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203-003
5HJJ-DPHV% 2*& )URP :HOO,QWHJULW\6SHFLDOLVW&3) &3) Q#FRQRFRSKLOOLSVFRP! 6HQW :HGQHVGD\0D\ 30 7R 5HJJ-DPHV% 2*& :DOODFH&KULV' 2*& %URRNV3KRHEH/ 2*& '2$$2*&&3UXGKRH%D\ 6XEMHFW .58&3DGQRQZLWQHVVHG0,7,$V $WWDFKPHQWV 0,7.58&3$'6,7HVWV[OV[ ůů͕ ZĞĐĞŶƚŶŽŶǁŝƚŶĞƐƐĞĚD/d/ƐŽŶϭͲWĂĚ͘WůĞĂƐĞůĞƚŵĞŬŶŽǁŝĨLJŽƵŚĂǀĞĂŶLJƋƵĞƐƚŝŽŶƐ͘ ZĞŐĂƌĚƐ͕ -DQ%\UQH :HOO,QWHJULW\6SHFLDOLVW &RQRFR3KLOOLSV$ODVND,QF 2IILFHSKRQH &HOOSKRQH &$87,21 7KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH .58& 37' Submit to: OOPERATOR: FIELDD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2011280 Type Inj N Tubing 605 745 740 730 Type Test P Packer TVD 3644 BBL Pump 0.6 IA 215 1830 1765 1760 Interval 4 Test psi 1500 BBL Return 0.5 OA N/A N/A N/A N/A Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2010800 Type Inj N Tubing 340 430 415 405 Type Test P Packer TVD 3564 BBL Pump 0.5 IA 450 1830 1770 1760 Interval 4 Test psi 1500 BBL Return 0.4 OA N/A N/A N/A N/A Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2011140 Type Inj N Tubing 665 705 690 685 Type Test P Packer TVD 3669 BBL Pump 1.0 IA 60 1820 1795 1785 Interval 4 Test psi 1500 BBL Return 0.8 OA N/A N/A N/A N/A Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2030030 Type Inj NTubing50505050 Type TestP Packer TVD 3833 BBL Pump 1.1 IA 230 1810 1720 1715 Interval 4 Test psi 1500 BBL Return 0.8 OA N/A N/A N/A N/A Result P TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Kuparuk / KRU / 1C Pad N/A Miller 05/10/22 Notes: Notes: 1C-111 1C-121 1C-190 Notes: 1C-127 Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechan i call In t eg r i t yy Tes t jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)2022-0510_MIT_KRU_1C-pad_4wells $2*&&ZDLYHGZLWQHVVMEU 9 9 9 9 9 - 5HJJ 9 05/10/22 $2*&&ZDLYHGZLWQHVVMEU 1C-190 PTD X0030 Regg, James B (CED) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Thursday, May 27, 2021 4:30 PM 0 -rt To: Regg, James B (CED) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; Autry, Sydney; Changklungdee, Toon Subject: RE: Defeated LPP/SSV on CPAI Well 1C-190 (PTD 203-003) 5/26/21 Jim, 1C -190's LPP has been placed back into normal service. `-I Kelly From: NSK West Sak Prod Engr Sent: Wednesday, May 26, 20213:04 PM To: Jim Regg <jim.regg@alaska.gov> Cc: CPF1 DS Lead Techs <n1140@conocophillips.com>; CPF1 Ops Supv <n2067@conocophillips.com>; Autry, Sydney <Sydney.Autry@conocophillips.com>; Changklungdee, Toon <Toon.Changklungdee@conocophillips.com> Subject: Defeated LPP/SSV on CPAI Well 1C-190 (PTD 203-003) 5/26/21 Jim, The low pressure pilot (LPP) on well 1C-190 (PTD# 203-003) was defeated today, 5/26/2021, when brought online after an extended downtime. The well is currently injecting at 1190 BWPD with a wellhead pressure of 95 psi and declining. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative ✓ Approval No. CO 406B.001." Please let me know if you have any questions. Kelly Kelly Lyons / Toon Changklungdee CPF1 / WestSak Production Engineer Office: (907) 659-7234 K2t( iC-iqo Zu36 )030 Regg, James B (CED) From: NSK West Sak Prod Engr <n1638@conocophillips.com Sent: Tuesday, March 2, 2021 12:41 PM {��� 3�2'?ffZj To: Regg, James B (CED) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Operations Superintendent; Braun, Michael (Alaska); Thomson, Stephanie; NSK West Sak Prod Engr; Lyons, Kelly A Subject: LPP/SSV Returned to Service on CPAI Well 1C-190 on 2/17/2021 Jim, The low pressure pilot (LPP) on well 1C-190 (PTD# 203-003) was returned to service and removed from the "Facility Defeated Safety Device Log" on 2/17/2021, after the well was shut back in for reservoir pressure management. The LPP had been defeated on 2/15/2021 when the well was returned to injection ahead of diagnostic logging. This notification is in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. Thank you, Toon Toon Changklungdee WestSak Production Engineer Office: (907) 659-7234 Toon's Cell: (303) 564-7586 Pager: (907) 659-7000 pp 497 K k4 (c- w Regg, James B (CED) From: Autry, Sydney <Sydney.Autry@conocophillips.com> 1 \ey, l 211 j I2�ZI Sent: Monday, February 15, 2021 4:34 PM To: NSK West Sak Prod Engr; Regg, James B (CED) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Operations Superintendent; Braun, Michael (Alaska); Thomson, Stephanie Subject: Defeated LPP/SSV on CPAI Well 1C-190 on 2/15/2021 Jim, The low pressure pilot (LPP) on well 1C-190 (PTD# 203-003) was defeated today, 2/15/2021, when brought online ahead of diagnostic logging with a wellhead pressure below the LPP setpoint. The well is currently injecting at 980 BWPD with a wellhead pressure of 45 psi. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. Sydney Autry for: Stephanie Thomson / Toon Changklungdee West Sak Production Engineers �© 2,030030 Regg, James B (CED) From: NSK West Sak Prod Engr <n1638@conocophiIli ps.com> Sent: Friday, January 1, 2021 9:21 AM To: Regg, James B (CED) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Operations Superintendent; Autry, Sydney; Braun, Michael (Alaska); Mowrey, Andrew F Subject: LPP/SSV Returned to Service on CPAI Well 1C-190 on 1/1/2021 Jim, The low pressure pilot (LPP) on well 1C-190 (PTD# 203-003) was returned to service and removed from the "Facility Defeated Safety Device Log" today on 1/1/2021, after the well was shut in for -reservoir pressure management. The _PP had been defeated on 11/28/2020 when the well was returned to injection after an extended shut-in period. This notification is in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Thank you, Adam Becia on behalf of Stephanie Thomson / Toon Changklungdee West Salk Production Engineers Office: 907-659-7234 Cell. 832-414-2.377 1 1<21C tc- Icio Regg, James B (CED) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Saturday, November 28, 2020 5:51 AM To: Regg, James B (CED) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Operations Superintendent; Braun, Michael (Alaska); Autry, Sydney; Thomson, Stephanie Subject: Defeated LPP/SSV on CPAI Well 1C-190 on 11/28/2020 Jim, The low pressure pilot (LPP) on well 1C-190 (PTD# 203-003) was defeated today, 11/28/2020, as the wellhead pressure fell below the LPP setpoint while on injection. The well is currently inctTJei—`ng-at 454 BWPD with a wellhead pressure of 6 psi. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Marina Krysinski for: Stephanie Thomson / Toon Changklungdee West Salk Production Engineers Office: 907-659-7234 Cell: 832-414-2377 1 ! " # " $%&' ( ') * +,! - *( ./ !0 1"! ! 2/ ./ 34 354-0 4 6 . 0 " * ( ' ( % 7 . 899 0 : 7. *9 0 3 ;8 * , . 0 < ; 5" : ( * " ') * ( / * +" : $ "(/ ' ( $ $,!= > />$ *! !6 ') ! 8 ", ' ' !! "# $ $ !! "# $ $ ' ' % &' () '! *!+ #, 8 %'#* < -)& ) .#/ 0# "1 '! 2# / . 0 -.3% -,* * *: : 5 ( ! 3 ! ! ?" & " : ? .; 34 354-49354-9@3531<0 +)!4 $ #% = : ( * , A ( :9, $ '/B /B,/!($ !' 7,! %%,,! .52.20 3.61525. 42 ",!="$ " #& +)!4 = = " C .24-03+5#+?- 8! = & )44<+4 9B2254 #& 4#?4? <63434 " <4* By Samantha Carlisle at 8:52 am, Nov 24, 2020 John W Peirce Digitally signed by John W Peirce Date: 2020.11.24 07:53:47 -09'00' DSR-11/24/2020 RBDMS HEW 11/25/2020 VTL 02/18/2021 SFD 11/24/2020 ! "#!$#%# &' $(&%)# &%) *&#+ ' ,-. * /01 ', -.*234 "5$6)( %(%#!$#& %3 ) !&%)#!$#%#&' $( #!$#%#*7 ',-.$% 88 &' #9:.: ; *8 '#+5 # * < # < 3= !$#%# $!/ !$#& %' Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.062 Top (ftKB) 28.0 Set Depth (ftKB) 110.0 Set Depth (TVD) … 110.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 7 5/8 ID (in) 6.875 Top (ftKB) 28.0 Set Depth (ftKB) 5,449.0 Set Depth (TVD) … 3,834.4 Wt/Len (l… 29.70 Grade L-80 Top Thread BTC-MOD Casing Description LINER SLOTTED OD (in) 4 1/2 ID (in) 3.958 Top (ftKB) 5,287.5 Set Depth (ftKB) 10,466.0 Set Depth (TVD) … 3,758.6 Wt/Len (l… 12.60 Grade L-80 Top Thread NSCT Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 5,287.5 3,832.9 87.27 SLEEVE BAKER TIE BACK SLEEVE 5.500 5,298.6 3,833.4 87.79 PACKER ZXP LINER TOP PACKER 4.940 5,306.6 3,833.7 88.17 NIPPLE RS NIPPLE 4.000 5,309.4 3,833.8 88.30 HANGER FLEX LOCK II HYD HANGER 5.500 5,317.3 3,834.0 88.64 XO BUSHING XO BUSHING 4.500 10,431.3 3,759.3 91.29 BUSHING BAKER PACKOFF BUSHING 2.350 Tubing Strings Tubing Description TUBING String Ma… 4 1/2 ID (in) 3.958 Top (ftKB) 23.6 Set Depth (ft… 5,295.9 Set Depth (TVD) (… 3,833.3 Wt (lb/ft) 12.60 Grade L-80 Top Connection NSCT Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 23.6 23.6 0.00 HANGER VETCO GRAY HANGER 4.500 515.0 513.2 10.25 NIPPLE CAMCO DB NIPPLE w/ 3.875 NO GO PROFILE 3.875 4,470.3 3,612.8 62.45 NIPPLE CAMCO DB NIPPLE w/ 3.812 NO GO PROFILE 3.812 5,283.5 3,832.7 87.07 XO BUSHING BAKER XO BUSHING VAM 3.880 5,285.3 3,832.8 87.16 SEAL ASSY BAKER BULLET SEAL ASSEMBLY w/ VAM BOX UP 4.860 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) PATCH Surface casing patch from bottom of starter head. Installed 6' 12"x65 .500 carbon steel sleeve on surface casing. 4/21/2011 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Zone Date Shot Dens (shots/f t)Type Com 5,602.0 10,401.0 3,830.4 3,760.0 WS D, 1C-190 3/9/2003 99.0 SLOTS Alternating slotted/solid pipe. 3 BLANK JTS:1 SLOTTED JT 8,300.0 8,305.0 3,795.0 3,795.1 WS D, 1C-190 9/5/2015 6.0 IPERF 2in Powerflow HSD guns, 2006FP, 6SPF 8,500.0 8,505.0 3,794.0 3,794.0 WS D, 1C-190 11/2/2017 6.0 APERF 2.5" Powerflow, (E-FIRE HEAD 3" X 2') ( GUN 3" X 5') Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,006.5 2,709.3 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 4/13/2003 Notes: General & Safety End Date Annotation 9/21/2015 NOTE: NET PRESSURE INCREASE OF 1000 PSI. 9/21/2015 NOTE: MBE TREATMENT DOWN COIL TUBING PUMP 261 BBLS OF 2.5% KCL WITH 2709 # OF 4 MM CRYSTAL SEAL 4/27/2016 NOTE: MBE TREATMENT DOWN COIL TUBING WITH NOZZLE PARKED ABOVE SLOTTED LINER AT 5600'. 4/27/2016 NOTE: PUMP 310 BBLS OF SEA WATER WITH 3135 # OF 4 MM CRYSTAL SEAL. NET PRESSURE INCREASE OF 750 PSI Comment SSSV: NIPPLE1C-190, 11/3/2017 10:43:12 AM Vertical schematic (actual) LINER SLOTTED; 5,287.5- 10,466.0 APERF; 8,500.0-8,505.0 IPERF; 8,300.0-8,305.0 SLOTS; 5,602.0-10,401.0 SURFACE; 28.0-5,449.0 SEAL ASSY; 5,285.3 XO BUSHING; 5,283.5 NIPPLE; 4,470.3 GAS LIFT; 3,006.5 NIPPLE; 515.0 CONDUCTOR; 28.0-110.0 HANGER; 23.6 Annotation Last Tag: ELMD Depth (ftKB) 10,447.0 End Date 2/17/2004 Annotation Rev Reason: ADDED PERFS Last Mod By pproven End Date 11/3/2017 KUP INJ KB-Grd (ft) 34.01 Rig Release Date 3/11/2003 Annotation Last WO: End Date 1C-190 H2S (ppm) Date ... TD Act Btm (ftKB) 10,466.0 Well Attributes Wellbore API/UWI 500292313600 Field Name WEST SAK Wellbore Status INJ Max Angle & MD Incl (°) 94.98 MD (ftKB) 9,068.11 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: RPPG MBE Trtmnt 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6.API Number: 7.If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 10466 None Casing Collapse Structural Conductor Surface Production Liner (Slotted) Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13.W ell Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15.W ell Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng (907)265-6471 3759 1500 psi Authorized Name: John Peirce Authorized Title: Staff Wells Engineer John Peirce John.W.Peirce@conocophillips.com Perforation Depth TVD (ft):Tubing Size: 3759 COMMISSION USE ONLY Tubing Grade:Tubing MD (ft): 3830'-3760' TVD 3795'-3795' TVD 3794'-3794' TVD 5299' MD and 3833' TVD 515' MD and 513' TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 25649, ADL 25650 203-003 P.O. Box 100360, Anchorage, Alaska 99510 50-029-23136-00 ConocoPhillips Alaska, Inc. Length Size KRU 1C-190N/A Kuparuk River Field/ West Sak Oil Pool 10466 None PRESENT WELL CONDITION SUMMARY L-80 TVD Burst 5296' MD MD 110' 3834' 110' 5449' 16" 7-5/8" 82' 5421' Perforation Depth MD (ft): 5602'-10401' MD (Slotted pipe) 8300'-8305' MD 8500'-8505' MD 4-1/2" 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: 10/14/2020 10466'5179' 4-1/2" 3759' Packer: ZXP Liner Top Packer SSSV: Camco DB Nipple w/ NoGo Profile m n P s 66 t t c Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 1:06 pm, Sep 23, 2020 320-392 John W Peirce Digitally signed by John W Peirce Date: 2020.09.23 09:13:30 -08'00' -00 DSR-9/24/2020 SFD 9/23/2020 VTL 9/29/20 10-404 SFD 9/28/2020 X Comm 9/30/2020 dts 9/29/2020 JLC 9/29/2020 RBDMS HEW 10/29/2020 Proposed RPPG Retreatment of 1C-190 to 1C-184 D Sand MBE 1C-190 single 4.5”, L-80, single horizontal West Sak D sand injector supports offset 1C-184 and 1C-135 producers. An initial Matrix Bypass Event (MBE) occurred 1/16/15 from 1C-190 injector to 1C-184. Well work described below was performed in 1C-190 unless specified otherwise. On 4/27/15, IPROF found MBE at ~8300’ RKB. On 9/5/15, perfs were shot at 8300 - 8305’ RKB. On 9/21/15, CT pumped 2709 lbs Crystal Seal to D MBE, then 1C-190 was returned to PWI for ~5 months with the MBE sealed. On 1/13/16, CT FCO’d to 9375’ CTMD and WHIP fell from 1000 psi (220 BWPD) to 120 psi (600 BWPD) with 1C-184 WC% spiking to 90%, so 1C-190 was SI 2/6/16 due to a reopened D MBE. On 4/27/16, CT Crystal Seal retreatment pumped 3135 lbs Crystal Seal to MBE at ~8300’ RKB. This treatment lasted ~2 months before breaking down. On 9/21/16, an MBE retreatment pumped 30 bbls Equiseal Gel & 2200 lbs Crystal Seal, but the treatment failed, so 1C-184 & 1C-190 were SI until 1C-190 returned to injection Nov 2016 to support 1C-135 until a new MBE broke Feb 2017 from 1C-190 to 1C-135, then 1C-190 became SI. On 4/2/17, CT FCO’d gel, and a 4/3/17 IPROF found a new MBE at 8505’ in 1C-190. The MBE treated at 8300’ RKB did not appear open. On 11/2/17, large hole perfs were shot at 8500 - 8505’ RKB, and on 11/11/17 6776 lbs RPPG was pumped to the MBE at 8505’ RKB. On 2/22/19, an IPROF showed MBE at ~8500’ RKB still open to 1C-184, but MBE at ~8300’ RKB still appeared sealed. On 4/10/19, 6908 lbs of RPPG was pumped but the treatment failed to seal the MBE. A 1C-184 producer CarboFusion Treatment of 10/26/19 fullbore pumped 91.5K lbs of CarboFusion proppant behind pipe targeting D MBE to 1C-190. On 11/28/19, 1C-190 CT FCO’d liner to 10455’ CTMD. In 2020, pressure communication studies indicate that rapid communication still exists between 1C-190 and 1C-184 due to a ‘enhanced permeability’ feature that is apparently still present between the wells. CarboFusion placed in the D MBE from 1C-184 has several darcy permeability. We propose pumping another 1C-190 RPPG retreatment of the D MBE at 8505’ RKB to seal it off against CarboFusion proppant job that is believed to be partly filling the MBE from 1C-184. Procedure 1) Fullbore Pumping: 1 to 2 weeks before RPPG job, put 1C-184 on production to drawdown on 1C-190 via open MBE, then at 12 hrs before RPPG job, put 1C-190 on injection at ~1000 BPD to displace all gas head and Diesel FP from wellbore to MBE, to ensure MBE is open and well is liquid packed and free of hydrocarbons. Injection into 1C-190 during early 2020 could be seen averaging ~2000 BWPD at 0 - 50 psi WHIP. RU Mixing Van and pumping equipment at 1C-190. SI injection to 1C-190, then swap to fullbore pumping 1 wellbore volume (129 bbls to MBE) of 2% KCL Brine to 1C-190, followed SI 1C-184 and swap to RPPG slurry at steady 1.5 - 2.0 bpm by adding 1 - 4 mm mesh RPPG to ultraclean 2% KCL Brine to make slurry at steady 0.75 ppg (target) concentration. Continue pumping steady bpm and ppg until WHIP reaches ~800 psi, then swap from RPPG slurry to pumping 88 bbls 2% KCL Brine, followed by 41 bbls Diesel FP to 2500’ TVD, followed by Shutdown. Wait 2 days for RPPG particles to fully crosslink before returning 1C-190, 1C-184, or 1C-135 to service. Coil Tubing (if needed): 2) An RPPG Fluff & Stuff or FCO may be performed depending on the post-RPPG injection performance. MIRU CTU & RIH with jet nozzle to tag RPPG in 1C-190 and then jet down through RPPG with Diesel to deep as possible to uncover liner slots for injection. Take returns to tanks if returns can be achieved, else fluff & stuff through RPPG while injecting Diesel away to formation. POOH. RD CTU. Return 1C-190 to injection and 1C-184 to production to evaluate the treatment results. Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.062 Top (ftKB) 28.0 Set Depth (ftKB) 110.0 Set Depth (TVD) … 110.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 7 5/8 ID (in) 6.875 Top (ftKB) 28.0 Set Depth (ftKB) 5,449.0 Set Depth (TVD) … 3,834.4 Wt/Len (l… 29.70 Grade L-80 Top Thread BTC-MOD Casing Description LINER SLOTTED OD (in) 4 1/2 ID (in) 3.958 Top (ftKB) 5,287.5 Set Depth (ftKB) 10,466.0 Set Depth (TVD) … 3,758.6 Wt/Len (l… 12.60 Grade L-80 Top Thread NSCT Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 5,287.5 3,832.9 87.27 SLEEVE BAKER TIE BACK SLEEVE 5.500 5,298.6 3,833.4 87.79 PACKER ZXP LINER TOP PACKER 4.940 5,306.6 3,833.7 88.17 NIPPLE RS NIPPLE 4.000 5,309.4 3,833.8 88.30 HANGER FLEX LOCK II HYD HANGER 5.500 5,317.3 3,834.0 88.64 XO BUSHING XO BUSHING 4.500 10,431.3 3,759.3 91.29 BUSHING BAKER PACKOFF BUSHING 2.350 Tubing Strings Tubing Description TUBING String Ma… 4 1/2 ID (in) 3.958 Top (ftKB) 23.6 Set Depth (ft… 5,295.9 Set Depth (TVD) (… 3,833.3 Wt (lb/ft) 12.60 Grade L-80 Top Connection NSCT Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 23.6 23.6 0.00 HANGER VETCO GRAY HANGER 4.500 515.0 513.2 10.25 NIPPLE CAMCO DB NIPPLE w/ 3.875 NO GO PROFILE 3.875 4,470.3 3,612.8 62.45 NIPPLE CAMCO DB NIPPLE w/ 3.812 NO GO PROFILE 3.812 5,283.5 3,832.7 87.07 XO BUSHING BAKER XO BUSHING VAM 3.880 5,285.3 3,832.8 87.16 SEAL ASSY BAKER BULLET SEAL ASSEMBLY w/ VAM BOX UP 4.860 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) PATCH Surface casing patch from bottom of starter head. Installed 6' 12"x65 .500 carbon steel sleeve on surface casing. 4/21/2011 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Zone Date Shot Dens (shots/f t)Type Com 5,602.0 10,401.0 3,830.4 3,760.0 WS D, 1C-190 3/9/2003 99.0 SLOTS Alternating slotted/solid pipe. 3 BLANK JTS:1 SLOTTED JT 8,300.0 8,305.0 3,795.0 3,795.1 WS D, 1C-190 9/5/2015 6.0 IPERF 2in Powerflow HSD guns, 2006FP, 6SPF 8,500.0 8,505.0 3,794.0 3,794.0 WS D, 1C-190 11/2/2017 6.0 APERF 2.5" Powerflow, (E-FIRE HEAD 3" X 2') ( GUN 3" X 5') Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,006.5 2,709.3 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 4/13/2003 Notes: General & Safety End Date Annotation 9/21/2015 NOTE: NET PRESSURE INCREASE OF 1000 PSI. 9/21/2015 NOTE: MBE TREATMENT DOWN COIL TUBING PUMP 261 BBLS OF 2.5% KCL WITH 2709 # OF 4 MM CRYSTAL SEAL 4/27/2016 NOTE: MBE TREATMENT DOWN COIL TUBING WITH NOZZLE PARKED ABOVE SLOTTED LINER AT 5600'. 4/27/2016 NOTE: PUMP 310 BBLS OF SEA WATER WITH 3135 # OF 4 MM CRYSTAL SEAL. NET PRESSURE INCREASE OF 750 PSI Comment SSSV: NIPPLE1C-190, 11/3/2017 10:43:12 AM Vertical schematic (actual) LINER SLOTTED; 5,287.5- 10,466.0 APERF; 8,500.0-8,505.0 IPERF; 8,300.0-8,305.0 SLOTS; 5,602.0-10,401.0 SURFACE; 28.0-5,449.0 SEAL ASSY; 5,285.3 XO BUSHING; 5,283.5 NIPPLE; 4,470.3 GAS LIFT; 3,006.5 NIPPLE; 515.0 CONDUCTOR; 28.0-110.0 HANGER; 23.6 Annotation Last Tag: ELMD Depth (ftKB) 10,447.0 End Date 2/17/2004 Annotation Rev Reason: ADDED PERFS Last Mod By pproven End Date 11/3/2017 KUP INJ KB-Grd (ft) 34.01 Rig Release Date 3/11/2003 Annotation Last WO: End Date 1C-190 H2S (ppm) Date ... TD Act Btm (ftKB) 10,466.0 Well Attributes Wellbore API/UWI 500292313600 Field Name WEST SAK Wellbore Status INJ Max Angle & MD Incl (°) 94.98 MD (ftKB) 9,068.11 K4U la -110 P-rL -,70WOo O Regg James B (CED) From: NSK West Salk Prod Engr <n1638@conocophillips.com> Sent: Thursday, February 13, 2020 12:57 PM To: Regg, James B (CED) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1&2 Ops Supt; Thomson, Stephanie; Mowrey, Andrew F; Braun, Michael (Alaska); NSK West Sak Prod Engr Subject: LPP/SSV Returned to Service on CPAI Well 1C-190 on 2/12/2020 Jim, The low pressure pilot (LPP) on well 1C-190 (PTDJ# 203-003) was returned to service and removed from the "Facility Defeated Safety Device Log" yesterday 2/12/2020, as the injection pressure increased above the LPP setpoint after a sustained injection period. The well is currently injecting 2040 BWPD at 625 psi wellhead pressure. The LPP had been defeated on 11/28/2019 when the well was returned for wellwork on an offset producer. This notification is in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Thank you, Toon Changklungdee / Marina Krysinski WestSak Production Engineer office: (907) 659-7234 Pager: (907) 659-7000 pp 497 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECOvEn DEC 3 ` 2019 1. Operations Abandon ❑ Plug Perforations L] Fracture Stimulate ❑ Pull Tubing ❑ Operations u wn E]Performed: Suspend EJ E] Other Stimulate E] Alter Casing L] Cl A m ❑ Plug for Retlrill ❑ erforate New Pool ❑Repair Well ❑ Re-enter Susp Well ❑ Other: Fusion Proppant Trtmt D 2. Operator Name: ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Development ❑ Exploratory ❑ Stratigraphic❑ Service I] 203-003 3. Address: P. 0. Box 100360, Anchorage, Alaska 6. API Number: 99510 50-029-23136-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25649, ADL 25650 KRU 1C-190 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 10,466 feet Plugs measured None feet true vertical 3,759 feet Junk measured None feet Effective Depth measured 10,466 feet Packer measured 5,299 feet true vertical 3,787 feet true vertical 3,833 feet Casing Length Size MD ND Burst Collapse CONDUCTOR 82 feet 16 110' MD 110' TVD SURFACE 5,421 feet 75/8" 5,449' MD 3834' TVD INER SLOTTED 5,179 feet 4 1/2 " 10,466' MD 3759' TVD Perforation depth: Measured depth: 5602-10401, 8300-8305, 8500-8505 feet True Vertical depth: 3830-3760, 3795-3795, 3794-3794 feet Tubing (size, grade, measured and true vertical depth) 4.511 L-80 5,296' MD 3,833' TVD Packers and SSSV (type, measured and true vertical depth) PACKER= ZXP LINER TOP PKR 5,299' MD 3,833' TVD SSSV = NONE 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: - - SHUT-IN Subsequent to operation: - _ 1007 - 43 14. Attachments (required per 20 MC 25070, 25.071, 625.283) 15. Well Class after work: Daily Report of Well Operations El Exploratory ❑ Development ❑ Service p Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ EI WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-416 contact Name: John Peirce Authorized Name: John Peirce Contact Email: JOhn.W.Peirce@cop.com Authorized Title: Sr. Wells Engineer _ Contact Phone: (907) 265-6471 Authorized Signature: �-' '� Date: Form 10-404 Revised 4/2017 VT2� 1Z11i /✓ Submit Original Only //r2//RBDMSh�IJDEC 052019 ConocoPhillips Alaska, Ii. KUP INJ WELLNAME 1CA90 WELLBORE 1C-190 tolo,tzarmla.aaas PM Last Tag whom e¢nzmaa I-) AnnotationOeptli(IMB) End Dab Wellbore last MW By [Battling ELMD 10,44].0 I&I]/2004 1C-190 ..boll ............................................................................................ Last Rev Reason Annahacn Entl Di Welllgr¢ Lzat Motl By MNGER; Yah Rev Reason: ADDED PERFS 111920 17 1C-190 pprove. Casing Strings C-ing Dezcrip0on 00(m) mpn) Top(nKe) set ad",XRS) set Depth (,a)... Mon11 Gmtl¢ T¢p TI In CONDUCTOR 16 1506 28.0 110.0 1MID 62.50 H40 WELDED Wzinp.. up... 0U(in) I.(in) lot --1 Sen U.P.a KB) SH Units I' out WDLen(I... o. Top ThIld SURFACE ]5B 6.87 28.0 5,449.0 3,834.4 29.70 No. BTC MOD Casing Descripllon 00(in) 110 [in? Top (XKD) $M Depin (XKa) SM .epIM1(ND)... WIILen (I... GreOe Top TM1 reatl LINER SLOTTED 4112 3.96 528]5 tO4fifl0 3,]58.6 12.60 L-80 NSCT Liner Details GONOUCT.R; 30.Ufla0 Nomine 1. Tap (XKR) Top (NO)(XKB) Top del (°) Xem Des Co. (in) 5,287.5 3,832.9 87.27 SLEEVE BAKER TIEBACK SLEEVE 5.500 5,298.8 3,8334 67.79 PACKER ZXP LINER TOP PACKER 4.940 wplinpaleo 5,306.6 3,833.] 88.17 NIPPLE RS NIPPLE 4.000 5,309.4 3,8338 8830 HANGER FLEX LOCK II HYD HANGER 5.500 5,317.3 3,834.0 88.64 XO BUSHING XO BUSHING 4.500 10,431.3 3]59.3 9129 BUSHING BAKER PACKOFF BUSHING 2.350 Tubing Strings Tubing Description lathing Ma 110(h) Top(XKB) set Degn (X.. Sat D¢pin (rvD1 (... Ad (611,10 G,atle Top Gonn¢clion TUBING 4112 3.96 23.fi 5,295.9 3.8333 12.fi0 L-80 NSCT Completion Details Top "at I Topmol xommal Top able) agent (°) KIM Des Corn To (in) GAS LIT S,.or.s 23.6 23.6 0.00 HANGER VETCOGRAYHANGER 4.500 5150 513.2 10.25 NIPPLE CAMEO DB NIPPLE w13875 NO GO PROFILE 3.875 4,470.3 31612.8 52.45 NIPPLE CAMCO DB NIPPLE as 3.812 NO GO PROFILE 3812 5,283.5 3,832.] 87071XO BUSHING BAKER XO BUSHING VAM 3,880 -A 5,2853 3,832.8 87.16 =L BAKER BULLET SEAL ASSEMBLY wI VAN BOXUP 4.860 Other In Hole (Wireline retrievable,plegs, valves, pumps, fish, etc.).. mpplE: a.ma3 Top(XKR) Top(ND) VIKe) Tap mol (°) Ou Com RUn Da@ ID(in) PATH Solace casing patcXfrom botlomostaTanheed. 4212011 0000 Installed 61745.500 carbon steel sleeve on surface ad,hu' Perforations S Slots Snot Toialle) Shan B) Top For) WB) 8-01/0 afti Unlwd one Di .en (anobm ) Type Co. XO BUSHING; Sand 5 5,602.0 10401.0 3,83D.4 3,]fi0.0 WB D, IC -190 3/92003 990 SLOTS Ali¢mating sl.netl/soli pipe.3 BLANK JTS:1 SLOTTED JT 8,300.0 8,306.0 3,795.0 3,795.1 WSD,1C-190 9152015 6.0 IPERF in Podimow HSDguns, SGA-ASSY.adG3 2006FP, 6SPF 8,500.0 8,505.0 3,7940 3794.0 WSTOC 0 11/21201] 6.0 APERF T5 Peft. ETITRE HEAD 3-X 2')(GUN 3"X 5') Mandrel Inserts at ag H Top (M(B) Top(NO) (ttKB) MCFe Matl¢I o0 (in) Sery Ce Type Latch Type PoRSIie (in) TRO flan (psi) Run Doh a.. 3,0065 2)09.3 CAMCO KBG-2 I DMY BK 0.000 00 41132003 Notes: General & Safety End dote I Ann adi n 9121/2015 NOTE: NET PRESSURE INCREASE OF 1000 PSI. 9212015 NOTE: MBE TREATMENT DOWN COIL TUBING PUMP 261 BIBLE OF 2.%KCL WITH 2709 Y OF 4 MM CRYSTALSEAL 4127/2016 NOTE: MTREATMENT DOWN COIL TUBING WITH NZZLE PARKED AVE SLOTTED LINER AT 5 421 NOTE, PUMP 310 BBLS OF SEA WATER AT I H 313l,k OP4 MM CRY ALEAL. NETPR S URE INCREASE OF 750 PSI sURFACE; 2B0.s,M90� SLOT.; 5,S'e,0.10.4010� IPERF;9,3cc ounsW.0i Irl MERF; 9.5.T.Oa,YJs.O �� IINERSLOTIE0;5,]6]1 10A9o0 1 C-184 Fusion Proppant Treatment DTTM JOBTYP START 10/26/19 MISC. CAPACITY SUSTAINMENT 10/26/19 MISC. CAPACITY SUSTAINMENT 11/2/19 MISC. CAPACITY SUSTAINMENT 11/21/19 MISC. CAPACITY SUSTAINMENT OF MBE TO 1C-190 SUMMARYOPS Performed duplicate freshwater SRIT from yesterday for additional pressure analysis; 4 -bpm @ 1500 -psi through 10 -bpm @ 2150 -psi. Modified treatment design and mixed 560 -bbl 80# HEC. Pumped Carbo Fusion Activated Proppant 6 - bpm in 4-10 PPA stages. Observed treating pressures 800- to 2020 -psi, with corresponding BHP 1650- to 2780 -psi. Pumped 100,000# Carbo Fusion Proppant, placing estimated 91,500# behind pipe. Opened support injector 1C-190 to tanks during treatment, initially observing minimal flow and accumulating 23 -bbl, until observing well going into a vac with 33k# sand away, 10k# into MBE. DHD obtained final fluid level in 1 C-190 at 450'. Freeze protected 1 C-184 with 16 -bbl diesel and 1 C-190 with 20 -bbl diesel. Ready for CT FCO to heal depth in well. FREEZE PROTECT PUMP 16 BBLS DIESEL DOWN TBG JOB COMPLETE PERFORMED FILL CLEANOUT/TUBING WASH FROM SURFACE TO 5500' CTMD PUMPING SLICK DIESEL AND DIESEL GEL SWEEPS AT 1.9 BPM, MAINTAINED 1:1 RETURNS THROUGHOUT CLEANOUT. LIGHT SAND CONCENTRATIONS OBSERVED THE LAST RETURNS SAMPLE WAS CLEAN DIESEL RIH WITH PDC BIT RECOMMENDED FROM CARBO, TAG SAND AT 5569' CTMD, COME ONLINE WITH N2 AT 400 SCFM AND 1 BPM SLICK SEAWATER DOWN COIL. TAKE 50' BITES MAKING WIPER TRIPS UP TO 5500' EACH TIME. CLEAN DOWN TO 7439' CTMD. GOT TEMPORARILY DETAINED FROM 7400-5650', JOB IN PROGRESS. 11/22/19 MISC. RIH WITH PDC BIT, TAG AT 7368' CTMD, COME ONLINE WITH N2 450 SCFM CAPACITY AND FLUID @1BPM, START CLEANING OUT. TOOK FIRST 25' BITE PU AND SUSTAINMENT PULLED HEAVY, TOOK 4 MORE BITES ALL WHILE CHASING UP TO 5500'. CLEANED DOWN TO 7518' CHASE BITE UP, GOT HUNG UP AT 7242' FOR 6 HRS. PRESSURE REGULATOR FOR REEL WENT OUT, LOST ALL REEL PRESSURE. CALLED MECHANICS TO FIX PROBLEM. GOT REEL FIXED AND STARTED TRYING TO MOVE PIPE AGAIN, SURGED PUMP DOWN COIL AND MANIPULATED COIL WT'S. FINALLY GOT PIPE MOVING. JOB IN PROGRESS. 11/23/19 MISC. SWAP OUT BOP'S, PERFORM BOP TEST, TRIM 50' COIL. RIH WITH 2" DJN, CAPACITY START N2 @ 700 SCFM AND FLUID AT 1 BPM FROM 2500', START CLEAN SUSTAINMENT OUT FROM 7,000', COULD NOT MAKE ANY HOLE PAST 7524' CTMD, PERFORM INJECTION TEST FROM 5,000'@ 2BPM WHP 30, IA 1376, OA 5 5 MIN WHP 286, IA 1377, OA 5 10 MIN WHP 304, IA 1379, OA 5 15 MIN WHP 331, IA 1380, OA 5 20 MIN WHP 343, IA 1380, OA 5 11/24/19 MISC. RIH WITH MOTOR GAS SEPARATOR AND PDC BIT, COME ONLINE WITH N2 CAPACITY 800 SCFM AND FLUID AT 1.5 BPM @ 2500', START CLEANING OUT FROM SUSTAINMENT 7000' TAKING 50' BITES, CHASING UP TO 5500' EVERY 150'. CLEANED OUT TO 8500'. JOB IN PROGRESS. 11/25/19 MISC. CLEANOUT WITH MOTOR AND MILL FROM 8,000' TO HARD TAG AT 9741' CAPACITY RKB, TAKING 50' BITES AND CHASING UP TO 5500', WELL FREEZE SUSTAINMENT PROTECTED, READY FOR SLICKLINE. 11/26/19 MISC. BRUSH & FLUSHED THRU CMU @ 5016' RKB. OPENED CMU @ 5016' RKB. CAPACITY SET 2.81" POGLM (ON CS LOCK IN CMU @ 5016' RKB (5/16" OV, OV IS NOT SUSTAINMENT RETRIEVABLE). SET SLIP STOP ON TOP OF POGLM @ 5016' RKB. PERFORMED GOOD DDT ON IA. READY FOR FLOWBACK. ,P't� 2c�3f?d3� Regg, James B (CED) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Friday, November 29, 2019 6:20 AM I J/Z To: Regg, James B (CED) Cc: CPF1 Ops Supv, CPF1 DS Lead Techs; CPF1 &2 Ops Supt; Braun, Michael (Alaska); Fox, Pete B; Mowrey, Andrew F Subject: Defeated LPP/SSV on CPAI Well 1C-190 on 11/28/2019 Jim, The low pressure pilot (LPP) on well 1C-190 (PTD# 203-003) was defeated last night, 11/28/2019, after the well was brought online for upcoming wellwork on an offset producer and the wellhead pressure could not be established above the LPP setpoint. The well is currently injecting at 950 barrels of produced water per day with a wellhead pressure of 24 prig. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative ✓ Approval No. CO 4068.001." Please let me know if you have any questions. Evan Reilly for Marina Krysinski / Toon Changklungdee West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY John Peirce Sr. Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1C-190 Permit to Drill Number: 203-003 Sundry Number: 319-416 Dear Mr. Peirce: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 �.aogcc.alaska.gov Enclosed is the approved application for the 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, (f� �L. Chmielowski Commissioner DATED this IS day of September, 2019. ABDMS-Z"�SEP 16 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 SEP 10 ^O;S G(2,C 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: Fusion Proppant 7rtmtE) 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhilli s Alaska Inc. Exploratory ❑ Development ❑ Stratigraphic ❑ Service Ei • 203-003 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23136-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1C-190 Will planned perforations require a spacing exception? Yes ❑ No El 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25649, ADL 25650 1 Kuparuk River Field / West Sak 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): 10,466' 3,759' • 10466 3759 1500psi NONE NONE Casing Length Size MD TVD Buret Collapse Conductor 82' 16" 110' 110' Surface 5,421' 75/8 5,449' 3,834' Slotted Liner 5,179' 41/2 10,466' 3,787' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5602-10401, 8300-8305, 8500- 3830-3760, 3795-3795, 3794- 4.500" L-80 5,296' 8505 3794 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER = ZXP Liner Top Packer MD = 5299 and TVD = 3833 SSSV = NONE N/A 12. Attachments: Proposal Summary 0 Wellbore schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development❑ Service p 14. Estimated Date for 9125/2019 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ O WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: John Peirce Contact Name: John Peirce Authorized Tide: Sr. Wells Engineer Contact Email: John.W.Peirce@cop.com Contact Phone: (907) 265-6471 � Authorized Signature: �� � .f � Date: O 1 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: :jBDMS L' SEP 16 2019 Post Initial Injection MIT Req'd? Yes ❑ No (� - Spacing Exception Required? Yes ❑ No Subsequent Form Required: d 4 G APPROVED BY Approved by: A, COMMISSIONER THE COMMISSION Date: VTL q//z//%ORIGINAL'S a� Form 10403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. qn 7i� � plli-,y Submit Form and Attachments in Duplicate KUP INJ WELLNAME 1C-190 WELLBORE 1C_190 �OPh'"'ps Well Attribute. Max Angle & MD TD IF Ed Noma WNIM,e APVIIWI 'A.IWre Salus ncl(D MD (RKID Ac[R[m^XKR .vask2, Inc. WE"BAK 41029J313fi00 IN.I d9R clan" in dFa +olpD.a+Ivm+e+rdwPM Last Tag Va,as alacli.mah1az01ep AnnodXm OepNRIKS) 1 a Data wellWreWIMM By Last Tag: EI -MD 10.44,0 271]2004 1C-190 Intborl _.._......._ __. ............ Last Rev Reason Annulalin Ena DWe wenlwre Lail Moa ey Rev Reason ADDED PERES 1113/201] 16190 pproven XANGER, as Casing Strings Cazinp Dezc,ipxon OO lin) ID(m) Top -8) Sit Depth (ARE) SM Depth Didg.wuLen ll..G,aae Top TM1,W CONDUCTOR 16 15.06 28.0 1a0.0 110.0 6250 H-00 WELDED Casing Cascrlptlpn OD(in) IDlln) Top idea, eel Depth DIA., .10epen nw)... WtlLm g... Grade Top TD_ SURFACE 7518 687 280 5,449.0 3,8344 29)0 L81 BTC -MOD Cming Deaerlptl0n0D lin) ID On) ToplRRa) .Drell da,SM DepO ITet,... WXm 11...... Top TRrcaa LINER SLOTTED 4112 3.96 5.2875 10.466.0 3,758.6 1260 L-80 NSCT Liner Details [axoueioR: id,anao Ne'�^'Im Top XKR) Top UNDXKe) Top Incl(•) Ittm Dee Com H 5,287.5 3,832.9 87,27 1 SLEEVE BAKER TIE BACK SLEEVE 5.500 5,298. 3,833.4 8].]9 PACKER ZXP LINER TOP PACKER 4.940 NIDILe. ssD 5.3066 3.8337 88.1] NIPPLE RS NIPPLE 4.000 53094 3,8338 88.30 HANGER FLEX LOCK HHYD HANGER 55(0 5,317.3 3,834.0 BB fi4 XO BUSHING XO BUSHING 500 10,431.3 3,759.3 91.29 BUSHING BAKER RACKOFF BUSHING 2.350 Tubing Strings Tubing Description $hi ng Ma... ID(In) Tap lflRO) eat [apN lX. SeI DepIR IND)l... Wl phot Correcton Into IT., TUBING d 12 3.96 23 fi 5,295.9 3.833.3 12.60 L-80 NSCT Completion Details Top III Topmcl Nominal TOp(XKBI IXKB) r) Nm Das Crim Duet I des LlFTsovel 23.6 2361 0.00 1 HANGER TVITTUTUIIAYHANGER 4500 5150 513.2 10.25 NIPPLE CAMCO DB NIPPLE .13.875 NO GO PROFILE 3.875 4,470.3 3.6128 62.45 NIPPLE CAMCO D8 NIPPLE./ 3.812 NO GO PROFILE 3.812 5.2835 3.8327 1 8,07 XO BUSHING BAKER XO BUSHING VAM 3.880 11 5285.3 3,832.8 61 In ISEALL AS5Y BAKER BULLET SEAL ASSEMBLY wI VAM BOX DP 4.660 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) NIPPLE', a,a>aa Top 1 Top(ND) Topmcl 0-31 (') Dm CBm Rm Dale ID Im) PATCFr Soace wain, pi om bomm g Stoner need. 4121/2011 0 000 Installed 6' 12"s65 .500 Carbon steel sleeve on surto,. Casing Perforations & Slots .he, Dm Top ni EM(ND) lzoci Tap MKB) BM Min (RKB) dont LInWa ZonO DMe 1 Type Co. XOBUeHING. Nouns 5,602.0 15.4717 3,8384 3,]60.0 WE D, 1C-190 3192003 990 SLOTS Allernagng SloneNsolid age. 3 BLANK JTS.1 SLOTTED JT 8,300.0 5. 3,7950 3.795.1 WS D, 1C-190 SI 15 60 (PERF 2in Powe owH Dguns, CEALAeer. seers 200BFP,6SPF 8,500.0 5. 3,]940 3,71M0 WS D, 1C-190 11122ow 6.0 APERF .5"Powe ow, IRE HEAD 3' X 2) (GUN 3"X _ 5') Mandrel Inserts s< m N T...) TopnVO) IRKS) Make Mosel Dead) Sera V, TKe Le4R Typ Pw1¢W III TRO Run to Run pah Cwn 3,006.5 2,7093 CAMCO KBG-2 1 GAS LIfT DMY BK 0.000 00 4I13I2003 Notes: General & Safety End Dale AnnWetinn 9/2112015 NOTE: NET PRESSURE INCREASE OF 1000 PSI. 912112015 NOTE'. MBE TREATMENT DWN COIL TUBING PUMP 261 BBLS OF 25o KCL WITH 27N6 OF4 MM CRYSTAL SEAL 42712016 NOTE MBE TREATMENT DOWN COLL TUBING WITH NOZZLE PARKED ABOVE SLOTTED LINER AT 5600 4/272016 NUT U L EA WATER WITH 3135# OF 4 MM CRYSTAL R URE INCREASE OF 750 PSI 811RFACE; iS.O5,Mg0� SLOTS, EapoiDw+a- IPERF;eAb.g-esD60 APERF.6.5110.0,850i LINER SLOTTED. NanS +p.asso Proposed 1C-184 to 1C-190 Fusion Proppant Treatment of D Sand MBE 1C-190 West Sak D Sd injector is a single horizontal monobore that supports 1C-184 producer. A Matrix Bypass Event occurred 1/16/15 from 1C-190 injector to 1C-184. A 4/27/15 1C-190 IPROF found the MBE at 8300' RKB, and on 9/21/15 CT pumped 2709 lbs of Crystal Seal into 1C-190 to seal the MBE. 1C-190 was returned to PWI for —5 months before the MBE treatment failed. On 4/27/16, a Crystal Seal retreatment was pumped into 1C-190 to place another 3135 lbs of Crystal Seal to the MBE at 8300' RKB. This treatment lasted 2 months before the treatment broke down. On 9/21/16, an MBE retreatment was pumped in 1C-90 with 30 bbls Equiseal Gel and 2200 lbs of Crystal Seal, but this treatment only lasted —6 weeks. On 4/3/17 a 1C-190 IPROF found a new MBE at 8505'. The MBE previously treated at 8300' RKB did not appear open. On 11/2/17, perfs were shot at 8500 - 8505' RKB in 1C-190 slot. On 11/11/17, 6776 lbs of RPPG was pumped to MBE at 8505' RKB, but on 10/8/18 an [PROF showed the MBE at 8500' RKB still open to 1C-184, but the MBE at 8300' RKB appeared sealed. On 4/10/19, an MBE retreatment pumped another 6908 lbs of RPPG to try to seal the MBE, but this treatment also failed. It is proposed that a new 'producer side' MBE treatment be field tested in 1C-184 to seal the open MBE from 1C-184 to 1C-190. The longevity of injector side MBE treatments may be limited due sand production around treated MBE's on the producer side. It is possible that removal of formation solids around treated MBE's or developing MBE's creates new MBE's, so we intend to halt this process. The proposed MBE treatment will be fullbore pumped as a proppant slurry with activator solution in viscous gel to place proppant through the large perfs that were pre -drilled in 1C-184 liner. The proppant slurry will be flushed away to fill void space in the MBE and in Liner x OH annulus. After slurry has been placed, the carrier gel breaks with time, and activator will react with a coating on the proppant to bond the proppant grains together only at point to point contacts between the grains. This fuses a proppant pack together of a high compressive strength to create new cemented matrix. Thus, the proppant pack should greatly resist degradation under drawdown when 1C-184 is on production. The proppant matrix is designed to retain a very high residual matrix permeability. The proppant pack is to limit solids production to halt MBE creation without damaging productivity. Coil tubing will mill excess proppant from tubing and liner before 1C-184 will be returned to production. Procedure 1) Fullbore Pumping: Pump an SRIT to determine injectivity to 1C-184, and to determine leakoff to formation. Use SRIT data to tune fusion proppant treatment design. RU manned flowback tanks at 1C-190 injector, then pump 150 bbls 1% KCL Brine or Seawater at 2 bpm to 1C-184 to the open MBE while monitoring for returns from 1C-190 to tanks. Record stabilized WHIP, but do not exceed 1150 psi WHIP on 1C-184. Increase rate to 3 bpm for 30 bbls, followed by 4 bpm for 40 bbls followed by 5 bpm for 50 bbls. Record flowback volumes, if any, at 1C-190. Next, mix & pump 80# HEC Gel batch with breaker per the same SRIT schedule as used with Seawater (above) while monitoring flowback tanks at 1C-190. Depending on injectivity and WHP, be prepared to add an additional step rate at 10 bpm for 10 minutes (100 bbls added volume). This is max anticipated pump rate that may be used to pump a fusion job. Flush hardline and tubing with 50 bbls of 1 % KCL Brine or Seawater followed by Diesel freeze protect. If no fluid returned at 1C-190, obtain final 1C-190 WHP and have DHD shoot 1C-190 fluid level in tubing. RD. 2) Fullbore fused proppant pack treatment using the following estimated schedule. (Note: the final schedule will be adjusted per Step #1 results. Est. target pump rate for the treatment is —10 bpm). W1 Clean Volume.- Proppant Conc From To Proppant SG Breaker HEC Gel Prop ant Activator lbs per Mals lbs per Mals lbs added alMlons PadBbls 00 0 0 0 0.25 80 0 0 4 ppg 16/80 Proppant 25 4 4 2.59 0.25 80 4200 22 Intermediate Flush 100 0 0 0 0.25 80 0 0 4 ppg 16/80 Proppant 150 4 4 2.59 0.25 80 25200 135 6 ppq 16/80 Proppant 95 6 6 2.59 0.25 80 24000 128 8 DDQ 16/80 Pro ant 95 8 8 2.59 0.25 80 32000 171 10 Don 16/80 Pro ant 1 36 10 10 2.59 0.25 80 15000 80 Flush 50 0 0 0 0.25 80 0 0 Diesel FP 47 0 0 1 0 0 1 0 0 0 Totals 698 [=:===I 100400 []F 536 After completion of the pump schedule, keep 1C-184 shut-in for 48 hours. Also keep 1 C-190 shut-in. 3) Coil Tubing: MIRU CTU on 1C-184 at —48 hrs after MBE treatment was completed. RIH to perform a tubing jewelry wash and fill cleanout to depth of 7400' RKB. Do not cleanout deeper in order to leave the proppant pack across MBE below 7400' RKB undisturbed. POOH. RD CTU. 4) Coil Tubing: MIRU CTU on 1C-184 at 14 days after MBE treatment. RIH with CT and attempt to clean out the remainder of wellbore with nozzles, milling BHA's, Nitrogen, etc, to the deepest depth possible. POOH with CT. Return 1 C-190 to injection and monitor BHP gauges in 1 C-184. Initiate flowback of 1 C-184 to surface tanks through flowback piping and monitor fluid rates and watercuts. If no significant solids are seen, return 1C-184 to service through normal piping with 1C-190 remaining on injection to evaluate treatment results. Kat lc --i ID Regg, James B (CED) P11)703i%3o From: NSK West Salk Prod Engr <nl638@conocophillips.com> Sent: Friday, July 19, 2019 8:00 AM (�'�� 7��� To: Regg, James B (CED) Cc: Fox, Pete B; CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1&2 Ops Supt; Braun, Michael (Alaska); Mowrey, Andrew F Subject: LPP/SSV Returned to Service on CPAI well 1C-190 on 7/18/2019 Jim, The low pressure pilot (LPP) on well 1C-190 (PTD# 203-003) was returned to service and removed from the "Facility Defeated Safety Device Log" last, 7/18/2019, after the well was shut in when wellwork was completed. The LPP had been defeated on 7/17/2019, after the well was returned to service to perform wellwork on an offset producer. This notification is in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Marina Krysinski / Toon Changklungdee West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 I«( IC- IqL- Regg, James B (CED) 12))) 76;W31 From: NSK West Sak Prod Engr <nl638@conocophillips.com> Sent: Thursday, July 18, 2019 10:10 AM Y:,e� 7'� Its To: Regg, James B (CED) Cc: CPF1 Ops Supv; CPF1 DS Lead Techs; CPF1 &2 Ops Supt; Braun, Michael (Alaska); Fox, Pete B; Mowrey, Andrew F Subject: Defeated LPP/SSV on CPAI Well 1 C-190 on 7/17/2019 Jim, The low pressure pilot (LPP) on well 1C-190 (PTD# 203-003) was defeated last night, 7/17/2019, after the well was brought online for wellwork on an offset producer and the wellhead pressure fell below the LPP setpoint. The well is currently injecting at minimal rates with a wellhead pressure of 3 psi. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. Marina Krysinski / Toon Changklungdee West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 1QT-u I C- j90 Regg, James B (DOA) D030 From: NSK West Sak Prod Engr <n1638@conocophiIIips.com> Sent: Tuesday, May 14, 2019 7:06 PM SII J/(9 To: Regg, James B (DOA) Cc: Fox, Pete B; CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1&2 Ops Supt; Braun, Michael (Alaska); Sudan, Hari Hara Subject: LPP/SSV Returned to Service on CPAI well 1C-190 on 5/14/2019 Jim, The low pressure pilot (LPP) on well 1C-190 (PTD# 203-003) was returned to service and removed from the "Facility Defeated Safety Device Log" today, 5/14/2019, after the well was shut in following—a monitoring period. The LPP had been defeated on 4/17/2019, after the well was returned to service to monitor a recent conformance job. This notification is in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. Marina Krysinski / Toon Changklungdee West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 4497 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 0Zi'F"_D MAY 0 9 2019 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operatio Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change App Plug for Reddll ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: RPPG MBE Trtmt 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ Stratigraphic❑ Service IR 203-003 3. Address: P. 0. BOX 100360, Anchorage, 6. API Number: Alaska 99510 50-029-23136-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: KRU 1 C-190 ADL 25649, ADL 25650 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kuparuk River Field / West Salk Oil Pool 11. Present Well Condition Summary: Total Depth measured 10,466 feet Plugs measured None feet true vertical 3,759 feet Junk measured None feet Effective Depth measured 10,466 feet Packer measured 5,299 feet true vertical 3,759 feet true vertical 3,833 feet Casing Length Size MD ND Burst Collapse CONDUCTOR 82 feet 16 110' MD 110' TVD SURFACE 5,421 feet 7 5/8 " 5,449' MD 3834' TVD INER SLOTTED 5,179 feet 41/2" 10,466' MD 3787'TVD Perforation depth: Measured depth: 5602-10401. 8300-8305. 8500-8505 feet True Vertical depth: 3830-3760. 3795-3795. 3794-3794 feet Tubing (size, grade, measured and true vertical depth) 4.5 " L-80 5,296' MD 3,833' TVD Packers and SSSV (type, measured and true vertical depth) PACKER - ZXP LINER TOP PACKER 5,299' MD 3,833' TVD SSSV -NONE 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A 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 - - - - Subsequenttooperation: Shut -In - - - - 14. Attachments (re uired per 20 MC 25.070, 25 071, & 25283) 15. Well Class after work: Daily Report of Well Operations O Exploratory ❑ Development ❑ Service O Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: i Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ d WAG 7 GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-130 Contact Name. John Peirce Authorized Name: John Peirce Contact Email: John.W.Peirce@cop.com Authorized Title: Sr. Wells Engineer o Contact Phone (907) 265-6471 Authorized Signature: � ' S�o �1 .¢. Date: Form 10-404Revised 4/2017 (moi L 5-1-'40 '7' �BDMS Submit Original Only ffd--/ (u MAY s 2n�s 1 G190 RPPG MBE TREATMENT DTTMSTAR-JOBTYP SUMMARYOPS 4/10/19 ANNCOMM PUMPED 6908# OF RPPG MIXED IN 350 BBLS 2% KCL, GAIN OF 850 PSI WHP, WELL IS FREEZE PROTECTED. KUP INJ WELLNAME 1C•190 WELLBORE 1C-190 ConoeoPhiilips Well Attrtbutes Max Angle & MD TO IFleld _r IWellEore AP1UVn IWeIIEO,e$blus n^I�'j MapSNNB) Act Blm^RKB) Alaska, Im. WEFT SAK VI099J313Rpp I. i in naa 1C1 W.5Wpta1i93]PM Last Tag VertislacNma'sene) AnrwYnon I DINAh KIKal I End band 1 WeIIWre 1 Laid MW By Last Tag:ELMD 1 1 ,44].0 lelfflUM 1C-190 ashaR _..........._. _..... ....... ................ _. Last Rev Reason Annolafan En00ab Vh118ore LestMW By HARDER: zs.e REV REason. ADDED PEELS 11/3/201] 11,1vu ipp.n Casing Strings Casing De6nrlpYwn OD (nl 10 (Inl Top IhMBI $el Oepin IXNB) Sef Oep1M1 (Np) W Veen (1... Gn4e Top TM1naE CONDUCTOR 16 150fi 26.0 1100 1100 fi2.50 Hd0 WELDED CssInB Oeacioned OO pn) ID BnI Tap(XNB) SN pepT M.1 sn Oapinlrvpl... when lL..G,ese Top ID,u! SURFACE 7518 6.87 28.0 5,4490 3,8344 29.]0 L430 BTC -MOD eas"0-ription OB an ID9n) To ma) SH Beds @KBI BH BeptM1 ITVDL.. I. p... D,Ma Tap TM1retl LINER SLOTTED 412 3.96 5,28]5 10,466.0 3,7586 12.130 L-80 INSCT Liner Details SONDMTOq,ffio-tfoe Nominallo Top MNID Top (VD)MED Top Inc]C) I tem Des core pine 5287.5 3,832.9 87.27 SLEEVE BAKER TIE BACK SLEEVE 5.500 5,298.6 3,833.4 87.79 PACKER ZXP LINER TOP PACKER 4.940 NIPPLE 111. 5,306.6 3833.7 88.17 NIPPLE RS NIPPLE 4.000 11 5309.4 3,833.8 88.30 HANGER FLEX LOCK II HYD HANGER 5.500 5,317.3 3A 0 88.64 XO BUSIEIN XO BUSHING 4.500 10,431.3 3,759.3 91.29 BUSHING BAKER RACKOFF BUSHING 2.350 Tubing Strings To., Descrlpfwn $Fine Me... ID pn) Tap (f0(BI $el DepN IR. SeI DegM1 (TVD/( WIpWX) Grxle 'PCon vection TUBING 41" 3.96 236 5,2959 3,833.3 1260 L -BO NSCT Completion Details Top RMD) Top Incl Nominal TOPlwa) wa) 17 IMM Das coin ID(s) cAs uFr'. so4es 23.6 23.6 0.00 IHANGER VETCO GRAY HANGER 4500 515.0 5132 1625 1 NIPPLE CAMCO DB NIPPLE w/3.875 NO GO PROFILE 3.875 4,470.3 3,612.8 62.45 NiP LE CAMCO DB NIPPLE wl3812 NO GO PROFILE 3812 5,283.5 3,832.7 87.07 1 XO BUSHING BAKER XO BUSHING VAN 3.880 5,285.3 3,8328 87.16 SEAL ASSY BAKER BULLET SEAL ASSEMBLY w/VAM BOX UP 4.860 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) MPPLE: QeN.3 Top(wia Dl Ton(Bad) Toi;ncl wa Com Run Oah IO (In) PATCH bunace Casing patcM1 norn towen a drier heart 421"011 0000 In5la11ea 6' 12"x85.500 carbon stcel Sleeve an surface casing. Perforations & Slots snot Dens Topmrce) peoples) Top ITVDI (RKS) B.RVD) gives) LmLMzono Date (slMarl[ ryPo Co. XO BUSHING 52M5 5602.0 10,401.0 $830.4 TW0 WS D, 1C-1ND 3N2003 99.0 SLOTS Al(Ema4ng slDReNSDliB pipe. 3 BLANK JTSA SLOTTED JT 0 $3050 3,75. 3,]95.1 WSg1C-190 015 60 7E -RF In owe owH Dguns, SEALAssr, s,ayss -TW0 2M6FP, SERF 8,505.0 3)94.0 3.794.0 WSD, iC-190 =F7-- 60 APERF 2.5PDwe nw, -FIRE HEAD3"X27(GUN3"X 5') Mandrel Inserts st Mi °It^ Tap(KKp) Beam, (RRB) FLLe Mc4el OD(NI bery Valve Type LDRn Type �UK panstr TRO qpn (in) Ipeil Run"N" Com 1 3,OO6S 2,]09.3 CAMCO K8G2 1 GA LIFT DMV 0.000 0.0 41132003 Notes: General & Safety End Dae Annoeanon T21/2015 NOTE. NET PRESSURE INCREASE OF 1000 PSI. 9212015 N TE MBETREA M NTD WNCOIL TUBING PUM P 26188E F 2 5 KCL WITH 27094 0 F4 MM CRYSTAL SEAL 4272016 NOTE: MBE TREATMENT DWN COIL TUBING WITHN ZLE PARKED ABOVE SLOTTED LINER ATM '. 41272016 NOTE. PUMP 310 BIBILS OF SEA WATER WITH 3 MM CRYSTAL SEAL,PHE65UHL INCREASE OF 750 PSI $VRFACE: ffiM,ai9,, SLOES; S.W2.6f0,W10� IPERF:ai-A.68,"!Wa APERFi 8,800.M5paa� LINER SLOTTED; 5,$7.5. f0..a- K t IC—iqc7 Regg, James B (DOA) ft ; c) 3CV30 From: NSK West Sak Prod Engr <nl638@conocophillips.com> Sent: Wednesday, April 17, 2019 11:02 AMni l 4/17 �� �' To: Regg, James B (DOA) ` �1�� Cc: CPF1 Ops Supv; CPF1&2 Ops Supt; Braun, Michael (Alaska); Sudan, Hari Hara; Fox, Pete B; CPF1 DS Lead Techs Subject: Defeated LPP/SSV on CPAI Well 1C-190 on 4/17/2019 Jim, The low pressure pilot (LPP) on well 1C-190 (PTD# 203-003) was defeated today, 4/17/2019, as the wellhead pressure fell below the LPP setpoint while on injection. The well is currently injecting 571 BWPD with a wellhead pressure of 502 psi. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. Marina Krysinski / Toon Changklungdee West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 ft Regg, James B (DOA) &9360 From: NSK West Sak Prod Engr <nl638@conocophiIli ps.com> Sent: Wednesday, April 10, 2019 6:36 PM IR11 41 it It To: Regg, James B (DOA) ll CC Cc: Fox, Pete B; NSK Optimization Engr; CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1&2 Ops Supt; Braun, Michael (Alaska); Sudan, Hari Hara Subject: LPP/SSV Returned to Service on CPAI well 1C-190 on 4/10/2019 Jim, i The low pressure pilot (LPP) on well 1C-190 (PTDfi 203-003) was returned to service and removed from the "Facility Defeated Safety Device Log" today, 4/10/2019, after the well was shut in following wellwork. The LPP had been defeated yesterday, 4/9/2019, after the well was returned to service to perform wellwork. This notification is in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. Marina Krysinski / Toon Changklungdee West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 %u (C- I qv P74 Z030a3c Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> �ei 4 ill Sent: Tuesday, April 9, 2019 8:03 PM To: Regg, James B (DOA) Cc: NSK Optimization Engr; CPF1 Ops Supv; CPF1&2 Ops Supt; Braun, Michael (Alaska); Sudan, Hari Hara; Fox, Pete B; CPF1 DS Lead Techs Subject: Defeated LPP/SSV on CPAI Well 1C-190 on 4/9/2019 Jim, The low pressure pilot (LPP) on well 1C-190 (PTD# 203-003) was defeated t�/9/2019, after the well was brought online for upcoming wellwork. The well is currently injecting at 1113 BWPD with a wellhead pressure of 0 psi. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device v Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Marina Krysinski / Toon Changklungdee West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY John Peirce Sr. Wells Engineer ConocoPhillips Alaska, Inc. P.0 Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, KRU I C-190 Permit to Drill Number: 203-003 Sundry Number: 319-130 Dear Mr. Peirce: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Ww .aogcc.alaska.gov Enclosed is the approved application for the 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, Daniel T. "amount, Jr. Commissioner DATED this Z.Zday of March, 2019. RBDMSL�� MAR 2 2 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 rr- F x �,r- 34y,% E" wii iGZ G+n D MAR 19 2059 AOGG"C 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: RPPG MBE TRTMT[D 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: COnocoPhllll sAlaska Inc. Exploratory ❑ Development ❑ Stratigraphic ❑ Service O 203-003 3. Address: 6. API Number: P. 0. Box 100360, Anchorage, Alaska 99510 50-029-23136-00 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1C-190 Will planned perforations require a spacing exception? Yes ❑ No O ' 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25649, ADL 25650 1 Kuparuk River Field / West Sak 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): 10,466' 3,759' 10466 3759 1475 psi NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 82' 16" 110' 110' Surface 5,421' 75/8 5,449' 3,834' Liner 5,179' 41/2 10,466' 3,759' Perforation Depth MO (ft) IPerforation Depth TVD (ft) ITubing Size: Tubing Grade: Tubing MD (ft): 5602.10401, 8300.8305, 3830-3760, 3795-3795, 4.500" L-80 5,296' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER = ZXP LINER TOP PACKER 5299 MD and 3833 TVD SSSV = NONE N/A 12. Attachments: Proposal Summary El Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development[:) Service El 14. Estimated Date for 4/10/2019 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG O GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 0 17. 1 hereby certify that the foregoing is tnie and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: John Peirce Contact Name: John Peirce Authorized Title: Sr. Wells Contact Email: John.W.Peime@cop.com gEnginneeer ,/ � 31 i� I1 Contact Phone: (907) 265-6471 Authorized Signature: ( . Date: COMMISSION USE ONLY Conditions of approval: Notify Commissio so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No Q/ Subsequent Form Required: M —404 APPROVED BY 2 1 Approved by: COMMISSIONER THE COMMISSION Date: / I` 3 Z / Vi6 3/2/Il9 MOUlv10(1r MAX L [ LUIS 3 u i O R I G 1114 A L submit Form and Form IOA 3 Revised 4/2017 ?-,e- Aptr ld application is valid for 12 months from the date of approval. Ana.�,hm/�•nn in Dupiivt• VVVV ,,eA14 sr0,0.a/19It, KUP INJ WELLNAME 1C-190 WELLBORE 1C-190 r�Q Well Attributes Max Angle & MD TO CoriocOI",iesdelleWNIMre Wre$b[MO IXKBI A[101m IXNB) Alaska.lnDWEST SAN 500292313600 mJ d.98 9,066.11 10.4669 iC-teo, marls s. in v pM Last Tag Vvny vJwlneec lsrbuq Anotoadn pepmfXXa) I End Oahe We"Wre LasIMW By Last Tag: ELMD 10,44].0 2/1]120,41 11-190 ose Last Rev Reason _................................................_.................................... Annotation End Oah WI Lea, MW By Rev Reason'. ADDED PERFS 1113201] 1C-190 1 Pproven w,NGER, ms Casing Strings [ring Description O011nl IO pnl rop IXK91 Set Depen (XNeI SN Orom INpl_. WULen B_. Gratle Tap Thwd CONDUCTOR 16 1506 28.0 1109 1100 6250 'F1 WELDED "sing DescrlPtlon OD llnl 1. Snl Tap (ENO) Set DeOm FIRE) Set Oepm tIvIN. Wlllwn B... Grace Tep TI1. SURFACE 738 6.87 28.0 5,449.0 3,8344 29]0 LA0 BTC -MOD I I 1 Casing Deimidolon OD(MI .B., T,(XNe) Set "'U' MAA) Set Oepm(TVD)...Lan ll..Orade Tap I. LINER SLOTTED 4112 3% 5,2875 10466.0 3,7586 1260 LA0 NSCT Liner Details colmucroR.mo.vop wommM lD Top (NINE) Top fND)BIKE)832S Top mul•1 IMm On coot Il5. 5,28].5 3,8329 8)2] SLEEVE BAKER TIE BACK SLEEVE 5.500 5,298.6 3,833.4 SU9 PA KER ZXP LINER TOP PACKER 4940 NIPPLE, 515,0 5,306.6 3,8337 88.1] NIPPLE RS NIPPLE 4000 5,309.4 3,833.8 88.30 HANGER FLEX LOCK II HYD HANGER 5.5 0 5,3173 3,834.0 86.64 XO BUSHING NO BUSHING 4500 10431.3 3,759.3 91.29 BUSHING BAKER PACKOFF BUSHING 2.350 Tubing Strings ruemD Descnpton IS11h, M._.Iolinl Ta01X¢BI set Depenllt_ Set Depenf1VD11... (P") G,aeo rop conneNon TUBING ]Wt 4112 396 236 5,295.9 3,833.3 12.60 L-80 NSCT Completion Details TaplNDl Topmcl Nom,nal ToP(I ("Ka) (°, Ihen De. Cam ID onl 238 236 000 HANGER VETCO GRAY HANGER 4 W GAS uiT 3one .5 5150 5132 10.25 NIPPLE CASCO DB NIPPLE w/ 3.8]5 NO GO PROFILE 38]5 4,470.3 3,812.8 6245 NIPPLE CASCO DB NIPPLE W13812 NO GO PROFILE 3.012 5,283.5 3,832.] 8707 XO BUSH ING BAKER XO BUSHING VAM 3,880 5,285.3 3.832.8 8716 SEALASSY BAKER BULLET SEAL ASSEMBLY w/VAMBOXUP 4.060 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) TopIXNB) Toplrvp) (XKB1 To, fl Dea Cam Rrn DMe 10 (Int NIPPLE: 4.4M3- PATCH Sinigh. cast, patch horn an. Or Slaaer heau. 41212011 O.ON IDStalleu 6' 12'x65.500 carbon steel sleeve on surface casing. Perforations 8 Slots Shot Den ToplNol BtmlNol IslwRm TapmKB) BOB Kn B1 IXKBI "In Urtoxi ne she ) rype Co. NO BUSKING: 5.233.5 5,602.0 10,401.0 3,8WA 3,760.0 WS D,1 -90 35120D3 990 SLOTSernabng (solid pipe. 3 BLANK LISA SL07EDJT 8,300,0 8,3 ,O 3,7950 3,795.1 WS D,1719 0 FRETS 60 (PERF In owe ow guns, SEA- ABBY', 5.235.3 ZO06FP,6SPF 8,500.0 8,505.0 3,)940 3,]940 WSD,1 -190 11 121201] 60 APERF owe ow, -FIRE HEAD Y X 2')( GUN Y'X 51 Mandrel Inserts $t an on Top(IU:B) TOP(NO)Valve (N161 Mab MWeI OD lln) 8ery Latch Tag Type Pools"' (In) TRO Run "O RunDM Com 1 3,0065 2,709.3 CASCO KBG2 1 G4S LIFT DMY BK 0000 0.0 4113120,43 BEEN Notes: General & Safety End Date Annohtwn 912112015 NOTE. NET PRESSURE INCREASE OF 1000 PSI. 912112015 NOTE'. MBE TREATMENT DOWN COIL TUBING PUMP 61BBLS OF 25 KCL WITH ] IS OF 4 MM CRYSTAL SEAL 412 712 01 6 NOTE: MBE TREATMENT DOWN COIL TUBING WITH NOZZLE PARKED ABOVE SLOTTED LINER AT 560a 412712016 NOTEr PUMP 310 SBULS OF SEAWATER WITH 3135# OF 4 MM CRYSTAL SEAL. NETPRESSURE INCREASE OF 750 PSI SURFACE. W aBAEo_ SLOTS: 5=11,10.tl10- IPEsN EsN.69.3m.0-1 L1 APERE;9.SN..506.0-1 1 LINERSLOTTED:EXO] t04R0 Proposed RPPG Treatment from 1C-190 to 1C-184 of D Sand MBE 1C-190 is a single 4.5", L-80, horizontal monobore West Sak D sand injector that supports 1C-184 producer to the east, and 1C-135 producer to the west. An initial Matrix Bypass Event (MBE) occurred 1/16/15 from 1C-190 injector to 1C-184. A 4/27/15 ]PROF found an MBE at —8300' RKB. On 9/5/15, perfs were shot at 8300 - 8305' RKB, and on 9/21/15 CT pumped 2709 lbs of Crystal Seal to the D MBE. 1C-190 was returned to PWI for —5 months while the MBE remained sealed. On 1/13/16, CT FCO was performed to 9375' CTMD and WHIP fell from 1000 psi (at 220 BWPD) to 120 psi (at 600 BWPD) and 1C-184 WC% spiked to 90%, so 1C-190 was SI 2/6/16 due to a reopened D MBE. On 4/27/16, CT Crystal Seal retreatment was pumped to place 3135 lbs of Crystal Seal to MBE at 8300' RKB. This treatment only lasted —2 months before the treatment broke down. On 9/21/16, an MBE retreatment was pumped with 30 bbls Equiseal Gel and 2200 lbs of Crystal Seal, but this treatment only lasted —6 weeks, so 1C-184 and 1C-190 were SI. 1C-190 was returned to injection in Nov 2016 to support 1C-135 until an MBE broke Feb 2017 from 1C-190 to IC -135 that resulted in 1C-190 LTSI. On 4/2/17, CT FCO removed gel from 1C-190, and 4/3/17 IPROF found a new MBE at —8505'. The MBE previously treated at 8300' RKB did not appear open. On 11/2/17, large hole perforations were shot at 8500 - 8505' RKB in slotted liner to enable RPPG passage through liner to MBE. An RPPG treatment on 11/11/17 pumped 6776 lbs of RPPG targeting the MBE at 8505' RKB. On 10/08/18, an ]PROF showed the MBE at 8500' RKB remained open to 1C-184, but the MBE at 8300' RKB appeared to remain sealed. It is proposed that a fullbore RPPG retreatment of the D MBE at 8505' RKB be pumped to seal it off. Procedure 1) Pumping At —12 hours before RPPG job, put 1C-190 on injection at 500 - 1000 BPD to displace all gas head and Diesel hydrocarbon contaminants to RPPG swelling and crosslinking away from wellbore to MBE, to ensure MBE is open and well is liquid packed and free as possible of hydrocarbons. RU Mixing Van and pumping equipment at 1C-190. SI the injection to 1C-190, and then swap to fullbore pumping 1 wellbore volume (129 bbls to MBE) of 2% KCL Brine to 1C-190, followed by RPPG slurry at steady rate between 1.5 - 2.0 bpm by adding 1 - 4 mm mesh RPPG to ultraclean 2% KCL Brine to make slurry at steady 0.75 ppg concentration from mix van. Continue pumping steady rate and concentration until WHIP reaches —800 psi, and then swap from RPPG slurry to pumping 88 bb]s 2% KCL Brine, followed by 41 bbls Diesel FP to 2500' TVD, followed by Shutdown. Wait 2 days for the swelling RPPG particles to fully crosslink in the MBE to form stout amalgamated non -flowing crosslinked gel before returning 1C-184 or 1C-135 to production, or 1C-190 to injection. Coil Tubing - if needed: 2) An RPPG Fluff & Stuff or FCO may be performed depending on post-RPPG injection performance. MIRU CTU. RIH with jet nozzle to tag RPPG in 1C-190 and then jet down through RPPG with Diesel to deep as possible to uncover liner slots to injection. Take returns to tanks if returns can be achieved, else fluff & stuff through RPPG while injecting away Diesel away to formation. POOH. RD CTU. Return 1C-190 to injection and 1C-184 to production to evaluate treatment results Originated: Schlumberger PTS - PRINTCENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: r AOGCC a ATfN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision \fit 333 W. 7th Ave, Suite 100 `•" Anchorage, AK 99501 203 003 30455 . • I 14 -Mar -19 14Mar19-J101 WELL NAME 1R-170 1E-1681-1 1C-190 1J-164 API N 0 50-029-22212-00 50-029-23230.60 50-029.23136.00 50-029.23278-00 SERVICE ORDER # EA77.00002 E90U-00005 E90U-00006 E901.1-00007 FIELD NAME KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER DESCRIPTION WL WL WL Memory DELIVERABLE IPROF Ver2 ]PROF IPROF IPROF DATA YPEr FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD 13 -Feb -19 23 -Feb -19 23 -Feb -19 25 -Feb -19 1 1 1 1 1J-136 50.029-23331-00 E90U-00009 KUPARUK RIVER Memory IPROF FINAL FIELD 26 -Feb -19 1 2M-21 50-103.20156.00 E540-00062 KUPARUK RIVER WL Caliper FINAL FIELD 7 -Mar -19 1 OR 14 6 Signature Please return via courier or sign/scan and email a copy Date lumberger and CPAI. Schlumberger -Private ATransmittal Receipt signature confirms that package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. The specific content of the CDs and/or hardcopy prints may or may not have been verified forcorrectness or quality level at this point. SLB 1(4f 1 (C- (aZ) P+� z(73o a Regg, James B (DOA) From: NSK West Sak Prod Engr <nl638@conocophillips.com> Sent: Sunday, February 24, 2019 6:S0 AM To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1&2 Ops Supt; NSK Optimization Engr; Fox, Pete B; Braun, Michael (Alaska) Subject: LPP/SSV Returned to Service on Well 1C-190 Jim, The low pressure pilot (LPP) on well 1C-190 (PTD# 203-003) was returned to service and removed from the "Facility Defeated Safety Device Log' this morning, 2/24/2019, after wellwork was completed and the well was shut-in. The LPP had been defeated on 2/20/2019 after the well was returned to service to perform diagnostic wellwork. This notification is in accordance with "Administrative Approval No. CO 4068.001." ✓ Please let me know if you have any questions. Marina Krysinski / Toon Changklungdee West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 l au (c --(qty Regg, James B (DOA) N Z03003o From: NSK West Sak Prod Engr <nl638@conocophillips.com> Sent: Wednesday, February 20, 2019 8:56 AM e� kg To: Regg, James B (DOA) ( (� �I Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1 &2 Ops Supt; NSK Optimization Engr; Fox, Pete B; Braun, Michael (Alaska) Subject: Defeated LPP/SSV on CPAI Well 1C-190 on 2/20/2019 Jim, ,/ The low pressure pilot (LPP) on well 1C-190 (PTD# 203-003) was defeated today, 2/20/2018, after the well was brought online for upcoming wellwork. The well is currently injecting at 1048 BWPD with a wellhead pressure of 42 psi. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeate�C3-aTety Device Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. Marina Krysinski / Toon Changklungdee West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 PTh 7030O30 Regg, James B (DOA) From: Byrne,Jan (ASRC Energy Services) <Jan.Byrne@contractor.conocophillips.com> Sent: Tuesday, May 15, 2018 3:26 PM �C' To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA);Wallace, � /211/8 Chris D (DOA) Subject: Recent SW MITIAs performed in Kuparuk. Attachments: MIT KRU 1C Pad 190 NON-WITNESSED 05-13-18.xlsx; MIT KRU 1C Pad pg 1 05-12-18.xlsx; MIT KRU 1C Pad pg 2 05-12-18.xlsx; MIT KRU 1C Pad pg 1 05-13-18.xl x; MIT KRU 1C Pad pg 2 05-13-18.xlsx Recent SW MITIAserformed in Kuparuk. p p Regards, Jan Byrne/ Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 #11#11Z-LLS TEAM SCANNED .JUN 0 1 2.01a Cor. " fps 1 • . • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reocinalaska.aov: AOGCC.Inspectorsealaska.sov phoebe.brooks(dalaska.sov chris.wallace(o)alaska.aov OPERATOR: ConocoPhillips Alaska Inc, FIELD/UNIT/PAD: Kuparuk/KRU/1C Pad DATE: 05/13/18 OPERATOR REP: Arend/Lomer AOGCC REP: Well 1C-190 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2030030 Type lnj N Tubing 50 50 50 50 Type Test P !! Packer TVD 3833 ' BBL Pump 1.4 i IA 40 1805 1715 " 1700 - Interval 4 Test psi 1500 BBL Return 1.4 ' OA Result P Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type lnj Tubing Type Test I'!I Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: ,I Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type lnj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj TubingType Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes III W=Water P=Pressure Test I=Initial Test P=Pass G=Gas 0=Other(describe in Notes) 4=Four Year Cycle F=Fail S=Slurry V=Required by Variance I=Inconclusive I=Industrial Wastewater 0=Other(describe in notes) N=Not Injecting Form 10-426(Revised 01/2017) MIT KRU 1C Pad 190 NON-WITNESSED 05-13-18 • • \CAA (C-t ZD Prb ZO3W30 Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> /7 Sent: Sunday, December 17, 2017 11:43 AM �� �1 (Z'1 1V/7 To: Regg,James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; NSK Optimization Engr; CPF1&2 Ops Supt;Autry, Sydney;Targac,Gary; Fox, Pete B; Sudan, Hari Hara Subject: LPP/SSV Returned to Service on CPAI well 1C-190 on 12/17/2017 Jim, The low pressure pilot (LPP) on well 1C-190(PTD#203-003)was returned to service and removed from the "Facility Defeated Safety Device Log" on 12/17/2017.The well is currently shut in. Prior to shutting in, the well was injecting at approximately 850 BWPD with a wellhead injection pressure of 13 psi. a" The LPP had been defeated on 12/10/2017, after the wellhead injection pressure fell below the LPP setpoint of 300 psi. This notification is in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Marina Krysinski / Mitch Autrey West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 SUN 1 • . K,g-irt 1 C— ct o Regg, James B (DOA) PTh ©30 From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Monday, December 11, 2017 5:54 AMtZ �r To: Regg, James B (DOA) 7 � Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; NSK Optimization Engr; CPF1&2 Ops Supt;Autry, Sydney;Targac, Gary; Fox, Pete B; Sudan, Hari Hara Subject: Defeated LPP/SSV on CPAI well 1C-190 on 12/10/2017 Jim, The low pressure pilot (LPP) on well 1C-190(PTD#203-003)was defeated yesterday, 12/10/2017, after the well was returned to service after an extended shut-in period.The well is currently injecting at a wellhead pressure of 313 psi and a rate of 868 BWPD.The LPP and surface safety valves(SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Marina Krysinski/Mitch Autrey West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497SCANNEEI 1 RECEIVED STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMMI ION DEC 1 ?i17 • REPORT OF SUNDRY WELL OPERATIONS ADCC 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: RPPG D MBE Trtmt 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development❑ Exploratory ❑ 203-003 3.Address: P. O. Box 100360, Anchorage,Alaska Stratigraphic❑ Service 0 6.API Number: 99510 50-029-23136-00 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 1C-190 ADL 25649,ADL 25650 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 10,466 feet Plugs measured None feet true vertical 3,759 feet Junk measured None feet Effective Depth measured 10,466 feet Packer measured 5,299 feet true vertical 3,759 feet true vertical 3,833 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 82 feet 16 " 110' MD 110 TVD SURFACE 5,421 feet 7 5/8" 5,449' MD 3834 TVD LINER SLOTTED 5,179 feet 4 1/2" 10,466' MD 3759 TVD Perforation depth Measured depth 5602-10401,8300-8305,8500-8505 feet True Vertical depth 3830-3760,3795-3795,3794-3794 feet Tubing(size,grade,measured and true vertical depth) 4.5 " L-80 5,296' MD 3,833'TVD Packers and SSSV(type,measured and true vertical depth) PACKER=ZXP Liner Top Packer 5299 MD 3833 TVD SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: scoNED JAN 2 4 2318 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure .rior to well operation: - - Shut-In - - Subsequent to operation: - - 483 - 247 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development ❑ Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG 0 GINJ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-383 Contact Name: John Peirce Authorized Name: John Peirce Contact Email: John.W.Peirce©cop.com Authorized Title: Sr.Wells Engineer .' ` 1 2/li /4 -7 Contact Phone: (907)265-6471 Authorized Signature: ' c- (. f ••-c.A Date: l Form 10-404 vised 4/2017 yri- 1/0 /1 Submit Original Only A l e R Ei Ell S 1,‘-v1,‘-vG7LS,, „1 2617 17 • S IC- I 90 RPPG D MBE TREATMENT DTTMSTA JOBTYP SUMMARYOPS 11/2/17 MISC. RIH WITH GAMMA RAY, CCL, E-FIRE AND 5' GUN, LOG CAPACITY FROM 8650'TO 8450' CORRECT DEPTH TO 8653.55', SUSTAINMENT PICK UP TO 8496.8' RKB, SHOOT FROM 8500'-8505' RKB, POOH CONFIRM GUNS FIRED. RDMO JOB COMPLETE. 11/11/17 MISC. Performed full-bore RPPG treatment pumping 213 bbls of CAPACITY - 0.75 ppg RPPG placing 6776#of RPPG into formation SUSTAINMENT followed by 55 lbs of crystal seal. Displaced with 5 bbls seawater, 120 bbl diesel. KUP • 1C-190 •ConocoPhldhhps - Well Attrib Max Angle&MD TD AiaSk:H.h.,,, Wellbore API/UWI Field Name Wellbore Status ncl g) MD(ftKB) Act Btm(ftKB) ConoCaPh181ps'; 500292313600 WEST SAK INJ 94.98 9,068.11 10,466.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1C-190,12/7/2017 3.53.13 PM SSSV:NIPPLE Last WO: 34.01 3/11/2003 Verocal schema'.(ac,* Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:ELMD 10,447.0 2/17/2004 Rev Reason:ADDED PERFS pproven 11/3/2017 asing Strings 1_EIf Casing Description 00(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread HANGER,23.5 /� CONDUCTOR 16 15.062 28.0 110.0 110.0 62.50 H-40 WELDED ' �r. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I..Grade Top Thread L J SURFACE 17 5/8 6.875 28.0 5,449.0 3,834.4 29.70 L-80 BTC-MOD „, , „A,,,.Casing Description OD(in) ID' (in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread jLINER SLOTTED 4 1/2 3.958 5,287.5 10,466.0 3,758.6 12.60 L-80 NSCT ( Liner Details Nominal ID ��^ Top(ftKB) Top(TVD)(ftKB) Top Incl(6) Item Des Com (in) 5,287.5 3,832.9 87.27 SLEEVE BAKER TIE BACK SLEEVE 5.500 CONDUCTOR,280-110.0-4 Il 5,298.6 3,833.4 87.79 PACKER ZXP LINER TOP PACKER 4.940 5,306.6 3,833.7 88.17 NIPPLE RS NIPPLE 4.000 5,309.4 3,833.8 88.30 HANGER FLEX LOCK II HYD HANGER 5.500 NIPPLE;515 0 5,317.3 3,834.0 88.64 XO BUSHING XO BUSHING 4.500 10,431.3 3,759.3 91.29 BUSHING BAKER PACKOFF BUSHING 2.350 Tubing Strings Tubing Description String Ma...ID(In) Top(ftKB) Set Depth(ft..]Set Depth(TVD)(...Wt(Ibttt) Grade Top Connection TUBING 41/2 3.958 23.6 5,2959 3,833.3 12.60 L-80 NSCT Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top net g) Item Des Com (in) 23.6 23.6 0.00 HANGER VETCO GRAY HANGER 4.500 515.0 513.2 10.25 NIPPLE CAMCO DB NIPPLE w/3.875 NO GO PROFILE 3.875 ... 4,470.3 3,612.8 62.45 NIPPLE CAMCO DB NIPPLE w/3.812 NO GO PROFILE 3.812 GAS LIFT,3,006.5 5,283.5 3,832.7 87.07 XO BUSHING BAKER XO BUSHING VAM 3.880 5,285.3 3,832.8 87.16 SEAL ASSY BAKER BULLET SEAL ASSEMBLY w/VAM BOX UP 4.860 11 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) C) Des Com Run Dale ID (in) € PATCH Surface casing patch from bottom of starter head. '4/21/2011 0.000 1-R7 Installed 6'12"x65.500 carbon steel sleeve on NIPPLE,4,470.3 surface Casing. Perforations&Slots Shot II Dens Top(WD) Btm(WD) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 5,602.0 10,401.0 3,830.4 3,760.0 WS D,1C- 3/9/2003 99.0 SLOTS Alternating slotted/solid 190 pipe.3 BLANK JTS:1 XO BUSHING,5,283.5 SLOTTED JT 8,300.0 8,305.0 3,795.0 3,795.1 WS D,1C- 9/5/2015 6.0 (PERF 2in Powerflow HSD 190 guns,2006FP,6SPF SEAL ASSY,5,285.3 g 8,500.0 8,505.0 3,794.0 3,794.0 WS D,1C- 11/2/2017 6.0 APERF 2.5"Powerflow,(E-FIRE 1 .1m1 190 HEAD 3"X 2')(GUN 3" / X 5') Maga Mandrel Inserts aSt - - all onN Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type - (in) (psi) Run Date Com i 1 3,006.5 2,709.3 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 4/13/2003 II _ 5 Notes:General&Safety End Date Annotation 9/21/2015 NOTE:NET PRESSURE INCREASE OF 1000 PSI. 9/21/2015 NOTE:MBE TREATMENT DOWN COIL TUBING PUMP 261 BBLS OF 2.5%KCL WITH 2709 8 OF 4 MM CRYSTAL SEAL 4/27/2016 NOTE:MBE TREATMENT DOWN COIL TUBING WITH NOZZLE PARKED ABOVE SLOTTED LINER AT 5600'. 4/27/2016 NOTE:PUMP 310 BBLS OF SEA WATER WITH 3135 8 OF 4 MM CRYSTAL SEAL. NET PRESSURE 1' Il INCREASE OF 750 PSI SURFACE,28 0-5,449.0 S - SLOTS;5,802.0-10,401.0 (PERF,8,300.0-8,305.0 APERF,8,500.68,505.0 LINER SLOTTED;5,287.5- 6 H 10,466.0 el 6 • O • a) O bo ; 7W r�ow „^ _...... r r r r r . . . . . . r a V ` _ r as a an m a a 0 o Q- ,F -o _ I� C _ U O N +-, > O0 r a 0 v / L) 8: CI C C Y Y M L NZS- CO O 6 Q O E a TO Q co Q0 r h h n r-- r ,_ ,_ ,_ v▪ a) O J > > > > > > > o v) 0 0 0 0 0 0 0 0 0 0 0 � _c +' � N C ,, zzzzzzzzzzz C cu � � v Z Q N M If) f• W O r r r 4- OU "6 (6 p +C+ 0 2 j E -0 a) Q O C I— (o N 'B U O 0 0 0 0 0 0 0 0 0 0 C v •p I- L” J J J J J J J J J J J C [J 0 W W W W W W W W W W W o N 'i --- H LL LL LL LL LL LL LL LL LL LL LL +' 0! N N a U a J J J J J J J J J J J .-a > C 1) (0 F- a Q Q a Q a a a a Q a a.) 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U) N N N N N N N N N N G -o O C as F N u C • U y.°Lb`c 4) — SZ OD u W _ U N Q N0 -I N t6 Y H 2 N .--i a 1T N N N CO c0 p N n +o c (-1-) IV e _ CO r r r M C � +, 10 = O_ lV i N j o r = J r ' r 4 N 4 W C ro N c — n- Q O W r W (Ni W r 11 y, O O - + 00 In i u r 3 r C C cu E E O ND a Q I` a` a 1- 1°- ®F Tx� 0 0 4,,, I i 6,,, THE STATE Alaska Oiland Gas ,�,-s..- of/\ jASKA Conservation Commission 11.E t i t 333 West Seventh Avenue k GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 wh Main: 907.279.1433 0 ALA&434' Fax: 907.276.7542 • www.aogcc.alaska.gov John Peirce Sr. Wells Engineer ConocoPhillips Alaska, Inc. scANNEDHp 0 1 201 P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1C-190 Permit to Drill Number: 203-003 Sundry Number: 317-383 Dear Mr. Peirce: 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, cf-•� ti-11 Cathy . Foerster � Commissioner DATED this C1'-day of August, 2017. RBDMS (A' Pi': 3 0 2017 • III III STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AUGf0 8 ? l7 APPLICATION FOR SUNDRY APPROVALS ATS V Zi 11 T 20 AAC 25.280 4(..X.;10C 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate [Vf• Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: RPPG D MBE Trtmt a 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ 203-003 ' 3.Address: Stratigraphic ❑ Service 0, 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-23136-00 r 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 0 / KRU 1C-190 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25649, 256Kuparuk River Field/West Sak 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): 10,466' 3,759' 10466 3759 NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 82' 16" 110' 110' Surface 5,421' 7 5/8 5,449' 3,834' Production Liner 5,179' 4 1/2 10,466' 3,759' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 5602-10401,8300-8305 . 3830-3760,3795-3795 4.500" L-80 5,296' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER=ZXP LINER TOP PACKER ' 5299 MD and 3833 ND SSSV: =NONE N/A 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development❑ Service 0 ' 14.Estimated Date for 9/1/2017 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG 0 . GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown 0 Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: John Peirce Contact Name: John Peirce Authorized Title: Sr.Wells Engineer Contact Email: John.W.Peirce@cop.com �71,I �? Contact Phone: (907)265-6471 Authorized Signature:�, Date: MI /[l / ��- COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 317-3V3 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes ❑ No Itr RDDMS LV AN 3 0 2017 f7 Spacing Exception Required? Yes ❑ No ' Subsequent Form Required: //3 — 4-0 Lc. 0 APPROVED BY Approved by: CY-4? COMMISSIONER THE COMMISSION Date: g_2_9 _/7 sh%o ('0 YrL d/Z 57 i 7_ Submit Form and Form 10-403 Revised 4/2017 IvVidaklicition Lid for 12 months from the date of approval. Attachments in Duplicate • • RPPG Treat dual `D' Sand MBE's from 1C-190 to 1C-184, and from 1C-190 to 1C-135 / 1C-190 is a single 4.5", L-80, horizontal monobore West Sak D sand injector that supports 1C-184 producer to the east and 1C-135 producer to the west. An initial Matrix Bypass Event (MBE) occurred 1/16/15 in the D sand from 1C-190 injector to 1C-184. A 4/27/15 IPROF identified an MBE at -8300' RKB. On 9/5/15, perfs were shot at 8300 - 8305' RKB, and on 9/21/15 CT pumped 2,709 lbs of Crystal Seal to the D MBE. 1C-190 was returned to PWI for-5 months with the MBE sealed. On 1/13/16, a 1C-90 CT FCO was done to 9375' and WHIP fell from 1000 psi (220 BWPD) to 120 psi (600 BWPD) and 1C-184 WC% spiked to 90%. 1C-190 was SI 2/6/16 due to a reopened D MBE. On 4/27/16 a CT Crystal Seal retreatment was pumped to place 3,135 lbs of Crystal Seal to the MBE at 8300' RKB. This treatment only lasted -2 months before the treatment broke down. On 9/21/16, an MBE retreatment was pumped with 30 bbls Equiseal Gel and 2,200 lbs of Crystal Seal, but this treatment only lasted until Nov 2016. As a result, 1C-184 and 1C-190 were SI. 1C-190 was returned to injection in Nov 2016 to support 1C-135 until another MBE occurred in Feb 2017 from 1C-190 to 1C-135 which has resulted in long term SI of 1C-190. On 4/2/17, CT FCO removed gel from 1C-190. A 4/3/17 1C-190 IPROF found a new MBE at -8505'. The MBE previously treated at 8300' RKB does not appear open, but this might be due to all flow entering the very dominant new MBE at 8505' RKB. f It is proposed that 1C-190 be perforated at 8500 - 8505' RKB at the new MBE, and that a fullbore RPPG treatment be pumped to the MBE at -8505' RKB. Procedure 1) Coil Tubing: RIH with pelf gun to perforate a 5' interval with large holes across the D MBE at -8500 - 8505' RKB, to enable better passage of RPPG slurry through the slotted liner to the MBE. 2) Pumping: If 1C-184 and 1C-135 producers are online, shut-in these wells as 1C-190 RPPG job is about to begin. This should help mitigate excessive vacuum of RPPG slurry while pumping it to the MBE(s). RU Mixing Van and pumping equipment on 1C-190. Fullbore pump RPPG slurry into 1C-190 at a steady rate in 1.0 - 1.5 bpm range in 3% KCL Water or Seawater. Add 1 - 4 mm mesh RPPG to the make up water at a steady 0.7 - 0.8 ppg slurry concentration in the mixing van. Continue pumping at steady rate and slurry concentration until the WHIP eventually reaches -800 psi, and then swap from RPPG slurry to pumping 88 bbls Seawater Spacer, followed by 41 bbls Diesel freeze protection to 2500' TVD, followed by Shutdown. This technique intends to leave maximum treating pressure acting on the MBE(s) near Frac pressure at shutdown to ensure that the MBE(s) are well packed with RPPG. Wait 2 days for the swelling RPPG particles to fully crosslink in the MBE to form stout amalgamated non-flowing crosslinked gel before returning 1C-184 or 1C-135 to production. • Coil Tubing: 2) RIH with jet swirl nozzle and tag top of RPPG in 1C-190, then jet down through RPPG and fill to as deep as possible to shear and mechanically break any RPPG remaining in the well, and to uncover all the perforation intervals to injection. Maintain 1:1 returns to tanks during FCO. POOH. RD CTU. Return 1C-190 to PWI service and return either 1C-184 or 1C-135 to production to evaluate treatment results. If treatment results look good, bring on the remaining producer and evaluate treatment results. • KUP I 1C-190 ,.Conn # tiliips .: \}Well Attribute Max Angle It TD Alaska.,inti., /Wellbore API/UWI Field Name Wellbore Status (°) MD(ftKB) Act Btm(ftKB) Caro ihiBrps 500292313600 WEST SAK INJ incl 94.98 9,068.11 10,466.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1C-190,7/25/2017 2:36:54 PM SSSV:NIPPLE Last WO: 34.01 3/11/2003 vertcal nchematc(actual) 'Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:ELMD 10,447.0 2/17/2004 Rev Reason:Crystal Seal Job,SEE NOTES pproven 5/4/2016 using Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread HANGER,23s CONDUCTOR 16 15.062 28.0 110.0 110.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread Casing Description OD(in) ID(in) 28.0 5,449.0 3,834.4 29.70 L-80 BTC-MOD it / SURFACE 75/8 6.875 �' J Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread LINER SLOTTED 4 1/2 3.958 5,287.5 10,466.0 3,758.6 12.60 L-80 NSCT Liner Details ' Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 5,287.5 3,832.9 87.27 SLEEVE BAKER TIE BACK SLEEVE 5.500 CONDUCTOR,28.0110.0--4 i ► 5,298.6 3,833.4' 87.79 PACKER ZXP LINER TOP PACKER 4.940 5,306.6 3,833.7 88.17 NIPPLE RS NIPPLE 4.000 5,309 4 3,833.8 88.30 HANGER FLEX LOCK II HYD HANGER 5.500 5,317.3 3,834.0 88.64 XO BUSHING XO BUSHING 4.500 NIPPLE;515.0 ;. 10,431 3 3,759.3 91.29 BUSHING BAKER PACKOFF BUSHING 2.350 Tubing Strings . Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING 41/2 3.958 23.6 5,295.9 3,833.3 12.60 L-80 NSCT j Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl r) Item Des Com (in) I, .j3 23.6 23.6 0.00 HANGER VETCO GRAY HANGER 4.500 515.0 513.2 10.25 NIPPLE CAMCO DB NIPPLE w/3.875 NO GO PROFILE 3.875 • 4,470.3 3,612.8 62.45 NIPPLE CAMCO DB NIPPLE w/3.812 NO GO PROFILE 3.812 i w' 5,283.5 3,832.7 87.07 XO BUSHING BAKER XO BUSHING VAM 3.880 GAS LIFT;3,008.5 5,285.3 3,832.8 87.16 SEAL ASSY BAKER BULLET SEAL ASSEMBLY w/VAM BOX UP 4.860 / Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl '3 Top(ftKB) (ftKB) (°) Des Com Run Date ID(In) PATCH Surface casing patch from bottom of starter head. 4/21/2011 0.000 Installed 6'12"x65.500 carbon steel sleeve on surface casing. NIPPLE;4,470.3 'i ¢ Perforations&Slots 8:€< § Shot Den Top(TVD) Btm(ND) (shoal Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 5,602.0 10,401.0 3,8304 3,760.0 WS D,1C- 3/9/2003 99.0 SLOTS Alternating slotted/solid 0 r 190 pipe.3 BLANK JTS:1 SLOTTED JT 8,300.0 8,305.0 3,795.0 3,795.1 WS D,1C- 9/5/2015 6.0 IPERF 2in Powerflow HSD • 00 BUSHING;5,283.5 190 guns,2006FP,6SPF Mandrel Inserts St SEAL ASSY,5285.3aese o� 1.al N n Top(TVD) Valve Latch Port Size TRO Run �,q', Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1- 3,006.5 2,709.3 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 4/13/2003 Notes:General&Safety AUL End Date I Annotation m 9/21/2015 NOTE NET PRESSURE INCREASE OF 1000 PSI. - - 9/21/2015 NOTE:MBE TREATMENT DOWN COIL TUBING PUMP 261 BBLS OF 2.5%KCL WITH 2709#OF 4 MM ) €: CRYSTAL SEAL 4/27/2016 NOTE:MBE TREATMENT DOWN COIL TUBING WITH NOZZLE PARKED ABOVE SLOTTED LINER AT 5600'. 4/27/2016 NOTE:PUMP 310 BBLS OF SEA WATER WITH 3135#OF 4 MM CRYSTAL SEAL. NET PRESSURE INCREASE OF 750 PSI SURFACE,28.0-5,449.0 ,te SLOTS;5,802.010,401.0 IPERF;8,300.0-8,305.0 LINER SLOTTED;5,287.5- J L 10,4880 Kruo c —1 c/o a300 30 Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Tuesday, April 04, 2017 8:48 AM {'<t'll 4/ /i 7 To: Regg,James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; NSK Optimization Engr; CPF1&2 Ops Supt;Jensen, Marc D; Stanley, Scott M; Sullivan, Michael; Krysinski, Marina L;Targac, Gary; Effiong, Michael Subject: LPP/SSV returned to service on well 1C-190 on 04/03/17 Jim, The low pressure pilot (LPP) on well 1C-190 (PTD#203-003)was returned to service and removed from the safety defeat log on 04/03/17, after the well was shut-in. The LPP had originally been defeated on 04/02/2017 when the well was restarted for troubleshooting and diagnostics. This notification is in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Best regards, Michael Effiong (Alternate: Scott Stanley) West Sak Production Engineer ConocoPhillips Alaska Inc. Office: 1 907 659-7234 Pager: 1 907 659-7000 pg. #497 Email: n1638Ca)conocophillips.com SCANNED ()E ' J 5 2l 1 • • Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> //,,� Sent: Sunday, April 02, 2017 9:45 PM `TI Z`j 1/7 To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; NSK Optimization Engr; CPF1&2 Ops Supt;Jensen, Marc D; Stanley, Scott M; Sullivan, Michael; Krysinski, Marina L; Targac, Gary; Effiong, Michael Subject: Defeated LPP/SSV on CPAI well 1C-190 on 04/02/2017 Jim, The low pressure pilot(LPP) on well 1C-190 (PTD#203-003)was defeated today, 4/2/2017, after the was restarted. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the"Facility Defeated Safety Device Log." The well is currently injecting 900 BWPD at a wellhead injection pressure of 1 psig. The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Best regards, Michael Effiong (Alternate: Scott Stanley) West Sak Production Engineer ConocoPhillips Alaska Inc. Office: 1 907 659-7234 Pager: 1 907 659-7000 pg. #497 Email: n1638 aC7,conocophillips.com 1 2_0 - 003 • • 2-1532 WELL LOG c!\rS TRANSMITTAL DATA LOGGED PROACTIVE DIAGNOSTIC SERVICES, INC. RECEIVED ����� /l3/201 7 M K.BENDER APR 1 2 2017 To: AOGCC Makana Bender AOGCC 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C MAI AK 99518 SCANNED 0 1 LU:1Iy, Fax: (907) 245-8952 1) Injection Profile 03-Apr-17 1C-190 1 Report /CD 50-029-23136-00 2) Signed : M✓ct4x'a'!2 , 6..e4t Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:Wchives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\ConocoPhillips_Transmit.docx 223005-7© Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Sunday, February 19, 2017 8:31 AM �' � t/uj/7 To: Regg,James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; NSK Optimization Engr; CPF1&2 Ops Supt;Jensen, Marc D; Stanley, Scott M; Sullivan, Michael; Krysinski, Marina L;Targac, Gary; Effiong, Michael Subject: LPP/SSV returned to service on well 1C-190 on 02/18/17 Jim, The low pressure pilot(LPP) on well 1C-190 (PTD#203-003)was returned to service and removed from the safety defeat log on 02/18/2017, after the well was shut-in. The LPP had originally been defeated since 02/15/2017. This notification is in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Kind Regards, Scott Stanley / Michael Effiong West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 NEW je1 b 1 Pager: (907) 659-7000 #497 S n1638@conocophiIlips.com 1 • 14Ctiti C-- 1c'c0 Regg, James B (DOA) 7630 From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Wednesday, February 15, 2017 4:37 PM (-2al¢' ti/i 7 To: Regg,James B (DOA) 1 Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; Sullivan, Michael; NSK Prod Engr Specialist; CPF1 Prod Engr; Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Krysinski, Marina L; CPF1&2 Ops Supt; Effiong, Michael Subject: Defeated LPP/SSV on CPAI well 1C-190 Jim, The low pressure pilot(LPP) on well 1C-190 (PTD#203-003)was defeated today, 2/15/2017, after the well head injection pressure fell below 500 psig. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The well is currently injecting 800 BWPD at a wellhead injection pressure of 275 psig. The AOGCC will be notified when the injection pressure has increased to above 500 psig and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Kind Regards, Scott Stanley/ Michael Effiong West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000#497 SCANNED RA' k 11 ni638@conocophinips.com 1 Aft (cto Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Friday, February 03, 2017 7:27 PM i 1(.4 (7 To: Regg, James B (DOA) Subject: RE: LPP/SSV Returned to Service on CPAI well 1C-190 - 01.15.2017 Jim, Please find responses to your enquiries below(in red). Kindly let me know if you have any additional questions. Thank you. Best regards, Michael Effiong (Alternate: Scott Stanley) APR 0 62017, West Sak Production Engineer SCANNED ConocoPhillips Alaska Inc. Office: 1 907 659-7234 Pager: 1 907 659-7000 pg. #497 Email: n1638conocophillips.com From: Regg,James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, February 03, 2017 9:33 AM To: NSK West Sak Prod Engr<n1638@conocophillips.com> Subject: [EXTERNAL]RE: LPP/SSV Returned to Service on CPAI well 1C-190-01.15.2017 Background: - LPS defeated 11/5/16 (notice included: "well head injection pressure is 3 psi at an injection rate of 790 BWPD") - Injection November through January 15: November(5 days); December(31 days);January (? Days) - LPS was reportedly restored to service on 1/15/17—notified AOGCC 2/2/17 Questions: - Well took 45 days to build pressure above 500psi Duration seems inordinate for past performance of this and other wells. Is there an explanation? o The well was shut-in for one month (Oct. 5—Nov. 5, 2016) during which time,two out of the three producers which it supports were online.This most likely contributed to the (localized) reduction in BHP of the normally pressured West Sak reservoir, resulting in the duration it took for the pressure to build up. - Why the delay in notifying AOGCC of its removal from the defeat log? o The delay in communicating this to you was a lapse in communication between the Drill Site Operator and our position. The Drill Site Operator was monitoring the injection pressure and when the injection pressure stabilized above the 500 psi LPP setting, the LPP was returned to service and the LPP was removed from the Safety Defeated Log properly. We have a process in place where we track the defeated pilots in our changeout notes and on the board in our office and we check the wellhead injection pressure every week or two to make sure that the pressure is still below the LPP setting and should rem ji.siefeated. Somehow the fact that the LPP was placed back in service was missed and not recognized or acted upon by our position. While investigating what happened today, we think we found a way to automate the internal communication using the Safety Defeat Log to notify our position and the Drill Site Lead Tech when a well is defeated due to low injection pressure and when it is returned to service to verifythat the proper notifications are made to the AOGCC. This should eliminate the breakdown in communication between the Drill Site Operator and our position and ensure that timely notifications are made to the AOGCC. 1 Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or iim.regg@alaska.gov. From: NSK West Sak Prod Engr [mailto:n1638@conocophillips.com] Sent:Thursday, February 02, 2017 9:07 PM To: Regg,JamesI3 (DOA) <jim.regg@alaska.gov> Cc: CPF1 DS Lead Techs<n1140@conocophillips.com>; CPF1 Ops Supv<n2067@conocophillips.com>; NSK Well Integrity Supv CPF1 and 2<n1617@conocophillips.com>; Sullivan, Michael <Michael.Sullivan@conocophillips.com>; NSK Prod Engr Specialist<n1139@conocophillips.com>; CPF1 Prod Engr<n1269@conocophillips.com>;Targac, Gary <Gary.Targac@conocophillips.com>; NSK Optimization Engr<n2046@conocophillips.com>; CPF1 DS Operators <n1275@conocophillips.com>; Krysinski, Marina L<Marina.L.Krysinski@conocophillips.com>; CPF1&2 Ops Supt <n2073@conocophillips.com> Subject: LPP/SSV Returned to Service on CPAI well 1C-190-01.15.2017 Jim, The low pressure pilot(LPP) on well 1C-190 (PTD#203-003)was returned to service and removed from the safety defeat log on 01/15/2017, after the stabilized and the wellhead injection pressure exceeded 500 psi. The well is currently injecting at approx. 1000 BWPD at a wellhead injection pressure of 595 psi. The LPP had originally been defeated on 11/05/2016. This notification is in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Best regards, Michael Effiong (Alternate: Scott Stanley) West Sak Production Engineer ConocoPhillips Alaska Inc. Office: 1 907 659-7234 Mobile: 1 713 632-4851 Pager: 1 907 659-7000 pg. #497 Email: n1638 p(�conocophillips.com 2 Kett 1c-1 D' • 3� Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.c m> Sent: Saturday, November 05, 2016 5:05 PM s((JDt kw To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; CPF1&2 Ops Supt; NSK Prod Engr Specialist; CPF1 Prod Engr; NSK Optimization Engr; CPF1 DS Operators; Targac, Gary; Sullivan, Michael; Krysinski, Marina L;Jensen, Marc D; Effiong, Michael Subject: The LPP/SSV for well 1C-190 was defeated on 11/05/2016 Jim, The low pressure pilot(LPP) on West Sak injector 1C-190 (PTD#203-003)was defeated today, 11/05/2016, after the well was brought online. The LPP and SSV have been tagged and their status is recorded in the"Facility Defeated Safety Device Log." The current well head injection pressure is 3 psi at an injection rate of 790 BWPD. The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Kind Regards, Scott Stanley / Michael Effiong West Sak Production Engineers SCANNED JUN o 82017, ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 n1638@conocophillips.com 1 • • Keck 1C- (? • Prb 'Z%3 CZ;3 Regg, James B (DOA) From: Sullivan, Michael <Michael.Sullivan@conocophillips.com> Sent: Monday, October 10, 2016 10:03 AM 1 /Di To: NSK West Sak Prod Engr; Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; CPF1&2 Ops Supt; NSK Prod Engr Specialist; CPF1 Prod Engr; Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Stanley, Scott M; Krysinski, Marina L Subject: LPP/SSV returned to service on well 1C-190 Jim, The low pressure pilot(LPP) on well 1C-190 (PTD#203-003)was returned to service and removed from the safety defeat log today, 10/5/2016, after the well was shut-in. The LPP had been defeated since 9/29/2016. This notification is in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Regards, Michael Sullivan Viscous Petroleum Engineer For the W. Sak Production Engineer ConocoPhillips Alaska 907-659-7234 sustap JUN 0 $2 Ci 7 1 • • .fit (c_ Av. 2)36v Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> �C\idHa Sent: Thursday, September 29, 2016 4:42 PM 1\ rt To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK • ••lem Well Supv; CPF1&2 Ops Supt; NSK Prod Engr Specialist; CPF1 Prod Engr; NSK Optimization Engr; CPF1 DS Operators; Targac, Gary; Sullivan, Michael; Krysinski, Marina L; Effiong, Michael; Haakinson, David Subject: The LPP/SSV for well 1C-190 was defeated on 9/29/2016 Jim, The low pressure pilot(LPP) on West Sak injector 1C-190 (PTD#203-003)was defeated today, 9/29/2016, after the well was brought online following an extended shut-in period. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The current well head injection pressure is 25 psi at an injection rate of 640 BWPD. The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Kind Regards, Scott Stanley / David Haakinson West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 n1638@conocophillips.com i RECEIV STATE OF ALASKA *OCT o 4 206 Ault OIL AND GAS CONSERVATION COMM ION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon r Plug Perforations r Fracture Stimulate IT Pull Tubing 6 Operations Shutdown I— P e r f o rm e d: Performed: Suspend IT Perforate r Other Stimulate IT Alter Casing r Change Approved Program[— Plug Plug for Redrill IT Perforate New Pool IT Repair Well IT Re-enter Susp Well IT Other: Crystal Seal Re-Trtmt 1.7" 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development IT Exploratory IT 203-003 3.Address: 6.API Number: Stratigraphic IT Service P. O. Box 100360,Anchorage,Alaska 99510 50-029-23136-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25649,ADL 25650 KRU 1C-190 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NONE Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 10466 feet Plugs(measured) None true vertical 3759 feet Junk(measured) None Effective Depth measured 10466 feet Packer(measured) 5299 true vertical 3759 feet (true vertical) 3833 Casing Length Size MD TVD Burst Collapse CONDUCTOR 82 16 110 110 SURFACE 5421 7 5/8 5449 3834 LINER SLOTTED 5179 4 1/2 10466 3759 Perforation depth: Measured depth: 5602-10401,8300-8305 SCANNED FEB 2 32017 True Vertical Depth: 3830-3760, 3795-3795 S4C�.iTt G Tubing(size,grade,MD,and ND) 4.5, L-80,5284 MD, 3833 TVD Packers&SSSV(type,MD,and ND) PACKER-ZAP LINER TOP PACKER @ 5299 MD and 3833 WE 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-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation - - Shut-in• - - Subsequent to operation - - 688 - 298 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: ,��✓' Daily Report of Well Operations F Exploratory r Development r Service Stratigraphic I', Copies of Logs and Surveys Run IT 16.Well Status after work: Oil IT Gas IT WDSPL [— Printed Printed and Electronic Fracture Stimulation Data IT GSTOR r WINJ F WAG IT GINJ r SUSP r SPLUG [- 17. 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: 316-383 Contact John Peirce @ 265-6471 Email John.W.Peirce©conocophillips.com Printed Name John Peirce Title Sr. Wells Engineer Signature A , Phone:265-6471 Date 1°14 d/ i( 11 6 .---,7‘ Vri- t 01121 L RBDMS (, OCT 10 2016 Form 10-404 Revised 5/2015 a a�.� /// Submit Original Only lib • 1C- 1 9 0 DTTMS JOBTYP SUMMARYOPS 9/21/16 MISC. PERFORM MBE TREATMENT DOWN COIL TUBING. PUMP 30 BBLS CAPACITY OF EQUISEAL GEL FOLLOWED BY 216 BBLS SEAWATER WITH 2200# SUSTAINMENT OF 1, 2, AND 4 MM CRYSTAL SEAL. NET PRESSURE INCREASE OF 1200 PSI. WELL LEFT SHUT IN AND FREEZE PROTECTED. WILL BE READY IN 3 DAYS FOR FLUFF AND STUFF. 9/28/16 MISC. PERFORM POST CRYSTAL SEAL FILL CLEANOUT FROM 5500' CTMD CAPACITY TO HARD TAG AT 8836' CTMD PUMPING SLICK SEAWATER AT 1.8 SUSTAINMENT BPM (EST, 530' OF RATHOLE) MAINTAINED 1:1 RETURNS THROUGHOUT CLEANOUT, MODERATE TO HEAVY CRYSTAL SEAL CONCENTRATIONS OBSERVED, F/P TBG TO 3500' CTMD, TURN WELL OVER TO DSO. JOB COMPLETE. KUP 1C-190 ConocoPhillips / 4 Well Attribute Max AngleWD TD Alaska.Inc, : Wellbore API/UWI Fold Name Wellbore Status (°) MD(ftKB) Act (ftKB) Conocomilhps•r500292313600 WEST SAK INJ Inc! Min 9,068.11 10,466.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 10-190,1(13/20163:01.59 PM SSSV:NIPPLE Last WO: 34.01 3/11/2003 Verticalschematic.(actual) - Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:ELMD 10,447.0 2/17/2004 Rev Reason:Crystal Seal Job,SEE NOTES pproven 5/4/2016 Casing Strings .........77r_.... . Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread HANGER,23.6-�. CONDUCTOR 16 15.062 28.0 110.0 110.0 62.50 H-40 WELDED C --as Casing Description OD 0n) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 75/8 6.875 28.0 5,449.0 3,834.4 29.70 L-80 BTC-MOD Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread ui r'LINER SLOTTED 4 1/2 3.958 5,287.5 10,466.0 3,758.6 12.60 L-80 NSCT Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 5,287.5 3,832.9 8727 SLEEVE BAKER TIE BACK SLEEVE 5.500 CONDUCTOR 28.0-110.o-4 to 5,298.63,833.4 87.79 PACKER ZXP LINER TOP PACKER 4.940 5,306.6 3,833.7 88.17 NIPPLE RS NIPPLE 4.000 5,309.4 3,833.8 88.30 HANGER FLEX LOCK II HYD HANGER 5.500 5,317.3 3,834.0 88.64 XO BUSHING XO BUSHING 4.500 m NIPPLE,515.0 10,431.3 3,759.3 91.29 BUSHING BAKER PACKOFF BUSHING 2.350 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)I...Wt(Iblft) Gratle Top Connection TUBING I 4 1/21 3.9581 23.61 5,295.91 3,833.31 12.601 L-80 I NSCT Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 23.6 23.6 0.00 HANGER VETCO GRAY HANGER 4.500 515.0 513.2 10.25 NIPPLE CAMCO DB NIPPLE w/3.875 NO GO PROFILE 3.875 4,470.3 3,612.8 62.45 NIPPLE CAMCO DB NIPPLE w/3.812 NO GO PROFILE 3.812 5,283.5 3,832.7 87.07 XO BUSHING BAKER XO BUSHING VAM 3.880 GAS LIFT,3,030.5 5,285.3 3,832.8 87.16 SEAL ASSY BAKER BULLET SEAL ASSEMBLY w/VAM BOX UP 4.860 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Inel iii Top(ftKB) MKS) rt Des Com Run Date ID(in) PATCH Surface casing patch from bottom of starter head. 4/21/2011 0.000 Installed 6'12"x65.500 carbon steel sleeve on surface casing. NIPPLE,4,470.3Di Perforations&Slots shot Top(ND) Atom(ND) Is shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 5,602.0 10,401.0 3,830.4 3,760.0 WS D,1C- 3/9/2003 99.0 SLOTS Alternating slotted/solid 190 pipe.3 BLANK JTS:1 SLOTTED JT 8,300.0 8,305.0 3,795.0 3,795.1 WS D,1C- 9/5/2015 6.0 (PERF 2in Powerflow HSD XO BUSHING,5,283.5 i 190 guns,2006FP,6SPF Mandrel Inserts St SEAL ASSY;5,285.3 - an (•' r. Top(ND) Valve Latch Port Size TRO Run N,1 Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com ��� "� 1 3,006.5 2,709.3 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 4/13/2003 Notes:General&Safety End Date Annotation 9/21/2015 NOTE:NET PRESSURE INCREASE OF 1000 PSI. 9/21/2015 NOTE:MBE TREATMENT DOWN COIL TUBING PUMP 261 BBLS OF 2.5%KCL WITH 2709#OF 4 MM i) if CRYSTAL SEAL 4/27/2016 NOTE:MBE TREATMENT DOWN COIL TUBING WITH NOZZLE PARKED ABOVE SLOTTED LINER AT 5600'. 4/27/2016 NOTE:PUMP 310 BBLS OF SEA WATER WITH 3135 8 OF 4 MM CRYSTAL SEAL. NET PRESSURE INCREASE OF 750 PSI SURFACE',28.0-5,449.0 -1 1- SLOTS;5,602 0-10,401.0 -1 r- (PERF;8,300.0-8,305.0 _ LINER SLOTTED;5,287.5- 10,466.0 OF 7'j • THE STATE Alaska Oil and Gas F:7„11%11 .7,4111 p fA L SKAL Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER g h Main: 907.279.1433 °P411:;:41‘1.- Fax: 907.276.7542 www.aogcc.alaska.gov t John Peirce p,` �''' Sr. Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1C-190 Permit to Drill Number: 203-003 Sundry Number: 316-383 Dear Mr. Peirce: 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, Cathy P. oerster Chair DATED this Z4 y of August, 2016. RBDMS (J- AUG - 2 2016 • STATE OF ALASKA 0 RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION JUL 2 5O1 APPLICATION FOR SUNDRY APPROVALS 07S 8i/ /C 20 AAC 25.280 AOGC 1.Type of Request: Abandon E Plug Perforations E Fracture Stimulate r Repair Well r Operations Shutdown r Suspend E Perforate r Other Stimulate r Pull Tubing IT Change Approved Program r Plug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing IT Other: Crystal Seal Re-Trtmt F 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory r Development IT 203-003 3.Address: 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service F 50-029-23136-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a Will planned perforations require a spacing exception? Yes r No F KRU 1C-190 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25649 ADL 25650 Kuparuk River Field/West Sak 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): 10,466' • 3,759' ' 10466 3759 • 1280 NONE NONE Casing Length Size MD ND Burst Collapse Conductor 82' 16" 110' 110' Surface 5,421' 7 5/8 5,449' 3,834' Intermediate Production Liner 5,179' 41/2 10,466' 3,759' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 5602-10401,8300-8305 ' 3830-3760,3795-3795 4.500" L-80 5,296' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-ZXP Liner Top Packer • 5299 MD and 3833 TVD SSSV: NONE 12.Attachments: Proposal Summary 2 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory IT Stratigraphic r Development IT Service F. 14.Estimated Date for 8/22/2016 15.Well Status after proposed work: Commencing Operations: OIL IT WINJ F ' WDSPL r Suspended r- 16. 16.Verbal Approval: Date: GAS IT WAG r GSTOR r SPLUG r Commission Representative: GINJ IT Op Shutdown r Abandoned I- 17. 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact John Peirce @ 265-6471 Email John.W.Peirceconocophillips.com Printed Name John Peirce Title Sr.Wells Engineer ,/,, __Kr- -- 7/2 /1, Signature Phone 265-6471 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: Post Initial Injection MIT Req'd? Yes ❑ No ( C:rjr-- V( 1 Spacing Exception Required? Yes ❑ No V. Subsequent Form Required: 16' '4"b APPROVED BY Approved by: /9 COMMISSIONER THE COMMISSION Date:i32- —1 �2( Rirel SubmitxolMand Form Re se i 1157- 1h IpNetAiLalid for 12 months from the date of approv f' 4 R vMSts in carU6 _ 2 2016 KUP P 1C-190 ConocoPhi lips (ef 4(f Well Attribu Max Angle•D TD • Alaskainc. t '` Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(MB) Act Btm(ftKB) Gxrocophillips'I 500292313600 WEST SAK INJ 94.98 9,068.11 10,466.0 • ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1C-190,7/25/2016 10 23:09 AM SSSV:NIPPLE Last WO: 34.01 3/11/2003 - Vertical schemabc(actual. 'Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag ELMD 10,447.0 2/17/2004 Rev Reason:Crystal Seal Job,SEE NOTES pproven 5/4/2016 Casing Strings am Description OD(in) ID(in) Top(ORB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread HANGER;23.6- CONDUCTOR 16 15.062 28.0 110.0 110.0 62.50 H-40 WELDED a Casing Description OD(in) ID(in) Top(ORB) Set Depth(ORB) Set Depth(TVD)...Wt/Len(I...Grade 'Top Thread Ijr SURFACE 7 5/8 6.875 28.0_ 5,449.0 3,834.4 29.70 L-80 BTC-MOD Damn CasDescription OD(in) ID(in) 'Top(ORB) Set Depth(ORB) Set Depth(ND)...WtlLen(I...Grade Top Thread ""`LINER SLOTTED 4 1/2 3.958 5,287.5 10,466.0 3758.6 12.60 L-80 NSCT Liner Details Nominal ID Top(RKB) Top IND)(RKB) Top Incl(°) Item Des Com (in) +�h `s, 5,287.5 3,832.9 87.27 SLEEVE BAKER TIE BACK SLEEVE 5.500 CONDUCTOR 28.0-110.0 ( 5298.6 3,833.4 87.79 PACKER ZXP LINER TOP PACKER 4.940 5,306.6 3,833.7 88.17 NIPPLE RS NIPPLE 4.000 5,309.4 3,833.8 88.30 HANGER FLEX LOCK II HYD HANGER 5.500 5,317.3 3,834.0' 88.64 XO BUSHING XO BUSHING 4.500 NIPPLE:515.0 'R(t 10,4313 3,759.3 91.29 BUSHING BAKER PACKOFF BUSHING 2.350 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..I Set Depth(ND)(...Wt(IbRt) Grade Top Connection TUBING 41/2 3.958 23.6 5,295.9 3,833.3 12.60 L-80 NSCT Completion Details Nominal ID Top(R(B) Top(TVD)(ftKB) Top Incl r) Item Des Com (in) 23.6' 23.6 0.00 HANGER VETCO GRAY HANGER 4.500 515.0' 513.2 1025 NIPPLE 'CAMCO DB NIPPLE w/3.875 NO GO PROFILE 3.875 4,470.3 3,612.8 62.45 NIPPLE 'CAMCO DB NIPPLE w/3.812 NO GO PROFILE 3.812 ` 5,283.5 3,832.7 87:07 XO BUSHING BAKER XO BUSHING VAM 3.880 a;ar GAS LIFT;3,006.5 _.i 5,285.3 3,832.8 87.16 SEAL ASSY BAKER BULLET SEAL ASSEMBLY WI VAM BOX UP 4.860 !`l '.' Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(MB) (ftKB) I°I Des Com Run Date ID(in) PATCH Surface casing patch from bottom of starter head. 4/21/2011 0.000 Installed 6'12"x65.500 carbon steel sleeve on surface casing. NIPPLE:4,470.3 }-.' Perforations&Slots t: < • I Shot Dens Top(ND) Btm(ND) (shoal Top(ftKB) Btm(ftKB) (ftKB) (ORB) Zone Date ft) Type Com 5,602.0 10,401.0 3,830.4 3,760.0 WS D,1C- 3/9/2003 99.0 SLOTS Alternating slotted/solid 190 pipe.3 BLANK JTS:1 SLOTTED JT 8,300.0 8,305.0 3,795.0 3,795.1 WS D,1C- 9/5/2015 6.0 (PERF tin Powerflow HSD XO BUSHING;5,283.5 190 guns,2006FP,6SPF Mandrel Inserts St SEAL ASSY;5,285.3 an N Top(ND) Valve Latch Port Size TRO Run 'ltl\I N N Top(ftKB) (RKCorn B) Make Model OD(in) Sery Type Type (in) (psi) Run Date __ 1 3,006.5 2,709.3 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 4/13/2003 Notes:General&Safety liiiik End Date Annotation 9/21/2015 NOTE:NET PRESSURE INCREASE OF 1000 PSI. r, .. - r' 9/21/2015 NOTE:MBE TREATMENT DOWN COIL TUBING PUMP 261 BBLS OF 2.5%KCL WITH 2709#OF 4 MM 1] [ CRYSTAL SEAL li a� 4/27/2016 NOTE:MBE TREATMENT DOWN COIL TUBING WITH NOZZLE PARKED ABOVE SLOTTED LINER AT 5600'. 4/27/2016 NOTE:PUMP 310 BBLS OF SEA WATER WITH 3135#OF 4 MM CRYSTAL SEAL. NET PRESSURE INCREASE OF 750 PSI SURFACE;28.0-5,449.0-� Z1 SLOTS;5,832.410,300 !PERE;8,300.0-8,305.8,0 1 r . 1 • • ., ; LINER SLOTTED;5,287.5- Le I 10,486.0 • 110 Ringing Gel & Crystal Seal Retreatment of `D' Sand MBE from 1C-190 to 1C-184 A Matrix Bypass Event (MBE) occurred 1/16/15 from 1C-190 injector to offset 10-184 producer in the D sand. A 4/27/15 IPROF found the MBE at —8300' RKB. On 9/5/15, perfs were shot at 8300 - 8305' RKB. On 9/21/15, a CT Crystal Seal job pumped 2709 lbs Crystal Seal to D MBE. On 10/1/15, 1C-190 returned to PWI for —5 months. On 1/13/16, a CT FCO was done to lockup at 9375', but then WHIP fell from 1000 psi (220 BWPD) to 120 psi (600 BWPD), and 1C-184 went from near 0% to 90% WC. On 2/6/16, 1C-190 was SI per evidence of a re-opened D MBE. Thus, on 4/27/16 a Crystal Seal retreatment was pumped down CT that placed 3135 lbs of Crystal Seal to the MBE at —8300' RKB. This treatment only lasted for a couple months before the MBE treatment broke down again. It is proposed that a third CT Crystal Seal Retreat be pumped to the D MBE at —8300' RKB. 1C-190 is configured for the retreatment. Job design will now include a `lead' stage of 20 bbls `ringing' Gel, followed by the Crystal Seal Slurry pumping. A post-Crystal Seal CT Fluff& Stuff will be performed to remove excess Gel and Crystal Seal from the liner, then 1C-190 will be returned to PWI. A post-job IPROF will eventually be performed to verify that the D MBE was sealed. Proposed Coil Tubing Procedure 1) MIRU CTU. RIH with a down port nozzle displacing 1 CT volume (-45 bbls) of Diesel FP from the CT to the tubing with 45 bbls Seawater pumped at 0.75 bpm down CT. Park nozzle at 7200' RKB to keep the nozzle 1100' above the MBE at —8300' RKB. During the 9/21/15 Crystal Seal treatment, CT had high PU weights below 7200'RKB that could have been caused by Crystal Seal crossflow &/or differential sticking behind CT at 8300' up to 7200' RKB to a thief zone. CT will be kept < 7200'RKB to avoid x-flow area and any potential heavy PU weights. When the nozzle is parked at 7200' RKB, start pumping Diesel down the CT x Tbg annulus at 0.4 bpm to keep CT backside flushed. Also pump 20 bbls of 'lead' liquid Gelant at 2 - 3 bpm from the nozzle while the nozzle is parked at 7200' RKB until Crystal Seal slurry reaches the nozzle. The Gelant stage will cure within 72 hours to form ringing Gel in the MBE after treatment. The Crystal Seal slurry stage will be blended `on-the-fly' at 0.25 ppg of Crystal Seal mixed into Seawater. Either a 1, 2, 4 mm mesh, or a '4 mm only' mesh Crystal Seal product will be used. When Crystal Seal slurry reaches the nozzle, continue Diesel at —0.4 bpm down CT x Tbg annulus, and start POOH with CT at 50 - 100 fpm while pumping Crystal Seal slurry from nozzle at 2 - 3 bpm. When nozzle reaches `safety' (above all slots at 5600' RKB), park nozzle at 5600' RKB and continue pumping Crystal Seal slurry until Flush is called. Maintain constant pump rate to monitor treating pressure on CT x Tbg annulus at wellhead. When WHP reaches 800 psi, call Flush consisting of a couple barrels of Seawater spacer, followed by Diesel down CT. After all Crystal Seal has exited the nozzle, halt all Diesel pumping down CT x Tbg annulus and SI the CT x Tbg annulus, then POOH from 5600' RKB while replacing voidage with Diesel. RD CTU. Wait at least 72 hours to let the Gelent `cure', and to let the Crystal Seal fully swell in the MBE before returning 10-190 to PWI. 2) RIH with jet swirl nozzle and tag top of Crystal Seal, then jet through Crystal Seal to Fluff & Stuff to deep as possible injecting away Crystal Seal from liner. Avoid taking any returns from the well. On occasion, near wellbore drawdown acting on a treated MBE has been noted to compromise treatment integrity by causing Crystal Seal slurry return flow back into the liner with sand. POOH w/CT. RD CT. Return 1C-190 to PWI service and monitor the offset producer 1C-184 watercut response. (Y) O c6 • 0 c O) 1� V r 1n 1v ^1 Q W � a) > 3 cosi Z ° QQ � n ONwv v J CO .y..,.N a) t -C C O F Y O as I- T I G r. Oa u_ V % O., n a C CD o p - "D w H 0 ro � `° r?o Q < Q J W CO 10 CO CO 10 f0 CO w C v N CO O Q (.7 .- ,_ . . . . . to y u J y y vJi J 0 T C C C C C C 7 a) C +-+ E (0 a a) V1 I-- N N 4 t0 N- 00 O N N L C 'C > aJ _CU Lit• Q 0 O -O E O >, Q V N a) U 4-+ I— 0 0) +--' (0 C 0 0 0 0 0 0 0 0 0 a a 5 i a d J J J J J J J J J } W W W W W W W W W OCa O (0 8;:r .-y I . LL LL U.. U. LL LL U.. U.. LI- 0 Q) E O Q J J J J J J J J J Q 0 cCo v I- Q Q Q Q Q Q Q Q Q C = 0) Q Z Z Z Z Z Z Z Z Z v v, a O) CI LL LL LL LL LL LL LL LL al . 0 a) f= a C } Y > Y U J W 6 _ E aJ a) C O p Cr' z .., a v c -0 VlI. O C O _0a 0 P. nr) v a) y RI 7. 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N N N N N N N N N _C- 1.`.' n Q 0) 0) 0) M O M O O O E O d NNN ON 0 NNN = O 0 0 0 O O O O CU O O O O O O O O O co O te0 u) 1n 1n O 1n 1n u) 1n u) 4-• 0 0 Q� w ,CO � y o E e, E v m o v aa W � 0 w Ir U.,' ,7 t> �+ Q O 0 0 0 , Ti 41 •C CO O 6J r-1 Q 'a N 0 r O O O O a+ C w rz ' �0 m Z M E a, • w = 2 L n -1 m 5 X Y a J (7 p L4 a w m 2 a Q N J - M N N N N E Z y -6 iyJ C .a w +-' @ fo `7 r-1 U ^ to Ca) 0 U K'C{1 cc—(t 0 • • PT-6 2430030 Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Sunday, June 05, 2016 4:12 PM � 6/6l(t, To: Regg,James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; CPF1&2 Ops Supt; Sullivan, Michael; NSK Prod Engr Specialist; CPF1 Prod Engr;Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Braden, John C; Haakinson, David; Stanley, Scott M Subject: LPP/SSV returned to service on well 1C-190 Jim, The low pressure pilot(LPP) on well 1C-190 (PTD#203-003)was returned to service and removed from the safety defeat log today, 6/5/2016, after the well was shut-in. The LPP had been defeated since 5/9/2016. This notification is in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Regards, Tyler Hall / David Haakinson West Sak Production Engineers salon JUN 1 6 2016 ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 n1638@conocophillips.com i STATE OF ALASKA ALOKA OIL AND GAS CONSERVATION COM I ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon i— Plug Perforations - Fracture Stimulate E Pull Tubing E Operations Shutdown fl Performed: Suspend I— Perforate P Other Stimulate I— Alter Casing P Change Approved Program P Plug for Redrill 1..... Perforate New Pool I....... Repair Well F Re-enter Susp Well P Other:Crystal Seal MBE Trmnt 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory 203-003 3.Address: 6.API Number Stratigraphic r Service I✓ P. O. Box 100360,Anchorage,Alaska 99510 50-029-23136-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25649,ADL 25650 KRU 1C-190 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): NONE Kuparuk River Field/Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 10466 feet Plugs(measured) None true vertical 3759 feet Junk(measured) None Effective Depth measured 10466 feet Packer(measured) 5299 true vertical 3759 feet (true vertical) 3833 Casing Length Size MD TVD Burst Collapse CONDUCTOR 82 16 110 110 SURFACE 5421 7.625 5449 3834 LINER SLOTTED 5179 4 1/2 10466 3759 C/44*1) JU1i1 GA Perforation depth: Measured depth: 5602- 10401, 8300-8305 s, LEc True Vertical Depth: 3830-3760, 3795-3795 M ED MAY 10 2016 Tubing(size,grade,MD,and TVD) 4.5, L-80, 5284 MD, 3833 TVD i0G Vti✓ Packers&SSSV(type,MD,and TVD) PACKER-ZXP LINER TOP PACKER @ 5299 MD AND 3833 TVD SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): n/a Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut-in Subsequent to operation Shur-in 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 4 Exploratory I— Development r Service Fi Stratigraphic Copies of Logs and Surveys Run fl 16.Well Status after work: Oil P Gas P WDSPL 1--- Printed Printed and Electronic Fracture Stimulation Data P GSTOR WINJ 1✓ WAG I— GINJ P SUSP SPLUG 1- 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: 316-190 Contact John Peirce (a 265-6471 Email John.W.Peirce@conocophillips.com Printed Name John Peirce Title Sr. Wells Engineer Signature j� Phone:265 6471 Date �� J f 7 _ ,c_ .,,'T� 5%ro//b Form 10-404 Revised 5/2015si ,//U//,6. RBDMS IN MO 1 0 2016 Submit Original Only • • 1 C-190 DTTM JOBTYP SUMMARYOPS START 4/27/16 FCO B&C CTU #1: PERFORM MBE TREATMENT DOWN COIL TUBING WITH NOZZLE PARKED ABOVE SLOTTED LINER AT 5600'. PUMP 310 BBLS OF SEA WATER WITH 3135#OF 4 MM CRYSTAL SEAL. NET PRESSURE INCREASE OF 750 PSI. WELL LEFT SHUT IN AND FREEZE PROTECTED. WILL RETURN IN TWO DAYS FOR FCO. 5/2/16 MISC. B&C CTU #1: PERFORM F&S FILL CLEAN OUT FROM CAPACITY CRYSTAL SEAL TAG AT 6553' TO COIL LOCKUP AT 9046' WITH SUSTAINMENT SLICK SEA WATER AND DJN. WELL LEFT SHUT IN AND FREEZE PROTECTED. TREATMENT COMPLETE. \ KUP I di 1C-190 ConocoPhiQips w Well Attribut Max AngleWD TD I Alaska.,Inc, . Wellbore APIIUWI Field Name Wellbore Status Inc'1^) MD(ftKB) Act Btm(ftKB) ,g,,''' 500292313600 WEST SAK INJ 94.98 9,068.11 10,466-0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(k) Rig Release Date 1C-190,514/20161113.23 AM SSSV:NIPPLE Last WO 34.01 3/11/2003 Verora(schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:ELMD 10,447.0 2/17/2004 Rev Reason:Crystal Seal Job,SEE NOTES pproven 5/4/2016 HANGER;23.67, Casing Strings �in 1 Casing Description OD lin) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread 4s'11■�Jiri CONDUCTOR 16 15.062 28.0 110.0 110.0 62.50 H-40 WELDED #jCasing Description OD(in) ID lin) Top(ftKB) Set Depth(ftKB) 'Set Depth(ND)...WtlLen p...Grade Top Thread -.SURFACE 7 5/8 6.875 28.0 5,449.0 3,834.4 29.70 L-80 BTC-MOD Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread LINER SLOTTED 41/2 3.958 5,287.5 10,466.0 3,758.6 12.60 L-80 NSCT Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl P) Item Des Com (in) CONDUCTOR;280-110.0 5,287.5 3,832.9 87.27 SLEEVE BAKER TIE BACK SLEEVE 5.500 5,298.6 3,833.4 87.79 PACKER ZXP LINER TOP PACKER 4.940 II 5,306.6 3,833.7 88.17 NIPPLE RS NIPPLE 4.000 5,309.4 3,833.8 88.30 HANGER FLEX LOCK II HYD HANGER 5.500 NIPPLE;515.05,317.3 3,834.0 88.64 XO BUSHING XO BUSHING 4.500 10,431.3 3,759.3 91.29 BUSHING BAKER PACKOFF FIUSHING 2.350 :ftTubing Strings I. Tubing Description String Me... ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)I...Wt(Ibttt) Grade Top Connection TUBING I 41/2, 3.9581 2361 5,295.91 3,833.31 12.601 L-80 NSCT Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 23.6 23.6 0.00 HANGER VETCO GRAY HANGER 4.500 515.0 513.2 10.25 NIPPLE 'CAMCO DB NIPPLE w/3.875 NO GO PROFILE 3.875 4,470.3 3,612.8 62.45 NIPPLE CAMCO DB NIPPLE w/3.812 NO GO PROFILE 3.812 GAS UFT 3,006 5 5,283.5 3,832.7 87.07 XO BUSHING BAKER XO BUSHING VAM 3.880 • 5,285.3 3,832.8 87.16 SEAL ASSY BAKER BULLET SEAL ASSEMBLY w/VAM BOX UP 4.860 17 I. Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top incl Top(ftKB) (ftKB) Topp)Ind Des Com Run Date ID(in) PATCH Surface casing patch from bottom of starter head. 4/21/2011 0.000 Installed 6'12"x65.500 carbon steel sleeve on NIPPLE;4,470.3 m surface casing. Perforations&Slots 11 Shot I Dens Top(ND) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com it 5,602.0 10,401.0 3,830.4 3,760.0 WS D,1C- 3/9/2003 99.0 SLOTS Alternating slotted/solid 190 pipe.3 BLANK JTS:1 igl SLOTTED JT X0 BUSHING;5,263,5 8,300.0 8,305.0 3,795.0 3,795.1 WS D,1C- 9/5/2015 6.0 IPERF 2in Powerflow HSD 190 guns,2006FP,6SPF Mandrel Inserts SEAL ASSY;5,285.3 N ,- St P.Viati s MOW on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD lin) Sery Type Type (in) (psi) Run Date Com 1 3,006.5 2,709.3 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 4/13/2003 Tr; Notes:General&Safety End Date Annotation 9/21/2015 NOTE:NET PRESSURE INCREASE OF 1000 PSI. am V YO 9/21/2015 NOTE:MBE TREATMENT DOWN COIL TUBING PUMP 261 BBLS OF 2.5%KCL WITH 2709#OF 4 MM 11 4 CRYSTAL SEAL 4/27/2016 NOTE:MBE TREATMENT DOWN COIL TUBING WITH NOZZLE PARKED ABOVE SLOTTED LINER AT 5600'. 4/27/2016 NOTE:PUMP 310 BBLS OF SEA WATER WITH 3135#OF 4 MM CRYSTAL SEAL.NET PRESSURE INCREASE OF 750 PSI SURFACE,25.05,449.0 6- SLOTS, SLOTS,5,6020-10,401.0 IPERF;8,300 0-8,305.0 LINER SLOTTED;5,287.516 - 10,486.0 26;oast) Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Monday, May 09, 2016 8:50 PM /pi To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; CPF1&2 Ops Supt; Sullivan, Michael; NSK Prod Engr Specialist; CPF1 Prod Engr; Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Sullivan, Michael Subject: Defeated LPP/SSV on well 1C-190 Jim, The low pressure pilot (LPP) on well 1C-190 (PTD#203-003) was defeated today, 5/9/16, after the well was brought online after a shut-in period . The well is currently stabilizing at a wellhead injection pressure of 222 psi and rate at 450 BWPD. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 PSIG and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Regards, Tyler Hall / David Haakinson West Sak Production Engineers Cono oPhillips Alaska, Inc. Office\(907) 659-7234 Pager: (907) 659-7000 #497 n1638@conocophillips.com SCANNED SEP. 2 6 2016 1 • OF ? • • 77; THE STATE Alaska Oil and Gas 7 of Conservation Commission ALASIc:A 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS 0' Fax: 907.276.7542 www.aogcc.alaska.gov John Peirce Sr. Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1C-190 Permit to Drill Number: 203-003 Sundry Number: 316-190 Dear Mr. Peirce: 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, Cathy P. Foerster Chair DATED this /d day of March, 2016. RBDMS W MAR 2 1 2016 RECEIVED • STATE OF ALASKA • MAR 14 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION G 10446. APPLICATION FOR SUNDRY APPROVALS 1GCC 20 AAC 25.280 1.Type of Request: Abandon fl Plug Perforations IT Fracture Stimulate ...... Repair Well 1 Operations Shutdown 1....... Suspend Perforate Other Stimulate n Pull Tubing I Change Approved Program I_._ Plug for Redrill r Perforate New Pool 1— Re-enter Susp Well E Alter Casing 1— Other: Crystal Seal MBE Trmnt 1.7• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. , Exploratory Development ..... 203-003 ' 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Services ' 50-029-23136-00 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a KRU 1C-190 • Will planned perforations require a spacing exception? Yes No 9. Property Designation(Lease Number): 10.Field/Pool(s): ADL 25649, ADL 25650 - Kuparuk River Field/West Sak Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: EffectivectDepth TXD: MPSP(psi): Plugs(MD): Junk(MD): 10,466' 3,759' 10,466' 3,659' 316h-T S�•4 1473 none Casing Length Size MD TVD Burst Collapse Structural Conductor 82' 16" 110' 110' Surface 5,421' 7.625 5,449' 3,834' Intermediate Production Liner 5,179' 5" 10,466' 3,759' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 5602-10401,8300-8305 3830-3760,3795-3795 4.500" L-80 5,296' Packers and SSSV Type: PACKER-ZXP Liner Top Packer Packers and SSSV MD(ft)and TVD(ft): 5299 MD,3833 TVD SSSV :NONE 12.Attachments: Proposal Summary 0 Wellbore schematic El 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory 1 Stratigraphic r Development Service C 14. Estimated Date for 15.Well Status after proposed work: Commencing Operations: O3Va9'POi ro OIL E WINJ '✓ . WDSPL r Suspended r 16.Verbal Approval: Date: GAS F WAG l_ GSTOR E SPLUG 1-- Commission Representative: GINJ 1 Op Shutdown Abandoned r-- 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact John Peirce Email John.W.Peirce@conocophillips.com Printed Name John Peirce @ 265-6471 Title Sr.Wells Engineer ,/4:4,,- 3/.ill-j 1 :', Signature ,{ ----._ Phone 265-6471 Date ,s COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 6 \ Liz - `6\O Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No n Spacing Exception Required? A 1�� q p g p q Yes ❑ Nod Subsequent Form Required: /0,�T�� RBDMS 1/V !Y'h.� � � 201 APPROVED BY Approved by: I ArtSSIONER THE COMMISSION Date:3 (/6—‘C a^TSi thmif ri Form 10-403 evise 11/2015 A p o e applicatio is valid for 12 m nth from the date of approval. Attachments in Duplicate U t, 3/t 6/!4 ?c 31i(t/1s. , 277i( 6 • • Crystal Seal Retreatment of 1C-190 to 1C-184 'D' Sand MBE A Matrix Bypass Event (MBE) occurred 1/16/15 from 1C-190 injector to offset 1C-184 producer in the D sand, resulting in 1C-190 shut-in. A 4/27/15 (PROF found the MBE at —8300' RKB behind slotted liner. On 9/5/15, large hole perfs were shot at 6 spf at 8300 - 8305' RKB. On 9/21/15, a CT Crystal Seal treatment pumped 2709 lbs Crystal Seal to D MBE. On 10/1/15, 1C-190 returned to PWI and remained on PWI fulltime for —5 months. On 1/13/16, a CT FCO was performed to lockup at 9375'. Shortly after FCO, 1C-190 WHIP fell from 1000 psi (220 BWPD) to 120 psi (600 BWPD), and 1C-184 went from near 0% to —90% WC. On 2/6/16, PWI was SI per this evidence of a re-opened D MBE. / It is proposed that a CT Crystal Seal Retreatment be pumped to the D MBE at —8300' RKB. 1C-190 is configured and ready as-is for the retreatment. A post-Crystal Seal CT Fluff & Stuff will be performed to remove excess Crystal Seal from the liner, then 1C-190 will then be returned to PWI. A post- Crystal Seal IPROF will eventually be performed to verify that the D MBE is completely sealed. Coil Tubing Procedure: 1) RIH with a down port nozzle on CT. Park the nozzle at 7200' RKB. Keeping the nozzle 1100' above the perfs at 8300 - 8305' RKB, is to reduce very high PU weight (experienced below 7200' RKB during the 9/21/15 Crystal Seal MBE treatment due to swelling slurry believed crossflowing behind CT to shallower thief sand while POOH). Pump a Crystal Seal treatment as follows: a) Pump —10 bbl SRIT with Seawater down CT. Select a steady treatment rate (target 2 - 2.5 bpm) to be held constant during treatment through Flush (step f) to monitor MBE response to treatment and watch for possible Crystal Seal screenout developing during slurry pumping. Pump Winter Seawater (or 2% KCL for making Crystal Seal slurry). Continue pumping steps b through e with very rapid ramping to the maximum slurry concentration (step e) before a total of 10 bbls Slurry has is pumped: b) Seawater with 0.05 ppg Crystal Seal (use 4 mm mesh crystals for all stages b through e) down CT. When called, go to c) Seawater w/0.10 ppg Crystal Seal down CT. When called, go to d) Seawater w/0.15 ppg Crystal Seal down CT. When called, go to e) Seawater with 0.20—0.25 ppg Crystal Seal down CT. Then, f) If screen out is seen, pump 1 CT volume Seawater Flush to displace remaining Crystal Seal Slurry from CT to well while POOH and pumping 0.5 bpm Seawater down CT backside to help mitigate Crystal Seal stacking behind CT and reduce excessive PU weight. If screen out is not seen and Flush is called, maintain at least 0.3 bpm Seawater down CT backside to keep Crystal Seal flushed from CT backside. Pump 1 full CT volume of Seawater to displace remaining Crystal Seal Slurry from CT to liner while POOH, then swap to Diesel FP down CT, followed by 1 CT volume of Diesel to FP CT & displace Diesel FP to tubing, followed by SD. RD CTU. Wait 24 hours to let Crystal Seal swell and seal the MBE before returning 1C-190 to PWI. 2) RIH with jet swirl nozzle and tag top of Crystal Seal, then jet down through Crystal Seal performing a Fluff & Stuff to deep as possible to mechanically break Crystal Seal left in liner. POOH w/CT. RD. Return 1C-190 to PWI service. 3) RIH with IPROF BHA to memory log down and up passes. Wait 2 hours. Log cool back pass. POOH with CT. RD CTU. Aq KUP I- 1C-190 COnf1Ct3phiii1 15Well Attribute Max Angle a TD Wellbore APUUWI Field Name • Wellbore Status Inc!(°) MD(ftKB) Act Btm(ftKB) c FUaskt`Inc< C.orloccPlliBips 500292313600 WEST SAK INJ 94.98 9,068.11 10,466.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1C-196 3/11/201614157 PM SSSV NIPPLE Last WO: 34.01 3/11/2003 Vesical schematic.*Wan Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:ELMD 10,447.0 2/17/2004 Rev Reason:PERFORATIONS lehallf 9/7/2015 HANGER;23.8 elfil710114 Casing StringsMk-AI Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread L`■ Ill CONDUCTOR 16 15.062 28.0 110.0 110.0 62.50 H-40 WELDED lftTCasing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I.. Grade Top Thread SURFACE 7 5/8 6.875 28.0 5,449.0 3,834.4 29.70 L-80 BTC-MOD Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I.. Grade Top Thread • LINER SLOTTED 4 1/2 3.958 5,287.5 10,466.0 3,758.6 12.60 L-80 NSCT Liner Details Nominal ID E Top(ftKB) Top(TVD)(ftKB) Top Incl(") Item Des Com (In) CONDUCTOR,280-110A 5,287.5 3,832.9- 8727 SLEEVE BAKER TIE BACK SLEEVE 5.500 5,298.6 3,833.4 87.79 PACKER ZXP LINER TOP PACKER 4.940 5,306.6 3,833.7 88.17 NIPPLE RS NIPPLE 4.000 vi ii 5,309.4 3,833.8 88.30 HANGER FLEX LOCK II HYD HANGER 5.500 NIPPLE,515.0 5,317.3 3,834.0 88.64 XO BUSHING XO BUSHING 4.500 11 10,431.3 3,759.3 91.29 BUSHING BAKER PACKOFF BUSHING 2.350 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(k..Set Depth(ND))...Wt(Iblft) Grade Top Connection TUBING I 41121 3.9581 23.61 5,295.91 3,833.31 12601 L-80 INSCT Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Mel 0) Item Des Com (in) 0.00 • 11 li 513.2 10.25 NIPPLE CAMCO DB NIPPLE w/3.875 NO GO PROFILE 3.875 GAS LIFT 3006.5 23.6 3,612.8 62.45 NIPPLE CAMCO•' NO GO PROFILE 5,283.5 3,832.7 87.07 XO BUSHING BAKER X0 BUSHING VAM 3 812 :1 t5,285 3 3,832 8 87 16 SEAL ASSY BAKER BULLET SEAL ASSEMBLY w/VAM BOX UP 4 860 g Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Inc' PATCH Surface casing patch from bottom of starter head. 4/21/2011 r 0.000 Installed 6'12"x65.500 carbon steel sleeve on NIPPLE;4,470.3 surface casing Perforations&Slots Shot Dens Top(ND) Btm(TVD) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 5,602.0 10,401.0 3,830.4 3,760.0 WS D,1C- 3/9/2003 99.0 SLOTS Alternating slotted/solid 190 pipe.3 BLANK JTS:1 SLOTTED JT XO BUSHING,5,283.5 8.300.0 8,305.0 3,795.0 3,795.1 WS D,1C- 9/5/2015 6.0 IPERF 2in Powerflow HSD 190 guns,2006FP,6SPF Mandrel Inserts SEAL ASSY,5,285.3 SSt Oftall t\ I/1 N Top(ND) Valve Latch Pert Size TRO Run MIMINIMIIMIN Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn ,a 1' 3,006.5 2,709.3 CAMCO IKBG-2 1 GAS LIFT DMY BK 0.000 0.0 4/13/2003 li 11 1 SURFACE',28.0-5,449.0 '- SLOTS,5,602.0-10,401.0 IPERF;8,300.0-8,305.0 LINER SLOTTED;5,287.5- k L 10,466.0 Regg, James B (DOA) 05C) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Saturday, February 06, 2016 4:58 PM (efl' 6()(o To: Regg,James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; CPF1&2 Ops Supt; Sullivan, Michael;Jensen, Marc D; NSK Prod Engr Specialist; CPF1 Prod Engr;Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Braden,John C; Haakinson, David; Stanley, Scott M; NSK West Sak Prod Engr Subject: LPP/SSV returned to service for well 1C-190 on 2/6/2016 Jim: The low pressure pilot(LPP) on well 1C-190 (PTD#203-003)was returned to service and removed from the safety defeat log today, February 6th, 2016, after the well was shut-in after the inability to build to a desired wellhead pressure. The pilot had been defeated since January 14th, 2016. This notification is in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Regards, David Haakinson / Tyler Hall West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 SCANNED t ;' r c) n1638@conocophillips.com 1 • t t(-IcfCJ P Lcu:.;c v36. Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Thursday,January 14, 2016 12:40 PM 4��°� 41 IP To: Regg,James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; CPF1&2 Ops Supt; Sullivan, Michael;Jensen, Marc D; NSK Prod Engr Specialist; CPF1 Prod Engr;Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Nenahlo, Thomas L; Braden,John C; Haakinson, David; Stanley, Scott M Subject: Defeated LPP/SSV on well 1C-190 Jim: The low pressure pilot(LPP) on well C-190 (PTD#203-003 as defeated on January 14th, 2016 when the well was brought online after a clean out following along term Sftu n period. The well is currently building surface pressure from an initial wellhead injection pressure of 40 psi. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the"Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 PSIG and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Kind Regards, SCANNED Tyler Hall / David Haakinson J Y, West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 n1638@conocophillips.com 1 STATE OF ALASKA ALADA OIL AND GAS CONSERVATION COMII.ION REPORT OF SUNDRY WELL OPERATIONS 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 r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well rgr.Re-enter Susp Well rOther:Crystal Seal MBE 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 203-003 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-23136-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25649,25650 KRU 1C-190 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 10466 feet Plugs(measured) none true vertical 3759 feet Junk(measured) none Effective Depth measured 10466 feet Packer(measured) 5299 true vertical 3759 feet (true vertical) 3833 Casing Length Size MD ND Burst Collapse CONDUCTOR 82 16 110 110 SURFACE 5421 7.625 5449 3834 LINER SLOTTED 5179 4.5 10466 3759 RECEIVED OCT I5 2015 Perforation depth: Measured depth: slots from 5602-10401, perfs 8300-8305' AOGCC True Vertical Depth: slots from 3830-3760, perfs 3795-3795' SCANNED N O V 2 3 2015 Tubing(size,grade,MD,and ND) 4.5, L-80, 5296 MD,3833 TVD Packers&SSSV(type,MD,and TVD) PACKER-ZXP LINER TOP PACKER @ 5299 MD,3833 TVD NIPPLE-CAMCO DB NIPPLE w/3.875 NO GO PROFILE @ 515 MD and 513 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation _ 411 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Fr. Exploratory r Development r Service FO1 Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Bectronic Fracture Stimulation Data r GSTOR r WINJ J 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: 315-085 Contact John Peirce('a) 265-6471 Email John.W.Peirce(ct�conocophillips.com Printed Name John Peirce Title Sr. Wells Engineer Signature d4 r Phone:265-6471 Date /Q /1 s as.X15 204,/c RBDMS)LOCT 212015 Form 10-404 Revised 5/2015 Submit Original Only 1C-190 Crystal Seal Treatment • DATE SUMMARY 8/5/2015 TRACTORED 3 3/8" PERF GUN WITH 3 3/38"TRACTOR TO 8030'. UNABLE TO GET DEEPER. POOH AND SWITCH TO 2: PERF GUN WITH 2 1/8"TRACTOR. UNABLE TO GET PAST 8100'. READY FOR COIL. 8/6/2015 PUMP 50 BBL OF DIESEL DOWN TBG AND 5 BBL DIESEL DOWN FLOW LINE JOB COMPLETE 9/4/2015 Late start after completion of cutting coil tubing and finish rigging down @ 1J. Perform Fluff n' Stuff with SSW w/Safe Lube down to 9,343' RKB before stacking out.. Well freeze protected and ready for TCP in morning. ****Job in Progress**** 9/5/2015 Peforate MBE interval from 8,300'to 8,305' RKB with SLB 2 inch Powerflow HSD guns (2006FP -6SPF, EHD 0.45", 4.5" PEN). Verified ASF. Well freeze protected and shut in. Ready for CrystalSeal treatment. ***Job in Progress*** 9/21/2015 B&C CTU #1: PERFORM MBE TREATMENT DOWN COIL TUBING PER DESIGN. PUMP 261 BBLS OF 2.5% KCL WITH 2709#OF 4 MM CRYSTAL SEAL. NET PRESSURE INCREASE OF 1000 PSI. TREATMENT DISPLACED INTO MBE WITH 40 BBLS SW AND 46 BLS DIESEL FOR FREEZE PROTECT. WELL TO BE LEFT SHUT IN UNTIL MINIMUM OF 24 HOURS. 9/30/2015 INJ. TEST PUMP 30 BBL DIESEL JOB COMPLETE KUP INJ • 1C-190 ConocoPhillips ; Well Attributes Max Angle&MD TD e . Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Alaska,Inc. 500292313600 WEST SAK INJ 94.98 9,068 11 10,466.0 -.. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1C-190,9(7/2015152:36 PM SSSV:NIPPLE Last WO: _ 34.01 3/11/2003 Vertical schematic(actuah ----- Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag-ELMD 10,447.0 2/17/2004 Rev Reason:PERFORATIONS lehallf 9/7/2015 HANGER;23.6- 1 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len I...Grade Top Thread 9 P PP `` El CONDUCTOR 16 15.062 28.0 110.0 110.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE 75/8 6.875 28.0 5,449.0 3,834.4 29.70 L-80 BTC-MOD Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(1...Grade Top Thread LINER SLOTTED 41/2 3.958 5,287.5 10,466.0 3,758.6 12.60 L-80 NSCT Liner Details -A'"-A-AN'"'\'‘ ri. I Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) CONDUCTOR,28.0-110.0 ., A. 5,287.5 3,832.9 87.27 SLEEVE BAKER TIE BACK SLEEVE 5.500 5,298.6 3,833.4 87.79 PACKER ZXP LINER TOP PACKER 4.940 5,306.6 3,833.7 88.17 NIPPLE RS NIPPLE 4.000 5,309.4 3,833.8 88.30 HANGER - FLEX LOCK II HYD HANGER 5.500 NIPPLE;515.0I , 5,317.3 3,834.0 88.64 XO BUSHING XO BUSHING - 4.500 10,431.3 3,759.3 91.29 BUSHING BAKER PACKOFF BUSHING 2.350 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)1...Wl(Ib/tt) Grade Top Connection TUBING I 4N17/.2..11D 1/21 3.9581 23.61 5295.91 3,833.31 12601 L-80 INSCT Completion Details HNominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 23.6 23.6 0.00 HANGER VETCO GRAY HANGER 4.500 Il515.0 513.2 10.25 NIPPLE CAMCO DB NIPPLE w/3.875 NO GO PROFILE 3.875 --- 4,470.3 3,612.8 62.45 NIPPLE CAMCO DB NIPPLE w/3.812 NO GO PROFILE 3.812 GAS LIFT,3,006.5 1 5,283.5 3,832.7 87.07 XO BUSHING BAKER XO BUSHING VAM ' 3.880 5,285.3 3,832.8 87.16 SEAL ASSY BAKER BULLET SEAL ASSEMBLY w/VAM BOX UP 4.860 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) •H Top(ND) Top Incl Top(ftKB) (ftKB) _ (°) Des Com Run Date ID(in) PATCH Surface casing patch from bottom of starter head. 4/21/2011 0.000 Installed 6'12"x65.500 carbon steel sleeve on surface casing. NIPPLE;4,470.3 $ !„ Perforations&Slots Shot I Dens Top(ND) Btm(TVD) (shotslf Top MB) Btm(ftKB) (ftKB) (ftKB) - Zone Date t) Type Com 5,602.0 10,401.0 3,830.4 3,760.0 WS D,1C-190 3/9/2003 99.0 SLOTS Alternating slotted/solid pipe.3 BLANK JTS:1 SLOTTED JT X0 BUSHING;5.263.58,300.0 8,305.0 3,795.0 3,795.1 WS D,1C-190 9/5/2015 6.0 IPERF tin Powerflow HSD guns,2006FP,6SPF Mandrel Inserts SEAL ASSY;5,285.3 rikSt- eti aa ss on Top(TVD) Valve Latch Port Size TRO Run t'lJ N Top(ftKB) (ftKB) _ Make - Model OD(in) Sew Type Type (in) (psi) Run Date Com t 3,006.5 2,709.3 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 4/13/2003 lint!, IMPr SURFACE;28.0-5,440.0-0 illb SLOTS;5,602.0-10,401.0 IPERF;8,300.08,305.0 LINER SLOTTED;5,287.5- r , 10,466.0 2_03-003 WELL LOG TRANSMITTAL DATA LOGGED (0/IC/2015 M.K.BENDER To: Alaska Oil and Gas Conservation Comm. May 13, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEWED RE: Injection Profile : 1C-190 MAY 2 1 2015 Run Date: 4/27/2015 AOGCC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1C-190 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-23136-00 Injection Profile 1 Color Log 50-029-23136-00SCANNEC `J�= 1 2 /015 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LE l"1'LR TO THE Al"I'EN T ION OF: Halliburton Wireline& Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed:Mxtiza4z4k.,4AiLedit (-- . of Tklt. ����y/,mss. THE STATE Alaska Oil and Gas s � '� of Conservation Commission - _ ALASIc:A •.itis. _--=' - 333 West Seventh Avenue " GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF Main: 907.279.1433 ALASY' Fax' 907.276.7542 www.aogcc.alaska.gov John Peirce 03 - DO 3 Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1C-190 Sundry Number: 315-085 SCANNED FE 2 Dear Mr. Peirce: �` 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, P9D4-„f1, Cathy P. oerster Chair DATED this lday of February, 2015 Encl. STATE OF ALASKA ` i r AL :A OIL AND GAS CONSERVATION COMIV, .ON APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Plug for Redrill r Perforate New Fool r Repair w ell r Change Approved Program r Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r Other:Crystal Seal MBE .7, 2 Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r 203-003 3.Address: 6.API Number: Stratigraphic r Service 17 , P.O. Box 100360,Anchorage,Alaska 99510 50-029-23136-00 • 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No KRU 1C-190 . 9.Property Designation(Lease Number). 10.Field/Pool(s): ADL 25649,25650. Kuparuk River Field/West Sak Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft). Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10466 ' 3759 • 10466' • 3759' • none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 82 16 110' 110' �1 SURFACE 5421 7.625 5449' 3834' R E C I V E D LINER SLOTTED 5179 4.5 10466' 3759' FEB 1 B 2015 AOGCC Perforation Depth MD(ft): Perforation Depth TVD(ft)• Tubing Size: Tubing Grade: Tubing MD(ft): slots from 5602-10401' • 3830'-3760' 4.5 L-80 5296 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-ZXP LINER TOP PACKER MD=5299 TVD=3833 NIPPLE-CAMCO DB NIPPLE w/3.875 NO GO PROFILE • MD=515 TVD=513 I 12.Attachments: Description Surrmary of Proposal 7 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory E Stratigraphic r Development r Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/4/2015 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ I' GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Contact: John Peirce @ 265-6471 Email: John.W.Peirce@conocophillips.com Printed Name John Peirce Title: Wells Engineer Signature 7.4Phone:265-6471 Date 2/1311 S Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness -SkS - 0 g S Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Spacing Exception Required? Yes ❑ No Er Subsequent Form Required: /d — 4 U 4_ / APPROVED BY /q Approved by' /2 COMMISSIONER THE COMMISSION Date: Z - ! < -/7 Approved application is valid tor 12months from the date of approval. �I l S /n�az"/S (Revised � ) ORIG ! ' " `� pForm 10-403 10 2012 Submit Form and Attachm is in Duplicate Vi l- Z/i /l5l �� �� RBDMS`J`I FEB 2 3 2015 err KUP INJ 1C-190 ConocoPhillips £- "4.` Well Attributes Max Angle&MD TD ' Alaska,Inc. UWI Wellbore APIIField Name Wellbore Status ncl l) MD(ftKB) Act Btm(ftKB)t„K v 500292313600 WEST SAK INJ 94.98 9068.11 10,466.0 • ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1C-190,9/10201312:2037 PM SSSV:NIPPLE Last WO: 34.01 3/11/2003 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:ELMD 10,447.0 2/17/2004 Rev Reason:WELL REVIEW osborl 9/18/2013 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread HANGER,23.6--'M r CONDUCTOR 16 15.062 28.0 110.0 110.0 62.50 H-40 WELDED ` 111 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(RKB) Set Depth)TVD)...Wt/Len(1...Grade Top Thread SURFACE 75/8 6.875 28.0 5,449.0 3,834.4 29.70 L-80 BTC-MOD (s3 1 1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread - LINER SLOTTED 4 12 1958 5,287.5 10,466.0 3,758.6 12.60 L-80 NSCT Liner Details Nominal ID I Top(RKB) Top(TVD)(ftKB) Top Incl CI Item Des Com (in) 5,287.5 3,832.9 87.27 SLEEVE BAKER TIE BACK SLEEVE 5.500 5,298.6 3,833.4 87.79 PACKER ZXP LINER TOP PACKER 4.940 CONDUCTOR;200-110 0-a. lk5,306.6 3,833.7 88.17 NIPPLE RS NIPPLE 4.000 5,309.4 3,833.8 88.30 HANGER FLEX LOCK II HYD HANGER 5.500 5,317.3 3,834.0 88.64 XO BUSHING XO BUSHING 4.500 10,431.3 3,759.3 91.29 BUSHING BAKER PACKOFF BUSHING 2.350 NIPPLE;515.0 f , Tubing Strings ' Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVG)(...Wt(lb/ft) Grade Top Connection TUBING 4 1/2 3.958 23.6 5,295.9 3,833.3 12.60 L-80 NSCT Completion Details Nominal ID Top OMB) Top(TVD)(ftKB) Top Incl(') Item Des Com (in) 23.6 23.6 0.00 HANGER VETCO GRAY HANGER 4.500 I 515.0 513.2 10.25 NIPPLE CAMCO DB NIPPLE w/3.875 NO GO PROFILE 3.875 4,470.3 3,612.8 62.45 NIPPLE CAMCO DB NIPPLE w/3.812 NO GO PROFILE 3.812 5,283.5 3,832.7 87.07 XO BUSHING BAKER XO BUSHING VAM 3.880 5,285.3 3,832.8 87.16 SEAL ASSY BAKER BULLET SEAL ASSEMBLY w/VAM BOX UP 4.860 GAS LIFT;3.006.5 liOther In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) 11 Des Com Run Date ID(in) PATCH Surface casing patch from bottom of starter head. 4/21/2011 0.000 Installed 6'12"x65.500 carbon steel sleeve on surface casing. Perforations&Slots Shot NIPPLE;4.470.3 1 r Dens Top(TVD) Btm(TVD) (shofsif Top(ftKB) Btm(ftKB) (MB) (ftKB) Zone Date t) Type Com 5,602.0 10,401.0 3,830.4 3,760.0 WS D,1C-190 3/9/2003 ' 99.0 SLOTS Alternating slotted/solid pipe.3 BLANK JTS:1 SLOTTED JT Mandrel Details St ati C XO BUSHING,5,283.5 N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sew Type Type (in) (psi) Run Date m 1 3,006.5 2,709.3 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 4/13/2003 SEAL ASSY.5.285.3 r rr7 E1MK SURFACE,28.0.5.4490-' SLOTS;5,602.0-10,401.0- LINER -10,401.0LINER SLOTTED;5.287.5- 10,466 0 - 10,4660 1C-190 to 1C-184 'D' Sand MBE Crystal Seal Treatment A Matrix Bypass Event (MBE) occurred 1-16-15 from 1C-190 injector to offset 1C-184 producer in the D sand. 1C-190 was shut-in due to the MBE and now awaits IPROF logging to determine where the MBE is in the slotted liner. 1C-184 remains on primary production to dewater the pattern post-MBE while the MBE remediation procedure (proposed below) is approved and finalized for execution. It is proposed that after a CT IPROF to find the MBE, that large hole perfs be shot across the MBE. Crystal Seal Slurry would then be pumped down CT through a nozzle at the MBE. A Post-Crystal Seal CT cleanout would be performed to remove excess Crystal Seal from the liner, and then a post-job (PROF will verify that the MBE has been sealed off. 1C-190 would then be returned to service. Coil Tubing Procedure: 1) RIH with jet nozzle to Fluff& Stuff the 4.5" slotted liner deep as possible to prepare for (PROF. 2) RIH with IPROF BHA to memory log down and up passes. Wait 2 hours, then log a cool back pass. 3) RIH with TCP gun to shoot 5' OAL of large diameter perf holes at 6 spf. 60 deg ph, over the MBE. Perfs create an acceptable path for 4mm mesh Crystal Seal particles to pass through the slotted liner. 4) RIH with either a large down port or side port nozzle on CT. Park the nozzle at the perf interval and then pump the Crystal Seal treatment as follows: a) Pump a SRIT with Seawater down CT to MBE. Select a steady treatment rate (likely 1.5 - 2 bpm) to be held constant during treatment through Flush (step f) to monitor MBE response to treatment and see Crystal Seal screenout develop during slurry pumping. Pump Winter Seawater (with adequate salinity) or 2% KCL for making Crystal Seal slurry; ie: b) 2% KCL Water with 0.05 ppg Crystal Seal (4 mm mesh for all stages b through e) down CT. Each stage volume TBD during pumping based on treating pressure seen during stage. When called, go to c) 2% KCL Water w/0.10 ppg Crystal Seal down CT, or go to Flush (step f) if screen out develops. d) 2% KCL Water w/0.15 ppg Crystal Seal down CT, or go to Flush if we see screen out develop. e) 2% KCL Water w/0.20 - 0.25 ppg Crystal Seal down CT, or go to Flush if we see screen out. f) If screen out occurs, pump 1 CT volume Seawater Flush to displace Crystal Seal from CT to well while POOH and pumping 0.5 bpm 2% KCL down CT backside to mitigate Crystal Seal stacking behind CT (which can cause excessive PU weight). Even if screen out is not seen prior to Flush, maintain at least 0.3 bpm of 2% KCL down CT backside to keep Crystal Seal flushed away from CT backside and mitigate PU weights. Pump 1 full CT volume of 2% KCL to displace remaining Crystal Seal Slurry from CT to liner while POOH, then swap to Diesel FP down CT, followed by 1 CT volume of Diesel to FP CT & displace Diesel FP to tubing, followed by SD. RD CTU. Wait at least 6 hours to let Crystal Seal fully swell and seal the MBE before returning 1C-190 to PWI. 5) RIH with jet swirl nozzle and tag top of Crystal Seal in well, then jet down through Crystal Seal to as deep as possible to shear & mechanically break all Crystal Seal remaining in the liner. POOH w/CT. 6) RIH with IPROF BHA to memory log down and up passes. Wait 2 hours. Log cool back pass. POOH with CT. RD CTU. Return 1C-190 to PWI service. )) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ 03 - Q Q 3 Well History File Identifier RESCAN w6'or Items: o Greyscale Items: ~or Quality Originals: o Other: DIGITAL DATA ~escan Needed I OVERSIZED (Scannable) D Maps: o Other Items Scannable by a Large Scanner Organizing (done) o Two-sided 11I11111I11111" III D Diskettes, No. D Other, Norrype: OVERSIZED (Non-Scannable) o Logs of various kinds: NOTES: BY: Helen( Maria] o Other:: , Date: 4- d-,..... OS: /s/ m P I Project Proofing Scanning Preparation ~ x 30 = 00 V1'VP + g = TO~AL PAGES 0 Z (Count 90 ~s not itelude cover sheet) 1/\AJ Date: t¡.. ~7 ó$ 151 I v~' I I Date: Lt ~7 ()5 151 BY: HelenA BY: HelenC Maria) BY: Production Scanning Stage 1 Page Count from Scanned File: 07 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES Î Hele'Ó1aria) Date: 4-. a-.7 ()& /s/ If NO in stage 1 page(s) discrepancies were found: YES NO NO Wì1) Stage 1 BY: Helen Maria Date: 151 Scanning is complete at this point unless rescanning is required. IIII I ReScanned I I " BY: Helen Maria Date: 151 Comments about this file: Quality Checked III "11111111111 III • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 October 26, 2011 Commissioner Dan Seamount R E Alaska Oil and Gas Commission . 333 West 7 Avenue, Suite 100 NOV 1) 201 ' ' Anchorage, AK 99501 _ CO3 0 dl & G Cis. C,,ist I ) G D t. Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped on 9/11 and, 9/12, 2011. The corrosion inhibitor /sealant was pumped 10/15, 10/16, 10/17 and, 10/18, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, r _ 1 1.1 r / td(d/ Martin Walters ConocoPhillips Well Integrity Projects Supervisor • • I I ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 10/26/11 1A,1B,1C,1D, 1E & 1Y PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal 1A -22 50029221270000 1910030 SF N/A 18" N/A _ 2.55 10/18/2011 WSW -01 50029205370000 1801400 20" N/A 20" N/A 2.5 10/16/2011 WSW -02 50029208120000 1821370 2'10" N/A 2'10" N/A 6 10/16/2011 WSW -03 50029208170000 1821420 12" 1.00 20" 09/11/2011 4.25 10/16/2011 WSW -07 50029208610000 1821880 _ SF N/A 19" _ N/A _ 1 10/17/2011 1C -170 50029231540000 2030780 19'3" 1.20 10" 09/11/2011 18.74 10/15/2011 1C-174 50029231400000 2030270 7' 1.00 8" 09/11 /2011 14.8 10/15/2011 1C -190 50029231360000 2030030 9'4" 1.50 8" 09/11/2011 15. 10/16/2011 1D-08 50029220266000 1770530 5'2" 1.20 6" 5/28/2011 3.8 10/15/2011 1D -12 50029229480000 1990840 18" N/A 18" N/A 3.4 10/15/2011 1D-41 50029232880000 _ 2051880 16" N/A 16" N/A 3.55 10/15/2011 1D-123 50029229140000 1981700 11'5" 2.30 5" 09/12/2011 4.4 10/15/2011 1E -11 50029207870000 1820510 22" N/A 15" N/A 1.2 10/17/2011 1Y -09 50029209350000 1830520 7' 2.00 5" 09/12/2011 1.7 10/18/2011 Page 1 of 1 • • Maunder, Thomas E (DOA) From: CPF1 Prod Engr [n1269 @conocophillips.com] Sent: Thursday, June 09, 2011 2:35 PM To: Gauer, Jenn L; Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt; NSK Prod Engr Specialist; Gangl, Melissa A Subject: LLP /SSV Defeated on 1C-190 : 09- June -2011 Tom / Jim, The low pressure pilot (LPP) on injector 1C- 1901PTD 203 -003) was defeated on 6/9/2011 when the well was returned to injection service after being shut since 1/15/11. Current wellhead pressure (as of 14:24 hrs 06/09/11) is 518 psi at an injection rate of 694 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 550 psi and the LPP /SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Daniel Bearden /David Lagerlef CPF1 Production Engineers n1269@conocophillips.com 659 -7493 pager 659 -7000 765 !!` JUN 6/13/2011 • • y ' ConocoPhi . llips Alaska R CENED P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 April 23, 2011 i F'`t A! Get Cow gen issi00 " 9T Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Commissioner Seamount: Enclosed please find the 10 -404 Report of Sundry Operations for ConocoPhillips Alaska, Inc., well 1C -190, PTD 203 -003, Sundry 310 -344 surface casing repair. Please call MJ Loveland or Perry Klein at 659 -7043 if you have any questions. Sincerely, fjityiNNEDMAY 0 3 201'1 - Perry K — -�— ConocoPhillips Well Integrity Projects Supervisor STATE OF ALASKA gib O4SKA OIL AND GAS CONSERVATION alimMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Plug Perforations r Stimulate r Other F SC inspection & Repair Alter Casing r Pull Tubing r Perforate New Pool r Waiver r Time Extension ("" Change Approved Program ! Operat. Shutdown r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: Conocgfhill ps Alaska, Inc. Development r Exploratory r " 203 -003 3. Address: 6 . API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service J 50- 029 - 23136 -00 00 7. PropertyDesignation: 8. Well Name and Number: ADL 25649 / 25650; ALK 467 / 468 1 C -190 9. Field /Pool(s): Kuparuk River Field / West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 10466 feet Plugs (measured) None true vertical 3759 feet Junk (measured) None Effective Depth measured 10466 feet Packer (measured) 5285, 5299 true vertical 3758 feet (true vertucal) 3833, 3833 Casing Length Size MD TVD Burst Collapse CONDUCTOR 82 16 110 110 0 0 SURFACE 5421 10 5449 3834 0 0 LINER SLOTTED 5178 7.625 10466 3758 0 0 Sleeve 6 12 5 0 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: Slotted Liner 5298 - 10466' RECEIVED True Vertical Depth: Slotted linker 3833 -3758' 6 Tubing (size, grade, MD, and TVD) 4.5, L -80, 5298 MD, 3833 TVD pi (}j� &8t� '' v'CrIrtgle Packers & SSSV (type, MD, and TVD) SEAL - BAKER BULLET SEAL ASSEMBLY WNAM BOX UP @ 5 MD and 3833 TVD PACKER - LINER ZXP PACKER - HRD PROFILE @ 5299 MD and 3833 TVD NIPPLE - Type Not Found (Manual Entry Required) @ 0 MD and 0 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 13. Attachments 14. Well Class after proposed work: Copies of Logs and Surveys run Exploratory r Development r Service 15. Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations X GSTOR r WAG r GASINJ r WINJ 'F SPLUG r 16. I hereby certify that the foregoing is true an. •.. re • he best of my knowledge. Sundry Number or N/A if C.O. Exempt 310 -344 Contact f o - - nd/'• - , Klein Printe• 'ame MJ Love . nd Title Well Integrity Project Supervisor Signatu - Phone: 659 -7043 Date I Z3 1‘, Form 10 -404 Revised 7/2009 7 "` ABr MS APR 2 6 20 19 doge Su # bm ro it Original Only • • 1C-190 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 04/10/11 Remove 9' 8" of conductor and landing ring. 04/11/11 UT inspection showed minor damage to surface casing, will install sleeve for proactive measures.. Notified state man Chuck Scheve the opportunity to witness damage to the SC. 04/21/111 Installed 6' 12 "x 65 .500 sleeve on SC. J 04/23/11 Performed MITOA (passed). Initial T /I /O = SI /SI /0 Pressured up OA to 1800# with 2 bbls of diesel for 1 hour. Start T /I /O = SI(0) /SI /1800. 15 min T /I /O = SI(0)/SI/1760. 30 min T /I /O = SI(0) /SI/1750. 45 min T /I /O = SI(0)/SI/1750. 60 min T /I /O = SI(0)/SI/1750. Bled OA down to 0 #. Final TWO = 51(0)151/0. Insulators wrapped SC sleeve with Denso, Installed 9' 4" 16" .375 conductor. : , �: . ©Cono coPhillips Alaska, Inc �; p This ph oto is copyright by d ' 8 � ■* ConocoPhillipsAlaska, In ■v� i , 1 , z — and cannot be released or 4,-,- ` .: ; �. .,, - pu blished without express r', - f4':44 �� t, written consent of d,j ^ �#��,},; ConocoPhillipsAlaska .e K i� '� y ` r ?t.c fay' , `s' kj # x #4 1 h! v ; 4 i f f s tt t" t • + 41 ` ��' 4 y ? , 5 a e .z .,.N 4,r . -- WI — ' , t e.. ... t . ti • /3 5 ..., . s • ,,, ,....,......,:....„,...,..„ :,r, . .., ,„. , .. • .... ■ A § r x ¢v� x 1 � ` .' xr .!a" ,. • '' i , . • 4 `V • k t i W ,4 r '� r„ ` 4 ;!,,,,- ; . , ',..,:f., ,''i,,:ia,„!..ZN ;:it:i , i . x ©Conoco Phillips Alaska, Inc • :,, a t� �� To is y b ..., , . .. ,...,„ ' . �/ ` Conoco Philli s Alaska, In and his cannot be released cop or c. t +, published phot without express written consent of � ,,,,,,,,,y,„,,,,4,-,,, '` ` ""`° `� ConocoPhillips Alaska r: ■ r. t 0 4. 1. z" -:; ' .., . , F C , _.....„,.. . W .. .• ..,„,_,...: • j F =k. • . t • ,....... , , . • .., • , ; 4 -• ., -... .„ , 4 j j. , ,'",. ; .iii - ',.,,?,.,, 1 ,,.• ,, ,, :, ,,,...12,..f ,,, , u 0 '5 ■ -,... ',.• • ....'' ', •• .. , —':. -3 ta , 4 1 : .,..: , ', : , 1' :. .., ":,':: r * ,.. • F tr. * � } �yy • li t i L` g }' a *' .fi Page 1 of 1 Maunder, Thomas E (DOA) From:' CPF1 Prod Engr [n1269@conocophillips.com] Sent: Friday, June 25, 2010 7:29 AM To: CPF1 Prod Engr; Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Jenkins, Lubbie Allen; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr 8~ Optimization Supv; Seitz, Brian; Pierson, Chris R Subject: LPP/SSV Returned to Service on 1 C-190 - 25-Jun-2010 Tom /Jim, The low pressure pilot (LPP) on injector 1C-190 (PTD 203-003) was returned to service on 06/25/2010 after the wellhead injection pressure stabilized above the setting of the low pressure pilot. Current wellhead pressure is 697 psig; injection rate is 474 bwpd. This pilot had been defeated on 06/05/10 in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. David Lloyd Lagerlef/Daniel Bearden CPF1 Production Engineers n1269@conocophillips.com 659-7493 pager 659-7000 765 From: CPFS Prod Engr Sent: Saturday, June 05, ZO10 4:03 PM To: CPFl Prod Engr; "Maunder, Thomas E'; "Regg, James B' Cc: CPFl DS Lead Techs; CPFi Ops Supv; NSK Problem Well Supv; Jenkins, Lubbie Allen; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitr, Brian Subject: LPP/SSV defeated on 1C-190 - 05-Jun-2010 Tom /Jim, The low pressure pilot (LPP) on injector 1C-190 (203-003) was defeated on 6/05/2010 when the well was returned to injection service after being shut in for 84 days. The well was shut-in 3/13/10 pending a choke repair. Current wellhead pressure (as of 15:39 6/05/10) is 456 psig; injection rate is 384 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. David Lloyd Lagerlef/Daniel Bearden CPF1 Production Engineers n1269@conocophillips.com 659-7493 pager 659-7000 765 6/30/2010 MEMORANDUM TO: P1tInSupgrvisor 2~ Z ~~~I~~ FROM: John Crisp Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, May 25, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1 C-190 KUPARUK RIV U WSAK 1C-190 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~ Comm Well Name: KUPARUK RN U WSAK 1C-190 API Well Number: 50-029-23136-00-00 Inspector Name: John Crisp Insp Num: mitJCr100524060854 Permit Number: 203-003-0 Inspection Date: 5/21/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well IC-I9o~Type Inj. N ~ TVD 3833 IA r 0 2240 2110 ~ 2090 ~ P.T.D zosooso TypeTest SPT I Test psi Isoo OA - Interval anzTST p~ P ~ Tubing aso soo soo I~ soot Notes: 4.4 bbls pumped for test.Monobore injector.`~No problems witnessed. - ~rq f ~'' jjW;~ ~. ~~..' Tuesday, May 25, 2010 Page 1 of 1 . • Page 1 of 1 Maunder, Thomas E (DOA) From: CPF1 Prod Engr [n1269@conocophillips.comJ Sent: Saturday, June 05, 2010 4:03 PM To: CPF1 Prod Engr; Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Jenkins, Lubbie Allen; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr ~ Optimization Supv; Seitz, Brian Subject: LPP/SSV defeated on 1C-190 - 05-Jun-2010 Tom /Jim, The low pressure pilot (LPP) on injector 1C-190 X203-003) was defeated on 6/05/2010 when the well was returned to injection service after being shut in for 84 days. The well was shut-in 3/13/10 pending a choke repair. Current wellhead pressure (as of 15:39 6/05/10) is 456 psig; injection rate is 384 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. David Lloyd Lagerlef/Daniel Bearden CPF1 Production Engineers n 1269@conocophillips.com 659-7493 pager 659-7000 765 6/7/2010 • WALL L~1G T1~4/1 f~11~,lTTAL ,,. PreoAcrivE D'wcrNOStic SemiicES, (NC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907J 659-5102 RE : Cased Hole/Open Hole/Mechanical Lags and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road a ~ ~~,~ ~;~~ ~ . ~ ~ } ~ „ ,` ~ ~~ Suite C Anchorage, AK 9951 S Fax (907) 245.8952 1 J Caliper Report 13,Jurr09 1 E•15 2) MTT Report 14Jun-09 1 G190 uz~ ~~~ -rb~ ~ ~~~~ ~C 3-b~3 ~`~1~3 Signed : ~" Print Name: 1 Report / EDE 1 Report JUN ~ ~ 2009 Date fit. a Gii Gss s. Camrnission Anchorage 50-029-20769-QO 50-029.23136-00 PROAcrrvE ptacsNOSrc SERVICES, troc., 130 W. INTERNATIONAL. AIRPORT RD Su17E C, ANgiORAQE, AK 99518 PHONE: (9071245-8951 Fax: (907)245.88852 E-MAIL : pdsanchorapeCaamemorvlog.com WEBSrrE : www.memorvloa.com ~~ C:~Documeads and settings~ownertnasktop~Tiansm~t_ea,oco.ao« • • Memory Magnetic Thickness Tool Log Results Summary Company: ConocoPhillips Alaska, Inc. Weil: 1C-190 Log Date: June 14, 2009 Field: Kuparuk Log No.: 10558 State: Alaska Run No.: 3 (2"d MTT) APt No.: 50-029-23136-00 Pipet Desc.: 4.5" 12.8 tb L-80 NSCT Top Log Intvl.: Surface Pipet Use: Tubing Bot. Log Intvl.: 212 Ft. (MD) Pipet Desc.: 7.625" 29.7 Ib L-80 BTC-MD Top Log Intvl.: Surface Pipet Use: Surface Casing Bot. Log Intvl.: 212 Ft. (MD) Pipe3 Desc.: 16" 62.50 Ib H-40 Welded Top Log Intvl.: Surface Pipe3 Use: Conductor Pipe Bot. Log Intvl.: 110 Ft. (MD} Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This MTT data is tied into the Mandrel Hanger @ D' Depth. This is the second time this well has been logged with the 12 Arm Magnetic Thickness Tool (MTT). The MTT responds to the total metal thickness of the 4.5" tubing and 7.625" surface casing, with some influence from the 16" conductor pipe. Passes at 5Hz, 8Hz, 10Hz and 12Hz were made at 20 fpm, with the 5Hz and 8Hz passes selected for analysis in this report. Due to the concentric pipe strings in the log interval, the MTT response is qualitative -indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. COMPARISON TO PREVIOUS MTT LOG RESULTS t A comparison of the current 8Hz pass to the previous 8Hz pass (December 30, 2006) indicates little, if any, change in metal thickness during the time between logs. A log plot overlay of the average metal thickness recorded by the MTT for the current and previous logs is induded in this report. The Delta Metal Thickness curve of the 5Hz pass of the current log is also included in this plot. ' The areas of metal loss indicated in the previous log are indicated very similarly in the current log. The reduced lagging speed, from Q5 fpm used for the previous lag to 20 fpm used for the current log, enhances the stability of the tool response to the metal volume surrounding it. The added stability and reliability of the ' data recorded at 20 fpm is believed to be the cause for some of the slight variance between the 2006 and current log results. During processing of the MTT data from the 2006 log, separate calibrations were not applied to the interval that includes the conductor pipe and the interval below the conductor pipe. The calibrations taken within the conductor pipe interval were applied to the entire log interval. This resulted in a indication of less metal below the conductor, relative to the interval including the conductor. In order to support a more consistent comparison, the previous data set was re-processed using a separate calibration for the interval below the conductor pipe. The current data set was processed similarly -using separate calibrations to represent "good pipe" intervals both above and below the bottom of the conductor pipe. This allows for a consistent comparison of the entire log interval for both data sets. ~ ProActive Diagnostic Services, inc. / P.O. Box 1369, Staf#ord, TX 77497 Phone. (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com ' Prudhoe Bay Feld OfFice Phone: (907) 659-2307 Fax: (907) 659-2314 A '" ' ~ ~ ~. ~ -~ • • INTERPRETATION O~ MTT LOG RESULTS The MTT log results cover the interval from surface to 212. Log plots of the 5Hz and 8Hz passes are included in this report. In conductor pipe: A 2% - 7% circumferential metal toss is recorded in the interval between 23' - 31'. A 1 % - 6°r6 circumferential metal loss is recorded in the interval between 73' - 79'. A 1% - 4% circumferential metal loss is recorded in the interval between 53' - 62'. A 1 % - 3% circumferential metal loss is recorded in the interval between 6' - 12'. Below conductor pipe: A 1 % - 6% circumferential metal loss is recorded in the interval between 115' - 153'. A 1 % - 5% circumferential metal loss is recorded from 195' to the end of the interval logged. A 1 % - 3% circumferential metal loss is recorded in the interval between 162' -165'. A 1% - 2% circumferential metal loss is recorded in the interval between 181' - 186'. The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which includes influences from the 4.5", 7.625" and 16" pipe. If all of the metal loss is specific to the 7.625" surface casing, the percent metal toss from that pipe alone is probably higher than the numbers expressed. Some of the metal loss indicated could be ffom either the 4.5" tubing or 16" conductor. Field Engineer: G. Etherton Analyst: HY. Yang & J. Burton Witness: R. Ober ProActive Diagnostic Ser/ices, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281} or (888} 565-9085 Fax: (281} 565-1369 E-maii: PDS~~memoryiog.com Prudhoe Bay Field Office Phone: (9071 659-2307 Faz: (907 } 659-2314 Comparison to Previous ~T Log Overlay ~~ o June 14, 2009 and December 30, 2006 uw~c Sc~nAca,, Mc. Database File: comp.db Dataset Pathname: 1!1!1/merge Presentation Format: comp8hz Dataset Creation: Mon Jun 15 20:33:55 2009 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness 2009 (5Hz) (%} 50 -50 Delta Metal Thickness 2009 (8Hz} (%} 50 -50 Delta Metal Thickness 2006 (8Hz) (%} 50 0 2009 20 40 60 2009 2006 80 100 of 16" Conductor. 120 140 160 180 2006 of 200 2009 -50 Delta Metal Thickness 2009 (5Hz) (%) -50 Delta Metal Thickness 2009 (8Hz) (%) -50 Delta Metal Thickness 2006 (8Hz) (%) 5" Jt. 3 -- - ~ -- 100 ottom of 16" Ca~xiuctor Tubing Coll ar ~ „_ 6 % M eta l Los s 120 Casi ng C olla r 4.5" Jt. 4 140 -- -- -Tubin Colla g ~~ % 4 Meta l Lo ss 160 3% Metal Loss 4.5" Jt. 5 Casing Collar Tu bing Col lar 180 4.5" Jt. 6 00 2 Delta Metal Thic kness -- 3% Metal Loss ubing Colla ~ ~~ 4% Metal Loss ine Spee -50 Delta Metal Thickness (%) 50 1.8 MTTP01 (rad) 11.8 0 LSPD (ft/min) 200 -7 MTTP12 (rad) 3 1 C~0 Recorded Magnetic Thick~s Log Data - 8Hz Pass (Surface to 212') June 14, 2009 PwoAerhre DL-gNOSttc Sewvlets„ Ire. Database File: 1c-190.db Dataset Pathname: 8Hz.1 Presentation Format: 2.8 scale Dataset Creation: Mon Jun 1510:00:51 2009 by Calc Warrior 7.0 STD Cas Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness (%) 50 2.8 MTTP01 (rad) 12.8 0 Line Speed (ft/min) -200 -5.6 MTTP12 (rad) 4 Tree Metal 4.5" Jt. 1 20 Metal Thickness Metal Loss g Collar pup Jt . 4 0 ~ ~ Ong Collar Pup Jt. Tubing Collar Metal Loss 60 " 4.5 Jt. 2 i~inn Collar 80 Tubing 5' Jt. 3 100 -Bottom of 16" Conductor ~~ Metal Loss 120 4.5" Jt. 4 140 ~g Collar 160 Loss 4.5" Jt. 5 ing ;Tubing Collar Metal 180 I I 14.5" Jt. 6 Metal Thickness 200 Metal Metal Loss -50 Delta Metal Thickness (%} 50 2.8 MTTP01 (rad) 0 Line Speed (ft/min) -200 -5.6 MTTP12 (rad) 1 ~. KUP 1 C-190 ConocoPhillips wean l ' Al,t~;.,,. ~, I we8bare rt rwrn Fldtl Rsne wee al»1s proe lry well Type Md 1 1 laKB) ID 1~41a- . 5002923 13600 WEST SAK INJ PWI 94,98 9,068.11 10,466.0 mm to isssnta SSSV: NI PPLE 2a 0 7/1/2008 Last WO: 31.01 gR >m 3!11/2003 A~tlon ) tl Last Tag: ELMD 10,447.0 2/17/2004 Rev Reason FORAMT UPDATE 11/12/2008 C>K >~ D esvipll on SUMg (k11 gN T ~ Bet ~1 ffim9 YR Imeaq m~ Tap 71rtl -'y }, ONDUC TOR 1 6 15.062 0.0 110.0 110.0 62.50 Hi0 WELDED L ~t SUR AC E 7 5/ 8 6,875 0.0 5,449.0 3,834.1 29.7 L-80 BTC~JID coNDUCroa. LIN O ED 4 1/ 2 3 958 5 7 0 46 0 0 3 75 6 12 60 L-80 NSCT 1,0 . , . . , , . Tubi SMn s D ecctlpa on lti) pn) T (aKD) set gaCa) 1~~g t7atle WYg Tap Mtl TUBING 412 3.958 D.0 5,298.D 3.833.2 12.60 L-80 NSCT NIPPLE. s,s M Hok A il J . Tu Run S R Fish atc. 1~ 1 hp (~) inc11') Cmrm6et Rul Date D 51 .0 51 3.1 10.25 NIPPLE CAMCO'DB' NIPPLE W13.87 NO GO RO FILE 3/9/2003 3.875 3.007.0 2,70 9.8 33.95 LI CAMCOIKBG-211/DMYIBK/// Cortrnant STA 1 4/1 003 3.938 4,4 .0 3,612 . 62.44 NI CAMCO'06' NI LE 13.812" N GO PRO FI 3.81 GAS LIEr .2 3.0 3.83 22 8 .05 XO BUSHING BAKER XO BUSHING VAM 319/2 3.880 3'007 5,286. 3,83 2.1 87.14 SEAL BA R BULLET' S L A BLY WNAM BO UP 3/9 3 4. ~ 5,298.0 3,833 .2 87.76 TIE-BACK SL N TIE-BACKS VE 31812003 5. i ~ 5,299.0 3,833 .3 87.81 PACKER UN ZXP PACKER - HRD ROFiIE 4.940 1 5,307.0 3,833 .7 88.19 NIPPLE LINE RS NIPPLE 3182003 4.880 NIPPLE, 4,470 10.431.0 3,759 .3 91.29 ACKO F LINER BA R P KOFF BUSHING 3182003 .350 10.464.0 3.758 .6 91.29 SHOE LINER REAM FLOA SHOE 3182003 3.958 "' Parfora tlons j TuP (TYDI aan (TM) pns 1 y ~ T !an 101 091 iar Die (~- Cenwr~t ! .61Y2.0 0,40 1.0 3,830.4 .0 D, 1C-190 319/2003 99.0 Sloss Ahetnaarlg sbt0edlsaW pye XO BUSNMlG. 5.2&3 sEAL.s,zes E TIEEACK SLV, 5,]98 PACKER. 5,298 NIPPLE, 5,307 SURFACE i 5.468 skis. 5.602-10.401 PACKOFF. ,0431 snoE.lo.a66 LWER SLOTTED, 10,466 m.,o,ass Jun 14 09 07:09p PDS Inc ~ 907 6314 p.15 -:, ~a~Q+Ci~~~11~~t !t~$ske, lnc... Tubing Detai! Weld: 1C-190 Date: 3!412003 Jt Nunber Nan of Jts GOMPtErE DESCR~T'ION QF E(2t1~M~NT RUN LENGTH 70PS Dt~ n Ri 141 RKB 23.57' 23.5 7 Vetco Gra Tubin han er wt NSCT Pu Jaint 4.31 23.57 Jts 169 to 169 1 Jts 4.5" NSCT, 126 f , L-80 Tubin 30.38 27 88 4.5" NSCT, 12.6 f., L-8p Pu Join# 9.78 5826 4.5" NSCT, 12.6 f L-8i} Pu Joint 9.70 6s,U4 Jts 155 to 168 14 Jts 4.5" NSCT, 12.6 f , L-80 Tubin 431.13 77.74 4.5" NSCT, 12.6 f., L-80 Pu Joint ~ 8.11 508.87 4.5" Camccl "©B' Nt le wJ 3.875" No-Go Profie 1.49 51a 9s 4.5" NSCT, 12.6 _, L-~80 Pu Jnin# +5.26 . 516A7 Jts 74 to 154 81 J1s 4.5" NSCT 12.8 f., L-$0 Tubin 2;77.53 ,2273 4.5" NSCT 12.6 f_, L-80 Pu Joint s2s 3ooo.2s Camca GLM, KBG 2 4.5" X 1" wJ DCR Shear ~.'aive BK f.atch 7.29 3006.52 4.5" NSCT, 12.6 f , L-SQ Pu Joint s.2d 3o13.s1 Jts 27 to 73 47 Jts 4.5° NSCT, 12.6 f. , L-$0 Tubin 1443.99 3020.05 4.5" NSCT, 92.6 f„ L-80 Pu ,loin[ s23 44s4_o4 4.5" CamCO "QB" Ni !e wJ 3.812" No-G© Profi<= 1.53 a47o29 4.5" NSGT, 12.6 _, Lam((} Pu Joint s.27 4471.82 Jts 1 do 26 2s Jts 4.5" NSCT, 12.6 f., L~0 Tubin 797.40 447s.os 4.5" NSCT 12.& f., L-80 Pu Joint 5.7a 5275.49 __ Pu Joint Xta 4.5" NSCT bax X 4.5" VAM in 228 5281.19 XO Sushin 4.S" X 5.5" VAM 1.80 52$3.47' Baker 5.57" Bullet Seal AS . wt 5.5" Vc'afT1 box ~ ! 10_fa5 528527 52s5.n2 TOL 5287.54'. Luca#or 2' above full located oasiflon. Ran Iota! at 1G9 Joints ~4-i/2' tubing Tubing landed Z' above tag A!t tubing is new Jet-Cube ffue~ compound used on iabing Tubing drafted y»7h 3.833" dnR Top ~5 jaiM.:: drifEed Up Wt. 78k to 39f0" {5{>ad~ ~~) Dn Wt TOk Block Wt. 30k pa ft' t4f Suioervisar Fred Heri-erflOead Gladder, Jun 14 09 07:09p PDS Inc Casing Defail 7-518° surface casfrlo C~>-tOCO PHILLIPS Alaska, Inc_ 907 6~ 14 p.14 W~LL:1C-190 DATE: 03/02l2Qa3 i 0f= i PAGFS 1f ITEMS COMPLETE DESCRIPT~N OF EQIIIPME_NT l2U~J LiJV~3Tti DEPTtI 7 518" Landing Joint (34.90 totaq G.9a above ro `ary DOYON [tT to LR ~ 28,00 28.t~ HF2G Vetco Gray Fluted Mandrel hangerwl2.76 pup 3.'.6 28.40 jts.105.127 75/8", 29.7#, L-80 BTG-MOA ID 6.$75 979.96 31.36 TAM Port Cotiar 2.43 1011.32 jtS 3-104 T Sl8°, 29.7#, L-EO BTC-MOD ID 6_$75" 4351.97 'E013.75 FC Float Collar Weatherford tJlode1402 Sure-Sea! 1.?3 5365.72 j1s i-2 75/8", 29.7#, L-BO BTC-MOD !D B.B75" 80.49 5367.05 FS Float Shoe Weatherford Mode! 303 sure-seal 1.49 5447.48 [3TM OF SHOE ~----s»» 5448.95 Td of 9 718" hole = 5455'1 5455_aa To1af Centralizers Used 4 TOTAi.. - Bow Spring Centralizers 25 TOTAL, Solid stand off straigh# vans centralizers 1-Baw spring centralizer on shoe jt. 8 1 on lt- #3. 2 -Run Bow spring Cent on Jt. Above ~ Below Tam Colr r. _ 25- Stand otf centralizers Jt. 2 8.4-thru 26 {float betwr~en ::atfar5l '#Nan er es in the to of - -nt # 127 ~•Fifl on the fl and To off eve 5 hints ""'Baker Lok a!i connections from the T of the FC ~1own ~* Break Cireu a# 3000' and on bottom- condt rnud t. ~ 80 Vis "Sta e u u to rrrinimize sur e '* Corrtrol n~rxing speed to minimize surge_ Rema-ics: String Weights with Blocks 160 k Up, 9Dk Drt, 35k Blocks. Ran 927/oints of casirx~ Drifted casing witf~ 6.875°p/asiic rabbit Used Jei Luhe thread compound ort aA cor~nectiav-s. RE: LPP/SSV defeated on 1C-190 (PTD 203-003) Regg, James B (DOA) From: Sent: To: Cc: NSK West Sak Prod Engr [n1638@conocophillips.com] Thursday, November 27, 2008 10:58 AM Regg, James B (DOA); Maunder, Thomas E (DOA) • ~ C~~~~( Page 1 ~~ ~ CPF1 DS Lead Techs; CPF1 Prod Supt; Targac, Gary; NSK Problem Well Supv; Jenkins, Lubbie Allen; NSK West Sak Prod Engr Subject: RE: LPP/SSV defeated on 1 C-190 (PTD 203-003) `~ Tom /Jim, The low pressure pilot on West Sak injector 1 C-190 (PTD 203-003} was put back into service on 11/2512008. The well is currently taking 935 bwpd injection at 640 psi wellhead pressure. .-- Please let me know if you have any questions. Regards, Hai Hunt ~as~~~li~~~~ ,1F ~ cy "~ ~~~ From: NSK West Sak Prod Engr Sent: Wednesday, November 19, 2008 6:39 AM To: 'jim.regg@alaska.gov'; 'tom.maunder@alaska.gov' Cc: CPFl DS Lead Techs; CPFl Prod Supt; Targac, Gary; NSK Problem Well Supv; Jenkins, Lubbie Allen; NSK West Sak Prod Engr Subject: LPP/SSV defeated on 1C-190 (PTD 203-003) Tom /Jim, The low pressure pilot (LPP) on West Sak injector 1 C-190 (PTD 203-003) was defeated on November 18, 2008 when the well was returned to service after being shut in for an extended period of time (since May 1, 2008). Current wellhead pressure is 358 psig; injection rate is 977 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001 ". Please let me know if you have any questions. Regards, Hai Hunt Hai Hunt /Eric Hollar NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 11/28/2008 LPP/SSV defeated on 1C-190 (PTD 203-003) Page 1 of 1 • Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophillips.com] Sent: Wednesday, November 19, 2008 6:39 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; Targac, Gary; NSK Problem Well Supv; Jenkins, Lubbie Allen; NSK West Sak Prod Engr Subject: LPP/SSV defeated on 1 C-190 (PTD 203-003) Tom /Jim, The low pressure pilot (LPP) on West Sak injector 1C-190 (PTD 203-003) was defeated on November 18, 2008 when the well was retumed to service after being shut in for an extended period of time (since May 1, 2008). Current wellhead pressure is 358 psig; injection rate is 977 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is retumed to normal, in accordance with "Administrative Approval No. CO 406B.001". Please let me know if you have any questions. Regards, Hai Hunt Hai Hunt /Eric Hollar NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1638@ConocoPhillips.com ~iJ 11/20!2008 • -,,,,_ '~ ~ ~ ~. ._ ~ r ,. ~~- r f ~, -. -~ ' • ~ 03~o~~ZOOs DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFiche\C~rPgs_InsertstMicrofilm Marker.doc Schlumberger -DCS 2525 Gambeil Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # 11 /02/07 N0.4356 ra '~~~~C ~~:5A~9811~~~ ~~v ~ ~ ZUQ~ Log Description Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk ~ /~~ - ~ ~ 3 ~,t,J ` ~' t~~ Date BL Color CD 6 1D-103 11837528 INJECTION PROFILE 10/27/07 1 1L-28 11839680 PRODUCTION PROFILE 10/28/07 1 2N-310 11839674 DDL ~ - 10/30/07 1 1C-190 11837524 INJECTION PROFILE (_j ~"- Q:' 10/20/07 1 2V-16 11837526 PRODUCTION PROFILE - "~~' 10/24107 1 1H-04 11837527 INJECTION PROFILE 10/25107 1 i Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • • . . ~ ConocoPhillips Alaska ,JUL 0 3 2007 9- ê{ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 2,2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 """. ....e03 ~'OJ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRD). Some of these wells were found to have a void in the conductor by surface casing annulus. The volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Perry Klein or M.J. Loveland at 907-659-7043, if you have any questions. 4¡~ M.J. Loveland ConocoPhillips Well Integrity Supervisor - ./-~ JUL 0 5 2007 . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/1/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft na aal 1 C-19 203-054 28" none 28" na 12 6/24/2007 1 C-123 201-084 22" none 22" na 24 7/1/2007 1 C-127 201-114 18" none 18" na 12 7/1/2007 1C-133 201-077 16" none 16" na 8.5 7/1/2007 1C-190 203-003 27" none 27" na 10 -- 2:+:;2 3K-12 186-165 6" none 6" na 3 6/24/2007 3K-19 201-108 6" none 6" na 3 6/24/2007 3K-20 201-088 4" none 4" na 1 6/24/2007 3K-23 197-097 8" none 8" na 5 6/24/2007 3K-24 198-249 4" none 4" na 1 6/24/2007 3K-25 198-081 6" none 6" na 3 6/24/2007 3K-26 197-077 8" none 8" na 5 6/24/2007 3K-27 197-046 6" none 6" na 3 6/24/2007 3K-31 198-082 8" none 8" na 5 6/24/2007 3K-34 198-077 7" none 7" na 4 6/24/2007 3K-35 197-109 3" none 3" na 2 6/24/2007 • Maunder, Thomas E (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Monday, March 19, 2007 9:14 AM To: Thomas Maunder Cc: NSK Problem Well Supv Subject: RE: 1C-174, 1C-121, 1C-t123, 1C-190, 1C-119 Thanks Tom ~4e~.-~~ MJ -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, March 19, 2007 9:01 AM To: NSK Prod Engr Tech Cc: NSK Well Integrity Proj; Allsup-Drake, Sharon K Subject: 1C-174, 1C-121, 1C-123, 1C-190, 1C-119 AlI, We have received 404s changing the status of these WS injectors back to lwinj. This change was requested in a review meeting held with the project engineers. Authority to inject MI in these wells expired 8/31/06 according to AIO 2B.001. In the Commission records, the effective date of the status change will be 9/1/06. Call or message with any questions. Tom Maunder, PE AOGCC ~t ~~~ ~ ~i ~~~~ ~~ • Maunder, Thomas E (DOA) From: NSK Weii Integrity Pro] [N1878@conocophiilips.com] Sent: Monday, March 19, 2007 9:14 AM To: Thomas Maunder Cc: NSK Problem Well Supv Subject: RE: 1 C-174, 1 C-121, 1 C-123, 1 C-190, 1 C-119 Thanks Tom ~~~•-~~ MJ -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Monday, March 19, 2007 9:01 AM To: NSK Prod Engr Tech Cc: NSK Well Integrity Proj; Allsup-Drake, Sharon K Subject: 1C-174, 1C-121, 1C-123, 1C-190, 1C-119 A11, We have received 404s changing the status of these WS injectors back to lwinj. This change was requested in a review meeting held with the project engineers. Authority to inject MI in these wells expired 8/31/06 according to AIO 2B.001. In the Commission records, the effective date of the status change will be 9/1/06. Ca11 or message with any questions. Tom Maunder, PE AOGCC 1 • Maunder, Thomas E (DOAj From: NSK Well Integrity Proj [N1878@conocophiltips.com] Sent: Monday, March 19, 2007 9:14 AM To: Thomas Maunder Cc: NSK Problem Well Supv Sabject: RE: 1 C-174, 1 C-121, 1 C-123, 1 C-190, 1 C-119 Thanks Tom l ~~ ~ ~~~~~ MJ -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, March 19, 2007 9:01 AM To: NSK Prod Engr Tech Cc: NSK Well Integrity Proj; Allsup-Drake, Sharon K Subject: 1C-174, IC-121, 1C-123, 1C-190, 1C-119 AlI, We have received 404s changing the status of these WS injectors back to lwinj. This change was requested in a review meeting held with the project engineers. Authority to inject MI in these wells expired 8/31/06 according to AIO 2B.001. In the Commission records, the effective date of the status change will be 9/1/06. Call or message with any questions. Tom Maunder, PE AOGCC • Maunder, Thomas E (DOA) From: NSK Wett integrity Proj [N1878@conocophillips.comj Sent: Monday, March 19, 2007 9:14 AM To: Thomas Maunder Cc: NSK Problem Well Supv Subject: RE: 1 C-174, 1 C-121, 1 C-123, 1 C-190, 1 C-119 Thanks Tom c}Vt._~~C~ ~~i ~~~ MJ -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.usJ Sent: Monday, March 19, 2007 9:01 AM To: NSK Prod Engr Tech Cc: NSK Well Integrity Proj; Allsup-Drake, Sharon K Subject: 1C-174, 1C-121, 1C-123, 1C-190, IC-119 A11, We have received 404s changing the status of these WS injectors back to lwinj. This change was requested in a review meeting held with the project engineers. Authority to inject MI in these wells expired 8/31/06 according to AIO 2B.001. In the Commission records, the effective date of the status change will be 9/1/06. Call or message with any questions. Tom Maunder, PE AOGCC 1 .... . . RECE\VEO MAR 1 3 1.007 ~ Comm\ssion ~ _ \, 0'\ & Gas Cons. G Ph-II- à!,asl\a \ onoco I IP5 ~nchofage Robert Buchholz / Robert Christensen Production Engineering Tech, Greater Kuparuk Unit, NSK-69 PO Box 196105 J\nchorage,AJ( 99519-6105 Phone: (907) 659-7535 Fax: 659-7314 March 9, 2007 Tom Maunder, P.E. Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission ~fí'é\t\1NEf) MAR 2 0 2007 33 W. ih Ave. Ste. 100 \i)1\ I'U1I Anchorage,AJC 99501 Dear Mr. Maunder, ConocoPhillips Alaska, Inc. has completed the West Sak EOR Pilot Project. Enclosed you will find 1 0-404 Rep~ of Sundry Well Operation for ConocoPhillips Alaska, Inc. well1C-190 (PTD ~003). The report records the change of well status from WAG Injection to WaterInJe~ipn Service. ,)Þ- 3·Z.. .O"? If you have any questions regarding this matter, please contact myself or Robert Buchhloz at 659-7535. Sincerely, ~. Robert D. Christensen Attachments . . RECf) <--.'l'· : ~.....-". ''''~ MAP "( ':,.'; ,;, (" \ I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA TIGM91i\ b r;" Repair Well 0 Pull Tubing D Operat. ShutdownD 1. Operations Performed: Abandon 0 Alter Casing D Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc, 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 87' . 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: Total Depth measured true vertical Effective Depth measured true vertical Casing Structural CONDUCTOR SURFACE SLOTTED LINER Length 110' 5362' 5179' Perforation depth: Measured depth: true vertical depth: Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) , "",q\í¡):)\On t..,,,/,I I ¡¡r'e ....~ Plug Perforations D Perforate New Pool D Perforate D 4. Current Well Status: Development D Stratigraphic D o WAGIN to WlNJ Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: Stimulate D Waiver D Other Exploratory D Service 0 203-003 1 6. API Number: 50-029-23136-00 J 9. Well Name and Number: 1C-190 J ¡49¿.. ~~"ço P\)1""',¡t'/ 10. Field/Pool(s): Kuparuk River Field 1 West Sak Oil Pool 1 0466' ' 3759' , Size 16" 7-5/8" 4-1/2" 4-1/2" , L-80, 5298' MD. no packer Oil-Bbl feet feet feet feet Plugs (measured) Junk (measured) MD TVD Burst Collapse 5298 110' 11 0' 5449' 3834' 10466' 3759' L\~\~ÇJ~~ \ v-:~d\a~~~~~~j þ.. \0 d \S t\:JO. \. ~ c ~ J:.-~s".ðd \"'- \~.... ~\\. V~~t'-~~~\~Õtd ~"'-::.~~C~ , ~~\-\.ð~ ~ \~~~\-'::?-~ ~i-- P\~ % /~ \ -Ofo. ~\\<;;:.\o..~?ck~-\o \w~~ <C.~C\\~ ~ 1\ -O~ A-~"1)v(~ h'ì.-a~ 3833 SSSV= NIP SSSV= 515' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run_ Daily Report of Well Operations _ Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 340 340 . Casin Pressure 10 10 Tubin Pressure 827 827 15. Well Class after proposed work: Exploratory D Development D Service 0 16. Well Status after proposed work: OilD GasD WAGD GINJD WINJ 0 . WDSPL D Contact 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: N/A Signature Form 10-404 Revised 04/2004 Title Phone 659-7535 Production Engineering Technician Date 3 1 S T fl MAR 1 " 2007 ~ "J -It, 007 Sub~riginal Only ~J1í667 ORIGINAL . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and / or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services. Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) 2) 3) 4) 5) 6) 7) 1 BL / EDE Disk 1 C -190 Injection Profile 25-Dec~6 SCANNED FEB 1 4 2007 U:rð- 9D3 -003 :t!: I L.jt·-t9 (f Print Name: ~ Lt nL.(, f-I fA () ß11l fA ,A. II.- €ÁA RECE\VED fEB 1 4 Date : . ¡-~'(\f<' ,;I.jæ\æ úil & Gas Cons.WIn¡ ¡ ",,,,¡,, , Anchorage Signed: (2~ PRoACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: ?DSANCHORAGE@MEMORYLOG.COIll1 WEBSITE : \i\/1NW.MEMORYLOG.COM D:lMaster _Copy _00_ PDSANC-2OxxIZ _ W ord\Distribution\Transmittal_ Sheets\Transmít_ OriginaL doc . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/ Open Hole/ Mechanical Logs and / or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services. Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) 2) 3) 4) 5) 6) 7) 1 Report 1 Report 1 D - 128 1C - 190 MTT Log MTT Log 29-Dec-G6 UI.~ \'4~ - (33 ~ ~Q-OeC-06 U","" "'03 -<)0""D SCANNED JAN 0 8 2007 Signed: I ~}jv Date Print Name: ~ h ( ì ~f} I II Cl (l1fJ. 01/1 Ú P A/1 PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL. c...,;è, .;..~'..,'. ~ ~~~:', =< - ~ ,~' ','": "'-'0'" ,; WEBSITE: ','/,'Fi,·,.·,:=:.': >"......:'}.:':',..' D·\OO.PDSM>lC-2006\Z _ W ord\Dismbullon\ Transnuttal. Sheets\ Transnut. Onginal.doc I I I I I I I I I I I I I I I I I I I . . Memory Magnetic Thickness Tool Log Results Summary Company: ConocoPhíllips Alaska, Inc. Well: 1C-190 Log Date: December 30, 2006 Field: Kuparuk Log No. : 6140 State: Alaska Run No.: 1 API No.: 50-029-23136-00 Pipe1 Desc.: 4.5" 12.6 Ib L-80 NSCT Top Log Intvl.: Surface Pipe1 Use: Tubing Bot. Log Intvl.: 194 Ft. (MD) Pipe2 Desc.: 7.625" 29.71b L-80 Top Log Intvl.: Surface Pipe2 Use: Surface Casing Bot. Log Intvl.: 194 Ft. (MD) Pipe3 Desc.: 16" 62.50 Ib H-40 Top Log Intv!.: Surface Pipe3 Use: Conductor Pipe Bot. Log Intvl.: 110Ft. (MD) Inspection Type: Assess External Co"osive Damage (Metal Loss) to Surface Casing. COMMENTS: This MTT data is tied into the Mandrel Hanger @ 0' Depth. This is the first log of this well with the 12 Arm Magnetic Thickness Tool (MTT). The Magnetic Thickness Tool responds to the total thickness of metal of the 4.5" tubing and 7.625" surface casing, with some influence from the 16" conductor pipe. Due to the concentric pipe strings in the log interval, the MTT response is qualitative - indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. In this log, the MTT was calibrated down hole (190'), where the readings are assumed to represent undamaged tubing and casing. All other readings are relative to this reference point, which include influences from the 4.5" tubing, 7.625" casing, and 16" conductor pipe. INTERPRETATION OF MTT LOG RESULTS: The MTT log results cover the interval from surface to 194'. A log plot of the entire pass, plus a detailed section of any interval showing damage is included in this report. The Delta Metal Thickness (%) curve in these plots refers to total metal surrounding the MTT tool. A maximum of 17% circumferential metal loss is recorded in the interval between 0' - 2'. A 7% circumferential metal loss is recorded in the interval between 28' - 30'. A 6% circumferential metal loss is recorded in the interval between 57' - 58'. A 5% circumferential metal loss is recorded in the interval between 77' - 79'. A 4% isolated metal loss is recorded at -8'. A 3% circumferential metal loss is recorded in the interval between 6' - 7'. A 2% circumferential metal loss is recorded in the interval between 28' - 30'. The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which includes influences from the 4.5", 7.625" and 16" pipe. If all of the metal loss is specific to the 7.625" surface casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some ofthe metal loss indicated could be from either the 4.5" tubing or 16" conductor. r Field Engineer: D. Cain Analyst: M. Tahtouh & J. Burton "roActlve Diagnostic SerJices, Inc. P.O. Box 1369, Stafford, TX 77497 or (888) 565-9085 Fax: 565-1369 E-mali: PDS@memory!og.co Prudhoe Ba)i field (jffjce Phone: 659--2307 Fax: 659-2314 JAN 0 9 ZOUI u::cc.-. .903 -ó03 ..-son & Gas Cons AnchoragE I I I I I I I I I I I I I I I I I I I cI) ÇL¿S. Magnetic Thickness I (8 HZ Log) F'R<>ÀC1ivE DiAq.">sdc SERvicES, INC. Database File: d\warrior\data\1c-190 8hz analysis\1c-190.db Dataset Pathname: 8HLog.1 Presentation Format 26SCAL -1 Dataset Creation: Tue Jan 0214:52:472007 by Calc Sondex Warrior V7.0 Charted by: Depth in Feet scaled 1150 -- -50 Delta Metal Thickness (%) 50 2.6 MTTP01 (rad) 12.6 0 Line Speed (ftlmin) -200 -6.2 MTTP12 (rad) 3.8 ~- -LV I - - f-- I \ -10 :-~ - Tree -- "~""m Hanger . - _.~._- ~ 58 ~- Pup Jt -7625" Collar 3% Metal Loss - .~ 4% Metal Loss f- '" i 10 -'J , I q " .~ ~ ,~ - - ^^-~ - '- -. J ¡:iè - 4.5" ,.- ^--~ Jt. 1 fl \ 20 "J, I I i ~t -- ¡;;;;;.;; e-2% Metal Loss ~- ¡.. . ~+ull_1 . ;': ¡¡.. - 70~~M~t~~ 30 '_00_' II I -4.5" Collar~- Pup Jt - ~- It- 40 ~ T ¡--- R ~ 4 5" Collar m_ . 7. 625" Collar Pup Jt. J. LI 50 U6~ Metalloss 4.5" Collar -- - ...... 60 ;3.- ~ 1- __m f--- ~ I' ~ - .> 4.5" Jt. 2 I ¡ I~ -, + I -. ~ - -"" ¡---" ~- - -~% Metal Loss ,;;! Ii"" - -- ~- i I I I 80 í:. - , I I , ...... I I I I I I I I I I I I I I I I I I I ,..... ~ ~_. Em I~=i .5" Collar ~ 7.625" Collar 90 ""'] - f: -- - 4.5" --- f-- Jt 3 I!- = l - -- 100 I '1 I- - - --~ 1 - 1·---' t .d1 I--- +-- . ./ ,~Bottom of 16" Conductor \ ~4. Collar__ . -- 7~. 11 120 ;.- ~.. 7 __I "--- { í '.. ~ 4,5" ~ ..- f Jt 4 ""j, "~--- - \ ~r~ .. ::;., > t;;c > f--'- 130 i ,p' 7.,625" Collar ~--' 4'- I-- , , I--- 1 I¿ ~ - f--- , . , - ~.._- f--' f-- .... <I ~ ( 140 ~ ..; - "'~ T ::; -.. ~ 4.5" Collar- .-- f-- -¿- 150 ~ -f ::. - ( \.: --- 4.5" i -.: . -- Jt. 5 l . , ., 160 ( I~ { ~ , ~ I < ~:; - -- ....- 1-,-- f ~ 170 I-- I ....k. ~ .,--- ~I 1 .625" Collar Þ=l p- ~..- -. -,. . 1--- 4.5" Colla 180 ~ ( I , 4.5" ~ \ SI - ) --- --- . Jt 6 ..- =f -.. , ~ ¿ 190 f,,- .. . f' I j ! End of Log I-- T -50 Delta Metal Thickness (%) 50 26 MTTP01 (rad) 126 0 Line Speed (ftlmin) -200 -6.2 MTTP12 (rad) 3.8 I I I I I I I I I I I I I I I I I I I cIa ~~" . Magnetic Thickness I (8 HZ Log) p~ DiAq"""s'¡c SER";C"", INC. ,,, Database File: d\warrior\data\1c-190 0-25'\1c-190.db Dataset Pathname: 8HLog.1 Presentation Format: 26SCAL -1 Dataset Creation: Tue Jan 0214:52:472007 by Calc Sondex Warrior VTO Charted by: Depth in Feet scaled 150 -50 Delta Metal Thickness (%) 50 2.6 MTTP01 (rad) 12.6 0 Line Speed (ftJmin) -200 -6.2 MTTP12 (rad) 3.8 Tree , Hanger 0 7% Metal Loss I I Pup Jt ¡ t- :> ~""... ¡~1' ~A.5" Collar- - -",- 7625" Coll~r I I I = "S! ( -, .~ l~ \_-- 3% Metal Loss -- i$ r IL -1~ ,J ,,-~ --'" ( ~ I I I I ~~. " (, I) {" *' r;, <~!a:- 4% Metal Loss rf ~,,-- . ~-r- <--, 15 I ~.. <I' 10 < \. _.I I --.. I < I <:: t ) 1(" ~ 311 = I ( S I I ~ I c 'rl ) Jl < < I -- 4.5" :s ~ ~ <: ~ > .Jt 1 ~ < i "' [:.::> , ) < 1 " " i 'I I , ') J ~;,~ I ( 20 I I I ( 1 r-"- r / ¿ ¡ :» ) J j 1 f é ( ( 0( < ,; '1 ) ~ 2% Metal Loss S ) I I I < I { ;> < .¿ .~ ~ I ~~ ';;Þ 1<' < I .;::> "> i> :f l , 'I:' :;" 1 I I ~ D ¡-50 Delta Metal Thickness (%) 50 2.6 MTTP01 (rad) 12.6 0 Line Speed (ftJmin) -200 -6.2 MTTP12 (rad) 3.8 I I I I I I I I I I I I I I I I I I I Magnetic Thickness I (8 HZ Log) PRoAcTivE DiAq""",",1c SERvlCEi, INC. Database File: d\warrior\data\1c-190 28'-70'\1c-190.db Dataset Pathname: 8HLog.1 Presentation Format: 26SCAL -1 Dataset Creation: Tue Jan 02 14:52:472007 by Calc Sondex Warrior V7.0 Charted by: Depth in Feet scaled 175 - -50 Delta Metal Thickness (%) 50 2.6 MTTP01 (rad) 12.6 0 Line Speed (ft/min) -200 -6.2 MTTP12 (rad) 3.8 -lfF1 ~~ 1T ~ 45" :r---" .¿: '- Jt 1 ~ =>-, ¿~ 30 ,,~ ti%..Me:~ss ~!-. -I , ~.... I 1'- -,- ..,-- -- I 45" Collar t, , 1. 1 "'i ~ ' >- --1- -.- J- :~ I Pup Jt. ,¿ '~ :¡; I ~ "j ;." ":? 40 ~ f- t-- 1-M s. ê~ ) 1--+~- ^M_~ ·~o I 4.5" Collar r\ ·r25"collar...:.... ~ Pup Jt. ,/ ~ / i- ¡ 7 50 I :;- 12 ). ~.~ - 4.5" Collar !--I ~l- ".- I<~?I - -'^- ~ J '",," l ~ :> I~ I ..!1i íf- 6% Metal Loss :-- "" .- 1 ~, -- ) ,¿ ,~ 'C:¡ ,l 3- } 60 :> - ~ ;, ~ "'" > ,,¿ " <é,' - > . I~ r ;;:- ~ r- 4.5" Jt 2 - ;. ,,¿ !b < ? ':; ~, -~.,.. _. ~ 1= 1-= L ¡ r' I~ ..~- -. I l.i" t7 Il'" ¡> -50 Delta Metal Thickness (%) 50 26 MTTP01 (rad) 12.6 0 Line Speed (ft/min) -200 -6.2 MTTP12 (rad) 3.8 I I I I I I I I I I I I I I I I I I I <£ )5. Magnetic Thickness I (8 HZ Log) Pn<>A.ciIvE DIAq"""",;c SERvicES, INC. Database File: d \warrior\data \ 1 c-190 70-90'\1 c-190. db Dataset Pathname: 8HLog.1 Presentation Format: 26SCAL -1 Dataset Creation: Tue Jan 0214:52:472007 by Calc Sondex Warrior V7.0 Charted by: Depth in Feet scaled 160 "" ." -50 Delta Metal Thickness (%) 50 2.6 MTTP01 (rad) 12.6 0 Line Speed (ft/min) -200 -6.2 MTTP12 (rad) 3.8 I vv '\ gr Is 5?- *? :; 'if . :::- <~ t" ..., <! ",:::; ~ ."fb' ,~ .- --... :;::::- ? -~..." , <;;, /' ~ /' " '" :,. ¿ ~ \ " '5 ~ :> ~ "=' , ~ I I :? I I [) {, - I -=::: .¿ ,:Þ :> , 45" ( , FÞ ::.- '; . Jt 2 ì > ~ ='" ß;> , :. !;. , 'i 70 I ~5 ¡ , ; 11 '$ 2;. ~ffit <: '-" "- " ~-_. ------- ~ =- ¿ -, ) ~ .~ ) ~. % '- ) .). I '" i" ') ~, ~ ! I> > ' I '> :, ;> , j : ? .:. ,., ? I~ I / ,¡J - 5% Metal Loss ¿ ¿ ~~ I I I ~ '",."", S. -L... }'ii. I{ 1 ."¿ I-- 5% Metal Loss 1:> """ I '':¿ '< 80 ~ ~ "I m - ~ ~.... "': - - -= '-" 4.5" Collar , ) I ~ I ). ;> > .¿ ? } I ! ) ~ ? ~ 1< - ~ N.c 1#= I ~'i~1t ~ = ~¿ ~ 7. 625" Collar 90 = 1 L,,-- f-= ~ ~. J~ ~ ~ ;:....... ~ 4-5" )- [ :> I Jt. 3 i i I I <; ~T -,-,--- _----..L.... -50 Delta Metal Thickness (%) 50 2.6 MTTP01 (rad) 12.6 0 Line Speed (ft/min) -200 -62 MTTP12 (rad) 3.8 I I I TUBING (()..5298, 00:4.500. 10:3.958) I SURFACE (()..5449, 00:7625. Wt:29.70) NIP (515-516. 00:5.630) I Gas Lift I ndrellDummy Valve 1 (30.07-30.0.8, 00:5984) I I I NIP (4470-4471, OD:5.450.) I XO (5283-5285, 00:5.520.) I SEAL (5285-5286, 00:5.570) I Perf (5298-10466) I PACKER (5299-5300, 00:6.550) I I SLOTTED LINER (5287,10.466, 00:4.500, Wt:12.60) I I PACKOFF 104;31-104;32, 00:4.950) I I SHOE 10464-10465, 00:4.50.0) I KRU 1C-190 Thread WELDED BTC-MD NSCT Thread NSCT Vlv Cmnt ID 3.875 3.812 3.880 4.860 Descri tion ZXP PACKER - HRD PROFILE RS NIPPLE BAKER LINER PACKOFF BUSHING REAMER FLOAT SHOE ID 4.940 4.880 2.350 3.958 Note TREE: ABB-VErCO GRAY 16 X 7 518" X 4.5" 5000 psi, HORIZONTAL TREE CAP CONNECTION: OTIS 9" MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor -:-, ~ ¿'11 5/ Z3/D(,c, DATE: Monday, May 22,2006 FROM: Jeff Jones Petroleum Inspector SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC lC-190 KUPARUKRIVUWSAK IC-190 Src: Inspector ;00'3 C'\ 0 ~ Reviewed By: . J-i P.I. Suprv :íP:7- Comm Well Name: KUPARUK RIV U WSAK lC-190 API Well Number 50-029-23136-00-00 Inspector Name: Jeff Jones Insp Num: miUJ060508180233 Permit Number: 203-003-0 Inspection Date: 5/8/2006 ReI Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well IC-190 IType Inj. I W i TVD 3833 ! IA ! 0 1760 1750 1750 ! I 2030030 ITypeTest I SPI i Test psi lOA l I P.T. 1500 I Tubing i , Interval 4YRIST P/F P 673 873 874 874 ----L Notes I well house inspected; no exceptions noted. Monobore injector. NON-CONFIDENTIAL SCANNED J (' Monday, May 22, 2006 Page I of 1 e e ConocoPhillips Alaska, Inc. KRU 1C-190 1 C-190 API: 500292313600 Well Tvpe: INJ AnQle @ TS: deç¡ @ TUBING SSSV Type: NIPPLE Orig 3/11/2003 Angle @ TO: 91 deg @ 10466 (0-5298, Comoletion: 00:4.500, 10:3.958) Annular Fluid: Last W/O: Rev Reason: Taa Reference Log: 28' RKB Ref LOQ Date: Last Uodate: 2/27/2004 SURFACE Last Tag: 10447 E-line TO: 10466 ftKB (0-5449, 1-11I Last TaQ Date: 2/17/2004 Max Hole AnQle: 95 deQ @ 9068 00:7.625, Casino Strino - ALL STRINGS (Slotted liner-3 its 4.5" TBG/1 it 4.5" Slotted TBG (â)5324' to 10466') Wt29.70) NIP (515-516, Description Size Too Bottom TVD Wt Grade Thread 00:5.630) CONDUCTOR 16.000 0 110 110 62.50 H-40 WELDED SURFACE 7.625 0 5449 3834 29.70 L-80 BTC-MD SLOTTED LINER 4.500 5287 10466 10466 12.60 L-80 NSCT Tubing String - TUBING Size I Top I Bottom I TVD I Wt I Grade 1 Thread 4.500 ! 0 I 5298 I 3833 I 12.60 I L-80 I NSCT Gas Lift D Perforations Summary 'ndrelfOummy Interval TVD I Zone I Status 1 Ft I SPF I Date Tvpe I Comment Valve 1 (3007-3008, 5298 - 10466 I 3833 - 10466 I WS 0 I 151681 99 I 3/9/2003 IPERF I SLOTTED LINER I 00:5.984) Gas lift MandrelsNalves I St I MD I TVD I ~~~ Man Type I V Mfr I V Type I V OD I Latch I Port I TRO Date I Vlv Run Cmnt 1 I 30071 2710 I CAMCO KBG-2 I I DMY I 1.0 I BK I 0.000 I 0 14/13/20031 , Other (1IuQS eQuip., etc.) - JEWELRY Depth TVD Tvpe DescriPtion 10 NIP 515 513 NIP CAMCO 'DB' NIPPLE W/3.875 NO GO PROFILE 3.875 (4470-4471, II III 4470 3613 NIP CAMCO 'DB' NIPPLE W/3.812" NO GO PROFILE 3.812 00:5.450) 5283 3832 XO BAKER XO BUSHING VAM 3.880 5285 3832 SEAL BAKER BULLET SEAL ASSEMBLY WNAM BOX UP 4.860 Other (I lugs, equip., etc.) - LINER Depth TVD Tvpe DescriPtion 10 5299 3833 PACKER ZXP PACKER - HRD PROFILE 4.940 5307 3833 NIP RS NIPPLE 4.880 10431 3759 PACKOFF BAKER LINER PACKOFF BUSHING 2.350 xo 10464 3759 SHOE REAMER FLOAT SHOE 3.958 (5283-5285, General Notes 00:5.520) Date I Note 3/9/2003/TREE: ABB-VETCO GRAY 16 X 7 5/8" X 4.5" 5000 psi, HORIZONTAL SEAL TREE CAP CONNECTION: OTIS 9" (5285-5286, 00:5.570) 4~ii!~"W¡j!",\\~ Perf ::::: (5298-10466) ::::: == PACKER (5299-5300, 00:6.550) SLOTTED LINER (5287-10466, 00:4.500, Wt12.60) 1== 1== 1== I F= 1== PACKOFF ~ ~10431·10432, ~. I 00:4.950) = = ::::::: = == = I I = == I I SHOE == :10464-10465, I. I 00:4.500) . e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparukl KRU / DS 1 C 08/05/05 Rogers - AES ~err <3)tò{05 ~~~~~. Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us o P o P Well P.TD. Notes: Well P.TD. Notes: Well P.TD. Notes: Test Details: ~C^NNELj NO\[ 0 3 2005 TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) MIT Report Form Revised: 06/19/02 2005-0805_MIT _KRU _1 C-190_MITIA.xls ) l ~ 2 tJ ~ ,- DATA SUBMITTAL COMPLIANCE REPORT 4/1/2005 Permit to Drill 2030030 MD ---------- Well Name/No. KUPARUK RIV U WSAK 1C-190 Current Status WAGIN $;J ~J ~ 4¡' Pit. ~~- API No. 50-029-23136-00-00 CUIC~ -- Operator CONOCOPHILLlPS ALASKA INC ./ 3758 / Completion Date 3/11/2003 ~ Completion Status ~ 10466 TVD REQUIRED INFORMATION Samples No ~----- ----~_.- Mud Log No DATA INFORMATION Types Electric or Other Logs Run: GRI RES Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ,------ i I i ,. I~ I iL~ : -</ i Rpt I I i I 1 i , ~ ~ ¡,,~Og I..... , C 1 I I Lag-· I _____ log I~ ¡ .~ ¡Log Log Log Run Scale Media No ~ma Ray ~a Ray t.A::1Š'Verification 25 25 Blu Blu Induction/Resistivity 25 Blu ~t Evaluation 5 Col ~7 I nd uction/Resistivity 25 Blu LIS Verification tJR.jéétion Profile 15 Blu J Spinner 15 Blu "'"femperature 15 Blu ~ Pressure 15 Blu Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint) Interval OH/ ~ Start Stop CH Received Comments An H2S Measurement is required to be submitted. This record automatically created from Permit to Drill Module on: 1/28/2003. 120 1 0466 1R:.. 3/17/2003 120 10466 ~3/17/2003 120 1 0466 Case 3/17/2003 A Directional Survey Log is required to be submitted. This record automatically created from Permit to Drill Module on: 1/28/2003. 120 10466 Case 3/17/2003 4070 5250 Case 4/14/2003 120 1 0466 Case 3/17/2003 120 10466 Case 3/17/2003 5160 1 0445 Case 3/26/2004 Injection Profile - SpinnersfT emperatu re/Pres sure I 5160 1 0445 Case 3/26/2004 Injection Profile - I SpinnersfT emperatu re/Pres sure 5160 10445 Case 3/26/2004 Injection Profile - Spin nersfT emperature/Pres sure 5160 1 0445 Case 3/26/2004 Injection Profile - Spin nersfT emperatu re/Pres sure Permit to Drill 2030030 MD 10466 TVD 3758 Well Cores/Samples Information: Name ADDITIONAL INFORM}I:l0N Well Cored? Y ~ Chips Received? Y I N J Analysis Received? . Y IN -- ----~- Comments: ------ Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 4/1/2005 Well Name/No. KUPARUK RIV U WSAK 1C-190 Operator CONOCOPHILLlPS ALASKA INC Completion Date 3/11/2003 Completion Status WAGIN Interval Start Stop Sent Received Daily History Received? Formation Tops Jlo Current Status WAGIN Sample Set Number Comments @N (9N Date: API No. 50-029-23136-00-00 UIC Y -' (L~~~ 03/05/04 Scblumberger NO. 3125 Schlumberger -Des 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD '- 1 C-190ßl).:3-ms 1E-34/9Y '"/ [0 (~ 1C-15L 1~03rt7~ 2Z-10 \5\-C) -. L3~~ 2P-447ao~--10 Ll 10709706 10709710 10709713 10696843 10696847 INJECTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE/DEFT PERF/SBHP 02116104 02/21/04 02125104 02/26/04 03/01/04 1 1 1 1 1 -~ R:CEI\ "[0 ~ .. -......--- SIGNED: "r=~ l '\.:;. ~ -\---~) \.. (1 0-- ~ f::::-..J~ DATE: t·tÞ.I~ 26 2004 l"\~8Ska au & Gas Cons. Commission Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. flJid"rarage ~~""'" ._ ^ c:\ ') MEMORANDUM ) State of Alaska Alaska Oil and Gas Conservation Commission ''2/lìl TO: Randy Ruedrich I( q,/ ~J Chair " DATE: June 18,2003 SUBJECT: Mechanical Integrity Tests THRU: Jim Regg <f?IIA . 1~'(\07 ConocoPhillips Alaska Inc. P.I. Supervisor \~lt1 1C 190,09, 14, 17,26 FROM: John H. Spaulding Kuparuk River Unit Petroleum Inspector Kuparuk River Field NON· CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. Well 1C-190 Type Inj. S T.V.D. 3833 Tubing 1000 1000 1000 1000 Interval ./ P.T.D. 2030030 Type test P Test psi 958 Casing 3000 3000 3000 3000 P/F Notes: Well 1 C-09 Type Inj. S T.V.D. 6205 Tubing 2370 2368 2370 2367 Interval 4 P.TD. 1821850 Type test P Test psi 1551 Casing 400 3100 3125 3100 P/F f Notes: Well 1C-14 Type Inj. G T.V.D. 6259 Tubing 3806 3811 3826 3823 Interval 4 P.TD. 1980170 Type test P Test psi 1565 Casing 50 3000 3000 3000 P/F f Notes: Well 1C-17 Type Inj. S T.V.D. 6145 Tubing 2370 2370 2372 2367 Interval 4 P.TD. 1982240 Type test P T est psi 1536 Casing 1000 3100 3100 3050 P/F f Notes: Well 1 C-26 Type Inj. S T.V.D. 6433 Tubing 2258 2258 2257 2258 Interval 4 P.TD. 1990510 Type test P T est psi 1608 Casing 900 3000 3000 3000 P/F f Notes: Type INJ. Fluid Codes Type Test Interval F = FRESH WATER INJ. M= Annulus Monitoring 1= Initial Test G = GAS INJ. P= Standard Pressure Test 4= Four Year Cycle S = SALTWATER INJ. R= Internal Radioactive Tracer Survey V= Required by Variance N = NOT INJECTING A= Temperature Anomaly Survey W= Test during Workover D= Differential Temperature Test 0= Other (describe in notes) Test's Details M.I.T.'s performed: Attachments: Number of Failures: Total Time during tests: ~ MIT report form 5/12/00 L.G. 2003-0618_MIT _KRU_1 C-26~s.xls 7/9/2003 ") ) Randy Thomas . Kuparuk Drilling Team Leader Drilling & Wells ConocriP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 April 9, 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 1 C-190 (APD # 203-003) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the Kuparuk well 1 C-190. If you have any questions regarding this matter, please contact me at 265-6830. Sincerely, ~ \~ \,~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad RECEIVED APR 1 6 2003 Alaska Oi/ & Gas Cons. Commission Anchorage ORIGINAL STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ) ') 1. Status of well Classification of SelVice Well Oil 0 Gas 0 2. Name of Operator ConocoPhillips Alaska, Inc.'·-"""''--'''~ 3. Address 'l:j~·'~':l~t~~~L~I..l: P.O. Box 100360, Anchorage, AK 99510-0360 i. . ~, ."',,;. 4. location of well at surface .' ¡ ? ~I ~"'." 'ot '~~, 1638' FNL, 1393' FWL, Sec. 12, T11N, R10E, UM:: ,5C%,.';:D ¡ (ASP: 562401, 596860~}~;:;~;;;;~~~;~;); At Top Producing IntelVal;.__"....._,Z=-~ ~ 1562' FSL, 2077' FEL, Sec. 12, T11 N, R10E, UM ~ \iEnit..:n ~. (ASP: 564230, 5966538) At Total Depth 1 ........._,/?.....f¿_..-. ¡: !'.:...,·"..,.,.D¡,··....."""'·¡1,1It·'tI) O'\K".'\'I.....,.'·'__OC"':'^;,..,¡ 1462' FSL, 1957' FEL, Sec. 13, T11N, R10E, UM (ASP: 564397, 5961159) 5. Elevation in feet (indicate KB, DF, etc.) 6. lease Designation and Serial No. RKS 89' AMSL feet ADL 25649 & 25650 / ALK 467 & 468 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. February 24, 2003 March 6, 2003 March 11, 2003 f 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional SUlVey 10466' MD /3758' TVD 10466' MD I 3758' TVD YES 0 No 0 Suspended o Abandoned 0 SelVice 0 MW AG Injector 7. Permit Number 203-003 I 8. API Number 50-029-23136-00 9. Unit or lease Name Kuparuk River Unit 10. Well Number 1 C-190 11. Field and Pool West Sak Oil Pool Kuparuk River Field 15. Water Depth, if offshore N/A feetMSL 20. Depth where SSSV set DB nipple @ 515' 16. No. of Completions 1 21. Thickness of Permafrost 1900' MD 22. Type Electric or Other logs Run GR/Res 23. CASING SIZE WT. PER FT. 16" 62.5# 7.625" 29.7# 4.5" 12.6# GRADE B L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 120' Surface 5449' 5288' 10466' HOLE SIZE CEMENTING RECORD AMOUNT PULLED 42" 191 sx ArcticCrete 9.875" 6.75" 650 sx AS IIIL, 275 sx Class G slotted liner 4.5" TUBING RECORD DEPTH SET (MD) 5296' PACKER SET (MD) 5299' 24. Perforations open to Production (MD + TVD of Top and Bottom and intelVal, size and number) 25. SIZE slotted liner: 5298' - 10466' MD 3833' - 3758' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A Date of Test N/A Flow Tubing Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Injector Production for OIL-BBL GAS-MCF Test Period> Calculated OIL-BBL W A TER-BBL CHOKE SIZE GAS-Oil RATIO 27. Date First Production N/A Casing Pressure GAS-MCF W A TER-BBl OIL GRAVITY - API (corr) 24-Hour Rate> 28. CORE DATA RCCEIVt::U APR 1 6 2003 Alaska Oil & Gas Cons. Commission Anchorage Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A RIBDMS IBFl {oý CONT,INUED ON REVERS~ ¡ID\ L APR 30Md OR\G\I\1.-\ Submit in duplicate Form 10-407 Rev. 7-1-80 29. ') 30. ) GEOLOGIC MARKERS FORMATION TESTS MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR. and time of each phase. NAME Top D Sand Base D Sand 5076' 1 0466' 3807' 3759' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. RECEIVED APR 1 6 2003 Alaska Oil & Gas Cons. Commission Anchoragø Questions? Call Steve Shultz 265-6826 Signed~ ~ ~ "___Title . R. Thomal Kuparuk Drilling Team Leader Date ~ Ir'/O) Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 1 0-407 nRtG1NAL ) ') PaÇJe1 Öf .6 Legal Well Name: 1 C-190 Common Well Name: 1 C-190 Spud Date: 2/22/2003 Event Name: ROT - DRILLING Start: 2/21/2003 End: Contractor Name: n1334@ppco.com Rig Release: Group: Rig Name: Doyon 141 Rig Number: Date · From - To Hours Code Sub Phase Descriþtion otOperations ·Code 2/21/2003 12:00 - 00:00 12.00 MOVE DMOB MOVE Moving rig & camp from Oberon #1 to 1C-190. 32 miles. 2/22/2003 00:00 - 12:00 12.00 MOVE MOB MOVE Move rig from Oberon #1 to 1 C-190. 12:00 - 18:00 6.00 MOVE RURD MOVE Level sub-spot pits-pumps-motors-boilers-rockwasher & pipe shed modules. Hook up service lines-berm rockwasher & prep rig for acceptance. (accept rig @ 1800 hrs. 02/22/2003) 18:00 - 00:00 6.00 MOVE OTHR MOVE Nipple up starting head to conductor-test seals 1200# 5 mins.-nipple up diverter spool & annular-knife valve-install riser & nipple up diverter lines. 2/23/2003 00:00 - 01 :00 1.00 MOVE RURD MOVE Continue nipple up diverter line-hook up ace lines & charge ace-install 4" valves on conductor. 01 :00 - 05:00 4.00 MOVE RURD MOVE Load pipeshed wI 4" XT39-mixing spud mud-load 5" hwdp in shed & strap same. 05:00 - 07:00 2.00 MOVE RURD MOVE Pick up 5" hwdp & rack in derrick-1 std. flex wt. Calibrate H2S monitor. 07:00 - 08:30 1.50 MOVE RURD MOVE Pick up bit-bit breaker-xo,s-stabload 2 motors in pipe shed-pick up 4" handling equipment-safety valve-dart valve. 08:30 - 12:00 3.50 MOVE RURD MOVE Pick up 4" XT 39 & stand in derrick. 12:00 - 13:00 1.00 MOVE SFTY MOVE Held pre spud meeting wI crews & all service personel. 13:00 - 15:00 2.00 MOVE RURD MOVE Pick up 4" XT 39 dp & stand in derrick. 15:00 - 17:00 2.00 MOVE RURD MOVE Pick up bha & rih. 17:00 - 17:30 0.50 MOVE RURD MOVE Test diverter & accumulator-Knife valve opened in 5 sees. annular closed in 20 secs.30 sees. to build pressure from 200# 17:30 - 00:00 6.50 MOVE RURD MOVE Wait on wireline unit to set plug in 1 C-26. 2/24/2003 00:00 - 01 :30 1.50 WAlTON OTHR MOVE Wait on wireline unit to set plug in 1C-26. 01 :30 - 07:00 5.50 WAlTON OTHR MOVE Load pipe shed wI 126 jts. 4" XT 39 dp-strap & pick up-stand in derrick & rih wI bha. (While waiting on wireline unit to set plug. 07:00 - 12:00 5.00 WAlTON OTHR MOVE Wait on wireline unit to set plug in 1 C-26. 12:00 - 13:00 1.00 DRILL OTHR SURFAC Flood conductor-test surface equipment for leaks. 13:00 - 00:00 11.00 DRILL DRLG SURFAC Drlg. 97/8" surface hole from 120' to 1085'.AST 3.2 ART 2.8 WOB 15 -, RPM 80 GPM 590 PP 1900# MW 8.9 VIS 186 PU 75k SO 75k RW 75k TO on 2-3k TO off 2k 2/25/2003 00:00 - 18:00 18.00 DRILL DRLG SURFAC Drlg. & surveys from 1085' to 3138'. WOB 15-20k RPM 80 SPM 140 GPM 593 PP 2700 PU 104k SO 87k RW 96k TO on 5k TO off 4k AST 3.6 ART 8.2. 18:00 - 19:00 1.00 DRILL CIRC SURFAC Circ. hole clean for wiper trip. 19:00 - 21 :00 2.00 DRILL WIPR SURFAC Monitor well-poh to 1085'-hole in good shape-monitor well. 21 :00 - 22:30 1.50 DRILL WIPR SURFAC RIH-wash 90' to bottom-no fill-no bottoms up gas. 22:30 - 00:00 1.50 DRILL DRLG SURFAC Drlg. & surveys from 3138 to 3300'. (sliding to build angle.) 2/26/2003 00:00 - 00:00 24.00 DRILL DRLG SURFAC Drlg. & surveys from 3300' to 4670'. ART 7.3 AST 8.3 WOB 10/25k RPM 80 SPM 140 GPM 590 PP 3000# PUW 116k SOW 82k RW 95k TO on 8k OFF 7k HRS. on bit 33.4 Footage 4550 HRS. on jars 77.7 2/27/2003 00:00 - 19:30 19.50 DRILL DRLG SURFAC Drlg.-sliding-building angle from 4670' to 5246'. WOB 15/25k RPM 80 SPM 140 GPM 590 PP 3150# PUW 109k SOW 78k RW 93k TO on 7k TO off 6k MW 9.2 VIS 102 HRS. on bit 47 Footage 5126'. 19:30 - 21 :00 1.50 DRILL CIRC SURFAC Circ. hole clean wI hi-vis weighted sweep. 21 :00 - 00:00 3.00 DRILL WIPR SURFAC Monitor well-Wiper trip to 3130'-no hole problems-rih to 4250'. 2/28/2003 00:00 - 00:30 0.50 DRILL WIPR SURFAC Finish wiper trip (no problems) 00:30 - 02:30 2.00 DRILL CIRC SURFAC Circ. hole clean wI hi-vis weighted sweep. 02:30 - 06:00 3.50 DRILL TRIP SURFAC Monitor well-pump out of hole to 2900'-poh to bha @ 1085'-observe well. 06:00 - 08:00 2.00 DRILL PULD SURFAC Laying down bha to 296'. 08:00 - 09:00 1.00 DRILL CIRC SURFAC Work thru tight spots from 296' to 175'. (wash & ream) Lots of sand returns. 09:00 - 11 :00 2.00 DRILL PULD SURFAC Lay down remainder of bha-down load mwd. (NOTE) No cones left on Printed: 3/17/2003 3:25:48 PM ) ) ConocoPhiUips Alaska Operations Su mmary Report·· .Page.2of 6 Legal Well Name: 1 C-190 Common Well Name: 1 C-190 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To HourS· . Code Sub Phase ·Code 2/28/2003 09:00 - 11 :00 2.00 DRILL PULD SURFAC 11 :00 - 13:00 2.00 DRILL PULD SURFAC 13:00 - 14:30 1.50 DRILL TRIP SURFAC 14:30 - 16:30 2.00 DRILL TRIP SURFAC 16:30 - 18:00 1.50 DRILL CIRC SURFAC 18:00 - 21 :00 3.00 DRILL DRLG SURFAC 21 :00 - 23:00 2.00 DRILL CIRC SURFAC 23:00 - 00:00 1.00 DRILL TRIP SURFAC 3/1/2003 00:00 - 02:30 2.50 DRILL TRIP SURFAC 02:30 - 04:30 2.00 DRILL PULD SURFAC 04:30 - 06:30 2.00 CASE SFTY SURFAC 06:30 - 10:30 4.00 CASE RUNC SURFAC 10:30 - 11 :00 0.50 CASE CIRC SURFAC 11 :00 - 14:00 3.00 CASE RUNC SURFAC 14:00 - 14:30 0.50 CASE OTHR SURFAC 14:30 - 15:30 1.00 CASE CIRC SURFAC 15:30 - 16:00 0.50 CASE OTHR SURFAC 16:00 - 19:00 3.00 CASE CIRC SURFAC 19:00 - 21 :30 2.50 CEMENT PUMP SURFAC 3/2/2003 21 :30 - 22:00 0.50 CEMENT DISP SURFAC 22:00 - 23:00 1.00 CEMENT OTHR SURFAC 23:00 - 00:00 1.00 CEMENT SURFAC 00:00 - 02:30 2.50 CEMENT RURD SURFAC 02:30 - 07:00 4.50 CEMENT RURD SURFAC 07:00 - 12:00 5.00 WELCTL BOPE SURFAC 12:00 - 13:30 1.50 DRILL PULD SURFAC 13:30 - 15:00 1.50 DRILL DEOT SURFAC 15:00 - 16:30 1.50 DRILL PULD SURFAC 16:30 - 18:00 1.50 DRILL PULD SURFAC 18:00 - 19:00 1.00 RIGMNT RSRV SURFAC 19:00 - 21 :30 2.50 DRILL TRIP SURFAC 21 :30 - 22:30 1.00 DRILL OTHR SURFAC 22:30 - 00:00 1.50 CEMENT DSHO SURFAC 00:00 - 00:30 0.50 CEMENT DSHO SURFAC 00:30 - 02:00 1.50 DRILL CIRC SURFAC 02:00 - 02:30 0.50 DRILL FIT SURFAC 02:30 - 03:00 0.50 DRILL DEOT SURFAC 03:00 - 00:00 21.00 DRILL DRLH PROD 3/3/2003 Start: 2/21/2003 Rig Release: Rig Number: Spud Date: 2/22/2003 End: Group: Description of Operations bit. Change out motor-scribe & dress MXC1 97/8" bit. Make up bit-pick up bha #2 RI H- (Tight @ 695' & 815') shallow test mwd @ 1085'. RIH to 5100' (Restrictions in hole @ 1450'-1640'-2000'-2100' & 2300'. Wash & ream 146' to bottom. Circulate & work by junk Drlg. from 5246 to 5455' TVD 3835'. ADT 1.7 AST 1.2 WOB 5/15k RPM 80 SPM 136 GPM 577 PP 3100# PUW 108k SOW 74k RW 92 TO on 6k TO off 6k. MW 9.6 Vis 112. CBU-pump hi-vis weighted sweep-circ. hole clean BU X 4. Monitor well & poh for 7 5/8" csg. Finish poh to bha. Lay down all bha. Clear floor-rig up to run 7 5/8" csg. (PJSM) Run 7 5/8" csg. to 3000'. (no problems) Circ. capacity of 7 5/8" csg. (Fill csag. wI thin mud) Finish running total of 127 jts. 7 5/8" 29.7# L-80 BTCM csg. PUW 160k SOW 90k. Pick up landing jt. & hanger-land hanger on landing ring @ 5449'. Establish circ. & CBU thru fill up tool. Lay down fill up tool & pick up cement head. Circ. -reciprocate & condition mud for cementing 7 5/8" csg. @ 6 bpm (PJSM on cementing) Pump 10 bbls. cw100-test lines 3500#-pump 40 bbls. cw100 & 50 bbls. mud push @ 10.2# followed wI 533 bbls. lead cement @ 10.7# & 55 bbls. tail cement 15.8# @ 7 bpm. Kicked plug out wl5 bbls. water. Displace cement @ 7 bpm wI rig pump-pumped 241 bbls. mud-bumped plug on calculated strokes wI 500# over-held 5 mins. bleed off-floats held. Recovered 150 bbls. cement returns @ surlace. Flush diverter stack & purge cement lines. Rig down cement equipment-lay down landing jt. & clear floor. Clear floor & nipple down diverter system. Nipple up vetco well head-test to 1200# 10 mins. Nipple up bope & change lower rams to 4". Rig up & test bope 250-5000 Annular 250-3500. (Witness test waived by John Crisp AOGCC) Install wear ring & clear floor. Make up bha. Attempt mwd program-tool memory failed. Lay down mwd-pick up back up mwd & program same. Function test andergauge stab.-pulse test mwd-pick up flex collar-hwdp & jars. Slip & cut 55' drlg. line. RIH wI BHA #3 Tag cement @ 5355'. CBU. Rig up & test Csg. 3000# 30 mins. chart same. Drlg. plugs-float collar & soft cement to 5398'. Drlg. cement-shoe & 20' new hole from 5455 to 5475 Circ.-displace spud mud wI KCL mud. Perlorm FIT EMW 12.0. Function test andergauge stab. & mad pass from 5455 to 5475. Drlg. horizontal hole from 5475' to 7076' (3804 TVD) SPR #1 20 spm 390# 30 spm 520# #2 pump 20 spm 280# 30 spm 410# ART 9.4 hrs. AST 3.4 hrs. WOB 2-7k RPM 80 SPM 60 GPM 255 PP 1300# PUW 111 k SOW 55k RW 85k TO on 6k OFF 6k MW 8.8 VIS 53 Rig on Printed: 3/17/2003 3:25:48 PM ) ) ConocoPhillipsAlaska OperationsS u rtlmaryReport Page 3 016 Legal Well Name: 1 C-190 Common Well Name: 1 C-190 Spud Date: 2/22/2003 Event Name: ROT - DRILLING Start: 2/21/2003 End: Contractor Name: n 1334@ ppco.com Rig Release: Group: Rig Name: Doyon 141 Rig Number: Date From... To Hours Code Sub Phase Description of Operations Code 3/3/2003 03:00 - 00:00 21.00 DRILL DRLH PROD hi-line power @ 1600 hrs. 3/4/2003 00:00 - 09:15 9.25 DRILL DRLG PROD Drlg,Slide & Survey 6?" horizontal hole from 7076' to 7916 MD' (3795' TVD) WOB 2-3k, RPM 80, SPM 60, GPM 255, PP 1450# PUW 112k SOW 53k RW 85k TQ on bttm 8k OFF 7k MW 8.8+ VIS 53 - Pumped 35bbl weighted sweep 09:15 - 10:00 0.75 DRILL CIRC PROD Finish pumping weighted sweep to surface.Had 25% cutting increase to surface per Baroid. 10:00 - 12:00 2.00 DRILL DRLG PROD Drlg,Slide & Survey 6?" horizontal hole from 7916' to 8076 MD' (3794' TVD) WOB 2-3k, RPM 80, SPM 60, GPM 255, PP 1500# PUW 115k SOW 53k RW 85k TO on bttm 9k OFF 7k MW 8.8 VIS 53 - ART 2.9 hrs, AST 2.6 hrs total - Having some difficulty sliding - SO wt running 53k to 44k 12:00 - 00:00 12.00 DRILL DRLG PROD DrlgiSlide & Survey 6?" horizontal hole from 8076' to 8944' MD' (3786' TVD) WOB 3-7k, RPM 80 -110, SPM 70, GPM 297, PP 1700# PUW 118k SOW 48k RW 82k TO on bttm 9k OFF 7k MW 8.8 VIS 53 - ART 6.5 hrs, AST 0.7 hrs - Pumped 35bbl weighted sweeps @ 8664' & 8944' - Had 25-30% increase in cutting to surface on BU per Bariod - Having difficulty sliding - Added EZ glide lube to mud up to 4% - This did not seem to improve conditions any. Work with sweeps,RPMs,ROP & P rate to maximize hole cleaning and improve Slide paramatures. 3/5/2003 00:00 - 03:15 3.25 DRILL DRLG PROD Drlg,Slide & Survey 6?" horizontal hole from 8944' to 9037 MD' (3789' TVD) ART 1.1 hrs, AST 0.6 hrs WOB 3-10k, RPM 100, SPM 68, GPM 285, PP 2150psi, PUW 117k, SOW 40k, RW 84k Troq on bttm 9k, off 8k, MW 8.9ppg, Vis 53 ~ Having major problems sliding- We are not able to get wt to bit - SOW @ minimum 35-40k -Can not build angle due to low wt transfer to Bi t- EZ glide lube in mud @ 4% 03: 15 - 04:30 1.25 DRILL CIRC PROD Pump 30 bbl Weighted Sweep @ 11.2ppg - Circu hole until clean (Total 5784 stks) 2xBU - Moderate show of cutting @ BU. 04:30 - 10:00 5.50 DRILL WIPR PROD Wiper Trip to Shoe @ 5449' - Pump & Bk Ream OOH to shoe - 60 SPM, 255 gpm, 80 RPMs - No tight hole - No problems encountered. 10:00 - 11 :30 1.50 DRILL CIRC PROD Circu 30 bbl EP lube pill around ( 9% EP) - Con't to circu and mix EP lube to 1 % total in system. 11 :30 - 13:00 1.50 DRILL WIPR PROD TIH to 8106' (Std #83) 13:00 - 14:00 1.00 DRILL PULD PROD P/U 27 jts 33# 4" HT 38 Spiral Wt DCs to enhance SO wt. ( SW DCs start on top std #83) 14:00 - 14:30 0.50 DRILL REAM PROD Wash to Bttm - No Fill - @ BU minimul cutting increase from wiper trip. 14:30 - 14:45 0.25 DRILL SURV PROD Cycle Anderguage Stab closed - Ck shot survey @ 9,037'. 14:45 - 00:00 9.25 DRILL DRLG PROD Drlg, Slide & Survey 6?" horizontal hole from 9037' to 9800' MD' (3777' TVD) ART 3.0 hrs, AST 1.8 hrs WOB 2-7k, RPM 90, SPM 65, GPM 275, PP 1700psi, PUW 120k SOW 68k RW 95k Troq on bttm 6k, off 5k, MW 8.9ppg, Vis 53 - The wiper trip, adding EP lube & adding the 14k (net gain) in SO wt have helped alleviate wt transfer problems. Able to slide without any problems, with up to 33k of SO wt if needed. WOB has improved to the point that we can now build angle. 3/6/2003 00:00 - 08: 15 8.25 DRILL DRLG PROD Drlg,Slide & Survey 6?" horizontal hole from 9800' to 1 0,466' MD' (3758' TVD) ART 3.7 hrs, AST 0.9 hrs WOB 3-10k, RPM 100, SPM 68, GPM 285, PP 2150psi, PUW 120k, SOW 55k, RW 93k Troq on bttm 8.5k, off 8k, MW 9.0ppg, Vis 51 08:15 - 10:30 2.25 DRILL CIRC PROD Pump 35 bbl, 11.0ppg sweep - Circu hole until clean (total 9516 stks BU X2) Pump rate @ 75 SPM, 318 gpm, RPMs 110. Moderate show of cutting on BU. 10:30 - 13:30 3.00 DRILL TRIP PROD Bk Ream OOH to SWDCs @ 8943' PR 65 SPM, 275 gpm, RPMs 50 - Printed: 3/17/2003 3:25:48 PM ') ) ConocoPhillipsAlaska Page 40f 6 Operations Sumn'lé:1ry Report Legal Well Name: 1 C-190 Common Well Name: 1 C-190 Spud Date: 2/22/2003 Event Name: ROT - DRILLING Start: 2/21/2003 End: Contractor Name: n1334@ppco.com Rig Release: Group: Rig Name: Doyon 141 Rig Number: Date From - To Hours Code Sub Phase Description ·of .Operations Code 3/6/2003 1 0:30 - 13:30 3.00 DRILL TRIP PROD No Tight hole - No excess T orq 13:30 - 14:30 1.00 DRILL TRIP PROD TOH on elevators wI SWDCs & Std Bk on DS derrick 14:30 - 14:45 0.25 DRILL TRIP PROD TIH wI 4" XT 39 DP tI 8943' 14:45 - 19:00 4.25 DRILL TRIP PROD Con't Bk Reaming OOH tI 5488' - PR 65 SPM, 275 gpm, RPMs 50 - No Tight hole - No excess troq 19:00 - 20:45 1.75 DRILL CIRC PROD Pump 11.0ppg Wt Sweep - Circu hole clean - Baroid condition EP lube to solid 1 % in system 20:45 - 21 :00 0.25 DRILL TRIP PROD Monitor well - Pump dry job 21 :00 - 23:00 2.00 DRILL TRIP PROD TOH tI 353' 23:00 - 00:00 1.00 DRILL PULD PROD UD BHA #3 3/7/2003 00:00 - 01 :00 1.00 DRILL PULD PROD Con't UD BHA #3 - Clear all tools from Rig floor 01 :00 - 02:00 1.00 CASE RURD PROD R/U tools to run 4.5" Slotted Liner 02:00 - 02:15 0.25 CASE SFTY PROD PJSM - Hazard recognition while running liner 02:15 - 07:15 5.00 CASE PULR PROD PU & Run 168 jts slotted liner - Ran 2 blank jts with a slotted jt every fourth jt to shoe - (128 blank jts + 40 slot jts) Screen depths = Top slot jt @ 5602' and the lower slot jt @ 1 0,402' - Ran one 4.5" X 6..5" solid straight bladed centrilizer per jt. Floating between collars. (168 total) 07:15 - 08:15 1.00 CASE RURD PROD R/U to run 2.875" inner wash string. 08:15 - 08:30 0.25 CASE SFTY PROD PJSM - Hazard recognition running inner string - This is a non-standard activity - Discussed all associated hazards and pinch points. 08:30 - 14:30 6.00 CASE PUTB PROD P/U & run 170 jts 2.875" inner wash string. 14:30 - 14:45 0.25 CASE PUTB PROD Space out wash string - Slick stick no go 2' above Baker packoff @ ( 34' above shoe) 14:45 - 15:00 0.25 CASE RUNL PROD M/U Baker Liner hanger assy. 15:00 - 15:30 0.50 CASE RUNL PROD Baker Rep prep Hanger assy to RIH 15:30 - 15:45 0.25 CASE CIRC PROD P/U 1 std XT39 DP - Circu Pipe volume @ shoe PRate 3 bpm, 550 psi, Up wt 95k, Dn wt 77k 15:45 - 22:15 6.50 CASE RUNL PROD RIH wI Liner on 4" XT39 DP - Ran 24 stds 4" DP. P/U and ran 9 stds SWDCs, followed by 23 stds of 4" DP. Tag bttm at 10.466' - Top of SWDCs 2213' from surface. Recorded T & D every 5 stds.- @ TD Up wt 115k, Dn wt 60k - After well CIO to seawater, Up wt 106k, Dnwt 74k ***Note**** Liner ran well - Saw NO excess dn wt 22:15 - 00:00 1.75 CASE CIRC PROD Est circu & stage up rate to 4 bpm , 1050 psi - Pump 25 bbl Hi Vis spacer - Displace well to seawater 8.6ppg - PRate 4 bpm, 168 gpm , PP 1190 psi, Recip string 20' 3/8/2003 00:00 - 01 :00 1.00 CASE CIRC PROD Con't displace well to seawater - PR @ 4 bpm , 1070 psi - Recip String 20' 01 :00 - 02:00 1.00 CASE CIRC PROD Drop & pump dn 1.5" setting ball @ 4 bpm - Slow PR to 2.5 bpm to land ball, pressure up slowly to 3300 psi - Ball seat sheared prematurely @ 3000 psi - Slack off and set 30k wt to verify hanger was set - "OK" - Work 2 rounds LH torq (max 5k torq) down to the release tool, PU to 100k -Tool did not release, slack back off to neutral. Work 2 more rounds LH torq (max 7k torq) down to release tool, PU 1 05k- Tool did not release, slacked back off to neutral. Rotated to the right and shear off safety release. Safety sheared and PU 97k up wt - Liner released ( Top of Tie Back Sleeve @ 5288') - PU 12' to unseat wash string from packoff . 02:00 - 04: 15 2.25 CASE CIRC PROD Circu inner string X 4.5" liner annulus at 5.5 bpm and 500 psi, until clean seawater returns were seen at the surface, as per the Baroid rep. 04:15 - 05:15 1.00 CASE CIRC PROD Monitor well - Mix & Pump dry job - Blw dn TD 05:15 - 08:00 2.75 CASE CIRC PROD TOH wI running tool- Baker running tool sub had backed off @ 3.5" IF conn leaving XO and wash string in hole. 08:00 - 09:00 1.00 CASE RURD PROD Make service breaks on running tool & UD same. Printed: 3/17/2003 3:25:48 PM ) ) ConocoPhiUips Alaskà Operations Summary Røport Legal Well Name: 1 C-190 Common Well Name: 1 C-190 Event Name: ROT - DRILLING Contractor Name: n1334@ ppco.com Rig Name: Doyon 141 Date From,,;To . Hours . Code ..Sub Phase· Code 3/8/2003 09:00 - 11 :30 2.50 FISH TRIP PROD 11 :30 - 12:00 0.50 FISH CIRC PROD 12:00 - 12:30 0.50 FISH FISH PROD 12:30 - 12:45 0.25 FISH FISH PROD 12:45 - 13:00 0.25 FISH TRIP PROD 13:00 - 15:45 2.75 FISH CIRC PROD 3/9/2003 15:45 - 19:30 3.75 FISH TRIP PROD 19:30 - 20:15 0.75 FISH PULD PROD 20: 15 - 20:30 0.25 CASE RURD PROD 20:30 - 00:00 3.50 CASE OTHR PROD 00:00 - 01 :30 1.50 CASE OTHR PROD 01 :30 - 01 :45 0.25 LOG SFTY PROD 01 :45 - 03:00 1.25 LOG RURD PROD 03:00 - 04:30 1.50 LOG ELOG PROD 04:30 - 06:00 1.50 LOG ELOG PROD 06:00 - 07:45 1.75 LOG OTHR PROD 07:45 - 09:30 1.75 LOG ELOG PROD 09:30 - 11 :15 1.75 LOG ELOG PROD 11 : 15 - 13: 15 2.00 LOG ELOG PROD 13:15 - 14:15 1.00 DRILL PULD PROD 14:15 - 15:15 1.00 RIGMNT RSRV PROD 15:15 - 17:00 1.75 DRILL. TRIP PROD 17:00 - 20:30 3.50 DRILL PULD PROD 20:30 - 21 :45 1.25 DRILL TRIP PROD 21 :45 - 00:00 2.25 DRILL PULD PROD 00:00-01:15 1.25 DRILL PULD PROD 01 : 15 - 01 :45 0.50 CMPL TN RURD CMPL TN 01 :45 - 02:15 0.50 CMPL TN RURD CMPL TN 02:15 - 02:30 0.25 CMPL TN SFTY CMPL TN 02:30 - 05:00 2.50 CMPL TN RUNT CMPL TN 05:00 - 09:30 4.50 WAlTON EQIP CMPL TN 09:30 - 13:00 3.50 CMPL TN RUNT CMPL TN 13:00 - 14:45 1.75 CMPLTN CIRC CMPL TN 14:45 - 15:45 1.00 CMPL TN SOHO CMPL TN 15:45 - 16:30 0.75 CMPL TN SEQT CMPL TN 16:30 - 17:00 0.50 CMPL TN RURD CMPL TN 17:00 - 19:30 2.50 CMPL TN RUNT CMPL TN 19:30 - 20:30 1.00 CMPL TN RURD CMPL TN 3/1 0/2003 Start: 2/21/2003 Rig Release: Rig Number: Spud Date: 2/22/2003 End: Group: Description of Operations TIH tI 5234' Break circu - Record PU & SO wts Wash to fish @ 5295' - Screw into 3.5" IF conn on fish wI 4.5 rounds, @ 5500 ft-Ibs torq (fish turning w/5500 ft-Ib torq). Test & ck set packer - Pressure up DP x casing Annulus to 2000 psi to test liner top packer. - Hold for 5 min to assure packer was set. P/U wash string to clear packoff to 5171'. (PU wt increased by 6K). Circu wI head pin & flush mud from inner 4.5" ann w/ seawater. - Circu @ 6 bpm @ 490 psi - Circu until clean per Baroid rep. - Simultaneously C/O swivel pk and service top drive. TOH w/fish - UD 3 jts DP (std#1) UD and inspect Baker running tool. R/U to UD 2.875" Tbg wash string. UD 2.875" Tbg wash string. Con't UD 2.875" wash string PJSM w/ Crew & SWS - Wireline Hazards recognition. R/U SWS wire line - Assemble tools for first run Run #1 - USIT Log wI Tractor - TIH to 4964' free fall (76.5 degrees) Tractor was powered up - Had instant power failure. TOH wI Run #1 - Hang tools - E- Line head completely shorted out.- Remove head. Rebuild wireline head TIH w/ Run #2 to 5250' Run USIT Log fl 5250' to 4070' TOH wI Run #2 - UD logging tools - RID SWS TIH w/9 stds SWDCs out of derrick - TOH & UD same Slip & Cut drill line (65' cut) - Pre-test swivel pkg 3200 psi "OK" TIH w/51 stds 4" DP from derrick. ( 4800') TOH UD 4" DP TIH with remaining 50 stds 4" DP from derrick. (4700') TOH UD 4" DP (@ midnight 1928' DP in hole) 62 jts Con't UD 4" XT39 DP - Clean subs & tools from Rig floor. ***Note*** AOGCC rep (John Spaulding) waived BOP test due 3/9/03. R/U & Pull wear bushing. R/U to run 4.5" completion tbg PJSM - Running Completion & detail review and hazard recognition. Run 4.5", 12.6#, L80, NSCT completion tbg - After reaching jt #73 the 4.5" x 1.5 MMG GLM was to be installed. It was found to have too large a body OD ( 7.031") to run in the 6.875" ID of 7.625" surface csg. UD MMG GLM - Ordered 4.5" x 1" KBG-2 wI DCR shear valve ( BK latch) - Wait on same - While waiting cleaned and doped 4" DP layed down earlier. Run 4.5",12.6#, L80, NSCT completion tbg - Tag TOL at 5288'. UWT = 77K, DWT =68K) P/U to 5280' - Circu 520 bbls clean seawater @ 5 bpm , 250 psi UD 2 jts tbg & Space out with 9.78' +9.70' pup jts. M/U Tbg hanger & Land Tbg - RILDS. T est hanger void to 250 / 5000 psi f/ 10 min " OK" - Pressure test 7.625' X 4.5" annulus to 2500 psi and chart for 30 min UD Landing Jt - Set BPV N/D BOPs - Remove Air boot pan N/U Tree - Test packoff 5000 psi f/10 min Printed: 3/17/2003 3:25:48 PM ) ) Page6of6 ConocoPhillips Alaska OpèrationsSult1maryReport Legal Well Name: 1 C-190 Common Well Name: 1 C-1 90 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From- To . Cd· Sub Phase Hours· . 0 e Code 3/10/2003 20:30 - 21 :15 0.75 CMPL TN SEaT CMPL TN 21:15-22:00 0.75 CMPL TN FRZP CMPL TN 22:00 - 00:00 2.00 CMPL TN FRZP CMPL TN 3/11/2003 00:00 - 01 :00 1.00 CMPL TN RURD CMPL TN 01 :00 - 01 :30 0.50 CMPL TN RURD CMPL TN Start: 2/21/2003 Rig Release: Rig Number: Spud Date: 2/22/2003 End: Group: Pull SPV - Set TWC - Test tree 250 I 5000 psi fl 10 min "OK" Pull TWC - R/U & pressure up on 7.625' x 4.5" annulus (27 stks) to 3150 psi, shear RP valve @ 3009'. Pump 5 bbls water wI returns frrbg. Circu diesel to surface pumping down 7.625" x 4.5" annulus. Total 114 bbls @ 3 bpm, 1300 psi. Install SPV - UD lubricator- Secure tree cap Install flow line Hyd accuated valve - Install all valve hands - All ports are flanged wI taped bull plugs, valves w/guages. - Secure Well Release Rig @ 0130 hrs 3/11/03 Printed: 3/17/2003 3:25:48 PM ) ) ConocoPhillips Alaska, Inc. Pad lC 190 slot #190 Kuparuk River Unit North Slope, Alaska SUR V E Y LIS TIN G by Baker Hughes INTEQ Your ref Our ref License MWD <0-10466'> svy6852 Date printed Date created Last revised 10-Mar-2003 25-Feb-2003 7-Mar-2003 Field is centred on n70 16 18.576,wI50 5 56.536 Structure is centred on n70 19 45.173,wI49 30 19.124 Slot location is n70 19 29.066,wI49 29 38.421 Slot Grid coordinates are N 5968602.070, E 562401.260 Slot local coordinates are 1637.60 S 1394.49 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ) ') conocoPhillips Alaska, Inc. SURVEY LISTING Page 1 Pad 1C,190 Your ref MWD <0-10466'> Kuparuk River Unit,North Slope, Alaska Last revised : 7-Mar-2003 Measured Inclin Azimuth True Vert RECTANGULAR Dogleg Vert G RID COO R D S Depth Degrees Degrees Depth COO R D I N ATE S Deq/100ft Sect Easting Northing 0.00 0.00 0.00 0.00 O.OON O.OOE 0.00 0.00 562401.26 5968602.07 120.00 0.00 0.00 120.00 O.OON O.OOE 0.00 0.00 562401.26 5968602.07 205.47 0.83 119.62 205.47 0.31S 0.54E 0.97 0.57 562401.80 5968601.77 293.26 3.25 114.29 293.19 1.64S 3.36E 2.76 3.38 562404.63 5968600.45 382.55 6.33 115 . 95 382.16 4.84S 10.09E 3.45 10.08 562411.39 5968597.31 475.91 9.22 114.79 474.65 10.23S 21.51E 3.10 21. 41 562422.85 5968592.02 562.64 11.51 113.79 559.96 16.635 35.74E 2.65 35.29 562437.13 5968585.73 657.14 12.33 113.28 652.42 24.435 53.64E 0.87 52'.54 562455.09 5968578.08 744.32 12.27 113.02 737.60 31.735 70.71E 0.09 68.89 562472.22 5968570.92 836.65 13.37 114 . 45 827.63 39.98S 89.46E 1.24 87.04 562491. 04 5968562.82 925.58 15.27 111.72 913.80 48.575 109.70E 2.27 106.37 562511.34 5968554.40 1016.31 17.85 113.71 1000.76 58.595 133.54E 2.91 129.06 562535.26 5968544.58 1111. 38 20.25 117.87 1090.62 72 .145 161. 43E 2.90 157.05 562563.26 5968531. 25 1205.94 21.10 120.31 1179.09 88.385 190.59E 1.28 187.92 562592.55 5968515.25 1299.46 22.54 122.22 1265.91 106.435 220.29E 1.72 220.56 562622.39 5968497.44 1392.93 24.69 126.39 1351. 55 127.575 251.17E 2.91 256.33 562653.43 5968476.56 1486.97 27.51 129.36 1436.00 153.005 283.78E 3.30 296.55 562686.24 5968451.39 1577.82 27.95 128.99 1516.41 179.715 316.S5E 0.52 337.86 562719.23 5968424.96 1672.62 29.75 131.22 1599.44 209.195 351.51E 2.21 382.70 562754.43 5968395.77 1765.98 32.06 130.47 1679.54 240.54S 387.79E 2.51 429.83 562790.96 5968364.72 1858.43 33.83 130.02 1757.12 273.015 426.17E 1. 93 479.15 562829.59 5968332.56 1952.46 33.71 128.37 1835.29 306.04S 466.67E 0.98 530.23 562870.36 5968299.86 2044.69 33.23 129.54 1912.23 338.02S 506.23E 0.87 579.89 562910.17 5968268.21 2139.04 35.65 127.39 1990.04 371.18S 548.02E 2.87 631.87 562952.22 5968235.39 2232.02 35.32 126.09 2065.75 403.46S 591.26E 0.89 684.08 562995.73 5968203.46 2325.92 34.50 128.22 2142.75 435.91S 634.09E 1. 56 736.14 563038.82 5968171.37 2420.16 34.23 128.20 2220.54 468.815 675.89E 0.29 787.93 563080.88 5968138.81 2513.15 33.74 127.59 2297.65 500.74S 716.91E 0.64 838.46 563122.15 5968107.22 2607.29 33.19 127.73 2376.18 532.465 758.00E 0.59 888.88 563163.50 5968075.85 2700.70 32.82 128.44 2454.52 563.848 798.05E 0.57 938.39 563203.79 5968044.79 2793.28 32.54 130.62 2532.45 595.65S 836.61E 1.31 987.29 563242.60 5968013.30 2886.64 34.45 130.60 2610.30 629.18S 875.72E 2.05 1037.90 563281.98 5967980.09 2980.02 34.21 130.86 2687.41 663.54S 915.62E 0.30 1089.64 563322.16 5967946.05 3074.73 33.63 131.13 2766.00 698.21S 955.52E 0.63 1141.62 563362.33 5967911.71 3169.02 33.18 131.11 2844.72 732.35S 994.62E 0.48 1192.69 563401.71 5967877.90 3258.70 35.15 133.23 2918.92 766.17S 1031.93E 2.57 1242.39 563439.28 5967844.38 3354.24 39.18 138.93 2995.06 807.79S 1071.82E 5.54 1299.81 563479.51 5967803.09 3446.80 42.46 135.98 3065.11 852.32S 1112.75E 4.11 1360.14 563520.80 5967758.91 3541.79 47.50 140.31 3132.29 902.36S 1157.44E 6.21 1427.13 563565.88 5967709.23 3633.06 51.70 142.93 3191. 44 956.86S 1200.54E 5.09 1496.60 563609.42 5967655.09 3726.80 55.53 143.39 3247.04 1017.258 1245.77E 4.10 1572.02 563655.14 5967595.08 3819.05 58.96 143.24 3296.94 1079.45S 1292.11E 3.72 1649.55 563701.98 5967533.26 3913.56 59.44 143.89 3345.33 1144.77S 1340.32E 0.78 1730.67 563750.72 5967468.35 4007.15 61. 89 144.13 3391.18 1210.78S 1388.26E 2.63 1812.17 563799.19 5967402.73 4101.04 62.09 144.49 3435.27 1278.108 1436.62E 0.40 1894.96 563848.09 5967335.81 4194.01 61.40 144.54 3479.29 1344.78S 1484.16E 0.74 1976.73 563896.16 5967269.53 4287.79 60.73 144.86 3524.66 1411.76S 1531.59E 0.77 2058.67 563944.13 5967202.94 4381.36 60.66 146.24 3570.46 1479.05S 1577.74E 1.29 2140.05 563990.82 5967136.04 4474.33 62.53 148.76 3614.69 1548.01S 1621.66E 3.12 2221. 36 564035.30 5967067.44 4569.74 65.45 151.60 3656.53 1622.40S 1664.27E 4.06 2306.08 564078.50 5966993.41 All data in feet unless otherwise stated. Calculation uses min~um curvature method. Coordinates from slot *190 and TVD from RKB(Doyon 141) (87.20 Ft above mean sea level). Bottom hole distance is 7705.65 on azimuth 165.47 degrees from wellhead. Vertical section is from wellhead on azimuth 141.43 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ) ) ConocoPhillips Alaska, Inc. 5URVEY LI5TING Page 2 Pad 1C,190 Your ref MWD <0-10466'> Kuparuk River Unit,North Slope, Alaska Last revised : 7-Mar-2003 Measured Inclin Az imuth True Vert R E C TAN GULAR Dogleg Vert G RID COO R D 5 Depth Degrees Degrees Depth COO RDINATES Deg/100ft Sect Easting Northing 4660.48 69.00 155.58 3691.66 1697.325 1701.43E 5.63 2387.83 564116.27 5966918.80 4753.35 71.01 159.75 3723.43 1778.03S 1734.57E 4.74 2471.59 564150.06 5966838.37 4848.92 73.20 163.80 3752.80 1864.395 1762.98E 4.64 2556.83 564179.17 5966752.25 4940.43 75.44 168.02 3777.55 1949.82S 1784.41E 5.07 2636.98 564201.29 5966667.01 5035.36 78.07 168.44 3799.29 2040.285 1803.25E 2.80 2719.45 564220.87 5966576.72 5128.99 81.17 170.44 3816.16 2130.80S 1820.12E 3.92 2800.75 564238.47 5966486.34 5181.92 82.90 172.06 3823.50 2182.61S 1828.09E 4.46 2846.22 564246.86 5966434.61 5224.31 84.26 172.43 3828.24 2224.345 1833.78E 3.32 2882.40 564252.88 5966392.92 5316.05 88.62 176.43 3833.93 2315.435 1842.65E 6.44 2959.15 564262.50 5966301.91 5393.73 90.06 178.03 3834.83 2393.01S 1846.41E 2.77 3022.15 564266.88 5966224.37 5522.85 91.66 181.14 3832.89 2522.105 1847.34E 2.71 3123.66 564268.87 5966095.32 5616.70 91. 97 180.57 3829.92 2615.895 1845.94E 0.69 3196.12 564268.23 5966001.53 5709.85 91.84 181.43 3826.82 2708.97S 1844.32E 0.93 3267.89 564267.36 5965908.44 5801.70 90.40 179.89 3825.03 2800.79S 1843.26E 2.30 3339.02 564267.05 5965816.62 5890.69 91.20 178.73 3823.78 2889.765 1844.33E 1.58 3409.25 564268.85 5965727.67 5930.17 90.74 177 . 29 3823.12 2929.21S 1845.70E 3.83 3440.95 564270.54 5965688.24 5990. 61 89.17 177 . 12 3823.16 2989.585 1848.65E 2.61 3489.99 564273.97 5965627.90 6083.22 93.90 178.14 3820.68 3082.05S 1852.48E 5.22 3564.67 564278.55 5965535.48 6176.50 91.08 179.23 3816.63 3175.215 1854.62E 3.24 3638.84 564281.45 5965442.35 6269.99 90.68 178.51 3815.20 3268.675 1856.46E 0.88 3713.07 564284.05 5965348.92 6363.49 90.98 178.66 3813.84 3362.135 1858.77E 0.36 3787.58 564287.12 5965255.49 6457.68 92.33 181.87 3811.12 3456.26S 1858.33E 3.70 3860.91 564287.45 5965161.36 6550.16 89.97 182.58 3809.26 3548.655 1854.74E 2.66 3930.90 564284.61 5965068.96 6644.27 91. 20 181.87 3808.30 3642.685 1851.09E 1. 51 4002.15 564281.72 5964974.91 6737.39 91. 59 181.70 3806.04 3735.735 1848.19E 0.46 4073.09 564279.58 5964881.85 6831.72 90.64 182.95 3804.20 3829.965 1844.36E 1. 66 4144.38 564276.52 5964787.60 6923.00 90.31 183.24 3803.44 3921.10S 1839.44E 0.48 4212.57 564272.33 5964696.43 7016.69 90.55 181.82 3802.74 4014.705 1835.30E 1. 54 4283.17 564268.96 5964602.81 7109.87 89.39 181. 31 3802.79 4107.845 1832.76E 1.36 4354.41 564267.17 5964509.66 7202.26 90.52 179.43 3802.86 4200.225 1832.16E 2.37 4426.27 564267.33 5964417.28 7297.30 90.95 181. 29 3801. 64 4295.255 1831.56E 2.01 4500.20 564267.50 5964322.27 7389.80 90.86 179.24 3800.18 4387.735 1831.13E 2.22 4572.24 564267.83 5964229.79 7482.88 90.77 177 .03 3798.86 4480.745 1834.16E 2.38 4646.85 564271.61 5964136.81 7577.12 91.07 177 . 55 3797.34 4574.875 1838.62E 0.64 4723.22 564276.83 5964042.74 7670.03 91.07 174.17 3795.61 4667.505 1845.32E 3.64 4799.83 564284.29 5963950.17 7764.03 89.33 173.90 3795.28 4760.995 1855.09E 1. 87 4879.02 564294.82 5963856.77 7856.86 90.76 175.06 3795.21 4853.395 1864.02E 1. 98 4956.82 564304.50 5963764.46 7949.70 89.72 175.33 3794.82 4945.905 1871.80E 1.16 5034.00 564313.02 5963672.02 8043.79 90.61 174.97 3794.55 5039.655 1879.75E 1.02 5112.27 564321.74 5963578.35 8137.26 90.18 175.37 3793.90 5132.795 1887.62E 0.63 5189.99 564330.36 5963485.29 8230.25 89.51 177 . 95 3794.15 5225.615 1893.04E 2.87 5265.94 564336.54 5963392.52 8324.38 88.96 177 .49 3795.41 5319.665 1896.78E 0.76 5341.81 564341.04 5963298.52 8418.12 91. 78 178.94 3794.81 5413.345 1899.70E 3.38 5416.88 564344.73 5963204.87 8512.23 89.02 175.97 3794.15 5507.335 1903.88E 4.31 5492.97 564349.67 5963110.92 8605.18 91.81 176.15 3793.48 5600.055 1910.27E 3.01 5569.45 564356.81 5963018.27 8698.01 91.50 178.21 3790.79 5692.725 1914.83E 2.24 5644.75 564362.12 5962925.65 8791.40 91.13 176.37 3788.65 5785.985 1919.25E 2.01 5720.42 564367.30 5962832.44 8883.18 89.02 179.01 3788.53 5877.675 1922.95E 3.68 5794.42 564371.74 5962740.79 8976.52 88.77 178.44 3790.33 5970.975 1925.02E 0.67 5868.66 564374.57 5962647.52 9068.10 94.98 178.26 3787.34 6062.425 1927.66E 6.78 5941.80 564377.95 5962556.10 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #190 and TVD from RKB(Doyon 141) (87.20 Ft above mean sea level). Bottom hole distance is 7705.65 on azimuth 165.47 degrees from wellhead. Vertical section is from wellhead on azimuth 141.43 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ) ) ConocoPhillips Alaska, Inc. 8URVEY LISTING Page 3 Pad 1C,190 Your ref MWD <0-10466'> Kuparuk River Unit,North Slope, Alaska Last revised : 7-Mar-2003 Measured Inclin Azimuth True Vert RECTAN GULAR Dogleg Vert G RID COORDS Depth Degrees Degrees Depth COO R D I NATE8 Deg/100ft Sect Easting Northing 9161.34 93.60 180.50 3780.36 6155.398 1928.66E 2.82 6015.12 564379.71 5962463.16 9254.22 91. 41 180.84 3776.30 6248.168 1927.58E 2.39 6086.98 564379.38 5962370.38 9348. 18 87.82 179.69 3776.93 6342.108 1927.14E 4.01 6160.16 564379.71 5962276.45 9443.70 88.74 179.25 3779.80 6437.58S 1928.02E 1.07 6235.36 564381.37 5962181.00 9533.75 90.25 178.34 3780.59 6527.608 1929.92E 1.96 6306.92 564383.99 5962091.00 9627.81 90.12 178.19 3780.29 6621.628 1932.77E 0.21 6382.21 564387.61 5961997.02 9721.79 89.63 179.51 3780.49 6715.578 1934.65E 1.50 6456.85 564390.25 5961903.09 9815.16 92.76 179.81 3778.55 6808.918 1935.21E 3.37 6530.17 564391.57 5961809.77 9907.72 93.10 181.81 3773.82 6901.348 1933.90E 2.19 6601.62 564391.01 5961717.35 10001.91 94.05 180.59 3767.94 6995.328 1931.93E 1. 64 6673.87 564389.81 5961623.36 10094.46 92.30 179.01 3762.82 7087.728 1932.25E 2.55 6746.32 564390.88 5961530.97 10187.94 88.96 177 . 95 3761. 79 7181.158 1934.73E 3.75 6820.91 564394.12 5961437.58 10281.41 91.26 180.81 3761.61 7274.598 1935.74E 3.93 6894.61 564395.89 5961344.15 10375.21 90.31 180.21 3760.32 7368.388 1934.91E 1.20 6967.42 564395.82 5961250.37 10408.06 91.29 181. 06 3759.87 7401. 228 1934.55E 3.95 6992.87 564395.72 5961217.53 10466.00 91.29 181.06 3758.56 7459.148 1933.47E 0.00 7037.48 564395.12 5961159.61 All data in feet unless otherwise stated. Calculation uses min~um curvature method. Coordinates from slot #190 and TVD from RKB(Doyon 141) (87.20 Ft above mean sea level). Bottom hole distance is 7705.65 on azimuth 165.47 degrees from wellhead. Vertical section is from wellhead on az~uth 141.43 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ) ConocoPhillips Alaska, Inc. Pad 1C,190 Kuparuk River Unit,North Slope, Alaska Top MD Top TVD ') SURVEY LISTING Page 4 Your ref MHD <0-10466'> Last revised: 7-Mar-2003 Rectangular Coords. Casing positions in string 'A' ----- O.OON Bot MD Bot TVD 2448.278 Rectangular Coords. 1847.67E 7 5/8" Casing 0.00 0.00 ----------------------------------------------------------------------------------------------------------- Casing Target name O.OOE 5449.00 3834.44 ------- Targets associated with this wellpath Rectangular Coordinates Geographic Location T.V.D. ----------------------------------------------------------------------------------------------------------- Revised Y14 Early Landing WS Y14 TGT#2 RV8D 6 WS Y14 D-TOE RVSD 6 W8 Y14 D-HEEL RVSD 6 W8 Y14 TGT#3 RV8D 6 564267.920,5966299.960,0.0000 564361.000,5964015.000,-2.000 564475.000,5961200.000,0.0000 564272.000,5966200.000,0.0000 564425.000,5962412.000,0.0000 3814.20 3807.20 3800.20 3814.20 3799.20 2317.438 4603.298 7419.40S 2417.43S 6206.91S 1848.06E 1922.57E 2013.69E 1851.33E 1973.54E 18-Nov-2002 26-Sep-2001 19-5ep-2001 19-5ep-2001 5-Sep-2002 1 03/25/03 Schlumberger NO. 2720 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk -' Well Job# Log Description Date BL Color CD 1~'2(~~'l'~1C-15 ðOB"'èQ3 1C-190 :Ð 0.3'0\ \ 3S-22 23101 23103 23102 SCMT USIT SCMT 03/11/03 03/09/03 03/06/03 1 1 1 --.... S'GN4 úß&{xpl DATE: T__ ~ 1"'. E\V1= 'D' Kt:v, ~ APR 1 4 2.003 Ala$a O;i & Gas Cons. c~ , An~ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. \ J Transmittal Form INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Reference: lC-190 Contains the following: 1 LDWG Compact Disc . (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - MPR Measured Depth Log 1 blue line - MPR TVD Log I LAC Job#: 426355 I Sent By: Glen Horel Received ~{Å (1~ ) a03--0D3 1/03 -7 r&¡. BAKER HUGHES Anchorage GEOScience Center Date: Mar 18,2003 Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 [r~~:'::;;~:~:-~J- !:-- 'II ~ 1<. ~.; ':'~', ~.~ ~,.. ~ I . ,~<'J WI.' irc.m~, "WIll", t ¡f ,.'_,tmIIi(.; i;~," ::~·t ":". ~.. : 'i,;!~"~","I~, :.~~.....-!D.. ,..,--:_...~;:r._.._.~ : .....IW ...........,.,.., ...........,- .....". ~-, :" lí\'A',:;;¡';I.'l;¡jli/:' :-.... .. ~.,....~..,...~'..,~!., .......".' .., In i::;:., ~~ ."'~~' u;' '!"', ._-_.'-'.,~~-_..'_..._,._.._._._-._-- :~S{', ; .. ~~"'~'" ~. '.,.." _.~.,. RECEIVED :~:--- MAR 1 7 2003 AJaeka Oii & Gas Cons. Commillian Anchcnge ------. ~~®~~r, (~ " lFÙ ., J:' ~? ~ J ) fE\ - fE\ (fù 'I! fK\ / iA'J..:;> IfÙ \~ _ \\ lh\ / ) \.:.:::) FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AND GAS CONSERVATION COlWllSSION Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage AK 99510 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: KRU lC-190 ConocoPhillips Alaska, Inc. Pennit No: 203-003 Surface Location: 1638' FNL, 1395' FWL, Sec. 12, TIIN, RI0E, UM Bottomhole Location: 1502' FSL, 1878' FEL, Sec. 13, TIIN, RI0E, UM Dear Mr. Thomas: Enclosed is the approved application for pennit to drill the above referenced service well. This pennit to drill does not exempt you from obtaining additional pennits or approvals required by law from other govenunental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Con1lnission reserves the right to withdraw the pem1it 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 COlnmission order, or the tenns and conditions of this pennit lnay result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~ð-~ Michael L. Bill Commissioner BY ORDER OF THE COMMISSION DATED this ;¡7Coday of January, 2003 cc: Department ofFish & Game, Habitat Section w/o encI. Department of Environmental Conservation w/o encI. Exploration, Production and Refineries Section 6. Property Designation ADL 25649 & 25650 ALK 467 & 468 7. Unit or property Name 11. Type Bond (see 20 AAe 25.0251) Kuparuk River Unit Statewide 8. Well numbe/-, Number 1 C-190 #59-52-180 9. Approximate spud date / Amount February 1,2003 $200,000 14. Number of acres in property 15. Propos~ depth (MD and TV D) 2560, /.it-' 10466 ' MO I 3801 'TVO 17. Anticipated PI¥\~ ¥ee, AAC 25.035 (e)(2)) Maximum surface~sig At total depth (TVO) 1800 psig Setting Depth 20. Attachments Filing fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling program 0 Drilling fluid program 0 Time vs depth plot Qefraction analysis 0 Seabed report 020 AAC 25.050 requirements 0 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Call Steve Shultz 263-4620 Signed \<-~~ R. Thomas Commission Use Only , Permit Number I API number '~:> / 3 /" I Approval date j ',' 171' II) Il.. .2ð..1" - 0 Q...? 50- o:¿ 9 - .,¿... ~ to '1'1' /e ''/ Conditions of approval Samples required 0 Yes ~ No Mud log required Hydrogen sulfide measures 0 Yes ,g¡ No Directional survey required ~ Yes Required working pressure for ~OPE D2M; 0 3M; 0 5M; 0 10M; 0 Q Other: T£>t f%' PE tc 3S C<:~ I)~~' AltL I, ~\,.'\. ì-- b ""'" fA. t'l t" J ,,~~ LC (,J.-.(, J. by Yrder of ORIGINAL SIGNED BY M L Bill Il -) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1b. Type of well. Exploratory U Stratigraphic Test Service j(I Development Gas 0 Single Zone 5. Datum elevation (OF or KB) RKB = 87 feet AMSL 1a. Type of work: Drill ~ Redrill U Re-entry DDeepen 0 2. Name of Op, e~éÙo~ 0" we w '\ú(.:l ... Phillips A~sKa, nc. t\. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface / 1638' FNL, 1395' FWL, Sec. 12, T11N, R10E, UM At top of productive interval / 1324' FSL, 2040' FEL, Sec. 12, T11N, R10E, UM At total depth 1502' FSL, 1878'FEL,Sec. 13, T11N, R10E, UM 12. Distance to nearest property line 13. Distance to nearest well/ 1878' @ TO feet 1C-12730' @ 400' 16. To be completed for deviated wells Kickoff depth: 350 MO 18. Casing program size U o feet Maximum hole angle 92° Top Bottom TVD 120' 3815' 3801' Hole Casing Weight 24" 16" 62.5# 9.875" 7.625" 29.7 6.75" 4.5" 12.6# Specifications Grade Coupling H-40 Weld L-80 BTCM L-80 NSCT/IBT MD 120' 5462' 1 0466' MD TVD 59' 59' 59' 59' .546tr' ,~. S'3Sou tJ64- Length 120' 5573' 5356' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured true vertical feet feet Plugs (measured) Effective Depth: feet feet Junk (measured) measured true vertical Casing Conductor Surface o Size Cemented Measured depth Length Perforation depth: measured true vertical Title: Kuparuk Drilling Team Leader Approved by Commissioner the commission Form 10-401 Rev. 12/1/85· ( iiGiNA... KiGA- 1/11/03 ) Development Oil IÁ ¡qo¿ Multiple Zone ß ¡ 10. Field and Pool Kuparuk River Field West Sak Oil Pool / Quantity of Cement (include stage data) ,/)332 sx AS 1/J ~sxAS III L~sxClass G Slotted liner - no cement / True Vertical depth RECEI~VED!: JAN 0 6 2003 ,~'iaska Oil & Gas Cons. Commission A.ncl1oraQ8 ¡I" (0 J Date PrAnfm:¡r! hv ShAmn AI/!';//n-nrAkp. Isee cover letter for other requirements U Yes MJ No o No Date y()¡1þ~ Submit in triplicate ConocJPhilh-.1s ,-~) Drill and Complete Procedure West Sak Well #lC-190 4 1/2" Injector \A'~II Pial" ~ummary Horizontal Locations Location at Suñace 11638' FNL, 1395' FWL, Sec 12, T11N, R10E, UM NGS Coordinates Northings: 5,968.602.15 Eastings: 562,401.40 RKB Elevation Pad Elevation 89.3' AMSL 59.2' AMSL Location at Top of 1324' FSL, 3240' FWL, See 12, TUN, R10E, UM Productive Interval (West ~;:¡k "n" ~;:¡nf'l) NGS Coordinates Mea8ured fJepth¡ RKB: 5367 Northings: 5,966,300 Eastings: 564,268 Total Vertical Depth¡ RKB: 3815 Total Vertical Depth¡ 55: 3777 I or.;:¡tinn ;:¡t Tnt;:¡1 nppth NGS Coordinates Northings: 5,961,200 Eastings: 564,475 11507' FSI, 3407' FWI, C:¡ec 13, T11N, Rl0F, UM Mea,CJl1red fJppth¡ RKB: Total Vprtical fJepth¡ RKR: Total Vertical fJepth¡ 55: 10466 3801 3713 /' Formation Markers and Directional Waypoints Measured Hole Angle True Vertical True Vertical Form;:¡tinn Tqps np,pth (RK~ fppt) OPo rp.p.~ Op,pth (RKR fp.p.t) nprth (..,,~ fppt) Ooyon #141 RKR 0 0 0 -89 KOP :t~o 0 :t~0 767 Base Permafrost 1,911 34 1,804 1,715 Top K-15 7,511 34 7,303 7,)14 Top UgnLJ r: 3,660 54 3,705 3,116 Top Ugnu B 4,707 61 3,478 3,389 Top UgnLJ A 4,378 61 3,536 3,447 ~ K13 4,687 69 3,697 3,603 Top West Sak ') 5,114 87 3,798 3,709 Y-14 (Target & 7 5/8" csg pt.) ~467 90 1.,81 5 1,776 West Sak Targpt #7 7,649 90 3,808 3,719 West Sak Target #3 9,753 90 3,800 3,711 Well TD 10,466 90 3,801 3,712 Casing/Tubing Program Hole / / / Casing Csg/Tbg Top Btm ~i7p. nn Wt/Ft Gr;:¡f'lp rnnn. . pngth MI1/TVO MIl/TVO 97/8" OH 7 5/8" 29.7# L-80 STCM 5,462' Surface 6 314" OH 41/2" 1/.6# 1-80 NScr 5,154' 5,467'/3,815' 10,466' / 3,800' Production 4 V2" 17.6# 1-80 NScr 5,000' Surface 5,000' / 3778' Logging/Formation Evaluation Program Open Hole 9 718" MWD/Directional LWD ( GR I RES) OJ 'G ø:\' A ,1 ¡J\A~ ConocóPhill~s Open Hole 6 3/4" Caspd Hole. ogs: MWD/Directional LWD ( GR / RES/ lAB) CSI / GR / CO Mud Program Opnsity (IWQ) Fllnnpl Visrnsity (sprnnds) Yield Point (cP) Plastic Viscostiy (lb/100 sf) 10 second Gel Strength (111./100 sf) 10 minute Gel Strength (111.1100 sf) rH API Filtratp (cc) ~oli"'s (0/0) Cementing Program ) Drill and Complete Procedure West Sak Well #1C-190 Horizontal Injector AFC- .t;p"d to R;lSp. of' Pp.rm;lf'rost Initial Value Final Value / 8.5 9.5 - 9.6* 150-'00 150-'00 30-60 30-60 ß;lSP. of' pp.rm;lf'ro'1to Tnt;ll Dppth Initial Value Final Value 9.5 9.5 150 75 25-45 25-45 8-15 11-22 11-22 11-22 15-30 10-25 15- 30 15-30 25-55 25-55 25-55 25-55 8-9 8-9 8-15 6 5-6 5-6 5-8 5-8 5-8 6-11 Holp C::IItpgory Surface Casing ~i.7pJOp.rth Volump 7 5/8"/5462'MD 40 bbls Steve Shultz 50 bbls 3~)bls (jf/skS) /~\ 46 bøls fj sks) Tyl"p of Cpmpnt CW Pre-flllsh MlIdpush XI lead SIl1rry (ASI iœ) Class "G" Cement 50% D124 Extender 3.5% D44 Accelerator 0.4% D46 Antifoam 30% D53 Thixotrop 1.5% D79 Extender 1.5% S 1 Accelerator Tail SllIrry Class "G" Cement 0.45% D65 Dispersant 0.3% M117 2.0 gps D600G 0.1% D135 0.1% D135 0.2% D47 3.0% D174 (1 G¡N¡~L Prol"prtip~ Density 8.4 ppg Density 10.2 ppg Density 10.7 ppg Yield 4.44 fe/sk 350% excess in permafrost 35% excess from bottom of permafrost to 4,462' Density 15.80 ppg Yield 1.2 fe/sk 20% excess from 4462' to 5462' Page 2 of 5 ConocóPhilla-~s ). Drill and Complete Procedure West Sak Well #lC-190 Horizontal Injector AFC- Blowout Prevention Equipment Information · Hydril Annular Diverter BOP, 21 1/4" X 2000 psi for Surface /' · Hydril Annular BOP 13 3/8" X 5000 psi. / · 3- Hydril Single Gate, Model MPL, 13 5/8" X 5000 psi. · Choke Manifold o 1-2 1/16" X 5000 psi manual gate valve o 12-3 1/8" X 5,000 psi manual gate valves o 1-3 1/8" X 5000 psi manual choke valve o 1-3 1/8" X 5000 psi remote operated hydraulic choke Please see "Diagram and Description of the Blowout Prevention Equipment" for Doyon #141, placed on file with the Commission. All equipment to be test to 3500 psi every seven days and witnessed by state official unless waived by the AOGCC. Well Objectives and Area History/,./.~_.___) This AFC provides funds to drill, case and complete a2';~je..~!9P"'Well through the D Sand. The well will b~,Çasedã9...d.·. . a d completed to support production from the producers~5A and 1C-135. This well is to be a horizont,ef inje¥and as such will be drilled in the "D" sand with minimal directional changes as possible. ~---- The majority of the directional work will take place in the surface hole with several turns, builds and tangent sections prior to reaching casing point for the 7 5/8" casing. The horizontal section will rise about 14 feet structurally from heel to toe but additional directional work should be minimal. This well will parallel a known fault which trends north/ south. Since 1C-190 is to be drilled into the same fault block as 1D-105A, bottom hole pressures have been taken from 105A with an estimated 1467 psi at 3442' TVD. This requires a minimum of 8.2 ppg mud to drill this well and with a 75 R,Pg"safety margin the total mud weight will be +/- 8.6 ppg. There shouldn't be a risk of over pressure. i~\ Other geological hazards which may be encountered during drilling include gas hydrates at the base of the permafrost and running sands and gravels at shallow depths. In addition to items which pose a threat to any drilling operation (i.e. stuck pipe, etc.) there is also some chance in drilling the 1C-190 well that the conductor may broach. These risks have been mitigated and are detailed in the drilling hazards summary. . Reservoir Pressure and Well Control The expected reservoir pressures in the West Sak sands in the 1C pad area vary from 0.43 to 0.46 psi/ft, or 8.2 to 8.81 ppg EMW (equivalent mud weight). These are pressures 0 . from actual well test data from the nearby 1D- 105A well. The vertical depth of the West Sak top in 1 90 is ~810'; thus the expected reservoir pressure is 1,467 psi, but there is the remote possibility that the higher' jectioJvf:>ressures from 1C-133 could be seen which would be approximately 1900 psi right at the wellhead. With s ~-1housa!)d feet between 1C-133 and 1C-190 the pressure would be 1800 psi I the area of drilling giving us a 9.1 ppg MWE." Steve Shultz ( -:, ~ ¡ r',J, ~ · w :4 r j-LII. Page 3 of 5 ConocóPhilltt1s ) Drill and Complete Procedure West Sak Well #1C-190 Horizontal Injector AFC- The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the vertical depth of the expected base of the West Sak formation is 1800 psi, calculated as: MPSP = 1800-(38~) 0.11 psijft) = 1380 psi The West Sak "0" sand will be penetrated with a mud weight of 9.5 ppg. This weight will provide for an overbalance of 75 psi. The surface hole will be drilled to TO with a 21-1/4" annular preventer and a 21-1/4" diverter spool with 16" side /' outlet and diverter line nippled up. After casing is run, the diverter will be nippled down and a 13-5/8", 5000 psi three ram BOP stack will be nippled up and tested to drill the production interval. Previous West Sak wells and current Kuparuk wells penetrate the West Sak sands using only a diverter, without problems. There is, however, a remote chance that the well could flow during drilling and that it will be necessary to divert flow. Unexpected flow could result from gas hydrates or from higher-than-expected formation pressures. These risks, and the mitigation and response plans are detailed in the Attachment "lC-190 Detail Risk Information". Prior to spud this information should be reviewed at a safety meeting with all involved hands. Additionally, the appropriate diverter drills should be held by each of the crews. Close Crossing and Offset Well Interception Risks Positional uncertainty calculations were performed on the proposed lC-190 wellbore using worst case 3D elliptical error models. Based on these calculations the following close approaches (existing wells having center lines which may lie less than 100 feet from the centerline of the proposed well bore) are anticipated. For more information see attached Baker Inteq Directional Plan. lC-19 1c-:n 1C-)3A lC-)5 lC-)7 lC-)6 Close Crossing Op,pth - MO 300 700 1)00 1300 1300 5000 Center to Center Separation at Close Crossing Depth Existing Well Name 40.39 78.3 57.33 81.88 37.63 183.15* / *AII of these wells have passed the "Major Risk" criteria for close approach issues with the exception of lC-26. Due to maintaining a well bore with minimum doglegs to facilitate the running of the 4 '/2" slotted liner for 5000'+ in open hole, a "Minor Risk" basing was needed for lC-26. Prior to the wellbore drilling to 5000', a plug will be set in lC- 26 (injector) and the tubing bled down. After drilling past 5200' the plug will be pulled and lC-26 will be place back on injection. It is the responsibility of the Directional Driller and Phillips Alaska Drilling Foreman to insure that the directional plan of 1C-190 is executed as planned, that the position of 1C-190 is monitored on an anti-collision diagram, and that no tolerance line for close approach wells is crossed. Waste Drilling Fluids Disposal Incidental fluids generated from drilling operations may be hauled to the nearest permitted disposal well or may bel pumped down the surface / production casing annulus of a permitted, existing well on Drill Site-1C. Cement rinse water is not to be injected down the dedicated disposal well but should be recycled or held for an open annulus. Any annuli used should be left with a non-freezing fluid during any extended shut down (in excess of four hours) of pumping operations. The West Sak lC-190 surface casing by production tubing annulus should be filled with diesel and/or non-freezing brine after setting the 4-1/2" tubing string and prior to the drilling rig moving off of the well. Possible Class II disposal wells are lR-18 and 3R-l1. All fluids hauled from 1C-190 must be properly documented and manifested. Steve Shultz ~ i/]JNA- Page 4 of 5 ConocóPt,ill~~s ) Drill and Complete Procedure West Sak Well #1C-190 Horizontal Injector AFC- Summary Procedure 1. Move inl Rig up Doyon #141 I 2. Install diverterl BOPE and function test 3. Spud and directionally drill 9 7/8" hole to casing point at ±5462' MD 1±3815TVD as per "./ directional plan. Run MWD, LWD tools as required for directional monitoring and data gathering. Casing point to be horizontal in the West Sak D-sand. / 4. Run and cement 7 5/8", 29.7#, L-80, BTC Mod casing to surface. Displace cement with mud and perform stage job if required. Note: Port Collar to be run at ±1,000', "fnove 16" diverter line, install blind flange, activate and test BOP's to 3500 psi (annular preventer to 2500 psi) Notify AOGCC 24 hours prior to test. PU 6 3/4" bit and RIH on directional assembly, once at top of float collar, test casing to 2500 psi /' for 30 minutes, drill out 7 5/8" shoe and 20' to 50 ' of new formation. Perform an FIT to 12.0 ppg MWE and record the results. Change over to clean LSND drilling fluid and directionally drill a 6 3/4" hole to TD at ±10,466' MD I / 3,712' TVD as per directional plan. 5. 6. 7. Condition hole for running the 4 V2" slotted liner, Change over to viscosified brine, PO<?.~ ~~nd run the 4 '12", 12.6#, L-80, NSCT slotted liner, set liner/hanger packer a~ 3715' Rig up and run CBL from liner top to 500 above the top of the Ugnu. / 8. 9. 10. RU and RIH with 4 1/2", 12.6#, L-80 production tubing with seals / 11. Space out and land tubing with seal assembly into PBR on hanger 12. Install back pressure valve and ND BOPE. Install production tree and test same, test annulus to 3000 psi, continue to pressure up to shear out sliding sleeve 13. Freeze protect the well with diesel down the annulus, circulating through sliding sleeve 14. Install back pressure valve and release Doyon #141. Steve Shultz ."R" '"""~,,~ i\ I v ' : ' Ii' ' , " ,,1 ,~ " i' I ~ 1 ~ ' I \..-1 , ¡ \\1 ;/:J b. Page 5 of 5 --) ._-J 1 C-190 Drilling Hazards Summary (Details of of these risks follow on next page) 9 7/8" Open Holel 7 5/8" Casing Hazard Broach of Conductor Risk Level Low Gas Hydrates Low Running Sands and Gravels Low Abnormal Reservoir Pressure Lost Circulation Swabbing Low Low . Moderate / 6 %" Open Holel 4 Y2" Slotted Liner Hazard Abnormal Pressure Risk Level Low S tuck Pipe Lost Circulation Hole Swabbing on Trips Low Low Low Mitigations Monitor cellar while drilling surface hole, conductor set @ 120' which is 40 feet deeper then the 80 foot standard of the past Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Dril treat Maintain planned mud parameters, weighted mud, viscous sweeps Divefter drills, increased mud weight, flow checks Reduced pump rates, rheology, LCM Trip speeds, proper hole fill, pumping out Mitigation Stripping drills, shut-in drills, increased mud weight Good hole cleaning, backreaming after TD Reduced pump rates, rheology, LCM Trip speeds, proper hole fill, pumping out II 'L~/~"IA r1I' 1/L.l ¡li/1_ 1C-190 16" Conductor ~ .....0 X Nipple ~ 120' ConocJPhillips Tangent Angle: +1-60 ..i____' C) ::t:J ~- ~ --- 7 5/79#, L-80, BUTT / ~.12 .~ ."" - ~ r-- 4 1/2", 12.6#, L-80, NSCT NoGo Nipple /' Csg pt. {i) 5300'M D/3812'TVD k"4 1/2", 12.6#, L-80, NSCT ~ - - J 10,466' MD/3800'TV[ ~. ._~) Crðatod by bmlchaol For: S Shultz ConocoPhillips Alaska, Inc. Dota plottod : 27-Doe-2002 Plot Referenco '0 1 C- 1 90 Ver:>ionI7. Coordinates arc In feot reference slot '190. Truo Vertical Depths arc reference: Est.RKB(Doyon 141). .. === ~ IN'I'KQ -- 800 ESTIMATED SURFACE LOCATION: 1638' FNL, 1393' FWL SEC. 12, T11N, R10E 141.43 AZIMUTH 2964' (TO TARGET) ***Plane of Proposol*** , , TRUE Field : Kuparuk RIver UnIt Location: North Slope, Alaska Structure : Pad 1 C Well: 190 400 East (feet) -> o 800 1600 2000 2400 2800 400 1200 -::,/\00 \<.~\.ÍI\è/í\.lff\ -::,/'00 <¿ '{-J.\\ è fí \.I ff\ lOo AZ EGC 13ase Permofrost Top T-3 -l: Top K-15 {) <1¿- Build/Turn 4.5/100 Top Ugnu C EOC ......77 .~ Top Ugnu B Top Ognu A '1'-2" Begin Final Bid/Turn Top West Sak D Target-7 5/8 Casing pt. j:l EOC TARGET LOCATION: 1224' FSL, 2037' FEL SEC. 12, T11N, R10E ~ ...:¡ ~ ..... ~ :J> N Target 2/Build 3/~g~ * Target 3/Build 3/~gg. TO LOCATION: 1502' FSL, 1878' FEL SEC. 13, T11N, R10E TO - Casing Pt... '" .n , l~ 6 ,..! A L - /KÎ I L11 fJ l·L ) ~ ConocoPhillips 400 - 0 - 400 - 800 -1200 -1600 - 2000 - 2400 - 2800 U1 - 3200 0 C -+ :r - 3600 ,,--.... - CD CD -+- - 4000 "'-" I V - 4400 - 4800 - 5200 - 5600 - 6000 - 6400 - 6800 - 7200 - 7600 350 - 700 - r--. 1050 - -+- Q Q) Q) '+- ::J:J '-" 1 400 - ..c -..- -+- ~ 0.. Q) 1750 - --- 0 --~~~ 0 <::::. 2100 - ~ U :;:: L r-- Q) > 2450 - Q) :J L 2800 - l- I V 3150 - 3500 - 3850 - 4200 - ConocoPhillips Alaska, Inc. Crealed by bmichael For: S Shultz Dale plaUed : 3O-oeo-2oo2 Plot Reterence i. 1C-190 Ve",ion/7. Coordinoles orB in feel ruference slot #190. True Vertical Depth. are reference Est.RKB(ooyon - .... INTt:Q Structure: Pad 1 C Well: 190 Field : Kuparuk River Unit Location: North Slope, Alaska o - I Estimated RKB ELEV: 87' 141.43 AZIMUTH 2964' (TO TARGET) KOP 2.00 4.00 6.00 DLS: 2.00 deg per 100 ft 8.00 Build/Turn 3/100 14.08 EOC Build/Turn 3/100 19.27 22.00 24.79 DLS: 3.00 deg per 100 ft 27.63 30.49 33.37 EGC Bose Permafrost ***Plane of Proposal*** ,,'<... cP " f0 çl \ " CS òeo, /)..~ ';)\) /)... <::)\"Cj. ,§<:- .~þ\"\ «)\)' <:J r¡, '")/)... <:J'") '")'b' <o'J G þ.,r¡,. d;) <:-\) ,-". \j~ ·.),\oç <:J\) <:J~~oG ~<:- \) «) ~ò\"\~ \jct \) ~ 0' 'Õ "\ oç \jo,<:- ~,0 ,\oç ¡j;0 'b" <òe <0'")' 'J ¥" 350 350 700 1400 2100 2450 1050 1750 o '<,\. " \)\) e< òeo, ç <:J\) þ., . «\.' <::)\"S' . <:-0, Got;,.... So'+- ~ \'ò 1<... 1 <0" ~'õ":> 'õ<' "\oç ,\oç~«.,.\)G x~ 'J \ " \)\) <ò~~ò r¡,\ e\. C, ,\o'~«.,.Q 2800 3150 3850 4550 5250 4900 3500 4200 Vertical Section (feet) - > Azimuth 141.43 with reference 0.00 N, 0.00 E from slot # 190 ...... ConocoPhillips f0 '""JI"cs <ò~~ò 1<.. 'J I e ,\o'~oG 5600 5950 6650 6300 l "- '___i «\.. . 00, GOt;,' "\\) 7000 7350 7700 - )Baker Hughes INTEQ ) Error Ellipse Survey Report çompauy: CondcdPhillips Alaska, Inc. Field: Kuparuk RiverUnit Site: Pad 1C Well: 190 We~lpath: .1C~19QV~~s#7 Field: Kuparuk River Unit North Slope, Alaska USA Map SysteniJS State Plane Coordinate System 1927 Geo DatumNAD27 (Clarke 1866) Sys Datum:Mean Sea Level Date: 12/27/2002 . Time: 15.:56:19 Co-ordinate(NE) Refel'eIiCe:.· vvell:190,TriJe North Vertical (l'V)))R¢ference: W~lIhead(87') 87.0 Sectiol1(VS) Reference: Well. (O~OON;O.OOE: 164: 82Azi) Survey cªtcuJationMethod: Minimum ClJrvature Db:. Page: 1 Oracl~ Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 Site: Pad 1C North Slope, Alaska Site Position: Northing: 5970228.13 ft Latitude: 70 19 45.173 N From: Map Easting: 560993.64 ft Longitude: 149 30 19.124 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 60.50 ft Grid Convergence: 0.24 deg Well: 190 Slot Name: Well Position: +N/-S -1637.53 ft Northing: 5968602.14 ft Latitude: 70 19 29.067 N +E/-W 1394.63 ft Easting : 562401.40 ft Longitude: 149 29 38.417 W Position Uncertainty: 0.00 ft Wellpath: 1C-190Vers#7 Current Datum: Wellhead (8?') Magnetic Data: 11/19/2002 Field Strength: 57497 nT Vertical Section: Depth From (TVD) ft 0.00 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Surface 0.00 ft Mean Sea Level 25.62 deg 80.74 deg Direction deg 164.82 Height 87.00 ft Plan: 1C-190 Vers#7 Date Composed: Version: Tied-to: 11/19/2002 22 From Surface Principal: Yes Position uncertainty andhias at survey station AILuncertainties 31.6 ·standard deviatioilighside-----> Lateral-------> Vertical--"-.,..> Magn. Semi-majo6emi-minor MD Inel Azlm TVD . Unc. Bias Unc. Bias Unc. Bias of Bias Unc. Une. Azimutll'ool ft deg deg ft ft ft ft ft ft ft ft ft ft deg 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE LINE 100.00 0.00 0.00 100.00 0.11 0.00 0.11 0.00 2.96 0.00 0.00 0.11 0.11 0.00 MWD 200.00 0.00 0.00 200.00 0.40 0.00 0.40 0.00 2.96 0.00 0.00 0.40 0.40 0.00 MWD 300.00 1.00 100.00 300.00 0.61 0.00 0.61 0.00 2.97 0.01 0.01 0.61 0.61 135.00 MWD 400.00 3.00 100.00 399.93 0.66 0.00 0.68 0.00 2.97 0.02 0.02 0.68 0.67 115.01 MWD 500.00 5.00 100.00 499.68 0.83 0.00 0.92 0.00 2.97 0.03 0.03 0.92 0.85 107.91 MWD 600.00 7.00 100.00 599.13 1.06 0.00 1.32 0.01 2.97 0.04 0.05 1.32 1.10 105.14 MWD 700.00 9.00 100.00 698.15 1.33 0.00 1.86 0.02 2.96 0.06 0.06 1.86 1.39 103.83 MWD 800.00 11.33 103.81 796.60 1.59 -0.01 2.51 0.04 2.95 0.08 0.09 2.51 1.69 103.19 MWD 900.00 14.08 109.24 894.15 1.85 -0.01 3.30 0.06 2.95 0.10 0.12 3.31 1.95 104.26 MWD 1000.00 16.92 112.91 990.50 2.16 -0.01 4.29 0.10 2.94 0.12 0.16 4.31 2.27 106.26 MWD 1100.00 17.00 113.00 1086.14 2.50 -0.01 5.43 0.15 2.94 0.15 0.22 5.45 2.60 108.04 MWD 1200.00 19.27 116.86 1181.25 2.89 0.00 6.60 0.20 2.96 0.18 0.28 6.65 2.93 109.53 MWD 1300.00 22.00 120.38 1274.83 3.31 0.00 7.92 0.27 2.97 0.21 0.35 8.01 3.28 111.31 MWD 1400.00 24.79 123.15 1366.60 3.76 0.00 9.44 0.36 2.98 0.24 0.44 9.56 3.66 113.25 MWD 1500.00 27.63 125.38 1456.32 4.23 0.00 11.17 0.46 3.02 0.27 0.56 11.32 4.07 115.19 MWD 1600.00 30.49 127.23 1543.72 4.71 0.00 13.10 0.59 3.08 0.30 0.69 13.28 4.50 117.04 MWD 1700.00 33.37 128.79 1628.58 5.22 0.00 15.23 0.74 3.17 0.34 0.85 15.45 4.95 118.76 MWD 1800.00 33.80 129.00 1711.71 5.72 0.00 17.57 0.92 3.33 0.37 1.02 17.76 5.40 120.25 MWD 1900.00 33.80 129.00 1794.81 6.23 0.00 19.94 1.09 3.54 0.41 1.19 20.11 5.84 121.40 MWD 2000.00 33.80 129.00 1877.91 6.76 0.00 22.33 1.26 3.77 0.44 1.37 22.47 6.29 122.30 MWD 2100.00 33.80 129.00 1961.01 7.30 0.00 24.71 1.44 4.02 0.48 1.55 24.84 6.75 123.03 MWD 2200.00 33.80 129.00 2044.11 7.84 0.00 27.10 1.61 4.27 0.53 1.73 27.22 7.21 123.62 MWD 2300.00 33.80 129.00 2127.20 8.39 0.00 29.50 1.78 4.54 0.57 1.91 29.60 7.67 124.11 MWD 2400.00 33.80 129.00 2210.30 8.94 0.00 31.90 1.96 4.81 0.61 2.09 31.99 8.13 124.53 MWD 'ì 1':',".;", ~., fA· Ii r. I ~f " J V' . r~ - )Baker Hughes INTEQ ) Error Ellipse Survey Report Company: ConocoPhillips Alaska,lnc. Date: 12/27/2002 Time: 15:56:19 Page: 2 Field: Kupatuk River Unit Co':'ordinate(NE) Reference: Wéll: 190, True North Sit e : Pad 1 C Vertical (TVD) Rèfèrènce:· . Wellhèad(87') 87.0 WeU:190 Section (VS) Reference: Well(0~00N,0.OOE,164.82Azi) W ellpi' th:1 C~19QV érs#7 Srirv~y C \lcu~i'til)n~Iêth(}(1: Minim""m qUrvature Db: P()siHon. uïlcertäinty andbiasätsurveystati()11 l\1ägn.·· Sèmi·lIÏajo6èDÏ¡..min()r Allunçertainties 31.6 . standi'rl:rd~v¡à~io~ighside.".~':'> Läteral-""".~·> Vertical':'·':'...,.> MD IDcI Aziin ..rVD Uric. Bias Unc; Bias ·Unc. Bias öf BiasUÏlc. Unc. AziDlut.rro()l ft deg deg ft ft ft ft ft ft ft ft ft ft deg 2500.00 33.80 129.00 2293.40 9.50 0.00 34.30 2.13 5.09 0.66 2.27 34.38 8.60 124.89 MWD 2600.00 33.80 129.00 2376.50 10.06 0.00 36.70 2.30 5.38 0.71 2.46 36.77 9.07 125.20 MWD 2700.00 33.80 129.00 2459.60 10.63 0.00 39.10 2.48 5.67 0.76 2.64 39.17 9.54 125.47 MWD 2800.00 33.80 129.00 2542.70 11.19 0.00 41.50 2.65 5.96 0.81 2.83 41.57 10.01 125.71 MWD 2900.00 33.80 129.00 2625.79 11.76 0.00 43.91 2.82 6.26 0.87 3.01 43.96 10.48 125.93 MWD 3000.00 33.80 129.00 2708.89 12.33 0.00 46.31 3.00 6.56 0.93 3.20 46.37 10.96 126.12 MWD 3100.00 33.80 129.00 2791.99 12.90 0.00 48.72 3.17 6.87 0.98 3.38 48.77 11.43 126.29 MWD 3200.00 34.52 129.69 2875.03 13.52 0.02 51.09 3.34 7.17 1.04 3.57 51.16 11.91 126.45 MWD 3300.00 38.53 133.11 2955.38 14.45 0.08 53.31 3.48 7.48 1.10 3.78 53.63 12.38 126.70 MWD 3400.00 42.63 135.97 3031.31 15.40 0.10 55.67 3.66 7.85 1.16 4.02 56.31 12.86 127.10 MWD 3500.00 46.79 138.41 3102.36 16.21 0.09 58.21 3.87 8.27 1.21 4.29 59.20 13.34 127.62 MWD 3600.00 51.00 140.53 3168.10 16.83 0.04 60.91 4.11 8.77 1.26 4.59 62.27 13.81 128.23 MWD 3700.00 55.24 142.42 3228.10 17.24 -0.03 63.77 4.38 9.33 1.30 4.92 65.49 14.25 128.92 MWD 3800.00 59.50 144.12 3282.01 17.45 -0.13 66.75 4.69 9.95 1.34 5.27 68.83 14.67 129.66 MWD 3900.00 61.38 144.82 3330.54 17.88 -0.18 70.13 5.05 10.63 1.37 5.65 72.30 15.07 130.43 MWD 4000.00 61.38 144.82 3378.44 18.61 -0.18 73.85 5.43 11.35 1.41 6.03 75.91 15.46 131.16 MWD 4100.00 61.38 144.82 3426.35 19.35 -0.18 77.58 5.82 12.07 1.44 6.41 79.54 15.85 131.83 MWD 4200.00 61.38 144.82 3474.25 20.09 -0.18 81.32 6.21 12.79 1.48 6.79 83.19 16.24 132.43 MWD 4300.00 61.38 144.82 3522.16 20.85 -0.18 85.07 6.60 13.52 1.51 7.17 86.85 16.64 132.99 MWD 4400.00 61.38 144.82 3570.06 21.61 -0.18 88.82 6.98 14.24 1.55 7.56 90.52 17.03 133.50 MWD 4500.00 63.81 148.46 3616.29 22.67 -0.11 91.06 7.20 14.97 1.58 7.95 93.94 17.40 133.99 MWD 4600.00 66.62 152.34 3658.22 23.52 -0.08 92.54 7.37 15.70 1.61 8.33 97.02 17.74 134.56 MWD 4700.00 69.52 156.05 3695.59 24.04 -0.11 93.73 7.51 16.48 1.64 8.70 100.06 18.08 135.21 MWD 4800.00 72.49 159.62 3728.14 24.21 -0.20 94.66 7.62 17.29 1.66 9.06 103.04 18.44 135.95 MWD 4900.00 75.53 163.08 3755.70 24.04 -0.34 95.34 7.70 18.12 1.68 9.41 105.96 18.83 136.76 MWD 5000.00 78.61 166.44 3778.08 23.59 -0.54 95.78 7.74 18.99 1.70 9.73 108.80 19.26 137.62 MWD 5100.00 81.74 169.73 3795.14 23.00 -0.80 95.99 7.74 19.88 1.71 10.04 111.57 19.77 138.54 MWD 5200.00 84.89 172.96 3806.79 22.44 -1.11 95.96 7.69 20.78 1.71 10.32 114.24 20.35 139.49 MWD 5300.00 88.05 176.17 3812.96 22.17 -1.47 95.68 7.60 21.69 1.72 10.57 116.82 21.03 140.49 MWD 5400.00 90.00 178.13 3814.00 22.61 -1.72 96.62 7.62 22.61 1.72 10.80 119.33 21.66 141.50 MWD 5500.00 90.18 178.13 3813.89 23.46 -1.74 99.75 7.89 23.50 1.72 11.02 121.79 22.14 142.44 MWD 5600.00 90.18 178.13 3813.57 24.39 -1.74 103.35 8.16 24.42 1.72 11.25 124.71 22.43 143.46 MWD 5700.00 90.18 178.13 3813.25 25.32 -1.74 106.97 8.42 25.35 1.72 11.48 127.67 22.74 144.44 MWD 5800.00 90.18 178.13 3812.92 26.25 -1.74 110.62 8.69 26.28 1.72 . 11.71 130.69 23.05 145.38 MWD 5900.00 90.18 178.13 3812.60 27.18 -1.74 114.28 8.95 27.21 1.72 11.94 133.75 23.36 146.29 MWD 6000.00 90.18 178.13 3812.28 28.11 -1.74 117.96 9.22 28.15 1.72 12.17 136.85 23.68 147.15 MWD 6100.00 90.18 178.13 3811.96 29.05 -1.74 121.65 9.49 29.08 1.72 12.40 139.99 23.99 147.98 MWD 6200.00 90.18 178.13 3811.64 29.98 -1.74 125.35 9.75 30.01 1.72 12.64 143.17 24.30 148.78 MWD 6300.00 90.18 178.13 3811.32 30.92 -1.74 129.07 10.02 30.95 1.72 12.88 146.38 24.61 149.54 MWD 6400.00 90.18 178.13 3811.00 31.85 -1.74 132.80 10.28 31.88 1.72 13.11 149.63 24.91 150.27 MWD 6500.00 90.18 178.13 3810.68 32.79 -1.74 136.54 10.55 32.82 1.72 13.35 152.91 25.21 150.97 MWD 6600.00 90.18 178.13 3810.36 33.72 -1.74 140.28 10.81 33.76 1.71 13.60 156.22 25.50 151.65 MWD 6700.00 90.18 178.13 3810.04 34.66 -1.74 144.04 11.08 34.69 1.71 13.84 159.55 25.78 152.29 MWD 6800.00 90.18 178.13 3809.72 35.60 -1.74 147.80 11.35 35.63 1.71 14.08 162.92 26.05 152.91 MWD 6900.00 90.18 178.13 3809.40 36.54 -1.74 151.57 11.61 36.57 1.71 14.32 166.30 26.32 153.50 MWD 7000.00 90.18 178.13 3809.08 37.47 -1.74 155.35 11.88 37.51 1.71 14.57 169.71 26.58 154.07 MWD 7100.00 90.18 178.13 3808.76 38.41 -1.74 159.13 12.14 38.45 1.71 14.81 173.14 26.83 154.62 MWD 7200.00 90.18 178.13 3808.44 39.35 -1.74 162.92 12.41 39.39 1.71 15.06 176.60 27.08 155.15 MWD 7300.00 90.18 178.13 3808.12 40.29 -1.74 166.72 12.67 40.33 1.71 15.31 180.07 27.32 155.66 MWD 7400.00 90.18 178.13 3807.80 41.23 -1.74 170.52 12.94 41.27 1.71 15.56 183.56 27.55 156.14 MWD 7500.00 90.18 178.13 3807.48 42.17 -1.74 174.32 13.21 42.21 1.71 15.81 187.07 27.77 156.61 MWD 7600.00 90.18 178.13 3807.16 43.11 -1.74 178.13 13.47 43.15 1.71 16.05 190.59 27.99 157.06 MWD ~ j f G ,r f\ ,} lj I .. .1 I :~ \1.l°"lj;t!m "naker Hughes INTEQ ') Error Ellipse Survey Report Company: ConocoPhillips Alaska, Inc. Date: 12/27/2002 Time: 15:56:19 Page: 3 Field: Kuparuk River Unit Co-ordinate(NE)Reference: Well: 190, True North . Site: Pad 1C Vertical (TVD) Reference: WellheCid(87') 87.0 Well: 190 Sèction (VS) Reference: Well.(0;00N,0¡00E,164.82Azi) WelJpll t h: 1 C-190Vers#7 Survey CalëulätionM~thod: .MinimumCurvature .Db: Oracle PosÎtiOi11incertainty and bias at survey station Lateral~--..---> Vertical.......,.....> Alluncerfainties a1~6 standard deviatio..ig.hšide---....> l\'Iag)). >Semi';måj o&emi" ïninor l\fD InCl Adm TVD Unc; nia s Unc. Biaš Vnc. Bias orBias Vnc. Unc. AzÍJllu tli'ool ft deg deg ft ft ft ft ft ft ft ft ft ft deg. 7700.00 90.29 178.18 3806.75 44.03 -1.76 181.86 13.73 44.09 1.71 16.30 194.09 28.25 157.50 MWD 7800.00 90.29 178.18 3806.25 44.97 -1.76 185.67 14.00 45.03 1.71 16.56 197.64 28.45 157.92 MWD 7900.00 90.29 178.18 3805.75 45.92 -1.76 189.49 14.26 45.97 1.71 16.81 201.21 28.65 158.32 MWD 8000.00 90.29 178.18 3805.25 46.86 -1.76 193.31 14.53 46.91 1.71 17.06 204.78 28.84 158.71 MWD 8100.00 90.29 178.18 3804.75 47.80 -1.76 197.14 14.79 47.85 1.71 17.31 208.38 29.02 159.09 MWD 8200.00 90.29 178.18 3804.25 48.74 -1.76 200.97 15.06 48.79 1.71 17.56 211.98 29.20 159.45 MWD 8300.00 90.29 178.18 3803.75 49.68 -1.76 204.80 15.32 49.73 1.71 17.82 215.59 29.38 159.80 MWD 8400.00 90.29 178.18 3803.25 50.62 -1.76 208.64 15.59 50.68 1.71 18.07 219.22 29.54 160.14 MWD 8500.00 90.29 178.18 3802.76 51.56 -1.76 212.48 15.85 51.62 1.71 18.32 222.85 29.71 160.46 MWD 8600.00 90.29 178.18 3802.26 52.51 -1.76 216.32 16.12 52.56 1.71 18.58 226.50 29.87 160.78 MWD 8700.00 90.29 178.18 3801.76 53.45 -1.76 220.16 16.38 53.50 1.71 18.83 230.15 30.02 161.09 MWD 8800.00 90.29 178.18 3801.26 54.39 -1.76 224.00 16.65 54.45 1.71 19.09 233.81 30.17 161.38 MWD 8900.00 90.29 178.18 3800.76 55.33 -1.76 227.85 16.92 55.39 1.71 19.34 237.48 30.31 161.67 MWD 9000.00 90.29 178.18 3800.26 56.28 -1.76 231.70 17.18 56.33 1.71 19.60 241.16 30.45 161.94 MWD 9100.00 90.29 178.18 3799.76 57.22 -1.76 235.55 17.45 57.27 1.71 19.86 244.85 30.59 162.21 MWD 9200.00 90.29 178.18 3799.26 58.16 -1.76 239.40 17.71 58.22 1.71 20.11 248.54 30.72 162.47 MWD 9300.00 89.95 178.10 3799.01 59.13 -1.70 243.01 17.99 59.12 1.71 20.37 251.93 30.78 162.70 MWD 9400.00 89.95 178.10 3799.09 60.07 -1.70 246.87 18.26 60.06 1.71 20.63 255.63 30.90 162.94 MWD 9500.00 89.95 178.10 3799.18 61.02 -1.70 250.73 18.52 61.01 1.71 20.89 259.35 31.03 163.18 MWD 9600.00 89.95 178.10 3799.26 61.96 -1.70 254.58 18.79 61.95 1.71 21.15 263.07 31.15 163.41 MWD 9700.00 89.95 178.10 3799.35 62.90 -1.70 258.45 19.05 62.90 1.71 21.41 266.79 31.27 163.63 MWD 9800.00 89.95 178.10 3799.43 63.85 -1.70 262.31 19.32 63.84 1.71 21.67 270.52 31.38 163.85 MWD 9900.00 89.95 178.10 3799.52 64.79 -1.70 266.17 19.59 64.78 1.71 21.93 274.26 31.49 164.06 MWD 10000.00 89.95 178.10 3799.60 65.74 -1.70 270.04 19.85 65.73 1.71 22.19 278.00 31.60 164.26 MWD 10100.00 89.95 178.10 3799.69 66.68 -1.70 273.90 20.12 66.67 1.71 22.45 281.75 31.71 164.46 MWD 10200.00 89.95 178.10 3799.77 67.62 -1.70 277.77 20.38 67.61 1.71 22.71 285.50 31.81 164.66 MWD 10300.00 89.95 178.10 3799.86 68.57 -1.70 281.64 20.65 68.56 1.71 22.97 289.25 31.91 164.85 MWD 10400.00 89.95 178.10 3799.94 69.51 -1.70 285.51 20.92 69.50 1.71 23.23 293.01 32.01 165.03 MWD 10466.14 89.95 178.10 3800.00 70.14 -1.70 288.07 21.09 70.13 1.71 23.40 295.50 32.07 165.15 MWD Or:~{'" .~6'~f . I""'~ ¡ï ,'.:,' ~ i I. ./J.. ..' § I '\.1V~ M I, ) :.:.» )Baker Hughes INTEQ ) Anticollision Report Company: ConpcoPhillips Alaska, Inc. Field: KuparukRiverUnit Reference Site: Pad1C Reference Well: 190 Reference Wellpatli:C-190Vers#7 NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation MethodVID Interval: 100.00 ft Depth Range: 0.00 to 10466.14 ft Maximum Radiu~OOOO.OO ft Date: 12/27/2002 Time: 13:31:13 Page: 1 Co-ordinate(NE) Reference: Well: 190, TrueNorth Vertical (TVD) Reference: Wellhead(87') 87,0 Plan: 1C-190 Vers#7 Principal: Yes Summary <-;..--..;..,;---~----;..---;..-- QffsetW ell path -;..;..---~-;..------.;;-;..---;..> Site Well Wellpath Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C 01 02 03 04 05 06 07 08 09 10 102 102 104 104 104 109 109 111 11 117 119 121 12 123 125 127 131 13 133 135 14 15 16 17 174 178 178 18 19 22 23 23 24 25 26 27 b (PB) c (B) f (IB) WS-1 WS-24 1 C-01 V2 1 C-02 VO 1 C-03 VO 1 C-04 VO 1 C-05 VO 1 C-06 VO 1 C-07 VO 1 C-08 VO 1 C-09 VO 1C-10 VO 1C-102 V4 1C-102L1 V3 1C-104 VO 1 C-104L 1 V1 1C-104PB1 VO 1C-109 VO 1C-109L1 VO 1C-111 VO 1C-11 VO 1 C-117 VO 1 C-119 VO 1C-121 VO 1 C-12 VO 1C-123 VO 1C-125 VO 1 C-127 VO 1C-131 VO 1C-13 VO 1C-133 VO 1 C-135 VO 1 C-14 VO 1C-15 VO 1C-16 VO 1 C-17 VO 1C-174 (V8) Vers#1.a V 1 C-178 B-Lat Vers#O.J 1C-178 D-Lat Vers#O.J 1C-18 VO 1 C-D(19) Vers#O.a VO P 1 C-22 VO Plan: 1 C-22 V 1 C-23A V2 1C-23PB1 VO 1 C-24 VO 1 C-25 VO 1 C-26 V2 1 C-27 V1 1 C-PB Vers#O.a VO Plan 1 C-B Vers#1 a VO Plan: 1 C-IB Vers#1.a VO Plan WS1 VO WS-24 VO Reference MD ft 399.05 297.89 296.21 294.65 293.17 291.78 290.49 289.24 288.22 289.73 199.99 199.99 289.16 289.16 289.16 100.00 100.00 200.00 288.91 291.33 291.67 292.01 2987.39 292.34 292.68 200.00 199.99 292.04 294.10 100.00 911.37 860.27 377.03 200.00 200.00 296.44 296.44 293.78 299.37 687.59 1156.43 1156.43 298.37 1266.23 4913.61 1282.84 297.57 297.00 298.15 300.00 4500.00 Date Composed: Version: Tied-to: Offset MD ft 400.00 300.00 300.00 300.00 300.00 300.00 300.00 300.00 300.00 300.00 200.00 200.00 300.00 300.00 300.00 100.00 100.00 200.00 300.00 300.00 300.00 300.00 3800.00 300.00 300.00 200.00 200.00 300.00 300.00 100.00 1000.00 900.00 400.00 200.00 200.00 300.00 300.00 300.00 300.00 700.00 1200.00 1200.00 300.00 1300.00 5000.00 1300.00 300.00 300.00 300.00 400.00 5800.00 Ci,' GINA.. Reference: Error Model: Scan Method: Error Surface: Db: Oracle Plan: 1C-190 Vers#7 & NOT PLANNED P~OGRt ISCWSA Ellipse Trav Cylinder North Ellipse 11/19/2002 22 From Surface Ctr-Ctr No-Gò DistanceArea ft ft 85.74 4.66 130.65 3.50 235.37 3.48 349.53 3.47 467.10 3.45 586.54 3.43 705.30 3.42 826.92 3.41 889.59 5.06 739.28 3.41 823.49 2.42 823.49 2.42 795.22 3.39 795.22 3.39 795.22 3.39 710.94 0.86 710.94 0.86 682.88 2.35 861.33 3.50 600.96 3.62 573.64 3.39 547.11 3.51 358.37 163.77 521.76 3.56 495.31 3.61 471.20 2.24 422.75 2.21 561.55 3.43 400.01 3.56 378.36 0.84 221.82 21.39 133.48 15.98 535.68 4.88 866.00 2.30 320.02 2.53 240.40 3.99 240.40 3.99 417.02 3.44 40.39 4.02 78.30 11.40 57.33 26.79 57.33 26.79 107.43 4.56 81.88 26.68 183.15 190.91 37.63 27.87 160.51 4.00 200.62 4.00 120.39 4.00 7747.26 5.87 9337.33 225.12 Allowable Deviation ft 81.08 127.15 231.88 346.06 463.65 583.11 701.88 823.51 884.53 735.86 821.07 821.07 791.83 791.83 791.83 710.08 710.08 680.53 857.83 597.34 570.25 543.61 195.50 518.21 491.71 468.96 420.55 558.14 396.45 377.52 200.81 118.84 530.82 863.70 317.49 236.41 236.41 413.58 36.37 67.02 31.52 31.52 102.87 60.01 13.29 11.90 156.51 196.62 116.39 7741.38 9122.45 Warning Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Minor Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk ) ) ConocoPhillips Alaska, Inc. Croated by mlehael For: S Shultz Doto plotted : JD-Doc-2DD2 Plot Reterence I. 1C-190 Verslon'7. Coordinates erc In feet n:lfcrcnco slot N190. TNe Vertical Depth. ore roIerenc. Est.RKB(Ooyon 141). ... === ~ :N'I'EQ Structure : Pad 1 C Well: 190 ~ ConocoPhiUiDS Iii! Field: Kuparuk River Unit Location: North Slope, Alaska 250 @ €J I I I , J I I ~30 CÄ 320 "'^' 800 , 31'0 50 60 290 70 280 80 270 90 260 100 110 240 120 230 130 140 150 200 160 170 ~ ~300 ~ Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well :~¡G¡IVA~ ) '\ } -------~ ConocoPhillips Alaska, Inc. Creatod by mienaol For: S Shultz Data plotted : :5O-Doc-2D02 Plot R.f....nc. ,. 1 C-190 V....lonl7. Coordrnotoa oro In toot rrAlllronco Dlot 1190. True VertIcal Depths are referoncm Est..RKB(Doyon 141). Structure: Pad 1 C Well: 190 ......- ConocoPhiUiDS iii Field : Kuparuk River Unit Location: North Slope, Alaska ... - ~ INTRQ 80 60 40 20 o 20 East (feet) - > 40 60 80 100 120 140 160 180 200 220 240 ~~ ~ 700 ,'=> _ .- s§Ð - 60 _.....900 - 40 ~- _________---- ~~ 20 ~oo ;o9!-~C-~~300 ~~5001'B-0 - - ~~'~"1DU * ~ II< 25_ ~/------/---- --~1~Õ--~ 1300 -20 o II< ". _ II< ¡m- __~0e --___ - 40 ,;g~~ ""'~3~0 - 60 ~~ ...... -80 A" ]OD- -$--300" .. 700 ... ... (f) '- ... ... 0 '- ~ - 100 C .. 900 1.90 -I- :r ",-..... -120 - CD CD -I- '-" -140 I V -160 -180 - 200 - 220 - 240 - 260 - 280 - 300 o iiGfNA- ) ) C",ctcd by michoel For: S Shultz ConocoPhillips Alaska, Well: 190 Structure: Pad 1 C Date plotted ; JQ-Deç-ZOOZ Plet Reference i. IC-190 Vereienf? Coordinates Ofe in fDOt reference slot 1190. True Vertical Dep1l1. ore refe~ce Es~RKB(Doyon H1). ... ~ RIJGaES ;N';~ Inc. V,.. iJi"& Ph "'!il· ~onoco E :1= IpS Field : Kuparuk River Unit Location: North Slope, Alaska 1050 700 350 350 It) * '3tó8° .. 4500 .. .3900 to 4800 * 4¡rst1 00 ill t 5400 * 5700 .. 6000 .. 6300 .. 6600 .. 6900 ~ 700 \600 East (feet) -> 1050 1400 1750 \ \ \ \ \ \ \ I I 3814 I I I I I I I I I I \ I I I I I 1 I I I I I I I I I I I I 1 I I I I I I I I I , I \ I I I I I I , I I I I I I I I I I , I I I 1 3800 ~ 2100 2450 2800 3150 3500 3850 4200 4550 1050 ~ ~ .. ~~OO ...........~900 - 14-00 .... .... .. ~200 -1750 ....~- - 2100 3900 - 2450 '< - 2800 -3150 - 3500 - 3850 tf) 0 s:: -+- - 4200 '3 ,......." -+. CD - 4550 CD -+- "--" I - 4900 V - 5250 - 5600 - 5950 - 6300 - 6650 - 7000 - 7350 - 7700 III ~EG' 1'\,A. r i 11 ,J :d~., ) ,) ConocoPhillips Alaska, Inc. ~ t:- nl-.."II- \..onocor": :1: IpS C~otod by mlchaol For: S Shultz Structure : Pad 1 C Well: 190 Date pletted : JQ-Doe-ZOOZ Plot Refercneo is: 1C-1g0 Veraionl7. Coordinates ora in feet rafClrence I3lo~ *190. True Vertical Depth. arc refercnce Est.RKß(Doycn 1'11). ... ~ ~ IN'I'EQ Field : Kuparuk River Unit Location: North Slope, Alaska East (feet) - > 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 o ~ , 1 300 -'¡"', ','It, 1 500 , "- , , ,*,1700 , , , ''010, ~900 , , ''010,2100 , , , , " ~:oo , , '*-- ~5,OO ",,~700 , , , " 2900 , , , , , \\3100 , , , , \ \ \ \ \ \ \ 3300 \ , \ \ \ \ \ \ \ \ \ \ \ \ \y;ssoo ~, "....~100 - laD - 200 , 'At ,3300 - 300 , - 400 25cro">jf~ ~- - 500 - 600 - 700 - 800 (f) o C -+ :J - 900 - 1000 -----. -+. CD CD -+ .......... - 1 lOa I V - 1200 ~tt l¡ - 1300 - 1400 - 1500 - 1600 - 1700 -1800 - 1900 O,i/GINAL I I ConocoPhillips Alaska, Inc. ~ Created by bmichael For: S Shultz Structure : Pad 1 C Well : 1 90 ConocoPhillips Dote plotted: 30-Deo-2002 Plot Relerence is 1 C-190 VersianH7, ¡ Field : Kuparuk River Unit Location : North Slope. Alaska I Coordinates ore in feet reference slol #190. True Vertical Depths ore relerence Est.RKB(Oayan 141), - ..... -- IN'IEQ ---- PROFILE COMMENT DATA ~ <===;;0 ~ ""'= ----- Point ----- MD Inc Dir TVD North East V. Sect Deg/100 KOP 250.00 0.00 100.00 250.00 0.00 0.00 0.00 0.00 --' Build/Turn 3/100 750.00 10.00 100.00 747.47 -7.56 42.86 32.63 2.00 EOC 1002.91 17.00 113.00 993.29 -25.84 98.60 81.68 3.00 Build/Turn 3/100 1114.50 17.00 113.00 1100.00 -38.59 128.63 110.37 0.00 c::> EOC 1714.73 33.80 129.00 1640.85 -179.10 340.90 352.57 3.00 ::'LJ Base Permafrost 1909.86 33.80 129.00 1803.00 -247.41 425.26 458.57 0.00 ---- Top T-3 2163.77 33.80 129.00 2014.00 -336.31 535.03 596.51 0.00 L') Top K -15 2510.35 33.80 129.00 2302.00 -457.64 684.86 784.79 0.00 --- ~ Build/Turn 4.5/100 3181.84 33.80 129.00 2860.00 -692.72 975.17 1149.58 0.00 ~ :t::=- Top Ugnu C 3658.64 53.48 141 .67 3204.00 -929.24 1199.69 1474.48 <""'" 4.50 r- EOC 3843.73 61.38 144.82 3303.58 -1054.20 1292.79 1630.23 4.50 Top Ugnu B 4205.73 61.38 144.82 3477.00 -1313.92 1475.86 1947.43 0.00 Top Ugnu A 4326.80 61.38 144.82 3535.00 -1400.78 1537.09 2053.52 0.00 Begin Final Bid/Turn a 4410.07 61.38 144.82 3574.89 -1460.53 1579.20 2126.48 0.00 K-13 4687.01 69.13 155.58 3691.00 -1678.54 1703.22 2374.26 or 4.50 -~ Top West Sak 0 5113.25 82.15 170.16 3797.00 -2071.56 1822.77 2756.08 4.50 EOC 5361 .46 90.00 178.13 3814.00 -2317.51 1847.92 2964.06 4.50 Target-7 5/8 Casing a 5461 .49 90.00 178.13 3814.00 -2417.49 1 851 . 1 8 3044.27 0.00 EOC 5467.63 90.18 178.13 3813.99 -2423.63 1851.39 3049.19 3.00 Target 2/Build 3/100 a 7648.54 90.18 178.13 3807.00 -4603.37 1 922.43 4797.75 0.00 EOC 7652.28 90.29 178.18 3806.98 -4607.10 1922.55 4800.75 3.00 Target 3/Build 3/100 a 9252.99 90.29 1 78.18 3799.00 -6206.99 1973.40 6083.35 0.00 EOC 9264.43 89.95 178.10 3798.98 -6218.42 1973.77 6092.52 3.00 TO - Casing pt. 10466.13 89.95 1 78.1 0 3800.00 -7419.47 2013.54 7056.38 0.00 ) ) Tie-In 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 59 60 61 62 63 64 65 66 67 68 69 70 71 01.40 II."" 11.,~'J.~""f.:t·.rI·\j :',. J.:,I JI,'; """"""."J"'J" šf;i~!'~;:: '.' "," ":1' r'~¡¡~~:" J"J J; ·,,(i ::f;·:,:~~ :",~ ';~ ~~4' ".,. "":'!~~~JSJ "'. .'." J. i/;}Ii".:{,*.. 'Ij\¡ '" "":'"~~~I'1\',, ',.",,,., ",¡I!:{>m1i1'1'31 . : .. . ,,' ':'. :.' ': . : ... . ." aa, !'J~ . ," ,.,., ·~e' 16~ " "" .. "~~~e\l~' : <':' ::'::,:~ ::~~::~1 ::. .:~ ::,:, :::~ :'~~~~~1~:~,: ..: :":'i",,~t¡'!\ø' ,"'J "'~~:~~~ClI' ::':,:: ::,' ::"~~~I~~;,:~,~' ;:. ::~':';, :':.;';t~~~~¡;,; .' ,': ':' ""'1' J'~1,!10' :.. ':'" ,,,\~~~.l1.,~, e~1 1,:1 ;i~~: j' ,:)'~ '(::~"~~' .". I~. ~:' ~ " ..I. I." I ., :::. :', ';"::;:r:~,,,:'~~' r:~':":':: ,::r \ "'IJ~~~"".JI"JI .:::,:,::,.:;:f.; 6" ì',{~::".' ,~::. ::\ :\;'. rj':n .""J'''''i~~:~,ü C'.".·.'.".' I: [il¡1 ::;" r, ;~:' ';!¡~j t~:j.j "'" " , .". .~~I~i*:; Co,"",,' J " ":!!.'II' :'~. ::,\ , .~ ,t~ \~t ~ ~.\~,,;~-'. . '!~'~' '1~t~!~:~ ,'i~'~~ I _~~?:~ .~~~ . : 1i ~,.::;~: '~: ", ,.~. I~ ,: I.. III 1 G. NA;.. ~ ) ) ConocóP't,illips Conoco/Phillips, Inc. Post Office Box 1 00360 Anchorage, Alaska 99510 January 3, 2003 Ms. Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill: 1 C-190 Surface Location: Target Location: Bottom Hole Location: 1638' FNL, 1395' FWL, Sec 12 T11N, R10E, UM 1324' FSL, 3240' FWL, Sec 12, T11 N, R10E, UM 1502' FSL, 3402' FWL, Sec 13, T11 N, R10E, UM Dear Commissioner: ,Jf"Ø":,rf'J Conoco/Phillips Alaska, Inc. hereby applies for a "Permit to Drill" to drill thrfuÍ~ell1 C-190. /' ~~~ The well will be drilled and completed using Doyon #141. Please utilize documents on file for this rig. The following logs are to be run on this well: GR/Res. Subject to AOGCC approval, fluids and cuttings generated from drilling the well will be pumped down an approved and existing annulus on Drillsite 1 C, or hauled to an approved Prudhoe or GKA Class II /' disposal well. The following people are the designated contacts for reporting responsibilities to the Commission: A) Completion Report (20 MC 25,070) Sharon Allsup-Drake, Drilling Technologist 263-4612 B) Geologic Data and Logs (20MC 25.071) Mike Werner, Geologist 265-6191 If you have any questions or require further information, please contact Steve Shultz at (907) 263-4620. Sincerely, ~~ R. Thomas Kuparuk Drilling Superintendent RECEIVED JAN 0 6 2003 l~laska Oil & Gas Cons. Commission Anchorage ·- § ~III r'..:~~""'~ S. K. ALLSUP-DRAKE PHilLIPS PETROLEUM COMPANY 711 G ST. ANCHORAGE AK 99501 j ....... C· HAS.·' E·· . chaseManhatt.anBankUSA,N.A. ValidU. pT.o·5000Dollars ~ rc- 1/3l:;;;-~;;:~~"""'~§kldk¿jß_~~-l~ í f 1:0 H .00 . I, 1,1: 21080000 I, 2725 'j'uo.OU, - - y -_."" - ¡. ___:.., ~--=.' , w"'i . _.' J A-~l.M· ;-.HG " ....,~_~ I ~ li >1 ;t \~ RECE\\lED JÞ\N 0 6 2.003 . 'OD lia on & Gas Cons. GomID\SS\ ~ èlas~· . Anchorage '-' )" ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function· of the original API number stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates The permit is approved subject . to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. , WELL PERMIT CHECKLIST CÖMPANY /J/!//r .!£.. k WELL NAME ~t' lie -/'10 PROGRAM: 'Exp _ Dev _ Redrll _ Re-Enter _ Serv:;:£. Wellbore seg _ FIELD&POOL ''1'70/£0 INITCLASS 1- c-J lf GEOLAREA 8"50 UNIT# ///Co ON/OFFSHORE ßN ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . ryt N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . , . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. .'. . Y N 6. W ell located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force.. . . . . . . . . . . . Y N / 11. Permit can be issued without conservation order. . . . . . . . Y N ' 12. Permit can be issued without administrative approval.. . . . . Y N Z- 0/ - Z. 2 0 I q q A oS I (Service Well Only) 13. Well located w(in area & strata authorized by injection order #2:...d. Y N / C ,- / 3_~) / C -::¿ C. J (Service Well Only) 14. All wells w/in % mile area of rev, iew identified. . . . . . . . . '. aNI J1. j' '* ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . N 16. Surface casing protects all known USDWs. . . . . . . . . . . N 17. CMT vol adequate to circulate on conductor & surf esg. . . . . N 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . ¥---N- ¡.J/~ 19. CMT will cover all known prod,uetive horizons. . . .' . . . .. . ~ ~fo ft-e-d 20. Casing designs adequate for C, T, B & permafrost. . . . . . . N Þ 4- / 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . .,' N cYVl O'V-' . ' 22. If a re-drill, has a 10-403 for abandonment been approved. . . ~ N/A-\ 23. Adequate wellbore separation proposed.. .'.' . . . . . ',' . . ' "' N 24. If diverter required,does 'it meet regulations. . '. . . . . ... . N D ", ' 25. Drilling fluid program sehema~ic & eqUiP, list adequate. . . . . !N it1t-r1L,' J11/A1 ì' 0 P P J ' 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . , N , 7 G) r. ' APPR DATE ~7.. BOPE press rating appropriate; test to 3500 psig. N j1{ SP I J "0 0 f~ {" " l 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . . N ~6A- i \ i 1 0 ~ 29. Work will occur without operation shutdown. . . . . . . . . . . N 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . .. 'ø~ \ ,Lt( d.ç. v..d1t· '''-IJ M ¡¿ t\ dr h L /¡q t :~.. ~:::n:: :~::::: :/::~::::~ :~::::~~~. . .' .. .. .. )féP ~ {ow.e~ ~ ~ II <\. <II \. f.vU "'-- . I ALA \4A.et. if".. ~v. :; 33. Data presented on potential overpressure zones. . . . . . . . Y /7 ' 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y, N' IV" ÎÍI" , ' ' , 35. Seabed condition survey (if ,off-shore). . . . . .. ...... 36. Contact namelphone for weekly progress reports. ..... " Y N' GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING UIC ENGINEER COMMISSIONER: RP~ APPR DATE t/~3 Ill. (Service Well Only) GEOLOGY APPR DATE H~. J;/N . (É~p'ora{cf4 Only) Rev: 10/15/02 v ~ 19tc"/77 /C-/2- ( Comments/lnstructions: TEM JDH JBR COT , 11 DTS 0 i/ G3¡ 03 MLB O~¿?/(/ ..J SFD_ WGA /" MJW '* r~û-{:Ðý ~Jt-t-- d.-v·'ll ~¡u¿ ~:>I€ti&,","- · G:\geology\permits\checklist.doc ) ') Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infannatian. information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. August 9,2005 7515 1 4.5" 12.6 lb. L-80 NSCT Tubing Well: Field: State: API No.: Top Log IntvI1.: Bot. Log IntvI1.: 1 C-190 Kuparuk Alaska 50-029-23136-00 Surface 5,035 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS: This log is tied into the 'DB' Nipple wI 3.812" No-Go Profile @ 4,470' (Driller's Depth). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damages. The caliper recordings indicate the 4.5" tubing logged appears to be in good condition. No significant wall penetrations or areas of cross-sectional wall loss are recorded throughout the tubing logged. No significant I.D. restrictions are recorded throughout the tubing logged. When the caliper log began, deposits prevented some of the fingers from opening completely until the tool passed through the 'DB' nipple, where the deposits were scraped off. As a result, minimum diameter information is unavailable for the bottom 19 joints logged (-565J. MAXIMUM RECORDED WAll PENETRATIONS: No significant wall penetrations (> 16%) are recorded throughout the tubing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL lOSS: No significant areas of cross-sectional wall loss (> 7%) are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the tubing logged. "~E"~'-" I;\.\jr ') ~ ?OO¡:¡ :sC;;~~H~."J,) h" tl r:.. ~} 1... - " I Field Engineer: L. Mills-Dawson Analyst: M. Lawrence Witness: T. Senden ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TI( 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659··2307 Fax: (907) 659··2314 --=f ~" 0)-- 0 ()~ clds" Well: Field: Company: Coun try: 1 C-190 Kuparuk ConocoPhillips Alaska, Inc. USA I Tubing: Weight 12.6 ppf Grade & Thread L-80 NSCT Nom.OD 4.5 ins Penetration and Metal Loss (% wall) _ penetration body 200 mI metal loss body 150 :11. 100 50 o I Oto lto 10 to 1% 10% 20% 20 to 40 to over 40% 85% 85% Number of joints analysed (total = 171) pene. 12 150 9 0 0 0 loss 1 23 48 0 0 0 0 Damage Configuration ( body) 10 o isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of joints damaged (total = 7) 42100 PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: Nom.lD 3.958 ins August 9, 2005 MFC 40 No. 99493 2.75 40 M. Lawrence Upper len. 1.2 ins Lower len. 1.2 ins Nom. Upset 4.5 ins Damage Profile (% wall) _ penetration body o o : Ë:" ~ mœ metal loss body 50 100 !=- : a 46~ æ- ~ GLM 1 ~ 55 ~ ~ 96 = § þ g ¡;. E r=- I , ¡;::=. ;=- E F æ: 143 ç:, t Bottom of Survey = 162 Analysis Overview page 2 ~ 'It PDSKfPORT JOINT TABULATION ~HEET Pipe: 4.5 in 1 2.6 ppf L-80 NSCT Well: 1 C-190 Body Wall: 0.271 in Field: Kuparuk Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. Nominal 1.0.: 3.958 in Country: USA Survey Date: August 9, 2005 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss 1.0. Comments (% wall) (Ins.) (Ins.) 01<) (Ins.) 0 50 100 .1 14 0 0.01 2 1 3.92 PUP 1 17 0 0.02 7 1 3.91 . 1.1 47 0 0.02 7 0 3.89 PUP t 1.2 57 0 0.01 2 1 3.89 PUP 2 67 0 0.01 4 1 3.89 3 98 0 0.02 8 .2 3.90 4 129 0 0.01 5 3.92 5 160 0 0.02 7 3.85 6 191 0 0.00 1 3.86 7 223 0 0.02 9 .2 3.91 8 255 0 0.02 6 3.92 9 286 0 0.02 7 3.92 10 316 0 0.02 7 3.90 11 347 0 0.01 2 3.90 t 12 377 0 0.02 7 3.91 13 407 0 0.00 1 3.91 14 438 0 0.02 7 3.90 15 469 0 0.01 2 3.90 15.1 500 0 0.01 4 .2 3.89 PUP 15.2 506 0 0 0 0 3.88 'DB' Nipple wI 3.875" No-Go Profile 15.3 507 0 0.01 5 1 3.89 PUP 16 513 0 0.01 2 1 3.90 17 544 0 0.00 1 0 3.92 18 575 0 0.02 7 1 3.92 19 605 0 0.02 6 1 3.90 20 635 0 0.02 7 1 3.91 21 666 0 0.00 1 0 3.91 22 697 0 0.02 7 1 3.90 23 727 0 0.02 7 1 3.90 24 758 0 0.02 7 1 3.91 Lt. Deposits. 25 788 0 0.02 7 2 3.87 Lt. Deposits. 26 820 0 0.00 1 3.90 27 851 0 0.01 2 3.90 28 882 0 0.02 7 3.90 29 912 0 0.02 7 3.91 30 943 0 0.02 7 3.91 31 974 0 0.01 4 3.92 32 1004 0 0.02 7 3.90 33 1035 0 0.03 10 3.89 34 1066 0 0.01 4 3.90 35 1096 0 0.02 7 3.90 36 1127 0 0.02 7 3.91 37 1157 0 0.02 8 3.90 38 1188 0 0.02 7 3.91 39 1219 0 0.02 7 3.91 40 1250 0 0.02 7 3.90 41 1280 0 0.02 9 3.90 42 1310 0 0.02 7 3.90 43 1341 0 0.02 7 3.91 44 1372 0 0.02 7 3.91 . Penetration Body IffiJ Metal Loss Body Page 1 PDS\~tPORT JOINT TABULATIONI~~HEET Pipe: 4.5 in 1 2.6 ppf L-80 NSCT Well: 1 C-190 Body Wall: 0.271 in Field: Kuparuk Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. N ominaILD.: 3.958 in Country: USA Survey Date: August 9, 2005 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body 0/0 Loss I.D. Comments (% wall) (Ins.) (Ins.) 0;;) (Ins.) 0 50 100 45 1403 0 0.02 7 3.91 . 46 1434 0 0.01 3 3.91 47 1465 0 0.02 9 3.90 48 1495 0 0.01 4 3.93 49 1526 0 0.02 7 3.92 50 1557 0 0.03 12 :2 3.90 Shallow pitting. 51 1587 0 0.02 7 3.91 52 1618 0 0.02 7 3.90 53 1649 0 0.01 4 3.91 54 1679 0 0.01 5 3.92 55 1710 0 0.02 7 3.90 Lt. Deposits. 56 1741 0 0.02 8 3.91 57 1771 0 0.02 7 3.91 58 1802 0 0.01 2 3.90 59 1833 0 0.03 10 3.91 60 1863 0 0.01 2 3.91 61 1893 0 0.02 6 3.91 62 1924 0 0.01 2 3.91 63 1955 0 0.02 7 3.91 Lt. Deposits. 64 1985 0 0.00 1 3.91 65 2016 0 0.01 2 3.86 66 2047 0 0.00 1 3.90 67 2078 0 0.00 1 3.91 68 2108 0 0.02 6 3.90 ¡ 69 2137 0 0.02 7 3.90 70 2167 0 0.02 7 2 3.89 71 2198 0 0.02 6 3.90 72 2229 0 0.02 7 3.89 73 2259 0 0.02 7 3.90 74 2290 0 0.01 4 3.90 75 2320 0 0.01 2 3.93 76 2352 0 0.01 3 3.90 77 2383 0 0.01 5 3.91 78 2413 0 0.02 7 3.91 79 2444 0 0.02 7 3.91 80 2475 0 0.02 7 3.91 81 2505 0 0.02 7 3.91 82 2536 0 0.02 7 3.87 83 2568 0 0.02 7 3.90 84 2598 0 0.02 7 3.90 85 2628 0 0.02 7 3.91 86 2659 0 0.02 7 3.91 87 2690 0 0.01 2 3.91 88 2721 0 0.02 7 3.90 89 2751 0 0.02 8 :2 3.90 90 2782 0 0.01 3 3.89 91 2813 0 0.01 4 3.91 ~ 92 2844 0 0.02 7 3.91 93 2874 0 0.00 1 3.91 94 2904 0 0.02 7 3.90 I Penetration Body :j.ì~/: Metal Loss Body Page 2 :1 1\ PDS'KEPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 N sa Well: 1 C-190 Body Wall: 0.271 in Field: Kuparuk Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. Nominal 1.0.: 3.958 in Country: USA Survey Date: August 9, 2005 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss 1.0. Comments (% wall) (Ins. ) (Ins.) OJ (Ins.) 0 50 100 !O 95 2935 0 0.02 7 1 3.91 r 96 2965 0 0.00 1 1 3.90 I 96.1 2996 0 0.02 8 1 3.88 PUP II 96.2 3002 0 0 0 0 N/A GLM 1 (Latch @ 3:30) -i 96.3 3009 0 0.02 7 1 3.84 PUP Lt. Deposits. 97 3015 0 0.02 7 1 3.90 98 3046 0 0.02 7 2 3.90 99 3077 0 0.02 7 3.91 100 3107 0 0.02 7 3.90 101 3138 0 0.01 2 2 3.88 102 3169 0 0.01 3 1 3.91 103 3200 0 0.02 7 1 3.91 104 3230 0 0.02 7 1 3.91 105 3261 0 0.01 3 1 3.90 106 3291 0 0.02 6 1 3.90 107 3322 0 0.02 9 3 3.91 108 3354 0 0.02 7 3 3.85 109 3386 0 0.01 4 1 3.89 110 3416 0 0.02 7 2 3.90 111 3447 0 0.02 7 3.87 112 3479 0 0.02 7 3.90 113 3510 0 0.01 3 2 3.89 114 3540 0 0.03 10 2 3.89 115 3571 0 0.02 8 1 3.91 116 3602 0 0.01 2 1 3.88 117 3634 0 0.03 11 1 3.89 118 3664 0 0.02 9 3 3.88 119 3696 0 0.03 10 1 3.90 120 3727 0 0.03 10 2 3.90 121 3757 0 0.02 7 2 3.90 122 3788 0 0.01 2 2 3.90 123 3819 0 0.01 4 3.90 124 3850 0 0.01 2 2 3.89 125 3880 0 0.01 2 1 3.90 126 3911 0 0.03 10 1 3.89 127 3942 0 0.03 11 3 3.85 128 3973 0 0.01 2 1 3.90 129 4004 0 0.03 12 1 3.89 Shallow pitting. 130 4034 0 0.02 7 2 3.90 131 4064 0 0.00 1 3.89 132 4096 0 0.02 8 2 3.90 133 4126 0 0.02 8 2 3.88 134 4156 0 0.01 2 2 3.90 135 4187 0 0.02 7 1 3.89 136 4217 0 0.03 10 3 3.89 137 4248 0 0.02 7 2 3.89 ~ 138 4278 0 0.01 2 1 3.89 139 4309 0 0.03 10 1 3.91 140 4340 0 0.02 9 3 3.86 141 4371 0 0.03 10 1 3.89 I Penetration Body ,:i:: Metal Loss Body Page 3 'I \ 'I PDS KEPORT JOINT TABULATION SHEET Pipe: 4.5 in 1 2.6 ppf L-80 N sa Well: 1 C-190 Body Wall: 0.271 in Field: Kuparuk Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. N ominaII.D.: 3.958 in Country: USA Survey Date: August 9, 2005 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss 1.0. Comments (% wall) (Ins. ) (Ins.) (Yo (Ins.) 0 50 100 142 4401 0 0.02 7 2 3.88 ,. 143 4432 0 0.01 2 2 3.84 l 143.1 4464 0 0.00 1 2 3.85 PUP 143.2 4470 0 0 0 0 3.81 'DB' Nipple wI 3.812" No·Go Profile ~ 143.3 4472 0 0.01 5 2 N/A PUP ~ 144 4478 0 0.02 8 2 N/A 145 4508 0 0.01 2 2 N/A 146 4538 0 0.02 7 2 N/A 147 4569 0 0.02 7 2 N/A 148 4600 0 0.02 7 2 N/A 149 4631 0 0.01 2 2 N/A 150 4662 0 0.01 6 1 N/A 151 4692 0 0.02 8 3 N/A 152 4723 0 0.02 8 2 N/A 153 4753 0 0.03 12 3 N/A Shallow pitting. 154 4780 0 0.04 14 7 N/A Line shallow corrosion. 155 4815 0 0.04 16 5 N/A Shallow corrosion. 156 4846 0 0.02 8 3 N/A 157 4876 0 0.03 12 4 N/A Shallow pitting. 158 4908 0 0.04 13 1 N/A Shallow corrosion. 159 4939 0 0.02 8 5 N/A 160 4966 0 0.03 10 4 N/A 161 4998 0 0.03 10 4 N/A 162 5029 0 0.02 7 6 N/A I Penetration Body ;)1:" ,i'I"'! Metal Loss Body Page 4 KRU 1C-190 ConocoPhillips Alaska, Inc. 1 C-190 TUBING (0-5298, 00:4.500. 10:3.958) SURFACE (0-5449. 00:7.625. Wt29.70) NIP (515-516. 00:5.630) Gas Lift mdrel/Oummy Valve 1 (3007-3008. 00:5.984) NIP (4470-4471, 00:5.450) XO (5283-5285, 00:5.520) SEAL (5285-5286, 00:5.570) Perf (5298-10466) PACKER (5299-5300, 00:6.550) l SLOTTEO LINER (5287-10466, 00:4.500, Wt:12.60) PACKOFF :10431-10432, 00:4.950) SHOE :1 04~~:.0~~~: ~ I I :_-- ...-..- I I' 1- --, ,,-'" -- - --- ..............,.. .........,'.... ._~,. M I" .' -- --, "-. - '-- -- - . . :=--~ --=.-- --=II E___. a=- API: 500292313600 SSSV Type: NIPPLE Angle @ TS: deg @ Angle @ TD: 91 deg @ 10466 Well Type: INJ Orig 3/11/2003 Completion: Annular Fluid: Last W/O: Reference Log: 28' RKB Ref Log Date: Last Tag: 10447 E-Line TD: 10466 ftKB Last Tag Date: 2/17/2004 Max Hole Angle: 95 deg @ 9068 Casing String - ALL STRINGS (Slotted Liner=3 jts 4.5" TBG/1 jt 4.5" Slotted TBG (à)5324' to 10466') Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 110 110 62.50 H-40 WELDED SURFACE 7.625 0 5449 3834 29.70 L-80 BTC-MD SLOTTED LINER 4.500 5287 10466 10466 12.60 L-80 NSCT TubIng String - TUBING Size I Top I Bottom 4.500 0 5298 Perforations Summary Interval I TVD I Zone I Status 1Ft I SPF I Date I Type I Comment 5298 -10466 3833 -10466 WS D 5168 99 3/9/2003 IPERF SLOTTED LINER Gas Lift MandrelsNalves St MD TVD Man Man Type V Mfr V Type V aD Latch Port TRO Date Mfr Run 1 3007 2710 CAMCO KBG-2 DMY 1.0 BK 0.000 0 4/13/2003 Other (plugs, equip., etc.) - JEWELRY Depth TVD Type Description 515 513 NIP CAMCO 'DB' NIPPLE W/3.875 NO GO PROFILE 4470 3613 NIP CAMCO 'DB' NIPPLE W/3.812" NO GO PROFILE 5283 3832 XO BAKER XO BUSHING V AM 5285 3832 SEAL BAKER BULLET SEAL ASSEMBLY WNAM BOX UP Other (plugs, equip., etc.) - LINER Depth TVD Type 5299 3833 PACKER 5307 3833 NIP 10431 3759 PACKOFF 10464 3759 SHOE General Notes Date Note 3/9/2003 TREE: ABB-VETCO GRAY 16 X 7 5/8" X 4.5" 5000 psi, HORIZONTAL TREE CAP CONNECTION: OTIS 9" Rev Reason: Tag Last Update: 2/27/2004 TVD 3833 I Wt I Grade I 12.60 L-80 Thread NSCT Vlv Cmnt ID 3.875 3.812 3.880 4.860 Description ZXP PACKER - HRD PROFILE RS NIPPLE BAKER LINER PACKOFF BUSHING REAMER FLOAT SHOE ID 4.940 4.880 2.350 3.958 ) **** REEL HEADER **** LDWG 03/03/18 AWS 01 **** TAPE HEADER **** LDWG 03/03/06 01 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: LISTAPE.HED TAPE HEADER KUPARUK RIVER UNIT MWD /MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 1 F. WENDLER D. WESTER # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: ') a 03,-00 ~ IIto3í lC-190 500292313600 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 18-MAR-03 7.625 5449.0 10466.0 MWD RUN 2 2 T STURDIVANT D. HElM 12 IIN 10E 87.20 59.20 MWD RUN 3 3 F. WENDLER F. HERBERT OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE 9.875 6.750 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! LDWG File Version 1.000 !!!!! ! !! !! !!! !!! ! !! Extract File: FILE001.HED FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # *** LIS COMMENT RECORD *** 1024 LDWG .001 **** FILE HEADER **** 8 bytes 132 bytes Minimum record length: Maximum record length: 82 records... Tape Subfile: 1 GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR TO DELIVERY FROM THE WELL SITE. SURFACE LOCATION: LAT: N 70 DEG 19' 29.067" LONG: W149 DEG 29' 38.417" LOG MEASURED FROM D.F. AT 87.2 FT. ABOVE PERM. DATUM (M.S.L.). COMMENTS: (1) Baker Hughes INTEQ runs 1 through 3 utilized Multiple Propagation Resistivity (MPR) and Gamma Ray services from 120-10466 feet MD (120 - 3759' TVD). (2) Per ConocoPhillips Alaska instructions (Mike Werner), the Gamma Ray curve from Run 3, 5449 to 10466 feet MD (3834 - 3759' TVD) is corrected for KCL mud. The GR is corrected for 6% (by weight) KCL con- centration. This correction is applied only to the edit- ed data file. The raw data files remain uncorrected. REMARKS: (1) Commenced LWD logging at 150 feet MD (150' TVD). (2) The interval from 3093 to 3137 feet MD (2781-2818' TVD) was logged up to 4.6 hours after being drilled due to a short trip. (3) The interval from 5201 to 5247 feet MD (3826 - 3830' TVD) was logged up to 27.2 hours after being drilled due to a trip out of the hole to pick up a bit. (4) Depth of 7 5/8" Casing Shoe - Logger: 5449 feet MD (3834' TVD) Depth of 7 5/8" Casing Shoe - Driller: 5449 feet MD (3834' TVD) (5) The interval from 8992 to 9036 feet MD (3791 - 3790' TVD) was logged up to 13.9 hours after being drilled due to a short trip and a change in drill pipe for directional purposes. (6) The interval from 10422 to 10466 feet MD (3760 - 3759' TVD) was not logged due to sensor-bit offset at TD. $ ) ) ') ) FILE SUMMARY PBU TOOL CODE MWD $ START DEPTH 150.0 STOP DEPTH 10466.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ BIT RUN NO 1 2 3 MERGE TOP 150.0 5201. 0 5411.0 MERGE BASE 5201.0 5411.0 10466.0 # REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT lc-190 5.xtf 150 - ConocoPhillips Alaska, Inc. lC-190 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GR 0.0 RPD RPD RPD 0.0 RPM RPM RPM 0.0 RPS RPS RPS 0.0 RPX RPX RPX 0.0 ROP ROP ROPS 0.0 FET FET RPTH 0.0 MTEM MTEM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 36 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 28 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME MSB 18704 6.75 MPR MEMORY 5247.0 150.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): 27-FEB-03 STOP DEPTH 5201.0 START DEPTH 150.0 FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ log header data for each bit run in separate files. 1 .2500 2 !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 ! ! !! !!! !!!!!!!! !! !! Extract File: FILEOll.HED *** LIS COMMENT RECORD *** 1024 LDWG .002 **** FILE HEADER **** 8 bytes 4124 bytes Minimum record length: Maximum record length: 781 records... Tape Subfile: 2 **** FILE TRAILER **** feet Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 150.000000 10466.000000 0.500000 737 Total Data Records: Tape depth ID: F 8 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAP I 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPM MWD 68 1 OHMM 4 4 4 RPS MWD 68 1 OHMM 4 4 5 RPX MWD 68 1 OHMM 4 4 6 ROP MWD 68 1 FPHR 4 4 7 FET MWD 68 1 HR 4 4 8 MTEM MWD 68 1 DEGF 4 4 ------- 32 ) ) ) BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. GAMMA. RAY RESIST. # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: # ) 5201. 0 o .3 84.3 TOOL NUMBER 804063 MPR 22008 SRIG 31867 9.875 .0 Spud Mud 9.20 .0 .0 300 .0 .000 .000 .000 .000 115.0 .0 .0 .0 .00 .000 .0 o BIT RUN 1 (MWD Run 1). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA. RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ *** INFORMATION TABLE: CONS MNEM VALU WDFN lc-190.xtf LCC 150 -------------------------------- \ ,} ) CN WN FN COUN STAT ConocoPhillips Alaska, I 1C-190 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 RACL RACL RAD 0.0 RASL RASL RACSLM 0.0 RACH RACH RAS 0.0 RASH RASH RACSHM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 52 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 19 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 RACL MWD 68 1 OHMM 4 4 7 RASL MWD 68 1 OHMM 4 4 8 RACH MWD 68 1 OHMM 4 4 9 RASH MWD 68 1 OHMM 4 4 10 ROPS MWD 68 1 FPHR 4 4 11 RPTH MWD 68 1 MINS 4 4 12 TCDM MWD 68 1 DEGF 4 4 ------- 48 Total Data Records: 1064 Tape File Start Depth 150.000000 Tape File End Depth 5201.000000 Tape File Level Spacing 0.250000 Spud Mud 9.50 .0 .0 250 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): # 9.875 .0 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # TOOL NUMBER 804063 MPR 22008 SRIG 31867 BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. RESIST. GAMMA RAY TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GRAM $ # 83.6 90.1 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: MSB 18704 6.75 MPR MEMORY 5457.0 5201. 0 5411.0 o 28-FEB-03 STOP DEPTH 5411.0 START DEPTH 5201.0 FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ log header data for each bit run in separate files. 2 .2500 3 !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILEOI2.HED *** LIS COMMENT RECORD *** 1024 LDWG .003 **** FILE HEADER **** 8 bytes 4124 bytes Minimum record length: Maximum record length: 1163 records... Tape Subfile: 3 **** FILE TRAILER **** feet Tape File Depth Units ) ) ) ) FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # .0 .000 .000 .000 .000 140.0 .0 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): o # REMARKS: # .0 BIT RUN 2 (MWD Run 2). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT 1c-190.xtf 150 ConocoPhillips Alaska, I 1C-190 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 RACL RACL RAD 0.0 RASL RASL RACSLM 0.0 RACH RACH RAS 0.0 RASH RASH RACSHM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 !! !! ! !!! ! ! !!! ! ! !!!! LDWG File Version 1.000 *** LIS COMMENT RECORD *** 1024 LDWG .004 **** FILE HEADER **** 8 bytes 4124 bytes Minimum record length: Maximum record length: 144 records... Tape Subfile: 4 **** FILE TRAILER **** feet Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 5201.000000 5411.000000 0.250000 ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 RACL MWD 68 1 OHMM 4 4 7 RASL MWD 68 1 OHMM 4 4 8 RACH MWD 68 1 OHMM 4 4 9 RASH MWD 68 1 OHMM 4 4 10 ROPS MWD 68 1 FPHR 4 4 11 RPTH MWD 68 1 MINS 4 4 12 TCDM MWD 68 1 DEGF 4 4 ------- 48 Total Data Records: 45 0.250 * F FRAME SPACE = Data record type is: 0 Datum Frame Size is: 52 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 19 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 * FORMAT RECORD (TYPE# 64) ) ) ) ) ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: FILE013.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 4 log header data for each bit run in separate files. 3 .2500 START DEPTH 5411. 0 STOP DEPTH 10466.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. RESIST. GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # 06-MAR-03 MSB 18704 4.75 MPR MEMORY 10466.0 5411.0 10422.0 o 87.8 95.0 TOOL NUMBER 184093 MPR 1074 SRIG 5318 6.750 5449.0 KCL Polymer 8.85 .0 .0 31000 .0 .000 .000 .000 .000 88.0 .0 .0 .0 .00 .000 .0 o BIT RUN 3 (MWD Run 3) . GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWÐ-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) REMARKS: ) ) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT 1c-190.xtf 150 ConocoPhillips Alaska, I 1C-190 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 RACL RACL RAD 0.0 RASL RASL RACSLM 0.0 RACH RACH RAS 0.0 RASH RASH RACSHM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 52 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 19 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units Size Length " ) 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 RACL MWD 68 1 OHMM 4 4 7 RASL MWD 68 1 OHMM 4 4 8 RACH MWD 68 1 OHMM 4 4 9 RASH MWD 68 1 OHMM 4 4 10 ROPS MWD 68 1 FPHR 4 4 11 RPTH MWD 68 1 MINS 4 4 12 TCDM. MWD 68 1 DEGF 4 4 ------- 48 Total Data Records: 1065 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 5411. 000000 10466.000000 0.250000 teet **** FILE TRAILER **** Tape Subtile: 5 1164 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 03/03/06 01 **** REEL TRAILER **** LDWG 03/03/18 AWS 01 Tape Subtile: 6 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes ) ') " é10h;¡ lJf ;Z 03 - Do) ConocoPhillips Alaska, Inc. Pad 1C 190 slot #190 Kuparuk River Unit North Slope, Alaska SUR V E Y LIS TIN G by Baker Hughes INTEQ Your ref Our ref License MWD <0-10466'> svy6852 Date printed Date created Last revised 10-Mar-2003 25-Feb-2003 7-Mar-2003 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w149 30 19.124 Slot location is n70 19 29.066,w149 29 38.421 Slot Grid coordinates are N 5968602.070, E 562401.260 Slot local coordinates are 1637.60 S 1394.49 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ') ) ConocoPhillips Alaska, Inc. 5URVEY LI5TING Page 1 Pad 1C,190 Your ref MWD <0-10466'> Kuparuk River Unit,North 5lope, Alaska Last revised : 7-Mar-2003 Measured Inclin Azimuth True Vert RECTANGULAR Dogleg Vert G RID COO R D 5 Depth Degrees Degrees Depth COORD I N ATE 5 Deg/100ft 5ect Easting Northing 0.00 0.00 0.00 0.00 O.OON O.OOE 0.00 0.00 562401.26 5968602.07 120.00 0.00 0.00 120.00 O.OON O.OOE 0.00 0.00 562401.26 5968602.07 205.47 0.83 119.62 205.47 0.315 0.54E 0.97 0.57 562401.80 5968601.77 293.26 3.25 114.29 293.19 1.645 3.36E 2.76 3.38 562404.63 5968600.45 382.55 6.33 115. 95 382.16 4.845 10.09E 3.45 10.08 562411.39 5968597.31 475.91 9.22 114.79 474.65 10.235 21.51E 3.10 21.41 562422.85 5968592.02 562.64 11.51 113.79 559.96 16.635 35.74E 2.65 35.29 562437.13 5968585.73 657.14 12.33 113.28 652.42 24.435 53.64E 0.87 52.54 562455.09 5968578.08 744.32 12.27 113.02 737.60 31.735 70.71E 0.09 68.89 562472.22 5968570.92 836.65 13.37 114.45 827.63 39.985 89.46E 1.24 87.04 562491.04 5968562.82 925.58 15.27 111.72 913.80 48.575 109.70E 2.27 106.37 562511.34 5968554.40 1016.31 17.85 113.71 1000.76 58.595 133.54E 2.91 129.06 562535.26 5968544.58 1111. 38 20.25 117.87 1090.62 72.145 161. 43E 2.90 157.05 562563.26 5968531.25 1205.94 21.10 120.31 1179.09 88.385 190.59E 1.28 187.92 562592.55 5968515.25 1299.46 22.54 122.22 1265.91 106.435 220.29E 1.72 220.56 562622.39 5968497.44 1392.93 24.69 126.39 1351.55 127.575 251.17E 2.91 256.33 562653.43 5968476.56 1486.97 27.51 129.36 1436.00 153.005 283.78E 3.30 296.55 562686.24 5968451.39 1577 . 82 27.95 128.99 1516.41 179.715 316.55E 0.52 337.86 562719.23 5968424.96 1672.62 29.75 131. 22 1599.44 209.195 351.51E 2.21 382.70 562754.43 5968395.77 1765.98 32.06 130.47 1679.54 240.545 387.79E 2.51 429.83 562790.96 5968364.72 1858.43 33.83 130.02 1757.12 273.015 426.17E 1. 93 479.15 562829.59 5968332.56 1952.46 33.71 128.37 1835.29 306.045 466.67E 0.98 530.23 562870.36 5968299.86 2044.69 33.23 129.54 1912.23 338.025 506.23E 0.87 579.89 562910.17 5968268.21 2139.04 35.65 127.39 1990.04 371.185 548.02E 2.87 631.87 562952.22 5968235.39 2232.02 35.32 126.09 2065.75 403.465 591.26E 0.89 684.08 562995.73 5968203.46 2325.92 34.50 128.22 2142.75 435.915 634.09E 1. 56 736.14 563038.82 5968171.37 2420.16 34.23 128.20 2220.54 468.815 675.89E 0.29 787.93 563080.88 5968138.81 2513.15 33.74 127.59 2297.65 500.745 716.91E 0.64 838.46 563122.15 5968107.22 2607.29 33.19 127.73 2376.18 532.465 758.00E 0.59 888.88 563163.50 5968075.85 2700.70 32.82 128.44 2454.52 563.845 798.05E 0.57 938.39 563203.79 5968044.79 2793.28 32.54 130.62 2532.45 595.655 836.61E 1.31 987.29 563242.60 5968013.30 2886.64 34.45 130.60 2610.30 629.185 875.72E 2.05 1037.90 563281.98 5967980.09 2980.02 34.21 130.86 2687.41 663.54S 915.62E 0.30 1089.64 563322.16 5967946.05 3074.73 33.63 131.13 2766.00 698.21S 955.52E 0.63 1141.62 563362.33 5967911.71 3169.02 33.18 131.11 2844.72 732.355 994.62E 0.48 1192.69 563401.71 5967877.90 3258.70 35.15 133.23 2918.92 766.175 1031.93E 2.57 1242.39 563439.28 5967844.38 3354.24 39.18 138.93 2995.06 807.795 1071.82E 5.54 1299.81 563479.51 5967803.09 3446.80 42.46 135.98 3065.11 852.325 1112.75E 4.11 1360.14 563520.80 5967758.91 3541.79 47.50 140.31 3132.29 902.365 1157.44E 6.21 1427.13 563565.88 5967709.23 3633.06 51.70 142.93 3191.44 956.865 1200.54E 5.09 1496.60 563609.42 5967655.09 3726.80 55.53 143.39 3247.04 1017.255 1245.77E 4.10 1572.02 563655.14 5967595.08 3819.05 58.96 143.24 3296.94 1079.455 1292.HE 3.72 1649.55 563701.98 5967533.26 3913.56 59.44 143.89 3345.33 1144.775 1340.32E 0.78 1730.67 563750.72 5967468.35 4007.15 61.89 144.13 3391.18 1210.785 1388.26E 2.63 1812.17 563799.19 5967402.73 4101.04 62.09 144.49 3435.27 1278.105 1436.62E 0.40 1894.96 563848.09 5967335.81 4194.01 61. 40 144.54 3479.29 1344.785 1484.16E 0.74 1976.73 563896.16 5967269.53 4287.79 60.73 144.86 3524.66 1411.765 1531.59E 0.77 2058.67 563944.13 5967202.94 4381.36 60.66 146.24 3570.46 1479.055 1577.74E 1.29 2140.05 563990.82 5967136.04 4474.33 62.53 148.76 3614.69 1548.015 1621.66E 3.12 2221.36 564035.30 5967067.44 4569.74 65.45 151.60 3656.53 1622.405 1664.27E 4.06 2306.08 564078.50 5966993.41 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #190 and TVD from RKB(Doyon 141) (87.20 Ft above mean sea level). Bottom hole distance is 7705.65 on azimuth 165.47 degrees from wellhead. Vertical section is from wellhead on azimuth 141.43 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ,) ) ConocoPhillips Alaska, Inc. 5URVEY LI5TING Page 2 Pad 1C,190 Your ref MWD <0-10466'> Kuparuk River Unit,North 5lope, Alaska Last revised : 7-Mar-2003 Measured Inclin Azimu th True Vert RECTANGULAR Dogleg Vert G RID COO R D 5 Depth Degrees Degrees Depth COO R D I N ATE 5 Deg/100ft 5ect Easting Northing 4660.48 69.00 155.58 3691.66 1697.325 1701.43E 5.63 2387.83 564116.27 5966918.80 4753.35 71.01 159.75 3723.43 1778.035 1734.57E 4.74 2471.59 564150.06 5966838.37 4848.92 73.20 163.80 3752.80 1864.395 1762.98E 4.64 2556.83 564179.17 5966752.25 4940.43 75.44 168.02 3777.55 1949.825 1784.41E 5.07 2636.98 564201.29 5966667.01 5035.36 78.07 168.44 3799.29 2040.285 1803.25E 2.80 2719.45 564220.87 5966576.72 5128.99 81.17 170.44 3816.16 2130.805 1820.12E 3.92 2800.75 564238.47 5966486.34 5181.92 82.90 172 . 06 3823.50 2182.615 1828.09E 4.46 2846.22 564246.86 5966434.61 5224.31 84.26 172.43 3828.24 2224.345 1833.78E 3.32 2882.40 564252.88 5966392.92 5316.05 88.62 176.43 3833.93 2315.435 1842.65E 6.44 2959.15 564262.50 5966301.91 5393.73 90.06 178.03 3834.83 2393.015 1846.41E 2.77 3022.15 564266.88 5966224.37 5522.85 91.66 181.14 3832.89 2522.105 1847.34E 2.71 3123.66 564268.87 5966095.32 5616.70 91.97 180.57 3829.92 2615.895 1845.94E 0.69 3196.12 564268.23 5966001.53 5709.85 91.84 181. 43 3826.82 2708.975 1844.32E 0.93 3267.89 564267.36 5965908.44 5801. 70 90.40 179.89 3825.03 2800.795 1843.26E 2.30 3339.02 564267.05 5965816.62 5890.69 91. 20 178.73 3823.78 2889.765 1844.33E 1. 58 3409.25 564268.85 5965727.67 5930.17 90.74 177.29 3823.12 2929.215 1845.70E 3.83 3440.95 564270.54 5965688.24 5990.61 89.17 177 . 12 3823.16 2989.585 1848.65E 2.61 3489.99 564273.97 5965627.90 6083.22 93.90 178.14 3820.68 3082.055 1852.48E 5.22 3564.67 564278.55 5965535.48 6176.50 91.08 179.23 3816.63 3175.215 1854.62E 3.24 3638.84 564281.45 5965442.35 6269.99 90.68 178.51 3815.20 3268.675 1856.46E 0.88 3713.07 564284.05 5965348.92 6363.49 90.98 178.66 3813.84 3362.135 1858.77E 0.36 3787.58 564287.12 5965255.49 6457.68 92.33 181.87 3811.12 3456.265 1858.33E 3.70 3860.91 564287.45 5965161.36 6550.16 89.97 182.58 3809.26 3548.655 1854.74E 2.66 3930.90 564284.61 5965068.96 6644.27 91. 20 181.87 3808.30 3642.68S 1851.09E 1. 51 4002.15 564281.72 5964974.91 6737.39 91.59 181.70 3806.04 3735.735 1848.19E 0.46 4073.09 564279.58 5964881.85 6831.72 90.64 182.95 3804.20 3829.965 1844.36E 1. 66 4144.38 564276.52 5964787.60 6923.00 90.31 183.24 3803.44 3921.105 1839.44E 0.48 4212.57 564272.33 5964696.43 7016.69 90.55 181. 82 3802.74 4014.705 1835.30E 1.54 4283.17 564268.96 5964602.81 7109.87 89.39 181. 31 3802.79 4107.845 1832.76E 1.36 4354.41 564267.17 5964509.66 7202.26 90.52 179.43 3802.86 4200.225 1832.16E 2.37 4426.27 564267.33 5964417.28 7297.30 90.95 181.29 3801.64 4295.255 1831.56E 2.01 4500.20 564267.50 5964322.27 7389.80 90.86 179.24 3800.18 4387.735 1831.13E 2.22 4572.24 564267.83 5964229.79 7482.88 90.77 177 . 03 3798.86 4480.745 1834.16E 2.38 4646.85 564271.61 5964136.81 7577.12 91.07 177 . 55 3797.34 4574.875 1838.62E 0.64 4723.22 564276.83 5964042.74 7670.03 91.07 174.17 3795.61 4667.505 1845.32E 3.64 4799.83 564284.29 5963950.17 7764.03 89.33 173.90 3795.28 4760.995 1855.09E 1. 87 4879.02 564294.82 5963856.77 7856.86 90.76 175.06 3795.21 4853.395 1864.02E 1. 98 4956.82 564304.50 5963764.46 7949.70 89.72 175.33 3794.82 4945.905 1871.80E 1.16 5034.00 564313.02 5963672.02 8043.79 90.61 174.97 3794.55 5039.655 1879.75E 1.02 5112.27 564321.74 5963578.35 8137.26 90.18 175.37 3793.90 5132.795 1887.62E 0.63 5189.99 564330.36 5963485.29 8230.25 89.51 177 . 95 3794.15 5225.61S 1893.04E 2.87 5265.94 564336.54 5963392.52 8324.38 88.96 177 .49 3795.41 5319.66S 1896.78E 0.76 5341. 81 564341.04 5963298.52 8418.12 91.78 178.94 3794.81 5413.345 1899.70E 3.38 5416.88 564344.73 5963204.87 8512.23 89.02 175.97 3794.15 5507.335 1903.88E 4.31 5492.97 564349.67 5963110.92 8605.18 91.81 176.15 3793.48 5600.055 1910.27E 3.01 5569.45 564356.81 5963018.27 8698.01 91.50 178.21 3790.79 5692.725 1914.83E 2.24 5644.75 564362.12 5962925.65 8791.40 91.13 176.37 3788.65 5785.985 1919.25E 2.01 5720.42 564367.30 5962832.44 8883.18 89.02 179.01 3788.53 5877.675 1922.95E 3.68 5794.42 564371.74 5962740.79 8976.52 88.77 178.44 3790.33 5970.97S 1925.02E 0.67 5868.66 564374.57 5962647.52 9068.10 94.98 178.26 3787.34 6062.425 1927.66E 6.78 5941.80 564377.95 5962556.10 All data in feet unless otherwise stated. Calculation uses min~um curvature method. Coordinates from slot #190 and TVD from RKB(Doyon 141) (87.20 Ft above mean sea level). Bottom hole distance is 7705.65 on azimuth 165.47 degrees from wellhead. Vertical section is from wellhead on azimuth 141.43 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ) ) ConocoPhillips Alaska, Inc. 5URVEY LI5TING Page 3 Pad lC,190 Your ref MWD <0-10466'> Kuparuk River Unit,North 5lope, Alaska Last revised : 7-Mar-2003 Measured Inclin Azimuth True Vert R E C TANGU LA R Dogleg Vert G RID C OORD5 Depth Degrees Degrees Depth C 0 0 RDINA T E 5 Deg/100ft Sect Easting Northing 9161. 34 93.60 180.50 3780.36 6155.395 1928.66E 2.82 6015.12 564379.71 5962463.16 9254.22 91.41 180.84 3776.30 6248.165 1927.58E 2.39 6086.98 564379.38 5962370.38 9348.18 87.82 179.69 3776.93 6342.105 1927.14E 4.01 6160.16 564379.71 5962276.45 9443.70 88.74 179.25 3779.80 6437.585 1928.02E 1. 07 6235.36 564381.37 5962181.00 9533.75 90.25 178.34 3780.59 6527.605 1929.92E 1.96 6306.92 564383.99 5962091.00 9627.81 90.12 178.19 3780.29 6621.625 1932.77E 0.21 6382.21 564387.61 5961997.02 9721.79 89.63 179.51 3780.49 6715.575 1934.65E 1.50 6456.85 564390.25 5961903.09 9815.16 92.76 179.81 3778.55 6808.915 1935.21E 3.37 6530.17 564391.57 5961809.77 9907.72 93.10 181. 81 3773.82 6901.345 1933.90E 2.19 6601.62 564391.01 5961717.35 10001.91 94.05 180.59 3767.94 6995.325 1931.93E 1.64 6673.87 564389.81 5961623.36 10094.46 92.30 179.01 3762.82 7087.725 1932.25E 2.55 6746.32 564390.88 5961530.97 10187.94 88.96 177 . 95 3761.79 7181.155 1934.73E 3.75 6820.91 564394.12 5961437.58 10281.41 91. 26 180.81 3761. 61 7274.595 1935.74E 3.93 6894.61 564395.89 5961344.15 10375.21 90.31 180.21 3760.32 7368.385 1934.91E 1.20 6967.42 564395.82 5961250.37 10408.06 91. 29 181. 06 3759.87 7401. 225 1934.55E 3.95 6992.87 564395.72 5961217.53 10466.00 91. 29 181.06 3758.56 7459.145 1933.47E 0.00 7037.48 564395.12 5961159.61 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #190 and TVD from RKB(Doyon 141) (87.20 Ft above mean sea level). Bottom hole distance is 7705.65 on azimuth 165.47 degrees from wellhead. Vertical section is from wellhead on azimuth 141.43 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ) ConocoPhillips Alaska, Inc. Pad 1C,190 Kuparuk River Unit,North Slope, Alaska Top MD Top TVD ) SURVEY LISTING Page 4 Your ref MHD <0-10466'> Last revised: 7-Mar-2003 Rectangular Coords. Casing positions in string 'A' O.OON ------------------- -------------------- 2448.27S Rectangular Coords. 1847.67E 7 5/8" Casing Bot MD Bot TVD 0.00 0.00 ----------------------------------------------------------------------------------------------------------- Casing Target name O.OOE 5449.00 3834.44 --------- - -- Targets associated with this wellpath Rectangular Coordinates Geographic Location T.V.D. ----------------------------------------------------------------------------------------------------------- Revised Y14 Early Landing WS Y14 TGT#2 RVSD 6 WS Y14 D-TOE RVSD 6 WS Y14 D-HEEL RVSD 6 WS Y14 TGT#3 RVSD 6 564267.920,5966299.960,0.0000 564361.000,5964015.000,-2.000 564475.000,5961200.000,0.0000 564272.000,5966200.000,0.0000 564425.000,5962412.000,0.0000 3814.20 3807.20 3800.20 3814.20 3799.20 2317.43S 4603.29S 7419.40S 2417.43S 6206.91S 1848.06E 1922.57E 2013.69E 1851.33E 1973.54E 18-Nov-2002 26-Sep-2001 19-5ep-2001 19-5ep-2001 5-Sep-2002 ) ¿;¡o/-¿)oL/ ).() J -00 :\ ConocoPhillips Alaska, Inc. Pad 1C 190 slot #190 Kuparuk River Unit North Slope, Alaska SUR V E Y LIS TIN G by Baker Hughes INTEQ Your ref Our ref License MWD <0-10466'> svy6852 Date printed Date created Last revised 10-Mar-2003 25-Feb-2003 7-Mar-2003 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w149 30 19.124 Slot location is n70 19 29.066,w149 29 38.421 Slot Grid coordinates are N 5968602.070, E 562401.260 Slot local coordinates are 1637.60 S 1394.49 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ) ConocoPhi11ips Alaska, Inc. SURVEY LI5TING Page 1 Pad 1C,190 Your ref MWD <0-10466'> Kuparuk River Unit,North Slope, Alaska Last revised : 7-Mar-2003 Measured Inc1in Az imu th True Vert RECTANGULAR Dogleg Vert G RID COO R D 5 Depth Degrees Degrees Depth COORD I N ATE 5 Deg/100ft 5ect Easting Northing 0.00 0.00 0.00 0.00 O.OON O.OOE 0.00 0.00 562401.26 5968602.07 120.00 0.00 0.00 120.00 O.OON O.OOE 0.00 0.00 562401.26 5968602.07 205.47 0.83 119.62 205.47 0.315 0.54E 0.97 0.57 562401.80 5968601.77 293.26 3.25 114.29 293.19 1.645 3.36E 2.76 3.38 562404.63 5968600.45 382.55 6.33 115. 95 382.16 4.845 10.09E 3.45 10.08 562411.39 5968597.31 475.91 9.22 114.79 474.65 10.235 21.51E 3.10 21.41 562422.85 5968592.02 562.64 11.51 113.79 559.96 16.635 35.74E 2.65 35.29 562437.13 5968585.73 657.14 12.33 113.28 652.42 24.435 53.64E 0.87 52.54 562455.09 5968578.08 744.32 12.27 113.02 737.60 31. 735 70.71E 0.09 68.89 562472.22 5968570.92 836.65 13.37 114.45 827.63 39.985 89.46E 1.24 87.04 562491.04 5968562.82 925.58 15.27 111.72 913.80 48.575 109.70E 2.27 106.37 562511.34 5968554.40 1016.31 17.85 113.71 1000.76 58.595 133.54E 2.91 129.06 562535.26 5968544.58 1111.38 20.25 117.87 1090.62 72 .145 161.43E 2.90 157.05 562563.26 5968531.25 1205.94 21.10 120.31 1179.09 88.385 190.59E 1. 28 187.92 562592.55 5968515.25 1299.46 22.54 122.22 1265.91 106.435 220.29E 1.72 220.56 562622.39 5968497.44 1392.93 24.69 126.39 1351.55 127.575 251. 17E 2.91 256.33 562653.43 5968476.56 1486.97 27.51 129.36 1436.00 153.005 283.78E 3.30 296.55 562686.24 5968451.39 1577 . 82 27.95 128.99 1516.41 179.715 316.55E 0.52 337.86 562719.23 5968424.96 1672.62 29.75 131. 22 1599.44 209.195 351.51E 2.21 382.70 562754.43 5968395.77 1765.98 32.06 130.47 1679.54 240.545 387.79E 2.51 429.83 562790.96 5968364.72 1858.43 33.83 130.02 1757.12 273.015 426.17E 1. 93 479.15 562829.59 5968332.56 1952.46 33.71 128.37 1835.29 306.045 466.67E 0.98 530.23 562870.36 5968299.86 2044.69 33.23 129.54 1912.23 338.025 506.23E 0.87 579.89 562910.17 5968268.21 2139.04 35.65 127.39 1990.04 371.185 548.02E 2.87 631.87 562952.22 5968235.39 2232.02 35.32 126.09 2065.75 403.465 591.26E 0.89 684.08 562995.73 5968203.46 2325. 92 34.50 128.22 2142.75 435.915 634.09E 1.56 736.14 563038.82 5968171.37 2420.16 34.23 128.20 2220.54 468.815 675.89E 0.29 787.93 563080.88 5968138.81 2513.15 33.74 127.59 2297.65 500.745 716.91E 0.64 838.46 563122.15 5968107.22 2607.29 33.19 127.73 2376.18 532.465 758.00E 0.59 888.88 563163.50 5968075.85 2700.70 32.82 128.44 2454.52 563.845 798.05E 0.57 938.39 563203.79 5968044.79 2793.28 32.54 130.62 2532.45 595.655 836.61E 1. 31 987.29 563242.60 5968013.30 2886.64 34.45 130.60 2610.30 629.185 875.72E 2.05 1037.90 563281.98 5967980.09 2980.02 34.21 130.86 2687.41 663.545 915.62E 0.30 1089.64 563322.16 5967946.05 3074.73 33.63 131.13 2766.00 698.215 955.52E 0.63 1141.62 563362.33 5967911.71 3169.02 33.18 131.11 2844.72 732.355 994.62E 0.48 1192.69 563401.71 5967877 . 90 3258.70 35.15 133.23 2918.92 766.175 1031.93E 2.57 1242.39 563439.28 5967844.38 3354.24 39.18 138.93 2995.06 807.795 1071.82E 5.54 1299.81 563479.51 5967803.09 3446.80 42.46 135.98 3065.11 852.325 1112.75E 4.11 1360.14 563520.80 5967758.91 3541. 79 47.50 140.31 3132.29 902.365 1157.44E 6.21 1427.13 563565.88 5967709.23 3633.06 51.70 142.93 3191. 44 956.86S 1200.54E 5.09 1496.60 563609.42 5967655.09 3726.80 55.53 143.39 3247.04 1017.255 1245.77E 4.10 1572 . 02 563655.14 5967595.08 3819.05 58.96 143.24 3296.94 1079.45S 1292.11E 3.72 1649.55 563701.98 5967533.26 3913.56 59.44 143.89 3345.33 1144.77S 1340.32E 0.78 1730.67 563750.72 5967468.35 4007.15 61.89 144.13 3391.18 1210.785 1388.26E 2.63 1812.17 563799.19 5967402.73 4101.04 62.09 144.49 3435.27 1278.10S 1436.62E 0.40 1894.96 563848.09 5967335.81 4194.01 61.40 144.54 3479.29 1344.78S 1484.16E 0.74 1976.73 563896.16 5967269.53 4287.79 60.73 144.86 3524.66 1411.76S 1531.59E 0.77 2058.67 563944.13 5967202.94 4381.36 60.66 146.24 3570.46 1479.055 1577.74E 1.29 2140.05 563990.82 5967136.04 4474.33 62.53 148.76 3614.69 1548.015 1621.66E 3.12 2221.36 564035.30 5967067.44 4569.74 65.45 151.60 3656.53 1622.405 1664.27E 4.06 2306.08 564078.50 5966993.41 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #190 and TVD from RKB(Doyon 141) (87.20 Ft above mean sea level). Bottom hole distance is 7705.65 on azimuth 165.47 degrees from wellhead. Vertical section is from wellhead on azimuth 141.43 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ) ConocoPhillips Alaska, Inc. Pad 1C,190 Kuparuk River Unit,North 5lope, Alaska Measured Inclin Depth Degrees 4660.48 4753.35 4848.92 4940.43 5035.36 5128.99 5181.92 5224.31 5316.05 5393.73 5522.85 5616.70 5709.85 5801.70 5890.69 5930.17 5990.61 6083.22 6176.50 6269.99 6363.49 6457.68 6550.16 6644.27 6737.39 6831.72 6923.00 7016.69 7109.87 7202.26 7297.30 7389.80 7482.88 7577.12 7670.03 7764.03 7856.86 7949.70 8043.79 8137.26 8230.25 8324.38 8418.12 8512.23 8605.18 8698.01 8791. 40 8883.18 8976.52 9068.10 69.00 71.01 73.20 75.44 78.07 81.17 82.90 84.26 88.62 90.06 91.66 91.97 91.84 90.40 91. 20 90.74 89.17 93.90 91.08 90.68 90.98 92.33 89.97 91. 20 91. 59 90.64 90.31 90.55 89.39 90.52 90.95 90.86 90.77 91.07 91.07 89.33 90.76 89.72 90.61 90.18 89.51 88.96 91. 78 89.02 91.81 91.50 91. 13 89.02 88.77 94.98 Azimuth Degrees 155.58 159.75 163.80 168.02 168.44 170.44 172 . 06 172.43 176.43 178.03 181.14 180.57 181.43 179.89 178.73 177 .29 177 . 12 178.14 179.23 178.51 178.66 181.87 182.58 181.87 181. 70 182.95 183.24 181.82 181. 31 179.43 181.29 179.24 177 . 03 177 . 55 174.17 173.90 175.06 175.33 174.97 175.37 177 . 95 177.49 178.94 175.97 176.15 178.21 176.37 179.01 178.44 178.26 True Vert Depth 3691.66 3723.43 3752.80 3777.55 3799.29 3816.16 3823.50 3828.24 3833.93 3834.83 3832.89 3829.92 3826.82 3825.03 3823.78 3823.12 3823.16 3820.68 3816.63 3815.20 3813.84 3811.12 3809.26 3808.30 3806.04 3804.20 3803.44 3802.74 3802.79 3802.86 3801.64 3800.18 3798.86 3797.34 3795.61 3795.28 3795.21 3794.82 3794.55 3793.90 3794.15 3795.41 3794.81 3794.15 3793.48 3790.79 3788.65 3788.53 3790.33 3787.34 ') 5URVEY LI5TING Page 2 Your ref MHD <0-10466'> Last revised: 7-Mar-2003 R E C TAN G U L A R Dogleg Vert COO R DIN ATE 5 Deg/100ft 5ect 1697.325 1778.035 1864.395 1949.825 2040.285 2130.805 2182.615 2224.345 2315.435 2393.015 2522.105 2615.895 2708.975 2800.795 2889.765 2929.215 2989.585 3082.055 3175.215 3268.675 3362.135 3456.265 3548.655 3642.685 3735.735 3829.965 3921.105 4014.705 4107.845 4200.225 4295.255 4387.735 4480.745 4574.875 4667.505 4760.995 4853.395 4945.905 5039.655 5132.795 5225.615 5319.665 5413.345 5507.335 5600.055 5692.725 5785.985 5877 .675 5970.975 6062.425 1701.43E 1734.57E 1762.98E 1784.41E 1803.25E 1820.12E 1828.09E 1833.78E 1842.65E 1846.41E 1847.34E 1845.94E 1844.32E 1843.26E 1844.33E 1845.70E 1848.65E 1852.48E 1854.62E 1856.46E 1858.77E 1858.33E 1854.74E 1851.09E 1848.19E 1844.36E 1839.44E 1835.30E 1832.76E 1832.16E 1831.56E 1831.13E 1834.16E 1838.62E 1845.32E 1855.09E 1864.02E 1871.80E 1879.75E 1887.62E 1893.04E 1896.78E 1899.70E 1903.88E 1910.27E 1914.83E 1919.25E 1922.95E 1925.02E 1927.66E 5.63 4.74 4.64 5.07 2.80 2387.83 2471.59 2556.83 2636.98 2719.45 G RID Easting 564116.27 564150.06 564179.17 564201.29 564220.87 564238.47 564246.86 564252.88 564262.50 564266.88 564268.87 564268.23 564267.36 564267.05 564268.85 564270.54 564273.97 564278.55 564281.45 564284.05 564287.12 564287.45 564284.61 564281.72 564279.58 564276.52 564272.33 564268.96 564267.17 564267.33 564267.50 564267.83 564271 . 61 564276.83 564284.29 564294.82 564304.50 564313.02 564321. 74 564330.36 564336.54 564341.04 564344.73 564349.67 564356.81 564362.12 564367.30 564371.74 564374.57 564377 . 95 COO R D 5 Northing 5966918.80 5966838.37 5966752.25 5966667.01 5966576.72 5966486.34 5966434.61 5966392.92 5966301.91 5966224.37 5966095.32 5966001.53 5965908.44 5965816.62 5965727.67 5965688.24 5965627.90 5965535.48 5965442.35 5965348.92 5965255.49 5965161.36 5965068.96 5964974.91 5964881.85 5964787.60 5964696.43 5964602.81 5964509.66 5964417.28 5964322.27 5964229.79 5964136.81 5964042.74 5963950.17 5963856.77 5963764.46 5963672.02 5963578.35 5963485.29 5963392.52 5963298.52 5963204.87 5963110.92 5963018.27 5962925.65 5962832.44 5962740.79 5962647.52 5962556.10 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #190 and TVD from RKB(Doyon 141) (87.20 Ft above mean sea level). Bottom hole distance is 7705.65 on azimuth 165.47 degrees from wellhead. Vertical section is from wellhead on azimuth 141.43 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 3.92 4.46 3.32 6.44 2.77 2800.75 2846.22 2882.40 2959.15 3022.15 2.71 0.69 0.93 2.30 1.58 3123.66 3196.12 3267.89 3339.02 3409.25 3.83 2.61 5.22 3.24 0.88 3440.95 3489.99 3564.67 3638.84 3713.07 0.36 3.70 2.66 1. 51 0.46 3787.58 3860.91 3930.90 4002.15 4073.09 1. 66 0.48 1. 54 1.36 2.37 4144.38 4212.57 4283.17 4354.41 4426.27 2.01 2.22 2.38 0.64 3.64 4500.20 4572 .24 4646.85 4723.22 4799.83 1. 87 1. 98 1.16 1. 02 0.63 4879.02 4956.82 5034.00 5112.27 5189.99 2.87 0.76 3.38 4.31 3.01 5265.94 5341.81 5416.88 5492.97 5569.45 2.24 2.01 3.68 0.67 6.78 5644.75 5720.42 5794.42 5868.66 5941.80 ) ) ConocoPhillips Alaska, Inc. SURVEY LISTING Page 3 Pad 1C,190 Your ref MWD <0-10466'> Kuparuk River Unit,North Slope, Alaska Last revised 7-Mar-2003 Measured Inclin Az imu th True Vert R E C TAN GULAR Dogleg Vert G RID COO R D S Depth Degrees Degrees Depth COO R DIN ATE S Deg/100ft Sect Easting Northing 9161. 34 93.60 180.50 3780.36 6155.39S 1928.66E 2.82 6015.12 564379.71 5962463.16 9254.22 91.41 180.84 3776.30 6248.16S 1927.58E 2.39 6086.98 564379.38 5962370.38 9348.18 87.82 179.69 3776.93 6342.10S 1927.14E 4.01 6160.16 564379.71 5962276.45 9443.70 88.74 179.25 3779.80 6437.58S 1928.02E 1.07 6235.36 564381.37 5962181.00 9533.75 90.25 178.34 3780.59 6527.60S 1929.92E 1. 96 6306.92 564383.99 5962091.00 9627.81 90.12 178.19 3780.29 6621.62S 1932.77E 0.21 6382.21 564387.61 5961997.02 9721.79 89.63 179.51 3780.49 6715.57S 1934.65E 1. 50 6456.85 564390.25 5961903.09 9815.16 92.76 179.81 3778.55 6808.91S 1935.21E 3.37 6530.17 564391.57 5961809.77 9907.72 93.10 181.81 3773.82 6901.34S 1933.90E 2.19 6601.62 564391.01 5961717.35 10001.91 94.05 180.59 3767.94 6995.32S 1931.93E 1. 64 6673.87 564389.81 5961623.36 10094.46 92.30 179.01 3762.82 7087.725 1932.25E 2.55 6746.32 564390.88 5961530.97 10187.94 88.96 177 . 95 3761. 79 7181.15S 1934.73E 3.75 6820.91 564394.12 5961437.58 10281.41 91.26 180.81 3761.61 7274.59S 1935.74E 3.93 6894.61 564395.89 5961344.15 10375.21 90.31 180.21 3760.32 7368.38S 1934.91E 1.20 6967.42 564395.82 5961250.37 10408.06 91. 29 181.06 3759.87 7401. 22S 1934.55E 3.95 6992.87 564395.72 5961217.53 10466.00 91. 29 181.06 3758.56 7459.14S 1933.47E 0.00 7037.48 564395.12 5961159.61 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #190 and TVD from RKB(Doyon 141) (87.20 Ft above mean sea level). Bottom hole distance is 7705.65 on azimuth 165.47 degrees from wellhead. Vertical section is from wellhead on azimuth 141.43 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ConocoPhillips Alaska, Inc. Pad lC,l90 Kuparuk River Unit,North Slope, Alaska Top MD Top TVD ) SURVEY LISTING Page 4 Your ref MHO <0-10466'> Last revised: 7-Mar-2003 Rectangular Coords. Casing positions in string 'A' O.OON ------ --------- -------------------- 2448.27S Rectangular Coords. l847.67E 7 5/8" Casing Bot MD Bot TVD 0.00 0.00 ----------------------------------------------------------------------------------------------------------- Casing Target name O.OOE 5449.00 3834.44 ----- Targets associated with this wellpath Geographic Location T.V.D. ---------- Rectangular Coordinates ----------------------------------------------------------------------------------------------------------- Revised Y14 Early Landing WS Yl4 TGT#2 RVSD 6 WS Yl4 D-TOE RVSD 6 WS Y14 D-HEEL RVSD 6 WS Y14 TGT#3 RVSD 6 564267.920,5966299.960,0.0000 564361.000,5964015.000,-2.000 564475.000,5961200.000,0.0000 564272.000,5966200.000,0.0000 564425.000,5962412.000,0.0000 3814.20 3807.20 3800.20 3814.20 3799.20 2317.43S 4603.29S 7419.40S 2417.43S 6206.91S 1848.06E 1922.57E 2013.69E 1851. 33E 1973.54E 18-Nov-2002 26-Sep-2001 19-5ep-2001 19-5ep-2001 5-Sep-2002
