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188-064
STATE OF ALASKA AL .:A OIL AND GAS CONSERVATION CON. SSION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing p Operations Shutdown r Performed Suspend r r Other Stimulate r Alter Casing J'� Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Scab Liner Fi 2.Operator Name: 4.Well Class Before Work. 5.Permit to Drill Number: ConocoPhillips Alaska, Inc Development p Exploratory r 188-064 - 3.Address: 6.API Number. P. 0. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-029-21828-00 7.Property Designation(Lease Number): 8 Well Name and Number: ADL 25513 KRU 30-08 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s) none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7770 feet Plugs(measured) none true vertical 6934 feet Junk(measured) none Effective Depth measured 7663 feet Packer(measured) 5424,7189 true vertical 6849 feet (true vertical) 5137,6479 Casing Length Size MD TVD Burst Collapse CONDUCTOR 75 16 110 110 SURFACE 2584 10.75 2619 2619 PRODUCTION 7713 7 7746 6915 SCAB LINER 1784 5.5 7208' 4qq�� 6494 RECEIVED .IUL 2 2 2015 Perforation depth Measured depth: 7416-7432,7439-7462, 7476-7496 !V/1 P1G CC True Vertical Depth: 6656-6668,6673-6692,6703-6719 V Tubing(size,grade,MD,and TVD) upper-3.5", L-80, 7137' MD,6439'TVD and lower-3.5", L-80, 7189-7435' MD, 6479-6671 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER HRD-E ZXPN PACKER @ 5424 MD and 5137 TVD PACKER-BAKER F-1 PACKER @ 7189 MD and 6479 TVD SAFETY VLV-CAMCO TRMaxx-CMT-5-SR SSSV @ 2002 MD and 2002 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 164 578 541 -- 125 Subsequent to operation shut-in 14.Attachments(required per 20 AAC 25 070,25 071,&25.283) 15.Well Class after work: Daily Report of Well Operations r Exploratory r Development r Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt 315-340 Contact Janelle Nesvold @ 263-4641 Email Janelle.R.Nesvold(c�conocophillips.com Printed Name Janelle Nesvold Title Sr. Wells Engineer Signature / Phone:263-4641 Date ?pi-05 V L /z /i 5 ,# l�'�.//D' RBDMS1\ JUL 2 4 2015 Form 10-404 Revised 5/2015 Submit Original Only KUP PROD 30-08 f ConocoPhillips ° Well Attributes Max Angle&MD TD {Alcl"ks7,(r1C, Wellbore API/UWI Field Name Wellbore Status eel(°) MD(ftKB) Act Btm(ftKB) 0,,,,„,„,,,,„,p,1 500292182800 KUPARUK RIVER UNIT PROD 42.82 4,800.00 7,770.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 30-08,7/21/20151142:42 AM SSSV:TRDP Last WO: 6/16/2015 33.981 7/20/1988 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag'SLM 7,414.0 4/5/2015 Rev Reason:WORKOVER,PULL PLUG,PULL smsmith 7/16/2015 HANGER;33.0 !tipg CATCHER,PULL SOV,SET WHIPSTOCK ,,,'a„"'a.,U,.''....,.'„"'.,'",..„,...„""" II ,., "„.Casing Strings ' I . J Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Sat Depth(TVD)... WE/Len(I...Grade Top Thread CONDUCTOR 16 15.062 35.0 110.0 110.0 62.50 H-40 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread SURFACE 10 3/4 9.794 35.0 2,619.0 2,618.8 45.50 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 33.0 7,746.3 6,915.4 26.00 J-55 BTC CONDUCTOR;35.0-1100 , Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..f Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING-UPPER- 31/2 2.992 33.0 7,13721 6438.8 9.30 L-80 EUE Brd Mod SSSV;2,0016 /._i':i WO 2015 Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Hem Des Com (in) 11 33.0 33.0 0.32 HANGER CAMERON GEN IV TUBING HANGER 2.950 Gas LIFT:2,497.1 2,001.8 2,001.6 0.55 SSSV CAMCO CMT-5-SR W/X PROFILE 2.813 illi 7,117.5 6,423.6 39.40 LOCATOR BAKER GBH-22 LOCATOR SUB 3.000 7,118.0 6,424.0 39.39'SEAL ASSY BAKER 80-40 GBH-22 SEAL ASSEMBLY 3.000 Tubing Description (string Ma...I ID(in) (Top(MB) -Set Depth(ft..f Set Depth(TVD)(...1WI(lb/ft) (Grade (Top Connection TUBING-SCAB 51/2 4.950 5,423.8 7,20821 6,493.8 15.50 L-80 BTCM SURFACE;35.0-2,619.o- 4° LINER-WO 2015 Completion Details al Nominal ID GAS LIFT;3,719.2 Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 5,423.8 5,136.4 41.83 PACKER BAKER HRD-E ZXPN LINER TOP PACKER 4.890 ® 5,439.3 5,148.0 41.77 HANGER BAKER HMC LINER HANGER 4.860 11 5,448.3 5,154.6 41.74 Liner Liner,5-1/2",15.58,L-80,BTCM-SCC,Box x Pin 4.950 GAS LIFT:4782.9 a 7,122.7 6,427.6 39.38 XO Reducing Crossover,5-1/2"BTC Box x 5"BTC Box 4.380 a 7,125.0 6,429.4 39.38 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 all 7,143.5 6,443.7 39.34 XO Reducing Crossover,5"BTC Box x 3-1/2"EUE 8rd Pin 2.980 GAS LIFT:5.3746 7,186.7 6,477.2 39.26 LOCATOR BAKER GBH-22 LOCATOR SUB 2.990 7,187.2 6,477.5 3926 SEAL ASSY rBAKER 80-40 GBH-22 SEAL ASSEMBLY 2.990 4. Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING-LOWER- 51/2 5.012 7,189.3 7,435.0 6,670.6 14.00 J-55 STC PACKER:5,423.8 WO 2015 r' Completion Details I Nominal ID Top(ftKB) ,Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 7,189.3 6,479.2 39.25 PACKER BAKER F-1 PRODUCTION PACKER 4.000 GAS LIFT,6,5613 I. 7,192.6 6,481.7 39.24 SBE BAKER 80-40 SEAL BORE EXTENSION 3.990 III � 7,212.0 6,496.7 39.19 XO Reducing Crossover,4-3/4"Stub Acme Box x 3-1/2"EUE 8rd Pin 2.930 7,292.1 6,558.9 38.95 Coupling Coupling,3-1/2"EUE 8rd Mod Box x Box 2.992 GAS LIFT'7.063.1 7,292.6 6,559.3 38.95 NIPPLE HALLIBURTON X NIPPLE 2.813 IIIIII 7,345.7 6,600.6 38.67 Ported Ported Crossover,3-1/2"EUE 8rd Mod Box x 5-1/2"STC 2.992 Crossover Pin 7,346 7 6,601.4 38.67 WEARSOX 6"OD Wearsox,5-1/2",146,J-55 STC Box x Pin 5.012 LOCATOR 7,1175 l� Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Intl XO Reducing 7 1226 `�.r Top(ftKB) (ftKB) I (°) I Des I Com Run Date ID(in) SEAL ASSY,7,118.0 We 7,583.0 6,786.8 38.20 FISH 8'Metal Strip From Ped Gun;Left in Hole 6/6/1989 SEE;7,125.0 4, IS Perforations&Slots XO Reducing;7,143.5lirt Shot Dens illTop(TVD) Blot(TVD) (shotslf Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 7,416.0 7,432.0 6,655.7 6,668.3 A-3,30-08 6/6/1989 12.0 APERF 2 1/8"EnerJet;60 deg. LOCATOR:7,186.7 j phasing 7,439.0 7,462.0 6,673.7 6,691.8 A-2,30-08 6/60989 - 12.0 APERF 2 1/8"EnerJet;60 deg. PACKER;7,189 3- NE,. phasing SEAL ASSY',7,187.2 s SBE,7,1926 4'. 7,476.0 7,496.0 6,702.8 6,718.5 A-1,30-08 9/22/1988 8.0 IPERF 4 1/2"HSD Ultrapak;45 tidsP deg.phasing i. Mandrel Inserts • St II i on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 2,497.1 2,496.8 CAMCO KBMG 5.55 GAS LIFT DMY BK-5 1.000 0.0 6/25/2015 NIPPLE;7,2926 2 3,7192 3,718.0 CAMCO KBMG 5.55 GAS LIFT DMY BK-5 1.000 0.0 6/25/2015 • 3 4,782.9 4,662.6 CAMCO KBMG 5.55 GAS LIFT DMY BK-5 1.000 0.0 6/25/2015 I 4 5,374.6 5,099.8 CAMCO KBMG 5.55 GAS LIFT DMY BK 1.000 0.0 6/25/2015 5 6,561.3 5,997.1 CAMCO KBG-2- 4.851 GAS LIFT DMY DK 1.000 0.0'6/25/2015 Ported Crossover 7,3456 9 6 7,063.1 6,381.6 CAMCO KBG-2- 4.851 GAS LIFT DMY DK 1.000 0.0 6/25/2015 9 WEARSOX,7,346.6 I Notes:General&Safety APERF;7416.0-7,4320-� I End Dale Annotation 7/10/1994 NOTE:WAIVERED WELL:IA x OA COMMUNICATION 2/28/2010 NOTE'View Schematic w/Alaska Schemtic9.0 APERF:7439.0-7,462.0-- 7/21/2015 NOTE:Upper tubing is 3 1/2"9.3#L-80 EUE 8rd Mod to 5381'MD XO to 31/2"9.36 L-80(BTM to 7137' NOTE:Lower tubing is 3 1/2"9.3#L-80 from 7189'-7345',X0 to 5 1/2"14#J-55 from 7345'-7435' IPERF;7476.0-7,4960 FISH:7,583.0 PRODUCTION:33.0-7,746.3 3r' `18 WELL WORK SUMMARY DATE SUMMARY PRE-RIG WELL WORK 5/5/2015 PULLED STA.#6 RM-DMY @ 7,148' RKB. LEFT POCKET OPEN. PULLED 3.5" BAIT SUB W/2.5" GUTTED BAIT SUB FROM 7240' RKB. PULLED CA-2 PRONG 7240' RKB. *IN PROGRESS 5/6/2015 PULLED 2.75" CA LOCK W/SOFT SET& GAUGES FROM 7240' RKB. RAN STRING SHOT. 10' SHOT INTERVAL=7167'-7177' RKB. RAN 2.625" CHEM CUT; CUT DEPTH WAS 7172' RKB. READY FOR BPV. 5/13/2015 (PRE RWO) FUNCTION TESTED ALL LDS'S AND GN'S(ALL FUNCTIONED CORRECTLY) 5/31/2015 MEASURED BHP @ 7116' SLM. READY FOR BPV(PRE-RIG) POST-RIG WELL WORK 7/10/2015 PULLED SOV AND SET DV @ 5375' RKB. PULLED CATCHER @ 7293' RKB. MIT-T @ 2500 PSI: PASSED. MIT-IA @ 2500 PSI: PASSED. EQUALIZED AND ATTEMPTED PULL PLUG @ 7293' RKB. IN PROGRESS. 7/11/2015 BAILED ON PLUG @ 7293' RKB. ATTEMPTED PULL SAME. IN PROGRESS. 7/12/2015 PULLED PLUG @ 7293' RKB. TAGGED @ 7432' SLM. MEASURED BHP @ 7435' RKB: 3524 PSI. DRIFTED w/ DUMMY WHIPSTOCK TO 7444' RKB. READY FOR INJ TEST& E/L SET W/S. Conoco hillips Time Log & Summary Wel/view Web Reporting Report Well Name: 30-08 Rig Name: NABORS 9ES Job Type: RECOMPLETION Rig Accept: 6/17/2015 2:00:00 AM Rig Release: 6/26/2015 6:00:00 AM Time Logs Date From To Dur S. Deoth E. Depth Phase Code Subcode T Comment 36/16/2015 24 hr summary Jack up the pits and pull pits forward away from the sub. Jack up the sub and move the sub off 30-02A. Continue to offload fluid from the pits. 30-08 well pressures: OA=580 psi, IA= 1100 psi, and tubing= 1200 psi (under BPV; recorded from BPV tag on wellhead). Spot matting boards/herculite around the well, stage equipment in the behind the well, and hang the tree in the cellar. Spot the sub over well 30-08 and spot the pits to the sub. 12:00 16:00 4.00 0 0 MIRU MOVE RURD P RD the pits and offload remaining fluid from the pits. Clean up and secure the cellar 16:00 17:00 1.00 0 0 MIRU MOVE MOB P Jack up the pits, pull matting boards, and pull pits forward away from the sub. 17:00 18:30 1.50 0 0 MIRU MOVE MOB P Jack up the sub, pull matting boards, and move the sub off 30-02A. Continue to offload fluid from the pits. 30-08 well pressures: OA=580 psi, IA= 1100 psi, and tubing=1200 psi (under BPV; recorded from BPV tag on wellhead). 18:30 20:00 1.50 0 0 MIRU MOVE MOB P Spot matting boards and herculite around the well. Stage equipment in the behind the well and hang the tree in the cellar. 20:00 22:00 2.00 0 0 MIRU MOVE MOB P PJSM. Spot the sub over well 30-08 and set matting boards. 22:00 00:00 2.00 0 0 MIRU MOVE MOB P PJSM. Spot the pits to the sub and set matting boards. 06/17/2015 Circulate 318 bbls of 10.8 NaCI/NaBr brine and shut down to empty kill tank. Tubing and IA at 0 psi; open up the tubing and IA and the well is on a slight vac. Install BPV, ND tree, install test dart in to BPV, NU DSA, and NU BOPE. Conducted initial BOPE test to 250/3000 psi: test 2-7/8"x 5"VBR's(lower pipe rams)and 3-1/2"x 6"VBR's(upper pipe rams)with 3-1/2"test joint;test annular to 250/3000 with 3-1/2"test joint; conducted CPAI Koomey Draw Down Test. All tested passed. The States right to witness was verbally waived by AOGCC inspector Louis Gramaldi on 6/16/15 via email 07:28 hours. Pull test dart/BPV. BOLDS, pull tubing free at 104K, pull hanger to the rig floor, and lay down tubing hanger. 00:00 02:00 2.00 0 0 MIRU MOVE RURD P Spot LEPD tank. Complete berming around rig, pits, LEPD tank, and cuttings box. Attach ground wire. Hook up interconnect,take pictures of the tree, break out 5'pup from TD, and record RKB's. *Rig Accepted at 2:00 hours* Page 1 of 14 'Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 06:00 4.00 0 0 MIRU WELCTL RURD P Start loading the pits with 11.0 ppg brine to dilute back to 10.8 ppg NaCI/NaBr(KWF). SimOps: Test gas alarms, RU the rig floor, RU in the cellar to kill the well, and RU hard line to the kill tank. 06:00 07:30 1.50 0 0 MIRU WELCTL MPSP P RU lubricator, PT to 2000 psi(good test), pull'H' BPV(tubing= 1150 psi and IA= 1200 psi), and RD lubricator. 07:30 08:30 1.00 0 0 MIRU WELCTL SEQP P PJSM. Purge lines, PT interconnect to 3500 psi(good test), verify flow line boots not leaking, and PT kill tank to 2500 psi(good test). 08:30 11:00 2.50 0 0 MIRU WELCTL KLWL P PJSM. SITP= 1100 psi and SICP= 1080 psi. Bleed gas off the tubing and IA(tubing =420 psi and IA= 150 psi). Circulate 10.8 ppg NaCl/NaBr down the tubing taking returns out the IA through the choke to the kill tank. Pumped 318 bbls and getting 10.7+ppg NaCl/NaBr back. Shut down to empty kill tank and shut in the well. 11:00 11:30 0.50 0 0 MIRU WELCTL OWFF P Observe the well for 30 minutes. Open the IA and tubing to verify flow and the well is on a slight vac. Blow down circulating equipment. 11:30 12:00 0.50 0 0 MIRU WHDBO MPSP P PJSM. Install'H' BPV per Cameron. 12:00 14:00 2.00 0 0 MIRU WHDBO NUND P PJSM. Bleed pressure off the control line and tubing head void. ND the tree, pull tree loose with TD, and set down in the cellar with the bridge crane. Clean and prep wellhead; install test dart into BPV. 14:00 15:30 1.50 0 0 MIRU WHDBO NUND P PJSM. NU DSA. NU BOPE, obtain RKB's, install riser, and install turnbuckles. SimOps: Start loading the pipe shed with 240 joints of 3-1/2"tubing(drift, strap, and tally).. 15:30 16:00 0.50 0 0 MIRU WHDBO RURD P RU BOPE testing equipment. Fill the BOPE and choke manifold with fresh water. Shell test the BOPE to 3000 psi. Page 2 of 14 'Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 21:00 5.00 0 0 MIRU WHDBO BOPE P Conduct initial BOPE test to 250/3000 psi: test 2-7/8"x 5"VBR's (lower pipe rams)and 3-1/2"x 6" VBR's(upper pipe rams)with 3-1/2" test joint;test annular to 250/3000 with 3-1/2"test joints. The states right to witness was waived by AOGCC inspector Louis Gramaldi on 6/16/15 via email 07:28 hours. Tests: #1)Annular with 3-1/2"test joint,TD Upper IBOP, Kill Demco, Chokes 1, 2, 3,&16(Passed) #2)Upper Pipe rams with 3-1/2"test joint, HCR Kill,TD Lower IBOP, Chokes 4, 5, &6(Passed) #3) Lower Pipe rams with 3-1/2"test joint, 3-1/2" EUE TIW(Passed) #4)Manual Kill, Blind rams, Chokes 7, 8, &9(Passed) #5)Manual Choke, Hydraulic Choke, HCR Kill(Passed) #6)Chokes 10& 11 (Passed) #7)Chokes 12, 13,& 14(Failed low test, grease/function, Passed) #8)Choke 15(Passed) #9)HCR Choke(Passed) #10)Manual Choke(Passed) #11)Blinds, HCR Kill, Outer Test Spool(Passed) #12)Inner Test Spool(Passed) Conduct CPAI Koomey Draw Down Test: Starting Accumulator Pressure= 2950 psi Accumulator Pressure After Closer= 1900 psi Pressure Gain of 200 psi=22 seconds Full System= 108 Seconds Average N2(6 Bottles)=2097 psi 21:00 21:30 0.50 0 0 MIRU WHDBO RURD P Blow down Iines,RD BOPE testing equipment,and drain the stack. 21:30 22:00 0.50 0 0 MIRU WHDBO OTHR P PJSM. RU Weatherford tubing pulling equipment. Change elevators to 3-1/2"tubing. RU SLB control line spooler. 22:00 22:30 0.50 0 0 MIRU WHDBO MPSP P MU pull tool, Check for pressure under BPV, no pressure, and pull test dart/BPV(well static). SimOps: Finished loading the shed with 240 joints of 3-1/2"tubing(drift, strap, and tally). Page 3 of 14 'Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 00:00 1.50 0 7,172 COMPZ RPCOM PULL P PJSM. BOLDS, pull tubing free at 104K, pull hanger to the rig floor, break out crossover, unscrew landing joint, lay down landing joint, and lay down tubing hanger. 06/18/2015 POOH laying down 3-1/2"tubing, spooling control line, and removing stainless steel bands. Lay down SCSSSV(recovered all 31 stainless steel bands),6 GLM's, and cut joint(13.25"). BOPE test to 250/3000 psi: test 2-7/8"x 5"VBR's(lower pipe rams)and 3-1/2"x 6"VBR's(upper pipe rams)with 4"test joint;test annular to 250/3000 with 4"test joint(all tests passed). PU, MU, and single in the hole with 5-3/4"overshot assembly for 3-1/2"tubing on 4" DP. 00:00 02:30 2.50 7,172 5,352 COMPZ RPCOM PULL P PJSM. POOH laying down 3-1/2" tubing, spooling control line, and removing stainless steel bands. Strapping and unloading the pipe shed as needed and monitoring the well on the trip tank. Lay down SCSSSV. Recovered all 31 stainless steel bands. 02:30 03:00 0.50 5,352 5,352 COMPZ RPCOM RURD P RD SLB control line spooler. 03:00 10:00 7.00 5,352 0 COMPZ RPCOM PULL P POOH laying down 3-1/2"tubing, 6 GLM's, and cut joint(13.25'). Strapping and unloading the pipe shed as needed and monitoring the well on the trip tank. 22 bbl/hr lose rate while POOH. 10:00 10:45 0.75 0 0 COMPZ RPCOM RURD P RD Weatherford tubing pulling equipment. Clean and clear the floor. 10:45 11:30 0.75 0 0 COMPZ RPCOM BOPE P RU to test BOPE with 4"and 5-1/2" test joint. Fill the BOPE and lines with freshwater. SimOps: Finish unloading the old 3-1/2"tubing from the pipe shed and begin loading the pipe shed with 4" DP. 11:30 13:00 1.50 0 0 COMPZ RPCOM BOPE P BOPE test to 250/3000 psi: test 2-7/8"x 5"VBR's(lower pipe rams) and 3-1/2"x 6"VBR's(upper pipe rams)with 4"test joint;test annular to 250/3000 with 4"test joint. Tests: 1) Dart Valve,Annular with 4"test joint(Passed). 2)4"TIW, Upper Pipe Rams with 4" test joint(Passed). 3) Lower Pipe Rams with 4"test joint (Passed). 13:00 13:30 0.50 0 0 COMPZ RPCOM BOPE T Lay down 4"test joint, PU 5-1/2"test joint, and 5-1/2"test joint had 5-1/2" BTC box top connection not 4-1/2" IF. Unable to find correct crossover and will test the BOPE with 5-1/2" test joint prior to running 5-1/2"liner. 13:30 14:00 0.50 0 0 COMPZ RPCOM RURD P Load fishing tools into the pipe shed and RU the rig floor to run DP. Page 4 of 14 'Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 16:30 2.50 0 0 COMPZ RPCOM RURD P Finish loading the pipe shed with 4" DP and six 4-3/4"DC's(strap and tally). 16:30 18:00 1.50 0 218 COMPZ RPCOM BHAH P PU and MU BHA#1 -5-3/4" Overshot assembly for 3-1/2"tubing. 18:00 00:00 6.00 218 7,067 COMPZ RPCOM PULD P Single in the hole with 4" DP from the pipe shed with BHA#1 to 7067' RKB(PU = 143K, SO= 120K). Lose rate at 6 bbl/hr. 06/19/2015 Engage overshot onto tubing stub at 7158', pulled seal assembly free with 37K over pull, TOOH standing back DP,and lay down seal assembly/cut joint. PU, MU, and TIH with spear, engage spear into PBR at 7176' RKB,jar packer free, closed upper pipe rams to circulate out packer gas, and TOOH. 00:00 00:45 0.75 7,067 7,128 COMPZ RPCOM FISH P PU two joints of DP and obtain parameters; PU = 143K, SO= 120K, and 2 BPM= 120 psi. SO,engage the fish at 7158'with 15K down, PU to 180K(37K over), and seal pulled free. PU and pull the seal assembly out of the PBR. 00:45 01:45 1.00 7,128 7,128 COMPZ RPCOM CIRC P Circulate the hole clean at 4.5 BPM =445 psi. 01:45 02:00 0.25 7,128 7,060 COMPZ RPCOM OWFF P Observe the well for flow,well on a slight vac. SimOps: Stand 1 stand of DP back and blow down the TD. 02:00 06:00 4.00 7,060 218 COMPZ RPCOM TRIP P TOOH standing back DP with BHA #1 -overshot assembly for 3-1/2" tubing and fished seal assembly. 06:00 07:30 1.50 218 0 COMPZ RPCOM BHAH P Stand back 2 stands of DC's, lay down BHA#1, and lay down fish(cut joint with seal assembly). Clean and clear the floor. 07:30 09:00 1.50 0 221 COMPZ RPCOM BHAH P Bring spear assembly to the rig floor. PU and MU BHA#2-spear assembly with 2 stands of DC's 09:00 10:30 1.50 221 3,500 COMPZ RPCOM TRIP P TIH with BHA#2 to 3500'RKB. 10:30 10:45 0.25 3,500 3,500 COMPZ RPCOM CIRC P Fill up the DP and break circulation at 3 BPM=380 psi. 10:45 12:00 1.25 3,500 7,165 COMPZ RPCOM TRIP P Continue to TIH with BHA#from 3500'to 7165' RKB(PU= 145K, SO =115K). 12:00 12:30 0.50 7,165 7,191 COMPZ RPCOM FISH P RIH to 7176' RKB, sting spear into PBR set 10K down, PU to 195K to confirm spear is engaged, SO 20K, PU to 200K to fire the jars, packer is free, and RIH to 7191' RKB. 12:30 13:00 0.50 7,191 7,191 COMPZ RPCOM CIRC P Circulate bottoms up staging the pumps up to 4 BPM=595 psi. At 1721 strokes return flow increased, and active pit gained 5 bbls(gas from below the packer). Shut down the pumps and shut in the well(closed the upper pipe rams and HCR Choke). SIDP=20 psi and SICP= 80 psi. Page 5 of 14 'Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:00 13:15 0.25 7,191 7,191 COMPZ RPCOM OWFF P Monitor the well shut in pressures: SIDP=20 psi, SICP= 180 psi. 13:15 13:45 0.50 7,191 7,191 COMPZ RPCOM CIRC P Circulate out the packer gas through the gas buster at 3 BPM=320 psi (10.8 ppg NaCI/NaBr in and out). Shut down the pumps. 13:45 14:00 0.25 7,191 7,191 COMPZ RPCOM OWFF P Monitor the well shut in pressures: SIDP=0 psi, SICP=0 psi. Open upper pipe rams. 14:00 15:45 1.75 7,191 7,191 COMPZ RPCOM CIRC P Circulate bottoms up at 2 BPM= 170 psi to ensure all the packer gas is out of the hole. 15:45 16:15 0.50 7,191 7,191 COMPZ RPCOM OWFF P Observe the well for flow;well on a slight vac. 16:15 17:30 1.25 7,191 7,351 COMPZ RPCOM JAR P PU to 1756' RKB and packer hung up. RIH to 7351'RKB(PU=145K, SO= 120K)to engage the jars, PU to 7156', PU to 225K,fire the jars, packer free, and SO to 7351' RKB to confirm packer is free(PU = 150K, SO= 120K). 17:30 18:45 1.25 7,351 6,315 COMPZ RPCOM TRIP P TOOH with BHA#2-spear assembly and PBR/packer assembly with tail pipe to 6315" RKB and packer hung up. 18:45 19:00 0.25 6,315 6,315 COMPZ RPCOM JAR P SO engage jars,fire jars twice, and work through tight spot. 19:00 00:00 5.00 6,315 221 COMPZ RPCOM TRIP P Continue to TOOH with BHA#2 from 6315'to 221' RKB. 36/20/2015 Lay down spear assembly and lay down AVA PBR and'RHS'packer(the packer was missing 4 dovetail slips),2 joints of 3-1/2"tubing, nipple,and shear out sub(SOS). Test BOPE components used to circulate out the packer gas with 4"test joint to 250/3000 psi and PT the BOPE with 5-1/2"test joint to 250/3000 psi. PU, MU, and TIH with cleanout assembly;cleanout to 7461' MD,TOOH standing back DP,and lay down cleanout assembly. PU and MU 2 wearsox joints, ported crossover, 1 joint of 3-1/2"tubing, nipple assembly, 2 joints of 3-1/2"tubing, packer/SBE assembly,J-hydraulic setting tool, and test packer. 00:00 00:15 0.25 221 221 COMPZ RPCOM OWFF P Observe the well for flow;well on a slight vac. SimOps: PJSM for laying down BHA. 00:15 00:30 0.25 221 221 COMPZ RPCOM RURD P RU Weatherford tongs. Change elevators from 4"DP to 3-1/2" DP for DC's. 00:30 01:15 0.75 221 0 COMPZ RPCOM BHAH P Lay down intensifier,stand back two stands of DC's, and lay down spear assembly. 01:15 01:45 0.50 85 0 COMPZ RPCOM PULL P Lay down AVA PBR and'RHS' packer(the packer was missing 4 dovetail slips), 2 joints of 3-1/2" tubing, nipple, and shear out sub (SOS) 01:45 02:00 0.25 0 0 COMPZ RPCOM RURD P RD Weatherford tongs. Change elevators to 4" DP. Clean and clear the floor. Page 6 of 14 'Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 03:30 1.50 0 0 COMPZ RPCOM BOPE P Drain the BOP stack, PU 4"test joint, MU 4" HT-40 TIW, pull the wear ring, set the test plug, fill the BOP stack with freshwater, and RU to test. 03:30 04:00 0.50 0 0 COMPZ RPCOM BOPE P Test BOPE components used during well closer to circulate out packer gas with 4"test joint to 250/3000 psi. The states right to witness was waived by AOGCC inspector Louis Grimaldi on 6/19/15 via email 18:31 hours. Test: 1) Upper pipe rams(3-1/2"x 6" VRB's)with 4"test joint,4"HT-40 TIW, HCR Choke(Passed) 04:00 04:30 0.50 0 0 COMPZ RPCOM BOPE P Break out 4" HT-40 TIW, lay down 4" test joint, PU 5-1/2"test joint, and MU 4"HT-40 TIW. 04:30 05:00 0.50 0 0 COMPZ RPCOM BOPE P BOPE test to 250/3000 psi: 3-1/2"x 6"VBR's(upper pipe rams)with 5-1/2"test joint and test annular to 250/3000 with 5-1/2"test joint. Tests: 1) Upper pipe rams with 5-1/2"test joint,4"HT-40 TIW(Passed) 1 2)Annular with 5-1/2"test joint,4" HT-40 TIW(Passed) 05:00 06:00 1.00 0 0 COMPZ RPCOM BOPE P Drain the stack, pull the test plug with 5-1/2"test joint, break out 4" HT-40 TIW, set wear ring, break out crossover, lay down 5-1/2"test joint, and blow down lines. 06:00 06:45 0.75 0 0 COMPZ WELLPF RURD P Bring string mills,flex joint, DP pup, and mule shoe to the rig floor. 06:45 08:00 1.25 0 232 COMPZ WELLPF BHAH P PU and MU BHA#3- cleanout assembly 08:00 11:00 3.00 232 7,425 COMPZ WELLPF TRIP P TIH with BHA#3 to 7425' RKB and tag fill with 10K down(PU= 150K, SO= 115K). PU and line up to circulate. 11:00 13:00 2.00 7,425 7,425 COMPZ WELLPF CIRC P Circulate bottoms up at 3 BPM = 260 psi. 13:00 15:00 2.00 7,425 7,461 COMPZ WELLPF REAM P Clean out fill from 7425'to 7461" RKB. PU = 153K, SO= 115K,40 RPM,torque=4.5K-5.5K ft-lbs, and 4 BPM=440. Pump hi-visc sweep to clean the hole and got frac sand over the shakers. 15:00 15:30 0.50 7,461 7,461 COMPZ WELLPF OWFF P Observe the well for flow,well on a slight vac. SimOps: Remove blower hose, blow down TD, install stripping rubbers, and line up on the trip tank. 15:30 18:30 3.00 7,461 232 COMPZ WELLPF TRIP P TOOH from 7461'to 232' RKB standing back DP. Page 7 of 14 'Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 19:00 0.50 232 232 COMPZ WELLPF SFTY P PJSM for laying down DC's and BHA. 19:00 20:00 1.00 232 0 COMPZ WELLPF BHAH P Change elevators to 3-1/2" DP. Lay down 6 DC's, and lay down BHA#3- cleanout assembly. Clean and clear the floor. 20:00 20:30 0.50 0 0 COMPZ WELLPF SVRG P Grease the crown,top drive and guide rails. 20:30 21:45 1.25 0 0 COMPZ RPCOM RURD P RU Weatherford tongs, 5-1/2"casing elevators, and 5-1/2"slips for Wearsoxs. Organize the pipe shed per running order. 21:45 22:00 0.25 0 0 COMPZ RPCOM SFTY P PJSM for picking up wearsoxs and packer/SBE assembly. 22:00 00:00 2.00 0 277 COMPZ RPCOM PUTB P PU and MU 2 wearsox joints, ported crossover, 1 joint of 3-1/2"tubing, nipple assembly, 2 joints of 3-1/2" tubing, packer/SBE assembly, J-hydraulic setting tool, and test packer. 06/21/2015 TIH with lower packer assembly with wearsoxs on 4" DP to 7411' RKB. Slip and cut 90'of drilling line. Wait for SLB Digital Slickline. Monitor the well on the trip tank. Spot SLB DSL unit and RU SLB DSL. RIH with CCL and gamma ray located the K-1 mark, correlate,tag 3-/2"x 2-3/8"crossover at 7183'SLM(7185'on DP tally)and RD SLB DSL. PU 2'to adjust depth from correlation to the K-1 marker,drop the setting ball,set F-1 packer per Baker rep and release J-hydraulic setting tool. Lay down 1 joint of DP and set test packer at 7113' RKB(center of element)with 20K down. PT the F-1 packer/'XX'plug combination to 2500 psi for 15 minutes(good test), TOOH and set the test packer at 5500' RKB(center of element)with 20K down. PT the 7"casing to 2500 psi for 15 minutes(good test). TOOH with test packer and J-hydraulic setting tool from 5500'to 825' RKB. 00:00 05:30 5.50 277 7,411 COMPZ RPCOM RCST P TIH with lower packer assembly with wearsoxs on 4"DP to 7411'RKB. 05:30 06:45 1.25 7,411 7,411 COMPZ RPCOM SLPC P Slip and cut 90'of drilling line. 06:45 07:15 0.50 7,411 7,411 COMPZ RPCOM SVRG P Service blocks,TD, crown, draw works, and adjust the brakes. 07:15 08:00 0.75 7,411 7,411 COMPZ RPCOM WAIT T Wait for SLB Digital Slickline. Monitor the well on the trip tank. SimOps: Calibrate block height. 08:00 09:30 1.50 7,411 7,411 COMPZ RPCOM WAIT T Wait for SLB Digital Slickline. Monitor the well on the trip tank. SimOps: Clean the rig,work on hazard hunt 09:30 10:00 0.50 7,411 7,440 COMPZ RPCOM ELOG P PU a single joint of DP from the pipe shed, RIH to 7440' RKB(PU= 145K, SO= 115K), MU XO's to 3-1/2"EUE 8rd,and MU 3-1/2" EUE 8rd TIW for digital slickline(DSL) 10:00 12:00 2.00 7,440 7,440 COMPZ RPCOM ELOG P Spot SLB DSL unit. PJSM. PU logging tools and lubricator. 12:00 12:30 0.50 7,440 7,440 COMPZ RPCOM SFTY P Crew change and PJSM for RU DSL. 12:30 14:30 2.00 7,440 7,440 COMPZ RPCOM ELOG P PU and MU DSL CCL and gamma ray,test tools, and MU lubricator. Page 8 of 14 'Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:30 16:30 2.00 7,440 7,440 COMPZ RPCOM ELOG P RIH with CCL and gamma ray, located the K-1 mark, correlate,tag 3-/2"x 2-3/8"crossover at 7183'SLM (7185'on DP tally). POOH with gamma ray and CCL. 16:30 18:00 1.50 7,440 7,440 COMPZ RPCOM ELOG P Lay down DSL tool and RD SLB DSL. 18:00 19:00 1.00 7,440 7,438 COMPZ RPCOM PACK P PU 2'to adjust depth from correlation to the K-1 marker, drop the setting ball, pump ball to seat(405 strokes), intial shear at 600 psi, bring the pressure up to 2600 psi hold, PU, overpulled 30K, SO, pressure up to 600 psi, and J-hydraulic setting tool released(lost 20K). 19:00 19:30 0.50 7,438 7,113 COMPZ RPCOM PRTS P Lay down 1 joint of DP, PU,and set test packer at 7113'RKB(center of element)with 20K down. PT the F-1 packer/'XX'plug combination to 2500 psi for 15 minutes(good test). 19:30 21:00 1.50 7,113 5,500 COMPZ RPCOM TRIP P TOOH with test packer and J-hydraulic setting tool to 5500'RKB (PU= 130K, SO= 100K) 21:00 22:00 1.00 5,500 5,500 COMPZ RPCOM PRTS P MU to the TD, RU on the test spool, circulate down the kill line, set the test packer at 5500' RKB(center of element)with 20K down, and close the upper rams. PT the 7"casing to 2500 psi for 15 minutes(good test). Open the upper rams. Blow down TD and kill line. 22:00 00:00 2.00 5,500 825 COMPZ RPCOM TRIP P TOOH with test packer and J-hydraulic setting tool from 5500'to 825' RKB. 06/22/2015 Continue to TOOH with DP, lay down test packer, and lay down J-hydraulic setting tool. PU and MU seal assembly, 1 joint of 3-1/2"tubing, seal bore extension assembly, 39 joints of 5-1/2" 15.5#liner, and HMC liner hanger/ZXPN liner top packer assembly. TIH with 5-1/2"scab liner assembly to 7221' RKB, PU, and pump 25 bbls of 10.8 ppg corrosion inhibited NaCI/NaBr followed by 92 bbls of 10.8 ppg brine. Engage seals into SBE, space out 3', pressure up to 2300 psi to set HMC liner hanger, pressure up to 3800 psi to shear ITTS, PU 5'to expose dog sub, set down 50K, and set ZXPN liner top packer. Close the annular and PT the ZXPN liner top packer/'XX'plug combination to 2500 psi for 15 minutes(good test). Swap the well over from 10.8 ppg brine to 8.45 ppg seawater and POOH laying down DP. 00:00 00:15 0.25 825 825 COMPZ RPCOM SVRG P Adjust the brakes on the draw works. 00:15 00:45 0.50 825 31 COMPZ RPCOM TRIP P Continue to TOOH with test packer and J-hydraulic setting tool from 825' .to 31'RKB. 00:45 01:30 0.75 31 0 COMPZ RPCOM BHAH P Change elevators from 4"DP to 3-1/2"tubing. Lay down test packer and J-hydraulic setting tool. PU spear and break out lifting sub 01:30 02:15 0.75 0 0 COMPZ RPCOM RURD P PJSM. PU Weatherford equipment and cup assembly. RU to run 5-1/2" scab liner. Page 9 of 14 'Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:15 05:30 3.25 0 1,793 COMPZ RPCOM PUTB P PJSM. PU and MU seal assembly, 1 joint of 3-1/2"tubing,seal bore extension assembly, 39 joints of 5-1/2" 15.5#liner, and HMC liner hanger/ZXPN liner top packer assembly. 05:30 06:00 0.50 1,793 1,793 COMPZ RPCOM RURD P RD Weatherford tongs and change elevators to 4" DP 06:00 11:30 5.50 1,793 7,221 COMPZ RPCOM RCST P TIH with 5-1/2"scab liner assembly on DP from 1793'to 7189' RKB. Tag top of F-1 packer at 7191' RKB and locate out at 7221'(PU= 145K, SO = 115K) 11:30 12:30 1.00 7,221 7,200 COMPZ RPCOM CRIH P PU seal out of the seal bore and pump 25 bbls of 10.8 ppg corrosion inhitbited NaCI/NaBr at 2 BPM = 180 psi followed by 92 bbls of 10.8 ppg NaCI/NaBr at 3 BPM=515 psi 12:30 13:00 0.50 7,200 5,420 COMPZ RPCOM PACK P Engage the seals and locate out with 3K down, PU to spaceout mark of 3', drop the setting ball and allow ball fall to seat. Pressure up to 2300 psi and SO 55K to set HMC liner hanger, PU15K, pressure up to 3800 psi to shear ITTS, bleed pressure to 0 psi, PU 5'to expose the dog sub, SO to tag, rotate at 10 RPM, and slace off 50K(good shear indication on weight indicator)to set ZXPN liner top packer(PU = 116K, SO= 110K). 13:00 13:30 0.50 5,430 5,420 COMPZ RPCOM PRTS P Close the annular and PT the ZXPN liner top packer/'XX' plug combination to 2500 psi for 15 minutes(good test). Bleed pressure to 0 psi and open the annular. 13:30 14:00 0.50 5,420 5,360 COMPZ RPCOM RURD P Lay down 2 joints of DP and prep pits to swap the well over to seawater. 14:00 15:00 1.00 5,360 5,360 COMPZ RPCOM DISP P Circulate the well from 10.8 ppg to 8.45 ppg seawater by pumping 45 bbl hi visc spacer followed by 8.45 ppg seawater at 8 BPM =600 psi. Shut down to monitor well. 15:00 16:30 1.50 5,360 5,360 COMPZ RPCOM CIRC T The well is out of balance,circulate another DP volume,well still out of balance, and pump 8.7 ppg dry job. 16:30 19:00 2.50 5,360 2,570 COMPZ RPCOM PULD P POOH laying down DP from 5360'to 2570' RKB. 19:00 19:30 0.50 2,570 4,376 COMPZ RPCOM TRIP P TIH with remaining 19 stands of DP in the derrick from 2570'to 4376' RKB. 19:30 23:00 3.50 4,376 43 COMPZ RPCOM PULD P POOH laying down DP from 4376' RKB to liner running/setting tool. 23:00 23:30 0.50 43 0 COMPZ RPCOM BHAH P Service break running tool and lay down. 23:30 00:00 0.50 0 0 COMPZ RPCOM RURD P MU wear ring pulling tool, pull wear ring, break out crossover,and lay down DP joint. Page 10 of 14 'Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/23/2015 24 hr Summary Rig up and RIH with 3-1/2"completion as per tally to 5,423'; observe string take weight every 30'after first GLM enter 5-1/2" Liner top. Work completion string down to 6,049', unable to work past. POOH with 3-1/2" completion to 3,200'standing back in derrick. 00:00 01:00 1.00 0 0 COMPZ RPCOM RURD P RU Weatherford tong, change elevators to 3-1/2"tubing, bring SLB spooling unit to the rig floor, and bring SLB basket to the rig floor. 01:00 09:00 8.00 0 5,129 COMPZ RPCOM PUTB P PJSM. PU, MU, and RIH with 3-1/2" tubing completion per tally to 5,129'. 09:00 10:00 1.00 5,129 5,129 COMPZ RPCOM RURD P Rig up Camco spooling unit. Hang Sheave in derrick. Connect control line to SSSV. 10:00 16:30 6.50 5,129 6,049 COMPZ RPCOM PUTB P Continue RIH with 3-1/2"tubing as per detail to 5,423'; 5-1/2"liner top. PUW/SOW 75K. Observe string taking 10K weight down at 5,430'. Work through. Observe string taking weight every—30'indicating 3-1/2" EUE collars hanging up on Liner top. Continue to pick up tubing to 6,049. Unable to work pipe down after second GLM went through liner top. 16:30 17:00 0.50 6,049 6,049 COMPZ RPCOM CIRC T PJSM. Observe fluid out of balance, pump 25 bbl dry job. 17:00 19:30 2.50 6,049 5,139 COMPZ RPCOM PULL T PJSM. POOH with 3-1/2" EUE completions, racking back stands to 5,139'. 19:30 20:00 0.50 5,139 5,109 COMPZ RPCOM PULL T Lay down SSSV. 20:00 21:15 1.25 5,109 4,550 COMPZ RPCOM PULL T POOH with 3-1/2"completion to 4,550'. 21:15 22:30 1.25 4,550 4,550 COMPZ RPCOM CIRC T Circulate and condition fluid-well still out of balance,observe 10.4 ppg fluid coming back. Circulate to even out fluid. 22:30 00:00 1.50 4,550 3,220 COMPZ RPCOM PULL T Continue to POOH, standing back stands to 3,220' 06/24/2015 Continue to POOH with 3-1/2"completion string. Observe damage on Seal assembly. Call out for new assembly. Rig up and test BOPE's 250/3000 psi with 3-1/2"test joint. All test pass. Accumulator test starting pressure 2900 psi, final pressure 1620 psi. First 200 psi recharge 31 sec. final 155 seconds. 6 N2 at 2066 psi. Pull test plug. Rig up and RIH with 3-1/2"completions, changing lower section to IBTM SCC to 5,880'. 00:00 01:30 1.50 3,220 1,742 COMPZ RPCOM PULL T Continue to POOH with 3-1/2" completion standing back in the derrick. 01:30 04:30 3.00 1,742 0 COMPZ RPCOM PULL T Continue to POOH laying down joints. 04:30 06:30 2.00 0 0 COMPZ RPCOM OTHR T Observe upper seals damaged on seal assembly. Discuss with Baker. Order out new seal assembly. Simops: Breakout pup joints on GLM and replace with IBTM pup joints. 06:30 07:00 0.50 0 0 COMPZ RPCOM RURD T Rig down Weatherford casing equipment. Page 11 of 14 'Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 08:30 1.50 0 0 COMPZ WHDBO RURD T Rig up to test BOPE's. Set test plug as per Cameron. 08:30 12:30 4.00 0 0 COMPZ WHDBO BOPE T Test BOPE's 250/3000psi with 3-1/2" test joint. Right to witness test waived by Johnnie Hill. Accumulator test:starting pressure 2900 psi,final 1620 psi. First 200 psi recharge 31 seconds,full recharge 155 seconds. 6 N2 bottles with 2066 psi average. 12:30 13:00 0.50 0 0 COMPZ WHDBO RURD T Rig down testing equipment. Pull test plug. 13:00 14:30 1.50 0 0 COMPZ RPCOM WAIT T Wait on new seal assembly from Baker. 14:30 16:00 1.50 0 500 COMPZ RPCOM PUTB T PJSM RIH with 3-1/2"completion as per tally to 500' 16:00 16:30 0.50 500 500 COMPZ RPCOM SVRG T Service rig; grease drawworks and _ service pipe skate. 16:30 00:00 7.50 500 5,880 COMPZ RPCOM PUTB T Continue to RIH with 3-1/2" completion as per tallyto 5,880'. Observe 5K bobble as GLM entered 5-1/2"Liner top. 06/25/2015 Continue to RIH with 3-1/2"completion as per detail to 7115'. Establish circulation and observe pressure increas as seals engage. No-Go assembly at 7,142'. Calculate space out(6.7'). M/U pup joints, full joint and hanger. M/U landing joint. Circulation annular volume. Displace well to corrosion inhibited seawater. Land completion, RILDS. Pressure test tubing to 3000 psi for 15 minutes, pressure test IA to 2500 psi for 30 minutes-both good. Shear out SOV. Monitor well, install BPV and test to 1000 psi from below. Perform BWM. N/D BOPE, N/U tree. Test tree and tubing hanger. Pull BPV. R/U to freeze protect well. 00:00 03:45 3.75 5,880 7,142 COMPZ RPCOM PUTB P Continue to RIH with 3-1/2" completion as per detail to 7,115'. Establish circulation at 0.5 bpm and observe seals assemby engage. Slack off to 7,142'and observe no-go with 10K down. PUW 90K SOW 80K 03:45 05:00 1.25 7,142 7,107 COMPZ RPCOM HOSO P Calculate space out, lay down 3 joints. Pick up space out pups (4.25', 8.11'), make up joint 218, hanger and landing joint. Make up control line to hanger. 64 Total SS bands ran for control line. 05:00 06:00 1.00 7,107 7,107 COMPZ RPCOM CIRC P Rig up circulating hoses. 06:00 07:30 1.50 7,107 7,107 COMPZ RPCOM CIRC P Circulate and condition fluid at 3 bpm 440 psi until well is balanced. 07:30 09:00 1.50 7,107 7,107 COMPZ RPCOM CRIH P Displace well to corrosion inhibited brine at 3 bpm. 09:00 09:30 0.50 7,107 7,107 COMPZ RPCOM THGR P Make up valve on hanger for control line to keep SSSV open and sever control line. 09:30 10:00 0.50 7,107 7,137 COMPZ RPCOM THGR P Land hanger and RILDS. • 10:00 10:30 0.50 0 0 COMPZ RPCOM RURD P Rig down circulating equipment. Lay down landing joint. Page 12 of 14 • 'Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:30 11:30 1.00 0 0 COMPZ RPCOM PRTS P Pressure test casing to 3000 psi for 15 minutes-good. While holding 1500 psi on tubing pressure test IA to 2500 psi for 30 minutes-good. Shear out SOV at 2,620 psi. 11:30 12:00 0.50 0 0 COMPZ RPCOM OWFF P Monitor well, static. 12:00 13:00 1.00 0 0 COMPZ WHDBO MPSP P Set'H' BPV as per cameraon. Test from below with 1000 psi for 10 minutes-good. Simops: Clean and clear rig floor. Send out casing tongs and spooling unit for control line. 13:00 18:30 5.50 0 0 COMPZ WHDBO SVRG P Perform BWM on BOPE. Open ram cavaties and inspect rams,wear plates, bonnet seals. Pick up 3-1/2" test joint and close annular to inspect. Replace annular regulater bladder on accumulater. 18:30 21:30 3.00 0 0 COMPZ WHDBO NUND P PJSM N/D BOPE, N/U tubing adapter and tree. Simops: move welding shack, electrical shop and Taylor camp to 3K. Begin moving auxiliary equipment to 3K. 21:30 22:30 1.00 0 COMPZ WHDBO PRTS P Test hanger voids 250/5000 psi- good. Test tree 250/5000 psi-good. 22:30 23:30 1.00 COMPZ WHDBO MPSP IP Pick up dry rod and pull BPV. 23:30 00:00 0.50 COMPZ WHDBO FRZP P Rig up to freeze protect well. 06/26/2015 Freeze protect well and allow to U-tube. Set BPV. Secure cellar. Rig down. *Rig released 06:00 00:00 01:00 1.00 COMPZ WHDBO FRZP P Continue rigging up LRS for freeze protect. Pressure test lines. Sim Ops:disconnected interconnect. Continue rigging down rig in prep for rig move. Clean pits. 01:00 01:45 0.75 COMPZ WHDBO FRZP T Attempt to reverse circulate 75 bbls of diesel for freeze protect, pressured up to 1500 psi after 1 bbls, no returns. Check surface equipment and attempt again. Check SSSV pressure and confirm control line is pumped open. Line up and attempt to circulate down tubing. Returns seen after 0.5 bbls pumped. SSSV had pressure trapped below it keeping it closed. Sim Ops: disconnected interconnect. Continue rigging down rig in prep for rig move, clean pits. Page 13 of 14 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:45 03:00 1.25 COMPZ WHDBO FRZP P Line up and freeze protect well by reverse circulating 75 bbls of diesel taking returns out to kill tank. Allow diesel to U-tube. 03:00 03:15 0.25 COMPZ WHDBO FRZP P Rig down circulating equipment. 03:15 03:45 0.50 COMPZ WHDBO MPSP P Set 3"'H' BPV. 03:45 06:00 2.25 DEMOB MOVE RURD P Secure tree and cellar. Install valves and gauges. Clean and clear the cellar. "Rig Released at 06:00 hours" Page 14 of 14 1e-Gk 30•-c;Y • Regg, James B (DOA) From: Regg, James B (DOA) Sent: Monday, June 22, 2015 10:01 AM 7' 47 '1Z7. I L To: janelle.r.nesvold@conocophillips.com' �' ' Cc: Loepp, Victoria T (DOA); 'AOGCC.Inspectors@alaska.gov' Subject: RE: 30-08 BOP Usage Notification Thank you for the notice. CPAI/Nabors 9ES plans call for re-testing the upper VBRs after the next trip out of hole. Please note that all BOPE components used for well control must be function pressure tested (including choke/kill line valves; choke manifold valves; etc. if used ). Jim Regg Supervisor, Inspections AOGCC smit1ELI JUL 0 2G1:. 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: Loepp, Victoria T(DOA) Sent: Friday, June 19, 2015 2:33 PM To: Regg, James B (DOA) Subject: FW: 30-08 BOP Usage Notification From: Nesvold, Janelle R [mailto:Janelle.R.Nesvold@conocophillips.com] Sent: Friday, June 19, 2015 2:30 PM To: Loepp, Victoria T(DOA) Subject: 30-08 BOP Usage Notification Victoria, Please see the attached BOP usage notification letter for 30-08 and let me know if you have any questions. An email has been sent to AOGCC Inspections. Thank you, Janelle Nesvold Senior Wells Engineer ConocoPhillips Alaska Inc. 700 G Street(ATO-1586) Anchorage,AK 99501 Work: (907) 263-4641 Cell: (281) 352-2927 1 - • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 June 19,2015 AOGCC Industry Guidance Bulletin No. 10-003 Reporting BOPE Use to Prevent the Flow of Fluids from a Well Dear Commissioner: As per AOGCC Industry Guidance Bulletin No. 10-003, I am following up the email notification of BOPE usage on Nabors 9 ES with a written report. Time of BOPE Use: 6/19/2015 at 12:54 hours API Number: 50-029-21828-00 PTD Number: 188-064 Rig Name:Nabors 9 ES - Operator Contact: Janelle Nesvold 907-263-4641 Janelle.R.Nesvold@conocophillips.com Operations Summary: Today 6/19/15 at 12:54 hrs the upper pipe rams were shut in on 30-08. We were in the process of pulling the retrievable packer and were 1700 strokes into a 2800 stroke circulation when we observed - flow increase and pit gain. The well was shut in. SIDPP was 20 psi and SICP was 180 psi. With the A sands open we are experiencing 20 bbl/hour losses with 10.8 ppg KWF. We circulated the trapped gas and crude out then observe 0 psi surface pressure. BOPE Used: Upper VBR's Reason for BOPE Use: Control flow of gas to surface Actions To Be Taken: We circulated a hole volume with 10.8 ppg brine. Well was observed to be dead by being shut _ in and observing zero pressures on the gauges. Plan to re-test upper VBRs after we trip out of the hole with the current BHA. If you have any questions or require any further information,please contact me at 263-4641. Sincerely, Janelle Nesvold RWO Engineer CPAI Drilling and Wells or ?Art • hw\�����j�,s� THE STATE Alaska Oil and Gas �w s��— '� THE STJ\ SI(A Conservation Commission _ =__-_-,.... All7_- .4 333 West Seventh Avenue ' .14910„c,--V7:, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 *ti, �� � ._ P Main: 907.279.1433 ALAS Fax: 907.276.7542 11 to www.aogcc alaska.gov ��� ,V0. \, V Janelle Nesvold SC)" Sr. Wells Engineer ConocoPhillips Alaska, Inc. - 0 VI' P.O. Box 100360 .\ ....,,,----------- Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 30-08 Sundry Number: 315-340 Dear Ms. Nesvold: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 1 /- Daniel T. Seamount, Jr. Commissioner DATED this day of June, 2015 Encl. STATE OF ALASKA A ,KA OIL AND GAS CONSERVATION COM. 31ON • S�, bi`1i1G APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1 Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Rill Tubing r Operations Shutdown r Suspend r Perforate r Other Stimulate r Alter Casing Change Approved Program 1.-- Rug for Redrill r Perforate New Pool r Repair Well .17, Re-enter Susp Well rOther: Cab .,`-, r 2.Operator Name. 4.Current Well Class. 5.Permit to Drill Number. ConocoPhillips Alaska, Inc. ' Exploratory r Development f- 188-064, 3.Address: Stratigraphic Service 6.API Number. r r P.0. Box 100360,Anchorage,Alaska 99510 50-029-21828-00 7.If perforating, 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No 1✓ KRU 30-08 9.Property Designation(Lease Number). 10.Field/Pool(s): ADL 25513 ' Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft) Effective Depth TVD(ft): Plugs(measured): 'Junk(measured): 7770 - 6934 7663' ; 6849' . none 7583' Casing Length Size MD TVD Burst Collapse CONDUCTOR 75 16 110' 110' SURFACE 2584 10 75 2619' 2619' PRODUCTION 7713 7 7746' 6915' RED I V E D JUN 0 2015 AO CC Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7416-7432,7439-7462,7476-7496 , 6656-6668,6673-6692,6703-6719 3.5 J-55 7275 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-AVA"RHS"RETRIEVABLE PACKER MD=7203 TVD=6490 ' SSSV-CAMCO TRDP SSSV MD=1803 TVD=1802 • 12.Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service r 14.Estimated Date for Commencing Operations. 15. Well Status after proposed work: 6/18/2015 OIL R7 WINJ r WDSPL r Suspended r- 16.Verbal Approval: Date: GAS r WAG p GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Janelle Nesvold @ 263-4641 Email: Janelle.R.Nesvold@conocophillips.com Printed Name Janelle Nesvold Title: Sr. Wells Engineer Signature or ' • - — Phone:263-4641 Date /(/(5 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 31 5 3 v Plug Integrity r BOP Test I'V Mechanical Integrity Test r Location Clearance r Other: ,'G p -Frs. t 71-o G O G p5 r (/l't p 5 P i'-5 2 / 6 /7S, ) Spacing Exception Required? Yes ❑ No 27 Subsequent Form Required: /G —4 G T APPROVED BY749/1 1Approved b COMMISSIONER THE COMMISSIONDate: !� J "-- 4,/§7/6— Approved application is valid for 1�i�non�f t the date of approval. Submit Form and Form 10-403 Revised 5/2015 ORIGINAL yy��'V'! 6 Att ments in Duplicate , � RBDMS JUN 1 0 2015 ConocoPhillips RECEIVED Alaska JUN 0 2 2015 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC June 1,2015 Commissioner State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby submits an Application for Sundry Approval to workover Kuparuk Producer 30-08(PTD# 188-064). 30-08 was originally drilled and completed on 9/22/1988 as an"A"sand gas-lifted producer in Kuparuk. In 2005 the well failed a TIFL and a leak was detected at GLM#3.After changing out the OV the well passed a TIFL. In 2007 the well failed a similar TIFL and the OV at GLM#4 had to be changed out.No rig work was required during this time. 30-08 failed a TIFL in February of 2015 and in April failed a CMIT.A production casing leak was identified at 5,700' MD using a temperature log. The proposed workover scope for 30-08 will be to pull the existing 3-1/2" tubing and packer, run a new packer with a 5-1/2"tailpipe completion, and install a scab liner across the production casing leak. If you have any questions or require any further information,please contact me at 263-4641. Sincerely, // 71j,e1,0_6, Janelle Nesvold Wells Engineer CPAI Drilling and Wells 30-08 Rig Workover • P&R Tubing,Install Scab Liner and 5-1/2"Tailpipe (PTD#: 188-064) Current Status: This well was shut in on March 8,2015 and is currently waiting to be worked over to fix a production casing leak. Scope of Work: Pull the existing 3-1/2"tubing and packer,run a new packer with a 5-1/2"tailpipe completion,and install a scab liner across the production casing leak./ General Well info: Well Type: Producer MPSP: 2,818 psi using 0.1 psi/ft gradient Reservoir Pressure/TVD: 3,470 psi/6,519' TVD(10.2 ppg EMW)measured on 05/6/2015. Wellhead type/pressure rating: Cameron Gen IV,7-1/16"5M psi top flange BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT results: CMIT TxIA failed-04/10/2015 MIT-T passed and MIT-IA failed-04/10/2015 Earliest Estimated Start Date: June 18,2015 Production Engineer: Scott Pessetto Workover Engineer: Janelle Nesvold(263-4641/Janelle.R.Nesvold@ConocoPhillips.com) Pre-Rig Work Slickline: 1. Inspect pad and work area for hazards. Complete the PJSM. 2. RU Digital Slickline. RIH and pull DV from Otis 3-1/2"x 1-1/2"LBX GLM#6 at 7148'RKB. 3. RIH and pull 2.72"bait sub,2.5"gutted JD,and 2.75"CA-2 plug. 4. RIH with chem cutter and cut tubing at 7172' RKB(middle of first full joint above PBR). 5. RD Digital Slickline. DHD: 1. PT POs and FT LDS. Set BPV w/i 24 hrs of rig arrival. Proposed Procedure MIRU,Kill Well,BOP Test 1. MIRU. 2. Pull BPV.Reverse circulate with 10.6 ppg brine.Obtain SITP&SICP,if still seeing pressure at surface, calculate new KWF,weight up,and repeat circulation as necessary. Verify well is dead. 3. Set BPV,ND tree,NU BOPE&test to 250/3,000 psi. 4. Pull BPV,screw in landing joint,BOLDS's,unland tubing hanger. Meat of the Workover(Tripping Pipe) 5. POOH laying down 3 '''A"tubing. a. If tubing will not pull free,RU E-line: Fire a string shot and cut the tubing in the middle of the first full joint below the previous cut. b. If tubing was cut,RIH w/overshot&grapple and pull seal assembly from PBR. 6. RIH with ltco spear assembly to engage Ava PBR and POOH with the remaining lower completion. 7. RIH with cleanout assembly down to right above the top set of perforations.Reverse circulate until fluid returns are clean. RIH w/3-1/2"Completion and Test Packer 8. MU lower completion and test packer assembly and RIH to set Model F permanent packer at—7,210'MD. 1 30-08 Rig Workover • P&R Tubing,Install Scab Liner and 5-1/2"Tailpipe (PTD#: 188-064) 9. RU Digital Slickline and tie-in to K1 marker to determine the correct depth position for the BTC liner and Wearsox. 10. Set Model F packer. Release from packer and rotate pipe to the left to set the Retrievamatic packer at —7,100'MD.Pressure up workstring to 1,500 psi to test packer from above. Release Retrievamatic and POOH standing back Drillpipe. RIH w/5-1/2"Liner 11. Pick up 5-1/2"liner and RIH to PBR.Fully engage PBR and pressure up to set the HMC liner hanger. 12. Slack off the liner top to set the ZXPN liner top packer.Pressure up IA to 2,500 psi to test liner for 10 minutes. POOH laying down inner string assembly and drillpipe. RIH w/Upper 3-1/2"Completion 13. MU the upper 3-1/2"completion and RIH. Swap well over to corrosion inhibited brine and engage seals into SBE until fully located. 14. PT the tubing to 3,000 psi,bleed tubing to 1,500 psi,PT the IA to 2,500 psi/30 mins,and record.Bleed the IA to zero,then tubing.Ramp up the IA pressure quickly to shear the SOV. 15. Pull the landing joint,install BOV.Pressure test the BPV to 1,000 psi from below. 16. ND BOPE. 17. NU tree,pull BPV. 18. Set BPV. 19. RDMO. Post-Rig Work 1. Pull ISA' BPV. 2. RU Slickline: a. Pull plug from 'X'Nipple b. Pull SOV and run DV. 3. Reset well house(s)and flowlines of adjacent wells. 4. Handoff to operations. 2 KUP PROD 30-08 ConocoPhillips i° Well Attributes Max Angle&MD TD Alaska Inc. Wellbore API/UWI Field Name Wellbore Status Inc!(°) MD(ftKB) Act Btm(ftKB) cn,n041.05, 500292182800 KUPARUK RIVER UNIT PROD 1 42.82 4,800.00 7,770.0 --- .r Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 30-08,5/102015401:12 PM SSSV:TRDP Last WO: 33.98 7/20/1988 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,414.0 4/5/2015 Rev Reason:GLV CIO,PULL PLUG/BAIT SUB, hipshkf 4/12/2015 _.... CUT TBG HANGER 33.0- I al4 Casing Strings '' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread Iiii-;... CONDUCTOR 16 15.062 35.0 110.0 110.0 62.5011-40 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Tap Thread SURFACE 103/4 9.794 35.0 2,619.0 2,618.8 45.50 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 33.0 7,746.3 6,915.4 26.00 J-55 BTC Tubing Strings �Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING 3 1/2 2.99233.0 7,274.9 6,545.6 9.30 J-55 EUE 8rd Mod CONDUCTOR;35.0-110.0 Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(") Item Des Com (in) 33.0 33.0 0.32 HANGER CIW Hanger+4'Pup 2.992 SAFETY VLV;1,802.6 �i{-,! 1,802.6 1,802.5- 0.57 SAFETY VLV CAMCO TRDP SSSV-2.812"ID 2.812 7,189.5 6,479.3 39.25 LOCATOR AVA Locator Sub 3.000 7,190.0 6,479.7 39.25 PBR AVA PBR 3.000 7,203.1 6,489.8 39.22 PACKER AVA"RHS"Retrievable Packer 3.000 7,240.4 6,518.7 39.11 NIPPLE CAMCO'D'Nipple 2.750"ID 2.750 7,274.2 6,545.0- 39.01 SOS AVA Ball Seat Shear Out Sub.TTL ELMD 725T ON 2.992 SWS 6/30/1988 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) GAS LIFT;2,565.0 Top(TVD( Top Incl Top(ftKB) (ftKB) (°I Des Com Run Dale ID(in) 7,172.0 6,465.8 39.29 CUT TBG RAN STRING SHOT 10'INTERVAL 7167'-7177', 5/6/2015 RAN 2.625"CHEM CUT,CUT DEPTH 7172'RKB SURFACE;35.0-2.619.0---4) 7,583.0 6,786.8 38.20 FISH 8'Metal Strip From Pert Gun;Left in Hole 6/6/1989 Perforations&Slots GAS LIFT;4,287.1 Shot Dens Top(TVD) Btm(TVD) (shots/f Top(RKB) Star(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 7,416.0 7,432.0 6,655.7 6,668.3 A-3,30-08 6/6/1989 12.0 APERF 2 1/8"EnerJet;60 deg. GAS LIFT;5,584.5 phasing 7,439.0 7,462.0 6,673.7 6,691.8 A-2,30-08 6/6/1989 12.0 APERF 2 1/8"EnerJet;60 deg. phasing GAS LIFT:6,302.9 7,476.0 7,496.0 6,702.8 6,718.5 A-1,30-08 9/22/1988 8.0 IPERF 4 1/2"HSD Ultrapak;45 deg.phasing of Mandrel Inserts GAS LIFT;6,728.9 St ati N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com -"( 2,565.0 2,564.8 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 4/6/2015 GAS LIFT;7,148.2 2 4,287.1 4,256.1 MMH FMHO 1 GAS LIFT DMY BTM 0.000 0.0 4/5/2015 3 5,584.5 5,256.5 MMH FMHO 1 GAS LIFT DMY BTM 0.000 0.0 4/5/2015 4 6,302.9 5,800.1 MMH FMHO 1'GAS LIFT DMY BTM 0000 0.0 4/10/2015 CUT TBG;7,172.0 I 5 6,728.9 6,125.2 MMH FMHO 1 GAS LIFT DMY BK 0000 0.0 4/28/1998 6 7,148.2 6,447.4 OTIS LBX 1 1/2 GAS LIFT OPEN 5/5/2015 Notes:General&Safety LOCATOR;7,189.5 End Date Annotation 7/10/1994 NOTE:WAIVERED WELL:IA x OA COMMUNICATION PBR;7.190.0 2/28/2010 NOTE:View Schematic w/Alaska Schemtic9.0 y,a• PACKER;7,203.1 NIPPLE,7,240.4 SOS;7,274.2 APERF;7.41607,4320- APERF,7,439.0-7,462.0- - - (PERF;7,4760-7,496.0- FISH;7.583.0 l PRODUCTION,33 0-7,746.3 a a 2 2 b o in Lo O p _ u II a y F �b in quern a 'n 9N� : Or, 2 �--I r' —73 a W y /4 — O to co N (CI # p' ^ 15 9k8 O �_ OM N m J d el J — II N U 11 11I1 a-o s I I a l l a1 ... 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N--- T M ON Na ci: 111,-,mwm p' c 11 \\ J (Oji 0 • J of td L_ E" 3 J occ0� - MNJ \\ 11 U to m N .o f" < N 8 • •\\ \ I ~o • of o . 2__`- f -0 y LL `Oo Xm -o 20E,0 ♦\\ II E 0 N - CZ Cn to O)U)O Y O N N {`=a d N 2 m \\\- 1 (a Z X ma) O d0o . \ U c-) r� N m U) m to 2 44 �v�a 0 0 0 \' .1 -_ a1 oo ° 1i n U N O N c // in...yO 4� U // V a m: d= // i:+ -:(o m¢ // all tr N• • / E / .0 '' II 'dill 13 M rk1 TA R fl TA o n * _ . .)-1 - :<0 .0 .---4.--i. r—r---in c v v \J a rr d �� Mill on O �a 3� Nth V .. r v: ii �- '- N (n o p 00 Q7 �a O c OMCOp L O Ya Inn(O coif �ov Es -errr tN _2 m N Ni -C nasi co CO co Fr.) LC)/2, N p at .o c'to QQ M a a� N.a.d..1' -'2 - ON it- -- 6� Qf�i�t� .60 io� ( tLD o A2> ^o N- N P.O. Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent Friday,June 05, 2015 10:20 AM To: janelle.r.nesvold@conocophillips.com Subject: KRU 30-08(PTD 188-064, Sundry 315-340)RWO Janelle, Please provide a post-RWO wellbore schematic. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W 7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loem@alaska.gov 1 051 -o 44 -7-5‘,445 WELL LOG TRANSMITTAL DATA LOGGED /5/2015 M K BENDER To: Alaska Oil and Gas Conservation Comm. March 23, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 DECEIVED APR 0 3 2015 RE: Multi Finger Caliper(MFC): 30-08 AOGCC Run Date: 3/8/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 30-08 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-21828-00 SCANNED 6 b 2015 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: 1/) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Organization (done) Well History File Identifier / RESCAN Color items: GrayScale items: Poor Quality Originals: Other: DIGITAL DATA [3 Diskettes, No. Other, No/Type TO'rAL PAGES' /F¢1 NOTES' ORGANIZED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: OVERSIZED (Scannable) [3 Maps: [3 Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Isl Project Proofing El Staff Proof By. Dale: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: ~SI SCANNED BY: BEVERLY BREN~ SHERYI. MARIA LOWELL ReScanned (done) RE SCANNEE) BY:~ BREN VINCENT SHERYL MARIA LOWELL Is! General Notes or Comments about this file: Quality Checked (doo~ • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 30, 2008 ~~ AI~G .~ ~~ 20D8 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • o ~'`~ l`~~~ ~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped July 27, 2008. The corrosion inhibitor/sealant was pumped July 3 and July 30, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, ~~~ M.J. Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field I Date 7/30/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1Y-06A 197-134 6" NA 6" NA 1 7/3/2008 1 Y-08 183-062 6" NA 6" NA 1 7/3/2008 1Y-18 193-106 15" NA 15" NA 1.7 7/3/2008 1Y-19 193-107 25" NA 25" NA 4.25 7/3/2008 1 Y-23 193-071 14" NA 14" NA 1.7 7/3/2008 1 Y-25 188-089 12" NA 12" NA 2.5 7/3/2008 30-01 188-073 SF NA 16" NA 3.5 7/30/2008 30-02A 207-158 SF NA 15" NA 3.1 7/30/2008 30-03 188-075 SF NA 16" NA 3.2 7/30/2008 30.06 188-060 18' 4.90 18" 7/27/2008 5.25 7/30/2008 30-08 188-064 9' 4" 9.50 36" 7/27/2008 25 7/30/2008 30-10 188-059 15' 3.00 16" 7/27/2008 6.3 7/30/2008 30-11 188-042 53' 5.90 46" 7/27/2008 12 7/30/2008 30-13 188-040 SF NA 12" NA 2 7/30/2008 30-15 188-031 32' 5.80 23" 7/27/2008 5.3 7!30/2008 30-18 188-026 39' 5.30 18" 7/27/2008 10 7/30/2008 30-08 Re-TIFL . . Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Monday, September 17, 2007 10:49 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF3 Prod Engrs; CPF3 DS Lead Techs Subject: 30-08 Re- TI FL Attachments: 30-08. Schematic. pdf; 30_0890 DAY TIO PLOT.jpg ~ "Ill Ct{ 01 , \<-.tiC¡ Tom & Jim, Kuparuk gas lifted producer 30-08 (PTD 1880640) failed a re- TIFL on 09/16/07 and still on the SCP report. The TIO immediately prior to SI for the TIFL was 150/1025/1280. A leaking GL V is suspected. Slickline will trouble shoot the tubing leak and repair if possible. / Attached is a schematic and 90 day TIO plot. «30-08.Schematic.pdf» «30_08 90 DAY TIO PLOT.jpg» s'CANNED SEP 2 12.001 Please let me know if you have any questions. """'...1'- 'f" Perry L. Greenwood Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n 1617@conocophillips.com 9/19/2007 . . KRU 30-08 API: 500292182800 Well Tvee: PROD Anale @ TS: 39 dea @ 7337 SSSV Type: TRDP Orig 7/20/1988 Angle @ TO: 38 deg @ 7770 sssv Como/etien: (1803-1804, Annular Fluid: Last W/O: Rev Reason: TAG FILL C/O OV 00:3.500) Reference Loa: Ref Loa Date: Last Ucdate: 11/13/2005 Last Taa: 7454 TD: 7770 ftKB Gas Lift 1,lii..fate: 9/29/2005 Max Hole AIIiiiIiìJiii 4800 TVD Wt Grade Thread MandrelNalva DescriPtion Size Top Bottom 1 CONDUCTOR 16.000 0 110 110 62.50 H-40 (2565-2566, SUR. CASING 9.625 0 2619 2619 36.00 J-55 PROD, CASING 7.000 0 7746 6915 26.00 J-55 Gas Lift Size Top 1 Bottom TVD I Wt I Grade I Thread I MandrelNalva 3.500 0 1 7275 6546 I 9.30 I J-55 I EUE 8RD MOD I 2 (4287-4288, Interval TVD Zone Status Ft SPFI Date Type Comment 7416-7432 6656 - 6668 A-3 16 12 6/6/1989 APERF 21/8" EnerJet; 60 deg. Gas Lift ' phasing MandrelNalva 7439 - 7462 6674 - 6692 A-2 23 12 6/6/1989 APERF 21/8" EnerJet; 60 deg. 3 phasing (5584-5585, 7476 - 7496 6703 - 6718 A-1 20 8 9/22/1988 IPERF 4 1/2" HSD Ultrapak; 45 d hasina Gas Lift St MD TVD Man Man Type VMfr V Type VOD Latch Port TRO Date Vly 3ndrel/Oummy Mfr Run Cmnt Valva 4 1 2565 2565 MMH FMHO GLV 1.0 BK 0.188 1294 11/26/200 (6303-6304, 00:5.313) 2 4287 4256 MMH FMHO GLV 1.0 BTM 0.250 1417 11/26/200 3 5584 5256 MMH FMHO OV 1.0 BTM 0.250 0 9/29/2005 4 6303 5800 MMH FMHO DMY 1.0 BK 0.000 0 4/28/1998 Gas Lift 5 6729 6125 MMH FMHO DMY 1.0 BK 0.000 0 4/28/1998 3ndrelIDummy Valva 5 6 7148 6447 Otis LBX DMY 1.5 RM 0.000 0 (6729-6730, 00:5.313) Depth TVD Type Description ID 1803 1803 SSSV Cameo 'TRDP' 2.812 Gas Lift 7190 6480 PBR AVA 3.000 3ndrel/Dummy 7203 6490 PKR AVA'RHS' 3.000 Valva 6 7240 6518 NIP Cameo 'D' Nipple NO GO 2.750 (7148-7149, 00:5.940) 7274 6545 SOS AVA 2.992 7275 6546 TTL 2.992 PBR Depth I Descrietion I Comment (7190-7191, 00:3.500) 7583 18' Metal Strip I From Perf Gun' Left in Hole Date 1 Note 7/10/19941 WAIVER ED WELL: IA x OA COMMUNICATION PKR (7203·7204, 00:6.151) NIP (7240-7241, 00:3.500) TUBING (0-7275, 00:3.500, 10:2.992) SOS (7274-7275, 00:3.500) Perf - - (7416-7432) >--". ... .........- -- . - ..... ~-- . .. . -...- Perf ... ........ (7439-7462) --.. - - - - 'm' - - ::::::::::: ::::::::::: Perf (7476-7496) - . m____ ----- - --. 8' Metal Strip (7583-7593, 00:2.125) 30-08 (PTD 1880640) failed TIFL . Regg, James B (DOA) . Page 1 of 1 From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Friday, September 07,200710:04 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: 30-08 (PTD 1880640) failed TIFL Attachments: 30-08 schematic.pdf; 30-08 90 day TIO plot.jpg .<) q ll'\\ 07 \" °i 1 Tom & Jim, Kuparuk gas lifted producer 30-08 (PTD 1880640) failed a TIFL on 09/06/07 and has been added to the SCP report. The TIO immediately prior to SI for the TIFL was 100/1275/1170. A leaking GL V is suspected. Slickline will trouble shoot the tubing leak and repair if possible. /' Attached is a schematic and 90 day TIO plot. Please let me know if you have any questions. «30-08 schematic.pdf» «30-0890 day TIO plot.jpg» Brent Rogers Problem Wells Supervisor 659-7224 9/19/2007 1'IJÐING PRESSURE FLOW SCRATCH 513 SCRATCfC58 PROD SUM SUMMARY lUFF MEMORANDUM TO: Julie Heusser, Commissioner THRU: FROM: Tom Maunder, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: Chuck Scheve; SUBJECT: Petroleum Inspector January 26, 2001 Safety Valve Tests Kuparuk River Unit 30 Pad Friday, January 26, 2,001: i traveled to the Kuparuk River Field and witnessed the 90-day retest of the safety valve systems on 30 Pad. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 12 wells and 24 components with one failure observed. The Low pressure pilot on WAG injector 30-05 tripped below the required set point. This pilot was retested and passed at the the time of this test. Eamie Barndt Conducted the testing today he demonstrated good test procedure and was a pleasure to work with All the wellhouses entered at this location were clean and all related equipment appeared to be in good condition. Summary:. I witnessed the 90-day SVS testing at 30 Pad in the Kuparuk River Field. KRU 30 Pad, 12' wells, 24 components, 1 failure '4.1% failure rate 12 wellhouse inspections Attachment: SVS KRU 30 Pad 1-26-01 CS X Unclassified Confidential (Unclassified if doc. Removed) SVS KRU 30 Pad 1-26-01CS.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Operator Rep: Eamie Barndt AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Field/Unit/Pad: Kupamk / KRU / 30 Separator psi: LPS 67 Date: 1/26/01 HPS .. .' . ii . . . i i I iii _ i ii I i i i i i i - ......... ....... ,- --,-.,- ·-,;:-"~;-..-:' :.',,,:"' '~'-. .... . ' ...... i.' :':'i'.-- .- "' .:' ,i ¥ '. :' ',.i' "'- f' "': ;' ' '' .... :: ' ' I Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GI~J, Number Number PSI PSI .Trip . Code .. Code Code Passed .GAS or CVCt~ 30-01 '"'18807~0 .... 67 '"701 80 P P OIL, 30-02 1880740 67 70 60 P p OIL 30-03 18i16750 "87 " 70 ' ' 60 P - 13. ........ OIL 30-04 1880620' ' 67 70 65 P ' 'P .......... OIL 30-06 1880600 ~0'-08 ' 188064~) " 67 70 ' 70!. 'P' P ' ' 'OIL 30'-09' ' '1880~J10i '" 67 ' ~0' '40 P P ' ' OIL 30-11 ..... 18804~20' 67 70 "60 p ~'P ........ OIL 30-13 1880400 67 70 -60 P ' P ' " OIL 30-14 1880390 . 30-i'~ 1880310 '" 67~ 70 76' ' i~ P .... OIL 30-1}~ 1880260 67i ''70 55 P" P ...... OIL 30-20 1970450 67 70 60 P P OIL 30-05 ''18807~0 "' 3'750 " 2000! 1100 3 ' ? ..... 1)~6/01 wA~ Wells: 12 Components: 24 Failures: _ 1~ Failure Rate: 4.17% [300 Day Remarks: Pilot on WAG injector 30-05 tripped below required set pressure. Pilot was retested and passed this date. RJF 1/16/01 Page 1 ofl SVS KRU 30 Pad 1-26-01 CS.xls MICROFILMED 10/12/00 DO NOT PLACE ANY NE W MA TERiAL UNDER THIS PAGE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__~X Plugging _ Perforate _ Pull tubing Alter casing _ Repair well Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, inc. Development X. 58' RKE 3. Address: Exploratory . 7. Unit or Property: P.O. Box 100360 Stratagrapic __ Anchorage, AK 99510-0360 Service Kuparuk River Unit 4. Location of well at surface: 8. Well number: 876' FNL, 1929' FWL, Sec 22, T13N, RgE, UM 30-08 At top of productive interval: 9. Permit number/approval number: 1255' FSL, 1893' FWL, Sec 15, T13N, RgE, UM 88-64 At effective depth: 10. APl number: 1459' FSL, 1891' FWL, Sec 15, T13N, RgE, UM 50-029-20828-00 At total depth: 11. Field/Pool: 1525' FSL, 1890' FVVL, Sec 15, T13N, R9E, UM Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 7770 feet Plugs (measured) None true vertical 6934 feet Effective Deptl measured 7663 feet Junk (measured) 8' metal strip from pert gun in rathole true vertical 6849 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 164 Sx AS II 121' 121' Surface 2584' 9-5/8" 1300 Sx AS III & 2619' 2619' 225 Sx AS II w/90 Sx AS I top job Production 7713' 7" 400 Sx TWL & 7746' 6915' 200 Sx Class G & 175 Sx AS I Liner Perforation Depth measured 7416'-7432', 7439'-7462', 7476'-7496' true vertical 6656'-6668', 6674'-6692', 6702'-6718' Tubing (size, grade, and measured depth) 3.5", 9.3 lb/fi, J-55 @ 7275' . Packers and SSSV (type and measured depth) Packer: AVA RHS @ 7203'; SSSV: Camco TRDP @ 1803' 13. Stimulation or cement squeeze summary Fracture stimulate "A" sands on 5/1/98. Intervals treated (measured) 7416'-7432', 7439'-7462', 7476'-7496' Treatment description including volumes used and final pressure Pumped 254,938 lbs of 16/20 and 12/18 ceramic proppant into formation, fp was 7200 psi. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 502 305 797 1338 188 Subsequent to operation 539 278 979 1277 188 15. Attachments MIT form 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _ZX Oil X Gas Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~)~ ~,~~- Title: Production Engineering Supervisor Date ~/~ ~'/~1 Form 10-404 R~ !,~'~]~)/15~88 SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT ,~ '~ ,~ELL SERVICE REPORT ~ K1(30-08(W4-6)) WELL JOB SCOPE JOB NUMBER 30-08 FRAC, FRAC SUPPORT 0420982238.3 DATE DAILY WORK UNIT NUMBER 05/01/98 PUMP "A" SANDS REFRAC DAY OPERATION COMPLETE I SUCCESSFUL ' KEY PERSON SUPERVISOR 5 (~) Yes O NoI (~) Yes O No DS-YOKUM JOHNS FIELD AFC# CC# DAILY COST ACCUM COST Sign~ ESTI MATE KD2116 230DS36OL $157,205 $184,176 " Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Ou{e'r ,~in'd I Final Ou[.e~'Ann 1122 PSI 0 PSI 500 PSI 500 PSII 600 PSII 700 PSI DAILY SUMMARY I PUMPED "A" SANDS REFRAC WITH 254'938# PROPPANT TO 12/18 ' 13 PPA PLACED IN PERFS' SCREENED OUT WITH 30 BBLS SHORT OF COMPLETE FLUSH. LEFT 11,370# IN PIPE FOR CLEANOUT. TIME LOG ENTRY 07:00 MIRU DOWELL FRAC EQUIP., HOT OIL PUMP AND APC SUPPORT. 08:44 HELD JOB SITE SAFETY MEETING. 09:25 PRESSURE TEST TREATING LINE TO 9600 PSI, OK. 09:16 PUMP 100 BBLS X-LINK GEL FOR BREAKDOWN TO 30 BPM AND 8400 PSI TO 5205 PSI. 09:19 PUMP 75 BBLS SLURRY WITH 3000# 16/20 PROPPANT FOR SCOUR, 15 BPM AND 5348 PSI. 09:22 PUMP 50 BBLS CONDITION GEL AT 15 BPM4742 PSI. 09:24 PUMP 75 BBLS SLURRY WITH 5700# 16/20 PROPPANT AT 2PPA FOR SCOUR, 15 BPM AND 4810 PSI. 09:30 pUMP 50 BBLS GEL AND 100 BBLS SEAWATER FOR FLUSH, AT15 BPM AND4521 PSI. SHUTDOWN ISIP 2140 PSI. 10:33 PUMP 181 BBLS FLUIDS FOR DISPLACEMENT, DATA FRAC AND FLUSH. 5 TO 15 BPM AND. 5434 PSI. SHUTDOWN ISIP 2316 PSL 11:43 PUMP 575 BBLS X-LINKED50# GEL FOR PAD AT 5 TO 15 BPM AND 5008 PSI. 12:29 PUMP 15,439 # OF 16/20 PROPPANT AT.2PPA, 15 BPM AND 4885 PSI. 12:42 PUMP 244,308 # OF i2/18 PROPPANT AT 6 TO 14 PPA, 15 BPM AND 4900 PSI. 13:56 PUMPED 30 BBLS FLUSH , WELL SCREENED OUT 30 BBLS SHORT OF COMPLETE FLUSH , LEAVING 11,370 # OF PROPPANT IN PIPE FOR CLEANOUT. MAX. PRESSURE 7200 PSI AT SCREEN SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $654.00 APC $7,700.00 $12,500.00 ARCO $500.00 $500.00 DIESEL $0.00 $315.00 DOWELL $144,805.00 $149,805.00 HALLIBURTON $0.00 $11,002.00 LI3-1'LE RED , $4,200.00 $9,400.00 TOTAL FIELD ESTIMATE $157,205.00 $184,176.00 " STATE OF ALASKA ~ OIL AND GAS CONSERVATION COMMI~.~rON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Repair well Perforate Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 5. Type of Well: Development Exploratory Stratigraphic Service 876' FNL, 1929' FWL, Sec. 22, T13N, R9E, UM At top of productive interval 1255' FSL, 1893' FWL, Sec. 15, T13N, R9E, UM At effective depth 1459' FSL, 1891' FWL, Sec. 15, T13N, R9E, UM At total depth 1525' FSL, 1890' FWL, Sec. 15, T13N, R9E, UM 12. Present well condition summary Total Depth: measured 7770' feet true vertical 6934' feet Plugs (measured) 6. Datum elevation (DF or KB) 58' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 30-08 9. Permit number/approval number 88-84 10. APl number 50-029-21828 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 7663' feet true vertical 6849' feet Junk (measured) Casing Length Size Conductor 8 0' I 6" Surface 25 8 4' 9 5/8" Production 7713' 7" Perforation depth: measured 7416'-7432', true vertical 6656'-6668', Tubing (size, grade, and measured depth) Cemented 164 Sx AS II 1300 Sx AS III & 225 Sx AS II Top job w/90 Sx AS I 400 Sx TWL, 200 Sx Class G & 175 Sx AS I 7439'-7462' & 7476'-7496' 6674'-6692' & 6702'-6718' 3.5" 9.3# J-55, EUE 8 RD, ABMOD, Tail @ 7275' Packers and SSSV (type and measured depth) SSSV: Camco TRDP, 1803', Packer: AVA RHS, 7203' 13. Stimulation or cement squeeze summary 14. Measured depth 110' 2619' 7746' Intervals treated (measured) Perforated interval. Treatment description including volumes used and final pressure True vertical depth 110' 2619' 6915' S E P ?- B AlasKa ull ~ ~o ...... 'Anchorage Refractured A Sand w/113.0 M LBS proppant & 1052 BBL gelled sea water. Final pressure 7500 psi. Representative Daily Average production or In!ection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 1093 498 208 1180 2994 ~ 1304 0- 1230 16. Status of well classification as: Water Injector m Oil X Gas Suspended Service 166 175 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~lned ~'~' ~ Form 10-404 Rev 09/12/g0 Title Petroleum Engineer Date (~/~' '~/~ ~'-' SUBMIT IN DUPLICATE ? STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION coMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS ,r--] SUSPENDED [] ABANDONED ~] SERVICE [] 2. Name of Operator ARCO Alaska, Inc. ~ 3. Address P.0. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 876' FNL, 1929' FWL, 5ec.22, T13N, R9E, UN At Top Producing Interval 1255' FSL, 1893' FWL, 5ec.15, T13N, RgE, UN At Total Depth 1525' FSL, 1890' FWL, 5ec.15, T13N, R9E, UN 5. Elevation in feet (indicate KB, DF, etc.) RKB 59 ' 6. Lease Designation and Serial No. ADL 25513 ALK 2554 7. Perr~i~_l~m ber 8. APl Number 50- 029-21828 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 30-8 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. Date Spudded 13. Date T.D. Reached I 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 07/10/88 I 07/19/88 ~//~,~./~_ ~'~3,~ h N/A feet MSL I 1 17. Total Depth (MD+TVD) 118. Plug Back Depth(MD+TVD)I-~9. Directional Survey I 20. Dept where SSSV set I 21. Thickness of Permafrost 7770'MD/6934 'TVD J 7663 'MD/6849'TVD IYES~ NO[-], ] 1803' feet MD ] 1700' (approx) 22. Type El~tric or Other Logs Run DIL/LSS/GR, NGT/CNL/EBT/LDT~ FMS~ SWC~ DIL/FDC/CNL~ CAL~ GR~ CBL~ Gyro 23. CASING, LINER AND CEMENTING RECORD CASING SIZE WT. PER FT. 16" 9-5/8" ~2 _S# GRADE HOLE SIZE CEMENTING RECORD AMOUNT PULLED H-b,O .I-SS 7" .l-SS SETTING DEPTH MD TOP BOTTOM Surf 11(3' Sllrf ?g19' 77b. F; ' 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) Perforated w/8 spf, 45° phasing 7476 ' -7496 ' MD/6702 ' -6718 'TVD 27. N/A 94" 1 9-1/~_" R-1/9" !300 S~ AS !!! & _?_?5 s: Top job w/90 sx AS ! /~r~l~ ~× TI W. 900 .~× (~IR~ ;~ C, & 97S _~x AS I 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 7275' 7203' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) IAMOUNT & KIND OF MATERIAL USED See attached Addendum, dated I 1-24-89 for fractu[e data. I PRODUCTION TEST Date First Production Date of Test Hours Tested Flow Tubing Casing Pressure Press. 28. jMethod of Operation (Flowing, gas lift, etc.) TEST PERIOD I~ CALCULATED I~ I OIL-BBL GAS-MCF WATER-BBL 24-HOUR RATE -~ I CORE DATA I CHOKE SIZE IGAS'OILRATIO I OIL GRAVITY-APl (corr) Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None NOTE: Drilled RR 7/20/88. Perforated well and ran tubing 9/22/88. Fractured well 12/23/88. ~.~ Form 10-407 ~, Rev. 7-1-80 099/WC5 CONTINUED ON REVERSE SIDE Submit in duplicate GEOLOGIC 'MARKERS FORMATION TESTS NAME ·' Include interval tested, pre~sure data, all fluids recovered and gravity, "ME'ASi DEPTH TRUE VERT. DEPTH GOR, and time of each phase. .... Top Kuparuk C ~'~34' 6591 ' N/A Base Kuparuk C 7365' 6615' Top Kupa ruk A · 7404' 6646' Base Kuparuk A . 7544' 6756' , 31. L~eOn~luAmTT(~Ca~leMdE~'~O/88 & 1-24-89) Core Description 32. I hereby certify that the foregoing is true'and correct to the best of my knowledge -- , INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 RCO Alaska, Inc: Subsidiary of Atlantic Richfield Company WELL I PBDT CONTRACTOR f REMARKS JFIELD - DISTRICT- STATE OPERATION AT REPORT TIME WELL SERVICE REPORT JDAYS J DATE / .AFc.' Alaska 0[I, & Gas uons. Gom'm'''tssi°~ [] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK knots REMARKS CONTINUED: '- - ' '":- · .:.. ' .".' ' ACCUM. DESCRIPTION ........ , ..... ,., ~, DAILY TOTAL .. CAMCO ' OTIS .... SCHLUMBERGER ':.".'. · ' · ~"~ DRESSER-ATLAS · .o DOWELL HALLIBURTON ARCTIC COIL TUBING FRACMASTER B. J. HUGHES ,/~../,?~' Roustabouts Diesel Methanol Supervision Pre-Job Safety Meetin'g/ AFL ,,, ... · -. .. · , , · TOTAL FIELD ESTIMATE // Signed ADDENDUM WELL: 8/24/88 12/23/88 30-8 Arctic Pak well w/225 sx AS I. Frac Kuparuk "A" sand perfs 7476'-7496' in eight stages per procedures dated 12/15/88 as follows: Stage iA: Pmp 33 bbls gelled diesel pre-pad @ 25 BPM, 7000-5400 psi Stage lB: Pmp 150 bbls gelled diesel Pad @ 25 BPM, 3900-3580 psi Stage 2: 585 bbls gelled diesel @ 25 BPM, 3900-3580 psi Stage 3: 60 bbls gelled diesel, 2 ppg @ 25 BPM, 3550-3410 psi Stage 4: 75 bbls gelled diesel, 4 ppg @ 25 BPM, 3380-3270 psi Stage 5: 80 bbls gelled diesel, 6 ppg @ 25 BPM, 3240-3140 psi Stage 6: 90 bbls gelled diesel, 8 ppg @ 25 BPM, 3100-3200 psi Stage 7: 80 bbls gelled diesel, 10 ppg, 25 BPM, 3150-2980 psi Stage 8: 69 bbls gelled diesel flush @ 25 BPM, 2980-3900 psi Fluid to Recover: Sand in Zone: Sand in Csg: Avg Pressure: 1144 bbls 80,192# 600-800# 3300 psi Drilling ~u~ervisor z D'~te )kRCO ALASKA, INC. KF'~'k, 30-8 SEC. 22, T13N, R9 SZDE WALL CORE DESCRIPT~. ,IS FOR THE STATE OF ALASKA DoM, DEPTH(MD) DESCRIPTION 3012.5 MISFIRE CONFIDENTIAL 3012.9 MISFIRE 3013.1 MISFIRE 3016.9 SAND, POROUS, OIL STAINED 3017.1 SAND, POROUS, OIL STAINED 3041.1 SAND, POROUS, OIL STAINED 3080.1 MISFIRE 3082.1 SAND, POROUS, OIL STAINED 3086.0 SAND, POROUS, OIL STAINED 3088.0 SAND, POROUS, OIL STAINED 3114.9 MISFIRE 3115.0 SAND, POROUS, OIL STAINED 3116.0 SAND, CLAY; SAND IS POROUS, OIL STAINED; CLAY HAS NO OIL STAIN 3119.1 SAND, POROUS, OIL STAINED 3124.1 NOT MUCH RECOVERED. MINERAL CEMENT(?), NOT POROUS 3126.0 SAND, POROUS, OIL STAINED 3135.1 SAND, POROUS, OIL STAINED 3139 MISFIRE 3140 SAND, POROUS, OIL STAINED 3142.9 SAND, POROUS, OIL STAINED 3144 CLAYSTONE, SILTY, V. LITTLE POROSITY, NO OIL STAIN 3151.1 SAND, POROUS, OIL STAINED 3166.1 SAND, POROUS, OIL STAINED 3169.1 SAND, POROUS, OIL STAINED 3170.9 SAND, POROUS, OIL STAINED 3181.1 SAND, POROUS, OIL STAINED 3184 SAND, POROUS, OIL STAINED 3437 NO RECOVERY 3441 SILTSTONE, V. LITTLE POROSITY, NO OIL STAIN 3451.1 SAND, POROUS, OIL STAINED; SILT, LITTLE POROSITY, NO OIL STAIN 3452.1 SAND, POROUS, OIL STAINED 3453 SAND, POROUS, OIL STAINED 3453.6 SILTSTONE, V. LITTLE POROSITY, NO OIL STAIN 3516.9 SAND, POROUS, OIL STAINED 3518.1 SAND, POROUS, OIL STAINED 3518.6 SAND, POROUS, OIL STAINED 3519.2 SAND, POROUS, OIL STAINED 3520 SAND, POROUS, OIL STAINED 3522.9 SAND, POROUS, OIL STAINED 3665 SAND, POROUS, OIL STAINED 3666.1 SILTSTONE, V. LITTLE POROSITY, NO OIL STAIN 3678.9 SILTSTONE, SOME OF IT IS POROUS AND HAS OIL STAIN, REMAINDER IS ARGILLACEOUS, HAS V. LITTLE POROSITY AND NO OIL STAIN 3680.1 SAND, POROUS, OIL STAINED 3681 SILTSTONE, V. LITTLE POROSITY, NO OIL STAIN ADDENDUM WELL: 30-8 8/2/88 Run CBL, Gyro, gauge ring. No depths given. APR-!8-' 90 1E]: 28 ID: KRU,,'CI:'NU/DR!LLING TEL N0:907-265-6218 ALL WEL~S LOCATED IN SEC. 22 T. !:5 N., R. 9 E., UMIAT MERIDIAN. NOTES I. ~ COORDINATES ARE A.S.R, ZONE 4. 2. ALL DISTANCES ~,IOWN ARE TI~JF.. 3. ELEVATIONS ARE 8.P.M.~,I_ 4. REFER. FIELD BOOK t-eS-3~ 5. O.G. Lrt. EVATI0N$ FROM C~D-RIXX-3365~ 6. HOFtIZONTAL, POSITION BASED ON ~0 CONTROL, MONUMENTS Prr~ U)UNSB~)AY & Well Y ASPs X LATITUDE LONGITUDE FNL E~LL i 6,0Z ~,095. Z75~5,478.17 ~Z8~ ]?,338" 1490 47' 30.8~7" 724' 164Z' 11,5' 2~,9' 2 6,022,073.~ 525,490.94 TO°~' 17.1~8" 149°47'30.5~'' 745' 1855' 7.7~ 5 6,022,052. 1~ 525,~.67 ~' 16 gl~" 149o 47:50, I~' 7eY lesz' 4 6,022,030.~ 525,515.58 ~2a~ ' " I~l ,, Iq9°47, zg.sm~ 189; 18~; 5 6,0Z~8.~ 525~528.5S 7~Z8, 149°47,29.4~. 81 I, 18gZ, ? 6,021,965.~ 5~5 ~55~.~ I~059 14~47 28.6~ 6~ 1917, 18.~, 2~1 9 6,0~1 ,~, tZ 5~ ,578.Z7 i5.6~2 149 47 ~7,974 89~ 1941 18.4 23.2 I0 6~OZl ,84~ 525 ~623.6t ~28' 14.~" 149°4T'26.6~'' 975' 1986' II 6,021,822.~ 525,655.71 ~' 14.651" 149° 4~'Z6.Z95" 1998' 23,5' ~7' I' t779, 16 525 ~66i .~ ' 13 6,0Z ~e~, 14, 2~3" 149~47,25.~. 1041', ZOZ4', 18.9, 2~.0, 15 6,021,735. 16 5Z5 ,~6. IZ ~o~, 13.~5 149°47 24.8~ 1084~ ~048, 19.0, 16 6,0~ I,?14, 15 5Z5~6~. 17 ~e28' 13.~3' 149°47'24.4~ I t~ 20~ 19. 17 6,0~1,69~ BE5,710.85 ~' 13. S69" 14904T'Z4.0~ I IZ~ 2073 19.0' 2~9' t8 6,0Z I ,670.97 525,7~.~ ~28' 13, t57" 149~47'Z3,733" 1149' 2085' 19.0' 23.3' , , . . - . . , , ..... . ..... - i, -- -- WeLL couOuc'ro AS BU L'r · . --- ..... ' ~ [~Am~O- ~Y-- ' ' LOUNSBURY 6 Associates p:..,,. ! ARCO Alaska, Inc. Date: April 24, 1989 Transmittal #: 7462 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 30-18 Sub-Surface Pressure Survey 2-1 1 -89 #64613 30-08 Bottom Hole Pressure Surveyq 2-26-89 #962636 30-05 Sub-Surface Pressure Survey 2-1 6-89 #29855 30-14 Sub-Surfece Pressure Survey 1-23-89 #72655 3 O- 18 Kuparuk Well Pressure Report 2 - 1 1 - 8 9 Sand 'A' 30- 14 Kuparuk Well Pressure Report 1 - 2 3 - 8 9 Sand 'A' 30-08 Kuparuk Well Pressure Report 2-23-89 Sand'A' 30-17 Kuparuk Well Pressure Report 3 - 0 4 - 8 9 Sand 'A' Receipt Acknowledged: DISTRIBUTION: D&M State of Alaska SAPC Mobil Chevron Unocal August 18, 1988 Mr. Randy Ruedrich ARCO Alaska, Inc. P.O. Box 360 Anchorage, Alaska 99510 Re: Our Boss Gyroscopic Survey Job No. AK-BO-80078 Well: 3-o-8 Field: Kuparuk Survey Date: August 1, 1988 Operator: T. McGuire Mr. Ruedrich: Please find enclosed~the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosure NL Sperry-Sun/NL Industries, Inc. RO. Box 231649, Anchorage, Alaska 99523-1649 Tel. (907) 522-1737 ARCO ALASKA, ' INC. 3-0-8 KUPARUK ALASKA VERTICAL SECTION CALCULATED ALONG CLOSURE ,: ..... c.~ SURVEYING COMPANY .... ._,FERRY ....IN WELL ANr:HORAGE ALASI<A DATE OF SURVEY AUGUST 1, 1'''-''~' COMPUTA T I ON DATE ....... BO.,~8.....~YROSCOP I ~J_3~B~E~ ................................. -'~ '-' '~'"~ dOB NUMBER AK-BO-~O078 AULd_loT 5~ 1~ KELLY B~:RHING ELEV = _ _ . .............. O_P~.~OR,M~j~OU!.~ ................ TRUE SUB,SEA bUUR:_~E MEASURED VERT I CAL VERT I CAL I NCL I NAT ! ON DEPTH DEPTH DEF'TH DEG MIN 0 0.00 -58.00 0 0 100 99.99 41.99 0 58 200 199.98 141.98 1 9 300 299.96 241.96 1 5 400 399.94 341.94 I 5 500 499.92 441.92 1 10 600 599.90 541.90 1 0 700 699.89 641.89 0 48 800 799.88 741.88 0 45 900 899.87 841.87 0 47 1000 999.86 941.86 0 31 1100 1099.86 1041.86 0 2:4 1200 1199.85 1141.85 0 33 1300 1299.85 1241.85 0 24 1400 1399.85 1341.85 0 28 1500 1499.84 1441.84 0 31 1600 1599.84 1541.84 0 42 1700 1699.83 1641.83 0 41 1800 1799.82 1741.82 0 34 1~00 1899.82 1841.82 0 30 2000 1999.81 1941.81 0 33 2100 2099.81 2041.81 0 48 2200 2199.80 2141.80 0 54 2300 2299.78 2241.78 0 58 2400 2399.77 2341.77 0 48 2500 2499.76 2441.76 0 54 2600 2599.75 2541.75 0 41 2700 2699.74 2641.74 0 51 2800 2799.73 2741.73 0 54 2~00 2899.72 2841.72 0 47 COURSE DOG-LEO DIRECTION SEVERITY DEGREES DEG/IO0 N 0. 0 E S 6~;.30 E o 7o.30 E M 0 S 7._. E S 64. 0 E S 73 . ,_-, ~ E ,:.73. ~_- · .,0 E S 70.69 E '=' 68 '-"- E · _, . ~", ..:! S ,_,.°c'. 8£) E S 64.80 E S 67.60 E N 82.69 E :_-: :::1.69 E N 83.19 E N 76.10 E S 88.39 E N 83. 0 E N 80. 0 E N 79.2:0 E N84. 02 S 87.69 E S 84. 0 E S 85.6~') E S 79.60 E N 88.89 E S 75.10 E S 84.60 E '.E; :32.50 E S 6:7.5(.") E TO...T..A_I-. .................... RECTANGULAR COORD I NATES VERT I c:AL NORTH/SOUTH EAST/WEST SECTION O. 00 0.98 0.21 0.07 0.21 0.22 0.17 0.22 0.05 0.19 O. :33 O. 05 O. 29 O. 20 0.13 O. 08 0.25 O. 00 0. O0 0.00 0.30 S 0.80 E -0.32 0.86 '-' 2.58 E -0 _ ;", ........... .~ ? 1.36 'S 4.48 E -1.44 2 03 S 6 '-'= . . ...._,E -'2. 1:3 '-' 73 ::; 8 "- E -2,.. o ~ :::/-, 3.27 '-.:; 9. '-~.:~"-" E -3 .43 3.75 S 11.43 E -3.93 4. '7. '..-., , . . .. ;~'..' :E' 12 71 E -4.4~ 4.54 S 14.r;1 E -4.77 4 82 '.--; 15.12 E ~.0'7 5,21 S 15, '-?':~.... E -~.~-_, ~7. 5.2:4 '.:; 16.94 E -._.~. 61 5.33 S 17.78 E -~5.61 .-,.o._.o ~t'-' 54 E 5.63 ..... '-,~'~ .~ . -- .~ 5.17 S 19.39 E -5.4'F.' 1 ' ~-I o 20 45 E =' 41 . --~-! m 0.12 4.86 S 22.76 E -5.23 0.07 4.6~ S 23.70 E -5.08 0,06 ............ ~4,_5~S . ~4,_6! E . °~ . 0.28 4 54 S ~5 7.9 E -4.95 0.12 4 65 S 27 29 E ~ 09 0.19 4.~9 S 30.45 E -5.48 0.20 ~.~ 10 S 31.~3 E -~.5 61 0.30 5.24 S 33,29 E -5, 78 0.21 5.47 S 34.62 E -6.02 0.06 ._~.64 S 36.16 E -6. 0.14 = 77 S 37.63 E ARCO ALASKA 3-0-8 KUPARUK ALASKA INC. .=,PERRY-._-,_N WELL SURVEYING COMPANY ....................... ANCHORAGE ALASKA DATE OF SURVEY AUGUST 1, COMPUTAT Z ON DATE ........ .B_Q~;~_C'LY_~O~CC!~iC....._~,SJJRVEY ...... -' '-' ,_lOB NUMBER AK-BO-80078 AUUU~:,T ~ '~R° ._l~ I .. KELLY BUSHING ELEV. = ..... C~;~T ~~~I_~ ............. VERTICAL SECTION CALCULATED'ALONG CLOSURE 58. O0 FT. . TRUE SLIB-SEA COLIRSE · MEASLIRED VERT I CAL VERT I CAL I NCL I NAT I ON DEPTH DEPTH DEPTH DEG M I N 3000 2997.71 2741.71 0 3100 3077.70 3041.70 0 52 3200 3179.67 3141.69 0 57 3300 3299.67 3241.67 I 4 3400 33??.65 3341.65 I 16 3450 344?.64 3371.64 I 16 3500 349?.63 3441.63 I 11 3550 3547.6.1 3:471.61 I 58 3600 35??.54 3541.54 3 40 3650 3649.35 3571.35 5 53 3700 36?8.96 3640.?6 8 3750 3748.32 36?0.32 ? 57 3800 37?7.46 373?.46 11 14 3850 3846.30 3788.30 13 28 3900 3894.6? 3836.6? 15 36 3?50 3942.76 3884.76 16 4000 3??0.74 3932.74 16 22 4050 4038.53 3?80.53 17 48 4100 4085.67 4027.67 21 6 4150 4132.06 4074.06 22 38 4200 4177.87 4119.87 24 33 4250 4222.96 4164.76 26 40 4300 4267.3? 420?.39 27 55 4350 4311.24 4253.24 29 28 4400 4354.47 42?6.47 30 50 4500 4437.38 4381.38 32 54 4600 4521.47 4463.49 36 40 4650 456,1.23 4503.23 38 3 4700 4600.15 4542.15 3? 42 4750 4638.02 4580.02 41 46 L. uURoE DOG-LEG D I RECT I ON SEVER I TY DEGREES DEG/1 O0 S 85.30 E S 79.3? E S 77.6? E N :_=:8.69 E N 85. i0 E N 81.6'.-? E N 75.50 E N ?.17 E N 9.39 W N 14.39 W N 14.80 W N 14.60 W N 13. 0 W. r',.l 10.30 W N ?. 0 W N 8. 0 W N 6.10 W N 4.10 W N 3.50 W N 4.17 W N 5.39 W N 6.30 W N 6.50 W N 6.1~ W N 6.30 W N 5.39 W N 3. OW N 1.10 W N 0.20 E N 1.10 E TOTAL ............................. RECTANGULAR COORDINATES VERTICAL NORTH/SOUTH EAST/WEST SECT I ON 0.13 5. :35 S :i~:~. o .~ E -6.4:_=: ~.:, 6.04 S 40.22 E -6.69 0.08 ./~. '-' "' ,~:~6 ~ ........ 4.l,_Z? E -7,03 0.27 6.51 S 43.54 E -7.21 0.21 6.40 '-' ~ 4~,.60 E -7.13 0.16 6~ 27 '-' _ 4~.,_ZO E -7, "~' 0.30 6.06 'S 47.76 E -6.83 3.70 5.08 S 48.40 E -~,=.86 3.84 2.65 S 48,.~8 E -3,42 4.51 1.43 N 47.37 E 0.66 4.84 7.41 N 45.81 E 6.67 '-' - - 15,09 _. 4 ~. ~ ..~ E 14. '~'9 · :.. z::: ~ .,. N ':: ('~ 2.63 24.03 N 41.61 E 23.35 4.61 34 50 N "'. '-'- . ~ 47 E .:::::. 86 4.31 . 46, 87 .N ...... ~7. ~8 E 46.27 1.54 60.47 N 35.35 E 59.89 1.08 74.44 N 33.62 E 73. ~:~'-'- 3... QZ ............... ,..8.?..~Z N ........... 3'2~. 6.61 105.68 N 31.2:1-{ 3.12 124.26 N 29.~8 ~, ?4 ...... 1 ~. 20 N ........ 28. @0 4.31 2.51 2.74 2.12 .4_, O0 :3.61 3.68 4.30 165.70 N 26. 188.48 N 23.53 ;~._12., 84. N 237.30 N 18.14 289.83 N 12.77 346,71N 8,65 377.03 N 7.57 408.42 N 7.33 441.04 N . 7.71 E 88.55~ E 105.16 E 123.76 E 145.7_3 E 165.25 E 188.08 E 211.97 E 236.98 E 289.58 E 346.53 E 376.86 E 408.24 E 440.86 ARCO ALASKA, KUPARUK ALASKA INC. .:,FERRY-.:,UN WELL .:,URVEY INO g;!.-]MF ~.NY. ........................................................... ~.A!;~E .... ~ ........... ANCHORAGE ALASKA DATE OF SURVEY AUoU..T 1, 1~8~ C:OMPUTAT I ON DATE BO~....~YROSCQ8.IC_~~ ................ AUGUST 5, 1 ':'-''- .:/o~ JOB NUMBER AK-BO-80078 KELLY BUSHING ELEV. = ~'-' ~,:.. 00 FT. VERTICAL SECTION CALC:uLA'~ED' ALONG ,-:LOSURE' TRUE SUB-SEA COURSE MEASURED VERTIC:AL VERTICAL INCLINATION DEPTH DEPTH DEPTH DEG M I N 4800 4675.00 4617.00 42 4.9 4.900 4748.47 46.90.47 42 36 5000 4822.12 4764.12 42 31 5100 48.95..91 4837..91 42 22 5200 4.96.9.86 4911.86 42 14 5300 5044.08 4.9986.08 41 55 5400 5118.48 5060.48 41 55 5500 51.93.10 5135.10 41 33 5600 5267..93 520.9.93 41 33 5700 5342..97 5284..97 41 11 5800 5418.14 536.0.14 41 19 5.900 5493.50 5435.50 40 52 6000 556.9.30 5511.30 40 33 6100 5645.32 5587.32 40 28 6200 5721.41 5663.41 40 25 6,300 57.97.62 573.9.62 40 16 6400 5873.87 5815.87 40 22 6500 5.950.05 5892.05 40 22 · 6600 6026.36 5968.36 40 10 6700 6102.81 6044.81 40 6 6800 6179.20 6121.20 40 16 6.900 6255.64 61.97.64 40 0 7000 6332.55 6274.55 39 26 7100 6409.77 6351.77 3.9 26 7200 6487.11 642.9.11 39 14 7300 6564.73 6506.73 38 56 7400 6642.82 6584.82 38 22 7500 6.721.26 6663.26 38 17 7600 6799.80 6741.80 38 11 7640 6831.27 6773.27 38 4 COURSE DOG-LEG D I REL. T I ON '.SEVER I TY DEGREE8 DEG/100 N 0.80 E N 0.40 E N 0.30 W N 0.60 W N 1.1~2 W N 1.69 W N 2. 0 W N 2.69 W N 2.80 W N 2.89 W N 2.80 W N 3.39 W N 3.19 W N 3.80 W N 4.10 W N 4.10 W N 3.19 W N 0.40 E N 0.20 E N 0.10 W N 0.19 W N 0.10 W N 0.19 W N 0.30 W N 0.30 W N 0.19 W N .0.50 W N 0.69 W N 0.89 W N 0.3'P W REL. TANOULAR COORDINATES VERTICAL NORTH/SOUTH EAST/WEST SECT I ON '-" 14 474.6'~ N 8.27 E ... ~,.... 542....~"::.-, N ~,.':' .gt'~ E 0.48 610.17 N . ?,(:)4. E . )..z~ 677.66 N o.51 E (;).43 744.96 N 7.45 E 0.46 811..96 N 5,76 E 0.20 878.74 N 3.60 E 0.60 .945.26 N 0.87 E 0 06 1011 ~'-' N ~.'~ 31 W 0.38 1077. ~'-' · _,._- N 5.60 W 0.15 1143.40 N 8.'-' 0.61 120.9,04 N . 12, 4?. W 0.34 1274.15 N 16.18 W 0.40 1338..99'9 N 20.15 W O. 20 140;~, 7;~ N 24, ~ ~ W 0.16 1468.31 N 29.25 W 0 5.9 1532 '"'~-' . .~o N 3:3.37 W 0.24 1662.24 N 34.61 W 0.21 1726.6.9 N 34.55 W (~, ! ? .....!.77_!, 2.~ N ;34.72 W iai 0.28 lo5~,.70 N 34.89 W 0.57 191.9.61 N 35.06 W C). 07 !.983, ~14 N ~!5, 34 W O. 21 2046.. 54 N '~5.6'7 W 0.31 2109.59 N 35..94 W 0.60 2172 ....... .-)--, N 36.32 W 0.15 2234.07 N 36.97 W 0.16 2295..96 N 37.84 W 0 '-"-' 2:'::'.--'(') 6,6, N '-~-' .,:,..' .... ~, 12 W 474.4.9 542.31 60.9.94 677.43 744.75 811,76 878.57 .945.12 1011.42 1077.48 1143.39 1209.08 1274.25 133.9.15 1403.94 1468~5~ 1533.22 1662.58 1727.03 1791,_~5 1856.02 1719.92 2046.85 210.9,90 2172,~6 2234.37 2296.27 2~20.77 ARCO ALA._~..A INC 3-0-8 ~ KUPARUK ALASKA VERTIC:AL :=;ECTION CALC:UL~TED'' nLONG CLO:=:URE oF'- .... ERRY-.=,-11.. N WELL SURVEY I Nl~,~ I:;OI~IE'ANY. ................................................................................... RAGE ~._4 ANCHORAGE ALASKA DATE OF SURVEY AUGUST 1 COMPLITAT I ON DATE 805S GYRO.~.08I C_...~$LIR_VF_~L --' i--* a~ ~ ~ ' ALIL, LI.~T 5, l Y,_,~ dOB NUMBER AK-BO-80078 KELLY BUSHING ELEV. = 58.00 FT. OSE~ ~OR, ~.~. 18E TRUE MEASURED VERTICAL DEPTH DEPTH SUB-SEA C:OLIRSE COURSE DOG-LEG TOTAL .............................. VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL DEPTH DEG MIN DE~REE~ DEG/IO0 NORTH/SOUTH EAST/WEST ._EL. TIUN 7700 6878..~3 6820 50 --,o - - .... :.._, 4 N 0 '-"- W O. O0 .-,-.~=.7 · ._.;~ 66 N :_~:~ 38 W 2:357.97 . C "D "D 7770 67 ....... 60 ,:.o,, ._' '-'-'?.. 60 ~::: 4 N 0 . ,.'::¢~.. W 0.00 2400 . .':::_-: N :38.68 W 2401 .15 HORIZONTAL DISPLACEMENT 2401 1.5 FEE]' AT NORTH 0 DEG. =-= '-' = . ~,._, MIN. WE=,T AT MD = 7770 THE CALCULATION PROCEDURES ARE BASED ON THE LISE OF THREE DIMENSIONAL RADIUS OF CURVATURE METHOD. ARCO ALASKA, KUPARUK ALASKA INC. oF ERRY-.:,L N WELL .:.L RVEY I NU E;U~FA[',JY._ ANCHORAGE ALASKA DATE OF :.-,URVEY AUGI~ST COMF'UTAT I ON~ [!ATE.. ' '-* 1 '--''-'''~ ALIL~U::,T5, :-.~o:~ dOB NUMBER AK-BO-80078 KELLY BUSHING ELEV. = ~!_PgR ~TE_LR_=M C__G_U ! R._E_ INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL ...... MEASURED VERT I CAL VERT I CAL RECTANGLILAR COORD I NATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERT I CAL CORREC..~T 1'_ ON 0 0.00 -._.=;._-,'". 00 0.00 0.00 0.00 1000 'F,'9'.~. -':'/- .=.._. '..P41 "--'~' ':":' ,:,_, 4 S 15 12 E 0, 14 0 !4 2()AA 1 '::,,'9':.',, '-' ....... ........ =,1 1941:31 4 ~,"-, S 24.61 E O, 19 0.05 3000 29.99.71 2941 71 ?, ':'~ '-"':' '-"- ._,._ S 0.29 .... · _,,_-,. ,:.~ E O. 10 4000 :::.9.9A. 74 :::'9:::2 74 74 44 N :3::: 62 E '9 '-,/. 8.97 ....... . . . . ,..~.. ". ....... 5000 o-=,--, 4,_,~.... 1 '=" 4764.12 6,10. 17 N 9.04 E 177.88 168.62 6000 5.~169:30 =-5 . ~:,._ 1 i. 30 1274 1 ....... , N 16, 18 W 430.70 252.82 7000 /. <,o9_,._,._,~_. 55 6274.55 1919. . . 61 N ._-,~,'-'=. 06 W 667.45 236, 75 · -' '3 ':,':' N '-"-' /_-.:.q, W '-"-' 7770 /-.:r:.-:, 6.0 6~7.~ 6.0 ..'-40t ..... .... oo6 40 168 95 · __I., .__I .__I I -- -- I "~lI I~lI m . THE CALCULATION F'ROCEDLIRES ARE BASED ON 1'HE USE OF THREE DIMENSIONAL RADIU~ OF C_:LIRV~TLIRE METHOD, ARCO ALASKA, INC. KUPARUK ALASKA ::,FERRY-.:,LN WELL SURVEYING_. ANL. HuRAL~E ALASKA COMPUTATION DATE AUGUST._.=,, 1'-'-'='~.~,_~o DATE OF SURVEY AUGUST 1, 1.:~,~, dOB NUMBER AK-BO-80078 KELLY BUSHING ELEV. = 58.00 FT. OPERA TOR~I~IC!~U IFiE ............... MEASURED DEPTH INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE VERT I CAL DEPTH SUB-SEA TOTAL VERT I CAL RECTANGULAR C:OORD I NATES MD-TVD DEPTH NORTH/SOUTH EAST/WEST D I FFERENC:8: VERTICAL CORRECTION 0 58 158 258 358 458 558 658 758 :_--,'58 ~58 1058 1158 1258 1358 1458 1558 1658 1758 0.00 58.00 158.00 258.00 358.00 458.00 558.00 658.00 758.00 858.00 ~58.00 1058.00 1158.00 1258.00 1358.00 1458.00 1558.00 1658.00 1758.00 =_ o O0 0.00 0.00 0.00 -- 'II III l 0.00 0.05 S 0.14 E 0.00 100.00 0.64 '-' . · :, 1 76 E O. 02 200.00 1.16 :--; 3.70 E 0.04 300.00 1 68 ',:-; 5 ?,'-' ..... ;, E 0.05 400 O0 ':' 4'P S 7 27 E 0 07 m .i~l . I 500. O0 :3.06 S '~. 22 E O. C):.~ 600.00 3.55 ::; 10. :-':-,' E 0. _1. 1 700.00 4.02 ,.E~ 1 '2.1 '.'-.? E 0.12 ~,0~).00 4.47 S 13.44 E 0.1~ '.:~00.00 4.66 '.';; 14.76 E 0, ! 4 1000. O0 5.05 .'_:; 1.5.61 E 0.14 1100 00 5 :R9 '.--; 16. ~'--' ...... ,._", E 0.15 1200.00 5.2'F~ S 17.48 E 0.1~ 1300.00 5.37 :--: 18.20 E 0.15 1400.00 5.26 :E; 1 '.~. 02 1500.00 5.07 '._:; 1 'B. :-~3 1600.00 =- O.s-~ .':; 21.16 1700.00 4. '~4 S -.~.'~"--' 34 O. 02 O. 02 .0, .(~2 ...... O. 02 O. 02 0.01 0.01 _. 0... O.;t O. O0 O. O0 _ . O.@O O. O0 E O. 16 0.00 8: ................... .Q...16___ .................. .0..00 E 0.17 0.01 E 0.18 O. 01 ARCO ALASKA, 3-0 -8 KUPARUK ALASKA MEASURED DEPTH 1858 1958 2058 2158 2258 2358 2458 2558 2658 2758 2858 2958 3058 3158 3258 3358 3458 3558 3658 INC. SPERRY-SUN WELL .:,_RVEYINO'-'Ii'. COMPANY ANCHORAGEALAoKA DATE OF SURVEY AUGUST 1, 1 COMPUTATION DATE AUGUST 5, 1988 JOB NUMBER AK-BO-80078 KELLY BUSHING ELEV. = 58.00 FT. INTERPOLATED VALUES FOR EVEN 100 FEET CiF SUB-SEA DEPTH TRUE SUB-SEA TOTAL VERT I CAL VERT I CAL RECTANGULAR COORD I NATES MD-TVD VERT I CAL DEPTH DEPTH NORTH/SOU]'H EAST/WEST DIFFERENC~ ~O~RE~!ON 1 q ~'-' '-"-' .'_-:.'~ E 0 18 ,--._,,.:,. O0 1 '-" ' - - ¢.00 O0 4 76, '.S 0 O0 ,~ . .,:2...D, , 19.'=i,'-'. ._ c,. 00 1700. O0 4.60 :s; 24.21 E O. 18 0,00 2 o 5:--: 00 2000 00 4 .=i":..._q --, =' --, ......._~. z.._,., i E 0.1'~'~. O. 01 91 ~,-, · _ ,=,. 00 ..'-.' 100 00 4 ~'--' .'_--: 2' 4, 63 E 0.2 A 0.01 · -, c, =, o 00 '.-' 2 A 0 00 4 74 S '-"-' '-"-' E 0 21 .0.01 ~' .' ---.'--, ~ .~. # . · · .~,'", · .' d:.. . · .-'-"-'.=,'-'._-,._ ,_-,. 00 2300 .00 4. :::9_. S 29.. oo'~-"--' E O. .._~,.r,.~ 0, 01 '~'~='--' 00 2400 00 5 11 S '~'1 27 E 0.24 0.01 ~ ~.-;0 ,, ,, . ._, 2.~8.00 '.2500.00 5.11 S 32.80 E 0.25 0.01 265:9.00 2600.00 5.41 S 34.00 E 0·26 0·01 '-' ~"-' _ .... 35. ,. o E 0.27 0.01 · .-7._,,z,. 00 2700. O0 %. %% S .~,' 2;-~?;:::. 00 2800. O0 5, 75 '..{-'; 37,06 E 0, '"'-;;~ O, 01 '-"-?~'-' 00 2c/6)0 00 5. a:! c. ,-.~ ._,~ ..... - ..... 38, 41 E O. 29 O. 01 :_::¢:)58. 00 3000.00 5. '.~2 ~;i. :_--:'?. 60 E 0.30 0.01 :_-.;! ~-,-,. . . · _-:, 00 3100.00 6.2:1 '.:; 41 11 E 0.~1 0.01 :--:25P.. 00 3200.00 6.53 ::; 42.76 E 0.32 0, 01 · :,'-"-'?,'-'.:,._ o. 00 3:_--:00.00 6.47 .:,'-' 44 .67 E 0 .34 0 .02 '-"~':' O0 :~4AC). 00 6.24 S 46.80. E .......... @. 8.6 ....................... .'Vb~ .......... 3558.00 3500.00 4.79 S 48.45 E 0.40 0.03 :3658. oO 3600. O0 2.2:-} N 47.15 E O. 69 O. 2:¢ ARCO ALASKA, 3-0-8 KUPARUK ALASKA MEASURED DEPTH 3759 3862 3965 4070 4178 4289 4404 4522 4645 4776 4912 5048 5183 5318 5453 5586 5719 5853 5985 INC. SPERRY-SUN WELL SURVEYING COMPANY RAGE ANCHORAGE ALASKA DATE OF SURVEY AUGUST 1, 1988 COMPUTATION DATE ALIGUST._~, 1'-'~'='yoo dOB NUMBER AK-BO-80078 KELLY BUSHING ELEV = . =_,~. £)0 FT. OE;E.FX~I£!F<=I~CGU IRE ........ _ ........ INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH ]'RUE VERT I C:AL DEF'TH SUB-SEA TOTAL VERTICAL RECTANGULAR C:CIORDINATES MD-TVD DEPTH NURTH/~,ULITH EAST/WEST DIFFERENCE VERTICAL CORRECTIO~ .... 3758. 3858. 3~58. 4058. 4158. 4258. 4358. 4458. 4558. 4658. 4758. 4858. 4958. 5058. 5158. 5258. 5358. 5458. 5558. 00 00 00 00 00 00 o0 00 00 00 00 00 00 00 00 00 00 00 00 3700.00 16.74 N 43.37 E 3800.00 37.28 N 38.97 E 3900.00 64.89 N 34.74 E, 4000.00 ~5.62 N 31.88 E 4100.00 135.21 N 29.13 E 4200.00 183.54 N 24.0~ E 4300.00 239.40 N 1,7.91 E 4400.00 302.04 N 11.6~ E 4500.00 374.50 N 7.62 E 4600.00 458.99 N 8.04 E 4700.00 551.29 N 9.04 E 4800.00 643.05 N 8.85 E 4900.00 734.20 N 7.68 E 5000.00 824.45 N 5.3~ E 5100.00 914.15 N 2.31E 5200.00 1002.72 N 1.88 W 5300.00 1090.67 N 6.~._ 5400.00 1178.34 N 10.63 5500.00 1264.50 N 15.65 1.83 1.14 4 04 '"' '-' ·. ~ ~ ~_ _1 .......... 7.88 :3.84 12.55 4.67 ~J. 17 7.6! 31.37 11.21 46.11 14.73 64, 30 . 18.1~ , 87.90 23.60 I 18.86 30.96 154.~ ........ :7.t6.0~ .... 190.67 35.72 225.~8 35.31 260.71 ......... ~4.72 295.08 34.37 328.73 33.65 W 395.04 33.06 W 427.13 32.10 ARCO ALASKA, 'INC. KUPARUK ALASKA :=;PERRY-SUN NELL SURVEY ! Nl:~ C~,~C!H~A~]¥ E'~GE' ANCHORAGE ALASKA DATE OF :E;URVEY AUGUST 1, 1988 COMPUTATION DATE AUGUST '= '--' ~"~" · -~ ? i .':,' ~-i i_-, KELLY BUSHING ELEV. - - ~,o. 00 FT. OPER_A_TL_]_R_-_M~L3.~!_!..R..~ ............. MEASURED DEPTH INTERPOLATED VALUES FOR EVEN 100 FEET-OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 6116 5658.00 5600.00 1349.77 N 20.87 W 458.67 31.54 6248 5758.00 5700.00 1434.80 N 26.85 W 490.06 31.39 6379 5858.00 5800.00 1519.41N 32.62 W 521.18 31.12 6510 5958.00 5900.00 1604.35 N 34.90 W 552.43 31.25 6641 6058.00 6000.00 1688.95 N 34.52 W 583.41 30,98 6772 6158.00 6100.00 1773.26 N 34.66 W 614.21 30.80 6903 6258.00 6200.00 1857.68 N 34.90 W 645.08 30.87 7032 6358.00 6300.00 1940.54 N 35.13 W 674.95 29.87 7162 6458.00 6400.00 2022.77 N :35.54 W 704.42 29.46 72~1 6558.00 6500.00 2104.16 N 35.~3 W 733.35 28.93 7419 6658.00 6600.00 2184.07 ;~ 36.43 W 761.37 28,02 7546 6758.00 6700.00 2263.06 I, 37.34 W 788.80 27.43 7673 6:358.00 6800.00 2341.61 ~, :3:3.26 W 815.96 27.16 7770 6933.60 6875.60 2400.83 N 38.68 W 836.40 2~.44 THE CALCULATION F'ROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATLIRE) F'OINT~ ARCO ALASKA, INC. 3-0-8 KUPARUK ALASKA SPERRY-SUN WELL SURVEYIN.G COMPANY E'AGE.i..1.O ......... ANCHL-IRAI}E ALASKA DATE OF SURVEY AUOUST 1, 1988 COMPUTATION DATE AUGUST 5, 1 ':'~'~' :-,=,~, dOB NUMBER AK-BO-80078 '-' - ._,0.00 FT. KELLY BU.:,HING ELEV, - ~'-' ....... C!E'.EBAT~R=~;QUI.~E .................... INTERPOLATED VALUES FOR .:,FEuIAL c,_RVEY POINTS MEASURED DEPTH ''l IR_IE VERTICAL DEPTH SUB-SEA VERTICAL DEPTH TOTAL RECTANGLILAR .... ' L. UURD I NATES NURTH/.:, J _ITH EAST/WEST MARKER 7334 7365 7404 7544 7640 7663 7770 6591.17 6615.38 6645.95 6755.80 6831.27 6849.37 6933.60 6533.17 6557.38 6587.95 6697.80 6773.27 6791.37 6875.60 2130.96 N 2150.33 N 2174.54 N 2261.33 N 2320.66 N 2334.84 N 2400.83 N 36.02 W' 36.14 W 36,35 W 37.31W 38.12 W 38.22 W 38,68 W TOP KLFARUK C: BASE KUPARUK C TOP KUPARLIK A BASE KUPARLIK A SURVEY DEPTH PBTD TD ARCO ALASKA, INC. :3-0-8 STRATIGRAPHIC ~MMABY DERIVED USING D IL DEF'THS AND SPERRY SUN SURVEY DATA ,MARKER ........ TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TD MEA;.~URE[ DEPTH BKB 7334 7365 7404 7544 7663 7770 TVD BKB SLIB-SEA 6591.17 6533.17 6615.38 6557.38 6645.95 6587.95 6755.80 6697.80 6849.:37 6791.37 6933.60 6875.60 COORDINATES THICKNESS WITH REF. TO WELLHEAD VERTICAL (ORIGIN- 876FNL 1929FWL) ..... ~E~ ~ ....... ~13N RJ..E 1) FROM LINEAR EXTRAPOLATION BELOW DEEPEST STATION. 2) COMPUTER PROGRAM - SPERRY SUN THREE DIMENSIONAL RADIUS OF CURVATURE. DATA CALCULATION AND INTERPOLATION BY RADIUS OF C:URVATLIRE COMPUTATION DATE ALIGUST 5, 1988 DATE OF ~LI~?.EY AU~L!ST .JOB NUMBER AK-BO-80078 I<ELLY _B_!JS_HING ELEV, = ~8,00 FT. SPERRY -SUN 5CRLE :- 1 INCH TO 500. O0 / 500.0 KUPRRUK 3 -0 -8 RK-80-80078 TRUE NORTH 7770 RRCO RLRSKRo INC. RUGUST t. 1988 -2000.00 -50~'.00 ~oOC. CO SPEFIR¥ -SIJlXl 0.00 SCALE :- 1 INCH TO [500.00 / [500.0 KUPRBUK ARCO ALASKA, INC. 3-0-8 AUGUST [, ~988 AK-BB-80078 1500.00 6000.00 t SCO. CC ~7770 VERT ~ CFtL PROJECT ~ ON ,"-' STATE OF ALASKA "~ AL~,~ :'A OIL AND GAS CONSERVATION COMMIS,_.,.)N REPOFIT OF SUNDRY WELL OPEFtATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Perforate Pull tubing ~ Alter casing __ Repair well __ Pull tubing ~ Other COMPLETE 2. NameofOperator ARCO Alaska, Inc. 3. Address P.O· Box 100360, Anchorage, AK 99510-0360 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 876' FNL, 1929' FWL, Sec.22, T13N, R9E, UM At top of productive interval 1255' FSL, 1893' FWL, Sec.15, T13N, R9E, UM At effective depth 1459' FSL, 1891' FWL, Sec.15, T13N, RgE, UM At total dep. th 1525' FSL, 1890' FWL, Sec.15, T13N, R9E, UM 6. Datum elevation (DF or KB) RKB _58 ' feet 7. Unit or Property name Kuparuk River Unit 380 _VYsell number 9. Permit number/approval number 88-64/8-600 i0. APl number 50-- 029-21828 11. Field/Pool Kuparuk River Oil Pool 12. Present well condition summary Total depth: measured true vertical 7770 'MD 6934 'TVD feet feet Plugs(measured) None Effective depth: measured true vertical 7663'MD 6849'TVD feet feet Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 80' 2584' 7713' 7" measured 7476'-7496'MD true vertical 6702 ' -6718 'TVD Size 16" 10-3/4" Cemented Measured depth Tubing(size, grade, and measured depth) 3-1/2", J-55, tbg w/tail ~ 7275' Packers and SSSV (type and measured depth) AVA 'RHS' pkr ¢ 7203' & Camco 'TRDP' SSSV ¢ 180;3' 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) 164 sx AS II 1300 sx AS III & 225 sx AS II Top job w/90 sx AS I 400 sx TLW, 200 sx Class G & 175 sx AS I Treatment description including volumes used and final pressure True vertical depth 1lO'MD 2619 'MD 7746 ' MD 110 'TVD 2619 'TVD 6915 'TVD RECEIVED Alaska .0il & (?as Cons,. Commission ' Ancho~-:;~ge 14. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments X . ~ ¥ ro Copies of Logs and Surveys run ~ Daily Report of Well Operations ..~ , 16. Status of well classification as: Oil X Gas_ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /I Form 10-404 Rev ~t~/15/88 WNOTE: Title Associ al;e Enqi near (Dani) SW03/041 Completion Well Hi story Date SUBMIT IN DUPLICATE ARCO 011 and Gas Company ~, Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO Alaska, Inc. Field ICounty, p~rO§~opE BOROUGH Lease or ~L: 25513 Title COMPLETE StateAK KUPARUK RIVER UNIT Auth, or W.O. nJl~K3005 30-8 IWell no. Operator ARCO Spudded or W.(~U~IT Date and depth as of 8:00 a.m. 09/22/88 ( TD: 7770 PB: SUPV:MDD API: 50-029-21828 I Oate 09/22/88 IH°ur 0230 HRS Complete recoilleSS1 d~y reported l^.c%~.,: 0o0o Prior status if e W.O. PERFORATING 7"@ 7746' MW:10.0 NACL ACCEPT RIG @ 0230 HRS, 9-22-88. TEST BOPE. RU AND PERF. DAILY:S4,000 CUM:$710,466 ETD:S710,466 EFC:$1,275,000 The above is c(M~sct For form preparation ~r~dis{~ibution, ~ see Procedures Many'al~,~ection 10, Drilling, Pages 86 arfO'~7. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ARCO Alaska, Inc. Field KUPARUK RIVER UNIT Auth. or W.O. no.____ AK3005 tCounty or ~%H SLOPE BOROUGH Lease or ~L: 25513 ITitle COMPLETE Accounting cost center code stateAK IWell no, 30-8 Operator ARCO Date and depth as of 8:00 a.m. 09/23/88 ( TD: 7770 PB: 7663 SUPV:MDD API: 50-029-21828 IA'R'C°'W~6.0000 Date 09/22/88 Complete record for each NORD ICIay d reported Iotal number of wells (active or inactive) on this ost center prior to plugging and I bandonment of this well I iHour 0230 }{RS IPrior status if a W.O. I 0) RIG RELEASED 7"@ 7746' MW: 10.0 PPG NACL/DIESEL PERFORATE 7476'-7496' W/ 8 SPF, 45 DEGREE PHASING. RIH WITH 3-1/2" COMPLETION STRING. RUN 221 JTS. OF 3-1/2" 9.3#,J-55,EUE-8RD AB-MOD IPC TUBING AND SET AVA 'RHS' PKR @ 7203, CAMCO 'TRDP' SSSV @ 1803', & TUBING TAIL AT 7275'. DISPLACE WELL WITH DIESEL. RELEASE RIG AT 2315 HRS, 9/22/88. DAILY:S146,751 CUM:$857,217 ETD:S857,217 EFC:$1,275,000 Old TO J New TD PB Depth I Released rig ~ Date Kind of rig Classifications (oil, gas, etc.) J ~ype completion (single, dual, etc.) Producing method ~ Official rese~oir name(s) Potential test data The above is co~ge~ For form preparati~ and ~str~ution, see Procedures Manual, S~n 10, Well no. J Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected Drilling, Pages 86 and 87. ARCO Alaska, Inc. Date: August 26, 1988 Transmittal #: 7276 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items· Please acknowledge receipt and return one signed copy of this transmittal. 30 - 06 Cement Bond Log 8 - 0 2 - 8 8 51 8 7 - 8 0 5 2 30 - 0 8 Cement Bond Log 8 - 0 1 - 8 8 3 0 8 5 - 7 6 4 8 3 O- 04 Cement Bond Log 8 - 0 3 - 8 8 6 9 8 0 - 8 8 6 6 30-07 Cement Bond Log 8-02-88 6457-8024 Receipt Acknowledged.: DISTRIBUTION: NSK Drilling Chevron(+sepia) State of Alaska(+sepia) SAPC(+sepia) Unocal(+sepia) Mobil(+sepia) WEST SAK ENGINEERING TRANSMITTAL #1200 TO: John Boyle State FROM: Pi. D. White/P. S. Baxter DATE:. Auoust 8. 1988 -- WELL NAME' KRU 30-8 TRANSMITTED HEREWITH ARE THE FOLLOWING: One copy of a sepia and blueline for KRU 30-8 11 5. 5, 5' 2" & 5" 2" & 5" 2" & 5" 2" & 5" Dual Induction - SFL Dual Induction- SFL Formation Microscanner Electromagnetic Propagation Log Natural Gamma Ray Spectrometry Log Compensated Neutron-Litho-Density (Raw) Compensated Neutron-Litho-Density (Poro) Long Spacing Sonic 7/1 5/88 run 1 7/1 5/88 run ! 7/1 5/88 run 1 7/15/88 run 1 7/1 5/88 run 1 7/1 5/88 run'l 7/1 5/88 run 1 7/15/88 run 1 PLEASE RETURN RECEIPT TO: ARCO Alaska, Inc. ATTN' P. S. Baxter, ATO-1269 00360 i Anchorage, A RECEIPTACKNOWLEDGED' (~~--' DATE:.. .... ARCO Alaska, Inc. Date: August 5, 1988 Transmittal #: 7248 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. -"' 30-08 OH LIS Tape and Listing 7-29-88 #72855 '"' 30-08 LSS Waveform Tape and Listing 7-27-88 #72855 3 O- 07 OH LIS Tape and Listing 8 - 0 3 - 8 8 # 7 2 8 6 0 Receipt Acknowledged: DISTRIBUTION: State of Alaska Lynn Goettinger STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM~oSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend ~ Operation Shutdown ~] Re-enter suspended well [] Alter casing ~i Time extension ~ Change approved program ~ Plugging [] Stimulate ~ Pull tubing ~ Amend order ~ Perforate r:-; Other 2. Name of Operator 5. Datum elevation(DF or KB) ARCO Alaska, Inc. RKB 59' feet 3. Address 6. Uniter Property name P. O. Box 100360, Anchorage, AK 99510-0360 Kuparuk River Unit 4. Location of wellatsurface 876' FNL, 1929' FWL, Sec. 22, T13N, R9E, UM Attop of productiveinterval 1320' FSL, 1848' FWL, Sec. 15, T13N, R9E, UM (approx) Ateffective depth 1466' FSL, 1828' FWL, Sec. 15, T13N, R9E, UM (approx) Attotaldepth 1533' FSL, 1826' FWL, Sec. 15, T13N, R9E~ UM (approx) 7. Well number 30-8 8. Permit number 88-64 9. APl number 50-- 029-21 828 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical 7770 'MD feet Plugs (measured) 6931 ' TVD feet None Effective depth: measured 7663 'MD true vertical 6847 ' TVD feet Junk (measured) feet None Casing Conductor Surface Production Perforation depth: Length Size 80 ' 1 6" 2584 ' 1 0-3/4" 771 3 ' 7" measured None Cemented 164 sx AS II 1300 sx AS III & 225 sx AS II Top job w/90 sx AS I 400 sx TLW & 200 sx Class G Measured depth 1lO'MD 2619'MD True Vertical depth 110'TVD 2619'TVD 7746'MD 6912'TVD RECEIVED true vertical Tubing (size, grade and measured depth) None None AUG - 9 1988 011 & Gas Cons. C0mmlssli r -".,~, ~nch0rage ' Packers and SSSV (type and measured depth) None 12.Attachments WFI I HIRTRRY 13. Estimated date for commencing operation September ~ 1988 14. If proposal was verbally approved -, .. , ~ :., ~ Name of approver ~. /c,, . .... Date approved Description summary of proposal [] Detailed operations program [] BOP sketch 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~ .~/./-¢.4,_./ Title Associate Engineer Commission Use Only (SA3/0024) (Dani) Date Conditions of approval Notify commission so representative may witness [] Plug integrity ~ BOP Test_ [] Location clearance Approvea uopy Retu rn,e_d.~ 0I:IIGIN^L SIGNED BY <~/~¢ I~ LONNIEC. SMITH - '- '" '- Approval No. Approved by Commissioner the commission Date ~ ~\ / Submit in triplicate(~ Form 10-403 Rev 12-1-85 ARCO Oil and Gas Company Well History- Initial Report-- Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only, District Field ARCO Alaska, Inc. tCounty, parish or borough NORTH SLOPE BOROUGH Lease or Unit ADL: 25513 Title DRILL KUPARUK RIVER UNIT Auth. or W.O. no, ISta~K 30-8 JWell no. AK3005/AW0440 API: 50-029-21828 Operator ARCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. 07/10/88 ( TD: 110' ( SUPV: JP S 07/11/88 ( TD: 2221' ( 2 SUPV: JPS 07/12/88 TD: 2640"-(' SUPV: JP S 07/13/88 ( TD: 3001'( SUPV:JPS J Date 07/10/88 iH°ur0700 Complete record for each day reported DOYON 14 ) ;lO) ) .11) ~) 19). ) 61) ) 20) 07/14/88 THR 07/16/88 (5-' TD: 4021' ( 1 RECEiVEI) AUG - <; 1988 Naslm 01i & Gas Cons. ~mmlsslim '.~, gnch0rag~ 07/17/88 ( ~ TD: 6371' ( 2~ SUPV: SLC ' 07/18/88 ( TD: 7730' ( 1 SUPV:SLC 50) ) 59) tARCO W.I. 56,0000 Prior status if a W.O. MU BHA #1 PREP TO SPUD WELL 16"@ 110' MW: 0.0 VIS: 0 ACCEPT RIG @ 0130 HRS 7/10/88. PREP TO SPUD. DAILY:S53,780 CUM:$53,780 ETD:S53,780 EFC:$690,000 DRILLING AHEAD 10-3/4"@ 2619' MW: 9.3 VIS: 46 SPUD @ 0700 7/10/88. DRILL 13-1/2" HOLE TO 2221'. DAILY:S44,471 CUM:$98,251 ETD:S152,031 EFC:$690,000 NU PREP TO TEST BOPE. 10'3/4"@ 2619' MW: 9.1 VIS: 43 DRILL 13-1/2" HOLE TO 2640'. CBU. POOH LD BHA. RU AND RUN SURFACE CASING. RAN 67 JTS OF 45.5~, J-55, BTC 10-3/4" CASING. FS @ 2619'. CEMENTED CASING WITH 1300 SX AS III LEAD, FOLLOWED BY 225 SX AS II TAIL. PERFORMED TOP JOB WITH 90 SX AS I. CIP @ 0300 HRS 7/12/88. NU BOPE. DAILY:S161,476 CUM:$259,727 ETD:S259,727 EFC:$690,000 CBU 10-3/4"@ 2619' MW: 9.1 VIS: 43 TEST BOPE..MU 9-7/8" DRILLING ASSEMBLY. RIH TO 2533' DRILL OUT FLOAT EQUIPMENT. PERFORM LOT OF 11.0 PPG EMW. DRILL 9-7/8" HOLE TO CORE POINT @ 3001'. CBU. CORE #1 F/3001'-3031'; CORED: 30', RECOVERED: 23'/77%. CORE #2 F/3031'-3056'; CORED: 25', RECOVERED: 18'/72%. DAILY:S37,781 CUM:$297,508 ETD:S297,508 EFC:$690,000 RUNNING LOGS CORE #3 F/3056'-3086'; CORE #4 F/3086'-3104'; CORE #5 F/3104'-3129'; CORE #6 F/3129'-3158'; CORE #7 F/3158'-3189'; CORE #8 F/3189'-3196'; 10-3/4"@ 2619' MW: 9.1 VIS: 47 CORED: 30', RECOVERED: 30'/100%. CORED: 20', RECOVERED: 16'/88%. CORED: 25', RECOVERED: 22'/88%. CORED: 29', RECOVERED: 29'/100%. CORED: 31', RECOVERED: 30.5'/100%. CORED: 7', RECOVERED: 8'/100%. DRILL TO 3516', KICK-OFF AND DRILL TO 4021'. RUN SHALLOW SAND LOGS (DIL/LSS/GR, NGT/CNL/EPT/LDT, FMS, SWC). DAILY:S174,808 CUM:$472,316 ETD:S472,316 EFC:$630,000 DRILLING 10-3/4"@ 2619' MW: 9.5 VIS: 37 FINISH SIDEWALL CORES(45 SHOT, 8 MISFIRE, 37 RECOVERED). MU BIT AND TURBINE AND TIH. DRILL AND SURVEY 4021'-6371'. DAILY:S24,567 CUM:$496,883 ETD:S496,883 EFC:$690,000 SHORT TRIP FOR LOGS 10-3/4"@ 2619' MW: 9.9 VIS: 41 DRILL AND SURVEY 6371'-7730' CIRC AND SURVEY. SHORT TRIP FOR LOGS. DAILY:S50,240 CUM:$547,123 ETD:S547,123 EFC:$690,000 The above is correct Signature For form preparation/a~-d distribution, see Procedures Mar~l_, Section 10, . _ J Date ASSOCIATE EI~II~'~ ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District County or Parish IState ARCO Alaska, Inc. Field KUPARUK RIVER UNIT JWell no. NORTH SLOPE BOROUGH Lease or Unit ADL: 25513 30-8 Irme DRILL Al?I: 50-029-21828 56.0000 Auth. or W.O. no. AK3005/AW0440 Operator ARCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. Old TD JA.R.Co. Date Released rig 07/19/88 ( 1 TD: 7770'( SUPV:SLC 07/20/88' ( 1 TD: 7770'( SUPV:SLC Classifications (oil, gas, etc.) Producing method Complete record for each day reported DO¥ON 1 4 07/10/88 Iotal number of wells (active or inactive) on thism cst center prior to plugging and I bandonment of this well our I Prlor status if a W.O. I 0700 HRS )) 40) o) POH LDDP 7"@ 7747' MW:10.1 VIS: 44 FINISH SHORT TRIP AND CIRC AND CONDITION HOLE. POH, LD BHA. RU SCHLUMBERGER RUN DIL/FDC/CNL/GR F/7693'-7150', CAL F/7693'-6300' RD SCHL. PU BHA, CUT DRILL LINE AND TIH. DRILL 7730'-7770'. CIRC AND CONDITION HOLE, SPOT PILL. POH LDDP. DAILY:S91,510 CUM:$638,633 ETD:S638,633 EFC:$690,000 RR 7"@ 7747' MW: 0.0 VIS: FINISH LDDP. CF, ANGE RAMS TO 7" AND TEST. RUN 195 JTS 7", 26#, J-55 CSG. SHOE @ 7746', COLLAR @ 7663'. CIRC 800 BBLS MUD AND CEMENT W/400 SX TLW @ 11.9 PPG AND 200 SX CLASS G @ 15.8 PPG. DISPLACE WITH 293 BBLS, 10.0 BRINE. BUMP PLUG TO 3500 PSI OK. FLOATS HELD OK. CIP 1745 7/19/88. WAIT 1 HOUR AND PUMP 150 BBL WATER TO CLEAR ANNULUS. ND BOPE, SET SLIPS, OF 7" W/AIR. INJECT 5 BBL OIL DOWN ANN. RELEASE RIG @ 0500 HRS, 7-20-88 DAILY:S242,641 CUM:$881,274 ETD:S881,274 EFC:$690,000 RECEIVED AUG - 9 198(I Naska 011 & Cons. Coar ssl6n ",,t Anch0raq(i PB Depth Kind of r g Type completion (single, dual, etc.) New TD Date Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Cji on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature J Date Title I For form prerT/a)/ation and distributio , see Procedur~ Manual, Section 10, Drilling, Pages 86 and 87. .ASSOCIATE ENGINEER ARCO Alaska, Inc. Date: July 29, 1988 Transmittal #: 7237 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 0 - 0 8 2" Dual Induction 7 - 1 8 - 8 8 3 80 0- 771 8 30-08 5" Dual Induction 7- 1 8-88 3800-7718 30-08 2"& 5" Porosity FDC 7-1 8-88 7150-7693 30-08 2" & 5" Raw FDC 7-18-88 7150-7683 30-08 Cyberlook 7-1 8-88 7150-7700 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Franzen D & M State of Alaska(+sepia) L. Johnston(vendor package) June 17, 1988 Telecopy: (907)276-7542 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 30-8 ARCO Alaska, Inc. Permit No. 88-64 Sur. Loc. 876'FNL, !929'FWL, Sec. 22, T13N, R9E, UM. Btmhole Loc. 1509'FSL, 1841'F%~L, Sec. 15, T13N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governraental agencies prior to co~mnencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. V.~y trqly you~,s, z C. V. Chatterton Chairman of Alaska Oil and gas Cousarvatiou Co~r~isaion BY ORDER OF THE COI.~iSSION dlf Enclosure F~sn & Game, cc: Department ofTM ~ Habitat Section w/o encl. Department of Environmental Conservation w/o enc!. STATE OF ALASKA ALASK.. OIL AND GAS CONSERVATION _3MMISSION PERMIT TO DRILL 20 AAC 25.005 i la. Type of work Drill [] Redrill []1 lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] Deepen,~11 Service Lq Developement Gas [] Single Zone ~ Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 59' , PAD 24'GL feet Kuparuk River Field Kuparuk River Oil Po! 3. Address 6. Property D.e;¢gnation P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25513v ALK 2554 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 2o AAC 25.O25) 876'FNL,1929'FWL,Sec.22,T13N,RgE,UM Kuparuk River Unit Statewide At top of productive interval(~ target) 8. Well nu.mber Number 1320' FSL,1848' FWL,Sec. 15,T1 3N,RgE,UM - . 30-8 #8088-26-27 At total depth 9. Approximate spud date Amount 1509'FSL,1841 ' FWL,Sec. 15,T13N,RgE,UM 07/02/88 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line DS 30-9 7716' ~'~ 3351 ' @ Surface feet 25' @ surface feet 2560 6822'.'~x/~, feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.O35 Kickoff depth 3600 feet Maximum hole angle 450 Maximum surface 1270 psig At total depth (TVD) 3200 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80 35 35 115 115' +200 cf 13-1/2"10-3/4" ~5.5# J-55 BTC 2569 35 35 2604 2604' 1300 sx AS I I I & , I--b~W ZZ~ sx A5 I I 8-1/2". 7" 26.0# J-55 BTC 7682 34 34 7716 6822' 400 sx TLW lead ~F-ERW 200 sx Class G tail 19. To be completed for Redrill, Re-entry, and Deepen Operations. TOC above Ugnu Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor SurfaceRECEIVED Intermediate Production JUN Liner Perforation depth: measured Alaska Oil & [las Cons. Commission true vertical ' Anchorage 20. Attachments Filing fee [] Property plat [] BOP Sketch [] DiverterSketch ~ Drilling program [] Drilling fluid program ~, Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements 21. I hereby cCy t~at the fore~,¢-I~ is/t,,~ and corr,ect to the best of my knowledge . i/ /...-/- .... ~ "'~'~- ' Reoional Drillino Enoineer Date ~ ...... ~./~ ~ O' ./~ ' ...... '~"ommission Us~ Only ~1~ TEI~ ) P~)3/6 Uf~ '; PermitNu~ber / i APInumber IApproval'dat~ I See cover letter 98-6/-( 50-- 0?-9 ~' 218~ 0 6 / '1 7 / 8 8 for other requirements Conditions of approval Samples required [] Yes ~ No Mud Icg required E3 Yes [~ No Hydrogen sulfide measures [] Yes 1~ No Directional survey required ~ Yes [] No Required wor~~/~~.~~~M; [] 1OM; © 15M Other: · by order of~'/~/'"/--/~ Approved by ~ ,,/.., k "''~'~~'/,~ Commissioner the commission Date Sub icate ARCO Alaska, Inc. Post Office Bo...00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 25, 1988 Mr. C. V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (f0k M REs I SR GEOL 'gFi b'.r:OL .... SYAT TE i ii..E: .... / RE' 20 AAC 25.071 Geologic Data and Logs Dear Mr. Chatterton' The Ugnu core planned for Kuparuk River Unit Well 30-12 has been moved to 30-08. Per our previous letter of April 20, 1988 and your response of May 2, 1988 (both attached), ARCO Alaska, Inc. (ARCO) will be the Operator and perform the coring. Standard Alaska Production Company will own the core and be responsible for filing Ugnu core data in accordance with 20 AAC 25.071. ARCO understands, as Operator, it will file all other required information for KRU well 30-08. Very truly yours, H. D. White HDW/RWC:ved Attachments cc' L.C. Smith AOGCC A. Garon SAPC ( ... ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Officf~'~3x 100360 Anchorage, ,laska 99510-0360 Telephone 907 276 1215 April 20, 1988 Mr. C. V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 RE: 20 AAC 25.071 Geologic Data and Logs Dear Mr. Chatterton: ARCO Alaska, Inc. plans to core the Ugnu formation in Kuparuk River Unit Well 30-12 for Standard Alaska Production Company. Under this arrangement, ARCO as operator, would perform the coring and immediately give the recovered core to Standard. Standard would own the core and be responsible for all costs and liabilities associated with collecting it. In 20 ACC 25.071, the operator is required to file certain core data with the Commission. In this case, however, the core data would not be available to ARCO. As a result, AR.C,O and Standard jointly request permission for Standard to assume ARCO s reporting duties for the Ugnu core in Well 30-12. Please advise Dan White (265-6193) with ARCO and Nick Freestone (564-4702) with Standard, if this reporting procedure meets your approval. Either may be contacted if you have any questions. Very truly yours, H. D. White Regional Engineer West Sak Engineering ARCO Alaska, Inc. N. J. Freestone Manager Shallow Sands Standard Alaska Production Company HDW/NJF:ved cc: L.C. Smith AOGCC ARCO Alaska. Inc. is a Subsidiary of Allan~,cRicqheldCom'ga~,'~ ALASKA OIL AND GAS CONSERVATION COMMISSION ! SIEVE C(7~PER, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 TELEPHONE (907) 279-1433 TE]',ECOP¥ NO: (907) 276-7542 May 2, 1988 Mr. H. D. White Regional Engineer West Sak Engineering ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Mr. N. J. Freestone Manager Shallow Sands Standard Alaska Production P. O. Box 196612 Anchorage, AK 99519-6612 Gent lemen .. Please refer to your joint April 20, 1988 letter regarding the reporting of geologic data for KRU Well 30-12. Your proposed handling of these data is approved. We will expect Standard Alaska Production Company to sample and timely file Ugnu formation core data in accord with 20 AAC 25.071(b)(3) and (7), erator, to file all other required information for Advise should you need further assistance. Very truly yours, _ ¢. V. Chatterton Cha±rman dlf: 1/CVC/5 P~ AflCOiALASKA. ;no. · Ped 30,. ~ell Hot 8 ?roposed ._Kupe.~uk Fleld,~ North Slope, Alae.ka : . .... I_OOQ_ .2000_ ; : · B/ PERHAFROST. TVD"I Z19 ~ "I0 _0 T/ UONU SNDS TVD-2Z04 ~ 3000 ........ T/ ~ S^K SNDS 'TVD-3499 -KOP TVD-3600 Ti'ID-3600 DEP'O - K-12 TVD-3889 THD-3890 DEP-22 4000 . ~_ .. ' : AVERAOE ANOLE ] 5000 __..~.. TVD"493!4 THD"5OZZ DEP-544 · I ~ K-5 TVD-58791 THD-6398 DEP-1466 · 60oo ............ . : ~ ' N' ~ T/ ZONE D TVD"6459 T~"7208 DEP"2032~ .... : : ~ T/ ZONE C TVD"6537 T~"~31Z DEP"2109 ,~ ~ :~'T/ ZONE'A TVD-6576 THD-7372 DEP-2147 ' : ~ TAROET CNTR TVD'~628 T~"~445 DEP"~19~ .ZOO0.- ~ B/: KUP SNDS 'TVD 6679 T~ ~516 DEP 2247 I 0 i! 000. ~ 2000 , VER~T-I CAL SECT! ON- .......... ! "TD-" (LOG" PT)' -' TVD-6822" THD-7716 DEP-2387' ' :. 3000 , ; ' 1 000 FEET i- ALE'.I~IN~ - 1 ARCO* ALASKA, Ino. Pod 30, Well Not 8 Propoeed Kuperuk Field. North Slope, Aleeke ~ 2000 : ....3000_, TD LOCATiOii~ 1 SOO' FSL. 1841 ' FWL: S~O. 15,.. TI 311q__ ROE'_ ; ............... ,_____ 2000__. ...................... ~ ......... 1000_ · .... ' 100.O___ ............................ ~ .............. WEST-EAST 1000 0 1000 I I I 20O0 I . TNtgET CENTER' DEI~I G? NORTH 3104.- WL:M' 81 TARGET LOCAT I ON, 13g0' FSL, 1840' FM. ~C- 15, TI3N. ROE ~1972, DEO(TO "~ ^ROEr'I I N T ~ 81,1RF~ .LOOATIOII ~ '* i 8?8' ~L.. 10~0' _F~IL , JUN ;L;~ l(-~;.,,., , Alaska Oil& Gas Cons. Commission ~ Anchorage · 1800L 1850' 750_ ...... 800--_ 900,_.. 950__ . 1 000. 1 900-' 1 950: 2000~ 2050 I ~.~ ~1-300 i . I - -'--~. .... : "' t,,.6ooi ,,9~ - i I ' i ~ ''~ soo_~_6°°i ' I i "'.t 3o0_. I i .............. i ~ "~go°o ! : , 1 4000~ ...... F--:""-: ............... '~ .................... t- ........ ' T 3800-. , .................... ,. ...... 1600 [ ~' ~':~- ' I 2100': 800- 85O- .................. I .......... 950- --"3"100 _ 100( _ 105(' 1101 ..., 2..9~..0...2~.0~.2-7-00 600 a, 600 I '/4800 ./~~ I .... 5200 ~ ' 1400 2700- ' °s°-I- ..... I / / I'- 000 1 800 1850: 900 · t 5400 1 200- / 600 ,/' 5500 1950. 2000 2050 21 O0 1.15~ GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS WITH UGNU/WEST SAK CORE 1) MIRU. 2) Install FMC diverter system. RU mud loggers. 3) Drill 13-1/2" hole' to 10-3/4" surface casing point according to directional plan. 4) Run and cement 10-3/4" casing. 5) Install and test BOPE. Test casing to 2000 psig. 6) Drill out cement and 10' new hole. Perform leak off test. 7) Drill 9-7/8" hole to core point according to directional plan. 8) Core UGNU/West Sak as directed with 9-7/8" x 5-1/4" equipment. 9) With coring complete, drill to about 4000' and log as directed. 10) Drill 8-1/2" hole to logging point according to directional plan. 11) Run open hole logs. 12) Drill 8-1/2" hole to provide 100' between PBTD and bottom of Kuparuk sands. 13) Run and cement 7" casing. Pressure test to 3500 psig. 14) Downsqueeze Arctic pack and cement in 7" x 10-3/4" annulus. 15) ND BOPE and install temporary Xmas tree. 16) Secure well and release rig. 17) Run cased hole logs. 18) Move in workover rig. NU BOPE. 19) PU 7" casing scraper and tubing, TIH to PBTD. Circulate hole with clean brine and TOH standing tubing back. 20) Perforate and run completion assembly, set and test packer. 21) ND BOPE and install Xmas tree. 22) Change over to diesel. 23) Flow well to tanks. Shut in. 24) Secure well and release rig. 25) Fracture stimulate. DEGASSER~ SHALE S STIR STIR SHAKERS LWIC4/~.h MUD GLEANER CENTRIFUGE TYPICAL MUD SYSTEM SCHEMATIC Density DRILLING FLUID PROGRAM Spud to Drillout Logging to 10-3/4" Casing Point to Coring .Weight Up 9.6-9.8 8.7-8.9 8.7-9.2 ~eight Up to TD 10.3 PV 15-30 5-15 5-15 9-13 YP 20-40 8-12 8-12 8-12 Viscosity 50-100 35-40 35-40 35-45 Initial Gel 5-15 2-4 2-4 3-5 10 Minute Gel 15-30 4-8 4-8 5-12 Filtrate API 20 ~10 10-20 pH 9-10 9.5-10.5 9.5-10.5 9.5-10.5 % Solids 10± 3-4 4-7 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 12.0 ppg EMW and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. TEM/8 ih In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluid disposal. RIVER UNIT 20" OlVERTER SCHEHATIC I I I [~ESCRI PTION 1. 16' C~TOR 2. FI*lC SLIP-ON WELl) STARTII~ FEAI) $. FI'tC DIVERTER 2000 PSI BALL VALV[~' 4. 20' 2000 I~1 ~11~ 5. 10' ~ BALL V~.V~/10' DIV~rl~ A SlI~t~ VALV~ I~'I'~LY C~I~tTI~J~ DIV~I(~I, 6. 20" 2000 PSI 4 ARCO ALA:~ut41, INC., I~QIJ[$T~ ~~kl. OF THIS DIVF. RTER 5'Y$1'E~ AS A VARIANCE FRCel 20AAC2~.035(b) MAINTENANCE & OPERATION II II 2 - I UPON INITIAL ~NSTALLATION, CLOSE PREVENTER VERIFY 'I'HA T VALVE OPENS PR~Y. 2. CLOSE ANNULAR PREVENTER AND BLOW AIR THROI. J6~ DIVERTER LINES EVERY 12 HOUI~. CLOSE ANNULAR PREVENTER IN THE EVENT 'INAT AN iNFLUX OF ~/ELLBORE FLUIDS OR GAS I$ DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DIVERSI(~. DO NOT .,SHUT IN WELL UNDER ANY CIRCUMSTANCES 7 6 1~8' ,~4:X)O PS] ~ ~ STACK_ ACCLM.LATOR CAPACI~ TEST :1. CI-I[CK ~ FILL ~K:CI, MJ~TCR RESERVOIR TO PRGI~R LEVEL WiTH I-IYORAU. lC FI.UID. 2. ASSkRE THAT AC(XM.LAT13~ PRESSI. I~E IS ~300 PSI ~TH 1500 P~I ~TRE~ CF' THE: REGU. ATGR. 5. CBSERVE TII~... T~EN C1.O~'__ ALL UNI]~J SII~I.T~~Y ~ REO3~ THE .TIhE AN:) PflESSI.IR~ REI~INII~ AF'I'I~ 4. RE03~ C~I ~ REP(~T, TIE ~~i.E Lt3~ER LIMIT 5 ii 4 ,I 13--5/8" B(~ STACK .TEST I. FILL B~ STAQ( AI~ Q-ID(E M~NIFCLD t~ITH ARCTIC DIESEL. 2. O-E~ THAT ALL LCX]( [X]V~I ~ IN V~]_LFE.~D ARE FLLLY RETRACTED. ~.AT TEST PLUG IN V~ITH I~1.1~dI~ JT ~ ~ IN L00(I~31~ 5. C1.C~E ~ PREVE~ A~D M~IJAL KILL ~ C3-O<~ LI~E V~ ~~ TO ~ ST~ 4. ~~ ~TO ~~I ~~DF~ i0 ~ ~~ TO~~I ~~F~ I0 ~_~[D ~~ TO 0 ~I. L1~ V~ ~ T~ PI~ ~ ~~ V~ ~KI~ ~~ LI~. ~~ TO ~~I ~ ~ ~I ~ IN ~ 4. 7.~I~ ~I~ ~L V~ LI~ ~ 4. ~ ~T ~~ TF~ ~ ~ A ~L ~I~ ~ITI~ ~ ~ ~Y 8. ~ T~ PI~ R~ ~ ~ ~~ PI~ ~T ~T~PI~ ~ TO ~ ~I ~~~I. 9. ~N~TT~PI~ ~ ~ ~ ~~ ~I. ~F~D ~ LI~ ~ F~ ~ ~UI~ ~T ~L V~ IN ~I~I~ ~ITI~ 12. ~ ~~I~ V~ ~Y. ~Y PI~ ~ETY V~ ~ I~I~ ~ TO ~ ~I. F~ SI~ ~ ~ TO ~ILLI~ ~V'I~. ~E~Y ~~ F~I~Y ~TE (8) (9 th~.t 13) 10. (10 and 13) 12. 13. Cas (14 thru 22) (23 thru 28) (29 thru 31) Company /4 }~C YES NO Is the permit fee attached ' "~ .eee®leeee®.eeeeeeeee.eeeeeeeeee.eee..ee~.. ~$ 2. Is well to be located in a defined pool ............................. ~__ 3. Is well located proper distance from property line .................. ~F 4. Is well located proper distance from other wells .................... ~ 5. Is sufficient undedicated acreage available in this pool ..' .......... ~. 6. Is well to be deviated and is wellbore plat included ................ ~ 7. Is operator the only affected party ................................. ~ .... 8. Can permit be approved before fifteen-day wait ...................... ~.,,, Does operator have a bond in force ................................ Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number 14. Is conductor string provided ........................................ ~ , ,,,,,, 15. Will surface casing protect fresh water zones ....................... .~ 16. Is enough cement used to circulate on conductor and surface ...... ... .~ 17. Will cement tie in surface and intermediate or production strings ... .~ 18. Will cement cover all know~ productive horizons ..................... ~ 19. Will'all casing give adequate safety in collapse, tension and burst.. ~ 20. Is this well to be kicked off from an existing wellbore ............. 21. Is old wellbore abandonment procedure included on 10-403 ............ 22. Is adequate wellbore separation proposed .... · ....................... ~' 23. Is a diverter system required ....................................... ~ ~,, 24. Is the drilling fluid program schematic and list of equipment adequate~ 25. Are necessary diagrams and descriptions of diverter and BOPE attached. ~ 26. Does BOPE have sufficient pressure rating - Test to ~~ psig .. ~ 27. Does the choke manifold comply w/API RP-53 (May 8~) .................. 28. Is the presence of H2S gas probable ................................. , W~f For exploratory and Stratigraphic wells: 29. Are data presented on potential overpressure zones? ................. 30. Are seismic analysis data presented on shallow gas zones .... ;~''"/ 31. If an offshore loc.. are survey results of seabed conditions 32 Additional requirements ' Geolq~y: Eng~A~er~i~g: WWBEw~~_ LcS ~ BEW / rev: 02/17/88 6.011 " INITIAL I GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ,,,,, , Additional Remarks: 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 information, 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. LIS T6PE VER~FiIC ~T~ON L~STING VP glO.H02 VERI':!CATION LISTING PAGE 1 ~ REEL HE~DER ~ ERVICE NAME :EOrT ATE :88/07/30 RIGIN :FLIC EEL NAME :72855 ONTINUATION ~ : REVIOUS REEL : OMMENTS :LIS TAPE, ARCO KUPARUK 3 0-8, AP~ ~50-029-2182~ ~ TAPE HEADER ~ ERVICE NAME :EDIT ATE :88/07/30 RIGIN :FLIC APE NAME :T2855 ONTINUATION ~ :1 REVIOUS T~PE : OMMENTS :LIS TAPE, ~RCO KUP~RUK ~ 0-8, ~PI ~5D-029-21828 * FIL~ HE~DER ~ ILE NAME :SDIT .001 ERVICE NAME :~L!C. ERSION ~ :O01AOZ ATE :8870'7/30 AXIMUM LENGTH :10~4 IL~E TYPE :LO REVIOUS FILE : COMMENTS .SCHLUMB ER.SE R ~L~SK~ COMPUTING CENTER )OB NUMBER AT AKCC: 72855 :UN fl, DATE LOGGED: 15-JUL-S8 ,DP: J. KOHRING ~ATE COMPUTEg: 2g-JUL-88 ;ASING = 10.75" @2614'('LOGGER) - BIT SIZE = 9.87'5" TO 3196' (LOGGER) VP OIO.~OZ. VE~TFT~A'TION. . _~ LISTING ~GE 2 BTT STZE = 8.5" 3196' TO 4020'(LOC~G:-R) YmE FLUID = BLAND LSN9 ENSITY = 9.2 LB/G RM = 5.41 @ 7t DF ISCOSITY = 53.0 5 RWF = ?.Ol @ 69 OF H = 8-5 RMC = N/~ LUID LOSS = 5.6 C3 RM AT BHT = 4.741 @ ~2 D~ IELD RE~'!~RKS (DIL/LSS P~SS): MUL'TIPLE 2" RUB3ER :IN STANDOFFS US:,~ ON LSS SONIC SONDE; BIT SIZE = 9 7/,~" 0 3196' ~ND 8 1/2" TO 4021'. OOL TYPES/NUMBERS: DIS 2140 DIC 214 SLS-SC 290 SLC 155 SGC 3109 IELD REMARKS (LDT/EDT/CNL/NGT P.~SS): TOOL ST~ING BOTTOM TO TOP: LDT/EPT/CNT/NGT. ~IT SIZE ~ 9 778" TO 3196' NO 8 1/~" TO 4021'; MATRIX OENSITY= S~ND (2.65); FLUID ENSITY = 1.0 G/C3; OLE CORRECTION = CALIPE~; iBHC = OPEN; TPM = 7.2; CNL BOWSPRING USED. EPT AIN P~SS (FIL'E 18) HAS POOR P~D CONTACT FROM ~532' TO 3500' USE REPEAT ECTION (FILE 17) OVER THIS INTERVAL. BIT SIZ:,: 9 7/8" TO 3~96', AND 9 1/2" ROM 3196' TO 4021'. OOL TYPES/NUMSERS: D~ S-C 4969 NGD-C 739 NSC-E 760 TCC-B 320 EPS-C 154 EPC-D 69 CNC-HA 3 32 VP 010.H02 VERIFICATION LISTING P~GE 3 DMPUTING CENTER REMARKS: EPT REP:AT (F17) SPLICED INTO LOG FILE (F18) FROM 3532' T3 3500' EPT ORDSIT¥ WAS RE-CALCULATED AT ~KCC BECAUSE IT WAS NOT SAVED ON FIELD ~APE. PHI.EPT ON THIS TAP: DOES NOT EXACTLY MATCH BLUELZN5 EPHIo OB NUMBER AT ~KCC: 72854 UN #2, DATE LOGGE3: 13-JUL-B8 DP: J. KOHRING ATE CDMPUTEO: 2$-JUL-~ ASING YPE FLUID ENSITY ISCOS[TY H LUID LOSS = 10.75" @2614'(LOGGER) - BLT SIZE : 8.5" TO 7724'(LDGGER) = LSNO = 10.0 LB/G RM = 4.65 @ 64 DF : 42.0 S RMF = 5.11 @ 64 DF : 9.5 RMC = 3.~3 ~ 64 OF = 4.8 C3 RM AT BHT = 2.158 g 146 OF IELD REMARKS: 1/2" STANDOFF ~NO 2' HOLE FINOER USE~ ON OIL; MATRIX DENSITY : SAND (2.65); LUID OENSITY: 1.O G/C~; HOLE CORRECTION : CALIPER; AN ADDITIONAL REPEAT PASS AS RUN OUE TO A SLIGHT CHANGE IN ILO 7422'-742B'. SECOND AND THIRD PASSES ERE GOOD. SP SHIFTS ~T 4759' AND AT 4098I. OOL TYPES/NUMBErS: DIS-EC 1'100 DIC-OA 1006 PGS-HB 508 CNC-A t238 VP OlO.H02 VEPI~IC~TIgN LISTING P&GE 4 SGC-JC 3533 !E ~-BE 1359 NL "!- B C 1015 -,-"'"'"'"'.~-,--,- THIS D~TA HaS NOT :.~E ~N_ _ DEPTH SHI=TED~ - OVERLAYS CIELD, PRINTS "'"'"'"'~.,.-,---,.-,- SCHLUMBERGER LOGS INCLUDED WITH THIS FILE (EDIT.O01): <SEE FIL~ EDIT.OO2 FOR 1.2" SAMPLED FDC/CNL DATA> <SEE FILE EglT.O02 FOR LOT/CNL 1.2" SAMPLE9 DATA> <SEE FILE EDIT.gOB FOR EPT 2" S~MPLED DAT~> RUN ~1: DUALINDUCTION SPHERICALLY FOCUSED LOG (.OIL) FIRST T~ LAST RE~OING: 4014' TO 2614' git MERGED g4014' TO ~UN 2, GR.'OIL MERGED AT 3987' LONG SP.~C~D SONIC LOG (.LSS) FIRST TO L~ST READING: 3979' TO 2614' NATURAL GAMMA LOG (.NGT) ~IRST TO LAST READING: 3962' TO 2614' L ITHO-O= ,_NSITY COMPENSATED LOG (.LOT) FIRST TO LAST ~RE~D!NG: 4016' TO 2614' CgM~ENS~TED N~UTRgN,_ LOG (.CNL) VP 010.H02 VERIFICATION LISTING PAGE FIRST Te L.&ST RE~DING: 398A' TO Z614] RUN ~1, CNL MERGED 70 RUN ~2 CNL TEN S. EPT ~ NVR. EPT ~ FV~. EPTs C~LI. EPT, SGR. EPT FIRST 70 E~ST ~E~DING: ~004' T~ 2616 CISED HOLE GAMMR RAY LOG (.CHL) ~IRST TO LAST RE~DING: 2516' TO 974' RUN ~2: DUAL ~g~T[ON SPHERICALLY FOCUSED LOG (~DIL) r~z~l lO L~ST REIOIN~: 7718' TO 3790' OIL MEP~ED .~4014' TO RUN I, GR.DIL MERGE AT 3987' F:DRMATI,JN DENSITY COMPENSATED kO~ (~FOC) FIRST TO L~ST ~EIOING. 6g ~ TO TI~B' COMPENSATED NEUTRON LOG (.CNL) FIRST TO LIST ~E~D!NG: g2T6Tg TO Tl~8' RUN ~1 CNL MmRGED TO RIJN CNL :~ INFORMATION RECgROS ABLE TYPE :CONS MNEM TUNI CN FN WN NATI STAT V~LU DEFI ARCO ALASKA, I~ COMPANY NAME KUPA~UK (WEST ~ FIELD NAME 3 0-8 WELL NAME U.S.~. NATION STATE OR PROVI~ VP 010.M02 V£RIFICATI~N LISTING ~GE 6 COUN SECT TOWN R LATI LONG OPER APIN APIN ABLE TYPE :CU~V COUNTY 2Z SECTION 13N TOWNSHIP 9E RANGE 878' =NL LATITUDE 1929' FEL LONGITUDE iSARBE~/M~LL~RY~ OPERATOR'S COD~ 50-029-2182B ~PI SERIAL NUM* 50-02q-ZlB2~ API SERIAL NUM~ MNEM DEFI ~EP'T 9EPTH CHANNEL TENS TENSION SFLU SFL UNAVER~GED$' ILM IL-MEDIUM RESI$ ILO IL-D~EEP RESIST~ SP SPON'T~NEOU:S PO~ GR GA~,MA TENS T~NSIgN DTL 9ELTA T LONG ~T 0ELT~-T GR G~MMA TENS T'EN SI ON GR GA~M A RAY TENS T~N;SION DPHI OENS!TY PO~OSZ~ DRHD DELTA RHO RHOB BULK gENSITY P E F ,m H 0 T 0 .- E L E C T R 'Z QLS QU.&L'IT Y CO NT ~0'.~ QSS QU~LZTY LL LONG LOWER WIN~ LS LONG SPACING LU LONG UPPER 1,-2'~ LITH L~'THOLOG WINOO~ SS1 SHORT SPACING SS2 SHORT SP~CZNG LSHV LONG SPACING SSHV SHOR'T SPACING CALI CALIPE~ SGR SP~EC'TRQSCDPY TENS T~NSZON NPHI NEUTRON ~OS~ TNR~ C~LI~R~TED THE~ RTNR R~W THeRMaL N~"' RCFT RCFT R C N T R C N T CFTC C~TC C N T C C N 'T r,~ G R G ~ ~ M A R ~ Y VP OlO.H02 VERIFICATION LISTING PAGE 7 TENS CS PDT~ URAN THOR WENG W4NG W3NG WZNG W1NS CGR SGR TENS DRHO NVR FVR CALI SGR TENS DPHI DRHO RHOB CAL! GR TENSION CABLE SOEED POTASSIUM URANIUM THORIUM WINDOW 5 (? WINDOW 4 (1.$ WINDOW 3 (1.1 WINDOW 2 (.5 WIND3W I (.150. COMPUTED GAMMA* SPECTRgSCDPY G* T:_-NSI~N DELT~ RH~ NEaR VOLTAGE R* ~AR VOLT,~G"E RE* C ,~L I P','6 R SPECTROSCOPY G* TENSION ,DENSITY POROSI* 'DELTA RHO ~ULK DENSITY C AL I P~R G~MM~ R~Y DATA FO'R~T R~CgRO ~ NTRY BLO~CKS TYPE SIZE ~EPR CODE I I 66 Z I 66 3 4 73 4 1 66 8 4 6~ 9 4 65 11 1 66 ~3 1 66 14 4 65 15 1 66 !6 1 66 0 I 66 )ATUM INEM SPECIFICATION BLOCKS SERVICE SERVICE UNIT ID ORDER ~ )EPT FT 'ENS OIL LB ;FLU OIL OHMM :LM OIL OHMM :LO OIL OHMM ;P OIL MV ;R OIL GA~! 'ENS LSS LB )TL LSS US/F tT LSS US/F ~ PI LOG TYPE CLASS API AP1 tPl FILE NO. O0 000 O0 0 1 O0 OOO O0 0 I 00 000 O0 0 O0 O00 O0 0 1 O0 000 O0 0 1 O0 gO0 O0 0 1 O0 000 O0 0 1 O0 000 OO 0 1 O0 000 00 0 1 O0 000 00 0 ENTRY 0 0 252 1 FT 4 0 FT 68 1 0 SIZE SPL 4 1 4 1 4 1 4 1 ,~ 1 4 1 4 1 4 1 4 1 4 1 0. 5000 REPR PROCESS CODE (:OCTAL) 68 00000000000000 68 00000000000000 68 O00OO000000:O00 68 00000000000000 68 O000000000000O 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 O00OO000000000 VP 010.H02 VERIfICaTION LISTING PAGE 8 R LSS S~I ENS CHL LB O0 000 R CHL GAPI ENS LDT LB O0 000 PHI LDT PU O0 000 RHO LDT G/C3 O0 OOO HOB LDT G/C3 O0 000 EF LDT O0 OOg LS LDT O0 gOO SS LDT O0 OOO L LDT CPS O0 S LDT CPS U LDT CPS O0 000 ITH LDT CPS O0 gO0 S1 LDT CPS O0 000 S2 LDT CPS O0 000 SHV LDT V O0 OOO SHV LDT V ALI LOT IN gO GR LOT G~PI O0 goo ENS CNL LB O0 OOO PHI CNL ~U O0 000 NRA CNL O0 gOO TNR CNL O0 OOO CFT CNL CPS O0 OOO CNT CNL CPS O0 iFTC CNL CPS O0 NTC CNL CPS O0 ,R CNL GAPI O0 OO9 'ENS NGT LB O0 000 iS NGT F/HR O0 gO0 'OTA NGT Pti O0 goo IRAN NGT PP~ O0 OOg 'HOR NGT PP~ O0 15NG NGT CPS O0 OOO 14NG NGT CPS O0 OOO 13NG NGT CPS O0 000 12NG NGT CPS O0 tlNG NGT CPS O0 ;GR NGT GAPI O0 goo ;GR NGT GAPI O0 go0 ~ENS EPT LB O0 000 )RHD EPT G/C3 O0 tVR EPT V O0 OOg :VR ~PT 'V O0 gOO ;ALI EPT IN O0 000 ;GR EP'T GAPI O0 OOO ~ENS FDC LB O0 000 )PHI FDC PU O0 000 )RHO FDC G/C3 O0 ~HOB FDC G/C3 O0 000 :ALI ~DC IN O0 OOO ;R FDC G~I O0 OOO O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O 0 0 O0 0 O0 0 O0 0 O0 O O0 0 O0 0 O0 0 OO 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 4 4 4 4 & 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 ¢ 4 4 4 4 4 4 4 4 4 4. 4 4 4 ,4 4 4 4 4 I 68 O0000OO0000000 1 68 OOO00000000OO0 1 68 00000000000000 1 68 00000000000000 1 68 OOOOO000000000 1 68 O0000OO0000000 I 68 O00000000OO000 I 68 O0000OO0000000 1 68 O000000OOOO000 1 68 09000000000000 1 68 O000000OOOOOO0 1 68 00000000000000 1 68 O000000OO00000 1 68 OgO0000OO00000 1 68 O000000OO00000 1 68 O00gOOO000000~ 1 68 OOO0000OOOO000 1 68 00000000000000 ! 58 00000000000000 1 68 O00000000000OO I 68 OOOOO000000000 1 68 OOO00OO00000:O0 1 68 00000000000000 1 68 O0000OOOO00000 1 58 O0000OO0000000 1 68 O000000OOOO000 1 68 OOO000000OOOOO 1 68 O000000000000O 1 68 O00000000OO00O 1 68 00000000000000 1 68 00000000000000 1 68 O00OO000000000 1 68 00000000000000 1 68 OOO00OO0000000 1 68 00000000000000 1 58 00000000000000 1 68 OOO000000OO000 1 58 00000000000000 1 68 O0000000000OO0 ! 68 OOO000OO000000 1 68 OOO00000000OOO 1 68 O000000000000O 1 :68 O0000OO0000OOO 1 68 O00000000OO000 1 58 00000000000000 I 6B O00OO00OO0000O 1 68 00000000000000 I 68 O000000000000O 1 58 O00OO000000000 1 68 00000000000000 1, 68 O0000OO0000000 1 68 O000000OO00000 1 58 O0000000000OO0 VP OlO.H02 VE~IFICATZON LISTING PAGE 9 DATA ~0 RM.&T NTRY BLOCKS TYPE SIZE REaR CODE ENTRY 1 1 66 0 2 I 66 0 3 ~ 7.3 252 4 B 4 6~ 9 4 6 5 FT 11 1 66 4 13 ! 66 0 14 4 65 ~T 15 1 66 68 16 ! 66 0 1 66 1 0.5000 ATUM SP'ECIF!CATION BLOCKS NEM SERVICE SERVICE UNIT APl AP1 AP1 AP1 FILE SIZE SPL REPR ID ORDER ~ LOG TYPE CLASS MOD NO. EPT FT O0 000 O0 0 1 4 ENS DIL LB O0 OOO O0 0 1 4 FLU DiL OHMM O0 000 O0 0 1 4 LM OIL OHMM O0 000 O0 0 1 4 LD OIL OHMM O0 000 O0 0 1 4 .P DIL MV O0 000 O0 0 1 4 ,R DIL GAPI O0 000 O0 0 I 4 ENS LSS LB O0 000 O0 0 1 4 ~TL LSS US/F O0 000 O0 0 '1 tT LSS US/F O0 000 O0 0 1 4 ~R LS~S G~PI O0 000 O0 0 1 4 'ENS CHL LB O0 OOO O0 0 1 4 ;R CHL GAPI O0 000 O0 0 1 4 'ENS LDT LB O0 000 O0 0 1 iPHI LDT PU O0 OOO O0 0 I 4 ~RHO LOT G/C3 O0 gO0 O0 0 1 :HOB LDT G/C3 O0 000 O0 0 1 4 'EF LDT ILS LDT O0 000 O0 0 I 4 tSS LDT O0 000 O0 0 1 4 .l LOT CPS O0 000 O0 0 1 .S LDT CPS O0 000 O0 0 1 .U LDT CPS O0 000 O0 0 1 .ITH LOT CPS O0 000 O0 0 1 ;SI LD'T CPS O0 000 O0 0 1 ;S2 LOT CPS .DO 000 O0 0 1 4 .SHV LOT V O0 000 O0 0 1 ;SHV LOT V O0 000 O0 0 1 ;ALI LOT IN O0 000 O0 0 I 4 ;GR LDT GAPI O0 OOO O0 0 i 4 'ENS CNL LB O0 0.00 O0 0 1 IPHI CNL PU O0 000 O0 O 1 4 'NRA CNL O0 000 O0 0 ITNR CNL O0 000 O0 0 1 tC~T CNL CPS O0 000 O0 0 ~ 4 ',mROCES,S CODE (OCTAL) 68 00000000000000 68 OOO0000000000O 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 OOOOOOO0000000 68 00000000000000 68 O00OO000000000 68 00000000000000 :68 00000000000000 68 O00000000OO000 68 00000000000000 68 00000000000000 68 O00OO000000000 68 O000000000000O 58 00000000000000 68 0000000~0000000 68 00000000000000 68 00000000000000 68 O0000OO0000000 68 00000000000000 68 00000000000000 68 00000000000000 68 OOO000000000OO 68 O000000000009O 68 OOO00000000000 68 68 00000000000000 68 00000000000000 68 O0000OO00OO00O 58 00000000000000 68 O0000'O00000000 68 00000000000000 68 000000~00000000 VP OiO.HOZ VERIFICATION LISTING PAGE IO CNT CNL CPS O0 FTC CNL CPS O0 NTC CNL CPS gO R CNL GAPI O0 ENS NGT LB O0 S NGT F/HR O0 OTA NGT PU O0 R~N NGT PPM O0 HOR NGT PP~ O0 5NG NGT CPS O0 4NG NGT CPS O0 3NG NGT CPS gO 2NG NGT CPS O0 ~NG NGT CPS O0 GR NGT GAPI O0 GR NGT G~PI O0 ENS EPT LB O0 RHO EPT G/C3 O0 VR EP'T V O0 VR EPT V O0 ALI EPT IN O0 GR EPT GAPI ENS FOC LB O0 !PHI FDC PU O0 ,RHO FDC G/C3 O0 HOB FDC G/C3 O0 ALI FDC IN O0 ,R FDC G~P! O0 000 OOO 000 000 gO0 OOO 000 000 gOO OOO OOg 000 000 000 OOO 000 OOO 000 000 000 000 000 000 000 000 000 000 O00 ~EPT LO ~TL ;R :HOB ,L ;S1 :ALI 'NRA ;FTC ;S 15NG IING iRHO ;GR :HOB 7741. 5000 'TENS 2.8136 SP - 999 . 2.500 D'T -999. 2500 TENS -9'99.2500 PEF -999. 2500 LS -999.2500 SS2 -999. 2500 SGR 3.0918 RTNR 795. 2611 CNTC -999. 2500 POTA :-999.2500 W4NG '-999.2500 CG~ -999.2500 NVR -999. 2500 'TENS !.4508 CALI ~EPT ',LO iTL ;R ',HO~ 7700.0000 TENS 3.2860 SP -99'9.2500 OT -999.2500 TENS -999.2500 PEF 3034.0000 -30.5313 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 3.13292 2422.5068 -999.2500 -999.2500 -999.2500 -999.2500 3034.0000 B.5391 6060.0000 -31.0156 -999.2500 -999.2500 -999.2500 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 00 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 OO O0 O0 gO O0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 SFLU GR GR DPHI QLS LU LSHV TENS RC~T GR UR,~N W3 NG SGR ~VR OPH! -GR SFLU GR GR OPHI QLS 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 .3. '7358 99.3125 -999.,2.500 ,-999. 2500 -999.2500 -999.2500 -999.2500 3034.0000 695.6271 99.3125 -999. 2500 -999.2500 -999.Z500 -999.2500 12.0 7 2 8 99.31.25 3.5843 99.3125 -999.2500 -999.2500 -999.2500 68 68 68 68 S8 68 68 68 68 68 6B 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 ILM TENS TENS DRHO QSS LI'TH SSHV NPHI ~CNT TENS THOR W2NG TENS CALI ORHO ILM TENS 'TENS ORHO qSS OOO00OO00gO000 OOO00000000000 OOO000000OO00O OOO00000000000 O000000000000O 00000000000000 00000000000000 O00OO000000000 O0000OO0000000 00000000000000 O000000000000O 00000000000000 OOO00OO0000000 O0000000000OO0 O000000000000O OOO00000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 OOOO0000000000 00000000000000 3.2587 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 35.6793 23513.1494 -999.2500 -999.2500 -999.3500 -999.2500 -999.2500 0.0752 :3.3834 -999.2500 -999.2500 -999.2500 -999.2500 VP 010.HOZ VERIfICaTION LISTING PAGE 11 L -999.2500 tS -999.2500 Si -999.2500 SS2 -999.2500 ALI -999.2500 SGR -999.2500 NRA 3.0918 RTNR 3.3292 FTC 795.2611 CNTC 2422.5068 S -999.2500 POT6 --'999.2500 5NG -999.2500 W4NG -999.2500 lNG -999.2500 CGR -999.~500 RHO -999.2500 NVR -999.2500 GR -999.2500 TENS HOB Z.,4733 C~LI 8.5156 EPT 7600.0000 LD 2.7550 TL -999.2500 R -999.2500 HOB -999.2500 L -999.2500 SI -999.2500 ALI -999.2500 NRA 3.5907 F'TC 536. 1537 S -999.2500 5NG -999. 2500 lNG -999. 2500 RHO -99 9. 2500 GR -999.2500 HOB 2.4387 EPT 7500.0000 LD 18.5509 TL -999. 2500 R -999.2500 HOB -999. 2500 t -999.2500 S1 -999.2500 ALI -999.2500 NRA 2.8492 FTC .~94. 7958 S '-99 9. 2500 5NG -999°2500 lNG -999.2500 RHO -999.2500 GR -999.2500 HOB 2.3362 EPT 740 O. 0000 LO 3.3138 TL -999. ,2500 R -999.2500 HOB -999. 2500 t -99 9. 2500 Si -999.2500 ALI -999.2500 TENS 6092.0000 SP -38.6250 97 -999.2500 TENS -999.2500 PEF -999.2500 tS -999.2500 SS2 -999.2500 SGR -999.2500 RTNR 3.9130 CNTC 1914.2410 POTA -999.2500 W4NG -999.2500 CGR -999.2500 NVR -999.2500 TENS 6092.0000 CALI 8.8437 TENS 6004.0000 SP -24.4844 97 -99'9.2500 TENS -999.2500 PEF -999.2500 LS -999.2500 SS2 -999.2500 SGR -999.2500 RTNR 2.9192 CN'TC 2502.88'04 PO'TA -999.2500 W4NG -999.2500 CGR -999'2500 NVR -999.2500 TENS 6004.0000 CALl 8.4297 LU LSHV TENS RCCT IJRaN W3NG SGR FVR 9PHI SFLU GR OR DPHI QLS LU LSHV TENS RCFT GR UR .~N W3NG SGR OPHI SFLU SR GR 9PHI QLS LU LSHV 'TENS RCFT UR ~ N W3NG SGR FVR DPHI TENS 6300.0000 SFLU SP -24.1719 GR 9T -999.2500 GR 'TENS -999.2500 9PHI PE= -999.25'00 QLS LS -999.2500 LU 552 -999.2500 LSHV SG~ -999.2500 TENS -999.2500 -999.2500 ~060.0000 695.6271 99.3125 -999.2500 -999.2500 -999.2500 -999.2500 10.7055 99.3125 2.9200 96.1875 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 6092.0000 469.5720 96.1875 -999.2500 -999.2500 -999.2500 -999.2500 12.8057 96.1875 23.3580 76.1250 -99'9. 2500 -999.2500 -999.2500 -999.2500 -'999. 2500 6004.0000 770.7'355 76.1250 -999- :2500 -999.2500 -999.2500 -999.2.500 19.0159 76.1250 3. 3228 92.6875 · -99:9.2 500 -999.25.00 -999.2500 -999. 2500 -999.2500 6300.0000 L I'TH SSHV NPHI RCNT TENS THOR WZNG TENS CALI DRHO ILM TENS TENS 9RHO QSS LITH SSHV NPHI RCNT TENS THOR W2NG TENS CALI DRHO I L M 'TENS TENS ORHO ~SS LITH S SHV NPHI R CN'T TENS THOR W2NG TENS CALI ORHO ILM 'TENS TENS ORHO QSS LITH SSHV NPHI -999.2500 -999.2500 35.7115 2353.1494 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 0.0889 2.8714 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 44.3496 1870.4451 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 0.0595 1'7. 8323 '-999.2500 -999. ~500 -999.2500 -999. 2500 -999.2500 -999. ,2500 31.7329 2470.8516 -999. 2500 -999.2500 -999.2500 -999.2500 -999.2500 0.0125 3.2558 -999. 2500 -999. 2500 -999. 2500 -999.2500 -999. 2500 -999.2500 39.1676 VP OlO.H02 VERIFICATION LISTING PAGE 112 NRA 3.2853 ~TNR FTC 556.2855 CNTC S -999. 2500 907~ 5NG -999.2500 W4NG lNG -999.2500 CGR RHO -999.25'90 NVR GR -999.2500 TENS HOB 2.4945 C~LI EPT 7300.0000 TENS LD 3.2745 SP TL -999.2500 OT R -999.2500 TENS HOB -999.2500 L -999.2500 LS S1 -999.2500 SS2 ALI -999.2500 SGR NRA 2.9313 RTNR FTC 859.9990 CNTC S -999.2500 5NG -999.2500 W4NG lNG -999.2500 CGR RHO -999.2500 NVR GR -999.2500 TENS HOB 2.5826 CALI EPT 7200.0000 TENS ID 1.9556 SP TL -999.2500 OT R -999.2500 TENS HOB -999.2500 PE~ L -'999.2500 tS $1 -999.2500 SS2 ALI -999.2500 SGR NRA 13.1219 RTNR FTC 65!5.6969 CNTC S -999.2500 ~OTA 5NG -999°2500 W4NG lNG -999.2500 CGR RHO -999.2500 NVR GR -999.2590 TENS HOB 2.35:52 CALl EPT 7100.0000 TENS LO 1.8078 SP TL -999.2500 gT R -999.25,00 TENS HOB -999.2500 gEF L -999.2500 LS S1 -999.2500 SS2 ALI -999.2500 SGR NRA -999.2500 RTNR FTC -'999.2500 CNTC S -999.2500 POTA 3.6840 RC:T 2143.2222 GR -999.2500 UR&N -999.2500 W3NG -999.2500 SGR -999.2500 =VR 5300.0000 DPH! 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ZSDO DT iR -999.2500 TENS ',HOB -999.2500 PEF ,L -999.2500 LS ;S1 -999.2500 SS2 ;ALI -999.2500 SGR 'NRA - 999. 2500 RTNR ',FTC -999.2500 CNTC :S -999.2500 ~OTA ISNG -999.2500 W~NG IING -999. 2500 CGR IRHO -999.2500 NVR ;GR -999. 2500 'TENS ',HOB -999.2500 C~LI iEPT 6800.0000 TENS :LD 1. 3849 SP ,TL -999. 2500 UT mR -99'9. 12500 'TENS :HOB -999. 2500 PEF ,L -999.2500 LS ~S1 -999.2500 SS2 iALI -999. 2500 SGR 'NRA -999.2500 :F'TC -999,.2500 CNTC :S -'999. 2500 15NG -999.2500 W4NG I1NG -999.2500 CGR )RHO -999.2500 NVR -999.2500 W3NG -999.2500 SGR -999.2500 -999.2500 DPH! -999.2500 GR 6140.0000 SFLU -28.8750 GR -999.2500 GR -999.2500 ~PH! -999.2500 QLS -999.2500 LU -999.2500 LSHV -999.2500 TENS -999.2500 RCFT -999.2500 GR -999.2500 UR~N -999.2500 W3NG -999.2500 SGR -999.2500 FVR -999.2500 DPH! -999.2500 GR 5988.0000 SFLU -31.70'31 GR -999.2500 GR -999.2500 DPHI -999.2500 QLS -999.2500 LU -999.2500 LSHV -999.2500 TENS -999.2500 RCFT -99'9.2500 GR -999.2500 UR~N -999.2500 W3NG -999.2500 SG~ -999.2500 FVR -999.2500 DPHI -999.2500 GR 6104.0000 SFLU -28.7656 "R '-999. 2500 GR -999.2500 DPHI -999.2.500 QLS -999.2500 LU -999. 2500 LSHV -999. 2500 TENS -999. 2500 RCFT -999.,2.500 GR -999.2500 URAN -999. 2500 W3NG '-999.2500 SGR -999. 2500 FVP -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.4256 116.6875 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 - 999. 2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 4.1040 163.2500 -999. 2500 -999.2500 -999.2500 -999. 2500 -999. 2500 -999.2500 -999.2500 -999.2 500 -999.2500 -'999.2500 -999.2500 -999.2500 -999.2500 -999.2500 1.4094 258.5000 -999. 2500 -999. 2500 -999.2500 -999.2500 -999.2500 -999.2500 ,-999.2500 -9 99.250 O -999.2500 -999. ,2500 -999.2500 -999.2500 W2NG TENS CALI gRHO ILM TENS TENS ORHO QSS LITH SSHV NPHI RCNT TENS THOR W2NG TENS CALI DRHO ILM TENS TENS DRHO QSS LITH SSHV NPHI RCNT TENS 'THO R WZNG "TENS CALI DRHO IL M TENS TENS ORHO QSS l I'TH SSHV NPHI RCNT TENS THOR W2NG T E N S CALI -999.2500 -999.2500 -999.2500 -999.2500 2.3590 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 3.2786 -999..2500 -999.:2500 -999.2500 -999.2500 -999.25'00 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 '-999.2500 -999..2500 1.4493 -999'2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 VP 010.H02 VERIFICATION LISTZNG PAGE 14 GR -999.2500 TENS -999.2500 HOB -999.2500 CALI -999.2500 EPT 6TO0.O000 TENS 5,548.0000 LO 1.7606 SP -29.46,38 TL -999.2500 DT -999.2500 R -999, 2500 TENS -999.2500 HOB -999. 2500 PEw -999, 2500 L -999.2500 tS -999.2500 S1 -999.2500 SS2 -999.2500 ALI -999.2500 SGR -999.2500 NRA -99~.2500 RTNR '999.2500 FTC -999. 2500 CNTC -999,2500 S -999,2500 POTA -999.2500 5NG -999.2500 W4NG -999.2500 lNG -999.2500 CGP -999.2500 RHO -999.2500 NVR -999.2500 GR '-99'9.2500 TENS -999.2500 HOB -999. 2500 CALl -999. 2500 EPT 5600.0000 TENS 56.~4. 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-999.2500 -999.2500 2.7768 102. 4375 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -'999.2500 -999. 2500 -999.2500 -999.2500 -999.2500 -999.25,00 -999.2500 -999.2500 -999.2.500 :2.5254 111.8125 -999.2500 -999.250'0 -999.2500 -999.2500 ORHO QSS LITH SSHV NPHI RCNT TENS THOR W2NG TENS CALI ~RHO ILM TENS 'TENS ORHO QSS LITH SSHV NPHI RCNT TENS 'THOR W2NG TENS CALI ORHO ILM TENS TENS DRHD .2SS LITH SSHV NPHI RCNT TENS T HO R W2NG 'TENS CALI DRHO ILM TENS TENS gRHO QSS l ITH -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.45'78 -999.2500 -999. 2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 '-999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.25~0 2.7018 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.25~0 -999.2500 -999.2500 -999.Z5~0 ,-999.2500 -999.2500 -999.2500 -999.25100 -999.2500 2.5936 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 VP 010.H02 VERIFICATION LISTING PAGE 17 SI -999.2500 SS2 ALI -999.2500 SGR NRA -999.2500 RTNR FTC -999.2500 CNTC S -999.2500 POTA 5NG -999.2500 W4NG lNG -999.2500 CGR RHO -999. 2500 NVR GR -999.2500 TENS HO8 -999.2500 CALI .EPT 5700.0000 TENS LD 2. 5624 SP 'TL -999.2500 gT ,R -999.2500 TENS ~HOB -999.2500 PEF ,L -99'9. 2500 LS ,Sl -999.2500 5S2 iALI -999. 2500 SGR 'NRA -999.2500 RTNR ',FTC, -999. 2500 CNTC ',S -999.2500 PgTA IENG -999.2500 W4NG I1NG -999.2500 CGR ~RHO -999.2500 NV~ ;GR -999.2500 TENS ',HOB -999. 2500 CALl )EP'T 5500. 0000 'TENS :LD 3.0632 SP ITL -999.2500 DT ~R -999,,, 2500 TENS ~HOB -999.2500 ~EF .L -999.2500 tS ;SI -999.2500 SS2 'ALI -999. 2500 SGR 'NRA -999. 2500 RTNR ~FTC -999. 2500 CNTC ~S -999.2500 POT~ 15NG -999. 2500 W&NG I1NG -999.2590 CG~ )RHO -999. 2500 NVR ~GR -999. 2500 TENS [HOB -999. 2500 CALl )EPT 5 500. 0000 TENS [LO 2. 864,6 SP )TL -999. 2500 g'T ;R -999.2500 TENS :~HOB --999. 2500 PEF .t -999.2500 tS ~S1 -999.2500 SS2 ~ALI -999.2500 SGR rNRA -999.2500 ~TNR -999.2500 tS~¥ -999.2500 TENS -999.2500 RCmT -999.2500 gR -999.2500 dR~N -999.2500 W3NG -999.2500 SG~ -999.2500 FVR -999.2500 9PHI -999.2500 5~ 4708.0000 SFLU -55.0938 GR -999.2500 GR -999.2500 DPH'I -999.2500 QLS -999.2500 LU -999.2500 LSHV -999.2500 'TENS -999.2500 RCFT -999.2500 gR -999.~500 ~R~N -999.2500 W3NG -999.2500 SGR -999.2500 FVR -999.2500 9PHI -999.2500 GR &660.0000 SFLU -64.3750 GR -999.2500 GR -999.~500 DPHI -999.2500 QLS -999.2500 tU -999.~500 LSHV -999.2500 TENS -999.2500 ~CFT -999.2500 -999.2500 URAN -999.2500 W3NG -999.2500 SGR -999.2500 -999.2500 OPHI -999.2,500 GR ¢960.0000 SFLU -64.1250 GR -999.2500 GQ -999.2500 OPgI -999.2500 QLS -999.2500 LU -999.~500 LSHV -999.2500 'TENS -999.2500 RC:~T -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -ggg.2500 2.,~307 99.5625 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999. 2500 · - 999.2500 -999. 2500 -999. 2500 -999.2500 13.4344 114.0625 -999.2500 -999.2500 -999.2500 -99'9.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 ,-999.2500 -999.2500 -999.2500 -999.2500 2.8170 95.3750 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.~500 -999.~500 SSHV NPHI RCNT TENS THOR W2NG TENS CALl ORHO ILM TENS TENS ORHO QSS LITH SSHV NPHI RCNT TENS THOR ~2NG TENS CALI DRHO ILM 'TENS 'TENS DRHO QSS LI'TH SSHV NPHI ~CNT TENS THOR WZNG 'TENS CALl ORHO ILM TENS TENS ORHO ~SS LITH SSHV NPHI RCNT -999.2500 -999.2500 -999.2500 -999.2500 -999.2590 -999.~500 -999.2500 -999.2500 -999.2500 2.5729 -999.~500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 3.0320 -999.2500 .-999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.8645 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.~500 VP 010.HOZ VERIFICATION LZSTING PAGE FTC -999.2500 CNTC -999.25D0 S -999.2500 POTA -999.2500 5NG -999.2500 W4NG -999.2500 lNG -999.2500 CGR -999.2500 RHG -999.2500 NVR -999.2500 GR -999.2500 TENS -999.2500 HOB -999.2500 CALI -999.2500 EPT 5400.0000 TENS 4340.0000 LO 2.7213 SP --66.9375 TL -999.2500 9T -999.2500 R -999.2500 TENS -999.2500 HOB -999.2500 mEF -999.2500 L -999.2500 tS -999.2500 S1 -999.2500 592 -999.2500 ALI -999.2500 SGR -999.2500 NRA -999.2500 RTMR -999.2500 FTC -999.2500 CNTC -999.2500 S -999.2500 ?OT~ -999.2500 5NG -999.2500 W4NG -999.2500 lNG -999.2500 CGR -999.2500 RHO -999.2500 NVR -99'9.2500 GR -999.2500 TENS -'999.25'00 HOB -999.2500 CALI -999.2500 EPT 5300.0000 'TENS 4368.0000 LD 2.8053 SP -72.3?50 TL -999.2500 gT -999.2500 R -999.2500 TENS -999.2500 HOB -999.2500 P~F -999.2500 L -999.2500 tS --999.2500 SI -999.2500 SS2 -999.2500 ALI -999.2500 SGR -999.2500 NRA -999.2500 RTNR -'999.2500 FTC -999.2500 £NTC -999.2500 S -999.2500 PO'TA -999.2500 'ENG -999.2500 W4NG --999.2500 I1NG -999.2500 CGR -999.2500 'RHO -99:9-2500 NVR -999.2500 ~GR -999.2500 TENS -999.2500 iHOB -999.2500 C~LI -999.2500 ~EPT 5200.0000 TENS 'LD 2.7451 SP -69.'5000 )TL -999.2500 OT -999.2500 ;R -999.2500 'TENS -999.2500 iHOB -999.2500 PEm -999.2500 ,L -999°2.500 LS -999.2500 ',S1 -999. 2500 SS'Z -999.2500 ',ALI -999.2500 SGR -999.2500 'NRA -999.2500 RTNR -999.2500 ',FTC -999.2500 CNTC -999.2500 iS -999.2.500 POTA -'999.2500 ~ENG 999.2500 W4NG -99.9.2500 GR URAN SGR FVR DPH! GR SFLU GR DPHI ~LS LU LSHV TENS RCFT GR UR~N W3NG SG :R FVR DPHI gR SFLU GR GR OPHI Q t S LU LSHV TENS RCFT GR UR ,~N W3NG :SG R ~VR DPHI GR SFLU GR GR OPHI ~tS LU LSHV TENS RCFT URAN -999.2500 -999.2500 --999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.6338 96.8750 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -99'9.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.67.61 100.4375 -999.2500 -999.2500 -999.2500 -999. 2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2 500 -999.2500 -999.2500 2.7454 94.2500 -999. 2500 -999.2500 -999.2500 -999. 21500 -999.2500 -999. ,2500 -999.2500 -999. 2500 -999.2500 -999.2500 TENS THOR W2NG TENS C~LI 9RHO ILM TENS TENS ORHO LITH SSHV NPHI RCNT TENS THOR WZNG TENS CALI DRHO ILM TENS TENS DRHO QSS LITH SSH'V NPH! RCNT TENS THOR W2NG TENS CALI DRHO ILM TENS TENS DRHO QSS LITH SSHV NPHI RCNT TENS THOR W2NG -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.7378 -999.2500 -999.2500 -999. 2500 -999.2500 -999.3500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.7935 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.~500 -999.2500 -999.2500 -999.2500 -999.2500' -999.2500 -999.2500 -999.2500 -999.2500 2.6991 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -'999.2500 -999.2500 -999.2500 VP 010.HOZ VERI~ICAT'ION LISTING PAGE 19 lNG -999.2500 CGR -99'9.2500 RHO -999.2500 NVR -999.2500 GR -999.2500 TENS -999.2500 HOB -999.2500 CALI -999.2500 EPT 5109.0000 TENS ~lOB.O000 LO 3.2081 SP -70.8750 TL -999.2500 gT -999.2500 R -999.2500 TENS -999.2500 HOB -999.2590 PEp -999.2500 L -999. 2500 LS -9gg. 2500 SI -999.2500 9S2 -'999.2500 ALI -999. 2500 SGR -999. 2500 NRA -999.2500 RTNR -999.2500 FTC -999.2500 CNTC -999.2500 S -999.2500 POTA -999.2500 5NG -999.2500 W4NG '-99'9.2500 lNG -999.2500 CGR -999.2500 RHO -999.2500 NVR -999.2500 GR -999.2500 TENS -999.2500 HOB --999.2500 CAtI -999.2500 EPT 5OOO.O000 TENS 4120.0000 LO 2.8752 SP '-70.6250 TL -999.2500 9'T -999.2500 R -999.2500 TENS -999.2500 HOB -999.2500 PEP --'999.2500 L -999.2500 tS -999.2500 SI -999.2500 SS2 -999.2500 ALI -999.2500 SGR -999.2500 NRA -999.2500 RTNR -999.2500 FTC -99'9.2500 CNTC --999.12500 S -999. 2500 POTA -999.2500 !SNG -999.2500 W4NG -999.2500 lNG -999.2500 CGR -999.Z500 ,RHO -999.2500 NVR -999.2500 ,GR -999.2500 TENS -999.2500 HOB --999.2500 CALI -999.2500 )EPT 4900.0000 'TENS 3984.0000 iLO 2.9991 SP -'711.93'75 )TL -999.2500 DT -999.2500 iR -999.2500 TENS -999.2500 :HOB -999.2500 DEr .-999.2500 ,L -999.2500 tS -999.2500 ;S1 -999.2500 5S2 -999.2500 ;ALI '-:999.2500 SGR -999.2500 'NRA -999.2500 RTNR -999.2500 ;FTC -999.2500 CNTC -'999.2500 ;S -999.2500 ~O'TA -999.2500 1:5NG -999.2500 ~4NG -999.2500 )lNG -999.2500 CGR -999.2500 )RHO -999.2500 NVR -999.2500 ;GR -999.2500 'TENS -999.2500 FVR DPHI GR SFLU GR GR gPHI ~LS LU LSHV TENS RCFT GR URAN W3NG SGR DPHI GR SFLU GR gR gPHI QLS LU LSHV TENS RCFT GR UR~N W3NG SGR FVR DPHI SFLU GR GR DPHI QLS LU LSHV TENS RCFT GP URAN W3NG SG~ mVR OPHI -999.2500 -999.2500 -999.2500 -999.2500 3.0403 97.4375 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -99'9.2500 -9'99.2500 -999.2500 -999.2500 -999.2500 -'999.2500 -999.2500 2. 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Z. 106. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. . 9~. -999. -999. -999. -999. -999. --999. -999. -999. -999. -999. -999. --999. -999. --999. . 94. - 999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. 2500 6627 6875 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 2930 2500 2 500 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 3598 1875 2500 2500 2500 2500 2500 2500 2500 Z500 2500 2500 2500 2500 2500 2500 3441 ILM TENS TENS ORHO QSS LITH SSHV NPHI RCNT TENS THOR W2NG TENS CALI DRHO ILM TENS TENS DRHO QSS LITH SSHV NPHI RCNT TENS THOR ~2NG TENS CALI' DRHO ILM 'TENS TENS DRHO QSS L.!TH SSHV NPHI RCNT TENS THOR WZNG TENS CALI ORHO ILM 2.B791 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.Z500 -999.2500 -999.~500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 1.9626 -999.2500 -999.2500 -'999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.6822 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -99'9.2500 -999.25~00 -999.2500 -999.2500 --999.25'00 1.0389 VP OlO.H02 VERIfICaTION LISTING PAGE 21 LD 1.0976 SP TL -999.2590 DT R -999.2500 TENS HOB -999.2500 ~EF L -999.2500 LS S1 -999.2500 SSZ ALI -999.2500 SGR NRA -999.2500 RTNR FTC -999.2500 CNTC S -999.2500 POTA 5NG -999.2500 W4NG lNG -999.2500 CGR RHO -999. 2590 NVR GR -999.2500 TENS HOB -999.2500 CALl EPT 4¢00.0000 TENS LD 2.4737 SP TL -999.2500 OT R -999. 2500 'TENS HOB -999. 2500 PEF L -999. 2500 LS S1 -999.2500 SS2 ALI -999.2500 SG~ NRA -999.2500 RTNR FTC -999. 2500 CN'TC S -99'9.2500 PO'TA 5NG -999.2500 W4NG lNG '-99'9. 2500 CGR RHO -999.2500 NVR GR -999.2500 TENS HOB -999.2500 CALl EPT 4300.0000 TENS LO 3.0276 SP TL -99'9.2500 9T R -999. 2500 'TENS HOB .-999. 2500 PfF L -999. 2500 tS S1 -999. 2500 SS2 ALI -999.2500 SGR NRA -999. 2500 RTNR FTC -'999. 2500 CNTC S -999.2500 POTA 5NG -999. 2500 W4NG lNG -999.2590 CGR RHO -999.2500 MVR GR -999.2500 TENS HOB -999.2500 CALI EPT 4200.0000 'TENS LD 3.1026 SP TL -999.2500 DT R -999.2500 TENS -30.5469 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 3560.0000 -29.D938 -999.2500 -999.2500 -999. 2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 .-999.2500 -999.25D0 3454.0000 -32.T813 -999.2500 -999.2500 -999.2500 -999.2500 -999.250,0 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 3330.0000 -36.9375 -999.2500 -999.2500 GR GR gPHI QLS tU LSHV TENS RC:T GR UR~N W3NG SGR gPHI SR SFLU GR DPHI QLS LU LSHV TENS RCFT GR UR&N W3NG SGR FVR 'DPHI GR SFLU GR OPHI QLS LU LSHV TENS RC:T GR URAN W3NG SGR FVR gPHI SFLU GR 9PHI 113.9375 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -99'9.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.2273 93.5625 -999.2500 -999. Z 500 -999.2500 -999.2500 -'999. 250 0 -.999.2500 -999.2500 -999.2500 -999. 2500 -999.2500 -999.2500 -999.2500 -999.,2500 -999.2500 2. 77115 85.0000 -999.2 500 -999.2500 -999. 2500 -999.2500 -999.2500 -999.2500 - 999. 2500 -999.2500 -999.2500 -999.25~0 .-999. 2590 -999. ZSOO -999.2500 -999.2500 2.8726 83.8125 -999.2500 -999.2500 TENS TENS DRHO QSS LITH SSHV NPHI RCNT TENS THOR WZNG TENS CALl ORHO 'IL M TENS TENS DRHO QSS LITH SSHV NPHI RCNT TENS THOR W 2 NG TENS CALI ORMO !LM TENS TENS DRHO QSS LITH SSHV NPHI RCNT TENS 'THO R W 2NG TENS CALI DRHO ILM 'TENS TENS DRHO -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.~500 -999.2500 -999.2500 -999.2500 -999.2500 2.3696 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -99'9.2500 2.9278 -999.2500 --999.2500 .-999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999..2500 -999.2500 -999.2500 -'999.2500 -999.2500 -999.2500 -999.2500 3.0260 -999.2500 -999.2500 -999.2500 VP 010,H02 VERIFICATION LISTING PAGE 22 HOB -999.2500 L -999.2500 tS SI -999.2500 SS2 ALI -999.2500 SGR NRA -999,2500 RTNR FTC -999, 2500 CNTC S -999,2500 POTA 5NG -999,2500 W4NG lNG -999,2500 CGR RHO -999.2590 NVR GR -999.2500 TENS HOB -999,2500 CALI EPT 4100.0000 TENS LD 2.9092 SP TL -999.2500 97 R -999.2500 TENS HOB -999,2500 PEF L -999,2500 LS SI -999.2500 SS2 ALI -999.2500 SGR NRA .-999.2500 RTNR FTC -999,2500 CN~TC S -999,2500 POTA 5NG .-999,2500 W4NG lNG '-999.2500 CG~ RHO -999.2500 NVR GR -999.2500 TENS HOB -,999,2500 CALl EPT 4000.0000 TENS LO 3.0319 SP TL 109.2500 DT R -999.2500 'TENS HOB 2,25'35 PEF L 221.0000 tS S1 235.0000 SSZ ,ALI 8.7500 SGR NRA 3.1869 R'TNR ,FTC 597,4518 CNTC S 1875.0000 POTA 15NG 9.6038 W4NG I1NG 334.9340 CGR )RHO 0.0080 NVR ~GR 105.0879 TENS iHOB -999.2500 CALl )EPT 3900.0000 TENS i:LD 2.6809 SP iTL 117.0000 OT iR -999.2500 rTENS IHOB Z,2431 PEF .L 222.8750 LS ;S1 230.87~0 SSZ -999.2500 QLS -999.2500 LU -999.2500 LSHV -999.2500 TENS -999.2500 RC~T -999.2500 GR -999.2500 URAN -999.2500 W3NG -999,2500 SGR -999,2500 ~VR -999,2500 gPHI -999,2500 GR 3270.0000 SFLU -37.4688 GR -999.2500 GR -999.2500 DPHI -999.2500 QLS -999.2500 LU -999.2500 LSHV -999.2500 TENS -999,2500 ~CFT -999,2500 GR -999.2500 UR~N -999.2500 W3NG -999.2500 SGR -999.2500 FVR -999,2500 OPHI -999.2500 GR 1210.0000 SFLU -20.0156 GR 108.7500 GR 1395.0000 DPHI 3.0820 QLS 409.0000 LU 332.2500 LSHV 105.0879 'TENS 3,36:21 RCF'T 11874.8052 GR 2.9717 URAN 19.Z077 W3NG 78.0540 SGR 4.1094 FV~ -999.2500 DPHI -999.2500 GP 1160.0000 SFLU -19.8281 SR 117.2500 GR '1340.0000 OPHI 2.8105 QLS 412.5000 LU 332.2500 LSHV -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.4604 86.3750 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999,2500 -999,2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 3.6388 75.0000 60.2813 24.0287 0.0000 375.7500 1192.0000 11395. 0000 ]5(50. 0175 105.0879 3. 8236 69. 4274 105.0879 0.7129 -999.2500 -999.2500 1.7172 91.2500 91. 2500 24.6595 -0. DO10 379.2500 11:93. 0000 QSS LITH SSHV NPHI RC NT TENS T HO R WZNG TENS CALI DRHO ILM TENS TENS DRHO QSS t I'TH SSHV NPHI RCNT TENS THOR W2NG 'TENS C A L I ~RHO ILM TENS TENS DRHO QSS LITH SSHV NPHI RCNT TENS THOR W2NG 'TENS CALI DRHO ILM TENS TENS ORHO QSS LITH SSHV -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.7569 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 3.2221 1,ZlO.O000 -999.2500 0.0080 0.0220 111.6875 1153.0000 37.0986 1903.4045 1395.0000 9.1825 176.4706 1395.0000 8,7500 -999.2500 2.7096 1160.0000 -999.2500 0.0011 0.0098 117.1250 1152.0000 VP OlO.H02 VERIFICATION LISTING PAGE 23 ALI 8.4544 SGR NRA 3.4799 RTNR FTC 520.6913 CNTC S 1933.0000 5NG 9,4737 W4NG lNG 333,6842 CGR RHO 9o0011 NVR GR 101.0174 TENS HOB -999.2590 CALI EPT 3800.0000 TENS LD 4.6304 SP TL !09.5000 DT R -999.2500 TENS HOB 2.1963 PEF L 24B.1250 tS S1 243.0000 SS2 ALI 8.8984 SGR NRA 3.3713 RTNR FTC 556.3563 CNTC S 1970,0000 POT~ 5NG 6,5646 W4NG lNG 24!5.9766 CGR RHO 9,01-41 NVR GR '?0. 2251 TENS HOB -999.2500 CALI EPT 3'700.0000 TENS LO 3.4444 SP iTL 11'3.5000 gT R -99'9.2500 TENS HOB ,2,!357 PEF t 226,3750 LS S1 231,8750 SSZ ALI 8.4141 SGR NRA 3.2823 RTNR FTC 582.1932 CNTC S 1977,0000 ~g'T~ 'ENG 12,0219 W4NG lNG 315,8470 CGR RHO 0.0019 NVR GR 90.6617 TENS HOB -999,2500 CALI EPT 3600.0000 TENS LO 4.2350 SP TL 114.5000 gT R -999.2500 TENS HOB 2.2426 PE~ L 223,0000 LS S1 241,0000 SS2 ALI 3.5156 SGR NRA 3.2957 RTNR F'TC 544.3289 CNTC 101.0174 TENS 3.5714 RCFT 1915.3665 GR 2.2965 URAN 7.3654 W3NG 70.8196 SG~ 4.1016 FVR --999.2500 OPHI -999,2500 GR 1135.0000 SmLU -27.3594 ~R 109.8750 GR 1309.0000 9PHI 2.,7168 QLS 460.5000 LU 343.7500 LSHV 70.2251 TENS ;3,5000 ~C~T 1841.5015 GR 1.2627 URAN 12.0350 W3NG 50.5614 SGR 4,0977 FVR -999,12500 QPHI .-999, 2500 GR 1080.0000 SFLU -28,92!9 113.T500 1.260,0000 DPHI 2.7344 QLS 418.7500 LU 33'4.0000 LSHV 90.6617 TENS 3.5625 RC~T 1977,2642 Z. 1099 UR.AN 13,1148 W3NG 68.0847 SGR 4,0977 FVR -999,~500 OPHI -999,2500 ~R 1035.0000 SFLU -39.9062 GR 11,4.2500 GR 1190.0000 DPHI 3.1934 QLS 421,2500 LU 339.7500 LSHV 93,8038 TENS 3.5552 RCFT 1913,6348 GR 1340,0000 491,2415 ;101,0174 4,2711 51,5789 101,0174 0.1095 -999,2500 -999,2500 4,5894 67,0000 67,0000 27,4954 -0.0146 424.7500 1192.0000 1300.0000 544.1815 70.2251 2.7812 2~.4464 70.2251 0.7046 -999.2500 -999,2500 4.1795 69.5000 69.5000 25.1073 -0.0020 38¢.7500 1192.0000 1260,.0000 580.9021 90.6617 3.1932 32,78,69 90,6617 0.6992 -999.2500 -999,2500 5.1602 73.8750 78.8750 24.6895 -0.0361 39~.7500 1192.0000 1190.0000 545,5115 93.8038 NPHI RCNT TENS THOR W2NG TENS CALI ORHO ILM TENS TENS DRHO QSS LITH SSHV NPHI 9CNT TENS THOR WZNG TENS CALI ORHO ILM 'TENS TENS DRHO QSS LITH SSHV NPH! RCNT TENS THOR W2NG TENS CALI ORHO ILM TENS TENS ORHO QSS LITH SSHV NPHI RCNT 'TENS 42.8573 1988.4148 1340.0000 9.9665 160.0000 1340. 0000 8,4844 -999,2500 4,4792 1135,0000 -999,2500 0,0141 0,0303 135,6250 1150.0000 40.2520 1842,5420 1300,0000 ~,6568 108.3151 1300.0000 8.8984 -999.2500 3.5529 1080.0000 -'999.2500 0.0019 0.0103 119.3125 1149.0000 39.34'70 2023.6633 1Z6D.O000 9.9822 171.5847 1260.0000 8.4141 -999,2500 4,2858 1035,0000 -999,2500 0,0156 0.0264 109,4375 1148,0000 39,4595 1921,9995 1190,0000 VP OlO.H02 VERIFICATION LISTING PAGE 24 S 198~.0000 °gTA Z.~595 UR~N 2.9269 THOR 9.9261 5NG 10.9290 W4NG 9.8361 W3NG 29.5082 W2NG 145.B552 lNG 337.7049 CGR 73.1099 SGR 93.8038 TENS 1190.0000 RHO 0.0156 NVR 4.0977 FVR 0.6948 CALi 8.5156 GR 92.8038 TENS -999.2500 OPHI -999.2500 DRHO -999.2500 HDB -999.2500 CALI -999.2500 GR -999.2500 EPT 3500.0000 TENS 1010.0000 SFLU 5.4843 ILM 3.9931 LD 3.8538 SP -43.4688 GR 81.9375 TENS 1010.0000 TL 120.2500 9T 122.0000 GR 81.9375 TENS -999.2500 R -999.2500 TENS 1170.D000 ~PHI 22.0022 DRHO 0.0087 HOB 2.2870 ~EF 2.9648 QLS 0.0054 QSS 0.0117 L 208.7500 LS 385.2500 LU 355.0000 LITH 107.0000 SI 233.3750 SS2 332.5000 LSHV 1193.0000 SSHV 1147.0000 ALI 8.5625 SGR 88.3228 'TENS 1170.0000 NPHI 38.8029 NRA 3.2644 R'TNR 3.3871 RC~T 555.2828 RCNT 1993.5120 FTC 572.9380 CNTC 1928.1650 GR 88.3228 TENS 1170.0000 S 1971.0000 PD'TA 2.3996 URaN 3.0082 THOR 8.5157 5NG 8.9087 W4NG 12.2494 W3NG 47.8842 W2NG 155.1292 lNG 272.8285 CGR 67.0536 SGR 88.3228 'TENS 1170.0000 RHO 0.0087 NVR ~.0977 FVR 0.6904 CALI 8.5625 GR $~.3228 TENS -999.2500 DPHI -999.2500 DRHO -999.2500 HOB -999.2500 C~LI -'999.2500 SR -999.2500 EPT 3&00.0000 'TENS 995.0000 SFLU 6.1600 ILM 5.7777 LD 5.7436 SP -45.2187 SR 68.2500 TENS 995.0000 TL 116.7500 OT 116.7500 GR 65.2500 TENS -999.2500 R -99'9.2500 TENS 1165.0000 DPHI 21.7416 DRHO 0.0191 HOB Z.2913 PEF 2.9160 QLS -0.0029 QSS 0.0205 t 209.1250 tS 389.7500 LU 359.2500 LITH 100.6250 SI 239.0000 SSZ 336.5000 LSHV 1193.0000 SSHV 1147.0000 ALI 8.7500 SGR 79.6389 TENS 1165.0000 NPHI 42.0582 NRA 3.4574 RTNR 3.5156 RCFT 544.9122 RCNT 2077.9204 FTC 590.1296 CN'TC 1991.3101 GR 79.6389 TENS 1165.0000 S 1964.0000 POTA 2.2036 UR~N 2.3917 THOR 8.1349 f5NG ~.8988 W4NG 12.2358 W3flG 47.~309 W2NG 13'7.9310 !lNG 26~.'7386 CGR 62.7292 SGR 79.6389 TENS 1165.0000 tRHO 0.0191 NVR ~.0977 FVR 0.6870 CALI 8.7500 ;GR 79.6389 TENS -999.2500 OPHI -999.2500 DRHO -999.2500 HOB -999.2500 CALI -99'9.2500 GR -999.2500 ~EPT 3300.0000 'TENS 975.0000 SFLU 3.9886 ILM 4.9819 iLD 5.0428 SP -47.1250 GR 60.7500 TENS 975.0000 ~TL '125.7500 OT 123.7500 GR 60.7500 TENS -999.2500 iR -999.2500 TENS 1150.0000 DPHI 28.6574 DRHO 0.02186 HDB 2.1772 PEF 3.1816 QLS 0.0029 QSS 0.0195 ,L 265.5000 LS 486.2500 LU 441.5000 LITH 128.625'0 S1 249.7500 SS2 359.7500 LSHV 1192.0000 SSHV 1146.0000 ALI ~.6094 SGR 65.9674 TENS 1150.0000 NPHI 46.7643 NRA 3.703~ 2TNR 13.9815 RC~T 483.3010 RCNT 1912.7944 FTC 503.3015 CNTC I~49.7365 GR 65.9674 TENS 115'0.0000 S 1966.0000 ~OT~ 1.51'34 UR~N 0.8660 THOR 10.1689 '5NG 15.3005 W4NG 4.3716 ~3NG 26.2.295 W2NG 121.3115 lNG 219.6721 CGR 59.8443 SGR 65.9674 TENS 1150.0000 VP OlO.H02 VERImICATION L!STING PS~E 25 RHO 0.0286 NVR ~R 65. 9674 TENS HOB -999.2500 CALI EPT 3200.0000 TENS LD 7.8726 SP TL 123. 2500 DT R -999.2500 TENS HOB 2.1973 L 272.2500 LS SI 264.7500 SS2 ALI 1§. 5859 SG~ NRA 3.6442 RTNR FTC 512.6732 CNTC S 1970.0000 oOTA 5NG 2.1882 W4NG lNG 274.6171 CGR RHO 0.0729 NVR GR 73.1404 TENS HOB -99;9.2500 C~LI EPT 3100.0000 'TENS LO 76.0857 SP TL 125.0000 R -999.2500 TENS HOB 2.0486 PEF L 320.7500 tS SI Z4B. Z500 SS2 ALI 11.0781 SGR NRA 3.7769 RTNR FTC 529.3046 CNTC S 1848.0000 PO'Tfi 5NG 4.052'7 W4NG lNG 96.2513 CGR RHO 0.0092 NVR GR 23.2997 TENS HOB -999.2500 CALI 'EPT 3000.0090 'TENS LD 10.8676 SP TL 124.2500 DT R -999.25D0 'TENS HOB 2.3010 PEF L 197.7500 tS Si 226.8750 SSZ ALI 10.1406 SGR NRA 3.4437 RTNR FTC 499.5842 CNTC S 1925.0000 POT~ 5NG 5.2301 W4NG lNG 226.987~ CGR RHO O.OOO6 NVR GR 68.2851 TENS HOB -'999.2500 CALI 4.0977 FV~ -999.~500 OPHI -999.2500 GR 950.0000 SFLU -49.0625 SR 122.5000 GR 1110.0000 OPHI 3.1660 QLS 507.5000 LU 371.7500 LSHV '73.1404 TENS 3.8793 RCFT 1~38.4768 GR 1.8302 URAN 7. 6586 W3NG 55.!886 SGR ~.0977 FV~ -999.!500 OPHI -999.2500 GR 925.0000 SFLU -6'7.1250 GR 126.2500 GR 1100.0000 OPHI 2.6563 QLS 595.5000 LU 356.2500 LSHV 2~.2997 TENS 4.0476 'RCmT 1937.3811 GR 0.4870 URAN 6.0790 W3NG 20.1142 SGR 4,.1016 -999.2500 -999.2500 915.0000 SFLU -48.40.63 GR 124.7500 GR 1105.0000 DPHI 2.7617 QLS 367.7500 LU 1319.7500 LSHV 68.2851 TENS 3.7778 RCFT 1790.3225 GR 1.4793 URAN 10.4603 W3NG 52.6750 S'G~ 4.1016 FV~ -999.2500 OPHI -999.2500 GR 0.6846 -999.2500 -999. 2500 8.6453 67. '7500 67.7500 27.4380 -0.0283 470.5000 1192.0000 1110.0000 491.9297 73.1404 2. 5249 37.1991 73.1404 0.6821 -999.2500 -999.2500 140.4207 25.2969 25.2969 36.4513 -0.0225 549. 5000 1191.0000 1100.0000 488. 1064 28.2997 1.1 577 14.1844 28.2997 0.6797 -999. 2500 -999.2500 10. 41340 68.1250 68.1250 21.1522 0.0015 340.2500 1191.0000 1105.0000 488.6548 68. Z 851 2. 2078, 34.5188 68.2851 0.6797 '-999.2500 -999.25.90 CALl DRHO ILM TENS TENS ORHO QSS LITH SSHV NPH! RCNT TENS THOR W2NG TENS CfiLI DRHO ILM 'TENS TENS DRHO QSS LITH SSHV NPHI RCNT 'TENS THOR W2NG TENS CALI ORHO ILM TENS TENS ORHO QSS LITH SSHV NPHI RCNT TENS THOR W2NG TENS CALI DRHD B.6094 -999.2500 7.7331 950.0000 -999.2500 0.0729 0.0381 131.3750 1146.0000 42.7275 1930.5625 1110.0000 7.6282 96.2801 1110.0000 10.5859 -999.2500 101.2618 925.0000 -999.2500 0.0~092 0.0400 1.64.7500 1145.0000 44.8037 1915.'7844 1100.0000 3.5064 41.5400 1100.0000 11.0781 -999.2500 10.3408 915.0000 -999.2500 0.0006 0.017I 87.0000 1146.0000 39.7189 1~61.0527 1105.0000 8.3487 1.09.8326 1105.0000 10.1406 -999.2500 VP OlO.HO2 VErifICaTION LISTING P~GE 26 EPT 2900.0000 TENS 390.0000 SFLU LO 18.1421 SP -73.7500 GR TL 133.0000 DT 130.0000 GR R -999.2500 TENS 1070.0000 DPHI HOB 1.8312 PE~ 3.0645 QLS L 508.0000 LS 957.5000 LU SI 281.7500 SS2 428.5000 LSHV ALI 12.1719 SGR 33.5704 TENS NRA 3.5459 RTNR 3.6809 ~C~T FTC 435.8516 CNTC 1552.9917 ~R S 1940.0000 PCTA 0.7452 UR~N 5NG 2.1390 W4NG 1.0695 W3NG lNG 130.4813 CGR 22.9793 SGR RHO 0.0636 NV9 4.1016 :VR GR 33.5704 'TENS -999.2500 OPHI HOB -999.2500 CALI -999.1500 GR EPT 2800.0000 TENS 875.0000 SFLU LD 15.7600 SP -71.5000 GR TL 132.7500 DT 133.5000 GR R -999.2500 TENS 1080.0000 DPHI HOB 1.8083 PEF 3.3828 ~tS L 511.5000 LS 958.5000 LU S1 274.2500 SS2 ~36.5000 LSHV ALI 13. ~3996 SOP 27. 9278 TENS NRA, 4.1238 RTNR 4.4000 RC~T FTC 340.8119 CNTC 1374.0461 S 1813.0000 POT~ 0.6949 URAN '5NG 6.5359 W4NG 2.1786 W3NG !lNG 96.9499 CGR 24.6590 SGR ~RHD 0.0406 NV~ 4.1055 FV~ ;GR 2'7.9278 TENS -999.12500 OPHI HOB -999.~500 CALl -999.2500 GR ~EPT 2700.0000 'TENS 850.0000 SFLU LQ 6.2925 SP -47.6875 TL 140.'7500 OT 1~4.2500 GR ,R -999.2500 TENS 1030.0000 9PHI HOB 2.0954 PEP 3.2695 QLS L 285.2500 LS 534.5000 LU S1 239.5000 SS! 350.5000 LSHV ALI 10.0313 SGR 66.5933 TENS NRA 4.1052 RTNR 4.1556 RCFT FTC ~33.6423 CNTC 172'1.8909 GR S 1934.0000 PO'TA 1.~26! URAN 5NG 7.48,66 W4NG 9.6257 W3NG lNG 225.7379 CG~ 45.7283 SGR RHO 0.0008 NVR 4.1055 GR 65.5933 'TENS -999.2500 DPHI HOB -999.2500 CALI -999.2500 GR ~EPT 2600.0000 'TENS 835.0000 SFLU LD 1949.9954 SP -2.9648 GR 17.4802 31.3281 31.3281 49.6269 -0.0239 899.0000 1190.0000 1070.0000 438.1993 33.5704 1.4980 14.9733 33.5704 0.67?2 -999.2500 -999.2500 15.1294 25.7969 25.79~9 51.0138 -0.0122 B9~.5000 1189.0000 1080. 0000 300. O0 69 27.9278 0.4623 9.8039 27.9278 0.6753 -999,.2500 -999.2500 8.1514 62.2813 62.2813 33.6107 -0.0396 4991. 0000 1191.0000 1030.0000 395.0756 66.5933 2.8096 28.8770 66.5933 0.6748 -999.2500 -999. 2500 2000.0000 22.5156 ILM TENS TENS DRHO QSS LITH SSHV NPHI RCNT 'TENS THOR N2NG TENS C~LI DRHO iLM 'TENS 'TENS ORHO QSS LITH SSHV NPHI RCNT 'TENS THOR W2NG TENS C~LI DRHO ILM TENS TENS DRHO 9SS LITH SSHV NPHI RCNT TENS THOR W2NG TENS CALI DRHO TENS 17.5896 ~90.0000 -999.2500 0.0636 0.0273 257.2500 1145.0000 40.0652 1587.1472 1070.0000 3.2337 47.0588 1070.0000 12.1719 -999.2500 16.3810 875.0000 -999.2500 0.0406 -0.0044 264.0000 1145.0000 50.0430 1413.1125 1080.0000 3.8986 47.9303 1080.0000 13.3906 -999.2500 6.0259 850.0000 -999.2500 0.0008 0.01'76 132.6250 1145.0000 51.996I 1683.93~2 1030.0000 6.9408 100.5348 1030.0000 10.0313 -999.2500 2000.0000 835.0000 VP 010.HOZ VERIFICATION LISTING PAGE 27 TL 94. 7500 97 R 21.3125 TENS HOB 1. 5242 35 ~: L 154.1250 LS SI 65.8750 SS2 ALI 9.9922 SGR NRA 4. 5359 RTNR FTC 255.3596 CNTC S 1943.0000 POT~ 5NG 2. 1075 W4NG lNG 88.5142 CGR RHO -0.~875 NVR GR 26.0926 TENS HOB -999. 2500 CALI EPT 2500.0000 'TENS LO -999.2500 SP TL -999.2500 9T R 19.4063 TENS HOB -999.2500 PEF L -999.2500 LS S1 '-999.2500 SS2 ALI -999.2500 SGR NRA -999.2500 RTNR FTC -999.2500 CNTC S -999.2500 POTA 5NG -999.2500 W4NG 'lNG -999.2590 CSR RHO -999.2500 NVR GR -999.2500 TENS HOB -999,2500 CALI ,EPT 2400.0000 TEN:S LD -999.2500 SP TL -999.2500 OT R 38.7188 TENS HOB -999.2500 PEF L -999.2500 LS SI -999.2500 SS2 ALI -999.25100 SGR NRA -999.2500 RTNR FTC -999.2500 CNTC S -999.2500 ~OTA 5NG -999.2500 W4NG lNG -999.2500 CGR RHO -999.2500 NVR GR -999.2500 TENS HDB -999,2500 CALl EPT 2300.0000 TENS LD -999.2500 SP TL -999.2500 DT R 26.6875 TENS HOB -999.2500 ~EF 40.7500 1030.0000 50.3]25 287.2500 122.5625 26.0926 4.7143 1126.0039 0,8571 2.1075 19.4899 4.1055 -999.2500 -999.2590 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 --999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -99g.2500 '-999.2500 -999.2500 --999.2500 -999.2500 -999,2500 -999,2500 -999,2500 -999,2500 -999.2500 .-999.2500 -999.25'00 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999,2500 -999.2500 -999.2500 GR 22.5156 DPHI 68.2311 QLS 0.1489 LU Z66.2500 LSHV 1192.0000 TENS 1030.0000 RC~T 227.8196 GR 26.0926 URAN 0.9339 W3NG 20.0211 SG~ 26.0926 FVR 0.6729 OPHI -999,2500 GR -999.2500 SFLU -999. 2500 GR -999.2500 :~R -999. 2500 9PHI -999.,2500 QLS -999.2500 LU -999.2500 LSHV -999.2500 TENS -999. 2500 RC~T -999, 2500 ~R -999. 2500 URAN -999.2500 W3NG - 999,. 2500 SGR -999.2500 FVR -999.2500 DPHI -999,2500 GR -999.2500 SFLU -999.2500 GR -999.2500 GR -999.2500 OPHI -999.2500 QLS -999.2500 LU -999.2500 LSHV -999.2500 TENS -999.2500 RCFT -999.2500 GR -999.2500 UR~N -999.2500 W3NG -999.2500 SGR -999.2500 FVR -999,2500 OPHI -999,2500 GR -999,2500 SFLU -999.2500 GR -999.2500 GR -999.2500 OPHI -999.2500 QLS -999,2500 TENS DRHO QSS LITH SSHV NPHI RCNT TENS THOR W2NG TENS CALI DRHg ILM TENS TENS DRHO QS S LITH SSHV NPHI RCNT TENS THOR WZNG TENS CALI ORHO ILM TENS TENS ORHO QSS LITH SSHV NPHI RCNT TENS THOR WZNG TENS CALI DRHO ILM TENS TENS ORHO QSS 845.0000 -0.8875 -0.1562 28.5000 1147,0000 59,9464 11~4.2148 1030.0000 1.8223 45.3109 1030.0000 9.9922 -999,2500 -999.2500 -999.2500 825.0000 -999.2500 -999.2500 -999.25~0 -999.2590 -999.2500 -999.2500 -999.2500 -999,2500 -999,2500 -999,2500 -999.2500 -999,2500 -999.2500 -999.2500 805.0000 -999.2500 -'999,2500 -999,2500 -999.2500 -999,2500 -999,2500 -999-2500 -999,2500 -999,2500 -999,2500 -999,2500 -999.2500 -999.2500 -999.2500 780.00'00 -999.2500 -99'9.2500 VP 010.HOZ VERI=IC~TION LISTING PAGE 28 L -999.2500 LS S1 -999.2500 5S2 ALI -999.2500 SGR NRA -999.2500 RTNR FTC -999.2500 CNTC S -999.2500 PQT~ 5NG -999.2500 W4NG lNG -999.2500 CGR RHO -999.2500 NVR GR -999.2500 TENS HOB -999.2500 C~lI EPT 2200.0000 TENS LD -999.2500 SP TL -999.2500 OT R 38.2500 TENS HOB -999.2500 PEF L -999.2500 LS SI -999.2500 SS2 ALI -999.2500 SGR NRA -999.2500 RTNR FTC -999.2500 CNTC :S -999.2500 POTA ISNG -999.2500 W4NG' lING -999.2500 CGR tRHO -999.2500 NV~ ;GR -999.2500 TENS IHOB -999.2500 CALI ~EPT 2100.0000 TENS ,rD -999.2500 SP ~TL -999.2500 DT ;R 19.~750 TEN]S [HOB -999.2500 PE~ ,t -999.2500 LS ,SI -999.2500 SSZ :ALI ,-999.2500 SG~ 'NRA -999.2500 ~TNR ;FTC -999.2500 CNTC ;S -999. 2500 POTA 15NG -999. 2500 W4NG I1NG -999.2500 CGR )RHO -999.2500 NVR ;GR -999.2500 TENS ,HOB -999.2500 CALI IEPT 2003.0000 TENS :LD -999.2500 SP iTL -999.2500 OT ;R 33.2813 TENS IHDB -999.2590 PEP .L -999.2500 tS ;SI -999.2500 SS2 ;ALI -999.2500 SGR -999.2500 LU -999.2500 LSHV -999.2500 TENS -999.2500 RCFT -999.2500 GR -999.2500 UR~N -999.2500 W3NG -999.2500 SGR -999.2500 FVR -999.2500 OPHI -999.2500 G~ -999.2500 SFLU -999.2500 GR -999.2500 GR -999.2500 DPHI -999.2500 QLS -999.2500 LU -999.2500 LSHV -999.2500 TENS -999.2500 RCFT -999.2500 GR -999.2500 UR~N -999.2500 W3NG -999.2500 SGR -999.2500 ~VR -999.2.500 DPHI -999.2500 GR -999.2500 SFLU -999.2500 gR -999.2500 GR -999.2500 DPH! -999.2500 QLS -999.2500 LU --999.~500 LSHV -999.2500 TENS -99'9.2500 ~CFT -999.2500 GR -999.2500 URAN -999.2500 W~NG -999.2500 SG~ -999o~500 FVR -999.2500 OPHI -'999.2500 GR -999.2500 SFLU -999.2500 GR -999.2500 GR -999..2500 OPHI -999.2500 QLS -999.2500 LU -999.2500 LSHV -999.2500 'TENS -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2590 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.25~0 -999.25~0 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2590 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -99'9.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 LITH SSHV NPHI RCNT TENS THOR W2NG TENS CALI DRHO ILM TENS TENS 9RHO QSS LITH SSHV NPHI RCNT TENS THOR W2NG TENS CALI ORHO ILM TENS TENS DRHO QSS LITH SSHV NPHI RCNT 'TENS THOR ~2NG TENS CALI DRHO ILM TENS TENS ORHO QSS LITH SSHV NPHI -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 755.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.25~0 -999.,2500 -'999.2500 -999.2500 -999.2500 -999.2500 735.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999-2500 -'999.2500 -999.2500 -99'9.2500 -999.2500 -999.2500 -999.2500 720.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 VP OlO.H02 VERIFICaT!ON LISTING PAGE Z9 ,NRA -999.2500 RTNR FTC -999.25D0 CNTC S -999.2500 POT.~ 5NG -999.2500 W4NG lNG -999.2500 CGR RHO -999. 2500 NVR GR -999.2500 TENS HOB -999. 2500 CALl EPT 1900.0000 TENS LD -999.2500 SP TL -999.2500 DT R 39.3125 TENS HOB -999.2500 PEF L -999.2500 LS S1 -999.2500 SS2 ALI -999.2500 SGR NRA -999.2500 RTN~ FTC -999.2500 CN'TC S -999.2500 POTA 5NG -999.2500 W4NG lNG -999.2500 CGR RHO -999.2500 NVR GR -999.25'00 T~NS HOB -999.2500 C~LI EPT 1800.0000 TENS LD -999.,2500 SP TL -999.2500 R 29.3594 'TENS HOB -999.2500 PE L -999.2500 LS S1 -999.2500 SS2 ALI -999.2500 SGR NRA -999.2500 RTNR FTC -999.2500 CNTC S -999.2500 PO'TA 5NG -999.2500 W4NG lNG -999.2500 CGR RHO -999.2500 NVP GR '-999.2500 TENS HOB -999.2500 CALl EPT 1700.0000 TENS LD -999.2500 SP TL -999. 2500 OT R 27.20'31 TENS HOB -999.2500 t - 999. 2500 tS SI -999.2500 SS2 ALI -999.2500 SGR NRA -999.2500 RTNR FTC -999. 2500 CNTC S --999.2500 'POT~ -999.2500 RC~T -999.2500 SR -999.2500 URbaN -999.2500 W3MG -999.2500 SGR -999.2500 FVR -999.2500 DPHI -999.2500 GR -999.2500 SFLU -999.2500 GR -999.2500 GR -999.2500 DPH! -999.2500 QLS -999.2500 tU -999.2500 LSHV -999.2500 TENS -999.2500 RCFT -999.2500 GR -999.2500 UR~N -999.2500 W3NG -999.2500 SGR -999.2500 FVR -999.2500 OPHI -999.2500 GR -999.2500 SFLU -999.2500 GR -999.2500 GR -999.2500 DPH! -999.2500 QLS -999.2500 LU -999.2500 LSHV -999.2500 TENS -999.2500 RC:T -999.~500 GR -999.2590 URAN -999.2500 ~3NG -999.2500 SGR -999.2500 FV~ -999.2500 DPHI -999.2500 GR -999.2500 S'FLU -999.2500 GR -999.25D0 GR -999.2500 OPHI -999.2500 QLS -999.2500 LU -999.2500 LSHV -999.2500 TENS -999.2500 RC~T · -999.2500 GR '-999.2500 UR~N -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.25'00 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -'999.25'00 -999.2500 -999.2500 -'999. 2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 ,-99'9. 2500 -999. 2500 -999.2500 -999.2500 -999. 2508 -999. 2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -'999.25,00 -999.2500 -999. 2500 -999.2500 -999. 2500 -999.2,500 -999. 2500 -999.2500 -999.2500 -999.2 500 RCNT TENS THOR WZNG TENS CALI DRHC ILM TENS TENS DRHO QSS LITH SSHV NPHI RCNT TENS THOR W2NG TENS CALI DRHO ILM TENS TENS DRHO QSS ti'TH SSHV NPHI RCNT TENS THOR W2NG TENS CALI DRHO ILM TENS TENS ORHO QSS LITH SSHV NPHI RCNT TENS THOR -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 695.0000 -999.Z500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -'999.2500 -999.2500 -999'2500 -999.2500 -999.2500 -999.2500 --999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 660.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -99'9.25'00 -999..2500 ,-999.2500 VP OlO.H02 VERIFICATION LISTING PAGE 30 5NG -99~.2500 W4NG lNG -999. 2500 ,~GR RHO -999.2500 NVR GR -999.2500 TENS HOB -999.2500 CALI EPT 1600.0000 TENS LO -999.2500 SP TL -999. 2500 9T R 31.2656 TENS HOB -999.2500 PEF L -99 9.25 O0 LS S1 -999.2500 SS2 ALI -999.2500 SGR NRA -999. 2500 qTNR FTC -999.2500 CNTC S -999.2500 ~OTA 5NG -999.2500 W4NG lNG -999. 2500 CGR RHO -999. 2500 NVR GR -999. 2500 TENS HOB -999.2500 CALI EPT 1500.0000 TENS LD -999.2500 SP ,TL .-999.2500 DT ,R 21.2656 'TENS HOB -999.2500 ,L -9'99.2500 LS ,SI -999.2500 SSZ ALI -999.2500 SGR 'NRA -999.2500 ~TNR ,FTC -999.2500 CNTC S -999.2500 PO'T~ ~ENG -999.2500 W4NG 'lNG -999.2500 CGR ~RHO -99:9.2500 NVR iGR -999.2500 TENS :HOB -999.2500 CALI IEPT 1400. OOOO 'TENS :LO -999.2500 SP ~'T t - 99 9.12500 O T iR 15.55'~7 TENS ',HOB -999. 2500 PEF ,L -999.2500 tS ;Sl -999.2500 SS2 ;ALI '-:999.2590 'NRA -999. 2500 RTNR iFTC -999.2500 CN'TC :S -999. 2500 POTA 15NG -999. 2500 W4NG I'ING -999.2500 }RHO -999.2500 -999.2500 W3NG -997.2500 SGR -999.2500 FVR -999.2500 OPHI -999.2500 GR -999.2500 SFLU -999.2500 GR -999.2500 5R -999.2500 9PH! -999.2500 QLS -999.2500 LU -999.2500 LSHV -999.2500 TENS -999.2500 RC~T -999.2500 SR -999.2500 UR~N -999.2500 W3NG -999.2500 SGR -999.2500 FVR -999.2500 OPHI -999.2500 G~ -999.2500 SFLU -999.2500 GR -999.2500 GR -999.2500 OPHI -999.2500 QLS -999.2500 LU -999.2500 tSHV -999.2500 TENS -99~.2500 RC~T -999.2500 GR -999.2500 URAN -999.2500 ~3NG '-999.2500 SGR -999.2500 FVR -999.2500 OPHI -999.2500 ~R -999.2500 SFLU -999..2500 GR -999.2500 GR -:999. 2500 - 999. 2500 qt S -999.2500 LU · -999.2500 LSHV -999.2500 TENS -999.25'00 RC -9.99.2500 GR -99'9 . 2500 U R ~, N -999.2500 WBNG -999.2500 -999. 2500 FVR -999.2500 W2NG -999.2500 TENS -999.2500 CALI -999.2500 9RHO -999.2500 -999.2590 ILM -999.2500 TENS -999.2500 TENS -999.2500 ORHO -999.2500 QSS -999.2500 LITH -999.2500 SSHV -999.2500 NPHI -999.2500 RCNT -999.2500 TENS -999.2500 THOR -999.2500 W2NG -999.2500 TENS ,-999.2500 CALI -999.2500 ORHO -999.2500 -999.2500 ILM -999.2500 TENS -999.2500 TENS -999.2500 DRMO -999.2500 QSS -999.2500 LITH --999.2500 SSHV -999.2500 NPHI -999.2500 RCNT -999.2500 TENS -999.2500 THOR -999.2500 W2NG -999.2500 TENS -999.2500 C~LI -999.2500 ORHO -999.2500 -999.2500 ILM '-999.2500 TENS -999.2500 TENS -999.2500 ORHO -999.2500 QSS -999.2500 LITH -999.2500 SSHV -999.2500 NPHI -999.2500 RCNT -999.2500 TENS -999.2500 THOR -999.~500 W2NG -999.2500 TENS -999.2500 CALI -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 640.0000 -999.2500 -999.~500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 625.0000 -999.2500 -999.2500 --999.2500 --999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 600.0O0'0 -999.25.00 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2590 -999.2500 -999.2500 -999.2500 VP 010.HOZ VERIFICATION LISTIHG PAGE 31 GR -999.2500 TENS HOB -999.2500 C~tl EPT 1300.0000 TENS LO -999.2500 SP TL -999.12500 DT R 30.3125 TENS HOB -999.2500 PEF L -999.2500 LS SI -999.2500 SS2 ALI -999.2500 SG~ NRA -999.2500 RTNR FTC -999.2500 CNTC S -999.2500 ~OTA 5NG -999.2500 W4NG lNG -999.2500 CGR RHO -99 9.25 O0 NVR GR -999.2500 TENS HOB -999. 2500 CALl EPT 1200.0000 TENS LD -999.2500 SP IL -999.2500 DT R 42.59138 TENS HOB -999.2500 PEF L -999.2500 LS SI -999.2500 SS2 ALI -999.2500 SGR NRA -999.2500 RTNR FTC -999.2500 CNTC S -999.2500 POT~ 5NG -999.2500 W4NG lNG '-999.2500 CGR RHO -999.2500 NV~ GR -999.2500 TENS HO6 -999.2500 CALI EPT 1100.0000 TENS LO -999.2500 SP TL -999.2!500 R 46.~437 'rEMS HOB -999.2500 PEF t -999.2500 tS SI -999.2500 SS2 ALI -999.2500 SGR NRA -999.2500 FTC -999.2500 CNTC S -999.2500 POT~ 5NG -999.21500 W4NG 'lNG -999.2500 CG~ ,RHO -999.2500 NV~ ~GR -999.2500 TENS HOB -999.2500 CALl -999.2500 gPgI -999.2500 GR -999.2500 S~LU -999.2500 GR -999.2500 GR -999.2500 DPHI -999.2500 QLS -999.2500 LU -999.~'500 LSHV -999.2500 'TENS -999.2500 RCFT -999.2500 GR --999.2500 UR~N -999.2500 W3NG -999.2500 SGq -999.2500 =VR -999.2500 DPHI -999.2500 GR -999.2500 SFLU -999.2500 GR -999.2500 GR -999.2500 DPHI -999.2500 QLS -999.2500 LU -999.2500 LSHV -999.2500 TENS -999.2500 ~C=T -999.2500 GR -999.2500 UR~N -999.2500 W3NG -999.2500 SGR -99'9.2500 ~VR -999.2500 OPM! 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O0 000 O0 0 2 ENS CNH LB O0 000 O0 0 Z 4 PHI CNH PU O0 OOO O0 0 Z 4 NRA CNH O0 000 90 0 Z 4 TNR CNH O0 000 O0 0 CFT CNH CPS O0 OOO O0 0 Z 4 PROCESS CODE (OCTAL) 1 68 00000000000000 1 68 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 58 00000000000000 1 68 00000000000000 I 68 00000000000000 I 68 00000000000000 1 68 00000000000000 I 68 ODOOOOOOOOOOOD I 68 O000000000OO00 I 68 O00OO000000000 I 68 O000000000000O 1 68 00000000000000 1 68 O0000DOOODO000 1 68 00000000000000 I 68 00000000000000 1 68 O00000000OO000 I 68 00000000000000 I 68 00000000000000 I 68 00000000000000 1 68 00000000000000 VP OlO.H02 VERIFICATION LISTING PAGE 37 3NT CNH CPS OC 000 O0 0 2 4 1 68 00000000000000 FTC CNH CPS O0 300 O0 0 2 4 1 68 O00OO000000000 NTC CNH CPS O0 000 O0 0 2 4 1 58 00000000000000 R CNH SA~I O0 000 O0 0 2 4 1 68 00000000000000 ENS FDH L~ O0 000 O0 0 2 4 1 68 00000000000000 PHI FDH PU O0 000 O0 0 2 ~ ! 68 00000000000000 RHO ~OH ~S/C3 O0 000 O0 0 Z ~ ! 68 00000000000000 HOE FDH G/C3 O0 900 O0 0 2 ~ 1 68 00000000000000 ALI FDH IN O0 000 O0 0 2 ~ I 68 00000000000000 R FDH · GBPI O0 OOO go 0 2 4 1 68 00000000000000 DATA EDT 7753.5996 TENS -999.2500 DPHI -999.2500 ORHO -999.2500 HOB -999.2500 PEF -999.2500 QL5 -999.2500 QSS -999.2500 L -999.2500 LS -999.2500 LU -999.2500 LITH -999.2500 S1 -999.2500 SS2 -999.2500 LSHV -999.2500 SSHV -999.2500 ALI -999. 2500 SGR -999. 2500 TENS 21350. 0000 NPHI 10. 3390 NRA 0.9441 RTNR 1.0165 RC¢T 1~7115.1875 RCNT 146885°9375 FTC 168186.,~063 CNTC 151215.3438 GR 2108.0000 TENS 2350.0000 PHI 280.8231 ORHO -6.'92~5 RHgB -1.9836 CALl 0.6904 R 2'108. OOOO EPT 7'700.29'98 TENS -999.2500 OPHI -999.2500 ORHO -999.2500 HOB -999.2500 DEF -999.2500 9LS -999.2500 QSS -999.2500 L -999.2500 LS -999.2500 LU -999.2500 kITH -999.2500 Si -999.2500 SS2 -999.2500 LSHV -999.2500 SSHV -99~9.2500 ALI -999.2500 SGR -999.2500 TENS 6120.0000 NPHI 33.0732 NRA 2.9368 RTNR 2.96~3 RCFT 717.41~3 RCNT 2~29.0732 FTC 839.1278 CNTC 2386.8882 GR 93.]~125 TENS 6120.0000 IPHI 10.0!21 ORHO 0.1118 RHOB 2.4848 C~LI 8.¢063 ,R 93.3125 ,EPT 7600.2998 TENS -999.2500 DPHI -999.2500 ORHO -999.2500 :HOB -999.2500 PEF -999.2500 QLS -999.2500 QSS -999.2500 .L -999.2500 LS -999.2500 LU -999.2500 kITH -999.2500 ,SI -999.2500 SS2 -999.2500 LSHV -999.2500 SSHV -999.2500 iALI -999.2500 SGR -999.2500 TENS 6032.0000 NPHI 45.6624 'NRA 3.6635 RTNR 3,8571 RCFT 483.~536 RCNT 1856.6289 ;FTC 559.4290 CNTC 1995.3303 GR 94.9375 TENS 6032.0000 iPHI 10.3657 ORHO 0.0627 RHOB 2.4790 CALI 8.8594 ;R 94.9375 IEPT 7500.2998 'TENS -999.2500 OPH! -999.2500 DRHO -999.2500 IHOB -999.2500 PEF -999.2500 QLS -999.2500 QSS -99'9.2500 .t -999,2500 LS -999.2500 LU -999.2500 kITH ,-999.2500 ;S1 -999.2500 SS2 -999.2500 LSHV -999.2500 SSHV -999.2500 :ALI -999.2500 SGR -999.2500 TENS 5800.0000 NPHI 30.7197 :NRA 2.77~8 ~TNR 3.1225~RCFT 72:8.5415 RCNT 2557.4678 :FTC 874.7340 CNTC 2497.9487 GR 71.1250 'TENS 5~00.0000 )PHI 21.9559 DRHO 0.0009 RHOB 2.2877 CALl 8.3906 ;R 71.1250 VP OlO.H02 VERI:ICATIgN LISTING PAGE 38 EPT 7~00,2998 'TENS HOB -999,2500 PE~ L -999,2500 LS S1 -999,2590 SS2 ALI -999,2500 SGR NRA 3.173T RTNR FTC 586,5100 CNTC PHI 4.5442 DRHO R 89.3750 EPT 7300.2998 'TENS HOB -999.2500 PEF L -999.2500 LS SI -999.2500 SS2 ALI -999,2500 SGR NRA 2,8893 RTNR FTC B91,5456 CNTC PHI 5.1854 DRHO R 120.9375 EPT 7200,2998 TENS HOB -999,2500 PE; L -999,2500 tS SI -999,2500 SS2 ALI -99'9,2500 SGR NRA 3,2562 ~TNR F'TC 651.7081 CNTC .PHI 17,0058 ORHO R 92,0000 EPT 7100.2998 'TENS HOB -999.2500 PE~ L -999.2500 LS S1 -999.2500 SS2 ALI -999,2500 SGR NRA -999,2500 RTNR FTC -999.2500 CNTC 'PHI -999,2500 ORHO ,R '-999.2500 ~EPT 7000,2998 TENS :HOB -999.2500 PEF ,t -999.2500 tS .S1 -999,2500 SS2 :ALI -999.2500 SGR 'NRA -999.2500 RTN~ :FTC -999,2500 CNTC IPHI -'999,2500 9RHO ;R -999,2500 iEPT 6900.2998 TENS ',HOB -999.2500 PEF ,L -999.2500 tS ;SI -999.2500 SS2 -999,2500 OPH! -999,2500 QLS -999,2500 LU -999,2500 LSHV -999.2590 TENS 3.5926 RCFT 2135.5913 GR 0.1645 RHOB -999.2500 DPHI -999.2500 QLS -999.2500 LU -999.2500 LSHV -999.2500 TENS 3.1176 RCFT 2~24.7671 GR 0,1539 ~HOB -999.2500 9PHI -999.2500 QLS -999.2500 LU -999.2500 LSHV -999,2500 TENS 3.4254 RCFT 1930,7056 GR 0.0457 RHqB -999.2500 5PHI -999.2500 qt$ -999.2500 LU -999.2500 LSHV -999.2590 TENS -999.2500 ~C~T -999.2500 GR -999.2500 RHg~ -999.2500 OPHI -999.2500 QLS -999.2500 LU -999.2500 LSHV -999.2500 TENS -999.2500 RCFT -999. 2500 '~R -999. 2500 :RHOB -999,2500 gPHI -999,2500 QLS -999,2500 LU -99'9,2500 LSHV -999.2500 -999.2500 -999.Z500 -999.2500 5940.0000 566.7584 89.3750 2.5750 -999.2500 -999.2500 -999.2500 -999.2500 5900.0000 826,2562 120.9375 2, 5644 -999.Z500 -999.2500 -999.2500 -999.2500 5660.00.00 92.0000 2.3694 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999,2500 -999,2500 DRHO QSS LITH SSHV NPHI RCNT TENS CALI DRHO ~SS LITH SSHV NPHI RCNT TENS CALI ORHO QSS LITH SSHV NPHI RCNT TENS CALl 3RHO QSS L ITH SSHV NPHI RCNT TENS CALI ORHO QSS LITH SSHV NPHI RCNT TENS CALI DRHO QSS L ITH SSHV -999.2500 -999.2500 -999.!500 -999.2500 37.5396 2067,8979 5940,0000 8.2969 -999.2500 -999.2500 -999.2500 -999.2500 31.9307 2259.4971 5900,0000 8.6484 -999.2500 -999.2500 -999.2500 -999.2500 38.2994 1821.4104 5660,0000 8.7969 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999,2500 -999, Z500 -999,2500 VP OlO.HO2 VERI~:IC~?ION LISTING PAGE {LI -999.2500 SGR ~RA -999.2500 RTNR FTC -999.2500 CNTC ~HI -)9'). 2500 9RHO ~ -999.2500 EPT 6800.2998 TENS MOB -'999.2500 PEF L -999.2500 LS S1 -999.2500 SS2 ALI -999.2500 SGR NRA -999.2500 RTNR FTC -999.2500 CNTC PHI -999.2500 gRHO R -999.2500 EPT 6700.2998 TENS HOB -999.2500 PEP L -999.2500 LS S1 -999.2500 SS2 ALI -999. 2500 SGR NRA -999.2500 RTNR FTC -999.2500 CNTC PHI -999.2500 ORHO R -999.2500 EPT 6600. 2998 'TENS HOB -999.2500 PEF L -999.2500 LS S1 -999. 2500 SS2 ALI -99'9. 2500 SGR NRA -999. 2500 RTNR FTC -999. 2500 CNTC ~PHI -999.2.500 gRHD R -999. 2500 EPT 6500.2995 TENS HOB -999.2500 PEF L -99'9. 2500 LS .Sl -999. 2500 SSZ ALI -999. 2500 SG~ ',NRA -999.2500 ~TNR iFTC -999. 2500 CN'TC )PHI -999.2500 ORHO ;R -99 9. 2500 )EPT 6400. 2998 TENS ',HOB -99-9. 2500 PEF .t -999o2500 tS ;S1 -999.Z500 SS2 ',ALI -999.2500 SGR 'N~A -999.2500 ~RTNR ~FTC -999.2_500 CNTC )PHI --999.2500 DRHO -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.~500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 ,-999.2500 -999.25,00 -999.2500 -999.2500 -99'9.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 ,-999.2500 ,-999.2500 -999.2500 -999.2500 TENS RCFT GR RHOB DPHI LU LSHV TENS RCFT RHOB OPHI QLS tU LSHV TENS RC:T gR ~HOB OPHI QLS LU LSHV TENS RC~T 9PHI QLS LU LSHV 'TENS RC~T RHOB QLS LU LSHV TENS RCFT GR RHgB -999.2500 NPWI -999.2500 RCNT -999.2500 TENS -999.2500 CALI -999.2500 DRHO -999.2500 QSS -999.2500 LITH -999.2500 SSHV -999.2500 NPHI -999.2500 RCNT -999.2500 TENS -999.2500 CALI -999. 2500 DRHO -99~. 2500 QSS -999.2500 LITH -999.2500 SSHV -999. ZSOO NPHI -999.2500 RCNT -999.2 500 TENS -999.2500 CALI -999.2500 DRHO -999.2500 QSS -999.2500 LITH -999.2500 SSHV -999.2500 NPHI -999.2500 RCNT -999.2500 TENS -99:9.2500 CALI -999.2500 ORHO -999.2500 QSS -999.2500 LITH -999°2500 SSHV -999.2500 NPHI -999. 2500 RCNT -999.2500 TENS -999. 2500 CALI -999.2500 DRHG -999.2500 QSS -999.2500 LITH -999.2500 SSHV -999.2500 NPHI -999.2500 RCNT -999.2500 TENS -999.2500 CALI -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.25'90 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 VP 010.H02 VE~I=!C~TION LISTING R -999.2500 EPT 6300.2998 TENS HOB -999.2500 PE.~ L -999.2500 LS SI -999. 2500 SSZ ALI -999.2500 SG~, NRA -999.2500 ~TNR FTC -999.2500 CNTC PHI -999. 12500 DRHO R -99 ~. 2500 EPT 6200.2998 TENS HOB -999.2500 L -999. 2500 LS S1 -999. 2500 SS2 ALI -999. 2500 SGR NRA -999.25'00 RTNR FTC -999. 2500 CNTC PHI -999.2500 ORHO R --999.2500 EPT 6100.2998 TENS HOB -999.2500 PEF L -999.2500 tS S1 -999.2500 SS2 ALI -99~9.2500 SG~ NRA -999.2500 RTNR FTC -999.2500 CNTC PHI -999.2500 9RHO R -999. 2500 EPT 6000.2998 TENS HOB -999.2500 PEF L '-999.2500 tS S1 -999,2500 SS2 ALI -99 9. 2500 SGR NRA -999.2500 RTNR FTC -999.2500 CNTC ,PHI -999,2500 DRHO ,R -999.2500 ,EPT 5900.2998 'TENS HOB -999.2500 ~EF L -999.2500 LS S1 -999.2500 SSZ :ALI -999.2500 SG~ NRA -999°2500 RTNR ,FTC -999.2500 CNTC ~PHI -999.2500 9RHO ,R '-999.2500 EPT 5800.2998 'TENS HOB .-999.2500 PEF -999.2500 OPHI -999.2500 ~LS -999.2500 LU -999.2500 LSHV -999.2500 TENS -999.2500 RC,~T -999.2500 GR -999.2500 RHOB -999. 2500 9PHI -999.2500 QLS -999.2500 LU -999.2500 LSHV -999.2500 TENS -999.2500 RCFT -999.2500 GR - 999. 2500 RHOB -999.2500 OPHI -999.2500 QLS -999.2500 LU -999.2500 LSHV -999.2500 TENS -999.2500 RCFT -999.2500 GR --999.2500 RH~~ -999.2500 OPHI -999.2500 ~LS -999.2500 LU -999.2500 LSHV -999. 2500 TENS -999.2500 RCFT -999.2500 GR -99'9. 2500 RHiD8 -999.2500 DPHI -999.2500 QLS -999.2500 LU -999.2500 LS HV -999.2500 TENS -999.2500 RCFT -999.2500 GR -999.2500 RHOB -999.2500 9PHI -999.2500 QLS -999. 2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.~500 -999.25~0 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999. 2500 -999.2 500 -999.2500 -999. ,2500 -999.2500 -999.2500 -99'9.2500 -999.2500 -999.~500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.~500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -99'9.2500 -999.2500 -999.2500 9RHO QSS LITH SSHV NPHI RCNT TENS CALI ~RHO QSS LITH SSHV NPHI RCNT TENS CALl ORHO QSS LITH SSHV NPHI RCNT TENS CALl DRHO QSS LI'TH SSHV NPHi RCNT TENS CALI DRHO qSS LITH SSHV NPHI R CN'T TENS CALl ORHO QSS -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 --999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.25'00 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2 500 -999.2500 -999. 2500 -999. 2500 -999.2500 -999. 2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2 500 -999.2500 -999.2500 -999.2500 --999.2500 VP 010.H02 VERIFICATION LISTING PAGE t -999.2500 tS S1 -999.2500 SS2 ALI -999. 2500 SGR NRA -999.2500 RTNR FTC -999.2500 CNTC PHI -999. 2500 ORHC R -999.2500 EPT 5700.2998 TENS HOB -999.2500 ~EF L -999.2500 tS S1 -999.2500 SSZ ALI -999.2500 SGR NRA -99'9.2500 RTNR FTC -999.2500 CNTC PHI -999.2500 ORHO R -999.2500 EPT 5500.2998 'TENS HOB -999.2500 DEF L -999.2500 LS S1 -999.2500 SS2 ALI -999.2500 SGR NRA .-999.2500 ~TNR FTC -999.2500 CNTC PHI -999.2500 ORHO ,R -999.2500 ,EPT 5500.2998 TENS HOB -999.2500 PEF t -999.2500 tS S1 -999.2500 SS2 ~ALI -999. 2500 'NRA -999.2500 >FTC -999.2590 CNTC ~PHI -999.2.500 ,R -999.2500 )EPT 5~00.2998 TENS IHOB -999.2500 PEF .L -999.2500 LS ;S1 -9'99.2500 SS2 ;ALI .-999.2500 SGR 'NRA -999.2500 RTNR ;FTC -999.2500 CNTC )PHI -999.2500 ORHO iR -999.2500 ~EPT 5300.2998 TENS IHOB -999.2500 PE~ .L -999.2500 tS iS1 -999.2500 ]SS2 iAtI -999.2500 SGR 'NRA -999.2500 RTNR -999.2500 LU -999.2500 LSHV -999.2500 TENS -999.2500 RC=T -999.2500 GR -999.2500 RHOB -999.2500 OPHI -999.2500 QLS -999.2500 LU -999.2500 LSHV -999.2500 TENS -999.2500 RCFT -999.2500 GR -999.2500 RHOB -999.2500 OPHI -999.2500 QLS -999.2500 LU -999.2500 LSHV -999,2500 TENS -999.2500 RCmT -999.2500 GR -999.2500 RHO~ -999.2500 OPHI -'999.2500 QLS -999.2500 tU -999.2500 LSHV -999.2500 'TENS -999.2500 RCFT -999.2500 GR -999.2500 !RHOB -999.2500 OPHI -999.2500 QLS -999. 2500 LU -999.2500 LSHV -999.2500 TENS -9'99.2500 RCFT -999.2500 ~R --99'9.2500 RHOB -999.2500 DPHI -999.2500 QLS -999.2500 LU -999.2500 LSHV -999.2500 TENS -99:9.2500 RC:T -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999. Z500 -99'9. 2500 -999.2 5'00 -999.!500 -99-9.2500 -999. 2500 -999.2500 -999. !500 -999. 2500 -999.2500 -999.2500 -999. 2500 -999.2500 -999.2500 -999.2500 -99'9.2500 -999. Z 500 -999-2500 -'999. 2500 -999. 2500 -999.2500 -999. 2500 -999. -999. 2500 -999. 2500 -999.2500 -999.2500 -999. 2500 -999.2500 -999. 2500 LITH SSHV NPHI RCNT TENS CALI ORHO DSS LITH SSHV NPHI RCNT TENS CALI DRHO QSS LITH SSHV NPHI RCNT TENS C~LI ORHO QSS LITH SSHV NPHI RCN'T 'TENS CALI DRHO QSS LITH SSHV NPHI RCNT TENS CALI DRHO QSS LITH SSHV NPHI RCNT -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 --999.2500 -999.2500 -999.2500 --999.2500 -999.Z500 -999.2500 -999.2500 -999.2500 -999.2500 -'999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.Z500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 V? OlO.H02 V~I~IC4TION LIS'TING FTC -999.2500 CNTC PHI -999.2500 ORHO R -999.2500 EPT 5200. 2998 TENS HOB -999.2500 PEF L -999.2500 tS S1 -999.2500 SS2 ALI -'999.2500 SGR NRA -999.2500 RTNP FTC -999.2590 CNTC PHI -999.2500 9RHD R -999.2500 EPT 5100.2998 TENS HOB -999.2500 PEF t -999.2500 LS S1 -999. 2500 SS2 ALI -999.2500 SGR NRA -999.2500 RTNR FTC -999.2500 CNTC PHI -999. 25100 DRHO R -999.2500 EPT 5000.2998 TENS HOB -999.2500 PSF L -999.2500 tS S1 -999.2500 SS2 ALI -999.2500 SGR NRA -999.2500 RTNR FTC -999.2500 CN'TC PHI -999.2500 ORHO R -999.2,500 EP'T 4900.2998 TENS HOB -999.2500 PEF L -999.2500 tS Si -999.2500 SS2 ALI -999.2500 SGR NRA -999.2500 RTNR FTC '-999.2500 CNTC PHI '-999.2500 DRHO R -999.2500 EPT 4800.2998 TENS HOB -999.2500 PEF L -999.2500 LS S! -999.2500 SS2 ALI -999.2500 SGR NRA -999.2500 RTNR FTC -999.2500 CNTC PHI -999.2500 ORHO R -999.2500 -999.2500 GR -999.2500 ~HQB -999.2500 ODHI -999.2500 QLS -999.2500 LU -999.2500 LSHV -999.2500 TENS -999.2500 RC~T -999.2500 GR -999.2500 RHO~ -999.2500 OPHI -999.2500 QLS -999.2500 LU -999.2500 LSHV -999.2500 TENS -999.2500 RCFT -999.2500 ~R --999.2500 RHOB -999.2500 OPHI '-999.2500 QLS -999.2500 LU -99'9.2500 LSHV -999.2500 TENS -999.2500 RCmT -999.2500 GR -999.2500 :RHOB -999.2500 OPHI -'999.2500 QLS -999.2500 LU -999.2500 LSHV -999.2500 TENS -999.2500 RC~T -999.2500 GR -999.2500 RHOB -999.2500 OPHI -999.2500 QLS -99'9.2500 LU -9~99.2500 LSHV -999.2500 TENS -999.2500 ~C~T -999.2500 GR -999.2500 ~HOB -999. ~500 -999.2500 -999.2500 -999. ~500 -999. 2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999. 2500 -999.2500 -999.2500 -99'9. 2500 -999.2500 -999.12500 -999.2500 -999. 2500 -999.2500 -999.2500 -999.2500 .-999.25,00 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999..2500 -999.2500 -99'9.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 TENS CALI DRHO QS S LITH SSHV NPHI RCNT TENS CALI DRHO QSS LITH SSHV NPHI RCNT TENS CALI ORHO QSS LITH SSHV NPHI RCNT TENS CALI DRHO QS S t I'TH SSHV NPHI RCNT TEN;S CALI DRHO QSS LITH SSHV NPHI RCNT TENS CALI PAGE 42 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.~500 -999.2500 -999.2500 -999.2500 -999.2500 -99'9.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -'999.2500 -999.2500 '-999.2500 --999.2500 --999.2500 -99'9.2500 --999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 VP 010.H02 VERIFICATION LISTING PAGE 43 EPT 4700. 2998 · TENS HOB -999.2500 PE: L -999. 2500 LS S1 -999.7500 SS2 ALI -999.2500 SGR NRA -999.2500 RTNR FTC -999.2500 CNTC PHI -999. 2500 ORHD R -999.2500 EPT 4600.2998 TENS HOB -999.2500 PEF L -999.2500 tS S1 -999.2500 SS2 ALI -999. 2500 SGR NRA -999. 2500 RTNR F'TC -999.2500 CN'TC PHI -999.2500 DP, HO R -999.2500 EPT 4500.2998 TENS HOB -999. 2500 PEP L -999.2500 tS S1 -999. 2500 SS2 ALI -999.2500 SGR NRA -999. 2500 RTNR FTC -999.2500 CNTC 'PHI -'999.2500 DRHO R -99 9. :2500 EPT 4~00.2998 TENS HOB -999.2500 PEF t -999.2500 LS S1 -999.2500 SS2 ALI -999.2500 SG~ NRA -999.2500 ~TNR FTC -999.2500 CNTC PHI -999.2500 ORHO R -999.2500 EP'T 4300.2998 TENS HOB -999.2500 PEF L -999.2500 tS S1 -99'9.2500 .SS2 ~LI -999.2500 SGR NRA -999.2500 R'TNR FTC -999.2500 CNTC PHI -999.2500 9RHD R -99'9.2500 EPT 4200.2998 'TENS HOB -999.2500 PEF L -999.2500 LS S1 -999.2500 SS2 -999.2500 9PHI -999.2500 QLS -999.2500 LU -999.2500 LSHV -999.2500 TENS -999.2500 ~C:T -999.2500 GR -999.2500 RHQB -999.2500 OPHI -999.2500 QLS -999.2500 LU -999.2500 LSHV -999.2500 TENS -999.2500 RCFT -999.2500 GR -999.2500 RHOB -9'99.2500 9PHI -999.2500 QLS -999.2500 LU -999.2500 LSHV -999.2500 'TENS -999.2500 RCFT -999.2500 GR -999.2500 RHO~ -999. 2500 9PHI -999.2500 QLS -999.2500 LU -99'9.2500 LSHV -999.2500 TENS -999. 2500 RCFT ,-999.25 O0 ~R -999. 2500 RHOB -999.2500 DPHI -999.2500 QLS -999. 2500 LU -999.2500 LSHV -999.2500 'TENS -99'9.2500 RCFT -999.2500 GR -999.2500 RHOB -999.2500 OPH! -999.2500 QLS '-999,,2.500 LU -999.2500. LSHV -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999. 2500 -999.2500 -999.2500 -'999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999. 2500 -999.2500 -999.2500 -999.2500 -999.2500 -999. 2500 -999.2500 .-999.2500 -999.2500 -999. 2500 --999. 2500 -999.2500 -999.2,500 -999. 2500 -999.2500 -999.2500 -999. 2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2 5:00 -999.2500 DRHO QSS LITH SSHV NPHI RCNT TENS C~LI DRHO QSS LITH SSHV NPHI RCNT TENS CALI ORHO QSS LITH SSHV NPHI RCNT TENS CALl ORHO QSS L ITH SSHV NPHI RCNT 'TENS CALI ORHO QSS LITH SSHV NPHI RCNT T E N ~S CALI DRHO QSS LITH SSHV -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -99'9.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 '-999.2500 --999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 .-999.2500 -999.2500 -999.2500 -999.2500 ~P 010.H02 VEqI~ICATIgN LIS'TING PAGE {LI -999.2500 SGR NRA -999.2500 RTNR FTC -999. 2500 CNTC PHI -999.2500 ORHO R - 999. 2500 EPT 4100.2998 TENS HOB -999. 2500 ~EF L -999.2500 LS S1 -999.2500 SS2 ALI -999.2500 SGR NRA -999.2500 RTNR FTC -999.2500 CNTC PHI -999.2500 gRHO R -999. 2500 EPT 4000.2998 TENS HOB 2.2428 OEF L 221 . 3750 L S SI 232.7500 SS2 ALI 8. 7578 SGR NRA '3°8583 RTNR FTC 502.5167 CNTC PHI -99 9. 2500 ORHD R -999.2500 EPT 3900.2998 'TENS HOB 2.2598 PE~ L 220.0000 tS S1 231.7500 SSZ ALI 8.4688 SGR NRA 2.8848 RTNR FTC 853.8062 CNTC PHI -999.2500 ORHO R -999.2500 EPT 3800.2998 TENS HOB 2. 2147 ~EF L 243.2500 tS S1 242.8750 SS2 ALI 8.9141 SGR NRA 3. 3629 RTNR FTC 550.80'55 CNTC PHI -999.2500 DRHO R -99'9. 2500 EDT 3'?00. 2998 'TENS HOB 2.21.70 DEF t 227.1250 tS S1 228. 2500 SS 2 ALI ~.4453 SGD NRA 3.4696 RTNR FTC 576. 7102 CNTC PHI -999.2500 ORHO -999.2500 TENS -999.2500 ~C:T -999.2500 GR -999.2500 RHOB -999.2500 DPMI - 999. 2500 QL S -999.2500 LU -999.2500 LSHV -999. 2500 TENS -999. 2500 RC,:T -999.2590 GR -999.2500 RHOB !380.0000 DPHI 2.8125 QLS &14.7500 LU 334.0000 LSHV 91. 9059 TENS 4.1020 RC'~T 1 926.,410~ GR -99:9.2500 ~H':OB 1345.0000 OPHI 2.B066 QLS 403.0000 LU 333.5000 LSHV 109.8459 TENS 3.0500 RC~T 2454.3613 5R -999.,2500 RHDB 1275.0000 OPHI 2.7!¢8 QLS 448.0000 tU 346.2500 LSHV 65. 8844 TE NS 3.~815 ~C~T 1911.5535 GR -999.2500 RHOB 1240.0000 DPHI 2.66180 QLS 427.7500 LU 333.0000 LSHV 77.1128 TENS 3.7500 RCFT 1959.5938 GR -999.2500 ~HOB -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 24.6806 -0.0215 387.0000 1194.0000 1380.0000 471.0198 91.9059 -999.2500 23.6505 0.0195 365.7590 1194.0000 1320.0000 779.9906 86.6923 -999.2500 2,6.38,44 0.0083 405.2500 1193.0000 1300.0000 518.6991 75.2720 -999.2500 26.2434 -0.0327 401.5000 1193.0000 1225.0000 560.6941 76.2246 -999.25'00 NPHI RCNT TENS CALI DRHD QSS LITH SSHV NPHI RCNT TENS CALI DRHO QSS LITH SSHV NPHI RCNT TENS CALI DRHO QSS LITH SSHV NPHI RCNT TENS CALl DRHO QSS L ITH SSHV NPHI RCNT TENS CALI DRHO LITH SSHV NPHI RCNT TENS CALI -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2590 -999.2500 0.0037 0.0117 118.2500 1149.0000 50.1772 1955.7969 -999.2500 -999.2500 0.0038 0. 0073 116. 5625 1149.0000 32.1374 2735.9'727 -999.2500 -999.2500 0.0158 0.9215 127.5000 1145.0000 40.5494 1836.2385 -99'9.2500 -999.2590 -0.0049 0.0024 122.0625 1147.0000 42.7905 199,6.5697 -999.2500 .-999.2500 VP OIO.H02 VERIFICATION LISTING PA~E 45 R -~99.2500 EPT 3600.2998. TENS 1185.0000 9PHI HOB 2.2696 PEF 3.1406 QLS L 227.6250 LS ¢22.0000 LU S1 249,2500 5S2 349.2500 LSHV ALI B, 55~7 SGR 89.6671 TEUS NRA 3.4768 RTN~, 3.4286 RC~T FTC 556.0114 CNTC 1941.6030 GR PHI -999.2500 DRHO -999.2500 RHgB R -999.2500 EPT 3500.2998 TENS 1185.0000 9PHI HOE 2.2904 PEF 2.8418 QLS L 210.5250 LS 392.5000 LU SI 239.7500 SS2 331.5000 ISHV ALI 8.55¢7 SGR 90.0258 TENS NRA 3.6993 ~'TNR 3.6154 RCFT FTC 520.0065 CNTC 1857.7771 GR PHI -999.2500 ORHO -999.2500 RHOB R -999.2500 'EPT 3400.2998 TENS 1155.0000 DPHI HOB 2.3234 ~EF 3.2090 QLS ,L 220.6250 LS 403.2500 LU S1 255.8750 SS2 349.5000 LSHV ,AL1 B.6875 SGR 80,2554 TENS NRA 3,~750 ~TNR 3.88~9 RCFT :FTC 577.9709 CNTC 1966.2124 GR ~PHI -9'99.1500 gRHO -999.2500 ~HO~ ;R -999.2500 ~EPT 3300.2998 TENS 1145.0000 OPHI ,HOB 2,2175 PE~ 2.9766 QLS ,L 254.2500 tS 474.7500 LU ,S1 256,5000 SS2 i]60.7500 LSHV ALI 8.6641 SG~ 66.5871 TENS NRA 3,5611 RTNR 3,5000 RCFT FTC 529.9169 CNTC 1872,6316 GR )PHI -999.2500 DRHO -999.2500 RHOB ,R -999.2500 ~EPT 3200.2998 'TENS 1:13:5,0000 DPHI :HOB 2.1853 PEF 13,2676 9LS ,t 278.7500 tS 523.5000 LU iS1 26'7.2500 SS2 :37'7.2500 LSHV :ALI 10.6719 S,G~ 75.94,~8 'TENS 'NRA 3. 8109 , RTNR 4.0455 ~CFT ;FTC ,¢31,!168 CNTC 1598.3113 GP ):PHI -999.2500 ORHO -999.2500 RHO~ ;R -999.2500 )EPT 3100.2998 TENS 1110.0000 OPHI tHO6 2.07t4 PE~ 3.0742 QLS 23.0532 DRHO -0.0054 QSS 389.7500 LITH 1193.0000 SSHV 1180.0000 NPHI 502.~116 RCNT 85.5954 TENS -999.2500 CALI 21.7916 ORHO -0.0073 QSS 363.5000 LITH 1192.0000 SSHV 1165.0000 NPHI ~42.0594 RCNT 91.~884 TENS -999.2500 CALI 19.7939 DRHO 0.0220 QSS 365.5000 LITH 1192.0000 .SSHV 1145.0000 NPHI 482.2220 RCNT 77.0724 'TENS -999.2500 CALI 26.2113 DRHO -0,0264 QSS 440.7500 LITH 1191,0000 SSHV 1125.0000 NPHI &80.6768 RCNT 41.4865 TENS -999.2500' CALI 28.1641 DRHO -0.0415 QSS 489.5000 LZTH 1192.0000 SSMV 1105,0000 NPHI 386.0408 RCNT 79.7932 TENS -999.2500 CAtI 35,0653 ORHO O.03O8 QSS 0.04B7 0.0278 108.7500 1148.0000 42.7176 1955.4165 -999.2500 -999.2500 0.0210 0.0342 109.1875 1147.0000 46.5941 1915.6638 -999.2500 -999.2500 0.0717 0.0425 105.3125 1146.0000 42.4370 2035.00Z0 -999.2500 -999.2500 0.0545 0.0337 130.7500 1146,0000 42,6576 1895.7974 -999.2500 -999.2500 0.0770 0.0356 138.1250 1145.0000 45.8693 1539.3428 -999.Z500 -999.2500 O.OOZO 0.0073 VP OlO.H02 VErifICATION LISTING L 315.0000 LS 565.5000 LU SI 241.7500 SS2 360.5000 LSHV ALI 11.1641 SG~ 32.8724 TENS NRA 3.2271 RTNR 3.0857 RCFT FTC 568.1219 CNTC 2222.4292 GR PHI -999. 2500 DRHO -999. 2500 RHOB R -999.2500 EPT 3000. 2998 TENS 1070. 0000 DPHI HOB 2.2925 PE,~ 6.4258 QLS L 189.6250 LS 355.7500 LU SI 217.1250 SS2 303.0000 LSHV ALI 10.11'72 SGR 68. 6002 TENS NRA 3. 5341 RTNR 3.4643 RC~T FTC 555.,6313 CNTC 1925.4272 GR PHI -999.2500 DRHD -999.2500 ~HOB R -999.2500 EPT 2900.2998 TENS !030.0000 OPHI HOB 1.78,22 PEF ~3.6777 OLS L 530.0000 LS 1008.0000 LU Sl 276.5000 SS2 43'9.5000 LSHV ALI 11.9766 SGR 37.7978 TENS NRA 3.3079 RTNR 3.5556 RCFT FTC 537.5968 CNTC 1~37.2593 GR PHI -999.2500 gRHO -999.2500 RHOB R -999.2500 EPT 2800.2998 TENS !040.0000 gPHI HOB 1.7667 PEF ]3.4785 QLS L 547.0000 LS 1035.0000 LU $1 276.5000 SSZ 431.0000 LSHV ALI 13.6563 SGR 26.0835 TENS NRA 3.5541 ~TNR 4.3913 RCFT FTC 554.9062 CN'TC 1985.3811 GR PHI -99'9.2500 DRHD -999.2500 ~HOB R -999.2500 EPT 2709.2998 TENS !015.0000 OPHI HOB 2.1547 ~EF 4.8711 QLS t 253.5000 tS 476.7500 LU SI 233.3750 SS2 338.0000 LSHV ALI 10.1094 SGR 56.7662 TENS NRA 4.1700 RTNR ~4.6000 RC:T FTC 409.0913 CNTC 1641.9768 GR PHI -999.2500 DRHg -999.2500 RHOB R -999.2500 EPT 2695.6997 'TENS -999.2500 9PHI HOB -999.2500 PEF -999.2500 QLS L -999.2500 LS -999.2500 LU S1 -999.2500 SS2 -'999.2500 LSHV ALI -999.250'0 SG~ -999.2500 TENS NRA -999..2500 ~TNR -999.2500 RCFT 501.5000 LITH 1190.0000 SSHV 1110.0000 NPHI 580.1361 RCNT 35.~669 TENS -999.2500 CALl 21.6654 DRHO -0.0093 QSS 332.0000 LITH 1191.0000 SSHV 1095.0000 NPHI 482.9984 RCNT 62.5963 TENS -999.2500 C~LI 52.5920 ORHO -O.OZgB QSS 956.0000 LITH 1190.0000 SSHV 1130.0000 NPHI 542.~140 RCNT 51.8501 TENS -999.2500 C~LI 53.5309 ORHO -0.0205 QSS gT6. 5000 LITH llBg.o000 SSHV 1010.0000 NPHI 541. 2594 RCNT 52°2577 TENS -999.2500 CALI 30.0186 DRHO -0.0381 QSS 446.5000 LITH 1190.0000 SSHV 1085. 0000 NPHI 386.0408 RCNT 70.9779 TENS '-999. 2500 'CALl -999.2500 DRHO -999.2500 QSS -999.2500 LITH -999.2500 SSHV -999.2500 NPHI -999.2500 RCNT PAGE 46 163.5000 1145.0000 36.'1733 2374.4390 -999.2500 -999.2500 -0.0154 0.0239 60.8750 1145.0000 41. 6542 2944.54%7 -999.2500 -999.2500 0.0441 O. '0005 266.2500 1144.0000 35.3702 2054.9150 -999.2500 -999.2500 0.0423 0.0171 28~.2500 11,44.0000 41.8152 2054.9150 -999.2500 -999.2500 -0.0029 0.0176 119.6250 1144.0000 53.1052 1'717.3010 -'999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.Z500 .-999.~500 VP 010.H02 VEPI~ICATI~N LISTING PAGE FTC PHI R -99'9.2500 CNTC -999.2500 DRHO -999.2500 -999.2500 GR -999.2500 RHOB -99g.2500 TENS -999.2500 CALI -999. Z 500 -999.2500 · - FILm. TRAILER ~-~-~-~' ILE NAME :EDIT .002 ERVICE NAME :mLIC ERSION ~ :O01A02 ATE :88/07/30 AXIMUM LENGTH :1024 ILE TYPE :LO EXT FILE NAME : :~ FILE HEADER ~ ILE N,~ME :EDIT .003 ERVICE NAME ::tic ERSION ~ : O01A02 ATE :$8/0T!30 AXIMUM LENGTH :t024 ILE TYPE : LO REVIOUS FILE : COMMENTS THIS DATA HAS NOT ~'EEN: DEPTH SHIFTED. . - OVERL~AYS FIEL'D PRIN'TS OMPUTING CENTER ~:EM~RKS: E~T REPE~T (FIT) SPLICEO INTO LOG FILE (FI. 8) FROM 3532' TO 3500' EPT : :0 AT AKCC BECk, USE I'T WAS NOT S6VEO ON ~IEL~ ~P~ ORO,SITY W~S R~_-C~LCULAT~ . PHI.EPT ON THIS TAPS OOES NOT EXACTLY M~TCH BLUELINE EPHI. :SCHLUMBEPGER LOGS INCLUDEO WITH THIS .FILE (EOIT.O03): ~ VP OlO.H02 VErifICATION LISTING ,~AGE ~8 ~.' <SEE FILE EO[T.O01 FOR 6" SAMPLEO DATA> * ~ <SE? =ILE EgIT.O02 FO~ 1.2" S~MPLED C~TA> ~ ~.,. RUN ~1 ONLY'. ~ ~ ELECTROMaGNeTIC PROP~,GATION LOG (.EPT) · · FIRST TO LAST READING: 400~' TO Z61~' · ~ INFORMATI2N R~CgRDS_ '~--,- ABLE TYPE :CONS MNEM TUNI V~LU DEFI CN FN WN NATI STAT COUN SECT TOWN R~NG LATI LONG O~ER APIN A~IN ABLE TYPE :CURV ~RCO ALASKa, I'~ COMPANY NAME KUPARUK (W~ST ~ FIELD NAME 3 0-8 WELL NAME U.S.~. N~TION ST:ATE OR PROVI~ COUNTY 22 SECTION I~N TOWNSHIP 9~ R~NGE 876~ FNL LATITUDE !929' F~L L~NGI'TUDE SARBERFMALLA~Y~ OPER~T[tR'S COD.~ 50-029-21'~B28 ~PI SERI.~L NUM~ 50-029-21828 AP! SERI,~L NUM~ MNEM DEPT NVU FVU NVD FVD DEF~ DEPTH CHANNEL NEAR VOLTAGE U~ r-Ap 'VDLTAGE UP~ NEAR VOLTAGE D~ FA~, VOLT,~,GE :DO'" VP 010.HDZ VERI=ICATZON LTSTING PAGE 49 EATT TPL EPHI EPT &TTENU&TIO~ TIME O~ PROP~G* EOT POROSITY * DAT~ :ORMAT,~ R'-_CORD .-~"~- NTRY BLOCKS TY~E SIZE RE~'R CODE ENTRY 1 I 66 0 2 1 66 0 3 4 73 32 4 1 66 8 4 68 6983712. 000 0 9 4 65 FT 11 1 66 32 13 1 66 0 14 4 65 FT 15 1 66 6B 16 1 66 1 0 I 66 I ATUM SPECIFICATION 3LOCKS NEM SERVICE SERVICE UNIT AP1 AP1 AP1 ,AP1 FILE SIZE SPL REPR ID ORDER ~ LOG TYPE CLASS MOO NO. 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