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Home My WebLink About208-111 STATE OF ALASKA KRU 2X-19A ' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon E Plug Perforations r Fracture Stimulate E Pull Tubing r Operations Shutdown E Performed: Suspend E Perforate E Other Stimulate p n Alter Casing r Change Approved Program Plug for Redrill fl Perforate New Pool I-.. Repair Well E Re-enter Susp Well E Other: Marcie Gel Jol> F 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory r 208- .L` _ 3.Address: 6.API Number: e,Alaska 99510 Stratigraphic Service E P. O. Box 100360,Anchorage, 50-029-22618-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25645,ADL 25642,ADL 25644 KRU 2X-19A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 10913 feet Plugs(measured) None true vertical 5872 feet Junk(measured) None Effective Depth measured 10844 feet Packer(measured) 8829 true vertical 5871 feet (true vertical) 5738 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 121 121 SURFACE 5750 7 5/8 5791 3899 INTERMEDIATE 9474 51/2 9512 5742 RECEIVED SLOTTED LINER 2032 2 3/8 10878 5755 OCT 062016 Perforation depth: Measured depth: 8951 SCANNED FEB 2 3 2017 AOGCC True Vertical Depth: 5710 Tubing(size,grade,MD,and TVD) 3.5, L-80, 8851 MD,5754 ND Packers&SSSV(type,MD,and TVD) PACKER-BAKER FAB-1 PERMANENT PACKER @ 8829 MD and 5738 ND SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): none 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 - - 0 0 Subsequent to operation Shut-in - - 0 0 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory E Development F Service E Stratigraphic Copies of Logs and Surveys Run T 16.Well Status after work: Oil F Gas L- WDSPL IT Printed and Electronic Fracture Stimulation Data IT GSTOR IT WINJ r WAG E GINJ r SUSP I- SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-446 Contact Mike(c l 265-1032 Email Michael.C.Hazenaconocophillips.com Printed Name Mike Haz Title Staff Wells Engineer Signature / - Phone:265-1032 Date j Oho II to v Ti-- tO /VV1 l RBDMS Le.-- OCT 1 0 Form 10-404 Revised 5/2015 �o�2/fib 2016 Submit Original Only aoczo I/ 2X- 1 9A DTTMSTAFJOBTYP SUMMARYOPS 9/11/16 ANNCOMM MIRU. RIH W/WEATHERFORD 3.5" LOWER WP LE PACKER (SER# CP350127). SET MIDDLE ELEMENT OF PACKER AT 8780', CCL TO ME = 11.2', CCL STOP DEPTH = 8768.8'. LOG CORRELATED TO SLB LEAK DETECT LOG DATED 06-SEP-2016. POOH. RDMO. 9/12/16 ANNCOMM RAN 3 1/2 ER TEST TOOL TO LOWER PACKER @ 8780' RKB GOOD CMIT TO 2500 PSI. SET 2.76 UPPER PATCH ASSEMBLY© 8750' RKB (OAL 30.32' 1.75" ID, MIT- IA TO 2500 PSI, PASS. READY FOR GEL JOB. 9/14/16 Conformance Pumped step-rate injection test(seawater): Polymer 1000-BWPD, 38-bbl, 0-psi WHP Treatment 2000-BWPD, 77-bbl, 0-psi WHP 3000-BWPD, 125-bbl, 0-psi WHP Pumped MARCIT and Cap-It crosslinked polymer gel treatment*: 211-bbl 5000-ppm MARCIT 509-bbl seawater 545-bbl 5000-ppm MARCIT 230-bbl 7000-ppm MARCIT 116-bbl 9000-ppm MARCIT 291-bbl 28,000-ppm MARCIT(Cap-It) 59-bbl 30,000-ppm MARCIT(Cap-It) 8-bbl sea water flush with breaker(12.5% sodium hypochlorite) 57-bbl sea water flush 17-bbl diesel freeze protect Total Volume: 2283-bbl *NALCO Champion Pump Reports and gel videos attached to WSR. 9/17/16 Conformance FREEZE PROTECT- PUMP 17 BBLS DSL DOWN TBG Polymer JOB COMPLETE Treatment " KUP PROD 2X-19A Con©coPhiltips A Well Attributes Max Angle&MD TD Alaska.lEtc• Wellbore API/UWI Field Name Wellbore Status Inc!7) MD(ftKB) Act atm(ftKB) Cenor9Ptaatps_'' 500292261801 KUPARUK RIVER UNIT PROD l 96.31 9,925.38 10,914.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2X.196 10/5/20162x1749 PM SSSV:NIPPLE 150 11/19/2015 Last WO: 45.50 11/17/1995 vertical Schemptic(ecluel) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ......................._........._...................... Last Tag: Rev Reason:SEE NOTES pproven 10/5/2016 q HANGER;36.4 /Nil Casing Strings - Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 43.0 121.0 62.58 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 7 5/8 6.875 41.0 5,790.9 29.70 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread { - INTERMEDIATE 51/2 4.950 38.5 9,512.2 5,741.6 15.50 L-80 LTCMOD a41 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ,• „ , , ;,,;,u,WINDOW 5 2.740 8,926.0 8,931.0 5,696.4 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread •M7CONDUCTOR;43.0-121.0+' 1 II .n SLOTTED LINER 23/8 1.995 8,846.0 10,877.7 5,754.7 4.60 L-80 ST-L Liner Details NIPPLE;1,903.7 es I Top(ftKB) Top(TVD)(91(B) Nominal ID Top Incl 7) Item Des Com (in) 8,846.0 DEPLOY SLV BAKER DEPLOYMENT SLEEVE 1.920 GAS LIFT;3,491.8 III 10,844.6 5,754.3 89.67 0-RING BAKER 0-RING SUB 1.000 � Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..'Set Depth(TVD)(...Wt(Ib//t) Grade Top Connection TUBING 31/2 2.992 36.4 8,851.3 9.30 L-80 ABM-EUE Completion Details Nominal ID Top(MB) Top(TVD)(ftKB) Top Incl 7) Item Des Com (in) 36.4 HANGER FMC GEN IV TUBING HANGER 3.500 SURFACE;41.0-5,790.9+ 1,903.7 NIPPLE CAMCO BP-61 HYDRAULIC LANDING NIPPLE w/1.562" 2.812 D DUMMY 8,812.9 SEAL ASSY BAKER SEAL ASSEMBLY(NO GO) 3.000 GAS LIFT;8,907.4 l 8,814.3 PBR BAKER 80-40 PBR 10'STROKE 3.000 till 8,827.8 ANCHOR BAKER 40FA36 KBH ANCHOR SEAL ASSEMBLY SEAL 3.000 GAS LIFT;8,038.1 t, 8,828.5 PACKER BAKER FAB-1 PERMANENT PACKER 3.000 8,839.8 NIPPLE CAMCO'D'NIPPLE 2.750 I. I 8,850.5 WLEG WIRELINE ENTRY GUIDE(WLEG&WHIPSTOCK 2.992 I COVERED BY S/T LINER) GAS UFT;9,757.1 ', `p01 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) PATCH;8,750.0 • Top(TVD) Top Incl 1 Top(ftKB) (ftKB) 7) Des Corn Run Date ID(in) 8,750.0 PATCH 2.76 UPPER PATCH ASSEMBLY @ 8750'RKB 9/12/2016 1.750 (OAL 30.32 1.75"ID) ( 8,780.0 PATCH WDF 3.5"LOWER WP LE PACKER.OAL=24'- 9/11/2016 1.750 PATCH;8.789.0 - MIDDLE ELEMENT OF PACKER AT 8780'(SER# CP350127) 8,927.0 5,693.5 43.02 WHIPSTOCK BAKER GEN II TTRW WHIPSTOCK,ORIENTED 8.1 7/1/2008 0.000 SEAL ASSY;8,812.9 -THRU TBG DEGREE LEFT OF HIGH SIDE-SET ABOVE TOC IN ORIGINAL WELLBORE PBR;8,814.3 Perforations&Slots ANCHOR SEAL;8,827.8 '.14 Shot PACKER;8,828.5 Top(ND) Btm(ND) (sh Dens •aaa'? Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t( Type Com 8,951.0 10,844.0 5,710.1 5,754.3 C-3,C-4,C-3, 5/27/2009 32.0 SLOTS 2 3/8"SLOTTED LINER Rai 2X-19A NIPPLE;9,839.E estIN Mandrel Inserts St on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 3,491.8 BST AXT 1 GAS LIFT DMY T-1 0.000 0.0 8/31/2016 5.00 2 6,907.4 BST AXT 1 GAS LIFT DMY T-1 0.000 0.0 8/31/2016 11:30 WLEG;8,850.5 !,'.1 3 8,036.1 BST AXT 1 GAS LIFT DMY T-1 9/1/2016 8:30 RI HIGH SEAL PKG 4 8,757.1 BST AXT 1 GAS LIFT OPEN 9/9/2016 11:30 Notes:General&Safety I End Date Annotation 5/28/2009 NOTE:WELL SIDETRACKED WINDOW;8,926.0-8,931.0 WHIPSTOCK-THRU TBG; 9/15/2016 -NOTE:Pumped 1107-BBL 3k-9k-ppm MARCIT gel(including 350-BBL 30k-ppm Cap-It)treatment- 8,927.0 1 9/18/2016 NOTE:targeting the slotted liner zones below 10500'MD(571511/0)15-18 September 2016. I II I I I I INTERMEDIATE;38.5-9,5122 SLOTS;8851.0-10,844.0 SLOTTED LINER;8,848.0- 10,877.7 A.%if 1.1V k,m J STATE OF ALASKA O C T 0 4 2016 ALAIDA OIL AND GAS CONSERVATION COMWION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed. Suspend r Perforate r Other Stimulate r Alter Casing 9 r Change Approved Program " Rug for Redrill r Perforate New Pool r Repair Well FY Re-enter Susp Well r Other: tbg patch 1.70 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p- Exploratory r 208-1110 3.Address: 6.API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service r 50-029-22618-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25642/25644/25645 KRU 2X-19A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 10913 feet Plugs(measured) none true vertical 5872 feet Junk(measured) none Effective Depth measured 10878 feet Packer(measured) 8750, 8780, 8829 true vertical 5755 feet (true vertical) 5680, 5702, 5738 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78' 16 121' 121' SURFACE 5750' 7 5/8 5791' 3899' INTERMEDIATE 9474' 51/2 9512' 5872' LINER 2032' 2 3/8 10878' 5755' Perforation depth: Measured depth: 8951'-10844' • --,•,) Et3 , a r°, 7 CAM 2 �_i , True Vertical Depth: 5710'-5754' Tubing(size,grade,MD,and ND) 3 1/2 ,L-80, 8851 MD, 5754 TVD Packers&SSSV(type,MD,and ND) NIPPLE=CAMCO BP-61 HYDRAULIC LANDING NIPPLE w/1.562" ID DUMMY @ 1904 MD, 1714 TVD PATCH =2.76 UPPER PATCH ASSEMBLY @ 8750' RKB(OAL 30.32' 1.75" ID)@ 8750 MD,5680 TVD PATCH =WDF 3.5"LOWER WP LE PACKER. MID ELEMENT OF PKR AT 8780'@ 8780 MD, 5702 TVD PACKER=BAKER FAB-1 PERMANENT PACKER @ 8829 MD and 5738 TVD 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): 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 N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations rY Exploratory r Development Pr Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Kelly Lyons/Brent Rogers Email: n1617(a conocophillips.com Printed Name ell. ons Title: Problem Wells Supervisor Signature 7 / Phone:659-7224 Date / 0 —/_/ (o 1/-7-1- /c /6 21 1 (° Form 10-404 Revised 5/2015 i"` 10//z4 Submit Original Only RBDMS t- - OCT 1 0 2016 • • Nov ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 October 1, 2016 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Foerster: Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. development well 2X-19A (PTD 181-065) for a retrievable patch set in the tubing above the packer. Please call Brent Rogers or myself @ 659-7224 if you have any questions. Sincerely, 4110 Kelly Lyons ConocoPhillips Problem Well Supervisor Enclosures • 2X-19A • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 08/30/16 TAGGED LINER @ 8846' RKB W/2.5" BAILER. MEASURED BHP @ 8840' RKB. BRUSHED& FLUSHED TBG 2.76"TO 8840' RKB. SET 2.75" CA-2 PLUG @ 8840' RKB. ATTEMPTED PT TBG, FAILED W/TBG x IA COMMUNICATION. SET BAITED PULLING TOOL ON PLUG. PULLED OV FROM 8036' RKB. IN PROGRESS. 09/06/16 PERFORM LEAK DECT LOG. RUN BASELINE PASS FROM SURFACE TO 8840' (TOP OF PLUG), LRS ESTABLISH LLR AT .3 BBL/MIN. LOG UP, LEAK DISCOVERED AT GLM#4 (8757') PERFORM 80 PFM UP DOWN PASS AND STOP COUNT ABOVE AND BELOW GLM #4.. DROP DOWN TO PLUG AND RESUME LOGGING UP 120 FPM. NO OTHER LEAKS FOUND. LAY DOWN FOR NIGHT. ***JOB IN PROGESS*** 09/11/16 MIRU. RIH W/WEATHERFORD 3.5" LOWER WP LE PACKER (SER#CP350127). SET MIDDLE ELEMENT OF PACKER AT 8780', CCL TO ME = 11.2', CCL STOP DEPTH = 8768.8'. LOG CORRELATED TO SLB LEAK DETECT LOG DATED 06-SEP-2016. POOH. RDMO. 09/12/16'RAN 3 1/2 ER TEST TOOL TO LOWER PACKER @ 8780' RKB GOOD CMIT TO 2500 PSI. SET 2.76 UPPER PATCH ASSEMBLY @ 8750' RKB (OAL 30.32' 1.75" ID, MIT- IA TO 2500 PSI, PASS. READY FOR GEL JOB. MIT IA PRE T/I/O= 180/0/240, INITIAL T/I/O= 200/2500/520, 15 MIN T/I/O= 180/2480/480, 30 MIN T/I/O= 180/2480/240********PASS******* Summary Set 30'Weatherford retrievable tubing patch from 8750'-8780'. Patch was set across leaking GLV at 8757' and was tested with a MITIA to 2500psi. KUP PROD • 2X-19A e ConocoPhillips .. . Well Attributes Max Angle&MD TD . Alaska,Inc. Wellbore APIIUWI Held Name Wellbore Status !noir) MD(ftKB) Act Btm(ftKB) t_ ,em 500292261801 KUPARUK RIVER UNIT PROD 96.31 9,925.38 10,914.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2X-19A 9/1320164:31:51 PM SSSV:NIPPLE 150 11/19/2015 Last WO: 45.50 11/17/1995 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date .._............................................................. Last Tag: Rev Reason:H2S,GLV C/O,SET PATCH pproven 9/13/2016 HANGER;36.4 ;- •� easing Strings 1-1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len II...Grade Top Thread SURCONDUCTOR 16 15.062 43.0 121.0 62.58 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(MB) Set Depth(ND)... Wt/Len(I...Grade Top Thread SURFACE 7 5/8 6.875 41.0 5,790.9 29.70 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...'Wt/Len(I...Grade Top Thread • INTERMEDIATE 5 1/2 4.950 38.5 9,512.2 5,741.6 15.50 L-80 LTCMOD - ,g J.. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread M,.,.,.,„"'.m.,,,.,,„^,^'a1,•^111.r >�SLOTTED LINER OD(I 2 3/8 ID(in) Top11KB)8,846.0 Set Depth(fKB)10,877.7 Set Depth(18547 WINDOW 5 2.740 8,926.0 8, 1. 1 III MWt/Len(I...Grade Top Thread CONDUCTOR;43.0-121.0” 54.60 L-80 ST-L Liner Details Ma Nominal ID NIPPLE;1.903.7timi Top(ftKB) Top(ND)(ftKB) Top Incl(') Item Des Corn (in) AM ® 8,846.0 DEPLOY SLV BAKER DEPLOYMENT SLEEVE 1.920 10,844.6 5,754.3 89.67 0-RING BAKER 0-RING SUB 1.000 GAS LIFT;3,491.8 Tubing Strings Tubing Description 'String Ma...I ID lin) I Top(ftKB) I KB) I Set Depth(ft..Set Depth(ND)(...I Wt(lb/ft) I Grade I Top Connection TUBING 31/2 2.992 364 8,851.3 9.30 L-80 ABM-EUE Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl 1") Item Des Com (in) 36.4 HANGER FMC GEN IV TUBING HANGER 3.500 SURFACE;41.0-5,790.9 1,903.7 NIPPLE CAMCO BP-61 HYDRAULIC LANDING NIPPLE w/1.562" 2.812 ID DUMMY 8,812.9 SEAL ASSY BAKER SEAL ASSEMBLY(NO GO) 3.000 GAS LIFT;6,907.4 8,814.3 PBR BAKER 80-40 PBR 10'STROKE 3.000 I 8,827.8 'ANCHOR BAKER 40FA36 KBH ANCHOR SEAL ASSEMBLY 3.000 SEAL GAS LIFT;8,036.1 Ii 8,828.5 PACKER BAKER FAB-1 PERMANENT PACKER 3.000 • 8,839.8 NIPPLE CAMCO'D'NIPPLE 2.750 I 8,850.5 WLEG WIRELINE ENTRY GUIDE(WLEG&WHIPSTOCK 2.992 COVERED BY SIT LINER) GAS LIFT;e,7571 I Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) PATCH;8,750.0 Top(ND) Top Incl Top(ftKB) (ftKB) (3 Des Com Run Date ID(In) 8,750.0 PATCH 2.76 UPPER PATCH ASSEMBLY©8750'RKB 9/12/2016 1.750 (OAL 30.32'1.75"ID) PATCH;8.780.0 I 8,780.0 PATCH WDF 3.5"LOWER WP LE PACKER.OAL=24'- '9/11/2016 1.750 MIDDLE ELEMENT OF PACKER AT 8780'(SER# I CP350127) 8,927.0 5,693.5 43.02 WHIPSTOCK BAKER GEN II TTRW WHIPSTOCK,ORIENTED 8.1 '7/1/2008 0.000 SEAL ASSY;8,812.9 -THRU TBG DEGREE LEFT OF HIGH SIDE-SET ABOVE TOC IN ORIGINAL WELLBORE PBR;8,814.3 ) ( Perforations&Slots ANCHOR SEAL;8,827.8 I Shot I ';c Dens PACKER;8,828.5 Top(ND) Btm(ND) (shots/f •sa• Top(ORB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 8,951.0 10,844.0 5,710.1' 5,754.3 C-3,C-4,C-3, 5/27/2009 32.0 SLOTS 2 3/8"SLOTTED LINER 2X-19A NIPPLE;8.839.6 s i Mandrel Inserts St ati on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ft613) Make Model OD(in) Sery _ Type Type (in) _ (psi) Run Date Cam 1 3,491.8 BST AXT 1 GAS LIFT DMY T-1 0.000 0.0 8/31/2016 5:00 2 6,907.4 BST AXT 1'GAS LIFT DMY T-1 0.000 0.0 8/31/2016 11:30 WLEG;8,850.5 3 8,036.1 BST AXT 1 GAS LIFT DMY T-1 • 9/1/2016 8:30 HIGH SEAL PKG 4 8,757.1 BST AXT ' 1-GAS LIFT 'OPEN 9/9/2016 11:30 k_ Notes:General&Safety End Date Annotation 5/28/2009 NOTE:WELL SIDETRACKED WINDOW;8,926.0-8,931.O- WHIPSTOCK-THRU TBG; 8,927.0 L —. r INTERMEDIATE;38.5-9.512.2 SLOTS;8,951.0-10,844.0 SLOTTED LINER;8,846.4 10,877.7 • • aJ z / O° _ I-O X ra l r d O v E N v v V] IPo L_a, = � ° l rco _ �n O N E aJ O ''' u ,, 4-, > -05 C CD ro y O vl CU L +' a a` o. 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(1)C a t0 O VC Z /1.4 ' L >m C N GW co J a a J am fa \V0 d a Ua U a g O Q 0 • ` w ao U V;U I0 . ' (i) lani 1 + C7 > 0• 0nD 0 41 0 - 13 a O c. z 1 (IS 7t1" W O coo: - a J J J J J J J J J I 1t{ — ror� 'a ar � � 3 � 33 � � � • Lia It ....42/11 1113.....,Pr'It E W W W W W W W W W > > > > > > > > > u z Y Y Y Y Y Y Y Y Y � ❑ a' a• ' w a' a' a' x a' ce a) w W a) T Q Q Q Q Q Q Q Q Q > a ,,, aaaaaaaa 1 .' > > > > > > > > �. Ia u Cil Y = Y Y Y Y Y Y Y C c as ra uiCD W in co N 00 W co M N X In .-� C=I 0 N N N in I) l0 cD CO CO E cv • 0 o 0 o o 0 0 0 0 a) 0 0 0 0 0 0 0 0 0 LIMAN GLS - LL LL LL LL U. LL lL LL. LL M 11111 j Pi j H F- F F F- H H F F- t9 (1' fa- W ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ c (Le) W VVI x V1 rou 0 0 0 0 0 0 0 0 0 to 11: ^Zr r r; co co Ln d ui co E o rn e- r) CO N N L 0 (I�`1 e- e- cD cD CO CO O LO Q 0 N N N N N N N N N Ni _L I•: Q) O O O T T O O T - N p N N N N N N N N N � • Q1 0 0 O O O 0 0 O O 3 0 0 0 0 0 0 0 0 0a+ 0 a) C u) I() L() V) u) II) N141 u L ) Q. U !Q• ) �' > v C. E C c La u *� op 2cr 1:1Q N O O N O O O a70 te+ E v C = Y N E N J j X Q Q LL U , E co ` a i a Q N W N N N N N N Z N .Y rtS V/It I (13C O CO3 0- L� Q 3i I I 1 I I I I I H a` a . • ,ofTy h am-\\1%%y-w. THE STATE Alaska Oil and Gas ,,,,,,,...- -_-4->5:1-- a ofALAS KA Conservation Commission i- 2___ _ 333 West Seventh Avenue 1/4" GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 "'"4 Main: 907.279.1433 OF ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Michael Hazen Staff Wells Engineer ConocoPhillips Alaska, Inc. SC 014E � �A 01 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2X-19A Permit to Drill Number: 208-111 Sundry Number: 316-446 Dear Mr. Hazen: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, a-7 Cat P. Foerster Chair DATED this t 5 day of September, 2016. RBDMS L.''SEP - 1 2016 • • . • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS If*/3//e6 20 AAC 25.280 , OGGC 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: MARCIT GEL JOB • a 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. • Exploratory ❑ Development Q, 208-111 ` 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-029-22618-01 ' 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NONE / Will planned perforations require a spacing exception? Yes ❑ No ❑✓ J KRU 2X-19A 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25645, 025642, 025644 ' Kuparuk River Field/Kuparuk Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: 'Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10913' 5872' ' 10844' 5871' ' 175 NA NA Casing Length Size MD TVD Burst Collapse Conductor 121' 16" 121' 121' Surface 5791' 7-5/8" 5791' 3899' Intermediate 9507' 5-1/2" 9507' 6219' Liner(CTD) 2030' 2-3/8" 10877' 5872' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Slotted Liner 8951-10844' • 5709-5754' 3-1/2" L-80 8851' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Packer:Baker'FAB-1"@ 8828';CAMCO BP-61 nipple @ 1903' . Baker FAB-1 PermPkr 8828'MD,5588'TVD;No SSSV,nipple @ 1904'MD/TVD 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑., ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 9-Sep-16 Commencing Operations: OIL Q • WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Mike Hazen:265-1032 Email hazenmc@conocophillips.com Printed Name Michael C H Title Staff Wells Engineer 0812/1-zit:,( 4, Signature Phone 265-1032 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: -i--\e-' . 7:::. Post Initial Injection MIT Req'd? Yes ❑ No �[� Spacing Exception Required? Yes LiNo Subsequent Form Required: 1 o —4 l'T RBDMS L'-SEP - 1 2016 APPROVED BY / Approved by: 9I-e-€.054 COMMISSIONER THE COMMISSION Date:9—7/,6 1/7'( 8 3 1/l�O Submit Form and Form 10-4 Re ised 11/2015ttt t n vd for 12 months fro the date of approval. Attachments in Duplicate � � 1rct1 V Aono/16 • 1114 KUP 2X 19A ConocoPhillipS4 Well Attributes TMax Angle&MD ID ,,SI(2 l h1C Wellbore APUUWI Field N MKS)Status Incl(°) MD KB) Act Bt (11K13)500292261801 KUPARUK RIVER UNIT PROD 96.31 9,925.38 10,914.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(R) Rig Release Date Ala "' SSSV:NIPPLE 25 10/28/2011 Last WO: 45.50 11/17/1995 Well Con1-g-2X-19A.1 0/1 01201 2 to 1 5 15 AM Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:WELL REVIEW osborl 10/10/2012 Casing Strings HANGER,36 ' Casing Description String O.. String ID...Top(SOB) Set Depth(1...Set Depth(TVD).. String Wt..String String Top Thrd CONDUCTOR 16 15.062 43.0 121.0 121.0 62.58 H-40 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd SURFACE 75/8 6.875 41.0 5,790.9 3,584.4 29.70 L-80 BTCM Casing Description String 0... String ID...Top(ftKB) Set Depth(L.Set Depth(TVD)...String Wt...String...String Top Thrd INTERMEDIATE 51/2 4.950 38.5 9,512.2 5,741.6 15.50 L-80 LTCMOD Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(WD)...String Wt..String...String Top Thrd WINDOW 5 2.740 8,926.0 8,931.0 5,693.4 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(WD)...String Wt..String...String Top Thrd 119 1 SLOTTED LINER 2 3/8 1.995 8,846.0 10,877 7 5,754.7 4.60 L-80 ST-L Liner Details , CONDUCTOR, Top Depth 43-121 IND) Top Mel Nomi... Top(ftKB) (RKB) C) Item Description Comment ID(in) NIPPLE,1,904 8,846.0 5,603.0 -3.47 DEPLOY SLV BAKER DEPLOYMENT SLEEVE 1.920 10,844.6 5,754.4 89.58 0-RING BAKER 0-RING SUB 1.000 ,d Tubing Strings GAS LIFT. . Tubing Description String 0... String ID...Top(ftKB) Set Depth(1...Set Depth(TVD)... String Wt...String... String Top Thrd 3,492 TUBING 31/2 2.992 36.4 8,851.3 5,608.1 9.30 L-80 ABM-EUE Completion Details Top Depth (ND) Top Incl Nomi... Top(ftKB) (ftKB) C) Item Description Comment ID(in) 36.4 -1,453.6-4283...HANGER FMC GEN IV TUBING HANGER 3.500 1,903.7 1,903.7-3376...NIPPLE CAMCO BP-61 HYDRAULIC LANDING NIPPLE w/1.562"ID DUMMY 2.812 SURFACE. A A 8,812.9 5,578.0 -19.55 SEAL ASSY BAKER SEAL ASSEMBLY(NO GO) 3.000 41-5,791 8,814.3 5,578.8 -18.89 PBR BAKER 80-40 PBR 10'STROKE 3.000 W 8,827.8 5,587.6 -12.30 ANCHOR BAKER 40FA36 KBH ANCHOR SEAL ASSEMBLY 3.000 GAS LIFT,,907 SEAL 6 8,828.5 5,588.1 -11.96 PACKER BAKER FAB-1 PERMANENT PACKER 3.000 1, 8,839.8 5,597.4 -6.47 NIPPLE CAMCO'D'NIPPLE 2.750 GASBLI 8,850.5 5,607.3 -1.28 WLEG WIRELINE ENTRY GUIDE(WLEG 8 WHIPSTOCK COVERED BY 8/r 2.992 LINER) Other In Hole ireline retrievable plugs,valves,pumps,fish,etc.) GAS LIFT, lelfej Top Depth 8,757 (WD) Top Mel Top(ftKB) (ftKB) 11 Description Comment Run Date ID(in) 8,927.0 5,689.6 35.89 WHIPSTOCK- BAKER GEN II TTRW WHIPSTOCK,ORIENTED 8.1 7/1/2008 0.000 SEAL Assv, THRU TBG DEGREE LEFT OF HIGH SIDE-SET ABOVE TOC IN 8,813 ORIGINAL WELLBORE PBR,8,814 Perforations&Slots ANCHOR ---�— Shot SEAL,8,828 Top(TVD) Btm(TVD) Dens Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date (ah,,• Type Comment PACKER,8,829 8,951.0 10,844.0 5,709.9 5,754.4 C-3,C-4,C-3, 5/27/2009 32.0 SLOTS 2 3/8"SLOTTED LINER �,',...."'� 2X-19A Notes:Ge ral&Safety NIPPLE,8,840 -- It End Date Annotation 5/2812009 (NOTE:WELL SIDETRACKED ,r MEG.8,850 i. m WINDOW. 8,9268.931 WHIPSTOCK- 166 THRU TBG, 8,927 Mandrel Details Top Depth Top Port (TVD) Incl OD Valve Latch Sian TRO Run Stn Top(ftKB) (ftKB) C) Make Model (in) Sets Type Type (in) (psi) Run Date Corn... 1 3,491.8 3,491.8 -26...BST AXT 1 GAS LIFT OV T-1 0.250 0.0 6/11/2009 NTERMEDIATE, 2 6,907.4 6,907.4 -94...BST AXT 1 GAS LIFT GLV T-1 0.188 1,364.0 5/31/2009 389,512-N Al ' SLOTS, g i 3 8,036.1 4,977.9 -39...BST AXT 1 GAS LIFT OV T-1 0.250 0.0 5/31/2009 6,951-10,844 1 1 4 8,757.1 5,576.8 -46...BST AXT 1 GAS LIFT DMY T-1 0.000 0.0 6/29/2008 SLOTTED LINER, 8.84610,878 TD(2X-19A), 10.914 • • KRU 2X-19A Producer MARCIT Gel Treatment Kuparuk producer 2X-19A started with initial oil production of 700 bpd. Water cut, however, has consistently increased over time; last well test data shows 98.5% water cut with only 11 bpd of oil. Excess water production is believed to come from two faults near the toe of the well. Recent conductor line production profiles showed most of the fluid coming beyond 9800 ft. The objective of the treatment will be to shut off water production from the lower portion of the well (Below 9800') while still leaving good productivity in the heal section of the lateral. It is estimated that a maximum pressure build during the treatment should not exceed 1,000 psi in order to prevent excessive gel entry into the heal of the well where we expect our more oil productive intervals. The treatment will consist of a 1,200-3,200 bbls of high molecular weight (MW) Marcit gel to isolate the near wellbore water producing formation followed by 100 bbls of Cap-it ringing gel to isolate the wellbore internally below the target depth of 1070 ft MD.This project is planned to be executed in conjunction with the 1D-03 polymer conformance job to ensure operational efficiency. Procedure: Slickline: 1. RIH & drift as deep as possible. Set plug in D-nipple at 8839'MD. Set catcher sub and swap GLVs at 3491', 6907', 8036' to DMY VLVs. Pull the GLV at 8757'MD and circulate the IA and TBG to corrosion inhibited seawater and freeze protect. Install DMY VLV at 8757' and perform MIT-T and MIT-IA. Pull catcher and plug from 8839'MD. Pumping: 2. Pump a Step Rate Injection Test (SRIT) down tubing to verify 'baseline' injectivity at several injection rates between 1.3 - 3.5 bpm. Record stable rates vs. injection pressure. K-19A Polymer Gel Rate Schedule Tank Usable Volume 1440 bbl arget Rate 2880 bpd Tank Fill Rate 1 bpm Settling Time 240 min Target TargetPolymer Polymer 3 Tank Tar t Concentration PU 24 Rate Treatment Rate Total Treatment PU24 Pol Concentration Tank Drain Tank Fill Total Tank Difference (ppm) Design Volume(bbl) (bpd) (bpd) Dilution Rate Rate(bpm) (#/day) (Ppm) Days Dags/hr (min) (min) Fill(min) Drain (hr) (min) 5000 500-2300 2667 2880 0 2.00 5035 5400 0.1-0.5 3.8 778 1440 1680 2333 10.9 7000 300 2240 2880 0 2.00 7049 9000 0.1 5.3 926 1440 1680 2777 18.3 9000 200 2592 2880 0 2.00 9063 10000 0.1 6.9 800 1440 1680 2400 12.0 30000 200 1000 1000 0 0.69 10490 30000 0.2 7.9 2074 1440 1680 6221 75.7 Total 3000 31636 0.5-1 Constraints 8 bags/hr 4 hr settling time 4 bpm tank fill(17 ft/s) 3 hr difference bit 3 tank drain and 1 tank fill*settle time //�� 30000 ppm max out PU24 Z ` 3. MIRU polymer mixing unit and equipment as per approved job site rig-up plans. Pump—3,000 bbls of MARCIT Gel as follows: /\ Coil Tubing: ef-0 at c 111 4. RIH &jet out Gel from the wellbore to as deep as possible. POOH with CT. RD CTU. Return 2X-19A to ct orr MCH 8/29/2016 • • PTO Loepp, Victoria T (DOA) From: Hazen, Mike C <Michael.C.Hazen@conocophillips.com> Sent: Wednesday,August 31, 2016 11:44 AM To: Haggerty-Sherrod,Ann (Northland Staffing Services) Cc: Loepp,Victoria T(DOA) Subject: Re: KRU 2X-19A(PTD 208-111,Sundry 316-430)Withdraw Sundry Follow Up Flag: Follow up Flag Status: Flagged Good Afternoon, Thanks for this...l'm at the airport awaiting a flight to the Slope. I appreciate the help. Regards, Mike 2.017 Sent from my iPhone ` SED FEB 1. 5 On Aug 31, 2016,at 10:53 AM, Haggerty-Sherrod,Ann(Northland Staffing Services)<Ann.Haggerty- Sherrod@contractor.conocophillips.com>wrote: Thank you Victoria, I will withdraw Sundry 316-430 and await the replacement Sundry#316-446. I have copied Mike Hazen so that he will have a copy of this response for his records. Thanks for your help. Ann From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday,August 31,2016 10:34 AM To: Haggerty-Sherrod,Ann (Northland Staffing Services)<Ann.Haggerty- Sherrod@contractor.conocophillips.com> Subject: [EXTERNAL]FW: KRU 2X-19A(PTD 208-111,Sundry 316-430)Withdraw Sundry Ann, Please withdraw this sundry in Mike's absence. Thanx, Victoria From: Loepp, Victoria T(DOA) Sent: Wednesday, August 31, 2016 10:32 AM To: 'Hazen, Mike C' Subject: KRU 2X-19A(PTD 208-111, Sundry 316-430)Withdraw Sundry Mike, • Please respond to this email requesting to withdraw Sundry 316-430. The sundry has been replaced with Sundry 316-446. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp a(�.alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793- 1247 or Victoria.Loeop@alaska.gov 2 ' • • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AUG 2 2 2016 APPLICATION FOR SUNDRY APPROVALS qcc 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ erations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Ch a Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: MARCIT GEL JOB n 2.Operator Name: 4.Current Well Class: N)5.Permit Drill Number: 'a ConocoPhillips Alaska, Inc. ‘ Exploratory E] Development Ai ç Z 111 20874410 3.Address: Stratigraphic ❑ Service L ' 6. Number: P.O.Box 100360,Anchorage,Alaska 99510 50-029-22618-01 7.If perforating: �*ati.`� Wz Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA- N, ?/E \ Will planned perforations require a spacing exception? Yes ❑ No Q ✓/U, KRU 2X-19A 9.Property Designation(Lease Number): 10.Field/Pool(s): �J ADL 25642 iv. River Field/Kuparuk Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total De,It D(ft): Total D-• D Sft) : Effective Depth MD: Effective Depth TVD: MP :�r�si): Plugs(MD): Junk(MD): /0? 95, I IN 9098 6227 �� NA NA Casing Length Size MD a TVD Burst Collapse Conductor 80' 16" 121' a 121' Surface 5750' 7-5/8" 5791' a 3899' Intermediate 9466' 5-1/2" 9512'1. 6219' Liner(CTD) 2031' 2-3/8" 10877 5754' 4 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Si •: Tubing Grade: Tubing MD(ft): Slotted Liner 8951-10844' 5709-5754' 3- i' L-80 8851 Packers and SSSV Type: A 'ack: s and SSSV MD(ft)and TVD(ft): Packer:Baker'FAB-1"@ 8828';CAMCO BP-61 nipple @ 1903k , i 5588'; 1903' ,. 12.Attachments: Proposal Summary Q Wellb• e e' atic 13.Well Class after proposed work: 49 Detailed Operations Program ❑ BOP Sketch 41J Exploratory ❑ Stratigraphic❑ Development vi Service [ 1 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 9 S` ' OIL ❑� WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and t - procedure approved herein will not be deviated from without prior writ-n approval. Contact Mike Hazen:265-1032 Email hazenmc@conocophillips.com Printed Name Michael C H. Title Staff Wells Engineer i f. :.�.� 22 4U ! Signature �� --- Phone 265-1032 Date COM MFSSt'OT 'it ONLY Conditions of approval: Notify Commi•sion so that a representative may witness Sundry Number: t — 4(30 Plug Integrity ❑ -,IP Test LI Mechanical Integrity Test ❑ Location Clearance ❑ Other: 6 ��gg cc�� 17 StOt f l .S IV e� Post Initial Injection MIT q'd? Yes ❑ No ❑ ®®�� RBDMS 1.1--SEP - 1 2016 Spacing Exception Req red? Yes ❑ No ❑ Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: i Submit Form and Form 10-403 Revised 11/2015 QARoIe& li4oAlid for 12 months from the date of approval. Attachmentss in Duplicate • • KRU 2X-19A Producer MARCIT Gel Treatment Kuparuk producer 2X-19A started with initial oil production of 700 bpd. Water cut, however, has consistently increased over time; last well test data shows 98.5% water cut with only 11 bpd of oil. Excess water production is believed to come from two faults near the toe of the well. Recent conductor line production profiles showed most of the fluid coming beyond 9800 ft. The objective of the treatment will be to shut off water production from the lower portion of the well (Below 9800') while still leaving good productivity in the heal section of the lateral. It is estimated that a maximum pressure build during the treatment should not exceed 1,000 psi in order to prevent excessive gel entry into the heal of the well where we expect our more oil productive intervals. The treatment will consist of a 1,200-3,200 bbls of high molecular weight (MW) Marcit gel to isolate the near wellbore water producing formation followed by 100 bbls of Cap-it ringing gel to isolate the wellbore internally below the target depth of 10,000 ft MD.This project is planned to be executed in conjunction with the 1D-03 polymer conformance job to ensure operational efficiency. Procedure: Slickline: 1.RIH&drift as deep as possible.Set plug in D-nipple at 8839'MD.Set catcher sub and swap GLVs at 3491',6907',8036'to DMY VLVs.Pull the GLV at 8757'MD and circulate the IA and TBG to corrosion inhibited seawater and freeze protect. Install DMY VLV at 8757'and perform MIT-T and MIT- IA.Pull catcher and plug from 8839'MD. Pumping: 2.Pump a Step Rate Injection Test(SRIT)down tubing to verify'baseline'injectivity at several injection rates between 1.3-3.5 bpm. Record stable rates vs.injection pressure. (-19A Polymer Gel Rate Schedule Tank Usable Volume 1440 bbl arget Rate 2880 bpd Tank Fill Rate 1 bpm Settling Time 240 min a Target Concentration PU 24 Rate Treatment Rate Total Treatment Target Polymer PU24 Polymer Concentration 3 Days Bags/hr Tank Drain Tank Fill Total Tank Difference (Ppm) Design Volume(bbl) (bpd) (bpd) Dilution Rate Rate(bpm) (0/day) (PPm) (min) (min) Fill(min) DrTainnk (hr) (min) 5000 500-2300 2667 2880 0 2.00 5035 5400 0.1-0.5 3.8 778 1440 1680 2333 10.9 7000 300 2240 2880 0 2.00 7049 9000 0.1 5.3 926 1440 1680 2777 18.3 9000 200 2592 2880 0 2.00 9063 10000 0.1 6.9 800 1440 1680 2400 12.0 30000 200 1000 1000 0 0.69 10490 30000 0.2 7.9 2074 1440 1680 6221 75.7 Total 3000 31636 0.5-1 Constraints 8 bags/hr 4 hr settling time 4 bpm tank fill(17 ft/s) 3 hr difference b/t 3tank drain and ltank fill+settle time 30000 ppm max out PU24 3.MIRU polymer mixing unit and equipment as per approved job site rig-up plans. Pump^'3,000 bbls of MARCIT Gel as follows: Coil Tubing: 4.RIH&jet out Gel from the wellbore to as deep as possible.POOH with CT.RD CTU.Return 2X-19A to injection. MCH 8/22/2016 KU P 2X-19A COn000P11iIip5 •>i& ' Weil Attributes Max Angle&MD_TD Alaska Inc. Wellbore API/UWI Field Name Well Status Incl(°) MD(ftK8) Act Btm(ftKB) ,,,,,,,,,,,„4„. 500292261901 KUPARUK RIVER UNIT PROD 96.31 9,925.38 10914.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date "' SSSV:NIPPLE 25 10/28/2011 Last WO: 45.50 11/17/1995 Well Conng'.•20.19A.10/10/2012 10 15 15 AM ---- Schemattc-Actual Annotation Depth(RKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:WELL REVIEW osborl 10/10/2012 Casing Strings 1 HANGER.36 Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD).. String Wt...String.. String Top Thrd CONDUCTOR 16 15.062 43.0 121.0 121.0 62.58 H-40 WELDED Casing Description String 0... String ID...Top(ttKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd SURFACE 75/8 6.875 41.0 5,790.9 3,584.4 29.70 L-80 BTCM Casing Description String 0... String ID...Top(ttKB) Set Depth(f...Set Depth(ND)...String Wt..String...String Top Thrd INTERMEDIATE 51/2 4.950 38.5 9,512.2 5,741.6 15.50 L-80 LTCMOD Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt..String... String Top Thrd P WINDOW 5 2.740 8,926.0 8,931.0 5,693.4 Casing Description String 0... String ID...Top(560) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd SLOTTED LINER 2 3/8 1.995 8,846.0 10,877.7 5,754.7 4.60 L-80 ST-L ""finer Details CONDUCTOR. Top Depth 43-121 (TVD) Top Incl Noon... Top(ttKB) (ttKB) II Item Description Comment ID PN NIPPLE,1,904 ;� 8,846.0 5,603.0 -3.47 DEPLOY SLV BAKER DEPLOYMENT SLEEVE 1.920 10,844.6 5,754.4 89.58 0-RING BAKER 0-RING SUB 1.000 I 11:1:' Tubing Strings GAS LIFT, i Tubing Description String O... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt...l String... String Top Thrd 3.492 TUBING 31/2 2.992 36.4 8,851.3 5,608.1 9.30 I L-80 ABM-EUE Completion Details Top Depth T--_-- )TVD) Top Incl Nomi... Top(RKB) IRKS) (°) Item Description Comment ID(in) 36.4 -1,453.6-4283...HANGER FMC GEN IV TUBING HANGER 3.500 1,903.7 1,903.7-3376...NIPPLE CAMCO BP-61 HYDRAULIC LANDING NIPPLE w/1.562"ID DUMMY 2.812 SURFACE. A „ ik 8,812.9 5,578.0 -19.55 SEAL ASSY BAKER SEAL ASSEMBLY(NO GO) 3.000 41-5,791 8,814.3 5,578.8 -18.89 PBR BAKER 80-40 PBR 10'STROKE 3.000 8,827.8 5,587.6 -12.30 ANCHOR BAKER 40FA36 KBH ANCHOR SEAL ASSEMBLY 3.000 GAS LIFT, SEAL 6,907 In 1111, 8,828.5 5,588.1 -11.96 PACKER BAKER FAB-1 PERMANENT PACKER 3.000 8,839.8 5,597.4 -6.47 NIPPLE CAMCO'D'NIPPLE 2.750 GAS LIFT. — 8,850.5 5,607.3 -1.28 WLEG WIRELINE ENTRY GUIDE(WLEG 8 WHIPSTOCK COVERED BY S/T 2.992 LINER) Other In Hole Wireline retrievable plugs,valves,pumps,fish,etc,). ,,,„ ,, GAS LIFT. )i 'I Top Depth 8,757 a' (TVD) Top Incl Top(RKB) (RKS) (°) Description Comment Run Date ID(In) _ 8,927.0 5,689.6 35.89 WHIPSTOCK- BAKER GEN II TTRW WHIPSTOCK,ORIENTED 8.1 7/1/2008 0.000 SEAL ASSY, THRU TBG DEGREE LEFT OF HIGH SIDE-SET ABOVE TOC IN 8,813 ) f ORIGINAL WELLBORE PBR.8.814 Perforations&Slots Shot ANCHORril Top(TVD) Btm(TVD) SEAL,8,828 Dens Top(RKB)Btm(ftK8) IRKS) (MEI) Zone Date (oh-' Type Comment PACKER,8,829 8,951.0 10,844.0 5,709.9 5,754.4 C-3,C-4,C-3, 5/27/2009 32.0 SLOTS 2 3/8"SLOTTED LINER 2X-19A Notes:General&Safety NIPPLE,8,840 -. End Date Annotation 5/28/2020 09 NOTE:WELL SIDETRACKED I. WLEG,8,850 WI WINDOW, 8,9268,931\ WHIPSTOCK • k_ - THRU TBG, 8,927 Mandrel Details Top Depth Top Port (TVD) inOD Valve Latch Size TRO Run I Stn Top(ttKB) (RKB) (°) Make Model (in) Sew Type Type (in) (psi) Run Date Corn... 1 3,491.8 3,491.8 -26...BST AXT 1 GAS LIFT OV T-1 0.250 0.0 6/11/2009 NTERMEDIATE, 2 6,907.4 6,907.4 -94...BST AXT 1 GAS LIFT GLV T-1 0.188 1,364.0 5/31/2009 389,512 ) SLOTS. 3 8,036.1 4,977.9 -39...BST AXT 1 GAS LIFT OV T-1 0.250 0.0 5/31/2009 8,951-10.844 4 8,757.1 5,576.8 -46...BST AXT 1 GAS LIFT DMY T-1 0.000 0.0 6/29/2008 SLOTTED LINER, 8,846-10,878 TO(2X-19A), 10,914 • • Loepp, Victoria T (DOA) From: Haggerty-Sherrod,Ann (Northland Staffing Services) <Ann.Haggerty- Sherrod@contractor.conocophillips.com> Sent: Wednesday,August 31,2016 10:54 AM To: Loepp,Victoria T(DOA) Subject: RE: KRU 2X-19A(PTD 208-111, Sundry 316-430)Withdraw Sundry Thank you Victoria, I will withdraw Sundry 316-430 and await the replacement Sundry#316-446. I have copied Mike Hazen so that he will have a copy of this response for his records. Thanks for your help. • Ann From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday,August 31,2016 10:34 AM To: Haggerty-Sherrod,Ann (Northland Staffing Services)<Ann.Haggerty-Sherrod@contractor.conocophillips.com> Subject: [EXTERNAL]FW: KRU 2X-19A(PTD 208-111,Sundry 316-430)Withdraw Sundry Ann, Please withdraw this sundry in Mike's absence. Thanx, Victoria From: Loepp, Victoria T(DOA) Sent: Wednesday, August 31, 2016 10:32 AM To: 'Hazen, Mike C' Subject: KRU 2X-19A(PTD 208-111, Sundry 316-430)Withdraw Sundry Mike, Please respond to this email requesting to withdraw Sundry 316-430. The sundry has been replaced with Sundry 316- 446. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp analaska.Qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 1 • • c a) a) C7 0 0 x0 Q Q L !u N lL a) v O VP r _ arm CC Vi �, -C _C C p a_Y o z „o _( 0 92 O a Y io O ° (`� U 6. 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They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~Q 8 - ~ ~ 1- Well History File Identifier Organizing (done) RE AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: gY; aria Project Proofing gY; Maria Date: ~i 1 Scanning Preparation ~_ x 30 = gY; -Maria Date: Production Scanning o Re~~~,~~ iuiuiiisiuiuu OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: /s/ /s/ c3~ + ~ ~ =TOTAL PAGES 'T (Count does not include cover sheet) ~d _ /s/ Stage 1 Page Count from Scanned File: ~~ (Count does include co er sheet) er in Scannin re aration: ~ YES NO Page Count Matches Numb 9 P gY: Maria Date: 3''O ~~ ~s~ ~, P Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s~ his Dint unless rescanning is required. III II'lII III II I I III Scanning is complete at t p IIIIIIIIIIIIIIIIIII ReScanned BY: Maria Date: ~s~ ments about this file: Quality Checked III IIIIII III III I Com ^ Two-sided DIGITAL DATA ^ Diskettes, No. ^ Other, No/Type: Date: 10/6/2005 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 3/412010 Permit to Drill 2081110 Well Name/No. KUPARUK RIV UNIT 2X-19A Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-22618-01-00 MD 10913 TVD 5872 Completion Date 5/28/2009 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION ~~''~/' Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: CL, GR, Resistivity (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Ty ~ MedlFrmt Number Name scale meaia No Start Stop cM Kecewea comments ~ D C Lis 18225 Induction/Resistivity 8751 10913 Open 7/6/2009 OH data plus PDF and cgm graphic files Log Induction/Resistivity 5 Col 8881 10913 Open 7/6/2009 MD MPR, GR Log Induction/Resistivity 2 Col 8881 10913 Open 7/6/2009 MD MPR, GR Log Induction/Resistivity 5 Col 8881 10913 Open 7/6/2009 TVD MPR, GR Well Cores/Samples Information: Interval Name Start Stop Sample Set Sent Received Number Comments ADDITIONAL INFORM/~N Well Cored? Y N Daily History Received? `._,? N Chips Received? 1~7'1P~ Formation Tops ~ N Analysis JLfd4"~ Received? Comments: }~e~ye~r1 C.Ar ~ ~s c'~ ~.®c~st~;.sc. ~-~ , ~~ ;`t~ v ~'o-r~`vc~ ~~~~ Owe- d. (~ < i !I DATA SUBMITTAL COMPLIANCE REPORT 3/412010 Permit to Drill 2081110 Well Name/No. KUPARUK RIV UNIT 2X-19A MD 10913 TVD 5872 Completion Date 5/28/2009 Compliance Reviewed By: -__- Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-22618-01-00 Completion Status 1-OIL Current Status 1-OIL UIC N Date: ~ (~ //t'~ BAKER HV~"sHES Baker Atlas PRINT DISTRIBUTION LIST CUMYANY BY EXYLUKA'I lUN (ALASKA) 1N(: (:UUN'1'Y NUK1'H SLUYE BURUUGH WELL NAME V-115L2 STATE ALASKA V-115L2PB1 FIELD PRUDHOE BAY UNIT DATE 8/27/2009 THIS DISTRIBUTION LIST AUTHORIZED BY: CATRINA GUIDRY SO #: 2117476 Copies of Copies Digital Copies of Copies Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR -DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person KRISTIN DIRKS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 802 ANCHORAGE, AK 99508 ANCHORAGE AK 99501 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE. AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated By BAKER ATLAS-PDC 17015 Aldine Westfield, Houston, Texas 77073 This Distribution List Completed Bv: ~~~,i~~ '_; AUG ~ ~ 20b~ ~iaska Gfl ~ Gas C®~s. C,a~rnissial] ~nchara~a Page 1 of 1 i CONOCO PHILLIPS ALASKA, INC. # PRINTS 2X-19A KUPARUK RIVER UNIT NORTH SLOPE BOROUGH, ALASKA ConocoPhillips Alaska, Inc. 1 NSK Wells Aide, NSK 69 700 G Street, Anchorage, AK 99501 ~ f'ti ~'~ ~~ ATTN: MAIL ROOM 1,~ AoGCC JUL 0 6 209 Christine Mahnken 333 West 7th Ave, Suite 100 Alaska Oil & Gas tons. ~mmission Anchorage, Alaska 99501 Anchorage BP Petrotechnical Data Center, M633 P.O. Box 196612 Anchorage, Alaska 99519-6612 David Douglas CHEVRON/KRU REP P.O.Box 196247 Anchorage, Alaska 99519 Glenn Fredrick State of Alaska; DNR, Div. of Oil and Gas 550 W. 7th Ave, Suite 800 Anchorage, Alaska 99501-3510 Kristen Dirks, Geologist ~~'~~' 1 1 1 # CDS 9~ ., .~~~~~~ L yr .. J k4~FK ~:. ~~r~'tssiot~ 1 1 1 1 ~~ ass STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ^ Gas Plugged Abandoned ^ Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: Development ^' Exploratory ^ Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillipsAlaska, Inc. 5. Date Comp., Susp., ,L*,Ia ~ l ~ 7' orAband.: May~2009 12. Permit to Drill Number: 208-111 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: May 22, 2009 • 13. API Number: 50-029-22618-01 4a. Location of Well (Governmental Section): Surface: 630' FSL, 600' FEL, Sec. 4, T11 N, R9E, UM 7. Date TD Reached: May 26, 2009 ~ 14. Well Name and Number: 2X-19A Top of Productive Horizon: 63' FNL, 352' FWL, Sec. 4, T11 N, R09E, UM 8. KB (ft above MSL): 118' RKB Ground (ft MSL): 41' AMSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 999' FNL, 1024' FEL, Sec. 5, T11 N, R09E, UM 9. Plug Back Depth (MD + TVD): 10844' MD / 5871' TVD Kuparuk River Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 518529 • y- 5970633 Zone- 4 10. Total Depth (MD + TVD): 10913' MD / 5872' TVD 16. Property Designation: ADL 25645,'025642, 025644• TPI: x- 514181 y- 5975210 Zone- 4 Total Depth: x- 512809 - 5974272 Zone- 4 11. SSSV Depth (MD + TVD): nipple @ 1904' MD / 1904' ND 17. Land Use Permit: 2560 18. Directional Survey: Yes ^/ No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (TVD): 1262' TVD " 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): ~°1~ mf- L~r,i ~:i , e~~}'~'~ /~J/h ,~5 CCL, GR, Resistivity ~S~ ~~ '7- ~ 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE CEMENTING RECORD AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.58# H-40 Surf. 121' Surf. 121' 24" 245 sx AS 1 7-5/8" 29.7# L-80 Surf. 5791' Surf. 3899' 9.875" 963 sx AS III, 420 sx Class G 5.5" 15.5# L-80 Surf. 9507' Surf. 6219' 6.75" 16o sx Class G 2.375" 4.4# L-80 8847' 10877' 5751' 5872' 3" slotted liner 23. Open to production or injection? Yes ^/ No ^ If Yes, list each 24. TUBING RECORD Interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET 3.5 8851' 8829' slotted liner 8951'-10844' MD 5710'-5754' ND 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED none 26. PRODUCTION TEST Date First Production June 3, 2009 Method of Operation (Flowing, gas lift, etc.) Gas Lift Oil Date of Test 6/13/2009 Hours Tested 24 hours Production for Test Period --> OIL-BBL 636 GAS-MCF 1615 WATER-BBL 2211 CHOKE SIZE 176 Bean GAS-OIL RATIO 2539 Flow Tubing press. 186 psi Casing Pressure 191 Calculated 24-Hour Rate -> OIL-BBL 636 GAS-MCF 1615 WATER-BBL 2211 OIL GRAVITY -API (corr) 21 deg. 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No ~ Sidewall Cores Acquired? Yes ^ No ^ If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. CCh9PLE710N~ ~ECE~~~~~ NONE ~AL~ JIJL ~QS ~~ ~ - ^~ ~ ska Oil ~ Gas Cons Go~mmission ~~ Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE ~c~ 7 r! r~ 28. GEOLOGIC MARKERS (List all formations and marke encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes Q No If yes, list intervals and formations tested, Permafrost -Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1306' 1262' . needed, and submit detailed test information per 20 AAC 25.071. Top Kuparuk C 8926' 5810' Bottom Kuparuk C 10913' 5872' Base C4 9080' 5866' top C3 9265' 5868' top C3 10740' 5870' N/A Formation at total depth: Kuparuk C 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Dan Venhaus @ 263-4372 Printed Nam D ~ enha Title: Wells Enoineer ^,,, Signature ~ G''G~~. Phone ~3 " L13~ Z Date ~~~~ ~ INSTRUCTIONS Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 Ccanc~oPhiflips WeIIC g -19A, 6ne120 _. _ Sch_ematc Agtua HANGER. 36- ~._.._,.~ KUP ~~ WeII Attribute_§_ Welitwre APVU WI FieldN ~ 500292261501 KUPA jGOmment 091:3621 P.,a iSSSV: NIPPLE I " Annotation (Depth (ftK8) Last Tag: Casin~Strings C g Description (,String CONDUCTOR 16 I Casing Description String SURFACE 75/ Casing Description String Liner De coNDUCTOR, __ 0.121 Top (HKB) 8,846.0( NIPPLE. 1,904 10,844.6 = Tubin ~, Tubing Des. .-( TUBING GAS UFT, Comple 3.492 ' t Top (ftK8). SURFACE, 5 5 I 36.4 41-s,7st 1,903.7 ~ 8,812.9 Gns uFr, s,9m 8,814.3 " ~~ 8,827-8 GAS LIFT, _ 8,82855 ~ 8,036 ~~~ 8,839-8 ' ~ i 8,850.5 .. GAS LIFT, Other Ir 8.757 t ' Top (ftK8) _,7 8.927 SEAL ASSV. _. I 6.E13 PBR, 8,614 --- I pertOra' ANCHOR- SEAL, 8,828 To ftK6 p ( 1 _ r\ 8,951 'ACKER, 6,829- - > ' Notes: l ___ End O: 5128/2009 ( NIPPLE. 8.840 ~ [ WLEG, 8 650 - PRODUCTION, _ 33-9,507 SLOTS, __ 6,951-10,844 SLOTTED I ~- ' LINER, Q846-10,676 10,914 Ina 2X-19A TD Act BM (ft KB) 10,914.0 Rig R I ase Date 1 111 7/1 99 5_ End Data 6!16/2009 Top Thrd Top Thrd ST-L 89.581 O-RING BAKER O-RING SUB String O._ I, String ID ... Top (ftK8) Set Depth (F... Set Depth (ND) ... String W[.. Str ng ... String T 3 1/2 ~ 2.992.. - .ails ..36.4 8,851.3 5,608.1 ..9.30 L 80 - - ABI Top Inc! (°) Item Description Commend -4283..., HANGER FMC GEN IV TUBING HANGER -3376... NIPPLE CAMCO BP-61 HYDRAULIC LANDING NIPPLE w/1.562" ID DUMMY -19.55 SEAL ASSY BAKER SEAL ASSEMBLY(NO GO) -18.59 PBR BAKER 80-00 PBR 10' STROKE -12.30 ANCHOR BAKER 40FA36 KBH ANCHOR SEAL ASSEMBLY SEAL -11.96 ,PACKER 'BAKER FAB-1 PERMANENT PACKER $ 47 NIPPLE ICAMCO'D' NIPPLE -t28 ~WLEG WIRELINE ENTRY GUIDE(WLEG&WHIPSTOCK COVERED BY S/T ~ LINER) Nirelin valves, pumps, fish, etc.) e retrievable plugs, _ -___„ To Inc! p . 1.6 35-89 WHIPSTOCK (BAKER GEN II TTRW WHIPSTOCK, ORIENTED 8.1 7/12UU8 0.000 DEGREE LEFT OF HIGH SIDE -SET ABOVE TOC IN (ORIGINAL WELLBORE ~ $IOts Shot Top (TVD) Bim (TVD) Dens (g) (ftK6) (ftK8) Zone Date (h Type Gommant 544'1 5,709.9 5,754.411 ,5/27/2009 32 0 SLOTS I2 3/8" SLOTTED LINER I -- __ ral & Safety Annotation _ _ _ _ NOTE: WELL SIDETRACKED wall Status PRODUCING t ~An otation (End Data Last WO' I obtion ~ Reason: SHOW WHIPSTOCK (ftK6) Sat Depth (f... Set Depth (T 0.0 121.0 121.0 , (ftK8) Set Depth (f... Set Depth (T ~onocoPhillips Time Log & Summary WelWiew Web Reporting Report Well Name: 2X-19 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 5/3/2009 12:00:00 AM Rig Release: 5/28/2009 2:00:00 PM ; Time Logs _ From To Dur S Depth E. Depth Phase Code 5ubcode T Comment _~ Date _ 5/01/2009 24 hr Summary Rig Acceptance 00:00 00:00 24.00 0 0 MIRU MOVE TRNS P Mobilize rig from Deadhorse to Ku aruk 2X-19A Pad 5/02/2009 Move Rig 00:00 07:00 7.00 0 0 MIRU MOVE MOB P Move rig onto 2X-19A, Prepare to s of ri over well head 07:00 10:30 3.50 0 0 MIRU MOVE PSIT P Spot Rig over 2X-19A 10:30 14:00 3.50 0 0 MIRU MOVE RURD T 3.5 hours downtime. Install drip pan extension in cellar 14:00 00:00 10.00 0 0 MIRU MOVE PSIT P Spot Rig. over 2X-19A, Stab BOP's onto 2X-19A 5/03/2009 Spot Rig over 2X-19A 00:00 05:30 5.50 0 0 MIRU WHDBO NUND P Nipple up BOP's to 2X-19A 05:30 09:00 3.50 0 0 MIRU MOVE OTHR P Secure all walkways safe to use, Build spill containment around desi Hated areas 09:00 10:00 1.00 0 0 MIRU MOVE OTHR P Thaw Steam lines 10:00 00:00 14.00 0 0 MIRU WELCTL BOPE T Downtime, due 10 hour limit. BOP testin 5/04/2009 BOP testing, Repairing leaks, Prepare for Slack Management 00:00 10:00 10.00 0 0 MIRU WHDBO BOPE T Continue with initial BOP test & choke manifold. 200 psi low & 3500 si for hi h. 10:00 13:00 3.00 0 0 MIRU WHDBO BOPE T testing manual valves & HCR. Outer valves on choke manifold 13:00 16:00 3.00 0 0 MIRU WHDBO BOPE T Testing 2-3/8 Rams and choke valves. 16:00 19:30 3.50 0 0 MIRU WHDBO BOPE T Fixing leaks on Kill hose & choke line hose. 19:30 00:00 4.50 0 0 MIRU WHDBO BOPE T Complete BOP test of Kill lines, choke lines, 2-3/8 rams, 2" upper & lower rams, and annular. 5/05/2009 Perfomed Slack Management, cut 41 feet off CT string. Both crews went through Fire, Spill & H2S drills. Table top and lessons learned captured for crew awareness. Pulled BPV, and started to R/U pressure de to ment a ui ment. 00:00 01:00 1.00 0 0 SURPRI WELLPF SLPC P PJSM for Slack Management 01:00 03:00 2.00 0 0 SURPRI WELLPF CIRC P Set up Equipment and valves to circulate slack management. ressure test reel iron and valves. 03:00 06:00 3.00 0 0 SURPRI WELLPF CIRC P Perfom Slack management on new CT strin Rage 1 of 2€l Time Logs _ ____ Date From To Dur S. De th E: De th Pha. e Code Subcode T Comment 06:00 08:00 2.00 0 0 SURPRI WELLPF CIRC P Redress mud pump #2, continue pumping with mud pump #1. Set up CT H draulic cutter. 08:00 09:00 1.00 0 0 SURPRI WELLPF CIRC P Complete testing inner reel valves 09:00 11:00 2.00 0 0 SURPRI WELLPF CTOP P Purged CT with air, Cut CT for slack mans ement. total of 41 ft cut. 11:00 15:00 4.00 0 0 SURPRI WELLPF CTOP P Install CT connector, rig up FMC to ull BPV 15:00 16:30 1.50 0 0 SURPRI WELCTL SFTY P Perform Fire, H2S & Spill response drills. 16:30 17:30 1.00 0 0 SURPRI WELCTL MPSP P Pull BPV 17:30 18:00 0.50 0 0 SURPRI WELLPF PRTS P Pressure test Ct Connector 18:00 20:00 2.00 0 0 SURPRI WELCTL PRTS P Testing of alarm systems and securing WH equipment. Install Bleed lines to tiger tank from IA,OA. ressure test. 20:00 21:00 1.00 0 0 SURPRI WELCTL SFT( P Perform table top drill of Fire Drill & discuss crew member activities. 21:00 21:30 0.50 0 0 SURPRI WELLPF CTOP P Stab injector onto well to pump slack formward. 21:30 22:30 1.00 0 0 SURPRI WELCTL SFTY P Perform H2S drill, including securing the well, muster stations, and table to discussion for crew awareness. 22:30 00:00 1.50 0 0 SURPRI WELLPF CTOP P Pump slack forward to finish slack mans ement. 5/06/2009 Perform Spill Drill. Install Managed pressure line. Rig up dummy BHA. RIHlPOOH to test depth counters. Problems with accurate depth measurements. Tag ice plug @ 80 ft, POOH, close swab valves, displace CT to ti er tank. Blow stack & lines d ,install down'et nozzle and call out LRS for ice lu removal. 00:00 02:00 2.00 0 0 SURPRI WELCTL SFTY P perform spill response drill, lessons learned & chemical awareness with entire ri crew. MSDS 02:00 04:30 2.50 0 0 SURPRI WELCTL NUND P Install MP line, Instrument flange on flow line. 04:30 06:00 1.50 0 0 SURPRI WELLPF CTOP P Pick up BHA and lubricator e ui ment#or first CT run in well. 06:00 10:30 4.50 0 0 SURPRI WELCTL CTOP P MU BHA into PDL. Practice tilting mast over wellhead stabbing PDL onto wellhead lowering BHA into well. 10:30 11:30 1.00 0 0 SURPRI WELCTL PRTS P Align valves, Fluid pack, psi test stack 11:30 12:00 0.50 0 0 SURPRI WELLPF CTOP P Open Well, RIH, inspecting Injector Head, Reel 12:00 13:30 1.50 0 0 SURPRI WELLPF CTOP P Calibrate Psi Sensors 13:30 15:30 2.00 0 0 SURPRI WELLPF CTOP P Calibrate Counters, POOH 15:30 16:30 1.00 0 0 SURPRI WELLPF CTOP T Tag Stripper, Adjust Counter on Levelwind 16:30 18:00 1.50 0 0 SURPRI WELLPF CTOP T Conitue Calibrating Tubing Counters. tag on ice plug or obstruction 80 ft in well ®~ .... P~~e 2 of 2(3 • ~~ Time Logs __ Date From To Dur S De th E. De th Pha e Code Subcode T Comment 18:00 22:00 4.00 0 0 SURPRI WELLPF CTOP T _ Wait on Counter issues, POOH to surface, shut in swab & purge CT to Tiger tank. Issues of a possible ice plug in well from static testing during the day with the CTES counters. Clean ice plugs from cement standing iron, install needle valves and bleed lines on risers. 22:00 23:00 1.00 0 0 SURPRI WELLPF CTOP T Little red arrived on location, hold a safe meetin riot to ri in u . 23:00 00:00 1.00 0 0 SURPRI WELLPF CTOP T Install a 2" OD downjetting nozzle. Pressure test the riser using teh QTS to 4000 si. 5/07/2009 Work CT through ice plug using hot diesel from 80 ft down to 300 ft. freeze protect well. Continue to perform equipment checks, training & depth corilation runs. Adjustments made on injector for CT alignment, and de th control. RIH to 8500 ft and work CT strin , to de the vs CCL. 00:00 01:00 1.00 0 0 SURPRI WELLPF CTOP P Begin Circulating Diesel through CT reel and displace SW to Rig pits. Density, Pump rate and pressure working on In Micro Motion. Out micro motion not workin at all. 01:00 01:18 0.30 0 0 SURPRI WELLPF CIRC P 33 bbls away stop pumping and switch to Tiger tank. Continue um in diesel. 01:18 02:00 0.70 0 0 SURPRI WELLPF CTOP P RIH and tag ice plug at 80 ft. pumping @ 1 bpm of 100 degree diesel. BHI CCL reading at tool, and temperature off/on when applied. Not stron readin s but it is readin . 02:00 03:00 1.00 0 0 SURPRI WELLPF CTOP P Break through ice plug at 340 ft. WH pressure max. at 480 psi, weight checks looked good P/U weight 12,000#. Circ ressure 2300 si. 03:00 04:00 1.00 0 0 SURPRI WELLPF CTOP P BHI Depth counters not working properly, CTES depth working on one display. Weight checks look good and no major marks on CT string. RIH to 1000 ft pumping diesel, ice plug look sremoved, stop moving pipe to start inspecting the counters. Circ. press 2400psi, WHP 200, pumped 150 tills of 100 degree diesel. Stop pumping/Shut in well at choke. Release LRS. 04:00 06:00 2.00 0 0 SURPRI WELLPF CTOP P Continue with CT testing of RIH/POOH. Heat up SW in pits to 130 degrees. Order 290 of 120 degree SW for testing. POOH with CT to zero depths for better test runs. Ins ect CT while POOH. 06:00 07:00 1.00 0 0 SURPRI WELLPF CTOP P Center counter Wheels onto Coil Tubin at Levelwind 07:00 08:00 1.00 0 0 SURPRI WELLPF CTOP P Lock/Out, Tag/Out CT reel to re-route H draulic hoses on Levelwind ~® ~T~g~ 3 s~f 2t} l ~~ Time Logs From To Dur S De th E. De th Phase Code Subcode T Comment _ _ I Date _ 08:00 09:00 1.00 0 0 SURPRI WELLPF CTOP P Fluid Pack Injection Methynol injection hose on PDL's with Methynol and function test. Remove Cover and bracket off of Reel Swival on CT Reel, to assure proper ali nment. 09:00 12:30 3.50 0 0 SURPRI WELCTL CTOP P RIH to 1000', Pull out of hole 100' checking gooseneck alignment, Markings on CT, Reel movement. Repeat these steps to 8000'. Reel Swival Test Good. 12:30 13:00 0.50 0 0 SURPRI WELCTL CTOP P Perform CCL Log testing E-line, and BHI Power and Comms. Test Good, Continue to RIH to 8500'. 13:00 14:00 1.00 0 0, SURPRI WELLPF CTOP P 8500' stop RIH. Set Brakes. Inspect Reel, CT and Injector Head Checking all Gripper blocks on Injector Head. Tor Gri er Block bolts to s ec. 14:00 18:00 4.00 0 0 SURPRI WELLPF CTOP P Pull Out of Hole (POOH) Checking Injector bearings and motors, Reel Bearings and Motors with heat gun for excessive heat building up. Also checking Gooseneck alignment, ad'ustin . 18:00 20:00 2.00 0 0 SURPRI WELLPF CTOP P POOH, inspect motor temperatures, hydraulic pumps, and reel drive tem eratures. 20:00 22:30 2.50 0 0 SURPRI WELLPF CTOP P Stop POOH @ 2400ft. Strap CT for depth measurements. LRS on location to pump 50 bbls of diesel for freeze protect of well due to CT displacement runs. Slight vibrations on injector motor while POOH slow) . 22:30 23:00 0.50 0 0 SURPRI WELLPF SFTY P Safety meeting discussing pumping, pressures, Wellhead lines, why we freeze rotect and CT dis lacement. 23:00 00:00 1.00 0 0 SURPRI WELLPF CIRC P Pump 50 bbls of freeze protect, WHP started to increase pressure after 35 bbls. Well diesel packed. Continue to POOH from 2300 ft. Injector sur in while POOH . 5/08/2009 POOH from 2300 ft slowly to perform Injector troubleshooting. Unstab CT to work on Injector. Perfromed alignment and motor sequence checks. Correcting problem by reducing the torque sequence & harmonic resistance on injector motor drag (Acedemy). While at surface training on pressure deployment and general walk throu h for new crew arrivin toda . 00:00 02:00 2.00 0 0 SURPRI WELLPF CTOP P Start to POOh from 2300 ft, Injector motors jacking and surging. Stop CT movement and diagnosing problem. Begin pressure testing the Managed pressure line while troubleshooting injector. 02:00 03:00 1.00 0 0 SURPRI WELCTL PRTS T Start to move injector, reel starting to surge. Encoder replaced on injector motor. 03:00 06:00 3.00 0 0 SURPRI WELCTL TRIP T POOH 2O-30'/min monitoring Injector head and reel. At surface, F"a 4 of 2tT ~~ l J Time Logs ~ Date From To Dur S Depth E. Depth Phase Code Subcode T Comment ' 06:00 09:00 3.00 0 0 SURPRI WELCTL CTOP P Secure well, lift injector off well, Hang BHA of into PDL. Pressure test MP line 5000 si. Test ood. 09:00 12:00 3.00 0 0 SURPRI WELCTL HOSO T Unstab CT from injector head. 12:00 15:00 3.00 0 0 SURPRI WELLPF SFTY P Hold Training session with crew. Watch Pressure Deployment Video, read through Procedure. Training with Driller on CTES software. 15:00 00:00 9.00 0 0 SURPRI WELLPF CTOP T Function test injector head at surface. Performing RIH/POOH sequence, aligning motors. Continue with rig repairs and housekeeping. Detected in hole torgue drag sequencing is the main problem. Correct problem by reducing the torgue sequnce and harmonic resitance on the injector motors. 5/09/2009 Stab CT, rehead, pressure test to 4500psi, Pull test 30,000#. RIH/POOH testing the injector and performing safe drills. 00:00 01:30 1.50 0 0 SURPRI WELLPF CTOP T Hold Safety meeting & Stab pipe into injector. 01:30 04:00 2.50 0 0 SURPRI WELLPF CTOP T Redress CT connector, pull test to 35,000#, install CT connector. 04:00 08:00 4.00 0 0 SURPRI WELLPF CTOP P Install CT depth counter, hold safety meeting for pressure testing CT strin and valve ali nment. 08:00 10:00 2.00 0 0 SURPRI WELLPF CTOP P Pressure test CTU connector to 4500 psi. Start cutting off bleeder line valves and welding flange assembly.ongoing all day (as re nested b State test . 10:00 12:00 2.00 0 0 SURPRI WELLPF PULD P P/U and manouvering PDL at surface, tilt the mast & practice ressure de to ment se uence. 12:00 18:00 6.00 0 0 SURPRI WELLPF CTOP P RIH/POOH down to 5000', completing tests on injector head and reel ali nment. 18:00 23:00 5.00 0 0 SURPRI WELLPF CTOP P Continue training crews on injector maintanance, RIH/POOH including tri and lock out rocedures. 23:00 00:00 1.00 0 0 SURPRI WELLPF SFTY P Perform, H2S, Fire and Spill drill with new ni ht crew. 5/10!2009 Deploy BHA #2, RIH and circulate well. Stop and wait on stripper parts and repairs. 00:00 01:00 1.00 0 0 SURPRI WELLPF SFTY P Complete Spil drill with discussion of MSDS and proper PPE for handling of chemicals. 01:00 02:00 1.00 0 0 SURPRI WELLPF CTOP P Pull short BHA #1 from well and lay down. 02:00 03:00 1.00 0 0 SURPRI WELLPF SFTY P Watch deployment video and discuss first steps for getting BHA#2 read . Paya 5 of 2d3 Time Logs _ To Dur S De th E. De th Phase Code Subcode T Comment From Date ___ _ 03:00 05:00 2.00 0 0 SURPRI WELLPF CTOP P measure space out for BHA, drill holes in no-go ring, install white vales and pressure gauges on lubricator. Rig up BOP test pump for testing PDL 05:00 06:00 1.00 0 0 SURPRI WELLPF PULD P P/U BHA # 2 for pressure de to ment. 06:00 07:00 1.00 0 0 SURPRI WELLPF SFTY P PJSM Pressure Deployment of Drillin BHA Trainin 07:00 11:00 4.00 0 0 SURPRI WELCTL CTOP P Pressure Deploy Drilling BHA with straight motor assembly. Train with crews walking through procedure and one line drawin . 11:00 13:00 2.00 0 0 SURPRI WELCTL CTOP P X-ray and Inspect welds on kill line. Train with crew watching Pressure Deployment Video, following procedure and one line drawing. Round table Questions and answers on Pressure De to in . 13:00 14:30 1.50 0 0 SURPRI WELCTL CTOP P RIH performing weight checks 1000' 14:30 15:30 1.00 0 0 SURPRI WELCTL CTOP P Stop CT to install Camera bracket over lookin front of Reel. 15:30 18:00 2.50 0 0 SURPRI WELCTI CTOP P Continue RIH Performing Wt. checks eve 1000' 18:00 19:00 1.00 0 0 SURPRI WELLPF CTOP P Stripper not sealing on CT. 19:00 00:00 5.00 0 0 SURPRI WELLPF CTOP T Replace Strpper assembly, not all the parts on location. Contineu circulating down well while waiting on re lacement arts. 5/11 /2009 Complete repairing stripper assembly. RIH/POOH and circulate through Managed Pressure Choke. Not functioning or operating as planned or designed. POOH, freeze protect and prepare to train on deploying dumm BHA 00:00 01:00 1.00 0 0 SURPRI WELLPF CTOP T Complete stripper repairs 01:00 03:00 2.00 0 0 SURPRI WELLPF CIRC P Continue to circulate the well for crew to familiarize with operational e ui ment. 03:00 04:00 1.00 0 0 SURPRI WELLPF SFTY P Stand down to discuss lessons learned and plan forward with the circulation schedule. 04:00 06:00 2.00 0 0 SURPRI WELLPF CTOP P Start circulating system utilizing the Managed pressure choke. Continue with seperate bbl rate .5 bpm, 1 bpm, 1.5 bpm. Chokes not functionin ro erl . 06:00 19:00 13.00 0 0 SURPRI WELLPF CIRC T Circulated while RIH/POOh to test Managed Pressure Chokes. Auto controls not functioning and manual controls are working but hooked up to incorrect chokes. Stan. to POOH from 8000' 19:00 20:00 1.00 0 0 SURPRI WELLPF CIRC P Rig up Diesel to pump down CT and freeze rotect the well from 3000'. 20:00 22:00 2.00 0 0 SURPRI WELLPF CTOP P POOH. and freeze protect well from 3000' pumping 60 bbls of diesel. tag u on stri er r~ac 6 of 2tl r~ Time Logs Date From To Dur S De th E. Depth Phase Code Subcode T Comment __ 22:00 23:00 1.00 0 0 SURPRI WELLPF CTOP P Safety meeting and pull BHA from well. 23:00 00:00 1.00 0 0 SURPRI WELLPF CTOP P Lay down BHA, perfrom injector and reel maintance. Start putting together dummy deployment string for training ur oses. 5/12/2009 Practice stripping up/down pipe. Defining operating settings for injector cart. Practice deployment with 2.8 de ree motor. 00:00 01:00 1.00 0 0 SURPRI WELLPF SFTY P Review and discuss pipe skate o erations 01:00 03:00 2.00 0 0 SURPRI WELLPF PULD P P/U lay down test joints, run pipe skate, test emergency trips. Make u de to merit dumm BHA 03:00 04:00 1.00 0 0 SURPRI WELLPF SFTY P review injector stripping up/down rocedure 04:00 06:00 2.00 0 0 SURPRI WELLPF CTOP P Practice and test paremeters for stri in the injector u /down 06:00 08:00 2.00 0 0 SURPRI WELLPF SFTY P Review stripping up/down procedure with da crew 08:00 12:00 4.00 0 0 SURPRI WELLPF CTOP P Strip injector up/down. Inspect and adjust control paremters for stripping of the injector cart. 12:00 16:00 4.00 0 0 SURPRI WELLPF PRTS P Pressure test PDL to 5000 psi 16:00 17:00 1.00 0 0 SURPRI WELLPF CTOP P Straighten CT and install on Well for stri in rocedures. .17:00 18:00 1.00 0 0 SURPRI WELLPF CTOP P Strip injector head up/down to check arameters. 18:00 20:00 2.00 0 0 SURPRI WELLPF CTOP P Night Crew continue to strip on and off well 20:00 21:00 1.00 0 0 SURPRI WELLPF SFTY P Conduct detailed review of pressure deployment procedure with night crew. 21:00 00:00 3.00 0 0 SURPRI WELLPF CTOP P Practice pressure deployment with one joint of 2-3/8" liner with UOC/LOC oh top and 2.8 degree motor and used bi-center bit on bottom. 5/13/2009 Finish deploying and pulling 2.8 deg BHA test. Foremost technician worked on top drive. MU safety joint and 'oints of slotted liner. 00:00 01:00 1.00 0 0 SURPRI WELLPF PULD P Lowering 2.8 degree motor into stack as er de o merit scenerio 01:00 06:00 5.00 0 0 SURPRI WELLPF SFTY P Training on Deployment and valve ali nment. 06:00 08:00 2.00 0 0 SURPRI WELLPF PULD P Pulled and layed down 2.8 degree motor BHA. Tights spots identified @ 25.56, 24.26, 19.96 ft. Measurements indicate going throu h 3.08" Tree. 08:00 13:00 5.00 0 0 SURPRI WELLPF RURD P Getting rig floor equipment ready for ickin u liner. 13:00 20:00 7.00 0 0 SURPRI WELLPF CTOP T Wait on Foremost technician for Top drive calibrations. 20:00 20:30 0.50 0 0 SURPRI WELLPF SFTY P Pre-job safety meeting on picking up 2-3/8" liner and use of i e skate. 20:30 22:30 2.00 0 0 SURPRI WELLPF RGRP T Servicing and working on top drive. PagB r' of 2~J l~ _Time Logs _ Date From To Dur S. De th E. De th Phase Code Subcode T Comment ___ 22:30 00:00 1.50 0 0 SURPRI WELLPF PUTB P MU safety valve onto a solid joint of 2-3l8" ST-L tubing. MU 4 joints of 2-3/8" solid/slotted liner. 5/14/2009 Perform safety joint drill with night crew and LD slotted liner. Pressure deploy & undeploy with straight motor. Day crew MU & LD slotted liner and perform safety joint drill. Performed more deploy & undeploys o erations. 00:00 01:00 1.00 0 0 SURPRI WELLPF SFTY P Perform safety joint drill. Performed after-action review with crew following drill. 01:00 03:00 2.00 0 0 SURPRI WELLPF PUTB P LD 4 joints of 2-3/8" slotted/solid liner. 03:00 03:30 0.50 0 0 SURPRI WELLPF SFTY P Prejob meeting on pressure de to ment. 03:30 06:00 2.50 0 0 SURPRI WELLPF CTOP P Pressure deployment BHA with straight motor without pumping any fluids. 06:00 07:30 1.50 0 0 SURPRI WELLPF SFTY P Round table discussion for Unde to ment 07:30 09:30 2.00 0 0 SURPRI WELLPF CTOP P Undeploy BHA 09:30 11:00 1.50 0 0 SURPRI WELLPF CTOP P Move the injector cart, and load pups into ri . 11:00 12:00 1.00 0 0 SURPRI WELLPF SFTY P Round table for Safety Stand Drill, M/U 8', 5', & 3' pup to set into stack for space out across Annular & 2-3/8 De to ment rams. 12:00 15:00 3.00 0 0 SURPRI WELLPF CTOP P PU/LD 2-3/8" slotted and solid liner. 15:00 16:30 1.50 0 0 SURPRI WELLPF SFTY P Perform Safety Joint Drill and round table discussion. 16:30 18;00 1.50 0 0 SURPRI WELLPF CTOP P Clean up rig floor, set up for de to ment for ni ht crew. 18:00 20:00 2.00 0 0 SURPRI WELLPF CTOP P Set stops on Top Drive, M/U Dummy BHA for pressure deployment trainin 20:00 21:30 1.50 0 0 SURPRI WELLPF CTOP P Complete Pressure Deployment Training run with straight motor. PJSM for Un-De to ment trainin . 21:30 00:00 2.50 0 0 SURPRI WELLPF CTOP P Undeploy tool from well. 5/15/2009 Perform deployment training with outgoing day crew. Stripping on and off well with new night crew. Centrifu es need re air. Ex ro choke and micro motion calibration. 00:00 02:00 2.00 0 0 SURPRI WELLPF CTOP P Finish undeploying BHA, Rig up Safety joint and prep to run jointed ie 02:00 02:15 0.25 0 0 SURPRI WELLPF SFTY P Spill Drill in cellar -All hands responded. Absorb, shovels, oily waste bags and fire extiguisher were immidiatly brought to cellar. Good drill 02:15 03:00 0.75 0 0 SURPRI WELLPF CTOP P Break down dummy BHA, M/U 30' safety joint. Position on drillers side of i e skate 03:00 03:15 0.25 0 0 SURPRI WELLPF SFTY P Pre-job safety meeting on picking up 2-3/8" liner. 03:15 03:45 0.50 0 0 SURPRI WELLPF CTOP P Run 4 joints 2 3/8 liner Page fl t~f 2~ Time Logs _ Date From To Dur S. De th E. De th Ph e Code Subcode T Comment 03:45 04:00 0.25 0 0 SURPRI WELLPF SFTY P _ Conduct Safety joint drill. Drill concluded in 4 1/2 minutes. 04:00 04:30 0.50 0 0 SURPRI WELLPF CTOP P Lay down 2-3/8" liner. 04:30 05:00 0.50 0 0 SURPRI WELLPF SFTY P Conduct H2S drill. Mustered at Nabors sho . 05:00 06:00 1.00 0 0 SURPRI WELLPF CTOP P MU BHA for day crew to practice ressure de to ment rocedures. 06:00 08:00 2.00 0 0 SURPRI WELLPF SFTY P Round table discussing Deploymenrt rocedure 08:00 11:00 3.00 0 0 SURPRI WELLPF CTOP P Deploy/Undeploy BHA discuss lessons learned 11:00 13:00 2.00 0 0 SURPRI WELLPF CIRC T Recalibrate Micro motion 13:00 16:00 3.00 0 0 SURPRI WELLPF CIRC T Work on calibrating X-pro choke systems. Centrifuges are also not wokring. Both electrical drives are burnt, replacement should be here at 10:00 PM. 16:00 18:00 2.00 0 0 SURPRI WELLPF CIRC T Pull apart pump # 1 to replace liner cu s/swabs. 18:00 20:00 2.00 0 0 SURPRI WELLPF CTOP T Rig Orientation /Valve alignment / Prep for stripping on and off well trainin 20:00 00:00 4.00 0 0 SURPRI WELLPF CTOP T Train new night crew on stripping ops 5/16/2009 Centrifuge repairs complete, Work ongoing on Expro Choke, Trimmed marked pipe. Good test on E-Line. CTC Failed Pressure test. 00:00 01:00 1.00 0 0 SURPRI WELLPF SFTY T PJSM -Pressure deployment -View deployment Video -Round Table stri in rocedure 01:00 05:30 4.50 0 0 SURPRI WELLPF CTOP T Pressure deployment training with ni ht crew 05:30 06:00 0.50 0 0 SURPRI WELLPF CTOP T Secure Pressure deployment e ui ment. Pre ri for Da Crew 06:00 09:00 3.00 0 0 SURPRI WELLPF CTOP T Continue with Rig repairs, wellding on transition rails in Mast. 09:00 11:00 2.00 0 0 SURPRI WELLPF CTOP T Wait on centrifuge parts, weld on Rig floor brackets. Seal up Rig floor u set. 11:00 12:00 1.00 0 0 SURPRI WELLPF CTOP T Finish welding on rig floor, set up to cut i e and rehead CT connection. 12:00 14:00 2.00 0 0 SURPRI WELLPF CTOP T Cut 50 ft of coil off. Trim CT depth on CTES. Centrifuge operator arrived with arts. Start re-headin CT. 14:00 15:00 1.00 0 0 SURPRI WELLPF CTOP T Centrifuge is operational, pull test CT connector to 30,000#. 15:00 18:00 3.00 0 0 SURPRI WELLPF CTOP P Pressure test CT connector to 4000 psi. CT connector failed. Cut and redress CT connector 18:00 20:30 2.50 0 0 SURPRI WELLPF CTOP P Trim coil, prep coil and install Kendal coil connector. Pull test CTC 30K Ibs, Good test 20:30 20:45 0.25 0 0 SURPRI WELLPF CTOP P Test E-Line Cable, Insulation test Good 500m ohmes, Continuity test ood 20:45 22:30 1.75 0 0 SURPRI WELLPF CTOP P Head Up E-line i~ag~a 9 of 2Q r~ Time Logs _ Date From To Dur S. Guth E. De th Ph e Code Subcode T Comment _ ___ 22:30 22:45 0.25 0 0 SURPRI WELLPF CTOP P Pressure test connector, test failed 22:45 00:00 1.25 0 0 SURPRI WELLPF CTOP P Remove E-line head, cut off CTC, trim and re i e for CTC 5/17/2009 Make Up CTC, RIH and displace wellbore fluid to Tiger Tank. Empty And Clean pits. Pump 1 maintenance, Unable to et lined u on hi hline ower 00:00 00:30 0.50 0 0 SURPRI WELLPF CTOP P Make up CTC 00:30 02:00 1.50 0 0 SURPRI WELLPF CTOP P Test E-line Cable -Good insulation and continui . Head u E-Line 02:00 02:15 0.25 0 0 SURPRI WELLPF CTOP P Pressure test CTC 400PSI Low and 4000 PSI Hi h, Good test 02:15 02:45 0.50 0 0 SURPRI WELLPF SFTY P PSSM, Make up Dummy BHA and Pressure De to 02:45 05:00 2.25 0 0 SURPRI WELLPF CTOP P Make up Dummy BHA. Pressure de to followin checklist 05:00 07:00 2.00 0 0 SURPRI WELLPF CTOP P Set up valves, change out pack offs and re are to RIH with dumm BHA 07:00 09:00 2.00 0 0 SURPRI WELLPF CIRC P Circulate at surface to check pumps and centrifuge again. Pump # 1 is down for com lete fluid end re airs. 09:00 10:00 1.00 0 0 SURPRI WELLPF CIRC P Clean out pits and wait for high line power transfer. First test run failed due to generator 1 & 2 not isolating ower. 10:00 10:30 0.50 0 0 SURPRI WELLPF CTOP P Hold Pre-RIH safety meeting to discuss crew assignments and res onsibilities. 10:30 11:00 0.50 0 0 SURPRI WELLPF CTOP P Set Injector and CTES paremeters 11:00 13:00 2.00 0 0 SURPRI WELLPF CTOP P Begin RIH with CT, circulating out diesel and chased a slush plug down to 300 ft. 13:00 15:00 2.00 0 0 SURPRI WELLPF CIRC P Sit at 2000 ft, circulate warm fluid and wait for high line power transit. Clean pits, scrub the rig floor, and discuss securin the well "drill". 15:00 17:00 2.00 0 0 SURPRI WELLPF CTOP T Tried to swap to high line power with no success again. The generator relay is not shutting down so it trips the hi h line ower feed. 17:00 19:00 2.00 0 0 SURPRI WELLPF CTOP P Continue RIH circulating fluid. 19:00 20:00 1.00 0 0 SURPRI WELLPF CTOP P Service pressure bulkhead in reel 20:00 23:00 3.00 0 0 SURPRI WELLPF CTOP P POOH Pumping 1.5 BPM @ 2500PSI, 23:00 00:00 1.00 0 0 SURPRI WELLPF CTOP P Tag up, Shut down pumps, Training on injector and storage reel daily lubrication and ins ection needs 5/18/2009 Complete repairs on Pump 1, Tripping following managed pressure schedule training. Remove Expro choke for re lacement. Ni ht crew liner runnin train 00:00 01:00 1.00 0 0 SURPRI WELLPF SFTY P CTD Engineers present managed pressure shedules and lay in kill wei ht fluid schedule to crews Page 1fl €sf 2~ Time Logs ,Date From To __ Dur S_Depth E. De th Phase Code Subcode T Comment I 01:00 02:00 1.00 0 0 SURPRI WELLPF CTOP P Service gooseneck, Investigate BHI de th counter sli a e 02:00 06:00 4.00 0 0 SURPRI WELLPF CTOP P Training, Run in and out of hole, CT Spooling, tagging up at surface, and Tri sheets 06:00 07:30 1.50 0 0 SURPRI WELLPF CTOP P Circulate on bottom and hold ressure with the choke 250 si 07:30 08:00 0.50 0 0 SURPRI WELLPF SFTY F' Discuss Managed pressure drilling, ressure schedules 08:00 09:00 1.00 0 0 SURPRI WELLPF CTOP P Switch to High-Line power and test surface aremters. Workin well. 09:00 13:00 4.00 0 0 SURPRI WELLPF CTOP P Begin POOH following the managed ressure schedules. 13:00 14:00 1.00 0 0 SURPRI WELLPF SFTY P Discuss and walk through valve alignment for pressure unde to ment/de to ment 14:00 18:00 4.00 0 0 SURPRI WELLPF CTOP P Pressure undeploy using 150 psi of pressure. Everything was a smooth with minor ad'ustments. 18:00 19:00 1.00 0 0 SURPRI WELLPF CTOP P Lubricate reel and levelwind, remove dummy BHA from PDL and make up safety joint. Prep for liner running trainin 19:00 20:00 1.00 0 0 SURPRI WELLPF CTOP T Remove ExPro auto choke for re lacement 20:00 00:00 4.00 0 0 SURPRI WELLPF CTOP P Jointed pipe running training includin safet ~oint drill 5/19/2009 Install 1.5" expro choke for managed pressure operations. MU and deploy dummy BHA. RIH/POOH to 4000' while circulatin to test new choke. Install testin manifold on BOP stack and be in BOP test. 00:00 02:00 2.00 0 0 SURPRI WELLPF CTOP P Continue liner running training. 02:00 02:30 0.50 0 0 SURPRI WELLPF SF?Y P PJSM, Make up dummy BHA, PJSM Install new ExPro choke 02:30 05:00 2.50 0 0 SURPRI WELLPF CTOP P Make up dummy BHA, Pressure deploy into well, Install new managed ressure choke 05:00 05:30 0.50 0 0 SURPRI WELLPF CTOP P Line up and pressure test Pump #1 and mans ed ressure choke 05:30 10:30 5.00 0 0 SURPRI WELLPF CTOP P RIH to 4000' ,circulating warm sea water to test new CT Managed pressure choke system & calibrations. 10:30 14:00 3.50 0 0 SURPRI WELLPF CTOP P Calibrate, function test, update software on ExPro choke 14;00 16:00 2.00 0 0 SURPRI WELLPF CTOP P POOH following managed pressure schedule @ 1.5 BPM pump rate. ExPro choke worked well. Setpoint changes were quickly achieved and maintained within 20 psi high or low. Choke reacted good to coil stopping and runnin back in well. 16:00 17:00 1.00 0 0 SURPRI WELLPF CTOP P Break down dummy BHA, Pressure test swab valves, blow down stack to install flan ed i er valves on stack. 17:00 20:00 3.00 0 0 SURPRI WELLPF CTOP P Install Piper valves on kill port of lower BOP I~~ 1't s~f ~~t Time Logs ~ Date From To Dur S De th E. De th Phase Code Subcode T Comment _ __ 20:00 _ 21:00 1.00 0 0 SURPRI WELLPF BOPE P _ MU test joint/TIW valve, prepare for BOP test. Lou Grimalldi on location 21:00 00:00 3.00 0 0 SURPRI WELLPF BOPE P Begin BOP testing 5/20/2009 Testing BOP equipment. Audible alarms for PVT, Gain/Loss not working. HCR on choke line leaking. State inspector left location at 0900 and returned at 1800. Test completed at midnight with the HCR still needing to be re laced. 00:00 02:00 2.00 0 0 SURPRI WELLPF BOPE T Wing valve is being used for the managed pressure line and the state inspector considers this to be a part of the BOP test. Wing valve is leaking at low pressure. Call out valve crew to service valves 02:00 09:00 7.00 0 0 SURPRI WELLPF BOPE P Continue testing BOP, #4 Rams (lower deployment) failed. State man leaving location. Houred out. Will wake u at 16:30 09:00 12:00 3.00 0 0 SURPRI WELLPF ROPE T Pulled #4 rams out of BOPE, looked good, installed new set of rams. Still no test, found HCR valve to be leaking. 10 hours BOPE testing have ast. Downtime 12:00 19:00 7.00 0 0 SURPRI WELLPF BOPE T Continue testing rams while waiting on state ins ector to return 19:00 22:00 3.00 0 0 SURPRI WELLPF BOPE T Continue with state witnessed testing of BOP. PVT system test. No audible alarms have been installed. 22:00 22:30 0.50 0 0 SURPRI WELLPF BOPE T Koomey draw down test. 22:30 00:00 1.50 0 0 SURPRI WELLPF BOPE T Test stripper and inner reel valve. 5/21 /2009 Changed out and tested Choke Line HCR.. Test deploy 2.6 deg motor and bicenter bit. PU and run window millin BHA. Tie in and start window millin . 00:00 08:00 8.00 0 0 SURPRI WELLPF BOPE T Change out HCR 08:00 08:30 0.50 0 0 SURPRI WELLPF SFTY P PJSM - P/U BHI Coil track - 2.6 de ree test motor and bit. 08:30 09:30 1.00 0 0 SURPRI WELLPF PULD P P/U Coil Ttack and Test 2.6 degree motor and Bi-center in well. Hook up to PLD and run up and down for de to ment test. 09:30 11:30 2.00 0 0 PROD1 WHPST PULD P BHA #1 - P/U BOT Mill and motor on Coil Track, Test tool. 2.74 Go - 2.73 No Go 11:30 15:00 3.50 0 0 PROD1 WHPST TRIP P RIH Pumping seawater @1 BPM followin ressure schedule, 15:00 15:30 0.50 0 8,852 PROD1 WHPST DLOG P 8800' Start tie in log, 300' hour for first 40, slow down to 150 ft. Set down @ 8850, PUH 5', RIH 10 FPM set down. Shut EDC pump .4 BPM 1400 PSI circ ressure RIH 15:30 16:00 0.50 8,852 8,852 PROD1 WHPST DLOG P Set down @ 8852 CTM 2000 WOB, 800 PSI motor work. 16:00 16:45 0.75 8,852 8,852 PROD1 WHPST DLOG P PUH to 8725 to tie in to different gamma signature. 44K P/U weight Lo down 150 FPH. .M. ~ Wage 12 8f 2L' Time Logs Date From To _ D_ur S De th E. Depth Phase Code Subcode T Comment _ 16:45 17:00 0.25 8,852 8,852 PROD1 WHPST DLOG P Find K-1 marker +71.5 foot correction. PUH to run CC log on tubing tail jewrey. Made correction from 8798 17:00 18:00 1.00 8,852 8,920 PROD1 WHPST DLOG P Start CC log @ 8841' to 8920' CTM. Confirms gamma tie-in. Start Biozan down CT 18:00 20:00 2.00 8,920 8,920 PROD1 WHPST EQRP T Recalibrate coil tubing depth counters by strapping 50' of coil between reel and gooseneck. CTES counter appears to be counting correctly, less than 0.1 % accurate. Academy injector drive motor calibration is greater than 0.5% off. BHI counter was greater than 0.5% off, reset and will be check while POOH 20:00 21:00 1.00 8,927 8,927 PROD1 WHPST MILL P RIH to tag and set depth to 8927'. PUH 10' and bring on pump at 1.54 BPM @3440 pump pressure, 3770psi down hole freespin. rih to 8925' and ark coil for 30 min. 21:00 00:00 3.00 8,927 8,934 PROD1 WHPST MILL P Begin time milling at - 1 FPH. Appear to be milling cement from 8927'. Tag pinch point at 8933.8'. Continue time milling up to 1000 WOB and 200 PSI of motor work. De th at midni ht 8934.6' 5/22/2009 Finish milling window. Milled 10' formation to 8948'. Swapped well over to flo-pro. POOH and un-deploy millin BHA. De to Drillin BHA for build section. 00:00 06:00 6.00 8,934 8,937 PROD1 WHPST MILL P Continue milling window from 8934.6', 1000 WOB, 150 psi motor work, 1 FPH. 06:00 07:00 1.00 8,937. 8,947 PROD1 WHPST DDRL P Drill 10' formation, drift and dry run through window. TOW 8932.7 CTM BOW 8938 BOW CTM. Swap to Flo Pro down coil 07:00 10:30 3.50 8,947 8,947 PROD1 WHPST TRIP P POOH 38K Ibs, following pressure table 10:30 13:00 2.50 8,947 8,947 PROD1 WHPST PULD P On surface, PJSM, Undeploy window milling BHA, Counters @ surface CTES -4.7 BHI 117.65 NAD127.37 Mill 2.73, Strin reamer 2.74 13:00 16:30 3.50 8,947 8,947 PROD1 DRILL PULD P P/U BHA #2 Build section with 2.5 degree motor. Pressure deploy. Surface Pressure 800 PSI 16:30 18:00 1.50 8,947 8,947 PROD1 DRILL SVRG P Reload software in expro choke - service horsehead 18:00 19:00 1.00 8,947 8,947 PROD1 DRILL SFTY P Pre Spud with night crew 19:00 21:00 2.00 8,947 8,947 PROD1 DRILL TRIP P Work with choke and training new crew on MPD o erations 21:00 00:00 3.00 8,947 8,947 PROD1 DRILL TRIP P RIH following MPD tripping schedule ~ar~~ 13 of ~~ Time Logs __ Date From__To Dur S. Depth E_De~th Phase Code___Subcode T Comment 5/23/2009 24 hr summary Drilled Build from 8947' to 9125'. Undeploy build BHA. Deploy lateral BHA which had a tool failure during surface testin Unde to lateral BHA and be in re-de to ment of lateral BHA. 00:00 01:00 1.00 8,947 8,947 PROD1 DRILL TRIP P Continue RIH following MPD tripping schedule 01:00 01:30 0.50 8,947 8,947 PROD1 DRILL DLOG P Correct depth at flag to 8062.12'. Tie in log from 8810' down. + 16' correction. Inteq depth set to 8853.7'. 01:30 02:00 0.50 8,947 8,947 PROD1 DRILL TRIP P Continue RIH to tag at 8947'. Tagged bottom of window on first attempt. Increased ROP to 15 FPM and slid b to bottom. 02:00 03:00 1.00 8,947 9,009 PROD1 DRILL DRLG P Begin drilling from 8947'. 1.5 BPM, 3100 PSI FS, BHP 3300, 18K RIW, 35000 PUW, Drilling at 2-3K WOB, 300-500PSI Motor work. 03:00 03:15 0.25 9,009 9,009 PROD1 DRILL CIRC P Inteq computer lock up. 03:15 09:15 6.00 9,009 9,125 PROD1 DRILL DRLG P 9125' Build section complete, POOH P/U Off 37k F/S 3050 BHP 3300 09:15 09:30 0.25 9,125 9,125 PROD1 DRILL DLOG P Tie into K-1 marker, Log down from 8820 Log down to 8854 BHI, O correction needed 8850 NAD, 8783 Orion 09:30 10:00 0.50 9,125 9,125 PROD1 DRILL TRIP P POOH, folowing MP Schedule, MP choke working on auto Shut EDC @6475 after getting bottoms u Hi h an le motor 10:00 12:00 2.00 9,125 9,125 PROD1 DRILL TRIP P Stop @ 200', Close EDC, 12:00 15:45 3.75 9,125 9,125 PROD1 DRILL PULD P Tag Surface, counters reading CTES 4.3, BHI 141.92 Bit, NAD 39.6 PJSM, Line up valves, Tag and Drop 1.9', Close BOPE. Undeploy Build section BHA as er rocedure 15:45 18:00 2.25 9,125 9,125 PROD1 DRILL PULD P Deploy Lateral drilling BHA with 1 degree motor, resistivity, new motor, and Hu hes bi-center bit. 18:00 19:30 1.50 9,125 9,125 PROD1 DRILL SFTY T Near Bit Inclinometer was not working during surface test of tools. PJSM with new crew to discuss unde to and de to ment of BHA. 19:30 00:00 4.50 9,125 9,125 PROD1 DRILL PULD T Undeploy BHA, CO lower half of Inteq BHA, deploy lateral drilling BHA. 5/24/2009 Pressure deployed lateral drilling BHA. RIH and drill ahead from 9125' to 9886'. 00:00 00:30 0.50 9,125 9,125 PROD1 DRILL PULD T Surface testing MWD tools 00:30 02:00 1.50 9,125 9,125 PROD1 DRILL PULD P Continue with deployment of lateral drillin BHA 02:00 04:15 2.25 9,125 9,125 PROD1 DRILL TRIP P RIH with Lateral driling BHA #3 following managed pressure tripping schedule 04:15 06:30 2.25 9,125 9,125 PROD1 DRILL DLOG P 8748' Stop trip, Close EDC, Log Gamma Ra Tie In +71' Correction ~~ge i4 of 2Q ~ Time Logs I Date From To Dur S. De th E. Depth Phase Code Subcode T Comment 06:30 08:30 2.00 9,125 9,125 PROD1 DRILL DLOG T Lock out injector to inspect gooseneck depth encoder feeding BHI. Counter wheel able to move lateraly on pipe. Secure side movement. 08:30 08:45 0.25 9,125 9,125 PROD1 DRILL DLOG P Run Gamma ray Tie in log +12 ft correction 08:45 09:30 0.75 9,125 9,125 PROD1 DRILL TRIP P Shut EDC, Run through window. Get RA Marker on whipstock @ 8932.5 Run to bottom. 09:30 10:00 0.50 9,125 9,125 PROD1 DRILL DLOG P 9125' PUH 300 Ft/Hr Mad pass build section 36K U 1.5 BPM 3340 FS 10:00 13:00 3.00 9,125 9,275 PROD1 DRILL DRLG P Drill Ahead @ 9125' 36K up 19k Down 3340 FS @ 1.5 BPM WHP 27 IA=180 OA =300 70 FPH 13:00 13:30 0.50 9,275 9,275 PROD1 DRILL WPRT P 9275' Wiper trip to window 37K U 3200PSI FS 13:30 15:00 1.50 9,275 9,425 PROD1 DRILL DRLG P 9275' Drill Ahead 120 FUHr 18k RIW FS3200 BHP 3400 300psi Motor work / 700 Ibs WOB 395 BBIs Active / 2 Centrifuges online IA=190 OA=350 15:00 15:45 0.75 9,425 9,425 PROD1 DRILL WPRT P 9425' Wiper trip to window 36.5k Pick U 3500 PSI FS 15:45 17:00 1.25 9,425 9,575 PROD1 DRILL DRLG P 9425' Drill Ahead 120 FUHr 17k RIW FS3400 BHP 3400 250psi Motor work / 800. Ibs WOB 393 BBIs Active / 2 Centrifuges online IA=190 OA=350 17:00 17:30 0.50 9,575 9,575 PROD1 DRILL WPRT P 9575' Wiper trip to above window and Tie In 37k Pick Up 3500 PSI FS 3510 BHP 389 BBIs Active 17:30 17:45 0.25 9,575 9,575 PROD1 DRILL DLOG P 8850, Rum gamma ray tie in log. Tie into K-1 Correct +1 foot BH 1=8868.33 HMI=8849.14 CTES=8782.3 Raw= 8787.8 Before Correction Tie in Ra Marker 8932.5' 17:45 18:15 0.50 9,575 9,575 PROD1 DRILL WPRT P 8966' RIH to Drill 18.6k RIW 1.5 BPM 3620 FS BHP=3430 18:15 19:30 1.25 9,575 9,712 PROD1 DRILL DRLG P 9575', drilling ahead 18K RIW, 37K PUW 1.5 BPM @ 3300 CTP FS Drilling at 1000-2000 WOB with 150 -200 si motor work for 2 to 2.5 FPM 19:30 20:30 1.00 9,712 9,712 PROD1 DRILL WPRT P 9712' Short trip to window. 37K PUW PQt~e 1 S csf 2~ • Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 20:30 21:45 1.25 9,712 9,865 PROD1 DRILL DRLG P 9712', Drilling ahead 18K RIW, 37K PUW 1.5 BPM @ 3350 CTP FS 3500 psi bottom hole drilling at 1000-2000 WOB with 150 - 250 si motor work for 2.5 FPM 21:45 23:00 1.25 9,865 9,865 PROD1 DRILL WPRT P 9865', Short trip to window. 37K PUW 23:00 23:15 0.25 9,865 9,886 PROD1 DRILL DRLG P 9865', drilling ahead 18K RIW, 37K PUW 1.5 BPM @ 3560 CTP FS 3500 PSI bottom hole Drilling at 1000 - 2000 WOB with 150-300 si motor work for 2.5 FPM 23:15 00:00 0.75 9,886 PROD1 DRILL CIRC P 9886', PUH for Geo to consult with town 5/25/2009 Drill from 9886' - 10,740'. Had 100% losses at 10, 375', gradually improved to 50% losses. 00:00 00:45 0.75 9,886 9,886 PROD1 DRILL WPRT P Continue to PUH while Geo confers with town. 00:45 01:15 0.50 9,886 9,886 PROD1 DRILL WPRT P RIH to resume drilling 01:15 03:00 1.75 9,886 10,050 PROD1 DRILL DRLG P Drilling ahead from 9886' 18K RIW, 37K PUW 1.5 BPM @ 3350 CTP FS 3520 BHP Drilling at 1000 - 2000 WOB with 100-250 psi motor work for 1.5 - 2.0 FPM 03:00 03:39 0.65 10,050 10,050 PROD1 DRILL WPRT P Short trip from 10050' 03:39 03:45 0.10 10,050 10,050 PROD1 DRILL DLOG P Tie into RA at 8933'. + 2' 03:45 04:30 0.75 10,050 10,050 PROD1 DRILL WPRT P Continue short trip to bottom 04:30 05:30 1.00 10,051 10,200 PROD1 DRILL DRLG P 15K RIW, 38K PUW 1.5 BPM @ 3325 CTP FS 3489 BHP Drilling at 800 - 1100 WOB with 900-100 psi motor work for 1.5 - 2.0 FPM 05:30 06:30 1.00 10,200 10,200 PROD1 DRILL WPRT P Wiper trip to 8950 06:30 07:10 0.68 10,200 10,200 PROD1 DRILL WPRT P RIH to resume drilling 07:10 08:14 1.08 10,200 10,350 PROD1 DRILL DRLG P Drilling ahead from 10200 11 K RIW, 38K PUW 1.5 BPM @ 3860 CTP FS 3495 BHP Drilling at 1000 - 1800 WOB with 100-320 psi motor work for 2.25 - 2.5 FPM 08:14 10:14 2.00 10,350 10,350 PROD1 DRILL WPRT P Wiper trip to 8960 -Geo: 5738@10550, 5750@10800, 5754 10900 Pack 9s3 of 2t1 • Time Logs Date From To D ur S_pepth E. De th Phase Code Subcode T Comment _ 10:14 11:29 _ _ 1.25 10,350 10,475 PROD1 DRILL DRLG P ._ _ Drilling -Lost all returns at 10,375 Reduce to 90'/hr, BHP 3050 15K RIW, 45K PUW 1.50 BPM @ 3800 CTP FS Drilling at 1000-1600 WOB with 100-300 si motor work for 1.50 FPM 11:29 11:48 0.33 10,475 10,475 PROD1 DRILL WPRT P Wiper to 10275' (100' above fault) 11:48 13:07 1.33 10,475 10,575 PROD1 DRILL DRLG P Drilling ahead with 1 BPM losses 14 RIW, 41 PUW 1.50 BPM @ 3100 CTP FS 3400 BHP Drilling at 1100 WOB with 100-300 psi motor work for 1.5-2.0 FPM 13:07 13:37 0.50 10,575 10,575 PROD1 DRILL WPRT P Wiper to 10175' (200' above fault) 13:37 14:56 1.33 10,575 10,675 PROD1 DRILL DRLG P Drilling ahead with 0.7 BPM losses 14 RIW, 43 PUW 1.50 BPM @ 3200 CTP FS 3420 BHP Drilling at 1200-2000 WOB with 150-400 psi motor work for 1.0-1.5 FPM 14:56 16:15 1.33 10,675 10,675 PROD1 DRILL WPRT P Wiper trip to 8860' (10' below TT) Total Losses: 338.8 BBL 619.5 FloPro left in its 16:15 17:55 1.67 10,675 10,675 PROD1 DRILL DLOG P Tie into RA at 8933'. + 2' Continue to RIH to 10,675' 17:55 19:25 1.50 10,675 10,714 PROD1 DRILL DRLG P Drilling ahead from 10675' 15K RIW 40K PUW 3200 BHP 1.4 BPM at 2950 CTP FS with 0.6 BPM return rate 2500 WOB with 100 psi motor work for 0.0 - 0.5 FPM 19:25 21:10 1.75 10,714 10,740 PROD1 DRILL DRLG P Begin circ fresh 8.6 ppg FloPro down coil. Returns. still 0.6 bpm. Very slow drilling -stacking 10K-12K at surface to et 1-2000 WOB. 21:10 23:55 2.75 10,740 10,740 PROD1 DRILL WPRT P Lay in 30 bbl hi-vis pill (60k+ LSRV) while POOH to try to reduce losses. Lowered pump rate to 0.7 BPM to maintain prime to mud pumps. Continue OOH to window. Pill had no affect on loss rate -still 0.6 b m returns. RIH. 5/26/2009 Drill from 10740 to 10913'. Geologist called TD. Wiper trip to surface and back to TD with a tie in. 00:00 00:45 0.75 10,740 10,788 PROD1 DRILL DRLG P Drilling ahead with 0.7 BPM losses. Penetration rate much improved for first 50'. 16 RIW, 38 PUW 1.50 BPM @ 3400 CTP FS 3340 BHP Drilling at 2000 WOB with 100-300 psi motor work for 1.5-2.0 FPM ~~e 17 Qf 20 Time Logs Date From To Dur S De th E. De th Ph e Code Subcode T Comment 00:45 02:15 1.50 10,788 10,790 PROD1 DRILL DRLG P Drilling ahead with 0.7 BPM losses. ROP decreased to less than 10 FPH. BHA length wiper did not make a difference. 15 RIW, 38 PUW 1.40 BPM @ 3000 CTP FS 3320 BHP Drilling at 1000 - 2000 WOB with 0 si motor work for 0 FPM 02:15 03:45 1.50 10,790 10,795 PROD1 DRILL DRLG P Set down to -4000 Ibs at surface and got up to 3500 Ibs WOB. At these weights the motor work increased to as high as 800 psi, drilling off about 4'. Losses went up to 1 BPM. Very erratic and slow drillin . 03:45 03:51 0.10 10,795 10,806 PROD1 DRILL DRLG P Broke through the hard spot. Continue drilling ahead. 1000 RIW 1.5 BPM @ 3100 CTP FS 3310 BHP Drilling at 2000 WOB with 200-300 si motor work for 100 ROP 03:51 04:33 0.70 10,806 10,810 PROD1 DRILL DRLG P Drilling No ROP 04:33 05:00 0.45 10,810 10,825 PROD1 DRILL DRLG P Drilling break for 15'. Lost motor work, had over pull at 10805', stacking weight when going down. Used orienter to get free. Condition Ihloe with 100 foot recip. two times. 05:00 06:00 1.00 10,825 10,825 PROD1 DRILL DRLG P Drilling ahead with 0.6 BPM losses. 15 RIW, 38 PUW 1.50 BPM @ 3100 CTP FS 3250 BHP Drilling at 2000 - 3000 WOB, still erratic drillin 06:00 07:15 1.25 10,825 10,910 PROD1 DRILL DRLG P Drilling ahead with 0.6 BPM losses. 15 RIW, 38 PUW 1:50'BPM @ 3100 CTP FS 3290 BHP Drilling at 1500 to 2000 WOB ROP smoothed out to 70 to 90 FPM 07:15 07:45 0.50 10,910 10,910 PROD1 DRILL DRLG P Stacked out at 10910', P/U 60K not moving, RIH to -2000 P/U to 60K. Trap 450 PSI, Shut Down pump, Relax coil. Hold 38k up weight. RIH to -2K, PUH and come on pumps, Po free at 55K 07:45 11:00 3.25 10,910 10,910 PROD1 DRILL WPRT P 10910' Wipe to window38K up weight 1.5 BPM @ 2910 .8 BPM returns No Over ulls / No Setdowns on tri 11:00 12:00 1.00 10,910 10,921 PROD1 DRILL DRLG P Tag Bottom @ 10910, Hard to get drilling. RiH 10FPM to -4k surface. Low ROP 4-10 FPM 23001bs WOB 1.5 BPM 3130 FS ~_ ~~g~ 9$ of 2t1 • J Time Logs ___ T_ Comment Date From To Dur S. De th E. De th Phase Code Subcod e 12:00 13:00 1.00 10,921 10,923 PROD1 DRILL __ _ DRLG _ P Drilling Break 40 FPM 2.6 WOB with 150-200 Diff Press .6 BPM Losses BHP=3305 Ran into hards of 10923 13:00 14:30 1.50 10,923 10,923 PROD1 DRILL DRLG P BHA Wiper trip, PUH 50', Run back to bottom 38K up 3100psi FS 3290 BHP Clean Pick U 14:30 18:30 4.00 10,923 0 PROD1 DRILL WPRT P Well is TD'd 10923 38K P/U Wi e O en hole and tubin 18:30 19:00 0.50 500 500 PROD1 DRILL WPRT P Tag stripper at full pump rate, RIH to 500', shut down pump and close EDC 19:00 22:00 3.00 500 8,820 PROD1 DRILL WPRT P Adjust reel saddle clamps, RIH following managed pressure tripping schedule 22:00 22:00 0.00 8,820 8,850 PROD1 DRILL DLOG P Tie in at formation marker, +20'. Close EDC 22:00 23:54 1.90 8,850 10,913 PROD1 DRILL WPRT P Continue wiper trip to TD 23:54 00:00 0.10 10,913 10,913 PROD1 DRILL DISP P Tag TD at 10913, recip while waiting for liner ill 5/27/2009 POOH and lay down drilling BHA #3 while swapping well to 10.2 Brine. PU and run 2 3/8" slotted liner. Set liner with de to ment sleeve at 8846'. Dis lace well to seawater and FP with 25 Bbls. diesel. 00:00 02:00 2.00 10,913 8,820 PROD1 DRILL DISP P Lay in 40 Bbls. liner running pill, 10.2 ppg with 2 ppb Alpine Beads from TD to window. 02:00 02:15 0.25 8,820 8,850 PROD1 DRILL DLOG P Tie in, Inteq computer locked up while laying in pill. Need to reestablish depth control for liner runnin coil fla s 02:15 04:45 2.50 8,850 0 PROD1 DRILL DISP P POOH swapping well to 10.2 ppg completion brine. Paint flag at 8800' EOP and 6800' EOP. Flow check after to in stri er. No flow 04:45 05:00 0.25 0 PROD1 DRILL SFTY P PJSM to lay down drilling BHA 05:00 07:00 2.00 0 PROD1 DRILL PULD P Lay Down drilling BHA 07:00 07:30 0.50 0 COMPZ CASING SFTY P PJSM Liner running prcedure and Safety joint contigency procedure reviewed 07:30 12:45 5.25 0 2,003 COMPZ CASING PUTS P P/U Liner - 2 3/8 indexing guide shoe, 1 solid joint, 2 3/8 O-ring Sub 60 Joints slotted liner, three solid joints, solid pup, and deployment sleeve. Conducted safe 'oint drill. 12:45 13:15 0.50 2,003 2,003 COMPZ CASING SFTY P Pre-job meeting on MU BHA to liner. 13:15 14:45 1.50 2,003 2,003 COMPZ CASING PULD P MU BHA and GS spear onto liner top de to ment sleeve. 14:45 16:45 2.00 2,003 8,875 COMPZ CASING RUNL P RIH with 2-3/8" slotted liner. 16:45 18:00 1.25 8,875 10,750 COMPZ CASING RUNL P Tie into pipe flag at 6800', putting liner shoe just above window at 8875'. CTES counter = 6765', HMI counter = 8844', Inteq = 8757' MD. PU = 27k, SO = 10k. Continue in hole. F'r~e 19 of 2Q J Time Logs Date From To Dur S De th E. De th Phase Code Subcode T Comment 18:00 19:30 1.50 10,750 10,878 COMPZ CASING RUNL P Set down at 10,750 & 10,806 but work past. Tag TD. PU to tie into pipe flag at 8800'. Log down with GR, confirm tie-in with K1 marker. Position liner top at 8846', bottom of liner at 10,878'. Pum off of liner. 19:30 00:00 4.50 10,878 0 COMPZ CASING RUNL P . POOH. Displace well to seawater. FP well with 25 Bbls. diesel. Offload remaining seawater and 10.2 brine. Cleanin its. 5/28/2009 POOH swapping well to Seawater and Freeze protecting from 2500' 25 BBLs Pumped. Pressure undeply liner runnin BHA, Set BPV, Pressure test tree ca to 4K, RDMO Release Ri 14:00 00:00 00:30 0.50 0 COMPZ CASING SFTY P PJSM for undeploying liner running BHA with 375 PSI wellhead ressure. Continue cleanin its. 00:30 02:30 2.00 COMPZ CASING PULD P Undeploy and laydown liner running BHA 02:30 04:30 2.00 DEMOB WHDBO DMOB P FMC on location to set BPV. Does not have the correct lubricator XO (7" Otis) to run through BOP stack. RU to blow down coiled tubing reel for rig move. Continue cleaning pits and offload KWF. 04:30 08:00 3.50 DEMOB WHDBO NUND P FMC on location with proper lub. RU to set BPV, Pump InOp, Rig up Rig enerpac Set BPV R/D FMC 08:00 14:00 6.00 DEMOB WHDBO NUND P Blow down Stack to Tiger Tank, Secure MP line, secure cellar transducers, Pull lubricator. Rig stack to Blocks. Lift stack and secure. Install Tree cap and test to 4K. Release Ri 14:00 Ra~~ 2~ €xf 2ti • 2X-19A Well Events Summary • DATE SUMMARY 5/31/09 GAUGE W/ 2.73" DRIFT TO DEPLOYMENT SLEEVE @ 8835' SLM (8846' RKB). SET CATCHER @ 8840' RKB. PULL DV'S @ 8036', 6907' & 3492' RKB. SET 1/4" OV @ 8036' RKB & NEW GLV @ 6907' RKB. OPEN POCKET @ 3492' RKB. IN PROGRESS 6/1/09 SET GLV @ 3492' RKB. RAN HOLEFINDER, SET BELOW STA #3 @ 8036' RKB. PT TBG TO 1900 PSI, GOOD TEST. JOB COMPLETE. 6/2/09 MEASURED SBHP @ 8840' RKB (2671 psi) & GRADIENT @ 8705' RKB (2226 psi) JOB COMPLETE 6/4/09 TAGGED ICE PLUG @ 440' SLM. ATTEMPT TO PUMP DOWN TBG, PRESSURED UP TO 3000 PSI. OBTAINED SAMPLE OF ICE. COMPLETE. 6/9/09 ICE PLUG REMOVAL WITH CTU #4. TAG ICE AT 546' CTMD. JET THROUGH PUMPING HEATED DIESEL DOWN COIL AT 1 BPM WITH SLB ICE PICK NOZZLE- RET FL. ICE PRESENT DOWN TO 3560' CTMD. ONCE THROUGH ICE, BRING ON GL 250 MCFPD AND CONTINUE RIH TO 8800' PUMPING 140 DEGF DIESEL DOWN COIL AT 1.3 BPM, WIDE OPEN CHOKE- DOWN FLOWLINE. TOTAL DIESEL PUMPED 270 BBLS. WELL LEFT ON PRODUCTION. 6/11/09 DRIFT TBG 2.78" TO 4000' SLM. PULLED GLV & SET 1/4" OV @ 3494' RKB. COMPLETE. Conoco hillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 2X Pad 2X-19A 500292261801 Baker Hughes. INTEQ Definitive Survey Report ~~~ BAKER Nu+~ INTEQ • 23 June, 2009 -~.-' ConocoPhillips /G~~ ConocoPhilli s ~~ ; p Definitive Survey Report , mss t_ -~ llVTEQ I' Company: ConocoPhillips(Alaska) Inc. .:.._... _ .. ,. ~~ Local Co-ordinate Reference: 2X-19 -n: . ~ «._ ~~ 'i', Project: Kuparuk River Unit TVD Reference: 2X-19 @ 118.OOft (2X-19) Site: Kuparuk 2X Pad MD Reference: 2X-19 @ 118.OOft (2X-19) ';'~ Well: 2X-19 North Reference: True Wellbore: 2X-19A Survey Calculation Method: Minimum Curvature ! Design: 2X-19A Database: EDMv16 Prod iProject Kuparuk River Unit _ _ _ - - - T -- ~ _.. Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2X-19 _. - .. u,n ~-,_. ~,, . ~. . ,....-_._ Well Position +N/S 0.00 ft Northing: 5,970,632.75ft Latitude: 70° 19' 51.366 N +E/-W 0.00 ft Fasting: 518,529.35ft Longitude 149° 50' 58.944 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft Wellbore 2X-19A Magnetics Model Name Sample Da te Declination Dip Angle Field Strength (°) (°) 1nT) User Defined 5/23/2009 22.17 80.81 57,672 Design 2X-19A ,. .. ._ . ~. ,W. . _ ..._.. ___. ..,. ..~ ~.,- u....,._.~,.. ..._,...._ _._,..' ~ Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 8,651.63 i Vertical Section: Depth From (TVD) +NF-S +E/-W Direction (ft) (ftl (ft) (°) 1 " ~ _ ~._~ _.,__..... 11800 _,.. ~: ~ 00 0 00 _ ~,:,_....,, .. ,~ .. _W.... ~__r..,.__.._..__~__...,. ~._.m:.:,_., 302.61 ..-..._m....... ^ _:._._:~,_...._ ._ _ E .-_ _,... . _e ._ . ', Survey Program Date 6/23/2009 ne.. _. ,__..e.. .. _ _.., .... ._, .... _ _. . ~ ~ _ .,,, i From To Survey Survey (ft) (ft) Survey (Wellbore) Tool Name Description Start Date End Date 283.07 8,651.63 2X-19 (2X-19) MWD MWD -Standard _ 1/16/2001 8,926.00 10,885.53 2X-19A (2X-19A) u__ MWD MWD -Standard 5/23/2009 5/26/2009. 6/23/2009 11:23:51AM Page 2 COMPASS 2003.16 Build 42F Y ConocoPhillips //.gar C t100 1. 0P~'II~~I S O p Definitive Survey Report -.~ ,m~_. ,.. _m Alaska. _ ~_.~ m~~~-. ~ m z~ . _ ~-- - - _ ~ ~ - . . , _ z_...~_ . _ . ~ _ .~ ....~., INTEQ ». Company: ConocoPhillips(Alaska) Ina Local Co-ordinate Referenc e: 2X-19 i Project: Kuparuk River Unit ND Reference: 2X-19 @ 118.OOft (2X-19) r Site: Kuparuk 2X Pad MD Reference: 2X-19 @ 118.OOft (2X-19) Well; 2X-19 North Reference: True Wellbore: 2X-19A Survey Cal culation Method: Minimum Curvature ' Design: ~ 2X-19A Database: .,_ - .~.., r ~ .-. ...~.~. EDMv _~ . 16 Prod .~- ,-,_.~, , _ .. _.~=n ~ .. _ . -_.~. ~ - _. , .~. ~.~ _ . -.w~., ~ m ....~.n ...,. ~... .~_.~ _ ........ ~.. .. ._ ~,... _.. .__ . ~, ...E.<.. . ~~_~,_... ~..~ _., . ..~-., Tm, ...,,.. ~._ ._ ,, ~,w_ ~.... ...,., .~ e...-s......~_~._~__ Map Map Vertical MD Inc ° Azi ° ND NDSS +N/-S +E/-W Northing Easting DLS ' ° Section Survey Tool Name Annotatl0n (ft) ( ) ( ) (ft) (ft) (ft) (ft) (ft) (~) /100 ) ( (ft) F 8,651.63 41.35 311.49 5,606.13 5,488.13 4,456.25 -4,209.52 5,975,078.14 514,309.25 1.25 5,947.43 MWD (2) TIP 2X-19 8,926.00 42.77 320.51 5,810.02 5,692.02 4,588.31 -4,336.78 5,975,209.88 514,181.68 2.26 6,125.80 MWD (2) KOP; Interpolated Azi 8,957.51 50.71 322.18 5,831.60 5,713.60 4,606.23 -4,351.09 5,975,227.76 514,167.33 25.49 6 147.51 MWD (2) , 8,994.58 68.72 323.60 5,850.22 5,732.22 4,631.67 -4,370.29 5,975,253.15 514,148.07 48.70 6,177.40 MWD (2) 9,024.16 79.02 310.86 5,858.45 5,740.46 4,652.40 -4,389.58 5,875,273.83 .514,128.73 54.02 6,204.81 MWD (2) 9,057.10 84.22 295.08 5,863.28 5,745.28 4,670.04 -4,416.83 5,975,291.40 514,101.44 49.93 6,237.28 MWD (2) 9,084.08 82.31 281.15 5,866.46 5,748.46 4,678.36 -4,442.23 5,975,299.65 514,076.02 51.76 6,263.15 MWD (2) 9,113.81 84.96 262.92 5,869.79 5,751.79 4,679.39 -4,471.63 5,975,300.61 514,046.62 61.58 6,288.48 MWD (2) I 9,154.86 90.00 256.91 5,871.59 5,753.59 4,672.21 -4,511.97 5,975,293.33 514,006.30 19.09 6,318.59 MWD (2) 9,187.21 91.17 252.42 5,871.28 5,753.26 4,663.66 -4,543.16 5,975,284.71 513,975.14 14.34 6,340.25 MWD (2) 9,216.21 93.37 248.25 5,870.11 5,752.11 4,653.91 -4,570.44 5,975,274.89 513,947.88 16.25 6,357.88 MWD (2) 9,251.41 92.09 243.28 5,668.44 5,750.44 4,639.48 -4,602.49 5,975,260.39 513,915.87 14.56 6,377.20 MWD (2) 9,282.22 92.36 239.65 5,867.24 5,749.24 4,624.78 -4,629.53 5,975,245.62 513,888.87 11.81 6,392.06 MWD (2) 9,312.98 92.61 242.71 5,865.90 5,747.90 4,609.96 -4,656.46 5,975,230.74 513,861.99 9.97 6,406.76 MWD (2) 9,344.77 92.88 241.27 5,864.38 5,746.38 4,595.05 -4,684.49 5,975,215.76 513,833.99 4.60 6,422.33 MWD (2) 9,378.04. 92.18 236.28 5,862.91 5,744.91 4,577.83 -4,712.90 5,975,198.47 513,805.62 15.13 6,436.99 MWD (2) H 9,426.01 92.58 230.50 5,860.92 5,742.92 4,549.26 -4,751.36 5,975,169.80 513,767.24 12.07 6,453.99 MWD (2) 9,455.64 92.27 225.53 5,659.66 5,741.66 4,529.46 -4,773.36 5,975,149.95 513,745.30 16.79 6,461.85 MWD (2) 9,490.77 90.40 218.24 5,858.84 5,740.85 4,503.33 -4,796.79 5,975,123.77 513,721.93 21.42 6,467.50 MWD (2) 9,522.21 89.08 211.77 5,858.99 5,740.99 4,477.59 -4,814.81 5,975,097.99 513,703.97 21.00 6,468.82 MWD (2) 9,554.11 91.26 207.14 5,858.89 5,740.89 4,449.83 -4,830.49 5,975,070.19 513,688.36 16.04 6,467.06 MWD (2) 9,587.91 91.23 201.92 5,858.16 5,740.16 4,419.09 -4,844.52 5,975,039.42 513,674.41 15.44 6,462.32 MWD (2) 9,616.82 91.32 196.64 5,857.51 5,739.51 4,391.82 -4,654.06 5,975,012.13 513,664.94 18.26 6,455.66 MWD (2) j~ 9,655.06 i 90.86 189.52 5,856.79 5,738.79 4,354.60 -4,862.71 5,974,974.90 513,656.39 18.65 6,442.88 MWD (2) . 9,681.34 92.09 184.99 5,856.11 5,738.11 4,328.55 -4,866.02 5,974,946.84 513,653.14 17.86 6,431.64 MWD (2) 9,712.52 93.04 160.07 5,854.71 5,736.71 4,297.44 -4,867.40 5,974,917.73 513,651.84 16.06 6,416.03 MWD (2) 9,746.31 94.67 175.09 5,852.44 5,734.44 4,263.77 -4,865.98 5,974,884.06 513,653.34 15.48 6,396.69 MWD (2) 9,774.93 95.96 179.45 5,849.79 5,731.79. 4,235.31 -4,864.62 5,974,855.61 513,654.77 15.82 6,380.21 MWD (2) 9,806.22 95.00 183.85 5,846.80 5,728.80 4,204.19 -4,865.52 5,974,824.49 513,653.95 14.33 6,364.19 MWD (2) ( a 9,835.73 95.01 189.52 5.844.22 5,726.22x- 4,175.00 -4,868.94 5,974,795.30 513,650.60 19.14 6,351.35 MWD(2) 6/23/2009 11:23:51AM Page 3 COMPASS 2003.16 Build 42F • / Pf ~ ConocoPhillips C01100 0 '11 ~Ip5 Definitive Sulvey Report Alaska;. Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: 2X-19 '' Project: Kuparuk River Unit TVD Reference: 2X-19 @ 118.OOft (2X-19) Site: Kuparuk 2X Pad MD Reference: 2X-19 @ 118.OOft (2X-19) !' Well: 2X-19 North Reference: True. '! Wellbore: 2X-19A Survey Calculation Method: Minimum Curvature '~ Design: 2X-19A Database: EDMv16 Prod Survey MD Inc (ft) (°) I 9, 866.31 94.48 ~ 9,895.63 94.67 9,925.38 96.31 9,954.64 92.58 9,964.73 92.06 ( 10,018.73 91.57 10,048.31 91.01 10,076.67 90.22 10,107.84 89.51 10,138.44 87.01 10,171.34 85.75 10,205.91 84.86 10,236.46 83.09 10,266.73 e 83.00 10,309.14 83.81 s 10,340.50 87.69 ~~ 10,369.91 90.92 10,399.80 92.52 10,433.08 91.60 10,463.17 90.28 10,493.96 E 87.72 10,525.13 86.83 10,554.81 86.83 10,586.17 86.15 10,616.32 85.48 10,645.20 82.19 10,676.29 82.54 10,708.71 85.07 10,739.49 85.91 10,769.16 88.03 ~ 10,802.42 91.11 Azi TVD TVDSS (°) (ft) (ft) 193.55 5,841.69 5,723.69 195.66 5,839.35 5,721.35 199.46 5,836.50 5,718.50 201.83 5,834.24 5,716.24 207.04 5,833.02 5,715.02 212.14 5,831.94 5,713.94 216.71 5,831.27 5,713.27 221.47 5,830.97 5,712.97 226.21 5,831.04 5,713.04 230.02 5,831.97 5,713.97 234.78 5,834.05 5,716.05 237.30 5,836.88 5,718.88 232.01 5,840.09 5,722.09 228.00 5,843.76 5,725.76 225.75 5,848.63 5,730.63 230.86 5,650.95 5,732.95 236.69 5,851.31 5,733.31 241.32 5,850.41 5,732.41 246.74 5,849.22 5,731.22 250.66 5,848.72 5,730.72 255.04 5,849.26 5,731.26 259.88 5,850.74 5,732.74 264.88 5,852.36 5,734.38 268.67 5,854.30 5,736.31 274,07 5,856.51 5,738.51 272.95 5,859.61 5,741.61 268.42 5,863.74 5,745.74 263.46 5,867.35 5,749.35 259.13 5,869.69 5,751.69 256.83 5,871.26 5,753.26 254.89 5,871.51 5,753.51 +N/_g +E/_yy (ft) (ft) 4,145.15 -4,875.03 4,116.87 -4,882.40 4,088.64 -4,891.33 4,061.35 -4,901.61 4,033.99 -4,914.05 4,004.45 -4,930.82 3,980.06 -4,947.54 3,958.06 -4,965.41 3,935.58 -4,986.99 3,915.16 -5,009.76 3,895.14 -5,035.76 3,875.89 -5,064.34 3,858.32 -5,089.11 3,839.02 -5,112.13 3,810.22 -5,142.87 3,789.43 -5,166.21 3,772.06 -5,189.92 3,756.68 -5,215.53 3,742.12 -5,245.42 3,731.20 -5,273.44 3,722.12 -5,302.85 3,715.36 -5,333.23 3,711.43 -5,362.59 3,709.67 -5,393.84 3,710.39 -5,423.89 3,712.15 -5,452.54 3,712.52 -5,483.35 3,710.16 -5,516.48 3,705.67 -5,545.81 3,699.50 -5,574.79 3,691.38 -5,607.03 Map Map Northing Easting (ft) (ft) 5,974,765.43 513,644.58 5,974,737.14 513,637.29 5,974,708.89 513,628.42 5,974,681.58 513,618.21 5,974,654.19 513,605.84 5, 974,624.61 513, 589.14 5,974,600.18 513,572.49 5,974,578.13 513,554.67 5, 974, 555.61 513,533.15 5,974,535.14 513,510.44 5,974,515.05 513,484.48 5,974,495.73 513,455.96 5,974,478.11 513,431.23 5,974,458.75 513,408.27 5,974,429.88 513,377.60 5,974,409.03 513,354.31 5 , 974 , 3 91.61 513 , 3 3 0.64 5,974,376.16 513,305.08 5,974,361.53 513,275.23 5,974,350.54 513,247.24 5,974,341.39 513,217.85 5,974,334.56 513,187.49 5,974,330.56 513,158.14 5,974,328.72 513,126.90 5,974,329.36 513,096.85 5,974,331.05 513,068.20 5,974,331.34 513,037.40 5, 974, 328.91 513 , 004.28 5,974,324.34 512,974.95 5,974,318.10 512,946.00 5,974,309.90 512,913.77 ~i~r ~~ uwrEQ Annotation Vertical DLS (°l100') Section Survey Tool Name (ft) 13.25 6,340.39 MWD (2) 7.20 6,331.36 MWD (2) 13.66 6,323.67 MWD (2) 15.09 6,317.63 MWD (2) 17.39 6,313.35 MWD (2) 15.06 6,311.57 MWD (2) 15.56 6,312.50 MWD (2) 17.01 6,315.70 MWD (2) 15.38 6,321.77 MWD (2) 14.89 6,329.95 MWD (2) 14.94 6,341.06 MWD (2) 7.71 6,354.76 MWD (2) 18.17 6,366.16 MWD (2) 13.15 6,375.14 MWD (2) 5.61 6,385.52 MWD (2) 20.42 6,393.98 MWD (2) 22.66 6,404.60 MWD (2) 16.38 6,417.87 MWD (2) 16.51 6,435.21 MWD (2) 13.74 6,452.93 MWD (2) 16.47 6,472.81 MWD (2) 15.77 6,494.76 MWD (2) 16.82 6,517.38 MWD (2) 12.26 6,542.75 MWD (2) 18.00 6,568.45 MWD (2) 12.03 6,593.53 MWD (2) 14.49 6,619.68 MWD (2) 16.58 6,646.32 MWD (2) 14.77 6,668.61 MWD (2) 10.53 . 6,689.69 MWD (2) 10.94 6,712.48 MWD (2) • 6/23/2009 11:23:51AM Page 4 COMPASS 2003.16 Build 42F Cor~oc Phillips' Alaska: Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk ZX Pad Well: 2X-19 Wel lbore: 2X-19A Design: 2X-19A .,..-.-, m . ~.. Survey .. ~... _... ... ~ .~_ ..~__„ . MD Inc Azi TVD TVDSS (ft) (°) (°) (ft) (ft) 10,834.10 89.91 252.19 5,871.23 5,753.23 10,869.96 89.08 248.58 5,871.54 5,753.54 10,865.53 88.77 246.21. 5,871.84 5,753.84 • 10,913.00 88.77 246.21 5,872.43 ~ 5,754.43 ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: 2X-19 TVD Reference: 2X-19 @ 118.OOft (2X-19) MD Reference: 2X-19 @ 118.OOft (2X-19) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDMv16 Prod Map Map Vertical +N/-S (ft) +E/-W Northing (ft) Easting DLS Section Survey Tool Name (°/100') (ft) (~) (ft) 3,682.40 -5,637.41 5,974,300.85 512,883.42 9.33 6,733.23 MWD (2) 3,670.37 -5,671.18 5,974,288.73 512,849.68 10.33 6,755.19 MWD (2) 9,664.38 -5,685.55 5,974,282.71 512,835.33 15.35 6,764.07 MWD (2) 3,653.30 -5,710.68 5,974,271.57 , 512,810.23 , 0.00 6,779.27 PROJECTED to TD ri.~ ~~ 1VTEQ Annotation 6123/2009 11:23:51AM Page 5 COMPASS 2003.16 Build 42F ~. ~-~ ~"° ~ ~~ -~ ~~'a' ~~ ~~ ! SARAH PAL/N, GOVERNOR ~+ ~! ALASSA OIL AIQD GA5 333 W. 7th AVENUE, SUITE 100 COI~T5L'`RQATIOr1T COMhII5SI01'1T ~ ANCHORAGE, ALASKA 9950 ~-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Venhaus CT Drilling Engineer ConocoPhillips Alaska Inc. c/o PO Box 196612 Anchorage, AK 99519-6612 Re: Kuparuk River Field, Kuparuk River Oil Pool, Kuparuk 2X-19A ConocoPhillips Alaska Inc. Permit No: 208-111 Surface Location: 630' FSL, 600' FEL, SEC. 04, T11N, R09E, UM Bottomhole Location: 4078' FSL, 1162' FEL, SEC. 05, T11N, R09E, UM Dear Mr. Venhaus: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, ~~°` Daniel T. Seamount, Jr. ~ Chair n DATED this Z day of July, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~~~ ~ ~ 20~~ ALAS~IL AND GAS CONSERVATION COMMI~N ~~ I PERMIT TO DRILL AIa~Ga t~i1 ~ Gas Cans, Com,ril;~::: 20 AAC 25.005 ~OC~,C~80g 1 a. Type of work _ ^ Drill ®Redritl ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test . ®Development Oil ^ Single Zone 1 c. Specify if well is proposed for: ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: Conoco Phillips Alaska Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 59-52-180 • 11. Well Name and Number: Kuparuk 2X-19A 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 11250' ' TVD 5815'ss 12. Field /Pool(s): Kuparuk River Unit /Kuparuk 4a. Location of Well (Governmental Section): Surface: 630' FSL 600' FEL SEC 04 T11 N R09E UM ' 7. Property Designation: ADS-025645 & 025642~D2SG River Pool ?,f,c8 , , . , , , Top of Productive Horizon: 7•f• 5216' FSL, 4926' FEL, SEC. 04, T11 N, R09E, UM 8. Land Use Permit: 13. Approximate Spud Date: July 15, 2008 Total Depth: 4078' FSL, 1162' FEL, SEC. 05, T11 N, R09E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 30,500' 4b. Location of Well (State Base Plane Coordinates): Surface: x-518530 y-5970633 Zone-ASP4 10. KB Elevation (Height above GL): 118' ' feet 15. Distance to Nearest Well Within Pool: 600' 16. Deviated Wells: Kickoff Depth: gg25 ~ feet Maximum Hole An le: 98 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2682 Surface: 2652 18. Casin Pro ram: S cificatio ns To - Settin De th -Bottom Quanti of Cement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 3" 2-3/8" 4.7# L-80 STL 2405' 8845' 5632'ss 11250' S815'ss Uncemented Slotted Liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 9518' Total Depth TVD (ft): 6227 Plugs (measured): 9047 Effective Depth MD (ft): 9418' Effective Depth TVD (ft): 6160' Junk (measured): None Casing Length Size Cement Votume MD TVD Conductor /Structural 121' 16" 245 sx Arcticset I 121' 121' Surface 5791' 7-5/8" 963 sx Arcticset III 420 sx Class'G' 5791' 3899' Intermediate Producti n 9507' S-1/2" 160 sx CI ss'G' 9507' 6220' Liner Perforation Depth MD (ft): 8822' - 9294' Perforation Depth TVD (ft): 5807' - 6074' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Dan Venhaus, 263-4372 Printed Name Dan aus Title CT Drilling Engineer Dan Venhaus, 230-0188 / Prepared By Name/Number: Si nature Phone 263-4372 Date b 'lQ ~~ Terrie Hubble, 564-4628 Commission lJse Ont. Permit To Drill Number: 208-~~~ API Number: 50-029-22618-01-00 Permit Approval See cover letter for Date: other re uirements Conditions of Approval: ~/ If box is checked, well may not be used to explore for, test, or produce coalbed me_th``ane, gas hydrates, or gas contained shales: L7 Samples Req'd: ^ Yes L~IVO Mud Log Req'd: ^ Yes p"No ~~~~''y~~? ~o HZS Measures: [-~Yes ^ No Directional Survey Req'd: C~es ^ No ~~ ~.dti \ ~ l ~V ~ "~"y~ Other: Date ~~ APPROVED BY THE COMMISSION COMMISSIONER Form 10-401 Revised~12/2005 ~ R ~ G l N ~ Lr ~J / ~ Submit In Duplicate 7. /, b a° r~ .~/i/~ • KRU 2X-19A Lateral -Coiled Tubing Drilling Summary of Operations: We112X-19 is currently a producer completed in both the A sand and the C sand with a 5-1/2" liner and 3-1/2" tubing. The CTD sidetrack will target the C-sand only. The A-sand has been plugged back with sand and a cement cap. For the drilling of the L1 lateral, a 3-1/2" x 5-1/2" whipstock will be set and cemented in place at 8925' MD at the top C4 perfs. The cement squeeze will isolate the existing C-sand perfs containing awatered-out interval in the lower section of perfs. The L1 lateral will land in the upper C3 @ 5750' TVD to avoid the suspected water interval. The horizontal will be drilled with a 2.70" x 3" bi-center bit on 2" e-coil. The well path will undulate twice to access sufficient cross-cut through the C4 sand and TD at 11,250' MD. The lateral will be completed with a 23/8" slotted liner (8 slots per foot) through the horizontal section and solid liner through the build to allow isolation options in the future. The liner top will be run up into the 3-1/2" tubing tail. CTD Drill and Complete 2X-19A program: .Tune 2008 Pre-Ri g Work 1. Test packoffs - T & IC. 2. MITOA. PPPOT-T & IC. 3. PT Master & Swab to 4500 psi. 4. Drawdown test on Master & Swab to 0 psi. `~~~ ~ 5. SBHP. Drift to 2.73" and tag PBTD 6. Caliper tubing and liner from PBTD to surface. ~~ 7. Run dummy whipstock drift 8. Run DGLV's. Load and test IA 9. Run & set whipstock on WPPT 10. Cement squeeze perforations - 15.8 ppg cmt 11. PT cement plug to 1500 psi. 12. Prepare well & pad for rig arrival Rig Work 1. .~ h``~ ~~~ MIRU Nordic Rig #2 using 2" coil tubing. NU 7-1/16" BOPE, test. Kill well with 8.5 ppg brine. RIH with aflow-by thru-tubing whipstock for 5'/z" liner. Set the whipstock at 8925' MD with high-side orientation. 2X-19A Lateral a. Mi112.74" window with high-side orientation. b. Dri112.70" x 3" bi-center lateral southwest to TD of 11,250' MD. c. Kill well. Run 23/8" slotted liner through horizontal section and blank pipe through build section. Top of liner inside 3-1/2" tubing tail ~ 8845'. Freeze protect. ND BOPE. RDMO Nordic 2. 4 Post-Rig Work 1. Obtain static BHP 2. Run GLVs. Return well to production. Page 1 of 3 June 16, 2008 KRU 2X-19A Lateral -Coiled Tubing Drilling Mud Program: • Will use chloride-based Biozan brine (8.5 ppg) for milling operations, and chloride-based Flo-Pro mud ' (~8.6 ppg) for drilling operations. Since there is no SCSSV installed in 2X-19, we will have to kill the well to deploy 23/8" slotted liner. Disposal: • No annular injection on this well. • Class II liquids to KRU 1R Pad Class II disposal well • Class II drill solids to Grind & Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. Casing Program: • 2X-19A: 23/8", 4.7#, L-80, ST-L slotted liner from 8,845' MD to 11,250' MD Existing Casing/Liner Information Surface: 75/8", L-80, 29.7 ppf Burst 6890 psi; Collapse 4790 psi Production: Slh", L-80, 15.5 ppf Burst 7000 psi; Collapse 4990 psi Well Control: • Two well bore volumes 0200 bbl) 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. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. Maximum / potential surface pressure is 2652 psi assuming a gas gradient to surface and maximum potential formation / pressure (i.e. based on highest bottom hole pressure measurement in the vicinity, which is 3226 psi in offset injector 2X-08 in March 2008). • 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. 2X-19A TD: 30,500' to property line, 600' to we112U-O1 Logging • MWD directional, resistivity, and gamma ray will be run over the entire open hole section. Reservoir Pressure The most recent static BHP survey in we112X-19 was taken September 2007, and measured reservoir / pressure of 2682 psi at 5735' TVD corresponding to 9.0 ppg EMW. Expect to encounter similar to slightly increasing pressure as the laterals are drilled away from the mother well, although higher pressures could be encountered with unexpected fault crossings. Page 2 of 3 June 16, 2008 u KRU 2X-19A Lateral -Coiled Tubing Drilling Hazards • Some lost circulation is expected as seen in previous C-sand CTD sidetracks. Expect to encounter similar to slightly increasing pressure as the laterals are drilled away from the mother well. • Hole cleaning in tubing which has a long tangent section @ 60 degrees. • Drilling toward large fault which could throw the well into the Kalubik shale forcing a plugback. • We112X-19 has 95 ppm HZS as measured in 2007. Injection we112X-08 is located 120' to the right side of the 2X-19 surface location but has no measured HZS since it is an injector. The maximum HZS level on the 2X pad is 210 ppm from we112X-16 (2007). All HzS monitoring equipment will be operational. Managed Pressure Drilling Managed pressure drilling (MPD) techniques will be employed to provide constant bottom hole pressure by using 8.6 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 allow use of less 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 will be installed 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 under trapped wellhead pressure. Pressure deployment of the 23/8" BHA will be accomplished utilizing the 23/8" pipe rams and slip rams. The annular preventer will act as a secondary containment during deployment and not as a stripper. We112X-19 does not have a SSSV, so the well will have to be killed 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 scenario is expected at TD: • Estimated reservoir pressure: 2682 psi at 8985' MD (5735' TVD), or 9.0 ppg EMW. ' • Expected annular friction losses while circulating: 800 psi (assuming friction of 90 psi/1000 ft). • Planned mud density: 8.6 ppg equates to 2565 psi hydrostatic bottom hole pressure at 5735' TVD • While circulating 8.6 ppg mud, bottom hole circulating pressure is estimated to be 3365 psi or 11.3 ppg EMW without holding any additional surface pressure. This will sufficiently overbalance formation pressure in 2X-19. If increased formation pressure is encountered while drilling the BL1 lateral, mud weight or choke pressure will be increased to maintain overbalance. • When circulation is stopped, it is anticipated that 800 psi of surface pressure shall have to be applied to balance reservoir pressure and maintain the same borehole pressure as during drilling operations. Page 3 of 3 June 16, 2008 ConocoPhillips Alaska, Inc. KRU 2X-19 ~ Zx-~ s API: 500292261800 Well T e: PROD An le TS: 43 de 8923 TUBING (0-1905, OD:3 500 SSSV Type: Nipple Orig COm IetlOn: 11/17/1995 Angle @ TD: 48 deg @ 9518 , . ID:2.ssz) Annular Fluid: Last W/O: Rev Reason: SLM TAG CMT sssv Reference L Ref Lo Date: Last U ate: 10/5/2007 (tsoa-t9os, OD 3 00 Last Ta : 9098 TD: 9518 ftKB : .5 ) Last Ta Date: 9/24/2007 Max Hole An le: 61 de 6432 Casin Strin -ALL STRINGS Descri lion Size To Bottom TVD Wt Grade Thread Lift G CONDUCTOR 16.000 0 121 121 62.58 H-40 as MandrelNalve SUR. CASING 7.625 0 5791 3899 29.70 L-80 ~ PROD. CASING 5.500 0 9507 6219 15.50 L-80 (3asz-34x3' Tubin Strin -TUBING Size To Bottom TVD Wt Grade Thread 3.500 0 1905 1715 9.20 L-80 ABM-BTC 3.500 1905 8851 5749 9.30 L-80 ABM-EUE Gas lift Perforations Summa MandrelNalve Interval TVD Zone Status Ft SPF Date T e Comment 2 (6907-6908, 8922 - 8986 5800 - 5846 C-4 64 10 9/22/2001 RPERF 2.5" HSD PJ HMX; 60 deg h 8986 - 9030 5846 - 5877 C-4,C-3,C-1 44 6 9/22/2001 RPERF 2.5" HSD PJ HMX; 60 deg h Gas Lin 9030 - 9032 5877 - 5879 C-1 2 10 9/22/2001 RPERF 2.5" HSD PJ HMX; 60 deg h MandrelNalve 3 (8036-8037 ~ ~ I 9032 - 9048 5879 - 5890 C-1 16 6 9/22/2001 RPERF 2.5" HSD PJ HMX; 60 deg h , 9264 - 9294 6045 - 6067 A-3 30 4 3/22/1996 IPERF 2.5 " HC; 180 de hasin Stimulations 8 Treatments Interval Date T e Comment 8922 - 8937 10/18/2003 FRAC 86M# 20/40 Gas un Gas Lift Mandrels/Valves MandrelNalve 4 (8757-8758, ~ --. _ St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 3492 260 5 BST AXT GLV 1.0 T-1 0.125 1402 10/21/200 2 6907 449 9 BST AXT GLV 1.0 T-1 0.156 1386 10/21/200 3 8036 519 4 BST AXT GLV 1.0 T-1 0.188 1392 10/22/200 4 8757 568 2 BST AXT OV 1.0 T-1 0.188 0 10/20/200 PBR aata eels Other lu s, a ui ., etc. -COMPLETION ( - , OD:3 500) De th TVD T e Descri lion ID . 1904 1714 SSSV Camco 'BP-6i' sin le line control ni le 2.812 8814 5723 PBR Baker'80-40' 10'stroke 3.000 8829 5733 PKR Baker'FAB-1' 3.000 8840 5741 NIP Camco 'D' Ni le NO GO 2.750 8850 5748 SOS Camco 2.992 PKR (8829-8830 8851 5749 TTL 2.992 , oD:a.ss3> 9047 5890 PLUG SAND PLUG 9/2/2007 0.000 NIP (8840-8841, OD:3.500) TUBING (1905-8851, OD:3.500, ID:2.992) SOS (8850-8851, OD 3 500 : . ) FRAC (8922-8937) Perf (8922-8986) Perf (8922-9048) Perf - (9030-9032) Perf (9264-9294) - ... - _. -~ 2X-19A Proposed CTD Sidetrack 16" 62# H-40 shoe @ 121' MD 7-5/8" 29.7# L-80 shoe @ 5791' MD 3-1/2" Camco BP-I6 control line nipple @ 1904' MD 3-1/2" 9.3# L-80 ABM-BTC Tubing from 1905' to surface 3-1/2" 9.3# L-80 ABM-EUE Tubing from 8851' to 1905' 3-1/2" BST AXT gas lift mandrels @ 3492', 6907', 8036', 8757' MD ~ of 2-3/8" liner inside TT) C-sand perfs 8922' - 9048' Sand/cement plugback to 9120' ELMD A-sand perfs 9264' - 9294' 3-1/2" 80-40 PBR @ 8814' MD (3" ID) FAB-1 packer @ 8829' MD (3.0" ID) 3-1/2" Camco D landing nipple @ 8840' MD (2.75" min ID, No-Go) 3-1l2" tubing tail @ 8851' MD 1/2" Baker cemented in place // / 5-1/2" 15.5# L-80 shoe @ 9507' MD ~OriOCOPhllli s Alaska Inc p Baker Hughes INTEQ Planning Report BAKER f~WGHES INTEQ ~ Company: ConocoPhillips Alaska Inc. Date: 6/17/2008 "fimc: 16:12:45 Page: 1 ', ~' Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 2X-19, True North Sitr. Kuparuk 2X Pad Vertical ITVll) Keference: 2X-19 118.0 bVell: 2X-19 Section fVS) Keference: Well (O.OON,O.OOE,215.OOAzi) i Wellpath: Plan 6, 2X-19A Sur~cr Calculation D4cthod: __ _ Minimum Curvature Db: Sybase ___ __ Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: Kuparuk 2X Pad Site Position: Northing: 5970513.01 ft Latitude: 70 19 50.180 N From: Map Easting: 518889.00 ft Longitude: 149 50 48.451 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.14 deg Well: 2X-19 Slot Name: Well Position: +N/-S 120.66 ft Northing: 5970632.75 ft ~ Latitude: 70 19 51.366 N +E/-W -359.38 ft Easting : 518529.35 ft Longitude: 149 50 58.944 W Position Uncertainty: 0.00 ft Wellpath: Plan 6, 2X-19A Drilled From: 2X-19 Tie-on Depth: 8651.63 ft Current Datum: 2X-19 Height 118.00 ft Above System Datum: Mean Sea Level Magnetic Data: 6/17/2008 Declination: 22.63 deg Field Strength: 57630 nT Mag Dip Angle: 80.81 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 118.00 0.00 0.00 2 15.00 Plan: Plan #6 Date Composed: 6/17/2008 copy Dan V.'s plan 6 Version: 2 Principal: Yes Tied-to: From: Definitive Path Targets Map Map <---- Latitude ---a < -- Longitude --a Name Description TVD +N/-S +E/-W Northing Eastin g Deg Min Sec Deg Min Sec Dip. Dir. - _ -- ~ Annotation nlll TVD ft ft _ _ _ 8651.63 5606.13 TIP 8925.00 5809.28 KOP 8945.00 5823.76 End of 9 Deg/100' DLS 9058.14 5868.45 4 9183.14 5872.28 End of 40 Deg/100' DLS 9433.14 5877.63 6 9683.14 5893.38 7 9783.14 5898.48 8 9903.14 5893.11 9 10083.14 5873.16 10 10233.14 5863.11 11 10583.14 5883.07 12 10733.14 5897.24 13 10808.14 5903.04 14 11008.14 5917.57 15 11250.00 0.00 TD ~ OriOCOPhllll s Alaska Inc BAK R HUGHES Baker Hughes INTEQ Planning Report 1NTEQ Company: ConocoPhillips Alaska Inc. llate: 6/17/2008 Time: 16:12:45 Pagc: 2 Cield: K uparuk Riv er Unit Co-ordinate(NE) Reference: We ll: 2X-19, True North Site: K uparuk 2X Pad Verti cal (TVD) 12eferencc: 2X- 19 118.0 Nell: 2X-19 Sccti ou (VS) Reference: We ll (O.OON,O.OOE,215.OOA zi) ~~ ~Vellpafh: Pl an 6, 2X-1 9A Survey Calculation Method: Min imum Curvatu re llh: Sybase Plan Sect ion informatio n NIll Incl ~~zim TVD +N/-S +El-W DLS Iluild Turn TFO "Ca rget ft deg deg ft ft ft deg/100ft deg /100ft deg/100ft deg 8651.63 41.35 311.49 5606.13 4456.25 -4209.52 0.00 0. 00 0.00 0.00 8925.00 42.77 320.48 5809.28 4587.80 -4336.35 2.26 0. 52 3.29 80.10 8945.00 44.46 319.60 5823.76 4598.37 -4345.21 9.00 8. 47 -4.39 340.00 9058.14 88.00 305.53 5868.45 4664.90 -4420.87 40.00 38. 48 -12.43 340.00 9183.14 88.71 255.52 5872.28 4686.99 -4539.85 40.00 0. 57 -40.01 270.00 9433.14 88.89 225.51 5877.63 4565.37 -4754.94 12.00 0. 07 -12.00 270.00 9683.14 84.05 195.84 5893.38 4353.31 -4880.91 12.00 -1. 93 -11.87 260.00 9783.14 90.12 185.46 5898.48 4255.34 -4899.31 12.00 6. 06 -10.37 300.00 9903.14 94.99 171.90 5893.11 4135.80 -4896.58 12.00 4. 06 -11.31 290.00 10083.14 97.58 193.47 5873.16 3958.17 -4904.83 12.00 1. 44 11.99 82.00 10233.14 90.05 209.87 5863.11 3819.70 -4959.96 12.00 -5. 02 10.93 114.00 10583.14 83.70 251.47 5883.07 3602.88 -5223.97 12.00 -1. 82 11.89 99.50 10733.14 85.55 269.46 5897.24 3578.29 -5370.63 12.00 1. 23 11.99 85.00 10808.14 85.60 278.49 5903.04 3583.46 -5445.15 12.00 0. 07 12.04 90.00 11008.14 86.19 254.43 5917.57 3571.21 -5642.78 12.00 0. 29 -12.03 270.50 11250.00 86.67 225.35 5932.97 3451.42 -5849.34 12.00 0. 20 -12.02 270.00 Survey - -- - - NID Incl - Azim SS TVll _ N!S E/W NIapN NIapF, llLS VS TPO "1'00 ft .deg deg ft ft ft ft ft deg/100ft ft deg 8651. 63 41.35 311.49 5488.13 4456.25 -4209. 52 5975078. 14 514309. 25 0.00 -1235. 86 0. 00 MWD 8675. 00 41.44 312.28 5505.66 4466.56 -4221. 03 5975088. 43 514297. 72 2.26 -1237. 71 80. 10 MWD 8700. 00 41.55 313.12 5524.39 4477.80 -4233. 20 5975099. 63 514285. 52 2.26 -1239. 93 79. 51 MWD 8725. 00 41.66 313.95 5543.08 4489.23 -4245. 24 5975111. 03 514273. 46 2.26 -1242. 40 78. 88 MWD 8750. 00 41.78 314.78 5561.74 4500.86 -4257. 13 5975122. 64 514261. 54 2.26 -1245. 10 78. 26 MW D 8775. 00 41.90 315.61 5580.37 4512.70 -4268. 88 5975134. 44 514249. 76 2.26 -1248. 05 77. 64 MWD 8800. 00 42.03 316.43 5598.96 4524.73 -4280. 49 5975146. 44 514238 .12 2.26 -1251. 25 77. 02 MWD 8825. 00 42.17 317.25 5617.50 4536.95 -4291. 95 5975158. 64 514226 .63 2.26 -1254. 69 76. 41 MWD 8850. 00 42.31 318.06 5636.01 4549.37 -4303. 27 5975171. 03 514215 .28 2.26 -1258. 37 75. 80 MWD 8875. 00 42.46 318.87 5654.48 4561.99 -4314. 45 5975183. 61 514204 .08 2.26 -1262. 30 75. 20 MWD 8900. 00 42.61 319.68 5672.90 4574.80 -4325. 47 5975196. 39 514193 .02 2.26 -1266 .47 74. 60 MWD 8925. 00 42.77 320.48 5691.28 4587.80 -4336. 35 5975209. 37 514182 .11 2.26 -1270 .88 74. 01 MWD 8945. 00 44.46 319.60 5705.76 4598.37 -4345. 21 5975219. 92 514173 .23 9.00 -1274 .45 340. 00 MWD 8950. 00 46.35 318.66 5709.27 4601.06 -4347. 54 5975222. 60 514170 .89 40.00 -1275 .32 340. 00 MWD 8975. 00 55.86 314.67 5724.95 4615.16 -4360. 91 5975236. 67 514157 .49 40.00 -1279 .21 340. 66 MWD 9000 .00 65.47 311.51 5737.18 4630.01 -4376. 82 5975251. 48 514141 .54 40.00 -1282 .24 343. 17 MWD 9025 .00 75.14 308.79 5745.60 4645.15 -4394. 80 5975266. 57 514123 .53 40.00 -1284 .33 344. 73 MWD 9050 .00 84.84 306.32 5749.94 4660.14 -4414. 30 5975281. 50 514103 .99 40.00 -1285 .42 345. 65 MWD 9058 .14 88.00 305.53 5750.45 4664.90 -4420. 87 5975286. 25 514097 .41 40.00 -1285 .55 346. 08 MWD 9075 .00 88.01 298.78 5751.04 4673.86 -4435. 13 5975295. 18 514083 .13 40.00 -1284 .72 270. 00 MWD 9100 .00 88.08 288.78 5751.89 4683.93 -4457. 97 5975305. 19 514060 .27 40.00 -1279 .86 270. 24 MWD 9125 .00 88.21 278.77 5752.70 4689.87 -4482. 21 5975311. 07 514036 .02 40.00 -1270 .83 270. 58 MWD 9150 .00 88.40 268.77 5753.44 4691.51 -4507. 11 5975312. 65 514011 .12 40.00 -1257 .89 270. 90 MWD 9175 .00 88.63 258.77 5754.09 4688.80 -4531. 92 5975309. 88 513986 .31 40.00 -1241 .44 271. 20 MWD 9183 .14 88.71 255.52 5754.28 4686.99 -4539. 85 5975308. 05 513978 .39 40.00 -1235 .41 271. 46 MWD 9200 .00 88.72 253.49 5754.66 4682.49 -4556. 10 5975303. 51 513962 .16 12.00 -1222 .40 270. 00 MWD 9225 .00 88.72 250.49 5755.22 4674.76 -4579. 86 5975295. 72 513938 .41 12.00 -1202 .44 270. 05 MWD 9250 .00 88.73 247.49 5755.77 4665.80 -4603. 19 5975286. 71 513915 .11 12.00 -1181 .72 270. 11 MWD 9275 .00 88.74 244.49 5756.33 4655.64 -4626. 02 5975276. 48 513892 .30 12.00 -1160 .30 270. 18 MWD 9300 .00 88.75 241.49 5756.87 4644.29 -4648 .29 5975265. 08 513870 .07 12.00 -1138 .23 270. 25 MWD 9325 .00 88.77 238.49 5757.41 4631.79 -4669 .93 5975252. 53 513848 .46 12.00 -1115 .58 270. 31 MWD 9350 .00 88.79 235.49 5757.95 4618.17 -4690 .88 5975238. 86 513827 .54 12.00 -1092 .40 270. 38 MWD 9375 .00 88.82 232.49 5758.47 4603.48 -4711 .10 5975224. 12 513807 .36 12.00 -1068 .77 270. 44 MWD 9400 .00 88.84 229.49 5758.98 4587.74 -4730 .52 5975208. 34 513787 .99 12.00 -1044 .75 270. 50 MWD 9425 .00 88.88 226.49 5759.48 4571.02 -4749 .09 5975191 .57 513769 .46 12.00 -1020 .39 270 .56 MWD ~OriOCOPhllll s Alaska Inc P Baker Hughes INTEQ Planning Report -. BAKER uur_wEs ii. i+.Y Company: ConocoPlhillips Alaska Inc. Field: Kuparuk River Unit Site: Kuparuk 2X Pad V1'cll: 2X-19 We$path: Plan 6, 2X-19A Snrvcv - -- _ 14ill Incl Azim S S TVT) ft deg deg ft 9433.14 88.89 225.51 5759.63 9450.00 88.54 223.52 5760.01 9475.00 88.02 220.56 5760.76 9500.00 87.51 217.60 5761.74 9525.00 87.00 214.64 5762.94 9550.00 86.51 211.68 9575.00 86.02 208.71 9600.00 85.54 205.74 9625.00 85.08 202.77 9650.00 84.63 199.79 9675.00 84.19 196.81 9683.14 84.05 195.84 9700.00 85.07 194.08 9725.00 86.58 191.48 9750.00 88.10 188.89 9775.00 89.62 186.30 9783.14 90.12 185.46 9800.00 90.81 183.56 9825.00 91.83 180.74 9850.00 92.85 177.92 9875.00 93.86 175.09 9900.00 94.87 172.25 9903.14 94.99 171.90 9925.00 95.35 174.51 9950.00 95.75 177.49 9975.00 96.13 180.48 10000.00 96.50 183.48 10025.00 96.85 186.48 10050.00 97.18 189.48 10075.00 97.49 192.49 10083.14 97.58 193.47 10100.00 96.76 195.33 10125.00 95.52 198.08 10150.00 94.27 200.82 10175.00 93.00 203.55 10200.00 91.74 206.27 10225.00 90.47 208.99 10233.14 90.05 209.87 10250.00 89.72 211.87 10275.00 89.22 214.83 10300.00 88.73 217.79 10325.00 88.24 220.75 10350.00 87.76 223.71 10375.00 87.28 226.67 10400.00 86.81 229.64 10425.00 86.35 232.61 10450.00 85.89 235.58 10475.00 85.45 238.56 10500.00 85.02 241.54 10525.00 84.61 244.52 10550.00 84.21 247.51 10575.00 83.82 250.50 10583.14 83.70 251.47 5764.35 5765.98 5767.82 5769.87 5772.11 5774.54 5775.38 5776.98 5778.80 5779.96 5780.46 5780.48 5780.34 5779.76 5778.74 5777.28 5775.38 5775.11 5773.13 5770.72 5768.13 5765.38 5762.47 5759.42 5756.23 5755.16 5753.06 5750.38 5748.25 5746.67 5745.63 5745.15 5745.11 5745.15 5745.38 5745.83 5746.49 5747.36 5748.44 5749.73 5751.22 5752.92 5754.80 5756.88 5759.14 5761.58 5764.18 5765.07 Date: 6/17/2008 'l'ime: 16:12:45 Yage: 3 Co-ordinate~NE) Reference: W211: 2X-19, True North Vertical ITVD) Reference: 2X-19 118.0 Section (VS) Reference: Well (O.OON,O.OOE,215.OOAzi) Survey Calculation A~Iethod: Minimum Curvature Db: Sybase N/S ft E/W ft MapN ft 4565. 37 -4754 .94 5975185. 90 4553. 35 -4766 .76 5975173. 85 4534. 79 -4783 .49 5975155. 26 4515. 40 -4799 .24 5975135. 83 4495. 23 -4813 .96 5975115. 63 4474. 34 -4827 .61 5975094. 70 4452. 78 -4840 .15 5975073. 12 4430. 61 -4851 .56 5975050. 92 4407. 90 -4861 .79 5975028. 19 4384. 70 -4870 .83 5975004. 97 4361. 08 -4878 .64 5974981. 33 4353. 31 -4880 .91 5974973. 56 4337. 09 -4885 .25 5974957 .33 4312. 78 -4890 .76 5974933 .01 4288. 20 -4895 .17 5974908 .42 4263. 43 -4898 .48 5974883 .64 4255. 34 -4899 .31 5974875 .55 4238. 53 -4900 .64 5974858 .74 4213. 55 -4901 .58 5974833 .76 4188. 58 -4901 .28 5974808 .79 4163. 67 -4899 .76 5974783 .89 4138. 90 -4897 .01 5974759 .13 4135. 80 -4896 .58 5974756 .03 4114. 18 -4894 .00 5974734 .42 4089. 36 -4892 .27 5974709 .61 4064. 51 -4891 .83 5974684 .76 4039 .67 -4892 .69 5974659 .93 4014 .94 -4894 .84 5974635 .19 3990 .37 -4898 .29 5974610 .61 3966 .03 -4903 .01 5974586 .27 3958 .17 -4904 .83 5974578 .40 3941 .97 -4908 .99 5974562 .19 3918 .16 -4916 .14 5974538 .37 3894 .68 -4924 .43 5974514 .87 3871 .58 -4933 .85 5974491 .75 3848 .93 -4944 .37 5974469 .07 3826 .78 -4955 .96 5974446 .90 3819 .70 -4959 .96 5974439 .81 3805 .22 -4968 .61 5974425 .31 3784 .34 -4982 .35 5974404 .40 3764 .20 -4997 .15 5974384 .22 3744 .86 -5012 .96 5974364 .84 3726 .36 -5029 .75 5974346 .30 3708 .76 -5047 .47 5974328 .66 3692 .10 -5066 .07 5974311 .96 3676 .44 -5085 .49 5974296 .25 3661 .82 -5105 .69 5974281 .58 3648 .27 -5126 .61 5974267 .98 3635 .83 -5148 .20 5974255 .49 3624 .54 -5170 .39 5974244 .15 3614 .42 -5193 .12 5974233 .98 3605 .52 -5216 .33 5974225 .01 3602 .88 -5223 .97 5974222 .36 MapE DLS VS `PFO Tool ft deg/100ft ft deg 513763.62 12.00 -1012.41 270.62 MWD 513751.83 12.00 -995.78 260.00 MWD 513735.15 12.00 -970.98 260.04 MWD 513719.45 12.00 -946.07 260.13 MWD 513704.79 12.00 -921.11 260.25 MW D 513691.19 12.00 -896.16 260.39 MWD 513678.70 12.00 -871.31 260.56 MWD 513667.35 12.00 -846.60 260.75 MWD 513657.17 12.00 -822.13 260.97 MWD 513648.19 12.00 -797.94 261.21 MWD 513640.44 12.00 -774.11 261.48 MWD 513638.19 12.00 -766.45 261.77 MWD 513633.89 12.00 -750.68 300.00 MWD 513628.44 12.00 -727.60 300.17 MWD 513624.09 12.00 -704.93 300.36 MWD 513620.85 12.00 -682.75 300.48 MWD 513620.03 12.00 -675.64 300.53 MWD 513618.75 12.00 -661.11 290.00 MWD 513617.87 12.00 -640.11 289.98 MWD 513618.22 12.00 -619.82 289.92 MWD 513619.81 12.00 -600.29 289.80 MWD 513622.62 12.00 -581.58 289.64 MWD 513623.06 12.00 -579.29 289.42 MWD 513625.69 12.00 -563.06 82.00 MWD 513627.48 12.00 -543.72 82.24 MWD 513627.98 12.00 -523.61 82.52 MWD 513627.19 12.00 -502.78 82.83 MWD 513625.09 12.00 -481.28 83.16 MWD 513621.71 12.00 -459.18 83.51 MWD 513617.04 12.00 -436.53 83.88 MWD 513615.25 12.00 -429.05 84.26 MWD 513611.13 12.00 -413.39 114.00 MWD 513604.04 12.00 -389.79 114.23 MWD 513595.81 12.00 -365.80 114.53 MWD 513586.45 12.00 -341.47 114.76 MWD 513575.98 12.00 -316.88 114.93 MWD 513564.45 12.00 -292.10 115.05 MWD 513560.47 12.00 -284.00 115.10 MWD 513551.85 12.00 -267.18 99.50 MWD 513538.17 12.00 -242.20 99.50 MWD 513523.42 12.00 -217.21 99.47 MWD 513507.65 12.00 -192.29 99.42 MWD 513490.91 12.00 -167.51 99.34 MWD 513473.24 12.00 -142.93 99.23 MWD 513454.68 12.00 -118.62 99.11 MWD 513435.30 12.00 -94.65 98.95 MWD 513415.14 12.00 -71.08 98.78 MWD 513394.25 12.00 -47.98 98.57 MWD 513372.70 12.00 -25.41 98.35 MWD 513350.54 12.00 -3.44 98.10 MWD 513327.84 12.00 17.88 97.83 MWD 513304.66 12.00 38.49 97.54 MWD 513297.02 12.00 45.04 97.23 MWD ~OriOCOPhllll s Alaska Inc P Baker Hughes INTEQ Planning Report r~° BAKER HUGHES INTEQ Company: ConocoPhillips Alaska Inc. Field: Kuparuk River Unit Sitr. Kuparuk 2X Pad ~Vcll: 2X-19 Wcllpath: e.,,....,., Plan 6, 2X-19A Date: 6/17/2008 Time: 16:12:45 Page: 4 Co-ordinate(NEj Reference: Well: 2X-19, True North Vertical (TVllI Reference: 2X-19 118.0 Section (VS) Reference: Well (O.OON,O.OOE,215.OOAzi) Sun~ev Calculation Method: Minimum Curvature llb: Sybase MD Incl __ Azim SS 'f VD N/S - E/W MapN ft deg_ deg ft ft ft ft 10600 .00 83. 88 253. 50 5766. 89 3597. 84 -5239. 96 5974217. 28 10625 .00 84. 16 256. 50 5769. 50 3591. 40 -5263. 97 5974210. 78 10650 .00 84. 46 259. 50 5771. 98 3586. 23 -5288. 30 5974205. 56 10675 .00 84. 77 262. 50 5774. 33 3582. 34 -5312. 88 5974201. 60 10700 .00 85. 09 265. 50 5776. 54 3579. 74 -5337. 65 5974198. 94 10725 .00 85. 43 268. 49 5778. 60 3578. 43 -5362. 52 5974197. 57 10733 .14 85. 55 269. 46 5779. 24 3578. 29 -5370. 63 5974197. 41 10750 .00 85. 55 271 .49 5780. 55 3578. 43 -5387. 45 5974197. 50 10775 .00 85. 57 274 .50 5782. 49 3579. 73 -5412. 33 5974198. 74 10800 .00 85. 59 277 .51 5784. 41 3582. 33 -5437. 12 5974201. 29 10808 .14 85. 60 278 .49 5785. 04 3583. 46 -5445. 15 5974202. 40 10825 .00 85. 62 276 .46 5786. 33 3585. 65 -5461. 82 5974204. 54 10850 .00 85. 66 273 .45 5788. 23 3587. 80 -5486. 66 5974206. 63 10875 .00 85. 72 270 .44 5790. 11 3588. 65 -5511. 57 5974207. 41 10900 .00 85. 78 267 .43 5791. 96 3588. 18 -5536. 49 5974206. 89 10925 .00 85. 86 264 .43 5793. 78 3586. 41 -5561. 36 5974205. 06 10950 .00 85. 94 261 .42 5795. 57 3583. 34 -5586 .10 5974201. 93 10975 .00 86. 04 258 .41 5797. 32 3578. 97 -5610 .65 5974197. 50 11000 .00 86. 15 255 .41 5799 .02 3573. 33 -5634 .94 5974191. 79 11008 .14 86. 19 254 .43 5799 .57 3571. 21 -5642 .78 5974189. 66 11025 .00 86. 19 252 .40 5800 .69 3566. 41 -5658 .91 5974184. 82 11050 .00 86. 20 249 .40 5802 .35 3558. 25 -5682 .48 5974176. 60 11075 .00 86. 22 246 .39 5804 .00 3548. 86 -5705 .59 5974167. 16 11100 .00 86. 26 243 .38 5805 .64 3538. 28 -5728 .17 5974156. 52 11125 .00 86. 30 240 .38 5807 .26 3526. 52 -5750 .17 5974144. 71 11150 .00 86. 35 237 .37 5808 .86 3513. 62 -5771 .53 5974131. 76 11175 .00 86. 42 234 .37 5810 .44 3499. 63 -5792 .18 5974117 .71 11200 .00 86. 49 231 .36 5811 .99 3484. 56 -5812 .07 5974102 .60 11225 .00 86. 57 228 .36 5813 .50 3468. 48 -5831 .14 5974086 .47 • 11250 .00 86 .67 225 .35 5814 .97 , 3451. 42 -5849 .34 5974069 .37 MapE DLS VS TFO Too ft deg/100ft ft deg 513281.04 12.00 58.34 85.00 MWD 513257.05 12.00 77.38 84.78 MWD 513232.73 12.00 95.57 84.47 MWD 513208.16 12.00 112.86 84.17 MWD 513183.41 12.00 129.20 83.89 M W D 513158.54 12.00 144.54 83.62 MWD 513150.43 12.00 149.31 83.38 MWD 513133.62 12.00 158.84 90.00 MWD 513108.73 12.00 172.05 89.84 MWD 513083.94 12.00 184.13 89.61 MWD 513075.91 12.00 187.81 89.38 MWD 513059.23 12.00 195.58 270.50 MWD 513034.40 12.00 208.06 270.66 MWD 513009.48 12.00 221.66 270.88 MWD 512984.56 12.00 236.33 271.11 MWD 512959.70 12.00 252.05 271.33 MWD 512934.97 12.00 268.76 271.55 MWD 512910.43 12.00 286.41 271.77 MWD 512886.16 12.00 304.97 271.98 MWD 512878.33 12.00 311.20 272.18 MWD 512862.21 12.00 324.38 270.00 MWD 512838.67 12.00 344.59 270.13 MWD 512815.58 12.00 365.53 270.33 MWD 512793.03 12.00 387.16 270.53 MWD 512771.06 12.00 409.41 270.73 MW D 512749.74 12.00 432.22 270.93 MWD 512729.13 12.00 455.53 271.12 MWD 512709.28 12.00 479.28 271.31 MWD 512690.24 12.00 503.39 271.49 MWD 512672.08 12.00 527.81 271.67 2.375 LEGEND mxe~tt-rvNa,' -1wt BP Alaska -~'~ 2X-,9(4X-,9, q ~~ _ , Plan 6, 2X-19A BAKER ~a"'~ 9,~u.A.N oN.at.9 NUGHE N 9w~9N~°~~o Y1an a, 2%-19a Noael~ egam2aai c.,,avl Li.~... a.aa 9. X5;'.2 INTEQ ,, a...9a,Y'm 1199tt ~"s 9' ,,..99N 9 An a prU~E ~EI W FromMTVY REFERENCE INFORMATION u Co-oA'naie (iNfWE)) R k - W II C ire 2% 19 True NwIM1 VSed@ionl (VS) Rakren e. IM (0 WN OOE~eval MeasureE OepiM1 Refarenr~~. '%-19 i1B 00 ~~ CalalaGOn MHFW. M'n mum Curvature "' m __ _ 27(.79 2%-19 wcr»N ... va.a ~~.. .r ~. n~.. ww`i.a' a~wraae .~,Y ..o ~.w im.ae .! Entl o790 Da 100'DL \` 4 ia. a ~~. or •• mar swam i ~u _~ ao`~ Entl oT ` ~ Da 100' DLS • ma,i .. i wnu m a wM a~esali su"u~i iu~o ' ~/`U - KOP 9 mai N ~ 1i m a~wao n w1w» .aaa re f TIP ulwuu ti» m°i w"i ms an ~~ olarav was sr ~~ ~~ »iw°a06w.u wwalo me me.w wa.w a« ~ r T .,.., w„r ..,,,. 11~. 1` aalsmae war m.m nr.. •-r aaer.u ewsv. rim arow es~ar ~l S L~e e axao . axxoTanoxs nn~e ~~ ruw ~ L~g - rw ao aan.lwt.n Name rvo .Nis .E-w sna9a ~ se9i:ie e9wils:oo tTCOV Nape C ! ~- 70 s>on.r9 e9asm ur a s txyaw• ou srso.u 9ow.1a = sise% ew ii Eitl waa o.Ww~ws ( ~t sn9.9e 9wa.u T //f sreo.w seozii 9 13 ans.sl i9 ~ 19 sTUna looeala ',~ a,.~n1 ,o:..,. „ a $T'wra:::;o4Sb;: ;. is _?.L.~_..<' 12 1u.w nzao.oo ,o ~~ f I a'c 5 D a a M> Y 2 F ~uparuk Managed Pressure Drillin• BOP Configuration for 2" Coil Tubing Well 2X-19A Rig Floor I Lubricator ID = 6.375" with 6" Otis Unions 1 7 1/16" 5000 psi, RX-46 7 1/16" 5000 psi RX-46 Tree Size 3-1/8", 5M Kill Line t Combi 2 1/16" 5000 psi , RX-24 OT ombi ~T 7 1/16" 5000 psi (RX-46) or ~- 4 1/16" 5000 psi (RX-39) Swab Valve Flow Tee SSV Master Valve Base Flan e Page 1 TRANSMITTAL LETTER CHECKLIST WELL NAME /~/2(~ Z ~ -' ~ f I~ PTD# Z.O~j ,. / ~ / Developments Service Exploratory Stratigraphic Test Non,-/Conventional W~eII ~ FIELD: _K u/~ca~..~-c~ ~- ~C j yc-/ POOL: /~k 4't ~~ /Ci ~-~r C~ * / < ~ d c 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 AP1 number are permit No. ,API No. SO- - 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), al[ 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 contingept 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 throw h tar et canes. Non-Conventional please note the following special condition of this permit: Well production or production testing of coal bed me~liane is not allowed for (name of well) until after (Corananv Narae) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. _fCoraaanv Narae) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev; 1/11!2068 WEtL PERMIT CWECKLIS7 Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 49D10D WeN Name: KUPARUK RIV UNIT 2X-19A Program DEV Well bore sag ^ PTD#:2081910 Company CONOCOPHILLIPS ALASKA INC Initial ClasslType DEV! PEND GeoArea 890 Unit 11160 On10ff Shore ~ Annular Disposal ^ Administration 1 Permitfeeattached---- --------- -- - - --- - --- NA ---- -- - - ---- ---- ------ --- ---- - ---- 2 Lease number appropriate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - _ No_ _ _ _ _ .Corrected omission on 401:_ TD is_in ApL024644; portion of productive inverval lies_ _ _ - - _ _ . _ _ _ _ _ _ _ _ 3 Unigvewelinameandnurobet___________________________ ________- Yes.- -_._-inADl25642; topof_productiveintervali(esinADL25645,_____-___-___.-__.__-___________ 4 Well located in a.defined-pooi_ - - . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _KUPARUK RIVER,-KUPARUK RVOIL - 49010Q, governed by Conservation Order No. 4326.. _ _ _ _ _ _ _ _ _ _ 5 Weli located proper distancefrom drilling unit_baundary_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ Yes _ _ _ _ - - Gonservat(on Order No. 432E contains no spacing restrictions with respectto drilling unit boundaries. - _ _ _ _ _ 6 Well located proper distance from other wells_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ Conservation Order No. 432G has no interwell_spaeing-restrictions, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 7 Sufficientacreage available in drilling unit_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - _ _ _ _ Conservation Order No. 432Chas-na interwell_spacing.restrictions, Wellbor-e-will be_more than 400' from - - _ - - 8 If deviated, is wellbore plat_ineluded _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes - - _ _ - _ an external property line where ownership or iandownership_changes. _ _ _ _ _ _ _ _ - _ _ _ _ . _ _ _ _ _ _ _ _ _ 9 0-peratoron~Caff_ectedparlY--- - ---- -- --- - - - --- Yes- ----------------- --- -- - ------ - -- -- - -- -- -- ---- 10 Operator has_appropriatebond'tnfQrce- ------ - -- - - - ---- Yes- -- -- ----- - -- - ---- - ----- ------ - - ----- - ---- 19 Pem)itcanbeissuedwtthcutconservationorder__________________ _________ _Yes- -------------------------------------------------------- -- - -------- Appr Date 12 Pe[mitcanbeissU~wiihoutadmini&t[ative_approval-----.------- --------- -YeS- ------------------------------------------------------------ -- - - -- 13 CappermltbeaRRrovedbaforel;?-daY-wait-- -- -- -- - - - ------ Yes- -- -- -- - --- --- -------- - ------ -- ----- ----- -- - SFD 7H12008 14 Well located within areaandstrataauthorizedby_Injectionp[der~(puti0#jn_ comments)_(For -NA__ ____________________________________________________________________-_--- 15 All wells-with(n114-miteatea-ofreyiewidentified(Forservicewellenly)_____ _________ _ NA__ ______-_____--__--_____--____---__----_---_-..-_---------------------- 16 Pte-produced injector,dpra6onofprQproductionlessthan3months_(Forservicewel(only)_ __NA__ _----------------------------------------------------------------------- 17 NonCOnven.gasc9nformstoA831.05.030(41.A),(L2,A-D)---- -- ------ NA-- - --- -- --- - -------- - ----- - -- - -- ------ - Engineering 18 CoDdudo[Stting_provided----------------------------- ------_-- - NA-- ------Gonductorsetin2X-19(194-175).------------------.-------------------------- 19 Sudacecegingprotectsall_known-U$DWg____________________ __________ _NA-_ .--___Allaqu(fersexempted, 40CFR_14~.102{b)~3).__---__-_--_--___--_____--___.__.___-__ 20 CMTvoladequatetoc~reulateonconducto[$surf-csg_.--________ ___-____ _NA-_ _____Surfaceoasingsetin2X•t9.___._--_____________________________________----- 21 CMT-voladequateto tie-in_longstring to surf csg_._____-_______ __________ _ NA__ ____Productioncasingsetin2X-19.-______________--_______-______-____-_--__--__ 22 CMT-will coyer all know_n_productivehorizons__._-_____________ _________ _-tyo__ -____.Siottedliner completion planned,___________.___________--_------------_----- 23 Casing desgns adequate for G, T E &_ Permafrost_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ - - _ _ Qriginal wall met design specifications. _ NA for slotted linec_ - - . _ - - _ . - - _ _ - - _ _ . _ _ - - _ _ _ _ _ _ - _ _ 24 Adequate tankage_or reserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ Rig equipped with steel pits, No reserve pit planned._ All waste_to approved disposal well(s), _ _ _ _ _ _ _ _ _ _ 25 Ifare-d[ill,has_a10r403 for abandonmentheenapR~ved----------- ---------- -Yes. ------308-212------------------------------------------------------------- 26 Adequate welibore separationproposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ Proximity anaysis performed, Nearest segment is P&A pcdion- of 2X-19 and paths diverge._ - - _ _ - _ 27 if diverterrriquired,doesltrneetregelations-------------------- ---------- --NA-- ----_-BOPStaGk willalteadY-~igplace,---------,_-----------.------------------------ Appr Date 28 Dnliing fiuld_progr8m schematic_& equip listadequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Maximum expected formation pressure 9,QEMW._ Managed pressute_drilling will be employed using6.6 ppg fluid_ TEM 711!2008 29 BOPI=s,-do theytneetregulation _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ . _ _ - - end appliad pressure_plus frlcfion tc overbalance fo[mationpressure. - - _ . - . _ _ - _ _ _ - _ _ - _ _ _ _ _ _ _ _ - ~~ 30 ROPE-press rating appropriate; test to-(put prig in-cemments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ - - _ _ . MASK calculated at 2652psi, 3400_psi-BOP testplanned, - _ _ _ _ _ _ - - _ _ _ _ - - _ _ _ . _ _ _ _ _ ~I 31 Choke-manifold r~mplieswlAPl_RP-53 (May 84)-- -- -- -- ---- -Yes- -- --- - ------ -- -- --- - ----- - -- - - - --- - 32 Workwihoccurwithoutoperationshutdown--__-_____--_____ __________ _Yes- ------------------------------------------------------------- - ------ 33 Is presence of H2$ gas probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ H2S is reported_at D$ ZX._ Mud shopld preclude H2$ on rg, Rig. has sensors and alarms._ - _ _ - - _ _ _ _ _ 34 Mechanical condition ofwellgwithinAORyerd'red(Fotserviceweilcnly)--- --------- - NA-- -------------_---------------------------------------------------------- Geology X35 Permit can be (sued w!o hydrogen sulfide measures _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No- _ _ _ _ _ _ H2S is present on 2X-Pad. 2X,19 measured 95-ppm_H2S_in 2007._ Measures required, _ _ _ _ - _ _ _ _ _ . _ _ _ _ 36 Data_presented 4n potential oyetpressurezones _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - _ - _ _ _ Expected reservolrpressure is 9.0-ppg EMW; will be drilled vdth coiled tubing i3<Q:6-ppg mud _ - _ _ - _ _ _ Appr Date 37 Seismicanalysisofshallowgas_zones______________________ _--______ _tJA_ ______usingmanaged.pressurQdrilling techniques._______________._--__--__-__-._-___- SFD 71112008 38 Seatredconditionsurvetr_('rf_offshore)______________________ __________ _ NA__ ______--_ -- ------------------------------------------------------------- 39 Contactnamelphoneforweekly_progressrepcds(exploratoryonly)---__ ______--_- - NA__ ________________-__-------___------_______--------------------------- Geologic Commissioner: Engineering P te iss Date: Commissioner: Da Date n C~~ ~/U~ ~ ^~~ Q QU ~~