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207-144
STATE OF ALASKA • AlIIKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool Repair Well Re-enter Susp Well Other:ESP to Gaslift 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r _ 207-144 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-029-23374-60 7. Property Designation(Lease Number): 8.Well Name and Number: ADL025663;ADL385172 WSAK 1J-174L1 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Kuparuk River Field/West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 19690 feet Plugs(measured) None true vertical 3057 feet Junk(measured) None Effective Depth measured 12880 feet Packer(measured) None true vertical 3122 feet (true vertical) Casing Length Size MD TVD Burst Collapse CONDUCTOR 76 20 120 120 SURFACE 3971 13.375 4021 2273 SEAL BORE DIVERTER 72 9.625 11455 3139 PRODUCTION 12040 10.75 12080 3206 B-SAND LINER 8240 9.625 19657 3057 .a,,:n N8' Perforation depth: Measured depth: Slots: 12245- 14582; 14584- 19568 i ,; True Vertical Depth: 3216-3198; 3198-3155 t_ r Tubing(size,grade, MD,and ND) 4.5, L-80, 9721 MD, 2932 TVD Packers&SSSV(type, MD,and ND) SSSV= None SCANNED � b 29 16 Packer= None 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 561 264 18 170 159 Subsequent to operation 1090 1353 30 564 165 14.Attachments(required per 20 MC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations p Exploratory r Development p Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil 17 Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Darrell Humphrey/Bob Christensen Email n1139conocophillips.com Printed Name di ob-rt I Christen, en Title NSK Production Engineering Specialist Signature W / 9 Phone:659-7535 Date 111141 ...4 10 it7// V77-- 7/2- l RED Pn 18 ZOt Form 10-404 Revised 5/2015 7w� Submit Original Only • 1J-174L1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 10/25/15 Successfully set Packoff Assembly(9,656' RKB) and pressure tested. Flowed fluids to surface via ESP. Slipstop set(9,654' RKB). 11/06/15 RECOVERED SLIPSTOP FROM 9654' RKB, RECOVERED PACKOFF ASSEMBLY FROM 9656' RKB, RETURN IN AM TO PULL ESP, JOB IN PROGRESS. 11/07/15 PULL ESP FROM 9661' RKB WITH 1 JARLICK, PULL TO SURFACE AND VERIFY WE HAVE IT WITH SWAB AND MASTER VALVES, RIH TO PUMP OFF OF ESP AT 1100' CTMD, WELL F/P TO 3000' CTMD, READY FOR SLICKLINE. 11/08/15 (AC EVAL) GAS MITIA PASSED 11/09/15 RECOVER 39' ESP PUMP @ 2550' SLM, SET CATCHER @ 2850' SLM, PULLED SOV @ 2403' RKB, SET GLV @ SAME, PULLED CATCHER SUB @ 2850' SLM. 11/10/15 Open well to Gaslifted Production KUP PROD 1J-174L1 .n`� .;\. Conocorl li0ips Well Attributes Max Angle&MD ID Alaska,Inc, Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) r_�orovrNetg 500292337460 WEST SAK PROD 94.42 11,949.54 19,750.0 --- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) II.Rig Release Date MULTIPLE LATERALS-1J-174L1,11/11/20153:05:02 PM SSSV:NONE 10 11/8/2014 Last WO: 9/8/2012 44.41 12/31/2007 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag Rev Reason:GLV C/O,PULL lehallf 11/11/2015 ---- ESP/PACKOFF/SLIPSTOP HANGER;22.8 �` Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(kKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread D SAND LINER 4 1/2 3.960 11,355.4 19,689.5 3,056.6 11.60 L-80 BTC I. 11 Liner Details I I Nominal ID Top(ORB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 11,355.4 3,127.3 83.11 HANGER RAM LINER HANGER 6.760 11,363.0 3,128.2 83.13 HANGER RAM LINER HANGER 6.000 -MICONDUCTOR;44.4-120.04 < Perforations&Slots Shot Dens Den ESP MANDREL;2,402.6 Top(ND) Btm(ND) (shots/f Top(ftKB) etm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 11,48 5.0 11,686.0 3,140.9 3,159.8 WS D,1J- 12/27/2007 32.0 SLOTS Slotted liner,2.5" 174L1 x.125",4 circumferential rows/ft,3"centers staggered 18 deg,non- 1 slotted ends V 11,768.0 12,878.0 3,163.0 3,122.3 WS D,1J- 12/27/2007 32.0 SLOTS Slotted liner,2.5" 174L1 x.125",4 circumferential rows/ft,3"centers staggered 18 deg,non- slotted ends 12,880.0 19,644.0 3,122.3 3,058.7 WS D,1J- 12/27/2007 32.0 SLOTS Slotted liner,2.5" 174L1 0.125",4 circumferential rows/ft,3"centers staggered 18 deg,non- SURFACE;49.5-4,020.5A slotted ends Notes:General&Safety End Date Annotation 12/28/2007 NOTE:MULTI-LATERAL WELL 1J-174(B-SAND),1J-174L1(D-SAND) ESP MANDREL;4,487.4 6/21/2008 NOTE:View Schematic w/Alaska Schematic9.0 2/1/2013 NOTE:INNER CASING LOCKDOWN SCREWS SEIZED ESP MANDREL',9,550 9 I DISCHARGE;9,633.9 za- • I INTAKE;9,675.7 'en SEAL:9,686.2 MOTOR;9,700.0 "]': GAUGE;9,716.7 /_t Centralizer;9,718.8 PRODUCTION 10.75'x9.625"_ 40.4-12,000.0 111 SLOTS;11,485.0-11,686.0 ] .-- SLOTS;11,768.0-12,878.0 —.1 ...- SLOTS; SLOTS;12,880.0-19,644.0 r W.— D-SAND LINER;11,355.4- I I 19,689.5 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. Qo7 L4u NOTES: BY: Organizing (done) Two -sided III [111 II I1 RE CAN DIGITAL DATA V Color Items: iskettes, No. I ❑ Greyscale Items: ❑ Other, No/Type: ❑ Poor Quality Originals: ❑ Other: Project Proofing BY: (Mari Date: 1/7/°9 Scanning Preparation x 30 = L + BY: ` Maria Date: , J 7/0 Production Scanning ReScanned Stage 1 Page Count from Scanned File: Maria BY: Maria Comments about this file: • • Image Project Well History File Cover Page Well History File Identifier Scanning is complete at this point unless rescanning is required. OVERSIZED (Scannable) ❑ Maps: ❑ Other Items Scannable by a Large Scanner OVERSIZED (Non - Scannable) ❑ Logs of various kinds: ❑ Other:: Date: . 7/°V /s/ (V\ II111 1111 /s/ v f Date: ❑ Rescan Needed (I (Count does include cover sheet) (Count does not include cover Isl Page Count Matches Number in Scanning Preparation: t/ YES NO BY: Date: 1 7 ©7 Is/ lA4 J Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: 111111 111 Date: /s/ a ( -1 - = TOTAL PAGES ` h 4' 11111111111 01111 Quality Checked III u 11111111111111 1111 111111 10/6/2005 Well History File Cover Page.doc MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C: \temp \Temporary Internet Files \OLK9 \Microfilm_Marker.doc Maunder, Thomas E (DOA) From: Packer, Brett B [J. Brett .Packer @conocophillips.com] Sent: Tuesday, April 28, 2009 8:59 AM To: Maunder, Thomas E (DOA) Subject: RE: 1J -137 (206 -108) and 1J -174 (207 -143) Attachments: 1J -174 Multi -lat RAM.pdf; 1J -137 Multi -lat drawing.pdf; Centrilift Y -Tool Schematic Draft.pdf Tom, I didn't include the profile view schematics because they haven't been updated yet. Those schematics were built by Baker Oil Tools, and they've kept the actual Visio drawing and only provide us with the pdf version, so we can't edit them ourselves. Attached are the schematics we have, but once again, they aren't up to date. 1J -174 � \-¼ The completion shown is correct, except for the depths of the ESP and GLM's. 1J-137 The completion shown is completely wrong. It now has an LEM installed and a Y -block ESP completion downsized to 3 -1/2" tubing. 5. Brett Tackgr Drilling eZ Wells Workpver EEngineer Work# (907) 265 -6845 CeI # (907) 230 -8377 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, April 28, 2009 8:19 AM To: Packer, Brett B Subject: 13 -137 (206 -108) and 13 -174 (207 -143) Brett, I am reviewing the 404s for the recent workovers on these multi - lateral wells. Would you please provide drawings that show the well in a "horizontal format" such as are included in the permit to drill? The straight drawings are somewhat difficult to relate to the operations report. I also request that horizontal drawings be included whenever a workover is done on a multilateral well. You can send the drawings via email. Call or message with any questions. Thanks in advance. Tom Maunder, PE AOGCC 9/30/2009 • • 8 2009 Page 1 of 1 Wellhead / Tubing / Tree: 13 -3/8" x 4.1/2 ", 5,000 psi Insulated Conductor: 20" 94# K -55 x 34" 0.312 WT +/- 80' 4013' MD - 13 -3/8" Casing Shoe, 688, L-80, BTC, 2270' TVD, 76 deg inc Tubing String 4 -1 /2" 12.6 #, L-80, IBTM 3.958" ID, 3.833" Drift 8" RAM Junction Mainbore Drift 3.68" Lateral Drift: 540" RAM Hanger/Seal Bore Diverter OD: 6.370" OveraN Length of RAM Junction: matt Seal Bore Diverter Running Tool: ND RAM Hanger Running Tool: HRD"E 4.112" Lateral Entry Module LEM OD: 6.98 "' . : ,.,.. Mainbore Drift w/o Diverters: 3.66" Mainbore Drift wI Isolation Diverter: Lateral Drift 1M "P2" DNerten , 3.68" ConocoPhillips 2007 West Sak Producer with Rotating self - Aligning Multilateral (RAM System 3927'MD -10J/4 "73.2 #,L -80, Dual lateral Completion BTC Casing Crossover 11355' MD - X 95/8" RAM Hanger 5.960" Lateral Drift ID 3.688" Mainbore Drift ID 2208' MD - GLM, Cameo, 4-1/2" x 1" KBMG, set 67 deg 9617' MD - Bottom of Motor Centralizer Centralift 418 HP KMHG 11360' MD -4=h" x 952" RAM Seal Bore Diverter ISBD/ with 3.68" Seal Bore 4 -1/2" 12.6# Hydril 521 an IBTM Tubing 11416'MD- 7 "X9 -52 "M "P liner Hanger Packer 1J -174 HB DLP AS COMPLETED 11366' MD - D -Sand Casing Exit, 3128' TVD, 83 deg inc 11444' MD - Sealbore Receptacle 4.75' ID 'D' Sand Lateral. 4 -1/2" 11.60, Hydril 521 and BTC, 1-80 Blank and Slotted Liner 11415' MO - 3.562" DB Nipple 3133' TVD, 84 deg 11425' MD - MLHR Production Anchor 11454' MD - Bottom of Seal Assembly 4.75" Seal OD 3.875"10 ® Baker Hughes 2008. This document may not be reproduced or distributed, In whole or in pad, in any form or by any means electronic or mechanical, including photocopying, recording, or by any information storage and retrieval system now known or hereafter invented, without written permission from Baker Hughes Inc. Positive Latching Collet fndieates Correct Location Odenfag Profile Taub -be alignment or LEM. Lateral Diverter MIA Hanged 1 1 Ramp reel'Baw far Lateral Isolation [Warier 3.6r ID Snapin/Snap Out Positive Locating Collet Ld rk Snap In/Snap Out Positive LematMg Colts Lateral laolation Upper Seale 5-1/2" Guide Shoe, 6.00" OD 19689' MD - 4 -112" Casing Shoe, 11.6 #, L -80 BTC, 3056' TVD Sand Lateral 6112" 15,511, Hydril 521 and BTC, L-80 Blank and Slotted Liner 12080' MD - 9 -5/8" Casing Shoe, 40.0 #, L-80 BTC , 3205' TVD, 85 deg inc 4 Orange Peeled Shoe 19656' MD - 5-1/2" Casing Shoe, 15.5 #, L -80 BTCM , 3156' TVD Baker Oil Tools S HUGHES Dwg lme: Drawing 5O.: 2007 West Sak Dual Lateral Completion - Producer P86e Ne.: p: 1 1. Operations Performed: Abandon ❑ Alter Casing ❑ Change Approved Program ❑ Repair Well • • Plug Perforations ❑ Stimulate ❑ Other ❑ _a Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Perforate ❑ Re -enter Suspended Well ❑ Pull Tubing Operat. Shutdown ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 4. Well Class Before Work: Exploratory ❑ Service ❑ 5. Permit to Drill Number: 207 -144 / - Development '' • 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic ❑ 6. API Number: 50 029 - 23374 - 60 7. KB Elevation (ft): RKB 121', GL 81' AMSL , 9. Well Name and Number: 1J - 174L1 8. Property Designation: • ADL 25661, 25660, 25663, 385172 10. Field /Pool(s): Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 19750' • feet true vertical 3055' feet Plugs (measured) Effective Depth measured 19688' feet Junk (measured) true vertical 3057' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 120' 20" 120' 120' SURFACE 3973' 13 -3/8" 4014' 2270' INTERMEDIATE 3886' 10.75" 3927' 2249' INTERMEDIATE 8153' 9.625" 12081' 3205' SLOTTED LINER 8334' 4.5" 19689' 3056' Perforation depth: Measured depth: slotted liner from 11485'- 11686', 11768' - 12878', 12880'- 19644' true vertical depth: 3141'- 3159', 3163'- 3122', 3122' -3059' O Tubing (size, grade, and measured depth) tubing in main wellbore, , MD. Packers & SSSV (type & measured depth) no packer no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure 987 355 35 -- 221 1386 136 898 — 232 14. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _X 15. Well Class after work: Exploratory ❑ Service ❑ Development ' 16. Well Status after work: WAG ❑ GINJ❑ WINJ ❑ WDSPL❑ Oil . Gas ❑ 17. 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 Signature 7&X Phone: 265 -6845 Sundry Number or N/A if C.O. Exempt: none Wells Engineer *(I7(2'1(01 Date Prepared by Sharon Allsuo -Drake 263 -4612 Form 10 -404 Revised 04/2006 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS` a Ijlf RECEIVED 7 � a 2. 4 2009 Gas Cons. Commission nrhnra Submit Origins Only Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, April 28, 2009 9:02 AM To: 'Packer, Brett B' Subject: RE: 1J -137 (206 -108) and 1J -174 (207 -143) Brett, OK, so are the BOT drawings in the process of being updated? For me and other users not so intimately involved with these wells, the straight drawings are somewhat confusing to use. I look forward to your reply. Tom From: Packer, Brett B [mailto:J. Brett .Packer @conocophillips.com] Sent: Tuesday, April 28, 2009 8:59 AM To: Maunder, Thomas E (DOA) Subject: RE: 1J -137 (206 -108) and 1J -174 (207 -143) Tom, • • didn't include the profile view schematics because they haven't been updated yet. Those schematics were built by Baker Oil Tools, and they've kept the actual Visio drawing and only provide us with the pdf version, so we can't edit them ourselves. Attached are the schematics we have, but once again, they aren't up to date. 1J-174 The completion shown is correct, except for the depths of the ESP and GLM's. 1 J -137 The completion shown is completely wrong. It now has an LEM installed and a Y -block ESP completion downsized to 3 -1/2" tubing. 3. Brett Backer Torilaing GZ 'Wel WorftpverEngineer Work" (907) 265 -6845 Cell# (907) 230 -8377 From: Maunder, Thomas E (DOA) [mailto :tom.maunder @alaska.gov] Sent: Tuesday, April 28, 2009 8:19 AM To: Packer, Brett B Subject: 1J -137 (206 -108) and 1J -174 (207 -143) 4/29/2009 Page 1 of 2 Brett, I am reviewing the 404s for the recent workovers on these multi - lateral wells. Would you please provide drawings that show the well in a "horizontal format" such as are included in the permit to drill? The straight drawings are somewhat difficult to relate to the operations report. I also request that horizontal drawings be included whenever a workover is done on a multilateral well. You can send the drawings via email. Call or message with any questions. Wellhead / Tubing / Tree: 13 -3/8" x 4 -1/2 ", 5,000 psi Insulated Conductor 20" 94# K -55 x 34" 0.312 WT *1- 80' 4013' MD - 13 -3/8" Casing Shoe, 688, L -80, BTC, 2270' TVD, 76 deg inc Equipment Specifications 7" X 9 -5/8" RAM Junction Mainbore Drift: 3.68" Lateral Drift: 5.80" RAM Hanger /Seal Bore Diverter OD: 8.375" Overall Length of RAM Junction: 38.3 ft Seal Bore Diverter Running Tool: FJD RAM Hanger Running Tool: HRD-E 4 -1 /2" Lateral Entry Module LEM OD: 6.99" Mainbore Drift w/o Diverters: 3.68" Mainbore Drift w/ Isolation Diverter: 2.50" Lateral Drift w/ "FB" Diverter: 3.68" OD of Diverters: 3.68" Tubing String 4-112" 12.6 #, L -00, IBTM 3.958" ID, 3.833" Drift 2394 'MD - GLM , Cameo ,4- 1/2 "x1 " KBMG Dual lateral Completion 3927' MD - 10 -3/4" 73.2 #, L - 80, BTC Casing Crossover 4487' MD - GLM, Camco, 4 -1/2" x 1" KBMG 11355' MD - 7" X 9 -5/8" RAM Hanger 5.960" Lateral Drift ID 1688" Mainbore Drat ID ConocoPhillips AS 2007 West Sak Producer COMPLETED with Rotating self - Aligning Multilateral (RAM System 9505' MD - GLM. Camco, 4 -1/2" x 1" KBMG 9587' MD — A -Well Discharge Pressure Sub 9711' MD - Bottom of Motor Centralizer Centralift 418 HP KMH 11360' MD - 4 -'." x 9 -5/8" RAM Seal Bore Diverter /SBD) with 3.68" Seal Bore 4 -1/2" 12.6# Hydril 521 and! IBTM Tubing 11366' MD - D -Sand Casing Exit, 3128' TVD. 83 deg inc 'D' Sand Lateral 11416' MD- 7 "x9 -5/8 "M Liner Hanger Packer 1J -174 HB DLP WO -09 11444' MD - Sealbore Receptacle 4.70'1D 4 -1 /2" 11.6 #. Hydril 521 and BTC, L-80 Blank and Slotted Liner ` —y \ mew l i t iwi=lisi ft 1 415' MD -3.562" DB Nipple - . . 4 , , N 3133' ND, 84 deg 11425' MD - MLHR Production Anchor 11454' MD - Bottom of Seal Assembly 4.75" Seal OD 3.875" ID ,' Baker Hughes 2008. This document may not be reproduced or distributed, in whole or in part. in any form or by any means electronic or mechanical, including photocopying, recording. or by any information storage and retrieval system now known or hereafter invented. without written permission from Baker Hughes Inc. 12080' MD - 9 -5/8" Casing Shoe, 40.08, L -80 BTC , 3205' TVD, 85 deg ine 5 -1/2" Guide Shoe, 6.00" OD 95/8 " ML TorqueMaster Packer Positive Latching Collet Indicates Correct Location Seal Bore for Lateral Isolation Diverter 3.88 "ID Lateral Access Window (Provide. Positive Lateral Ames. en neleetatele oweded Lateral Entry Module ILEM1 With Diverters and Isolation Lateral Access "FB" Diverter /Installed m I FMt ' laotoethae, odd. m ' e,a m LEN In Lateral Diverter Lateral Isolation Ran anger) Ramp Upper Seals Note: GS S sed for running and puling diverter 19689' MD - 4 -1/2" Casing Shoe, 11.68, L -80 BTC, 3056' TVD 'B' Sand Lateral 5 -1/2" 15.58, Hydril 521 and BTC. L-80 Blank and Slotted Liner TRW Da March 18, 2009 4 -1/2" Orange Peeled Shoe 19656' MD - 5 -1/2" Casing Shoe, 15.5 #, L -80 BTCM , 3156' TVD 2007 Weal Sak Dual Lateral Completion - Producer pawn By: Snap In/Snap out Positive Locating Collet Baker Oil 'Fools Snap In/Snap Out Positive Locating Collet Lateral Isolation Lowe, Seals (seals inside RAM Seal Bore Diverted BAKER HUGHES ateral lsolationflniectioll Sleeve (Installed in LEMI • No. tat • Conoco Phillrps asks. )r . _009! CA0Egg1ULTIPLE LATF;.RALS 1J 17411, 4/1712/09 8.35:06 At4 Srnem Actual HANGER. 36 CONDUCTOR, 44-120 ESP MANDREL - 2.354 SURFACE, 504,021 ESP MANDREL, 4,487 SP MANDREL. 5505 ESP DISCHARGE, - 9.587 PUMP ASSY, 9,632 - ESP INTAKE,___ 9,662 SEAL, 9,672 SEAL, 9,679 ESP MOTOR. 9,686 GAUGE, 9,708 Centralizer 9.711 Seel Bore DIvener, 11,360. 11,455 SLOTS. 11,485.11,688 NTERMEDIATE, 40- 12,080 SLOTS, 1,768. 12,878 SLOTS, 2,880.19,644 D-SAND LINER, 11,355. 19,689 TD (1J- 17411), 19,750 KUP Well Attributes W ellbore API/U W I Field Name 500292337460 WEST SAK Comment H2S (ppm) SSSV: NONE 0 Annotation Depth (ftKB) [End Date Last Tag Casing Strings Casing Description String 0... String ID... Top (ftKB) Set Depth (f... D -SAND LINER 4 12 3.960 11,355.4 19,6895 Liner Details Top Depth (TVD) Top Inc' Top MKS) (MKS) ( °) Item Description 11,355.4 HANGER 3,127.3 83.11 11,363.0 Tap (B) 11,485 11,768 12,880 Mandrel Details 3,128.2 83.13 HANGER Perforations & Slots Btm (ftKB) 11,686 12,878 19,644 3,142.2 3,163.0 3,122.2 Notes: General & Safe End Dab Annotation 12/28/2007 NOTE: MULTI - LATERAL WELL 1J -174 (B- SAND), 1J -1 74L1 (D -SAND) 6/21/2008 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 2,393.8 4,487.1 2,352.7 Stn Top (ftKB) 1 2 3 9,504.8 Top (TVD) She (TVD) (RIM (MKS) 3,122.2 3,058.8 Top Depth Top (TVD) Inel MEN ( °) Make Modal CAMCO KBMG 83.52 CAMCO KBMG 2,912.2 86.74 CAMCO • Max Angle & MD TD Well Status P10411,) Type Inc! ( °) •10 (ftKB) Act Btm (ftKB) PRODUCING 94.42 11,949.54 19,750.0 (Date - - -- (Annotation End Date KB -Grd (M) Rig Release Dab 1/1/2009 1Last WO: 3/18/2009 44.41 12/31/2007 / Annotation End Date Rev Reason: ESP WORKOVER I 4/17/2009 Zone WS D, 1J -174L1 WS D, 1J -174L1 WS D, 1J-174L1 Date 12/27/2007 12/27/2007 KBMG OD M) 1 ESP 1 ESP 1 ESP Valve Sam Type SOV DMY DMY Set Depth (TVD) 3,056.8 Comment Shot Dens (nh... Type 32.0 SLOTS 32.0 SLOTS Latch Type BK -5 BK -5 BK -5 String Wt... ISIring ... [String Top Thrd 11.60 I L -80 ( BTC Comment Slotted liner, 2.5" x .125 ", 4 circumferential rows/ft, 3" centers staggered 18 deg, non - slotted ends 12/27/2007 32.0 SLOTS Slotted liner, 2.5' x .125", 4 circumferential rows/ft, 3" centers staggered 18 deg, non - slotted ends Slotted liner, 2.5" x .125 ", 4 circumferential rows/ft, 3' centers staggered 18 deg, non - slotted ends Pod Size (in) 0.000 0 000 0.000 TRO Run (pal) 0.0 0.0 0.0 1J-174L1 Run Date 3/27/2009 3/16/2009 3/16/2009 ID (In) 6.760 6.000 ~onoc4Phillips Time Log. & Summary iNellview tYeb ReAOrttng Report - - -- _ -_ - Well Name: 1J-174 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 3/14/2009 1:00:00 AM Rig Release: 3!18/2009 3:00:00 PM - -_ ___ - -- - Time Logs Date From To Dur S Depth E Depth Phase Code 5ubcode_ T Comment - ---- __ 3/14/2009 2a hr Summary Move in mats. Move rig in and set down. Accepted Nordic Rig 3 @ 0100 hrs on 3-14-09. Berm up and load its w/ 8.6 KWF. Pull BPV. Kill well. Install BPV, ND Tree and NU BOPE, Test BOPE. 00:00 02:00 2.00 COMPZ MOVE MOB P Relocate double mats from 1J-137 to 1J-174 and set. Move in Nordic rig 3 and set down. Accepted Nordic rig 3 @ 0100 hrs on 3-14-09. 02:00 06:30 4.50 COMPZ RPCOM OTHR P Berm up, Spot tanks, mud shack and highline trailer. Load pits 8.6 ppg 6% KCL water. RU to Lubricate out BPV -BPV leaking along w/ Master and swab valve-Call out valve shop to grease tree valves. RU lubricator ull BPV. 06:30 09:30 3.00 COMPZ WELCTI KLWL T RU circ. lines and attempt to PT, valves and hoses to kill tanks frozen. Applied heater to thaw lines and valves. Re laced two valves. 09:30 10:00 0.50 COMPZ WELCTI KLWL P Pressure test lines to 250/2500 psi. Opened well, IA press - 690 Tbg 490 psi. Bled IA down to 240 psi and Tbg to 340 psi. Start well kill by pumping dwn IA taking returns out tubing. Pumped 35 bbls with no returns. 2BPM w/ICP 390 and 420 FCP. 10:00 15:00 5.00 COMPZ WELCTI KLWL P Switched to pump down tubing to flush w/150 bbls 4 BPM @ 520 psi IA, 70 psi tubing. Switched to pump down IA. Pumped 4 BPM @ICP 530 psi, Increased rate to 5 BPM 400 psi. Pumped 670 bbls. Shut down monitor well, after 15 min IA 460 si. 15:00 15:30 0.50 COMPZ WELCTI KLWL P Pumped down tubing w/no returns, 2 BPM w/60 psi. 202 bbls. Shut down, monitor well, tbg 0 IA ,after 15 min IA had slight blow and 10 psi. Pumped 50 bbls down IA @ 6 BPM w/60 psi. Shut down monitor well. Well dead. Tb 0 IA 0 15:30 17:30 2.00 COMPZ WELCTL NUND P Set BPV. ND tree. Pumping 25 bbls down IA every hour. Break off Bonnet and load out various valves. 17:30 20:30 3.00 COMPZ WELCTI NUND P NU BOPE ~~ _ F~~~ ~ ~` 5 Time Logs __ Date From To Dur S, Depth E_ Depth Phase Code Subcode T Cornment___ _ 20:30 00:00 3.50 COMPZ WELCTI ROPE P RU to Test BOPE @ 250/2,500 psi - Test BOPE 24 hr Notice was given to AOGCC @ 0800 hrs on 3-13-09 and Waived by Lou Grimaldi 0655 hrs on 3-14-09. 3/15/2009 Continue do Test BOPE @ 250!2,500 psi. Circulate well w/ Hot viscosified Sea water w/ 6% KCL. BOLDS and POOH w/ 4 1/2 ESP Com letion. 00:00 03:30 3.50 COMPZ WELCTI BOPE P Continue to Test BOPE @ 250/2,500 psi Draw down: 3,000 psi, 1,600 psi after - 200 psi in 29 sec., 3,000 psi in 2 minutes, 25 seconds. Nitrogen bottles - 4 @ 2,275 psi. 24 hr Notice was given to AOGCC @ 0800 hrs on 3-13-09 and Waived by Lou Grimaldi 0655 hrs on 3-14-09. 03:30 04:00 0.50 COMPZ WELCTI OTHR P Pull test dart. 04:00 06:00 2.00 COMPZ WELCTt CIRC P Notify Security and 1J Pad operator for venting of gas on 1 J-174. Blow air thru kill to kill tank -clear. Open IA to Choke manifold - 160 psi, begin to bleed off and Pump 110 bbls thru BPV @ 2 bpm @ psi. To clear an as below BPV. 06:00 06:30 0.50 COMPZ RPCOM PULL P Pull BPV. MU landing jt. BOLDS 06:30 08:00 1.50 COMPZ RPCOM OTHR P Load pits. Monitor well while MU top drive. 08:00 08:30 0.50 COMPZ RPCOM PULL P Unset hanger free w/87K, PU 4', Pump 150 bbls down tubing @ 8 BPM w/50 si. 08:30 10:00 1.50 COMPZ RPCOM CIRC P BD top drive and kill line out to kill tank. Pump 520 Bbls hot 6% KCL water down IA @ 9 BPM w/100 psi . Shut down, well on vac. 10:00 11:00 1.00 COMPZ RPCOM PULL P Pull hanger to rig floor. Disconnect from Penetrator, break out tubing hanger and landing jt, LD. Change out elevators. String cable over sheave. 11:00 22:30 11.50 9,088 100 COMPZ RPCOM PULL P POOH standing back, drifting and strapping 4 1/2' tubing, removing al! jewelry, and spooling up the ESP cable. Pum in 40 bbls er hr. 22:30 00:00 1.50 100 0 COMPZ RPCOM PULD P Disconnect ESP cable. Pull sample from ESP Components. Found Splice to motor lead damaged and Motor B-Phase was shorted out to round. COMPZ RPCOM _~ mms ~ ~~ ~ ® v ~® F~a~~. 2 ut 5 i~__ Time Logs --- - Date From To Dur S. Depth E_Degth Phase Code Subcode T Commen_t___ 3/16/2009 24 hr Summary Prep Pipe shed, Change over to DP equip., RIH w/ DP and slip and cut Drill line. Standby for Cold weather variance on crane, Make other arrangements, POOH laying down DP. Change over to RIH w/ 4 1/2 ESP Com letion. MU ESP motor ass and Seal sections and service. 00:00 00:30 0.50 COMPZ RPCOM PULD P Break down ESP components and lay down the same. 164 -Cannon X Cplg clamps 8 -Stainless Steel Bands 3 - Protectolizers 2 -Flat uards 00:30 01:30 1.00 COMPZ RPCOM OTHR P Change over to DP Equipment and re i e shed. 01:30 03:00 1.50 0 5,816 COMPZ RPCOM TRIP P MU Bull nose and RIH w/ 3 1/2 DP to 5,816' 03:00 04:30 1.50 5,816 5,816 COMPZ RPCOM SVRG P Slip and cut 84' Drill line and service ri . 04:30 05:30 1.00 5,816 5,816 COMPZ RPCOM OTHR P Strap and Tally new completion e ui ment 05:30 09:00 3.50 5,816 COMPZ RPCOM OTHR T Standby with kill string in the hole for Crane verification to swap out ESP Cables ool 09:00 15:00 6.00 5,816 0 COMPZ RPCOM TRIP P POOH laying down 3 1/2" DP in pipe shed. Cannot unload pipeshed until weather warms up enough for the loader to work. 15:00 16:30 1.50 0 0 COMPZ RPCOM OTHR P RU ground spooler and loaded with new 9800' cable and applied Tioga heater to warm up. Removed old ESP a ui ment. Load new um . 16:30 21:00 4.50 0 0 COMPZ RPCOM RCST P PU perforated xover intake and two jts of 4 1/2" RIH. RU slickline, RIH w/109 stage P35 ESP pump. Set pump. Set packoff on top of pump and PT to 1000 psi. and chart for 15 min. Set slipstop. RD slickline. MU Discharge sub and crutch, Stand back in derrick 21:00 23:00 2.00 0 40 COMPZ RPCOM PULD P PU and MU Centralizer, A-Well I-Pump Sensor, Motor, Lower Seal section and Upper seal section and service the same. 23:00 00:00 1.00 40 40 COMPZ RPCOM PJSM, Start MLE over Sheave and connect Motor Lead to motor. 3/17/2009 Continue RIH w/ 4 1/2 ESP Completion to 9,700' and make final splice. Land Hanger and RILDS. ~ e ~~~ _ e_ ®_ F~~~~~. 3 €s€ ~' 4 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 02:30 2.50 40 90 COMPZ RPCOM RCST P RIH on PerfX-O Assy and 1 jt, install x-cplg clamp @MLE Splice. Meg motor: 17 Pi, 19 Pd, 35.24 Ti, 43.34 Tm, .057 Vx, .046 Vv, .7 Ph / Ph, 5G Ph/Grd. Plug in Cable : 16 Pi, 16 Pd, 58.64 Ti, 55.58 Tm, .107 Vx, .066 Vv, 3.052 Ph/Ph, 1G Ph/Grd. MLE: 2G Pi. 1st Jt: 16 Pi, 17 Pd, 60.08 Ti, 57.74 Tm, .087 Vx, .051 Vv, 3.052 Ph/Ph, 1G Ph/Grd. 02:30 13:00 10.50 90 8,664 COMPZ RPCOM RCST P MU and RIH w/ 2nd Jt, GLM# 3 assy, followed by 26 more jts. Meg Line. Continue to RIH w/ 4 1/2 ESP completion from derrick and Meg ESP Cable eve 1,000' 13:00 18:30 5.50 8,664 8,664 COMPZ RPCOM RCST T Stop RIH due to discharge pressure not reading while cable testing. - Troubie shoot downhole discharge gauge. - Contact town, plan to pull completion and change out gauge. - Picked up spare gauge. Spare gauge would not test. Gauge looked like it was previously used. - Tested Centrilift surface box on 1J-137 and obtained good readings. - Pulled gauge from old 1J-174 completion. Gauge did not test. - Contacted town, plan to complete the well with no discharge pressure since no replacement gauge was .available. 18:30 20:00 1.50 8,664 9,645 COMPZ RPCOM RCST P Continue to RIH f/ 8,664' w/ 4 1!2 ESP Completion to 9,645'. PU and MU TBG hanger and landing jt. S ace out for Finals lice. 20:00 23:30 3.50 9,645 9,645 COMPZ RPCOM OTHR P Make final splice and test cable. Connect to Penetrator and meg again. Meg readings - Pi = 1,076 psi, Pd = 57 psi, Ti = 60.62, Tm = 58.64, Vx = .079, Vy = .071, Ph / Ph = 3.052, Ph/grd = 1G Used: 19 SS Bands, 162 x-cplg clamps, 2 flat guards, 3 Protectrolizers 23:30 00:00 0.50 9,645 9,713 COMPZ RPCOM HOSO P Land hanger w/ tail @ 9,713' 93k up wt, 45k do wt. RILDS 3/18/2009 Test upper and lower seal. Set BPV. ND BOP and NU Tree. Test Tree ,Pull BPV. Freeze Protect well. Secure and dress Tree. Remove ESP spool and Spooling unit from rig floor. Move rig from over 1J-174. Move mats and clean cellar. RDMO, towards 3H Pad. 00:00 00:30 0.50 9,713 COMPZ RPCOM DHEQ P Test upper and lower seals on han er 5,000 si. ~~ s ®~~ mm ~=-~e~€~ ~ c+~ Time Logs _ _ __ _ _ _ _ _ Date From To Dur S. De th E. De th Phase Code Subcode T Comment ~~ 00:30 01:00 0.50 COMPZ RPCOM MPSP P Set BPV 01:00 04:30 3.50 COMPZ RPCOM NUND P PJSM, ND BOP and set back. 04:30 05:00 0.50 COMPZ RPCOM NUND P NU Bonnet. 05:00 05:30 0.50 COMPZ RPCOM DHEQ P Conduct Final Meg of ESP Cable and ESP pump components. Pi = 1,011 psi, Pd = 58 psi, Ti = 62.96, Tm = 60.62, Vx = .063, Vy = .085, Ph/Ph = 3.0, Ph/Grd = 1G. 05:30 07:30 2.00 COMPZ RPCOM NUND P NU Tree. 07:30 09:00 1.50 COMPZ RPCOM DHEQ P Pull BPV, set TWC, PT tree 250/5000 si, ull TWC 09:00 11:00 2.00 COMPZ RPCOM FRZP P PJSM w/ hot oil, test lines 2500 psi. Freeze protect well with 40 bbl of diesel down the tubing and 170 bbl of diesel down the IA. 11:00 14:00 3.00 COMPZ RPCOM RURD P Set BPV. Secure tree, stage mats for ram off well. 14:00 15:00 1.00 COMPZ RPCOM RLOC P PJSM. Move rig off well. Clean up cellar box, move T-mats, clean well site. Release Nordic Rig 3 @ 15:00 hrs on 3-18-09 DATA SUBMITTAL COMPLIANCE REPORT 7 2/9/2008 Permit to Drill 2071440 Well Name/No. KUPARUK RIV U WSAK 1J-174L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23374-60-00 MD 19750 TVD 3055 Completion Date 12/30/2007 REQUIRED INFORMATION Mud Log No Completion Status 1-OIL Samples No Current Status 1-OIL Directional Survey DATA INFORMATION Types Electric or Other Logs Run: GR/RES Well Log Information: Log/ Electr Data Digital Dataset Typ Med/Frmt Number Name D Asc Directional Survey ~t Directional Survey ~pt LIS Verification C Lis 16228/Induction/Resistivity /Log Induction/Resistivity t/L~og Induction/Resistivity ,,~ C 16235 ~ee Notes I! iKpt 1~~(?j LIS Verification l`iQ ~I ED ~,,, t S 16475 Induction/Resistivity Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y / N Chips Received? Y / N Analysis Y / N Received? UIC N (data taken from Logs Portion of Master Well Data Maint Log Scale Log Run Media No Interval Start Stop OH / CH Received Comments • 40 19750 Open ----- 3/7/2008 ------- ------ --------_ 40 19750 Open 3/7/2008 f 11300 ,2si~l~ Open 5/7/2008 LIS Veri, ROP, FET, RPD, ~473-a RPM, RPS, RPX, GR 11300 X50 Open 5/7/2008 LIS Veri, ROP, FET, RPD, lQ,'tT'o RPM, RPS, RPX, GR 25 Col 120 19750 Open 5/7/2008 MD ROP, DGR, EWR 25 Col 120 3054 Open 5/7/2008 TVD ROP, DGR, EWR 0 0 5/7/2008 EWR Log in TVD and MD in CGM, EMF and PDF graphics 3994 19750 Open 6/19/2008 LIS Veri, GR, RPD, RPM, RPS, TPX, FET, ROP ~ ~~~,~ 3994 19750 Open 6/19/2008 LIS Veri, GR, RPD, RPM, RPS, TPX, FET, ROP Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? Y / N Formation Tops ~ N DATA SUBMITTAL COMPLIANCE REPORT 12/9/2008 Permit to Drill 2071440 Well Name/No. KUPARUK RIV U WSAK 1J-174L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23374-60-00 MD 19750 ND 3055 Completion Date 12!30/2007 Completion Status 1-OIL Current Status 1-OIL UIC N Comments: Compliance Reviewed By: __ Date: ~ i WELL LOG TRE1NSl0~IITTAL To: State of Alaska June 9, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`" Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data 1J-174 L1 Redo AK-MW-527561 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23374-60 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: _ ~ _::~u~, ~ // Signed: ~ _ ~~~~~ STATE OF ALASKA ~ JUN ®3 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIQIa ad & Gas Cons. COmmiS5i0t'! 1. Operations Performed: Abandon ^ Repair Well ~ Plug Pertorations ^ Stimulate ^ Other Alter Casing ^ Pull Tubing ^~ .Pertorate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Pertorate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConOCOPhillipS Alaska, InC. Development ^~ Exploratory ^ 207-144 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-23374-60 7. KB Elevation (ft): 9. Well Name and Number: RKB 121', GL 81' AMSL ' 1J-174L1 . 8. Property Designation: 10. Field/Pool(s): 25661, 25660, 25663, 385172 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 19750' feet true vertical 3055' feet Plugs (measured) Effective Depth measured 19688' feet Junk (measured) true vertical 3057' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 120' 20" 120' 120' SURFACE 3973' 13.375" 4014' 2270' INTERMEDIATE 3886' 10.75" 3927' 2249' INTERMEDIATE 8153' 9,625" 12081' 3205' SLOTTED LINER 8334' 4.5" 19689' 3056' Perforation depth: Measured depth: slotted liner from 1148 5'-11686', 11768'-12878', 12880'-19644' true vertical depth: 3141'-3159', 3163'-3122', 3122'-3059' Tubing (size, grade, and measured depth) tubing in main wellbore, , MD. Packers &SSSV (type & measured depth) no packer no SSSV 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 2561 not available 75 -- 306 Subsequent to operation 1364 250 120 -- 248 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: none contact Brett Packer @ 265-6845 Printed Name Brett Packer Signature -- `~~~ `~ Title Phone: 265-6845 Wells Group Engineer / / Date (. / 3 /~~' r 1~ t on All ` Drak 263-4612 Pre b h r j''~ ~ +~ d ~ ~ iPF&> ~11C ~$ ~ ~~a~ Su~O~ in On~ ~v~~ ~; Form 10-404 Revised 04/2006 1 1 ~ ~ "'~ ~ a '~.. 9 ~, Y '~ KRU 1 J-174L1 ConocoPhillips Ataska~ Inc. • i Cont~coPhilps Time Log Summa Wellvtew Web Regsortfng Well Name: 1 J-174 Job Type: RECOMPLETION ---- j_Time Logs --- - ----- - Date From To Dur_ _ S._Depth- E. De~th_Phase Code Subcode T__ COM 04/17/2008 08:00 10:00 2.00 MIRU MOVE MOB P PJSM, commence move Nordic rig 3 (1J-166 to 1J-174) well to well, same ad, derrick u . 10:00 12:00 2.00 MIRU MOVE RURD P PJSM, spot rig over 1J-174, commence RU all related plumbing / electrical. Accept Nordic rig 3 this date 1100 hrs. 12:00 14:30 2.50 COMPZ RPCO OTHR P Take on WO fluids to rig pits, cont RU tree lines for kill. Plumb to kill tank / all related a ui . 14:30 15:30 1.00 COMPZ RPCOti SFEQ P PT hard lines @ 2,500 psi and blow down. 15:30. 21:00 5.50 COMPZ RPCO CIRC P Pump down the IA @ 3 bpm @ 600 psi ICP, then increase to 4 bpm @ 370 psi. Recovering 145 bbls of diesel mixed fluid from well bore. IA volume pumped was 1,023 bbls 8.5# 6%-KCL. Then 300 bbls of 8.5 6% KCL was bull headed down tbg @ 4 bpm @ 180 si. Total hole volume = 1,269? bbls. 21:00 21:30 0.50 COMPZ RPCOti OWFF P Monitor well for flow 21:30 22:00 0.50. COMPZ RPCOh SFTY P Held PJSM on ND-Tree and NU of 13 5/8 BOPE. 22:00 22:30 0.50 COMPZ RPCOti OTHR P Shoot fluid level on IA = 260' 22:30 23:00 0.50 COMPZ RPCO OTHR P Set BPV. 23:00 00:00 1.00 COMPZ RPCOh NUND P ND Tree. 04!18/2008 00:00 01:00 1.00 COMPZ RPCOti NUND P Continue to ND Tree 01:00 08:30 7.50 COMPZ RPC06 NUND P NU BOP. NU HCR Valve and 3 1/8" Manual Valve. NU Riser. Open doors and visually check 27/8 x 5 1/2 VBRs on to and 4 1/2 rams in lower. 08:30 14:00 5.50 COMPZ WELC7 BOPE P PJSM, test BOPE all components 250 / 2500 psi. Perform time /volume / press test to accumulator unit. Nitrogen within spec. All tests successful,. no re-tests. Witness waived Mr Bob Noble AOGCC. Notified 4/16/08 0700 hrs. 14:00 15:30 1.50 COMPZ RIGMN SVRG P PJSM, slip / cut drlg line. 15:30 17:00 1:50 COMPZ WELC BOPE P Pull blanking plug, pull. BPV, MtJ Ldg 't. i ~ Time Logs _ __ Date From_ To Dur S_D~th E. Depth Phase Codg Subcod_e T_ COM _ - 04/18/2008 17:00 20:00 3.00 COMPZ WELCT -0THR P NoPress on tbg. Bleed gas cap from IA..Initial ress = 60 si. 20:00 20:30 0.50 COMPZ RPCOh OTHR P Shoot Fluid Level @ 300' 20:30 22:00 1.50 COMPZ RPCOh WOEQ T Wait on Generator for spooler -found problem during pre-trip check -fix and sent out. 22:00 22:30 0.50 9,583 9,551 COMPZ RPCOh OTHR P BOLDS, Unseat hanger @ 100k and ull to ri floor. U wt 105k 22:30 23:00 0.50 9,551 9,520 COMPZ RPCOh PULD P Lay down landing joint and hanger 'oint. 23:00 00:00 1.00 9,520 9,426 COMPZ RPCOti TRIP P Pooh and stand back 4 1/2 completion string w/ 100k up wt. Stand back 1 stand and thread ESP cable over sheave to spooling unit outside rig floor throu h Ele hant trunk. 04/19/2008 00:00 09:30 9.50 9,426 3,228 COMPZ RPCOti PULD P Continue to Pooh w/ ESP Completion, drifting tbg to 3:833" and strapping. Changing collar seals as pulled. Fill hole with 3 x's tbg displacement. Found sand in tbg starting @ 3,228' out of the hole. Sand up various de ths. Difficul driftin . 09:30 11:00 1.50 3,228 3,228 COMPZ RPCOh PULD P PJSM, C/O ESP spools. 11:00 16:00 5.00 3,228 950 COMPZ RPCOh PULD P Flow check, resume POH, standing bk 4-1/2 tbg. Cont POH to perfed tbg jt. Inspect. First shot indentations. No holes. Second shot with holes. 16:00 17:00 1.00 950 950 COMPZ RPCO RURD P LD perf jt, arrange floor /ground area for slickline. 17:00 19:30 2.50 950 950 COMPZ RPCOb SLKL P Held PJSM, Rih and attempt to pull slip stop and pack off. Unable to get to desired depth due to sand. RD slickline. 19:30 00:00 4.50 950 103 COMPZ RPCOti PULD P Pooh laying down sanded up 4 1/2 tbg and 't w/ sli sto and ack off. 04/20/2008 00:00 01:00 1.00 103 COMPZ RPCOh OTHR P Disconnect ESP Cable and pull TCC Pum . 01:00 03:30 2.50 COMPZ RPCOh OTHR P Break down motors and pull oil sam les. To section was locked u . 03:30 04:30 1.00 0 COMPZ RPCOh OTHR P Meg motors and lay down them down. 12 of 17 Stainless steel bands were recovered, along w/ 274 x-cplg clamps, 3 protectorlizers, 2 flat uards. 04:30 05:30 1.00 COMPZ RPCO OTHR P clean and clear rig floor of sand. 05:30 06:30 1.00 COMPZ RPCOti OTHR P RD ESP equip, clear floor. 06:30 08:00 1.50 COMPZ WELCT EORP P Flush BOP stack in prep for packoff re lacement. 08:00 14:30 6.50 COMPZ RPCOh OTHR P PJSM, Bleed OA while load pipe shed with 3-1/2 DP workstring, prep same. Initial press OA 125 psi. Will not bleed dn. Total 20 bbls diesel taken during bleed. Multi le shut ins with 125 si. ~~ Pa , _ c of h • Time Lomas Date From To Dur S De th E De th Phase Code Subco e T COM 04/20/2008 14:30 16:00 1.50 COMPZ WELC OTHR P PJSM, Pump seawater do OA, arrest press. 140 bbls needed to stop flow. Bleed to "0" si. 16:00 21:00 5.00 COMPZ WELCT EQRP P PJSM, R/U,Attempt to Back out the lower lock down screws and found 1 that was barely functional. Also found 1 that was not functional at all., Call B. Packer WO Eng. and reviewed the options and decided. to attempt to ack void w/ lastic for seal. 21:00 21:30. 0.50 COMPZ RPCOCv SFEQ P PT to 4,800 psi for 30 minutes w/ plastic. Call B. Packer WO Eng. and Ves Cash w/ Vetco Gray and in#orm them that we were able to test and that his met their approval. The decision was also made to paint the Lower Lock down screws that were non functional RED. 21:30 22:00 0.50 COMPZ RPCOh OTHR P Release from the 133/8 x 10 3/4 Pack off ass and la down ullin tool. 22:00 00:00 2.00 COMPZ RPCOh FRZP P Held PJSM w/ LRS. RU and PT LRS pump lines @ 2,000 psi. Pump 142. bbls of diesel to freeze protect the 13 3/8 x 10 3/4 OA @ 2 bpm @ 1,425 psi max. Final SIP was 750 si OA. 04!21/2008 00:00 00:30 0.50. COMPZ RPCOh OTHR P Set wear ring 00:30 01:30 1,00 0 211 COMPZ RPCOh PULD P PU and MU 8.5" RCJB assy. 01:30 06:00 .4.50 211 2,172 COMPZ RPCOh TRIP P PU and Rih w/ 31/2 DP drifting the same w/ 61 jts. Arrange 4 1/2 tbg in derrick and prepare to stand back 20 stands. 06:00 07:30 1.50 2,172 298 COMPZ RPCOti TRIP P Pooh w/ 20 stands 3 1/2 DP. 07:30 20:00 12.50 298 8,570 COMPZ RPCOti TRIP. P Continue to Rih w/ 3 1/2 DP drifting the same f/ 298', Pumping DP Vol. every 1,000'. Begin taking wt @ 8,570'. 95k u wt, 50k do wt. 20:00 20:30 0.50 8,570 7,595 COMPZ RPCOti TRIP P Pooh w/ 9 stands to 7,595'. 20:30 22:00 1.50 7,595 8,536 COMPZ RPCOh TRIP P Continue to Rih w/ 31/2 DP drifting the same f! 7,595' to 8,536°, 22:00 00:00. 2.00 8,536 9,214 COMPZ RPCOh CIRC P Pump ball down @ 4 bpm @ 500 psi. When ball seated pressure increased to 650 psi, increased PR to 6 bpm @ 2,500 psi. Begin washing down f/ . 8,570' to 9,214' w! no returns as of midnight. 100k up wt; 50k do wt; 75k Rot wt 04/22!2008 00:00 05:00 5.00 COMPZ RPCOh TRIP P Continue to wash down from 9,214' to 10,049'. Circulating @ 6 bpm @ 2,500 psi. Encountered leak in wash i eon to drive. 05:00 06:30 1.50 COMPZ RIGMN' RGRP T PJSM, Replace wash pipe /packing ass . I P-~., 3 ~~f 5 • • Time Logs _ __ ___ Date From To _ Dur S Depth E. Depth Phase Code Subcode T COM _ 04/22/2008 06:30 ____ 11:30 _ 5.00 COMPZ RPCO TRIP P Resume RIH, wash /ream sands from 9-5/8 csg to top of RAM hgr 11350 ft. Taking wt. Must wash entire interval. 5 - 6 bpm, 2600 psi. Intermittent returns while conventional and reverse circ. 1.1:30 15:30 4.00 COMPZ RPCOh CIRC P Re-cip rotate pipe with light sweeps. Sands to surface intermittent) . 15:30 22:00 6.50 COMPZ RPCOI~ TRIP P PJSM, POH 3-1/2 DP from 11,350' to 200'.. 22:00. 23:30 1.50 GOMPZ RPCOh PULD P L/D BHA &cleanout reverse.circjunk basket. Recovered 5 small metal feces. 23:30 00:00 0.50 COMPZ RPCOti OTHR P Unload RCJB, load tools and prep for runnin 2-7/8" cleanout ass . 04/23/2008 00:00 01:00 1.00 COMPZ RPCOti TRIP P Prep for cleanout run, PU 2-7/8" Muleshoe 01:00 03:00 2.00 COMPZ RPCOCV TRIP P Single in 66 joints 2-7/8", 10.4 Ib/ft, S-135 drill i e w/ muleshoe. 03:00 06:00 3.00 COMPZ RPCOh TRIP P Cont RIH 2-7/8 DP to 3280 ft. Take wt, no further ro ress. 06:00 09:00 3.00 COMPZ RPCOh CIRC P Mix /pump "Safe Lube" tubed seawater, reduce wall friction. 09:00 09:30 0.50 COMPZ RPCOti RURD P Break top drive, blow do lines. 09:30 10:30 1:00 - - COMPZ RPCOti TRIP P Regain movement, coat RIH. Wash / rotate all stands do to 9065 ft. 10:30 12:00 1.50 COMPZ RPCOh CIRC P Reverse circ annulus volume. No returns. Attempt reverse /strip through bag. Pressures too high at 2800 psi. Will not fall through annular. Element smoking /high heat. Open annular, re for conv. circ. 12:00 19:00 7.00 COMPZ RPCOM1 TRIP P Resume wash /rot (up 1.00, dn45, rot 85, 8.5 bpm - 2500 psi) 90% returns. 9065 - 13000 ft. 19:00 00:00 5.00 COMPZ RPCOti CIRC P Attempt to reverse circ. w/ no retums. Recip & Circ. down DP at 8.5 bpm, 2600 psi, 50 rpm's. Up wt: 105K, Dwn wt: 45K, Rot wt 75K. Reverse / conventional circ equattime periods forbalance while add SafeLube to system, seeing 70% returns. 1708 bbls lost toda . 04/24/2008 00:00 15:30 15.50 13,000 0 COMPZ RPCOCV TRIP P POOH laying down 3-1/2 DP. LD 2-7/8 PAC. Fill with tri le dis lacement. 15:30 16:30 1.00 0 COMPZ RPCOti RURD P PJSM, clear floor,. RU for 4-1 /2 ESP com letion. Pull wear rin . 16:30 19:00 2.50 COMPZ RPCOti RURD P Arrange pipeshed, load jewelry and tubin 19:00 21:00 2.00 COMPZ RPCOti PULD P PJSM, RU ESP cable sheave,'string MLE over sheave to the rig floor. MU intake & 2'tstubin 21:00 23:30 2.50 COMPZ RPCOh SLKL P . PJSM, RU slickline, set pump, set:. packoff & test to 1500 psi for 15 min. RDMO slickline. _ _-,. L t~ri J~~ 4 of ~~ • • ~~ Time Logs _ - -- -- -- - Date _From_To Dur___5 De th E. Depth Phase Code Su6co_de_ __T COM_.__ 04/24/2008 23:30 00:00 0.50 COMPZ RPCOh PULD P PU A-Well discharge sub, attach to tubin ,stand back in derrick. 04/25/2008 00:00. 03;30 3.50 COMPZ RPCOti RCST P PU motor. Attach A-Well I-Pump ' sensor and 6" centralizer to bottom. Service motor.. Lower into hole. PU tandem seal section and attach to motor. Co. man witnessed free rotation of shaft and proper oil filling of motor and seal sections.' Attach MLE and connect capillary tube to A-Well sensor.. 03:30 04:30 1:00 COMPZ RPCOti RCST P PU perforated intakeand pump section and attach to seal section. Installed total of 3 protectolizers and 12 stainless steel bands on motor & seal section. Connect capillary tube to dischar a ressure sub. 04:30 06:00 1.50 COMPZ RPCO RCST P PU single jt of tbg, .install GLM #3 and begin running stands from derrick installing x-coupling clamps on the first 6 joints above the GLM and then on eve other'oint. - 06:00 08:00 2.00 COMPZ RIGMN OTHR T Repair damaged armour on ESP cable discovered at 650 ft. As yet undetermined source of damage. Possible dama a before delive to ri . 08:00 15:00 7.00 COMPZ RPCOti RCST P Resume RIH 4-1/2 ESP completion F/650' -- 5091'. Megger ESP cable every 1000 ft and record P/lJ and S/O wts. At 3068 ft: PU wt = 57K, S/O wt = 55K, at 5091 ft P/U wt = 75K, S/O wt = 52K. 35K blocks 15;00. 17:00 2.00 COMPZ RIGMN OTHR T Accidentally set slips set on ESP cable, crimped cable. Splice ESP cable. 17:00 22:30 5.50. COMPZ RPCOh RCST P Resume RIH 4-1/2 ESP completion F! 5091' - 8745'. Begin fill tbg !annulus at 1000 ft intervals. Incomplete fill through port P/U wt'= 93K, S/O wt = 45K. 35K blocks 22:30 00:00 1.50 COMPZ RPCOti RCST P RIH 4-1/2 ESP completion F/ 8745' -- 9300'. 04/26/2008 00:00. .00:45 0.75 COMPZ RPCOti RCST P Finish RIH w/ ESP completion. ESP final depth 9705 ft RKB. 154 coupling clamps, 14 stainless bands ran in well 00:45 02:30 1.75 COMPZ RPCO RCST P Clean rig floor, megger ESP cable--tested good. Tested A-Well au a--failed! -- rau SofS i • Time Logs _ _ _______ _ _ Datz From To Dur S De th E. De th Phase Code Subcode T COM __ 04/26/2008 02:30 03:30 1.00 COMPZ RPCO OTHR NP Discussed. w/ Weatherford, indicated the gauge tested good at previous test at 8800 ft in the hole. Could possibly be a problem in the last 900 ft, but unlikely since the ESP cable tested OK. He indicated that the test box seems to be ok and it is most likely the gauge. Contacted Eric Hollar & .Neil Spenceteyfor their preference on whether to pull the completion and replace the gauge. Both were in agreement that it is worth it to acquire the pressure data. Decision was made to ull com letion. 03:30 05:00 1.50 COMPZ RIGMN SVRG P Slip & Cut drill line. Weatherford called back indicating that the problem might be with their test box. They tested their test box on another well with the same results.. They are heading back to their shop to get a new transceiver 05:00 08:00 3.00 COMPZ RPCOti WOEQ T Take delivery new A-Well transceiver, re-test. Test successful. 08:00 14:30 6.50 ~ COMPZ RPC014 HOSO P MU tbg hgr/ landing jt. connect. penetrators, test upper hgr connections /elect terminals. Land h r, confirm ali nment, RILDs. 14:30 15:00 0.50 COMPZ RPCOh DHEQ P Testtbg hgr /all seals 5000 psi 15 min. Test successful. No re-tests. 15:00 16:30 1.50 COMPZ RPCOh RURD P LD Idg jt, flush BOPE, blow do lines. 16:30 21:30 5.00 COMPZ WELCT NUND P PJSM, ND BOPE. c/o lower pipe rams to 2-3/8" for next well, Inspect annular element, break capon annular. Annular element tore w/large rubber pieces missing while trying to reverse circulate and stri throw h annular. 21:30 00:00 2.50 COMPZ WELL- Test ESP cable, NU tree, test packoff 04/27/2008 00:00 02:00 2.00 COMPZ RPCOti SFEO P Replace tubing pressure port needle valve and broken presstre gauge. Fill tree w/diesel. Test tree to 5000 psi for10 min. RU lubricator and pull two wa check. 02:00 04:30 2.50 COMPZ RPCOh FRZP P PJSM, Freeze protect well w/ 35 bbls diesel down the tubing at 2 bpm 500 PSI and 190 bbls diesel down the IA at 5 bpm. Connect tbg /annulus, allow "U" tube. Press check well. "O"psi tb "X annulus. Install BPV. 04:30 08:00 3.50 COMPZ MOVE DMOB P Clean cellar, prep for rig move. Clean pits, RD, break do all components. Secure for move. NORDIC RIG 3 RELEASED THIS DATE 4/27/08 0800 HRS. ~_ rr,, , ~{,; • 1J-174 Pre and Post Rig Summary DATE SUMMARY 1/24/08 SET SLIPSTOP CATCHER.CHANGE SHEARED SOV WITH 2000# TBG SOV IN STA #1 @ 2209' RKB.PULL SLIPSTOP CATCHER. JOB COMPLETE. 3/19/08 Travel from slb camp to 1J-pad.miru coil unit.perform bop test.Return in AM to continue with FCO. 3/20/08 UNABLE TO REACH TOP OF SLIP STOP DUE TO COIL LIMIT LOCKUP.RETURN WITH ANOTHER UNIT WITH PIPE STRAIGHTENER OR A DIFFERENT SIZE COIL.JOB INCOMPLETE. 3/22/08 MADE ANOTHER ATTEMPT TO REACH SLIP STOP WITH COIL WHILE PUMPING DIESEL MIXED WITH LUBE VIS.WAS ABLE TO MAKE ANOTHER 1200' BEFORE REACHING LOCKUP ON COIL LIMIT @ 8025' CTMD.RDMO AND LET iCOIL UNIT PERFORM TUBING PUNCH. 3/23/08 SHOT 2' PERF INTERVAL IN TUBING AT DEEPEST POSSIBLE DEPTH OF 8633'- 8635' MD. GOOD INDICATION GUNS FIRED. HOWEVER UNABLE TO INJECT INTO FORMATION AFTERWARDS, POOH TO CHECK GUNS, ALL SHOT FIRED, WILL RERUN PERF GUNS WITH HEAVIER CHARGES IN AM. NOTIFIED DSO OF DEPARTURE. 3/24/08 SHOT 2' PERF INTERVAL IN 4.5" TUBING AT 8633'-8635' MD. GOOD INDICATION GUNS FIRED. ABLE TO INJECT THROUGH PERF'S @ .75 BPM @ 650 PSI. POOH. ALL SHOTS FIRED. NOTIFIED DSO OF WELL STATUS. JOB COMPLETE. 3/26/08 SET CATCHER SUB @ 2213' SLM. PULLED UNSHEARED DCK AND SET DV @ 2209' RKB. PULLED CATCHER. PERFORMED INJECTIVITY TEST DOWN TBG: 1.5 BPM @ 150 PSI. READY FOR BPV. 3/29/08 T POT (PASSED), T PPPOT (PASSED), IC POT (FAILED), IC PPPOT (FAILED), FUNCTION TEST LDS'S 4/30/08 SET 1" SOV (2000# TBG SHEAR) @ 2450' RKB, PULLED CATCHER @ 2498' WLM, COMPLETE. WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1J-174+L1+PB1+PB2 AK-MW-5275614 Apri129, 2008 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1J-174+L1+PB1+PB2 2" x 5" MD Resistivity & Gamma Ray Logs: 1 Color Log 50-029-23374-00,60,70,71 2" x 5" TVD Resistivity & Gamma Ray Logs: 1 Color Log 50-029-23374-00,60 Digital Log Images: 1 CD Rom 50-029-233 74-00,60,70,71 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: ~~- ~/3 ~~~~ ~ 0233 l La3Lf Signed: i~3s WELL LOG TRANSMITTAL To: State of Alaska Apri125, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`" Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data 1J-174 L1 AK-MW-527561 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23374-60 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 f~ .s ' , Date: tin~~r ~ sJ,yj ao~ ~yy i i ~ Signed: r~~ ~~~a~ 12-Feb-08 AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-174 L1 Dear Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 11,280.36' MD Window /Kickoff Survey: 11,366.00' MD (if applicable) Projected Survey: 19,750.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Alien 6900 Arctic Blvd. Anchorage, AK 99518 Date_ '7 ~"th. ~1C~~ Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~c~~-rug ConocoPhillips Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 a ~ k ~~' January 15, 2008 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 #~ g e ~ ,~;r~r d~ Elf ~.% r._.~.: ~.. ;.; ~~k Oil ~ ~ ~ ,~ 4 €~e;. ~~~ Subject: Well Completion Reports for 1J-174 and 1J-174L1 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations of the Kuparuk West Sak multi-lateral 1 J-174 1 J-174L1. If you have any questions regarding this matter, please contact me at 265-6830 or Dennis Hartwig at 265-6862. Sincerely, R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad ~G1 STATE OF ALASKA JAN 2 2 2Q~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPC~9~~ ~lf~ E~(9~mm~ss~on 1a. Well Status: Oil ^ . Gas Plugged ^ Abandoned ^ Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. WeILClass. Development Q Exploratory ^ Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: December 30, 2007 ~ 12. Permit to Drill Number: 207-144 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: December 19, 2007 ~ 13. API Number: 50-029-23374-60 4a. Location of Well (Governmental Section): Surface: 1724' FSL, 2471' FEL, Sec. 35, T11 N, R10E, UM 7. Date TD Reached: December 22, 2007 14. Well Name and Number: 1 J-174L1 Top of Productive Horizon: 1214' FSL, 79' FWL, Sec. 3, T10N, R10E, UM 8. KB (ft above MSL): 121.5' RKB Ground (ft MSL): 81' AMSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 1918' FNL, 196' FWL, Sec. 15, T10N, R10E, UM 9. Plug Back Depth (MD + TVD): 19688' MD / 3057' TVD West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558741 y- 5945537 Zone- 4 10. Total Depth (MD + TVD): 19750' MD ! 3055' TVD 18. Property Designation: ALK 25661, 25660, 25663, 385172 TPI: x- 550783 y- 5939689 Zone- 4 Total Depth: x- 550974 ' - 5931279E Zone- 4 11. SSSV Depth (MD + TVD): none 17. Land Use Permit: 471, 2177, 472, 2181 18. Directional Survey: Yes ^/ No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (TVD): approx. 1530' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): top of window @ i 1366 MD GR/RES ~,1, 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 34" 78.6# H-40 41' 120' 41' 120' 42" 338 sx AS 1 13.375" 68# L-80 41' 4014' 41' 2270' 16" 740 sx AS, 245 sx LiteCRETE 10.75" x 73.2# L-80 41' 3927' 41' 2249' 12.25" 853 sx LiteCRETE 9.625" 40# L-80 3928' 12081' 2250' 3205' 12.25" included above 4.5" 11.6# L-80 11355' 19689' 3127' 3056' 8.5" slotted liner 23. Open to production or injection? Yes ^ No ~ If Yes, list each 24. TUBING RECORD Interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET tubing in main wellbore na none alternating slotted liner from: 11355'-19689' MD slotted liner from 11485'-11686' MD and 11768'-12878' MD and 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12880'-19644' MD DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED na 28. PRODUCTION TEST Date First Production waiting on facility hook-up Method of Operation (Flowing, gas lift, etc.) shares production with 1J-174 Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No Q - Sidewall Cores Acquired? Yes No 0 If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. it)tArLE:TkO~.~ )7AT~ NONE l2. ' VAR IED -t; Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE ~,y(a,~ ~v'zz,°~ r 28. GEOLOGIC MARKERS (List all formations and ma encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes ^~ No If yes, list intervals and formations tested, Permafrost -Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1744' 1530' needed, and submit detailed test information per 20 AAC 25.071. T3 1932' 1638' K15 2683' 1924' Ugnu C 7232' 2658' Ugnu B 8690' 2821' Ugnu A 9140' 2870' K13 10253' 2989' West Sak D 11276' 3118' West Sak C 19750' 3055' West Sak B 19750' 3055' N/A Formation at total depth: West Sak D 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, slotted liner detail sheet 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Dennis Hartwig @ 265-6862 Printed Name Rand Thomas Title: Drilling Team Leader s , 1 ~l ~ ~~ ~~ l ---' ' I+one Z ~ s 6-~ ~~ Date Signature \ ~ ~ INSTRUCTIONS Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on alf types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhoie well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 ~- ! ;/-~~~~ KRU 1 J-174L1 ( Cc~nc~cc~Phillips Aias~, lnc, ' 1 J-174L1 APL 5002y2337460 Well T e: PRDD An le a) TS: de a) TueiNG SSSV Type: NONE Orig Angle @ TD: deg @ (asses, 'i OD:4.500, Com letion: tD:3ssa) Annular Fluid: Last W/O: Rev Reason: NEW WELL Reference Lo : 41' RKB Ref Lo Date: Last U date: 1!1/2008 Last Ta TD: 19689 ftKB Last Tart Date• Max Hole Angle: 0 deg r7 -- _ - - - Casing String. -ALL. STRINGS _ Descn lion Size To Bottom TVD Wt Grade Thread ', CONDUCTOR 20.000 0 120 120 94.00 H-40 WELDED SURFACE 13.375 0 4013 4013 68.00 L-80 BTC INTERMEDIATE 10.750 0 3927 3927 73.20 L-80 BTCM PUMP INTERMEDIATE 9.625 3927 12080 12080 40.00 L-80 BTCM (s52s-95x1, ', OD:3.800) D-SAND SLOTTED LINER 4.500 11355 19689 19689 11.60 L-80 TC/HYD 521 D-SAND WINDOW 9.625 11366 11367 11367 0.00 XO Screen ' (s55~-s5sa, _ Tubing String -TUBING -- - OD:5.130) ~ Size Top Bottom TVD Wt Grade Thread X1.500 ~ 0 ~ 9619 ~ 9619 ~ 126(J ~ L-80 ~ iBTM -- -- - --- ', SEAL Perforations Summary ' ~, (s5sa-ss~s, Interval ND Zone Status Ft SPF Date T Comment oDS.13o) __-- 11485 - 11686 11485 - 11686 201 32 12/27/2007 Slots Slotted liner, 2.5" x .125", 4 ~ circumferential rows/ft, 3" ! SEAL centers staggered 18 deg, (s5~s-9561, ~ non lotted ends 'i oD:5.130) 11768 - 12878 11768 - 12878 1110 32 12/27/2007 Slots Slotted liner, 2.5" x .125", 4 '~ circumferential rows/ft, 3" MOTOR "~+ ~ =r ` centers staggered 18 deg, (s5e1-ss15, oD:s.s2o) _ _ non-slotted ends -- 12880 - 19644 12880 - 19644 6764 32 12/27/2007 Slots Slotted liner, 2.5" x .125", 4 - circumferential rows/ft, 3" centers staggered 18 deg, non-slotted ends Gas Lift Mandre Is/Valve s _ St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv HANGER Cmnt :11355-11360, 1 2209 2209 CAMCO KBMG _ oDSS25> 'Other lu s e uip., etc.) -"COMPLETION: De th TVD T e Descri lion ID seat Bore ~ 36 36 HANGER ~ ~ VETCO GRAY TUBING HANGER 3.938 ~ : " 9474 9474 SUB ; UNIQUE DISCHARGE SUB 0.000 ~11360 366r oo:a.soo) 9529 9529 PUMP 4 1/2 (48.73' OAL) TTC ESP @ 95' SLM. SET4 1/2 D&D PACKOFF 0.000 ASSEMBLY (100" OAL-36" FROM F.N. TO KOBE-83" FROM F.N. TO CHECK 47' SLM. 4 1/2 SLIP STOP 40' SLM set 12/28!2007 9557 9557 XO Screen TTC CROSSOVER w/SCREEN INTAKE 0.000 9568 9568 SEAL UPPER TANDEM SEAL SECTION GSB3DB FER HL SSCV SB/SB PFSA 0.000 CL5 9575 9575 SEAL LOWER TANDEM SEAL SECTION GS63D6 FER HL SSCV SB/SB PFSA 0.000 CL5 9581 9581 MOTOR BAKER KMH 41$ HP MOTOR 0.000 9615 9615 GAUGE WEATHERFORD A-WELL GAUGE 0.000 9617 9617 Centralizer MOTOR CENTRALIZER 0.000 11355 11355 HANGER D-SAND LINER RAM HANGER ABOVE/BELOW COLLET 3.940 __ __ 11360 11360 SCI Bore D-SAND LINER SEAL BORE DIVERTER f/RAM HANGER TO BELOW 3.940 Diverter COLLET PROFILE 11392 11392 XO D-SAND LINER 6.625" x 4.5" PORTED CROSSOVER 4.500 11416 11416 NIP D-SAND LINER RAM CAMCO DB-6 NIPPLEw.3.562 NO GO PROFILE 3.562 TERMEDIATE (3sz~-1zo6o, - 11451 11451 SEAL -- - -- D-SAND LINER RAM BAKER SEALASSEMBLY 3.880 OD:9.625, 19667 19687 XO -- - -- D-SAND LINER CROSSOVER 4.5" TO 5.5" 4.500 wrao.oo> _ _ _ = General Notes _____ __ --; Date Note 2/28/200 NOTE: MULTI-LATERAL WELL 1J-174 B-SAND 1J-174L1 D-SAND Time Logs _ Date From To Dur 5. De th E. De th Phase Code Subco e T CUM _ 12/15/2007 05:45 06:15 0.50 19,652 19,652 COMPZ RPCO DHEQ P Pick up to verify release of liner . PU wt 220k (loss of 20k PU weight). Line up to pump down the kill line with the top pipe rams closed (3-1/2" x6"), to test the MLZXP packer f/ 5 minutes to 2500 psi. Chart the test. Lost 30 psi. Good test. Bleed pressure, open rams. Note: A pre job safety meeting was held for displacement f/ 8.8 ppg SFOBM w/ 1 % 776 tube to 8.4 ppg MOBM while testin the acker. 06:15 06:30 0.25 19,652 11,395 COMPZ RPCO TRIP P Pull and stand and set back, then pull 71' of next stand out of the hole. Circulatin sub ositioned 11365'. 06:30 08:45 2.25 11,395 11,395 COMPZ RPCO CIRC P Line up, then displace well f/ 8.8 ppg SFOBM w/ 1 % tube 776 to 8.4 ppg MOBM. Pumping 10.5 bpm (105 spm) w/ 1360 psi initial, 1260 final psi. 8.4 MOBM to surface after pumping 8000 strokes 803 bbls . 08:45 10:00 1.25 11,395 10,400 COMPZ RPCOh TRIP P POOH f/ 11365' - 10400' MD on Elevators; Hole Swabbing -Hole Took 30 Bbls to Fill vs. Calculated 12 Bbls for 15 Stands; P/U 220, S/O 0 10:00 11:15 1.25 10,400 9,500 COMPZ RPCOh TRIP P Pump Out-of-Hole f/ 10400' - 9500' MD; 197 GPM @ 360 PSI; P/U 200, S/O 0 11:15 18:00 6.75 9,500 11 COMPZ RPCOti TRIP P POOH on Elevators f/ 9500' - 11' MD; Monitor Hole On Trip Tank; Hole Took 101 Bbls to Fill Vs. 76 Calculated for Entire 95 Stand Trip. Record PU and SO wt's er Ri en leer. 18:00 19:30 1.50 11 0 COMPZ RPCOti PULD P UD MWD, Baker Liner Running Tools 19:30 20:00 0.50 0 0 COMPZ RPCOh OTHR P Clean & Clear Rig Floor; Clear BOT S ecific Tools 20:00 21:00 1.00 0 0 COMPZ WELC OTHR P Pull Wear Ring, Set Test Plug, P/U Test Joint, & R/U to Test BOPE. 21:00 00:00 3.00 0 0 COMPZ WELC BOPE P Test Annular Preventer w/ 4-1/2" test joint, Blind Rams, Upper Pipe Rams (3-1/2" x 6" variables) and Associated Valves to 250 (Low) - 3500 (High), hold each test f/ 5 minutes, chart test.; AOGCC Witness Waived by John Cris . 12/16/2007 00:00 00:15 0.25 0 0 COMPZ WELCT ROPE P Continue BOPE Test; Test of Koomey; Start = 3100 PSI, After closing. = 1500 PSI, 35 Seconds f/ 200 PSI Increase, 3 Minutes 3 Seconds = Full Charge (3100 PSI); 2400 PSI on 5 Bottle Average; Gas Alarms Tested Good 00:15 01:15 1.00 0 0 COMPZ WELC OTHR P Rig Down Test Equipment & Pull Test Plug; Lay Down Test Joint & Set Wear Rin ;Blow Down Kill & Choke Lines t Pa€~~ 24 ~f ~7 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM 12/16/2007 01:15 02:00 0.75 0 0 PROD2 DRILL PULD P Bring Baker Tools f/Outside to Rig Floor & Invento 02:00 02:15 0.25 0 0 PROD2 STK OTHR P PJSM for P/U and M/U Whipstock and Millin Ass . 02:15 03:45 1.50 0 0 PROD2 STK PULD P Make Up Lower and Upper Mills and Lay Down; P/U & M/U Whipstock Ass 03:45 06:00 2.25 0 0 PROD2 STK OTHR P Orient Whipstock face to MLZXP Anchor. Whipstock face is 10.82 degrees to the right of the anchor lug. This anchor will index into the MLZXP packer which was oriented to 26 deg left. (Tool circumference was 7.32", offset was 0.22"). P/U Milling Assy, and 1 Jt. HWDP and M/U to Whipstock Assy; P/U MWD and M/U to Mill & Whipstock Orient MWD to the whipstock face. MWD to whipstock offset was 100.26 deg. The whipstock was to the right of MWD by 100.27 deg. (Circumference. of tool was 6.75", offset was 1.88" 06:00 06:45 0.75 0 0 PROD2 STK OTHR P Upload MWD Software 06:45 07:30 0.75 0 251 PROD2 STK PULD P P/U Remainder of BHA #6 (which is the whi stock assembl 07:30 08:00 0.50 251 535 PROD2 STK TRIP P Trip in the hole 3 stands of 5" drill pipe 08:00 08:15 0.25 535 565 PROD2 STK CIRC P Make a top drive connection on stand #4, then shallow test MWD. Pumping 600 gpm w/ 1190 psi, OK. Blow down the to drive. 08:15 17:15 9.00 565 10,242 PROD2 STK TRIP P Trip in the hole w/the Baker whipstock, (BHA #6). PU 5" HWDP from the pipe shed/MU/RIH from 9831'. Note; Pipe stopped at 10-3/4" x 9-5/8" Crossover @ 3,928' and had to work thru same -also pipe stopped several times at different depths on the way in the hole to bottom working thru each one. 17:15 18:30 1.25 10,242 10,305 PROD2 STK OTHR P MAD pass f! 10242' to 10305' anchor depth, MWD Gamma depth"s 10109' to 10172'. Pumping 595 gpm w/ 2960 si. Runnin seed 3' fUmin 180'/hr . 18:30 19:30 1.00 10,305 11,394 PROD2 STK TRIP P Continue to trip in the hole w/ the Baker whipstock, (BHA #6). Picking up a total of 45 jts of 5"drill pipe from the i e shed. P~r~~ 25 €~f ~7 J I Time Logs _ Date From To Dur S De th E. De th Ph se Code Subcode T COM 12/17/2007 07:45 08:15 0.50 330 1,400 PROD2 STK TRIP T Continue trip in the hole w/ BHA #7 whi stock retrieval assembl 08:15 08:30 0.25 1,400 1,400 PROD2 STK CIRC T Fill pipe. Test MWD pumping 608 gpm w/ 1780 si. Blow down the to drive. 08:30 14:00 5.50 1,400 11,318 PROD2 STK TRIP T Continue trip in the hole w/ BHA #7 whi stock retrieval assembl 14:00 15:15 1.25 11,318 11,318 PROD2 STK OTHR T Make a top drive connection. Pumping 500 gpm w/ 2950 psi. Tagged up at the top of the whipstock (11366'), Pickup and rotate string a turn, slack off and engaged slot of whipstock 11372', set down 10k. Picked up 15k overpull to verify that the whipstock assembly anchor was in the collet profile of the MLZXP pacer f/the "B" lateral. Repeat pull test several times, same results. Observed MWD reading of 24 left of highside while hooking the whipstock (MLZXP is oriented 26 left of highside, whipstock is oriented 15 left of highside). Slacked off and released from whipstock, then picked up to 11318'. Pumps off : PU wt 220k, SO wt 135k. Pumps on: PU wt 205k, SO wt 130k. 15:15 15:30 0.25 11,318 11,318 PROD2 STK OWFF T Monitorwell-static. 15:30 15:45 0.25 11,318 11,040 PROD2 STK TRIP T Pull out of the hole. Hole taking proper dis lacement. 15:45 16:00 0.25 11,040 11,040 PROD2 STK OWFF T Monitor well- static. Pump a dry job. Blow down the to drive. 16:00 21:15 5.25 11,040 171 PROD2 STK TRIP T Pull out of the hole w/ BHA #7 whi stock retrieval hook . 21:15 21:30 0.25 171 171 PROD2 STK OWFF T Monitor well- static. Remove stripping rubbers. 21:30 22:00 0.50 171 90 PROD2 STK PULD T Lay down two joints of 5" HWDP, jars and bum er sub. 22:00 22:45 0.75 90 90 PROD2 STK OTHR T Download Sperry Sun MWD 22:45 23:30 0.75 90 0 PROD2 STK PULD T Continue to laydown BHA #7 (MWD, float sub, one joint of 5" HWDP, Baker retrieva hook . 23:30 23:45 0.25 0 0 PROD2 STK OTHR T Pre job safety meeting on PU/MU BHA #8. 23:45 00:00 0.25 0 66 PRODZ STK PULD T PU Baker mills, one joint of 5" HWDP, float sub and bum er sub. 12/18/2007 00:00 00:15 0.25 66 125 PROD2 STK PULD T Continue to PU/MU BHA #8: 2 jts of 5" HWDP 00:15 00:30 0.25 125 125 PROD2 STK OTHR P Function top set of pipe rams, bottom set of pipe rams, Annular, HCR kill line and HCR on the choke line. Blind rams were functioned when out of the hole. 00:30 07:15 6.75 125 11,366 PROD2 STK TRIP T RIH w/ BHA #8 (8-5/8" Milling assembly). Record PU and SO wt's every 10 stands. Fill pipe every 25 stands. F~age 2T €a~ 37 ~~ Time Lo s ! Date From To Dur 5 De th E. De th Phase Code Subcode T COM 12/18/2007 07:15 08:00 0.75 11,366 11,366 PROD2 STK MILL P Obtain Slow Pump Rates and Dry tag top of whipstock @ 11370' MD due to compression, PU 215k, SO 140k, Rotatin 178k. 08:00 12:00 4.00 11,366 11,383 PROD2 STK MILL P Mill window for D-lateral. 12:00 13:00 1.00 11,383 11,404 PROD2 STK CIRC P .Pump 40 bbl sweep then dri1121' of new hole. 13:00 14:45 1.75 11,404 11,404 PROD2 STK CIRC P Circulate and pump 40 bbl sweep. Slack off and dry tag bottom. No obstructions observed going in or out of window. 14:45 15:00 0.25 11,404 11,404 PROD2 STK OWFF P Monitor well -static. 15:00 19:45 4.75 11,404 174 PROD2 STK TRIP P POOH 5 stands. Hole took proper fill. Pump dry job, blow down top drive, continue POOH. 19:45 20:00 0.25 174 174 PROD2 STK OWFF P Monitor well -static. 20:00 21:00 1.00 174 0 PROD2 STK PULD P Lay down milling BHA. Gaged mills, window mill 8.50", lower string mill 8.375", u er strip mill 8.625" 21:00 21:45 0.75 0 0 PROD2 DRILL PULD P Clear and clean rig floor. 21:45 23:45 2.00 0 0 PROD2 DRILL CIRC P Pick up stack washer and flush stack, pumping 900 gpm, reciprocating from 15' to 70', rotating 30 rpm. Cycled HCR kill, choke, annular preventor, upper and lower pipe rams. Lay down stack washer. 23:45 00:00 0.25 0 0 PROD2 DRILL SFTY P PJSM -Changing saver sub 12/19/2007 00:00 01:15 125 0 0 PROD2 DRILL OTHR P .Change out saver sub. Clear and clean ri floor 01:15 01:30 0.25 0 0 PROD2 DRILL SFTY P PJSM -Pick up BHA #9 01:30 04:00 2.50 0 350 PROD2 DRILL PULD P Pick up BHA #9, bit, geo-pilot, MWD, TM HOC & float sub. Upload MWD. Pick up flex collars, jars, bumper sub and HWDP. 04:00 04:45 0.75 350 350 PROD2 DRILL PULD P Shallow pulse test MWD w/480 gpm, 950 psi, 30 rpm -test good. Blow down to drive. 04:45 10:30 5.75 350 11,315 PROD2 DRILL TRIP P TIH on elevators, Fill pipe every 25 stands. Record PU & SO every 10 stands. Monitor displacement via trip tank. Installed CCV Valve below top sin le on stand 85. 10:30 10:45 0.25 11,315 11,315 PROD2 DRILL CIRC P Record slow pump rates. Blow down to drive. 10:45 11:00 0.25 11,315 11,315 PROD2 DRILL SFTY P PJSM -Slip and Cut drilling line. 11:00 13:00 2.00 11,315 11,315 PROD2 DRILL OTHR P Slip an cut drilling line, service crown, to drive and blocks. P~as~~ 2~ of 37 Time Lois Date From To Dur S. De th E. De rth Phase Code Subcode T COM 12/19/2007 13:00 18:00 5.00 11,315 12,050 PROD2 DRILL DDRL P Drilling D-Lateral. Crossed fault @ 11774' MD with 5' throw to the south. Total 70' out of pay while building an le from window to D sands. 18:00 00:00 6.00 12,050 12,422 PROD2 DRILL DDRL P Drilling D-Lateral. Experienced trouble steering. Adjust flow rate, rpms and WOB. Geo-pilot reporting housing roll via Insite. 12/20/2007 00:00 06:00 6.00 12,422 12,740 PROD2 DRILL DDRL P Drilling D-Lateral. 06:00 12:00 6.00 12,740 13,978 PROD2 DRILL DDRL P Drilling D-Lateral. 12:00 12:45 0.75 13,978 13,978 PROD2 DRILL SFTY P Safety awareness meeting on the rig. Attended by CPAI Drilling Supervisor, CPAI Drilling Field Supervisor, CPAI Safety Rep, DDI Toolpusher, DDI Safety Rep, RLG, Sperry Sun, Little Red, MI, DDI Rig manager and all non-essential rig crew. Discussed recent COP incidients and discussed preventative measures taken in our o ration to achieve Tar et Zero oats. 12:45 18:00 5.25 13,978 14,929 PROD2 DRILL DDRL P Drilling D-Lateral. 18:00 00:00 6.00 14,929 15,786 PROD2 DRILL DDRL P Drilling D-Lateral. Safety awareness meeting in camp with night crew. Attended by CPAI Drilling Supervisor, CPAI Safety Rep, DDI Toolpusher, DDI Tourpusher, night rig crew and members of day crew that could not attend day meeting. Discussed recent COP incidients and discussed preventative measures taken in our o eration to achieve Tar et Zero oals. 12/21/2007 00:00 06:00 6.00 15,786 16,489 PROD2 DRILL DDRL P Drilling D-Lateral. Flow rate 621 gpm, SPP 4020 si, ECDs 11.82 06:00. 12:00 6.00 16,489 17,309 PROD2 DRILL DDRL P Drilling D-Lateral. Flow rate 610 gpm, SPP 4000 si, ECDs 11.85 12:00 18:00 6.00 17,309 18,166 PROD2 DRILL DDRL P Drilling D-Lateral. Flow rate 600 gpm, SPP 4050 si, ECDs 11.90 18:00 00:00 6.00 18,166 18,832 PROD2 DRILL DDRL P Drilling D-Lateral. Flow rate 600 gpm, SPP 4070 si, ECDs 11.95 12/22/2007 00:00 06:00 6.00 18,832 19,403 PROD2 DRILL DDRL P Drilling D-Lateral. Flow rate 580 gpm, SPP 3980 si, ECDs 11.99 06:00 09:30 3.50 19,403 19,750 PROD2 DRILL DDRL P Drilling D-Lateral to TD. Flow rate 570 m, SPP 4000 si, ECDs 12.16 09:30 11:15 1.75 19,750 19,750 PROD2 DRILL CIRC P Circulate 1.5 bottoms up @ 570 gpm, 3950 psi, 140 rpm, torque 22k, ECDs 12.15 ppge before beginning to circulate. 11:15 12:00 0.75 19,750 19,310 PROD2 DRILL REAM P Backream, pumping 570 gpm, 4030 si, 140 r m, for ue 20k. 12:00 18:00 6.00 19,310 15,884 PROD2 DRILL REAM P Backream, pulling 40-45 fpm, pumping 630 gpm, 3950 psi, 140 rpm, torque 18k. f~as~e 29 ca# 37 Time Logs D e From To Dur S. D th E. De th Ph Code Subcode T COM 12/24/2007 00:30 01:15 0.75 19,748 19,748 PROD2 DRILL CIRC P Drop ball to close circulation sub. Pump ball down at 3 bpm, 330 psi, rotating 50 rpm. Ball landed early. Pressure up to 1500 psi hold for 1 minute, pressure up to 2000 psi hold for 30 seconds, pressure up to 2500, sub closed at about 2300 psi: Established circulation thru bit. 01:15 04:00 2.75 19,748 19,748 PROD2 DRILL CIRC P Displace well over to 8.8 ppg, 79 vis SFOBM. Displaced at 500 gpm, 3210 psi, rotating 100 rpm (14100 strokes). Before displacement ECDs 11.78 ppge after 11.43 ppge. Pumps off rotating 40 rpm, PU 245k, rotating wt 140k. 04:00 04:15 0.25 19,748 19,748 PROD2 DRILL OWFF P Monitor well -static 04:15 10:30 6.25 19,748 11,312 PROD2 DRILL TRIP P Pull out of hole on elevators to window. Monitoring well via trip tank. Recording PU & SO every 10 stands. Lost 17 bbls more than calculated for tri . 10:30 12:30 2.00 11,312 11,312 PROD2 DRILL CIRC P Add tubes to system. Increase tubes in cased hole from 1 % to 3%. Pumped at 400 gpm, 1700 psi, rotating 120 rpm and reciprcating pipe 90'. Before tube: torque 17k, PU 228k, SO 90k, rotating wt 145k After tube: torque 10k, PU 180k, SO 115k, rotatin wt 140k 12:30 13:00 0.50 11,312 11,312 PROD2 DRILL OWFF P Monitor well -static. Blow down top drive. 13:00 14:30 1.50 11,312 8,421 PROD2 DRILL TRIP P Pull out of hole on elevators. Monitoring well via trip tank. Recording PU & SO eve 10 stands. 14:30 15:00 0.50 8,421 8,421 PROD2 DRILL PULD P Breakout and lay down circ sub. Retrieved 2 balls. 15:00 18:00 3.00 8,421 2,353 PROD2 DRILL TRIP P Pull out of hole on elevators. Monitoring well via trip tank. Recording PU & SO eve 10 stands. 18:00 20:15 2.25 .2,353 355 PROD2 DRILL TRIP P Drop mud dawg (drillpipe wiper), pull out of hole and lay down 21 stands of 'old' drillpipe. Monitoring well via trip tank. Lost total of 26 bbls on trip from td. 20:15 21:45 1.50 355 76 PROD2 DRILL PULD P Rack back 1 stand of HWDP and lay down 2 singles. Lay down jars, bumper sub, flex collars and float sub. Break off bit. 21:45 00:00 2.25 76 0 PROD2 DRILL PULD P Download MWD. Lay down MWD and eo- ilot. Clear and clean ri floor. 12/25/2007 00:00 00:30 0.50 0 0 COMPZ RIGMN SVRG P Service top drive, drawworks and iron rou hneck. 00:30 01:00 0.50 0 0 COMPZ DRILL SFTY P PJSM -Picking up BHA to rig floor. 6~ag~ 31 of 37 • Time Logs Date From To Dur S D th E. De th Phase Code Subcode T COM 12/25/2007 01:00 02:15 1.25 0 180 COMPZ DRILL PULD P Pick up and make up hook, 1 joint HWDP, string magnet, bumbper sub, jars, float sub, MWD and 2 joints of HWDP. 02:15 03:00 0.75 180 180 COMPZ DRILL PULD P Download MWD.. Monitoring well via tri tank -static 03:00 03:45 0.75 180 1,133 COMPZ DRILL TRIP P Run in hole on elevators and shallow test MWD. Seeing high standpipe ressure 03:45 04:30 0.75 1,133 1,133 COMPZ DRILL OTHR T Trouble shoot high standpipe pressure. Tested surface equipment. Rotated BHA and pressure dropped to normal 04:30 11:30 7.00 1,133 11,297 COMPZ DRILL TRIP P Continue RIH on elevators to 11,297', Fill pipe every 25 stands, Lost 6 bbls mud while RIH. 11:30 13:00 1.50 11,297 11,294 COMPZ DRILL CIRC P Break circ w/ 427 gpm @ 2430 psi Up 210K, Dn 130K, Orient Whipstock retrieving hook & hook @ 11,372" (On depth), Pull whipstock loose w/ 90K over ull, Pull u to 11,294'. 13:00 13:15 0.25 11,372 11,294 COMPZ DRILL CIRC P Attempt to circ btm's up- No good - loosin mud. Lost 7 bbls 13:15 13:30 0.25 11,294 11,294 COMPZ WELCT OWFF P Monitorwell-Static 13:30 20:00 6.50 11,294 119 COMPZ DRILL TRIP P POOH on elevators w/ whipstock f! 11,294' to 119', Lost 23 bbls over calculated f/displacement for entire trip out, Monitor well @ 6,588', 2,880, & 532' on wat out of hole. 20:00 20:30 0.50 119 119 COMPZ DRILL OTHR P Down load MWD. 20:30 21:45 1.25 119 61 COMPZ DRILL PULD P Lay down MWD, Float sub, Jars & Bumper sub, String magnet, 1 jt HWDP & Retrievin tool. 21:45 22:00 0.25 61 61 COMPZ DRILL OTHR P Pick up and check orientation of whi stock and Anchor- OK, 22:00 23:00 1.00 61 0 COMPZ DRILL PULD P Lay down Whipstock, Debris sub, Magnet, Blank sub, Unloader, Shear disconnect, Pu & Anchor. 23:00 00:00 1.00 0 COMPZ DRILL OTHR P Clean & Clear rig floor. Note; Lost 88 bbls mud for the da . 12/26/2007 00:00 00:45 0.75 COMPZ DRILL PULD P Pick up Boot baskets and Crossovers to rig floor, Rig GBR Casing tong E ui ment. 00:45 01:15 0.50 COMPZ CASINC SFTY P PJSM w/All Baker oil tools, GBR, ConocoPhillips, Doyon on picking up Diverter s tem. 01:15 02:30 1.25 104 COMPZ CASINC PUTB P Pick up & Make up Diverter as per detail, Orient Diverter to Anchor for 11 de . Ri ht of Hi hside. 02:30 03:45 1.25 104 155 COMPZ CASIN PUTB P Pick up & Make up MWD & Upload same. Pace 32 of 37 n ., Time Logs _ Date From To D r S De th E. D th Ph Code Subcode T COM 12/26/2007 03:45 04:15 0.50 155 155 COMPZ CASIN DHEQ P Surface test MWD & FJD Tool on Diverter to release, Had good detection on MWD at 265 gpm @ 580 psi, FJD Tool relesed at 410 gpm @ 1350 si. 04:15 04:30 0.25 155 220 COMPZ CASINC PUTB P Make up Float sub, 2 Boot baskets, Crossovers & 2 Strin Ma nets. 04:30 13:30 9.00 220 11,454 COMPZ CASINC RUNL P RIH w/ RAM Seal Bore Diverter at 90 ft/min to 11,398', Record Up & Dn wt's every 10 stands, Fill pipe every 25 stands, Lost 6 bbls while RIH. 13:30 14:00 0.50 11,454 11,454 COMPZ CASIN RUNL P Break circ, Circ at rate of 265 gpm @ 1140 psi, Tool face of 1 deg Left, Obtain wt's of Up 215K & Dn 110K, Set down w/ 20K & Latch Anchor w/ 11 deg Right of Highside toolface on depth w/Mule shoe @ 11,454', Top of Seal Bore Diverter @ 11,360' w/ Seal Assembly spaced out 10.25' inside Seal Bore Extention, Pull test Anchor w/ 70K over, Reiease from Diverter by staging rate at 25 gpm increments up to 475 m 3450 to release. 14:00 14:15 0.25 11,454 11,454 COMPZ WELCT OWFF P Monitor well -Static. 14:15 15:15 1.00 11,454 11,019 COMPZ DRILL TRIP P POOH to 11,019', Blow down top drive, Line u hole fill um . 15:15 17:45 2.50 11,019 11,019 COMPZ RIGMN SVRG P PJSM, Cut & Slip Drilling line, Adjust Brakes, Serive ri Lost 2 bbls mud 17:45 00:00 6.25 11,019 2,858 COMPZ DRILL TRIP P POOH w/ Diverter running tool f/ 11,019' to 2,858'. 12/27/2007 00:00 01:15 1.25 2,858 114 COMPZ DRILL TRIP P POOH w/ Diverter running tool f/ 2,858' to 114'. 01:15 02:15 1.00 114 57 COMPZ DRILL PULD P Clean & Lay down String Magnets, Boot baskets and Crossovers (Good amount of metal shavin son ma nets 02:15 02:45 0.50 57 57 COMPZ DRILL PULD P Down load MWD. 02:45 03:45 1.00 57 COMPZ DRILL PULD P Lay down MWD, Seal Bore Diverter runni tools. 03:45 04:30 0.75 COMPZ CASIN RURD P Rig to run 4-1/2" D-Lateral liner, PJSM with all involved personal for running liner. 04:30 12:00 7.50 8,291 COMPZ CASINC PUTB P Pick up & Run 4-1/2", 11.6#, L-80, Slot /Blank as per detail, Up 112K, Dn 90K, Lost 5.1 bbls over calculated. 12:00 13:30 1.50 8,291 8,343 COMPZ CASINC PUTB P Pick up RAM Hanger and Inner string as er Baker oil tools. 13:30 14:00 0.50 8,343 8,343 COMPZ CASINC RURD P Rig down GBR casing equipment, Clean & Clear ri floor. 14:00 14:45 0.75 8,343 8,441 COMPZ CASINC PUTB P Pick up Bumper sub, RIH to 8,441', Record Up 115K, Dn 95K, Rot 100K, Tq 3/4K, Break circ thru Hanger e ui ment. ~~ Pay 33 cif 37 • Time Logs __ Date From To Dur S De th E. De th Ph e Code Subcode T COM 12/27/2007 14:45 _ 22:00 7.25 8,441 19,531 COMPZ CASINC RUNL P RIH w/ 4-1/2", 11.6#, L-80 liner & RAM Hanger on 5"drill pipe & HWDP f/ 8,441' to 19,531', Record T & D every 10 stands, Fill pipe every 25 stands, Did not have to rotate pipe -Ran pipe on elevators the entire wa . 22:00 22:45 0.75 19,531 19,689 COMPZ CASIN OTHR P PU stand 119. 240k up, 90k down with no pumps. Rotating torque last movement up: 12k ft-Ibs @ 30rpm. Rotating torque last movement down: 13.5k ft-Ibs @ 30 rpm, 150k rotating weight down. PU stand 120. Set top drive top drive torque limit to 15.5k ft-Ibs. Pump 214 gpm @ 850 psi and RIH with stand 120 rotating 30 rpm. Turn pumps off 35' in on stand 120 (ported X-O at 11,366'). Land RAM hanger at 69' in (top of RAM hanger at 11,355', liner shoe at 19,689' rotating entire way. Set down 20k, turn top drive off. PU, see bumper sub open at 220k, snap RAM hanger out at 270k (50k overpull). Pull entire stand 120 out. Pump 209 gpm, rotate 30 rpm, RIH, turn pumps off 35' in, land RAM hanger 69' in on stand 120 (same depth as previous land point). turn top drive off, set down to block weight. PU, see bumper sub open at 220k, pull to 245k (25k overpull to confirm RAM han er is latched . 22:45 23:45 1.00 19,689 19,689 COMPZ CASIN CIRC P Drop Ball &Circ at rate of 5.0 bpm @ 840 psi f 1500 stks, Then slowed to 2.0 bpm @ 310 psi, Ball on seat w/ 1950 stks. 23:45 00:00 0.25 19,689 19,689 COMPZ CASINC OTHR P Pressure up to 3000 psi to release running tool, Pick up to 235K twice in attem t to release liner- No ood. 12/28/2007 00:00 00:15 0.25 19,689 11,355 COMPZ CASINC OTHR P Attempt to release from liner by appling 3000 psi on drill pipe and checking to see if running tool was free- No Good, Applied 3300 psi to release running tool and that finally released the runnin tool. 00:15 00:30 0.25 11,355 11,196 COMPZ DRILL TRIP P POOH f/ 11,355'to 11,196'. 00:30 02:00 1.50 11,196 11,196 COMPZ DRILL CIRC P Circ Btm's up at rate of 380 gpm @ 1400 si. 02:00 02:15 0.25 11,196 11,196 COMPZ WELC OWFF P Monitor well-OK. 02:15 12:00 9.75 11,196 720 COMPZ DRILL PULD P Pump dry job, Drop Mud Dog I.D. wiper, POOH & Lay down 5" Drill pipe f/ 11,196' to 720' 12:00 12:30 0.50 720 720 COMPZ WELC OWFF P Monitor well- Static. ~'a~ 3~# of 3~ ', Time Logs ~ Date From To Dur S De th E. De th Phase Code Subcode T COM 12/30/2007 23:45 00:00 0.25 COMPZ RPCO OTHR P Secure well, Release rig at 24:00 hours 12/30/07 E~~c~~ 37 of 37 ~ ! Halliburton Company Survey Report Compan}~: ConocoPhillipsAlaskalnc. Datr. 1/8/2008 fimr. 07'37'53 PaCc: ( I Field: Kuparuk River Unit Co -ordinate(~ti'E) Reference: Well: 1J-174. Tr ue North Site: Kuparuk 9J Pad Ve rtical (TS"D) Re [erencc 1J-174 Doyor+ 1 5 (81+40.5 121.5 SSeil: 1J-174 Sec tiun(S~S)ReCerence: Well (0.€70N,0.t)OE,180.OUAzi) S1cllpath: 1J-174L1 Su rve} Calculation Method: Minimum Curvature Dh: Orade Field: Kuparuk River Unit __ - North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 - -- Well: 1 J-174 Slot Name: 50-029-23374-00 Well Position: +N/-S -382.67 ft Northing: 5945536.61 ft Latitude: 70 15 42.494 N ~ +E/-W -52.13 ft Easting : 558740.81 ft Position Uncertainty: 0.00 ft Longitude: 149 31 30.524 W j J Wellpath 1J-174L1 Drilled From: 1J-174P61 50-029-23374-60 Tie-on Depth: 11280.36 ft Current Datum: 1J-174 Doyon 15 (81+40.5 Height 121.53 ft Above System Datum: Mean Sea Level Magnetic Data: 11/10/2007 Declination: 23.09 deg Field Strength: 57623 nT Mag Dip Angle: 80.80 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg _ 40.53 OAO 0.00 180.00 Survey Program for Definitive Wellpath Date: 12/22/2007 Validated: Yes Version: 3 Actual From To Survey Toolcode Tool Name ft ft 50.00 461.00 1J-174PB1 Gyro (50. 00-461.00) CB-MAG-SS Camera based mag single shot ~ 508.50 11280.36 1J-174PB1 IIFR+MS+SAG (508.50- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11366.00 19720.57 1J-174L1 IIFR+MS+SAG (11366.00 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC _~ Survey ~~ SID Incl A2im IVU S}s"CS~D i1!S 1:'!! Map.A- MapF: Tool ft deg deg ft ft ft ft ft ft 40.53 0.00 0.00 40.53 -81.00 0.00 0.00 5945536.61 558740.81 TIE LINE 50.00 0.35 249.08 50.00 -71.53 -0.01 -0.03 5945536.60 558740.78 CB-MAG-SS 120.00 0.16 226.19 120.00 -1.53 -0.15 -0.30 5945536.45 558740.51 CB-MAG-SS 151.00 0.36 237.75 151.00 29.47 -0.24 -0.41 5945536.37 558740.40 CB-MAG-SS ~ 200.00 0.54 232.25 200.00 78.47 -0.46 -0.72 5945536.14 558740.09 CB-MAG-SS 267.00 2.49 233.60 266.97 145.44 -1.52 -2.14 5945535.08 558738.68 CB-MAG-SS 363.00 5.64 238.24 362.72 241.19 -5.24 -7.84 5945531.31 558733.02 CB-MAG-SS 461.00 8.86 241.39 459.92 338.39 -11.39 -18.56 5945525.08 558722.34 CB-MAG-SS 508.50 9.91 236.81 506.79 385.26 -15.38 -25.19 5945521.04 558715.74 MWD+IFR-AK-CAZ-SC 603.64 12.54 237.41 600.10 478.57 -25.42 -40.75 5945510.87 558700.27 MWD+IFR-AK-CAZ-SC 698.58 15.45 240.50 692.21 570.68 -37.21 -60.44 5945498.94 558680.67 MWD+IFR-AK-CAZ-SC 793.54 20.77 241.94 782.43 660.90 -51.36 -86.33 5945484.58 558654.89 MWD+IFR-AK-CAZ-SC 888.73 23.82 244.33 870.50 748.97 -67.63 -118.55 5945468.06 558622.80 MWD+IFR-AK-CAZ-SC 984.34 25.36 248.14 957.44 835.91 -83.62 -154.96 5945451.79 558586.52 MWD+IFR-AK-CAZ-SC 1079.17 29.35 249.39 1041.65 920.12 -99.37 -195.58 5945435.72 558546.03 MWD+IFR-AK-CAZ-SC 1173.46 33.55 247.63 1122.07 1000.54 -117.43 -241.33 5945417.31 558500.43 MWD+IFR-AK-CAZ-SC 1269.34 37.55 246.00 1200.07 1078.54 -139.41 -292.54 5945394.94 558449.39 MWD+IFR-AK-CAZ-SC 1365.12 40.79 245.38 1274.31 1152.78 -164.32 -347.66 5945369.60 558394.48 MWD+IFR-AK-CAZ-SC 1460.41 44.98 245.72 1344.12 1222.59 -191.15 -406.68 5945342.31 558335.67 MWD+IFR-AK-CAZ-SC 1554.68 46.42 246.05 1409.96 1288.43 -218.71 -468.26 5945314.28 558274.31 MWD+IFR-AK-CAZ-SC 1650.38 49.77 248.34 1473.87 1352.34 -246.27 -533.92 5945286.20 558208.88 MWD+IFR-AK-CAZ-SC ~ 1745.78 50.88 252.31 1534.79 1413.26 -270.97 -603.04 5945260.97 558139.96 MWD+IFR-AK-CAZ-SC ~ 1840.83 53.83 249.73 1592.84 1471.31 -295.47 -674.18 5945235.92 558069.02 MWD+IFR-AK-CAZ-SC 1935.78 57.54 247.52 1646.37 1524.84 -324.08 -747.17 5945206.75 557996.26 MWD+IFR-AK-CAZ-SC 2030.49 61.49 246.70 1694.41 1572.88 -355.83 -822.34 5945174.41 557921.35 MWD+IFR-AK-CAZ-SC 2126.64 63.76 245.73 1738.61 1617.08 -390.27 -900.47 5945139.37 557843.50 MWD+IFR-AK-CAZ-SC 2221.15 67.60 243.97 1777.53 1656.00 -426.88 -978.40 5945102.15 557765.87 MWD+IFR-AK-CAZ-SC 2315.63 68.70 240.48 1812.70 1691.17 -467.74 -1055.96 5945060.69 557688.63 MWD+IFR-AK-CAZ-SC • • Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Dair: 1/8!2008 time 07:37:53 Page: 2 Field: Kuparuk River Unit ('o-ordinate(NE) Reference: WeEI: 1J-174, True North ~iYe: Kuparuk 1J Pad ~'crtical (C~~D) Reference: 1J-174 Doyon 15 (81+40.5 121-5 Weil: 1J-174 Section (~S)Reference: Well (O.OON.O OOE,180.OOAzi1 Wellpath: 1J-174L1 5wveyCalculation3lcthod: Minimum Curvature Ph: Oracle Snrvev MD Inc! Azim ft deg deg - _-- -- 2411.62 72.28 236.38 2506,31 73.30 235.14 2601,59 76.59 235.97 2697,20 73.97 237.05 2790.67 74.01 237.45 2887.71 75.26 235.59 2982.52 74.41 236.37 3078.08 73.83 236.55 3173.10 73.38 238.09 3268.00 75.00 238.53 3363.34 75.13 238.67 3457.80 75.82 237.20 3552.72 74.53 235.85 3647.22 74.65 234.87 3742.44 74.65 235.21 3838.09 73.86 236.32 3933.06 75.08 236.20 3991.88 76.27 235.69 4045.36 76.31 238.36 4139.95 77.68 236.46 4235.18 79.51 235.62 4330.39 82.14 236.29 4426.17 83..39 236.19 4521.76 83.60 237.36 4617.38 83.41 235.87 4713.17 84.16 234.27 4807.51 83.46 234.53 4900.98 83.66 234.56 4997.48 82.79 231.60 5093.72 83.96 231.68 5188.36 84.02 232.50 5283.81 83.60 234.19 5378.85 83.15 235.17 5474.38 82.47 235.14 5569.19 83.94 237.22 5664.47 83.41 237.61 5759.50 84.28 236.28 5854.45 83.85 235.00 5949.64 84.09 234.00 6045.24 83.97 234.05 6139.32 83.60 234.59 6235.65 84.21 235.57 6330.79 82.23 235.57 6425.78 83.10 236.55 6521.76 83.65 236.71 6616.55 83.48 234.74 6713.09 83.65 233.79 6807.21 83.72 233.77 6902.46 82.53 234.04 6995.90 84.19 235.29 7091.95 84.72 235.41 7188.14 84.16 235.62 T~ D ft 1844.77 1872.79 1897.53 1921.82 1947.60 1973.32 1998..12 2024.27 2051.09 2076.94 2101.52 2125.21 2149.49 2174.61 2199.81 2225.77 2251.20 2265.75 2278.43 2299.71 2318.54 2333.72 2345.79 2356.62 2367.43 2377.80 2387.98 2398.46 2409.85 2420.95 2430.86 2441.15 2452.12 2464.07 2475.29 2485.79 2495.98 2505.80 2515.80 2525.74 2535.92 2546.15 2557.38 2569.51 2580.58 2591.21 2602.03 2612.38 2623.78 2634.59 2643.87 2653.19 tit's "l'~'D ft 1723.24 1751.26 1776.00 1800.29 1826.07 1851.79 1876.59 1902.74 1929.56 1955.41 1979.99 2003.68 2027.96 2053.08 2078.28 2104.24 2129.67 2144.22 2156.90 2178.18 2197.01 2212.19 2224.26 2235.09 2245.90 2256.27 2266.45 2276.93 2288.32 2299.42 2309.33 2319.62 2330.59 2342.54 2353.76 2364.26 2374.45 2384.27 2394.27 2404.21 2414.39 2424.62 2435.85 2447.98 2459.05 2469.68 2480.50 2490.85 2502.25 2513.06 2522.34 2531.66 N/S ~ E/V1' ~1npti ft ft ft -515.12 -1133.00 5945012.71 -566.02 -1207.77 5944961.24 -618.05 -1283.64 5944908.63 -669.07 -1360.75 5944857.01 -717.67 -1436.31 5944807.82 -769.29 -1514.35 5944755.60 -820.49 -1590.19 5944703.82 -871.27 -1666.80 5944652.45 -920.49 -1743.53 5944602.63 -968.46 -1821.22 5944554.07 -1016.45 -1899.85 5944505.47 -1065.00 -1977.34 5944456.33 -1115.60 -2053.87 5944405.13 -1167.39 -2128.83 5944352.77 -1220.00 -2204.08 5944299.57 -1271.79 -2280.19 5944247.19 -1322.62 -2356.28 5944195.78 -1354.53 -2403.49 5944163.50 -1382.81 -2447.07 5944134.89 -1432.45 -2524.72 5944084.65 -1484.59 -2602.14 5944031.91 -1537.21 -2680.02 5943978.69 -1590.01 -2759.01 5943925.28 -1642.05 -2838.46 5943872.63 -1694.32 -2917.78 5943819.74 -1748.85 -2995.85 5943764.62 -1803.44 -3072.11 5943709.43 -1857.32 -3147.77 5943654.97 -1914.87 -3224.37 5943596.83 -1974.20 -3299.33 5943536.92 -2032.03 -3373.59 5943478.52 -2088.68 -3449.71 5943421.29 -2143.26 -3526.74 5943366.11 -2197.41 -3604.52 5943311.36 -2249.80 -3682.73 5943258.36 -2300.80 -3762.53 5943206.75 -2352.34 -3841.71 5943154.60 -2405.64 -3919.67 5943100.70 -2460.61 -3996.74 5943045.14 -2516.46 -4073.69 5942988.69 -2571.01 -4149.66 5942933.55 -2625.84 -4228.20 5942878.12 -2679.26 -4306.12 5942824.10 -2731.86 -4384.28 5942770.90 -2784.30 -4463.90 5942717.85 -2837.34 -4541.73 5942664.20 -2893.37 -4619.60 5942607.58 -2948.64 -4695.07 5942551.72 -3004.35 -4771.48 5942495.42 -3058.03 -4847.19 5942441.16 -3112.38 -4925.84 5942386.20 -3166.59 -5004.75 5942331.39 SiapF. "fool ft 557611.97 MWD+IFR-AK-CAZ-SC 557537.61 MWD+IFR-AK-CAZ-SC 557462.15 MWD+IFR-AK-CAZ-SC 557385.45 MWD+IFR-AK-CAZ-SC 557310.28 MWD+IFR-AK-CAZ-SC 557232.65 MWD+IFR-AK-CAZ-SC 557157.22 MWD+IFR-AK-CAZ-SC 557081.01 MWD+IFR-AK-CAZ-SC 557004.68 MWD+IFR-AK-CAZ-SC 556927.37 MWD+IFR-AK-CAZ-SC 556849.13 MWD+IFR-AK-CAZ-SC 556772.03 MWD+IFR-AK-CAZ-SC 556695.90 MWD+IFR-AK-CAZ-SC 556621.36 MWD+IFR-AK-CAZ-SC 556546.53 MWD+IFR-AK-CAZ-SC 556470.83 MWD+IFR-AK-CAZ-SC 556395.15 MWD+IFR-AK-CAZ-SC 556348.19 MWD+IFR-AK-CAZ-SC 556304.83 MWD+IFR-AK-CAZ-SC 556227.58 MWD+IFR-AK-CAZ-SC 556150.58 MWD+IFR-AK-CAZ-SC 556073.12 MWD+IFR-AK-CAZ-SC 555994.55 MWD+IFR-AK-CAZ-SC 555915.52 MWD+IFR-AK-CAZ-SC 555836.61 MWD+IFR-AK-CAZ-SC 555758.98 MWD+IFR-AK-CAZ-SC 555683.15 MWD+IFR-AK-CAZ-SC 555607.93 MWD+IFR-AK-CAZ-SC 555531.78 MWD+IFR-AK-CAZ-SC 555457.30 MWD+IFR-AK-CAZ-SC 555383.50 MWD+IFR-AK-CAZ-SC 555307.83 MWD+IFR-AK-CAZ-SC 555231.23 MWD+iFR-AK-CAZ-SC 555153.88 MWD+IFR-AK-CAZ-SC 555076.09 MWD+IFR-AK-CAZ-SC 554996.71 MWD+IFR-AK-CAZ-SC 554917.93 MWD+IFR-AK-CAZ-SC 554840.40 MWD+IFR-AK-CAZ-SC 554763.77 MWD+IFR-AK-CAZ-SC 554687.27 MWD+IFR-AK-CAZ-SC 554611.73 MWD+IFR-AK-CAZ-SC 554533.63 MWD+IFR-AK-CAZ-SC 554456.14 MWD+IFR-AK-CAZ-SC 554378.40 MWD+IFR-AK-CAZ-SC 554299.20 MWD+IFR-AK-CAZ-SC 554221.79 MWD+IFR-AK-CAZ-SC 554144.37 MWD+IFR-AK-CAZ-SC 554069.34 MWD+IFR-AK-CAZ-SC 553993.37 MWD+IFR-AK-CAZ-SC 553918.08 MWD+IFR-AK-CAZ-SC 553839.87 MWD+IFR-AK-CAZ-SC 553761.39 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Compan}': GenocoPhlllips Alaska Inc- Duty. i/8i2008 Circe- 07'37:53 f'a~c 3 FirJd: Kuparuk River Unlt Co-ordinatei~l':) Kcfcrcnec: Well. 1J-174. True North Site Kuparuk 1J Pad ~'crtiail (T~~t)1 Reference: 1J-174 Doyon 15 131+40-5 121-5 \~ell: 1J-174 Section IBS) Reference: Well (QOON,O.OOE,130.OOAzi) ~~ellpath: 1J-174L1 Smze}' Calculation Method: Minimum Curvature llb: Grade tin~,e~ _- VD Iuc! Azim T~'D Sc.T~'D \ S F./~~ MapN S1apF foul '~ ft deg deg ft ft ft ft ft ft 7282.65 84.03 234.69 2662.91 2541.38 -3220.30 -5081.90 5942277.08 553684.67 MWD+IFR-AK-CAZ-SC 7377.38 83.72 235.11 2673.02 2551.49 -3274.46 -5158.96 5942222.33 553608.04 MWD+IFR-AK-CAZ-SC i 7474.22 83.29 234.91 2683.97 2562.44 -3329.63 -5237.79 5942166.54 553529.66 MWD+IFR-AK-CAZ-SC 7568.31 83.66 235.30 2694.67 2573.14 -3383.11 -5314.46 5942112.47 553453.41 MWD+IFR-AK-CAZ-SC 7663.31 83.03 235.59 2705.68 2584.15 -3436.63 -5392.17 5942058.35 553376.12 MWD+IFR-AK-CAZ-SC 7758.72 82.98 235.02 2717.29 2595.76 -3490.53 -5470.04 5942003.85 553298.69 MWD+IFR-AK-CAZ-SC 7853.64 84.08 235.04 2727.99 2606.46 -3544.59 -5547.32 5941949.20 553221.84 MWD+IFR-AK-CAZ-SC ! 7949.85 82.91 236.40 2738.89 2617.36 -3598.43 -5626.30 5941894.75 553143.29 MWD+IFR-AK-CAZ-SC 8044.56 84.31 236.98 2749.43 2627.90 -3650.12 -5704.96 5941842.46 553065.04 MWD+IFR-AK-CAZ-SC 8138.61 83.72 236.02 2759.24 2637.71 -3701.74 -5782.96 5941790.23 552987.46 MWD+iFR-AK-CAZ-SC 8233.85 83.29 235.06 2770.01 2648.48 -3755.28 -5860.98 5941736.08 552909.86 MWD+IFR-AK-CAZ-SC 8329.71 83.16 235.44 2781.32 2659.79 -3809.54 -5939.19 5941681.22 552832.08 MWD+IFR-AK-CAZ-SC 8424.82 83.78 235.85 2792.14 2670.61 -3862.87 -6017.20 5941627.30 552754.50 MWD+IFR-AK-CAZ-SC 8520.36 83.71 237.93 2802.55 2681.02 -3914.74 -6096.75 5941574.81 552675.37 MWD+IFR-AK-CAZ-SC j 8614.62 83.72 234.38 2812.87 2691.34 -3966.92 -6174.55 5941522.03 552597.98 MWD+IFR-AK-CAZ-SC ~ 8710.45 83.35 233.25 2823.66 2702.13 -4023.13 -6251.41 5941465.23 552521.58 MWD+IFR-AK-CAZ-SC 8805.50 84.03 234.27 2834.11 2712.58 -4078.98 -6327.60 5941408.79 552445.83 MWD+IFR-AK-CAZ-SC 8900.16 83.84 236.35 2844.11 2722.58 -4132.55 -6405.00 5941354.62 552368.86 MWD+IFR-AK-CAZ-SC 8995.82 83.91 235.16 2854.32 2732.79 -4186.07 -6483.62 5941300.49 552290.66 MWD+IFR-AK-CAZ-SC 9091.24 83.78 235.28 2864.55 2743.02 -4240.19 -6561.54 5941245.78 552213.17 MWD+IFR-AK-CAZ-SC 9186.63 83.90 235.24 2874.78 2753.25 -4294.23 -6639.47 5941191.13 552135.67 MWD+IFR-AK-CAZ-SC 9282.10 83.71 235.75 2885.08 2763.55 -4348.00 -6717.69 5941136.76 552057.89 MWD+IFR-AK-CAZ-SC 9378.39 83.47 235.74 2895.83 2774.30 -4401.86 -6796.78 5941082.29 551979.23 MWD+IFR-AK-CAZ-SC 9472.74 84.03 236.79 2906.11 2784.58 -4453.95 -6874.77 5941029.60 551901.65 MWD+IFR-AK-CAZ-SC 9567.86 84.34 236.76 2915.74 2794.21 -4505.80 -6953.93 5940977.14 551822.90 MWD+IFR-AK-CAZ-SC 9662.57 83.90 235.98 2925.45 2803.92 -4557.97 -7032.38 5940924.36 551744.87 MWD+IFR-AK-CAZ-SC 9757.75 84.03 235.58 2935.45 2813.92 -4611.20 -7110.64 5940870.53 551667.03 MWD+IFR-AK-CAZ-SC 9853.10 84.22 235.58 2945.21 2823.68 -4664.82 -7188.89 5940816.31 551589.22 MWD+IFR-AK-CAZ-SC 9947.66 83.53 233.61 2955.30 2833.77 -4719.28 -7265.52 5940761.25 551513.02 MWD+IFR-AK-CAZ-SC 10042.24 84.09 230.48 2965.50 2843.97 -4777.11 -7339.65 5940702.86 551439.35 MWD+IFR-AK-CAZ-SC 10137.74 83.10 227.40 2976.16 2854.63 -4839.43 -7411.20 5940639.98 551368.30 MWD+IFR-AK-CAZ-SC 10233.35 83.84 225.88 2987.03 2865.50 -4904.65 -7480.26 5940574.23 551299.76 MWD+IFR-AK-CAZ-SC I 10328.54 82.41 221.91 2998.43 2876.90 -4972.73 -7545.77 5940505.65 551234.78 MWD+IFR-AK-CAZ-SC 10423.29 82.98 219.48 3010.48 2888.95 -5043.98 -7607.04 5940433.93 551174.07 MWD+IFR-AK-CAZ-SC 10519.50 83.65 216.63 3021.68 2900.15 -5119.22 -7665.94 5940358.24 551115.77 MWD+IFR-AK-CAZ-SC ~ 10614.03 83.10 212.55 3032.59 2911.06 -5196.50 -7719.23 5940280.55 551063.09 MWD+IFR-AK-CAZ-SC ~ 10709.41 82.91 211.17 3044.21 2922.68 -5276.91 -7769.20 5940199.77 551013.75 MWD+IFR-AK-CAZ-SC i 10804.51 82.73 211.25 3056.10 2934.57 -5357.61 -7818.10 5940118.70 550965.49 MWD+IFR-AK-CAZ-SC 10899.91 82.48 207.80 3068.38 2946.85 -5439.91 -7864.71 5940036.04 550919.53 MWD+IFR-AK-CAZ-SC 10994.66 82.41 205.41 3080.84 2959.31 -5523.89 -7906.77 5939951.75 550878.12 MWD+IFR-AK-CAZ-SC 11090.17 82.17 201.86 3093.66 2972.13 -5610.58 -7944.71 5939864.77 550840.87 MWD+IFR-AK-CAZ-SC 11185.27 82.66 198.79 3106.21 2984.68 -5698.97 -7977.45 5939776.14 550808.82 MWD+IFR-AK-CAZ-SC 11280.36 82.92 194.65 3118.15 2996.62 -5789.30 -8004.58 5939685.61 550782.40 MWD+IFR-AK-CAZ-SC 11366.00 83.14 191.77 3128.55 3007.02 -5872.05 -8024.01 5939602.72 550763.62 MWD+IFR-AK-CAZ-SC 11411.13 84.31 192.48 3133.48 3011.95 -5915.91 -8033.43 5939558.79 550754.54 MWD+IFR-AK-CAZ-SC 11472.28 84.19 193.44 3139.61 3018.08 -5975.20 -8047.07 5939499.40 550741.36 MWD+IFR-AK-CAZ-SC 11568.45 83.81 194.96 3149.66 3028.13 -6067.92 -8070.54 5939406.51 550718.63 MWD+IFR-AK-CAZ-SC 11655.75 85.57 196.33 3157.74 3036.21 -6151.61 -8093.98 5939322.64 550695.84 MWD+IFR-AK-CAZ-SC 11758.19 88.75 196.02 3162.81 3041.28 -6249.87 -8122.47 5939224.18 550668.11 MWD+IFR-AK-CAZ-SC 11853.32 91.12 196.13 3162.92 3041.39 -6341.27 -8148.81 5939132.58 550642.49 MWD+IFR-AK-CAZ-SC 11949.54 94.42 195.83 3158.27 3036.74 -6433.65 -8175.27 5939040.00 550616.76 MWD+IFR-AK-CAZ-SC ~ i 12044.20 92.90 193.19 3152.23 3030.70 -6525.09 -8198.93 5938948.39 550593.81 MWD+IFR-AK-CAZ-SC 12139.14 91.17 188.94 3148.85 3027.32 -6618.19 -8217.14 5938855.17 550576.34 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Compnn}~: ConocoPhillips Alaska Inc. llaiee: 1/%2008 Timer 07.37.53 Pair. -t Field: Ku paruk River Unit ('o-ordinate(NE} k c(crcncc: Weli: 1 J-174, T iue NoRh Site: Kuparuk1~lPad ~cRi cal(TVD)Rc fcrcncc: 1J-'174 Doyun 15{oi+40.5 121.5 11 ell: 1 J -174 Section (VS) Refer ence: Well (O OON,O. OOE,180.OOAzi) WellpaYlt: 1J -174L1 Sun c~~ Gilc ula[io n Method: Minimum Curvature nb: Oracfe Surrey MD Intl Azim f~ D Sys 1~~ D \/S F/!1 Mflp1~k Map F, fool ft deg deg ft ft ft ft ft ft 12234.40 91.16 187. 61 3146. 92 3025. 39 -6712 .43 _.. -- -8230 .84 5938760. 82 --- 550563.37 MWD+IFR-AK-CAZ-SC 12330.07 90.68 186. 06 3145. 38 3023. 85 -6807 .41 -8242. 23 5938665. 77 550552.72 MWD+IFR-AK-CAZ-SC I I 12425.33 90.06 184. 67 3144. 77 3023. 24 -6902 .25 -8251. 13 5938570. 88 550544.56 MWD+IFR-AK-CAZ-SC ' ~ 12520.73 93.18 184. 40 3142. 07 3020. 54 -6997 .30 -8258. 67 5938475. 78 550537.76 MWD+IFR-AK-CAZ-SC ~ I 12616.02 94.02 182. 05 3136. 09 3014. 56 -7092 .24 -8264. 02 5938380. 81 550533.15 MWD+IFR-AK-CAZ-SC 12710.37 94.26 178. 28 3129. 27 3007. 74 -7186 .33 -8264. 29 5938286. 73 550533.62 MWD+IFR-AK-CAZ-SC 12806.20 91.85 175. 07 3124. 16 3002. 63 -7281 .84 -8258. 74 5938191. 27 550539.91 MWD+IFR-AK-CAZ-SC 12901.36 90.86 172. 45 3121. 91 3000. 38 -7376 .40 -8248. 40 5938096. 80 550550.99 MWD+IFR-AK-CAZ-SC 12997.34 89.87 171. 48 3121. 30 2999. 77 -7471 .43 -8234 .99 5938001. 89 550565.14 MWD+IFR-AK-CAZ-SC 13091.22 90.06 170. 42 3121 .36 2999. 83 -7564 .14 -8220. 22 5937909. 30 550580.63 MWD+IFR-AK-CAZ-SC 13187.49 90.49 167. 73 3120. 90 2999. 37 -7658 .66 -8201. 98 5937814. 94 550599.61 MWD+IFR-AK-CAZ-SC 13281.47 90.12 167. 49 3120. 40 2998. 87 -7750 .45 -8181. 81 5937723. 32 550620.49 MWD+IFR-AK-CAZ-SC 13376.63 90.31 167. 73 3120. 04 2998. 51 -7843 .39 -8161. 40 5937630. 55 550641.63 MWD+IFR-AK-CAZ-SC 13471.99 90.25 167. 09 3119. 57 2998. 04 -7936 .46 -8140. 61 . 5937537. 66 550663.14 MWD+IFR-AK-CAZ-SC 13567.70 90.49 167. 60 3118. 96 2997. 43 -8029 .84 -8119. 64 5937444. 45 550684.83 MWD+IFR-AK-CAZ-SC 13663.89 89.57 169. 69 3118. 91 2997. 38 -8124 .14 -8100. 70 5937350. 31 550704.50 MWD+IFR-AK-CAZ-SC ~ , i 13758.55 90.60 174. 04 3118 .76 2997. 23 -8217 .82 -8087. 31 5937256. 74 550718.62 MWD+IFR-AK-CAZ-SC ~ 13854.59 91.30 176. 09 3117. 17 2995. 64 -8313 .49 -8079. 05 5937161. 15 550727.63 MWD+IFR-AK-CAZ-SC 13949.49 90.74 175. 80 3115. 48 2993. 95 -8408 .14 -8072. 34 5937066. 57 550735.07 MWD+IFR-AK-CAZ-SC I 14043.73 90.37 173. 51 3114. 57 2993. 04 -8501 .96 -8063. 57 5936972. 83 550744.58 MWD+IFR-AK-CAZ-SC ~~ 14139.19 90.68 174. 32 3113. 70 2992. 17 -8596 .87 -8053. 45 5936878. 01 550755.44 MWD+IFR-AK-CAZ-SC i 14233.56 90.31 173. 71 3112. 88 2991. 35 -8690 .72 -8043. 61 5936784. 24 550766.01 MWD+IFR-AK-CAZ-SC 14329.57 90.43 174. 62 3112 .26 2990. 73 -8786 .23 -8033. 85 5936688. 82 550776.51 MWD+IFR-AK-CAZ-SC 14425.49 90.49 175. 43 3111 .49 2989. 96 -8881 .79 -8025 .53 5936593. 34 550785.58 MWD+IFR-AK-CAZ-SC 14614.34 90.25 176. 71 3110. 27 2988. 74 -9070 .19 -8012. 59 5936405. 07 550799.99 MWD+IFR-AK-CAZ-SC 14709.96 89.87 175. 11 3110. 17 2988. 64 -9165 .56 -8005. 77 5936309. 76 550807.55 MWD+IFR-AK-CAZ-SC 14804.87 91.21 174. 10 3109. 28 2987. 75 -9260 .04 -7996. 84 5936215. 36 550817.21 MWD+IFR-AK-CAZ-SC 14900.01 90.18 174. 41 3108 .12 2986. 59 -9354 .70 -7987. 32 5936120. 80 550827.47 MWD+IFR-AK-CAZ-SC 14995.49 89.88 173. 50 3108 .07 2986. 54 -9449 .64 -7977. 27 5936025. 94 550838.26 MWD+IFR-AK-CAZ-SC j ~ 15091.34 90.49 174. 61 3107 .76 2986. 23 -9544 .98 -7967. 34 5935930. 70 550848.93 MWD+IFR-AK-CAZ-SC ~ 15185.47 89.69 172. 85 3107 .61 2986. 08 -9638 .54 -7957 .06 5935837. 23 550859.94 MWD+IFR-AK-CAZ-SC 15280.96 90.55 171. 68 3107. 41 2985. 88 -9733 .16 -7944. 21 5935742. 72 550873.53 MWD+IFR-AK-CAZ-SC 15375.74 90.18 172. 47 3106. 81 2985. 28 -9827 .03 -7931. 14 5935648. 96 550887.33 MWD+IFR-AK-CAZ-SC 15471.17 90.37 176. 10 3106. 35 2984. 82 -9921 .97 -7921. 64 5935554. 11 550897.57 MWD+IFR-AK-CAZ-SC 15566.14 90.31 175. 56 3105. 79 2984. 26 -10016 .68 -7914. 73 5935459. 46 550905.21 MWD+IFR-AK-CAZ-SC ~ 15661.87 90.25 175. 36 3105. 32 2983. 79 -10112 .11 -7907 .16 5935364. 10 550913.53 MWD+IFR-AK-CAZ-SC 15756.43 90.87 177. 37 3104 .40 2982. 87 -10206 .47 -7901. 16 5935269. 80 550920.26 MWD+IFR-AK-CAZ-SC 15851.14 91.11 179. 57 3102 .76 2981. 23 -10301 .13 -7898 .63 5935175. 17 550923.53 MWD+IFR-AK-CAZ-SC 15948.00 91.30 180. 33 3100. 72 2979. 19 -10397 .97 -7898. 55 5935078. 35 550924.37 MWD+IFR-AK-CAZ-SC 16042.52 90.80 181. 83 3098. 99 2977. 46 -10492 .45 -7900. 33 5934983. 86 550923.32 MWD+IFR-AK-CAZ-SC 16137.16 90.62 182. 27 3097. 82 2976. 29 -10587 .02 -7903. 71 5934889. 28 550920.68 MWD+IFR-AK-CAZ-SC 16231.52 89.75 181. 85 3097 .51 2975. 98 -10681 .32 -7907. 11 5934794. 97 550918.02 MWD+IFR-AK-CAZ-SC 16327.16 91.27 181. 78 3096 .66 2975. 13 -10776 .90 -7910. 13 5934699. 37 550915.74 MWD+IFR-AK-CAZ-SC 16423.10 90.55 182. 55 3095 .14 2973. 61 -10872 .76 -7913. 76 5934603. 49 550912.86 MWD+IFR-AK-CAZ-SC 16518.79 90.68 182. 58 3094 .11 2972. 58 -10968 .35 -7918 .04 5934507. 88 550909.33 MWD+IFR-AK-CAZ-SC 16613.76 90.49 181. 16 3093. 14 2971. 61 -11063 .26 -7921. 14 5934412. 96 550906.97 MWD+IFR-AK-CAZ-SC 16708.19 90.55 178. 61 3092. 28 2970. 75 -11157 .68 -7920. 95 5934318. 56 550907.89 MWD+IFR-AK-CAZ-SC 16803.96 90.12 176. 35 3091 .72 2970. 19 -11253 .35 -7916. 74 5934222. 93 550912.85 MWD+IFR-AK-CAZ-SC 16899.60 90.18 174. 99 3091 .47 2969. 94 -11348 .72 -7909. 52 5934127. 63 550920.81 i MWD+IFR-AK-CAZ-SC 16994.97 90.74 176. 30 3090 .71 2969. 18 -11443 .80 -7902. 28 5934032. 61 550928.80 MWD+IFR-AK-CAZ-SC 17088.86 90.43 178. 92 3089 .75 2968. 22 -11537 .60 -7898. 36 5933938. 86 550933.44 MWD+IFR-AK-CAZ-SC 17184.27 91.11 178. 48 3088 .47 2966. 94 -11632 .98 -7896. 20 5933843. 51 550936.35 MWD+IFR-AK-CAZ-SC • Halliburton Company Survey Report Companc: ConocoPhillips Alaska Ina Uatc 1B/2008 lime 07:37:53 Pat;c: Field: Kuparuk River Unit < o-ordin>~te(,V H.1 Reference: Well: 1 J-174, True North Sitr. Ku paruk iJ Pad ~~crti cal (T~~l)) Re ference: 1 J-1 %4 Doyon 1 5 (3i X40.5 121.5 ~~ell: 1J -174 ticcti un ~ ~S) Kefe rence: Weil (O.OON,O.O OE,180-OOAzi) \~cllpaLLh: 1.1 -174L1 Surveyl.'ale~dalio u 1]ethod: Minimum Curva ture Dh: Oracle tiu ncc ~~1T> Incl Azirn T~'D S}'s "f~'D Y/S E/~1` ~lapti ~tapl' lbul ft deg deg ft ft ft ft ft ft 17280.51 91.23 177.92 3086.50 2964.97 -11729.15 -7893.18 5933747.38 550940.12 MWD+IFR-AK-CAZ-SC 17374.87 89.63 178.08 3085.79 2964.26 -11823.44 -7889.88 5933653.12 550944.15 MWD+IFR-AK-CAZ-SC 17470.67 90.25 181.47 3085.89 2964.36 -11919.23 -7889.51 5933557.35 550945.27 MWD+IFR-AK-CAZ-SC 17564.69 91.28 182.46 3084.64 2963.11 -12013.18 -7892.73 5933463.38 550942.78 MWD+IFR-AK-CAZ-SC 17659.94 91.23 180.83 3082.55 2961.02 -12108.37 -7895.46 5933368.19 550940.79 MWD+IFR-AK-CAZ-SC 17755.46 90.31 178.60 3081.27 2959.74 -12203.87 -7894.99 5933272.70 550942.01 MWD+IFR-AK-CAZ-SC 17850.95 90.37 174.58 3080.70 2959.17 -12299.17 -7889.31 5933177.46 550948.43 MWD+IFR-AK-CAZ-SC 17946.72 90.00 176.03 3080.39 2958.86 -12394.62 -7881.47 5933082.09 550957.02 MWD+IFR-AK-CAZ-SC ~ 18041.20 89.75 178.54 3080.60 2959.07 -12488.98 -7877.00 5932987.77 550962.23 MWD+IFR-AK-CAZ-SC 18137.29 90.79 181.79 3080.15 2958.62 -12585.06 -7877.27 5932891.70 550962.70 MWD+IFR-AK-CAZ-SC 18231.59 90.99 180.54 3078.68 2957.15 -12679.32 -7879.19 5932797.43 550961.52 MWD+IFR-AK-CAZ-SC 18327.17 90.00 179.16 3077.86 2956.33 -12774.90 -7878.94 5932701.87 550962.51 MWD+IFR-AK-CAZ-SC 18420.39 90.80 178.99 3077.20 2955.67 -12868.10 -7877.43 5932608.69 550964.75 MWD+IFR-AK-CAZ-SC 18516.51 90.80 178.71 3075.86 2954.33 -12964.19 -7875.51 5932512.63 550967.42 MWD+IFR-AK-CAZ-SC 18611.43 90.55 177.80 3074.74 2953.21 -13059.06 -7872.62 5932417.79 550971.05 MWD+IFR-AK-CAZ-SC 18707.07 90.06 177.20 3074.24 2952.71 -13154.61 -7868.44 5932322.29 550975.97 MWD+IFR-AK-CAZ-SC 18802.23 89.63 178.90 3074.49 2952.96 -13249.71 -7865.21 5932227.23 550979.95 MWD+IFR-AK-CAZ-SC 18898.12 90.06 178.56 3074.75 2953.22 -13345.57 -7863.08 5932131.39 550982.82 MWD+IFR-AK-CAZ-SC 18993.58 90.56 179.27 3074.24 2952.71 -13441.01 -7861.27 5932035.98 550985.37 MWD+IFR-AK-CAZ-SC 19087.76 91.17 183.03 3072.81 2951.28 -13535.15 -7863.16 5931941.84 550984.22 MWD+IFR-AK-CAZ-SC 19181.77 91.05 182.35 3070.99 2949.46 -13629.04 -7867.57 5931847.93 550980.54 MWD+IFR-AK-CAZ-SC 19277.67 88.95 180.72 3070.99 2949.46 -13724.89 -7870.14 5931752.07 550978.72 MWD+IFR-AK-CAZ-SC 19372.99 91.42 183.36 3070.68 2949.15 -13820.14 -7873.53 5931656.81 550976.07 MWD+IFR-AK-CAZ-SC 19466.92 93.29 182.36 3066.82 2945.29 -13913.86 -7878.22 5931563.05 550972.12 MWD+IFR-AK-CAZ-SC 19561.25 92.16 181.00 3062.34 2940.81 -14008.04 -7880.98 5931468.87 550970.09 MWD+IFR-AK-CAZ-SC 19658.56 92.96 179.09 3057.99 2936.46 -14105.25 -7881.06 5931371.67 550970.77 MWD+IFR-AK-CAZ-SC ~~ i 19720.57 91.48 177.42 3055.59 2934.06 -14167.18 -7879.17 5931309.76 550973.14 MWD+IFR-AK-CAZ-SC 19750.00 91.48 177.42 3054.83 2933.30 -14196.57 -7877.84 5931280.39 550974.70. PROJECTED to TD t~ ' `° Slotted and Blank Liner Detail weu: 1J-174 Cono~a P . ~~l . l~ ps 4-1/2", 11.6 ppf,L~O, BTC and Hyd 521 ,Slot and Blank "D" lat liner Date: 12/27/2007 Alaska;[ric; Rig: Doyon 15 Depth Jt Number Num of Jts Well Equi .ent Description and Comments ~. Page 1 Length Tops 5" DP to Surface =_> 11338.69 Baker Lubricated Bum er Sub Does not sta in hole 9.04 11338.69 Liner Runnin Tool 5" Does not sta in hole 7.67 11347.73 RAM Hanger, above Collet 7.59 11355.40 RAM Hanger, 6.625", 20 f, Hydril 521 Below Collet Pin down 29.1s 11362.99 Cross over -Ported 6-5/8", 20 f, Hydril 521 x 4-1/2" H dril 521 3.92 11392.18 Pu Jt. 4-1/2", 1.2.6#, L-80, H dril 521 3.67 11396.10 Jts 194 to 195 2 Jts 4-1/2", 11.6 f, L-80, H dril 521 Blank Casin s5.5s 11399.77 Jts 189 to 193 5 Jts 4-1/2", 11.6 f, L-80, H dril 521, Slotted Casing 200.23 11485.33 Jts 187 to 1ss 2 Jts 4-1/2", 11.6 f, L-80, Hydril 521 Blank Casin s2.s2 11685.56 Jts 160 to 186 27 Jts 4-1/2", 11.6 f, L-80, H dril 521, Slotted Casing 111o.os 117ss.18 Cross over- 4-1/2", 12.6 f, Hydril 521 box x 4-1/2" BTC in 1.65 12878.2s Jts 80 to 159 80 Jts 4-1/2", 11.6 f, L-80 BTC, Slotted Casing w/ for ue rin s 3394.27 12879.91 Jts 1 to 79 79 Jts 4-1/2", 11.6. f, L-80, BTC Slotted Casing 3369.45 16274.18 4-1/2", 11.6 f, L-80, BTC Blank Casing 43.35 19643.63 X-O, 4-1/2", 12.6 f L-80, BTC Box x 5-1/2", 15.5 f, L-80, BTC Pin 1.39 19686.98 5-1/2" BTC Baker Guide Shoe 1.10 19688.37 Bttm of Shoe =_> 19689.47 19689.47 The To of the Baker Seal Bore Diverter is 11,360.09' 19689.47 Ram Han er will Collet into the collet rofile inside of the Seal Bore Diverter 19689~4~~ The Collet rofile is 2.90' down from the to of the Seal bore diverker 19689.47 The Collet de th will be 11;362.99' 19689.47 Seal Bore Diverter "window"--Oriented to 11 De Right of high side. 19689.47 To of'B' liner MLZXP Oriented to 26 De Left of high side. 19689.47 TD 8-1/2" hole 19,750' MD / 3,054' TVD, 91.48 deg. 19689.47 5-1/2" Shoe 19,689' MD / 3,056' TVD , 92.16 de 19689.47 60.53' Rat Hole 19689.47 Run 1 H dro-Form 4-1/2" x 6.13" PN 80590 er joint =Total of 193 19689.47 On jtS # 1 thru # 193 19689.47 Milled TOW 11,366' MD 3,128' TVD , 83.14 deg 19sss.47 Milled BOW 11,383' MD 3,130' TVD , 83.58 deg 19689.47 19689.47 19689.47 Slots are: 2.5" x 1/8" , 8 slots per row, 4 rows/ft, 3 ft stand off each end. 19689.47 Remarks: Ran tot al of 195 jts Csg + shoe jt = 8,285.56', 191 jts Slotted= 8,074.03', 4 jts Inc S hoe Blank, Blank= 214.02', Ran Total of 195 Hydro-Forms on jt #1 thru 195. up Wt 240K Used Run-N-Seal thread com ound on all connections. Dn Wt 9oK Tor ue: BTC to 2600, BTC w/ for rin 5000, H d 521 to 4300, 6-5/8"Hyd 521 to 6600 ft Ib: Block Wt 7oK Tor ue Rings in joints 80 thru 159 = 80 for ue rings. Drifted liner w/ 3.875" teflon rabbit. Rot wt 178K Su ervisors: Mike Thornton / Dennis Hartwig Rot torque 13,000 ft/Ib ~~Q~C~ 0~ G~~~G':N~! S%! ALASSA OIL A11TD G~,S C011TSER~A7`IO1Q COMI-IISSIOIQ Randy Thomas Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 SARAH PALIN, GOVERNOR 333 W. 7thAVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, West Sak Oil Pool, 1J-174L1 ConocoPhillips Alaska, Inc. Permit No: 207-144 Surface Location: 1724' FSL, 2471' FEL, SEC. 35, T11N, R10E, UM Bottomhole Location: 1916' FNL, 198' FWL, SEC. 15, T10N, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well KRU 1J-174, Permit No 207-143, API 50-029-23374-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commissia~'s petroleum field inspector at (907) 659-3607 (pager). ~" DATED this 7! I day of October, 2007 cc: Department of Fish 8a Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Conoco~hillips ~ Alaska Post OfFce Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907)265-6830 Email: Randy.L.Thomas@conocophillips.com October 16, 2007 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 ~~~® `~~~ F ~ ~ 2007 y; +,.: t ;~ ~~S 3;~7A~» Coin r-rUS5i0q Anchorage Re: Applications for Permit to Drill, West Sak Producer, 1J-174 and 1J-174 L1 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore producer well, a horizontal well in the West Sak ~~B"and °D" sands. The main bore of the well will be designated 1J-174, and the lateral bore of the well will be designated iJ-174L1. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for each of these well bores. The expected spud date of iJ-174 is November 7, 2007. If you have any questions or require any further information, please contact Dennis Hartwig at 265-6862. Sincerely, ...,,.. 5 `- _. 1 Randy Thomas Greater Kuparuk Area Drilling Team Leader STATE OF ALASKA ~ ~ ALASKA OIL AND GAS CONSERVATION COMMISSION (a~, ~~I~D PERMIT TO DRILL ~kask;z p;! & Gas Cons. Canmission 20 AAC 25.005 Anchorage 1 a. Type of Work: 1 b. Current Well Class: Exploratory ^ Development Oil ^ 1c. Specify if well is proposed for: Drill ^/ Re-drill ^ Stratigraphic Test ^ Service ^ Development Gas ^ Coalbed Methane ^ Gas Hydrates ^ Re-entry ^ Multiple Zone^ Single Zone ~ Shale Gas ^ 2. Operator Name: 5. Bond: / Blanket Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 1J-174L1 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 19691' ' TVD: 3079' ' Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property DesignZa ' n: p.s3,e`7 38 l72 Surface: 1724' FSL 2471' FEL Sec T11 N R10E UM 35 • ADL 25661 25663 ~ West Sak Oil Pool ' , , . , , , , , .m Top of Productive Horizon: 8. Land Use Permit: /°' 13. Approximate Spud Date: 1148' FSL, 90' FWL, Sec. 3, T10N, R10E, UM f ALK 471, 2177, 472, 2181 11/21/2007 - Total Depth: 9. Acres in Property: 14. Distance to 1916' FNL, 198' FWL, Sec. 15, T10N, R10E, UM " 2560 Nearest Property: < 1 mile 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest 1J-162L2 Surface: x- 558741 ~ y- 5945537 ' Zone- 4 (Height above GL): 121' AMSL feet Well within Pool: , 268' @ 11339' MD 16. Deviated wells: Kickoff depth: 11339' ' ft. 17. Maximum Anticipated Pressures in psig (see zo AAC 25.035) Maximum Hole Angle: g1 ° deg Downhole: 1379 psig ° Surface: 1034 psig 18. Casing Program if ti S Setting Depth Quantity of Cement Si pec ica ons B ttom T f k ze op o c. . or sac s Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 40" 20"x 34" 94# K-55 Welded 80' 40' 40' 121' 121' 260 cf ArcticCRETE 16" 13-3/8" 68# L-80 BTC 4000' 40' 40' 4000' 2265' 740 sx AS Lite, 230 sx DeepCRETE 12.25" 10.75" 73.2# L-80 BTCM 4000' 40' 40' 4000' 2265' 410 sx DeepCRETE, 430 sx DeepCR. 12.25" 9-5/8" 40# L-80 BTCM 8000' 4000' 2265' 12000' 3192' see above 8.5" 4.5" 11.6# L-80 Hydril 521 8353' 11339' 3120' 19692'- 3079' - slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ^ BOP Sketch Drilling Program / Time v. Depth Plot Shallow Hazard Analysis / Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dennis Hartwig @ 265-6862 Printed Name Randy Thomas Title Drilling Team Leader -~_..., Signature ~ ''~ ,_ ~ ~~~;:~,,._,....,..,~,~ Phone "Z ~ ~ ~.~ i~ S ~, Date 1 ~ ~' ((~ ~V ~~ ,,,~ ~~ a n Drak Commission Use Only Permit to Drill ~~ API Number: ~ Permit Approval See cover letter Number: Z~7- ~ 50- ~79- Z~7 ~U Date: • ~g . D~ for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce Coalbed m thane, gas hydrates, or gas contained in shales: Samples req'd: Yes ^ No ~ ud log req'd: Yes ^ No [~. Other:3pQ~~~ 30~~~ H2S measures: Yes [] No ~ e I nal svy req'd: Yes [a' No ^ ~!D~~ ~O ~ PROVED BY THE COMMISSION f DATE: ,COMMISSIONER Form 10-401 Revised 12/2005 ~~3 Submit m Duplicate ~,- io.2~•07 Ap~n for Permit to Drill, Well 1J-174 L1 Revision No.O Saved: 16-Oct-07 Permit It -West Sak Well #1J-174 L1 App/ication for Permit to Drill Document M p x i m i x p Well ValuE Table of Contents 1. iNell Name .................................................................................................................. 2 Requirements of 20 AAC 25.005 (fl -•-•--.....-•-•--•-••--• ....................................................•--•----................... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ..................................................•-•--................................................ 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) ..............................................•-•--•--............................................ 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casing and Cementing Program ............................................................................ 3 Requirements of 20 AAC 25.005(c)(6)-••-•--••---•--•-•-•• ..............................................•-•--........................... 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(~) ..............•-•---..................................:......-•-•--•-•--........................... 4 8. Drilling Fluid Program ............................................................................................. 4 Requirements of 20 AAC 25.005(c)(8) ...............................................•-•-•--.....................................-•----.. 4 Lateral Mud Program (MI VersaPro Mineral Oil Base) ........................................................................... 4 9. Abnormally Pressured Formation Information ..................................................... 4 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 4 10. Seismic Analysis ..................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ..........................................:..............:...................................... 5 11. Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12. Evidence of Bonding ............................................................................................... 5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 5 1J-174 L1 PERMIT IT Page 1 of 6 ~"'~ (°~ ~ ~ ~ Printed: 16-Oct-07 App~n for Permit to Drill, Well 1J-174 L1 Revision No.O Saved: 16-Oct-07 13. Proposed Drilling Program ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 6 Requirements of 20 AAC 25.005 (c)(14) .............~--~~---........................................................................... 6 15. Attachments ............................................................................................................. 6 Attachment 1 Directional Plan ......................................~----~--.................................................................. 6 Attachment 2 Drilling Hazards Summary ...............................................:............................................... 6 Attachment 3 Well Schematic ................................................................................................................ 6 1. Well Name Requirements of 20 AAC 25.005 (1) Each we/I must be identified by a unique name designated by the operator and a unique API number assigned by the commission under Z0 AAC 25.040(6). For a wel! with multip/e we!/branches, each branch must Simi/arly be identified by a unique name and API number by adding a suffix to the name designated for the we// by the operator and to the number assigned to the wef/ by the commission. The well for which this Application is submitted will be designated as iJ-174 L1. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An app/ication for a Permit to Dril/must be accompanied try each of the fol/owing items, except for an item already on file with the commission and r"dentified in the application: (2) a p/at identifying the property and the property's owners and showing (A)che coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmenta/section lines (B) the coordinates of the proposed location of the wel/ at the surface, referenced to the state p/one coordinate system for this state as maintauted by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the wel/ at the top of each objective formation and at total depth; Location at Surface 1,724' FSL, 2,471' FEL, Section 35, T11N, R10E ASPZone 4 NAD 27 Coordinates RKB Elevation 121.0' AMSL Northings.• 5,945,537 Eastings; 558,741 Pad Elevation 81.0' AMSL Location at Top of Productive Interval West Sak "D" Sand 1,148' FSL, 90' FWL, Section 3, T10N, R10E - ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 11 339' Northings: 5,939,623 Eastings; 550,795 Tota/ ~ertica/De th RKB; 3,120' Tota/ vertical De th, SS.• 2,999' Location at Total De th 1,916' FNL, 198' FWL, Section 15, T10N, R10E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB,' 19,691' Northings: 5,931,280 Eastings; 550,977 Tota/ t/ertica/De th, RKB; 3,079' Total ~ertica/ De th, SS.• 2,958' and (D) other information required by 20 AAC 25.050(b); ~ y ~ ~ ~ ~ 1J-174 L1 PERMIT IT ~ ~ e ~ : ~ Page 2 of 6 ` ~ a ~ -r . , , Printed: 16-Oct-07 ApK~on for Permit to Drill, Well 1J-174 L1 Revision No.O Saved: 16-Oct-07 Requirements of 20 AAC 25.050(b) If a well is to be intentional/y deviated, the application for a Permit to DriO (Farm i0-401) must (I) me/ude a p/at, drawn to a suitab/e sca/e, showing the path of the proposed wellbore, including all adjacent we/!bores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan 1J-160L1 and (2) for al! wel/s within 200 feet of the proposed we//bore (A) /ist the names of the operators of those we//s, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the applicatioon by certr`fred mail; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Cori/! must be accompanied by each of the fol/owing items, except for an item a/ready on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPS) as required by 20 AAC25.035, 20 AAC 25.036, ar 20 AAC 25.037, as app/icab/e; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1J-174 L1. Please see information on Doyon 15 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An app/ication for a Permit to Dri/! must be accompanied by each of the fo/%wing items, except for an r"tem already on file with the commission and identified in the application: (4) information on dri//ing hazards, inc/udmg (A) the maximum downhole pressure that maybe encountered, criteria used to determine it, and maximum potential surface pressure based an a methane gradient; f The expected reservoir pressures in the West Sak sands in the 1J area are 0.44 psi/ft, or 8.4 ppg EMW (equivalent mud weight). Pressures are predicted based on the undisturbed West Sak pressure gradient. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak °D" sand formation is 1,034 psi, calculated thusly: MPSP = (3,133 ft TVD)(0.44 - 0.11 psi/ft) = 1,034 psi (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potentia/ causes of ho/e prob/ems such as abnormal/y geo pressured strata, /ost circulation zones, and zones that have a propensity for differentia! sticking; Please see Attachment 2: iJ-174 Ll Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An app/ication for a Permit to Dril/must be accompanied by each of the fo/lowing items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC25.030(fJ; The parent wellbore, 1J-174, will be completed with a 10-3/4" x 9-5/8" tapered intermediate casing landed in the West Sak B-Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the °Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. No formation integrity test will be performed in the drilling of the 1J-174 L1. 1J-174 L1 PERMIT IT Page 3 of 6 /'ti ~ ~ ~ ~ ~ ~ ~ ~ Printed: 16-Oct-07 App~n for Permit to Drill, Well 1J-174 L1 Revision No.O Saved: 16-Oct-07 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the fo/%wing items, except for an item already on file with the commission and identified m the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre- perforated /finer, or screen to be insta/led; Casing and Cementing Program See also Attachment 3: Cement Summa Hole Top Btm Csg/Tbg Size Weigh Length MD/TVD MD/TVD OD in in t Ib/ft Grade Connection ft ft ft Cement Pro ram 4-1/2 81/2" D Sand 11.6 L-80 BTC 8,353 11,339 / 19,692 / 3,079 Slotted- no cement slotted Lateral (1J-176 Ll) 3 120 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An app/ication for a Permit to Drilf must be accompanied by each of the fo/%wing items, except for an item already on file with the commission and identified in the application.• (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); No diverter system will be utilized during operations on iJ-174 Li. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An app/icatr"an for a Permit to Dril! must be accompanied by each of the fol%wing items, except for an item already on fi/e with the commission and identified in the application: (8) a drilling fluid program, fine/uding a diagram and description of the dri//ing fluid system, as required by 20 AAC 25.033; Drilling will be done with mud having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro, Mineral Oil Base) Value Densit 8.4 - 8.5 Plastic Viscostiy Ib/100 s 15 - 25 Yield Point cP 18 28 HTHP Fluid loss (ml/30 min 200psi 8 150° <4.0 Oil /Water Ratio 70 / 30 Electrical Stabilit 650-900 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 15. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An app/ication far a Permit to Drill must be accompanied by each of the fo/%wmg items, except for an item already on file with the commission and identified in the application: (9) far an exp/oratory or stratigraphic test we/l, a tabu/anon setting out the depths of predicted abnormal/y geo pressured strata as required by 20 AAC 25.033(1); Not applicable: Application is not for an exploratory or stratigraphic test well. 1J-174 L1 PERMIT IT Page 4 of 6 ~"~ ~ ~~ ~ ~ Printed: 16-Oct-07 ~~~ , ,~ Ap~on for Permit to Drill, Well 1J-174 L1 Revision No.O Saved: 16-Oct-07 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application far a Permit to Drill must be accompanied by each of the fo/lowing items, except for an item a/ready on fi/e with he commission and identified in the application: (10) for an exploratory or stmt/graphic test wel% a seismic refraction or reflection analysis as required by 20 AAC 2S.06i(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Dril/must be accompanied by each of the fo/%wing items, except for an item a/ready on fi/e with the cammission and identified in the application: (11J for a well dri/led from an offshore p/alform, mobi/e bottom-founded struchrre, jack-up rig, or t7oating drilling vess% an analysis ofseabed conditions as required by 20 AAC 25.061(6); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An app/ication for a Permit to Drill must be accompanied by each of the fo/%wing items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An app/ication for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 3, Well Schematic. Note: Previous operations are covered under the iJ-174 Application for Permit to Drill. , 1. Run and set Baker Gent WindowMaster whipstock system, at window point of +/- 11,339' MD / 3,120' TVD, the top of the D sand. 2. Mill 8-1/2" window. POOH. 3. Pick up 8-1/2"drilling assembly with LWD, MWD, PWD and rotary steerable tool. RIH. 4. Drill to TD of B sand lateral at +/- 19,692' MD / 3,079' TVD, as per directional plan. 5. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. Pump out of hole. 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. RIH and set Baker Seal Bore diverter 8. PU and run 4-1/2" slotted liner with Baker Oil Tools RAM Hangar system. 9. RIH and land RAM hanger in Baker seal bore diverter. 10. Release hanger running tool. Pull out of hole laying down drillpipe as required. 11. PU ESP completion as required and RIH to depth. Land tubing. Set BPV 12. Nipple down BOPE, nipple up tree and test. Pull BPV. 13. Freeze protect well with diesel by pumping into 4-1/2" x 10-3/4" / 9-5/8"annulus, taking returns from tubing and allowing to equalize. (If the schedule and equipment availability allows, the Wells Group will freeze protect the well post rig). 14. Set BPV and move rig off. 1J-174 L1 PERMIT IT Page 5 of 6 Printed: 16-Oct-07 15. Rig up wire line unit. Pull BPV. 16. Set gas lift valves in mandrels. Use ESP to clean up well. 17. Place well on production. App~n for Permit to Drill, Well 1J-174 L1 Revision No.O Saved: 16-Oct-07 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(94) An application for a Permit to Dril/ mustc be accompanied by each of the fol%wing items, except for an item already on file with the camnussion and identr`fied in the application: (14) a general description of how the operator p/ans to dispose of dri/ling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1J Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on 1J Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic 1J-174 L1 PERMIT IT ~ ~ R ~ Page 6 of 6 Printed: 16-Oct-07 ~ . ~~ =~ a :,~ ConocoPhillips ~as~ r1 L Plan: 1 J-174 L1 (wp11) Sperry Drilling Services Proposal Report -Geographic 22 August, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-174 (Q1 Phase 2) -Slot 1J-174 1J-174 L1 Local Coordinate Origin: entered on Well Plan 1J-174 (Q9 Phase 2) -Slot 1J Viewing Datum: Doyon 15 @ 121.OOft (Doyon 15 (40 + 81)) TVDs to System: N North Reference: True Unit System: API - US Survey. Feet .~ ._... ,:' ,~,,, .,;fie. _. .. _._, ._,.>.S;A,,;~~."~"~.."'~~:~_ F~" .~'.-.,__ ;' ~~ ems: F3perry Drillin® S~rvic®~ ~L.~~~id..~RT® Sperry Drilling Services Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-174 (Q1 Phase Wellbore: 1J-174 L1 Plan: 1J-174 L1 (wp11) WELL DETAllS: Plan IJ-l74 (Ql Phase 2) NAD 1927 (NADCON CONUS) Alaska Zone 04 Ground Level. 81.00 +N/-S +E/-W Northing Easing Lati[[ude Longitude Slot 0.00 0.00 5945536.61 558740.81 70°IS'42.494N 149°31'30.524W IJ-174 FORMATION TOP DETAILS No. TVDPath TVDSS MDPath Formation 1 1530.00 1409 1743.39 Pfrost 2 1637.00 1516 1931.38 T3 3 1923.00 1802 2679.98 Kt5 4 2126 00 2005 3464 32 Casing Pt ANNOTATIONS - TVD MD Annotation ' ' ' ' 5 ' 2659 00 2538 7237.42 Ugnu C 3119.60 11339.07 FWL-Sec 3-T10N-R10E FSL, 90 TVD: 1148 L1: KOP ~ 11339 MD, 3120 ' ' ' ' 6 . 00 2847 2726 8937.21 Ugnu B 3117.04 15049.34 FWL - Sec10-T10N-R10E FNL, 191 TVD: 2555 MD, 3117 L1: PA Boundary @ 15049 . 17 00 2796 9570 11 U A 3078 80 19691 62 198' FWL-Sec 15-T10N-R10E 3078' TVD: 1916' FNL L1: TOE @ 19692' MD 7 . 29 . gnu . . , , 8 3035.00 2914 10607.82 K 13 9 3119.60 2998.6 11339.05 W Sak D 333 - CASING DETAILS No MD TVD TVDss Name Size 667 1 4000.00 2264.65 2143.65 13 3/8" 13-3/8 2 11339.07 3119.60 2998.6 5/8" TOW 9-5/8 3 19691.63 3078.80 2957.8 4 1 /2" 4-1 /2 1000 1333 ~\ 1 I ~_ 1667 L1: KOP ~ 11339' MD, 3120' TVD: 1148' FSL, 90' FWL-Sec 3-T10N-R10E c ._ 0 2000 °o -------------- ------- - -------------- - ------------------------------ s 2333 L1: PA Boundary @ 15049' MD, 3117' TVD: 2555' FNL, 191' FWL - Sec10-T10N-R10E Q 9 5/8" TOW , ' ~ ~ 02667 -----o--i---~'----------- -- o ------------------i-- 0 41y2" ° -°-- -Y-----------------------------a-- ~-----°--i-'--g-----------$M ------------------~-----------------------------~---------------~\----~ ~ 3000 -'r--~------ ---- °t- ----------~ ~-------11--------I---------r-------I----'---~------------~---- -'- / ___ A -- W Sak D ~ ° ~ to! - ° a o° oo ~ ! a i 3333 °o 0 0: 3667 1J-174 MB_D Heel (07/03/07) ' ` 1J-174 MB_D_CP8 (07/03/07) 4000 1J-174 MB_D_CP2 (07/03/07) 1J-174 MB_D_CP4 (07/03/07) 1J-174 MB_D_CP6 (07103/07) 4333 1J-174 MB_D_CP7 (07/03/07) 1J-174 MB_D Toe (07/03/07) 1J-174 MB_D_CP1 (07103/07) 1J-174 MB_D~CP3 (07/03/07) 1J-174 MB_D_CPS (07/03/07) 4667 5333 5667 6000 6333 6667 7000 7333 7667 8000 8333 8667 9000 9333 9667 10000 10333 10667 11000 11333 11667 12000 12333 12667 13000 13333 13667 14000 14333 14667 Vertical Section at 180.00° (1000 fUin) ~>> ~- ConocoPhillips Alaska x"~~+ 1~"•: ~~ + ~ , g p Project: Kuparuk River Unit ELL DETAILS: Plante-174 (Q1 Phase 2~AD 1927 (NADCON CONUS) Alaska Zone 04 Site: Kuparuk 1J Pad Ground Level: 81.00 ~3psrry OrilUng Services Well: Plan 1J-174 (Q1 Phase N/-S +EI-W Northing Easting Latittude Longitude Slot Wellbore: 1J-174 L1 0.00 0.00 5945536.61 558740.81 70°15'42.494N 149°31'30.524W 1J-174 Plan: 1J-174 L1 (wp11) REFERENCE INFORMATION Co- rdinate(N/E)Reference: wenaianlJ-na(nlPhase2)-slot 1J-17a,True rlonh ertical(TVD)Reference: ooyontsr~lzl.ooe(ooyonls(ao+slp M asured Depth Reference: Ooyon is ~ 1zl.oolt (ooyon 1s (ao + s1)> Calculation Method: Minimum Curvature -5500 _ _ - 9 5/8" TOW -6000 CASING DETAILS -6500 '~ I l ] 74 MB D H l 7 / 7 No MD ND NDss Name Size - (0 /03 0 ) ee - 1 4000.00 2264.65 2143.65 13 3/8" 13-3/8 2 11339.07 3119.60 2998.69 5/8" TOW 9-5/8 -7000 ~ 3 19691.63 3078.80 2957.8 41/2" 4-1/2 Ll: KOP @ 1 1339' MD, 3120' TVD: 1148' FSL, 90' FWL -Sec 3-Tl ON-RI OE ~ - 17-174 MB D CP2 (07/03/07 -~~~ IJ-174 MB_D_CP3 (07/03/07) -9500 ~ 11-174 MB D CP4 (07/03/07) N -10000 L it ~ -10500 1 J-174 MB D CPS (07/03/07) o -11000 rn 1J-174 MB D CP6 (07/03/07 -11500 _ ) 12000 IJ-174 MB D CP7 (07/03/07) 13000 ~ - '-°-~- 11-174 MB D CP8 (07/03/07) LL PA Boundary @ 15049' MD, 311T TVD: 2555' FNL, 191' FWL- Sec10-TION-RIDE ANNOTATIONS ND MD Annotation 3119.60 11339.07 L1: KOP @ 11339' MD, 3120' TVD: 1148' FSL, 90' FWL-Sec 3-T10N-R10E 3117.04 15049.34 L1: PA Boundary @ 15049' MD, 3117' ND: 2555' FNL, 191' FWL - Sec10-T10 3078.80 19691.62 L1: TOE @ 19692' MD, 3078' ND: 1916' FNL, 198' FWL-Sec 15-T10N-R10E 14000 I]-174 MB D Tce (07/03/07) - -_ 4 I/2" - -079 i i 14500 IJ-174 LI (wpl I) 15000-, 10000 -9500 -9000 -8500 -8000 -7500 -7000 -6500 -6000 -5500 -5000 -4500 -4000 -3500 West(-)/East(+) (1250 ft/in) T M Azimuths to True North Magnetic North: 23.51 ° Magnetic Field Strength:57621.4nT Dip Angle: 80.82° Date: 5/22/2007 Model: BGGM2006 ;nnn _~cnn _~nnn icnn innn ,~'~ ConocoPhillips l;laska ~-' Halliburton Company COI"lOCC3~'i1~~ip5 Compass Proposal Report -Geographic Alaska ..: Sperry Drilling Servl~ezs Database: Company: .Sperry EDM .11 ConocoPhillips Alaska, Inc. Local Co-ordinate Reference: TVD Reference: Well Plan 1J-174 (Q1 Phase 2) -Slot 1J-174 Doyon 15 @ 121.OOft (Doyon 15 (40 + 81)) Project: I<uparuk River Unit MD Reference: Doyon 15 @ 121.OOft (Doyon 15 (40 + 81)) Site: I<uparuk 1J Pad North Reference: True Well: Plan 1J-174 (Q1 Phase 2) Survey Calculation Method: Minimum Curvature Wellbore: 1J-174 L1 Design: 1J-174 L1 (wp11) Project Kuparuk River Unrt: North Sfopz Alaska. U nited States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Plan 1J-1'4 ~Q1 Phase 2) -Slot 1J-174 Well Position +N/S 0.00 ft Northing: 5,945,536.61 ft Latitude: 70° 15' 42.494" N +E/-W 0.00 ft Easting: 558,740.81 ft Longitude: 149° 31' 30.524" W Position Uncertainty O.OOft Wellhead Elevation: ft Ground Level: 81.OOft Wellbore 1J-174 L1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2006 5/22/2007 23.51 80.82 57,621 Design 1J-174 L1 (wp11) Audit Notes: , Version: Phase: PLAN Tie On Depth: 11,339.05 Vertical Section: Depth From (ND) +N!-S +EI-W Direction (ft) (ft) (ft) (°) 40.00 0.00 0.00 180.00 8/22/2007 3: 25:01 PM Page 2 of 8 COMPASS 2003.11 Build 48 ~QC10U}~E'11~~1 Halliburton Company ~-~~~ ~ '~ ' ~fi~ Compass Proposal Report -Geographic gpe~~.y priliing 8~rvices Database: .Sperry EDM .11 ~ Local Co-ordinate Reference: Well Plan 1J-174 (Q1 Phase 2) -Slot 1J-174 Company:... ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 @ 121.OOft (Doyon 15 (40 + 81)) Project: Kuparuk River Unit MD Reference: Doyon 15 @ 121.OOft (Doyon 15 (40 + 81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-174 (Q1 Phase 2) Survey Calculation Method: Minimum Curvature -~ Wellbore: 1J-174 L1 Design: 1J-174 L1 (wp11) i Plan Summary J Measured Dogleg Build Turn Depth Inclination Azimuth TVD TVDSS +N/-S +E!-W Rate Rate Rate TFO (ft) - l~) (~) lft) (ft) (ft) (ft) (°/100ftj (°I100ft) (°I100ft) (°) 11,339.05 83.68 192.56 3,119.60 2,998.60 -5,852.00 -7,992.47 0.00 0.00 0.00 0.00 11,355.55 85.92 192.56 3,121.10 3,000.10 -5,868.04 -7,996.04 13.60 13.60 0.00 0.00 11,385.55 85.92 192.56 3,123.23 3,002.23 -5,897.25 -8,002.54 0.00 0.00 0.00 0.00 11,740.14 91-.03 175.57 3,132.73 3,011.73 -6,249.41 -8,027.49 5.00 1.44 -4.79 -73.59 11,922.26 91.03 175.57 3,129.44 3,008.44 -6,430.96 -8,013.42 0.00 0.00 0.00 0.00 11,941.39 90.52 175.00 3,129.18 3,008.18 -6,450.03 -8,011.84 4.00 -2.68 -2.97 -132.07 12,391.39 90.52 175.00 3,125.10 3,004.10 -6,898.29 -7,972.63 0.00 0.00 0.00 0.00 12,683.64 89.86 177.85 3,124.12 3,003.12 -7,189.95 -7,954.40 1.00 -0.22 0.97 102.99 13,091.63 89.86 177.85 3,125.10 3,004.10 -7,597.64 -7,939.08 0.00 0.00 0.00 0.00 13,213.88 90.06 179.05 3,125.18 3,004.18 -7,719.85 -7,935.77 1.00 0.16 0.99 80.83 14,191.10 90.06 179.05 3,124.20 3,003.20 -8,696.94 -7,919.65 0.00 0.00 0.00 0.00 14,268.13 90.49 179.69 3,123.83 3,002.83 -8,773.96. -7,918.81 1.00 0.57 0.82 55.54 14,991.28 90.49 179:69 3,117.60 2,996.60 -9,497.07 -7,914.89 0.00 0.00 0.00 0.00 ~. 15,006.67 90.57 179.55 3,117.46 2,996.46 -9,512.46 -7,914.79 1.00 0.48 -0.88 -61.46 15,891.52 90.57 179.55 3,108.70 2,987.70 -10,397.24 -7,907.91 0.00 0.00 0.00 0.00 ~, 15,937.76 90.11 179.51 3,108.43 2,987.43 -10,443.47 -7,907.53 1.00 -1.00 -0.09 -174.69 16,811.74 90.11 179.51 3,106.80 2,985.80 -11,317.42 -7,900.09 0.00 0.00 0.00 0.00 16,864.37 90.63 179.52 3,106.46 2,985.46 -11,370.05 -7,899.64 1.00 1.00 0.01 0.47 17,611.97 90.63 179.52 3,098.20 2,977.20 -12,117.57 -7,893:33 0.00 0.00 0.00 0.00 17,704.33 89.71 179.52 3,097.92 2,976.92 -12,209.94 -7,892.55 1.00 -1.00 0.00 179.82 18,291.13 89.71 179.52 3,100.90 2,979.90 -12,796.70 -7,887.62 0.00 0.00 0.00 0.00 18,416.20 90.96 179.51 3,100.17 2,979.17 -12,921.76 -7,886.56 1.00 1.00 -0.01 -0.64 19,691.64 90.96 179.51 3,078.80 2,957.80 -14,196.98 -7,875.54 0.00 0.00 0.00 0.00 8/22/2007 3:25:01PM Page 3 of 8 COMPASS 2003.11 Build 48 9.~ ~' Halliburton Company ConocoPhillips Compass Proposal Report -Geographic qj Sperryt Driili~g Services Database: Sperry EDM .11 Local Co-ordinate Reference: Well Plan 1J-174 (Q1 Phase 2) -Slot 1J-174 Company: ConocoPhillips Alaska, Inc. ND Reference: Doyon 15 @ 121.OOft (Doyon 15 (40 + 81)) Project: Kuparuk River Unit MD Reference: Doyon 15 @ 121.OOft (Doyon 15 (40 + 81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-174 (Q1 Phase 2) Survey Calculation Method: Minimum Curvature Wellbore: 1J-174 L1 Design: 1J-174 L1 (wp11) Planned Survey. 1J-1;4 L1 (vdp11) Map Map MD Incl Azimuth TVD (ft) TVDSS +N!-S +E!-W Northing Easting DLSEV Vert Section (ft) (~) (~) (ft) (ft) (ft) 1ft1 lft) ('1100ft) (ft) 11,339.05 83.68 192.56 3,119.60 2998.60 -5,852.00 -7,992.47 5,939,623.00 550,795.00 0.00 5,852.00 ~ L1: KOP @ 11339' MD , 3120' TVD: 1148' FSL, 90' FWL-Sec 3-T10N-R10E - W Sak D - 9 518" TOW 11,355.55 85.92 192.56 3,121.10 3000.10 -5,868.04 -7,996.04 5,939,606.94 550,791.55 13.60 5,868.04 11,385.55 85.92 192.56 3,123.23 3002.23 -5,897.25 -8,002.54 5,939,577.69 550,785.28 0.00 5,897.25 11,400.00 86.12 191.86 3,124.23 3003.23 -5,911.34 -8,005.59 5,939,563.57 550,782.34 4.98 5,911.34 11,500.00 87.55 187.06 3,129.75 3008.75 -6,009.80 -8,022.00 5,939,465.00 550,766.70 5.00 6,009.80 11,600.00 89.00 182.28 3,132.76 3011.76 -6,109.39 -8,030.13 5,939,365.36 550,759.35 5.00 6,109.39 11,700.00 90.45 177.49 3,133.25 3012.25 -6,209.36 -8,029.92 5,939,265.41 550,760.34 5.00 6,209.36 11,740.14 91.03 175.57 3,132.73 3011.73 -6,249.41 -8,027.49 5,939,225.37 550,763.08 5.01 6,249.41 11,800.00 91.03 175.57 3,131.65 3010.65 -6,309.09 -8,022.86 5,939,165.74 550,768.17 0.00 6,309.09 11,900.00 91.03 175.57 3,129.84 3008.84 -6,408.77 -8,015.14 5,939,066.13 550,776.68 0.00 6,408.77 11,922.26 91:03 175.57 3,129.44 3008.44 -6,430.96 -8,013.42 5,939,043.95 550,778.57 0.00 6,430.96 11,941.39 90.52 175.00 3,129.18 3008.18 -6,450.03 -8,011.84 5,939,024.91 550,780.29 4.00 6,450.03 12,000.00 90.52 175.00 3,128.65 3007.65 -6,508.41 -8,006.74 5,938,966.57 550,785.85 0.00 6,508.41 12,100.00 90.52 175.00 3,127.74 ' 3006.74 -6,608.03 '-7,998.02 5,938,867.03 550,795.34 0.00 6,608.03 12,200.00 90.52 175.00 3,126.84 3005.84 -6,707.64 -7,989.31 5,938,767.50 550,804.83 0.00 6,707.64 12,300.00 90.52 175.00 3,125.93 3004.93 -6,807.26 -7,980.59 5,938,667.97 550,814.33 0.00 6,807.26 12,391.39 90.52 175.00 3,125.10 ` 3004.10 -6,898.29 '-7,972.63 5,938,577.00 '~ 550,823.00 0.00 ~ 6,898.29 1J-174 MB_D_CP7 (07/03/07) 12,400.00 90.50 175.08 3,125.02 3004.02 -6,906.87 -7,971.88 5,938,568.43 550,823.81 0.99 6,906.87 12,500.00 90.28 176.06 3,124.35 3003.35 -7,006.57 -7,964.16 5,938,468.80 550,832.31 1.00 7,006.57 12,600.00 90.05 177.03 3,124.06 3003.06 -7,106.39 -7,958.13 5,938,369:05 550,839.11 1:00 7,106.39 12,683.64 89.86 177.85 3,124.12 3003.12 -7,189.95 -7,954.40 5,938,285.53 550,843.50 1.00 7,189.95 12,700.00 89.86... 177.85 3,124.16 3003.16 -7,206.29 -7,953.78 5,938,269.19 550,844.24 0.00 7,206.29 12,800.00 89.86 177.85 3,124.40 3003.40 -7,306.22 -7,950.03 5,938,169.30 550,848.78 0.00 7,306.22 12,900.00 89.86 177.85 3,124.64 3003.64 -7,406.15 -7,946.27 5,938,069.42 550,853.31 0.00 7,406.15 13,000.00 89.86 177.85 3,124..88 3003.88 -7,506.08 -7,942.52 5,937,969.53 550,857.84 0.00 7,506.08 13,091.63 89.86 177.85 3,125.10.. 3004.10 -7,597.64 -7,939.08 5,937,878.00 550,862.00 0.00 7,597.64 1J-174 MB_D_CP2 (07/03/07) 13,100.00 89.88 177.93 3,125.12 3004.12 -7,606.01 -7,938.77 5,937,869.64 550,862.37 0.99 7,606.01 13,200.00 90.04 178.92 3,125.20 3004.20 -7,705.97 -7,936.02 5,937,769.71 550,865.90 1.00 7,705.97 13,213.88 90.06. 179.05 3,125.18 3004.18 -7,719.85 -7,935.77 5,937,755.84 550,866.26 1.00 7,719.85 13,300.00 90.06 179.05 3,125.10 3004.10. -7,805.95 -7,934.35 5,937,669.75 550,868.35 0.00 7,805.95 13,400.00 90.06 179.05 3,125.00 3004.00 -7,905.94 -7,932.70 5,937,569.79 550,870.78 0.00 7,905.94 13,500.00 90.06. 179.05 3,124.90 3003.90 -8,005.93 -7,931.05 5,937,469.83 550,873.21 0.00 8,005.93 13,600.00 90.06 179.05 3,124.80 3003.80 -8,105.91 -7,929.40 5,937,369.87 550,875.64 0.00 8,105.91 13,700.00 90.06 179.05 3,124.69 3003.69 -8,205.90 -7,927.75 5,937,269.91 550,878.07 0.00 8,205.90 13,800.00 90.06 179.05 3,124.59 3003.59 -8,305.89 -7,926.10 5,937,169.95 550,880.50 0.00 8,305.89 13,900.00 90.06 179.05 3,124.49 3003.49 -8,405.87 -7,924.45 5,937,069.99 550,882.93 0.00 8,405.87 14,000.00 90.06 179.05 3,124.39 3003.39 -8,505.86 -7,922.80 5,936,970.03 550,885.36 0.00 8,505.86 14,100.00 90.06 179.05 3,124.29 3003.29 -8,605.85 -7,921.15 5,936,870.07 550,887.79 0.00 8,605.85 14,191.10 90.06 179.05 3,124.20 3003.20 -8,696.94 -7,919.65 5,936,779.00 550,890.00 0.00 8,696.94 1J-174 MB_D_CP3 (07/03/07) 14,200.00 90.11 179.13 3,124.19 3003.19 -8,705:83 -7,919.51 5,936,770.11 550,890.21 0.99 8,705.83 14,268.13 90.49 179.69' 3,123.83 3002.83 -8,773.96 -7,918.81 5,936,701.99 550,891.44 1.00 8,773.96 14,300.00 90.49 179.69 3,123.55 3002.55 -8,805.83 -7,918:63 5,936,670.13 550,891.87 0.00 8,805.83 8/222007 3:25:01PM Page 4 of 8 COMPASS 2003.11 Build 48 Y~ ~~ ~~~ -; r#~ ~©i10CE3~'11~~t~35 Halliburton Company _ ~~=~ ..': - e :` ~ Compass Proposal Report -Geographic gp®rry Drilling Services Database: .Sperry EDM .11 ~ m Local Co-ordinate Reference: Well Plan 1J-174 (Q1 Phase 2) -Slot 1J-174 Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 @ 121.OOft (Doyon 15 (40 + 81)) Project: Kuparuk River Unit MD Reference: Doyon 15 @ 121.OOft (Doyon 15 (40 + 81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-174 (Q1 Phase 2) Survey Calculation Method: PAinimum Curvature Wellbore: 1J-174 L1 Design: 1J-174 L1 (wp11) Planned Survey 1J-174 L1 (wp11) MD Incl Azirnuth ND (ftj TVDSS +N!-S +E/-W Ift) (°) (°) {ftl (ft) (ft) 14,400.00 90.49 179.69 3,122.69 3001.69 -8,905.82 -7,918.09 14,500.00 90.49 179.69 3,121.83 3000.83 -9,005.81 -7,917.55 14,600.00 90.49 179.69 3,120.97 2999.97 -9,105.81 -7,917.01 14,700.00 90.49 179.69 3,120.11 2999.11 -9,205.80 -7,916.47 14,800.00 90.49 179.69. 3,119.25 2998.25 -9,305.80 -7,915.93 14,900.00 90.49 179.69 3,118.39 2997.39 -9,405.79 -7,915.38 14,991.28 90.49 179.69 3,117.60 2996.60 -9,497.07 -7,914.89 1J-174 MB_D_CP4 (07/03/07} 15,000.00 90.54 179.61 3,117.52 2996.52 -9,505.79 -7,914.84 15,006.67 90.57 179.55 3,117.46 2996.46 -9,512.46 -7,914.79 15,049.34 90.57 179.55 3,117.04 2996.04 -9,555.12 -7,914.46 L1: PA Bou ndary ~ 15049' MD, 3 117' TVD: 2555' FNL, 191 ' FWL - Sec1 0-T10N-R10E 15,100.00 90.57 179.55 3,116.53 2995.53 -9,605.78 -7,914.06 15,200.00 90.57 179.55 3,115.54 2994.54 ~ -9,705.77 -7,913.29 15,300.00 90.57 179.55 3,114.55 2993.55 -9,805.77 -7,912.51 15,400.00 90.57 179.55 3,113.56 2992.56 -9,905.76 -7,911.73 15,500.00 90.57 179.55 3,112.58 2991.58 -10,005.75 -7,910.95 15,600.00 90.57 179.55 3,111.59 2990.59 ` -10,105.74 -7,910.18 15,700.00 90.57 179.55 3,110.60 2989.60 -10,205.73 -7,909.40 15,800.00 90.57 179.55 3,109.61 2988.61 -10,305.73 -7,908.62 15,891.52 90.57 179.55 3,108.70 2987.70 -10,397.24 -7,907.91 1,f-174 MBID_CP5 (07/03/07) 15,900.00 90.48 179.55 3,108.62 2987.62 -10,405.72 -7,907.84 15,937.76 90.11 179.51 3,108.43 2987.43 -10,443.47 -7,907.53 16,000.00 90.11 179.51 3,108.31 2987.31 -10,505.71 -7,907.00 16,100.00 90.11 179.51 3,108.13 2987.13 -10,605.71 -7,906.15 16,200.00 90.11 179.51 3,107.94 2986.94. -10,705.71 -7,905.30 16,300.00 90.11 179.51 3,107.75 2986.75 -10,805.70 -7,904.45 16,400.00 90.11 179.51 3,107.57 2986.57 -10,905.70 -7,903.60 16,500.00 90.11 179.51 3,107.38 2986.38 -11,005.69 -7,902.74 16,600.00 90.11 179.51 3,107.19 2986.19 -11,105.69 -7,901.89 16,700.00 90.11 179.51 3,107.01 2986.01 -11,205.69 -7,901.04 16,800.00 90.11 179.51 3,106.82 2985.82 -11,305.68 -7,900.19 16,811.74 90.11 179.51 3,106.80 2985.80 -11,317.42 -7,900.09 1J-174 MB_D_CP6 (07/03/07} 16,864.37 90.63 179.52 3,106.46 2985.46 -11,370.05 -7,899.64 16,900.00 90.63 179.52 3,106.07 2985.07 -11,405.68 -7,899.34 17,000.00 90.63 179.52 3,104.96 2983.96 -11,505.67 -7,898.50 17,100.00 90.63 179.52 3,103.86 2982.86 -11,605.66 -7,897.65 17,200.00 90.63 179.52 3,102.75 2981.75 -11,705.65 -7,896.81 17,300.00 90.63 179.52 3,101.65 2980.65 -11,805.64 -7,895.96. 17,400.00 90.63 179.52 3,100.54 2979.54 -11,905.63 -7,895.12 17,500.00 90.63 179.52 3,099.44 2978.44 -12,005.62 -7,894.27 17,600.00 90.63 179.52 3,098.33 2977.33 -12,105.61 -7,893.43 17,611.97 90.63 179.52 3,098.20 2977.20 -12,117.57 -7,893.33 1J-174 ME3 [3 CP7 (O7/0~07} Map Map Northing Easting DLSEV Vert Section (ft) (ft) (°/100ft) (ft) 5,936,570.15 550,893.19 0.00 8,905.82 5,936,470.18 550,894.51 0.00 9,005.81 5,936,370.20 550,895.83 0.00 9,105.81 5,936,270.22 550,897.15 0.00 9,205.80 5,936,170.24 550,898.47 0.00 9,305.80 5,936,070.26 550,899.79 0.00 9,405.79 5,935,979.00 550,901.00 0.00 9,497.07 5,935,970.29 550,901.12 1.00 9,505.79 5,935,963.62 550,901.22 1.00 9,512.46 5,935,920.96 550,901.89 0.00 9,555.12. 5,935,870.31 550,902.67 0.00 9,605.78 5,935,770.34 550,904.23 0.00 9,705.77 5,935,670.37 550,905.79 0.00 9,805.77 5,935,570.39 550,907.35 0.00 9,905.76 5,935,470.42 550,908.90 0.00 10,005.75 5,935,370.45 550,910:46 0.00 10,105.74' 5,935,270.47 550,912.02 0.00 10,205.73 5,935,170.50 550,913.57 0.00 10,305.73 5,935,079.00 550,915.00 0.00 10,397.24 5,935,070.53 550,915.13 0.99 10,405.72 5,935,032.78 550,915.74 1.00 10,443.47 5,934,970.55 550,916.75 0.00 10,505.71 5,934,870.57 550,918.38. 0.00 10,605.71 .5,934,770.60 550,920.02 0.00 10,705.71. 5,934,670.62 550,921.65 0.00 10,805.70 5,934,570.64 550,923.28 0.00 10,905.70 5,934,470.67 550,924.91 0.00 11,005.69 5,934,370.69 550,926.54 0.00 11,105.69 5,934,270.71 550,928.18 0.00 11,205.69 5,934,170.73 550,929.81 0.00 11,305.68 5,934,159.00 550,930.00 0.00 11,317.42 5,934,106.38 550,930.86 1.00 11,370.05 5,934,070.76 550,931.44 0.00 11,405.68 5,933,970.79 550,933.06 0.00 11,505.67 5,933,870.82 550,934.68 0.00 11,605.66 5,933,770.85 550,936.31 0.00 11,705.65 5,933,670.88 550,937.93 0.00 11,805.64 5,933,570.91 550,939.56 0.00 11,905.63 5,933,470.93 550,941.18 0.00 12,005.62 5,933,370.96 550,942.81 0.00 12,105.61 5,933,359.00 550,943.00 0.00 12,117.57 8/22/2007 3:25:01PM Page 5 of 8 COMPASS 2003.11 Build 48 ~~~ 'r C011000~'11~~Ip5 Alaska Halliburton Company Compass Proposal Report -Geographic ~... ~ ,.., _ w,,,-x~ Sperry Drilling 8ervlces Database: .Sperry EDM .11 Local Co-ordinate Reference: Well Plan 1J-174 (Q1 Phase 2) -Slot 1J-174 Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 @ 121.OOft (Doyon 15 (40 + 81)) Project: Kuparuk River Unit MD Reference: Doyon 15 @ 121.OOft (Doyon 15 (40 + 81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-174 (Q1 Phase 2) Survey Calculation Method: Minimum Curvature Wellbore: 1J-174 L1 Design: 1J-174 L1 (wp11) Planned Survey 1J-174 L1 (wp11) Map Map MD Incl Azimuth TVD (ft} TVDSS +N/-S +E/_y~ Northing Fasting DLSEV Vert Section (ft) (°) (') (ft) (ft) (ft) (ft) (ft) (°I100ft) (ft) 17,700.00 89.75 179.52 3,097.90 2976.90 -12,205.60 -7,892.59 5,933,270.99 550,944.43 1.00 12,205.60 17,704.33 89.71 179.52 3,097.92 2976.92 -12,209.94 -7,892.55 5,933,266.66 550,944.50 1.00 12,209.94 17,800.00 89.71 179.52 3,098.41 2977.41 -12,305.60 -7,891.75 5,933,171.01 550,946.05 0.00 12,305.60 17,900.00 89.71 179.52 3,098.92 2977.92 _ -12,405.59 -7,890.91 5,933,071.04 550,947.67 0.00 12,405.59 18,000.00 89.71 179.52 3,099.42 2978.42 -12,505.59 -7,890.07 5,932,971.06 550,949.29 0.00 12,505.59 18,100.00 89.71 179.52 3,099.93 2978.93 -12,605.58 -7,889.23 5,932,871.08 550,950.91 0.00 12,605.58 18,200.00 89.71 179.52 3,100.44 2979.44 -12,705.58 -7,888.39 5,932,771.11 550,952.52 0.00 12,705.58 18,291.13 89.71 179.52 3,100.90 2979.90 -12,796.70 -7,887.62 5,932,680.00 550,954.00 0.00 12,796.70 1J-174 MB_D_CP8 (07/03/07) 18,300.00 89.80 179.52 3,100.94 2979.94 -12,805.57 -7,887.55 5,932,671.13 550,954.14 0.99 12,805.57 18,400.00 90.80 179.51 3,100.42 2979.42 -12,905.57 -7,886.70 5,932,571.16 550,955.77 1.00 12,905.57 18,416.20 90.96 179.51 3,100.17 2979.17 -12,921.76 -7,886.56 5,932,554.97 550,956.04 1.00 12,921.76 18,500.00 90.96 179.51 3,098.77 2977.77 -13,005.55 -7,885.84 5,932,471.19 550,957.42 0.00 13,005.55 18,600.00 I 90.96 179.51 3,097.09 2976.09 -13,105.53 -7,884.97 5,932,371.23 550,959.06 0.00 13,105.53 I 18,700.00 90.96 179.51 3,095.41 ' 2974.41 -13,205.51 ' -7,884.11 5,932,271.27 ' 550,960.70 0.00 13,205.51 18,800.00 90.96 179.51 3,093.74 2972.74 -13,305.50 -7,883.24 5,932,171.31 550,962.35 0.00 13,305.50 18,900.00 90.96 179.51 3,092.06 2971.06 -13,405.48 -7,882.38 5,932,071.34 550,963.99 0.00 13,405.48 19,000.00 90.96. 179.51 3,090.39' 2969.39 -13,505.46 '- -7,881.52 5,931,971.38 '~ 550,965.63 0.00 '~ 13,505.46 19,100.00 90.96 179.51 3,088.71 2967.71 -13,605.44 -7,880.65 5,931,871.42 550,967.28 0.00 13,605.44 19,200.00 90.96 179.51 3,087.04 2966.04 -13,705.43 -7,879.79 5,931,771.45 550,968.92 0.00 13,705.43 19,300.00 90.96 179.51 3,085.36 2964.36 -13,805.41 -7,878.93 5,931,671.49 550,970.56 0.00 13,805.41 19,400.00 90.96 179.51 3,083.69 2962.69 -13,905.39 -7,878.06 5,931,571,53 550,972.21 0.00 13,905.39 19,500.00 90.96 179.51 3,082.01 2961.01 -14,005.37 -7,877.20 5,931,471.57 550,973.85 0.00 14,005.37 19,600.00 90.96 179.51 3,080.34 2959.34 -14,105.35 -7,876.34 5,931,371.60 550,975.49 0.00 14,105.35. 19,691.64 90.96 179.51 3,078.80 2957.80 -14,196.98 -7,875.54 5,931,280.00 550,977.00 0.00 14,196.98 L1: TOE ~ 19692' MD, 3078' TVD : 1916' FNL, 1 98' FWL-Sec 15-T10N-R10E - 4 112" -1J-174 MB_D Toe (07/03/07) 8/22/2007 3:25:01PM Page 6 of 8 COMPASS 2003.11 Build 48 ~~~.. ~OC1QC0~lt~~l~?5 Ala~ca Halliburton Company Compass Proposal Report -Geographic ~ .., o _ . Sperry Drilling 8®rvio®s Database: .Sperry EDM .11 Local Co-ordinate Reference: Well Plan 1J-174 (Q1 Phase 2) -Slot 1J-174 Companyi ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 @ 121.OOft (Doyon 15 (40 + 81)) Project: Kuparuk River Unit MD Reference: Doyon 15 @ 121.OOft (Doyon 15 (40 + 81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-174 (Q1 Phase 2) Survey Calculation Method: Minimum Curvature Wellbore: 1J-174 L1 Design: 1J-174 L1 (wp11) Geologic Targets 1J-174 L1 TVD TVDSS Target Name +N/-S +E/-W Northing Easting (ft) (ft) -Shape ft ft (ft) (ft) 3,106.80 1J-174 MB_D_CP6 (07103107) -11,317.42 -7,900.09 5,934,159.00 550,930.00 - Polygon Point 1 0.00 0.00 5,934,159.00 550,930.00 Point 2 -800.29 6.76 5,933,359.00 550,943.00 3,117.60 1J-174 MB_D_CP4 (07/03/07) -9,497.07 -7,914.89 5,935,979.00 550,901.00 - Polygon Point 1 0.00 0.00 5,935,979.00 550,901.00 Point 2 -900.24 6.98 5,935,079.00 550,915.00 3,125.10 1J-174 MB_D_CP1 (07/03/07) -6,898.29 -7,972.63 5,938,577.00 550,823.00 - Polygon Point 1 0.00 0.00 5,938,577.00 550,823.00 Point 2 -699.36 33.55 5,937,878.00 550,862.00 3,098.20 1J-174 MB_D_CP7 (07/03/07) -12,117.57 -7,893.33 5,933,359.00 550,943.00 - Polygon Point 1 0.00 .0.00 5,933,359.00 550,943.00 Point 2 -679.19 5.70 5,932,680.00 550,954.00 3,100.90 1J-174 MB_D_CP8 (07/03/07) -12,796.70 -7,887.62 5,932,680.00 550,954.00 - Polygon Point 1 0.00 0.00 5,932,680.00 550,954.00 Point2 -1,400.28 12.08 5,931,280.00 550,977.00 3,124.20 1J-174 MB_D_CP3 (07/03/07) -8,696.94 -7,919.65 5,936,779.00 550,890.00 - Polygon Point 1 0.00 0.00 5,936,779.00 550,890.00 Point 2 -800.14 4.76 5,935,979.00 550,901.00 3,078.80 1J-174 MB_D Toe (07/03107) -14,196.98 -7,875.54 5,931,280.00 550,977.00 - Point 3,108.70 1J-174 MB_D_CP5 (07/03/07) -10,397.24 -7,907.91 5,935,079.00 550,915.00 - Polygon Point 1 0.00 0.00 5,935,079.00 550,915.00 Point 2 -920.18 7.82 5,934,159.00 550,930.00 3,125.10 1J-174 MB_D_CP2 (07/03/07):. -7,597.64 -7,939.08. 5,937,878.00 550,862.00 - Polygon Point 1 0.00 0.00 5,937,878.00 550,862.00 Point 2 -1,099.37 19.43 5,936,779.00 550,890.00 3,134.60 1J-174 MB_D Heel (07/03/07) -5,852.01 -7,992.47 5,939,623.00 550,795.00 - Polygon Point 1 0.00 0.00 5,939,623.00 550,795.00 Point 2 -1,046.30 19.84 5,938,577.00 550,823.00 8/22/2007. 3:25:01PM Page 7 of 8 COMPASS 2003.11 Build 48 ~~~~:.~ n i-~' Halliburton Company C011000~'t1~~Ip5 Compass Proposal Report -Geographic Alaska Sperry Drilling Services Database: .Sperry EDM .11 t_ocal Co-ordinate Reference: Well Plan 1J-174 (Q1 Phase 2) -Slot 1J-174 Company: ConocoPhillips Alaska, Inc. ND Reference: Doyon 15 @ 121.OOft (Doyon 15 (40 + 81)) Project: I<uparuk River Unit MD Reference: Doyon 15 @ 121.OOft (Doyon 15 (40 + 81)) Site: I<uparuk 1J Pad North Reference: True Well: Plan 1J-174 (Q1 Phase 2) Survey Calculation Method: Minimum Curvature Wellbore: 1J-174 L1 Design: 1J-174 L1 (wp11) Prognosed Casiny Points Measured Verticat Casing liolg Depth Depth _ Diameter Diamet¢r (ft1 (ft) {") 1~~) 4,000.00 2,264.65 13-3/8 16 11,339.07 3,119.60 9-5/8 12-1/4 19,691.63 3,078.80 4-1/2 8-1/2 Proynosed Formation Intersection Points Measured Depth (ft) Inclination Azimuth (~) (') ND fft1 NDSS +N/-E (ft) ' +E/-W (ft) iftl Name 1,743.39 53.96 248.97 1,530.00 -270.38 -580.21 Pfrost 1,931.38 57.59 246.50 1,637.00 -328.19 -723.49 T3 2,679.98 75.00 237.00 1,923.00 -663.35 -1,323.30 K15 3,464.32 75.00 237.00 2,126.00 -1,075.93 -1,958.72 Casing Pt 7,237.42 ~ 83.65 235.00 ~ 2,659.00 ~ -3,187.56 -5,031.35 Ugnu'C 8,937.21 83.65 235.00 2,847.00 -4,156.54 -6,415.20 Ugnu B 9,570.11 83.65 235.00 2,917.00 -4,517.33 -6,930.46 Ugnu.A 10,607.82 83.21 215.08 3,035.00 -5,191.79 -7,701.09 K 13 11,339.05 83.68 192.56 3,119.60 -5,852.00 -7,992.47 iN Sak D Plan Annotati ons Measured Vertical Local Coo rdinates Depth Depth +N/-S +EI-W Comment (ft) lft) (ft) (ft) 11,339.07 3,119.60 -5,852.02 -7,992.47 L1: KOP @ 11339' MD, 3120' ND: 1148' FSL, 90' FWL-Sec 3-T10N-R10E .15,049.34 3,117.04 -9,555.12 -7,914.46 L1: PA Boundary c@ 15049' MD, 3117' ND: 2555' FNL, 191' FWL - Sec10-T1 19,691.63 3,078.80 -14,196.97 -7,875.54 L1: TOE @ 19692' MD, 3078' ND: 1916' FNL, 198' FWL-Sec 15-T10N-R10E 8/22/2007 3:25:01PM P ~ COMPASS 2003.11 Build 48 ConocoPhillips ~~~ Plan: 1J-174 L1 (wp11) Sperry Drilling Ser~rices Anticollision Summary 21 August, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-174 (Q1 Phase 2) 1 J-174 L1 Local Coordinate Origin: Centered on Well Plan 1J-174 (Q1 Phase 2) -Slot 1J Viewing Datum: Doyon 15 @ 121.OOft (Doyon 15 (40 + 81)) TVDs to System: N North Reference: True Unit System: API - US Survey Feet -.,, Sperry .Drilling S®rvice>s t~,l~ SURVEY PROGRAM Date: 2007-08-21700:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 40.00 1000.00 C~GI'RO-SS 1000.00 4000.00 MWD+IFR-AK-CAZSC 4000.00 11339.05 M W D+1 NR-AK-CAZrSC 11339.05 19691.32 1J-174 Ll (wpll) MWD+IFR-AK-CAZSC 0 COMPANY DETAILS: ConocoPhillips Alaska, Inc. Engineering Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surface: Elliptical Conic Warning Method: Rules Based 240 270 180 Travelling Cylinder Azimuth (TFO+AZI) ~°~ vs Centre to Centre Separation X200 ft/inJ REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Plan 1J-174 (Q1 Phase 2) -Slot 1J-174, True Vertical (TVD) Reference: Doyon 15 ~ 121.OOft (Doyon 15 (40 + 81)) Section (VS) Reference: Slot - 1J-174(O.OON, O.OOE) Measured Depth Reference: Doyon 15 @ 121.OOft (Doyon 15 (40+81 )) Calculation Method: Minimum Curvature From Colour To MD 300 0 11000 11000 112so 11250 -----~ 11500 11500 11750 11750 12000 12000 12250 12250 ~ - 12500 12500 12750 12750 13000 13000 13250 13250 13500 13500 13750 13750 14000 14000 14250 14250 14500 14500 14750 14750 15000 15000 15250 15250 -- ---- 15500 lssoo 1s7sa 1s7so lsaoo 16000 - 16250 162s0 16500 16500 16750 167s0 17000 17000 ~-"-~~~-"~-.'" 17250 17250 17500 17500 17750 17750 18000 18000 18250 18250 18500 18500 18750 18750 - '-. 19000 lsooa 19zsa 19250 19500 19500 0 NAD 27 ASP Zone 4 : WELL DETAILS: Plan 1J-174 (01 Phase 2) Ground Level: 81.00 +N/-S +FJ-W Northing Easting Latittude Lo 0.00 0.00 5945536.61 558740.81 70°15'42.494N 149°31'3 ANTI-COLLISION SETTINGS Interpolation Method: MD Interval: 25Stations Depth Range From: 11339.05 To 19695.9915758557 Maximum Range:2165.59915758557 Reference: Plan: 1J-174 L1 (wp11) Q 60 330 30 50 60 120 210 \ 150 180 Travelling Cylinder Azimuth (TFO+ALq ~°~ vs Centre to Centre Separation X35 ft/in~ Slot secnol4 oETnl~s Sac MD Inc Ro ND ~WS ~E/-W DL°9 TFece VSac Tcrget 1 11339.05 8).80 192 58 3119.60 -5852 00 -]992 4i 000 0.00 565] 00 2 1135555 85.92 19356 1131.10 -5660.04 -]996.04 1].60 0.00 5868.04 J 1130555 85.92 193.56 J12J.23 -569].25 -0002.51 0.00 000 589725 4 11]40.14 91.03 1]55] ]132.]3 -fi249.41 -602].49 5.00 5 11922.26 91.03 1]5.5] 3129.44 8130.% -001342 0.00 -]3.59 8249.41 000 8430.% 6 11941.39 %S3 1]5.00 ]129.16 4450.03 -0011.84 4.00 -1320] 6450.03 90.52 1]5.00 31..510 9829 ]9]1.83 0.00 I. 1.1 I I.~.0111J - 6 12683.61 &986 17/.85 )124.12 -]169.% -]951.40 100 6986 1]]65 3125.10 -]59]64 -]939.06 000 t0I 99 ]169.95 000 ]54 1.1 I]d MB_D_t;P: 10]!0);0]) 10 13213.60 %% 1]8.05 N25.18 -]]19.85 -]e%.]] 1.OD 80.0.1 ]71885 110 %O6 1]9.05 312420 ~%%94 -]919.65 0.00 0.p0 J-I ]0 M8 D_CP310i/03'01) 12 14268.13 %.48 1]8.88 )12].8] -0]]3.% -]818.81 1.OD 55.51 BTT3.% I3 1099126 11969 311]60 -949)0] -191489 000 0.00 9d9i 07 tJ I]4 MB_D_CPd ,Oi.O}0]) 14 150%.GT 80.5] 1]8.55 3111.48 -8512.46 -]814]9 1.00 15 1589152 90.5] 1)955 3106]0 1039]24 ]90].91 0.00 41.46 %12.46 000 I - JI]4 MB D_CP510]i01'0]) 1 16 1593]]8 80.11 1]9.51 3108Ai-fOM3A] -)90].53 1.00 -1]1.89 1044]<] I] 16911 ]d %.11 1]9.51 310680.131]42 -]90009 000 000 11311 i2 IJ-1 i4 MBOLPfi 10-030'1 18 160613] 90.63 179.52 310fi.4fi -113]0.05 -]889.61 1.00 OAT 11)10.05 - 19] 90.83 1]95_^ 309820-1 1]5) -]894.33 000 000 I iJ I]O MB OGP],o]03:9~~ - - 20 1!]09.33 69.71 129.52 3WT.92 -12108.9/ -]692.55 100 113 89]1 11951 )10090 ~11]%]0 -]88]62 000 1]9.82 1220994 1.4 MB DCPB ': ~_. - - 22 1841620 %.% 1]9.51 ]100.1] -12831.]fi -]866.% 1.OD .. i959~64 %% 1]9.51 30)680 -141%% -]8)5.54 000 12921 ]6 ~ - ~ ~. I'd M8_D ioe ;~' .... Halliburton Company Anticollision Report C Companp: ConocoPhillips Alaska Inc. Date: 8/21/2007 Time: 14:17:11 Page: 1 Field: Kuparuk River Unit Keference Sitc: Kuparuk 1J Pad Co-ordinate(nF,) Reference: Well: Plan 1J-174, Tr ue North Keference ~tiell: Plan 1J-174 Vertical ("1'VD) Reference: Doyon 15 (40+81) 12 1.0 Reference W'ellpath: Plan: 1J-174L1 DU: Oracle GLOBAL SCAN APPLIED: All wellpa ths within 200'+ 100/1000 of reference Reference: Plan: 1J-174L1 (wp11) & NOT PLANNED Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 11339.05 to 19691.64 ft Scan Method: Trav Cylinder North Maximum Radius: 2165.16 ft Error Surface: Ellipse + Casing Casing Points MD TVD Diameter hole Size Name ft ft in in 3700.00 2187.00 13.375 16.000 13 3/8" 11078.27 3090.18 9.625 12.250 9 5/8" 19665.31 3079.24 4.500 8.500 41/2" Plan: 1J-174L1 (wp11) Date Composed: 9/19/2006 Version: 10 Principal: Yes Tied-to: From: Definitive Path Summary <_________-----____-- Offset ~Vellpath ----------------------> Reference Offset Ctr-Ctr So-Go allowable Site Nell VI'ellpath ~1D I1~iD Distance Area Deviation Warning ft ft ft ft ft Kuparuk 1J Pad Plan 1J-174 Plan: 1J-174 V3 Plan: 11350.00 11350.00 0.15 0.00 0.15 Pass: No Errors Kuparuk 1J Pad Plan 1J-176 Plan 1J-176 L1 V1 Plan 18999.50 17730.04 1694.27 368.82 1325.45 Pass: Major Risk Kuparuk 1J Pad Plan 1J-176 Plan 1J-176 V1 Plan: 1 18998.26 17733.59 1697.70 388.48 1309.22 Pass: Major Risk Kuparuk 1J Pad Rig: 1J-162 Plan 1J-162 L1 V4 Plan Out of range Kuparuk 1J Pad Rig: 1J-162 Plan 1J-162 V8 Plan: 1 Out of range Kuparuk 1J Pad Rig: 1J-162 Rig 1J-162 V1 Aut of range Kuparuk 1J Pad Rig: 1J-162 Rig 1J-162L1 VO Out of range Non-Pad KRUST-02 KRUST-02 VO 17521.13 3600.00 1003.42 196.68 806.74 Pass: Major Risk i '~OGRAM 1J-174 L~Drillin~ Hazards ~mmarv (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 8-1/2" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud weight. Stuck Pipe Low Good hole cleaning, PWD tools, hole opener runs, decreased mud weight Lost Circulation Low Reduced pump rates, mud rheology, LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets),pum ing out, backreaming f"~ ~ ~` ~ ~ ~ 1J-174 L1 Drilling Hazards Summary ,, ~ ~ ,~ ;~ t m..> prepared by Mike Greener 9/14/2007 10:36 AM V V Wellhead / Tubing I Tree: 13-318" x 4112", 5,000 psi `" ~ Insulated Conductor: 20" 94# K-55x34" 0.312 WT +I- 80' ConocoPlli I li ps I 133/8" Casing Shoe, 68#, L-80, BTC ~ 4000' MD, 2265' ND, 75 deg inc Tubing String 41/2" 12.6#, L-00, IBTM 3.958" 10,3.833" Ordt 2007 West Sak Producer with Rotating self-Aligning Multilateral (RAMT"") System 10-31a'•73.z#,L-EO, BT~ca9ing Dual lateral Completion Lateral Entry Module 3800' MD 1 J-174 H B D LP With Diverters and Is ~~ v I?teral Access "FB" Diverter ' W P_11 gnatalre in LEM, GLM, Camco, 4112" x 1" KBMG, set @ <67 deg, +/- 2200' MD wile" ML Tor9ueMastar l~(~~ Pxkx ~~ ~~5 Baker Oil Tools mpKarea ~°rrxr L°vr~°n snap misnap ovt Orienting Prolik Poahlve Locating Collet (AUrmNC Mlgnm.m at, cu In Lateral Diverter Lateral Isolation +l- 7485 MD -Bottom of Motor Centralizer MMXangx) Ramp upper Seals Centralift 418 HP KMHFER with FC6000 Pump seal ogre rpr Lateral Isolation Dlvenar " Snap INSnap OUt ].ee ID Poskive Locating U_ ~ • \ ~~ 1U 0.Sand Casing Exit Collet = 11339' MD, 3120' ND, 'D' Sand Latera a l lateral n°wa`vnnaow '^«"«'«"""'"""`°""` L"e°"`°"`~' 83 deg inc rra.taraq oroen.n Lower xale itl RAM / (seals ins e Seal sore owerter) 7" X9S/8" RAM Hanger : GS Spear use0 for running and pulli ng dlverters 5.960" Lateral Dritt ID / 4.12" 11.6#, BTC, L$0 Slotted Liner 3.686" Mainbore Drg[ ID ` / i 4-112" Guitle S , 6.00" OD Equipment Specifications 7" X 9-5I8" RAM Junction Mainbore Drit: 7.68" Lateral Drit: 5.80" j RAM Hanger/Seal Bore Diverter OD: 8.775" J Overall Length of RAM Junction: 38.7 ft Seal Bore Diverter Running Tool: FJD RAM Hanger Running Tool: HRD-E 41/2" Lateral Entry Module LEM OD: 6.99" Mainbore Drrtt wlo Owerters: 3.68" Mainbore Drift w/ Isolation Divener: 2.50" Lateral Dnft wl "FB" Diverter: 3.68" OD of Diverters: ].68" 4Y." z 9-5/8" RAM Seal Bore Diverter (SBD) with 3.68" Swl Bore 4112" 126# IBTM Tubing T' X 9-518" MLZXP Liner Hanger Pxker Set at+l- 11,440 Sealbore Receptacle 4.75"ID 11.6#, L-80 BTCM 3079' ND , As Planned Seal Assembly 'l3' Sand Lateral 4.75" Seal OD 3.875"ID S1/2" 16.5#, BTC, L-80 Slotted Llrrer / 5112" Eccentric Guide Shoe # <..., 5112" Casing Shoe, 15.5#, LAO BTCM -- ~~ ~ ~ ~~~ ~- ~19696'MD, 3156'TVD 9-518" Casing Shce, 40.0#, L-80 BTC 12000' MD, 3192' TVD, 84 deg inc 3.`582" De Nipple- V ML Production Anchor i ` 1 r ~ TRANSMITTAL LETTER CHECKLIST WELL NAME K~CC ~~- / ~7' L PTD# ~ ~ ^ ~ y Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT {OPTIONS) APPLIES MULTI LATERAL segment of existing The permit is for a new wellbo re P/ ' / well ~~~ ~~ ~~7 V (If last two digits in permit No. 2_U7 ~5~3, API No. 50-~- ~3 -~ API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_~ from records, data and logs acquired for well SPACING The permit is approved subject to ful! compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. , assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. SCompany Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 7/13/2007 CJ rn o Q N ~ o o ~ a~ o Q i c O N O W~ ~ O EO N O a` C "~ !6 N ai o Z O Z (6 .~ ~_ O ~ Z O J U Y >, U = W_ n O U U H ~ o W ~ ~ ~ 0 J N J W ~ d : : : : ~~ .c~ ~ ~ ~~ ~ ~~ ~ ~ ~~ ~ ~ ~~ ~~ : o: : ~ U: : ~~ a m' , o, S : o. -o. : O O, C, ~ ~ N. L• N d D L• N' ~ ; Q' N~ ~ ~ ~~ O a O C• ~~ ~~ y: O ~ : T ~- ~- Q~ ~~ ~ ~: c. ~ ~ T m ~ ~ ~: ~~ ~~ ~' ~; d o ° o; ~ ; _:.~ o: ~: ~~ o~~ ~ O; ~~ ~ ~~ ~ ~~ ~~ p. o ~ oo, : o. Q. a c. ~ ~ ~ ~ ~ ~ ~ o `o. p. ~r O. m. a~, : U. Q. Y: U. ~ ~ : : ~ ~ Q; o; m aNi; m; m, aNi; a~'i, a~'i' a`~i; a`~i; ayi; a~'i Q Q; Q, d, Z Z, }; } } } } } }' }, } } } Z', Z Z, Z LL T N~ ~ G ~ ; E. 3 : E. o : ~ ~ ~, ~ o, , : ~ o. ~ o. a`~; ~, ~ : O. ~, ~ o. ~, r D. m a, ~ ~ m' '~, ~ ~~ : ~ a' ~ s, ~~ o~ ~~ a ~ o: o~ ~~: a m. a~: `o, : r w ~ ~ a. o, m. m w o' o, Q N c, o. o o a~ >, o~~ a m m: ~~ ~: fly ~~ ~: Q~ N~ ~~ ~: L• L• ~ N• ~: 7. Ul, (O, p ~ : r~~ ~' N: a O. ~. ~ ~ ~ $ N~ V3D Q C ~ N. U, 4 is ~ _: a a a v. c. ~, .Q, n. .fl a: ~: o : ~ = O O O •U ~ (6 f4 Q ~ N: ~ O ~ aoi, .~ m o o' ~' a n ~ ~ ~ ~ ~ 3: ~ o a, ~, ~, ~; ~; ~; m, O, O, a a U ~' ¢; a Z' N M~~ c0 I~ W O O N M ct ~ cD h ~ --- 0 0 ~ ~ N ~ 0 N O w .~ ~ a Q N : 3 ~: : N: : o: : o_ a o`. ~~ (0. ~ fl' ~ Q -o. o: a v. N O: ~ ~ ~ ~' p Q ~ ~ f6. ~ ~ a ~, ~ ~ ~ ~~ ~' ~~ ~ m; ~ a. ~ ~; ~ N ~ C• ~ ~ ~: ~ Z ~ ~, ~ ~ a M. ~ Y O. • ~~ ~ ~~ ~ ~~ y ~ N~ ~ N. ~ m a~: o ~: Y: ~~ d'~ ~ ~~ a U: ~~ ~ Z. ~: D. ~ M: ~ 07 ~' U', ~ ~ m. ~ ~ : ~ ~ ~ ~ 4 ~ o. o: ~ ~ M c. ~- w, ~~ o y 4 m. a m v ~~ ~ f~q~~ C ~ ~~ L N ~ ~ ~ a ~ ~U) (4 U ~ O x' ~ .U ~ ~ O, ~ 01 O`~ (O. ~ Q• ~ ~ N• U Q in a in. O ~: a`~ m ~ ~ _ Q; Q; Q', Q; o; Q; aNi; Q, a Q; a`~i, aNi; ai; ayi; a o; Q z, z z z z, z } z, }; z,} } } } }' z z, : : 3; r c~' ~~ ~~ ~~ ~~ ~~ ~~ a, ~~ ~ ~~ ~~ aoi~ ~ ~~ a~: ~: N ~: ~ ~: o: w, o. o pQ ~ f6. ~ V, ~ ~ LLy ~~ U. N N, ~ C COQ Vl, ~ ~~ ~~ 3' ~ >: p: a' o: ~ ~ ~ ~ .4 o rr a. O ~: ~ ~ s. ~ y: o ~ ~ o Q. o. L: m. m. o: o: rn o d t ~ U• .-~~ ~: ~ C• N, o. ° of ~ U 'a n. °- ~: .~ o. ~ a, .~ ~: 3 o ai c a o, m. ~: o m. ~: Q: m: m m o' o' m' ° Z o o ~_ ~~ 3 0 o a~ Y, ~, ~ N ai a co ca ~ rn m' o o' `os ~ v. '3. N. 00 0 0 N M~~ CO I~ M 0 0 N M V N N N N N N N N N N M M _M M M -- - n - -- 0 0 N 0 N G O m .~_ C Q W IW ~; ; ~' ~ E. '3 L• 3, w ~: ~ 4 v. w ~ O. N O N Oi ~~ V: N• X. N. N. p, N. ~ m ~O: C: ~: N, ~: r N. ~ ~: •3 ~ 4 _; w' ~: ~ a O : ~ , ~: r N• ~: f6. N j. ~ ~ ~ a' ~ ~' _ a o, 3. •a, _ ~ ~ '~ 3: o°-. N. y: to 3. ~: od ~, ~, ~, U' ~ ~ ~ 3 m a a a n ~ F- N a 0 0 a~, m, Q', Q', Q, } } Z, Z, Z o, 0 o' o- ~ y ~: N -oa, ~ o ~' ti ~' '~' N' ar N of ~, ar c. p. a N' ~ a o `~' ~ ~, ~, Y a. o. a> o. o m 3 ~«_. o: O 'C p. T 3, o' s: ~ V/ N~ p~ N~ C~ ,_~ N: 4?, >. :0 N~ U' Q U ~, U• E' co ~' m c m. ~ •a~ a~, o, a, o, v~, cn, U. l!') C4 f~- 00 O) M M M_ M M 0 0 N ~ N 0 rn Q ~ C7 D O U a O Q N C 0 N O f6 a f6 O L U G f6 (6 .N L F- O a a C f6 0 Y m O A ~, N f6 0 Q . a 0 U a~ q 0 ~__\\ 'V rn ~ o ~~ ~ c .O W U ~~` w3 cam/ m D °-- a~ U C O O ~ C7 E O /'1 U `/v~/I Well History File APPENDIX • Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infom~ation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. 1J-174Llredo.txt Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Jun 03 12:05:40 2008 Reel Header Service name .............LISTPE Date . ...................08/06/03 Origin ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date . ...................08/06/03 Origin ...................STS Tape Name...... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS writing Library Physical EOF Comment Record TAPE HEADER Kuparuk River unit, west Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 2 JOB NUMBER: Mw-000527561 LOGGING ENGINEER: B. HENNINGSE OPERATOR WITNESS: M. THORNTON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD i scientific Technical Services scientific Technical services 1J-174 L1 500292337460 ConocoPhillips Alaska, Inc Sperry Sun 03-JUN-08 MWD RUN 10 MW-000527561 B. HENNINGSE M. THORNTON 35 11N l0E 1724 2471 .00 121.53 81.00 Page 1 • • 1J-174Llredo.txt OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 10.750 3927.0 2ND STRING 8.500 9.625 11366.0 3RD STRING PRODUCTION STRING REMARKS: 1. THIS FILE IS A RE-ISSUE OF THE .TIF FILE CREATED 4-22-08, AND PRESENTS COMPLETE MERGED AND RUN DATA. THIS SUPERCEDES ALL PREVIOUS FILES CREATED. 2. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 3. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 4. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 5. MWD RUNS 2, 10 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4), AND AT -BIT GAMMA (ABG). THIS WELL BORE EXITS 1J-174 AT 11366'MD/ 3128'TVD. LOG DATA ABOVE THIS POINT CAN BE FOUND ON THE 1J-174 MAIN WELL BORE LOG SUITE. 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM MIKE WERNER OF CONOCOPHILLIPS ALASKA, INC. TO R. KALISH OF SPERRY DRILLING SERVICES. MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1,2, & 10 REPRESENT WELL 1J-174 L1 WITH API#: 50-029-23374-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 19750'MD/3054'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC = SMOOTHED DUAL GAMMA RAY COMBINED SEXP = SMOOTHED EXTRA-SHALLOW PHASE SHIFT RESISTIVITY SESP = SMOOTHED SHALLOW PHASE SHIFT RESISTIVITY SEMP = SMOOTHED MEDIUM PHASE SHIFT RESISTIVITY SEDP = SMOOTHED DEEP PHASE SHIFT RESISTIVITY SFXE = SMOOTHED RESISTIVITY FORMATION EXPOSURE TIME-HOURS SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 Page 2 i • 17-174Llredo.txt FT FOR ALL CURVES. File Header Service name... .......STSLIB.001 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/03 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPD RPM RPS RPX FET ROP 1 clipped curves; all bit runs merged. .5000 START DEPTH 3994.0 4008.0 4008.0 4008.0 4008.0 4013.0 4031.0 STOP DEPTH 19712.5 19705.0 19705.0 19705.0 19705.0 19705.0 19750.0 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 MERGE TOP MERGE BASE 2 3994.0 11366.0 10 11366.5 19750.0 REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD FPH 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 Page 3 • • 17-174Llredo.txt RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 3994 19750 11872 31513 3994 19750 ROP MWD FPH 0 10615.6 258.685 31439 4031 19750 GR MWD API 22.62 109.98 64.9185 31438 3994 19712.5 RPX MWD OHMM 2.82 2000 38.0521 31395 4008 19705 RPS MWD OHMM 1.3 2000 37.6975 31395 4008 19705 RPM MWD OHMM 1.57 2000 38.3374 31395 4008 19705 RPD MWD OHMM 1.75 2000 40.5679 31395 4008 19705 FET MWD HR 0.13 572.37 0.659862 31385 4013 19705 First Reading For Entire File..........3994 Last Reading For Entire File...........19750 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/03 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.001 comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3994.0 11366.0 RPx 4008.0 11366.0 RPD 4008.0 11366.0 RPS 4008.0 11366.0 RPM 4008.0 11366.0 FET 4013.0 11366.0 ROP 4031.0 11366.0 Page 4 s • 17-174Llredo.txt LOG HEADER DATA DATE LOGGED: 26-NOV-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11366.0 TOP LOG INTERVAL (FT): 3994.0 BOTTOM LOG INTERVAL (FT): 11366.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 76.3 MAXIMUM ANGLE: 86.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124724 EWR4 ELECTROMAG. RESIS. 4 63122 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 3927.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 8.90 MUD VISCOSITY (S): 60.0 MUD PH: 10.1 MUD CHLORIDES (PPM): 200 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.900 72.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.146 123.8 MUD FILTRATE AT MT: 1.700 75.0 MUD CAKE AT MT: 2.000 74.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FPH 4 1 68 4 2 Page 5 • 1.7-174Llredo.txt GR MWD020 API 4 1 68 8 3 RPX MwD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MwD020 HR 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 3994 11366 7680 14745 3994 11366 ROP MWD020 FPH O 10615.6 233.976 14671 4031 11366 GR MWD020 API 22.62 109.98 64.1171 14745 3994 11366 RPX MWD020 OHMM 2.82 31.12 10.5825 14717 4008 11366 RPS MWD020 OHMM 1.3 47.68 12.7219 14717 4008 11366 RPM MWD020 OHMM 1.57 58.3 13.3639 14717 4008 11366 RPD MWD020 OHMM 5.6 1394.79 13.9172 14717 4008 11366 FET MwD020 HR 0.13 80.46 0.746817 14707 4013 11366 First Reading For Entire File..........3994 Last Reading For Entire File...........11366 File Trailer Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/03 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 11366.5 19705.0 RPM 11366.5 19705.0 RPS 11366.5 19705.0 RPx 11366.5 19705.0 GR 11366.5 19712.5 ROP 11366.5 19750.0 Page 6 17-174Llredo.txt FET 11366.5 19705.0 LOG HEADER DATA DATE LOGGED: 22-DEC-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 19750.0 TOP LOG INTERVAL (FT): 11366.0 BOTTOM LOG INTERVAL (FT): 19750.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: $3,$ MAXIMUM ANGLE: 94.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 119546 EWR4 ELECTROMAG. RESIS. 4 127479 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 16.000 DRILLER'S CASING DEPTH (FT): 11366.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 70.0 MUD PH: .O MUD CHLORIDES (PPM): 34000 FLUID LO55 (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 123.8 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth Units. .. .. ..... Datum specification Block sub-type...0 Page 7 • 17-174Llredo.txt Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD100 FPH 4 1 68 4 2 GR MWD100 API 4 1 68 8 3 RPX MWD100 OHMM 4 1 68 12 4 RPS MWD100 OHMM 4 1 68 16 5 RPM MWD100 OHMM 4 1 68 20 6 RPD MWD100 OHMM 4 1 68 24 7 FET MWD100 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11366.5 19750 15558.3 16768 11366.5 19750 ROP MWD100 FPH 0 687.24 280.303 16768 11366.5 19750 GR MWD100 API 40.39 104.16 65.6264 16693 11366.5 19712.5 RPX MWD100 OHMM 9.1 2000 62.2919 16678 11366.5 19705 RPS MWD100 OHMM 9.23 2000 59.7365 16678 11366.5 19705 RPM MWD100 OHMM 8.83 2000 60.3746 16678 11366.5 19705 RPD MWD100 OHMM 1.75 2000 64.0849 16678 11366.5 19705 FET MWD100 HR 0.13 572.37 0.583183 16678 11366.5 19705 First Reading For Entire File..........11366.5 Last Reading For Entire File...........19750 File Trailer service name... .......STSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/03 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.004 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/06/03 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS writing Library. Reel Trailer Service name .............LISTPE Date . ...................08/06/03 on 9in ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical services scientific Technical services Page 8 i 1]-174Llredo.txt Physical EOF Physical EOF End Of LIS File • Page 9 1J-174Ll.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Apr 22 13:39:07 2008 Reel Header Service name .............LISTPE Date . ...................08/04/22 Ori in ...................STS Ree~ Name. .... ........UNKNOWN continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS writing Library. Tape Header Service name .............LISTPE Date . ...................08/04/22 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS writing Library. Physical EOF Comment Record TAPE HEADER Kuparuk River unit, west Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 2 JOB NUMBER: MW-000527561 LOGGING ENGINEER: B. HENNINGSE OPERATOR WITNESS: M. THORNTON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD scientific Technical services scientific Technical services 1J-174 L1 500292337460 ConocoPhillips Alaska, Inc Sperry Sun 22-APR-08 MWD RUN 10 Mw-000527561 B. HENNINGSE M. THORNTON 35 11N l0E 1724 2471 .00 121.53 81.00 Page 1 ~Co~~~ • 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1J-174Ll.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 10.750 3927.0 8.500 9.625 11366.0 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 4. MWD RUNS 2, 10 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) , ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4), AND AT -BIT GAMMA (ABG). THIS WELL BORE EXITS 1J-174 AT 11366'MD/ 3128'TVD. LOG DATA ABOVE THIS POINT CAN BE FOUND ON THE 1J-174 MAIN WELL BORE LOG SUITE. 5. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM MIKE WERNER OF CONOCOPHILLIPS ALASKA, INC. TO R. KALISH OF SPERRY DRILLING SERVICES. MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1,2, & 10 REPRESENT WELL 1J-174 L1 WITH API#: 50-029-23374-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 19750'MD/3054'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC = SMOOTHED DUAL GAMMA RAY COMBINED SEXP = SMOOTHED EXTRA-SHALLOW PHASE SHIFT RESISTIVITY SESP = SMOOTHED SHALLOW PHASE SHIFT RESISTIVITY SEMP = SMOOTHED MEDIUM PHASE SHIFT RESISTIVITY SEDP = SMOOTHED DEEP PHASE SHIFT RESISTIVITY SFXE = SMOOTHED RESISTIVITY FORMATION EXPOSURE TIME-HOURS SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name... .......STSLIB.001 Service Sub Level Name... Page 2 17-174Ll.tapx version Number. ........1.0.0 Date of Generation.......08/04/22 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE ROP FET RPD RPM RPS RPX GR 1 clipped curves; all bit runs merged. .5000 START DEPTH 11300.0 11300.0 11300.0 11300.0 11300.0 11300.0 11300.0 STOP DEPTH 19750.0 19705.0 19705.0 19705.0 19705.0 19705.0 19712.5 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 MERGE TOP MERGE BASE 2 11300.0 11366.0 10 11366.0 19750.0 REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loggin Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD FPH 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 Page 3 • 1)-174Ll.tapx First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 11300 19750 15525 16901 11300 19750 ROP MWD FPH 0 687.24 279.701 16901 11300 19750 GR MWD API 40.39 104.16 65.7148 16826 11300 19712.5 RPX MWD OHMM 8.31 2000 61.9029 16811 11300 19705 RPS MWD OHMM 9.23 2000 59.3919 16811 11300 19705 RPM MWD OHMM -8.83 2000 60.0382 16811 11300 19705 RPD MWD OHMM 1.75 2000 63.7372 16811 11300 19705 FET MWD HR 0.13 572.37 0.580967 16811 11300 19705 First Reading For Entire File..........11300 Last Reading For Entire File...........19750 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/22 Maximum Physical Record..65535 File Ty e ................L0 Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/22 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPx 11300.0 11366.0 FET 11300.0 11366.0 RPD 11300.0 11366.0 RPS 11300.0 11366.0 Gr 11300.0 11366.0 ROP 11300.0 11366.0 RPM 11300.0 11366.0 LOG HEADER DATA DATE LOGGED: 26-NOV-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory Page 4 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 DGR EWR4 1]-174Ll.tapx BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 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 (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth Units. .. .. ..... Datum Specification Block sub-type...0 11366.0 11300.0 11366.0 76.3 86.0 TOOL NUMBER 124724 63122 12.250 3927.0 Fresh water Gel 8.90 60.0 10.1 200 .0 1.900 72.0 1.146 123.8 1.700 75.0 2.000 74.0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RoP MwD020 FPH 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HR 4 1 68 28 8 Page 5 17-174Ll.tapx • First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 11300 11366 11333 133 11300 11366 ROP MWD020 FPH 30.92 260.33 203.719 133 11300 11366 GR MWD020 API 53.6 94.43 76.8029 133 11300 11366 RPX MWD020 OHMM 8.31 31.12 13.1223 133 11300 11366 RPS MWD020 OHMM 9.88 47.68 16.1738 133 11300 11366 RPM MWD020 OHMM 10.44 58.3 17.8563 133 11300 11366 RPD MWD020 OHMM 10.46 60.19 20.1271 133 11300 11366 FET MWD020 HR 0.19 0.57 0.303083 133 11300 11366 First Reading For Entire File..........11300 Last Reading For Entire File...........11366 File Trailer service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/22 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/04/22 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 11358.5 19705.0 RPM 11358.5 19705.0 RPS 11358.5 19705.0 RPx 11358.5 19705.0 FET 11358.5 19705.0 GR 11366.5 19712.5 ROP 11366.5 19750.0 LOG HEADER DATA DATE LOGGED: 22-DEC-07 SOFTWARE Page 6 C~ 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 DGR EWR4 17-174Ll.tapx BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA Insite 6.02 Memory 19750.0 11366.0 19750.0 83.8 94.4 TOOL NUMBER 119546 127479 OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 11366.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 70.0 MUD PH: .O MUD CHLORIDES (PPM): 34000 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 123.8 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name service order units Size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 ROP MwD100 FPH 4 1 68 4 2 GR MWD100 API 4 1 68 8 3 RPX MWD100 OHMM 4 1 68 12 4 RPS MWD100 OHMM 4 1 68 16 5 Page 7 ~ ~ 17-174Ll.tapx RPM MWD100 OHMM 4 1 68 20 6 RPD MWD100 OHMM 4 1 68 24 7 FET MWD100 HR 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 11358.5 19750 15554.3 16784 11358.5 19750 ROP MWD100 FPH 0 687.24 280.303 16768 11366.5 19750 GR MWD100 API 40.39 104.16 65.6264 16693 11366.5 19712.5 RPX MWD100 OHMM 3.76 2000 62.682 16694 11358.5 19705 RPS MWD100 OHMM 0.1 2000 60.1026 16694 11358.5 19705 RPM MWD100 OHMM 3.19 2000 61.1445 16694 11358.5 19705 RPD MWD100 OHMM 0.02 2000 64.6917 16694 11358.5 19705 FET MWD100 HR 0.13 572.38 1.13112 16694 11358.5 19705 First Reading For Entire File..........11358.5 Last Reading For Entire File...........19750 File Trailer service name... .......STSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/22 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.004 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/04/22 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Reel Trailer Service name .............LISTPE Date . ...................08/04/22 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Physical EOF Physical EOF Library. scientific Technical services Library. scientific Technical services Page 8 1.7-174Ll.tapx End Of LIS File Page 9
