Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
203-089
! " # " $%&' ( ') * +,! - *( ./ !0 1"! ! 2/ ./ 34 354-0 4 6 . 0 " * ( ' ( % 7 . 899 0 : 7. *9 0 3 ;8 * , . 0 < ; 5" : ( * " ') * ( / * +" : $ "(/ ' ( $ $,!= > />$ *! !6 ') ! 8 ", ' ' !! "# $ !! "# $ ' ' %&' ()$'! *!+ #, 8 6 %'#* < )&%$)- #. $/# "0 '! %-1# , / 2 -,* * *: 6 / : 5 ( ! 3 ! ! ?" & " : ? .; 34 354-49354-9@3531<0 +)!3 $ #% = : ( * , A ( 6 6 :9, 4 '/B /B,/!($ !' 7,! %%,,! 1 1/ 2 50 1 31 ",!="$ 6 " #& 6 +)!3 = = " C .24-03+5#+?- 8! = & )44<+4 9B2254 6 6 #& 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 07:55:05 -09'00' VTL 2/24/21 SFD 11/24/2020RBDMS HEW 11/25/2020 DSR-11/24/2020 ! "#!$#%# &' $(&%)# &%) *&#+ ' ,-. * /01 ', -.*234 "5$6)( %(%#!$#& %3 ) !&%)#!$#%#&' $( #!$#%#*7 ',-.$% 88 &' #9:.: ; *8 '#+5 # * < # < 3= !$#%# $!/ !$#& %' Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag:1C-184 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Open CMU, Set POGLM 11/26/2019 1C-184 oberr Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 30.0 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) 6.87 Top (ftKB) 27.9 Set Depth (ftKB) 5,798.0 Set Depth (TVD) … 3,852.8 Wt/Len (l… 29.70 Grade L-80 Top Thread BTCM Casing Description 5.5" INNER LINER - WO OD (in) 5 1/2 ID (in) 5.00 Top (ftKB) 28.0 Set Depth (ftKB) 5,652.1 Set Depth (TVD) … 3,837.0 Wt/Len (l… 15.50 Grade L-80 Top Thread BTCM Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 28.0 28.0 0.00 HANGER VETCO GRAY MANDREL HANGER w/Pup Joint 4.950 5,553.0 3,822.9 81.18 XO REDUCING Crossover 5'' BTC Mod Box x 5 1/2'' BTC Mod SCC Box 4.360 5,555.3 3,823.3 81.23 SBE BAKER 80-40 SBE 4.000 5,573.4 3,826.0 81.62 XO REDUCING Crossover 3 1/2'' 9.3# EUE8rd Pin x 5"" BTC-M Box 2.970 5,588.8 3,828.1 81.95 SLEEVE-C BAKER CMU SLIDING SLEEVE w/ Nipple 2.810 5,638.0 3,835.0 81.88 XO ENLARGING 6' Crossover 3 1./2'' IBTM Box x 5 1/2'' 17# Hydril 521 Pin 2.890 5,641.3 3,835.5 81.87 SEAL ASSY 10' BULLET SEAL ASSEMBLY 5.75'' Seal OD Hydril 521 (3.00' stick-up) 4.800 Casing Description LINER 4.5" SLOTTED OD (in) 4 1/2 ID (in) 3.86 Top (ftKB) 5,644.3 Set Depth (ftKB) 11,885.0 Set Depth (TVD) … 3,819.4 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) 5,644.3 3,835.9 81.86 SLEEVE-C BAKER TIEBACK SLEEVE 5.750 5,655.3 3,837.5 81.83 PACKER ZXP LINER TOP PACKER 4.930 5,663.3 3,838.6 81.81 NIPPLE RS NIPPLE 4.880 5,666.2 3,839.0 81.80 HANGER BAKER FLEX LOCK HYD TO LINER HANGER 4.860 5,675.5 3,840.4 81.77 XO BUSHING XO BUSHING 3.910 11,850.7 3,818.6 88.68 BUSHING BAKER PACKOFF BUSHING 3.958 Tubing Strings Tubing Description TUBING WO - 2014 String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 22.3 Set Depth (ft… 5,568.4 Set Depth (TVD) (… 3,825.2 Wt (lb/ft) 9.30 Grade L-80 Top Connection 3.5 Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 22.3 22.3 0.00 HANGER VETCO GRAY TUBING HANGER w/ Pup Joint 2.875 5,016.2 3,671.1 69.54 SLEEVE-C BAKER CMU SLIDING SLEEVE w/DS NIPPLE (OPENED11/26/2019) 2.810 5,071.3 3,690.2 69.75 GAUGE SCHLUMBERGER DOWNHOLE GAUGE MANDREL w/ NDPG gauge 3.000 5,548.3 3,822.2 81.08 SEAL ASSY BAKER 80-40 GBH-22 LOCATOR SEAL ASSEMBLY (7.00' stick up) 2.990 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 5,014.5 3,670.5 69.52 C-Lock W/POGLM Set 2.81" C-Lock W/ POGLM (5/16" OV OAL=53") 12/4/2019 5,015.0 3,670.7 69.53 Slip Stop Set Slip Stop @ 5015' RKB 12/4/2019 9,743.0 3,828.5 91.86 FISH FISH lOST 4/14/2006, Lower portion of TRICO jet pump assy, pushed down to 9743 RKB on 4/14/04 4/14/2006 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 5,710.0 11,850.0 3,845.1 3,818.6 WS D, 1C-184 6/8/2003 12.0 IPERF Liiner alternating solid/pre- perfed joints 12 pre-perfed round 1" holes in every other joint. Notes: General & Safety End Date Annotation 9/5/2008 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 4/14/2006 NOTE: CT overshot JP & pushed it down to 9747 CTMD; POOH without fish after attempt to latch 4/14/2006 NOTE: cont. at max downweight. CT was in lock up due to buckling @ 9747'. 4/13/2006 NOTE: CT burned over stuck JP 1C-184, 11/11/2020 10:51:20 AM Vertical schematic (actual) X O LINER 4.5" SLOTTED; 5,644.3- 11,885.0 FISH; 9,743.0 IPERF; 5,710.0-11,850.0 SURFACE; 27.9-5,798.0 5.5" INNER LINER - WO; 28.0- 5,652.1 SEAL ASSY; 5,548.3 GAUGE; 5,071.3 SLEEVE-C; 5,016.1 C-Lock W/POGLM; 5,014.5 CONDUCTOR; 30.0-110.0 HANGER; 22.3 KUP PROD KB-Grd (ft) 35.40 Rig Release Date 6/10/2003 1C-184 ... TD Act Btm (ftKB) 11,890.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292315500 Wellbore Status PROD Max Angle & MD Incl (°) 92.37 MD (ftKB) 9,811.38 WELLNAME WELLBORE1C-184 Annotation Last WO: End Date 11/14/2014 H2S (ppm) 50 Date 12/16/2013 Comment SSSV: NONE 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): 11890'9743' MD Casing Collapse Structural Conductor Surface Inner Liner 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 None3839'1500 psi Authorized Name: John Peirce Authorized Title: Staff Wells Engineer John Peirce John.W.Peirce@conocophillips.com Perforation Depth TVD (ft):Tubing Size: COMMISSION USE ONLY Tubing Grade:Tubing MD (ft): 3845'-3819'' TVD 5655' MD and 3836' TVD N/A PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 25649, ADL 25650 3820' 203-089 P.O. Box 100360, Anchorage, Alaska 99510 50-029-23155-00 ConocoPhillips Alaska, Inc. Length Size KRU 1C-184N/A Kuparuk River Field/ West Sak Oil Pool 11885' L-80 TVD Burst 5568' MD MD 110' 3853' 3837' 110' 5798' 16" 7-5/8" 80' 5-1/2"5624' 5770' Perforation Depth MD (ft): 5652' 5710'-11885' MD (Slotted pipe) 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 11885'6241' 3-1/2" 3819' Packer: ZXP Liner Top Packer SSSV: None 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 320-393 John W Peirce Digitally signed by John W Peirce Date: 2020.09.23 09:11:14 -08'00' DSR-9/24/2020 10-404 SFD 9/23/2020 SFD 9/23/2020 X VTL 9/29/20 -00 Comm. 9/30/2020 dts 09/29/2020 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. Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag:1C-184 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Pull POGLM Close CMU 8/13/2019 1C-184 jhansen8 Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 30.0 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) 6.87 Top (ftKB) 27.9 Set Depth (ftKB) 5,798.0 Set Depth (TVD) (… 3,852.8 Wt/Len (l… 29.70 Grade L-80 Top Thread BTCM Casing Description 5.5" INNER LINER - WO OD (in) 5 1/2 ID (in) 5.00 Top (ftKB) 28.0 Set Depth (ftKB) 5,652.1 Set Depth (TVD) (… 3,837.0 Wt/Len (l… 15.50 Grade L-80 Top Thread BTCM Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 28.0 28.0 0.00 HANGER VETCO GRAY MANDREL HANGER w/Pup Joint 4.950 5,553.0 3,822.9 81.18 XO REDUCING Crossover 5'' BTC Mod Box x 5 1/2'' BTC Mod SCC Box 4.360 5,555.3 3,823.3 81.23 SBE BAKER 80-40 SBE 4.000 5,573.4 3,826.0 81.62 XO REDUCING Crossover 3 1/2'' 9.3# EUE8rd Pin x 5"" BTC-M Box 2.970 5,588.8 3,828.1 81.95 SLEEVE-C BAKER CMU SLIDING SLEEVE w/ Nipple 2.810 5,638.0 3,835.0 81.88 XO ENLARGING 6' Crossover 3 1./2'' IBTM Box x 5 1/2'' 17# Hydril 521 Pin 2.890 5,641.3 3,835.5 81.87 SEAL ASSY 10' BULLET SEAL ASSEMBLY 5.75'' Seal OD Hydril 521 (3.00' stick-up) 4.800 Casing Description LINER 4.5" SLOTTED OD (in) 4 1/2 ID (in) 3.86 Top (ftKB) 5,644.3 Set Depth (ftKB) 11,885.0 Set Depth (TVD) (… 3,819.4 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) 5,644.3 3,835.9 81.86 SLEEVE-C BAKER TIEBACK SLEEVE 5.750 5,655.3 3,837.5 81.83 PACKER ZXP LINER TOP PACKER 4.930 5,663.3 3,838.6 81.81 NIPPLE RS NIPPLE 4.880 5,666.2 3,839.0 81.80 HANGER BAKER FLEX LOCK HYD TO LINER HANGER 4.860 5,675.5 3,840.4 81.77 XO BUSHING XO BUSHING 3.910 11,850.7 3,818.6 88.68 BUSHING BAKER PACKOFF BUSHING 3.958 Tubing Strings Tubing Description TUBING WO - 2014 String Max … 3 1/2 ID (in) 2.99 Top (ftKB) 22.3 Set Depth (ft… 5,568.4 Set Depth (TVD) (ft… 3,825.2 Wt (lb/ft) 9.30 Grade L-80 Top Connection 3.5 Completion Details Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 22.3 22.3 0.00 HANGER VETCO GRAY TUBING HANGER w/ Pup Joint 2.875 5,016.2 3,671.1 69.54 SLEEVE-C BAKER CMU SLIDING SLEEVE w/DS NIPPLE (CLOSED 8/13/2019) 2.810 5,071.3 3,690.2 69.75 GAUGE SCHLUMBERGER DOWNHOLE GAUGE MANDREL w/ NDPG gauge 3.000 5,548.3 3,822.2 81.08 SEAL ASSY BAKER 80-40 GBH-22 LOCATOR SEAL ASSEMBLY (7.00' stick up) 2.990 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 9,743.0 3,828.5 91.86 FISH FISH lOST 4/14/2006, Lower portion of TRICO jet pump assy, pushed down to 9743 RKB on 4/14/04 4/14/2006 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,710.0 11,850.0 3,845.1 3,818.6 WS D, 1C-184 6/8/2003 12.0 IPERF Liiner alternating solid/pre- perfed joints 12 pre-perfed round 1" holes in every other joint. Notes: General & Safety End Date Annotation 4/13/2006 NOTE: CT burned over stuck JP 4/14/2006 NOTE: CT overshot JP & pushed it down to 9747 CTMD; POOH without fish after attempt to latch 4/14/2006 NOTE: cont. at max downweight. CT was in lock up due to buckling @ 9747'. 9/5/2008 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 Comment SSSV: NONE 1C-184, 10/22/2019 1:39:05 PM Vertical schematic (actual) LINER 4.5" SLOTTED; 5,644.3-11,885.0 FISH; 9,743.0 IPERF; 5,710.0-11,850.0 SURFACE; 27.9-5,798.0 5.5" INNER LINER - WO; 28.0-5,652.1 SEAL ASSY; 5,548.3 GAUGE; 5,071.3 SLEEVE-C; 5,016.1 CONDUCTOR; 30.0-110.0 HANGER; 22.3 KUP PROD KB-Grd (ft) 35.40 Rig Release Date 6/10/2003 Annotation Last WO: End Date 11/14/2014 1C-184 H2S (ppm) 50 Date 12/16/2013... TD Act Btm (ftKB) 11,890.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292315500 Wellbore Status PROD Max Angle & MD Incl (°) 92.37 MD (ftKB) 9,811.38 WELLNAME WELLBORE1C-184 RECEI Fn STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION DEC 3 - 2019 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Op Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Fusion Proppant Trtmt 2. Operator Name: ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Development p Exploratory ❑ Stratigraphic❑ Service ❑ 1 203-089 3. Address: P. 0. Box 100360, Anchorage, 6. API Number: Alaska 99510 50-029-23155-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25649, ADL 25650 KRU IC -184 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 11,890 feet Plugs measured None feet true vertical 3,820 feet Junk measured None feet Effective Depth measured 11,885 feet Packer measured 5,655 feet true vertical 3,839 feet true vertical 3,837 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 feet 16 110' MD 110' TVD SURFACE 5,770 feet 7 5/8 " 5,798' MD 3853' TVD INNER LINER 5,624 feet 5 1/2 " 5,652' MD 3837' TVD PERFED LINER 6,241 feet 4 1/2" 11,885' MD 3819' TVD Perforation depth: Measured depth: 5710-11850 feet True Vertical depth: 3845-3819 feet Tubing (size, grade, measured and true vertical depth) 3.5 " L-80 5,568' MD 3,825' TVD Packers and SSSV (type, measured and true vertical depth) PACKER = ZXP LINER TOP PACKER 5,655' MD 3,837' 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: - - SHUT-IN 14. Attachments (required per 20 MC 25.070, 25.071, 825.283) 15. Well Class after work: Daily Report of Well Operations 2 Exploratory ❑ Development p Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil p Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.G. Exempt: 319-415 Contact Name: John Peirce Authorized Name: John Peirce Authorized Title: Sr. Wells Engineer Contact Email: John.W.Peirce@cop.com Signature: Contact Phone: (907) 265-6471 Authorized � C ' _ Date: � 2 Form 10-404 Revised 4/2017 YTG /7//(0//9 Submit Original Only T.fr-2-11W14f RBDMS SS' DEC n,9 2nig 1 C-184 FUSION PROPPANT TREATMENT OF MBE TO 1 C-190 DTTM JOBTYP SUMMARYOPS START 10/26/19 MISC. Performed duplicate freshwater SRIT from yesterday for additional pressure CAPACITY analysis; 4 -bpm @ 1500 -psi through 10 -bpm @ 2150 -psi. Modified treatment SUSTAINMENT 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 1C-190 at 450'. Freeze protected 1C-184 with 16 -bbl diesel and 1 C-190 with 20 -bbl diesel. Ready for CT FCO to heal depth in well. 10/26/19 MISC. FREEZE PROTECT CAPACITY PUMP 16 BBLS DIESEL DOWN TBG SUSTAINMENT JOB COMPLETE 11/2/19 MISC. PERFORMED FILL CLEANOUT/TUBING WASH FROM SURFACE TO 5500' CAPACITY CTMD PUMPING SLICK DIESEL AND DIESEL GEL SWEEPS AT 1.9 BPM, SUSTAINMENT MAINTAINED 1:1 RETURNS THROUGHOUT CLEANOUT. LIGHT SAND CONCENTRATIONS OBSERVED THE LAST RETURNS SAMPLE WAS CLEAN DIESEL 11/21/19 MISC. RIH WITH PDC BIT RECOMMENDED FROM CARBO, TAG SAND AT 5569' CAPACITY CTMD, COME ONLINE WITH N2 AT 400 SCFM AND 1 BPM SLICK SEAWATER SUSTAINMENT 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 @1 BPM, 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. KUP PROD WELLNAME 1C-184 WELLBORE 1C-184 Well Attributes Max Angle & MD TD C0110C°Phillips .P'rcme Wellsor mutoWl Wellba-Stu- MD(flK6) pctB KB) Alaturk T.111C. IWFCT CCK snmo�n i ccnn nnwr. .. .. ...- .. 1C 1a1, ii/i2mR?36.11 PM __ ... _. ......--.. ...°.�.° w.v.cw.a Last Tag Ve,g� smassoa (scud) AutoWion pepLM1 (flK9) En00atr evel-limme--T Last Most By Last Tag: 1C-184 Imosbor .............................................................. Last Rev Reason Annoiatun EnEDi WBIIM1ore Last MM By KAm ER: YL,a Rev Reason: Open CMU, Set POGLM 1112612019 1C-184 oberr Casing Strings casing description 00 (in) ID (In) Tap (ttKB) Sel Dep)M1 (MB) Ret DepiM1 (NO)... WIILen 6... Gentle Top TM1reatl CONDUCTOR 16 15.06 30.0 1111.0 no.0 fi250 H-00 WELDED Casing us¢crisum Oogn) I Id lin) Top (ryKB) semeplydi Stl Depth IND)... WtlLen(I...Issue ITop Thmad SURFACE 75/6 6.87 27.9 5,798.0 3,852.8 29.70 1 IBTCM Ceslnp Dexriomin OD lin) Olin) Topmmit, set Depth posts lost Depth IND)...uni R._GreGe Top TM1natl 5.5"INNER LINER -WO 512 5.00 28.0 5,652.1 3,837.0 1550 GL-80rad BTCM Liner Details NaminallD Tap lDxe) Top (NO)di To Incl (°) 14m Des cont (In) couducroR; No n o g 280 280 0.00 HANGER VET CO GRAY MANDRELHANGER WIPup Joint 4.950 5,553.0 3,622.9 81.18% mssover'BT Motl Boxx5112"BTC Mod 4360 REDUCING Box 5,5553 3,8233 81.23 SBE BAKER80-0OSBE 4.000 5,5734 3A26 61.62 XO Cmssover312'9.3#EUEBrd PinxS"'BTCM Be. 2.970 REDUCING 5,588.8 3,828.1 8195 SLEEVE -C BAKER CMU SLIDING -SLEEVE w/Nipple 2.810 Randal 5,6380 3,8350 81.88 XO 6' Crossover 1. MBox x 51 1HyddJ521 2890 ENLARGING Pin SI, v, 0181 POGLIM5018x 591.3 3,835.5 81EAL .87 SASSY 10' LLET EAL AS EMBLV 5 75eel ODHytldl 4.800 521 (3.00'suck-up) Casing Oemoulwn OO fin) 0 (n) Tap prole sac DepIM1 (XKR) Ret Depth mD)... wuL.n p... G,tlo iop Thread LINER 4.5"BLOTTED 412 386 5,644.3 11,8850 3,8194 12.60 L-80 NSCT Liner Details Nominal l0 Top MB) Tap(NOHXKB) iop lncH°) Item Dea 6om (1n) 5,644.3 3,835.8 81.86 SLEEVE -C BAKERTIEBACK SLEEVE 5350 Gi Gans 5,655.3 3,8325 81.83 PACKER ZXP LINER TOP PACKER 4.930 5,6633 3,838.6 8181 NIPPLE RS NIPPLE 9880 5,6662 3,8390 81.89HANGER BAKER FLEX LOCK HYD TO LINER HANGER 4860 5,6]5.5 3,640.4 81.]7 XO BUSHING XO BUSHING 3.910 11,850.] 3,818.6 8868 BUSHING BAKER PACKOFF BUSHING 3.956 Tubing Strings Tubing description Rking Ma... 10 (in) rap (nKB) Set OepIM1 (tt. Set Deptn (Npf (... WI IIpM6 Gado Top Connection TUBING WO -2014 3112 2.99 22.3 5,568.4 3,8252 9.30 L-80 3.5 sEALASSY;559aa Completion Details To MID) Top mal Nominal Top (nxe 1 emen 1°1 Izln as cam ID (In) 22.3 22.3 0.00 HANGER VETCO GRAY TUBING HANGER m/ Pup Joint 2.875 5,016.2 3,671.1 69.54 SLEEVE -C BA -K -CMU 5LIDINGSLEEVE w/DS NIPPLE 2.810 (OPENEDII/26/2019) Sp71.3 3,690.2 6875 GAUGE SCHLUMBER6ERD0WNH 7EGAU dE MANDREL wI ND P Iff- gauge 5,548.3 3,822.2 8108 SEALASSY BA ER 8040 OBH-22 LOCATOR SAL ASSEMBLY Q 00'Stick 2990 up) Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top".) Top mal Top mne) mice) I r) Des Co. Ran Date IDIIn) 5,015.5 3,6]0 8 fi953 Slip Stop 5lip Sbp set on top of POGLM W 5016' RKB, 20" GAL 1126201 1.500 9 5,016.2 3,6]1.1 89.54POGLM 81- C Lock on' POLMw "OV(NMetrievabie 11/26/201 0.000 55 INNER LINER -WO:d - thru lock) 53- GAL 12 9 eeol 9,743.0 3,828.5 91.86 FISH portion Of TRICO let pump 4114/2006 0.000 11-ISHIGST41141200iwer easy, pushed tlown to 9743 RKB on 4/14/04 Perforations & Slots snot Top MIKE)BM(flKB) Top RVD) NS) s1 IND) InKa) LInkNIDne Date Den Isxatsm ) Type Com 5,710.0 11,8500 3,845.1 3,818.8 WSg1C-184 WWO03 120 (PERF 1-uneraftematingSolid/pre- pertedjointo 12 pre -peeled round 1" holes in every 0therjoint. Notes: General & Safety End ccs Ann buhon 41IW2006NOT E: CT burned over stuck JP 4114/2006 NOTE: CT overshot JP 8 pushed it dagan to 9747 CTMD; POOH Without Men after attempt to latch 41142006 NOTE: contat max d vereaught. CT was in lock up due to buckling @ 9747. 9/52008 NOTE: VIEW SCHEMATIC w/Alaska Schemadc9.0 SURFACE; to ob,75e0 IPElso 5,]10011.850.0 EIRH', Iii p -_ J LINER 4.7 SLOTTED, 5,694,1 'i In 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-184 Permit to Drill Number: 203-089 Sundry Number: 319-415 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 w .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, sie�elowski Commissioner IBDMS&� SEP 16 2019 DATED this 13 day of September, 2019. I r. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIONf APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Reddll ❑ Perforate New Pool ❑ Reenter Susp Well ❑ Alter Casing ❑ Other: Fusion Proppant Trtmt2 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. COnocoPhillf s Alaska Inc. Exploratory ❑ Development p • Stratigraphic F1Service ❑ 203-089 ' 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50029231550060 7. If perforating: 8. Well Name and Number: yg What Regulation or Conservation Order governs well spacing in this pool?�/ N/A ' 1C-184 Will planned perforations require a spacing exception? Yes ❑ No ElKRU 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). 11,890' 3,820' 11885 3839 1500psi NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 80' 16" 110' 110' Surface 5,770' 75/8 5,798' 3,853' Inner Liner 5,624' 51/2 5,652' 3,837' Perfect Liner 61241' 41/2 11,885' 3,819 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8824.11850 3839.3819 3.500" L-80 5,568' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER = ZXP Liner Top Packer MD = 5655 and TVD = 3837 SSSV = NONE N/A 12. Attachments: Proposal Summary Wellbore schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development El Service ❑ 14. Estimated Date for 9/25/2019 15. Well Status after proposed work: Commencing Operations: OIL O WINJ ❑ 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 Title: Sr. WellsEngineerContact Email: John.W.Peirce@cop.com Contact Phone: (907) 265.6471 Authorized Signature: X GtJ — q / 110 / 1 C ' Date: / COMMISSION USE ONLY Conditions of approval: Notify Commi Sion so that a representative may witness Sundry Number: I ' Ll I Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ml� ;1 B DMS �tl SEP 16 2019 Spacing Exception Required? Yes ❑ No 0 Subsequent Form Required: APPROVED BY Approved by: ,;� COMMISSIONER THE COMMISSION Date: -1 ��- Submit Form and Form 10403 Revised 4/2017 Approved application QselRd11 lt ,vto of approval. ^^1J aegttaghments In Duplicate !r /Y1.15'_.. 9✓f-I KUP PROD WELLNAME 1C-184 WELLBORE 1C-184 COflOCOPFUlGp5 ' ti Wan Attributes Max Angle S MD TD IFIere Name IW¢IILa,n APWWI IWe111q,e aYius .111"7) Ma 1.X01 ..1.(Ad.) Alaska, Inc. WEST SAK SWIP'15500 PROt'i OiT OAni IItion NONE I.,.. aloams Ig l a sa PM Last Tag Yn'Ozl soMmarc lama9 An.... Depmaddil EM Data WNIWrc Last Moa By .._........................... RANGER:?13 CONDUCTOR30.01100 sLEEv>_o: s,me1 al al S,N1s seu Assv; s.saea SS INNEfl LINER WO; y.6 s.ea' _ woaACE:y].es]gl0 /PERF; 5,TD611,1i FI8X:6.]43.0� LINER 45' SLOTTED: S. g- 11,affi0 Last Tag: 1C-np, flaricalb.1 Last Rev Reason A ... Ulion EmIDale WeIIED,e LastMca By Rev Reason'. Pull POGLM Close CMU BI13I2019 1C-184 Ihansen8 Casing SWngs Caalna Description OB (it) lather Top(KKa) set Depth set Depm ITV0)... WVbn (I... Gnae TnpT ovs! CONDUCTOR 16 15.06 300 110.0 1100 62.50 HAO WELDED Camay Deacnptbn BO (in) ID pp Top MBI RI DepO IaKBI tial Oeplin HVDL.. WOLen p...Gmae Irma Th ... 6 SURFACE ]518 6.87 Z's 5,798.0 3.852.8 29]0 L-80 BTCM CasMy aucaptlon Bo (in) ID [in) TOp mkel 1. Depu 111 1. OptM1 pVO)... when p... Gvee Tmpmrema 5.5"INNERLINER-WO 5112 500 280 5,852.1 3.8JZ0 15.50 L -BO BTCM Liner Details r..m.n.1 lD M Top(tBj I Tmp(rvDgthol) To mmir) 1lem Das corn rn) 28.0 28.0 0.00 HANGER VETCOGRAY MANDREL HANGER w/Pup Joint 4.950 5,553.0 38229 81.18 XO Crossover 5 BTG Mod Box It 5112'BTCMod SCC 4.360 REDUCING Box 5.5557 3,8233 8123 SBE BAKER 8040 SBE 4000 5,573.4 3,826.0 81.62 % Crossover 312" 9.3p EUEBM Pin x 5'" BTCM Box 2970 REDUCING 5,588.8 3,828.1 81.95 6LEEVE-0 BAKER MU SLIDINGSLEEVE W/ Nipple open 2.810 CMU -12/&14) 5,838.0 3,835.0 81.88 X mssover .a' IB Box x 5 9 HyddlqNSCT"d 2.690 ENIARGING Pin 5,641.3 3,835.5 8187 BEALA 6Y ULL T EALA B eat H 4800 521 (3.00'suck-up) Casing Desc,ison OD(n) 10(1.1 Top (hNBj set Depm'aIhd set De pal 1X01..gg ll.. Grateop Tio LINER4.5"SLOTTED 412 38fi S,fi44.3 11,885.0 3819.4 1,or L-80 Liner Details Top(WB) mPITVm1aKa) rcp l.aq° nem Des Com No al ID 5,644.3 3,835.9 81.86 SLEEVE BAKER TIEBACK SLEEVE 5.750 5,655.3 3,837.5 81.3 PACKER ZXP LINER TOP PACKER 4.930 5663.3 3,838.6 1.81 NIPPLE RS NIPPLE 4.880 5.6662 3,839.0 1W HANGER BAKER FLEX LOCK HYD TO UNER HANGER 4.860 5,675.5 3,840.4 81T/ XO BUSHING TOBUSHING 3.910 11850.7 3,818.6 8868 BUSHING BAKER PACKOFF BUSHING 3958 Tubing Strings T.Woli Desenptimn same ma... lona) TOPORK R set Depth m.. SoOspih (1V0)1... WIIINX) G„aa rmp cm.necmm� TUBING WO -2014 31/2 299 22.3 5,568.4 3,8252 9.30 LA0 3.5 Completion Details Top(TvD) Toplmd Nmmi.al Too hourn 1NKB 1°) Nem Des Com1ID I", 223 22.3 0.00 HANGER VETCO GRAY TUBING HANGER W Pup Joint 2.875 5,0162 3,6]1.1 69.54 SLEEVE -0BAKER ONO SLIDING SLEEVE wIDS NIPPLE (CLOSE 2. &1312019) 5,071,3 3,690.2 9J5 7AUGE SCHLUMBERUER DOWNHOLEU EMANDREL wI NDPG gauge 5,548.3 3,822.2 81.08 SEALASSY BAKER 8040 GBH 22 LOCATOR SEALASSEMBLY (7.00'stick 2.990 no) Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top lhlca) Top".) MK-) I Top mal fl Des I Cam Runoan w(i.) 9,]43-0 I 3828.5 91. FI ri FI HIOBTWI4 , owerponiono TRI je,pump easy, pushed dawn to 9743 RSB on 4114104 41 Perforations 8 Sloffi Top dedlu atm a dIK ) 1'op(rvDl (Itl(6) eM (TV9) faKB) LInYMZone pNe Sens Den (aho6m I Type Co. 5,710.0 11,850.0 3,845.1 3,8186 Wb U.IL-184 61812003 12.0 (PERF I Liiner alterocang stili pre- peded joints 12 pre-perfed round 1"boles in every otherjunl. Notes: General & Safety Fnd Dtle A.nmiafion 4/132006 NOTE: CT burned over stuck JP 4114/2006 NOTE: CT overshot JP a pushed II down to 9747 CTMD, POOR without fish after attempt to latch 4/1412008 NOTE'. cant at max downvol CT was in tick up due to buckling @ 9]4]'. 9/512008 NOTE: VIEW SCHEMATIC w/Alaska SchemMic9.0 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 1 CA 84 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 1 C-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 WHIP, 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). Clean Volume Bbls JPad 0 100 Proppant Conc From To Proppant SG Breaker HEC Gel Proppant Activator lbs per Mals lbs per Mals lbs added gallons 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 ppg 16/80 Proppant 95 6 6 2.59 0.25 80 24000 128 8 ppg 16/80 Proppant 95 8 8 2.59 0.25 80 32000 171 10 ppg 16/80 Proppant 36 10 10 2.59 0.25 80 15000 80 Flush 50 1 0 1 0 0 1 0.25 80 0 0 Diesel FP 47 0 0 0 0 0 0 0 Totals 698 100400 � 536 After completion of the pump schedule, keep 1C-184 shut-in for 48 hours. Also keep 1C-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 1C-190 to injection and monitor BHP gauges in 1C-184. Initiate flowback of 1C-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. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS MAY 0 9 2019 FITATIRT1 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operatio w mt�r Performed: Suspend [:]Perforate E]Other Stimulate E]Alter Casing E]Change Approved Program ❑ Plug for Reddll Elerforate New Pool El RepairWell ❑ Re-enter Susp Well El Other RPPG MBE Trtmt [712. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development [DExploratory Stratigraphic❑ ❑ Service E]6. 203-089 3. Address: P. O. BOX 100360, Anchorage, API Number: Alaska 99510 50-029-23155-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: KRU 1C-184 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 11,890 feet Plugs measured None feet true vertical 3,820 feet Junk measured None feet Effective Depth measured 11,885 feet Packer measured 5,655 feet true vertical 3,839 feet true vertical 3,837 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 feet 16 110' MD 110' TVD SURFACE 5,770 feet 7 5/8 " 5,798' MD 3853' TVD INNER LINER 5,624 feet 51/2 " 5,652' MD 3837' TVD LOTTED LINER 6,241 feet 41/2" 11,885' MD 3819' TVD Perforation depth: Measured depth: 8824-11850 feet True Vertical depth: 3839-3819 feet Tubing (size, grade, measured and true vertical depth) 3.5 " L-80 5,568' MD 3,825' TVD Packers and SSSV (type, measured and true vertical depth) PACKER - ZXP LINER TOP PACKER 5,655' MD 3,837' 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: Shut4n - - - - Subsequent to operation: :hh 4n - - - - 14. Attachments (required per 20 MC 25.070, 25.071, 8 25.283) 15. Wel I Class after work: / F� Daily Report of Well Operations 121 Exploratory ❑ Development 19 Service 71Strafigraphic ❑ Copies of Logs and Surveys Run El16. Well Status after work: Oil Rr'/ Gas EIWDSPL E]Printed and Electronic Fracture Stimulation Data ❑ GSTOR ElWINJ [3WAG ❑ GINJ C1SUSP❑ 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: 319-129 Contact Name: John Peirce Authorized Name: John Pierce Contact Email: John.W.Peirce@cop.com Authorized Title: Sr. Wells Engineer Atl Signature: 4 1 � Date: 4 Contact Phone: (907) 265-6471 8 u[horize 1 1 Form 10-404 Revised 4/2017V %�L rJ �2 / // 9 lt-110 e RBDMSJ� MAY 10 2019 Submit Original Only 1 C-184 OFFSET PRODUCER FOR 1 C-190 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. -�..���e�L KUP PROD WELLNAME 1C-184 WELLBORE 1C-184 CbrxxxiMill1ps dell AtVibutes Max Angle & MD 7D Fk K" eeeusore Apinuse W¢Ilbo,e Bretua NI') MDlfil(91 Acr BIm(ITKul Alaska, Oc. ^ IWE$T SAK 1500292315500 (PROD 237 9B11AR "dorm NONE IC1aa SYA19]:t 4:E3AM Last Tag Ve*Fy atMmehFiseu9 Annotation I Dec. good I End D. 1 We11Mre List MM By _............. .. ............_.. HANGER: as CONDUCTOR; 3p.Gn8U RUEEVE-L: 5.019.1 FOGLMSo 0 ERUGE;s,or12 sEN.assv 6sma 55'INNERLINER-M.WOR s.asz t_ SURFACE 27a6796.0 FISH: e.7xs.0 IPERF: 8.82.6116'd e-� LINER aS 9qM; Soust 11.8450 __........... ` Last Tag: 1C-184 1dNNpGr Last Rev Reason anner.IM End Bak Wenbore test Matl By Rev Reason; OPEN CMU, SET PODIUM 62/ 17 1 1C-184 p"oven Casing Strings Lasing.ascription OO On) 1 10 (in) IDpIoul) aet 0 Oeptx(nKBI SN Ed INO)... YNLen (L.. Gratle Top Txhout CONDUCTOR 16 1506 30.0 110 1100 62.50 H<0 WELDED Oasine Gessuptron I O011n1 IO lint TopIMBI sNOMMKB1 Set MMe:NOL..vil 11... Grade TOP TnreaE SURFACE 7518 897 279 5,798.0 3,8528 29.70 Ld0 BTC. Larinp Description 006n) I.. in) Top(M(B) sNOepelaKa) SNOepIM1 (NO)... Waten 9... GrMe Tap Thread 5.5"INNERLINER-WO 5112 5.no 28.0 5,652.1 3.8370 15.50 Ude BTCM Liner Details Na 1 110 Top NICE) Top Drop) RIKB) To Incl Pl 1(¢m Des Com (int 28.0 80 000 HANGER VET CO GRAY MANDREL HAN TER wPop Joint 4.950 5,553.0 3,WB 81.18 NO Reducing Crossover B'BTC Mod Box x 1 Mod 4.360 Box 5,555.3 3,8233 81.23 SBE BAKERS DSBE 4000 5,573 4 3,826.0 81.62 XO Reducing Crossover 3112' 9.3# EUEBrd Pin x 5" BTC -M Box 2.970 5,588.8 3,828.1 81.95 9LEEVE-0K RGMU SLIDING wl Nipple(Open CMU -12/&14) 2810 5,630.0 3.8350 81.88 X Enlarging W Crospoper 3 1 72- IBTM Boxx 5 1 Q"9# ydnl5 90 Pin 5,641.3 3,8355 81.87 $EALASSY III BULLET EALA LY 5.75" Seal OD Hydril 4800 521 (3.W a9ckgp) LmInO Bncription Oelinl I011nl Tap INKBI sN MpM (111(8) Set EdPth IN01... WIILen 11... G,Me Top Threat LINER 4.5"SloRed 412 3.86 5,644.3 11,885.0 3,6194 12.60 L-80 NSCT Liner Datalls Nomin.l 1p Tw lttxBl Top INO)BIKB) Top Ind (°) roam Des Co. (In) 5 fi44.3 3,835.9 81.86 SLEEVE BAKER TIEBACK SLEEVE 5750 56553 3,837.5 8183 PACKER ZXP LINER TOP PACKER 4.930 5,6633 3,838.6 8181 NIPPLE RSNIPPLE 4,880 5,6662 3,839.0 81.80 HgNGER BAKER FLEX LOCK HYD TO LINER HANGER 4860 5.675.5 3,840.4 8177 XO BUSHING XO BUSHING 3,910 11,851)7 3,818.6 88.68 BUSHING BAKER PACKOFF BUSHING 3,958 Tubing Strings Tuaino Descnpeian snino m a... 1o(in) Top lNKel set Depth (n..set Hi INO11...wr(1WR1 Grade top connection TUBINGWO-2014 312 2.99 22.3 55fi84 3,8252 930 L -Bp 3.5 Completion Details rod Irv-) Topincl Nominal Top lnuto rudd 1°) Ikm Des Com 10 (in) 223 2.3 0.00 HANGER VETCO GRAY TUBING HANGER ed Pup Joint 2.875 5,016.2 3,6]1.1 .M SLEEVEC BAKER CMU SLIDING SLEEVE WDS NIPPLE (OPEN 41MI2017) 2.810 5,071.3 3,690.2 69.75 GAUGE SCHLUMBERGER DOWNHOLE GAUGE MAN wl NDPG 3.000 Pope 5.548.3 3,822.2 81.8 SEALASSY BAKE H- LOCATOR SEAL ASSEMBL 'suck 2.990 Do) Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top(ftKB) T.'RVH Vda) Taplo=1 11I Des Co. Run Oak Rignl 5016.0 3,671.0 6954 PODIUM. T' -L LM ( 5116" OV 153" OAL) SHOOK AND SPARTEK GAUGE(101- GAL),E%T AIA SEAL BTM PRO STACK 41292017 9.7430 3,828.5 91.66 FISH FIS D I1 ,Lmver pDNon of T RlCOlelpump assy, pushetl down - 9743 RKB on 4114104 32212006 O.DDD Perforations & $lots Top lNlel can lnKB) roylND) (..I aon Greg) (Itl(al unxwmne Dam snw Dms Iahebm 1 TVP, Com 88240 11,850.0 3,039.1 3,816.6 WSU,1C-1 6I020D3 I 12.0 :PERF posted liner aouraing lidlsfotlM pipe joints Notes: General & Safety End mm Annomxon 812912008 NOTE. WORKOVER 91512008 NOTE: VIEW SCHEMATIC w1ADIS Schema1wil0 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY John Peirce Sr. Wells Engineer ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1C-184 Permit to Drill Number: 203-089 Sundry Number: 319-129 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 www. a o g c c. a l o s k a. g o v 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. Si erely, Daniel T. Seatnount, Jr. Commissioner DATED this 2- day of March, 2019. aBDos�*" 0 111019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 SIVE"® MAR 19 2019 -ACC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Progmm❑ Plug for Rednll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: RPPG MBE TrtmtE) 2. Operator Name: 4. Curtent Well Class: 5. Permit to Drill Number: ConocoPhilli S Alaska Inc. Exploratory ❑ Development O Stratigraphic ❑ Service ❑ 203-089 3. Address: 6. API Number: P. 0. Box 100360, Anchorage, Alaska 99510 50-029-23155-00-00 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 ❑ No El KRU IC -184 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): 11,890' 3,820' 11885 3839 1475psi NONE 9743 Casing Length Size MD TVD Burst Collapse Conductor 80' 16" 110' 110' Surface 5,770' 75/8 5,798' 3,853' Inner Liner 5,624' 51/2 5,652' 3,837' Slotted Liner 6,241' 412 11,885' 3,819' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8824-11850 3839-3819 3.500" L-80 5,568' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER = ZXP LINER TOP PACKER SSSV = NONE 5655 MD and 3837 TVD 12. Attachments: Proposal Summary 0 Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development [ Service ❑ 14. Estimated Date for 4/10/2019 15. Well Status after proposed work: Commencing Operations: OIL I] WINJ ❑ 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 Title: Sr. Wells Engineer Contact Email: John.W.Peirce@cop.com Contact Phone: (907) 265-6471 Authorized Signature: tN ' • 3 � Cls+. Date: � L y. COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: n Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No p Spacing Exception Required? Yes ❑ No C!r Subsequent Form Required: iL APPROVED BY Z/( Approved by: COMMISSIONER THE COMMISSION Date: Via s//,///7UKI(iINAL 5/3,j I RBDMSJ�✓MAR 2 2 all Form and Form 10-003 Revised 4/2017 I,- Approvapplication is valid for 12 months from the date of approval. A chments in Duplicate �.F_ 3x/(9'14 ConocoP11l11ps Alaska. Inc. KUP PROD WELLNAME 1C-184 SAK WELLBORE 1C-184 1cae4. aDeaoreasT:w pM a, Last Tag Annotation [mandate) I Lauth- auth ByLast _...._.... ........ _._._................ _..-........_......__.............. HANGER, M3 coaoucroRonoo : so. .Ups S; s01at GUf pO. a.ere0 wuGE; Smrs eEALAssv; sstes s5'INNERUNER-WDI mo_ a,m, SURFACE; V.M,T e0. FISH; B,TA4' 0�1 IEERF, 9,aN,611 as, LINER 05'alcaN;S.wa.; II,w50 ` I L LastTag: 1C-184 Im¢sEor Last Rev Reason Annotation End Deh Wellnare Last MaO ay Rev Reason'. OPEN CMU, BET POGLM 5/2/201] 1C-184 pproven Casing Strings cxine Dnznptano0 (in) IO (in) Top (0Ke1 semeprn lrflte) set 0mtn lrv0)_. WULzn p... Grade rop rnrew CONDUCTOR 16 15.06 30.0 110.0 1100 62.50 H-40 WELDED Ceslnp 0eecapsbn 10DOm 10(m) I Top MIKE) seroeptantial SNCspn RVO1... WtlLen O... Gratle iop inroad SURFACE 7Sl8 6.87 27.9 5,7980 3,8528 28.70 L -W BTCM CMInN."Elmmum Oapn) ID(Inl Top(KK81 set Geprn(eM Set0"Ovin-AWLen O...Grm" Top M"d B.5"INNER LINER -WO 512 500 280 5,652.1 3,837.0 15.50 L-80 BTC Liner Details Nominal m Top MKBI Top C.) Top Incl r) Ihm ax Com pn) 280 28.0 0.00 HANGER VE I UU GRAY MANDREL HANGER wIPup Joint 4.950 5,553.0 3,82.9 81.18 %O Retlucilg Crossover 5' Mod Bdxx "BT Mo 4360 Box 5,5553 3,823. 81.23 S8E BAKER 8040 SBE 4.000 5,5]34 3,8260 81.62 XO Reducing Crossover 3la" SU EUE8rtl Pin x S"BTCM Box 2.910 5588.8 3,8281 8195 SLEEVE ER CIAU SLIDINGVE W ip a op¢n 2810 CMU -1216114) 5,638.0 3.83S0 81.88 XO Enlarging 6 Cemsenner 31.12- JBTox x5112' 17#Hydril 521 2890 Pin 5, 1.3 3,835.5 81.87 SEALASSV 'BU EALA LY5W eat DHy n 4.800 521 (3.00 stick-up) coming Eewrippi 00 hN to (in) Top We) SNGepq"Instl GepN Mod12.6s. 11._Graae Tap Torsed LINER 45"Slotted 4112 3.86 5,644.3 11,885.0 38194 0 L-80 INSCT Liner Details T"(MB) TOPIND10tKB) Twmd r) Man Deo xomrou lG Cam (in) 5,644.3 3,835.9 81,86 SLEEVE BAKER TIEBACK LEEVE 5.750 5,6553 ,837 5 8183 PACKER 2JlP LINER TOP PACKER 4.930 5,663.3 3,838.6 8181 NIPPLE RS NIPPLE 4.880 5,666.2 3,8390 81.80 HANGER BAKER FLEX LOCK HYD TO LINER HANGER 4.860 5.575.5 3.8404 817770 -BUSHING XC BUSHING 3.910 11,8507 3,818.6 8868 BUSHING BAKER RACKOFF BUSHING 3.958 Tubing Strings Tuning Description imup Ma... l0 (int ToplrcNBl ST Oep@(R. Set aepm (TVO)4.. WIIIbM) Grays TOp Connectbn TUBING WO -2014 3112 2.99 22.3 5,568.4 3.8252 930 L-80 3.5 Completion Details rop(rvDi Top andNommal Tap hies) inns) r9 rhm oez cam main) 22.3 22.3 000 HANGER VETCO GRAY TUBING HANGER w/ Pup Joint 2.875 5,0182 3,671.1 6954 LEEVEC BAKER CMU SLIDING SLEEVE WS NIPPLE (OPEN 47291201)) 2.810 _77713 3,697,2 69.75 UGE bLHLUMBERGER DOWNHOLE GAUGE NANDREL wI NDPG 3.000 gauge ,54 3 3,8272 8108 SEAL ABBY KE7 80 40 GBH-22LOCATOR SEAL ASSEMBLY (7,00'SOCK --2990 up) Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top IPK.) rap E) (rcKBI Topmm 19 oez coin Run Dave ID (in) 5,016.0 3,671.0 69.54 P GLM .1"C -L C "POGLM 1'OV75 AL SHOCK AND SPARTEK GAUGE(101"OAL),EXT AVA SEAL BTM PKG STACK 4/29x201] ,]430 3,8285 91.66 FISH H I ,Lower pOMmp-o T lelpump assy, pushed down to 9743 RKB on 4/14104 3722/2006 O0DD Perforations & Slots Tapams) I Btm(KKB) I Tap 11Vq MKB) I BtmfND) MKB) LinxMZanepsh sna Denz Isna[s/!f Com 8,8240 11,850.0 3,839.1 31818.6 WS D, 1C-184 6182003 120 (PERR F ISINtedihme,dannuthat, soliNslon¢d pipe loinis Notes: General d Safety End oats Annatanon 8/292008 NOTE'. WORKOVER 9/5/2008 NOT: VIEW SCHEMATIC wIAlaska Solemali¢90 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 IPROF 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 1C-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 IPROF 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 bbls 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. RECEIVED STATE OF ALASKA DEC 1 1 2017 ALA OIL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATIONS ADCC 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well LI Re-enter Susp Well LI Other: RPPG D MBE Trtmt 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development p Exploratory ❑ 203-089 3.Address: P. O. Box 100360,Anchorage, Alaska Stratigraphic❑ Service ❑ 6.API Number: 99510 50-029-23155-00 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 1C-184 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 11,890 feet Plugs measured None feet true vertical 3,820 feet Junk measured 9743 feet Effective Depth measured 11,885 feet Packer measured 5,655 feet true vertical 3,839 feet true vertical 3,837 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 feet 16 " 110' MD 110 TVD SURFACE 5,770 feet 7 5/8 " 5,798' MD 3853 TVD INNER LINER 5,624 feet 5 1/2 " 5,652' MD 3837 TVD INER SLOTTED 6,241 feet 4 1/2 " 11,885' MD 3819 TVD Perforation depth Measured depth 8824-11850 feet True Vertical depth 3839-3819 feet Tubing(size,grade,measured and true vertical depth) 3.5 " L-80 5,568' MD 3,825'TVD Packers and SSSV(type,measured and true vertical depth) PACKER=ZXP Liner Top Packer 5,655' MD 3,837'TVD SSSV: = NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: 4 2 . 2 ti o S SCANNED ti.A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 105 52 259 — 245 Subsequent to operation: 166 28 331 — 265 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) X15.Well Class after work: Daily Report of Well Operations 0 Exploratory 0 Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG ❑ GINJ❑ SUSP❑ SPLUGE 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: 317-382 Contact Name: John Peirce Authorized Name: John Peirce Contact Email: John.W.Peirce@cop.com Authorized Title: Sr.Wells Engineer ,y 1--- /A / Contact Phone: (907)265-6471 Authorized Signature: W _, Date: 12/,11 fl- •_.I. •. 27pW Submit Original Only Y VTL / Z L ^�"' , �. nr 7 1 ,� e i RE:1 fes c C C 12 2617 • IC- 190 - IC- 184 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 PD 1C-184 Conoco/ fillips z Well Attribute Max Angle flit TD A)sk,3.Irk;, Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) CorwctiVhillips 500292315500 WEST SAK PROD 92.37 9,811 38 11,890.0 °°. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1C-184,12/111201711:1429 AM SSSV:NONE 50 12/16/2013 Last WO: 11/14/2014 35.40 6/10/2003 vertical sc/Ur11aUE/wSiall Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason OPEN CMU,SET POGLM pproven 5/2/2017 Casing Strings 9�11f I Casing Description ODI in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread HANGER,n.3 7e CONDUCTOR 16 15.062 30.0 110.0 110.0 62.50 H-40 WELDED �qtl Il- � Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread � .i . SURFACE 7 5/8 6.875 27.9 5,798.0 3,852.8 29.70 L-80 BTCM Casing Descr ption OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread III IIII 5.5'INNER LINER-WO 5 1/2 5.000 28.0 5,652.1 3,837.0 15.50 L-80 BTCM 11� l ILiner Details i i Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) �II• 28. 0 28.0 0.00 HANGER VETCO GRAY MANDREL HANGER w/Pup Joint 4.950 IIIIIIIIIIIIIIII5,553.0 3,822.9 81.18 XO Reducing Crossover 5"BTC Mod Box x 5 12"BTC Mod SCC 4.360 Box CONDUCTOR;30.0-110.0 5,555.3 3,823.3 81.23 SBE BAKER 80-40 SBE 4.000 5,573.4 3,826.0 81.62 XO Reducing Crossover 3 1/2"9.3#EUE8rd Pin x 5""BTC-M Box 2.970 j 5,588.8 3,828.1 81.95 SLEEVE-0 BAKER CMU SLIDING SLEEVE w/Nipple(open 2.810 CMU-12/6/14) 5,638.0 3,835.0 81.88 XO Enlarging 6'Crossover 3 1./2"IBTM Box x 5 1/2"17#Hydril 521 2.890 Pin It 5,641.3 3,835.5 81.87 SEAL ASSY 10'BULLET SEAL ASSEMBLY 5.75"Seal OD Hydril 4.800 521(3.00'stick-up) SLEEVE-C;5,016.1 I1'I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread POGLM;5,016.0 LINER 4.5"Slotted 4 1/2 3.865 5,644.3 11,885.0 3,819.4 12.60 L-80 NSCT I Liner Details I Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) 5,644.3 3,835.9 81.86 SLEEVE BAKER TIEBACK SLEEVE 5.750 It 5,655.3 3,837.5 81.83 PACKER ZXP LINER TOP PACKER 4.930 5,663.3 3,838.6 81.81 NIPPLE RS NIPPLE 4.880 5,666.2 3,839.0 81.80 HANGER BAKER FLEX LOCK HYD TO LINER HANGER 4.860 GAUGE',5,071 3 41illo 5,675.5 3,840.4- 81.77.XO BUSHING XO BUSHING 3.910 11,850.7 3,818.6 88.68 BUSHING BAKER PACKOFF BUSHING 3.958 il Tubing Strings Tubing Description String Me...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND))...Wt(Ibit) Grade Top Connection TUBING WO-2014 31/2 2.992 22.3 5,568.4 3,825.2 9.30 L-80 3.5 Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl I°) Item Des Com (in) SEAL ASSY;5,548.3 22.3' 22.3 0.00 HANGER VETCO GRAY TUBING HANGER w/Pup Joint 2.875 5,016.2' 3,671.1 69.54 SLEEVE-C BAKER CMU SLIDING SLEEVE w/DS NIPPLE(OPEN 2.810 it al 4/29/2017) 5,071.3' 3,6902 69.75 I GAUGE SCHLUMBERGER DOWNHOLE GAUGE MANDREL w/ 3.000 NDPG gauge I- _5,548.3 3,822.2' 81.08 SEAL ASSY BAKER 80-40 GBH-22 LOCATOR SEAL ASSEMBLY 2.990 q (7.00'stick up) Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 5,016.0 3,671.0 69.54 POGLM 2.81"C-LOCK 8 3"POGLM(5/16"OV/53"OAL) 4/29/2017 SHOCK AND SPARTEK GAUGE(101"OAL),EXT AVA SEAL BTM PKG STACK 9,743.0 3,828.5 91.86 FISH FISH IOST 3/11/2006,Lower portion of TRICO jet 3/22/2006 0.000 pump assy,pushed down to 9743 RKB on 4/14/04 Perforations&Slots Shot 55"INNER LINER-WO;28.0- Iia 1? Dens 5,6521 Top(ND) Btm(ND) (shots/ �I..'., Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft( Type Com 8,824.0 11,850.0 3,839.1 3,818.6 WS D,1C- 6/8/2003 12.0 IPERF Slotted liner alternating 184 solid/slotted pipe joints rx tamer Notes:General&Safety I1M11End Date Annotation 1 i 8/29/2008 NOTE WORKOVER 9/5/2008 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 SURFACE,27.9-5,7980_1L FISH;9,743.0 IPERF;6,824.0-11,850.0 LINER 4.5"Slotted,5,644.3- a , 11,885 0 • T • • OF y",,\ %% , THE STATE Alaska Oil and Gas �, s _�� of LAsKAL Conservation Commission ttt _ 333 West Seventh Avenue *ti; - GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ®'ALAS'.P Fax: 907.276.7542 www.aogcc.alaska.gov John Peirce Sr. Wells Engineer ConocoPhillips Alaska, Inc. saws ,�E P 0 1 ,1 • P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1C-184 Permit to Drill Number: 203-089 Sundry Number: 317-382 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 . Foerster Commissioner DATED this 2. ay of August,2017. RBDIVIS AUG3 0 2017 . • • ffi- EC;6'V E la STATE OF ALASKA a 1,l ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS � 's,,. �l 20AAC25.280 _ 1.Type of Request: Abandon ❑ Plug Perforations El Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing El Change Approved Program!: Plug for Redrill 0 Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: RPPG D MBE TrtmtE 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development 2. 203-089 ' 3.Address: Stratigraphic CIService ❑ 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-23155-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1 C-184 Will planned perforations require a spacing exception? Yes ❑ No 2 i 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25649,ADL 25650 • Kuparuk River Field/West Sak Oil Pool i 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): 11,890' . 3,820' - 11885 . 3839, NONE 9743 Casing Length Size MD TVD Burst Collapse Conductor 80' 16" 110' 110' Surface 5,770' 7 5/8 5,798' 3,853' Liner 5,624' 5 1/2 5,652' 3,837' Slotted Liner 6,241' 5 1/2 3,819' 3,819' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8824-11850 . 3839-3819 3.500" L-80 5,568' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER=ZXP LINER TOP PACKER , 5655=MD and 3837 TVD SSSV: =NONE N/A 12.Attachments: Proposal Summary 2 Wellbore schematic 2 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory El Stratigraphic❑ Development 0 ' Service ❑ 14.Estimated Date for 9/1/2017 15.Well Status after proposed work: Commencing Operations: OIL ID •• WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS El WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: John Peirce Contact Name: John Peirce Authorized Title: Sr.Wells Engineer Contact Email: John.W.Peirce@cop.com W Contact Phone: (907)265-6471 Authorized Signature: e••- Date: gI /%7 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 317-3cdz. Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes El No [g Spacing Exception Required? Yes No Subsequent Form Required: II�pp 6 ❑ � q q �� �d� RBDMS L� AM 3 0 2017 APPROVED BY Approved by: ,f ,i_,..,"_., COMMISSIONER THE COMMISSION Date: ii,... ._.....( 7 ab $ /-01' #,/iii -7^ C8/2V/7- Submit /z 5//7-- 0 IiiIp9j ASubsin Form ane Form 10-403 Revised 4/2017 C s valid 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 (PROF 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. 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 perf 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 D 1 C-1 84 ConocoPhilhps is Well Attribu Max Angle w I D TD 1i3*wi�Cc"t Inc. Wellbore API/UWI Feld Name Wellbore Status ncl(°) MD(ftKB) Act Min(ftKB) Cfxwc0Ph(11ips 500292315500 WEST SAK PROD 92.37 9,811.38 11,890.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 10-184,7/26/201711:34:54 AM SSSV:NONE 50 1206/2013 Last WO: 11/14/2014 _ 35.40 6/10/2003 ..:.Vertical schematic(octva0 Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:OPEN CMU,SET POGLM pproven 5/2/2017 1 f Casing Strings HANGER;22.3 Casing Description OD(in) ID(in) Top((KB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread y , � CONDUCTOR 16 15.062 30.0 110.0 110.0 62.50 H-40 WELDED 1. '�I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE 7 5/8 6.875 27.9_ 5,798.0 3,852.8 29.70 L-80 BTCM Tggg,.bw Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread i 5.5 INNER LINER-WO 5 1/2 5.000 28.0 5,652.1 3,837.0 15.50 L-80 BTCM IM' Liner Details INominal ID j' ,°,�. Top(ftKB) Top(TVD)(ftKB) Top Incl C) Item Des Com (in) � 28.0 28.0 0.00 HANGER VETCO GRAY MANDREL HANGER w/Pup Joint 4.950 5,553.0 3,822.9 81.18 XO Reducing Crossover 5"BTC Mod Box x 5 1/2"BTC Mod SCC 4.360 Box CONDUCTOR;30.0-110.0 r l 5,555.3 3,823.3 81.23 SBE BAKER 80-40 SBE 4.000 5,573.4 3,826.0 81.62 XO Reducing Crossover 3 1/2"9.38 EUE8rd Pin x 5""BTC-M Box 2.970 5,588.8 3,828.1 81.95 SLEEVE-0 BAKER CMU SLIDING SLEEVE w/Nipple(open 2.810 CMU-12/6/14) 5,638.0 3,835.0 81.88 XO Enlarging 6'Crossover 3 112"IBTM Box x 5 1/2"178 Hydril 521 2.890 Pin 11 5,641.3 3,835.5 81.87 SEAL ASSY 10'BULLET SEAL ASSEMBLY 5.75"Seal OD Hydril 4.800 521(3.00'stick-up) SLEEVE-C;5,016.1 1li Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread POGLM;5,016.0 LINER 4.5 Slotted 41/2 3.865 5,644.3 11,885.0 3,819.4 12.60 L-80 NSCT Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Intl(°) Item Des Com (in) 5,644.3 3,835.9 81.86 SLEEVE BAKER TIEBACK SLEEVE 5.750 illr 5,655.3 3,837.5 81.83 PACKER -ZXP LINER TOP PACKER 4.930 ill 5,663.3 3,838.6 81.81 NIPPLE RS NIPPLE 4.880 5,666.2 3,839.0 81.80 HANGER BAKER FLEX LOCK HYD TO LINER HANGER 4.860 • GAUGE;5,071.3 11 5,675.5 3,840.4 81.77 XO BUSHING XO BUSHING 3.910 4 11,850.7 3,818.6 88.68 BUSHING BAKER PACKOFF BUSHING 3.958 41 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..l Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING WO-2014 3 1/2 2.992 22.3 5,568.4 3,825.2 9.30 L-80 3.5 • .I, Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) SEAL ASSY,5,548.3 22.3 22.3 0.00 HANGER VETCO GRAY TUBING HANGER w/Pup Joint 2.875 lik so-ai ., 5,016.2 3,671.1 69.54 SLEEVE-C BAKER CMU SLIDING SLEEVE w/DS NIPPLE(OPEN 2.810 it 4/29/2017) 5,071.3 3,690.2 69.75 GAUGE SCHLUMBERGER DOWNHOLE GAUGE MANDREL w/ 300 NDPG gauge 5,548.3 3,822.2 81.08 SEAL ASSY BAKER 80-40 GBH-22 LOCATOR SEAL ASSEMBLY 2.990 ' (7.00'stick up) Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top not Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 5,016.0 3,671.0 69.54 POGLM 2.81"C-LOCK 8 3"POGLM(5/16"OV/53"OAL) 4/29/2017 SHOCK AND SPARTEK GAUGE(101"OAL),EXT AVA SEAL BTM PKG STACK 9,743.0 3,828.5 91.86 FISH FISH IOST 3/11/2006,Lower portion of TRICO jet 3/22/2006 - 0.000 pump assy,pushed down to 9743 RKB on 4/14/04 j; Perforations&Slots J Shot 5.5"INNER LINER-WO;28.0. (; �I Dens 5'6521 Top(ftKB) Btm(ftKB Top(ND) Btm(TVD) (shots/ € I ) (ftKB) (ftKB) Zone Date ft) Type Com 8.824.0 11,850.0 3,839.1 3,818.6 WS D,1C- 6/8/2003 12.0 IPERF Slotted liner alternating 184 solid/slotted pipe joints Notes:General&Safety J i1M)'' End Date Annotation 8/29/2008 NOTE:WORKOVER 9/5/2008 'NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 • 0 SURFACE.27.9-5,798.0-J ea FISH.9,743.0 (PERF;8,824.0-11,8500 .-" s r illil IlLLINER 4.5"Slotted;5,644.3- 4 11,885.0 STATE OF ALASKA AKA OIL AND GAS CONSERVATION COMMISSION • REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon E Plug Perforations E Fracture Stimulate Pull Tubing E Operations Shutdown E Performed: Suspend E Perforate E Other Stimulate p Alter Casing E Change Approved Program Plug for Redrill r Perforate New Pool fl Repair Well E Re-enter Susp Well -.. Other:Crystal Seal Re-Trtmt 1 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory E 203-089 3.Address: 6.API Number: Stratigraphic n Service P.O. Box 100360,Anchorage,Alaska 99510 50-029-23155-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25649,ADL 25650 KRU 1C-184 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 11890 feet Plugs(measured) None true vertical 3820 feet Junk(measured) 9743 Effective Depth measured 11885 feet Packer(measured) 5655 true vertical 3839 feet (true vertical) 3837 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 110 110 SURFACE 5770 7 5/8 5.5"INNER LINEF 5624 5 1/2 5652 3837 LINER 4.5"SLOTI 6241 4 1/2 11885 3819 RECEIVE() i� q OCT 17 2016 Perforation depth: Measured depth: 8824-11850 SCANNED ED MAR 0 2201Z True Vertical Depth: 3839-3819 A®G(1J' Tubing(size,grade,MD,and ND) 3.5, L-80, 5568 MD,3825 ND Packers&SSSV(type,MD,and TVD) PACKER-ZXP Liner Top Packer @ 5655 MD and 3837 TVD SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): none Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation - - Shut-In - - Subsequent to operation - - Shut-In - - 14.Attachments(required per 20 MC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory r Development F Service E Stratigraphic Copies of Logs and Surveys Run n 16.Well Status after work: Oil F Gas E WDSPL fl Printed and Electronic Fracture Stimulation Data E GSTOR E WINJ r' WAG r GINJ r" SUSP r" SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-382 Contact John Peirce a 265-6471 Email John.W.Peirceaconocophillips.com Printed Name John Peirce Title Sr. Well Engineer Signature ° Phone:265-6471 Date I j716 / frc... 10/10 1[4, Form 10-404 Revised 5/2015 /04o 746RBDMS L�-OCT 2 0 2016 Submit Original Only • • IC- I 90 to IC- I 84 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 MOD • 1C-184 Cono+col3-irHips z Well Attrib Max Angle&MD TD Al7,i$ka,Ir1i.< Wellbore APW WI Field Name Wellbore Status nob(°) MD(ftKB) Act Atm(ftKB) • Cono Nips 500292315500 WEST SAK PROD 92.37 9,811.38 11,890.0 sY.° ... Comment H25(ppm) Date Annotation End Date keGrtl(ft) Rig Release Date 1C-184,10/132016 3 28 27 PM SSSV:NONE 50 12/16/2013 Last WO: 11/14/2014 35.40 6/10/2003 Verbal ac6ematw Zachul) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:RESET JET PUMP,SLIPSTOP pproven 12/15/2015 Casing Strings HANGER;22.3111!11Casng Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I..Grade Top Thread CONDUCTOR 16 15.062 30.0 110.0 110.0 62.50 H-40 WELDED 1 . ��� Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 75/8 6.875 27.9 5,798.0 3,852.8 29.70 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread 1#e! �� 5.5 INNER LINER-WO 51/2 5.000 28.0 5,6521 3,837.0 15.50 L-80 BTCM Liner Details Nominal ID ,,,,,,n,,,,,,,,,,,,,,,,,,,,,,,,,,,,,u.,,,,n."'II.... - ,.,,,. lop(ftKB) lop(ND)(ftKB) lop Ind(*) Item Des Com (in) 28.0 28.0 0.00 HANGER VETCO GRAY MANDREL HANGER w/Pup Joint 4.950 ,� 5,553.0 3,822.9 81.18 XO Reducing Crossover 5"BTC Mod Box x 5 1/2'BTC Mod SCC 4.360 Box CONDUCTOR;30.0-110.0 " 5,555.3 3,823.3 81.23 SBE BAKER 80-40 SBE 4.000 5,573.4 3,826.0 81.62 XO Reducing Crossover 3 1/2"9.3#EUE8rd Pin x 5""BTC-M Box 2.970 5,588.8 3,828.1 81.95 SLEEVE-0 BAKER CMU SLIDING SLEEVE w/Nipple(open 2.810 CMU-12/6/14) 5,638.0 3,835.0- 81.88 XO Enlarging 6'Crossover 3 1./2"IBTM Box x 5 1/2"17#Hydril 521 2.890 Pin :1)1-ii 5,641.3 3,835.5' 81.87 SEAL ASSY 10'BULLET SEAL ASSEMBLY 5.75"Seal OD Hydril 4.800 LI SLIP STOP;5,014.5 521(3.00'stick-up) 5 ,. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread SLEEVE-0;5,016.1 LINER 4.5"Slotted 4 1/2 3.865 5,644.3 11,885.0 3,819.4 12.60 L-80 NSCT POGLM,5,018.0 Liner Details :::,1. Nominal ID lir lop(MB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 5,644.3 3,835.9 81.86 SLEEVE BAKER TIEBACK SLEEVE 5.750 5,655.3 3,837.5 81.83 PACKER ZXP LINER TOP PACKER 4.930 5,663.3 3,838.6 81.81 NIPPLE RS NIPPLE 4.880 '( 5,666.2 3,839.0 81.80 HANGER BAKER FLEX LOCK HYD TO LINER HANGER 4.860 GAUGE;5,071 3 114Th 5,675.5 3,840.4 81.77 XO BUSHING XO BUSHING 3.910 iiri 11 850.7 3,818 6 88.68 BUSHING BAKER PACKOFF BUSHING 3.958 tall Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..I Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING WO-2014 31/2 2.992 22.3 5.568.4 3,825.2 9.30 L-80 3.5 tr Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 22.3 22.3 0.00 HANGER VETCO GRAY TUBING HANGER w/Pup Joint 2.875 SEAL nssv.s 5483 r 5,016.2 3,671.1 69.54 SLEEVE-O BAKER CMU SLIDING SLEEVE w/DS NIPPLE(Opened 2.810 2-14-15) id 5,071.3 3,690.2 69.75 GAUGE SCHLUMBERGER DOWNHOLE GAUGE MANDREL w/ 3.000 NDPG gauge 5,548.3 3,822.2 81.08 SEAL ASSY BAKER 80-40 GBH-22 LOCATOR SEAL ASSEMBLY 2.990 (7.00'stick up) 1E' Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 5,014.5 3,670.5 69.52'SLIP STOP TBG STOP(OAL=20") 2/1/2016 0.000 5,016.0 3,671.0 69.54 POGLM 2.81"C-LOCK 8 3"POGLM(5/16"OV/53"OAL) 2/1/2016 SHOCK AND SPARTEK GAUGE(101"OAL),EXT AVA SEAL BTM PKG STACK 9,743.0 3,828.5 91.86 FISH FISH IOST 3/11/2006,Lower portion of TRICO jet 3/22/2006 0.000 pump assy,pushed down to 9743 RKB on 4/14/04 Perforations&Slots 5.5"INNER LINER-WO;28.0- I = Shot 5,652.1 Dens I.. Top(TVD) Btm(TVD) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (5KB) Zone Date ft) Type Com 8,824.0. 11,850.0 3,839.1. 3,818.6 WS D,1C- 6/8/2003 12.0 (PERF Slotted liner alternating - " 184 solid/slotted pipe joints Notes:General&Safety 'i i� End Date Annotation -=-- ____„, 8/29/2008 NOTE:WORKOVER 9/5/2008 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 SURFACE;27.9-S,7980-i L FISH;9,743.0 (PERF;8,824.0-11,850.0 111 LINER 4.5'Slotted;5,644.3- 11,885.0 of 71, y�'P�1/ is THE STATE • Alaska Oil and Gas p Conservation Commission ALAsKA 333 West Seventh Avenue "*21.\-T7 GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 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-184 Permit to Drill Number: 203-089 Sundry Number: 316-382 SCANNED OC f 3 1 201 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, t?"4'\ Cathy . Foerster Chair DATED this&day of August, 2016. RBDMS L'- Alin. _ 7 9nic RECEIVED • STATE OF ALASKA • JUL2 5 2016 s' ALASKA OIL AND GAS CONSERVATION COMMISSION p // /� APPLICATION FOR SUNDRY APPROVALS AOGC 20 AAC 25.280 1.Type of Request: Abandon E Plug Perforations r Fracture Stimulate r Repair Well E Operations Shutdown E Suspend E Perforate fl Other Stimulate E Pull Tubing E Change Approved Program I- Plug for Redrill E Perforate New Pool Re-enter Susp Well r Alter Casing f Other: Crystal Seal Re-Trmt fJ • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory E Development 17 • 203-089 3.Address: 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-23155-00 • 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 17 ✓ KRU 1C-184 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): 11,890' • 3,820' ` 11,885 ' 3839 - 1280 None 9743 Casing Length Size MD ND Burst Collapse Conductor 80' 16" 110' 110' Surface 5,770' 7 5/8 5,798' 3,853' Liner Tie-Back 5,624' 5 1/2 5,652' 3,837' Production Liner 6,241' 41/2 11,885' 3,819' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8824-11850 s 3839-3819 31/2 L-80 5,568' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): PACKER-ZXP Liner Top Packer 5655 MD,and 3837 TVD SSSV:NONE 12.Attachments: Proposal Summary E Wellbore schematic E 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory fl Stratigraphic fl Development F'Service E 14.Estimated Date for 8/22/2016 15.Well Status after proposed work: Commencing Operations: OIL F' WINJ E WDSPL r Suspended 16.Verbal Approval: Date: GAS E WAG fl GSTOR E SPLUG F' Commission Representative: GINJ E Op Shutdown F Abandoned E 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 @ 265-6+371 Email John.W.Peirce(conocophilliPs.com Printed Name John Peirce Title Sr.Wells Engineer 704 14—r. ,,e ,� 7/2 5/I 6, Signature 4.----, Phone 265-6471 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: _ 3 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ NoCASP-7. Sit Spacing Exception Required? Yes ❑ No I� Subsequent Form Required: I 0 f/4 ÷ APPROVED BY Approved by: MMISSIONER THE COMMISSION Date:R-3—/ .� Submit Form and Form 1 - 03 e e 11/4o �/� NAT,n .,valid for 12 months from the date of approval. mems in Du ire - ic3 � yRA1,41 l47l� RBDI r.'-- t. . 2 2016 l KUP PMD 1C-184 ConocoPhillips Well Attribute Max Angle TD Alaska IncWellbore API/UW Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(BOB) Cort0L Phillips t'', 500292315500 WEST SAK PROD 92.37 9,811.38 11,890.0 • ... Continent H2S(ppm) Date Annotation End Date KB-Grd(ft) 'Rig Release Date 1c-184,7/25201612:06.26 PM SSSV:NONE 50 12/16/2013 Last WO: 11/14/2014 35.40 6/10/2003 Vertical schema5U(anted) Annotation Depth(BOB) End Date Annotation Last Mod By End Date Last Tag. Rev Reason:RESET JET PUMP,SLIPSTOP pproven 12/15/2015 Casing Strings • HANGER;22.3 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread 11���I Y CONDUCTOR 16 15.062 30.0 110.0 110.0 62.50 H-40 WELDED I _ Casing Description OD(in) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth)TVD)...Wt/Len(I...Grade 'Top Thread I�-�I : SURFACE 75/8 6.875 27.9 5,798.0 3,852.8 29.70 L-80 BTCM I'1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread -- 1 5.5 INNER LINER-WO 51/2 5.000 28.0 5,652.1 3,837.0 15.50 L-80 BTCM Liner Details Nominal ID k I Top(BOB) Top(TVD)(ftKB) Top Incl e) Item Des Coin (In) 28.0 28.0 0.00 HANGER VETCO GRAY MANDREL HANGER w/Pup Joint 4.950 3 M 5,553.0 3,822.9 81.18 XO Reducing Crossover 5"BTC Mod Box x 5 12"BTC Mod SCC 4.360 Box CONDUCTOR;30.0-110.0 II. 5,555.3 3,823.3 81.23 SBE BAKER 80-40 SBE 4.000 5,573.4 3,826.0 81.62 XO Reducing Crossover 3 1/2"9.3#EUE8rd Pin x 5-BTC-M Box 2.970 5,588.8 3,828.1 81.95 SLEEVE-0 BAKER CMU SLIDING SLEEVE w/Nipple(open 2.810 CMU-12/6/14) 5,638.0 3,835.0 81.88 XO Enlarging 6'Crossover 3 1.2"IBTM Box x 5 1/2"17#Hydril 521 2.890 Pin .iti5,641.3 3,835.5 81.87 SEAL ASSY 10'BULLET SEAL ASSEMBLY 5.75"Seal OD Hydril 4.800 SLIP STOP;5,014.5 521(3.00'stick-up) Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ROB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SLEEVE-0;5,016.1 LINER 4.5"Slotted 41/2 3.865 5.644.3 11,885.0 3,819.4 12.60 L-80 NSCT POGLM;5,016.0 + o Liner Details 1. ,i Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl('I Item Des Com (in) 5,644.3 3,835.9 81.86 SLEEVE BAKER TIEBACK SLEEVE 5.750 5,655.3 3,837.5 81.83 PACKER LT LINER TOP PACKER 4.930 ) 5,663.3 3,838.6 81.81 NIPPLE RS NIPPLE -- 4 880 5,666.2 3,839.0 81.80 HANGER BAKER FLEX LOCK HYD TO LINER HANGER 4.860 GAUGE.5071.3 uI 5,675.5 3,840.4 81.77 XO BUSHING XO BUSHING 3.910 11,850.7 3,818.6 88.68 BUSHING BAKER PACKOFF BUSHING 3.958 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..!Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING WO-2014 3 1/2 2.992 22.3 5,568.4 3,825.2 9.30 L-80 3.5 Completion Details '.ii Nominal ID Top(SOB) Top(TVD)(ftKB) Top Teel r) Item Des Com (in) 22.3 22.3 0.00 HANGER VETCO GRAY TUBING HANGER w/Pup Joint 2.875 sear assv S 5463 t' ''f Me 5,016.2 3,671.1 69.54 SLEEVE-0 BAKER CMU SLIDING SLEEVE w/DS NIPPLE(Opened 2.810 g'_ y ). „ 2-14-15) t ' I,. 5,071.3 3,690.2 69.75 GAUGE SCHLUMBERGER DOWNHOLE GAUGE MANDREL w/ 300 NDPG gauge €'F`y 5,548.3 3,822.2 81.08 SEAL ASSY BAKER 80-40 GBH-22 LOCATOR SEAL ASSEMBLY 2.990 EE (7.00'stick up) I Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) aLII ITop(TVD) Top In 'I Top(ftKB) IftKB) Ind (°) Des Com Run Date ID(In) ... j 5,014.5 3,670.5 69.52 SLIP STOP TBG STOP(OAL=20") 2/1/2016 0.000 I.. 5,016.0 3,671.0 69.54 POGLM 2.81"C-LOCK 8 3"POGLM(5/16"OV/53"OAL) 2/1/2016 SHOCK AND SPARTEK GAUGE(101"OAL),EXT AVA SEAL BTM PKG STACK 9,743.0 3,828.5 91.86 FISH FISH IOST 3/11/2006,Lower portion of TRICO jet 3/22/2006 0.000 • pump assy,pushed down to 9743 RKB on 4/14/04 i•,..,km, Perforations&Slots 5.5'INNER LINER-WO;26.0- I;ia^-(I Shot 5,652.1 �I Dens Top(TVD) Btm(TVD) (shots/ Top(HKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 8,824.0. 11,850.0 3,839.1 3,818.6 WS D,1C- 6/8/2003 12.0 IPERF Slotted liner alternating 184 solid/slotted pipe joints `I Notes:General&Safety End Date Annotation 8/29/2008 NOTE:WORKOVER 9/5/2008 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 J [ . SURFACE;27.9-5,7980 FISH;9,743.0-tip- IPERF;6,624.0-11,650.0 IIILLINER 4.5"Slotted,5,6443 A 11,6850 1 • • 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 1C-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 1C-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. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMION • REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug 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 1- Plug Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: Crystal Seal MBE r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory r 203-089 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-23155-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25649,ADL 25650 KRU 1C-184 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 11890 feet Plugs(measured) None true vertical 3820 feet Junk(measured) 9743 Effective Depth measured 11885 feet Packer(measured) 5655 true vertical 3839 feet (true vertical) 3837 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 110 110 SURFACE 5770 10 5798 3853 5.5"INNER LINEF 5624 5 1/2 5652 3837 LINER 4.5"SLOT 6241 4 1/2 11885 3819 Perforation depth: Measured depth: 8824-11850 SOWED JAN 2 5 2U17 ECEIVED True Vertical Depth: 3839-3819 JUN 232016 Tubing(size,grade,MD,and ND) 3.5, L-80, 5568 MD, 3825 ND AOGCC Packers&SSSV(type,MD,and ND) PACKER-ZXP Liner Top Packer @ 5655 MD and 3837 ND SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): none Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 272 - 740 - 308 Subsequent to operation 232 - 265 - 285 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 F Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil F Gas F. WDSPL I— Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r- 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: 316-189 Contact John Peirce ta'�.265-6471 Email John.W.Peirce ct conocophillips.com Printed Name John Peirce Title Wells Engineer Signature 4&..r.„.....7 Phone:265-6471 Date /'a3 ij 6 (474- V7Z q/21/4- Form /2//GForm 10-404 Revised 5/2015 47-34 RBDMS VV JUN 2 3 2016 Submit Original Only • 1 C-190 to 1C-184 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 SD1C-184 ConoroPhi lips s . Well Attributes Max Angle D TD Alaska.inc. Wellbore API/UWI Field Name Wellbore Status ncl C) MD(ftKB) Act Btm(ftKB) pphlp ps ;" 500292315500 WEST SAK PROD 92.37 9,811.38 11,890.0 ".. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1C-/04,6/22/201610:40:44 AM SSSV:NONE 50 12/16/2013 Last WO: 11/14/2014 35.40 6/10/2003 Vertical schemato(actua0 Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:RESET JET PUMP,SLIPSTOP pproven 12/15/2015 HANGER;22.3 Etil Casing Strings tI:11 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread . f CONDUCTOR 16 15.062 30.0 110.0 110.0 62.50 H-40 _WELDED l ` .; Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...'Wt/Len(I...Grade Top Thread i t �,__ SURFACE 75/8 6.875 27.9 5,798.0 3,852.8 29.70 L-80 BTCM II Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread f , •a 5.5"INNER LINER-WO 5 1/2 5.000 28.0 5,652.1 3,837.0 15.50 L-80 BTCM Liner Details Nominal ID IMMO I Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 28.0 28.0 0.00 HANGER VETCO GRAY MANDREL HANGER w/Pup Joint 4.950 CONDUCTOR;30.0.110.0 5,553.0 3,822.9 81.18 XO Reducing Crossover 5"BTC Mod Box x 5 1/2"BTC Mod SCC 4.360 Box 5,555.3 3,823.3 81.23 SBE BAKER 80-40 SBE 4.000 5,573.4 3,826.0 81.62 XO Reducing Crossover 3 1/2"9 3#EUE8rd Pin x 5""BTC-M Box 2.970 5,588.8 3,828.1 81.95 SLEEVE-0 BAKER CMU SLIDING SLEEVE w/Nipple(open 2.810 CMU-12/6/14) 5,638.0 3,835.0 81.88 XO Enlarging -6'Crossover 3 1./2"IBTM Box x 5 1/2"17#Hydril 521 2.890 '. '' Pin SLIP STOP;5,014.5 x l". 5,641.3 3,835.5 81.87 SEAL ASSY 10'BULLET SEAL ASSEMBLY 5.75"Seal OD Hydril 4.800 I� 521(3.00'stick-up) SLEEVE-O;5,016.1 II Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len 0...Grade Top Thread POGLM;5,015.0 I. LINER 4.5"Sloped 4 1/2 3.865 5,644.3 11,885.0 3,819.4 12.60 L-80 NSCT Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl C) Item Des Com (in) 5,644.3 3,835.9 81.86 SLEEVE BAKER TIEBACK SLEEVE 5.750 5,655.3 3,837.5 81.83 PACKER ZXP LINER TOP PACKER 4.930 I5,663.3 3,838.6 81.81 NIPPLE RS NIPPLE 4.880 5,666.2 3,839.0 81.80 HANGER 'BAKER FLEX LOCK HYD TO LINER HANGER 4.860 GAUGE;5,071.3 4/111. 5,675.5 3,840.4- 81.77 XO BUSHING 'XO BUSHING 3.910 4 11,850.7 3,818.6 88.68 BUSHING BAKER PACKOFF BUSHING 3.958 Tubing Strings Tubing Description Stung Ma...ID(n) Top(ftKB) Set Depth(ft.. Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING WO-2014 31/2 2.992 22.3 5.568.4 3,8252 9.30 L-80 3.5 Completion Details Nominal ID as se Top(ftKB) Top(TVD)(ftKB) Top Incl C) Item Des Com (in) SEAL ASSY;5,548.3 1 22.3 22.3- 0.00 HANGER VETCO GRAY TUBING HANGER w/Pup Joint 2.875 V 5,016.2 3,671.1 69.54 SLEEVE-O BAKER CMU SLIDING SLEEVE w/DS NIPPLE(Opened 2.810 11 2-14-15) I 5,071.3 3,690.2 69.75 GAUGE SCHLUMBERGER DOWNHOLE GAUGE MANDREL w/ 3.000 NDPG gauge f 5,548.3 3,822.21 81.08 SEAL ASSY BAKER 80-40 GBH-22 LOCATOR SEAL ASSEMBLY 2.990 II (7 00'stick up) IIIOther In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) I Top(TVD) Top Incl Top(ftKB) (ftKB) (°) Des Corn Run Date ID lin) 5,014.5 3,670.5 69.52 SLIP STOP TBG STOP(OAL=20") 2/1/2016 0.000 I 5,016.0 3,671.0 69.54 POGLM 2.81"C-LOCK 8 3"POGLM(5/16"OV/53"DAL) 2/1/2016 SHOCK AND SPARTEK GAUGE(101"OAL),EXT AVA SEAL BTM PKG STACK 9,743.0 3,828.5 91.86 FISH FISH IOST 3/11/2006,Lower portion of TRICO jet 3/22/2006 0.000 11:.. pump assy,pushed down to 9743 RKB on 4/14/04 Perforations&Slots 55"INNER LINER-WO;28.0. IF. 56521 Shot 1I Top(ND) Btm(TVD) (Dens hots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Corn 8,824.0 11,850.0 3,839.1 3,818.6 WS D,1C- 6/8/2003 12.0 (PERF Slotted liner alternating - 184 solid/slotted pipe joints 4 , Notes:General&Safety End Date Annotation 8/29/2008 NOTE:WORKOVER 9/5/2008 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 SURFACE;27.9-5,788.0 6, FISH;9,743.0 • IPERF;8,824.0-11,850.0 i Im LINER 4.5"Slotted;5,644.3 ,. a 11,885.0 V OF T�� III • gift���y/�,4. THE STATE Alaska Oil and Gas , ` � � of e LAsKA Conservation Commission :; 5 A 4, �� 333 West Seventh Avenue ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ''*` Main: 907.279.1433 OFA ,.8p. Fax: 907.276.7542 www.aogcc.alaska.gov John Peirce SCANNED r ' Y 4 ,Fr Sr. Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1C-184 Permit to Drill Number: 203-089 Sundry Number: 316-189 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 Ay of March, 2016. RBDMS ,v MAR L 1 2016 • • RECEIVED . STATE OF ALASKA MAR 14 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS �eOGC �� 20 AAC 25.280 F `°� '�" 1.Type of Request: Abandon r Plug Perforations r Fracture Stimulate r Repair Well r Operations Shutdown '— Suspend Suspend 1 Perforate r Other Stimulate r Pull Tubing E Change Approved Program r Plug for Redrill f"`• Perforate New Pool r Re-enter Susp Well r Alter Casing r Other: Crystal Seal MBE J 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. ° Exploratory r Development 1' , 203-089 3.Address: 6.API Number: Stratigraphic r Service r P.O. Box 100360,Anchorage,Alaska 99510 50-029-23155-00 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 17i KRU 1C-184 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: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): • 11,890' ` 3840' 11,885' • 3839' 1462 None 9743' Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 110' 110' Surface 5,770' 10" 5,798' 3853' Liner Tie-Back 5624' 5.5" 5652' 3837' Production Liner 6241' 6.55" 11,885' 3839' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8824'-11850' . 3839'-3819' 3.5" L-80 5568' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Packer:ZXP Liner Top Packer SSSV:None . 5655'MD/3838'TVD 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory r Stratigraphic r Development ° Service r 14. Estimated Date for 15.Well Status after proposed work: 3/29/2016 Commencing Operations: OIL WINJ r WDSPL r Suspended r 16.Verbal Approval: Date: GAS r WAG r GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r 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(a)conocophillips.com Printed Name John Peirce @ 265-6471 Title Wells Engineer te../'4 tt-irr: 3/14/16 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 V Spacing Exception Required? Yes ❑ No d Subsequent Form Required: 10 —464 RBDMS LV MHIt c 1 2016 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 3_4, _/a ‘31-32:4";;:17 n 3)0‘. ,e5, ,,,4c Submit Form rm and Form 10-403 Revised 11/2015 OjrIpNaA ILIld for 12 months from the date of approval. Attachments in Duplicate • . 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 (PROF BHA to memory log down and up passes. Wait 2 hours. Log cool back pass. POOH with CT. RD CTU. �j i i KUP &OD 1C-184 ConocoPhilbps a Well Attribu Max Ang JID TD Alaska,I{1C. Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) ConeCOVhi(Sps 500292315500 WEST SAK PROD 92.37 9,811.38 11,890.0 y ° ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date 1C-184,3/11/20161147:03 AM SSSV:NONE 50 12/16/2013 Last WO: 11/14/2014 35.40 6/10/2003 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:RESET JET PUMP,SLIPSTOP pproven 12/15/2015 HANGER;22.3 °Il IE� Ilk Casing Strings .iCasing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread )(LIl ,. } CONDUCTOR 16 15.062_ 30.0 110.0 110.0 62.50 H-40 WELDED F I it Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread •^, ; SURFACE 7 5/8 6.875 27.9 5,798.0 3,852.8 29.70 L-80 BTCM tCasing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread 5.5"INNER LINER-WO 5 1/2 5.000 28.0 5,652.1 3,837.0 15.50 L-80 BTCM • • ill[w,Liner Details III Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) 28.0 28.0 0.00 HANGER VETCO GRAY MANDREL HANGER w/Pup Joint 4.950 1 5,553.0 3,822.9 81.18 XO Reducing Crossover 5"BTC Mod Box x 5 1/2"BTC Mod SCC 4.360 CONDUCTOR;30.0.110.0 Box 5,555.3 3,823.3 81.23 SBE BAKER 80-40 SBE 4.000 5,573.4 3,826.0 81.62 XO Reducing Crossover 3 1/2"9.3#EUE8rd Pin x 5""BTC-M Box 2.970 5,588.8 3,828.1 81.95 SLEEVE-O BAKER CMU SLIDING SLEEVE w/Nipple(open 2.810 CMU-12/6/14) 5,638.0 3,835.0 81.88 XO Enlarging 6'Crossover 3 122"IBTM Box x 5 1/2"17#Hyddl 521 2.890 Pin SLIP STOP;5,014.55,641.3 3,835.5 81.87 SEAL ASSY 10'BULLET SEAL ASSEMBLY 5.75"Seal OD Hydril 4.800 521(3.00'stick-up) SLEEVE-O;5,016.1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade -Top Thread POGLM;5,016.0 LINER 4.5"Slotted 4 1/2 3.865 5,644.3 11,885.0 3,819.4 12.60 L-80 NSCT Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 5,644.3 3,835.9 81.86 SLEEVE BAKER TIEBACK SLEEVE 5.750 5,655.3 3,837.5 81.83 PACKER ZXP LINER TOP PACKER 4.930 5,663.3 3,838.6 81.81 NIPPLE RS NIPPLE 4.880 5,666.2 3,839.0 81.80 HANGER BAKER FLEX LOCK HYD TO LINER HANGER 4.860 GAUGE;5,071.3 n - 5,675.5- 3,840.4 81.77 XO BUSHING XO BUSHING 3.910 II11,850.7 3,818.6 88.68 BUSHING BAKER PACKOFF BUSHING 3.958 I Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft.. Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING WO-2014 31/2 2.992 22.3 5.568.4 3.825.2 9.30 L-80 3.5 CI Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl C) Item Des Corn (in) SEAL ASSY;5,548.3 s`. 22.3 22.3 0.00 HANGER VETCO GRAY TUBING HANGER w/Pup Joint 2.875 5,016.2 3,671.1 69.54 SLEEVE-0 BAKER CMU SLIDING SLEEVE w/DS NIPPLE(Opened 2.810 2-14-15) 11 5,071.3 3,6902 69.75 GAUGE SCHLUMBERGER DOWNHOLE GAUGE MANDREL w/ 3.000 1 7 NDPG gauge 5,548.3 3,8222 81.08 SEAL ASSY BAKER 80-40 GBH-22 LOCATOR SEAL ASSEMBLY 2.990 1 (7.00'stick up) II Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 5,014.5 3,670.5 69.52 SLIP STOP TBG STOP(OAL=20") 2/1/2016 0.000 5,016.0 3,671.0 69.54 POGLM 2.81"C-LOCK 8 3"POGLM(5/16"OV/53"OAL) 2/1/2016 SHOCK AND SPARTEK GAUGE(101"OAL),EXT AVA SEAL BTM PKG STACK 9,743.0 3,828.5 91.86 FISH FISH IOST 3/11/2006,Lower portion of TR ICO jet 3/22/2006 0.000 2..: pump assN,pushed down to 9743 RKB on 4/14/04 Perforations&Slots 5.5°INNER LINER-W0;28.0- I I Shot 5,652.1 Dens I _ ) Top(TVD) Btm(TVD) (shots/ • •• Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 8,824.0 11,850.0 3,839.1 3,818.6 WS D,1C- 6/8/2003 12.0 (PERF Slotted liner alternating son 184 solid/slotted pipe joints �I, Notes:General&Safety End Date Annotation 8/29/2008 NOTE:WORKOVER , 9/5/2008 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 SURFACE;27.9-5,798.0-+119 -4 FISH;9,743.0 (PERF;8,824.0-11,850.0 h ....tLINER 4.5'Stoned;5,644.3_ 11,865.0 STATE OF ALASKA AIWA OIL AND GAS CONSERVATION COMARION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon E Plug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown E Performed: Suspend E Perforate I- Other Stimulate fl Alter Casing fl Change Approved Program Plug for Redrill r Perforate New Pool r Repair Well E Re-enter Susp Well E Other:Crystal Seal MBE F 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory E 203-089 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-23155-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25649, 25650 KRU 1C-184 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 11890 feet Plugs(measured) None true vertical 3840 feet Junk(measured) 9743 Effective Depth measured 11885 feet Packer(measured) 0 true vertical 3839 feet (true vertical) 0 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 110 110 0 0 SURFACE 5770 10 5798 3853 0 0 LINER TIE-BACK 5624 5.5 5652 3837 SLOTTED LINER 6241 6.55 11885 3839 0 0 Perforation depth: Measured depth: 8824'-11850' SCA RECEIVED True Vertical Depth: 3839'-3819' FEB 11 2016 Tubing(size,grade,MD,and TVD) 3.5, L-80, 5568 MD, 3825 TVD 9�/� COGC Packers&SSSV(type,MD,and ND) PACKER:ZXP LINER TOP PACKER@5655'MD,3838'TVD �„�I SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): none Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 43 - 356 - 273 Subsequent to operation 307 - 1 - 268 14.Attachments(required per 20 MC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory E Development F Service r Stratigraphic E Copies of Logs and Surveys Run r 16.Well Status after work: Oil F Gas E WDSPL Printed and Electronic Fracture Stimulation Data E GSTOR WINJ E WAG r GINJ E SUSP E 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: 315-084 Contact John Peirce(cD_265-6471 Email John.W.Peirce@conocophillips.com Printed Name John Peirce Title Wells Engineer Signature / J ,� Phone:265-6471 Date 2ff fiG Form 10-404 Revised 5/2015Z /,%b RBDMS Lk_ FEB 1 1 2016 Submit Original Only •• 1C-184 • DTTMSTA JOBTYP SUMMARYOPS PUMPING PUMPED 40BBL DSL DWN IA, PUMP 30BBL DSL DWN TBG TRACKING PUMP 3BBL METH DWN TEST, PUMP 3BBL METH DWN PRODUCTION LINE, 5BBL METH 9/20/15 ONLY DWN POWER FLUID LINE (JOB COMPLETE) ESP/ PULLED SLIPSTOP &3" RC JET PUMP (AR-1014/ 10B RATIO) @ 5016' RKB; BRUSH n' JET PUMP FLUSHED CMU &SET 2.81" C-LOCK W/3" RC JET PUMP (PH-1110/ 11A RATIO--HAS SILICON CARBIDE THROAT)W/EXT AVA SEAL BTM PKING STACK& SPARTEK GAUGE @ 9/23/15 5016' RKB: SET 3 1/2 SLIPSTOP ON TOP OF JET PUMP: CONFIRMED CIRCULATION THRU PUMPING FREEZE PROTECT IA, TBG WITH 62 BBLS DIESEL, PO, TEST AND POWER FLUID W/9 BBLS TRACKING METH. JOB COMPLETE ONLY 11/14/15 ESP/ PULLED SLIP STOP &2.81" C-LOCK W/3" RC JET PUMP (SER# PH-1110) @ 5016' RKB; RAN JET PUMP ISO SLEEVE IN CMU @ SAME & MITIA(2500 PASS); SET 2.81"C-LOCK W/3" RC JET PUMP 11A RATIO (SER#AR-1014)W/AVA STINGER SEALS ON BTM IN CMU @ 5016' RKB; SET 3 1/2" SLIP STOP ON TOP OF JET PUMP @ SAME. CONFIRM CIRCULATION THRU JET PUMP. 12/15/15 JOB COMPLETE. PUMPING FREEZE PROTECT TUBING,IA& FLOW LINES TRACKING PUMPED 3 BBLS METHANOL DOWN POWER FLUID FLOW LINE ONLY PUMPED 36 BBLS DIESEL DOWN IA PUMPED 24 BBLS DIESEL DOWN TBG PUMPED 2 BBLS METHANOL DOWN TEST F/L PUMPED 2 BBLS METHANOL DOWN PRODUCTION F/L 1/8/16 JOB COMPLETE 1/31/16 ESP/ PULLED TBG STOP @ 5015' RKB. IN PROGRESS. ESP/ PULLED 3" RC JET PUMP ( SN: PH-1110) @ 5016' RKB. PUMPED 40 BBLS DSL DOWN IA. JET PUMP SET 3" POGLM ON 2.81" C-LOCK @ 5016' RKB. UNABLE TO DRAW DOWN IA DUE TO LACK OF PRESSURE; PUMP 40 BBLS DSL DOWN TBG. SET TBG STOP ON POGLM @ 5015' RKB. 2/1/16 JOB COMPLETE. KUP OD • 1 C-184 ConocoPliillips .,s Well Attrib Max Angle&MD TD Alas ka_Ino Wellbore APW WI Field Name Wellbore Status Inc!(°) MD(kKB) Act Btm(ftKB) e500292315500 WEST SAK PROD 92.37 9,811.38 11,890.0 canocownkips-r , ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1C-184,2/1020166'52'39 AM SSSV:NONE 50 12/16/2013 Last WO: 11/14/2014 35.40 6/10/2003 Vertical schematic(actual) 'Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag. Rev Reason:RESET JET PUMP,SLIPSTOP pproven 12/15/2015 HANGER;22.3 wqf Casing Strings 1 'i Casing Description OD(in) ID(in) Top(kKB) Set Depth(kKB) Set Depth)T/D)..Wt/Len(I..Grade Top Thread CONDUCTOR 16 15.062 30.0 110.0 110.0 6250 H-40 WELDED YY, 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 27.9 5,798.0 3,852.8 29.70 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(kKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread �I 5 5"INNER wu Liner Details ER-WO 5 1/2 5.000 28.0 5,652.1 3,837.0 15.50 L-80 BTCM �,,.rr,,,,,.,...,..mi.,....i..,,n,,r.. .. g. Nominal ID lop(ftKB) Top(TVD)(ftKB) Top Intl(°) Item Des Corn (in) I 28.0 28.0 0.00 HANGER VETCO GRAY MANDREL HANGER w/Pup Joint 4.950 "I 5,553.0 3,822.9 81.18 XO Reducing Crossover 5"BTC Mod Box x 5 1/2"BTC Mod SCC 4.360 CONDUCTOR;30.0-110.0 , 1 Box 5,555.3 3,823.3 81.23 SBE BAKER 80-40 SBE 4.000 5,573.4 3,826.0 81.62 XO Reducing Crossover 3 1/2"9.38 EUE8rd Pin x 5""BTC-M Box 2.970 ;: 5,588.8 3,828.1 81.95 SLEEVE-0 BAKER CMU SLIDING SLEEVE w/Nipple(open 2.810 CMU-12/6/14) c 5,638.0 3,835.0 81.88 XO Enlarging 6'Crossover 3 112"IBTM Box x 5 1/2"17#Hydril 521 2.890 Pin SLIP STOP;5,014.5 int 5,641.3 3,835.5 81.87 SEAL ASSY 10'BULLET SEAL ASSEMBLY 5.75"Seal OD Hydril 4.800 521(3.00'stick-up) SLEEVE-0;5,018.1 11 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(kKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread PUMP;5,016.0 Cell LINER 4.5"Slotted 41/2 3.865 5,644.3 11,885.0 3,8194 12.60 L-80 NSCT Jr Liner Details 6, Nominal ID I Top(kKB) Top(TVD)(ftKB) Top Ind(°) Item Des Com (in) 5,644.3 3.835.9 81.86 SLEEVE BAKER TIEBACK SLEEVE 5.750 4 5,655.3 3,837.5 81.83 PACKER ZXP LINER TOP PACKER 4.930 11 5,663.3' 3,838.6 81.81 NIPPLE RS NIPPLE 4.880 5,6662 3,839.0 81.80 HANGER BAKER FLEX LOCK HYD TO LINER HANGER 4.860 GAUGE.5,071.3 I lb 5,675.5' 3,840.4 81.77 XO BUSHING XO BUSHING 3.910 11,850.7 3,818.6 88.68 BUSHING BAKER PACKOFF BUSHING 3.958 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING WO-2014 31/2 2.992 22.3 5.568.4 3,825.2 9.30 L-80 3.5 U, Completion Details Nominal ID e. Top(ftKB) Top(ND)(ftKB) Top Incl r) Item Des Com On) SEAL ASSY,5,548.322.3 22.3 0.00 HANGER VETCO GRAY TUBING HANGER w/Pup Joint 2.875 iA ' 'illif- 5,016.2 3,671.1 69.54 SLEEVE-O 'BAKER CMU SLIDING SLEEVE w/DS NIPPLE(Opened 2.810 2-14-15) N 5,071.3 3,690.2 69.75 GAUGE SCHLUMBERGER DOWNHOLE GAUGE MANDREL w/ 3.000 NDPG gauge 1. 5,548.3 3,822.2 81.08 SEAL ASSY BAKER 80-40 GBH-22 LOCATOR SEAL ASSEMBLY 2.990 I, (7.00'stick up) 1111 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 5,014.5 3,670.5 69.52 SLIP STOP 2.71"X 20"SLIPSTOP 12/15/2015 0.000 I 5,016.0 3,671.0 69.54 PUMP 3.0"JET PUMP(PH-1110,11A RATIO(SER#AR- 12/15/2015 1014),SILICON CARBIDE THROAT,EXT AVA SEAL PKG)SHOCK AND SPARTEK GAUGE(101" OAL),EXT AVA SEAL BTM PKG STACK 9,743.0 3,828.5 91.86 FISH FISH IOST 3/11/2006,Lower portion of TR ICO jet 3/22/2006 0.000 pump assy,pushed down to 9743 RKB on 4/14/04 5.5.INNER LINER-WO;28.0- [' ,� .-I Perforations&Slots 5,852.1 'I�l: Shot Dens " "- Top(ND) Btm(ND) (shots/ Top(ftKB) Btm(kKB) (ftKB) (ftKB) Zone Date ft) Type Com 8.824.0 11,850.0 3,839.1 3,818.6 WS D,1C- 6/8/2003 12.0 IPERF Slotted liner alternating imam. 184 solid/slotted pipe joints Mir Notes:General&Safety End Date Annotation 8/29/2008 NOTE.WORKOVER 9/512008 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 SURFACE;27.95,798.0-® L FISH;9,743.0 IPERF;8,824.0-11,850.0 I LINER 4.5'Slotted',5.644.3- a . 11,885 0 I�j/tv THE STATE Alaska Oil and Gas mw - ' Conservation Commission �=--- � ofALAS • == 333 West Seventh Avenue ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main. 907.279 1433 ALAS ' Fax' 907.276.7542 www.aogcc.alaska.gov John Peirce `; 2 6 :/.01',) Wells Engineer Q� ConocoPhillips Alaska, Inc. LO 3 Q C� P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1C-184 Sundry Number: 315-084 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, / �J Cathy r. Foerster Chair DATED thisy of February, 2015 Encl. STATE OF ALASKA AL A OIL AND GAS CONSERVATION COMM ON • APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool 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 r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. ConocoPhillips Alaska, Inc. Exploratory r Development r, 203-089 3.Address: Stratigraphic r Service r 6.API Number. P.O. Box 100360,Anchorage,Alaska 99510 50-029-23155-00 • 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 F / KRU 1C-184 • 9.Property Designation(Lease Number): 10.Field/Pool(s). ADL 25649,25650 - Kuparuk River Field/West Sak Oil Pool 11. .3Lfh PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft) Effective Depth ND(ft): Plugs(measured): Junk(measured): 11890 -3826-3? Io 11885' 3839' 4 none 9743' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 110' 110' SURFACE LINER TIE BACK 5770 7.625 5798' 3837; RECEIVED 5624 5.5 5652' SLOTTED LINER 6241 4.5 11885' 3839' FEB 13 2015 AOOCC Perforation Depth MD(ft). Perforation Depth ND(ft): Tubing Size: Tubing Grade. Tubing MD(ft): slotted liner from 8824'-11850' ‘ 3839'-3819' 3.5 L-80 5568 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft) PACKER-ZXP LINER TOP PACKER . MD=5655 TVD=3838 no SSSV 12.Attachments: Description Summary of Proposal F 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development F. 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 r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265-6471 Email: John.W.Peirce@conocophillips.com Printed Name John Peirce Title: Wells Engineer Signature r.,-1.,_!._ .-74 Phone:265-6471 Date 2/13/1S. Commission Use Only Sundry Numbe: 35?ti Conditions of approval: Notify Commission so that a representative may witness 31 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Spacing Exception Required? Yes ❑ No Er Subsequent Form Required: / C — 4c / APPROVED BY Approved by: , 47 �(1.u.......„ COMMISSIONER THE COMMISSION Date: 2--L 5— / proved application is valid tormonth trpm the date of approval. RA _� 12 Form 10-403(Revised 10/2012) oRIGINAL �'� V /S Submit Form and A chments in Duplicate z/I /i 5 '�� RBDMSIJ FEB Z 3 2015 • .4KUP PROD 1C-184 ConocoPhilIi ps Well Attributes Max Angle&MD TD ,, Alaska.(Ito. t _� Wellbore APIIUWI Field Name Wellbore Status ncl(") MD(ftKB) Act Btm(ftKB) ,,...,4,,,,,.f'i 500292315500 WEST SAK PROD 92.37 9,811.38 11,890.0 ".- Comment 1125(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1C-184,2/2/20159:32:04 AM SSSV:NONE 50 12/16/2013 Last WO: 11/14/2014 _ 35.40 6/10/2003 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:PULLED JET PUMP,CLOSED lehallf 2/2/2015 CMU HANGER;22.3 1 I [t`■` Casing Strings iIId)I�j F■ C sing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I..Grade Top Thread Il CONDUCTOR 16 15.062 30.0 110.0 110.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread �I r SURFACE 75/8 6.875 27.9 5,798.0 3,852.8 29.70 L-80 BTCM Casing Descnption OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread I 5.5"INNER LINER-WO 5 1/2 5.000 28.0 5,652.1 3,837.0 15.50 L-80 BTCM tor.Liner Details Nominal ID I Top(ftKB) Top(TVD)(MB) Top Incl r) Item Des Com (in) 28.0 28.0 0.00 HANGER VETCO GRAY MANDREL HANGER w/Pup Joint 4.950 a•-• 5,553.0 3,822.9 81.18 XO Reducing Crossover 5"BTC Mod Box x 5 1/2"BTC Mod SCC 4.360 CONDUCTOR;30.0.110.0 .1 Box 5,555.3" 3,823.3 81.23 SBE BAKER 80-40 SBE 4.000 5,573.4 3,826.0 81.62 XO Reducing Crossover 3 1/2"9.3#EUE8rd Pin x 5""BTC-M Box 2.970 5,588.8 3,828.1 81.95 SLEEVE-O BAKER CMU SLIDING SLEEVE w/Nipple(open 2.810 CMU-12/6/14) I 5,638.0' 3,835.0 81.88 XO Enlarging 6'Crossover 3 112"IBTM Box x 5 1/2"17#Hydril 521 2.890 Pin 5,641.3' 3,835.5 81.87 SEAL ASSY 10'BULLET SEAL ASSEMBLY 5.75"Seal OD Hydril 4.800 SLEEVE:5,016.1 +� 521(3.00'Stick-Up) Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread LINER 4.5"Slotted 4 12 3.865 5,644.3 11,885.0 3,819.4 12.60 L-80 NSCT a Liner Details Nominal ID II Top(ftKB) Top(ND)(ftKB) Top Incl r) Item Des Com (in) 5,644.3 3,835.9 81.86 SLEEVE BAKER TIEBACK SLEEVE 5.750 5,655.3 3,837.5 81.83 PACKER ZXP LINER TOP PACKER 4.930 GAUGE;5,071.3 4r. 5,663.3 3,838.6 81.81 NIPPLE RS NIPPLE 4.880 ll 5,666.2 3,839.0 81.80 HANGER BAKER FLEX LOCK HYD TO LINER HANGER 4.860 5,675.5 3,840.4 81.77 X0 BUSHING XO BUSHING 3.910 I11,850.7 3,818.6 88.68 BUSHING BAKER RACKOFF BUSHING 3.958 1 Tubing Strings v Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(113/ft) Grade Top Connection • TUBING WO-2014 312 2.992 22.3 5,568.4 3,825.2 930 L-80 3.5 Completion Details SEAL ASSY;5.548.3 i Nominal ID a Top(ftKB) Top(TVD)(ftKB) Top Incl r) Item Des Com (in) • 22.3 22.3 0.00 HANGER VETCO GRAY TUBING HANGER w/Pup Joint 2.875 1 5,016.2 3,671.1 69.54 SLEEVE BAKER CMU SLIDING SLEEVE w/DS NIPPLE CLOSED 2.810 2115 5,071.3 3,690.2 69.75 GAUGE SCHLUMBERGER DOWNHOLE GAUGE MANDREL w/ 3.000 NDPG gauge 5,548.3 3,822.2 81.08 SEAL ASSY BAKER 80-40 GBH-22 LOCATOR SEAL ASSEMBLY 2.990 (7.00'stick up) Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) ITop(TVD) Top Incl Top(ftKB) (ftKB) r) Des Com Run Date ID(in) I 9,743.0 3,828.5 91.86 FISH FISH IOST 3/11/2006,Lower portion of TRICO jet 3222006 0.000 pump assy,pushed down to 9743 RKB on 4/14/04 Perforations&Slots Shot Dens Top(TVD) Btm(THD) (shots/f 1 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 5.5'INNER LINER-WO;28.0- II 2 11'.. 8,824.0 11,850.0' 3,839.1 3,818.6 WS D,1C-184 6/8/2003 12.0 (PERF Slotted liner alternating 5,652.1 solid/slotted pipe joints IAI Notes:General&Safety End Date Annotation 8/29/2008 NOTE:WORKOVER ata 9/5/2008 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 SURFACE;279-5.798.0 A Au 1 - FISH,9,7430 (PERF;8.824.011,850.0 LINER 45"Slotted;5644.3- 11,885.0 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 IPROF. 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 ~ . 'bject Well History File C~ )er 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. ::l () ~ - Q <¿;: 9- Well History File Identifier Organizing (done) o Two-sided 1111111111111111111 ~can Needed 1 RESCAN ~olor Items: D Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) D Maps: o Other Items Scannable by a Large Scanner D Diskettes, No. D Other, NolType: D Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: BY: Helen_~ o Other:: Date: 8 :Jó 0.5 /s/ tyþ 0 ( I· 1111 I' .11 JI () Date:?) 8ì3 OS 151 yv~ NOTES: Project Proofing BY: Helen ~ Scanning Preparation BY: Helen ~ eX. X 30 = (¡9Ó I , + /J..{) = TOTAL PAGES fiG (Count doJs not in/lude cover sheet)V\A-D Date:<6' ~/oS' 151 1'1 . 1 Production Scanning Stage 1 Page Count from Scanned File: Có I (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES NO Date~,J.3 / OS: /s/ mp YES NO BY: Heie~ Stage 1 BY: If NO in stage 1, page(s) discrepancies were found: Helen Maria Date: /5/ II! 11111111111 1111I 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned 1 BY: Helen Maria Date: 151 Comments about this file: Quality Checked 1111111111111111111 WELL LOG -,---S-,.. • TRANSMITTAL • PROACTIVE DIAGNOSTIC SERVICES, INC. To: AOGCC Christine Mahnken 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 R o a d , ti$ Suite C r ,. JL . r , Anchorage, AK 99518 �) Fax: (907) 245 -8952 1 FC --r-6 1) Caliper Report 12- May -11 2T -14 1 Report / CD 50- 103 - 20061 -00 2) Caliper Report 17- May -11 1C-184 1 Report / CD 50-029-23155-00 Signed : tvt..........sL C Date : °o �w.� )NA ' l Print Name: 14.0,..J6,.....\_ Q�c,�.� `� PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 - 8951 FAx: (907)245 - 8952 E-MAIL : PDSANCHORAGECWMEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\ rchives\ Distribution\ TransmittalSheets \ConocoPhillips_Transmit.docx 1 • • VS Memory Multi- Finger Caliper Log Results Summary ' Company: ConocoPhillips Alaska, Inc. Well: 1C -184 Log Date: May 17, 2011 Field: Kuparuk (West Sak) Log No.: 6302 State: Alaska 1 Run No.: 1 API No.: 50-029-23155-00 Pipet Desc.: 2.875" 6.5 lb. L-80 EUE Top Log Intvll.: Surface Pipet Use: Tubing Bot. Log Intvll.: 5,091 Ft. (MD) Pipe2 Desc.: 3.5" 9.3 lb. Hydrill 511 Top Log Intvl2.: 5,091 Ft. (MD) Pipe2 Use: Tubing Bot. Log Intvl2.: 5,521 Ft. (MD) 1 Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS : 1 The caliper data is tied into the 2.875" x 3.5" cross -over at 5,071' (Driller's Depth). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage. 1 The caliper recordings indicate the 2.875" tubing appears to be in good condition, with the exception of a 20% wall penetration recorded in an isolated pit in joint 25 (812'). No other significant wall penetrations, areas of cross - sectional wall loss or 1.D. restrictions are recorded. The caliper recordings indicate slight buckling from — 1,080' to -- 2,130' and in the first full joint below GLM 1 (- 2,580'). 1 The caliper recordings indicate the 3.5" tubing logged appears to be in good condition with respect to corrosive and mechanical damage, with no significant wall penetrations, areas of cross sectional wall or I.D. restrictions recorded throughout the tubing logged. 1 2.875 "TUBING - MAXIMUM RECORDED WALL PENETRATIONS: Isolated Pitting ( 20 %) Jt. 25 @ 812 Ft. (MD) 1 No other significant wall penetrations are recorded. 2.875 "TUBING - MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: No significant cross - sectional wall loss (> 7 %) are recorded. 2.875 "TUBING - MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded. 3.5 "TUBING - MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations are recorded throughout the tubing logged. 3.5 "TUBING - MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: No significant cross - sectional wall loss (> 4 %) are recorded throughout the tubing logged. 3.5 "TUBING - MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the tubing logged. 1 I Field Engineer: D. Cain Analyst: C. Lucasan Witness: C. Fitzpatrick ?roActi :ve Diaonostic Services, Inc, / P.O. t�C_ •' 1369, Staff6fd, T 7=49 Phone: (23 � ; r 565-9085 : (2,81) 56 ,'369 E-mail: '1S co lit�(;c=. te.�>�, Gi ��3�s;:s) f d',,'. _���5 -; � , C -�, r'I_.. ,� ei fi lE'i7i +Jl V�OC�.. Uri G+'udhee Bay Held Office Phone: (007) 659-2307 Fax: (90 ) 659- 2314 1 .. ; c�3 O71 /14. I Correlation o g Recorded Damage to Borehol Profile I t Pipe Pipe 2 1 2.875 in (17.5' - 5090.6') Well: 1C-184 3.5 in (5090.6' - 5500.4') Field: Kuparuk (West Sak) Company: ConocoPhillips Alaska, Inc. I Country: USA Survey Date: May 17, 2011 I ■ Approx. Tool Deviation ■ Approx. Borehole Profile 1 20 - I 25 789 I 50 1588 4.\--N\ 75 2386 ET I GLM 1 -- S Z - t .. Q- I ° 100 3209 CI I 125 4006 I 150 _ 4805 GLM 2 1 — I 5091 111 9 14 5500 1 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) Bottom of Survey = 14 I I I • • I PDS Report Overview d14 ". Body Region Analysis I Well: 1C -184 Survey Date: May 17, 2011 Field: Kuparuk (West Sak) Tool Type: UW MFC 24 No. 211390 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 I Tubing: 2.875 ins 6.5 ppf L -80 EUE Analyst: C. Lucasan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 2.875 ins 6.5 ppf L -80 EUE 2.441 ins 2.875 ins 6.0 ins 6.0 ins I Penetration(% wall) Damage Profile (% wall) I 200 MI Penetration body Metal loss body 0 50 100 0 I 150 100 50 0 I 0 to 20 to 40to over 20% 40% 85% 85% 50 Number of joints analysed (total = 163) I 162 1 0 0 GLM 1 I Damage Configuration ( body ) 20 98 I 15 • 10 I 5 0 I Isolated General Line Other Hole / Pitting Corrosion Corrosion Damage Pos. Hole 148 GLM 2 I Number of joints damaged (total = 16) 16 0 0 0 0 Bottom of Survey = 156.4 I I I I • 0 PDS REPORT JOINT TABULATION SHEET I Pipe: 2.875 in 6.5 ppf L -80 EUE Well: 1C -184 Body Wall: 0.217 in Field: Kuparuk (West Sak) Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.441 in Country: USA Survey Date: May 17, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 0.1 17 0.03 0.03 12 7 2.45 Pup 1 I 1 20 0.04 0.02 11 1 2.40 2 51 0.03 0.02 11 1 2.41 3 83 0.03 0.02 11 , 2 2.39 ■ 4 116 0.04 0.03 12 2 2.38 I 5 6 148 0 0.02 11 2 2.39 180 0.03 0.03 12 2 2.39 7 212 0.03 0.03 12 2 2.40 8 244 0.03 0.03 12 2 2.40 I 9 276 0.03 0.03 12 2 2.39 10 308 0.03 0.02 10 2 2.41 • 11 340 0.04 0.03 12 3 2.40 Shallow Pitting. 12 372 0.03 0.03 12 3 2.38 I 13 405 0.03 0.03 12 2 2.38 14 437 0.03 0.03 15 3 2.39 I Shallow Pitting. • 15 468 0.03 0.03 12 2 2.39 15.1 500 0 0 0 0 2.31 DS Nipple 16 502 0.03 0.03 12 2 2.40 I / 17 533 0.04 0.03 12 2 2.39 18 566 0.03 0.03 12 2 2.39 Shallow Pitting. 19 598 0.03 0.03 13 2 2.39 Shallow Pitting. 20 629 0.03 0.02 11 2 2.39 I 21 661 0 0.02 9 2 2.41 II 22 693 0.04 0.03 13 2 2.40 Shallow Pitting. ■ 23 725 0.03 0.03 12 1 2.39 Shallow Pitting. 24 757 0.03 0.02 11 2 2.39 I 25 789 0.04 0.04 20 2 2.39 Isolated Pitting. 26 821 0.03 0.03 12 2 2.40 Shallow Pitting. • 27 853 0.03 0.02 11 2 2.40 28 885 0.03 0.03 12 2 2.38 Lt. Deposits. I 29 917 0.04 0.03 12 2 2.39 • 30 949 0.03 0.02 11 2 2.39 31 981 0.03 0.02 11 2 2.39 IN 32 1013 0.03 0.03 15 2 2.41 Shallow Pitting. 33 1045 0.03 0.02 11 2 2.40 I 34 1077 0.04 0.03 12 2 2.40 Slight Buckling. 35 1109 0.04 0.03 12 4 2.40 Shallow Line of Pits. Slight Buckling. is 36 1141 0.04 0.03 12 3 2.40 Slight Buckling. ■ 37 1173 0.04 0.03 12 2 2.39 Slight Buckling. I 38 1205 0.03 0.03 12 3 2.38 Slight Buckling. • 39 1237 0.04 0.02 11 2 2.39 Slight Buckling. ■ 40 1269 0.04 0.03 12 2 2.40 Shallow Pitting. Slight Buckling. ■ 41 1301 0.03 0.02 11 2 2.39 Slight Buckling. • I 42 1333 0.03 0.02 11 2 2.39 Slight Buckling. 43 1365 0.03 0.03 13 3 2.39 Shallow Pitting. Slight Buckling. • 44 1396 0.03 0.02 10 2 2.41 Slight Buckling. 45 1428 0.03 0.02 11 2 2.38 Lt. Deposits. Slight Buckling. • I 46 1461 0.03 0.02 11 2 2.40 Slight Buckling. 47 1492 0.04 0.03 13 3 2.41 Shallow Line of Pits. Slight Buckling. ■ 48 1523 0.04 0.02 11 2 2.41 Slight Buckling. I I Pe nerBo t1ti0n M etal Loss Body Page 1 I I PO T JOINT TABULATION SHEET P REPORT I Pipe: 2.875 in 6.5 ppf L -80 EUE Well: 1C-184 Body Wall: 0.217 in Field: Kuparuk (West Sak) Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.441 in Country: USA Survey Date: May 17, 2011 I Joint it. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments ( %wall) (Ins.) (Ins.) % (Ins.) 0 50 100 49 1556 0.05 0.03 13 4 2.39 Shallow Line of Pits. Slight Buckling. ■ I 50 1588 0.03 0.03 12 2 2.40 Slight Buckling. ■ 51 1620 0.04 0.03 12 1 2.38 Slight Buckling. ■ 52 1652 0 0.03 12 1 2.40 Slight Buckling. ■ 53 1684 0.04 0.04 17 3 2.39 Shallow Line of Pits. Slight Buckling. ■ I 54 1716 0.03 0.03 12 2 2.37 Lt. Deposits. Slight Buckling. ■ 55 1748 0.03 0.02 11 2 2.40 Slight Buckling. ■ 56 1779 0.04 0.03 12 2 2.41 Slight Buckling. ■ 57 1812 0.04 0.02 11 3 2.39 Slight Buckling. ■ I 58 1844 0.03 0.02 11 2 2.40 Slight Buckling. ■ 59 1875 0.04 0.03 12 2 2.41 Slight Buckling. ■ 60 1907 0.03 0.03 12 3 2.39 Slight Buckling. ■ 61 1939 0.04 0.04 17 3 2.37 Shallow Line of Pits. Lt. Deposits. Slight Bucklin•■ 62 1971 0.03 0.02 9 1 2.40 Slight Buckling. ■ I 63 2003 0.03 0.02 11 2 2.40 Slight Buckling. ■ 64 2035 0.03 0.03 12 3 2.39 Slight Buckling. ■ 65 2067 0.03 0.03 12 3 2.37 Lt. Deposits. Slight Buckling. • 66 2099 0.04 0.03 12 2 2.40 Slight Buckling. • I 67 2131 0.03 0.02 11 2 2.40 Slight Buckling. ■ 68 2163 0.03 0.02 11 2 2.40 ■ 69 2196 0.03 0.02 10 2 2.38 Lt. Deposits. ■ 70 2228 0.04 0.03 12 3 2.38 Lt. Deposits. • I 71 2258 0 0.02 11 1 2.39 ■ 72 2290 0.03 0.02 11 2 2.38 Lt. Deposits. • 73 2322 0 0.02 11 1 2.36 Lt. Deposits. ■ • 74 2354 0 0.03 12 2 2.37 Lt. Deposits. ■ I 75 2386 0.03 0.02 10 2 2.36 Lt. Deposits. ■ 76 2418 0.03 0.02 10 2 2.36 Lt. Deposits. • 77 2450 0.03 0.02 11 2 2.38 Lt. Deposits. ■ 78 2482 0.04 0.02 10 2 2.37 Lt. Deposits. ■ I 79 2514 0.04 0.03 12 2 2.37 Lt Deposits. • 79.1 2546 0 0.02 11 1 2.36 Pup Lt. Deposits. 7 9.2 2554 0 0 0 0 2.31 GLM 1 (Latch 5:00) ' 79.3 2561 0.03 0.02 10 2 2.36 Pup Lt. Deposits. ■ 80 2569 0.03 0.02 11 2 2.37 Lt. Deposits. Slight Buckling. • I 81 2602 0.03 0.02 10 2 2.37 Lt. Deposits. ■ 82 2633 0.03 0.03 12 2 2.35 Lt Deposits. ■ 83 2666 0.04 0.02 11 2 2.33 Lt. Deposits. ■ 84 2698 0.04 0.02 11 2 2.38 ■ I 85 2730 0.03 0.03 12 2 2.38 Lt. Deposits. • 86 2761 0.03 0.02 11 3 2.36 Lt. Deposits. • 87 2794 0.03 0.03 12 3 2.34 Lt Deposits. • 88 2826 0.03 0.02 11 2 2.37 Lt. Deposits. IN I 89 2858 0.04 0.02 11 2 2.35 Lt. Deposits. 90 2890 0.03 0.02 9 2 2.37 Lt. Deposits. 91 2922 0.04 0.02 11 2 2.38 ■ 92 2954 0.03 0.02 11 2 2.35 Lt. Deposits. is I 93 2986 0.04 0.02 11 2 2.38 ■ 94 3017 0.03 0.03 12 2 2.36 Lt. Deposits. ■ 95 3049 0.03 0.02 11 2 2.34 Lt Deposits. Penetration Bo I Metal Loss Body Page 2 I I PDS RE JOINT TABULATION SH • O I Pipe: 2.875 in 6.5 ppf L -80 EUE Well: 1C-184 Body Wall: 0.217 in Field: Kuparuk (West Sak) Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.441 in Country: USA Survey Date: May 17, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 96 3081 0.04 0.03 12 2 2.36 Lt. Deposits. • I 97 3113 0.03 0.02 11 2 2.33 Lt. Deposits. • 98 3145 0.03 0.03 12 4 2.33 Lt. Deposits. • 99 3177 0.03 0.02 11 2 2.34 Lt. Deposits. • 100 3209 0.04 0.03 12 2 2.35 Lt Deposits. ■ I 101 3241 0.04 0.02 11 2 2.37 Lt. Deposits. • 102 3273 0.04 0.03 12 2 2.34 Lt. Deposits. • 103 3305 0.03 0.02 10 2 2.37 Lt Deposits. ■ 104 3337 0.05 0.03 12 3 2.33 Li Deposits. ■ I 105 3369 0.04 0.03 12 3 2.35 Lt. Deposits. ■ 106 3401 0.04 0.03 12 3 2.36 Lt. Deposits. IN 3433 0.03 0.02 11 3 2.33 Lt. Deposits. ■ 108 3465 0.04 0.03 12 2 2.35 Lt. Deposits. • 109 3497 0.04 0.03 12 2 2.34 Lt. Deposits. • 110 3529 0.02 11 2 2.38 • 111 3561 0.02 11 3 2.36 Lt. Deposits. • 112 3593 0.02 8 2 2.37 Lt Deposits. 113 3624 03 0.02 11 2 2.35 Lt. Deposits. • I 114 3657 1 1 0.03 12 4 2.33 Lt. Deposits. • 115 3687 0.03 12 2 2.37 Lt. Deposits. • 116 3719 4 0.02 10 3 2.37 Lt. Deposits. • 117 3751 ! 1 0.03 12 2 2.36 Lt. Deposits. • I 118 3783 0.02 11 2 2.35 Lt. Deposits. • 119 3813 0.0 i 0.02 11 2 2.34 Lt. Deposits. • 120 3846 0.04 0.02 11 2 2.35 Lt. Deposits. • 121 3877 0.04 0.03 12 2 2.36 Lt. Deposits. • I 122 3910 0.03 0.02 9 2 2.37 Lt. Deposits. • 123 3941 0.03 0.02 11 2 2.34 Lt. Deposits. • 124 3974 0.03 0.02 11 2 2.37 Lt. Deposits. • 125 4006 0.03 0.03 12 2 2.35 Lt. Deposits. ■ I 126 4038 0.04 0.03 12 1 2.37 Lt. Deposits. ■ 127 4070 0 0.03 12 2 2.35 Lt. Deposits. • 128 4102 0.03 0.02 10 2 2.36 Lt. Deposits. • 129 4134 0.04 0.03 12 3 2.34 Lt. Deposits. ■ 4166 0.03 0.02 11 2 2.35 Lt. Deposits. ■ I 130 131 4198 0.04 0.03 12 2 2.35 Lt. Deposits. mu 132 4230 0.04 0.03 12 2 2.36 Lt. Deposits. mu 133 4262 0.04 0.02 9 2 2.38 134 4294 0.03 0.03 12 1 2.36 Lt. Deposits. ■ I 135 4326 0.03 0.03 12 2 2.35 Lt. Deposits. ■ 136 4358 0.03 0.02 10 2 2.38 Lt. Deposits. IN 4390 0.04 0.03 12 3 2.35 Lt. Deposits. ■ 138 4423 0.03 0.03 12 3 2.35 Lt. Deposits. • I 139 4455 0.04 0.03 12 2 2.38 Lt Deposits. ■ 140 4487 0.04 0.03 12 2 2.36 Lt. Deposits. 141 4519 0.03 0.01 7 2 2.37 Lt Deposits. 3 142 4551 0.03 0.03 12 2 2.34 Lt. Deposits. ■ I 143 4583 0.04 0.02 11 3 2.38 ■ 144 4615 0.03 0.03 12 1 2.36 Li Deposits. • 145 4647 0.04 0.02 10 3 2.36 Lt Deposits. I Penetration l Body I Meta Loss Body Page 3 I I • I PDS RE JOINT OINT TABULATION SHE I Pipe: 2.875 in 6.5 ppf L -80 EUE Well: 1C -184 Body Wall: 0.217 in Field: Kuparuk (West Sak) Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.441 in Country: USA Survey Date: May 17, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (°/0 wall) (Ins.) (Ins.) % (Ins.) 0 50 100 146 4679 0.03 0.03 12 3 2.37 Lt. Deposits. C I 147 4711 0.03 0.02 10 2 2.36 Lt. Deposits. 148 4743 0.03 0.02 11 3 2.37 Lt. Deposits. C 149 4774 0.03 0.02 11 2 2.38 Lt. Deposits. 150 4805 0.03 0.03 12 2 2.39 • I 151 4837 152 4870 0 0.02 11 1 2.36 Lt. Deposits. 0 0.02 11 1 2.39 • 153 4902 0.03 0.02 8 2 2.40 • II 154 4934 0.03 0.02 10 2 2.38 Lt. Deposits. • I 155 4966 0.03 0.03 12 1 2.39 • 155.1 4998 0.04 0.02 7 2 2.37 Pup Lt. Deposits. 155.2 5007 0 0 0 0 2.27 GLM 2 (Latch @ 10:30) • 155.3 5013 0.05 0.01 6 1 2.38 Pup 156 5021 0.03 0.02 9 2 2.36 Lt. Deposits. • I 156.1 5053 0.03 0.01 6 1 2.34 Pup Lt. Deposits. 156.2 5059 0 0 0 0 2.31 Sliding Sleeve 156.3 5066 0 0.02 10 2 2.38 Pup Lt. Deposits. • 156.4 5071 0 0 0 0 2.50 Cross -over I r ' Penet Metal Loss ation Body I I I I I I I I Page 4 I I • • I CLiRS., PDS Report Cross Sections I Well: 1C -184 Survey Date: May 17, 2011 Field: Kuparuk (West Sak) Tool Type: UW MFC 24 No. 211390 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 2.875 ins 6.5 ppf L -80 EUE Analyst: C. Lucasan 1 I Cross Section for Joint 25 at depth 811.539 ft Tool speed = 54 Nominal ID = 2.441 I Nominal OD = 2.875 Remaining wall area = 98% .- i Tool deviation = 7° j I / 1 \ I / 1 I I I Finger = 1 Penetration = 0.044 ins Isolated Pitting 0.04 ins. = 20% Wall Penetration HIGH SIDE = UP I I 1 1 I I 7 I • • I PDS Report Overview Cle,. Body Region Analysis I Well: 1C -184 Survey Date: May 17, 2011 Field: Kuparuk (West Sak) Tool Type: UW MFC 24 No. 211390 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 I Tubing: 3.5 ins 9.3 ppf Hydrill 511 — Analyst: C. Lucasan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. ' 3.5 ins 9.3 ppf Hydrill 511 2.992 ins 3.5 ins 6.0 ins 6.0 ins I Penetration(% wall) Damage Profile (% wall) I 20 ii El= Penetration body Me Metal loss body 0 50 100 1 I 15 10 I 5 . 0 r I 0 to 20 to 40 to over 20% 40% 85% 85% III Number of joints analysed (total = 14) . I 14 0 0 0 I Damage Configuration ( body) I I 11 1 I Isolated General Line Other Hole / Pitting Corrosion Corrosion Damage Pos. Hole I Number of . oints dama :ed total = 0 0 0 0 0 0 Bottom of Survey = 14 I I I I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf Hydrill 511 Well: 1C-184 Body Wall: 0.254 in Field: Kuparuk (West Sak) Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: May 17, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 1 5091 0 0.02 9 4 2.95 I 2 3 5122 0 0.02 9 2 2.97 5154 0.04 0.03 11 2 2.95 • • 4 5185 0 0.03 11 2 2.95 5 5216 0 0.02 9 2 2.94 I 6 5248 0.03 0.03 10 2 2.92 Lt. Deposits. 7 5279 0 0.03 10 1 2.95 8 5311 0.03 0.02 9 2 2.94 9 5342 0 0.03 ( 10 2 2.93 Lt. Deposits. • 10 5374 0 0.02 6 1 2.94 11 5405 0 0.03 11 4 2.90 Lt. Deposits. r • 12 5437 0 0.02 8 2 2.92 Lt. Deposits. C 13 5468 0 0.02 9 2 2.93 Lt. Deposits. 14 I 5500 0 0.02 9 2 2.94 • I Penetration Body Metal Loss Body I I I I I I I 1 I I Page 1 I I .,, KUP Conoco Phillips / g attributes ngle & MD TD Alaska. . Inc . W re APIIUWI Field Name Well Status PM MKS) 1 C -184 Act Btm (RKB) dips 500292315500 WEST SAK PROD 92.37 9,811.38 11,890.0 ConocoR Comment H28 (ppn) Date Annotation End Date K8-trd (ft) Rig Release Date - -- Well car90 - X184, 1/22rz011 s 48 16 AM SSSV: NIPPLE 60 7/10/2009 Last WO: 8/29/2008 35.40 6/10/2003 Schematic - Actual _ Annotation Depth OMB) End Date Annotation Last Mod... End Dote Last Tag: Rev Reason: Pull Pump Assy, Close CMU, set plug Imosbor 1/22/2011 Casing Strings Casing Description String 0... String ID ... Top (I1 B) Set Depth (f... Set Depth (TVD) ... String Wt... String... String Top Thnd HANGER. 22 \ AIL_ .- CONDUCTOR 16 15.062 30.0 110.0 110.0 62.50 H WELDED Casing Description String O_. Sting 10 _. Tap 91KB) Set Depth (L.. SA Depth (1VD) _ String Wt String... String Top Tird I/ SURFACE 7 5/8 6.875 27.9 5,798.0 3,852.6 29.70 L-80 BTCM Casing Description string 0... String ID _. Top (M03) Set Depth (L. Set Depth (1VD) _. wing Wt.. String._ String Top 11111 INNER LINER 5.5" 5 1/2 5.000 28.0 5,651.5 3,836.0 15.50 L-80 BTCM Liner Details Top Depth MB) MR Ind Noma- I ] Top B) ( R Descants= Oescrip Connie,! 1D 91* 1111 28.0 28.0 -0.66 HANGER Casing Mandrel Hanger wlpup 1 4.950 5,603.7 3,824.7 77.92 SBR 80-40 Casing Seal Bore w /5" BTC pin X pin 4.000 5,629.6 3,831.3 79.13 SLEEVE 27/8 ", CMD, w/2.312"B X profile 2.312 CONDUCTOR, 5,641.8 3,834.0' 79.70 SEAL ASSY Tie Back Seal Assembly w /2' space out 4.880 34110 Casing Description String 0... String ID _. Tap MB) Sri Depth (L_ Set An Depth (1VD) _ String Wt- String - String Top 1hd NIPPLE, 508 LINER Slatted 41/2 3.865 5,644.3 11,885.0 Details 3,819.4 12.60 L -80 NSCT Liner Details Top Depth )WD) Top incl I Top ti1Ka) Oge) C) Item Description Comment ID (in) 5,644.3 3,834.5 79.81 SLEEVE BAKER TIEBACK SLEEVE 5.750 5,655.3 3,836.7 80.33 PACKER ZXP LINER TOP PACKER 4.930 GAS LIFT. 5,663.3 3,838.2 80.70 NIPPLE RS NIPPLE 4.880 2 558 5,666.2 3,838.7 80.83 HANGER BAKER FLEX LOCK HYD TO LINER HANGER 4.860 I 5,675.5 3,840.3 81.27 XO BUSHING XO BUSHING 3.910 11,850.7 3,818.6 88.68 BUSHING BAKER PACKOFF BUSHING 3.958 G A S LET, T ubing Strings 5 .007 Tubing Description !String 0... String B _. Tap (NB) Set Depth (f._ Set Depth (TIM) ... String Wt... String... String Top Tied TUBING 27/8 2.440 22.3 5,617.8 3,828.4 6.50 L -80 EUE i Completion Details Top Depth SLEEVE-C. (TVD) Top Ind Need... 5,060 Top 91 B) MB) CI item Description Comment 113 (kg PLUG. 5560 22.3 22.3 -0.70 HANGER Tubing Hanger w/4 1/2 IBT x 2 7/8 &d X -O 2.875 506.3 5061 1.20 Cameo "DS" Nipple 2 7/8 °x 2.312" ( &d EUE - box X pin) 2.312 i 5,059.8 3,684.9 68.49 SLEEVE -C Baker Model "CMD" Sliding Sleeve w /Ruted Wire Protector Subs ea.end 2.313 (CLOSED 1/16/2011) 5,071.2 3,689.2 68.71 XO - Reducing Crossover Sub 27/8" 8rd EUE Box X 3 1/T Hydrill 511 pin 2.500 GAUGE. 5080 5,080.3 3, 692.7 68.87' GAUGE 'Gable Gauge /Carrier 3.000 5,599.0 3,823.4 77.70 SEAL ASSY SEAL ASSEMBLY 2.960 I Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVDI Top Inci Tap (NB) MB) 0 Description Comment Run Date ID tin) 5,059.8 3,684.9 68.49 PLUG 2.31 "XX PLUG(OAL=43") 1/16/2011 0.000 i 9,743.0 3,828.5 91.91 FISH FISH IOST 3/112006, Lower portion of TRICO jet pump 3/22/2006 0.000 assy, pushed down to 9743 RKB on 4/14/04 SEAL Assn, Perforations & Slots 5,599 Shot Top(IVO) Btrn(1VD) Dens I Top tithe) Blm 9118) (BKB) (RKB) zone Date (Mt- l pe Comment 8,824.0 11,850.0 3,839.1 3,818.6 WS D, 1C-184 6/8/2003 12.0 IPERF Slotted liner alternating solid/slotted pipe joints Notes: General & Safety Bid Date Annotation 9/5/2008 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 ( I. INNER LINER 55'. 285.651 Mandrel Details I Top Depth Top Port SURFACE. _. J • IrvDI kid OD Valve Latch Size op(MO3) 91KB) C) Make Model tin) Sera Type TIP. (in) (psi) Run Date Com... 1 2,557.8 2,294.7 51.85 CAMCO KBMG -M2 1 Gas Lift DMY BK 0.000 0.0 8/28/2008 2 5,006.6 3,667.8 69.78 CAMCO KBMG -M2 1 Gas Lift DMY BK 0.000 0.0 8/25/2008 II FISH, 9,743 IPERF, 1i 1 AIN 8,824 -11850 E- LINER 4 5" Sb 5,644-11585 TO. TD, 11,890 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ^ Repair Well ^~ Plug Perforations ^ Stimulate ^ Other ^ Alter Casing Q Pull Tubing ~ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COnOCOPhIIIIpS Alaska, InC. Development ~ Exploratory ^ 203-089 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23155-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 28' / 87' AMSL • 1 C-184 8. Property Designation: 10. Field/Pool(s): ADL 25649 & 25650 ~ Kuparuk River Field /West Sak Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 11890' feet true vertical 3840' feet Plugs (measured) Effective Depth measured 11885' feet Junk (measured) 9743' true vertical 3839' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR ,,,,, ~( 828' 16" " 110' 110' SURFACE ~~" 5770' 7-5/8" 5798' 3852' INNER C.Y~ 5624' 5.5" 5652' 3836' SLOTTED LINER 6241' 4.5" 11885' 3839' Perforation depth: Measured depth: 8824'-11850' true vertical depth: 3839'-3819' A~ E ~°~,a ~~~ {~1r' ~, ~ `pry Tubing (size, grade, and measured depth) 2-7/8", L-80, 5618' MD. Packers & SSSV (type & measured depth) Baker ZXP pkr @ 5x55' Camco'DS' nipple @ 506' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 106 64 35 -- 226 Subsequent to operation SI -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 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: 308-286 contact Brett Packer @ 265-6845 Printed Name Brett Packer Title Wells Engineer Signature -~- ~~ ~~ Phone: 265-6845 Date ~0~~,(7 1 1 Pre ared b Sharon All u -Orak 263-4612 ~y /b . Z.t~. G~ Form 10-404 Revised 04/2006 ~~ ~ ~ ~ ~ A ~ ~ _ ~~• ~~! ~~ ~~' ~~Q~ Submit Original Only t ~f' r1 ~1 ConocoPhilips Time Log & Summary ~~,~~~ ~Q~ ~~~fl~Fn9 Report _ ___ _ - Well Name: 1C-184 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 8/24/2008 12:00:00 PM Rig Release: 8/29/2008 12:00:00 AM -- ---- - -- Time Logs Date From To Dur _S. Degthi E Depth Phase Code __5ubcode T Comment 8/21 /2008 24 hr Summary Ran ESP completion on 1C-109, RDMO, moved rig toward 1G184 and got stuck, jacked up and shored up ri ,backed onto mats, re aired ad and laced mats. 12:00 13:00 1.00 MIRU MOVE MOB P Set up rig mats. Move rig back off of well (1C-109). Move rig mats over to 1C-184 and level up around well. MU containment (Handy Berm) around cellar. 13:00 15:00 2.00 MIRU MOVE MOB P Move rig T-mats and set up on new well. Standb time w/full crew 15:00 16:00 1.00 MIRU MOVE MOB T Moved rig down pad and turn corner, pad soft and gave out under front of rig. Jack up and shore up rig, back ri onto mats. 16:00 00:00 8.00 MIRU MOVE MOB T Wait for pad repair and rig mat placement, (stand time by with full crew . 8/22/2008 Pull out of hole with CAT. Move rig back on solid ground and wait on rig mats. Refill hole with gravel and repair ad. stand b with crew .Clean and aint ri . 00:00 12:00 12.00 MIRU MOVE MOB T Rolled forward approx 30' on mats and pad gave way, folded up rig mats, cont jack up and shore up rig, placing rig mats under rig. Pull out of hole with CAT. Move rig back on solid ground and waiting on rig mats. Refill hole with gravel and repair pad. stand b with crew). 12:00 00:00 12.00 MIRU MOVE MOB T Cont cleaning and painting rig while waiting on rig mats. (Stand by with crews 8/23/2008 Cleaned and painted on rig. Conducted multiple man down drill with all of day crew and Kuparuk Fire & Rescue. Recieved ri mats and laid out on ad to move ri over well. stand b with crew 00:00 07:00 7.00. MIRU MOVE MOB T Cont cleaning and painting rig while waiting on rig mats. (Standby time with full crew 07:00 08:30 1.50 MIRU RPCOM SFTY P Conducted Four Men Down Drill with all of day crew and Kuparuk Fire & Rescue. Standb time w/full crew 08:30 12:00 3.50 MIRU MOVE MOB T Cont cleaning and painting rig while waiting on rig mats. (Standby time w/full crew . 12:00 00:00 12.00 MIRU MOVE MOB T Cont cleaning and painting rig while waiting on rig mats. Recieved and unloaded mats, laid out double stacked over entire back corner of ad. Standb time with full crew -~ ---- Page 1 esf ~ ~~ Time Logs Date From To Dur S Depth E Depth P~h se_Code Subcode T Comment __ 8/24/2008 24 hrSummarv Moved rig ahead on mats to well site, RU and killed well, ND tree, NU BOP and started testing. 00:00 12:00 12.00 MIRU MOVE PSIT T Moved rig ahead on mats to well site, too soft, rig sinking. Backed up rig, laid out rig mats, tripple stacked under rig. Spot rig over well and level up. Accepted Nordic 3 Rig @ 1200hrs 8/24/2008.(Standby time w/f II r w . 12:00 13:00 1.00 MIRU MOVE RURD P Spot kill tank in containment and RU hardline. 13:00 14:00 1.00 COMPZ WELCTL OTHR P RU lubricator, pull BPV. 14:00 16:00 2.00 COMPZ WELCTI CIRC P Reverse circulate 210 bbls of 9.6 ppg Brine down annulus thru CMU taking returns to kill tank, @ 5 BPM, 400 psi. SD monitor well 0 press. well dead. 16:00 16:30 0.50 COMPZ WELCTL OTHR P B/D and RD circulating line, Set BPV. 16:30 18:30 2.00 COMPZ WELCTI NUND P ND tree, NU DSA and installed blankin lu . 18:30 23:30 5.00 COMPZ WELCTL NUND P NU 13 5/8" BOP and function test. 23:30 00:00 0.50 COMPZ WELCTL BOPE P Start testin BOPE. Witness of test waived by AOGCC Rep John Crisp at 12:00 8/24/08. 8/25/2008 Tested ROPE, decompleted well, rack and tally 5 1/2", RU and started running 5 1/2" inner casing. 00:00 03:00 3.00 COMPZ WELCTL BOPE P Cont testing BOPE at 250/3,000 psi 250/2,500 si annular . 03:00 04:00 1.00 COMPZ RPCOM RURD P Pull blanking plug and BPV, install isolation sleeve, install landing joint and MU top drive. BOLD's, pull hanger to floor, hanger unseated first attem tat 125K, u wt 95K. 04:00 06:00 2.00 5,643 5,600 COMPZ RPCOM CIRC P Circ 1 1/2 hole volumes with 9.6 ppg brine containing .6% safelube. ICP at 5 bpm = 220 psi, RU floor to POOH LD tubing and spool tech wire, cont rack and tall 145 ~nts 5 1/2" casin . 06:00 07:00 1.00 5,600 5,600 COMPZ RPCOM PULD P LD Hanger and Landing jt. Hang sheave for TECH wire. 07:00 19:00 12.00 5,600 0 COMPZ RPCOM PULD P m letion and spooling up TECH wire. Most jts crimped while backing threads out, retrieved all cannon clam s. 19:00 23:00 4.00 COMPZ RPCOM OTHR P Clean floor, unload 4 1/2" tubing and jewelery from shed, re-locate 5 1/2" casing in shed to disperse weight (rig settlin on ad . 23:00 00:00 1.00 0 200 COMPZ CASING RNCS P PJSM, PU and MU seal assembly, sliding sleeve, 80-40 seal bore, XO's and pups, PU and single in hole with , 5 1/2" casin to 200'. 8/26/2008 Run 5 1/2" inner string, ND BOP and change out casing/tubing head, NU BOP and test. Rih to recover storm acker 97'. P~~~ 2 cf 5 r~ ~~ Time Los _ __ 9. - - __ -- --- - - Date From To Dur S De th E. De th Phase Code Subcode T Comment _ 00:00 04:00 4.00 200 4,284 COMPZ CASING RNCS P Cont single in hole with 5 1/2" inner casing string, from 200' to 4,284' 100 'nts , u wt 85K -down wt 75K. 04:00 06:30 2.50 4,284 4,376 COMPZ WELCTL OTHR T CO elevators and PU storm packer, MU on 3 1/2" DP and RIH, attempt to set packer at 92', could not get packer to catch. POOH and inspect. Storm packer was for 7" casing instead of 7 5/8". 06:30 07:30 1.00 4,376 4,376 COMPZ WELCTL OTHR T Wait on replacement storm packer. 07:30 08:30 1.00 4,376 4,376 COMPZ WELCTL OTHR T Unload Storm Packer, MU 7 5/8' Storm Packer ,RIH & set @ 97'. Pull and lay down running tool. Test to 1000 si. 08:30 11:00 2.50 4,376 4,376 COMPZ WELCTL NUND P ND OPE. 11:00 14:30 3.50 4,376 4,376 COMPZ WELCTL EQRP P ND tubing head, NU new 5 1/2" Vetco Gra casin and tubin head. 14:30 19:00 4.50 4,376 4,376 COMPZ WELCTL EQRP P ND spool and bottom double gate. Set BOP stack back on new well head w/DSA and NU. 19:00 23:00 4.00 4,376 4,376 COMPZ WELCTL BOPE P Set blankin lu and body test w/ 2.875 x 5.5 VBR's w/ 5.5 test joint to 250/3000 psi. VBR's failed and 5.5 fixed rams installed. Body test was completed. Witnessing of test waived by Jeff Jones w/AOGCC @ 1930 hrs. 8/25/08. 23:00 00:00 1.00 4,376 4,376 COMPZ WELCTL OTHR P Held PJSM, MU Storm packer retreiving tool. Rih to recover storm acker 97'. 8/27/2008 Release Storm packer and Pooh and lay down same. Continue to RIH w/ 5.5" inner string. Locate and space out. Spot corrosion inhibited KW fluid between 5.5 & 7.625". Land 5.5 and RILDS. PT new IA to 2,500 psi for 30 minutes and chart. Rack and tally 3.5" and 2.875" TBG. Change 5.5" rams to 2.875" rams and test to 250/3,000 si. MU and Rih w/ com letion to 3,812'. 00:00 01:00 1.00 4,376 4,284 COMPZ WELCTL TRIP P POOH w/Storm Packer f/ 97'; 01:00 03:00 2.00 4,284 5,640 COMPZ CASING RNCS P Held PJSM, RIH w/ 5.5, 15.5# L-80 BTCM f/ 4,284' to 5640'. Up wt 97K Dwn wt. 77K. 03:00 06:00 3.00 5,640 COMPZ CASING RNCS P Locate and space out @ 5643' MD. Test seals down IA ten minutes, MU s ace out u s and casin han er. 06:00 07:00 1.00 COMPZ CASING CIRC P Reverse circulate 95 bbls corrosion inhibited 9.6 ppg brine (1% by volume CRW-132) to fill the 5 1/2" x 7 5/8" annulus. 07:00 07:30 0.50 COMPZ CASING OTHR P Land 5 1/2' casing. Up wt 97K dwon wt 77K. RILDS 07:30 09:00 1.50 COMPZ RPCOM DHEO P RU and test 7 5/8" x 5 1/2" casin to_ 2500 si f/30 min. ~.Y.... ~ P~~ 3 ~f 5 Time Logs _ _ _ _ _ Date From To Dur 5 De th E Depth Phase Code Subcode T_ Comment _ 09:00 11:30 2.50 COMPZ WELCTI BOPE P BO landin ~t and LD. Change pipe rams from 5 1/2" to 2 7/8" and test 250/3000 psi. Witnissing waived by Jeff Jones (AOGCC) @ 07:30 hrs 8/26/2008. To employ 2 7/8" rams and not the 3 1/2" rams for only 500' of 3 1!2" tubing on BHA was approved by Tom Maunder via Email 10:00 am 8/27/2008. 11:30 14:30 3.00 COMPZ RPCOM OTHR P Load 2 7/8" tubing in pipe shed, stra and drift to 2.347". 14:30 00:00 9.50 0 3,812 COMPZ RPCOM RCST P PU & MU Seal Assy. 16 jts 3 1/2" tubing, Ziebel Guage Carrier, and CMD sliding sleeve. Make up pressure guage in carrier and clamp to tubing as TIH to 3,812' MD. 60k u wt, 50k do wt. 8/28/2008 Continue to Rih f/ 3,812' to 5,619'?. Space out and Spot 50 bbls corrosion inhibited brine followed by 40 bbls KW fluid. Land hanger and RILDS. PT TBG and IA . Shear out SOV. Set TWC and ND BOPE and NU Tree. FP to 2,500'. RDMO 1C-184. Released Nordic ri 3 24:00 hrs on 8-28-08. 00:00 04:00 4.00 3,812 5,600 COMPZ RPCOM RCST P Continue to PU and Rih w/ 2.875" Completion f/ 3,812' to 5,600' MD 63 u wt, 50k do wt. 04:00 06:30 2.50 5,600 5,614 COMPZ RPCOM HOSO P Locate ands ace out no 0 5614' OKB, confirmed by pumping slow and lowering seals into SBE and pressure increase. MU space out pup and hanger. Make final splice in Zieble Pressure Gau a TEC wire. 06:30 07:00 0.50 5,614 COMPZ RPCOM CIRC P Pumped 50 bbls corrosion inhibited 9.6 ppg brine. (1% by volume CRW-132) @ 3 BPM w/420 psi. and chased with tubin volume to s ot. 07:00 07:30 0.50 COMPZ RPCOM HOSO P Drain stack, Land Hanger, 63K up wt, 50K dwon wt. RILDS 07:30 10:00 2.50 COMPZ RPCOM DHEQ T RU to test tubing and IA. With annulus open attempted to test_ tubing, not pressuring up. Tripple check all surface equipment and alignment. Full circulation both IA and tubin . 10:00 10:30 0.50 COMPZ RPCOM NUND T LD landing jt and remove isolation sleeve. 10:30 12:30 2.00 COMPZ RPCOM SLKL T PJSM, RU Haliburton slickline 12:30 16:00 3.50 COMPZ RPCOM SLKL T RIH w/slickline and set sto catcher 2608'. RIH w/kickover tool & pull _ SOV sheared . RIH w/dummy valve and set in GLM @ 2562'. RIH and ulled sto catcher. RD slickline FTage 4 rsf 5 Time Logs Date __ From To Dur _ _ S. De th E._[7e~th Phase `Code Subcode T __ _ Comment _ 16:00 98:00 2.00 COMPZ RPCOM DHEQ P RU and pressure upon tubing to 2000 psi, bled off to 1750 psi in 10 min. Check surface for leaks, repressure to 2000 psi and bled off to 1750 psi in 10 min. Bled off tubing, ressured IA to 3250 psi / 30 min, (chart). Bled off IA press. Pressured back upon tubing ~~si a~ me results bled off to 1750 psi in 10 min. 18:00 18:30 0.50 COMPZ RPCOM OTHR P LD Landing joint and set BPV 18:30 21:30 3.00 COMPZ RPCOM NUND P Nipple down BOPE 21:30 23:00 1.50 COMPZ RPCOM NUND P Nipple adapter and Tree 23:00 23:30 0.50 COMPZ RPCOM SFEO P Test Tree @ 250/5,000 psi. 23:30 00:00 0.50 COMPZ RPCOM OTHR P Set BPV and Secure Well. SITP = 0 psi, SttAP = 0 psi, SIOAP = 0 psi. Release Nordic Rig 3 @ 24:00 hrs on 8-28-08. ( F~~~e 5 cif s ~ ~ KUP ~ 1C-184 1 COtIOC li Ip5 ~ _ Well Attributes_ _ -- _ _ __ E6JitC"v;;, I wellbore APVUWI Feld Name Well Status ProNlnj Well Type '1lncl l°) MD(HKB) TD (maxi (H... ~~ .~ 500292315500 (WEST SAK (PROD. I 92.37 9,811.38 I 11,590.0 'Comment 'H2S (ppm) Data Annotation End Date KB-Grd (ft) (Rig Release Date - ... fie 16186 1017/200810 Well C 37 54 AM ( ^ le SSS f ~ N 100 PP 7/1/2008 (Last WO~ 8/29/2008 35.40 ~ 6/10/2003 _ O . : _ _ _______ _SChem_atLC-~ACWaI ~ t ~ De th H A Kel End Date P Ignnofation Entl Date L]SI I ay: Rev Reason PULL fBP FIST I, SE I JE I PUMP 10'712008 Casing Strings Casing Description ~Shing O... String lD.. . Top (HKB( 'Set Depth(f...'.Set Depth(TVD)... String Wt,..String Gr... Shing Top Thrd HANGER. 22- CONDUCTOR 16 15.062 0.0 110.0 1 110.0 C>250 H-40 WELDED ~- Casing Description Skiing 0... Skiing ID ... Top (HK81 'Set Depth (t._'Set Depth (TVD) ... String Wt... String Gr... String Top Thrd ,. SURFACE / 5/8 6.875 0.0 5,798.0 3,852.6 29.70 ' L-80 BTCM Casing Description 'String 0... String ID ... Top (HKB) 'Set Depth (f._;Set Depth (TVDI ... String W[... ~Stdng Gr... String Top Thrd INNER LINER 5.5" 51/2 5.000 '~ 0.0 ~ 5,651.5 ~ 3,836.0 '~. 15.50 ~ L-80 BTCM Liner Details _. Top Depth'. .. _.____.. __ _.._ __-'-__._ - (ND) Top , ftK8) Incl (°) ttam Desai t (TOP (kKB) ( pion Comment ID in _..-. _(_). 28.0 28.0 -0.66 HANGER _-._-. Casing Mandrel Hanger w/pupjt 4.95C CONDUCTOR 5,601.4 3,824.0 77.81 XO Cross-Over Sub, S 1/2", 15.5#, BTCM, box X 5" BTCM box 4.37C . ono __ 5,603.7 3,824.7 77.92 SBR 80-40 Casing Seal Bore w/5" BTC pin X pin __ 4.000 - - 5.622.5 3.829.6 78.80 XO Cross-Over Sub, 5"B7CM box X 2 7/8" EUE pin 2.39C NIPPLE, 506 ~ _._ -. 5,629.6 3,831.3 79.13 SLEEVE 2 7/8", CMD, w/2.312"B X profle - _ 2.312 - - 5,639.5 3,833.5 79.59 XO Cross-Over Sub, 2 7/8" EUE Mod box x 5 1/2" 17# New Vam Pin - 2.43L ( ~ ~~ ~ 5,641.8 3,834.0 79.70 SEAL ASSY Tie Back Seal Assembly w/ 2' space out 4.88C GAS LIFT, '~; ' } Casing Description (String O... (String lD .. .TOp (HKB) (Set Depth(t...Set Depth(TVDj...String Wt...Stdng Gr... (String Top Thrd 2'550 ,. LINER 4_S"Slotted 41/2 3.865 5.644.3 11.885.0 3,8194 12.60 L-80 ~ NSCT FLEX LOCK HYD SLEEVE, 5,060 - PVMP, 5,062- - -- - GAJGE 5080 -- SEAL ASSY, s,ss9 INNER LINER 5.5'.0-5,651 SURFACE, _ 0-5,]98 r FISH, 9,]43 - --- IPERF. 6,621-11,850 11.850.71 3,818.61 88.68IBUSHING (BAKER PACKOFF BUSHING tubing Strings - ---- - ubing Description Sbing 0... (String ID ...TOp (ft KB) Set Dnpth (f... Sat Dopth {TVD)... (String Wt...Stdng Gr... (String Top Completion De Top Depth tails_ ', (ND) '~. Top T~ (HKB) I (HK8) 1, Incl (°) Kam Description Comment _ _ _ ID (in) 22.3 22.3 ~, -0.70 HANGER Tubing Hangerw/41/2IBTx27l88rdX-0 2.875 506.2 506.1 I ' 1.20 NIPPLE _- __ -_ Camco "DS" Nipple 2 7/8" x 2.312" (8rd EUE - box X pin) 2.312 -5,059.Si 3,684 9 i 68.49 SLEEVE Baker Model "CMD" Sliding Sleeve w/Fluted Wire Protector Subs ea.end 2.321 5,0712' 3,689.2 1 68.77 XO -Reducing Crossover Sub 2 7/8" 8rd EUE Box X 3 1/2" Hyddll 511 pin 2.500 5,080-3 3,692.7 68.87 GAUGE Leble Gauge/Cartier 3.000 ( 5,599.0 3,823.4 77.70 SEAL ASSY SEAL ASSEMBLY _-_ 2.960 __ Other_In Hole (Wireline retrievabl Top Depth ~. e plugs, valves, pumps, fish, etc.) ..- --' __ _-.. (ND) Top Top (HKB) (HKB( Incl (°) i Description Comment Run Date ID (in) 5,042.0 3,677.9 68.16 PUMP 2.313" X-LOCK w/2.5" RC JET SUMP (SN CP-1146), 10-B 10/6/2008 0.000 RATIO, #10 NOZZLE, #11 THROAT. 2.5" SLIPSTOP SET ON TOP OF X-LOCK @ 5059' 9,743.0 3,828.5 91.91IFISH FISH IOST 3/11/2006, Lower portion of 7RIC0 jet pump assy, 3/22/2006 0.000 pushetl down to 9743 RKB on 4/14/04 Perforations '~ _ _ 'Shot '~ Top (ND) Btm (TVD) ~ Dens Top (RKB) Btrn (HKB) (kKB) 1 (HKB) Zone Data ~ (ski'- T pe Comment 8,824-0 11850.0, 3,839.11, 3,818.6'WS D, 1C-184 6/8/2003 .12.0 IPERF Slotted liner aRemating solid/slotted _ _ j Pipe joints 1 Notes General 8 Safe ena Date a,notatinn 9/5/2008 NO iE: VIEW SCHEMATIC w/Alaska Schematic9.0 Mandrel Details - '1 Top Deplh Top ~ - -- - - - Porl (TVD) Incl OD Valve Latch Size TRO Run SN ToP (kKB) (ttKel (°) i Make Motlel (inl Serv Type Type (in) (psi) Cam... Run Dab 1 2,557.8 2,294.7151.85 CAMCO KBMG-M2 1 Gas Lift DMY BK O 0.0 &28/2008 2 5,006.6', 3,667.8169.78 CAMCO KBMG-M2 1 Gas LiH (DMY BK _0~ 0.0 - - 8/25/2008 LINER 6.5' SbIIed. J 5,614-11.885 TD. 11,890 1C-184 (203-089) Maunder, Thomas E (DOA) Page 1 of 1 From: Maunder, Thomas E (DOA) Sent: Wednesday, August 27, 2008 10:01 AM To: 'Packer, Brett B' Subject: RE: 1 C-184 (203-089) Brett, You have accurately captured our conversation that it is acceptable to just employ 2-718" rams. This approval applies to this well opera#ion only and should not be considered as an unlimited approval. Tom Maunder, PE AOGCC From: Packer, Brett B [mailto:J.Brett.Packer@eonocophillips.com] Sent: Wednesday, August 27, 2008 9:37 AM To: Maunder, Thomas E (DOA) ~~;~.~~~ AU~a ,'. ~ ~~OS Subject: iC-184 (203-089) ~`~' Tom, To summarize our conversation this morning regarding 1C-184 (PTD# 203-089, Sundry # 308-286), we have just landed the 5.5" inner casing string and are getting ready to run the completion. Our current BOP configuration is {1) set of 5.5" rams, blind rams, and annular preventer. We have only a single pipe ram configuration due to BOP clearance under the rig floor and the height of the wellhead once we added the additional casing spool. Only a single set of pipe rams is required since the MASP is < 3000 psi. We currently have a plug set downhole in the liner at 5690' and 9.6 ppg brine in the hale, well above the 7.4 ppg K1NF needed. The completion to be run consists of a 3.5" seal assembly and 16 joints 0500') of 3.5" tubing which is then crossed over to 5000 ft of 2-7/8" tubing to surface. Our initial concern was whether we needed to have 3.5" rams in the BOP stack for running the bottom 500' of 3.5" tubing, or whether that 500' could be considered a BHA and we could just install 2-7I8" rams since the 2-718" is the majority of the tubing string. You indicated this morning that it would be fine to install just the 2-7/8" rams for the running of the completion. The rig supervisors would like to have an email confirmation to include in #heir files approving this ram configuration, so if you could please confirm this with a simple response to this email, 1 will forward it to them. Thanks! ,7. Brett Packer ~Drilrirag ~'WetZs 4Narf~ver Engineer ~Work# 265-6845 Ce[C# 230-8377 8/27/2008 1C-184 Ram configuration • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, August 20, 2008 4:28 PM To: 'Packer, Brett B' Subject: RE: 1C-184 (203-089) Ram configuration Page 1 of 2 Brett, You are correct that with a MASP < 3000 psi that the requirement is for 1 set of pipe rams. Sorry about the 3500 psi test note. I forgot that this is a WS well. When WS wells are drilled, the BOP test requirement is for 3000 psi and that is appropriate for WS workovers as well. Call or message with any questions. Also, please include the permit number in the subject line. It helps for filing Tom Maunder, PE AOGCC From: Packer, Brett B [mailto:].Brett.Packer@conocophillips.com] Sent: Wednesday, August 20, 2008 4:21 PM To: Maunder, Thomas E (DOA) Subject: 1C-184 Ram configuration dO~NN~~ BUG ~ ~ 2008 Tom, I tried calling you several times this afternoon, with no answer, so I hope you were able to get away from the office and enjoy this sunny day. So instead, I thought I'd email this question regarding 1C-184 and the Sundry that was just approved. This workover involves installing an additional 5.5" inner casing string, thus requiring modifications to the wellhead to add an additional casing spool. I was just notified by the rig that once we make the wellhead modifications, the wellhead will be 18".taller and we won't have room for the BOP stack in it's current configuration. Originally, we had planned to use two sets of pipe rams in the 13-5/8" stack because that has just become standard practice regardless of whether two pipe rams are required or not. But since this well falls in the category of < 3000 psi MASP {actual is 1081 psi), we are only required to have one set of pipe rams, one set of blind rams, and an annular preventer. So we decided to drop one set of pipe rams which will give us an additional 2 feet of clearance and allow us to make the wellhead modifications. When I received the Sundry application back today, it is stated that we need to test the BOP to 3500 psi. Does this 3500 psi BOP test affect how we have to configure our stack, considering we only planned to run one set of pipe rams based on the MASP less than 3000 psi? This welt has extremely law pressure (EMW = 7.4 ppg) and cannot flow to surface without some means of artificial lift. We have a plug set downhale isolating us from the formation and we'll have KWF in the hole during the workover, so I must ask, what is the reasoning behind testing to 3500 psi vs. 3000 psi? This is the first time we've seen this request on a West Sak well. We don't have any problem testing to 3500 psi, but if that means we have to have two sets of pipe rams, then we will not be able to complete this workover as planned We are planning on moving to this well tomorrow afternoon, so I look forward to your response. Thanks! ,~ Brett hacker 8/24/2008 • ~T ~y Brett Packer Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 • SldR,4li 9~.4LIPl, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Field: Kuparuk River 1C-184 Sundry Number: 308-286 ~~3 -' ~ $ 9 Dear Mr. Packer: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~ _. ~ - ~~ y, r~ ~ / ~ .. ~~ Daniel T. Seamount, Jr. Chair DATED this~~day of August, 2008 Encl. ,~„'.-- ~ ConocoPh i I I i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 13, 2008 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: r: ?~!~._ . ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the West Sak Well 1C-184 (PTD# 203-089). Producing well 1C-184 was drilled and completed in June 2003. It was first brought online in September 2003 as a West Sak D-sand surface powered jet-pump producer. In September 2005, it was temporarily converted to gas lift to confirm the water cut and determine how the well would flow on gas lift. It remained on gas lift for two weeks at which time it was converted back to jet pump service. A recent discovery of severe casing corrosion in two Tarn jet-pumped wells had raised concern for the possibility of similar corrosion issues in West Sak jet-pumped wells. 1C-184 is one of the original four West Sak single casing jet-pumped wells along with 1C-135, 1C-170 and 1C-178. Subsequent to the corrosion discovery at Tarn, apro-active workover on 1C-170 to pull the tubing and inspect the casing revealed that we are not seeing the same corrosion issues similar to what was seen at Tarn. Nevertheless, new internal policy now dictates that we must have two barriers between any energized fluid (power fluid or gas lift) and the formation. Thus, the original four West Sak single casing jet-pumped wells were shut-in until such time that an inner string of 5'/2" casing can be installed within the 75/8" surface casing. The workover on 1C-135 was successfully completed in July 2008 and 1C-184 is to be the second of the four wells to be worked over in this fashion. The proposed workover will pull the 3'/2' 8rd EUE tubing, install an inner string of 5'/z" BTCM casing and re-complete the well with a 2'/8" 8rd EUE jet-pump/gas-lift completion. This Sundry is intended to document the proposed change to the casing structure as well as request approval to workover the well. The current SBHP is 1400 psi as measured on 8!11/08. This equates to an EMW of 7.4 ppg at mid-pert. An IBP will be set in the liner below the packer to isolate the well from the formation and 9.6 ppg brine will be used as a workover fluid. Attached is a proposed schematic along with a general workover procedure. If you have any questions or require any further information, please contact me at 265-6845. Sincerely, 'r,r;'% .. ~ ;,'~ p,' Brett Packer Wells Engineer CPAI Drilling and Wells ~ ~ _ ~ p~~ STATE OF ALASKA . vd 1 v ALASKA OIL AND GAS CONSERVATION COMMISSION r, !' ^ ~ .~. ~`~;;J ;~, .., ~~ APPLICATION FOR SUNDRY APPROVAL a _., 20 AAC 25.280 ~:,; ; ' , ', 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing Q Repair well ^~ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing Q Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Exploratory ^ 203-089 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23155-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? Y@S ^ NO ^~ 1C-184 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25649 & 25650 RKB 28' / 87' AMSL Kuparuk River Field /West Sak Oil Pool 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11890' 3840' 11885' 3839' 9743' Casing Length Size MD TVD Burst Collapse CONDUCTOR 110' 16" 110' 110' SURFACE 5770' 7-5/8" 5798' 3852' LINER 6052' 4-1 /2" 11885' 3839' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8824'-11890' 3839'-3840' 4-1/2" L-80 5643' Packers and SSSV Type: Packers and SSSV MD (ft) Baker ZXP pkr 5654' Camco 'DB' nipple 523' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ~ Development ^~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat August 20, 2008 Oil ^~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brett Packer @ 265-6845 Printed Name Brett Packer Title: Wells Engineer ~. ~; ~~ ~' ' `~'~ D ~ ~` ~ _ ~ Signature ~- Phone 265-6845 o ate ~ Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness BCo Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ ,~~ et~~~t~ ~~1®~'~ Other: 3~~~QS ~ ~~~ ~ S~ Subsequent Form Required: ~j~.~ ~• ~ ~~ ~~~ ~ ZQ~S `~ v s~ ~~: ~ APPROVED BY 1 Approved b r ,'' - - _ -- COMMISSIONER THE COMMISSION Date: Form 103 Revised 06/200 t ~ l ~ /- ~ t Submit in Duplicate • West Sak 1 C-184 • General Workover Procedure PTD 203-089 Pre-Riq Work 1. Prepare location for arrival of Workover Rig. (DONE) 2. Pull jet-pump, confirm CMU is open. (DONE) 3. Run caliper log from CMU at 7083' RKB to surface. (DONE) 4. Obtain SBHP. (DONE) 5. Set 2%8" IBP in liner at 5695' RKB below the ZXP packer. Perform a pressure test and drawdown test on the IBP. 6. Set BPV. General Workover Procedure 1. Verify Sundry approval acquired. 2. MIRU Nordic #3. 3. Pull BPV. Load hole with 9.6 ppg brine. Set BPV. ND tree. 3~~~~ 4. NU BOPE. Install blanking plug. Pressure test BOPE to 250/~si ~'~~L~- • The current SBHP is 1400 psi at 5012' RKB (3669' TVD) as measured on 8/11/08 which equates to 7.4 ppg at mid-pert depth of 3760' TVD. An IBP will be set in the liner to isolate the formation. Kill weight fluid is expected to be 7.4 ppg at a mid-perf depth of 3830' TVD. 9.6 ppg brine will be used during this workover. The calculated maximum anticipated surface pressure assuming a gradient of 0.1 psi/ft is 1081 psi.) 5. Pull 3'h" tubing. 6. With 2000' of tubing pulled, set storm packer at +/-100'. ND BOP and tubing head. Install new Vetco Gray 11 ", 5M casing spool to accommodate the new 5'/2" casing and new 11", 5M tubing head for the new 3'/i" IBTM tubing. ressure test packoff to 5000 psi. NU BOP and pressure test below blind ram to 250/3 psi. ~Sp ~ ~ ~ 7. Pull storm packer. Continue POOH laying down 3%" completion. 8. RIH w/ 5'h" BTCM inner casing string. Sting into SBE, mark pipe, pull up and circulate in corrosion inhibited 9.6 ppg brine. Space out and land 5'h" casing. RILDS. PT 5'h" x 75/8" annulus to 2500 psi. 9. RIH w/ 2%8" 8rd EUE tubing. Sting into SBE, mark pipe, pull up and circulate in corrosion inhibited 9.6 ppg brine. Space out and land 2'/8" completion. RILDS. Pressure test IA to 3500 psi. Shear the SOV. 10. Set 2-way check. ND BOPE. NU tree and pressure test to 5000 psi. 11. Pull 2-way check, freeze protect with diesel. 12. Set BPV and RDMO workover rig Post-Riq Work 1. Pull BPV 2. RU Slicktine: Set catcher sub below bottom GLM. Pull the SOV and replace w/ a DV. Retrieve the catcher sub. 3. RU CTU: Open lower CMU and load OA with diesel freeze protect. Close lower CMU. Pull IBP at 5695' RKB. Set jet-pump in upper CMU. 4. Return to production. ._ ,~ 1~'~f~ 2008 RWO PROPOSED COMPLETION API: 500292315500 PTD: 203-089 Wellhead: Gray Horiz X-mas Tree: 4-1/8", 5K psi Lift Threads: 4.909" MCA BPV: 4" 'H' . Tubing = 2'/8', 6.5 ppf, L-80, 8rd EUE • 2.313" DS-nipple at 500' • Ziebel Downhole Gauge • Baker 2%" CMD w/ 2.313" X profile at XXXX' • Baker locator w/ 17' seal assy. at XXXX' • Casing = 5%",15.5 ppf, L-80, BTCM. • Crossover from 5'/",15.5# BTCM. • SBE • Baker 2%a" CMD w/ 2.313" X profile at XXXX' • Baker 80-40 Locator w/ 10' seal assy. (5.75" OD) at 5639' MD Well: 1 C-184 Conductor: 16", 62.5#, H-40 at 110' Surface Casino: 7.625", 29.7#, L-80 at 5798' New Inner Casino: 5.5", 15.5#, L-80 BTCM Perforated Liner: 4.5", 12.6#, L-80 NSCT to 11,885 Sliding sleeve for jet pump. Ziebel Downhole Gauge/Carrier Crossover to 5.5" BTCM 20' SBE CMD Tie Back Sleeve ~ ZXP PKR O O O O O O O 10 O Directional: O Max Incline: 92.4° @ 9811'. O Max Dogleg: 6.3° @ 5499' O Fill at: TD: 11,890' RKB Gas Lift Mandrels: MD TVD Tvpe 2581 2300 2-7/8" KBMG, 1" 5000 3662 2-7/8" KBMG, 1" Last Updated: 6-Aug-08 Updated by: JBP --- 1~ ~ Ctall~~~a~~lillps Alaska, Inc. 1C-184 TUBING ' API: 500292315500 Well T e: PROD (a~43 SSSV T e: NIPPLE Ori Com letion: 6/10/2003 OD:4.500, Annular Fluid: Last W/O: ID:3.958) Reference Lo : 28' RKB Ref Lo Date: ^^^ u ^ PBR/SBR (5639-5643, OD:6.380) TIE BACK (5643-5654, OD:6.390) PACKER (5654-5662, OD:6.550) NIP (5662-5665, OD:6.050) Liner Hanger (5665-5675, OD:6.450) PUP (5680-8824, OD:4.500) Perf (882411890) SLOTTED LINER (5838-11690, OD:4.500, _~ 1 1 1 ~, ~ - ~ <:~ ^ ~ - ,I '' ............. KRU 1 C-184 Rev 1 ~ Last Tag Date I ~~ Max Hole Anale• 192 deq ~ 9811.. I - _ I I Casing String -ALL STRINGS ~I~escription Size Top Bottom TVD Wt Grade Thread SUF.FaCE ~ 7.625 G S ~h'd 352 L5, 70 L-°0 BTCM _ CONDUCTOR ± 16.000 _ 0 110 110 - 62 SO H-40 WELDED -_ _ __ Casing String -SLOTTED 1_INER (Alternating its blanklslotted _ pipe wl12-1" round ho Description Size Top Botto TVD Wt Grade Thread s~oTFED urJER a roo ~ m 1 ie~o i 1s~o 1 ~ 5u ~-ao rus~T Tubing String - TUSING'' _ __ ' Size Top_ Bottom TVD Wt Grade Thread 4.500 0 5643 3536 12 60 L-50 IBT Perforations Summary terval ND Zone talus Ft SPF Date e omment Q ~ `." ~ 3839 - 11390 W`= D 3065 ,~ r, 5;003 IF'ERF er wi12 - 1 round l holey lo nt Gas Lift MandrelsNalves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 2718 2394 CAMCO KBG-2 DMY 1.0 BK-5 0.000 0 4/17/2006 2 4926 3638 CAMCO IOther (plugs, equip., De th TVD T e KBG-2 _ DMV 1 A BK 0 QQO 0 8/8/2003 etc.) -LINER DETAIL _ - _ __ Descri lion 1 ID 5643 3836 TIE BACK BAKER TIE BACK SLEEVE 5.750 5643 3836 PUP 3.958 5654 3837 PACKER BAKER ZXP W/HRD PROFILE 4.930 5662 3838 NIP RS NIPPLE 4.930 5665 3839 Liner Han er BAKER FLEX LOCK HANGER 4.860 5675 3840 XO CROSSOVER BUSHING 3.910 5680 3841 PUP BLANK PIPE THAT ALTERNATES WITH PRE-PERFORATED LINER, EVERY OTHER 31' JOINT TO 11890' 3.958 8879 3839 PUP BLANK PIPE THAT ALTERNATES WITH PRE-PERFORATED LINER, EVERY OTHER 31' JOINT TO 11890' 3.958 11851 3819 BUSHING - __ 0.000 Other De th .(plug TVD s, equip., T e - ___ _ etc.) -COMPLETION Descri lion ~, ID 24 24 HANGER VETCO GRAY 4.500 523 523 NIP CAMCO'D' NIPPLE W/NO GO PROFILE 3.875 5012 3669 PUMP SET TRICO JET PUMP ON 4.5" DB LOCK (S/N PH-1058) 10-B RATIO, #10 NOZZLE, #11 THROAT OAL 53 1/2' 5/11/2007 0.000 5012 3669 SLEEVE-O BAKER CMU SLIDING SLEEVE W/DB PROFILE -OPENED 2/18/2005 3.812 5037 3678 Gauge Carrier BAKER MODEL 925 GAUGE CARRIER 3.980 5137 3713 NIP CAMCO NO GO'D' NIPPLE 3.750 5637 3835 XO 4.500 5639 3835 PBR/SBR BAKER LOCATOR SUR/PRR SEAL ASSEMBLY 4.800 - _ _ -_ _ _ -- - Fish -FISH De th Descri lion Comment 9743 FISH IOST 3/11/2006, Lower portion of TRICO jet pump assy, pushed down to 9743 RKR nn d/1 dlOd General ..Notes ~ ~ WELL LOG TRANSM/TTAL ,~ .. ProActive Diagnostic Services, Inc. To; AOGCC Christine Mahnken 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 following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax (907) 2458952 1) Caliper Report 2) Signed Prtint Name: 12 Aug-08 1 G184 1 Report / E~ 50-029-23155.00 2~ -059 /1,~a5' ..~-~-- ~~~~~~ ~ iJ u" j~ ~~UUtS /~ Date PROACTfl/E DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907245-8951 FAX: (90245-88952 E-MAIL ^~~ 9 `~. _ .. s;' ... '(i ~; :' _ , ., , r~ WEBSITE • - - C:\DocumeMs and Seltings\OwneflDesktop\Transmit_Conow.doc • • Malnalry Mufti-Finger Caliper L©g Results Summery ,;, Company: CanocoPhillips Alaska, Inc. Well: 1C-184 Log Date: August 12, 2008 Field: Kuparuk Log No.: 8705 State: Alaska Run No.: 1 (MIT) API No.: 50-029-23155-00 Pipet Desc.: 4.5" 12.6 Ib. L-80 IBT Top Log tntvl1.: Surface Pipet Use: Tubing Bot. Log Intvl1.: 5,643 Ft. (MD) Inspection Type : Corrosive & Mechanics! Damage Inspection COMMENTS This caliper data is tied into the Tubing 7aii ~ 5,643' (MD). This tog was run to assess the cond~ion of the tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate the 4.5" tubing appears to be in good condition, with the exception of a maximum wall penetration of 20°~ recorded in an isolated pit in joint 33 (1,020'}. No other significant wall penetrations {> 18%}, areas of cross-sectional wall loss (> 5%}, or LD restrictions are recorded. MAXIMUM RECORDED WALL PENETRATIONS Isolated pitting ( 20°10) Jt. 33 ~ 1,020 Ft. (MD) No other significant wall penetrations (> 18%) are recorded. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS : No significant areas ofcross-sectional wall loss (> 5°~) are recorded. MAXIMUM RECORDED ID RESTRICTIONS No significant I.D. restrictions are recorded. ~~~ AUK ~. ~ 200 Field Engineer: K. Miller Analyst: C. Waldrop Witness: C. Fitzpatrick ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281j 565-1369 E-mail: PDS~memorylog.eom Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907} 659-2314 203-0~ '~ ~~~ • • Correlation of Recorded Damage to Borehole Profile Pipe 1 4.5 in (13.2' - 5657.7') Well: 1 C-184 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: August 12, 2008 Approx. T ool Dev iation . Ap prox. B orehole Profile 16 758 1528 2302 _ GLM 1 ~+ .__ t 3098 a a~ 3872 4642 GLM 2 5478 5658 179.4 50 100 0 Da mage P rofile ( % wall) /Tool Deviati on (deg rees) Bottom of Survey = 179.4 1 25 50 y Q 75 E Z 100 ~ 'o 125 150 175 • • PDS Report Overview ~ ~,. Body Region Analysis Well: 1 C-184 Survey Date: August 12, 2008 Field: Kuparuk Tool Type: UW MFC 40 No. 213121 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Ana st: C. Waldro Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 4 5 ins 12 6 ppf L$0 IBT 3 958 ins 4 5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body t~ metal loss body 200 150 100 50 0 .0 to 1 to 10 to ZO to 40 to over 1% 10% 20% 40% 85% 85% Number of'oints anal sed total = 188 pene. 25 151 12 0 0 0 loss 64 124 0 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole /pons pitting corrosion corrosion corrosion ible hole Number of 'oints dama ed total = 1 1 0 0 0 0 Damage Profile (°~ wall) ~ penetration body ,~:~; metal loss body 0 50 100 0 50 GLM 1 98 148 GLM 2 Bottom of Survey = 179.4 Analysis Overview page 2 • PDS REPORT JOINT TABI, Pipe: 4.5 in 12.6 ppf L-80 IBT Well: Body Wall: 0.271 in Field: Upset Wall: 0.271 in Company: Nominal I.D.: 3.958 in Country: Survey Date: • ELATION SHEET 1 C-184 Kuparuk ConocoPhillips Alaska, Inc:. USA August 12, 2008 Joint No. Jt. Depth (Ft) f'~~n. I I),tic~t Ilm) Pen. Body (Ins.) Pen. °~~~ ~Ic~t,~l I o55 °~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 13 0.01 4 I 3.91 PUP 1 16 0.02 8 3.89 2 47 ~~ 0.01 3 ; 3.90 3 78 U 0.00 1 ' 3.89 4 109 U 0.01 3 ~ 3.89 5 139 U 0.01 3 t 3.89 6 170 a 0.01 3.89 7 201 (1 0.01 -t ~ 3.90 8 231 O 0. 1 -1 3.89 9 2 61 O 0.00 I ; 3.90 10 291 (~ 0.00 1 3 3.90 11 321 O 0.01 2 3 3.90 12 353 O 0.01 1 _' 3.90 13 384 a 0.01 ~1 3.89 14 416 O 0.01 2 ? 3.90 15 448 a 0.01 3 ; 3.90 16 478 U 0.01 3 ~ 3.90 16.1 509 U 0 U ~) 3.88 C mco XD- i le 17 511 (1 0.01 1 3.89 18 541 ~) 0.02 7 ~ 3.91 19 571 t) 0.01 2 ~ 3.89 20 602 O 0.05 1 t3 j 3.90 21 632 O 0.02 ~) c 3.86 22 664 t 1 0.02 (, 3.89 23 694 O 0. 3 lu ) 3.83 24 726 ~) 0.03 12 ; 3.84 25 758 U 0. 3 1O ~i 3.90 26 790 t) 0.03 1 U 3.89 27 820 U 0.02 ~) t 3.90 28 851 O 0.03 lU ~ 3.88 29 882 n 0.01 ' 3.84 30 914 U 0.02 t3 3.89 31 945 U 0.01 3.89 32 975 (1 0.02 `~ ~ 3.91 33 1005 0 0.05 :.'U ~' 3.91 Isolated ittin . 34 1036 ~) 0.03 12 ' 3.90 35 1067 ~) 0.04 14 -t .89 36 1097 O 0.02 t3 3 3.90 37 1128 O 0.04 14 ~ 3.89 38 1158 U 0.02 3.90 39 118 U 0.00 1 1 3.90 40 1220 O 0.02 ti 3.88 41 1252 U 0.02 ~~ t .91 42 1283 l) 0.03 1? _' 3.86 4 1311 O 0.02 t3 s 3.90 44 1342 U 0.04 15 t 3.91 45 1373 U 0.03 I u 3 3.91 46 1404 O 0.01 2 ? 3.88 47 1434 O 0 01 4 3 3.90 48 1465 ~) 0.02 ~) ~ 3.84 _ Penetration Body Metal Loss Body Page 1 • PDS REPORT JOINT TABI, Pipe: 4.5 in 12.6 ppf L-80 IBT Well: Body Wall: 0.271 in Field: Upset Wall: 0.271 in Company: Nominal I.D.: 3.958 in Country: Survey Date: • ' LATI O N SHEET 1 C-184 Kuparuk ConocoPhillips Alaska, Inc USA August 1 Z, 2008 Joint No. Jt. Depth (Ft.) I'~~n. ~ ll,«~t (Im.) Pen. Body (Ins.) I'~~n `i~, ~.t~ I,~l I ~~~> °~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 49 1498 t~ 0.00 1 3.91 50 1528 t~ 0.01 3 _' 3.91 51 1559 t) 0.03 11 3.88 52 1 90 t) 0.00 1 3.89 53 1621 t) 0.03 1 U 3.89 54 1652 t) 0.01 3 s 3.89 55 1683 ~) 0.01 3 3.89 56 1713 f) 0.00 1 _' 3.91 57 1744 t) 0.01 S ~' 3.91 5 1776 U 0.02 6 ~' 3.91 59 1806 U 0.01 4 3 3.89 60 1838 t) 0.03 I O I 3.92 61 1868 l~ 0.01 5 I 3.91 62 1900 t) 0.02 t, 3. 1 63 1931 a 0.01 -1 1 3.90 64 1962 U 0.02 ~~ I 3.90 65 1993 U 0.01 5 _' 3.91 66 2024 U 0.01 3 I 3.90 67 2055 a 0.01 2 1 3.87 Lt. D osits. 68 20 6 U 0.01 ~ ' 3.87 69 2118 U 0.01 4 1 .91 70 149 l) 0.01 3.90 71 2180 t ~ 0.01 ' 3.88 72 2211 U 0.01 ~ ~ 3.84 Lt. De osits. 7 2242 t) 0.01 ; ~ 3. 1 74 2273 U 0.01 4 I 3.93 75 2302 l~ 0.01 4 3.91 76 2333 t) 0.01 3 t 3.90 77 2364 t) 0.01 4 I 3.92 78 2395 l) 0.01 3 1 3.92 79 2426 l) 0.01 5 3.90 80 2458 U 0.01 4 3.88 81 2488 U 0.01 .3 _' 3.90 82 2519 i) 0.01 3 1 3.92 83 2550 a 0.00 1 3.89 84 2581 ~ ~ 0.00 1 1 3.91 85 2 11 t) .00 1 ' 3.92 86 2642 t) 0.01 3.91 87 673 U 0.01 _' 3.92 87.1 2704 t) 0.01 -1 1 3.92 PUP 87.2 2712 t) 0 tl l) N A GLM 1 Latch 11:00 87.3 2719 l) 0.02 9 1 3.85 PUP 88 726 t) 0.00 1 ~ 3.9 89 2757 t) 0.01 3 I 3.90 90 788 t1 0.01 4 ~ 3.9 91 2819 t) 0.01 t 3.93 92 2851 U 0.00 1 I 3.92 93 2882 t~ 0.01 3 ~ 3.89 94 2912 ~ ~ 0.01 2 3.92 95 2943 0.01 3 ~ 3.89 Penetration Body Metal Loss Body Page 2 • PDS REPORT JOINT TABI, Pipe: 4.5 in 12.6 ppf L-80 IBT Well: Body Wall: 0.271 in Field: Upset Wall: 0.271 in Company: Nominal I.D.: 3.958 in Country: Survey Date: • ILATION SHEET 1 C-184 Kuparuk ConocoPhillips Alaska, Inc USA August 12, 2008 Joint No. Jt. Depth (Ft.) I'~•n. OI»c~( Iln~.) Pen. Body (Ins.) Pc~n. % ~~1c~t.il I oss "r~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 96 2975 t~ 0.02 b ~' 3.9 97 3006 (~ 0 01 3 3.90 98 3036 t1 .01 3 ' 3.91 99 3067 U 0.01 3 _' 3.90 00 3098 U 0.00 1 ; 3.89 101 312 9 U 0.00 I ~ 3.91 102 3161 t ( 0.00 I _' 3.90 103 3191 t I 0.01 ~ _' 3.92 104 3222 i? 0.00 I _' 3. 105 3253 (~ 0.01 1 1 3.91 106 3283 a 0.01 i .90 107 331 U 0.01 ~ I 3.89 108 3345 c ~ 0.00 I 1 3.91 109 376 (~ 0.01 i I 3.92 110 3406 (~ 0. F3 3.91 111 3437 a 0.01 .' 3.91 112 3468 a 0.01 ~ 3.87 113 3499 t 1 0.01 4 I 3.92 114 3530 a 0.01 3 1 3.92 115 3561 U 0.01 3 I 3.92 116 3593 t) 0.01 4 3.87 117 3624 U 0.01 3.87 118 3655 t t 0.01 -3 I 3.88 119 3686 ll 0.01 _' I 3.87 120 371 (1 0.01 Z ! 3.92 121 3747 (I 0.01 3 I 3.91 122 3777 t) 0.01 4 _' 3.90 123 3809 t ~ 0.01 5 2 3.85 124 3841 U 0.01 5 1 3.9 125 3872 (1 0.00 I ~ 3.91 1 6 3904 U 0.02 r3 ~ 3.88 127 3935 c1 0.01 ~1 ~ 3.91 128 3965 U 0.01 ~ 1 3.86 129 3995 a 0.02 ~> 3.91 130 4026 ti 0.02 t3 1 3.91 131 4057 U 0.03 1O 1 3.90 132 4088 l1 0.01 & 1 3.92 133 4119 U 0.02 ~> I 3.91 134 4150 (~ 0.02 ~~ I 3.89 135 4178 U 0.02 8 _' 3.87 136 4210 U 0 02 ~~ ~ 3.90 137 4241 U 0.03 I U 1 3.92 138 4 72 t~ 0.03 1 1 I 3.87 139 4303 (1 0.01 i I 3.93 140 4334 l) 0.02 3 _' 3.90 141 4365 tt 0.02 ti _' 3.88 142 4393 U 0.01 Z I 3.92 143 4424 11 0.02 ;t 3.92 144 4455 t~ 0.02 (~ I 3.92 145 4486 ~ ~ 0.01 4 _' 3.91 _ Penetration Body Metal Loss Body Page 3 • PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 IBT Well: 1 C-184 Body Wall: 0.271 in Field: Kuparuk Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: August 12, 2008 Joint No. Jt. Depth (Ft.) Pc~n. Utrie~t (Ins.j Pen. Body (Ins.) I'c~n. ~~ ~trt,~l I ~~ss ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 14b 4517 t~ 0.02 ~i ~ 3.91 147 4548 a 0.02 ~) i 3.92 148 4 80 a 0.01 ~ I 3.88 149 461 1 ~ ~ 0.01 ~ I 3.91 150 4642 i ~ 0.01 4 .' 3.92 151 4673 a 0.04 I5 t 3.89 152 4704 c) 0.01 ~ I 3.91 153 473 U 0.01 4 I 3.87 154 476 0 0.01 I I 3.91 15 4796 U 0.01 3 I 3.91 1 6 482 8 U 0.01 3 1 3.90 157 858 ~) 0.01 4 s 3.91 158 4889 l1 0.01 t _' 3.91 158.1 4919 U 0.01 4 _' 3.89 PUP 158.2 4927 (1 0 l) U N A GLM 2 Latch ~ 4:30 158.3 4934 U 0.02 3 3.92 PUP 159 4942 t) 0.00 1 ) 3.92 60 4973 t) 0.01 2 I 3 92 160. 5003 t) 0.01 i 1 3.93 PUP 160. 5010 U 0 t) t) 3.81 Baker CMU (idin Sleeve 160.3 5021 t) 0.01 1 1 3.90 PUP 1 0.4 027 U 0 U U 3.98 Bak r M del 925 Gau e Carrier 160.5 5038 l1 0.01 4 1 3.90 PUP 161 5046 t) 0.01 4 I 3.92 16 507 t) 0 01 3 ~ .9 163 5108 U 0.01 -~ 3.93 163.1 5138 t) 0 U t) 3.75 Camco XD-Ni le 164 5140 t) 0.02 t3 2 3.92 165 5 70 U O.D3 I t) I 3.90 166 5201 (1 0 tl 1 3.89 167 5 32 U 0.03 t U 2 3.91 168 5261 O 0.03 13 I 3.90 169 292 11 0.02 I 3. 4 170 5324 l) 0.03 10 1 3.91 171 5356 t) 0.01 3 I 3.92 172 5385 U 0 U 1 3.92 173 54 7 U 0 U _' 3.91 174 5447 U 0 O I 3.92 175 5478 t) 0 O 1 3.93 176 5510 U 0.02 t3 3.91 177 5541 a 0.03 1l) I 3.93 178 5571 U 0 O ~ 3.90 179 5603 !_) 0.01 ~~ 3.90 179.1 5634 t) 0.03 10 _' 3.92 PUP 179.2 5643 U 0 O U 3.96 WLEG 179.3 5645 U 0 u i ~ 4.80 PBR SBR 179.4 5658 t) 0 l) ~ 1 5.75 Tie Back Sleeve __ Penetration Body Metal Loss Body Page 4 ~1 ~ PDS Report Cross Sections ,V ~ i~ Well: 1C-184 Survey Date: August 12, 2008 Field: Kuparuk Tool Type: UW MFC 40 No. 213121 Company, ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubing: 4.5 ins__ 12.6 f L-80 IBT Anal st: C. Waldro Cross Section for Joint 33 at depth 1020.46 ft Tool speed = 43 Nominal ID = 3.958 Nominal OD = 4.500 Remaining wall area = 98 Tool deviation = 5 ° Finger 11 Penetration = 0.054 ins Isolated pitting 0.05 ins = 20% Wall Penetration HIGH SIDE = UP • Cross Sections page 1 ConocoPhillips Alaska, Inc. • KRU 1C-784 1 C-184 API: 5002923155 00 Well T : PROD An le T5: d SSSV T e: NIPPLE Ori Com letion: 6/102003 An le TD: 89 d 11890 Annular Fluid: Last W/O: Rev Reason: SET JET PUMP Reference Lo 28' RKB Ref L Date: Last U ate: 5/19200 7 Last Ta TD: 11890 ftK6 Last Ta Date: Max Hole An le: 92 d 9811 Casin Strin -ALL S TRINGS Descri lion Size To Bottom TVD VYt Grade Thread SURFACE 7.625 0 5798 3852 29.70 L-80 BTCM CONDUCTOR 16.000 0 110 110 62.50 H-40 WELDED Casin Strin -SLOT TED LINER Altlernatin 'ts blank/slotted i w/12-1" round ho Descri lion Size To Bottom TVD VYt Grade Thread SLOTTED LINER 4.500 5838 11890 11890 12.60 L-80 NSCT Tubin Strin -TUBI NG Size To Bottom TVD Wt Grade Thre ad 4.500 0 5643 3836 12.60 L-80 IBT Pertorations Summa Interval TVD Zone Status Ft SPF Date T e Comment 8824 - 11890 3839 - 1189 0 WS D 3066 99 6/82003 IPERF Slotted Liner w/12 - 1" round holes/oint Gas Lift MandrelsNal ves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 2718 2394 CAMCO KBG-2 DMY 1.0 BK-5 0.000 0 4/172 006 2 4926 3638 CAMCO KBG-2 DMY 1.0 BK 0.000 0 8!820 03 Other lu s ui ., etc. -LINER DETAIL De th TVD T Descri lion ID 5643 3836 TIE BACK BAKER TIE BACK SLEEVE 5.750 5643 3836 PUP 3.958 5654 3837 PACKER BAKER ZXP W/HRD PROFILE 4.930 5662 3838 NIP RS NIPPLE 4.930 5665 3839 Liner Han er BAKER FLEX LOCK HANGER 4.860 5675 3840 XO CROSSOVER BUSHING 3.910 5680 3841 PUP BLANK PIPE THAT ALTERNATES WRH PRE-PERFORATED LINER, EVERY OTHER 31' JOINT TO 11890' 3.958 8879 3839 PUP BLANK PIPE THAT ALTERNATES WITH PRE-PERFORATED LINER, EVERY OTHER 31' JOINT TO 11890' 3.958 11851 3819 BUSHING 0~ Other lu s, ui ., etc. -COMPLETION De th TVD T Descri lion ID 24 24 HANGER VETCO GRAY 4.500 523 523 NIP CAMCO'D' NIPPLE W/NO GO PROFILE 3.875 5012 3669 PUMP SET TRICO JET PUMP ON 4.5" DB LOCK (SM PH-1058) 10-B RATIO, #10 NOZZ #11 THROAT OAL 53 12' 5/112007 LE, 0.000 5012 3669 SLEEVE-0 BAKER CMU SLIDING SLEEVE W/DB PROFILE -OPENED 2/182005 3.812 5037 3678 Gauge Carrier BAKER MODEL 925 GAUGE CARRIER 3.980 5137 3713 NIP CAMCO NO GO'D' NIPPLE 3.750 5637 3835 XO 4.`.00 5639 3835 PBR/SBR BAKER LOCATOR SUB/PBR SEAL ASSEMBLY 4.800 Fish -FISH De th Descri lion Comment 9743 FISH IOST 3/11/2006, Lower portion of TRICO jet pump assy, pushed down to 9743 RKB on 4/14/04 General Notes Date Note 1 011 52 0 0 5 NOTE: TIGHT COLLARS 711' &900' MILLED TO 3.872" ID • -.,.._ ~~~- _., MICROFILMED 03/01/2008 DO NOT PLACE ~~`t''.. .:~- ;~ ~~, ~~: ANY NEW MATERIAL UNDER THIS PAGE • F:\I.aserFiche\CvrPgs_Inserts\Microfilm Marker.doc . . ~ ConocoPhillips Alaska RECEIVED JUL 1 0 Z007 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Alaska Oil & Gas Cons. Commission Anchorage July 6,2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AI< 99501 :S:GANNED JUL 1 1 2007 8-03-0,&9 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level ofapprox. 1.0 foot. The remaining 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 M.J. Loveland at 907-659-7043, if you have any questions. ConocoPhillips W ell Integrity Project Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitorl Well Name prD# cement pumped cement date inhibitor sealant date ft bbls ft gal 1 C-125 201-199 11" na na 4.8 6/9/2007 1C-170 203-078 23" na na 14.5 6/912007 1C-174 203-027 28" na na 9 6/9/2007 1C-178 203-041 40" na na 16 6/912007 1C-184 203-089 24" na na 10.4 6/912007 Kuparuk Field June 9,2007 . . 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) 245-8951 1) 1 Report 2) 1 Report 3) 1 Report 4) 5) 6) 7) 1 C - 135 MTT Log 8-Sep-06 ;)0 I - é)DÒ 1 C - 178 MTT Log 8-Sep-06 {)03 - û~{ I 8-Sep-06 .{;)ó'¿'rO 15<1 ~ 1 C - 184 MTT Log ~·("'*4"U~.Ir.;.:r, PJt\' vi '/.' j~ne\'1~:I'J""',"', "U ¡¡ t ,~. Signed: eÚ -,' .-- - RECEIVED Date: OCT 0 4 2006 -_._------.--'..-~ ,.¥ Print Name: C,[l (ì"SH I/lt? ¡no /,r¡ 1/1 /<' Ql-1 i\laska Oil & Gas Cons. Commission Anchorage PRoACTIVE DIAGNOSTIC SERVICES. INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: PDSANCHOR.I\.GE(å!MEMORYlOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\OOJ'DSANC·200óìZ _ WordlDislribution\Transmiltal_ Sheets\Transmi'_ Original. 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: ConocoPhillips Alaska, Inc. Well: 1C-184 Log Date: September 8, 2006 Field: Kuparuk Log No. : 6603 State: Alaska Run No.: 1 API No.: 50-029-23155-00 Pipe1 Desc.: 4.5" 12.6 Ib L-80 IBT Top Log Intvl.: Surface Pipe1 Use: Tubing Bot. Log Intvl.: 180 Ft. (MD) Pipe2 Desc.: 7.625" 29.71b L-80 BTCM Top Log Intvl.: Surface Pipe2 Use: Production Casing Bot. Log Intvl.: 180 Ft. (MD) Pipe3 Desc.: 16" 62.5 lb. H-40 Welded Top Log Intvl.: Surface Pipe3 Use: Conductor Pipe Bot. Log Intvl.: 116 Ft. (MD) Inspection Type: Assess External Co"osive Damage (Metal Loss) to Production Casing. COMMENTS: This MTT data is tied into the Tubing 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" production 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 (181'), 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 180'. A log plot of the entire log interval, plus a detailed section of the interval showing damage is included in this report. The Delta Metal Thickness (%) curve in these plots refers to total metal surrounding the MTT tool and the results show one interval of metal loss in this log interval from the mandrel hanger to -9' below the mandrel hanger, although two collars mask some of this interval. A maximum of 23% circumferential metal loss is recorded in the interval between 0' and 9'. No other areas of significant metal loss are recorded throughout the interval logged. 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 ofthe metal loss is specific to the 7.625" production casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal loss indicated could be from either the 4.5" tubing or 16" conductor. Field Engineer: N. Kesseru M. Lawrence & J. Burton Witness: T. Sendon CEIVED 1::/.,),:;J; OCT 0 4 2006 6)63 -ö'?f1 ~ Oil & Gas Cons. Commission Anchorage I I I I I I I I I I I I I I I I I I I ~ ~s. Magnetic Thickness Too p~ DIAq""""Ì<: SER\!ICE5, INC. Database File: Dataset Pathname: Presentation Format: Dataset Creation: Charted by: g (10Hz Pass) d\warrior\data\ 1 c-184\ 1 c184. db Kuparuk!1C184/run1!10hz.1 2.6 scale Wed Sep 1316:26:04 2006 by Calc Sondex Warrior V1.O Depth in Feet scaled 1 : 150 - -50 Delta Metal Thickness (%) 50 o Line Speed (ftlmin) -200 -. < 2.6 -6.2 Tree --¡ç-- - 5"1 Coll~uP Jt. 0.1 ¡--23% Metal Los í II _ - -- ...~ -···f- l.....~]625.. Casing Collar "-"- --.----- -- __1+ __m , , - ~ \ { -t=i ( .......- -. '" .. - -- _.~.- < ~-:-t - \ ( l. - -.- _.~.- f---I-.J .- .~---~...^ ----- ~ ¡' -j-----. Joint 1 20 - f-----e--- I ~ --. ¡c- i .5" Collar I:; = Itl 40 - --= -..-- ~- Ìff"-- 1. 625" Casing C~()~n.t 2 u--f- è-- -..... ¡--..:: - - - -"" -- ---.. 60 '5" Collal -----._-- --.. - 1- "-_.... - Joint 3 --- -- 80 - '-- --' -- -- f- .....- t=[ >--- ,.- __I, ___ _u_ .__ i , I :.:'S --:¿C::--7 ~"')h'J 0-""'\""';i""!...... 0.....11.....". '- 1--- MTTP01 (rad) MTTP12 (rad) 1 - 1--- ~ - ----- -- -\ --- '- ~-rjil ~ -0; j --- -- /' \ 1 ~ 1--- - ,~__c "" '::¡; ~ ~ - _Om 1 _ { , -- ~- - 12.6 3.8 -..-- - - -- f- ~ - I--- [Œ- - -- < , - f---- "- --f- ;;¡¿~~. I I I I I I I I I I I I I I I I I I I -t' I m- 'ULO vCl;:) II I!,J vUIIClI ~_Mt 4. 5" Collar -- -K-...... - 100 4IF- .¡ - I <: -- I- ~--- - I-- .-- I I ~ I I - I Joint 4 í I - ~ I-- - f--- -- '-- f--- -- '\ I \ ~ Bottom of 16", Cond",wr I-- V C / - \. -.. '-;¡> - { _~M 4.5" Colla! "{ J I-- ( (. " I-- \ ~_. i-' ..-- \: .-- lC ,-- ~~ "~'M '\,., '-... i(,,,,, - -7625" Casing Collar C (:" ffi c.. "( ~ ~ b 140 Joint 5 f--. -- I i i : 1 i , ~ I 't -----. f-- l' 4. 5" Collar í ~ =F# 160 I ( J f j ì - ( l ( { 1 1 Joint 6 g~ -. "- ~ ¡ j J I ¡ , -t - 1,--" I~,,^.I... 7 """\t::" ''"'- . I'-.. s_, >'''' \. \W, ........ 1"_'1 ~I -50 Delta Metal Thickness (%) 50 26 MTTP01 (rad) 12.6 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 <126. Magnetic Thickness Too og (10Hz Pass) p~ DI"",""""I<: SER\!ICE5, INC. Database File: d\warrior\data\1 c-184\1 c184.db Dataset Pathname: Kuparuk!1 C184/run1/1 Ohz.1 Presentation Format: 2.6 scale Dataset Creation: Wed Sep 1316:26:04 2006 by Calc Sondex Warrior V1.O Charted by: Depth in Feet scaled 125 . -50 Delta Metal Thickness (%) 50 2.6 MTTP01 (rad) 12.6 0 Line Speed (ftlmin) -200 -6.2 MTTP12 (rad) 3.8 , I I \1 < < ¡ Mandrel Hanger·' -, (\ '. ';<.~.. I mTOES è~~~ !~ ! J ."........ b····~ Pup Jt. 0.1 I , I ~..~ ¡:¡" Collar .øæ~=., > I I === ~ "3 ~< I +1 :::- <; I < r" < i> f ( þ --t < , I .--- { 1 1\ I t I I I I " ) I I 5 ~ i ,+ -7625" Casing Collar <' I /. c-- j~ ! J j ! I , Y . ¡ " I +- Indication of Clean 7.625" Casing I I 1 I I I (-9' Below Mandrel Hanger) I I I I , 10 I I I I I I I Joint 1 \ I I I I I 45" Tubing I I I I -50 Delta Metal Thickness (%) 50 2.6 MTTP01 (rad) 12.6 0 Line Speed (ftlmin) -200 -62 MTTP12 (rad) 38 I KRU 1C-184 I I TUBING 11C-184 (0-5643, API: 500292315500 Well Tvpe: PROD Angle @ TS: deq@ 004.500, SSSV Type: NI PPLE Oríg 6/10/2003 Angle @ TO: 89 deg @ 11890 103.958) Completion: Annular Fluid: Last W/O: Rev Reason: Set JET PUMP, DMY Reference 28' RKB Ref Log Date: Last Update: 4/18/2006 Log: Last T a¡:¡: TO: 11890 ftKB Last Tag Max Hole 92 deg @ 9811 Date: Angle: All Oescriotion I Size Top Bottom I TVO I wt I Grade I Thread SURFACE ~ 7.625 0 5798 I 3852 I 29.70 I L-80 I BTCM CONDUCTOR 16.000 0 110 1 110 1 62.50 I~ ~h;..~ ~ 81.. UNI=R OescriDtion I Size Top I Bottom I TVO I wt I SLOTTED LINER I 4.500 5838 11890 1 11890 1 12.60 1 L-80 I NSCT ~ Size I TOD I Bottom TVO I wt I Gracie Thread 4.500 0 1 5643 1 3836 I 12.60 1 L-80 1 IBT Interval TVD I Zone I status I Ft I SPF I Date Type I Comment 8824 - 3839 - 1 WSD I F06, 9916/8/2003 ¡PERF I Slotted Liner w/12 - 1" 11890 11890 round St MD I TVD Man Man Type VMfr V Type VOD Latch Port TRO I Date Vlv Mfr Run Cmnt 1 271812394 CAMCO KBG-2 DMY 1.0 BK-5 0.000 o ~/17/200 ~3638 CAMC~ KBG-2 DMY 1.0 BK 0.000 o 18/8/2003 .) .111\11:1 II:\III!:I IV Depth TVD Type Description ID 5643 3836 TIE BACK BAKER TI E BACK SLEEVE 5.750 5643 3836 PUP 3.958 5654 3837 PACKER BAKER ZXP WIHRD PROFILE 4.930 5662 3838 NIP RS NIPPLE 4.930 5665 3839 Liner BAKER FLEX LOCK HANGER 4.860 PBRISBR Hanoer (5639-5643, 006.380) 5675 3840 XO CROSSOVER BUSHING 3.910 TIE BACK 5680 3841 PUP BLANK PIPE THAT ALTERNATES WITH PREPPERFORATED 3.958 (5643-5654, LINER, EVERY OTHER 31' JOINT TO 11890' 006 390) 8879 3839 PUP BLANK PIPE THAT ALTERNATES WITH PREPPERFORATED 3.958 LINER, EVERY OTHER 31' JOINT TO 11890' 11851 3819 BUSHING 0.000 PACKER ,...... -,. ~... u::un:::. DV (5654-5662, Deoth TVD Description ID 006 550) 24 24 HANGER VETCO GRAY 4.500 NIP 523 523 NIP CAMCO '0' NIPPLE WINO GO PROFILE 3.875 (5662-5665, 5012 3669 PUMP TRICO JET PUMP, SIN PH-1075, 10-B RATIO, #10 NOZZLE, 0.000 00:6.050) #11 THROAT (OAL 53 1/2') ON 4.5" DB LOCK, set 4/17/2006 Liner Hanger 5012 VE-O BAKER CMU SLIDING SLEEVE WIDB PROFILE - OPENED 3.812 (5665-5675. 2/18/2005 00:6 450) 5037 3678 Gauge BAKER MODEL 925 GAUGE CARRIER 3.980 Carrier pup 5137 13713 NIP CAMCO NO GO '0' NIPPLE 3.750 (568(}'8824, 5637 35 XO 4.500 004.500) 5639 PBRISBR BAKERLOCATOR~IIRIPRRSEALASSEMBLY 4.800 Fish - FI )H -~ Deoth Description I Comment Perf 9743 FISH ¡lOST 3/11/2006, Lower portion of TRICO jet pump assy, (8824-11890) ¡pushed down to 9743 RKB on 4/14/04 \totes Date Note 8/812003 UNABLE TO PASS TIGHT COLLAR W/3.845" NO GO ON DB-6 LOCK & JET PUMP 8/8 & -- 9/18/03 @ 711' SLM -- 0/15/200 COLLARS ~ 711' & 900' MILLED TO 3.872"10 SLOTTED LINER (5838-11890, 004.500, \NU2.60) I I I I I I I I I I I I I I I I 1 C-184: 81 to be converted back to jet pump lift. ) ) Subject: lC-184: 81 to be converted back to jet pump lift. From: NSK West Sak Prod Engr<n1638@conocophillips.com> J.O-S'"'®,~ Dåte: Sun, 02 Oct 2005 11 :58:45 -0800 td:'N~¡(W est SfÛ<:P(oClÈngr -<ni6~8@co~ocop~ilÎipsi;.cpm~,.t()~;M~\lnder~": " . ~t¢1n .~Jn"a1J11d¥~@å~í1.stat~.~~~s>, J~p1 ~egg <:jim~1"egg@a~in~stat~.å1ç. us> ,"" " C¢:CP~l:prod SUPY5nl1~2@conocophinips.co~>,:cP:En P8:L~~d Techs· <nIl:140@co~oc"ophilIips~com>,." ~SKPr¿þlem \VeIl: Sup¥ <n~ 617@cónocophillips.com> . Tom / Jim, 1 C-184 was shut in today and will be converted back to jet pump lift soon (Slickline work is required to do this). The well was produced with a temporary gas lift setup from 9/18/05 to 10/2/05 (14 days total). This email is being sent as a follow up to Pete's email from September 19 (attached below). Please let me know if you have any questions or concerns. Thanks, Hai Hai Hunt / Peter Nezaticky West Sak Production Engineer ConocoPhillips Alaska, Inc. email: n1638@conocophillips.com phone: ( 907 ) 65 9 - 7 0 61 pager: (907) 659-7000 pager# 836 ªCANNED NO\f 0 92005 . -----Original Message----- From: Nezaticky, Peter On Behalf Of NSK West Sak Prod Engr Sent: Monday, September 19, 2005 3:27 PM To: Tom Maunder; Jim Regg Subject: 1C-184 Tom / Jim, 1C-184 was converted from jet pump lift to temporary gas lifted production 9/18/05. The plan is to gas lift the well for about 14 days to confirm the water cut and determine how the wells flow on lift gas. After this test period the well will be converted back to jet pump production and the AOGCC will be notified with an email of the change. Thanks, Peter Nezaticky / Hai Hunt ConocoPhillips Alaska Inc. West Sak Production Engineer 1 0[2 10/4/2005 7:55 AM t Q Jlf!h, À~~~ DATA SUBMITTAL COMPLIANCE REPORT 7/6/2005 Permit to Drill 2030890 Well Name/No. KUPARUK RIV U WSAK 1C-184 Operator CONOCOPHILLlPS ALASKA INC {~ u..¿ ;(r fVlø] ^~~3 API No. 50-029-23155-00-00 MD 11890 r -- ---- --------- ------ TVD 3840" Completion Date 6/10/2003 r Completion Status 1-01l REQUIRED INFORMATION Mud log No Samples No --------.------ -------- DATA INFORMATION Types Electric or Other Logs Run: GRlRes Well log Information: log/ Electr Data Digital Dataset Type· Med/Frmt Number ~- ; ED C Asc ED C Pds ED C Pds log Pds , log Rpt Rpt Name Directional Survey Log log Scale Media Run No - -------- 12065 LIS Verification 12065 I nd uctionlResistivity 12065 I nd uctionlResistivity 12065 Induction/Resistivity 1-3 25 Final 25 Final 25 Blu Final 25 Blu Final 1-3 Final Pds 12065 Induction/Resistivity 12065 LIS Verification Directional Survey Well Cores/Samples Information: Name Interval Start Stop Sent ADDITIONAL INFORMAR.0N Well Cored? Y 1 tù Daily History Received? Chips Received? - Y 1 N Formation Tops Analysis Y / N Received? Current Status 1-01l UIC N Directional Survey ~ (data taken from logs Portion of Master Well Data Maint) Interval OHI Start Stop CH Received Comments 120 11890 Open 2/20/2004 2490 11890 Open 7/28/2003 .t~4 11890 Open 7/28/2003 RWD-Propagation J..,,/c{ú Resistivity, Gamma Ray 1.20- 11890 Open 7/28/2003 RWD-Propagation ~ iio- ~ Resistivity, Gamma Ray 11890 Open 7/28/2003 RWD-Propagation Resistivity, Gamma Ray - )~~ MD 11890 Open 7/28/2003 RWD-Propagation Resistivity, Gamma Ray - TVD 2490 11890 Open 7/28/2003 0 11890 Open 6/19/2003 - ~~7 Received Sample Set Number Comments ·(DN &/N DATA SUBMITTAL COMPLIANCE REPORT 7/6/2005 Permit to Drill 2030890 Well Name/No. KUPARUK RIV U WSAK 1C-184 Operator CONOCOPHILLlPS ALASKA INC MD 11890 1VD 3840 Completion Date 6/10/2003 Completion Status 1-01L Current Status 1-01L ------------ - ----~~ Comments: -- - - - ---------- fk Date: -- -- --------- Compliance Reviewed By: API No. 50-029-23155-00-00 UIC N :1~ÁJ~l -- Conoc;p.,illips ) ConocoPhillips Alaska; Inc.,Slot #184 Pad 1 C, Kuparuk River Unit,North Slope, Alaska _, ~03-'08( SURVEY LI~ I iNG Page 1 r'¡. BAKER Wellbore: 184 HUGHES Well path: MWDw/IFR<0-11890'> INTEQ Date Printed: 9-Feb-2004 . . .J Wellbore N.~JI1_EL______._____._ t84. "··_··'_·"_···_·'·___.___·,__.__v..____.,_"" . _~. __.___n._____ ,,___ ._. _".._ -···-········-..I.~~~~J:~ioÔ3--_. ._----.--......---... .-------.....-.......-.-..-.........-------.- -----....~..~-~~~~~~~~;~... .. -----_._--_._.__.~--,--._.- ~---_._- ."-".----,---.-.. --- ...,-..--.--- ,..--.-..---.-_._._._____.__"__. "---__________.._.___.__. .___..v____.___.______,._..,._"...._....__._.__.____..__.____"_.~_.___.__~_._____._______.._._.._.._.__._.__..____."___.__"_.__0_____,_....,,.__ __'._.._....__....._"...___.._.__...,___.___.._.___.........._____.__,"._.._.,__.~___. _____........_.,_._..,._._.._..,..____ _Well_ Name 184 I Government ID I Last Revised 14-Apr -2003 Slot .-..--.- .-.--,,-..,--- ,-....._-, ._-,_.. Name Slot #184 Installation ~·_,__.__.~~u......,__~.,,_.,_ , .. .. _n..,__..". _'_"_'__~_"..."._'_"_'_"__ ___. ..__~,........_.._..~.._.. .._..._... ." ._,. .._ .___.._.,.,_,. .0. _._,__.._~__._...__.. ___'""'__"'."__·_'~_'_.__O_"__""'''_O'_______"''_'''__''._ __._._...~. _.. ~,___,_~._,~_,__,,_,._...w_.__..,....,,_._....___.~,_._ _._"~.._,.___~..__.__.__,,_..,, _..__._.._.. Field --..,.-.---........, ..-'....,,_.,...._. Name Kuparuk River Unit Eastinq 487754.620J··N~rthi~q···· ·-~~-:·~9~~·.·~~:JCif~··~~~~~;R~~~:~:·~·I~::·~:;·~~···~ ~~~-~·~~~~·N~rth-AliQ~~-~~t····;r~·: Comments RECEIVE C) -----..--------..-n--·-----------·-----F-EB-,-O--·2fm4-----.-..---------. -..-.-- .Arøska.uil~'ß~$Cºös.Corrimìssiol1 ' . , Aochorag~ ., .,,·__._._.__..._"'"_·__O_n.___~__.._. _______._ _.._..._. '"..._ ......,__,__~_,__._,.... ._ -...- .-- ...,.- ,- --..,-.-..-.. ". -------.--..---.--.----,-...--..--. --. "..~....~-_.__._---- ~."----_._._-~._- l_ ____ -, ---~-,,-~. .__.__...-_."._---------_.._-~..._-_.- "-.,, ....-.--.------ .--..---------------..--.-- - ------------- ------.,,-------...-.-..---....----.-- -------...--- ---...- ...-.....-.--...- All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Doyon #141 87.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 117.91 degrees Bottom hole distance is 8122.21 Feet on azimuth 157.84 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ~~~N\ ~ ) ConocriPhillips ConocoPhillips AlaSKa, Inc.,Slot #184 Pad 1C, Kuparuk River Unit,North Slope, Alaska WellpatbJGricO Repor1.______..______ MD[ft] Inc[deg] Azi[deg] TVD[ft] North[ft] ... '__H'~_'''_'_ . ...,,_, --.. . "-'"....-".-.--.--" " -- "-- ...-.-"-.....--..-----.--...,,. _ .,_, .,. n·~,,_~.. .__. .._."._._.'"" 0.00 O_QO . Q,QO Q,OO O,QQN 120.00 0.00 0.00 120.00 O.OON 209.QOPJì2 JQ.Q,~? . _ ___2_QJLºQ . ... Q,:41;>_ 29.5,OQ 0.~6 J4.{5.~9.. 2~4.~9 _ 1.1.2$. 382.83 0.91 142.26 382.82 1.968 474.1.8 1..29 142,136 . ~74J5 __.:3..36..$ 564.37 1.04 114.11 564.32 4.508 655_72 2.67 77_58 655.62 4.388 749.38 5.62 75.02 749.03 2.738 839.24 6.65 75.07 838.37 0.25S ~2_9J:)L J...06_ . ]º'-~~.._ ... .92ftlQ__ .b..3._~N.m_...._ 1017.93 7.20 76_70 1015.73 4.93N ..:1.1.1.2_,.18 9.75 7],2,8_.. ..jJ_o.a,~.9. 8.05N J2,-º{5..,~.ª__ _ JJ.~!:)_ ... _..~º,_5ª.._._ . .....12.0J.07__ _ J_L3.~N__._ . J2.~~-.0.8 14,22.. 8!3_58. . 12.9.1,[.9 . t3.,6ÞN. . _.. _13.90..:..8J?______JZJ_Q.... ~Q,42. ..... 1380.11 .. ..... t4,?_2.f'.I...._.. 1~~!3.,.o3 2QJ1~__ . .....92_,_!:)Q_ _HIO..._li1 . 13.,-3.9N_.. 15Z~J3Z _ 24.79. 93.12 155q.ª0 . .J162N 1672.40 .27.75 92.24 1!339.,67 9JON 1766.84 29.60 92.83 1722_52 7.69N 1899.99 32.Ht 92,.g{5 1802.45 5.27N 1953.44 36.58 94_11 1879.55 2.00N 2045.58 39.85 92.18 1951.94 1.108 2140.19 43.43 93.56 2022.63 4.27S 2231.42 47.80 93.43 2086.43 8.248 . - 2.3.2,9_J'.1__. _..9ºJ~.____..___~2.A~!3__ _.._.__.2..t4.~L3.2 _ ._.._J_~:.J4.$_ 2420.68 50.27 93.42 2209.11 16.138 ...?!:)l3.J~O. 52..º.o__ .92.J33 22.EiI..54_..2º~ºª$_. .. 2.6Q~ÆL.. _..þJ)Q .... _.. ..__92._.p~_ . 2.3..22._94__.. . __2.3~.3_9§__.. __2_9JtEi,4..2_ .5.:L..a.!3.._._. . .._..9..3.JJL__ ___ _?;3Z~82.. .. ....2..7..'-0_Q$.._... __£71t9..,_QI.......___.9Ll§...__ _...ª-4~21_____~2:4..3.LI:L_ ____3...11..ß.$___ 28fU_.ß8_.__ 51.7:3.__. _JlEißl .. 2499..ºL~ 3..1lQ§$ .. 2~I9J 2___ _ _ 51-7Et, .9Z.1L _ 2q_q:1.{5{5 _ . _4JL3..Q$... 3069.50 . _ _52..Q8_ _97,32. . 2.!3Ht_8_2...5Ei,-9P$ __ _ 3163.06 52.29 97.45 2667.86 65.13S __32Q.ºßl~_ . __Ei2,,2.9___n_9.8-64_._ __2..7..2..9.12..7p)5_Q$ 3350.70 52.22 98.96 2782.68 86.878 3443.06 52.29 99.35 2839.22 98.49S 3536.43 52.18 99.14 2896.40 110.358 3629_83 52.31 98.55 2953.59 121.70S ~~~};~--I- -;;:~{ I ~-~:~~ - - ..~~~~:~~ ~ ¡}~~~ 3J!..lQ,~>-8__ 1__93...t6 --i- ...'1(2..4,41.. _:3..1.2.4-6.9 ¡ 160ß2~ A_QO~...7.4. 5.:3.7.5_ 1JQ,~1_:l1eQ,3J -. [-.. 182.Q98 40~L6_º__L_P.4-8-º __-- 116.30 ._:3_2.3_5~14__" .~2..1..~.2J.s..__. 419_LQ~_.. 56,06 119.94 32ß8.16 449A7S 428~.02__"57-86 124.97 ..:3:33_8.88 291.31S.. 4:377..:3_3 90-12 126.8~. :3;38_9.9_5_ 33...a.,2_tS___. 447..1.23 _ 60_84 128.35 .343:3...22 .3_8S.05S i 4564.22 59_24 127_88 3479.66 437.77S 465..7.4Q 61.~7 130_66 3525_82 _ 48..9-01S SURVEY LI~ .-ÌNG Page 2 Wellbore: 184 Wellpath: MWDw/IFR<0-11890'> Date Printed: 9-Feb-2004 r'¡. BAKER HUGHES INTEQ ... .1..~.~.~~[~~~~:~-~·~~~--:~~~~~--~-~:~~~:~~~~.[ffL_ _ Easting ._n~~~~.i~.=.:~-~-·-------- 9.00~ .Q,QQ 0.00_ 5q23Q1.!;>Q 5.~..E36º9.a.e4. O_OOE 0_00 0.00 562301.50 5968668.64 .... __.....__..0..:2;3/;_ . . __Q.72 0.39_Q92.:301.7..;3 Q9ß8£:1º.8.2:3_ _ . Q,_991; _. __ _..QJ_9___._ . _ . lJJ .. ~..º_2_3Q2JL __ _ __Qª-Eì6._ºßL52 1.29E 0.51 2.06 562302.80 5968666.69 2.:3p.E 0,42. 3.65 56230;3.86.5..99ª£:195.30 3.71E 0.70 5.39 562305.25 5968664.17 6.55E 2.12 7.84 562308.08 5968664.31 13.11E 3_16 12.86 562314_63 5968666_02 22.39E 1_15 19.90 562323.88 5968668.58 _ . __.. .:3_4~.ª_ºf;....______. .QAJ!..___. ...__.__2?..:~_1_ ....9£:12.:3_3.~ ,~2_. _ _ .. .._._ __.º9.ºª-ºl1-,~L 43.51 E 0.16 36.14 562344.96 5968673.93 ._!57..,Q5.E 2.71 4{5,{54. ....!562.:3!56.AZ !;>96ª!?]7.16 74.3._8_E .._ 2....14.. ___§º,~_9._..__.___.Q92._:315JZ____º_ªºª9_ªQß4n__._ 9!5,;3QI;. 2,6.:4 77.83 .5.£:12.3..99.9'7'_ 5.9_ß~mª3.Qa 12.0.,Q5.I::. 3_33_. .9.9,.43. ... .____5.9_2.42.1.12. Q9E'-ª!?ª:3-8º_ ...J5.Q.6.Q.I;___ ..._..3]JL .. n' 12E5.99 !5ß2452.JE5...p_9P.a!38~.28. J89,59E 4,4Z.... __ J.~9A.2.._.._ _.__ _ ___Þ!3..2.48Z,9.:3__.. __ ._Q_9E5a_º..81,13_0~~.._. 227,a8E 3.22 199,.84 _ 51:32.529.27 !5~Eì868Q.,23_ 273.15E 1.98 237.78 562574.55 5968678_59 320.92E 2.78 281_12 562.62.2...33 5996..676.58 373.57E 4.75 329.19 562675.00 5968673.74 430.48E 3_78 380.92 562731_92 5968671_12 493.25E 3.91 437.87 562794.71 5968668.46 558.31E 4.79 497.22 562859.80 5968665.03 _____.9.2.§}....:32..ç.___.._ .. _..__._2.:.92.___..__.____ ...9!>JJm...__ _ .....__ ºº2..~~.o_,!34.._ ... . ._Þ..9'ª-ªJì.ßJ.1.:3.____._ 702.18E 0.47 628_06 563003.72 5968658.34 17_4_,.ºa~ 1.9_2. .9_!;).3.".a.a.!5§.:,tQZ6.14 5.ªº6.ß_5.4,~9. ___...-ª-4~,Q2../;_.. . __Q,4.1.. . _.. __..L5.7,!>JL__ 5.6314_6.60 _ .. ___§~§a§º2....2.?. _ . __ ..9JIJº-!;. 0_57 6.23-1299:3_41a19. ._ .__!5...9ºª649.._4.9._n..__. _ _._.__~9.Q...§JE;..__ . Q.,9.4_.. __..890,2.1:'-_ 563_~92.24 _ _ . .._59~:m-º4~,-º!3_ _.___ . _tQ-º~"º'§'I;.._ ....__lJ:4 n' ________~L2.J__~ ..pJ53.~§4..1.2.___ __ ~___þj~º-ª9_3.9A2._________ .. __.J_t3._6.75E .1,30102._6,2._0 59..34.3.aA8_.. __. p..9_6_8J1:31BL.... J2.Q9....911; 0.89 _.1.P9.þ.....2.:1... __96:35.1.1..,71 .._Þ9.,ªª-6_2,3,Q9 1283.46E 0.33 1164.66 563585.33 5968614.17 1.:3Q9-Z..9E;..__... tQl t2~4,~1.. 5.{5~º5.~LZ3.___.. ... . .. Q..9§8§Q~._42 1430.26E 0.28 1304.56 563732.29 5968593_65 1502.37E 0_34 1373.72 563804.48 5968582_63 1575.22E 0.21 1443.65 563877.42 5968571.38 1648.18E 0.52 1513.44 563950.47 5968560.63 .1.I.2._L3_1E:... .. 0,98 _ _19!33_-A_5 5_6492.3.,96 _ _5.9E3!35.4..9.7.3_ 1794.73E 0.38 1653.85 564097.19 5968538.54 ..1!315..7._3.6E ..4.8Q E2...5.,ºº... ..5Q4J6.~.~4_ i5~J,5..6_þ'24.:L4 u -- i ---I - 193_8)53..1;. !;i.QQ __ I 1..798.57 __96.4_2.4.L4_9... ¡ _..þ'~68~02.06 ____2P.PJt:3_QE 4]9_. 187.4_.5Q564~11.30 _59t3ß472-13 . 2076_13E3A&... __:___1~q..1.4J~.. 564379...42._ ___g96Ji4..3I:L4:L___. 21.41.85E 4.93' ..2029_98 56444~A8 _ 5_9J:18395.15 _ 2206.62E _2_.9_6 21013.29 564~10_-º~ 59158~48.80 227't36E . 1.612188,80 _564575.78 5_9t3_829~.50 2334.74E 1.78 2268_09 564639_57 5968250.31 239..7.-3_8..E 3.46 2~47A~ 564702_62_ 5968199.59 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Doyon #141 87.00 above mean sea level) Vertical 8ection is from O.OON O.OOE on azimuth 117.91 degrees Bottom hole distance is 8122.21 Feet on azimuth 157.84 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated c:onoc6PhilliPS ConocoPhillips Alas.) Inc.,Slot #184 Pad 1C, Kuparuk River Unit, North Slope, Alaska SURVEY La_ ANG Page 3 Wellbore: 184 Wellpath: MWDw/IFR<0-11890'> Date Printed: 9-Feb-2004 ,&¡. BAKER HUGHES INTEQ Well path (Grid) Report MD[ft] Inc[deg] Azi[deg] TVD[ft] North[ft] East[ft] Dogleg Vertical Easting Northing .-----..--.--.--- ...-----..---.--.-.-- -.-.------.-.-.-----.. -----__._______ ____.__.__._.________..____._._._.___.__.______ . [!1eg{1ºPJtL_____$ªºti91JrftL_ ___.___________.___ __._______.__________.._._,_____.. . ______._ .."... . A.75..1.,1.4_ 94~3~L .1.:3_2,.82. 3~ߪ,§JL_ . ..5.H.:5..7_8__. _ ___24§.~.,J¡1 E 3.82 _ 2426,,o12,...96017º-5.,.39_. ._5.~ßßJ44_.þEL. 4844.25 66.63 137.98 3607.17 604.898 2519.05E 5_59 2509.19 564825.24 5968084.74 ___1~38.2j__ n___º_8A_3_____HZj}4 __ __~!H_3._lQ__ _____J:ìZ.1.J~~Å __n____2§IA_._2J~E____ 5.24__.25._8JL3.3._ _ . __ _ 994ª81.._QZ. ...5._~6,~HU¿t2º .5.932,9.9.___ .º-9_JT _ _.. _147.1..1 ..3.9L6J'3.Q__, ,..,Z4.3J~ß~_.___ __.___2§Z!L5.3J;___ .___..~.~9___________2.º_6L~~L_ ______Q9.49.31ßQ u __5.9.º_Z94..f:L8_4__ _ ___ 5125.79 69.72 151.47 3709.06 819.248 2669.41E 4.37 2742_39 564977.35 5967871.67 ._~2H3~ßl 1'1A:5. _ _.J55.,3.Q_374º_,.QJ.. 89Z.IJ~L 2708.71 E... __ .4_,.39 _ . .2,8J3,J~.5.. ..565..Q.1I.:lQ_ . _ .5.9_6.l7_!:J3.5.3. 5312.39 73.09 158.52 3768.49 979.64S 2743.63E 3.72 2883.06 565052.90 5967711.90 5406.20 75.18 159.85 3794.14 1063.988 2775_69E 2.61 2950.87 565085.65 5967627.84 5499.24 80.02 163.28 3814.11 1150_168 2804.39E 6.33 3016.56 565115.06 5967541.91 5592.01 82.02 166.42 3828.60 1238.59S 2828.32E 3.98 3079.11 565139.73 5967453.69 ___º"ªª5."!?Q._ __._ _!3..1.,Z.4_..__ _..199.,-!:J~L__.,__._:3J~.41,ª_4 _J3Z.~L2}~L.,_._,_ .___284.7'.,4_8.1;__ . .,..._,.._,._._~L€L._.. _..,_.____:3j~ß,~1___ 565159,.4..4_._~.____ 5967363. 1ft __ 5757.66 85.10 171.98 3850.08 1399.958 2858.51E 5.43 3181.32 565171.25 5967292.60 ___5.85.2,.95._.___ .".JH;¡~.!;Ij ____ _.._lZ;t5.4_.... _3ª5.4,HL._.____J4..Q~AZ$_. ._'n_2ªZQ..3~E.____._..__._º,,:3,º..,.,._._,_,._ 323_9_..5.9 ___n_5.§Þ.H~Â.JJ.L__n'.. ...,._.... .__º9.º_7.19_~J_Q_ ____590-ºJ~4___ _ ___ ~1.:,32_. . _1L4,9.6__ _. __3.!3.5.~t66 .:15.42-,11.$._ ....__.4_875.,2.9.1;.__._____ .u,4_,º~_.,_,._.._,. ..__.32§2&~L._ __..____º_º-pJ-ª_§L2J_.__ _ __.._ ._,..____5.~tº-71ºº,,-º_Q___ .____... .. ._..~.!:J.4Z.85...__ . .ª9_,6~L_._ 175.85.. .. _ ~8~3,2º_m_ jÞaß-.8.?S___ _..267JLQ.QE .____~tQ~h__ n_ .~fJŒ.a9... _.q9~J~_:3_._~Þ ..__._Þ9fì71Q3ߪ ..5.994..,_3JL._ _ª~J.I_._m.______1Zq._ª_3_... .)8.5..3.14.__._... 1 6~º_,.2]$._. .__._2ߪ2,_4.2E;._ _ . J_,.P.!L. __3:3.12,º~ .qº.5.1~ZJJ.._ .. .. ..._!::!fJ97_º-5.LÞ1......____ . __..º-Q4.L.1J__ _ _ __-ªJLIDL~_ _17.8.~.4__.___ :3_ª_P.4.Q~____~JfìßJ._9.:3§____ .____Z_8_84Jto.E.. .________(5,40._ 3~.a9 .53 5651 !:m.88 ÞfJ.6ZQJQ,8.8._ __..9º.8.7 ,90. ... fJQ,59 ____J]}L3~L .._:3.8_5.4]5...._ .172_8.--4.1.$... ..28._ª5.J4E_ _ A,2o._____ _ _ _.33..5fJ.J2_...___ ..____º"6~ZºJ.'_2º__.__.__ ____-º-ß6Ei9.-º4.42___._ 61 ~2.20 90.ºº.. 179.91 :38.54,q1 17.73.01$ 2ªª.9..QfE _ ..1.,98.3;38._0..25 56Þ2Q1.899_9969J9,8.3 6181.32 90.25 180_09 3854.38, 1822.138 2886.02E 0.53 3403.24 565202.27 5966870.71 922Q.Q8 ª.9.97 179,38 :3.8.5.4.4.9 1869.8~S_ 288..Q.23E 1.71 :3424.3756.5202.84 _p99º8.25.9Eì 6275.43 88.95 178.47 3854_76 1916.228 2887.16E 2.77 3448.29 565204.18 5966776.64 6326.49 89.57 179.31 3855.42 1967_278 2888.15E 2_04 3473.05 565205_59 5966725.61 6372.26 89.97 179.82 3855.60 2013.048 2888.49E 1.42 3494.78 565206.32 5966679.85 6469.07 90.31 179.37 3855.36 2109.84S 2889.18E 0.58 3540.70 565207.81 5966583.06 ____º5..ß~§§._._ .... ___ _9.1,.1.:3... ._.t!3._QA3__ . _ .___~ª-º_4J.§__..._.____~2_º§.31 S_..__ . ..___2_a-ª-~".:3.ºç_.______ _.__1.,:3_9__._._._ _.... .~ªß-,_ºL_ .___§_º-5.2Q~LZª_____ ___ _______5.9...Eiß±.8_Ei_,.ºº. 6662.92 89.85 180.87 3853.32 2303.67S 2888.24E 1.39 3630.60 565208.48 5966389.25 _ __º-Z5..9.,5._f_.. _ _.. Jl9j¡~L.._ _. ..._Hl1AJ. ._ ......_. _~-ª-5.;3J.Q___. _. .._24QQ:2º~_.__ _._._2.!3.-ª-º-,32.1;__._ __. ___Q,§~L_ ___ __ _:3.6]4. tL._ ___ ....... __.§º_!i2º'?-,-~Q.__ .... _.._ . __....__Þ9§J¡ZJ!2.,61___._._____ ___ºªºº--_2º__._ ._!;)J,9º-_____ ..__JßmQ'-8.1___.___.~_9_2_,ºL_._ __...._249.ß.9º-$_. ___.m_2JHt4A.ºE;_.________2J~_...___.___...:3.ZJLI3_ ._ .._9ª~-º9"~fJ______.._____.ºJ!§.º.t9_º,.9--º-_.___.___ ___6_9.!io._,J3L____.__.jKL_~J._.__..._..__.Jª-º~11___ _____3.ߺ_QJH:_.___ .__.....29..9.1_Þ.9_$___ __._2.ª-ª-~.J¡JtI;_________..___.1.,ºL ___ ___ ___ _3.79_L3.3________ . _ 5..9_º"29º,~_2_. ....u_ . __________§~_ººJ.º_L~L__._.__. ___Iº4~Jº_______ 90.15 _-----.1ª-º"Zº--___._3.8.ÞO. M..____268...9. 84.$.__...___.__._.__2_8.ª_2:.9..~tE__._____.___._º,º_2_____.__ .__.._3..8.9JLZZ._._ _________._.Þ.9.!i2ºº.:..44___ ..... ._.__.__9~ºß-º--º~-º-9.____..__. _._LH9_,.9_2___. _ ___6_9.,.3!3__ _... 180.34 __. ~.8.-º_Q:.96 . _ _. .Zl8.L_£9.$._..._. ..__.._.2.8..8._2,_L11;.___ _._.___º.:..8._9____..____...__.J.8_5J_,.5..º-______. 565206.36 ---º-_9659_QÞ.:~~ n_ _Z242. g-º-_ ._J3.9,.ÞL.. _ . J ßJJ_8~___a.8_þ.1.~..ªtL __2.8_!3.:3J~2.$____.___ n_2..8.!3._ºJ~3E_ ....._ __ ..... Oj~º______._3ª9þ_,_º2. ____.___þ.ºþ2Qþ,!3.!3._ . _. . _ ________9_9º-Þa_Q.9"_:32.__...___._ _.7~:39.8.9.._ . ___9.Q,Jß_ 180..]5_.. m__.:3_8.5..Z,_Q'ì:._ .____2jL8-ºJ5~~__.__.__2_81~t20_1;...____ ___0.].1____.._ __.._.3~t3.~:.4_'L___ _n__n_5J:iþ.2º5.-0Eì_._ _...þ.9º-~Z12AQ_ 7434.51 90.25 182.15 3851.72 3075.12S 2876.80E 1.48 3981.60 565203.45 5965617.81 __ Jq3.3_-_;3~..._ _9 :L.þ~q __ . .~ª2, 9_:3___ _~.6p_Q ...1_3____ .. __~.11_3_,8.4~L_____2aZ2 -.7.1..1;____ _ ___ _JA_ L____ __4º2.4_._~4_ .___ _Þº~2PO_,_2.3. .._5.Q.9Þ..~19, º-6 ___ ___ 7629.36 90.00 183.05 3848.80 3269.758 2868.09E 1_74 4065_00 565196_36 5965423.13 7725.97 90.83 181.90 3848.10 3366.26S 2863.92E 1.47 4106.50 565192.99 5965326.60 7758.73 91.50 181_26 3847.43 3399.008 2863.02E 2.83 I 4121.02 565192.35 5965293.85 7822.49 90.80 179.55 3846.15 3462.74S 2862.57E 2.90 4150.46 565192.43 5965230.12 _ _ L91LaJ_ i ___ª-!:!,Z9_ _. .J7~þ§ ._ mq _ ~ª-45..,-6.º __ __ __ ;3.§!:>.~tQ§~.__.._.. __2ª_ß_~t14_E____ _ __ JA~__ --l __4.1 9EL4.Eì_._ __._____~6..5.194J~_º____ J____.._~9.ºp_L3.4., 8...4 i~~~iji~!~~~~~~~··i~;i~Lfai.#i tn ~ii~~~ --1~}i ~~ ~ :~~~:~~ " ,,~!sii~in I ~~:~:~~ ","' i --.-.__. _.___.____~_.._.._.___u__._._.. .._____.___._. ____._._..________ .l._____ .._ .._ .__.._____ ___,__.___ ..________ __..._____________...hn ._.______. ___.__.__.____..__.__.._...____u_u.._ __ __ 1..._____ ...__5.9_9.4..842.,.~5.._______~ __8.2º-º_I8_;____Q2. 00~~_179-62_~_3_8.4..6-,16_ .L_3.9_0Jt9.3_S___L____4JtE5.L82E________·LÞ_3._.._i__..43.ß_º_.2_L___.___ _5.!i5.29..1-3.2___ ._ ,_" __ ~ßß.4192. Q3 _ I 8.:3QJ:3..1 ~._¡nQJJI__! _. n~,63 31345,5 L_! 3.~4§:28_$ _ 1_ 28.6ªJ,2E;._ u.. n_ J -,-133. __._ : _4.:36..1..19__ __.____!i6.§~9_L!lli __--1___Þ..9..º-4I4ßJ~9..._~: _ . 8:3.ß0.Ø8__; __~:mAO_: _ J7!:}.29. 3~44]6 400J.1J8__q!_ __2-ª§!3.!33_E.. ..1.54 _ __1.. 4~.I,_82__ _. ..!5-º~2º,2_.~?n_J__..__q~ß_4§-ª1.8ß___ i __-ª-4Q~.3_6.. __ ___9.0-'.:3Z_______'1l~.Jß__ .~_a_44A'L__. __ __4.P...4.3A13..$..._:_ ._u2.ß-º-!:L~_m=____.__Q,_27__.___L4.42ß._:Lþ._____5_9þ_2_Q~ß~L . ____p_~ß.4ß49,þJ__ ___8A~_9.Eì_L.! ___ .Ø-º___8!L_~.._J I.8,3:L_ . ~_a13_ÆL _ .. At3_!:!]_OS __... ._ ,2ßLL3.1~___ _ _n_ _LOJ____._____ _ 4415___Q-º--___ __-º6ß_ZO_6J~.n _!5~__Ei45!53.32 8597_07 90.71 178.28 3842.21 4237.118 I 2874.21E 0.10 4523.21 565210.50 5964455.95 J3~_ºJ)6 . 9_0-,-9ª-_ ~__ . 17.1312 _~_841-56__12J30,6_8$ . __ _ ___28I.5,3Þ1=_.._ _..1-113_ __ .____ 4S14_-62nq_ ____Þ!3!:>2J2-00___ 5964412_39 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Doyon #141 87.Oft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 117.91 degrees Bottom hole distance is 8122.21 Feet on azimuth 157.84 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ¥ ConocoPhillips ) ConocoPhillips AlasKa, Inc.,Slot #184 Pad 1 C, Kuparuk River Unit, North Slope, Alaska ) SURVEY U~ .ING Page 4 Well bore: 184 Wellpath: MWDw/IFR<0-11890'> Date Printed: 9-Feb-2004 r&i. BAKER HUGHES INTEQ Well path (GridtJ~eport _________._ MD[ft] Inc[deg] Azi[deg] TVD[ft] I North[ft] East[ft] Dogleg Vertical Easting -]Northing --------.------ -.. -------..---- ----.-----------.-------.--- -.-----.---..------_______._ ..__ ____.___.____._.._. _ __ LQª.Q{1QºftL._ .. _$.~QUºolf.t] ..... _. ___..._______.____________00_._. .. ..... .........__._....._._ ______. ._._ ... .ªº!;j_~_J_?~.1ß~. _._ .17_º,[_8 _~ª~P.3I.__ ·n~~,ºª8 _ __.~a1.?AJ!;_ _.~,ªJL.__... .4~7_0J~º.5J?º2J.4.ÆLJ__ Q~tº4~90.02 8789.57 89.91 176_99 3839_09 4429.388 2882_65E 1.79 4620.67 565220.53 5964263.78 .._Ji8_8J?A3..__ ._.~LQ,lQ_ 176.90 3a39..04 __:492~L1QS __2JU~Lª.H: _..0,-2900 Aº-1.Q.,þJ _5_ºQ~.2º-QQ_ 59Q4167.1.1 - .._8.!;j.ß)-,14.__ ~ºA~L__.. _.___Eß-,-Q~L _ _~__~~~t4!;j_n_ _. ..A.º-2l,29_$.__ .___2_~9_:L.2ª.I:___ __.____._.º,A~_ . 412QJl2 ....._Q.6.9.2_~2...Ilt _Q~.6.4_QIÇLQ_L _ 9078.84 89.91 177.39 3838.16 4718.22S 2898.23E 0.99 4769.64 565238.51 5963975.10 917ß.&ª__ . 8~.,!H __118..18. .3.ß38._2ª___. n4ªJE),l9.$ 2902.02E .OJ3.1 4818.85 565243.11 Q~6~8.ZZJ8. 9275.55 91.81 178.96 3836.78 4914.818 2904.48E 2.05 4867.19 565246.39 5963778.59 9368_64 91_62 179.54 3834.00 5007.858 2905.70E 0.66 4911.81 565248.38 5963685_57 9465_42 90.31 179.35 3832.37 5104.618 2906_63E 1.37 4957.93 565250.12 5963588.83 9564.11 90.43 180.35 3831.73 5203.308 2906.89E 1.02 5004.35 565251.20 5963490.16 __9jìJìQ,4º-_.. ___ _..~.º-'-~ª___._____..___..J.ª_Q'-9_º__ _____.~830.55 __Q2~1t~t4$ _ __.4_~tQ.tL1.3.I;____m____ .o.J'-t.____ .... 5Q48..ºª__ __.QJ3Q2Þ.1.23 º_9..6.~3~4,Q3 9756.58 92.00 178.55 3828.04 5395.728 2906.88E 2.34 5094.41 565252.78 5963297.77 _.JH~J.L~JL..92,--~Z.. ______J}!Lº.6.___. ..._3.ª.4Q,9.9..... _ __ .~49_QA!2$.nn __4_9._0ft!2º_I;.. :1.12..__.__º14t.~º____n .. ºßQ2!24,ªQ. .. n' __ _Q9.6~24q,º_º- _9._8.-º-2_LQ__ _.__ ._9JJ?º_.__.___. EZ,º9..._...._____3_81.4.:p.º_._._._. _n__ ._pÆ~.t.n.$.__ .___ _.___2!;UP-,-º_º-I;__._._. _ _.. .._.2,QJL.. ___9.:l4.2J_6___..._.___._Q.º~2§º}ß.____ ~9.º-~2()J ,8t_ ..._9..9.0.1:1:.19___._ ___8.9...8..8. _J]J',.9.º..38.2.~_,lQ.________QQ4LJQ$ _ 2912. IOE _n _ n.~A.1.QJ TI>A~__ .. .._Þºº2º!:J,13º..._. ._g9.9~.146.4º- S~þQ_,!1Þ. . _._9.0, 113_JJ.º.,4~ ..... .. __3.ª~~]~ ___ .___._Q_þ88 __928 2~J.!2.,2QE__._... m._ .1,8._9 _ .. QJ~2_,_2º_Qº9.2§_2_]0 .. Þ9.ß~:1º1J¡9 ... __..1 ºQ4Z,49__ _no. _ 8~_,-Q_8..____ . J]4.,~TJa.2.4.,.~.ß.. . ___Q.6.13!5,9_ß_S..__ . __2_9.;23J_13.I;._ ...._._._..__2_,22_._. ____Q.244:.P8.__. .... ___n!:5º9_2Z1A9. 5963007.67 lQJ 43,þ.1._ _. ... 8.9...91____ __JZZ,ª_9.._._._ ._~.a_4~AJL______Þ·La.1._4.4S.___~___2..~ªªß~I:~_ _.___._._1_º_2_.____ ..___.þ.4.9.1t7..8....._.. _____.. _. 5_Q.Q2a.2J14_____... .. n' ..._._..._º!:J_º.2.9..1.2.,.31. 1.0241.,1_4 __ 91.29172,(30.. _ _ 38..44..7.9. _587.8.28S 29..46J6.E. 1.795:3.159,01 Þº-!52.!:J§.QI_ ___Þ.9.ß2ßJQ,5_9 10287.05 91.35 174.50 3823.70 5923.89S 2951.32E 4.14 5380.91 565301.60 5962770.03 1Q337.25_ a8..º5 1}5..07 3_8.2~.70 Þß73,a88 . 29ÞQ,a.8.E .5.90Q4Qª.34_!5ºQ~09þ8 ___._Þßß.2Z2Q,Qß 10388.35 88.13 174.89 3825.14 6024.76S 2960.35E 1.08 5436.11 565311.47 5962669.25 10434.05 88_34 176.29 3826.55 6070_308 2963.86E 3.10 5460.53 565315.36 5962623.74 10530.71 89.45 176.18 3828.41 6166.73S 2970.21E 1.15 5511.27 565322_50 5962527_38 10627.53 89.79 176.15 3829.05 6263.348 2976.68E 0.35 5562.21 565329.78 5962430.84 ...__1ºZ2~L6º_._... _...ª-L3.~__. __ _ __.1I§_]Þ_._..__~_:lß2JUJ.._ ____º-3-ºº2_2$____ _._ ._...2.~_ª~.,.!54.I;_____._____.Lº_ª__.________Þ.QJª. 62~. _______!59_!5;3_:iL4.4__.__. __ . _ . __.º9.62.3.;HLQ~__.______ 10815.01 90.49 176.43 3826.68 6450.348 2989.70E 1.19 5661.25 565344_35 5962243.97 .1Qª-Q_!5,ß_Þ___._~JAZ_ ... ____Jlº-,4~t__ ___ª.~t2º~1;L_____ ___º_Þ1Q,l9.~L ____2.9-ª-º,~.4_!;__. _. .____.Lºª____. _. ._§Z()J~,ºZ_ ... m_ _!2ßÞ_:iQ.Q'z4... ...____ __._.Q9.º2_H?~_,ºª. _lQ9..9_º_:;3_Q_.____._.9_1J~..___....____ .E_º_,2ª-___ ___3ª.2.:3-'.º~L_.___._6_º~J_,£4~L._ .___~ºº-Lº9.J;_._ . _.__._._____QAl .___ _._!5I§§,99..._._ ._.. __. J'-º_!2ª!5Z:..24..___.______ ... ___._ !59.ß2-º_º_3,J.9 __JJ-ºª_ª,ªº__ .._. ..~.:L 13.4___.___.1.1.623___. .____ª82º-=-8._L_..__ .._...6Z 18 ,-º-Zs._.__.____ªººº-.,aJ!;____ _n__.._ ºJ~_L___.. ... .Qa_Q1,9.2_. _____._Q§§ªº_3,9_ª_______ _________º9._9J_ª-7.'_þJ;J,4_ ___.___ _._JJ_1Zß,-3~.__.__Jtt_ª.L._. ___Jl1.Q4.._ _. ____._.~.ª.lIJ~º_.._.__. ._-º-ª-1.P-=-8._9.s...__ _ ....____ªQl1..IÞI:____ ... _.. _.__J-'-Q.2___.__._._.._þ.ª_49._,!5.Q_......__.._.__9ß.§.~_º-~,~.ª_____. ..._.. ........_ __.__._þ.9_º-.1ß-ª3j1º-.._.__.. ."_ ... ....... J12º-L4_Q...____.....92-' º-~__ 177.95 __3_8J.4,ª.2 n______9_9..QLG.L8_.___;tQ19.:.2..Q.!;________.._QA_2__._____ __!5.8.9..ÞJ!.~L____.___._ . !:5.P_!5~.I~_,.º_4__.____ ___.__.____þ.9Q:1..Zª2,9..1..... ..____ - . JJ.3.!5þJ'_3.._. __ . !HtQ_ß________JIº_.2I_______3ßJ..3_..9._6____. __J?9..8._!:),9._2.$.___._ ._._~Q HtLPJ; _m_m__. __3._J~4._._. ... ____ 5940 .33 _____m_þ-º.§.3.?_a..ª~___.__. _ _ __mo. __9_96 tZº-4-'ZJ_n_____ -- _J_t4.4..EtOi.___ .J~~.Q.9_... _ ._ ..1.ZÞ-.~_a_..._ ___....3.ªJ_4J;J_3... m___.zQª-º,Q~S __ 3.Q2.§,2-ª1;.__ ._........ J..19.___. __ _.__9.9Jt8,.ª~._.. ____.___._º"Q9.3.ª-6Ji>______ .__. ._!59..tUß.14Jì.4.___..___ 11538.57 90.52 175.51 3814.76 7172.328 3033.63E 0.91 6038.02 565394.27 5961522.45 _._.1J.º-3:tª-º__._ 9..0A~L. ..__.__.11.~-,II._____ 3.81.~Jt3_ _I2ßZA~$.__. __:3JM_Q.I3.6J;_. _ 0.28______ J)Qª8.J~Þ__ __on... _ _5ß_Q.4º_2,3.L >_.. _p9614.2Z,.4J__ . 11682_38 89_29 175.41 3814.03 7315_718 3044_61E 2.57 6114.84 565406.43 5961379.17 11731.35 88.04 174.27 3815.17 7364.468 3049.01E 3_45 6141.55 565411.24 5961330.46 11827.99 88.56 175.02 3818.03 7460.64S 3058.02E 0.94 6194.53 565421.05 5961234.37 11840.22 88.68 175.15 3818.33 7472.828 3059.07E 1.45 6201.16 565422.20 5961222.20 n_.l1J~9º,QP__ -ªa_JH~______J7q_.1..Q__ no. ___ªª19A_L_ L__. Z_p2ZAJ~ ___.._~ººª_.2.~I;._ ... _. .__. 0-,0.0_ ___L_94_2!tPJLn. ____ __ . ººi>42IL82__ .______.____ ._Q~JUn~,_6_!2 All data is in Feet unless otherwise stated Coordinates are from 810t MD's are from Rig and TVD's are from Rig ( Doyon #141 87.0ft above mean sea level) Vertical 8ection is from O.OON O.OOE on azimuth 117.91 degrees Bottom hole distance is 8122.21 Feet on azimuth 157.84 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ConocriPhillips ) ConocoPhillips AlasKa, Inc.,Slot #184 Pad 1C, Kuparuk River Unit,North Slope, Alaska ). SURVEY u~ liNG Page 5 Wellbore: 184 Well path: MWDw/IFR<0-11890'> Date Printed: 9-Feb-2004 Comments -MRrft~-iß~çi:óJ·=~~t1·à1i·~N~.~b[~i~¿¿~4:i~J;ª~Uftl-3Qei¿~J~~~T~~~~~6ªiª·~~.Nº·.$.Œ8Y~Y·.·.·~-··- -. ...- ",". ."._~_,.".._..._._"__.".___~._.,, .._.... .0__"'.- ."'.....,.._..,_....".."...,._" ...__._".,_ ·_..·......""._M____",·._.._.·~_,,_" __,.."'.,,._ .._-_.."------_._,._--------~--_._-,-_.".,------_._...--..--. Hole Sections Diameter Start rinl MDrftl ._.__..._.___ 9718 63/4 Casinas Name __._'"._·__·...__._______._,w'..·.__..____._~___._.,,_._"'__~"._.____,,~__~."'_. .. _.~_._____,.._..__.,_~________.,___,.._w ..,...._.".._..R_'....,___..__..__,._..,.___,,_._......._..~....____w__.__._ Start Start Start End End End Start Well bore TVDrftl Northrttl Eastrftl MDfftl TVDrftl Northrftl Eastrftl Jt.Qº .... ... . _. ._______Q,Q.Q_ _. ___.___ _º_,º.9J~! _.______ºJJ..º-I;_..__._.___þߺ-8.JK 385...3-,2.º___.1.44~tI~ ~_~ 2ßJ:~~.JJ)_E: .184. 5808.0C 3853.2€ 1449.75S 2865.16E 11890.0C 3819.47 7522.41S 3063.28E 184 Top Top MDrftl TVDrftl JJLçQm!lJ.çt.QL_ __ __ __.m _JLQQ nn_____ _:U:¡!ª"_Ǫ~jDg__ . ._____ JLOQ . ._4J!2'~I,..iIJ~L_____ . Þ!HJtOÇ_.__ ,&¡. BAKER HUGHES .lNTEQ ...--...,...-..-.-.-..--.-.--.-....-.-- Top Top Shoe Shoe Shoe Shoe Northrftl Eastrftl MDrftl TVDrftl Northrftl Eastrftl _ ~Q,º.Q____ m_.º~Qº-~___~____ .n-º_,ººr; _______.._1.2_Q.,QÇ ___....120,00 .. .... ______Q.,QQN .. __ ._ __..oJ)Q ¡;. .H34...__ _ 0,.0.9 Q,QQN.__ O. OQ¡; .. ._.. .._ºZ~ª,QÇ ..__._..__3ª.Þ2,ª.C_..__.__1.13~,8.4~._ _._.._..48º_~!.~º'!;Jª~__..___._._._.___._______ .:38~ºA:Þ .129.2].1.9.._ 2.840.34E 1H~~º._QC .:3ßJ9AZ__. ]Þ22,41~_ 3063.28E 184 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Doyon #141 87.0ft above mean sea level) Vertical Section is from O.OON O_OOE on azimuth 117.91 degrees Bottom hole distance is 8122.21 Feet on azimuth 157.84 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated Wellbore ') ConocriP'hillips ) Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 October 13, 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-184 (APD # 203-089) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 1 C-184. If you have any questions regarding this matter, please contact me at 265-6830 or Steve Shultz at 263-4620. Sincerely, ~ \\,,~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad RECEI\/ED OCT ì 6 200~~:· .~Iaska Oil & Gas Cons. Commission .Anchorage OQIGINAL \ STATE OF ALASKA '\ ALA~ï,Á OIL AND GAS CONSERVATION COMr\.....,t;ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil [2] Gas U Plugged U Abandoned D 20AAC 25.105 GINJ D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a_ location of Well (Governmental Section): WINJ D WDSPl D No. of Completions _ Surface: 1571' FNL, 1294' FWL, Sec. 12, T11N, R10E, UM At Top Productive Horizon: 2355' FSL, 1144' FEL, Sec. 12, T11N, R10E, UM Total Depth: 3810' FNL, 936' FEL, Sec. 13, T11N, R10E, UM 4b. location of Well (State Base Plane Coordinates): Surface: x- 562302 ' y- TPI: x- 565155 y- Total Depth: x- 56541,á'1Þ I>~ y- 18. Directional Survey: Yes [2] NoU 5968669 . 5967338 5961176 . Zone-4 Zone-4 Zone-4 21_ logs Run: GR/Res 22. Suspended U WAG D 20AAC 25.110 Other 5. Date Comp., Susp., or Aband.: June 10, 2003 6. Date Spudded: May 28, 2003 ' 7. Date TD Reached: June 7,2003 " 8. KB Elevation (ft): RKB 28' / 87' AMSL 9. Plug Back Depth (MD + TVD): 11885' MD 1 3839' TVD 10. Total Depth (MD + TVD): 11890' MD 1 3840' TVD· 11. Depth where SSSV set: D' nipple @ 523' 19. Water Depth, if Offshore: N/A feet MSL CASING SIZE GRADE H-40 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 110' Surface 5798' 5643' 11885' WT. PER FT. 62.5# 29.7# 12.6# 16" 7.625" 4.5" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): pre-perforated 4.5" liner from 5835' - 11859' MD . 26. Date First Production September 29,2003 Date of Test Hours Tested 10/8/2003 12 hours Flow Tubing Casing Pressure press. 284 psi not available 27_ Test Period --> Calculated 24-Hour Rate -> HOLE SIZE 1b. Well Class: Development [2] Exploratory D Service D Stratigraphic Test D 12. Permit to Drill Number: 203-089 1 13. API Number: 50-029-23155-00 14. Well Name and Number: 1C-184 15. Field/Pool(s): Kuparuk River Field West Sak Oil Pool 16. Property Designation: ADL 25649 & 25650 17. land Use Permit: ALK 467 & 468 20. Thickness of Permafrost: 2440' MD 24" CEMENTING RECORD AMOUNT PUllED :-'..p"'....,~- '.. .' .,".".. - - '. f'·' ,. , I ~" :; b'~ ;Ò ~ CJ 3' : ·_--~-:~.Ã~:~~; c~ : -_.~~-~.~¿;p..,.~_. ~-,. Form 10-407 Revised 2/2003 CONTINUED ON REVERSE SIDE 9.875" 6.75" pre-perforated liner 540 sx AS Lite & 269 sx Class G Neat 24. SIZE 4.5" TUBING RECORD DEPTH SET (MD) 5643' PACKER SET (MD) 5654' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A WATER-BBl 65 WATER-BBl 130 CHOKE SIZE GAS-Oil RATIO 168 PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Water Jet Lift Oil Production for Oll-BBl GAS-MCF 431 54 Oll-BBl GAS-MCF 821 138 CORE DATA 100% Oil GRAVITY - API (corr) not available Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". NONE flQI0. INAL \.. ,.: I.,J RECEI\¡7ED OCT 1 6 20C~~ ,Alaska Oil & Gas Cons. Commission ,Anchorage Submit in duplicate tRBDMS B!FL OCT? .) G~ GEOLOGIC MARKERS ) 29. ') FORMATION TESTS 28. NAME MD TVD Include and briefly summarize test results. List inteIVals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1C~184 West Sak D 5715' 3865' N/A 1~' E'~C"'\ !.I'''-' ;r ¡~_ ~ t¡ , ,¡&' Ir,"'" '. L... ø ,\t rL~: ()[~1' :1 6 Af~$ka Oil & Gas Cons. ~'nchoraøf; 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve Shultz @ 263-4620 Printed N~, R. !homas._ Title: Signature \ ~\ \. ~'-'\..~e Kuparuk Drilling Team leader '2." S~ 6tl '3r 0 Date \t;J ({") 10, 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 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments, Item 13: The API number reported to AOGCC must be 14 digits (ex: 50~029~20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 1 0-407 Revised 2/2003 O r~ â """" ~ ì ,í'\ t ~ ~r \ji,! i' 1 l; , \ \1 i'\ \,,~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-184 1 C-184 ROT - DRILLING n1334@ppco.com Doyon 141 . . Hours Code Sub Code. Start: 5/27/2003 Rig Release: Rig Number: Spud Date: 5/28/2003 End: Group: DescriptibnolOperations 5/27/2003 10:00 - 12:00 2.00 MOVE MOVE MOVE Move Sub & Rig Modules off 1 C-170 and down pad. 12:00 - 13:00 1.00 MOVE POSN MOVE Spot & Level Sub over weIl1C-184. ( 180' move) 13:00 - 14:30 1.50 MOVE POSN MOVE Place matts & Spot all utility modules - Pits, Pump, Power & Boiler modules. 14:30 - 15:30 1.00 MOVE POSN MOVE Place matts & Spot both pipe shed modules - Spot & berm Rock washer module. 15:30 - 16:00 0.50 MOVE RURD RIGUP Hook up all service lines - Finish Rig accept list **NOTE"" Rig Accept 16:00 hrs 5/27/2003 16:00 - 18:30 2.50 DRILL PULD SURFAC Load pipe shed with 4" DP - Mixing Spud Mud - N/U Diverter Riser 18:30 - 19:30 1.00 DRILL RIRD SURFAC C/O Saver Sub on Top Drive 19:30 - 21 :30 2.DO DRILL PULD SURFAC Load pipe shed wI BHA tools & HWDP 21 :30 - 22:30 1.00 RIGMNT RSRV SURFAC Slip & Cut Drill line ( 59' cut) - Service Top Drive 22:30 - 00:00 1.50 DRILL PULD SURFAC P/U 4" Dp and Std Bk in derrick (14 stds @ Midnight) 5/28/2003 00:00 - 03: 15 3.25 DRILL PULD SURFAC Con't P/U 4" DP and std bk in derrick (total 55 stds in derrick) 03:15 - 05:15 2.00 DRILL PULD SURFAC P/U 10 stds HWDP wI jars & 1 std NMCSDP std bk in derrick 05: 15 - 05:30 0.25 WELCTL OTHR SURFAC Preform Diverter test - AOGCC John Spaulding waived witness test. 05:30 - 07:30 2.00 DRILL PULD SURFAC P/U BHA #1 ( Navidrill Mach 1 C wI 1.5? AKO) 07:30 - 07:45 0.25 DRILL SFTY SURFAC PJSM - Spill prevention & hazards while spudding 07:45 - 08:15 0.50 DRILL DRLG SURFAC Fill conductor and surface lines - Check system for leaks"OK" 08:15 - 09:30 1.25 DRILL DRLG SURFAC Drlg 9.875" hole fl 138' to 265' wI Navidrill,2 short NMCSDP, MWD, XO and using 1 std HWDP. Minimize flow rates to 350 gpm to minimize wash out under conductor 09:30 - 10:30 1.00 DRILL TRIP SURFAC Std Bk 1 std HWDP - P/U 1 Std NMCSDP 10:30 - 12:00 1.50 DRILL DRLG SURFAC Drlg,Slide & Survey 9.875" hole 265' to 400' MD' ART 1.2 hrs, AST 0.0 hrs, WOB 5-10 k, RPMs 80, PR 130 spm, 552 gpm, PP 1080 psi, Up wt 52k, Dn wt 52k, RW 52k, Mud wt 8.9 ppg, Vis 200 12:00 - 00:00 12.00 DRILL DRLG SURFAC Drlg,Slide & Survey 9.875" hole 400' to 1733' MD' (1692'TVD) KOP 624' - ART 4.7 hrs, AST 2.8 hrs, WOB 15-25k, RPMs 80, PR 120 spm, 509 gpm, PP 2500 psi, Up wt 81 k, Dn wt 80k, RW 82k, Torq on bttm 3k ft-Ibs, off bttm 2k ft-Ibs, Mud wt 9.1 + ppg, Vis 166. Had moderate show of Hidrates gas fl 850' to 1500' 5/29/2003 00:00 - 07:45 7.75 DRILL DRLG SURFAC Drlg,Slide & Survey 9.875" hole fl 1733' to 2574' MD' (2305'TVD) ART 2.3 hrs, AST 2.6 hrs, WOB 10-25k, RPMs 90, PR 130 spm, 552 gpm, PP 3100 psi, Up wt 89k, Dn wt 79k, RW 85k, Torq on bttm 3k ft-Ibs, off bttm 2k ft-Ibs, Mud wt 9.1 ppg, Vis 99. Drilling going well - No problems 07:45 - 09:15 1.50 DRILL CIRC SURFAC Pump Hi Vis Wt'd sweep - Circu hole clean - BU X 3+ (Total 7130 stks) Had a moderate show of cutting @ BU with sweep 09:15 - 12:00 2.75 DRILL TRIP SURFAC TOH to 175' - Had minor excess drag (15K)- No swab 12:00 - 13:00 1.00 DRILL TRIP SURFAC UD BHA #1 - UD MWD, Motor, Pony Collars, Bit - Std Bk NMCSDC's 13:00 - 13:15 0.25 DRILL TRIP SURFAC Grade Bit - Clean tools off floor 13:15 - 14:00 0.75 DRILL TRIP SURFAC P/U BHA #2 - P/U 2 part AutoTrak, rotate sleeve - M/U new MX-C1 14:00 - 14:30 0.50 DRILL TRIP SURFAC Program AutoTrak - H/U BPA manifold 14:30 - 15:00 0.50 DRILL TRIP SURFAC TIH wI BHA & HWDP to 900' 15:00 - 15:45 0.75 DRILL CIRC SURFAC Shallow Test AutoTrak "OK" - Actuate & Test BPA downlink"OK" 15:45 - 16:45 1.00 DRILL TRIP SURFAC TIH to 2558- No tight hole 16:45 - 17:30 0.75 DRILL CIRC SURFAC CBU - Downlink & Conn - Wash to Bttm 17:30 - 00:00 6.50 DRILL DRLG SURFAC Drlg wi AutoTrak 9.875" hole fl 2574' to 3116' MD' (2643'TVD) ART 4.5 hrs, WOB 5-20k, RPMs 130, PR 128 spm, 543 gpm, PP 2900 psi, Up wt 94k, Dn wt 77k, RW 87k, Torq on bttm 5k ft-Ibs, off bttm 3k ft-Ibs, Mud wt 9.2 ppg, Vis 94. No problems - AutoTrak working well. 5/30/2003 00:00 - 00:00 24.00 DRILL DRLG SURFAC Drlg wI AutoTrak 9.875" hole fl 3116' to 5104' MD' (3716'TVD) ART 17.3 hrs, WOB 5-20k, RPMs 140, PR 126 spm, 535 gpm, PP 3250 psi, Up wt 124k, Dn wt 78k, RW 98k, Torq on bttm 5-10k ft-Ibs, off bttm 5k Printed: 6/23/2003 4:14:50 PM ) Legal Well Name: 1 C-184 Common Well Name: 1 C-184 Spud Date: 5/28/2003 Event Name: ROT - DRILLING Start: 5/27/2003 End: Contractor Name: n1334@ppco.com Rig Release: Group: Rig Name: Doyon 141 Rig Number: Date From ."To Hours Code Sub Phase Descriþtion of Operations Code 5/30/2003 00:00 - 00:00 24.00 DRILL DRLG SURFAC ft-Ibs, Mud wt 9.3 ppg, Vis 96. Had hard spot @ 5100' - Very slow drilling 5100' to 5107' ( 2.1' TVD) Afterward ROP returned to 1 OO'+/hr - No other problems - AutoTrak working well. Av ROP for day 114.9 ft/hr 5/31/2003 00:00 - 12:00 12.00 DRILL DRLG SURFAC Drlg wi AutoTrak 9.875" hole fl 5104' to 5706' MD' (3861'TVD) ART 8.9 hrs, WOB 15-25k, RPMs 140, PR 120 spm, 509 gpm, PP 3200 psi, Up wt 120k, Dn wt 79k, RW 97k, Torq on bttm 6-10k ft-Ibs, off bttm 6-7k ft-Ibs, Mud wt 9.3 ppg, Vis 63. - ROP varied from 50 to 100 fph - AutoTrak working well. Av ROP for tour 67.6 ft/hr 12:00 - 16:00 4.00 DRILL DRLG SURFAC Drlg wi AutoTrak 9.875" hole fl 5706' to 5805' MD' (3874'TVD) ART 3.4 hrs, WOB 20-30k, RPMs 140, PR 124 spm, 526 gpm, PP 3250 psi, Up wt 118k, Dn wt 77k, RW 95k, Torq on bttm 6-10k ft-Ibs, off bttm 6-7k ft-Ibs, Mud wt 9.2 ppg, Vis 56. - Several hard spots were encountered between 5755' & 5795' - AutoTrak working well. Av ROP for tour 29.1 ft/hr - Survey & Downlink ribs in on tool 16:00 - 18:00 2.00 DRILL CIRC SURFAC Pump 35 bbl Wt/ Hi Vis sweep ( 12.0 ppg & 220 Vis) - Very small increase of cutting when sweep to surface - Circu hole clean - Total 3+ BUs - Clean @ shakers ( total 16,700 stks) 18:00 - 19:15 1.25 DRILL TRIP SURFAC Pre-cautionary back ream 10 stds OOH t/ 4890' - No excess drag or tight hole observed 19:15-22:45 3.50 DRILL TRIP SURFAC Observe well "Static" - Pump dry job - TOH t/156' - TOH on elevators - Minor to no excess drag - No swab - Hole fill correct as calculated 22:45 - 23:45 1.00 DRILL TRIP SURFAC UD BHA #2 - UD XOs, Stb, 3 NMCSDPs, Fit sub, Brk Bit 23:45 - 00:00 0.25 DRILL TRIP SURFAC Down Load AutoTrak - Clean & Grade bit - Clean Floor 6/1/2003 00:00 - 00:45 0.75 DRILL TRIP SURFAC Con't Download MWD - UD AutoTrak, Clear tools from floor. 00:45 - 02:00 1.25 CASE RURD SURFAC R/U to run 7.625" Surface Csg. 02:00 - 02:30 0.50 CASE SFTY SURFAC PJSM on running Csg -Review csg detail & hazard recognition with crew and contractors. 02:30 - 06:30 4.00 CASE RUNC SURFAC Run 7.625" 29.7# L80 BTCM csg to 3000'. 06:30 - 07:15 0.75 CASE CIRC SURFAC Circu @ 3000' circu 1760 stks (pipe volume 1380 stks). 07:15 - 10:00 2.75 CASE RUNC SURFAC Run 7.625" csg to 3158' Tight - Wash & work pipe fl 3158' to 3202'- Unable to work past 3202' MD. 10:00 - 11 :00 1.00 CASE RUNC SURFAC R/U to UD Csg - Mix and pump dry job - PJSM on laying dn csg - Driller discussed with each crew member his role and responsibility for task being preformed. 11 :00 - 12:00 1.00 CASE RUNC SURFAC UD 7.625" csg. t/2944' Up wt 115k, Dn wt 92k 12:00 - 12:15 0.25 CASE SFTY SURFAC Crew Change - PJSM wi new crew - Review known hazards - Discuss roles & responsibilities. 12:15 - 13:15 1.00 CASE RUNC SURFAC UD 7.625" csg fl 2944' to 2550' 13:15 - 14:00 0.75 CASE RURD SURFAC RID Franks fill tool & 350T Csg tools - R/U 150T csg tools ( YC elevators & hand slips). 14:00 - 20:15 6.25 CASE RUNC SURFAC UD 7.625" Csg - Bk jt out of top of float - M/U 10' pup & Std Bk FC & FS jts in derrick. 20:15 - 20:45 0.50 DRILL RIRD SURFAC RlU DP handling tools. 20:45 - 21 :15 0.50 DRILL PULD SURFAC P/U BHA #3 HO assy - P/U 9.875" HO, XO, Fit sub, stab, 1 NMCSDP, NM stab, 2 NMCSDP, XO, HWDP wi Jars. 21:15 - 22:15 1.00 DRILL TRIP SURFAC TIH wi HO t/3140' - Tight 10k set dn wt. 22: 15 - 23:00 0.75 DRILL REAM SURFAC Wash & Ream fl 3077' to 3357' - WOHO 3-5k, RPMs 140, PR 136 spm, 576 gpm, PP 2100 - Reams very easily will little to NO torq. Did not appear to have any ledges or shoulders.*** Note: Inspect box/pin connections on 7-5/8" csg and replace seal rings. 23:00 - 23:30 0.50 DRILL TRIP SURFAC TI H fl 3357' to 4130' - Tight 25k set dn wt. 23:30 - 00:00 0.50 DRILL REAM SURFAC Wash & Ream fl 41 05' to 4200' - WOHO 3-5k, RPMs 130, PR 120, 509 gpm, PP 1950 - Very little to NO torq - Mud coming back is very thick- Printed: 6/23/2003 4:14:50 PM .) ConocoPhillipsAlaska OperationsSl.lmm~ry. Report Moderate amount of oil showing in returns mud. PU-107K, SO-77K, ROT-87, TOon-4,000 ft-Ib. Wash & Ream fl 4198' to 4292' - WOHO 3-5k, RPMs 130, PR 100, 509 gpm, PP 1700 - Mud coming back is very thick - Oil show at shakers - PU-109K, SO-78K, ROT-87, TO on- 2-3k ft-Ib. 1.00 DRILL CIRC SURFAC Shakers overflowing - Losing mud - Circu @ reduced rate (2 bpm) - Change shaker screens to 150s on 2 shakers. ** Note** Poly Plus RD was used to viscosify the mud in too large a quantity and had an adverse reaction after reaching a high point of consentration. Mud men and pit watchers have been instructed NOT to use Poly Plus for general vis building of the mud system. TIH V 5693' - No problems - No tight hole. M/U Top Drive - Pre-Cautionary ream & wash to bttm fl 5693' to 5805' - No tight hole - No fill - No excess torq. Pump 30 bbl WVHi Vis sweep ( 12.0ppg & 170 vis) Circu until shakers are clean (Total 11 ,096 stks) 2+ BUs, Monitor well "STATIC", Pump dry job. TOH V 114' UD BHA #3 - UD NMCSDP, Stab's & HO - Clean all tools from rig floor. R/U to run 7.625 Csg - UD 10' pup used to std bk FC & FS jts. PJSM - Review csg running detail sheet - Review casing running checklist - Review known hazards - Review spill protection & cautions. Run 7.625" 29.7# L80 BTCM Csg (4 jts ) Con't running 7.625" csg V 2500' ( 58 jts) Circu Csg volume - Recip csg string - Work PR up to 6 bpm @ 300 psi Run 7.625" 29.7# L80 BTCM Csg 2500' to 3202' - ** Note ** Back at the TROUBLE point. Return to planned time on code. *** Lost 29 hrs 45 min total *** Con't running 7.625" csg fl 3202' to 5770', avg MU torque for csg= 8,000 ft-Ib. RID Franks fill tool - M/U Landing jt wI 7.625" hanger(19.5" flange). Land csg at 5,798', UWT=180K, DWT=100K. Circ and Cond, staging pumps up to 7 bpm and 400 psi. Circu total of 10,609 stks. Mud properities @ start 9.9 ppg, 79 Vis, PV 15, YP 17, Gels 8/20. After condt 9.5 ppg, Vis 40, PV 11, YP 12, Gels 4/7 Pump 10 bbl of CW-100 and test lines to 3,500 psi, pump 40 bbl of CW-100, 50 bbl of Spacer wI red dye, drop btm plug, pump 412 bbl of 10.7 ppg AS Lite III Lead cmt at 6 bpm. Con't CMT 7.625" Surface csg. - Pump 56 bbls 15.8ppg Tail slurry, drop top plug, and kick out wirh 20 bbls H20. Rig displace CMT wI 2785 stks treated mud. PR 6 bpm thru 2200 stks and reduce rate to 2 bpm to bump plug. Pressure @ bump 1000 psi, pressure up to 1500 and hold 5 min, bleed off, Floats held. (Calcu stks to bump 2806) CIP @ 01:22 hrs. Had 25 bbls 10.6+ CMT to surface- Surface csg shoe @ 5798' MD (3873' TVD) FC @ 5708' MD RID CMT head - UD Landing Jt - Remove cmt head and csg equip from rig floor. N/D Diverter system N/U & Install Csg head, Orient to flow line per tree drawing in well plan (ABB Vetco rep Trevor Job) N/U BOPs Test BOPs - Test Rams & Choke manifold valves to 250 I 5000 psi Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-184 1 C-184 ROT - DRILLING n 1334 @ ppco.com Doyon 141 Date . From -To Hours Code Sub Phase Code 6/1/2003 23:30 - 00:00 0.50 DRILL REAM SURFAC 6/2/2003 00:00 - 00:30 0.50 DRILL REAM SURFAC 00:30 - 01 :30 01 :30 - 02:15 0.75 DRILL TRIP SURFAC 02: 15 - 02:30 0.25 DRILL REAM SURFAC 02:30 - 04:30 2.00 DRILL CIRC SURFAC 04:30 - 08:00 3.50 DRILL TRIP SURFAC 08:00 - 09:30 1.50 DRILL TRIP SURFAC 09:30 - 11 :00 1.50 CASE RURD SURFAC 11 :00 - 11 :30 0.50 CASE SFTY SURFAC 11 :30 - 12:00 0.50 CASE RUNC SURFAC 12:00 - 14:30 2.50 CASE RUNC SURFAC 14:30 - 15:15 0.75 CASE CIRC SURFAC 15:15 - 15:45 0.50 CASE RUNC SURFAC 15:45 - 18:15 2.50 CASE RUNC SURFAC 18:15 - 18:45 0.50 CASE RURD SURFAC 18:45 - 22:00 3.25 CEMENT CI RC SURFAC 22:00 - 00:00 2.00 CEMENT PUMP SURFAC 6/3/2003 00:00 - 00:45 0.75 CEMENT PUMP SURFAC 00:45 - 01 :30 0.75 CEMENT DISP SURFAC 01 :30 - 03:00 1.50 CEMENT RURD SURFAC 03:00 - 05:00 2.00 WELCTL NUND SURFAC 05:00 - 06:00 1.00 WELCTL NUND SURFAC 06:00 - 09:00 3.00 WELCTL NUND SURFAC 09:00 - 13:30 4.50 WELCTL BOPE SURFAC Start: 5/27/2003 Rig Release: Rig Number: Spud Date: 5/28/2003 End: Group: Description of Operations···· Printed: 6/23/2003 4:14:50 PM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-184 1 C-184 ROT - DRILLING n1334@ppco.com Doyon 141 H· . 'C·.· ·d·' ..... Sub . ours> ··0.· e·· Code Start: Rig Release: Rig Number: 5/27/2003 Spud Date: 5/28/2003 End: Group: From~ To Phase .. Description of Operations 6/3/2003 09:00 - 13:30 4.50 WELCTL BOPE SURFAC Test Annular 2501 3500 psi. No failures - AOGCC rep Jeff Jones waived witness test. 13:30 - 14:00 0.50 WELCTL BOPE SURFAC Pull test jt - Install wear bushing - UD landing jt 14:00 - 21 :00 7.00 DRILL TRIP SURFAC TIH picking up singles out of pipe shed - Install 1 Lo Tad per stand and record serial numbers. ( 54 stds total 5211') 21 :00 - 23:30 2.50 DRILL TRIP SURFAC TOH & std bk in derrick 54 stds wI Lo Tads (DS) 23:30 - 00:00 0.50 DRILL PULD SURFAC Move 9 stds HWDP from ODS to DS of derrick. 6/4/2003 00:00 - 02:15 2.25 DRILL PULD SURFAC P/U Bit, Motor, MWD -Initialize MWD, orient tools, 3 NMCSDP, XO, 2 HWDP wI Jars - TIH - Bridge @ 165' 02:15 - 02:45 0.50 DRILL TRIP SURFAC TOH - Rack bk std HWDP - Pull BHA out @ examine bit - CMT present on bit & Turbo Back reamer. 02:45 - 03:15 0.50 DRILL TRIP SURFAC TIH wI BHA #4 V 165' 03:15 - 03:30 0.25 DRILL REAM SURFAC Wash and Ream 165' to 175' - Still can not freely TIH without rotating & pumping. 03:30 - 04:00 0.50 DRILL TRIP SURFAC TOH to P/U Mill tooth bit 04:00 - 06:00 2.00 DRILL TRIP SURFAC Consult Rig team - P/U Mill tooth bit on assy #5 - TIH V 175 06:00 - 06:30 0.50 DRILL REAM SURFAC Wash & Ream fl 175' to 347' - TIH wlo pumps to 441' no obstructions 06:30 - 07:30 1.00 DRILL TRIP SURFAC Std bk DP - P/U BHA #6 & TIH 07:30 - 10:15 2.75 DRILL PULD SURFAC TIH - P/U 30 singles out of pipe shed - Con't TIH wI DP from derrick to 5250' - Taking weight 5-10k 10:15 - 12:00 1.75 DRILL REAM SURFAC Wash & Ream to 5708', tag FC. 12:00 - 12:45 0.75 DRILL CIRC SURFAC Circu & Condt mud for Csg Test, PR 70 spm, 297gpm. 12:45 - 13:30 0.75 DRILL DEQT SURFAC Test 7.625' Csg to 3000 psi on chart for 30 min.- Lost 60 psi over 30 min 13:30 - 14:30 1.00 RIGMNT RSRV SURFAC Slip & Cut drill line ( 63' cut) - Service Top Drive 14:30 - 16:00 1.50 DRILL DRLG SURFAC Drlg FC, CMT, FS + 20' new hole V 5825' 16:00 - 16:30 0.50 DRILL CIRC SURFAC C/O mud to new 9.2 ppg Flo-Pro mud - Circu until uniform out & in. 16:30 - 17:00 0.50 DRILL LOT SURFAC Preform FIT to 12.5 EMW. 17:00 - 20:00 3.00 DRILL DRLG PROD Drlg,Slide & Survey 6.75" hole 5825' to 6043' MD (3874' TVD) ART 1.0 hrs, AST 0.5 hrs, WOB 3-1 Ok, RPMs 90, PP 1100, PR 70, 297gpm, Torq on bttm 4-5k ft-Ibs, off bttm 4k ft-Ibs. 20:00 - 20:45 0.75 DRILL SURV PROD Tool failed - The MWD failed to send up a survey within set quality standards at a time of 20:07 hrs. @ 6043'. The MWD engineer worked with the driller to change parameters such as flow and highside toolface of the MWD tool in order to obtain an acceptable survey. Flow rates were decreased from 300 gpm to 275 gpm,as it was suspected that movement in the pipe was causing G total values to occur out of specifications. The pipe was also worked in-between surveys and rotated in the event that it would work torsion out of the drill string and decrease the possibility that string movement was causing the invalid surveys. An eventual increase in flow to 320 gpm allowed the MWD tool to take a valid survey at 20:40 hrs. Spect low flow rates and pipe movement. 20:45 - 00:00 3.25 DRILL DRLG PROD Drlg,Slide & Survey 6.75" hole 6043' to 6324' MD (3874' TVD) ART 1.1 hrs, AST 0.5 hrs, WOB 3-1 Ok, RPMs 90, PP 1100, PR 70, 297gpm, Torq on bttm 4-5k ft-Ibs, off bttm 4k ft-Ibs. Up wt 95, DN wt 67, RW 83 6/5/2003 00:00 - 12:00 12.00 DRILL DRLG PROD Drlg, Slide & Survey fl 6324' to 7678' MD (3871' TVD) ART 7.4, AST 0.0, WOB 1-5k, RPMs 90/100, PR 70 spm, 297 gpm, PP 1500 psi, Up wt 97k, Dn wt 63k, RW 81 k, Torq on bttm 5k ft-Ibs, Off bttm 6K ft-Ibs 12:00 - 00:00 12.00 DRILL DRLG PROD Drlg, Slide & Survey fl 7678' to 9032' MD (3859' TVD) ART 6.2, AST 0.8, WOB 1-15k, RPMs 90/100, PR 70 spm, 297 gpm, PP 1550 psi, Up wt 103k, Dn wt 56k, RW 82k, Torq on bttm 7k ft-Ibs, Off bttm 6K ft-Ibs. *** NOTE** After brining the pumps up for a survey at 20:15 hrs on Printed: 6/23/2003 4: 14:50 PM Legal Well Name: 1 C-184 Common Well Name: 1 C-184 Spud Date: 5/28/2003 Event Name: ROT - DRILLING Start: 5/27/2003 End: Contractor Name: n1334@ppco.com Rig Release: Group: Rig Name: Doyon 141 Rig Number: FrOm;. To Hours Code Sub Phase Description of Operations. Code 6/5/2003 12:00 - 00:00 12.00 DRILL DRLG PROD June 5,2003 at a measured depth of 8,645 feet the MWD tool failed to pulse. The MWD engineers worked with the driller by having him increase the flow from 300 gpm to 320 gpm and work the pipe several times between survey attempts. The MWD engineer also requested that the driller bring the pumps up quickly on two attempts and slowly on one attempt. After working with these variables several times, a slow increase in flow to 320 gpm proved to work and the MWD tool began pulsing again. A survey was then taken at 20:39 hrs. Suspect low flow rates/possible pulser blockage. 6/6/2003 00:00 - 00:30 0.50 DRILL CIRC PROD Circu & Condition - Pump up Survey - Stop pump & Monitor well "Static" 00:30 - 03:45 3.25 DRILL TRIP PROD Back ream f/9032' to 5810' -PR 70 spm, 297 gpm, 90 RPMs - No problems encountered - No excess torq or drag noted - Recorded Up & Dn Wt every 5 stds on TOH, for T&D data. 03:45 - 04:30 0.75 DRILL CIRC PROD CBU X 2 - PR 70 spm, 297 gpm, 90 RPMs - Spot 35bb118% lube pill in csg. Pill properties = 26 bbls mud, 2 drums FloLube, 1 drum LubeTex, 1 drum Drilzone, 3 bbls H20, 2 sxs KCL & S200 for 9.2 ppg wt 04:30 - 04:45 0.25 RIGMNT RSRV PROD Finish Service on Top Drive & Rig - Ck & Service brake linkage ( Did most of service on rig while pumping BUs & spotting pill) 04:45 - 06:00 1.25 DRILL TRIP PROD TIH t/ 8935' - No Tight hole - No problems 06:00 - 06:15 0.25 DRILL REAM PROD Wash & Ream to bttm 8935' to 9032' - No fill noted 06:15 - 12:00 5.75 DRILL DRLG PROD Drlg,Slide & Survey 6.75" hole f/9032' to 9612' MD (3852' TVD) ART 3.7 hrs, AST 0.0 hrs, WOB 5-1 Ok, RPMs 90/100, PR 70 spm, 297 gpm, Up wt 115, Dn wt 61, RW 87, Torq on bttm 6000k ft-Ibs, Off bttm 7000k ft-Ibs, Mud wt 9.2 ppg, 54 Vis - Drilling going well - Dir control good - Resistivity 36 - 42 ohms 12:00 - 00:00 12.00 DRILL DRLG PROD Drlg,Slide & Survey 6.75" hole f/9612' to 10,773" MD (3848' TVD) ART 6.1 hrs, AST 1.4 hrs , WOB 5-1 Ok, RPMs 90/100, PR 70 spm, 297 gpm, PP 1700, Torq on bttm 9k ft-Ibs, off-8k ft-Ibs, Mud wt 9.2 ppg, 54 Vis - Drilling going well -No problems with dir control, Resistivity running 30 - 50 ohms, with mostly 36 to 42 readings. 617/2003 00:00 - 12:00 12.00 DRILL DRLG PROD Drlg,Slide & Survey 6.75" hole f/1 0,773' to 11,683' MD (3834' TVD) ART 5.5 hrs, AST 0.8 hrs, WOB 3/1 Ok, RPMs 90/100, PR 70 spm, 297 gpm, PP 2000 psi, Up wt 135k, Dn wt 63k, RW 101k, Torq on bttm 9k ft-Ibs, Off bttm 9k ft-Ibs, Mud wt 9.2, Vis 56 - Drilling going well - Sliding is very easy, no problems what so ever. 12:00 - 13:30 1.50 DRILL DRLG PROD Drlg,Slide & Survey 6.75" hole f/11 ,683' to 11,890' MD (33840' TVD) ART 1.0 hrs, AST 0.2 hrs, WOB 3/5k, RPMs 100, PR 70 spm, 297 gpm, PP 2000 psi, Up wt 135k, Dn wt 61k, RW 95k, Torq on bttm 9k ft-Ibs, Off bttm 8k ft-Ibs, Mud wt 9.2, Vis 55 - Drilling & Sliding going well - No problems observered. 13:30 - 14:30 1.00 DRILL CIRC PROD Survey - Pump Wt / Hi Vis Sweep ( 11.2 ppg @ 120 Vis - CBU - (Had minor show of increase in cuttings @ BU) Monitor well for flow "Static" 14:30 - 21 :00 6.50 DRILL TRIP PROD Back ream to surface shoe - Rates used, 70 spm, 297 gpm, 90 RPMS - No tight hole observed -No problems - Record T & D each 5 stds for data. 21 :00 - 22:45 1.75 DRILL CIRC PROD @ Shoe - CBU X 2 until shakers clean - Pump Lub pill - Lube pill properties- 30 bbls Flo Pro mud, 1.3 bbls LubeTex, 1.3 bbls FloLube, 1.3 bbls DrillZone ( 34 bbl pill @ 15% Lubricants) EMS tool was dropped after pumping the lube pill and pumped to bttm with the dry job). Lub pill is spotted across the csg. Blow dn Top Drive 22:45 - 00:00 1.25 DRILL TRIP PROD TOH on elevators to 3150' - Std Bk Lo Tads in derrick, DS. Printed: 6/23/2003 4: 14:50 PM .) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-184 1 C-184 ROT - DRILLING n1334@ppco.com Doyon 141 Date From- To Hours Code Sub Phase Code 6/8/2003 00:00 - 01 :30 01 :30 - 03:30 03:30 - 04:00 04:00 - 04:15 04:15 - 05:30 05:30 - 06:30 06:30 - 09:30 09:30 - 10:00 10:00 - 12:00 12:00 - 13:00 13:00 - 13:45 13:45 - 14:30 14:30 - 23:15 23:15 - 00:00 6/9/2003 00:00 - 00:45 00:45 - 02:30 02:30 - 04:00 04:00 - 04:15 04:15 - 08:45 08:45 - 09: 15 09:15-11:00 11 :00 - 11: 15 11:15 - 12:00 12:00 - 21 :00 1.50 DRILL 2.00 DRILL TRIP PROD PULD PROD 0.50 CASE 0.25 CASE RURD CMPL TN SFTY CMPL TN 1.25 CASE 1.00 CASE PUTB CMPL TN OTHR CMPL TN 3.00 CASE PUTB CMPL TN 0.50 CASE 2.00 CASE 1.00 CASE PUTB CMPL TN RUNL CMPL TN RUNC CMPL TN 0.75 CASE CIRC CMPLTN 0.75 CASE CIRC CMPL TN 8.75 CASE CMPL TN 0.75 DRILL TRIP CMPL TN 0.75 DRILL 1.75 DRILL 1.50 DRILL PULD CMPLTN TRIP CMPLTN CI RC CMPL TN 0.25 WELCTL OBSV 4.50 DRILL TRIP 0.50 CMPL TN RURD 1.75 CMPL TN RUNT 0.25 CMPL TN SFTY CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN 0.75 CMPL TN RUNT CMPL TN 9.00 CMPL TN RUNT CMPL TN Start: 5/27/2003 Rig Release: Rig Number: Spud Date: 5/28/2003 End: Group: Con't TOH to 253' UD BHA - UD std 4" HWDP wI jars, 3 NMCSDP, EMS tool, brk bit, turbo bk stab, Dn load MWD, UD MWD & Motor. RIU Csg tools to run 4.5" 12.6# L80 NSCT liner PJSM - Review csg running detail - Discuss known hazards - Driller discuss each mans role & responsibility Run 4.5" 12.6# L80 NSCT liner to 2005' Tour Pusher advised CPAI Co rep that we had a crew member that was DOWN in the pipe shed. He complained of chest pain and was having trouble breathing. The CPAI Co rep immediately called the Emergency res ponce unit @ KOC (5:34 AM), they arrived @ 5:50 AM and attended to the crew member. He was breathing on his own and talking at this point. The EMTs transported him to the KOC clinic for further evaluation,leaving the location @ 6:25 AM ( Later it was reported he had had an Azmatic Bronchitis attack. The tool pusher sent him in so he could see his doctor.He was transported to Anchorage.) Con't to Run 4.5" 12.6# L80 NSCT liner to 6205' - 5 min rotary table PJSM wI Baker rep. P/U & MIU Baker Liner Hanger tools wI Baker Rep Con't running liner on DP to 9155' ( DP has 1 Lo Tad per std) Con't running liner on DP to 11,890' ( used 50 stds DP wI Lo Tads + 9 stds Push Pipe ( 1 HWDP + 2 SWDCs) Up wt 120k, Dn wt 83k Tag up @ 11,890' to verify bttm. Pick up to 11,885' Drop Ball - Circu to bttm @ 2 bpm, 400 psi - With ball on seat pressure up to 1800 psi to set hanger, continue pressure up to 3000 psi to release hanger& Set packer. Had indication of set - P/U off hanger. Top of tie back sleeve @ 5643.43' Circu BU @ 70 spm, 870 psi - Pump dry job - Blow dn top drive. TOH - UD 9 stds push pipe ( std = 1 HWDP + 2 SWDCs) , 150 jts Dp, 50 Lo Tads - Make service breaks on Baker running tool and UD same. Clean tools from rig floor. TIH wI DP from derrick to 470' ( UD 4 Lo Tads that were in derrick stds) Have total 65 stds left DP in derrick. *** Note*** We have been seeing the injection pressure slowly coming up in the annulus pumping from @ 2 bpm , 1000 to 1350 psi to 2 bpm ,1400 to 1600 psi. It is also hard to start back to injection after it has set from a time.At one point it took 2150 psi to get it to moving (we had 400psi on tbg). At this time we are going to pump a large H20 flush (400 or 500 bbls or until it cleans up) We suspect polymers from the mud may be the problem??? UD 5 stds Dp TIH wI 4" DP from derrick to 5646' Circu 290 bbls sea water and displace over to 9.2 ppg brine. (230 bbls 9.2 ppg brine) Monitor well for 15 min "Static" TOH UD all 4" DP - Clear tools from rig floor Pull wear bushing R/U to run 4.5" completion Tbg PJSM - Review tbg running detail - Review known hazards - Driller discuss roles & responsibility of each man Run 4.5" 12.6# L80 NSCT completion Con't to run 4.5" 12.6# L80 NSCT completion - Install a cannon clamp on gauge wire each joint. Ran 181 jts tgb to tag, Ran 163 across collar Printed: 6/23/2003 4:14:50 PM ") Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . QonoboPhillips Alaska Operations>Sumrnary..R~port 1 C-184 1 C-184 ROT - DRILLING n1334@ppco.com Doyon 141 Date . From .~ To Hours Code. Sub Phase Code 6/9/2003 12:00 - 21 :00 21 :00 - 22:00 22:00 - 23:00 6/1 0/2003 23:00 - 00:00 00:00 - 01 :00 01 :00 - 02:00 02:00 - 02:30 02:30 - 04:00 04:00 - 05:00 05:00 - 06:00 06:00 - 07:00 07:00 - 08:00 9.00 CMPL TN RUNT CMPL TN 1.00 CMPL TN SOHO CMPL TN 1.00 CMPL TN SOHO CMPL TN 1.00 CMPL TN NUND CMPL TN 1.00 WELCTL NUND DEMOB 1.00 WELCTL NUND CMPL TN 0.50 CMPL TN FRZP CMPL TN 1.50 CMPL TN FRZP CMPL TN 1.00 CMPL TN FRZP CMPL TN 1.00 CMPL TN NUND CMPL TN 1.00 CMPL TN NUND CMPL TN 1.00 CMPL TN OTHR CMPL TN Start: 5/27/2003 Rig Release: Rig Number: Spud Date: 5/28/2003 End: Group: Descriþtion .ofOperations cannon clamps, 10 mid joint clamps. Tag up @ 5644' - Space out - UD 2 jts tgb - M/U tbg hanger Leaves 179 jts in string) Land tbg - Seal are spaced 3.83' above no-go.- RILDS - UD landing jt- Install TWC C/O Bttm rams to 5" Dp - Start N/D BOPs ND BOPE. NU tree & test t/5000 psi for 5 min. Pull TWC & RU circulating lines. Pressure annulus t/2500 psi hold f/30 min. Pressure to 3000 to shear RP valve and freeze protect with 90 bbl dsl. U- Tube to balance. RU Lubricator and install BPV. Install actuator valve. Clean out rockwasher and cellar. RELEASE RIG 6/11/03 0800 HRS. Printed: 6/23/2003 4: 14:50 PM ) ) conocoPhillips Alaska, Inc. Pad lC 184 slot #184 Kuparuk River Unit North Slope, Alaska SUR V E Y LIS TIN G by Baker Hughes INTEQ Your ref Our ref License MWD wi IFR <0-11890'> svy6924 Date printed Date created Last revised 16-Jun-2003 29-May-2003 8-Jun-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 29.729,w149 29 41.311 Slot Grid coordinates are N 5968668.640, E 562301.715' Slot local coordinates are 1570.22 S 1295.48 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ') ConocoPhillips Alaska, Inc. Pad IC,184 Kuparuk River Unit, North 5lope, Alaska Measured Inclin Depth Degrees 0.00 120.00 206.00 295.00 382.83 474.18 564.37 655.72 749.38 839.24 929.61 1017.93 1112.18 1205.98 1299.08 1390.86 1486.03 1578.87 1672.40 1766.84 1859.99 1953.44 2045.58 2140.19 2231.42 2325.71 2420.68 2513.80 2603.48 2695.42 2789.07 2881.68 2976.12 3069.50 3163.06 3256.67 3350.70 3443.06 3536.43 3629.83 3723.38 3817.39 3910.68 4003.74 4097.60 4191. 03 4284.02 4377.33 4471.23 4564.22 7.06 7.20 9.75 11.95 14_22 17.10 20.62 24_76 27.75 29.60 32.19 36.58 39.85 43.43 47.80 50.14 50.27 52.00 51.29 51.45 51.34 51.33 51.36 52.17 51.88 51.88 51.82 51.88 51.78 51.90 51.90 51.85 52.75 53.34 54.37 55.65 57.44 59.70 60.42 58.82 Azimuth Degrees 0.00 0.00 0.62 0.46 0.91 0.00 0.00 150.97 145.39 142.26 True Vert Depth 0.00 120.00 206.00 294.99 382.82 474.15 564.32 655.62 749.03 838.37 928.10 1015.73 1108.95 1201. 07 1291.75 1380.11 1470.16 1555.80 1639.67 1722.52 1802.45 1879.55 1951.94 2022.63 2086.43 2148.32 2209.11 2267.54 2323.19 2380.59 2439.02 2496.88 2555.87 2613.66 2671.23 2729.02 2787.11 2844.16 2901.86 2959.57 3017.29 3075.33 3132.41 3188.39 3243.78 3297.37 3348.65 3397.31 3444.18 3491.20 R E C TAN G U L A R COO R DIN ATE 5 O.OON O.OON 0.415 1.125 1. 965 3.365 4.505 4.385 2.735 0.255 2.39N 4.93N 8.05N 11 .3 9N 13.65N 14.22N 13.39N 11 .62N 9.70N 7.69N 5.27N 2.00N 1.105 4.275 8.245 12.145 16.135 20.085 23.385 26.975 31.735 37.955 46.165 55.415 64.895 75.205 86.515 98.075 109.865 121.155 132.605 144.335 159.265 181.815 212.165 248_245 289.885 336.575 386.205 435.725 O.OOE O.OOE 0.23E 0.66E 1.29E 2.35E 3.71E 6.55E 13.11E 22.39E 32.85E 43.51E 57.05E 74.38E 95.30E 120.05E 150.80E 186.56E 227.88E 273.15E 320.92E 373.57E 430.48E 493.25E 558.31E 629.32E 702.18E 774.58E 844.83E 916.56E 989.59E 1061.62E 1134.91E 1207.67E 1280.81E 1353.73E 1426.81E 1498.51E 1570.96E 1643.53E 1716.25E 1789.27E 1861.51E 1932.30E 2001.69E 2069.17E 2134.58E 2199.06E 2263.54E 2326.65E ) 5URVEY LI5TING Page 1 Your ref MWD wi IFR <0-11890'> Last revised 8-Jun-2003 Dogleg Degl1 00 ft 0.00 0.00 0.72 0.19 0.51 0.42 0.70 2.12 3.16 1. 15 3.65 5.39 7.84 12.86 19.90 Vert 5ect G RID Easting COO R D 5 Northing 5968668.64 5968668.64 5968668.24 5968667.52 5968666.69 5968665.30 5968664.17 5968664.31 5968666.02 5968668.57 5968671.30 5968673.93 5968677.15 5968680.63 5968683.06 5968683.84 5968683.25 5968681.77 5968680.19 5968678.55 5968676.52 5968673.67 5968671.04 5968668.38 5968664.94 5968661.62 5968658.22 5968654.86 5968652.13 5968649.12 5968644.96 5968639.32 5968631.71 5968623.05 5968614.17 5968604.46 5968593.74 5968582.77 5968571.57 5968560.87 5968550.01 5968538.87 5968524.54 5968502.56 5968472.78 5968437.25 5968396.15 5968349.99 5968300.89 5968251.89 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #184 and TVD from RKB(Doyon 141) (87.10 Ft above mean sea level). Bottom hole distance is 8114.57 on azimuth 157.89 degrees from wellhead. Vertical section is from wellhead on azimuth 117.91 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 1. 29 1. 04 2.67 5.62 6.65 142.86 114.11 77.58 75.02 75.07 76.52 76.70 77.28 80.58 86.58 90.42 92.50 93.12 92.24 92.83 92.95 94.11 92 .18 93.56 9~.43 92.86 93.42 92.83 92.55 93.18 94.27 95.61 97.17 97.32 97.45 98.64 98.96 99.35 99.14 98.55 99.35 98.90 104.41 110.91 116.30 119.94 124.97 126.82 128.35 127.88 0.49 0.16 2.71 2.44 2.84 27.91 36.14 46.65 60.40 77.83 3.33 3.76 4.47 3.22 1. 98 99.44 127.00 159.43 196.85 237.79 2.78 4.75 3.78 3.91 4.79 281.13 329.20 380.93 437.89 497.24 2.52 0.47 1.92 0.83 0.56 561.83 628.08 693.91 757.53 822.61 0.92 1.13 1. 29 0.88 0.33 889.37 955.94 1024.55 1093.18 1162.25 1. 00 0.28 0.34 0.21 0.51 1231.52 1301. 39 1370.16 1439.71 1509.12 0.67 0.38 4.77 5.62 4.76 1578.75 1648.76 1719.59 1792.70 1868.23 3.47 4.91 2.95 1. 61 1. 77 1944.75 2022.05 2100.88 2181.09 2260.03 0.00 0.00 0.39 1.11 2.06 562301.72 562301.72 562301.94 562302.39 562303.02 562304.10 562305.47 562308.30 562314.85 562324.10 562334.54 562345.18 562358.69 562375.99 562396.89 562421.64 562452.38 562488.15 562529.49 562574.77 562622.55 562675.23 562732.14 562794.93 562860.02 562931.06 563003.94 563076.36 563146.62 563218.37 563291.43 563363.51 563436.86 563509.68 563582.89 563655.88 563729.04 563800.83 563873.37 563946.02 564018.82 564091.93 564164.28 564235.24 564304.88 564372.64 564438.38 564503.23 564568.10 564631.61 ') ConocoPhillips Alaska, Inc. Pad 1C,184 Kuparuk River Unit, North 5lope, Alaska Measured Inclin Depth Degrees Azimuth Degrees 4657.40 4751.14 4844.25 4938.21 5032.09 5125.79 5218.87 5312.39 5406.20 5499.24 5592.01 5685.60 5757.66 5852.05 5900.94 5947.85 5994.38 6041.11 6087.60 6132.20 6181. 32 6226.08 6275.43 6326.49 6372.26 6469.07 6565.55 6662.92 6759.52 6856.26 6950_87 7049.16 7146.62 7242.96 7339.89 7434.51 7533.33 7629.36 7725.97 7758.73 7822.49 7917.81 8014.51 8111.59 8209.83 8260.78 8306.15 8360.98 8403.36 8499.61 60.95 63.97 66.21 67.99 69.34 69.29 71. 02 72.66 74.75 79.59 81. 59 81.31 84.67 89.91 91. 32 89.66 89.17 88.89 90.56 90.06 90.25 89.97 88.95 89.57 89.97 90.31 91.13 89.85 89.69 91.66 90.31 90.15 89.36 89.57 90.18 90.25 91.59 90.00 90.83 91. 50 90.80 89.79 88.80 89.14 91.29 130.66 132.82 137.98 142.94 147.11 151.47 155.30 158_52 159.85 163.28 166.42 169.96 171. 98 173.54 174.96 175.85 175.83 178.34 179_35 179.91 180.09 179.38 178.47 179.31 179.82 179.37 180.43 180.87 181.41 180.81 180.11 180.70 180.34 181.18 180.75 182.15 182.53 183.05 181. 90 181.26 179.55 178.56 178.83 179.86 179.94 92.00 91.17 90.40 90.37 90.80 17 9.62 179.63 179.29 179_18 178.31 True Vert Depth 3537.96 3581.30 3620.54 3657.12 3691. 29 3724.40 3756.00 3785.16 3811.48 3832.14 3847.31 3861.23 3870.02 3874.48 3873.96 3873.56 3874.03 3874.82 3875.05 3874.81 3874.67 3874.59 3875.05 3875.71 3875.90 3875.66 3874.45 3873.61 3874.00 3872.86 3871.24 3870.84 3871.26 3872.16 3872.37 3872.01 3870.43 3869.09 3868.39 3867.73 3866.45 3865.96 3867.15 3868.89 3868.52 3867.06 3865.81 3865.06 3864.77 3863.79 R E C TAN G U L A R COO R DIN ATE S 486.745 542.095 602.215 668.945 740.585 815.935 894.195 975.925 1060.085 1146.115 1234.445 1325.015 1395.635 1489.138 1537.778 1584.538 1630.935 1677.595 1724.075 1768.675 1817.795 1862.545 1911.888 1962.938 2008.708 2105.505 2201.978 2299.338 2395.918 2492.628 2587.215 2685.505 2782.958 2879.288 2976.198 3070.785 3169.508 3265.418 3361.928 3394.665 3458.408 3553.718 3650.378 3747.435 3845.668 3896.595 3941.948 3996.765 4039.145 4135.365 2389.03E 2451.02E 2510.26E 2565.32E 2615.42E 2660.17E 2699.37E 2734.20E 2766.19E 2794_84E 2818.75E 2837.69E 2848.91E 2860.78E 2865.68E 2869.44~ 2872.81E 2875.19E 2876.12E 2876.41E 2876.41E 2876.62E 2877.54E 2878.53E 2878.88E 2879.57E 2879.73E 2878.63E 2876.71E 2874.83E 2874.07E 2873.38E 2872.50E 2871.22E 2869_58E 2867.19E 2863.16E 2858.48E 2854.31E 2853.41E 2852.96E 2854.53E 2856.73E 2857.84E 2858.01E 2858.21E 2858.50E 2859.02E 2859.59E 2861.70E Dogleg Deg/lOOft 8URVEY LI8TING Your ref Last revised 3.45 3.81 5.57 5.22 4.38 2339.04 2419.72 2500.21 2580.10 2657.90 ) Page 2 MWD wi IFR <0-11890'> 8-Jun-2003 Vert 5ect G RID Easting COO R D 8 Northing 5968201.38 5968146.55 5968086.92 5968020.64 5967949.41 5967874.44 5967796.51 5967715.07 5967631.18 5967545.40 5967457.28 5967366.87 5967296.35 5967202.96 5967154_36 5967107.65 5967061.27 5967014.64 5966968.18 5966923.59 5966874.47 5966829.72 5966780.40 5966729.37 5966683.61 5966586.82 5966490.36 5966393.01 5966296.42 5966199.71 5966105.13 5966006.85 5965909.40 5965813.07 5965716.16 5965621.56 5965522.82 5965426.89 5965330.36 5965297.61 5965233.87 5965138.60 5965041.96 5964944.93 5964846.71 5964795.79 5964750.44 5964695.63 5964653.27 5964557.08 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #184 and TVD from RKB(Doyon 141) (87.10 Ft above mean sea level). Bottom hole distance is 8114.57 on azimuth 157.89 degrees from wellhead. Vertical section is from wellhead on azimuth 117.91 degrees. Grid is alaska - Zone 4_ Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 4.35 4.29 3.71 2.61 6.32 2732.71 2803.98 2873.02 2940.67 3006.25 3.97 3.75 5.43 5.79 4.09 3068.72 3127.85 3170.81 3225.07 3252.16 4.02 1. 05 5.40 4.20 1. 68 3277.36 3302.06 3326.00 3348.58 3369.71 0.53 1.71 2.77 2.04 1. 42 3392.69 3413.83 3437.73 3462.50 3484.23 0.58 1. 39 1. 39 0.58 2.13 3530.14 3575.44 3620.02 3663.53 3707.13 1. 61 0.62 0.89 0.90 0.77 3750.73 3796.12 3840.94 3884.90 3928.81 1. 48 1. 41 1. 74 1.47 2.83 3970.96 4013.60 4054.36 4095.84 4110.36 2.90 1. 48 1. 06 1. 12 2.19 4139.80 4185.79 4232.98 4279.38 4325.51 1. 53 1. 83 1. 54 0_27 1. 01 4349.52 4371.00 4397.12 4417.45 4464.35 564694.39 564756.83 564816.55 564872.14 564922.82 564968.18 565008.01 565043.50 565076.17 565105.51 565130.13 565149.81 565161.60 565174.23 565179.52 565183.66 565187.41 565190.17 565191.48 565192.13 565192.53 565193.10 565194.43 565195.84 565196.55 565198.03 565198.98 565198.67 565197.53 565196.44 565196.45 565196.56 565196.46 565195.97 565195.12 565193.50 565190.27 565186.37 565182.99 565182.35 565182.42 565184.77 565187.75 565189.65 565190.62 565191.23 565191.90 565192.86 565193.77 565196.66 ') ) ConocoPhi11ips Alaska, Inc. 8URVEY LI8TING Page 3 Pad 1C,184 Your ref MWD wi IFR <0-11890' > Kuparuk River Unit, North 810pe, Alaska Last revised 8-Jun-2003 Measured Inc1in Azimuth True Vert R E C T A N G U L A R Dogleg Vert G RID C o 0 R D 8 Depth Degrees Degrees Depth C 0 0 R D I N A T E 8 Deg/lOOft 8ect Easting Northing 8597.07 90.71 178.28 3862.50 4232.778 2864.59E 0.10 4512.50 565200.35 5964459.70 8640.66 90.98 178.72 3861.86 4276.348 2865.74E 1. 18 4533.90 565201.85 5964416.15 8693.12 91.62 176.78 3860.67 4328.748 2867.79E 3.89 4560.24 565204.33 5964363.77 8789.57 89.91 176.99 3859.38 4425.048 2873.04E 1. 79 4609.94 565210.35 5964267.53 8886.43 90.15 176.90 3859.33 4521.768 2878.20E 0.26 4659.77 565216.30 5964170.86 8983.74 90.49 176.65 3858.79 4618.918 2883.67E 0.43 4710.08 565222.56 5964073.76 9078.84 89.91 177.39 3858.46 4713.888 2888.62E 0.99 4758.89 565228.28 5963978.85 9176.88 89.94 178.18 3858.59 4811.858 2892.40E 0.81 4808.09 565232.86 5963880.92 9275.55 91.81 178.96 3857.08 4910.478 2894.87E 2.05 4856.42 565236.13 5963782.33 9368.64 91.62 179.54 3854.29 5003.518 2896.08E 0.66 4901.04 565238.10 5963689.32 9465.42 90.31 179.35 3852.66 5100.278 2897.02E 1. 37 4947.16 565239.82 5963592.58 9564.11 90_43 180.35 3852.03 5198.968 2897.28E 1. 02 4993.57 565240.89 5963493.90 9660.26 90.98 180.56 3850.84 5295.108 2896.52E 0.61 5037.89 565240.90 5963397.77 9756.58 92.00 178.55 3848.34 5391.388 2897.26E 2_34 5083.61 565242.43 5963301.51 9811.38 92.37 178.06 3846.25 5446.118 2898.88E 1. 12 5110.66 565244.50 5963246.80 9852.70 91.66 177.59 3844.80 5487.388 2900.45E 2.06 5131. 36 565246.40 5963205.55 9908.15 89.88 176.95 3844.05 5542.768 2903.09E 3.41 5159.61 565249.49 5963150.20 9950.05 90.18 176.23 3844.03 5584.588 2905.58E 1. 86 5181.39 565252.32 5963108.40 10047.45 89.08 174.37 3844.66 5681.658 2913.56E 2.22 5233.87 565261.09 5963011.41 10143.51 89.57 172.89 3845.79 5777.108 2924.22E 1. 62 5287.96 565272.52 5962916.05 10241.14 91.29 172 . 60 3845.06 5873.948 2936.55E 1. 79 5344.18 565285.64 5962819.32 10287.05 91.35 174.50 3844.00 5919.558 2941.71E 4.14 5370.08 565291.16 5962773.77 10337.25 88.65 175.07 3844.00 5969.548 2946.27E 5.50 5397.50 565296 .13 5962723.82 10388.35 88.13 174.89 3845.43 6020.428 2950.74E 1. 08 5425.27 565301.01 5962672.98 10434.05 88.34 176.29 3846.84 6065.968 2954.25E 3.10 5449.69 565304.90 5962627.47 10530.71 89.45 176_18 3848.71 6162.398 2960.60E 1.15 5500.43 565312.02 5962531.11 10627.53 89.79 176.15 3849.35 6259.008 2967.07E 0.35 5551.36 565319.28 5962434.57 10724.66 91. 32 175.75 3848.41 6355.888 2973.93E 1. 63 5602.76 565326.93 5962337.76 10815.01 90.49 176.43 3846.98 6446.008 2980.09E 1. 19 5650.39 565333.82 5962247.69 10905.65 91. 47 176.44 3845_43 6536.458 2985.73E 1. 08 5697.70 565340.19 5962157.30 10996.30 91.13 176.28 3843.37 6626.908 2991.48E 0.41 5745.11 565346.68 5962066.92 11083.85 91.84 176.23 3841.10 6714.238 2997.20E 0.81 5791. 04 565353.11 5961979.64 11176.35 91.81 177.64 3838.16 6806.558 3002.14E 1. 52 5838.61 565358.80 5961887.37 11267.25 92.03 177.95 3835.11 6897.338 3005.63E 0.42 5884.19 565363.03 5961796.63 11355.63 89.08 176.27 3834.26 6985.588 3010.09E 3.84 5929.43 565368.20 5961708.43 11446.01 89.69 175.38 3835.23 7075.718 3016.67E 1.19 5977.42 565375.52 5961618.36 11538.57 90.52 175.51 3835.06 7167.988 3024.02E 0.91 6027.10 565383.62 5961526.17 11633.96 90.48 175.77 3834.23 7263.098 3031. 27E 0.28 6078.02 565391.64 5961431.13 11682.38 89.29 175.41 3834.32 7311.378 3034.99E 2.57 6103.91 565395.75 5961382.89 11731.35 88.04 174.27 3835.46 7360.128 3039.40E 3.45 6130.62 565400.55 5961334.17 11827.99 88.56 175.02 3838.33 7456.308 3048.41E 0.94 6183.60 565410.35 5961238.08 11840.22 88.68 175.15 3838.62 7468.488 3049.46E 1. 45 6190.22 565411.49 5961225.91 11890.00 88.68 175.15 3839.77 7518.078 3053.67E 0.00 6217.15 565416.10 5961176.36 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #184 and TVD from RKB(Doyon 141) (87.10 Ft above mean sea level). Bottom hole distance is 8114.57 on azimuth 157.89 degrees from wellhead. Vertical section is from wellhead on azimuth 117.91 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 30-Apr-2003 21-Mar-2003 21.-Mar-2003 2853.39E 2816.52E 3012.75E 2492.16S 1491.73S 7494.10S 3847.10 3848.10 3792.10 WS Y15 D MIDPT TGT 3 565175.000,5966200.000,0.0000 WS Y15 D-HEEL RVSD 3 565130.000,5967200.000,0.0000 WS Y15 D-TOE RVSD 30 565375.000,5961200.000,0.0000 Revised -------------------------------------------------------------------------------------------------------. Target name Rectangular Coordinates T.V.D. Geographic Location ------------------------------------- ------------------------------------- Targets associated with this wellpath SURVEY LISTING Page 4 Your ref MWD wi IFR <0-11890'> Last revised: 8-Jun-2003 ) ConocoPhillips Alaska, Inc. Pad 1C,184 Kuparuk River Unit, North Slope, Alaska ') ) ') 8C'),3 ·'-089 Transmittal Form r&l. BAKER HUGHES INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Reference: 1 C-184 Ii Ii ]i 11 Ii Ii 11 I II II 1\ Ii 11 Ii 11 II 'I Ii 11 I¡ I' 11 ¡ I ,¡ 11 Contains the following: ~ 1 LDWG Compact Disc \ VJO (Includes Graphic Image files) 1 LDWG lister summary 1 blue line - MPR Measured Depth Log 1 blueline - MPR TVD Log I I Ii I~A~Ob#: 487044 Sent By: Glen Horel Date: July 25, 2003 ,. ~ Received By~\.,,-,-,,\¡,-'ù,S;' ~\ 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 RECEIVED JUL 28 2003 Alaska 01': & Gas Cons. Commts!ion AnchOí~'t3 r-~·R!I'L\T P.\5S - IOO·SOO DU;:~-·-~ . "'U"·;';';:;;~·';::·',··:';;';';:,i;"· .......'11' ,.AI .1 :.'\ 1I'r..'~ "" ~. , .. ..... .... 1tW!'I'I'''IP" I\IIInII oU ...., 1"'.'11.', ." ,'La ..... ,'-'-'" .,.-. .,.-.'. _..._.._~-_. ....--...-..-. ~'" ~ ..., .... ..........." "".'on....~ ........... I .-. ,- -..--..----.........------.-.-....-----. ~~~.:__.~;:::__:~.~~-"'-~::; -"I'[ 'IIIII!II ,,~ ...." I"""¡~ .... ,"'hC -.',"" . : W""''':øI .. . T;~··:"Â~ '"-'--_. .,-. "----..------.-----. ) IÆVŒ (ill~ !Æi!Æ~&!Æ ) A.ItA.~KA. OIL AND GAS CONSERVATION COMMISSION I FRANK H. MURKOWSK', GOVERNOR 333 W. ?TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage AK 99510 Re: Kuparuk River Field lC-184 ConocoPhillips Alaska, Inc. Permit No: 203-089 Surface Location: 1571' FNL, 1294' FWL, Sec. 12, TIIN, RI0E, UM Bottomhole Location: 1494' FSL, 978' FEL, Sec. 13, TIIN, RI0E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. 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, «~~ Rand;R~drich Commissioner BY ORDER OF THE COMMISSION DATED this.Jf day of May, 2003 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. Exploration, Production and Refineries Section ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ) k?tŠ- PERMIT TO DRILL 20 AAC 25.005 1 a. Type of Work: Drill [2] Re-entry D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: Redrill U 1b. Current Well Class: Stratigraphic Test D P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 1571' FNL, 1294' FWL, Sec. 12, T11N, R10E, UM Top of Productive Horizon: 2217' FSL, 1170' FEL, Sec. 12, T11N, R10E, UM Total Depth: 1494' FSL, 978' FEL, Sec. 13, T11 N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 562301.5 y- 5968668.6 Zone- 4 16. Deviated wells: Kickoff depth: 600 ft. Maximum Hole Angle: 90.6° 18. Casing Program Size Specifications Hole Casing Weight Grade Coupling Length 24" 16" 62.5# H-40 Weld 92' 9.875" 7.625" 29.7# L-80 BTCM 5682' 6.75" 4.5" 12.6# L-80 NSCT 6387' (Height above GL): 89' AMSL 17. Anticipated Pressure (see 20 AAC 25.035) Max. Downhole Pressure: 1610 psig / Max. Surface Pressure: 1248 psig Setting Depth Quantity of Cement Bottom c. f. or sacks TVD (including stage data) 120' Pre-installed 3842' 579 sx AS Lite & 220 sx Class G 3792' liner MD 28' 28' 5560' ExploratoryU Development Oil ~ Multiple Zone D Service D Development Gas D Single Zone 0 5. Bond: U Blanket U Single Well 11. Well Name and Number: Bond No. 59-52-180 1C-184 6. Proposed Depth: 12. Field/Pool(s): MD: 11890' TVD: 3792' Kuparuk River Field 7. Property Designation: , ALK 25649 & 25650 West Sak Oil Pool 8. Land Use Permit: 13. Approximate Spud Date: 5/28/2003 ADL 467 & 468 9. Acres in Property: 2560 14. Distance to Nearest Property: 978' at TD 10. KB Elevation 15. Distance to Nearest Well within Pool: None. Top TVD MD 120' 5710' 11890' 28' 28' 3824' 19 Total Depth MD (ft): PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Plugs (measured) (To be completed for Redrill and Re-Entry Operations) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Structural Conductor Detailed Operations Intermediate Prod uction Liner Perforation Depth MD (ft): Size Cement Volume MD TVD Length Perforation Depth TVD (ft): Contact Steve Shultz @ 263-4620 Title Kuparuk Drilling Team Leader, I _ Phone 2~3 _ ~/ 13 .;- Date S /Í ~/ (~::;J 3 PreDared bv Sharon AlIsuD-Drake Commission Use Only Permit Approval See cover letter Date: f -/ f - V ~ for other requirements Mud log required æi- IS:' ~ Directional survey req~E ~. \lit. bI 20. Attachments: Filing Fee 0 Property Plat D BOP Sketch 0 Diverter Sketch D Drilling Program ~ Seabed Report D 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed N~me R~Th as Signature 1~ /_4 r: ¡- ~ 1// ., ~ u !;iY / / k - l.o l-Vtç,S . c/ Permit to Drill API Number: Number: :2.ða -D87 Conditions of approval : Samples required Hydrogen sulfide measures 50- Dz-&J - 2.~ /S"Ç-L:ù Yes ~o U Yes ~NO Other: ~ \>S\ ~"'-\ ~\ ~ ~ \tV..... \..) \~ ~Q ~ ~ ":> \- Time v. Depth Plot U Drilling Fluid Program 0 Date: Shallow Hazard Analysis U 20 AAC 25.050 requirements 0 MAY 1 4 2003 Approved by ~ R.--... L ~, I) 1 C7,~IS"~IONER Form 10-401 Revised 312003 · ( ·1 ¡ \.;¡ i j J A L BY ORD~a Oil & Gas Cons. Commission THE COMMISSION AnrJijJrage 0 ç! '1 "3 Submit in duplicate PHILLIPS Ala,,_ 1a, Inc. A Subsidiary of PHilLIPS PETROLEUM COMPANY Drill anL lomplete Procedure West Sak Well #lC-184 4 Yz" Producer ~NE'II Plan ~urrlßlary Horizontal Locations Location at Surface 11571' FNL, 1294' FWL, See 12, TUN, Rl0E, UM NGS Coordinates Northings: 5,968668.64 Eastings: 562,301.5 RKB Elevation Pad Elevation 89.3' AMSL 59.2' AMSL Location at Top of 2488' FSL, 1200' FEL, See 12, TllN, Rl0E, UM Productive Interval (West ~ak "0" ~and) NGS Coordinates Measured Depth, RKB: 5610 Northings: 5,967471.1 Eastings: 565097.34 Total Vertical Depth, RKB: 3837 Total Vertical Depth, .'>5: 3743 . ocation at Targpt #1 NGS Coordinates Northings: 5,967200 I 7717' FSI , 1170' FFI , Spc.l?, T11N, R10F, UM Measured Depth, RKB: Eastings: 565130 Total Vertical Depth, RKB: Total Vertical Depth, 55: 5884 3848 3758 Location at Total Depth (Targpt #") NGS Coordinates Northings: 5,961200 Eastings: 565375 11494' FSL, 978' FEL, See 13, TUN, Rl0E, UM Mea_,>ured Depth, RKR: Tot¡:¡1 Vertic¡:¡1 Depth, RKR: Total Vertical Depth, 55: 11890 3797 3703 Formation Markers and Directional Waypoints Measured Hole Angle True Vertical True Vertical Formation Tops Depth (RKB Degrees Depth (RKB feet) Depth (55 feet) fppt) Ooyon # 141 RKB 0 0 0 -89 KOP 600 0 600 511 Rase Permafrost 1,865 33 1,808 1,719 Top K-15 7,575 57 7,307 7,713 Top Ugnu C 4,058 54 3,717 3,178 Top Ugnu R 4,661 67 3,543 3,454 K13 5,/ 86 75 3,777 3,683 Top of the West Sak "IJ" Sand 5,610 83 3,837 3,743 7 5/8" Casing Pt. 5,710 86 3,847 3,753 1 st West Sak Tarqet (heel) 5,884 90 3,848 3,759 2nd West Sak Tarqet, Well TD (toe) 11,890 91 3,792 3,703 · '~r ''"'¡ ~ 'JA . I 1/04 ~ ii, '"" hi PHILLIPS Ala }a, Inc. A Subsidiary of PHILLIPS PETRvL-t:UM COMPANY ) and Complete Procedure . West Sak Well #lC-184 Horizontal Producer Casing/Tubing Program Hole/ Casing Csg/Tbg ~i~p on Wt/Ft r.radp 97/8" OH 7 5/8" 29.7# L-80 6 314" OH 4-1/7" 17.6# 1-80 Conn. BTCM NSCT . pngth 5,682' 6,387' Top MQJTvn Surface 5,560'/3,874' Btm MQJTVn 5,710' / 3,842' 11,890' / 3,797' Liner Dimensions and Strengths OD Wt Conn. Cplg OD ID Drift Collapse Burst Tensile Yield (in) ( ppf) Grade Type (inches) (inches) (inches) (psi) (psi) (kips) 4-1/2" 12.6 L-80 NSCT 5.00 4.000 3.875 6,350 7,780 267 Logging/Formation Evaluation Program Open Hole 9 7/8" Open Hole 6 3/4" MWD/Directional LWD ( GR / RES) MWD/Directional LWD ( GR / RES) Mud Program Spud to Base of Base of Permafros to From Surface Shoe to Pprmflfrost Tot::ll npl'th of,Ç,'rfacp Tot::ll nppth of WP/l Initial Value Final Value Initial Value Final Value Horizontal Interval npnsity (nr~) 8.5 9.7 9.7 9.5 9.7 Funnel Viscosity 150-200 150-200 150 75 45-60 (spconrls) Yield Point (cP) 30-60 30-60 20-40 15-30 18-26 Plastic Viscostiy 8-15 11-22 15- 30 15-30 5-11 (lhJ100 sf) 10 second Gel 10-30 10-25 10-25 10-25 4-7 Strength (lb/100 ~f) 10 minute Gel 25-55 25-55 20-40 20-40 6-14 Strength (lb/100 ~f) rH 8-9 8-9 8-9 8-9 8.5-9.7 API Filtr;ltp (cc) 8-15 <8 <8 <8 <6 MßT <70 <70 <70 <70 <5 !"olirls (%) S-8 5-8 5-8 6-11 3-8 Steve Shultz I ,~~~. 6, , 'A f JØ i I \';'1 J J V;: ;¡œ Page 2 of 5 PHILLIPS Ala }a, Inc. A Subsidiary of PHilLIPS PETRliLEUM COMPANY ) and Complete Procedure West Sak Well #lC-184 Horizontal Producer Bit Program Hole Size Type Model Jets Depths Flow A V's DP A V's DC's Maximum Section Feet Rate Feet/Min Feet/Min Revs GPM Surface 9 7/8" Hughes MX-Cl 14,14,14,12C 0- 600- 180 282 600K 5,710' 700 Horizontal 6 3f4" Secu rity MDT52 16,16,16 5,710'- 250- 207-250 320 NA Production 11,890' 300 Cementing Program Holp Catpgory Surface Casing ~i7pJnp.rth Volllmp 7 5/8"/5710'MD 40 bbls 50 bbls 441 bbls (579.0 sks) 46 bbls (220 sks) Typp. of Cpmpnt CW Pre-flush Mud push XI I PCld Slurry (ASI ite) 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 Triil Slurry 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 Steve Shultz J [J ;:~ ~11 ~ ! , ,n ¡ \.;,1 iv/L.. Propprtips Density 8.4 ppg Density 10.2 ppg Density 10.7 ppg Yield 4.28 fe/sk 250% excess in permafrost 35% excess from bottom of permafrost to 4975' Density 15.80 ppg Yield 1.17 fe/sk 20% excess from 4610' to 5610' Page 3 of 5 PHILLIPS Ala )a, Inc. A Subsidiary of PHILLIPS PETRULËUM COMPANY ) and Complete Procedure West Sak Well #lC-184 Horizontal Producer Well Objectives and Area History This AFC provides funds to drill, case and complete an producing well through the D Sand This well is to be a horizontal producer 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 56 feet structurally from north to south but additional directional work should be minimal. The total horizontal length will be approximately 6,000' heading west and down dip in the "D" sand. A minor north-south fault has been identified about 200 feet east of the northern target and may influence local dips in the first 1000' of lateral. At its deepest point in the lateral, the vase of the "D" sand appears to be over 44 feet above the locally interpreted "D" sand oil-water contact (3845'ssTVD). 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 8.8 ppg EMW (equivalent mud weight). Since 1C-184 is to be drilled into the same fault block as 1C-190 (just recently drilled), bottom hole pressures have been taken from 1C-190 with an estimated 1610 psi at 3625' TVD. This requires a minimum of 8.6 ppg mud to drill this well and with a 75 psi safety margin the total mud weight will be +/- 9.0 ppg. There shouldn't be a risk of over pressure. The maximum anticipated surface pressure would be 1248 psi assuming a gas gradient of .1 psi/ft. ----fÞ The surface hole will be drilled to TD 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. 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 No close approach issues for this well, all wells in the vicinity of 1C-184 have passed major risk assessment. Waste Drilling Fluids Disposal Incidental fluids generated from drilling operations may be hauled to the nearest permitted disposal well or may be pumped down the surface / production casing annulus of a permitted, existing well on Drill Site-1"-A request to the AOGCC will be made that 1C-19 be approved for annular injection. 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 1C- 184 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 1R-18 and 3R-11. All fluids hauled from lC-184 will be properly documented and manifested. Steve Shultz CR t~t"'AL .,. l)i.~\Jl~ Page 4 of 5 PHILLIPS Ala '~a, Inc. A Subsidiary of PHILLIPS PETRvLEUM COMPANY ) and Complete Procedure West Sak Well #lC-184 Horizontal Producer Procedure for lC-184 ~: ~~R=-::~\,,«c~, ~~K.~\~~~'>-\, A-Q ~(,Ç 3. MU 9.785" bit and 6 3/4" BHA, directionally drill the surface hole to 5,710'MD/3,842'TVD. 4. CBU and POOH 5. RU and run 7 5/8" casing to TD, cement in place '~ 1<J.f)()__ ~ \..:)() t~ -4.. So --\ \ß~ \" ~ ,.;/ ,-~ft os- 6. MU 6 314" bit with 4 314" BHA, RIH to float collar 7. Drill out float and shoe, then 20 feet of new hole, perform FIT, change hole over to MI flo-pro 8. Directionally drill the 6 314" lateral to +1-ll,890'MD/3792'TVD, CBU, POOH 9. RU and run 4112" pre-perforated liner to TD 10. Set hanger and liner top packer, release, POOH 11. RU and run 4 112" jet pump completion 12. ND BOPE, release rig 13. RDMO Doyon #141 Steve Shultz C L' ~ l' ~'.'J\. r.,. ~: .' . j ,q I, ~ Ll i· ø '., ~ Page 5 of 5 ) ) ConocoPhillips Alaska, Inc. Crcatc<l by bmíchaal For: S. Shultz Dato plottc<l : 12-May-2003 Plat Roforenco i. 1C-1B4 Vors'1. Coordinate" ore in 1eM1t reference slot 1184. True Vertical Depths ore referencD Est. RKB (D-141). - 5!æ!!!!! ~ n,¡;;;Q Structure: Pad 1 C Well: 184 ~/ ConocoPhillips Field : Kuparuk River Unit Location: North Slope, Alaska 400 - 00 ~ "!2 ~60 c~(o<:> (\)((\bt~e5~"J \? 1,,00 0(( ';¡'ò ';¡,ò<:>e '\ G ¥ 'J,. ~~<òv: ~o ,\0\\,.0 ,,0« -<':.)<(\OG \(\ '" ' "'''' ill It: '" ~ o.e~ 1> 94 AZ "'''' v "d~ 1':' 96.03 AZ 1"«(\ <ò\Ò - (\c\ G ~\ \f>PV: o - 400 - ESTIMATED SURFACE LOCATION: 1571' FNL, 1294' FWL SEC. 12, T11N, R10E 800 - 1200 - l ~op West Sak D 117.91 AZIMUTH 7 5/8 Casing ". Target - EOC 1600 - 3187' (TO TARGET) ~ ...;¡ TARGET LOCATION: ","''''Plane of Proposal"''''''' a, 2217' FSL, 11 70' FEL ~ SEC. 12, T11 N, R10E 2000 - , > N 2400 - <f Jt WS Y15 MIDPT TGT EOC 2800 - TRUE ...-.... -+- 3200 - Q) Q) "I- '--'" ..!: 3600 - - .... ::1 ...;¡ 0 ?' .... (J1 4000 - 0> > I N V 4400 - 4800 - 5200 - 5600 - 6000 - 6400 - 6800 - m LOCATION: 1494' FSL. 978' FEL 7200 - SEC_ 13, T11 N, R10E l-L TO - Casing pt. 7600 - 400 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 East (feet) -> Q!"""I"<!'!II "I"J~I r,~", ' (\ ,'\ " Ji, ," i t i~. ':" . ~.,J f ~~ I ~~\,:4 ¡ ~ ( !-';1, \~ '0 :7"J ~"-' ~) ~..~ "-~i:> ".~~ ~ ,,---., +-- Q) Q) '+- '---' ...I: +-- 0.. Q) o o o :.;:: L Q) > Q) ::s L l- I V 3600 - 3900 - ConocoPhillips Alaska, o - I Created by bm;chael For: S Shultz Date plotted: 13-Moy-2DD3 Plot Reference is 1C-1B4 VeroD!. Coordinate8 are in feet reference slot #184. True Vertical Depth. ore reference Est RKB (0-141). - .... - 1N"n:Q Inc. Structure : Pad 1 C Well : 184 Field: Kuparuk River Unit Location: North Slope, Alaska I Estim'd RKB: 87' 300 - 600 - KOP . 2.00 4.00 6.00 . 8.00 Build/Turn 3/100 12_74 15.57 18.46 DLS: 3.00 deg per 100 ft 21.38 24.31 27.26 900 - DLS: 2.00 deg per 100 ft 1200 - 1500 - 1800 - Build 4/100 32.00 Base Permafrost 36.00 40.00 44.00 Top T-3 48_00 EGC DLS: 4.00 deg per 100 ft 2100 - Top K-15 2400 - 2700 - Turn 2/100 EOC TANGENT ANGLE 51.76 DEG 3000 - Begin Final Bld/Tm 51.79 52.95 54.93 57.62 60_92 64_72 68.91 73.41 80.55 Top Ugnu C 3300 - o 300 600 900 1200 1500 1800 2100 2400 2700 3000 1 5/'ò . *~ cos\(\q ,\G'\ ,~.:~~'\ -J.."~ ~S~OC .. 117.91 AZIMUTH 3187' (TO TARGET) ***Plane of Proposal*** , TRUE TARGET ANGLE 90.05 DEG DLS: 4.00 deg per 100 ft TOf) Ugnu B o'f. <;) OC Top Ugnu A \. S / ~ ~es \. K13 ,\0<:( ,\6~o.,e ~ ConocoPhillips - "~ TO - Casing pt. :::( 3300 3600 3900 4200 4500 4800 5100 5400 5700 Vertical Section (feet) -> Azimuth 117.91 with reference 0.00 N, 0.00 E from slot #184 6000 6300 ::.' :\ J t~, 1(1 II I': 1:1 I J Ie. I.: I; II;: I'~I ·"1 ~ 'I -- .:.:\ ~J - - ~'(, " , ~ I~~ .:. "~I " :., :-..:. :\:< :\J :'0:. ).:. :-. ~ ) ~, :\'~ J(I J I J':' J! JJ J~. J.:. J~ J:.': J ,I ~.I) ~ I ~.:\ ~..J ~c ~I:, ~.I:' ~,;I r,ll ~ I ~.:: ~, :~ t: J t...~. ~,r:, r", ~ r",'? ..:'" ~ ;"1:1 , ~ ~I:I ,~": I ~I..I ~::; ~:::~~ '~(I -, ~,' ft ~1'7aH8 '~I:O :, }".tWä·'ia "'J :\'~~t~1 ~I:' :<', ~7&'ä '~I:' ~ '.17ª.1.8_ :\J~(11 ~~I) I'" . I ~J ~, ~ '~I~ :' <I - oj, :~~;-:::~ ,:~~ ~,:¡qÒQ:~; " ç ,} , \};fJ - ,,' ,,~JII'J l '; ) \,,,,.-, \J 81 ~II~¡ 90_63&'Ilm1!J.l 3792.00!, )§r@~~ 565375.00.~.~ -7494.10&~11l1:1~~ C ~ r ,~:; ':\.1:\~ L H I ~.¡ ¡ 'llf"~ , 0.1 )~iã~llj¡ ) ConocoPhillips Alaska, Inc. Pad 1C 184 slot #184 Kuparuk River Unit North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref Our ref License 1C-184 Vers#l prop5433 Date printed Date created Last revised 12-May-2003 21-Mar-2003 12-May-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 29.729,w149 29 41.317 Slot Grid coordinates are N 5968668.639, E 562301.496 Slot local coordinates are 1570.22 S 1295.26 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North 10·... 'k' ,r L:!' ~ ~ '~"~. i !l i\ ~ .I ¡ '¡:!!õl ) ConocoPhillips Alaska, Inc. Pad lC,184 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 0.00 500.00 600.00 700.00 800.00 900.00 1000.00 1100.00 1200.00 1300.00 1400.00 1500.00 1600.00 1700.00 1792.60 1842.60 1865.85 1942.60 2042.60 2124.15 2142.60 2242.60 2336.60 2500.00 2575.12 3000.00 3200.00 3279.60 3500.00 3793.04 3800.00 3900.00 4000.00 4057.66 4100.00 4200.00 4300.00 4400.00 4500.00 4600.00 4661. 04 4700.00 4800.00 4808.69 4900.00 5000.00 5100.00 5200.00 5286.56 5300.00 6.00 8.00 10.00 12.74 15.57 18.46 21. 38 24.31 27.26 30.00 32.00 32.93 36.00 40.00 43.26 44.00 48.00 51.76 51.76 51.76 51. 76 51. 76 51. 76 51. 76 51.76 51. 79 52.26 52.95 53.45 53.85 54.93 56.19 57.62 59.20 60.92 62_03 62.77 64 _ 72 64.89 66.77 68.91 71.13 73.41 75.43 75.75 0.00 0.00 0.00 2.00 4.00 75.00 75.00 75.00 75.00 75.00 0.00 500.00 600.00 699.98 799.84 899.45 998.70 1097.47 1195.50 1292.45 1388.07 1482.08 1574.22 1664.26 1745.52 1788.38 1808.00 1871. 27 1950.05 2011.00 2024.35 2093.80 2154.37 2255.50 2302.00 2564.98 2688.77 2738.05 2874.46 3055.84 3060.15 3121.71 3182.46 3217.00 3242.10 3300.35 3356.92 3411.53 3463.93 3513.85 3543.00 3561.05 3605.30 3609.00 3646.39 3684.11 3718.29 3748.75 3772.00 3775.35 R E C TAN G U L A R COO R DIN ATE S 0.00 N 0.00 N 0.00 N 0.45 N 1. 81 N 4.06 N 7.22 N 11. 26 N 15.19 N 17.97 N 19.60 N 20.06 N 19.37 N 17.53 N 14.79 N 12.99 N 12.12 N 9.09 N 4.80 N 1. 02 N 0.13 N 4.88 S 9.90 S 18.85 S 22.97 S 46.24 S 57.20 S 62.67 S 80.84 S 105.01 S 105.60 S 117.80 S 136.89 S 150.99 S 162.77 S 195.33 S 234.40 S 279.79 S 331. 29 S 388.63 S 426_39 S 451. 54 S 519.72 S 525.88 S 592.84 S 670.52 S 752.41 S 838.09 S 915.01 S 927.16 S 0.00 E 0.00 E 0.00 E 1.69 E 6.74 E 15.16 E 26.93 E 42.04 E 61. 33 E 85.61 E 114.82 E 148.87 E 187.68 E 231.14 E 275.42 E 301.10 E 313.55 E 356.88 E 418.28 E 472.32 E 485.02 E 556.76 E 628.45 E 756.48 E 815.34 E 1148.24 E 1304.94 E 1367.21 E 1539.36 E 1768.25 E 1773.69 E 1851. 52 E 1928.60 E 1972.56 E 2004.55 E 2079.00 E 2151. 59 E 2221.97 E 2289.78 E 2354.71 E 2392.79 E 2416.43 E 2474.65 E 2479.53 E 2529.08 E 2579.45 E 2625.53 E 2667.08 E 2699.23 E 2703.90 E Dogleg DegllOOft ') PROPOSAL LISTING Page 1 Your ref 1C-184 Vers#l Last revised : 12-May-2003 Vert Sect 0.00 0.00 0.00 2.00 2.00 0.00 0.00 0.00 KOP 1. 28 5.11 75.00 75.00 75.00 81. 25 85.29 88.10 90.17 91.77 93.03 94.00 94.00 94.00 94.00 94.00 94.00 94.00 94.00 94.00 94.00 94.00 94.00 94.00 96.03 96.03 96.03 96.38 101. 42 106.38 109.19 111.24 115.97 120.57 125.03 129.35 133.52 135.99 137.54 141. 44 141. 77 145.20 148.85 152.39 155.84 158.76 159.21 2.00 2.00 2.00 3.00 3.00 11.50 20.42 31.88 Build/Turn 3/100 47.09 67.25 3.00 3.00 3.00 3.00 3.00 92.30 122.17 156.79 196.06 236.47 Build 4/100 4.00 4.00 4.00 4.00 4.00 260.01 271.42 Base Permafrost 311.12 367.40 416.92 Top T-3 4.00 4.00 4.00 0.00 0.00 428.56 494.31 560.01 EOC 677.34 731.28 Top K-15 0.00 0.00 2.00 0.00 0.00 1036.36 1179.97 Turn 2/100 1237.57 EOC 1398.20 1611.79 Begin Final Bld/Trn 4.00 4.00 4.00 4.00 4.00 1616.87 1691.36 1768.41 1813.85 Top Ugnu C 1847.64 4.00 4.00 4.00 4.00 4_00 1928.68 2011.11 2094.55 2178.58 2262.79 4.00 4.00 4.00 4.00 4.00 2314.12 Top Ugnu B 2346.78 2430.14 2437.34 Top Ugnu A 2512.46 4.00 4.00 4.00 4.00 4.00 2593.33 2672.37 2749.19 2813.61 K13 2823.42 All data is in feet unless otherwise stated. Coordinates from slot #184 and TVD from Est. RKB (D-141) (87.00 Ft above mean sea level). Bottom hole distance is 8077.10 on azimuth 158.10 degrees from wellhead. Total Dogleg for wellpath is 138.42 degrees. Vertical section is from wellhead on azimuth 117.91 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ nr:;\,,' : }, '(',oi¡ I, :'\-' ~f¡ ,I . ., ~ .~ I ' , I i '',' ,:¡I ;:) ,r'~-~ 1 ~~ ) ') ConocoPhillips Alaska, Inc. PROPOSAL LISTING Page 2 Pad 1C,184 Your ref 1C-184 Vers#l Kuparuk River Unit,North Slope, Alaska Last revised : 12-May-2003 Measured Inc lin . Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/100ft Sect 5400.00 78.13 162.51 3797.95 1019.17 S 2735.82 E 4.00 2894.69 5500.00 80_55 165.75 3816_45 1113 _ 68 S 2762.68 E 4.00 2962.65 5600.00 83.00 168.95 3830.76 1210.23 S 2784.34 E 4.00 3026.98 5610.38 83.26 169_28 3832_00 1220.35 S 2786.29 E 4.00 3033.44 Top West Sak D 5700.00 85.47 172.11 3840.80 1308.35 S 2800.70 E 4.00 3087.37 5710.38 85.73 172 . 43 3841. 60 1318.60 S 2802.10 E 4.00 3093.40 7 5/8 CSG 5800.00 87.96 175.25 3846.54 1407.56 S 2811. 69 E 4.00 3143.51 5884.35 90.06 177.89 3848.00 1491.73 S 2816.74 E 4.00 3187.36 WS Y15 D-HEEL RVSD 30 APR 03 5900.00 90.06 177.89 3847.98 1507.37 S 2817.32 E 0.00 3195.19 6000.00 90.06 177.89 3847.89 1607.30 S 2821. 00 E 0.00 3245.22 6100.00 90.06 177.89 3847.79 1707.23 S 2824_69 E 0.00 3295.24 6200.00 90.06 177.89 3847.69 1807.17 S 2828.37 E 0.00 3345.27 6300.00 90.06 177_89 3847.59 1907.10 S 2832.05 E 0.00 3395.29 6400.00 90.06 177.89 3847.49 2007.03 S 2835.74 E 0.00 3445.32 6500.00 90.06 177.89 3847.39 2106.96 S 2839.42 E 0.00 3495.34 6600.00 90.06 177.89 3847.29 2206.90 S 2843.10 E 0.00 3545.37 6700.00 90.06 177.89 3847.19 2306.83 S 2846.78 E 0.00 3595.39 6800.00 90.06 177.89 3847.09 2406.76 S 2850.47 E 0.00 3645.41 6885.46 90.06 177.89 3847.00 2492.16 S 2853.61 E 0.00 3688.16 WS Y15 D MIDPT TGT 30 APR 03 6900.00 90.45 178.08 3846.94 2506.69 S 2854.12 E 3.00 3695.42 6906.81 90.63 178.18 3846.87 2513.50 S 2854.34 E 3.00 3698.80 EOC 7000.00 90.63 178.18 3845.85 2606.64 S 2857.31 E 0.00 3745.01 7500.00 90.63 178.18 3840.34 3106.35 S 2873.23 E 0.00 3992.95 8000.00 90.63 178_18 3834.83 3606.07 S 2889.14 E 0.00 4240.89 8500.00 90.63 178.18 3829.33 4105.78 S 2905.06 E 0.00 4488.82 9000.00 90.63 178 .18 3823.82 4605.50 S 2920.97 E 0.00 4736.76 9500.00 90.63 178 .18 3818.32 5105.22 S 2936.89 E 0.00 4984.70 10000.00 90.63 178.18 3812.81 5604.93 S 2952.80 E 0.00 5232.64 10500.00 90.63 178.18 3807.31 6104.65 S 2968.72 E 0.00 5480.58 11000.00 90.63 178.18 3801.80 6604.37 S 2984.63 E 0.00 5728.52 11500.00 90.63 178.18 3796.30 7104.08 S 3000.55 E 0.00 5976.46 11890.24 90.63 178.18 3792.00 7494.10 S 3012.97 E 0.00 6169.97 WS Y15 D-TOE RVSD 30 APR 03 All data is in feet unless otherwise stated. Coordinates from slot #184 and TVD from Est_ RKB (D-141) (87.00 Ft above mean sea level). Bottom hole distance is 8077.10 on azimuth 158.10 degrees from wellhead. Total Dogleg for wellpath is 138.42 degrees. Vertical section is from wellhead on azimuth 117.91 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ OR' ~ .! J :-\ f .~ ,I ;1 ,," ') ) ConocoPhillips Alaska, Inc. Pad 1C,184 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref 1C-184 Vers#l Last revised : 12-May-2003 Comments in wel1path -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 600.00 600.00 0.00 N 0.00 E KOP 1100.00 1097.47 11. 26 N 42.04 E Build/Turn 31100 1792.60 1745.52 14.79 N 275.42 E Build 4/100 1865.85 1808.00 12.12 N 313.55 E Base Permafrost 2124.15 2011.00 1. 02 N 472.32 E Top T-3 2336.60 2154.37 9.90 S 628.45 E EOC 2575.12 2302.00 22.97 S 815.34 E Top K-15 3200.00 2688.77 57.20 S 1304.94 E Turn 2/100 3279.60 2738.05 62.67 S 1367.21 E EOC 3793.04 3055.84 105.01 S 1768.25 E Begin Final Bld/Trn 4057.66 3217.00 150.99 S 1972.56 E Top Ugnu C 4661.04 3543.00 426.39 S 2392.79 E Top Ugnu B 4808.69 3609.00 525.88 S 2479.53 E Top Ugnu A 5286.56 3772.00 915.01 S 2699.23 E K13 5610.38 3832.00 1220.35 S 2786.29 E Top West Sak D 5710.38 3841.60 1318.60 S 2802.10 E 7 5/8 CSG 5884.35 3848.00 1491 . 73 S 2816.74 E WS Y15 D-HEEL RVSD 30 APR 03 6885_46 3847.00 2492.16 S 2853.61 E WS Y15 D MIDPT TGT 30 APR 03 6906.81 3846.87 2513.50 S 2854.34 E EOC 11890.24 3792.00 7494.10 S 3012.97 E WS Y15 D-TOE RVSD 30 APR 03 Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 0.00 0.00 O.OON O.OON O.OOE 5710.38 3841.60 O.OOE 11890.20 3792.00 1318.60S 7494.06S 2802.10E 7 5/8" Casing 3012.97E 4 1/2" Casing Targets associated with this wellpath ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- WS Y15 D-HEEL RVSD 3 565130.000,5967200.000,0.0000 WS Y15 D MIDPT TGT 3 565175.000,5966200.000,0.0000 WS Y15 D-TOE RVSD 30 565375.000,5961200.000,0.0000 3848.00 3847.00 3792.00 1491.73S 2492.16S 7494.10S 2816.74E 2853.61E 3012.97E 21-Mar-2003 30-Apr-2003 21-Mar-2003 OR' p,~, III i'¡ !:; ~,; .,~: "" .fJ ), 4J \.""" J I~ ',:: ".'~!; ') ) ConocoPhillips Alaska, Inc_ Pad lC 184 slot U84 Kuparuk River Unit North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref Our ref License lC-184 VersU prop5433 Date printed Date created Last revised 12-May-2003 21-Mar-2003 12-May-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 29.729,w149 29 41.317 Slot Grid coordinates are N 5968668.639, E 562301.496 Slot local coordinates are 1570.22 S 1295.26 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North OR~A ' I>.~ ¡," ~, '1 ',' ~' "" r.: ..I, ~~ § ~ I ,,,,,J;1,',' ,':!,',1 ,! "', "," "i \. , "!' J ',.1 "........!, .t¡j t" , ~ :'1 \¡'IA Ii II ',.' ,:::.I!] O '"',',,',' ,:") J"\ Ð "~, ;, A' , .í i' '. J.:' ¡ ,,\ "r~ ,jÎi:rl1 1.1 d t' '~:'~I All data in feet unless otherwise stated_ Calculation uses minimum curvature method_ Coordinates from slot #184 and TVD from Est. RKB (D-141) (87.00 Ft above mean sea 1evel)_ Bottom hole distance is 8077 _10 on azimuth 158.10 degrees from wellhead_ Total Dogleg for wellpath is 138 _ 42 degrees_ Vertical section is from wellhead on azimuth 117.91 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. PROP05AL LI5TING Page 1 Pad 1C,184 Your ref 1C-184 Vers#1 Kuparuk River Unit, North 51ope, Alaska Last revised : 12-May-2003 Measured Inclin Azimuth True Vert R E C TAN G U L A R G RID COO R D 5 G E 0 G RAP H I C Depth Degrees Degrees Depth COO R DIN ATE 5 Easting Northing COO R DIN ATE 5 0.00 0.00 75.00 0.00 o _OON O.OOE 562301.50 5968668.64 n70 19 29.73 w149 29 41.32 500.00 0.00 75.00 500.00 o .OON 0_ OOE 562301.50 5968668.64 n70 19 29.73 w149 29 41. 32 600.00 0_00 75_00 600.00 o .OON O.OOE 562301.50 5968668.64 n70 19 29.73 w149 29 41.32 700.00 2_00 75.00 699.98 0.45N 1. 69E 562303.18 5968669.10 n70 19 29.73 w149 29 41.27 800.00 4.00 75.00 799.84 1. 81N 6.74E 562308.22 5968670.50 n70 19 29.75 w149 29 41.12 900.00 6.00 75.00 899.45 4.06N 15 _16E 562316.62 5968672.82 n70 19 29.77 w149 29 40.87 1000.00 8.00 75.00 998.70 7.22N 26.93E 562328.36 5968676.07 n70 19 29.80 w149 29 40.53 1100.00 10.00 75.00 1097.47 11.26N 42.04E 562343.44 5968680.24 n70 19 29.84 w149 29 40.09 1200.00 12 _ 74 81.25 1195.50 15.19N 61.33E 562362.69 5968684.32 n70 19 29.88 w149 29 39.53 1300 _ 00 15.57 85.29 1292_45 17.97N 85_61E 562386.95 5968687.30 n70 19 29.91 w149 29 38.82 1400.00 18.46 88.10 1388.07 19.60N 114,82E 562416.14 5968689.16 n70 19 29.92 w149 29 37.97 1500.00 21.38 90.17 1482.08 20.06N 148_87E 562450.19 5968689_91 n70 19 29.93 w149 29 36_97 1600.00 24.31 91. 77 1574 _22 19.37N 187.68E 562489.00 5968689.54 n70 19 29.92 w149 29 35.84 1700.00 27.26 93.03 1664.26 17.53N 231.14E 562532_46 5968688.04 n70 19 29.90 w149 29 34.57 1792.60 30_00 94 _ 00 1745_52 14 _ 79N 275.42E 562576_76 5968685.66 n70 19 29_87 w149 29 33.28 1842_60 32.00 94.00 1788.38 12 _ 99N 301.10E 562602.46 5968684_08 n70 19 29_86 w149 29 32,53 1865 _ 85 32_93 94_00 1808.00 12 _12N 313_55E 562614 _ 91 5968683_31 n70 19 29_85 w149 29 32_17 1942.60 36.00 94.00 1871.27 9_09N 356_88E 562658.25 5968680.63 n70 19 29.82 w149 29 30_90 2042.60 40.00 94.00 1950.05 4.80N 418.28E 562719.68 5968676.84 n70 19 29.78 w149 29 29,11 2124.15 43.26 94.00 2011.00 1_02N 472.32E 562773 _ 74 5968673.50 n70 19 29.74 w149 29 27_53 2142.60 44.00 94.00 2024.35 o .13N 485.02E 562786.45 5968672 .71 n70 19 29.73 w149 29 27.16 2242.60 48.00 94.00 2093.80 4.885 556.76E 562858 _22 5968668.28 n70 19 29.68 w149 29 25.07 2336.60 51.76 94.00 2154.37 9.905 628.45E 562929.95 5968663.85 n70 19 29_63 w149 29 22.97 2500.00 51.76 94.00 2255.50 18.855 756.48E 563058.03 5968655.94 n70 19 29_54 w149 29 19.24 2575.12 51.76 94.00 2302,00 22.975 815.34E 563116.91 5968652.30 n70 19 29_50 w149 29 17.52 3000.00 51.76 94.00 2564.98 46.245 1148.24E 563449 _ 96 5968631.73 n70 19 29.27 w149 29 07.80 3200.00 51. 76 94 _ 00 2688.77 57.205 1304.94E 563606 _ 73 5968622.05 n70 19 29.16 w149 29 03.23 3279.60 51. 76 96.03 2738.05 62.675 1367,21E 563669.04 5968617.10 n70 19 29.11 w149 29 01. 41 3500.00 51. 76 96.03 2874_46 80.845 1539.36E 563841.32 5968600.32 n70 19 28.93 w149 28 56_39 3793.04 51. 76 96.03 3055.84 105.015 1768.25E 564070.38 5968578.02 n70 19 28.69 w149 28 49.71 3800_00 51. 79 96 _38 3060.15 105.605 1773.69E 564075.81 5968577_47 n70 19 28.69 w149 28 49.55 3900_00 52 _26 101. 42 3121.71 117.805 1851.52E 564153.74 5968565.91 n70 19 28.57 w149 28 47_28 4000_00 52_95 106_38 3182.46 136.895 1928.60E 564230.96 5968547_45 n70 19 28_38 w149 28 45_03 4057.66 53.45 109.19 3217.00 150_995 1972.56E 564275_03 5968533.70 n70 19 28.24 w149 28 43.74 4100.00 53.85 111. 24 3242.10 162.775 2004.55E 564307.11 5968522.18 n70 19 28.12 w149 28 42.81 4200.00 54.93 115.97 3300.35 195.335 2079.00E 564381. 82 5968490.23 n70 19 27.80 w149 28 40.64 4300.00 56 _19 120.57 3356.92 234.405 2151.59E 564454.72 5968451.76 n70 19 27.42 w149 28 38.52 4400.00 57.62 125.03 3411.53 279.795 2221.97E 564525.45 5968406.95 n70 19 26_97 w149 28 36_47 4500.00 59.20 129.35 3463.93 331.295 2289 _ 78E 564593.68 5968356.01 n70 19 26.46 w149 28 34.49 4600.00 60.92 133 .52 3513.85 388.635 2354.71E 564659.06 5968299.20 n70 19 25.90 w149 28 32.59 4661. 04 62.03 135.99 3543.00 426.395 2392.79E 564697.44 5968261.75 n70 19 25.53 w149 28 31.48 4700.00 62.77 137.54 3561.05 451.545 2416.43E 564721.29 5968236 _80 n70 19 25.28 w149 28 30.79 4800.00 64.72 141. 44 3605.30 519.725 2474.65E 564780.05 5968169.10 n70 19 24.61 w149 28 29.09 4808_69 64.89 141. 77 3609.00 525_885 2479.53E 564784.99 5968162.98 n70 19 24.55 w149 28 28.95 4900 _ 00 66.77 145.20 3646.39 592.845 2529.08E 564835.07 5968096.44 n70 19 23.89 w149 28 27_51 5000.00 68.91 148.85 3684.11 670.525 2579.45E 564886.07 5968019.17 n70 19 23.13 w149 28 26_04 5100_00 71.13 152_39 3718.29 752_415 2625_53E 564932.80 5967937.67 n70 19 22.32 w149 28 24.69 5200_00 73.41 155.84 3748,75 838.095 2667_08E 564975_04 5967852.34 n70 19 21.48 w149 28 23.48 5286.56 75.43 158 _ 76 3772.00 915.015 2699.23E 565007.82 5967775.69 n70 19 20.72 w149 28 22_55 5300_00 75,75 159.21 3775.35 927.165 2703.90E 565012.59 5967763,58 n70 19 20.60 w149 28 22.41 ) ) r" ~ , I II ,; ~ : . " ~ ;j ':,'-)' ,~,:::, O R·'~ " ~, I~ .,~ p All data in feet unless otherwise stated_ Calculation uses minimum curvature method. Coordinates from slot #184 and TVD from Est _ RKB (D-141) (87 _ 00 Ft above mean sea level) _ Bottom hole distance is 8077 _10 on azimuth 158 _10 degrees from wellhead. Total Dogleg for we11path is 138.42 degrees. Vertical section is from wellhead on azimuth 117_91 degrees_ Grid is alaska - Zone 4_ Grid coordinates in FEET and computed using the Clarke - 1866 spheroid ConocoPhillips Alaska, Inc. PROPOSAL LISTING Page 2 Pad 1C,184 Your ref 1C-184 VersU Kuparuk River Unit,North Slope, Alaska Last revised : 12-May-2003 Measured Inclin Azimuth True Vert R E C TAN G U L A R G RID COO R D S G E 0 G RAP H I C Depth Degrees Degrees Depth COO R DIN ATE S Easting Northing COO R DIN ATE S 5400.00 78 _13 162_51 3797_95 1019.17S 2735.82E 565045.25 5967671.84 n70 19 19.70 w149 28 21. 48 5500.00 80 _ 55 165.75 3816_45 1113 .68S 2762.68E 565072.87 5967577.56 n70 19 18.77 w149 28 20.70 5600.00 83.00 168.95 3830.76 1210_23S 2784.34E 565095.31 5967481.20 n70 19 17.82 w149 28 20.07 5610_38 83_26 169.28 3832_00 1220.35S 2786.29E 565097.34 5967471.10 n70 19 17.72 w149 28 20_01 5700.00 85 _ 47 172_11 3840.80 1308.35S 2800.70E 565112.48 5967383.23 n70 19 16.85 w149 28 19_59 5710.38 85.73 172 . 43 3841.60 1318.60S 2802.10E 565113.95 5967372 _ 98 n70 19 16.75 w149 28 19_55 5800_00 87.96 175.25 3846.54 1407.56S 2811_ 69E 565124.27 5967284.12 n70 19 15_88 w149 28 19_27 5884.35 90.06 177 . 89 3848.00 1491.73S 2816.74E 565130.00 5967200.00 n70 19 15.05 w149 28 19.13 5900.00 90_06 177.89 3847.98 1507.37S 2817.32E 565130.70 5967184.36 n70 19 14.89 w149 28 19_11 6000.00 90.06 177 . 89 3847.89 1607.30S 2821. OOE 565135.20 5967084.48 n70 19 13_91 w149 28 19.00 6100_00 90.06 177.89 3847.79 1707.23S 2824.69E 565139.70 5966984.59 n70 19 12 _ 93 w149 28 18_90 6200.00 90_06 177.89 3847.69 1807.17S 2828.37E 565144.19 5966884.70 n70 19 11.95 w149 28 18_79 6300 _ 00 90_06 177 _ 89 3847_59 1907.10S 2832_05E 565148.69 5966784_81 n70 19 10.96 w149 28 18.68 6400.00 90.06 177 _ 89 3847.49 2007.03S 2835_74E 565153.18 5966684_92 n70 19 09.98 w149 28 18.58 6500.00 90_06 177 . 89 3847_39 2106.96S 2839.42E 565157.68 5966585.03 n70 19 09.00 w149 28 18.47 6600.00 90.06 177 . 89 3847.29 2206.90S 2843.10E 565162.17 5966485.14 n70 19 08.01 w149 28 18.37 6700.00 90.06 177.89 3847.19 2306.83S 2846.78E 565166.67 5966385.25 n70 19 07_03 w149 28 18.26 6800 _ 00 90_06 177_89 3847_09 2406.76S 2850.47E 565171.16 5966285.36 n70 19 06_05 w149 28 18.16 6885_46 90.06 177 . 89 3847.00 2492.16S 2853.61E 565175_00 5966200_00 n70 19 05.21 w149 28 18_07 6900 _ 00 90.45 178.08 3846.94 2506.69S 2854.12E 565175.63 5966185_47 n70 19 05.07 w149 28 18_05 6906.81 90.63 178 .18 3846.87 2513.50S 2854.34E 565175.91 5966178.67 n70 19 05.00 w149 28 18.04 7000.00 90.63 178.18 3845.85 2606.64S 2857_31E 565179.63 5966085 _ 57 n70 19 04.08 w149 28 17_96 7500.00 90 _ 63 178.18 3840.34 3106.35S 2873.23E 565199.60 5965586 _ 04 n70 18 59_17 w149 28 17.50 8000 _ 00 90.63 178 .18 3834.83 3606.07S 2889_14E 565219 _ 58 5965086.52 n70 18 54.25 w149 28 17_05 8500.00 90.63 178.18 3829.33 4105_78S 2905.06E 565239.56 5964587.00 n70 18 49.34 w149 28 16.59 9000.00 90.63 178 .18 3823.82 4605_50S 2920.97E 565259.53 5964087.48 n70 18 44.42 w149 28 16.13 9500.00 90_63 178.18 3818.32 5105.22S 2936.89E 565279.51 5963587.95 n70 18 39.51 w149 28 15.68 10000.00 90_63 178_18 3812_81 5604.93S 2952.80E 565299.48 5963088.43 n70 18 34.59 w149 28 15.22 10500_00 90.63 178 .18 3807.31 6104.65S 2968 _ 72E 565319.46 5962588_91 n70 18 29.68 w149 28 14_77 11000 _ 00 90.63 178.18 3801. 80 6604_37S 2984.63E 565339.43 5962089.39 n70 18 24.76 w149 28 14.31 11500 _ 00 90 _ 63 178 _ 18 3796_30 7104.08S 3000.55E 565359_41 5961589_86 n70 18 19.85 w149 28 13.85 11890.24 90.63 178 _ 18 3792_00 7494.10S 3012.97E 565375.00 5961200.00 n70 18 16.01 w149 28 13.50 " ) O ~ " t /"!,' ,f ~, r¡ ,'\, , , ,j ~ ¡\ ,,', " . ~ ~ ~",' ~Iì ' ;' .~ . ~1,J \¡."i I ~:) ',I" " ,~\C(.;.¡ 2816.74E 21-Mar-2003 2853.61E 30-Apr-2003 3012.97E 21-Mar-2003 1491.73S 2492_16S 7494_10S 3848.00 3847.00 3792.00 WS Yl5 D-HEEL RVSD 3 565130_000,5967200.000,0.0000 WS Y15 D MIDPT TGT 3 565175.000,5966200.000,0.0000 WS Y15 D-TOE RVSD 30 565375.000,5961200.000,0.0000 ----------------------------------------------------------------------------------------------------------- Revised Rectangular Coordinates T.V.D. Geographic Location Target name - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - -- - - - - -- - - - --- - - - - - - - - - - - - - - - - - - - - - - - -- Targets associated with this we11path 2802_10E 7 5/8" Casing 3012.97E 4 1/2' Casing 1318.60S 7494_06S O.OOE 5710.38 3841.60 O.OOE 11890.20 3792.00 O.OON O.OON 0.00 0.00 0.00 0.00 - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 600 _ 00 600_00 0_ OON O.OOE KOP 1100.00 1097_47 11 . 26N 42.04E Build/Turn 3/100 1792.60 1745.52 14.79N 275.42E Build 4/100 1865.85 1808.00 12 .12N 313.55E Base Permafrost 2124.15 2011_ 00 1.02N 472.32E Top T-3 2336.60 2154.37 9.90S 628.45E EOC 2575.12 2302.00 22.97S 815.34E Top K-15 3200.00 2688.77 57.20S 1304.94E Turn 2/100 3279.60 2738.05 62.67S 1367.21E EOC 3793.04 3055.84 105.01S 1768.25E Begin Final Bld/Trn 4057.66 3217.00 150.99S 1972.56E Top Ugnu C 4661.04 3543.00 426.39S 2392.79E Top Ugnu B 4808.69 3609.00 525.88S 2479.53E Top Ugnu A 5286.56 3772.00 915.01S 2699.23E K13 5610.38 3832.00 1220.35S 2786.29E Top Wes t Sak D 5710.38 3841.60 1318.60S 2802.10E 7 5/8 CSG 5884.35 3848.00 1491.73S 2816.74E WS Y15 D-HEEL RVSD 30 APR 03 6885 _ 46 3847.00 2492.16S 2853_61E WS Y15 D MIDPT TGT 30 APR 03 6906.81 3846.87 2513.50S 2854.34E EOC 11890 _ 24 3792_00 7494.10S 3012_97E WS Y15 D-TOE RVSD 30 APR 03 Casing positions in string 'A' ----------- -------- ------- ---- -- ---- - ---- ---- ---- - ------ ---- Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - -- - -- Comment Rectangular Coords_ TVD MD -------------------- -------------------- Comments in wellpath PROPOSAL LISTING Page 3 Your ref 1C-184 Vers*l Last revised : 12-May-2003 ConocoPhillips Alaska, Inc_ Pad 1C, 184 Kuparuk River Unit,North Slope, Alaska Presented by Baker Hughes INTEQ ') ) 'c~ 160 - 140 - 120 - 100 - 80 - ^ 60 - I ,,--..., - 40 - Q) Q) '+- '--'" ....c 20 - L 0 Z 0 - 20 - 40 - 60 - :::?Ë~~~J 1: J -~-- --'-~ -ci.~~~ ~~ i Created by bmichael For: S Shultz I Date p!atted : 13-May-2003 I Plot Reference Is 1 C-184 Vers'1. Coordinates ore in feet reference ~lo1 6184. True Vertical Depths ore reference Est. RKB (0-141). .. UIœI tNC:IB IN'n:€} 900 ~09_"- - 700 800 * 80 - 100 I I I I I I I 60 40 20 0 20 40 60 ConocoPhillips Alaska, Inc. ~ ~~5 "II" r--~nnr~¡"'n ,=....,¡¡ 11_...._11 ..1 IpS Structure : Pad 1 C Well : 184 Field : Kuparuk River Unit Location: North Slope. Alaska ~ ____ 1600 1700 300 - ....- - - - - - - - - - -..... - - - - _ _ _ _ _ _ _ _ .} ~o_o 1900 -------~ 1000 '" 500 _ ~o~lPO ~ ~ .~ I 80 I I I I I 120 140 160 180 200 East (feet) - > I 220 I 260 I 340 I 380 I 360 I 300 I 320 I 240 I 280 I 100 (~~ '-'~7":::· r' '. ""- t""'-.~... i ConocoPhillips Alaska, Inc. ~/ ConocoPhillips Created by bmichael For: S Shultz Date plaited; '3-May-2.003 Plot Reference i. 1C-I84 Vers#" Coordinates ere in feel reference slot #184. True Vertical Depths ore reference Est. RKB (0-141). - UIœI IIUGIti INn:q Structure : Pad 1 C Well : 184 Field : Kuparuk River Unit Location: North Slope. Alaska ^ I ~ 160 - '< 140 - ~ 120 - ,'f,fJ. 100 - 80 - 60 - ,--... -+- ill ill '+- '--" 40 - -C -+- L o Z 1>'" 23 20 - - §- - - - - - *" 19_0Q _ _ _ _ _ _ _ _ 2000 -------~-- o 20 - --------@) 0 ID 60 - 1900 ~ 1800 * 1700 ~ :ID '" 1 non II< 80 - I I I I I I I I I I I I I I I 340 360 380 400 420 440 460 480 500 520 540 560 580 600 620 640 660 680 700 720 740 760 780 800 East (feet) -> ^ I <:::) ,--.... v :')t-=:J Q) - '-" ""---- . (-:' --;.;~ ...c -+- ""'- L 0 Z -""'-----... -'õJI ~~L:::;M ,--.... V r-- Q) - '--" ..c -+- :J 0 (f) I V ConocoPhillips Alaska, Inc. ereated by bmichael For: S Shultz Date plotted: 13-t.4ay-20D3 Plot Reference i. 1C-184 Versl1. Coordinate, are in feet reference :¡!ot #184. Vertical Depth, ore reference Est. RK8 (0-141). - BAKIIt HUGID IN'I-.:t) 240 -~ ~~ ~~ 200 - 160 - 120 - 60 - 40 - -u""' 23 o - ~/ r- -~~ nh~II"--= ~OfïU~Or!l II Ip~ Structure : Pad 1 C Well : 184 Field : Kuparuk River Unit Location: North Slope, Alaska 40 - --..®- - - - - - - - ....23.0.9_ _ _ _ 2400 - - - - - - -+- - - - -2~OO_ '" ?100 j( 2300 2500 '" - -.,.. - - _ _ _ 2600 --------..--- 60 ~ .~ ~ -ID 120 - 160 - 200 - 240 - 720 760 2100 '" 2200 '" 600 640 1000 1160 East (feet) -> 1040 10BO 1120 BBO 920 960 ~ 2400 '" 2500 * 2600 '" lID 2700 ---.------__ æoo 2300 - - - - - -+-MOQ __ t< '" 2500 ?qOO 1< ® - -; ¡- - - - - -fiE> --> 1200 1240 12BO 1320 1360 1400 1440 14BO 1520 1560 1600 1640 ) ') ConocoPhillips Alaska, Inc. Created by bmlcha.1 For: S. Shultz Date platt.d : 1 J-May-200J Plat Ref.rence i. 1C-IB4 v....I1- Caardinat.. are In reet r.f.rence slot HIB4. True Vertical Depths arc reference E3t. RK8 (D-141). .- iiIüIliiII ~ !!'!T!:Q Structure : Pod 1 C Well : 184 y COñocõPhillips Field : Kuparuk River Unit Location: North Slope, Alaska East (feet) - > 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 8000 ~~~~ ...... 3100 3300 3500 3700 3900 4100 4300 1lB>~0- - ........ ®----*-"* * II< I ;--I ; II< 330ò'" , , '", 3500 , , \ "-" 3700 \ \ \ \ \ \ \ \ 3300 *4500 *4700 4900 5100 5300 5500 5700 5900 6100 6300 - * II< '" II< II< II< ~-,-,....... _ ~ - 400 - 800 -1200 -1600 - 2000 - 2400 - 2800 - 3200 (f) 0 C -I- - 3600 :::r 4500 ,;--.., -+0 CD - 4000 CD -I- ............ I - 4400 V - 4800 - 5200 - 6000 - 6400 - 6800 - 7200 ~ - 7600 J """".' .~~ ~ "I 1 ~ .. I ~ r L,' , i A '., .: :.¡ .,/' . n ~ ".~ ~ ~ .J I" ~ 1.- ) ) ConocoPhillips Alaska, Inc. Creoted by bmichael For: S. Shultz Date plotted: 13-May-2003 Plot Reference i. 1 C-' 84 Vers'1. Coordinatcðl aro in feet rofaronco alot #184. Struc'lu re : Pad 1 C Well: 184 ~ r ~- - - 6"!.pæ.... "'.11"._ - ~~E EOc.:v= E E ~S Field : Kuparuk River Unit Location: North Slope, Alaska True Vertlcol Depths ore reference Est. RK8 (0-1+1). .- iiiAIIIII ~ INTEQ TRUE NORTH ~ 3 350 10 340 20 330 30 ~ \ \ \ \ 310 * 700 I * 300 320 40 ,\6. 60 290 70 280 80 270 90 260 100 110 230 140 150 160 170 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well O hr"::.~ ...."\. · "I ~ .~ ì _ . f, li ¡i \./ ¡L}¡ L 1. )ker Hughes Incorporate" ) Anticollision Report Company: ConocoPhillips Alaska, Inc. Field: Kuparuk River Unit Reference Site: Pad 1C Reference Well: 184 Reference Wellpath: 1C-184 Vers#1 NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD + Stations Interval: 25.00 ft Depth Range: 0.00 to 11890.25 ft Maximum Radius: 5000.00 ft Survey Program for Definitive Wellpath Date: 4/30/2003 Validated: No Planned From To Survey ft ft 0.00 11890.25 Planned: 1C-184 Vers#1 V22 Casing Points MD ft 5710.38 11890.20 TVD ft 3841.60 3792.00 Diameter in 7.625 5.500 Hole Size in 9.875 6.750 Name 7 5/8" Casing 5 1/2" Liner Summary <-;.--------"'------ Offset W ell path --.;..;...--'-;.,..----:-:"'--> Site Well Well path 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 11 113 117 119 121 12 123 125 127 131 13 133 135 14 15 16 170 17 172 174 178 178 18 190 19 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 V5 1C-102L 1 V3 1C-104 VO 1C-104L1 V1 1C-104PB1 VO 1C-109 VO 1 C-109L 1 VO 1 C-111 VO 1C-11 VO 1C-113 VO Plan: 1C-113 1C-117 VO 1C-119 VO 1C-121 VO 1C-12 VO 1 C-123 VO 1C-125 VO 1C-127 VO 1C-131 VO 1C-13 VO 1C-133 VO 1C-135 VO 1C-14 V1 1C-15V1 Plan: 1C-15L1 1 C-16 VO 1C-170 Vers#2 V9 Plan: 1C-17 VO 1C-172 Vers#O.h V5 Pia 1C-174 V24 1C-178 BLat Vers# 2.b 1C-178 D LatVers#2.b 1C-18 VO 1C-190 V8 1 C-19 V6 Date: 5/13/2003 TilDe: 16:06:27 Page: Co-ordinate(NE) Reference: Well: 184, True North Vertical (TVD) Reference: . Wellhead(87') 87.0 Version: 5 Toolcode MWD+SAG Reference MD ft 1193.74 691.38 592.98 663.45 661.87 700.00 542.99 657.51 700.00 700.00 284.98 284.98 559.58 559.58 559.58 234.98 234.98 210.00 409.91 0.00 559.98 359.98 384.96 2854.51 334.99 309.97 234.99 209.99 631 .19 584.94 167.99 809.40 774.49 1071.49 670.48 209.99 599.89 224.79 324.99 324.99 655.14 224_79 1469.69 Offset MO ft 1200.00 700.00 600.00 675.00 675.00 725.00 550.00 675.00 725.00 725.00 300.00 300.00 575.00 575_00 575.00 250.00 250.00 225.00 425.00 0.00 575.00 375.00 400.00 3450.00 350.00 325.00 250.00 225.00 650_00 600_00 175.00 850.00 800.00 1150.00 675.00 225.00 600.00 225.00 325.00 325_00 675.00 225.00 1450.00 O R~~ ~('" '1 " ,;,0. f i .J ::'. J,f\. ' I I, 1 f 1 , ) I .' ~ " ,'~ I , e \\,\¡ ~ ~ ., . 1"t!1!J Reference: Error Model: Scan Method: Error Surface: Tool Name Db: Oracle Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing MWD + Sag correction Ctr;'Ctr No;'Go . Distance Area ft ft 162.05 85.39 130.61 234.21 348.53 466.55 586.96 707.75 776.33 627.32 712.22 712.22 685.51 685_51 685.51 603.59 603.59 574.33 742.38 547.52 496.80 470.59 446.78 225.27 423.02 399.34 378.71 338.22 444.24 319.30 305.79 68.79 29.09 381.51 280.61 752.83 241.36 201.00 120.48 120.48 301_32 121.01 71_92 22.53 12_89 11.15 12.40 12.37 13.12 10.22 12_30 17.23 13.15 5.55 5.55 10.80 10.80 10.80 4.85 4.85 4.14 8.22 10.88 6.77 7.27 158.22 6.32 6_17 4.64 4.25 12.25 10.95 3.37 20.50 17.40 27_58 12.52 4.24 11.49 4.60 6.47 6.47 12.11 4.43 34.75 Allowable Deviation· ft 139.53 72.51 119.46 221.82 336_16 453.44 576.74 695.46 759.11 614.17 706.67 706.67 674.72 674.72 674.72 598.75 598.75 570.19 734.16 485.93 463.82 439.51 90.70 416.70 393.16 374_07 333.98 431.99 308.35 302.42 48.29 11_76 354.00 268.10 748.59 229.86 196.40 114.01 114.01 289.21 116.58 43_57 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 No Offset Stations 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 .A.. lker Hughes Incorporate ) Anticollision Report Company: ConocoPhillips Alaska, Inc. Fièld: Kuparuk River Unit Reference Site: Pad 1C Reference Well: 184 Reference Wellpath: 1C-184 Vers#1 Summary <---~- Site ...;,:.._- OffSet Wellpatb - Well .. Pad 1C Pad 1 C Pad 1 C Pad 1C Pad 1C Pad 1 C Pad 1C Pad 1 C Pad 1C 22 23 23 24 25 26 27 WS-1 WS-24 Date: 5/13/2003 Time: 16:06:27 Page: 2 Co-ordinate(NE)Reference: Well: 184, True North Vertical (TVD) Reference: Wellhead(87') 87.0 Db: Oracle Reference MD ft 400.18 640.05 640.05 345.99 916.67 366.99 767.63 1C-22 V3 1 C-23A V2 1C-23PB1 V1 1 C-24 VO 1 C-25 VO 1C-26 V2 1 C-27 V1 WS1 V1 WS-24 VO 0,1 i G; Offset MD ft 400.00 650.00 650.00 350.00 925.00 375.00 775.00 ~ ~ .~ ;'iin: J '-Ii r"Ô ~ Ctr-:-Ctr No-Go Distance Area ft . ft 41.00 7.80 76.35 12.99 76.35 12.99 98.37 7.78 127.22 18.73 138.65 6.90 153.65 16.12 Allowable Deviation ft 33.21 63.40 63.40 90.59 108.61 131.75 137.59 Warning Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Out of range Out of range 1- lker Hughes Incorporate\. ) Error Ellipse Survey Report Company: ConòcoPhillips Alaska, Inc. Field: Kuparuk River Unit Site: Pad 1C Well: 184 Wellpath: 1 C~184 Vers#l Field: Kuparuk River Unit North Slope, Alaska USA Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Site: Pad 1 C North Slope, Alaska Site Position: Northing: 5970228.13 ft From: Map Easting: 560993.64 ft Position Uncertainty: 0.00 ft Ground Level: 60.50 ft Well: 184 Well Position: +N/-S -1570.22 ft Northing: 5968668.64 ft +E/-W 1295.26 ft Easting : 562301.50 ft Position Uncertainty: 0.00 ft Wellpath: 1C-184 Vers#1 Current Datum: Magnetic Data: Field Strength: Vertical Section: Wellhead(87') 4/7/2003 57503 nT Depth From (TVD) ft 0.00 +N/-S ft 0.00 Height 87.00 ft Date: 5/13/2003 Time: 16:14:38 Page: Co-ordini\Íe(NE)Refërence: Well: 184, True North Vertical (TVD) Reference: Wellhead(87')87~0 Section (VS) Reference: Well (0;00N,0.00E,158; 1 OAzi) Survey CalculatiollMethod: Minimum Curvature Db: Oracle Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 Latitude: Longitude: North Reference: Grid Convergence: 70 19 45.173 N 149 30 19.124 W True 0047 deg Slot Name: Latitude: Longitude: 70 19 29.729 N 149 29 41.317 W Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Surface 0.00 ft Mean Sea Level 25047 deg 80.75 deg Direction deg 158.10 Survey Program for Definitive Wellpath Date: 4/30/2003 Validated: No Version: 5 Planned From To Survey Toolcode Tool Name ft ft 0.00 11890.25 Planned: 1C-184 Vers#1 V22 MWD+SAG MWD + Sag correction Position uncertainty and bias at survey station All uncertainties at 2.6· standard deviation Highside-----> Lateral------> Vertical------> Magn. Semi-major Semi-minor MD Incl Azim TVD Unc. Bias Vnc. Bias Unc. Bias of Bias Unc. Unc. Azimuth Tool 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 25.00 0.00 0.00 25.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 MWD+SAG 50.00 0.00 0.00 50.00 0.03 0.00 0.03 0.00 0.95 0.00 0.00 0.03 0.03 0.00 MWD+SAG 75.00 0.00 0.00 75.00 0.07 0.00 0.07 0.00 1.96 0.00 0_00 0.07 0.07 0_00 MWD+SAG 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+SAG 125_00 0.00 0.00 125.00 0.18 0.00 0_18 0.00 2.96 0.00 0.00 0_18 0.18 0.00 MWD+SAG 150.00 0.00 0_00 150.00 0.25 0.00 0.25 0.00 2.96 0.00 0.00 0.25 0.25 0.00 MWD+SAG 175.00 0.00 0.00 175.00 0.32 0.00 0.32 0.00 2.96 0.00 0.00 0.32 0.32 0.00 MWD+SAG 200.00 0.00 0.00 200.00 DAD 0_00 DAD 0.00 2_96 0_00 0.00 DAD DAD 0.00 MWD+SAG 225.00 0.00 0.00 225.00 0047 0.00 0047 0.00 2.97 0.01 0.01 0047 0047 0.00 MWD+SAG 250.00 0_00 0.00 250.00 0.54 0_00 0_54 0_00 2_97 0_01 0.01 0.54 0.54 0.00 MWD+SAG 275.00 0.00 0.00 275.00 0.61 0_00 0.61 0.00 2.97 0.01 0.01 0.61 0.61 0.00 MWD+SAG 300.00 0.00 0.00 300.00 0.69 0.00 0.69 0.00 2.97 0_01 0.01 0.69 0.69 0.00 MWD+SAG 325_00 0_00 0_00 325_00 0.76 0.00 0.76 0.00 2.97 0.01 0.01 0.76 0.76 0.00 MWD+SAG 350.00 0.00 0_00 350.00 0_83 0.00 0.83 0.00 2.97 0.01 0.01 0.83 0.83 0.00 MWD+SAG 375.00 0.00 0.00 375.00 0.90 0.00 0.90 0.00 2.97 0_02 0.02 0.90 0.90 0.00 MWD+SAG 400.00 0.00 0.00 400.00 0.98 0.00 0.98 0.00 2.97 0.02 0.02 0_98 0_98 0_00 MWD+SAG 425.00 0.00 0.00 425.00 1_05 0.00 1.05 0.00 2.97 0.02 0.02 1.05 1.05 0.00 MWD+SAG 450.00 0.00 0.00 450.00 1.12 0_00 1.12 0.00 2.97 0.02 0.02 1.12 1.12 0.00 MWD+SAG 475.00 0.00 0.00 475.00 1_19 0_00 1.19 0.00 2_98 0_03 0.03 1.19 1.19 0_00 MWD+SAG 500.00 0.00 0.00 500.00 1.27 0.00 1_27 0.00 2.98 0.03 0.03 1.27 1.27 0.00 MWD+SAG 525.00 0.00 0.00 525.00 1_34 0.00 1_34 0.00 2.98 0.03 0_03 1.34 1_34 0.00 MWD+SAG 0....· ç ", ~":~ i~L I ~"j ,} .. ., J'''', ¡ /~ ~ ,_ ~ ~ J \.';)pj f .~ 1./ 1'\\ . ~ .L-lker Hughes Incorporate\. ) Error Ellipse Survey Report Company: ConöcoPhillips Alaska, Inc. Date: 5/13/2003 Time: 16:14:38 Page: 2 Field: Kupäruk River Unit Co;.ordlnate(NE)· Reference: Well: 184, True North Site: Pad tC Vertical (TVD)Refereúce: Wellhead(87') 87.0 Well: 184 Section (VS) Reference: Well (0.00N,0.00E,158.10Azi) Wellpath: 1C~184 Vers#1 Survey Calculation Method: Minimum Curvature Db: Oracle Position uncertainty and bias at survey station AU uncertainties at 2.6 standard deviation Highside~-~;';'> Lateral·;.····;.> Vertical·...:.--> . Magn. Seml·major Semi-minor MD loci Azim TVD Unc. Bias Unc. Bias Unc. Bias of Bias Une. Une.Azimuth Toöl ft deg deg ft ft ft ft ft ft ft ft ft ft deg 550.00 0.00 0.00 550.00 1.41 0.00 1.41 0.00 2.98 0.04 0_04 1.41 1.41 0.00 MWD+SAG 575.00 0.00 0.00 575.00 1.48 0.00 1.48 0.00 2.98 0.04 0.04 1.48 1.48 0.00 MWD+SAG 600.00 0.00 0.00 600.00 1.56 0.00 1.56 0.00 2.98 0.04 0.04 1.56 1.56 0.00 MWD+SAG 625.00 0.50 75.00 625.00 1.60 0.00 1.60 0.00 2.99 0.05 0.05 1.60 1.60 135.00 MWD+SAG 650.00 1.00 75.00 650.00 1.65 0.00 1.65 0.00 2.99 0.05 0.05 1.65 1.65 135.00 MWD+SAG 675.00 1.50 75.00 674.99 1_70 0.00 1.70 0_00 2.99 0.06 0.06 1.70 1.70 103.36 MWD+SAG 700.00 2.00 75.00 699.98 1.74 0.00 1.75 0.00 2.99 0.06 0.06 1.75 1.74 106.56 MWD+SAG 725.00 2.50 75.00 724.96 1.78 0.00 1.78 0.00 2.99 0.07 0.07 1.78 1.78 100.55 MWD+SAG 750.00 3.00 75.00 749.93 1.81 0.00 1.82 0.00 2.99 0.07 0.07 1.82 1.81 98.82 MWD+SAG 775.00 3.50 75.00 774.89 1.83 0.00 1.85 0.00 3.00 0.08 0.08 1.85 1.84 98.13 MWD+SAG 800.00 4.00 75.00 799.84 1.86 0_00 1.89 0.00 3.00 0.08 0.08 1.89 1.87 97.83 MWD+SAG 825.00 4.50 75.00 824.77 1.90 0.00 1.94 0.00 3.00 0.09 0.09 1.94 1.91 90.98 MWD+SAG 850.00 5.00 75.00 849.68 1.94 -0.01 2.00 0.00 3.00 0.09 0.09 2.00 1.95 89.99 MWD+SAG 875.00 5.50 75.00 874.58 1.98 -0.01 2.05 0.00· 3.00 0.10 0.10 2.06 1.99 89.17 MWD+SAG 900.00 6.00 75.00 899.45 2.01 -0.01 2.11 0.01 3.00 0.10 0.10 2.11 2.03 87.64 MWD+SAG 925.00 6.50 75_00 924.30 2.06 -0.01 2.19 0.01 3.00 0.11 0.11 2.19 2.08 86.32 MWD+SAG 950.00 7.00 75.00 949.13 2.10 -0.01 2.27 0.01 3.00 0.11 0.11 2.28 2.13 85.07 MWD+SAG 975.00 7.50 75.00 973.93 2.15 -0.01 2.36 0.01 3.00 0.12 0.12 2.36 2.18 83.91 MWD+SAG 1000.00 8.00 75.00 998.70 2.19 -0.01 2.44 0.01 3.00 0.13 0.13 2.44 2.23 82.83 MWD+SAG 1025.00 8.50 75.00 1023.44 2.24 -0.01 2.56 0.01 3.00 0.13 0.13 2.56 2.28 82.19 MWD+SAG 1050.00 9_00 75.00 1048.15 2.29 -0.01 2.67 0.02 3.00 0.14 0.14 2.68 2.34 81.57 MWD+SAG 1075.00 9.50 75.00 1072.83 2.34 -0.01 2.79 0.02 3.00 0.15 0.15 2.79 2.39 80.98 MWD+SAG 1100.00 10.00 75.00 1097.47 2.39 -0.02 2.91 0.02 3.00 0.15 0.16 2.91 2.45 80.42 MWD+SAG 1125.00 10.67 76.86 1122.06 2.43 -0.02 3.06 0.03 3.00 0.16 0.16 3.06 2.50 80.32 MWD+SAG 1150.00 11.35 78.50 1146.60 2.47 -0.02 3.21 0.03 3.00 0.17 0.17 3.21 2.54 80.16 MWD+SAG 1175.00 12.04 79.95 1171.08 2.50 -0.02 3.35 0.04 3.00 0.18 0.18 3.35 2.59 79.97 MWD+SAG 1200.00 12.74 81.25 1195.50 2.54 -0.02 3.50 0.04 3.00 0_18 0.19 3.50 2.64 79.77 MWD+SAG 1225.00 13.44 82.42 1219.85 2.57 -0.02 3.69 0.05 3.00 0.19 0.20 3.69 2.68 80.15 MWD+SAG 1250.00 14.15 83.47 1244.13 2.61 -0.02 3.88 0.05 2.99 0_20 0.21 3.88 2.72 80.41 MWD+SAG 1275.00 14.86 84.42 1268.33 2.64 -0.03 4.07 0.06 2.99 0.21 0.22 4.08 2.76 80.58 MWD+SAG 1300.00 15.57 85.29 1292.45 2.67 -0.03 4.26 0.07 2.99 0.21 0.23 4.27 2.81 80.71 MWD+SAG 1325.00 16.29 86.08 1316.49 2.72 -0.03 4.51 0.08 2_99 0.22 0.24 4.52 2.86 81.27 MWD+SAG 1350.00 17.01 86.81 1340.44 2.76 -0.03 4.75 0.09 2.98 0.23 0.25 4.77 2.91 81.70 MWD+SAG 1375.00 17.73 87.48 1364.30 2.80 -0.03 5.00 0.10 2.98 0.24 0.26 5.01 2_95 82_05 MWD+SAG 1400.00 18.46 88.10 1388.07 2.84 -0.04 5.25 0.11 2.98 0.25 0.27 5.26 3.00 82.33 MWD+SAG 1425.00 19.19 88.68 1411.73 2.88 -0.04 5.55 0.12 2.97 0.26 0.29 5.57 3.06 82.89 MWD+SAG 1450.00 19.91 89.21 1435.29 2.93 -0_04 5_86 0.14 2.97 0.26 0_30 5.88 3.11 83.34 MWD+SAG 1475.00 20.64 89.71 1458.74 2.98 -0.04 6.16 0.15 2.97 0.27 0.32 6.18 3.17 83.72 MWD+SAG 1500.00 21.38 90_17 1482.08 3_02 -0_04 6.46 0.17 2.96 0.28 0.33 6.49 3.22 84.04 MWD+SAG 1525.00 22.11 90.61 1505.30 3.08 -0.05 6.83 0.19 2.96 0.29 0.35 6.86 3.28 84.55 MWD+SAG 1550.00 22.84 91.02 1528.40 3.13 -0.05 7.19 0.21 2.96 0.30 0.37 7.22 3.34 84.98 MWD+SAG 1575.00 23.58 91.40 1551.37 3.18 -0.05 7.55 0.22 2.95 0.31 0.39 7.58 3.40 85.34 MWD+SAG 1600.00 24.31 91.77 1574.22 3.23 -0.05 7.91 0.24 2.95 0.32 0.41 7.95 3.46 85.65 MWD+SAG 1625.00 25.05 92.11 1596.94 3.29 -0.06 8.33 0.27 2.95 0.33 0.43 8.37 3.52 86.10 MWD+SAG 1650.00 25.78 92.43 1619.52 3.34 -0.06 8.75 0.29 2_95 0_34 0.46 8.79 3_58 86_48 MWD+SAG 1675.00 26.52 92.74 1641.96 3.40 -0.06 9.17 0.32 2.95 0.35 0.48 9.21 3.64 86.81 MWD+SAG 1700.00 27.26 93.03 1664.26 3.45 -0.07 9.59 0.34 2_95 0.35 0_50 9.63 3.71 87.09 MWD+SAG 1725.00 28_00 93.31 1686.41 3.51 -0_07 10.06 0_37 2.95 0.36 0.53 10_11 3_77 87.49 MWD+SAG 1750.00 28.74 93.58 1708.40 3.57 -0.07 10.54 0.40 2.95 0.37 0.56 10.58 3_84 87.82 MWD+SAG 1775_00 29.48 93.83 1730_24 3_63 -0_08 11_01 0.43 2.95 0_38 0_59 11.06 3.90 88.10 MWD+SAG 1792.60 30.00 94.00 1745.52 3.67 -0.08 11.34 0.45 2.95 0.39 0.61 11.39 3.95 88.27 MWD+SAG 1800.00 30.30 94.00 1751.93 3.68 -0.08 11 .49 0.46 2.92 0.39 0.62 11.54 3.99 88.35 MWD+SAG 1825_00 31_30 94.00 1773.40 3_73 -0_09 12_04 0.50 2.93 0.40 0.66 12.08 4.06 88.71 MWD+SAG o , i ¡ ":1 '" I h ¡ .1 .! . f .k.. lker Hughes Incorporate\. ) Error Ellipse Survey Report Company: ConocoPhilliþs Alaska,lnc. Date: 5/13/2003 Time: 16:14:38 Page: 3 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 184, True North Site: Pad 1C Vertical (TVD) Reference: Wellhead(87') 87.0 Well: 184 Section (VS) Reference: Well (O.OON,O.OOE, 158.10Azi) Well path: 1C-184Vers#1 Survey Calculation Method: Minimum Curvature Db: Oracle Position uncertainty and bias at survey station All uncertainties at 2;6 standard deviation Highside---.,."> Latetal------> Vertical---~ Magn. Semi-major Semi;'minor MD InCl Azim TVD Unc. Bias Une. Bias Une. Bias of Bias Une. Une. AzimUth Tool ft deg deg ft ft ft ft ft .ft ft ft ft ft deg 1850.00 32.30 94.00 1794.65 3.79 -0.10 12.58 0.54 2.93 0.41 0.69 12.63 4.13 89.00 MWD+SAG 1875.00 33.30 94.00 1815.66 3.84 -0.10 13.13 0.58 2.94 0.42 0.73 13.17 4.19 89.23 MWD+SAG 1900.00 34.30 94.00 1836.44 3.88 -0.11 13.67 0.62 2.95 0.43 0.77 13.71 4.26 89.42 MWD+SAG 1925.00 35.30 94.00 1856.97 3.96 -0.12 14.29 0.66 2.95 0.44 0.81 14.32 4.34 89.83 MWD+SAG 1950_00 36.30 94.00 1877.25 4.01 -0.13 14.90 0.71 2.95 0.45 0.86 14.93 4.41 89.99 MWD+SAG 1975.00 37.30 94.00 1897.26 4.05 -0.13 15.51 0.76 2.96 0.46 0.90 15.54 4.49 90.05 MWD+SAG 2000.00 38.30 94.00 1917.02 4.10 -0.14 16.12 0.81 2.96 0.47 0.95 16.16 4.56 90.24 MWD+SAG 2025.00 39.30 94.00 1936.50 4.14 -0.15 16.80 0.86 2.97 0.48 1.00 16.84 4.63 90.38 MWD+SAG 2050.00 40.30 94.00 1955.71 4.20 -0.16 17.49 0.92 2.98 0.48 1.06 17.51 4.71 90.54 MWD+SAG 2075.00 41.30 94.00 1974.64 4.25 -0.17 18.17 0.97 2.99 0.49 1.11 18.19 4.78 90.71 MWD+SAG 2100.00 42.30 94.00 1993.27 4.31 -0.18 18.85 1.03 3.00 0.50 1.17 18.87 4.85 90.88 MWD+SAG 2125.00 43.30 94.00 2011.62 4.36 -0.19 19.59 1.10 3.01 0.51 1.23 19.62 4.93 91.01 MWD+SAG 2150.00 44.30 94.00 2029.66 4.41 -0.20 20.34 1.16 3.03 0.52 1.29 20.36 5.00 91.14 MWD+SAG 2175.00 45.30 94.00 2047.40 4.47 -0.21 21.08 1.23 3.05 0.53 1.36 21.10 5.07 91.26 MWD+SAG 2200.00 46.30 94.00 2064.83 4.52 -0.22 21.82 1.29 3.06 0.54 1.42 21.85 5.14 91.39 MWD+SAG 2225.00 47.30 94.00 2081.95 4.57 -0.22 22.63 1.37 3.09 0.54 1.49 22.65 5.21 91.49 MWD+SAG 2250.00 48.30 94.00 2098.74 4.63 -0.23 23.43 1.44 3.12 0.55 1.57 23.45 5.28 91.59 MWD+SAG 2275.00 49.30 94.00 2115.21 4.68 -0.24 24.23 1.52 3_14 0.56 1.64 24_25 5_35 91.69 MWD+SAG 2300.00 50.30 94.00 2131.35 4.73 -0.26 25.03 1.59 3.17 0.57 1.71 25.05 5.41 91.78 MWD+SAG 2325.00 51.30 94.00 2147.15 4.78 -0.27 25.87 1.67 3.18 0.57 1.79 25.89 5.49 91.87 MWD+SAG 2336.60 51.76 94.00 2154.37 4.81 -0.27 26.26 1.71 3.19 0.58 1.83 26.28 5.53 91.90 MWD+SAG 2350.00 51.76 94.00 2162.66 4.86 -0.27 26.72 1.75 3.22 0.58 1.87 26.74 5.56 91.95 MWD+SAG 2375.00 51_76 94.00 2178.14 4.95 -0.27 27.57 1.84 3_27 0_59 1.95 27.59 5.61 92.02 MWD+SAG 2400.00 51.76 94.00 2193.61 5.04 -0.27 28.42 1.92 3.33 0.60 2.03 28.44 5.67 92.09 MWD+SAG 2425.00 51.76 94.00 2209.08 5.14 -0.27 29.28 2.00 3.39 0.60 2.12 29.29 5.72 92.16 MWD+SAG 2450.00 51.76 94.00 2224.56 5.23 -0.27 30.13 2.08 3.45 0.61 2.20 30.15 5.77 92.22 MWD+SAG 2475.00 51.76 94.00 2240.03 5.33 -0.27 30.99 2.17 3.52 0.62 2.28 31.00 5.82 92.28 MWD+SAG 2500.00 51.76 94.00 2255.50 5.42 -0.27 31.84 2.25 3.58 0.63 2.36 31.86 5.88 92.34 MWD+SAG 2525.00 51.76 94.00 2270.98 5.52 -0.27 32.70 2.33 3.65 0.64 2.44 32.72 5.93 92.39 MWD+SAG 2550.00 51.76 94.00 2286.45 5.61 -0.27 33.56 2.41 3.71 0.64 2.53 33.58 5.98 92.44 MWD+SAG 2575.00 51.76 94.00 2301.93 5.71 -0.27 34.42 2.50 3.78 0.65 2.61 34.43 6.04 92.49 MWD+SAG 2600.00 51.76 94.00 2317.40 5.81 -0.27 35.28 2.58 3.84 0.66 2.69 35.29 6.09 92.53 MWD+SAG 2625.00 51.76 94.00 2332.87 5.90 -0.27 36.14 2.66 3.91 0.67 2.78 36.15 6.14 92.58 MWD+SAG 2650.00 51.76 94.00 2348.35 6.00 -0.27 37.01 2.74 3.98 0.68 2.86 37.02 6.20 92.62 MWD+SAG 2675.00 51.76 94.00 2363.82 6.10 -0.27 37.87 2.83 4.05 0.68 2.94 37.88 6.25 92.66 MWD+SAG 2700.00 51.76 94.00 2379.30 6.19 -0.27 38.73 2.91 4.12 0.69 3.02 38.74 6.30 92_69 MWD+SAG 2725.00 51.76 94.00 2394.77 6.29 -0.27 39.59 2.99 4.19 0.70 3.11 39.60 6.36 92.73 MWD+SAG 2750.00 51.76 94.00 2410.24 6.39 -0.27 40.46 3.08 4.26 0.71 3.19 40.47 6.41 92.76 MWD+SAG 2775.00 51.76 94.00 2425.72 6.49 -0_27 41_32 3_16 4_33 0.72 3.27 41.33 6.47 92_80 MWD+SAG 2800.00 51.76 94.00 2441 .19 6.58 -0.27 42.19 3.24 4.40 0.73 3.36 42.20 6.52 92.83 MWD+SAG 2825_00 51.76 94_00 2456_67 6.68 -0.27 43_05 3_32 4.47 0_73 3.44 43.06 6.58 92_86 MWD+SAG 2850.00 51.76 94_00 2472.14 6.78 -0.27 43.92 3.41 4.54 0.74 3.52 43.93 6.63 92.88 MWD+SAG 2875.00 51.76 94.00 2487.61 6.88 -0.27 44.78 3.49 4.61 0.75 3.61 44.79 6.69 92.91 MWD+SAG 2900.00 51_76 94.00 2503.09 6_98 -0_27 45_65 3_57 4.68 0.76 3.69 45.66 6.74 92.94 MWD+SAG 2925.00 51.76 94.00 2518.56 7.08 -0.27 46.52 3.65 4.76 0.77 3.77 46.52 6.80 92.96 MWD+SAG 2950.00 51.76 94.00 2534.04 7.18 -0.27 47.38 3.74 4.83 0.78 3.86 47.39 6.86 92.99 MWD+SAG 2975.00 51.76 94.00 2549.51 7.28 -0.27 48.25 3.82 4.90 0.79 3.94 48.26 6.91 93.01 MWD+SAG 3000.00 51.76 94.00 2564.98 7.37 -0.27 49.12 3.90 4.98 0.80 4.02 49.13 6.97 93_04 MWD+SAG 3025.00 51.76 94.00 2580.46 7.47 -0.27 49.99 3.98 5.05 0.81 4.11 49.99 7.02 93.06 MWD+SAG 3050.00 51.76 94.00 2595.93 7.57 -0.27 50.85 4.07 5.13 0.82 4.19 50.86 7_08 93_08 MWD+SAG 3075.00 51.76 94.00 2611 .4 1 7.67 -0.27 51.72 4.15 5.20 0_82 4.27 51_73 7.14 93.10 MWD+SAG 3100.00 51.76 94.00 2626_88 7.77 -0.27 52.59 4.23 5.27 0_83 4_36 52_60 7_19 93_12 MWD+SAG O )"". ~ i'~l ~''7/ ~ ~ j ';.,¡!i I~ ! "l'tl L~ker Hughes Incorporatel. ) Error Ellipse Survey Report Company: ConocoPhillips Alaska, Inc. Date: 5/13/2003 Time: 16:14:38 Page: 4 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 184, True North Site: Pad 1C Vertical (TVD)Refei'erice: Wellhead(87') 87.0 Well: 184 . Section (VS) Refetence: Well (O.OON,O.OOE, 158.1 OAzi) Wellpath: 1C-184 Vers#1 Surveÿ Calculation Method: Minimum Curvature Db: Oracle Positiori uncertainty arid bias at survey statiori All uncertainties at 2.6.· standard deviation Highside~---> Lateral----",,-> V ertical---.,~ Magn. . Semi-major Semi-minor MD Incl Azim TVD Un£~. Bias Unc. Bias Unc. Bias of Bias · Unc~ Unc~ Azimuth Tool ft deg deg .ft ft ft ft ft ft ft ft ft ft deg 3125.00 51.76 94.00 2642.35 7.87 -0.27 53.46 4.32 5.35 0.84 4.44 53.47 7.25 93.14 MWD+SAG 3150.00 51.76 94.00 2657.83 7.97 -0.27 54.33 4.40 5.42 0.85 4.53 54.33 7.31 93.16 MWD+SAG 3175.00 51_76 94.00 2673.30 8.07 -0.27 55.20 4.48 5.50 0.86 4.61 55.20 7.37 93.17 MWD+SAG 3200.00 51.76 94.00 2688.77 8.17 -0.27 56.07 4.56 5.57 0.87 4.69 56.07 7.42 93.19 MWD+SAG 3225.00 51.76 94.64 2704.25 8.25 -0.24 56.85 4.64 5.63 0.88 4.78 56.87 7.46 93.22 MWD+SAG 3250.00 51.76 95.27 2719.72 8.36 -0.21 57.63 4.71 5.69 0.89 4.86 57.67 7.49 93.24 MWD+SAG 3275.00 51.76 95.91 2735.20 8.47 -0.17 58.41 4.79 5.75 0.90 4.95 58.47 7.53 93.27 MWD+SAG 3279.57 51.76 96.03 2738.03 8.50 -0.17 58.55 4.80 5.76 0.90 4.96 58.62 7.53 93.27 MWD+SAG 3300.00 51.76 96.03 2750.67 8.55 -0.17 59.21 4.87 5.81 0.91 5.03 59.27 7.56 93.30 MWD+SAG 3325.00 51.76 96.03 2766.15 8.65 -0.17 60.08 4.95 5.88 0.92 5.12 60.14 7.62 93.35 MWD+SAG 3350.00 51.76 96.03 2781.62 8_75 -0.17 60_95 5.04 5.96 0.93 5.20 61.02 7.68 93.39 MWD+SAG 3375.00 51.76 96.03 2797.09 8.85 -0.17 61.82 5.12 6.03 0.94 5.29 61.89 7.74 93.43 MWD+SAG 3400.00 51.76 96.03 2812.57 8.95 -0.17 62.70 5.20 6.11 0.95 5.37 62.76 7.79 93.47 MWD+SAG 3425.00 51.76 96.03 2828.04 9.05 -0.17 63.57 5.29 6.19 0.96 5.46 63.63 7.85 93.51 MWD+SAG 3450.00 51.76 96.03 2843.52 9.14 -0.17 64.45 5.37 6.26 0.97 5.54 64.51 7.91 93.55 MWD+SAG 3475.00 51.76 96.03 2858.99 9_24 -0.17 65.32 5.46 6.34 0_98 5.63 65.38 7.97 93.58 MWD+SAG 3500.00 51.76 96.03 2874.46 9.34 -0.17 66.19 5.54 6.42 0.99 5.71 66.25 8.03 93.62 MWD+SAG 3525.00 51.76 96.03 2889.94 9.44 -0.17 67.07 5.62 6.50 1.00 5.80 67.12 8.09 93.66 MWD+SAG 3550.00 51.76 96.03 2905.41 9.54 -0.17 67.94 5.71 6.57 1.01 5.88 68.00 8.15 93.69 MWD+SAG 3575.00 51.76 96.03 2920.89 9.64 -0.17 68.82 5.79 6.65 1.02 5.97 68.87 8.21 93.72 MWD+SAG 3600.00 51.76 96.03 2936.36 9.74 -0_17 69.69 5_87 6_73 1.03 6.05 69.74 8.26 93.76 MWD+SAG 3625.00 51.76 96.03 2951.83 9.84 -0.17 70.56 5.96 6.80 1.04 6.14 70.62 8.32 93.79 MWD+SAG 3650.00 51.76 96.03 2967.31 9.94 -0.17 71.44 6.04 6.88 1.05 6.23 71.49 8.38 93.82 MWD+SAG 3675.00 51.76 96.03 2982.78 10.04 -0.17 72.31 6.13 6.96 1.07 6.31 72.36 8.44 93.85 MWD+SAG 3700.00 51.76 96.03 2998.26 10.14 -0.17 73.19 6.21 7.04 1.08 6.40 73.24 8.50 93.88 MWD+SAG 3725.00 51.76 96.03 3013.73 10_24 -0.17 74.06 6.29 7.12 1.09 6.48 74.11 8.56 93.91 MWD+SAG 3750.00 51.76 96.03 3029.20 10.34 -0.17 74.94 6.38 7.19 1.10 6.57 74.99 8.62 93.93 MWD+SAG 3775.00 51.76 96.03 3044.68 1 0.44 -0.17 75.81 6.46 7.27 1.11 6.65 75.86 8.68 93.96 MWD+SAG 3793.04 51.76 96.03 3055.84 10.51 -0.17 76.44 6.52 7.33 1.12 6.71 76.49 8.72 93.98 MWD+SAG 3800.00 51.79 96.38 3060.15 10.57 -0.14 76.65 6.54 7.35 1.12 6.74 76.72 8.73 93.99 MWD+SAG 3825.00 51_88 97.64 3075.60 10.80 -0.06 77.32 6.60 7.39 1.13 6.83 77.47 8.76 94.04 MWD+SAG 3850.00 52.00 98.91 3091.01 11.13 0.03 77.95 6.65 7.44 1.14 6.91 78.22 8.77 94.08 MWD+SAG 3875.00 52.12 100.16 3106.38 11.54 0.11 78.55 6.70 7.49 1.15 7.00 78.98 8.79 94.13 MWD+SAG 3900.00 52.26 101.42 3121.71 12.03 0.20 79.10 6.75 7.54 1.17 7.09 79.73 8.81 94.18 MWD+SAG 3925.00 52.42 102.67 3136.98 12.57 0.28 79.64 6.79 7.59 1.18 7.18 80.49 8.83 94.27 MWD+SAG 3950.00 52.58 103.91 3152.20 13.16 0.37 80.14 6.84 7.64 1.19 7.27 81.25 8.86 94.36 MWD+SAG 3975.00 52.76 105.15 3167.36 13.81 0.45 80.61 6.88 7_69 1.20 7.36 82_02 8.87 94.45 MWD+SAG 4000.00 52.95 106.38 3182.45 14.49 0.53 81.04 6.92 7.74 1.21 7.45 82.78 8.89 94.54 MWD+SAG 4025.00 53.16 107.60 3197.48 15.18 0_61 81.45 6_95 7.80 1.22 7.54 83_54 8.92 94_68 MWD+SAG 4050.00 53.38 108.82 3212.43 15.90 0.68 81.83 6.99 7.86 1.23 7.63 84.31 8.95 94.81 MWD+SAG 4075.00 53.61 110.03 3227.31 16.63 0.76 82.17 7.02 7.91 1.24 7.72 85.07 8.97 94.94 MWD+SAG 4100.00 53_85 111 .23 3242.10 17.38 0_84 82.48 7_05 7_97 1.25 7_81 85_83 8.98 95.08 MWD+SAG 4125.00 54.10 112.43 3256.80 18.11 0.91 82.77 7.07 8.03 1.27 7.91 86.59 9.02 95.24 MWD+SAG 4150.00 54.37 113_62 3271.41 18_85 0.98 83.03 7.10 8.09 1.28 8.00 87.35 9.06 95.41 MWD+SAG 4175.00 54.64 114.80 3285.93 19.59 1.04 83.26 7.12 8.15 1.29 8.09 88.11 9.09 95.58 MWD+SAG 4200.00 54.93 115.97 3300.35 20.32 1.11 83.46 7.14 8.21 1.30 8.18 88.88 9.10 95.75 MWD+SAG 4225_00 55.23 117.14 3314.66 21.03 1.17 83.64 7.16 8.27 1.31 8.28 89.63 9.16 95.95 MWD+SAG 4250.00 55.54 118.29 3328.86 21_72 1.23 83.79 7.18 8.34 1.32 8.37 90.38 9.21 96_15 MWD+SAG 4275.00 55.86 119.44 3342.95 22.41 1.29 83.92 7.19 8.40 1.33 8.46 91.13 9.25 96.35 MWD+SAG 4300.00 56.19 120.57 3356.92 23.08 1.35 84_02 7_20 8.47 1.34 8_56 91.89 9.28 96.55 MWD+SAG 4325.00 56.54 121.70 3370.76 23.71 1.40 84.10 7.21 8.54 1.35 8_65 92.63 9_36 96_78 MWD+SAG 4350.00 56.89 122.82 3384.49 24.33 1.44 84.15 7.22 8.60 1.36 8.74 93.37 9.42 97.01 MWD+SAG 4375.00 57.25 123.93 3398_08 24.93 1.49 84_19 7.23 8_67 1_37 8_84 94.11 9.48 97.24 MWD+SAG On "1 I .' ~"~~ ii",., " r ~,_i f ,¡ ". I i C_'?I l lker Hughes Incorporate\. ) Error Ellipse Survey Report Company: ConocoPhillips Alaska, Inc. Date: 5/13/2003 Time: 16:14:38 Page: 5 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 184. True North Site: Pad 1 C Vertical (TVD) Reference: Wellhead(87') 87.0 Well: 184 Section (VS) Reference: Well(O.OON.O~OOE, 158.1 OAzi) Wellpath: 1C-184 Vers#1 Survey CalCulation Method: Minimum Curvature Db: .Oracle Position uncertainty and bias at survey station All uncertainties at 2.6 standard deviation Highside----~> Lateral-------> Vertical-:..----> Magn. Semi-major Semi':'minor MD Incl Azim TVD Unc. Bias Unc. Bias Unc. Bias of Bias . Unc. Unc. Azimuth Tool ft deg deg ft ft ft ft ft ft ft ft ft ft deg 4400.00 57.62 125.03 3411.53 25.51 1.53 84.20 7.23 8.74 1.38 8.93 94.86 9.52 97.47 MWD+SAG 4425.00 58.00 126.13 3424.85 26.04 1.57 84.19 7.24 8.81 1.39 9.02 95.58 9.62 97.72 MWD+SAG 4450.00 58.39 127.21 3438.02 26.56 1.61 84.17 7.24 8.89 1.40 9.11 96.30 9.71 97.97 MWD+SAG 4475.00 58.79 128.28 3451.05 27.05 1.64 84.12 7.24 8.96 1.41 9.21 97.03 9.78 98.22 MWD+SAG 4500.00 59.20 129.35 3463.93 27.51 1.67 84.06 7.24 9.03 1.42 9.30 97.76 9.84 98.48 MWD+SAG 4525.00 59.62 130.40 3476.65 27.93 1.70 83.98 7.24 9.11 1.43 9.39 98.47 9.98 98.75 MWD+SAG 4550.00 60.05 131 .45 3489.21 28.33 1.72 83.88 7.23 9.19 1.44 9.48 99.18 10.09 99.02 MWD+SAG 4575.00 60.48 132.49 3501.61 28.69 1.74 83.77 7_23 9.26 1.45 9.57 99.89 10.19 99.29 MWD+SAG 4600.00 60.92 133.52 3513.85 29.03 1.76 83.65 7.22 9.34 1.46 9.66 100.60 10.28 99.57 MWD+SAG 4625.00 61.37 134.54 3525.91 29.32 1.77 83.50 7.21 9.42 1.47 9.75 101.28 10.44 99.85 MWD+SAG 4650.00 61.83 135.55 3537.80 29.59 1.78 83.34 7.20 9.50 1.48 9.84 101.97 10.59 100.14 MWD+SAG 4675.00 62.29 136.55 3549.52 29.82 1.79 83.17 7.19 9.58 1.49 9.93 102.66 10.72 100.43 MWD+SAG 4700.00 62.77 137.54 3561.05 30.03 1_79 82.99 7.18 9.67 1.50 10_02 103.36 10.84 100.72 MWD+SAG 4725.00 63.24 138.53 3572.40 30.19 1.79 82.79 7.17 9.75 1.51 10.11 104.02 11.03 101.03 MWD+SAG 4750.00 63.73 139.51 3583.56 30.32 1.78 82.59 7.15 9.84 1.51 10.19 104.69 11.22 101.33 MWD+SAG 4775.00 64.22 140.48 3594.53 30.42 1.78 82.37 7.14 9.92 1.52 10.28 105.36 11.38 101.63 MWD+SAG 4800.00 64.72 141 .44 3605.30 30.49 1.77 82.14 7.12 10.01 1.53 10.37 106.03 11.53 101.94 MWD+SAG 4825.00 65.22 142.39 3615_88 30.51 1.75 81.90 7.10 10_09 1_54 10.45 106.67 11.76 102.25 MWD+SAG 4850.00 65.73 143.33 3626.25 30.51 1.73 81.65 7.08 10.18 1.55 10.54 107.31 11.98 102.56 MWD+SAG 4875.00 66.25 144.27 3636.42 30.47 1.71 81.39 7.06 10.27 1.55 10.62 107.96 12.18 102.88 MWD+SAG 4900.00 66.77 145.20 3646.39 30.41 1.68 81.13 7.04 10.36 1.56 10.71 108.61 12.37 103.19 MWD+SAG 4925.00 67.30 146.12 3656.14 30.30 1.65 80.84 7.02 10.45 1.57 10.79 109.22 12.64 103.52 MWD+SAG 4950.00 67.83 147.04 3665.68 30.16 1.62 80.56 6.99 10.54 1.58 10.87 109.84 12.90 103.84 MWD+SAG 4975.00 68.37 147.95 3675.01 30.00 1.59 80.27 6.97 10.64 1.58 10.95 110.46 13.14 104.17 MWD+SAG 5000.00 68.91 148.85 3684.11 29.80 1.55 79.97 6.94 10.73 1.59 11.03 111.09 13.36 104.49 MWD+SAG 5025.00 69.46 149.75 3693.00 29.56 1.50 79.66 6.91 10.82 1.60 11.11 111.68 13.68 104.82 MWD+SAG 5050.00 70.01 150.63 3701.65 29.30 1.46 79.34 6.88 10.92 1.60 11.19 112.27 13.97 105.15 MWD+SAG 5075.00 70.57 151.52 3710.09 29.01 1.41 79.03 6.85 11.01 1.61 11.27 112.87 14.25 105.49 MWD+SAG 5100.00 71.13 152.39 3718.29 28.69 1.36 78.70 6.82 11.11 1.61 11.34 113.47 14.52 105.82 MWD+SAG 5125.00 71.69 153.27 3726.26 28.33 1.30 78.37 6.79 11.21 1.62 11 .42 114.03 14.87 106.15 MWD+SAG 5150.00 72.26 154.13 3733.99 27.95 1.24 78.03 6.75 11.31 1.63 11.49 114.59 15.20 106.49 MWD+SAG 5175.00 72.83 154.99 3741.49 27.55 1.18 77.68 6.71 11.40 1.63 11.57 115.17 15.52 106.83 MWD+SAG 5200.00 73.41 155.84 3748.75 27.11 1.11 77.34 6.68 11.50 1.64 11.64 115.74 15.82 107.17 MWD+SAG 5225.00 73.99 156.69 3755.76 26.65 1.04 76.98 6.64 11.60 1.64 11.71 116.28 16.21 107.51 MWD+SAG 5250.00 74.57 157.54 3762.54 26.17 0.97 76.62 6.59 11.70 1.65 11.78 116.82 16.59 107.85 MWD+SAG 5275.00 75.16 158.38 3769.06 25.66 0.90 76_26 6_55 11.80 1_65 11_85 117.36 16.95 108_19 MWD+SAG 5300.00 75.75 159.21 3775.34 25.13 0.82 75.90 6_51 11.91 1.65 11.92 117.91 17.29 108.53 MWD+SAG 5325.00 76.34 160.04 3781.37 24.58 0.74 75.53 6.46 12.01 1.66 11.98 118.42 17.72 108.88 MWD+SAG 5350.00 76.93 160.87 3787.15 24.01 0_66 75.15 6.41 12_11 1_66 12.05 118.93 18_13 109.22 MWD+SAG 5375.00 77.53 161.69 3792.68 23.43 0.57 74.78 6.36 12.22 1.67 12.11 119.45 18.52 109.57 MWD+SAG 5400_00 78.13 162.51 3797_95 22.83 0.48 74.40 6_31 12_32 1_67 12.18 119.97 18.91 109.91 MWD+SAG 5425.00 78.73 163.33 3802.96 22.22 0.39 74.02 6.26 12.42 1.67 12.24 120.45 19.37 110.26 MWD+SAG 5450.00 79.34 164.14 3807.72 21.59 0.29 73.63 6_20 12.53 1.68 12.30 120.94 19.82 110_61 MWD+SAG 5475_00 79_94 164_95 3812.21 20.96 0.20 73.25 6_14 12.63 1.68 12.36 121.43 20.25 110.96 MWD+SAG 5500.00 80.55 165_75 3816.45 20.33 0.10 72.86 6.09 12.74 1.68 12.42 121.93 20.67 111.30 MWD+SAG 5525.00 81.16 166.55 3820.42 19.70 -0.01 72 .46 6.02 12.85 1.68 12.47 122.38 21 _16 111.65 MWD+SAG 5550.00 81.77 167.35 3824.13 19.07 -0.11 72.07 5.96 12.95 1.69 12.53 122.84 21_65 112_00 MWD+SAG 5575.00 82.39 168.15 3827.58 18.45 -0.22 71.68 5.89 13.06 1.69 12.58 123.30 22.11 112.35 MWD+SAG 5600.00 83.00 168_95 3830.76 17.84 -0.33 71.29 5.83 13.17 1.69 12.64 123.78 22.57 112.70 MWD+SAG 5625.00 83.62 169.74 3833.67 17_25 -0.44 70_88 5_75 13_27 1.69 12.69 124.20 23_09 113_05 MWD+SAG 5650.00 84.23 170.53 3836.32 16.69 -0.55 70.48 5.68 13.38 1.69 12_74 124.63 23.61 113.40 MWD+SAG 5675.00 84.85 171.32 3838.69 16_17 -0_67 70_09 5_61 13.49 1.69 12_79 125_07 24_11 113.75 MWD+SAG Of""" ·{"'ì" 1 ~' t If i, , t ; '···~i \.;f i J ;,! / '. ~ llker Hughes Incorporatel.) Error Ellipse Survey Report Company: ConocoPhillips Alaska, Inc. Date: 5/13/2003 Time: 16:14:38 Page: 6 Field: Kupäruk River Unit Co-ordinate(NE) Reference: Well: 184, True North Site: Pad 1 C Vertical (TVD)Reference: Wellhead(8?') 87;0 Well: 184 Section (VS) Reference: Well (O.OON,O.OOE, 158.1 OAzi) Well path: 1 C~184V ers#1 Survey Calculation Method: Minimum Curvature Db: Oracle Position uncertainty and bias at survey station Alluncertaiiltiesat .2. 6 standard deviation Highside--.;-;,;-> Lateral-~-----> Vertical-----:> Mago~ . Semi~major Semi-minor MD Incl Azim TVD Unc. Bias Uile. Bias Uoc; Bias of Bias Unc; Une. Azimuth Tool ft deg deg ft ft ft ft ft ft ft ft ft ft deg 5700.00 85.47 172.11 3840.80 15.69 -0.79 69.69 5.53 13.60 1.70 12.84 125.51 24.59 114.10 MWD+SAG 5725.00 86.09 172.89 3842.64 15.27 -0.91 69.29 5.45 13.71 1.70 12.88 125.91 25.15 114.45 MWD+SAG 5750.00 86.71 173.68 3844.21 14.90 -1.03 68.89 5.36 13.82 1.70 12.93 126.32 25.69 114.80 MWD+SAG 5775.00 87.33 174.46 3845.51 14.61 -1.15 68.49 5.28 13.93 1.70 12.97 126.73 26.22 115.15 MWD+SAG 5800.00 87.96 175.25 3846.54 14.41 -1.28 68.09 5.19 14.04 1.70 13.01 127.15 26.73 115.50 MWD+SAG 5825.00 88.58 176.03 3847.29 14.29 -1 .40 67.69 5.10 14.14 1.70 13.05 127.52 27.30 115.85 MWD+SAG 5850.00 89.20 176.81 3847.78 14.27 -1.53 67.30 5.01 14.25 1.70 13.09 127.90 27.86 116.20 MWD+SAG 5875.00 89.82 177.60 3847.99 14.35 -1.66 66.90 4.91 14.36 1.70 13.13 128.29 28.41 116.55 MWD+SAG 5884.36 90.06 177.89 3848.00 14.41 -1.71 66.75 4.88 14.40 1.70 13.15 128.44 28.61 116.68 MWD+SAG 5900.00 90.06 177.89 3847.98 14.48 -1.71 67.32 4.92 14.47 1.70 13.17 128.68 28.87 116.90 MWD+SAG 5925.00 90.06 177.89 3847.96 14.58 -1_71 68.19 4.99 14.58 1.70 13.21 129.07 29.15 117.25 MWD+SAG 5950.00 90.06 177.89 3847.93 14.69 -1.71 69.06 5.05 14.68 1.70 13.24 129.47 29.42 117.60 MWD+SAG 5975.00 90.06 177.89 3847.91 14.79 -1.71 69.93 5.12 14.79 1.70 13.28 129.88 29.69 117.94 MWD+SAG 6000.00 90.06 177.89 3847.88 14.90 -1.71 70.81 5.19 14.89 1.70 13.32 130.30 29.94 118.29 MWD+SAG 6025.00 90.06 177.89 3847.86 15.01 -1.71 71.69 5.25 15.00 1.70 13.35 130.71 30.23 118.63 MWD+SAG 6050.00 90.06 177.89 3847.83 15_11 -1.71 72.57 5.32 15.11 1.70 13.39 131.13 30.51 118.97 MWD+SAG 6075.00 90.06 177.89 3847.81 15.22 -1.71 73.45 5.39 15.21 1.70 13.43 131.56 30.78 119.31 MWD+SAG 6100.00 90.06 177.89 3847.78 15.32 -1.71 74.33 5.45 15.32 1.70 13.47 131.99 31.03 119.66 MWD+SAG 6125.00 90.06 177.89 3847.76 15.43 -1.71 75.22 5.52 15.42 1.70 13.51 132.43 31.33 120.00 MWD+SAG 6150.00 90.06 177.89 3847.73 15.54 -1.71 76.11 5.59 15.53 1.70 13.55 132.87 31.61 120.33 MWD+SAG 6175.00 90.06 177.89 3847.71 15.64 -1.71 77_00 5.65 15.64 1.70 13_59 133.31 31.89 120.67 MWD+SAG 6200.00 90.06 177.89 3847.68 15.75 -1.71 77.89 5.72 15.74 1.70 13.63 133.77 32.15 121.01 MWD+SAG 6225.00 90.06 177.89 3847.66 15.86 -1.71 78.79 5.79 15.85 1.70 13.67 134.22 32.44 121.34 MWD+SAG 6250.00 90.06 177.89 3847.63 15.96 -1.71 79.69 5.85 15.96 1.70 13.70 134.68 32.73 121.68 MWD+SAG 6275.00 90.06 177.89 3847.61 16.07 -1.71 80.58 5.92 16.07 1.70 13.75 135.15 33.00 122.01 MWD+SAG 6300.00 90.06 177.89 3847_58 16.18 -1.71 81 .48 5.99 16.17 1.70 13.79 135.62 33.27 122.34 MWD+SAG 6325.00 90.06 177.89 3847.56 16.28 -1.71 82.39 6.05 16.28 1.70 13.83 136.09 33.56 122.67 MWD+SAG 6350.00 90.06 177.89 3847.53 16.39 -1.71 83.29 6.12 16.39 1.70 13.87 136.57 33.85 123.00 MWD+SAG 6375.00 90.06 177.89 3847.51 16.50 -1.71 84.20 6.19 16.49 1.70 13.91 137.06 34.12 123.33 MWD+SAG 6400.00 90.06 177.89 3847.48 16.61 -1.71 85.10 6.25 16.60 1.70 13.95 137.55 34.39 123.66 MWD+SAG 6425.00 90.06 177.89 3847.46 16.71 -1.71 86.02 6.32 16.71 1.70 13.99 138.05 34.68 123.98 MWD+SAG 6450.00 90.06 177.89 3847.43 16.82 -1.71 86.93 6.39 16.82 1.70 14.03 138.54 34.96 124.31 MWD+SAG 6475.00 90.06 177.89 3847.41 16.93 -1.71 87.84 6.45 16.93 1.70 14.07 139.05 35.23 124.63 MWD+SAG 6500.00 90.06 177.89 3847.39 17.04 -1.71 88.75 6.52 17.03 1.70 14.11 139.56 35.49 124.95 MWD+SAG 6525.00 90.06 177.89 3847.36 17.15 -1.71 89.67 6.59 17.14 1.70 14.16 140.07 35.78 125.27 MWD+SAG 6550.00 90.06 177.89 3847.34 17.26 -1.71 90.58 6.65 17.25 1.70 14.20 140.59 36.06 125.59 MWD+SAG 6575.00 90.06 177.89 3847.31 17.36 -1.71 91.50 6.72 17.36 1.70 14.24 141.11 36_33 125_90 MWD+SAG 6600.00 90.06 177.89 3847.29 17.47 -1.71 92.42 6.79 17.47 1.70 14.28 141.64 36.59 126.22 MWD+SAG 6625.00 90.06 177.89 3847.26 17.58 -1.71 93_34 6_85 17.58 1_70 14.33 142.17 36_87 126.53 MWD+SAG 6650.00 90.06 177.89 3847.24 17.69 -1.71 94.26 6.92 17.68 1.70 14.37 142.71 37.14 126.85 MWD+SAG 6675.00 90.06 177.89 3847.21 17.80 -1.71 95.18 6.99 17.79 1.70 14.41 143.25 37.40 127_16 MWD+SAG 6700.00 90.06 177_89 3847_19 17.91 -1_71 96_10 7_05 17.90 1.70 14.46 143.80 37_66 127.46 MWD+SAG 6725.00 90.06 177.89 3847_16 18.02 -1.71 97.03 7.12 18.01 1.70 14.50 144.35 37.93 127.77 MWD+SAG 6750.00 90_06 177_89 3847_14 18.12 -1_71 97.95 7.19 18.12 1.70 14.55 144.90 38.19 128.08 MWD+SAG 6775.00 90.06 177.89 3847.11 18.23 -1.71 98.88 7.25 18.23 1.70 14.59 145.46 38.45 128.38 MWD+SAG 6800.00 90.06 177.89 3847.09 18.34 -1.71 99.80 7.32 18.34 1_70 14.63 146.03 38.70 128.68 MWD+SAG 6825.00 90.06 177.89 3847.06 18.45 -1.71 100.73 7.39 18.45 1.70 14.68 146.60 38_96 128.98 MWD+SAG 6850.00 90.06 177.89 3847.04 18_56 -1.71 101.66 7.45 18.56 1.70 14.72 147.17 39.22 129.28 MWD+SAG 6875.00 90.06 177.89 3847.01 18.67 -1.71 102.59 7.52 18.67 1.70 14.77 147.75 39.47 129.58 MWD+SAG 6885.47 90.06 177.89 3847.00 18.72 -1.71 102.98 7.55 18_71 1_70 14.79 147_99 39_57 129.70 MWD+SAG 6900.00 90.45 178.08 3846.94 18.83 -1.80 103.20 7.54 18.78 1.70 14.81 148.32 39.76 129_88 MWD+SAG 6906.85 90.63 178.18 3846.87 18.89 -1.84 103_31 7.54 18.81 1.70 14.82 148.48 39.84 129.96 MWD+SAG 6925_00 90.63 178.18 3846.67 18.97 -1.84 104_00 7.59 18_89 1_70 14.86 148_90 40.08 130.18 MWD+SAG ~~ llker Hughes Incorporatet) Error Ellipse Survey Report Company: ConocoPhillips Alaska, Inc. Date: 5/13/2003 Time: 16:14:38 Page: 7 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: ·184; True North Site: Pad 1 C Vertical (TVD) Reference: Wêllhêad(8?') 87.0 Well: 184 Section (VS) Reference: Well (0:00N,0.00E,158.1 OAzi) Well path: 1 C,;.184 Vers#1 Survey CalculationMethod: Minimum Curvature Db: Oracle Positionuncettainty and bias at survey station All uncertainties at . 2.6 standard deviation. Highside-----> Lateral-------> Vertical':"-,.-> Magn. Senii,;.major Semi;'minot MD Incl Azim TVD Unc. Bias Unc. Bias Unc. Bias of Bias Une. Une. Azimuth Tool ft deg deg ft ft ft ft ft ft ft ft ft ft deg 6950.00 90.63 178.18 3846.40 19.08 -1.84 104.95 7.66 19.00 1.70 14.90 149.48 40.40 130.48 MWD+SAG 6975.00 90.63 178.18 3846.12 19.19 -1.84 105.91 7.72 19.11 1.70 14.95 150.07 40.71 130.77 MWD+SAG 7000.00 90.63 178.18 3845.85 19.31 -1.84 106.86 7.79 19.22 1.70 14.99 150.66 41.01 131.07 MWD+SAG 7025.00 90.63 178.18 3845.57 19.41 -1.84 107.79 7.85 19.33 1.70 15.04 151.26 41.26 131.36 MWD+SAG 7050.00 90.63 178.18 3845.30 19.52 -1.84 108.73 7.92 19.44 1.70 15.08 151.86 41.50 131.64 MWD+SAG 7075.00 90.63 178.18 3845.02 19.63 -1.84 109.66 7.99 19.55 1.70 15.13 152.47 41.74 131.93 MWD+SAG 7100.00 90.63 178.18 3844.74 19.74 -1.84 110.59 8.05 19.66 1.70 15.17 153.08 41.97 132.21 MWD+SAG 7125.00 90.63 178.18 3844.47 19.85 -1.84 111.53 8.12 19.77 1.70 15.22 153.69 42.21 132.49 MWD+SAG 7150.00 90.63 178.18 3844.19 19.96 -1.84 112.47 8.18 19.88 1.70 15.26 154.31 42.44 132.77 MWD+SAG 7175.00 90.63 178.18 3843.92 20.07 -1.84 113.40 8.25 19.99 1.70 15.31 154.93 42.67 133.04 MWD+SAG 7200.00 90.63 178.18 3843.64 20.18 -1.84 114.34 8.32 20.10 1.70 15.35 155.55 42.89 133.32 MWD+SAG 7225.00 90.63 178.18 3843.37 20.29 -1.84 115.28 8.38 20.21 1.70 15.40 156.18 43.13 133.59 MWD+SAG 7250.00 90.63 178.18 3843.09 20.40 -1.84 116_22 8.45 20.32 1.70 15.45 156.81 43.35 133_86 MWD+SAG 7275.00 90.63 178.18 3842.82 20.51 -1.84 117.16 8.51 20.43 1.70 15.49 157.45 43.57 134.13 MWD+SAG 7300.00 90.63 178.18 3842.54 20.62 -1.84 118.10 8.58 20.54 1.70 15.54 158.09 43.78 134.40 MWD+SAG 7325.00 90.63 178.18 3842.27 20.73 -1.84 119.04 8.65 20.65 1.70 15.59 158.73 44.01 134.66 MWD+SAG 7350.00 90.63 178.18 3841.99 20.84 -1.84 119.98 8.71 20.76 1.70 15.63 159.38 44.23 134.93 MWD+SAG 7375.00 90.63 178.18 3841.72 20.95 -1.84 120.92 8.78 20.87 1.70 15.68 160_03 44.44 135.19 MWD+SAG 7400.00 90.63 178.18 3841.44 21.06 -1.84 121.86 8.84 20.98 1.70 15.73 160.69 44.64 135.45 MWD+SAG 7425.00 90.63 178.18 3841 .17 21.17 -1.84 122.80 8.91 21.09 1.70 15.78 161.34 44.86 135.70 MWD+SAG 7450.00 90.63 178.18 3840.89 21.28 -1.84 123.75 8.98 21.20 1.70 15.82 162.01 45.07 135.96 MWD+SAG 7475.00 90.63 178.18 3840.62 21.39 -1.84 124.69 9.04 21.32 1.70 15.87 162.67 45.27 136.21 MWD+SAG 7500.00 90.63 178.18 3840_34 21.50 -1.84 125_64 9.11 21.43 1.70 15.92 163.34 45.47 136.47 MWD+SAG 7525.00 90.63 178.18 3840.07 21.61 -1.84 126.58 9.17 21.54 1.70 15.97 164.01 45.68 136.72 MWD+SAG 7550.00 90.63 178.18 3839.79 21.72 -1.84 127.53 9.24 21.65 1.70 16.02 164.69 45.88 136.96 MWD+SAG 7575.00 90.63 178.18 3839.51 21.83 -1.84 128.47 9.31 21.76 1.70 16.06 165.37 46.08 137.21 MWD+SAG 7600.00 90.63 178.18 3839.24 21.94 -1.84 129.42 9.37 21.87 1.70 16.11 166.05 46.27 137.46 MWD+SAG 7625.00 90.63 178_18 3838.96 22.05 -1.84 130.36 9.44 21.98 1.70 16.16 166.73 46.47 137.70 MWD+SAG 7650.00 90.63 178.18 3838.69 22.16 -1.84 131.31 9.50 22.09 1.70 16.21 167.42 46.66 137.94 MWD+SAG 7675.00 90.63 178.18 3838.41 22.27 -1.84 132.26 9.57 22.20 1.70 16.26 168.11 46.85 138.18 MWD+SAG 7700.00 90.63 178.18 3838.14 22.39 -1.84 133.21 9.64 22.31 1.70 16.31 168.81 47.03 138.41 MWD+SAG 7725.00 90.63 178.18 3837.86 22.50 -1.84 134.16 9.70 22.42 1.70 16.36 169.51 47.22 138.65 MWD+SAG 7750.00 90.63 178.18 3837.59 22.61 -1.84 135.10 9.77 22.54 1.70 16.41 170.21 47.41 138.88 MWD+SAG 7775.00 90.63 178.18 3837.31 22.72 -1.84 136.05 9.83 22.65 1.69 16.45 170.91 47.59 139.11 MWD+SAG 7800.00 90.63 178.18 3837.04 22.83 -1.84 137.00 9.90 22.76 1.69 16.50 171.62 47.76 139.34 MWD+SAG 7825.00 90.63 178.18 3836.76 22.94 -1.84 137.95 9.97 22.87 1_69 16.55 172.33 47_95 139.57 MWD+SAG 7850.00 90.63 178.18 3836.49 23.05 -1.84 138.90 10.03 22.98 1.69 16.60 173.04 48.12 139.80 MWD+SAG 7875.00 90.63 178.18 3836.21 23.16 -1.84 139.85 10.10 23.09 1.69 16.65 173.76 48.30 140.02 MWD+SAG 7900.00 90.63 178.18 3835.94 23_27 -1_84 140.80 10.16 23.20 1.69 16_70 174.48 48.46 140.24 MWD+SAG 7925.00 90.63 178.18 3835.66 23.38 -1.84 141 .76 10.23 23.32 1.69 16.75 175.20 48.64 140.46 MWD+SAG 7950.00 90.63 178_18 3835.39 23_50 -1.84 142_71 10.30 23.43 1.69 16.80 175_92 48_81 140.68 MWD+SAG 7975.00 90.63 178.18 3835.11 23.61 -1.84 143.66 10.36 23.54 1.69 16.85 176.65 48.98 140.90 MWD+SAG 8000.00 90.63 178.18 3834.84 23.72 -1.84 144.61 10.43 23.65 1.69 16.90 177.38 49.14 141.11 MWD+SAG 8025.00 90_63 178.18 3834_56 23_83 -1.84 145.56 10.49 23.76 1.69 16.95 178.11 49.31 141.33 MWD+SAG 8050.00 90.63 178.18 3834.28 23.94 -1.84 146.52 10.56 23.87 1.69 17.01 178.84 49.47 141.54 MWD+SAG 8075.00 90.63 178.18 3834.01 24.05 -1.84 147.47 10.63 23.99 1.69 17.06 179.58 49.63 141.75 MWD+SAG 8100.00 90.63 178.18 3833.73 24.16 -1.84 148.42 10.69 24.10 1.69 17.11 180.32 49.78 141_96 MWD+SAG 8125.00 90.63 178.18 3833.46 24.28 -1.84 149.38 10_76 24.21 1.69 17.16 181.07 49.94 142.16 MWD+SAG 8150.00 90.63 178.18 3833.18 24.39 -1.84 150.33 10.82 24.32 1.69 17.21 181.81 50.10 142.37 MWD+SAG 8175.00 90.63 178.18 3832.91 24.50 -1.84 151.29 10_89 24.43 1.69 17.26 182_56 50.25 142.57 MWD+SAG 8200.00 90.63 178.18 3832.63 24.61 -1_84 152.24 10.96 24.54 1.69 17.31 183.31 50.40 142.77 MWD+SAG 8225.00 90.63 178.18 3832.36 24.72 -1_84 153_20 11_02 24_66 1.69 17_36 184_06 50.56 142_97 MWD+SAG OR r'.'~;.;j' i 'j .. ;1 \ I ~,.. 4 * ,~ ~I: .... \;~:::,~., L _1.er Hughes Incorporatel -") Error Ellipse Survey Report Company: ConocoPhillips Alaska, Inc. Date: 5/13/2003 Time: 16:14:38 Page: 8 Field: Kuparuk River Uhit Co:-ordhiate(NE) Rderence: Well: 184, True North Site: Pad 1 C Vertical (TVD) Reference: Wellhead(87') 87.0 Well: 184 Section (VS) Reference: Well(0.00N;0~00E,158.10Azi) Wellpath: 1C-184 Vers#1 Survey Calculation Method: Minimum Curvature Db: Oracle Pósition uncertainty and bias at survey station AU uncertainties at 2;6 standard deviation Highside-:--.....> Lateral-...----> Vertical-----> Magn. Semi-major Semi-minor MD Ind Azim TVD Unc. Bias Unc. Bias Unc. Bias of Bias Une. Une. Azimuth Tool ft deg deg ft ft ft ft ft ft ft ft ft .ft deg 8250.00 90.63 178.18 3832.08 24.83 -1.84 154.15 11.09 24.77 1.69 17.41 184.82 50.71 143.17 MWD+SAG 8275.00 90.63 178.18 3831.81 24.95 -1.84 155.11 11.15 24.88 1.69 17.47 185.58 50.85 143.37 MWD+SAG 8300.00 90.63 178.18 3831.53 25.06 -1.84 156.06 11.22 24.99 1.69 17.52 186.34 50.99 143.56 MWD+SAG 8325.00 90.63 178.18 3831.26 25.17 -1.84 157.02 11.29 25.11 1.69 17.57 187.10 51.14 143.75 MWD+SAG 8350.00 90.63 178.18 3830.98 25.28 -1.84 157.98 11.35 25.22 1.69 17.62 187.86 51.28 143.94 MWD+SAG 8375.00 90.63 178.18 3830.71 25.39 -1.84 158.93 11 .42 25.33 1.69 17.67 188.63 51.42 144.13 MWD+SAG 8400.00 90.63 178.18 3830.43 25.50 -1.84 159.89 11.48 25.44 1.69 17.73 189.40 51.56 144.32 MWD+SAG 8425.00 90.63 178.18 3830.16 25.62 -1.84 160.85 11.55 25.55 1.69 17.78 190.17 51.70 144.51 MWD+SAG 8450.00 90.63 178.18 3829.88 25.73 -1.84 161.80 11.62 25.67 1.69 17.83 190.94 51.84 144.69 MWD+SAG 8475.00 90.63 178.18 3829.60 25.84 -1.84 162.76 11.68 25.78 1.69 17.88 191.72 51.97 144.88 MWD+SAG 8500.00 90.63 178.18 3829.33 25.95 -1.84 163_72 11.75 25.89 1.69 17.94 192.50 52.10 145.06 MWD+SAG 8525.00 90.63 178.18 3829.05 26.06 -1.84 164.68 11.81 26.00 1.69 17.99 193.28 52.24 145.24 MWD+SAG 8550.00 90.63 178.18 3828.78 26.18 -1.84 165.64 11.88 26.12 1.69 18.04 194.06 52.37 145.42 MWD+SAG 8575.00 90.63 178.18 3828.50 26.29 -1.84 166.59 . 11.95 26.23 1.69 18.09 194.84 52.50 145.59 MWD+SAG 8600.00 90.63 178.18 3828.23 26.40 -1.84 167.55 12.01 26.34 1.69 18.15 195.63 52.62 145.77 MWD+SAG 8625.00 90.63 178.18 3827.95 26_51 -1.84 168.51 12.08 26.45 1.69 18.20 196.42 52.75 145.94 MWD+SAG 8650.00 90.63 178.18 3827.68 26.63 -1.84 169.47 12.15 26.56 1.69 18.25 197.21 52.88 146.11 MWD+SAG 8675.00 90.63 178.18 3827.40 26.74 -1.84 170.43 12.21 26.68 1.69 18.31 198.00 53.00 146.28 MWD+SAG 8700.00 90.63 178.18 3827.13 26.85 -1.84 171.39 12.28 26.79 1.69 18.36 198.80 53.12 146.45 MWD+SAG 8725.00 90.63 178.18 3826.85 26.96 -1.84 172.35 12.34 26.90 1.69 18.41 199.59 53.25 146.62 MWD+SAG 8750.00 90_63 178.18 3826_58 27.07 -1_84 173.31 12.41 27.02 1.69 18.47 200.39 53.37 146.79 MWD+SAG 8775.00 90.63 178.18 3826.30 27.19 -1.84 174.27 12.48 27.13 1.69 18.52 201.19 53.48 146.95 MWD+SAG 8800.00 90.63 178.18 3826.03 27.30 -1.84 175.23 12.54 27.24 1.69 18.57 201.99 53.60 147.12 MWD+SAG 8825.00 90.63 178.18 3825.75 27.41 -1.84 176.19 12.61 27.35 1.69 18.63 202.79 53.72 147.28 MWD+SAG 8850.00 90.63 178.18 3825.48 27.52 -1.84 177.15 12.67 27.47 1.69 18.68 203.60 53.83 147.44 MWD+SAG 8875.00 90.63 178.18 3825.20 27.64 -1.84 178.11 12.74 27_58 1.69 18.73 204.40 53.95 147.60 MWD+SAG 8900.00 90.63 178.18 3824.93 27.75 -1.84 179.07 12.81 27.69 1.69 18.79 205.21 54.06 147.76 MWD+SAG 8925.00 90.63 178.18 3824.65 27.86 -1.84 180.03 12.87 27.80 1.69 18.84 206.02 54.17 147.92 MWD+SAG 8950.00 90.63 178.18 3824.37 27.97 -1.84 180.99 12.94 27.92 1.69 18.90 206.83 54.28 148.07 MWD+SAG 8975.00 90.63 178.18 3824.10 28.09 -1.84 181.95 13.00 28.03 1.69 18.95 207.65 54.39 148.22 MWD+SAG 9000.00 90_63 178.18 3823_82 28.20 -1.84 182.92 13.07 28.14 1.69 19.00 208.46 54.49 148.38 MWD+SAG 9025.00 90.63 178.18 3823.55 28.31 -1.84 183.88 13.14 28.25 1.69 19.06 209.28 54.60 148.53 MWD+SAG 9050.00 90.63 178.18 3823.27 28.42 -1.84 184.84 13.20 28.37 1.69 19.11 210.10 54.71 148.68 MWD+SAG 9075.00 90.63 178.18 3823.00 28.54 -1.84 185.80 13.27 28.48 1.69 19.17 210.92 54.81 148.83 MWD+SAG 9100.00 90.63 178.18 3822.72 28.65 -1.84 186.76 13.33 28.59 1.69 19.22 211.74 54.91 148.98 MWD+SAG 9125.00 90.63 178.18 3822.45 28.76 -1.84 187.73 13.40 28.71 1.69 19.28 212.56 55.02 149.12 MWD+SAG 9150.00 90.63 178.18 3822.17 28.88 -1.84 188.69 13.47 28.82 1.69 19.33 213.39 55.12 149_27 MWD+SAG 9175.00 90.63 178.18 3821.90 28.99 -1.84 189.65 13.53 28.93 1.69 19.39 214.21 55.22 149.41 MWD+SAG 9200.00 90.63 178.18 3821.62 29.10 -1.84 190.61 13_60 29_05 1.69 19.44 215.04 55.32 149.55 MWD+SAG 9225.00 90.63 178.18 3821.35 29.21 -1.84 191.58 13.66 29_16 1.69 19.50 215.87 55.42 149.70 MWD+SAG 9250.00 90.63 178.18 3821.07 29.33 -1.84 192.54 13.73 29.27 1.69 19.55 216.70 55.52 149.84 MWD+SAG 9275.00 90.63 178_18 3820_80 29.44 -1_84 193.50 13.80 29_38 1_69 19.61 217.53 55_61 149_98 MWD+SAG 9300.00 90.63 178.18 3820.52 29.55 -1.84 194.47 13.86 29.50 1.69 19.66 218_37 55.71 150.11 MWD+SAG 9325_00 90.63 178.18 3820.25 29.67 -1_84 195.43 13_93 29_61 1.69 19.72 219.20 55.80 150.25 MWD+SAG 9350.00 90.63 178.18 3819.97 29.78 -1.84 196.39 13.99 29.72 1.69 19.77 220.04 55.90 150.39 MWD+SAG 9375.00 90.63 178.18 3819.70 29.89 -1.84 197.36 14.06 29_84 1.69 19.83 220.87 55.99 150.52 MWD+SAG 9400.00 90.63 178.18 3819.42 30.00 -1.84 198.32 14.13 29.95 1.69 19.88 221.71 56.08 150.65 MWD+SAG 9425.00 90.63 178.18 3819.14 30.12 -1.84 199_28 14.19 30.06 1.69 19_94 222.55 56.17 150.79 MWD+SAG 9450.00 90.63 178.18 3818.87 30.23 -1.84 200.25 14.26 30.18 1.69 19.99 223.39 56.26 150.92 MWD+SAG 9475.00 90.63 178.18 3818.59 30.34 -1.84 201.21 14.32 30.29 1.69 20.05 224.24 56_35 151.05 MWD+SAG 9500.00 90.63 178.18 3818.32 30.46 -1_84 202.18 14.39 30.40 1.69 20.11 225.08 56.43 151.18 MWD+SAG 9525.00 90_63 178.18 3818.04 30.57 -1.84 203.14 14.46 30.52 1.69 20.16 225.92 56.52 151.30 MWD+SAG 9550.00 90.63 178.18 3817.77 30.68 -1.84 204.11 14.52 30.63 1.69 20.22 226_77 56_61 151.43 MWD+SAG l't)· 1 ': )..7 ~ i '¡ .;' , 1 .(>~ l Jker Hughes Incorporate~ ) Error Ellipse Survey Report Company: ConocoPhillips Alaska, Inc. Date: 5/13/2003 Time: 16:14:38 Page: 9 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 184, True North Site: Pcid1 C Vertical (TVD)Reference: Wellhead(8T)·87.0 Well: 184 Section (VS) Reference: Well (O.OON,O;OOE, 158.1 OAzi) Well path: 1 C..:184 Vers#l Survey Calculation Method: Minimum Curvature Db: Oracle Position' uncertainty and bias at survey station All uncertainties at . 2,6.. standard deviation HighSide-----> Lateral-:---:--> VertiCal-:-,.-..;.> Magn.Semi-major Semi-minor MD InCl . Azim TVD Un¢. Bias Unc. Bias Uoc; Bias ofBiasUnc. Unc. Azimuth Tool ft deg deg ft ft ft ft ft ft ft ft .ft ft deg 9575.00 90.63 178.18 3817.49 30.79 -1.84 205.07 14.59 30.74 1.69 20.27 227.62 56.69 151.56 MWD+SAG 9600.00 90_63 178.18 3817.22 30.91 -1.84 206.04 14.65 30.86 1.68 20.33 228.47 56.78 151.68 MWD+SAG 9625.00 90.63 178.18 3816.94 31.02 -1.84 207.00 14.72 30.97 1.68 20.39 229.32 56.86 151.80 MWD+SAG 9650.00 90.63 178.18 3816.67 31.13 -1.84 207.97 14.79 31.08 1.68 20.44 230.17 56.95 151.93 MWD+SAG 9675.00 90.63 178.18 3816.39 31.25 -1.84 208.93 14.85 31.20 1.68 20.50 231.02 57.03 152.05 MWD+SAG 9700.00 90.63 178.18 3816.12 31.36 -1.84 209.90 14.92 31.31 1.68 20.56 231.88 57.11152.17 MWD+SAG 9725.00 90_63 178.18 3815.84 31.47 -1.84 210.86 14.98 31.42 1.68 20.61 232.73 57.19 152.29 MWD+SAG 9750.00 90.63 178.18 3815.57 31.59 -1.84 211.83 15.05 31.54 1.68 20_67 233.59 57_27 152.41 MWD+SAG 9775.00 90.63 178.18 3815.29 31.70 -1.84 212.79 15.12 31.65 1.68 20.72 234.44 57.35 152.53 MWD+SAG 9800.00 90.63 178.18 3815.02 31.81 -1.84 213.76 15.18 31.76 1.68 20.78 235.30 57.42 152.64 MWD+SAG 9825.00 90.63 178.18 3814.74 31.93 -1.84 214.72 15.25 31.88 1.68 20.84 236.16 57.50 152.76 MWD+SAG 9850.00 90.63 178.18 3814.46 32.04 -1.84 215.69 15.31 31.99 1.68 20.89 237.02 57.58 152.87 MWD+SAG 9875.00 90.63 178.18 3814.19 32.15 -1.84 216.65 15.38 32.10 1.68 20_95 237.88 57_65 152.99 MWD+SAG 9900.00 90.63 178.18 3813.91 32.27 -1.84 217.62 15.45 32.22 1.68 21.01 238.74 57.73 153.10 MWD+SAG 9925.00 90.63 178.18 3813.64 32.38 -1.84 218.59 15.51 32.33 1.68 21.06 239.61 57.80 153.21 MWD+SAG 9950.00 90.63 178.18 3813.36 32.49 -1.84 219.55 15.58 32.44 1.68 21.12 240.47 57.88 153.32 MWD+SAG 9975.00 90.63 178.18 3813.09 32.61 -1.84 220.52 15.64 32.56 1.68 21.18 241.34 57.95 153.43 MWD+SAG 10000.00 90.63 178.18 3812.81 32.72 -1_84 221 .49 15.71 32.67 1.68 21.24 242.20 58.02 153.54 MWD+SAG 10025.00 90.63 178.18 3812.54 32.83 -1.84 222.45 15.78 32.78 1.68 21.29 243.07 58.09 153.65 MWD+SAG 10050.00 90.63 178.18 3812.26 32.95 -1.84 223.42 15.84 32.90 1.68 21.35 243.94 58.17 153.76 MWD+SAG 10075.00 90.63 178.18 3811.99 33.06 -1.84 224.39 15.91 33.01 1.68 21.41 244.81 58.24 153.87 MWD+SAG 10100.00 90.63 178.18 3811.71 33.17 -1.84 225.35 15.97 33.12 1.68 21 .46 245.68 58.30 153.97 MWD+SAG 10125.00 90.63 178.18 3811.44 33_29 -1.84 226_32 16.04 33.24 1.68 21.52 246.55 58.37 154.08 MWD+SAG 10150.00 90.63 178.18 3811.16 33.40 -1.84 227.29 16.11 33.35 1.68 21.58 247.42 58.44 154.18 MWD+SAG 10175.00 90.63 178.18 3810.89 33.51 -1.84 228.25 16.17 33.47 1.68 21.64 248.29 58.51 154.29 MWD+SAG 10200.00 90.63 178.18 3810.61 33.63 -1.84 229.22 16.24 33.58 1.68 21.69 249.17 58.58 154.39 MWD+SAG 10225.00 90.63 178.18 3810.34 33.74 -1.84 230.19 16.30 33.69 1.68 21.75 250.04 58.64 154.49 MWD+SAG 10250.00 90.63 178.18 3810.06 33.85 -1.84 231.15 16.37 33.81 1.68 21.81 250.92 58.71 154.59 MWD+SAG 10275.00 90.63 178.18 3809.79 33.97 -1.84 232.12 16.44 33.92 1.68 21.87 251.79 58.77 154.69 MWD+SAG 10300.00 90.63 178.18 3809.51 34.08 -1.84 233.09 16.50 34.03 1.68 21.92 252.67 58.84 154.79 MWD+SAG 10325.00 90.63 178.18 3809.23 34.20 -1.84 234.06 16.57 34.15 1.68 21.98 253.55 58.90 154.89 MWD+SAG 10350.00 90.63 178.18 3808.96 34.31 -1.84 235.02 16.63 34.26 1.68 22.04 254.43 58.97 154.99 MWD+SAG 10375.00 90.63 178_18 3808.68 34.42 -1.84 235.99 16.70 34.38 1.68 22.10 255.31 59.03 155.09 MWD+SAG 10400.00 90.63 178.18 3808.41 34.54 -1.84 236.96 16.77 34.49 1.68 22.16 256.19 59.09 155_18 MWD+SAG 10425.00 90.63 178.18 3808.13 34.65 -1.84 237.93 16.83 34.60 1.68 22.21 257.07 59.15 155.28 MWD+SAG 10450.00 90.63 178.18 3807.86 34.76 -1_84 238.89 16.90 34.72 1.68 22.27 257.95 59.22 155.37 MWD+SAG 10475.00 90.63 178.18 3807.58 34.88 -1.84 239.86 16.97 34.83 1.68 22.33 258.83 59.28 155.47 MWD+SAG 10500.00 90.63 178.18 3807.31 34.99 -1.84 240.83 17.03 34.94 1.68 22.39 259.72 59.33 155.56 MWD+SAG 10525.00 90.63 178.18 3807.03 35.10 -1.84 241.80 17.10 35.06 1_68 22.45 260_60 59.40 155.65 MWD+SAG 10550.00 90.63 178.18 3806.76 35.22 -1.84 242.77 17.16 35.17 1.68 22.50 261.49 59.45 155.75 MWD+SAG 10575.00 90.63 178.18 3806.48 35.33 -1_84 243.73 17.23 35.29 1.68 22.56 262.37 59_51 155.84 MWD+SAG 10600.00 90.63 178.18 3806.21 35.45 -1.84 244.70 17.30 35.40 1.68 22.62 263.26 59.57 155.93 MWD+SAG 10625.00 90.63 178.18 3805.93 35.56 -1.84 245.67 17.36 35.51 1.68 22.68 264.15 59.63 156.02 MWD+SAG 10650_00 90.63 178_18 3805_66 35.67 -1_84 246.64 17,43 35.63 1.68 22.74 265.04 59.69 156.11 MWD+SAG 10675.00 90.63 178.18 3805.38 35.79 -1.84 247.61 17.49 35.74 1.68 22.80 265_93 59.74 156.20 MWD+SAG 10700.00 90.63 178.18 3805.11 35.90 -1.84 248.58 17.56 35.86 1.68 22.85 266.82 59.80 156.28 MWD+SAG 10725.00 90.63 178.18 3804.83 36.01 -1.84 249.55 17.63 35.97 1.68 22.91 267.71 59.85 156.37 MWD+SAG 10750.00 90.63 178.18 3804.56 36.13 -1.84 250.51 17.69 36.08 1.68 22.97 268_60 59.91 156,46 MWD+SAG 10775.00 90.63 178.18 3804.28 36.24 -1_84 251.48 17.76 36.20 1.68 23.03 269,49 59.96 156.54 MWD+SAG 10800.00 90.63 178.18 3804.00 36.36 -1.84 252.45 17.82 36.31 1_68 23.09 270_38 60.02 156_63 MWD+SAG 10825.00 90.63 178.18 3803.73 36,47 -1.84 253,42 17.89 36,42 1.68 23.15 271.27 60.07 156.71 MWD+SAG 10850.00 90.63 178_18 3803.45 36.58 -1.84 254.39 17.96 36_54 1.68 23.21 272.17 60_12 156_80 MWD+SAG O e""': .-\,:'\ . ,t ... \; : I' .' r, ì ~;t~ f .. J l_..ker Hughes IncorporateL ) Error Ellipse Survey Report Company: ConòcoPhillips Alaska, Inc. Date: 5/13/2003 Time: 16:14:38 Page: 10 Field: Kuparuk River Unit Co.,.ordinate(NE) Reference: Wen: 184, True North Site: Pad 1C Vertical (TVD) Reference: Wellhead(87') 87~0 Well: 184 Section (VS) Reference: Well (0.00N;0.00E,158.10Azi) Wellpath: 1 C;'184 Vers#1 Survey Calculation Method: Minimum Curvature Db: Oracle Position uncertainty and bias at survey station AU uncertainties at 2.6 standard deviation Highside----,;,> . Lateral-.,.---.;..> Vertical---':'-> Magn. Semi':'majorSemi-minor MD ·Ind Azim TVD Unc~ Bias Unc. Bias Unc. Bias ofBiasUnc. Unc;AzimuthTool ft deg. deg ft ft ft ft ft ft ft ft ft ft deg 10875.00 90.63 178.18 3803.18 36.70 -1.84 255.36 18.02 36.65 1.68 23.27 273.06 60.18 156.88 MWD+SAG 10900.00 90.63 178.18 3802.90 36.81 -1.84 256.33 18.09 36.77 1.68 23.32 273.96 60.23 156.97 MWD+SAG 10925.00 90.63 178.18 3802.63 36_92 -1_84 257.30 18.15 36.88 1.68 23.38 274.85 60.28 157.05 MWD+SAG 10950.00 90.63 178.18 3802.35 37.04 -1.84 258.27 18.22 36.99 1.68 23.44 275.75 60.33 157.13 MWD+SAG 10975.00 90.63 178.18 3802_08 37.15 -1.84 259.23 18.29 37.11 1.68 23.50 276.65 60.38 157.21 MWD+SAG 11000.00 90.63 178.18 3801.80 37.27 -1.84 260.20 18.35 37.22 1.68 23.56 277.54 60.43 157.29 MWD+SAG 11025.00 90.63 178.18 3801.53 37.38 -1.84 261.17 18.42 37.34 1.68 23.62 278.44 60.48 157.37 MWD+SAG 11050.00 90_63 178.18 3801.25 37.49 -1.84 262.14 18.48 37.45 1.68 23.68 279.34 60.53 157.45 MWD+SAG 11075.00 90.63 178.18 3800.98 37.61 -1.84 263.11 18.55 37.56 1.68 23.74 280.24 60.58 157.53 MWD+SAG 11100.00 90.63 178.18 3800.70 37.72 -1.84 264.08 18.62 37.68 1.68 23.80 281.14 60.63 157.61 MWD+SAG 11125.00 90.63 178.18 3800.43 37.84 -1.84 265.05 18.68 37.79 1_68 23.86 282_04 60.68 157.69 MWD+SAG 11150.00 90.63 178.18 3800.15 37.95 -1.84 266.02 18.75 37.91 1.68 23.92 282.94 60.73 157.76 MWD+SAG 11175.00 90.63 178.18 3799.88 38.06 -1.84 266.99 18.81 38.02 1.68 23.97 283.84 60.78 157.84 MWD+SAG 11200.00 90.63 178.18 3799.60 38.18 -1.84 267.96 18.88 38.14 1.68 24.03 284.75 60.82 157.92 MWD+SAG 11225.00 90.63 178.18 3799.33 38.29 -1.84 268.93 18.95 38.25 1.68 24.09 285.65 60.87 157.99 MWD+SAG 11250.00 90.63 178.18 3799.05 38.41 -1.84 269.90 19.01 38.36 1.68 24.15 286.55 60.92 158.07 MWD+SAG 11275.00 90.63 178.18 3798.77 38.52 -1.84 270.87 19.08 38.48 1.68 24.21 287.46 60.96 158.14 MWD+SAG 11300.00 90.63 178.18 3798.50 38.63 -1.84 271.84 19.14 38.59 1.68 24.27 288.36 61.01 158.22 MWD+SAG 11325.00 90.63 178.18 3798.22 38.75 -1.84 272.81 19.21 38.71 1.68 24.33 289.27 61.06 158.29 MWD+SAG 11350.00 90.63 178.18 3797.95 38.86 -1.84 273.78 19.28 38.82 1.68 24.39 290.17 61.10 158.36 MWD+SAG 11375.00 90.63 178.18 3797.67 38.98 -1.84 274.75 19_34 38.93 1.68 24.45 291.08 61.15 158.43 MWD+SAG 11400.00 90.63 178.18 3797.40 39.09 -1.84 275.72 19.41 39.05 1.68 24.51 291.99 61.19 158.51 MWD+SAG 11425.00 90.63 178.18 3797.12 39.20 -1.84 276.69 19.47 39.16 1.68 24.57 292.89 61.23 158.58 MWD+SAG 11450.00 90.63 178.18 3796.85 39.32 -1.84 277.66 19.54 39.28 1.67 24.63 293.80 61.28 158.65 MWD+SAG 11475.00 90.63 178.18 3796.57 39.43 -1.84 278.63 19.61 39.39 1.67 24.69 294.71 61.32 158.72 MWD+SAG 11500.00 90.63 178.18 3796.30 39_55 -1.84 279.60 19.67 39.50 1.67 24.75 295.62 61.36 158.79 MWD+SAG 11525.00 90.63 178.18 3796.02 39.66 -1.84 280.57 19.74 39.62 1.67 24.81 296.53 61.41 158.86 MWD+SAG 11550.00 90.63 178.18 3795.75 39.77 -1.84 281.54 19.80 39.73 1.67 24.87 297.44 61.45 158.93 MWD+SAG 11575.00 90.63 178.18 3795.47 39.89 -1.84 282.51 19.87 39.85 1.67 24.93 298.35 61.49 159.00 MWD+SAG 11600.00 90.63 178.18 3795.20 40.00 -1.84 283.48 19.94 39.96 1.67 24.99 299.26 61.53 159.06 MWD+SAG 11625.00 90.63 178.18 3794.92 40.12 -1.84 284.45 20.00 40.08 1.67 25.05 300.17 61.57 159.13 MWD+SAG 11650.00 90.63 178.18 3794.65 40.23 -1.84 285.42 20.07 40.19 1.67 25.11 301.08 61.62 159.20 MWD+SAG 11675.00 90.63 178.18 3794.37 40.34 -1.84 286.39 20.13 40.30 1.67 25.17 301.99 61.66 159.27 MWD+SAG 11700.00 90.63 178.18 3794.09 40.46 -1.84 287.36 20.20 40.42 1.67 25.23 302.90 61.70 159.33 MWD+SAG 11725.00 90.63 178.18 3793.82 40.57 -1.84 288.33 20.27 40.53 1.67 25.29 303.82 61.74 159.40 MWD+SAG 11750.00 90.63 178.18 3793.54 40.69 -1.84 289.30 20.33 40.65 1.67 25.35 304.73 61.78 159.46 MWD+SAG 11775.00 90.63 178.18 3793.27 40.80 -1.84 290.27 20.40 40.76 1.67 25.41 305.64 61.82 159.53 MWD+SAG 11800.00 90.63 178.18 3792.99 40.92 -1.84 291.24 20.46 40.88 1.67 25.47 306.56 61.86 159.59 MWD+SAG 11825.00 90.63 178.18 3792.72 41.03 -1.84 292.21 20.53 40.99 1_67 25_53 307.47 61.90 159_66 MWD+SAG 11850.00 90.63 178_18 3792.44 41.14 -1.84 293.19 20.60 41.10 1.67 25.59 308.39 61.93 159.72 MWD+SAG 11875.00 90.63 178_18 3792.17 41.26 -1.84 294.16 20.66 41.22 1.67 25.65 309.30 61.97 159.78 MWD+SAG 11890.25 90.63 178.18 3792.00 41.33 -1_84 294.75 20_70 41_29 1.67 25_69 309_86 61.99 159.82 MWD+SAG 1, i,.: L¡' ! ,,' ) ) 1 C-184 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 Gas Hydrates Running Sands and Gravels Abnormal Reservoir Pressure Lost Circulation Swabbing Risk Level Low Low Low Low Low Moderate 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 Driltreat Maintain planned mud parameters, weighted mud, viscous sweeps Diverter drills, increased mud weight, flow checks Reduced pump rates, rheology, LCM Trip speeds, proper hole fill, pumping out 6 %" Open Holel 4 Y2" Pre-perforated Liner Hazard Abnormal Pressure Stuck Pipe Lost Circulation Hole Swabbing on Trips Risk Level Low Low Low Low 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 ) ") lC-184 Detailed Risk Information Broach of Conductor: There is a chance that the conductor on 1 C-184 may broach. Therefore the cellar area should be continuously monitored during the drilling of the surface hole section. If broaching occurs, stop drilling immediately. Contact the AOGCC field inspector, the drilling Engineer, and the Conoco/Phillips Drilling Team Leader and inform them of the broach. We have taken the added precaution of setting the conductor at 120' on this well rather then 80' that has been standard in the past. Therefore, the added depth should help to preclude any broaching of the conductor. Gas Hydrates: The shallow gas phenomenon referred to as gas hydrates have been encountered on wells drilled from 1 C pad. Gas hydrates are formed over time as gas from deeper source rock migrates to shallower depths. As the migrating gas entered the permafrost zone, the gas became entrained in water crystals and freezes in place over time. During drilling operations, the warm fluid from surface circulating systems increases the temperature in the near-well bore area, thus thawing the entraining water crystals and releasing the entrained gas into the well bore, often in significant quantities. When gas hydrates are encountered, large volumes of intermittent gas expand near the surface, resulting in large bubbles of escaping gas. These bubbles may push fluid over the bell nipple. The gas may continue to expand and escape the well bore until either the thaw "bulb" is extensive enough that no further thawing takes place or surface casing is run and cemented. The following steps have been shown to be successful in minimizing (though not necessarily eliminating) the effects of gas hydrates upon drilling operations: 1. Control Drilling. This will limit the amount of cuttings into the well bore and assist in reducing the size of the instantaneous gas breakout. 2. Reduced Pump Rates. Slower pump rates may assist in reducing the amount of hydrate entrained cuttings brought to surface in "slugs" and thereby reduce the instantaneous effects of hydrate gas breakout. Reduced pump rates should always coincide with reduced ROP's in order to avoid overloading the well bore with cuttings and increasing the risk of stuck pipe. 3. Reduced Drilling Fluid Temperature. Keeping the temperature as low as possible will reduce the rate of thaw of the hydrates. The most effective way to reduce the temperature is to insure all fluid and make-up water additions are as cold as possible. 4. Additions of DrilTreat. Experience in other hydrate prone areas of the North Slope indicates DrilTreat (lecithin) may provide hydrate breakout inhibition. Should hydrates be encountered the mud system should be treated with DrilTreat. O r"~ "''', 0 .. Ii ' ~.< .···2 it,:.:, J '! ,~ , , t \: ,L"~ ') ) 5. Kelly Down Circulation. Circulating every Kelly down for 3-5 minutes prior to making the next connection will aid in hoe cleaning and reducing cutting/hydrate load in the wellbore. 6. Reduced Fluid Viscosity. Although this practice has shown to be beneficial in other hydrate-prone areas, the decision to reduce viscosity must with consideration given to the benefits of higher viscosity, such as additional hole cleaning, especially where shallow sand and gravel problems may be encountered. Typical viscosity reductions are in the 50-90 sec.lqt. range to realize benefits but may not be advisable if sand/gravel problems are encountered. Runnine Sand and Gravels: Running sands and gravels have been an historical problem in wells drilled on several pads in the GSA. These running intervals may result in substantial circulating and hole cleaning time and cost, as well as substantial risk of stuck drill pipe and lor casing. The following guidelines are recommended for drilling these intervals: 1. Maintain the fluid viscosity at the minimum values specified in the Detailed Mud Program. Be prepared to raise the viscosity to higher values if problems persist. Do not let the viscosity fall below specified values. 2. If running sand and gravel problems persist, pump intermittent densified sweeps, of 40-60 bbls in size while in the build or vertical section of the hole. Density of the sweeps should be 2-5 ppg above existing system weight. Viscosify these sweeps with addition of gel and Barofibre. 3. To maximize hole cleaning, rotate the drill string at the maximum rate while sweeping the hole. 4. Increase the mud weight to the maximum recommended weight to assist in holding sand/gravel back. Wellbore Washout: A number of wells in the lCllD area have experienced significant hole erosion and washout in the surface interval as evidenced by the high excess cement volumes pumped and subsequent low return volume. Because optimized Jet Impact Force is not necessary for maximum ROP in the surface interval, larger nozzles will not adversely affect ROP yet at the same time will allow for significantly increased flow rates and improved hole cleaning. Reservoir Overpressurization Contineencies: It is possible, though highly unlikely, that higher that predicted reservoir pressures might be encountered during the drilling of 1 C-184. The consequences such an encounter could be extremely serious. Therefore, the following guidelines have been established. Any deviations fro the guideline should be discussed with Drilling Team Leader, Engineering Supervisor or Operation Drilling Engineer before hand. {J ¡:'.. . "...." .~:~'" 2 ¡ '\1 f , ï '" "'r ) ) · Hold a Pre-spud meeting with all crews including Drillsite Operators and Simultaneous Operations Coordinator. a. Discuss diverter line orientation. b. Identify essential/non-essential personnel (Co-man, Tool Pusher, driller, Derrick Hand, Pit Watcher, Mud Engineer) c. Establish roles and responsibilities of essential personnel while on diverter. d. Review muster areas. . Conduct a pre-reservoir meeting a. Review essential/non-essential personnel b. Review roles and responsibilities of essential personnel while on diverter. c. Review muster areas. d. Conduct a Diverter Actuation Drill prior to penetrating the D-Sand · After penetrating each sand (maximum 5' penetration) and before drilling ahead: a. Shut down and check for flow (monitor well a minimum of 10 minutes before drilling ahead). · Ensure adequate stock of LCM materials on location to address possible losses while pumping higher weight mud if required. · If well flows while circulating at maximum rate, increase mud weight as required while continuing to circulate at maximum rate. · If unable to control well. a. Put well on diverter. b. Evacuate all non-essential personnel to predetermined muster areas. c. Continue to circulate fluid, at maximum rate, while attempting to increase mud weight d. If all available mud has been pumped and well is still out of control, begin pumping water until other kill methods con be employed. Prior to penetrating the reservoir, alert the APC dispatch office and insure that they are aware that all vacuum trucks may be place in water hauling service if need be. As a last resort, use injection water header on pad as water source. Ensure beforehand that hoses, piping and valves are available for rapid rig up to the water injection header, that an available tie-in spot is available, and that the pad operator is aware of the situation. Note: The Company man should review the Drilling Emergency Response Plan prior to penetrating the reservoir (print a copy of the manual and have it on hand should the need arise). The Emergency Response Plan is on the Web and can be located by logging onto the PAl Home Page and following the steps listed below: Lost Circulation: In the event that returns are lost, the Drilling Engineer on Duty should be contacted, and the Lost Circulation Decision Tree found in the 1 C-184 Well Plan folder on the Operation Web Page should be consulted. 11 ¡~,. 'l, " " \,1" ,f ~ ~ ~" J " , ' í ~I~ ..)~ ~1 ,g :j \",¡IJ"~ j r .' I, ; ~:.L" ') ) Hole Swabbin2: Hole swabbing may occur while tripping out of the well bore. Mud parameters should be carefully monitored and maintained per the mud plan during drilling operation to prevent bit balling as well as other factors that may contribute to swabbing. Hole fill volumes should be carefully calculated and monitored, and if there is any concerns whatsoever that the hole has not taken sufficient fluid, the drill string should be tripped back to bottom and circulated. If need be, the string should be circulated out of the hole. All tripping practices should conform to the Phillips Alaska Drilling Policy. Stuck Pipe: Due to the long length of the lateral in the D sand, there is a risk that the drill string or liner may become differentially stuck. In order to mitigate the risk the drill string should not be left static for any long period of time. In addition good drilling practices need to be implemented to ensure that the hole stays clean and drill cutting do not become a problem. In the event that tight hole is observed and backreaming is opted for, the drill string should be ran back in to a depth where working and rotating the pipe is free and clear if possible. Upon commencing backreaming, the flowrate and RPM should be at the same rates as when the hole was originally drilled. Keeping the RPM and circulation at a very low rate while backreaming will only build a cuttings bed above the bit and eventually could lead to stuck pipe. O .f'"',· . '\ 1'1. l ';i, , . I f \.:' , !! ~ f\.. j $ .j ."'.!!t,: 1 C-184 1611 Conductor ~ o ~ 120" 08-6 Nipple @ +/-500" 3.87511 10 Conoc~Phillips 4 1/211,12.6#, L-80, IBY-Mod 4 1/211 X 111 GLM (K8G-2) @ +/- 20001 and 3,500' -- { ~.'~:} 4 1/211 Sliding Sleeve (1.0. 3.8111) ., Tangent Angle: +/-60 [---~ Cameo 08-6 o-Gu Nipple @ 4800' Top of Angle is +/-65 degrees 3.7510 Csg Pt.:+/- 5710"MO/3,842'TVO X4 1/211,12.6#, L-80, NSCT .. ... .~ · . · . . .. .. 11 890' MO/3792'TV[ . .. ' ner Hanger @ +/- 5560" ~ .) ') y ConocoPhillips Conoco/Phillips, Inc. Post Office Box 1 00360 Anchorage, Alaska 99510 May 14, 2003 Ms. Sara Palin 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-184 Surface Location: Target Location: Bottom Hole Location: 1571' FNL, 1294' FWL, Sec 12 T11N, R10E, UM 2217' FSL, 1170'FEL,Sec12,T11N, R10E, UM 1494' FSL, 978' FEL, Sec 13, T11 N, R10E, UM Dear Commissioner: Conoco/Phillips Alaska, Inc. hereby applies for a "Permit to Drill" to drill 1 C-184 as a producer well. 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. . 7 Sincer . // v~~ ~?f í?O~5 R. Thomas Kuparuk Drilling Superintendent RECE\VEO Mþ..'( 1 4 2003 C mm\SS\on ~\aska Q\\ & Gas Cons. ° Anchorage --. -- . / ---". I I / / I \ , .f'/~ J i ,// " / / / / / ' /'~ - /' Jí<;~----i;)'- /7' ¿tJ~:~ í / I : 0 ~ ¡. ¡. 0 0 ¡....... I: 2 ¡. 8 0 0 0 0... 2 7 2 5 7 III . 0 L. 2 VaJid Up To 5000 Dollars / ~'\ / (. 'I ,'\/í/1 / ) I/~ ./;¿::...../'/' L/. - ~-v . -'- .-~~-"'-'-=-~~=-=-~-=--'=.~--=-==-~~---.....~---- -.---=---~~,--=-=--=-~ t1J~~rjj{J~ _-...-_~__.~ ..... CHASE Chase Manhattan Bank USA, N.A. '-, lOO Whj'. Clay Center Or_ New.rk. DE 19711 ()(. - - __ - .' /1 - ;IL- Y 'f ¡ /J ;o~./···. ,//" i1¡'" J /_', ¡:'~~7T~/~!É >1 /fIE:: /-:-r 11tJl~~~i;j rrU~I~~~_____~ .)31 [t/'-j. OnDEF;-)¡-~r----7~~~-~ f /,1 I' ~ ;"- .: . I ./ I'. I / ¡i /' . ;./ ./'-·~v / . _ . . n --. ¡U,;-¿ t/ ~ð, I C-Ø:.' ,. J. Ij,~L)J_'" .--. ~__~~~_~VJ--::::~ V~~~lr~... ~_~- V!~V';:'.. '~~--/"f___~.~~_ í...'~_<'~~-~....'~~ÕQLU:\KS UJ 62-14/311 DATE tf¿~~)~_L4~_x~~;~; S. K. ALLSUP-DRAKE CONOCOPHILLlPS 711 G STREET - AT01530 ANCHORAGE AK 99501 1042 Rev: 07/10/02 C\j ody\templates ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMtTT AL LETTER WELL NAME kett. IC-Ißt PTD# ?/J:3 - 07š1 CHECK WHAT APPLIES ADD-ONS (OPTIONS) MlJL TI LATERAL (If API num ber last two (2) digits are between 60-69) paOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE "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). 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 PERMITCHECKI...IST· Company .c_QJ~º_C_QE_1:I1L.L1E.S_ALASJ~8J_~.c Well Name: J5.uEhB.UJ~BlY_U W_SA~---.-iC=--1_84 PTD#: 2030890 Field & Pool KUPARUK RIVER. WE.sT SAK OIL - 490150 Initial Classrrype DEV / 1-QI1__ GeoArea ,.ß90 Administration 11 p~rmit fee attached _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ y~s _ _ _ _ _ _ _ _ _ _ _ 12 _Leas~_n!Jrnb~r _appropriate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~$ _ _ _ _ _ _ _ . _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . - - - - - - - - - - - - - - - - - - 3 Uni.que well. n.am~ _and ou_mb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ y ~$ _ _ _ _ - _ _ _ - _ _ _ - _ _ . - - _ _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - 4 _W~IIJQcat~d i_n_a_d.efjne_d_pool_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - _ _ _ 5 _W~II JQ~t~d pr.op~r _di.stance.frorn. c!rijling unit_ b_oundary _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ - - - _ _ - - _ 6 _W~IIJQcated pr.op~r _di.stançe.frorn. Qtlwr w~lIs_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~$ _ _ _ . _ _ _ _ _ _ _ _ - _ _ - - - - - _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - 7 _S_uff¡cient .acreage_ayaili3ble i.n.d.rilJiog unit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ . _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ - _ - - - - - - - - - - - . - - - - - - - _ _ - 8 Jrd~viated, .is_ weJlbQre platinclu_dec! _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ . " _ _ . " _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ " _ _ - - - - - _ - - - - - - - - _ - - - _ _ - - _ _ _ 9 _Qper:.ator onl~ affected party _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ . _ _ _ - _ _ _ - _ _ " - - - - - - y ~$ - - - - - - - - - - - - - - - - - . - - - - - - - - - - - - - - - - - - - " - - - - - - - - - - - - - - - - - - - - . " . - - - - - - - - - - - - - - 1 0 _Qper:.ator bas _ appropri_ate_ Þ.ond ion Jorçe. _ _ _ " . _ _ _ _ " _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ . _ y ~s _ . _ _ _ _ _ _ _ _ _ _ " " _ _ _ . _ _ _ " _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - " _ _ - _ _ - - - _ - _ _ _ _ _ _ _ 11 P~rmit. can be i.ssued witlJQut çon$~rva.tion ord~r. _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ . _ .. _ _ _ _ Y~$ _ _ _ - - _ _ _ - _ _ _ . _ _ - - . - - - - _ - - - - _ - - - - - - . . - . - - - . - - - - - - - - - - - - - - . - - - " - - - " - - - - - - - - Appr Date 12 P~[mit.can be i_s$ued witlJQut administr:.ati\(e_approvaJ - - - - - . - " - - - - - - - - - - - - .. " - . - Y~$ . - - - - - - - - - - - . - - . " - - - - - - - - - - . - - - - - - - . . - . - . - - . - - - - - - - - - - - - .. - . - " " - - - - - - - - . - SFD 5/15/2003 13 _C_an permit.be ßPprQv~d b~fore _15-day. wait. - - - " - . . - - - " .. - - - - - - - - - - - " - . . . - - Y~$ " - - - - - - - - - - - " . - . . - - " . - - - - - - - - - - - - - - . - - - - - " . - - - - - - - - - - - - - . - - - - - - .. . - - - - - - - - - - 14 _We.IIJQ~t~dwi.th.inareaçm_d_strati3authQri_zec!by.lojectiol)Ord~r:.#(puUO#[n_c.olJlm~otsHFQr" NA _ _ _ _ _ _ _ _ _ _ _ _. _" _ _ _ _. _ - _ _ _ - _ _ - - _. _' _" - - _ _" -. _ - - - - - - - - - - - - - - - - - - -" -. - - _ _. - _ __ 15 _A)!wel)s_witniflJ~4_llJite.are_a_ofr:.eyiewid~ot[fied(For:.s.erv.ic~weIJOI1IY-L _ _ _ _ _ _ _ _ _ _ _. _ _ NA _ _ _ _ _ _ _ _ _ _ _ -" _ _ - -.. _ - - - _ - - - - -" - - -" - -''.. _." -. - - - - - - - - - - - -. - - - - - - -... - - - -" - - _ -- 16 Pr~-proc!u_cedinjeGtQr; .duri3tio_n_ofpr~-.propuctioOI~$s_than,,3rnQn.ths_(FQr_ser:.vi.ceweRQnly) _.. NA _ _ _ _ _ _ _ _ _ _ _ _ _" _ _ _ _ _ _ _" _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _" _.. _ _ _ _ _ _. _" _ _ _ - _ _ _ - _ _ _ _" _ _ _ _ _ _ _ _ _ __ 17 ACMP. finding _of CQn.si.stenGy_h.as been Js.sued.for.tbi$ pr.oiec( _ _ _ _ _ _ _ _ . " . _ _ _ _ _ . _ _ NA - _ _ " - _ _ - - _ - - - . . - . - - - . - - - - - - - - . . " - - - " - - - - . - - - . . - - - - - - - - - . . - - - " - - " - " . . - - - - - - - Engineering Appr Date TEM 5/15/2003 ~~ Geology Appr SFD Date 5/15/2003 Geologic Commissioner: DIS Program _D_E'Y..,~______ Unit~ ~J..J..Lu--/--l-..l-W0n/Off Shore .pn Well bore seg Annular Disposal D ~ 18 _C_onc!u.ctor str:.ing.PJQvided _ _ " . _ _ _ _ _ _ _ _ _ _ " . . _ . . . _ _ _ _ _ " _ _ _ . _ . _ _ _ _ _ " _ " Y~$ - _ _ - _ _ - - - _ - - - . . . " - - - " - - - - - - - - - - - - - " - - - " - - - - - - - - - - - - - - - - - - - - - - - - .- - - - - - - . - - - - 19 _S.!Jr:fac~_cas.ing_PJQtec.ts.all"knQwn_USQWs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _AII_aq.!JifeJs.ex~lJlpt~d4QCfß~47_.t02_(Q).(3L _ _ -. _ _ _ _" _ _ _ _ _ - _ _ _ _ _ _ _ -. -"" -. _ _ _ _ _ _ _ _ _ __ 20 _CMTv_otadeQu_ate.to çirc.!Jlate_ofl_cOl1d_uctor,,& SUJrCSg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ " _ " _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ " _ _ " _ _ _ - _ " _ _ - _ _ _ - _ _ _ " _ _ . . _ " _ . _ _ _ - " _ _ - - _ _ - " .. _ _ " _ _ _ _ _ . _ _ _ _ " _ _ _ _ _ 21 _CMT v_ot adequ_ate..to tie-i.n JQng _striog to .s!Jrf çs.g_ _ .. _ _ _ .. .. _ _ .. _ .. .. _ _ .. _ _ _ _ _ _ _ _ _ .. _ NA _ _ _ _ _ _ .. Wel) QnJy_ has .syrfa.ce ça,sing._ _ _ _ _ _ _ _ _ _ _ _ _ .. .. .. .. _ .. _ _ _ . _ .. _ .. _ .. _ _ .. _ _ _ . .. .. _ .. .. .. _ .. _ .. _ _ _ _ _ 22 _CMT-will Goyer"all Koown_Pfo..duGtiYe IJQri¡on_s_ _ _ _ " " _ _ _ _ _ .. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ " No.. .. " _ _ _ _ _ Slotte.dJio~r_completi.oo pl;3oned._ _ _ _ .. _ _ _ " _ _ _ " _ _ _ " _ _ " _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ " _ _ _ _ _ _ " _ _ _ _ _ _ 23 _C_asiog de.sigo$ ad_equa.t~ f.or:. C,_T, 13 _&_ p"ermafr.ost.. _ _ _ _ _ " _ _ " _ . _ _ _ _ _ _ _ _ " _ _ _ _ _ _ Y~s _ _ _ - - _ _ - - " - - - - - " - - " - - " - - - - - - - - - - - " - - " - - - .. - - - - - .. - - - - - - - " - - - . " - - - - _. - - - _ _ _ 24 Adequ;3te..tan_kage_oJ re_serye pit _ " _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ " _ _ _ _ .. _ Y~$ _ _ _ _ _ _ _ ~o r:.es~rve_ pitpJa_noed_. .Rig equipped_ with_steeLpits._ Wi3ste to_a_ppr.ov~d_a.nouhJs_oJ Glass 1.1 welt _ _ _ _ _ _ _ _ _ _ 25 Jra_ re-pr:.ilt, has.a_ 1.0::-4.03 fQr i3bandonment Qe~o apPJQv~d _ " _ _ _ _ _ _ _ _ _ .. _ _ _ " _ _ . _ _ _ NA_ . . _ _ - _ _ " - _ .' - - _ - - " - _ - - _ _ - - - - - - - - - " - - - - - - - - - - - .. " " - - - - - - - - - .. - " " - - - -" - - _ - - _ _ _ _ 26 Adequ.ate..w:eUbore_ s.epari3tjon _proposed _ _ _ _ _ " .. _ _ _ _ _ " _ _. .. _ _ _ _ _ _ _ " _ _ " _ _ .. _ _ Y~$ _ _ _ _ _ _ _ pr.ox.imety çalçuJa~ions.p'er:fQrm~d._ ~Q çIQs.e_apprOé\ch js_sues..ide_ntifi.ed._ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 27 Jf_div~r:.t~r J~q.!JiJed. dQe~ it me~t reguJa.tions_ _ _ _ _ . _ _ _ . _ _ . .. _ _ _ _ _ .. _ _ _ _ " _ _ _ _ " _ ..Y~s . _ _ _ _ _ _ _ _ _ _ _ " _ _ _ . _ _ . - _ _ . - _ . - - - - _ - - - - - - . - - . - " - - . - - - - - - - .. - _ " - - _ - - .. _ _ _ _ . _ _ _ 28DJilJiOgflujd_p'rogram$G.hemat[c_&_~q.!JipJist.adequat~_ _ _ _ _ _ _ _ __.. _ _ _ _ _ _ _ _ _"" _" _ "y~s_" _ _ _ _ _Max~stimatec!8HP@8..5I;:MW._P.lanned_MW_9_.5@_s_ur:fac~.TD_a.nd9.2jnlat~ral._ _ _ _ _ _. _ _ _ _ _ _ _ _ _ __ 29 _BOPE~,_d.o"they meet.reguJa"tion _ _ . _ _ _ _ _ _ _ _ _ _ _ . . .. _ _ . _ " _ .. _ _ _ _ _ _ _ " " _ _ _ _ ..Yes _ _ _ _ _ _ _ - - _ . _ - " - - - - - - .. _ - - - - " - - - - - - - - - .. " _ - - .. _ - - - _ - - - - _ - - - - - - - _ " - - _ _ _ .. _ _ _ _ . _ _ _ 30 "BOPE_Pfess ratiog appropr:.iate; .t~st to_(pu.t psig i.n .comments).. _ .. _ _ _ _ _ _ _ " _ _ . _ _ _ _ " _ ..Y~s _ _ _ _ _ _ _ MAS!? e~t@ 1246 psi._ 350,,0_p.si_appr.opriate..for..te~t,..é~"ltbQugb PPCo wi)! likeJy_tesHo.5.00Q psj._ _ _ _ _ _ _ _ . _ 31 ..C_hoke_l1Janifold CQrnpJies. w/API.R.P-53. (May 64).. " . _ _ _ _ _ _ _ _ . _ _ _ _ _ .. _ .. _ _ .. . _ _ _ _ Y~s _ _ _ _ .. _ _ _ _ _ _ _ - _ _ " - _ _ _ - _ _ - - _ - - .. - _ - - - - - " - - - - " - - - .. _ - - - - - - .. - - - - _ _ - " _ _ _ _ _ _ _ _ _ _ _ _ 32 _WQrk will oçc.!Jr:. without..operatiofl_sbutdown" _ _ " _ __ _ _ " _ _ _ _ _ _ _ _ .. . _ _ _ _ " .. _ _ _ _ _ .Yes _ _ _ _ _ -- .. _ - - - " - - - - - - - - - - - - - - - - - - - - - - " - - - " .. - . - - - - - - - - - - - - .. - - ". - . - _ - _ . 33 .1$ pres.ence_ Qf .H2S gas_ prob_aÞI~ _ _ _ .. _ _ _ _ _ _ _ .. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ " . _ " . _ No.. . " _ . _ . _ _ - _ _ _ - _ . - - - - " - - " - - - - .. .. " - - .. - - - - - - - - - - - _ - " . _ - - " .. " 34 ..MeçlJa_nic~l_cPlJdjtlo[1.of. wells wLthil1 AOß yerified. (For_s.erv[ce well onJy) _ _ _ _ _ _ _ _ _ _ _ " _ " NA _ _ _ " _ _ _ - . _ _ _ - _ - . - .. - - - " - .. - - - - - - - - - - - - . - - " . - - - - - - .. - - .. - - - - - - - - - " - " _ - . - _ .. _ _ _ _ _ _ 35 ..P~r:.rnitc.ao be Lssued w!o_ hydr.ogen_s"ulfide lJleé\S!J[es _ . _ _ _ _ . _ _ _ _ " _ _ _ _ _ _ _ _ _ _ " _ _ ..Y~s _ _ _ _ _ _ _ _ - _ _ _ - _ " - - _ - - - _ - - - - - - - " - .. - - - - . - - - " " - - - - _ - - - - - - - - - - - - _ . - - _ - - - _ _ _ _ _ _ _ _ 36 .D.ata_PJ~seotedon.pote"ntialpyeJPres_sur~_zones_. _ _" _ _" _ _ _.. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ..Y~s_ _ _ _ _ _ _Expeçted..r~se"lilojrpre$suJei,s_8._2_-_8,8_ppgEMW._O\f.erpr~s$l,Irecontiogencies_ioDetai!e.d..Rjs_kJnfQrm;3tiQn_seç_ 37 _S~i.slJlic_aflalys.is_ Qf ~haJIQW gé\s"z.ooes_ _ ". _ _ _ _ _ _ _ _ _ _ _. .. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ " _ _ _ _ _ - _ _ " - _ " - - _ _ _ - _ _ - - _ _ - - - _ _ - - _ _ - _ _ _ _ - _ _ _ " . _ _ _ .. _ _ _ _ .. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 38 _S~aQed _conditi.oo survey..(if off-sh.ore) _ _ _ _ _ .. . _ ,,_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ " _ _ NA _ _ _ _ _ _ _ _ . _ _ _ - _ " .. - - .. - - " .. _ _ - - _ - - - - - - " - - - - - - - - - _ - - - _ _ - . . - - - - " " - - _ _ - - _ _ _ _ _ _ _ _ 39 _ CQnta_ct. l1arn_e!pnoneJor..w:eekly progress_reports [exploratory ..only]. _ _ .. _ _ _ _ . .. _ . _ _. _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ " _ .. " _ _ " _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ . - _ " . _ _ _ _ _ __ _ _ _ _ .. _ _ _ .. .. _ _ .. _ _ _ _ _ _ _ _ _ _ _ _ _ .. t' Date: Engineering Commissioner: Public Commissioner Date Excellent discussion of potential risks and mitigation measures in the "Detailed Risk Information" attachment at the end of the application packet. Topics include: hydrates, running sand/gravel, well bore washout, overpressure, lost circulation, swabbing, and stuck pipe. Approval for annular injection will be requested for this well. Date Of I-J/O:; ~~ ") ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitling Process but is part" of the history file. To improve the readability of the Well History file and to simplify finding information, infomlation 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. ) 803 --o~l **** REEL HEADER **** LDWG 03/07/26 AWS 01 **** TAPE HEADER **** LDWG 03/07/25 01 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA LDWG File Version 1.000 Extract File: LISTAPE.HED lC-184 500292315500 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 25-JUL-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 1 F. WENDLER F. HERBERT MWD RUN 2 2 S. DRAKE D. GLADDEN MWD RUN 3 3 F. WENDLER D. GLADDEN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 12 IlN 10E 89.00 59.00 # WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 9.875 6.750 7.625 5800.0 11890.0 # REMARKS: PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE RECEIVED JUL 2. 8 20Q3 Alaska eM & Gas Cons. CommimJion Anc:tror!ge !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 ! ! ! ! ! ! ! !! ! ! ! ! ! ! ! ! !! Extract File: FILEOOl.HED *** LIS COMMENT RECORD *** 1024 LDWG .001 **** FILE HEADER **** 8 bytes 132 bytes Minimum record length: Maximum record length: 88 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' 29.729" LONG: W149 DEG 29' 41.317" LOG MEASURED FROM D.F. AT 89.0 FT. ABOVE PERM. DATUM (M.S.L.) . COMMENTS: (1) Baker Hughes INTEQ run 1 utilized NaviTrak Directional only services from 120 to 2574 feet MD (120 - 2305' TVD). (2) Baker Hughes INTEQ run 2 utilized AutoTrak RCLS (Rotary Closed Loop System) which includes the RNT (Reservoir Navigation Tool) resistivity and Gamma Ray services from 2574 to 5805 feet MD (2305 - 3874' TVD). (3) Baker Hughes INTEQ run 3 utilized Multiple Propagation Resistivity (MPR) and Gamma Ray services in a steerable assembly from 5805 to 11890' MD (3874 - 3840' TVD). (4) Per ConocoPhillips Alaska instructions, the Gamma Ray curve from this log is the depth reference for this well. As such, no depth shifts have been applied. REMARKS: (1) The 9 7/8" hole section from 120 to 2574 feet MD (138 - 4479' TVD) was drilled with a directional only tool. As such, no logs are presented over this interval. (2) Depth of 7 5/8" Casing Shoe - Logger: 5800 feet MD (3873' TVD) Depth of 7 5/8" Casing Shoe - Driller: 5799 feet MD (3873' TVD) Please note that due to the change in Resistivity tools at the 7 5/8" casing point, from RNT to MPR, that the presentation goes from 2 resistivity curves to 4 resistivity curves. (3) The interval from 5759 to 5805' MD (3870 - 3873' TVD) was logged up to 96.0 hours after being drilled due to the 7 5/8" casing run. (4) The interval from 11855 to 11890 feet MD (3839 - 3840' TVD) was not logged due to sensor-bit offset at TD. $ ) ) ) FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 2490.0 STOP DEPTH 11890.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ BIT RUN NO 2 3 MERGE TOP 2490.0 5770.0 MERGE BASE 5770.0 11890.0 # 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 1c-184 5.xtf 150 - ConocoPhillips Alaska, Inc. 1C-184 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAM 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 31-MAY-03 # LOG HEADER DATA DATE LOGGED: SOFTWARE STOP DEPTH 5770.0 START DEPTH 2490.0 FILE HEADER FILE NUMBER: AAW 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 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: 715 records... Tape Subfile: 2 **** FILE TAAILER **** feet Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 2490.000000 11890.000000 0.500000 672 Total Data Records: ONE DEPTH PER FRAME 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 0.500 * F FRAME SPACE = \ ,) ) 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 RNT GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL RES. NAVIG. TOOL 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): # ) MSB 18704 6 . 75 ATK MEMORY 5805.0 2490.0 5770.0 o 51.3 84.7 TOOL NUMBER SHE 35313 RNT 20047 RNT 20047 9.875 120.0 Spud Mud 9.15 .0 .0 250 .0 .000 .000 .000 .000 118.0 .0 .0 .0 .00 .000 .0 o BIT RUN 2 (MWD Run 2) . GR/RNT. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - 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) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1c-184.xtf ) ) LCC CN WN FN COUN STAT 150 ConocoPhillips Alaska, I lC-184 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPCH RPCH RPS 0.0 RACL RACL RAD 0.0 RACH RACH RAS 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: 36 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: 28 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 8 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 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 ROPS MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 8 TCDM MWD 68 1 DEGF 4 4 ------- 32 Total Data Records: 469 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 2490.000000 5770.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 559 records... Minimum record length: 8 bytes 93.0 .0 .0 .0 .000 .000 .000 .000 Flo Pro 9.20 .0 .0 24500 .0 6.750 5800.0 TOOL NUMBER DAS 34690 MPR 1119 SRIG 5021 88.1 92.4 MSB 18704 4.75 MPR MEMORY 11890.0 5770.0 11890.0 o 08-JUN-03 # 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: # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # RESIS. BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. GAMMA RAY TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GRAM $ # # 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: STOP DEPTH 11890.0 FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ START DEPTH 5770.0 log header data for each bit run in separate files. 3 .2500 3 !!!! !!! !!!!!!! !!!!! LDWG File Version 1.000 !! !! !!!!!!!!!! !!!!! Extract File: FILE012.HED *** LIS COMMENT RECORD *** 1024 LDWG .003 **** FILE HEADER **** 4124 bytes Maximum record length: ) ) ) ) NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 o # REMARKS: BIT RUN 3 (MWD Run 3) . 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 lc-184.xtf 150 ConocoPhillips Alaska, I lC-184 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM RPCL RPSL RPCH RPSH RACL RASL RACH RASH ROPS RPTH TCDM GRAM RPCL RPSL RPCH RPSH RACL RASL RACH RASH ROPS RPTH TCDM 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 GRAM RPD RPM RPS RPX RAD RACSLM RAS RACSHM ROPS RPTHM TCDM * 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: 1289 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 5770.000000 11890.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 4 1388 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 03/07/25 01 **** REEL TRAILER **** LDWG 03/07/26 AWS 01 ) Tape Subfile: 5 Minimum record length: Maximum record length: ) 2 records... 132 bytes 132 bytes
