.60 6,602.60 1,442.30 2,873.06 6,009,682.08 532,173.01 8.76 3,175.64 MWD (2) 9,090.34 87.27 344.48 6,672.80 6,603.80 1,471.29 2,865.50 6,009,711.04 532,165.34 6.78 3,186.37 MWD (2) 9,120.24 86.68 341.84 6,674.37 6,605.38 1,499.86 2,856.86 6,009,739.57 532,156.58 9.04 3,195.98 MWD (2) r 9,150.32 85.42 339.83 6,676.45 6,607.45 1,528.20 2,847.01 6,009,767.88 532,146.62 7.87 3,204.47 MWD (2) 9,180.21 88.47 337.92 6,678.04 6,609.04 1,556.04 2,836.25 6,009,795.67 532,135.75 12.03 3,211.93 MWD (2) 9,210.22 91.38 337.29 6,678.08 6,609.08 1,583.78 2,824.82 6,009,823.36 532,124.21 9.92 3,218.79 MWD (2) 9,240.32 94.82 337.38 6,676.45 6,607.45 1,611.52 2,813.24 6,009,851.04 532,112.53 11.43 3,225.52 MWD (2) 9,270.89 98.22 338.18 6,672.98 6,603.98 1,639.63 2,801.75 6,009,879.11 532,100.93 11.42 3,232.55 MWD (2) 9,300.25 97.97 340.74 6,668.85 6,599.85 1,666.84 2,791.55 6,009,906.28 532,090.63 8.67 3,240.10 MWD (2) 9,330.20 97.11 343.23 6,664.92 6,595.92 1,695.08 2,782.37 6,009,934.48 532,081.34 8.73 3,249.07 MWD (2) 9,360.17 97.69 346.94 6,661.05 6,592.05 1,723.79 2,774.73 6,009,963.16 532,073.58 12.43 3,259.57 MWD (2) 9,390.40 95.96 349.62 6,657.46 6,588.46 1,753.18 2,768.63 6,009,992.52 532,067.37 10.50 3,271.72 MWD (2) 9,420.75 96.77 352.74 6,654.10 6,585.10 1,782.98 2,764.01 6,010,022.30 532,062.63 10.56 3,285.31 MWD (2) } 9,450.37 96.70 355.66 6,650.62 6,581.62 1,812.24 2,761.03 6,010,051.54 532,059.54 9.79 3,299.93 MWD (2) 9,480.23 94.76 357.28 6,647.64 6,578.64 1,841.89 2,759.20 6,010,081.19 532,057.59 8.45 3,315.71 MWD (2) 9,510.29 91.87 356.27 6,645.90 6,576.90 1,871.85 2,757.52 6,010,111.14 532,055.79 10.18 3,331.78 MWD (2) 9,540.33 89.02 355.95 6,645.67 6,576.67 1,901.82 2,755.48 6,010,141.09 532,053.63 9.55 3,347.57 MWD (2) 9,570.23 88.13 358.65 6,646.41 6,577.41 1,931.67 2,754.07 6,010,170.94 532,052.11 9.51 3,363.81 MWD (2) 9,610.00 88.13 358.65 6,647.71 6,578.71 1,971.41 2,753.13 6,010,210.67 532,051.02 0.00 3,386.18 PROJECTED to TD • 6/22/2010 8:14:22AM Page 5 COMPASS 2003.16 Build 69 PT 2 0 - L i Z _ - JK - U5'tiL1 purveys Well Plan 9 `-- Parent Well :i1. -U9A COnocoP'11l11 s Well 3IL -O9BL1 J 1easlu ed Depth P1.0 3K -09B Surveys —Top A6 --Top A3 Stl'lictlll'A1 Cross- Illtelptet ati —Top A2 Base A2 pay Top Mi}uveach P.L4 is 6525 r..n L _ L _ 1 _ J _ r..u _4111q r..II ca r..0 sr L ' J Saimaa , _1 1 1 1 I , , .... 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"T_i= Ale aslued I)epth / • 3K- 09BL1: KOP @ 8059' Intersected shale • • ConocoPhillips Alaska RECIPIENTS No other distribution is allowed without OH FINAL OH FINAL written approval from ConocoPhillips Image files and/or Digital Data contact: Lisa Wright, 907 263 -4823 hardcopy prints ConocoPhillips Alaska, Inc. 1 Hardcopy Print NSK Wells Aide, NSK 69 ATTN: MAIL ROOM 700 G Street, Anchorage, AK 99501 AOGCC 1 Hardcopy Print, Christine Mahnken 1 Graphic image file 1 Disk * / 333 West 7th Ave, Suite 100 in lieu of sepia ** Electronic Anchorage, Alaska 99501 CGM / TIFF LIS BP 1 Hardcopy Print, Petrotechnical Data Center, MB33 1 Graphic image file 1 Disk * / David Douglas in lieu of sepia ** Electronic P.O. Box 196612 CGM / TIFF LIS Anchorage, Alaska 99519 -6612 CHEVRON /KRU REP 1 Hardcopy Print, Glenn Fredrick 1 Graphic image file 1 Disk * / P.O.Box 196247 in lieu of sepia ** Electronic Anchorage, Alaska 99519 CGM / TIFF LIS Brandon Tucker, NRT State of Alaska; DNR, Div. of Oil and Gas 1 Disk * / 550 W. 7th Ave, Suite 800 Electronic Anchorage, Alaska 99501 -3510 LIS RECENED ? 2 7 201 *Mb masa& bye / 9 <3 04" nch bags jjo - 0/0 - 613 /490-5 ato -oG 5 /996C, 310 - 49 0/ 0 —b C(5 . . Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, May 31, 2010 10:27 PM D 210-64-12- To: Ohlinger, James J f rD Cc: Nabors CDR2 Company Man Subject: RE: 3K- 09BL1 -01 James, Just got home. Had a good weekend in Seward. I will catch up with you in the morning (Tuesday) . You of course have verbal approval to proceed as we discussed earlier. Guy Original Message From: Ohlinger, James J [mailto: James .J.Ohlinger @conocophillips.com] Sent: Sun 5/30/2010 10:14 AM To: Schwartz, Guy L (DOA) Cc: Nabors CDR2 Company Man Subject: 3K- 09BL1 -01 Mr. Schwartz - thank you for calling me back last night on Memorial weekend. As we discussed we have verbal approval to continue drilling for the 3K- 09BL1 -01 sidetrack. 3K- 09BL1 -01 Details: We'll be kicking off an aluminum liner top billet from 3K -09BL1 at 7850' MD. Drilling northeast into the A2 sand interval to a TD of 9345' MD. Attached are some simple schematics showing the trajectory and proposed completion. Currently we are running liner for the 3K -09BL1 and will conduct our BOP test afterwards before commencing drilling again. The Nabors CDR2 -AC Company men will be forwarding this email and information to your Slope Inspectors. Please contact me if you have any questions, and I'll be following up with the proper paperwork Tuesday, June 1st. 1 3K -09B + Proposed CTD Sidetrack f,-r,D .Ato - o,(Z 3-1/2" TRMAXX5E SCSSV @ 2,183' MD ID = 2.812" , 311 ZOt o 3 -1/2" 9.3# L -80 EUE 8rd Tubing to surface ID = 2.992" 16" 62# H-40 shoe @ 110 MD 3-1/2" Cameo MMG gas lift mandrels @ 2396' 3533' 9-5/8" 36# J -55 shoe @ 3172' MD 4607' • 5586' 6307 6839' 7 S __.. _ _ 3-1/2" X Nipple @ 6888' MD (2.813" profile) Packer to I Pads for Cement Tubing Tail = 104' ill — 4-- ----- 7033' - 7035' Baker PBR @ 6922' MD (4" ID) Baker KBH -22 Anchor Seal Assembly @ 6935' MD (3.0" Tubing Tail to ID) Top of Whipstock = 100 Baker SAB3 Packer @ 6936' MD (4.0" ID) \\\ • , • 2-5/8" Openhole anchor/whipstock @ 7150' ��\ South Laterals KOP - 7700' 3K- 09BL2 -01: 9075' WP03 2 -5/8" Openhole anchor /whipstock @ 7200' 7250' - Bottom of Pilot Hole ' -- I3K 09BL2: 9075' WP06 A3 - sand pads North Laterals I \ ._ _ 7279' - 729T MD KOP - 8059' M , -- I I A2 - sand parts —...m 7310' - 7326' MD - - - == �� 7333' 7339' _ ®� `` ► 3K 09BL1: 10,050' WP07 7344' . _ _ \ ` � 7348' - 7352' — �� 1 7359' - 7363' %% , _ ,I 3K -098: 9975' WP06 7" 26# J -55 shoe @ 7559' MD • ' � KOP - 7850' 3K- 09BL1 -01: 9345' WP07 The dark blue line represents the proposed sidetrack COMMI11111111111, lot xi I ' secturn ,. IF ( a ID. ' ifl Jo .0 L r. 0 * ig SeS -Pa H Iti . / a IL q . ) ... 31 (31C. OSOR Glso :Il-093L2_,1107 OK.09 {Oa L2) 240 0 7 - - 400- S 22.0_ i 2000: 3K43S. SLI Suit 3 1 .. 6600- --I-- - 1 --4 - -------4-----1-- • 1800 6800- I-. 1600: ' ei ; , 14 0 0 7 01K • • BL2 5 1000 1200 1400 1600 1800 2000 2200 2400 0 , Vertical Section at 14.50° [ft] ' 7' 1200— •0 _ „---, _Inii z ■,.:::,...... , loao- VET 311.11- 0 1° El I I I I N Om : 2 L.09BL2 _wp0•7 PIC .09 .00 SU) _ 800— \ - 1102217AEM 1 „ i .7,___ \ .,. • 600— FIR11 PATE IL419SL I 0 0 A \ -. / ' \ / I/ co ■ / 1 ,.,, / j r....) • 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 L ./ We st(-)/East(+) [ ft ] 8000 8200 8400 8600 8800 9000 9200 9400 9600 9800 l0000 Measured Depth [ft] dimmisimear-- - - 3K -09BL 1 Surreys Well Plan 9 .... -Parent Well 3K -09A ConocoPhilli s Well 3K -09BL1 Measured Depth Pi 3K -09B Surreys Tap A6 —Tap A3 Structural Cross - Section Intei'hreta —Top A2 Base A2 pay Tap Miluveach Polygon -6525 __ _ T_ • • -- . • • - ,- • • • • • • . 1 �SOTLt�L 1 __ I __ T l ____ _ _ _ _ r i F.9.9 I T • - � f- Fault •E' F..1! •F' Fowl* !2 :C: Ti _�__ -. _ _r- _l -I North • -_ J J_J__ _ - _� __ L_J. J.. L _ J _�_. _r L "DT" J - ___ Northeast F..Ik •D• - � _;_J - ___ - L _I -L.1. _J__t_L_ _J -_ _ J _ 1 III III 1 1 1 1 r 1 ■ i 1 17' DIN 1 5' DTN i' DM �3' 075 1 1 1 1 1 1 1 1 1 . _L_ _...L_ _J____ 1 1 1 , - 1 1 1 - 1 1 1 , 1 1 1 • _ - 1 C ��4L r -6550 Parent Well ' 1 1 1 , , 1 1 -. , 'ti_ ; ; ; ; ; - _1_ -1 _ ice t _ L _ 1 _ __ _ t _ an9 _. ___ 3K -09A 1 1 ,,.+ _ , 1 , _ _.. _L__J__ _ L _ J _J _...L a ,.- ' _ ____ _• �. J _L_ _ _J_.1..L_ J. _I.. L. 1 , 1 1 , 1 1 1 1 1 1 1 — _ T _ 1 1 ,., _ _ _ _ ____ _ ' _ _.4- - ` , , , 1 1 1 , 1 , , , K _ - -4- _ _4__;_ - � _ , 1 1 , , 3 _ ;;__ , - 1 - - , - -65 f5 . r T1f: _, .a ` _T - i - - r - T - 1 ` I -� I ► - ri - - 1 7 - r s to 1 1 1 , 1 , � Ai / A5 / Al dR 3K -09A - T - ; , -- -� - - r-i-i----�-i- '�:.T-.i:., a _ -T r - � iTi� - _1_J__,__ • Fa al%'A' -J_J _L_J_J____L_1_ L_ 1_J �1� - -L• (i . z• DINE - ill Ar 3 P 1 �+lr. U 660 — 1 _ —� T ■ V: —• .•�"'"' • --1- i -- - r - �- � FadR'O' A3 Pa= _,__ _ _ __ p, 1 1 1 1 , , 1 1 Y I∎ T-1--.- - T - i Faai%'B - 1 - 1 - 4 -2• DTME 1 •Y'C - • - -- r- -r-,- - r - -r- - 1. -1- OW" - 1 ✓ 1 1 1 , -2' DTSY �. J_J._ ' �' ' i� , a_ W � °A3 - '�' _T�IIrL_ 6625 — 1► 1 1 -_. '4 -T-4 ' r- i-r - --1-r- r -T 1--- - i- - - -r-r �� - i r, � - r' � r - ; 7 1 7 t7 � r- - _1 _ 1 _ J L_J_J �_L _ J_ J___. _t _ _J____t ' 'L.' t: l J _t L_ J l_ 1 , , 1 r , , , ` ', A2 1 a oust ear fir 'PPM i - 6650 —r v�� .31111: d �� - ' - - - • - - - - r -_.,•_ rlr-_. .. -- 1 • _ 1 _ J I L _ ; wj � ` 1 _ 1 . J _ _ _ _ l - l J _ � L _ 1 ... _ _ 1 _ _ . _ -t _ 1 _ _ _L _.. _ L _ _ J 1- - L .. t � �— •. 4. . . rr 1 1 1 1 , t r , 1 ill 1 , l -- w - ''Y� .tii. .. V"� -' L • J - - -L -� J_ L.Y fA2 Y -I. _ ' - __, L_ L_ _ J__L , , -. . T 1 ,_ 4 _, Laaar _ i - - 1 • ,.. _ _r -•` A 1_f - _ 1 �� 1 , , 1 1 1 1 1 1 1 f _ _.—.'- 4 - __r_T -1 -- -t_ -- r -r_T- _ 1 -r -T- • ._T_ __, , r -_ 6675 >� �i moon. L.u►r A3 swims A' • 1 1 3K -S9BLI T O 1 1 _ 1 ! 3K -596 KOP• - i- .j. - _L _ � t. __I__ _a_ _ 1__L_•_ _, _ L _ , L_ — - - ; _ • ' S: • : . '' I' ,. .� :1 1 < 8059'MDl- 4" - 1 1 1 1 ^ 10.018D/-666Y 1 1 1 1 'Mrr 1 �� "Y . .1 1 iii-i:rim-.i....- 1 1 1 1 1 1 1 1 1 1 r . A2P .rLi-i T- r 1 - 7 - 7 ---- 1 - 1 - -- r- --r r - r - r - r - I - 7 7 7 7 - r - --L. J • -.I .. J ' L .1-- _ 7 - 1 J J 7-7 .-- L _ . L _ L _ _ t _ 1 _ 1- _ _ _ t . L 1- _ _ _ _ L _ t , _ _ J _ _ • 6700 7000 7200 7400 7600 7800 8000 8200 8400 8600 8800 9000 9200 9400 9600 9800 10000 10200 Vertical Exaggeration: - 7.7x Ale a sure d Depth 3K- 09BL1 -01 Anne**b True Norm WELLBORE DETAILS: 3K -09B REFERENCE INFORMATION Filiiii Project: Kuparuk River Unit Magnetic North . 21.65° Site: Kuparuk 3K Pad 1 F. Parent Wellbore: 3K -09A Coo Reference: WeY3K-09, True North BAKER ConocoPhil Well: 3K - Strength 57673.8en7 Vertical (TVD) Reference: 36-09 @ 69.008 (36-09) �' D 6 e aie. soar Tie on MD: 7200.00 Section (VS) Reference Ski- (0.00N, 0.00E) hps p{d1:3K 8 wp06 3K-0 -0 Mo HUGHES Measured Depth Reference: 3K -09 69.00ft (3K-09) Calculation McBwd: Minimum Curvature 1 -10 -1 7 I T .' /o- oY2 A 2i1K•22A 7 3K -2Yl3K 2Y" - , - -- 3K{n, Kays 75 / h 3Kd9/3K •19 3___{ / ' 3K -108.. -19• l h 0004 _ -__ __� .____ -. — _ -_ __.. -__— ___ ._ 3 08/3K -108 LI 3K413/3K {13 2851 —. _ . /6,0 0 9 2700 'x- __ - -._ • •-g 2550 : / - -_ - - __ - -- - / 3K- 102 /3K402L1981_ 2.11 - 3K •/3K -0911 ® __ < / . . '' 3K- 20/3K -20 S 2251 - -_ _---� • 1951 :// _ - " S 1650... __ ^ l3 / / 1500 ® • (6140K -103PM i `F 3K- ia3�Liat u,Pa �1200t/ �r —_-. _ - 3K -I03 (EI4)/3K•]03 {,l' + 3K -107 (E14)/3K -103 LI ▪ 10501 - -- - -- — O 900, r ▪ 750 _._ . -.. O t73 •11 3K - T KL � / /' • - 3 i�6 – 3K•27/3K•2 l' a , y /� � AAP 150 ,! _ g ter i1� __ 33Cd')HK -19. .c u' f` - 151 _.._ - -_ - __ -_ Y •. 3 —. -__ -"-- 3K- 26/3K -26 I . 11 - _ - - 1 '�_. -751 _ \\ -•11 1K- 15!71$ _. _. 3ti 1K -1; 11,%16 'LK -1 G 3 3K- 12/3K•12 3K-32/3K-32 r i -150 0 150 300 450 600 750 900 1050 1200 1350 1500 1650 1800 1950 2100 2250 2400 2550 2700 2850 3000 3150 3300 3450 3600 3750 3900 4050 4 4350 4500 4650 4800 4950 5100 5250 5400 3K-09 @ 69.00ft (3K -09) West( - )/East( +) (150 ft/in) AnmurisW True North WELLBORE DETAILS: 3K -09BL2 - REFERENCE INFORMATION all Project: Kuparuk River Unit A M agrolic NoM:21.65' FA. Site: Ku paruk 3K Pad Magnetic P;e8 Parent Wellbore: 3K -09A Co (NE) Reference: Wel 36 True North Wellbore: 3K-09BL2 Well 3K sfe ngt.57W3.6en r Tie on MD 7150.00 Vertical (TVD) Reference: 3K-09 @ 69.001I (3K-09) BAKER dat BO A2C0 Section (VS) Reference: Slot- (0.00N, 0.00E) ConocoPhillips Plan :�K-0 o� ° 3K- 09/3K Dy�7/ I Measured Depth Reference. 3K-09 69.00((3K-09) HUGHES Calculation Method: Minimum Curvature _.... _ . 3 . . - 3KdN1K -01 -. % ` \ � -- . r 3K- 23/3K -2} I 3K -2 ' -20 3K -03/3K -03 __ 31L 31L 3K09,3K-0 0 ��3K -25L7 '2$ 24/3K•24 3K -103 e- )/3K -10 '.1 1,,,g 31,. x; +K K ll . - 3K - 22/. K)2`2 �. 3K 7 K - 113x 500 _- - -- - - _ - -. . -. _ _.. _.. / / aoo -04n r \ / % 300 . -�\ _ > ___ � —._ i' 200 - -_ - - -_ _.. _. -_ _ -. _. _. _ _. .� 3K 10213K- 2LIPB1 J Q 3K -09/ -09A 111 3A- 102/3K -102L1 — .- _. _ _ 3K- 19/3K- -09 '`C a � , � � - - __ - ... ___.__. _._ i�� 1 _ _ 3K.0 7K - 177 ,, - 09/3" Off 3K 0/3K-I0 7 IOW • 3K - 26/3K -26 - 301 - K 1 ;gK i n i -711 - � _ — - O -800 i _ -- - - - - -- - --_. _ _.. - -__ \ �-� -900 -_ - _..__ -_- _ _ __ __ ___ _ _______ —__ —. __ _ -___ - O 1100 -. _._ -. - - -_-- -. -__- -- -_. ' \/ T 120 / - - - -- - - -`- '-- -- -- — -- .- _ - 3K -09/3K-09BL2 - - - 3K- 3113K -31 - -- -____ 3K- 32/3K -32 1301 _... _. —_ ___ _. __ _ -._ - -_ - __ - -_— l n -1 11 - 3K- 15 45 - _ - _ .___ -___ _. _ ...__. —. \ __ _. -_ _... \ . 3K - 09BL2 - 01 3K -1711 _____ _.__— _ •1.11 _._ __... _._ -__. .___..._. ___- __- —_` - 2111 __.. _....._ _. 3K- I2.3K -72 3K- 33/3K -35 \ - 6.Ini3K 3K- 14/3K•14 -10 ,, -300 -200 - 100, ,, 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 3K -09 @ 69.00ft (3K -09) West( - )/East( +) (100 ft/in) • • SLIT'AUE E[F LataKKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 James Cawvey Alaska Wells Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 -0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3K -09B ConocoPhillips Alaska, Inc. Permit No: 210 -042 Surface Location: 1234' FSL, 317' FWL, Sec. 35, T13N, R9E, UM Bottomhole Location: 1773' FNL, 1965' FEL, Sec. 35, T13N, R9E, UM Dear Mr. Cawvey: Enclosed is the approved application for permit to re -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. Sincerely, Daniel . Seamount, Jr. Chair DATED this 1 4 4=1<- day of April, 2010. cc: Department of Fish & Game, Habitat Section w/o encl. (via e -mail) Department of Environmental Conservation w/o encl. (via e -mail) 0 STATE OF ALASKA • REC E IVED ALASKA OIL AND GAS CONSERVATION COMMISSION q�7� Q 9 2010 PERMIT TO DRILL 20 AAC 25.005 - klaska Cell & Gas Cong,Conlpli188lOtl 1 a. Type of Work: 1 b. Proposed Well Class: Development - Oil 5 • Service - Winj ❑ Single Zone IN • 1 c. Specify if vAindallad for: Drill ❑ Re -drill 0 Stratigraphic Test ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Re -entry ❑ Exploratory ❑ Service - WAG ❑ Service - Disp ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: U Blanket ❑ Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59 - 52 - 180 • 3K - 09B - 3. Address: 6. Proposed Depth: 12. Field /Pool(s): P.O. Box 100360 Anchorage, AK 99510 - 0360 MD: 9975' ' TVD: 6672' ` Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 1234' FSL, 317' FWL, Sec. 35, T13N, R9E, UM . ADL 25519 • Kuparuk River Oil Field Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1921' FSL, 2368' FEL, Sec. 35, T13N, R9E, UM 2555 4/26/2010 Total Depth: 9. Acres in Property: 14. Distance to 1773' FNL, 1965' FEL, Sec. 35, T13N, R9E, UM 2560 Nearest Property: 7220' . 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: •69 feet • 15. Distance to Nearest Well Open Surface: x - 529306 . y - 6008229 • Zone 4 GL Elevation above MSL: 30 feet to Same Pool: 3K -03 , 1350 . 16. Deviated wells: Kickoff depth: 7200 ft. 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 100° deg Downhole: psig At $ / t Surface: 3863 psig 18. Casing Program: Specifications Top - Setting Depth - Bottom f Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2.375" 4.7# L - 80 ST - L 1775' 8200' 6655' 9975' 6672' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) 7580 6980 7400', 7453' Casing Length Size Cement Volume MD TVD Conductor /Structural 80' 16 1540# Poleset 110' 110' Surface 3172' 9.625 1400 sx AS IV, 125 sx CI G 3172' 3169' Intermediate Production 7559' 7 910 sx Class G, 175 sx AS 1 7559' 6962' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 7279' 7297', 7310' 7326', 7333', 7339', 7344', 7348' 7352', 7359' - 7363' 6727'- 6743', 6754'- 6767', 6773', 6779', 6783', 6786'- 6790', 6796' -6799' 20. Attachments: Property Plat ❑ BOP Sketch El Drilling Program 0 Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 5 21. Verbal Approval: Commission Representative: Date: 40 moo _G 22. I hereby certify that the foregoing is true and correct. Contact James Ohlinger @ 265 - 1102 Printed Name V. Cawvey Title Alaska Wells Manager Signature 7.,„ e Phon -63o6 Date 4. /g /Zel)() Commission Use Only Permit to Drill API Nu ' ber: Permit Ap roval See cover letter Number: �`t;t��y Z .— Z 50 \ 0 I -6..,/ Date: Li 114 O for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed coalbed ngthane, gas hydrates, or gas contained in shales: •*•4o f$ . SO /es 7 Samples req'd: Yes ❑ o Mud log req'd: Yes ❑ No [✓]/ Other: - 250 0 PS4 A' MAK/an. je.sf 6 measures: Yes [v No ❑ Directional svy req'd: Yes Q' No ❑ 0 P . APPROVED BY THE COMMISSION / 47/ DATE: / , COMMISSIONER Form 10 - 401 (Revised 7/2009) This permit is valid for 24 m h or t e lit o 1ofDfD A (20 AAC 5.005(g)) '- § ubmit in Duplicate yi3•/o % -0) ,-. $ . 70 • Permit to Drill Summary of Operations KRU 3K -09B, 3K- 09BL1, 3K- 09BL2, and 3K- 09BL2 -01 Laterals Coiled Tubing Drilling Overview: Well 3K -09A is currently a producer completed in the A3 and A2 sands through the 7" production casing with 3- 1/2" tubing to surface. The proposed CTD sidetracks will be named 3K -09B, 3K- 09BL1, 3K- 09BL2, and 3K- 09BL2-01 and will target the A3 and A2 -sands to access provide offlake in two dead segments to the north of 3K -09A, replace the existing production near the (cemented) motherbore, and improve sweep efficiency across two baffling fault zones south of the parent well. A cement plug will be placed across the existing perforations, and a 2.80" pilot hole will be a drilled on the high- / side of the 7" casing to a depth of approximately 7,250' MD. Two whipstocks will then be set at 7,200' MD and 7,150 for high-side casing exits. 9 9 The 3K -09B is planned for a 2 -3/8" slotted liner with a liner -top aluminum billet for the KOP for the BL1 lateral at • —8,200' MD. 3K -09BL1 will be completed with 2 -3/8" slotted liner with the liner top brought up into the pilot hole inside the 7" casing at 7,195' MD. The completion for 3K -09BL2 will consist of 2 -3/8" slotted liner with a liner - top aluminum billet for the KOP for the BL2 -01 lateral at —7,700' MD. The completion for 3K- 09BL2 -01 will be 2 -3/8" slotted liner with the liner top brought up into the existing 3 -1/2" tailpipe to approximately 6,970' MD. Operational Outline Pre -Rig Work • Slickline: Dummy perf gun drift. Obtain SBHP. Dummy GLVs, MIT -IA. • • E -line: Run GR/CCL jewelry log / tie -in log (K1 Marker to Tubing Tail). Shoot holes in the 3%2" tubing below the Baker SAB3 Packer from 7033' to 7035' RKB. • Coil: Mill out the XN- nipple at 6984' RKB to 2.80" with a left -hand motor. • Coil: Lay in cement plug from PBTD plug to —7033' RKB. ' • Slickline: Tag top of cement, pressure test cement plug. • Prepare wellsite for rig arrival. Rig Work 1. MIRU Nabors CDR2 -AC rig using 2" coil tubing. NU BOPE and test. 2. Mill cement pilot hole. 3. Set top of whipstock at 7,200' MD. 4. Mill 2.80" window at 7,200'. 5. 3K -09B Sidetrack • a. Drill a 2.70" x 3" bi- center lateral to a TD of 9,975' MD b. Run the 2%" slotted liner from TD to —8,200' MD. An aluminum liner top billet will .V ,. be placed at —8,200' MD. 6. 3K -09BL1 Lateral a. Kick off of the aluminum liner top billet at —8,200' MD b. Drill a 2.70" x 3" bi- center lateral to a TD of 10,050' MD c. Run the 2 %" slotted liner from TD to 7,195' MD, into the pilot hole inside the 7" casing Page 2 of 5 4/6/2010 ORIGINAL • • Permit to Drill Summary of Operations Cont. KRU 3K-09B, 3K- 09BL1, 3K- 09BL2, and 3K- 09BL2 -01 7. Set top of whips o ck at 7,150' MD. 8. Mill 2.80" window at 7,150'. 9. 3K -09BL2 Sidetrack a. Drill a 2.70" x 3" bi- center lateral to a TD of 9,075' MD • b. Run the 2%" slotted liner from TD to 7,700' MD. An aluminum liner top billet will • be placed at —7,700' MD. 10. 3K- 09BL2 -01 Lateral a. Kick off of the aluminum liner top billet at —7,700' MD • b. Drill a 2.70" x 3" bi- center lateral to a TD of 9,075' MD c. Run the 2%" slotted liner from TD to —6,970' MD, inside the 3 -1/2" tubing tail of the • motherbore. Post -Rig Work 1. Install GLV's 2. Obtain SBHP 3. Produce to system Mud Program • Chloride -based Biozan brine (8.9 ppg) for milling operations, and chloride -based Flo-Pro mud ( -10.0 ppg) for drilling operations. • There is an SSSV installed in 3K -09A so we will not have to load the well with completion fluid to deploy the 2-%" slotted liner. Disposal: • No annular injection on this well. • Class II liquids to KRU 1R Pad Class II disposal well , • Class 11 drill solids to Grind & Inject at PBU Drill site 4 • Class 1 wastes will go to Pad 3 for disposal. New Completion Details: Lateral Name Top Btm Liner Details Other Details MD MD 3K - 09B 8,200 9,975 2 % ", 4.7 #, L -80, ST -L slotted Unanchored aluminum billet 3K - 09BL1 7,195 10,050 2%", 4.7 #, L -80, ST -L slotted 3K - 09BL2 7,700 9,075 2% ", 4.7 #, L -80, ST -L slotted Unanchored aluminum billet 3K - 09BL2 - 6,970 9,075 2 % ", 4.7 #, L -80, ST -L slotted Existing Completion Details: Category OD Weight Grade Top Btm Burst Collapse (ppf) MD MD psi psi Conductor 16" 62 H -40 0 110 1640 670 Surface 9 5 / 8 " 36 J -55 0 3,172 3520 2020 Casing 7" 26 J -55 0 7,559 4980 4320 Tubing 3'/2" 9.3 L -80 0 6,940 10,160 10,530 Page 3 of 5 4/6/2010 DRIGINAL • Permit to Drill Summary of Operations Cont. KRU 3K -09B, 3K- 09BL1, 3K- 09BL2, and 3K- 09BL2 -01 Well Control: • Two well bore volumes of KWF will be available to the rig during drilling operations. The kill weight fluid may or may not be stored onsite, but if it is stored offsite it will be in the Kuparuk Field within a short drive to the rig. • BOP diagram is attached for operations with 2" coil tubing. • Pi •e rams blind rams and the CT •ack off will be •ressure tested to 250 psi and to 5000 •si. Maximum potential surface pressure is 3863 psi assuming a gas gradient to surface based on the potential offset well pressure of an equivalent 13.0 ppg mud weight. ' • The annular preventer will be tested to 250 psi and 2500 psi. Directional: • See attached directional plans. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. ' • Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance • 3K -09B 7220' 3K -09BL1 7220' 3K -09BL2 8200' 3K -09BL2 -01 8200' • Distance to Nearest Well within Pool (toe measured to offset well 3K -03, and 3K -12) Lateral Name Distance 3K -09B 1350' 3K -09BL1 1350' 3K -09BL2 1200' 3K -09BL2 -01 1200' Logging MWD directional, resistivity, and gamma ray will be run over the entire open -hole sections. • Reservoir Pressure 3K -12 is the closest offset well injecting in the A -sand interval and had a static bottom hole pressure of 3584 psi (10.3 ppg EMW). 3K -12 has been flowing back for several months to bring the reservoir pressure down. 3K -05 3K_ has been shut in since October '09 from injecting water and it measured 4564 .s 13.2 pp. EMW, Feb. '10 . gi,r- -1;7k Similar pressures are expected as the laterals are drilled. The most recent static bottom ole pressure reading - 7'1*'4 1 p in 3K -09 was 2065 psi (6.0 ppg EMW). The 3K -09 has been shut -in for 5 months to allow the reservoir 44 ' pressure to build up high enough to drill without excessive losses and to mitigate high differential pressure at �4 � 1 ` 5 fault crossings. T Hazards • Laterals are approaching injectors in both directions. Pressure is expected to increase along wellbore. ./ Maintain sufficient ECD to overbalance. A 10.0 ppg mud system, annular friction and 400 psi on the drilling choke will supply enough pressure to overbalance. • Well 3K -09 has 120 ppm H as measured on Feb. '09. The maximum H level on the 3K pad is 400 • ppm measured on Jan. '09 at 3K -27. All H monitoring equipment will be operational. Page 4 of 5 4/6/2010 • • Permit to Drill Summary of Operations Cont. KRU 3K-09B, 3K 09BL1, 3K- 09BL2, and 3K 09BL2 -01 Managed Pressure Drilling Managed pressure drilling (MPD) techniques will be employed to provide constant bottom hole pressure by using 10.0 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allows for the use of Tess expensive drilling fluid and minimizes fluid losses and /or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure is located between the BOPE choke manifold and the mud pits, and will be independent of the BOPE choke. Using this technique will require deployment of the BHA with trapped wellhead pressure. Pressure deployment of the 2 %" BHA will be accomplished utilizing the 2 pipe rams and slip rams. Well 3K -09 does have a SSSV, so the well will not have to be loaded with completion fluid prior to running slotted liner. Operating parameters and fluid densities will be adjusted based on real -time bottom hole pressure measurements while drilling and shale behavior. The following charts show the different pressure parameters in both "pumps on" and "pumps off" conditions. Drilling Conditions: Pressure at the Window Using MPD (FloPro) Pumps On Pumps Off (1.5 bpm) Formation Pressure 4480 psi 4480 psi Mud Hydrostatic (10.0 ppg) 3384 psi 3384 psi Annular friction (i.e. ECD) 684 psi 0 psi Mud + ECD Combined 4068 psi 3384 psi (no choke pressure) (underbalance (underbalanced d -412 psi) .553 psi) Target Pressure (13.3 ppg) 4500 psi 4500 psi Choke Pressure Required 432 psi 1116 psi • to Maintain 13.3 ppg Example: Using the 3K -05 SBHP from Feb. '10 and assuming a reservoir pressure of 4480 psi (Shut -in and dropping 1 psi /day) at 6663' TVDss (12.9 EMW). While drilling and circulating at 1.5 bpm with 2" e-coil, head from the 10.0 ppg mud (3384 psi), plus an estimated 684 psi of annular friction (assuming friction of 95 psi /1000 ft) plus 530 psi WHP will provide 4600 psi BHP (13.6 ppg EMW) and overbalance the reservoir by -100 psi. When circulation is shut down, the mud will still be underbalanced to the reservoir pressure. However maintaining -1216 psi at surface when the pumps are shut down will maintain a constant 13.6 ° EMW to promote wellbore stability. Page 5 of 5 4/6/2010 ORIGINAL 3K -09B + Proposed CTD Sidetrack II I ` 1, 3 -1/2" TRMAXX -5E SCSSV @ 2,183' MD ID = 2.812" — 3-1/2" 9.3# L -80 EUE Brd Tubing to surface ID = 2.992" 16" 62# H -40 shoe @ 110' MD 3 -1/2" Cameo MMG gas lift mandrels @ 2396' 3533' 4607' 9 -5/8" 36# J-55 shoe 5586' @ 3172' MD 6307' moommi 6839' _ 3-1/2" X Nipple @ 6888' MD (2.813" profile) 1 i i G •/ �0 Baker PBR @ 6922' MD (4" ID) Baker KBH -22 Anchor Seal Assembly @ 6935' MD (3.0" ID) Packer to - IPerfs for Cement Baker SAB3 Packer @ 6936' MD (4.0" ID) Tubing Tail = 104' x 11"7 _ •/1 1 7033' -7035' _'..< ! 2.813 "'XN' Nipple @ 6984' MD (2.75" min ID) WLEG @ 7049' MD Tubing Tail to'** Tubing Tail @ 7050' MD Top of Whipstock = 100' 2 -5/8" Openhole anchor /whipstock@ 7150' ,�1 L;. 'South Laterals • KOP - 7700' I 3K- 09BL1: 9075' WP03 2 -5/8" Openhole anchor/whipstock @ 7200' - ■A1 • 7250' - Bottom of Pilot Hole �, ""—'— 3K- 09BL2: 9075' WP06 ` , • North Laterals I A3 - sand perfs 7279' ' :: 9' l fs 7310' r " S '� KOP - 8200' 3K- 09BL1: 10,050' WP07 7333 ® --•-^- y m-. _ 7326' MD 7339' - �� * �„"• 7344' -'- 3 ,, , , x4 x . • , 7348' - 7352' --® PBTD @ 7410' " L. - 7° 26# J-55 shoe @ 13K-09B: 9975' WP06 7359' - 7363' �� 11/22/09 7559' MD KUP 3K -09A CanocoPhi lips Well Attributes Max Angle & MD� TD Wellbore APWWI ' ■ Field Name Well Status Inol ( °) 'MO (961(8) Act Btm (MB) �w+lh� ASHY' (1 500292165601 1 RIVER UNIT PROD 37.33 1 4,675.00 7,580.0 Comc , '" Comment H2S (ppm) Date Annotation End Date KB (96) Rig Release Date -. wexconn6:. - .668. tv25206610:03:37 AM SSSV: TRDP 135 1/12/2008 Last WO: 9/5/2008 ( 39.90 10/17/1986 Schematic - Actual Annotation Depth (MB) End Date (Annotation 'Last Mod -_ End Date Last Tag: SLM 7,397.0 11/22/2009 Rev Reason: TAG Imosbor 11/26/2009 Casing Strings a. HANGER, 0 s Casing Description !String 0... String ID ... Top (961(8) .Set Depth (f... Set Depth (ND) String Wt... String String Top Thrd CONDUCTOR I 16 15.062 0.0 I 110.0 110.0 1 62.50 H CONDUCTOR, Casing Description String 0... String ID ._ Top (fIKB) Set Depth (t._ Set Depth (TVD)... String Wt... String ... String Top Thrd 0.110 9 ption 36.00 1 Top pt g Safety valve,. PROD String 7 o... Ist 9 6.151 To 0 8 1 Depth ( ', � 7,559.0 26 (L.. Set Depth String - J - String String Top Thrd SURFACE 9 5/8 8.697 0.0 3,172.0 2.183 - I Tubing Strings Tubing Description String 0... String ID ... Top (ftlCB) Bet Depth (f... Set Depth (ND) ... I String Wt.. String ... String Top Thrd ■ GAS UrT, ' TUBING 31/2 2.992 0.0 6,940.4 6,434.6 9.30 1 L -80 EUE 8rd 2,396 .. - Completion Details Top Depth' (TVD) Top Ind Nomi_. Top (MB) ( (°) (ern Deseriplion Comment n9 Hanger (Pup t 3.66 ID (in) SURFA 0.0 0.0 0.00 HANGER 3.5" Gen V Tubi Han er EUE 8rd Mod PU ' 3.500 oa,m ) 2,183.3 2,183.3 1.24 Safety Valve 3.5" 7RMAXX -5E SCSSV w/ 2.812" X Profile EUE 8rd Mod 2.812 GAS LIFT, 3,533 - - " - " - 6,888.0 6,390.0 31.54 NIPPLE 3.5" X Nipple w/ 2.813" profile 2.813 6,927.6 6,423.7 31.23 LOCATOR Baker 3.5" Locator O.D. 4.54" I. D. 3.99" 3.030 GAS LIFT, 6,927.9 6,424.0 31.23 SEAL ASSY Baker 80-40 PBR w /Sea( Assembly O.D. 4.01" I.D. 2.99 2.990 4 Tubing Description :String 0... String ID... Top (9668) Set Depth (1. Set Depth (ND)... String Wt... String... String Top Thrd I TUBING Original 31/2 2.992 6,921.6 7,050.0 6,528.1 9.30 L-80 EUE 8rd GAS LIFT, Completion Details ' ? ='= 1 5,586 Top Depth (TVD) Top Incl Monti... Top (MB) (MB) ( °) Item Daseriptbn Comment ID (In) It 6,921.6 6,418.7 31.87 PBR Baker PBR Po li sh P Bore Receptacle (6 Pins 40,000 lb Shear ) _ 4.000 GAS LIFT, 6,307 , 6,935.0 6,430.0 31.25 SEAL ASSY Baker KBH-22 Anchor Seal Assembly (3.5 " EUE 8rd Box Up) 3.000 6,935.9 6,430.8 31.25 PACKER Baker 7" x 4.5" SA83 Retainer Production Packer (LTC Box Down) 3.250 GAS LIFT, 6,839 it _ 6,946.4 6,439.7 31.28 XO- Reducing Crossover 4.5" LTC Box x 3.5" EUE 8rd Pin 3.500 1 .' 6,983.8 6,471.6 31.09 NIPPLE 2.813 " 'XN' Nipple (2.75" No-Go) 2.750 NIPPLE, 6,886 7,049.1 6,527.4 31.59 WLEG Wire)ine Entry Guide 4.18" 0.0. 2.992 I Other In Hole reline retrievable plugs, valves, pure : . :,n.lir Top Depth 1 (TVD) Top Intl T op (MEI) (MB) C) Description Comment Run Dale ID (in) LOCATOR, .: I 7,400 FISH 1 1/2" OV 1.5" OV LOST 2/24/2006 2/24/2006 6,928 P8R, 6,922 7,473 FISH 1 1/2" DV 8 TG Latch Dropped to Rathole 12/16/1986 12/16/1986 a SEAL ASSY, 6,928 SEAL ASSV,, : Perforations & Slots - - 6,935 Shot Top (TVD) Btm (TVD) Derr PACKER, 6,936 - Top (MB) Btm (ftKB) (BBB) (MB) Zone Date Oh.- Type Comment 1-- 7,279 7,297 6,723.4 6,738.7 A-3, 3K-09A 9/27/1987 8.0 RPERF 2 1/8" Silver Jet, 60 ph 7,284 7,284 6,727.7 6,727.7 A-3, 3K-09A 12/14/1986 1.0 IPERF 2 1/8" EnerJet, 0 deg ph _ IP 7,289 7,289 6,731.9 6,731.9 A-3, 3K -09A 12/14/1986 1.0 IPERF 21/8" EnerJet, 0 deg ph x0 Reducing, 8,946 6 �. 7,292 7,292 6,734.5 6,734.5 A -3, 3K -09A 12/14/1986 1.0 ERE 2 1/8" EnerJet, 0 deg ph a 7,294 7,294 6,736.2 6,736.2 A-3, 3K -09A 12/14/1986 1.0 IPERF 2 1/8" EnerJet, 0 deg ph a 7,310 7,326 6,749.8 6,763.4 A -2, 3K-09A 9/27/1987 8.0 RPERF 2 1/8" Silver Jet, 60 ph 7,315 7,315 6,754.0 6,754.0 A -2, 3K -09A 12/14/1986 1.0 IPERF 21/8" EnerJet, 0 deg ph NIPPLE, 6,984 In 7,325 7,325 6,762.5 6,762.5 A -2, 3K-09A 12/14/1986 1.0 IPERF 2 1/8" EnerJet, 0 deg ph a 7,333 7,333 6,769.3 6,769.3 A -2, 3K-09A 12/14/1986 1.0 IPERF 2 1/8" EnerJet, 0 deg ph WLEG, 7,049 ' 7,339 7,339 6,774.4 6,774.4 A -2, 3K -09A 12/14/1986 1.0 IPERF 2 1/8" EnerJet, 0 deg ph 7,344 7,344 6,778.7 6,778.7 A -2, 3K-09A 12/14/1986 1.0 IPERF 2 1/8" EnerJet, 0 deg ph 7,348 7,352 6,782.1 A -2, 3K -09A 12/14/1986 1.0 IPERF 21/8" EnerJet, 0 deg ph IPERF, 7,264 - 7,359 7,363 A -2, 3K -09A 12/14/1986 1.0 IPERF 2 1 /8" EnerJet, 0 deg ph RPERF, - _ 7,279.7,297 T Notes: General :& Safety IPERF,7,289 - End Date Annotation (, ' - 9/20/2008 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 IPERF, 7,292 IPERF, 7,294 - -- IPER,315 R 7,310.7,326 IPERF, 7,325 IPERF, 7,333 IPERF, 7,339 • - - -- - IPERF, 7,344 -- -. Mandrel Details Top Depth Top Port (ND) Ind OD Valve Latch Size TRO Run IPERF, Stn Top (MB) (nKB) (°) Make Model (in) Serf Type Type (in) (psi) Run Date Corn.- _ 7,348 - 7,352 1 2,396.3 2,3962 2.10 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,346.0 9/28/2008 2 3,532.7 3,523.8 11.53 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,327.0 9/28/2008 IPERF, 3 4,606.5 4,510.4 37.11 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/2/2008 7,3547,363 4 5,586.4 5,305.4 34.86 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,307.0 9/28/2008 5 6,307.0 5,900.3 33.83 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/2/2008 FISH, 7,400 4 6 6,839.0 6,348.4 32.17 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.188 0.0 9/27/2008 FISH, 7,473 • P5ODUCON, 0. TD (31( -09A), O RIGIN A L 7,580 • • vex ConocoPhill _ _- Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3K Pad 3K -09 3K -09B Plan: 3K -09B wp06 Standard Planning Report 05 April, 2010 FARO - BAKER HUGHES • • -f ConocoPhillips Vaal ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co- ordinate Reference: Site Kuparuk 3K Pad I I Company: ConocoPhillips(Alaska) Inc. TVD Reference: -- Mean Sea Level Project: ` Kuparuk River Unit MD Reference: 3K -09 © 69.00ft (3K -09) Site: Kuparuk 3K Pad North Reference: True Well: 3K - 09 Survey Calculation Method: Minimum Curvature Wellbore: 3K - 09B Design: 3K -09B_wp06 Project Kuparuk River Unit 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 Kuparuk 3K Pad Site Position: Northing: 6,008,428.74ft Latitude: 70° 26' 2.781 N From: Map Easting: 529,306.18ft Longitude: 149° 45' 39.930 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.23 ° Well 3K - 09 Well Position +N / - - 200.11 ft Northing: 6,008,228.65ft • Latitude: 70° 26' 0.812 N +E / - -1.04 ft Easting: 529,305.92 ft 6 Longitude: 149° 45' 39.960 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00ft ' Wellbore 3K - 09B . Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) - r) (nT) I BGGM2009 7/15/2010 17.14 79.87 57,394 Design 3K- 09B_wp06 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,200.00 Vertical Section: Depth From (TVD) +W-S +El -W Direction - - _: _-. (ft) (ft) (ft) r) 0.00 - 200.11 -1.04 25.00 4/5/2010 9:16:01AM Page 2 COMPASS 2003.16 Build 69 ORIGINAL III • ConocoPhillips rue ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co- ordinate Reference: Site Kuparuk 3K Pad Company: ConocoPhillips(Alaska) Inc. TVD Reference: Mean Sea Level Project Kuparuk River Unit MD Reference: 3K -09 © 69.00ft (3K -09) Site: Kuparuk 3K Pad North Reference: _ True Well: 3K - 09 Survey Calculation Method: Minimum Curvature Welibore: 3K - 09B Design: 3K 09B_wp06 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System _ +NI-S +E/-W Rate Rate Rate TFO (ft) ( °) ( °). (ft) (ft) (ft) (1100ft) (1100ft) (1100ft) (^)_._ Target 7,200.00 31.59 90.32 6,587.12 - 167.18 1,939.62 0.00 0.00 0.00 0.00 7,215.00 34.59 90.32 6,599.68 - 167.23 1,947.81 20.00 20.00 0.00 0.00 7,265.00 55.59 90.32 6,634.79 - 167.42 1,983.02 42.00 42.00 0.00 0.00 7,379.85 93.80 59.03 6,665.25 - 136.35 2,085.66 42.00 33.27 -27.24 316.00 7,729.85 90.02 17.17 6,653.04 132.85 2,296.59 12.00 -1.08 -11.96 265.80 7,904.85 87.87 38.07 6,656.30 287.02 2,377.25 12.00 -1.23 11.94 96.00 8,054.85 90.13 55.93 6,658.93 388.88 2,486.49 12.00 1.51 11.91 83.00 8,254.85 93.97 32.22 6,651.67 531.39 2,624.53 12.00 1.92 -11.86 279.50 8,354.85 93.88 44.25 6,644.79 609.61 2,686.16 12.00 -0.09 12.03 90.00 8,529.85 90.00 23.59 6,638.80 753.96 2,783.18 12.00 -2.22 -11.80 259.80 8,729.85 85.14 0.06 6,647.40 948.09 2,823.91 12.00 -2.43 -11.77 258.00 8,904.85 90.08 339.62 6,654.77 1,119.22 2,793.19 12.00 2.82 -11.68 283.00 1 9,004.85 100.00 332.84 6,645.99 1,210.23 2,753.16 12.00 9.92 -6.78 326.00 9,204.85 90.12 354.83 6,628.15 1,400.24 2,698.39 12.00 -4.94 10.99 113.00 9,424.85 86.69 21.02 6,634.37 1,616.13 2,728.41 12.00 -1.56 11.90 97.70 9,534.85 86.78 7.80 6,640.66 1,722.26 2,755.68 12.00 0.08 -12.02 270.00 9,975.00 85.67 60.73 6,671.89 2,072.40 2,994.05 12.00 -0.25 12.03 93.00 4/5/2010 9:16:01AM Page 3 COMPASS 2003.16 Build 69 ¢ $RIG1N AL • III ConocoPhillips Ird as ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: -- _ = Site Kuparuk 3K Pad Company ConocoPhillips(Alaska) Inc. TVD Reference: Mean Sea Level Project Kuparuk River Unit MD Reference: 3K-09 © 69.00ft (3K -09) Site: _ = - Kuparuk 3K Pad North Reference: True Well: - 3K - 09 Survey Calculation Method: Minimum Curvature Welibore : 3K - 09B Design: 3K 09B_wp06 Planned Survey Measured TVD Below - Vertical Do gleg ` Toolface Map Map Depth Inclination Azimuth System +W3 +Et , Section Rate_ == Azimuth = -_ - Northing - Fasting (it) (°) ( o ) (g) (it) (ft) (ft) (°t100R)_ (°) (ft) _ (ft) 7,200.00 31.59 90.32 6,587.12 - 167.18 1,939.62 850.00 0.00 0.00 6,008,269.20 531,246.24 TIP / KOP 3K - 09A 7,215.00 34.59 90.32 6,599.68 - 167.23 1,947.81 853.42 20.00 0.00 6,008,269.19 531,254.43 End of DLS 20 7,265.00 55.59 90.32 6,634.79 - 167.42 1,983.02 868.13 42.00 0.00 6,008,269.13 531,289.64 3 7,300.00 66.67 79.25 6,651.70 - 164.49 2,013.41 883.63 42.00 -44.00 6,008,272.18 531,320.02 7,379.85 93.80 59.03 6,665.25 - 136.35 2,085.66 939.67 42.00 -38.62 6,008,300.60 531,392.15 End of DLS 42 7,400.00 93.62 56.62 6,663.95 - 125.64 2,102.68 956.56 12.00 -94.20 6,008,311.38 531,409.13 7,500.00 92.64 44.64 6,658.47 -62.42 2,179.73 1,046.43 12.00 -94.36 6,008,374.90 531,485.92 7,600.00 91.54 32.68 6,654.82 15.47 2,242.04 1,143.36 12.00 -95.01 6,008,453.03 531,547.92 7,700.00 90.37 20.74 6,653.14 104.63 2,286.90 1,243.11 12.00 -95.45 6,008,542.35 531,592.42 7,729.85 90.02 17.17 6,653.04 132.85 2,296.59 1,272.79 12.00 -95.65 6,008,570.61 531,602.00 5 7,800.00 89.14 25.55 6,653.55 198.13 2,322.12 1,342.74 12.00 96.00 6,008,635.97 531,627.27 7,900.00 87.93 37.49 6,656.12 283.19 2,374.28 1,441.88 12.00 95.94 6,008,721.23 531,679.09 I 7,904.85 87.87 38.07 6,656.30 287.02 2,377.25 1,446.60 12.00 95.63 6,008,725.08 531,682.04 1 6 8,000.00 89.30 49.40 6,658.66 355.64 2,442.90 1,536.53 12.00 83.00 6,008,793.94 531,747.42 8,054.85 90.13 55.93 6,658.93 388.88 2,486.49 1,585.09 12.00 82.72 6,008,827.35 531,790.87 7 8,100.00 91.03 50.58 6,658.47 415.88 2,522.65 1,624.84 12.00 -80.50 6,008,854.49 531,826.93 8,200.00 92.96 38.73 6,654.98 486.83 2,592.77 1,718.78 12.00 -80.55 6,008,925.71 531,896.76 8,254.85 93.97 32.22 6,651.67 531.39 2,624.53 1,772.59 12.00 -80.97 6,008,970.39 531,928.34 8 i 8,300.00 93.95 37.65 6,648.54 568.31 2,650.32 1,816.94 12.00 90.00 6,009,007.40 531,953.98 8,354.85 93.88 44.25 6,644.79 609.61 2,686.16 1,869.52 12.00 90.38 6,009,048.85 531,989.65 9 8,400.00 92.91 38.91 6,642.11 643.32 2,716.06 1,912.70 12.00 - 100.20 6,009,082.66 532,019.42 8,500.00 90.67 27.11 6,638.98 726.99 2,770.40 2,011.50 12.00 - 100.52 6,009,166.54 532,073.43 8,529.85 90.00 23.59 6,638.80 753.96 2,783.18 2,041.34 12.00 - 100.89 6,009,193.55 532,086.10 10 8,600.00 88.25 15.36 6,639.88 820.03 2,806.55 2,111.10 12.00 - 102.00 6,009,259.71 532,109.20 , 8,700.00 85.84 3.59 6,645.05 918.35 2,822.96 2,207.14 12.00 - 101.87 6,009,358.08 532,125.23 8,729.85 85.14 0.06 6,647.40 948.09 2,823.91 2,234.50 12.00 - 101.26 6,009,387.82 532,126.06 11 8,800.00 87.08 351.85 6,652.16 1,017.84 2,818.97 2,295.62 12.00 -77.00 6,009,457.55 532,120.85 8,900.00 89.94 340.19 6,654.77 1,114.66 2,794.85 2,373.19 12.00 -76.44 6,009,554.27 532,096.35 8,904.85 90.08 339.62 6,654.77 1,119.22 2,793.19 2,376.61 12.00 -76.14 6,009,558.81 532,094.67 12 9,000.00 99.52 333.18 6,646.82 1,205.97 2,755.33 2,439.24 12.00 -34.00 6,009,645.41 532,056.47 j 9,004.85 100.00 332.84 6,645.99 1,210.23 2,753.16 2,442.18 12.00 -34.54 6,009,649.66 532,054.28 13 9,100.00 95.40 343.39 6,633.22 1,297.60 2,718.12 2,506.55 12.00 113.00 6,009,736.88 532,018.91 9,200.00 90.37 354.30 6,628.18 1,395.41 2,698.85 2,587.06 12.00 114.42 6,009,834.60 531,999.26 9,204.85 90.12 354.83 6,628.15 1,400.24 2,698.39 2,591.24 12.00 114.97 6,009,839.43 531,998.78 14 9,300.00 88.60 6.15 6,629.22 1,495.22 2,699.20 2,677.66 12.00 97.70 6,009,934.41 531,999.22 i 9,400.00 87.06 18.06 6,633.02 1,592.75 2,720.11 2,774.89 12.00 97.57 6,010,032.01 532,019.74 9,424.85 86.69 21.02 6,634.37 1,616.13 2,728.41 2,799.59 12.00 97.12 6,010,055.42 532,027.94 15 4/5/2010 9 :16 :01AM Page 4 COMPASS 2003.16 Build 69 '_ : ‘ 1 I G1NAL • . r- ConocoPhillips FA a, s ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Prod v16 Local Co- ordinate Reference: ' Site Kuparuk 3K Pad Company: - ' _° ConocoPhillips(Alaska) Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: - 3K -09 Q 69.00ft (3K -09) • Site: - Kuparuk 3K Pad North Reference: -- True Well: = 3K - 09 Survey Calculation Method: . Minimum Curvature Welibore: -- ° - 3K - 09B Design: 3K -09B_wp06 Planned Survey Measured TVD Below - - - Vertical Dogleg Toolface -= Map - Map Depth - == - _ _Inclination Azimuth ` item +NIS +E/ - on - Rate == A zimuth Northing _ Eastlng - = (ft) (°) (°) (ft) (ft) (ft) (ft) ( °NOOft) ( °) (ft) (ft) 9,500.00 86.73 11.99 6,638.69 1,687.99 2,749.70 2,873.71 12.00 -90.00 6,010,127.36 532,048.95 9,534.85 86.78 7.80 6,640.66 1,722.26 2,755.68 2,907.30 12.00 -89.48 6,010,161.64 532,054.79 ! 16 ■ 9,600.00 86.40 15.62 6,644.54 1,785.89 2,768.87 2,970.54 12.00 93.00 6,010,225.32 532,067.731 9,700.00 85.96 27.64 6,651.23 1,878.47 2,805.58 3,069.96 12.00 92.53 6,010,318.04 532,104.08 9,800.00 85.68 39.67 6,658.55 1,961.33 2,860.75 3,168.38 12.00 91.73 6,010,401.11 532,158.91 9,900.00 85.60 51.70 6,666.17 2,030.86 2,931.96 3,261.49 12.00 90.85 6,010,470.91 532,229.85 9,975.00 • 85.67 60.73 6,671.89 • 2,072.40 2,994.05 3,325.37 12.00 89.93 6,010,512.68 532,291.77 TD 4/5/2010 9:16:01AM Page 5 COMPASS 2003.16 Build 69 It • ! ConocoPhillips ream ConocoPhtllups Planning Report BAKER Alaska HUGHES Database : - EDM Alaska Prod v16 Local Co- ordinate Reference: , Site Kuparuk 3K Pad Company: ConocoPhillips(Alaska) Inc. TVD Reference: Mean Sea Level Project == = Kuparuk River Unit MD Reference: 3K -09 © 69.00ft (3K -09) Site: Kuparuk 3K Pad North Reference: True Well: ° 3K - 09 Survey Calculation Method: _ Minimum Curvature Welibore: ' - ` 3K - 09B Design: 3K- 09B_wp06 Targets Target Name - hit/miss target Dip Angle Dip Dir. - TVD +WS +E/-W Northing - Easting Shape (') (') (ft) (ft) ( ( (R) Latitude - Longitude 3K -09B t5 0.00 0.00 6,655.00 1,119.39 2,793.21 6,009,558.98 532,094.69 70° 26' 13.784 N 149° 44' 17.951 W - plan hits target center - Point 3K -09B, BL1 fault 3 0.00 0.00 0.00 1,830.72 2,471.98 6,010,268.98 531,770.70 70° 26' 20.781 N 149° 44' 27.372 W - plan misses target center by 6641.17ft at 9327.84ft MD (6630.01 TVD, 1522.78 N, 2702.98 E) - Polygon Point 1 0.00 1,830.72 2,471.98 6,010,268.98 531,770.70 Point 2 0.00 1,741.60 2,758.67 6,010,180.99 532,057.71 Point 3 0.00 1,679.85 2,950.45 6,010,120.00 532,249.71 Point4 0.00 1,741.60 2,758.67 6,010,180.99 532,057.71 3K -09B t8 0.00 0.00 6,672.00 2,071.68 2,993.98 6,010,511.97 532,291.70 70° 26' 23.149 N 149° 44' 12.048 W - plan hits target center - Point 3K -09B t7 0.00 0.00 6,642.00 1,736.58 2,757.64 6,010,175.98 532,056.70 70° 26' 19.854 N 149° 44' 18.989 W' - plan hits target center - Point 3K -09B fault 1 0.00 0.00 0.00 663.30 2,297.36 6,009,101.00 531,600.68 70° 26' 9.300 N 149° 44' 32.508 W - plan misses target center by 6648.89ft at 7200.00ft MD (6587.12 TVD, - 167.18 N, 1939.62 E) - Polygon Point 1 0.00 663.30 2,297.36 6,009,101.00 531,600.68 Point 2 0.00 397.49 2,499.35 6,008,836.01 531,803.70 Point 3 0.00 171.78 2,676.49 6,008,611.02 531,981.70 Point 4 0.00 397.49 2,499.35 6,008,836.01 531,803.70 3K -09B, BL1 fault 2 0.00 0.00 0.00 830.72 2,449.03 6,009,269.00 531,751.69 70° 26' 10.947 N 149° 44' 28.055 W - plan misses target center by 6647.56ft at 8500.00ft MD (6638.98 TVD, 726.99 N, 2770.40 E) - Polygon Point 1 0.00 830.72 2,449.03 6,009,269.00 531,751.69 Point 2 0.00 1,282.71 2,722.81 6,009,722.01 532,023.66 Point 3 0.00 1,782.50 3,048.78 6,010,223.03 532,347.63 Point 4 0.00 1,282.71 2,722.81 6,009,722.01 532,023.66 3K -09B t1 0.00 0.00 6,666.00 - 140.90 2,077.16 6,008,296.02 531,383.67 70° 26' 1.392 N 149° 44' 38.977 W - plan hits target center - Point 3K -09B t3 0.00 0.00 6,659.00 385.55 2,481.28 6,008,824.00 531,785.68 70° 26' 6.568 N 149° 44' 27.113 W - plan hits target center - Point 3K -09B t6 0.00 0.00 6,628.00 1,400.79 2,698.31 6,009,839.98 531,998.69 70° 26' 16.552 N 149° 44' 20.734 W - plan hits target center - Point 3K -09B t2 0.00 0.00 6,653.00 96.31 2,283.12 6,008,534.01 531,588.68 70° 26' 3.724 N 149° 44' 32.931 W - plan hits target center - Point 3K -09B, BL1 Polygon 0.00 0.00 0.00 - 194.24 1,907.94 6,008,242.02 531,214.67 70° 26' 0.868 N 149° 44' 43.943 W - plan misses target center by 6587.25ft at 7200.00ft MD (6587.12 TVD, - 167.18 N, 1939.62 E) - Polygon Point 1 0.00 - 194.24 1,907.94 6,008,242.02 531,214.67 Point 2 0.00 -28.19 1,900.58 6,008,408.03 531,206.66 Point 3 0.00 305.87 2,151.90 6,008,743.04 531,456.64 Point4 0.00 613.60 2,488.13 6,009,052.06 531,791.63 Point 5 0.00 932.94 2,666.39 6,009,372.06 531,968.61 Point6 0.00 1,104.18 2,610.05 6,009,543.06 531,911.61 Point 7 0.00 1,410.84 2,448.22 6,009,849.05 531,748.59 Point 8 0.00 1,859.69 2,498.97 6,010,298.06 531,797.57 4/5/2010 9:16 :01AM Page 6 COMPASS 2003.16 Build 69 1 N is_ . L i • . ConocoPhillips 13 a ConocoPhillips Planning Report BAKER Alaska HUGHES Database: = EDM Alaska Prod v16 Local Co- ordinate Reference: = - Site Kuparuk 3K Pad Company: ConocoPhillips(Alaska) Inc. TVD Reference: - Mean Sea Level Project • Kuparuk River Unit MD Reference: 3K -09 © 69.00ft (3K -09) Site: Kuparuk 3K Pad North Reference: True Well: 3K Survey Calculation Method: - Minimum Curvature Wellbore: 3K Design: - 3K 09B_wp06 Point 9 0.00 2,376.14 2,913.01 6,010,816.08 532,209.54 Point 10 0.00 2,085.13 3,165.91 6,010,526.09 532,463.55 Point 11 0.00 1,828.97 2,939.89 6,010,269.07 532,238.56 Point 12 0.00 1,612.44 2,815.04 6,010,052.07 532,114.58 Point 13 0.00 1,441.38 2,825.38 6,009,881.07 532,125.59 Point 14 0.00 1,202.78 2,973.47 6,009,643.08 532,274.60 Point 15 0.00 798.56 3,017.91 6,009,239.08 532,320.62 Point 16 0.00 368.35 2,802.22 6,008,808.07 532,106.65 Point 17 0.00 112.52 2,495.19 6,008,551.06 531,800.65 Point 18 0.00 - 233.37 2,197.82 6,008,204.04 531,504.68 Point 19 0.00 - 194.24 1,907.94 6,008,242.02 531,214.67 3K -09B t4 0.00 0.00 6,639.00 753.39 2,782.76 6,009,192.99 532,085.69 70° 26' 10.185 N 149° 44' 18.262 W - plan hits target center - Point Casing Points Measured Vertical - Casing Hole Depth - Depth Diameter Diameter (ft) (ft) Name ( "Y'' - 3,172.00 3,100.46 10 3/4" 10 -3/4 13 -1/2 9,975.00 6,671.89 2 3/8" 2 -3/8 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S W (ft) (ft) eft) " (ft) Comment 7,200.00 6,587.12 - 167.18 1,939.62 TIP / KOP 3K -09A 7,215.00 6,599.68 - 167.23 1,947.81 End of DLS 20 7,265.00 6,634.79 - 167.42 1,983.02 3 7,379.85 6,665.25 - 136.35 2,085.66 End of DLS 42 7,729.85 6,653.04 132.85 2,296.59 5 7,904.85 6,656.30 287.02 2,377.25 6 8,054.85 6,658.93 388.88 2,486.49 7 8,254.85 6,651.67 531.39 2,624.53 8 8,354.85 6,644.79 609.61 2,686.16 9 8,529.85 6,638.80 753.96 2,783.18 10 8,729.85 6,647.40 948.09 2,823.91 11 8,904.85 6,654.77 1,119.22 2,793.19 12 9,004.85 6,645.99 1,210.23 2,753.16 13 9,204.85 6,628.15 1,400.24 2,698.39 14 9,424.85 6,634.37 1,616.13 2,728.41 15 9,534.85 6,640.66 1,722.26 2,755.68 16 9,975.00 6,671.89 2,072.40 2,994.05 TD 4/5/2010 9:16:01AM Page 7 COMPASS 2003.16 Build 69 • Acmrm.roTmaNarm WELLBORE DETAILS: 3K-09B REFERENCE INFORMATION Project: Kuparuk River Unit Magn.hc North :21.65° Mal Site: Kuparuk3K Pad MagnGeFak Parent Wellbore: 3K -09A Co-ordinate (WE) Reference: We113K -09, True North \.^' Well: 3K -09 Strength 5rhriean Tie on MD: 7200.00 Vertical (TVD) Reference: Mean Sea Level BAKER /'' • Wellbof@: 3K-096 Did Modal: 809 0 ei° Sechon(VS) Reference: Sbt- (0.00N, 0.00E) ConocoPhillips PIan:3K-09B wp06(3K- 09/3K -09B) Ma as Measured Depth Reference: 3K -09 @ 69.00 (311-09) Calculation Method: Minimum Curvature HUGHES 2800 2600 WELL DETAILS: 3K -09 3K- 09/3K -09B Ground Level: 0.00 2400 - - • - +N / - +E/ -W Northing Easting Latitude Longitude Slot - TD ' 0.00 0.00 8008228.65 529305.92 70° 26' 0.812 N 149° 45' 39.980 W : , 2200 SECTION DETAILS ANNOTATIONS -- - - 2000 Sec MD Inc Azi TVDSS +N/-S +E/ -W DLeg TFace VSec Target Annotator f : 1 7200.00 31.59 90.32 6587.12 32.93 1940.66 0.00 0.00 850.00 TIP /KOP3K -09A 1500 2 7215.00 34.59 90.32 6599.68 32.89 1948.85 20.00 0.00 853.42 End of DLS 20 3 7265.00 55.59 90.32 6634.79 32.69 1984.06 42.00 0.00 868.13 3 R 4 7379.85 93.80 59.03 6665.25 63.76 2086.71 42.00 316.00 939.67 End of DLS 42 r 1600 5 7729.85 90.02 17.17 6653.04 332.97 2297.64 12.00 265.80 1272.79 5 6 7904.85 87.87 38.07 6656.30 487.14 2378.29 12.00 96.00 1446.60 6 ° 01 aoo 7 8054.85 90.13 55.93 6658.93 589.00 2487.53 12.00 83.00 1585.09 7 • 8 8254.85 93.97 32.22 6651.67 731.51 2625.58 12.00 279.50 1772.59 8 12 9 6354.85 93.88 44.25 6644.79 809.73 268720 12.00 90.00 1869.52 9 +1200 11 10 8529.85 90.00 23.59 6638.60 954.07 2784.22 12.00 259.80 2041.34 10 11 8729.85 85.14 0.06 6647.40 1148.20 2824.95 12.00 258.00 2234.50 11 p 1 000 10 12 8904.85 90.08 339.62 6654.77 1319.33 2794.23 12.00 283.00 2376.61 12 13 9004.85 100.00 332.84 6645.99 1410.34 2754.20 12.00 326.00 2442.18 13 9 14 9204.85 90.12 354.83 6628.15 1600.35 2699.44 12.00 113.00 259124 14 800 8, 15 9424.85 86.69 21.02 6634.37 181624 2729.45 12.00 97.70 2799.59 15 .5 16: 9534.65 86.78 7.80 6640.66 1922.37 2756.72 12.00 270.00 2907.30 16 0 600 7 , 17 9975.00 85.67 60.73 6671.89 2272.51 2995.09 12.00 93.00 3325.37 TD cA End of DLS 42 6, L __' _.___ _ ____. - _ _ __._ _ 400 End of DLS 20` 5' . 200 T1P /KOP3K -09A ` ` - 09/3K -09 ' - 3 ' 0 m. -200 ' . ^ 47,....., , 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 vro 6240- - West(- )/East( +) (200 ft /in) - - - r 6320- , ' ' , : ' , 6400- •^. 6480 _ • T1P /KOP3K -09A 6560_ i • .„ End of DLS 20 ` - -• 6640- 3 - r CI 3 6720- End of DLS 42 5 6 71 ', 8 9 11 12 ]3 p CO 3K- 09/3K -09B • m 6800_ - 6880a i F'" 6960 ;1:- u'uiJ ( I i ; 3K- 09/3K -09- .J 7040- � ' i, 7120 560 640 7 800 880 960 1040 1120 1200 1280 1360 1440 1520 1600 1680 17 2400 0 2 6 8 n _ 00 720 60 1840 1920 2000 2080 2160 2240 2320 2400 2480 2560 2640 2720 2800 2880 2960 3040 3120 3200 3280 3360 3440 3520 3600 Vertical Section at 25.00° (80 ft /in) • R ECE VED :t r oct�Phi lips APR 0 9 2010 Alaska P.O. BOX 100360 C ( flI$SI ANCHORAGE, ALASKA 99510 -0360 Alaska al&Gas Coos. Anchorage April 6, 2010 Commissioner- State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an application for permits to drill a quadrilateral out of the Kuparuk Well 3K -09A using the coiled tubing drilling rig, Nabors CDR2 -AC. Two of the CTD laterals will be drilled in a northeasterly direction and will target the A -sands in the fault blocks • containing the 3K -05 and 3K -07 injection wells. The other lateral pair will be drilled in a southwesterly direction across a highly baffling fault into the fault block containing the 3K -12 injection well. The original motherbore perforations will be cement squeezed prior to CTD operations and it is expected that the exposure to the reservoir in the near wellbore region from the CTD laterals will be sufficient to replace motherbore production. Attached to this application are the following documents: - Permit to Drill Application Forms for 3K -09B, 3K- 09BL1, 3K- 09BL2, and 3K- 09BL2 -01 - Detailed Summary of Operations - Proposed Schematic - Directional Plans - BOP Schematic If you have any questions or require additional information please contact me at 907 - 265 -1102. Sincerely, „. 52-,-,fr ee - e _ James Ohlinger Coiled Tubing Drilling Engineer • e, ` .:i it \\I d7 • • TRANSMITTAL LETTER CHECKLIST WELL NAME S ' �� T PTD# � — /Z-' (- L f —C 2 k /Development Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: (71e cc � - ti� c POOL: I�t V: 72 . 1 c. - �f __ !� /��_c_ t` (J Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- - - API number are between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / 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 • • 0 0) a) a V) N co a) o U a) c Q I ° 1 a 1 w 717 1 m I 0. p, o a a 0! 3 o O' 4 as W, E >-c E, p 1 0 u v O' 0 I y r ui' a) I ay E, N, 0, p 0 c W ) co E O m, 0 ) c o a), c 0 E. 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