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191-062
STATE OF ALASKA RECLI -' ED *KA OIL AND GAS CONSERVATION COI4SION REPORT OF SUNDRY WELL OPERATIONS JUN 12 2018 1.Operations Abandon ❑ Plug Perforations Fracture Stimulate Pull Tubing 0 e ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate Ell=1ElOk o Alter Casing l=1 Chan I ❑ Plug for Redd!! ❑ .erforate New Pool ❑ Repair Well 0 Re-enter Susp Well❑ Other: 1 ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development 0 Exploratory ❑ 191-062 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic❑ Service ❑ 6.API Number: 99510 50-029-22167-00 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 1 L-23 ADL 25664 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 10,346 feet Plugs measured None feet true vertical 6,291 feet Junk measured 10,200 feet Effective Depth measured 10,226 feet Packer measured 9,634 feet true vertical 6,225 feet true vertical 5,906 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 34 feet 16 " 78' MD 78 TVD SURFACE 5,263 feet 9 5/8" 5,306' MD 3609 TVD PRODUCTION 10,300 feet 7 " 10,343' MD 6290 TVD Perforation depth: Measured depth: 9794-9874, 9796-9874, 10012-10050, 10156-10165 feet True Vertical depth: 5992-6035, 5993-6035, 6110-6130, 6187-6192 feet Tubing(size,grade,measured and true vertical depth) 3.5" L-80 9,817'MD 6,004'TVD Packers and SSSV(type,measured and true vertical depth) PACKER-PACKER,BAKER,4762 FHL 9,634' MD 5,906'TVD SSSV -NONE 12.Stimulation or cement squeeze summary: rY: Intervals treated(measured): N/A SCOW JUN 20c'lr' Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 80 34 126 1058 220 Subsequent to operation: Shut-In Shut-In Shut-In Shut-In Shut-In 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations I] Exploratory ❑ Development El Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLU3❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Name: Ron Phillips Authorized Name: Ron Phillips Contact Email: Ron.L.Phillips©cop.com Authorized Title: Sr.Wells Engineer p -- / Contact Phone: (907)265-6312 Authorized Signature: D. • Date: Ch07 ap/ Uri 6/ FIBOMS2h JUN 13 2018 Form 10-404 Revised 4/2017 t/4/ Submit Original Only . KUP PROD 1L-23 Conocoi hillips tiA t 1` _ ld Narn Max�&MD TD sP Field Name`- Wellbore APl/UWI Wellbore Status Incl(°) ftKB) Act Btm(ftKB) Ala k2,1nG. - KUPARUK RIVER UNIT 500292216700 PROD j2.82 3,100.00 10,346.0 c.W050 hil1W Comment H2S(ppm) Date Annotation End Date I KB-Grd(ft) \Rig Release Date 1 ... SSSV:None 20 12/21/2015 Last WO: 5/13/2018 42.99 5/14/1991 1L-23,6/12/2018 3:57:53 PM Last Tag Vortical schematic(actual) Annotation End Date Depth(ftKB) Last Mod By Last Tag:Doyon 14 5/11/2018 10,200.0 doyonl4cm HANGER;39.4 ;0Last Rev Reason N. Annotation End Date Last Mod By Rev Reason.Installed new GLV's and Pull WRP Post RWO 6/2/2018 zembaej t,f' Casing Strings ®� Cas'ng Descr ption OD(n) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD) Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.06 44.0 78.0 78 0 62.58 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.92 43.0 5,306.3 3,609.3 36.00 J-55 BTC CONDUCTOR;44.0.78.0 IL Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.28 43.2 10,342.9 6,289.7 26.00 J-55 BTC-MOD n."',Tubing Strings 11. Tubing Description String Ma... ID(in) Top(ft)(B) Set Depth(ft.. Set Depth(TVD)(...Wt(lb/ft) Grade Top ConnectionTUBING RVVO 2018 3 GAS LIFT;3,130.6 �°; / 7. 6,004 6 9 30 L-80 EUE 8rd Mod Completion Details ' Top(ND) Top net Nominal Top Inks) (ftKB) (°) Item Des Com ID(in) 39.4 39.4 0.03 HANGER Tubing Hanger,FMC,TC-1A-EN,7-1/16"x 3-1/2"EUE 8rd Top x 2.992 Bottom,3"ISA BPVG 9,616.9 5,897.1 57.95 LOCATOR Locator Sub,Baker,GBH-22(bottom of locator spaced out 3') 2.990 SURFACE;43.5'5.306.3- 9,617.9 5,897.6 57.94 SEAL ASSY Seal Assembly,Baker,80-40(total length=11.79') 2.990 9,620.2 5,898.9 57.94 PBR PBR,Baker,80-40 4.000 9,633.6 5,906.0 57.90 PACKER Packer,Baker,4782 FHL(60K shear release) 2.910 GAS LIFT;5,3855 it- 9,687.1 5,934.5 57.77 NIPPLE Nipple,Halliburton,2.813"X profile,SN:4 2.813 9,798.0 5,994.0 57.24 WEDGE ASSY Wedge Assembly,Northem Solutions 2.992 4 9,812.0 6,001.6 57.21 NIPPLE Nipple,Halliburton,2.813"X profile, 2.813 9,817.1 6,004.4 57.20 WLEG WLEG,Baker 2.990 GAS LIFT;6,924.8 ii- Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Inc' E. Top(ftKB) (ftKB) ('l Des Com Run Date ID(in) 9,845.0 6,019.5 57.16 WHIPSTOCK Northern Solutions HEW whipstock,oriented HS 6/11/2018 GAS LIFT;8,086.9 ,_ 10,200.0 6,211.6 56.94 FISH 1 1/2"GLV Fell to Rathole 4/6/1995 0.000 Perforations&Slots 3t „Ititt 1.m.. Shot,. Dens GAS LIFT,8,964.9 Top(ND) Bier(ND) (shots/ft Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Linked Zone Date ) Type Com 9,794.0 9,874.0 5,991.9 6,035.2 C-4,1L-23 8/17/1991 6.0 APERF 2 1/8"Flow Jet;0 deg. phasing 9,796.0 9,874.0 5,992.9 6,035.2 C-4,UNIT B,1L 9/2/1992 4.0 RPERF 2.5"Hollow Carrie;180 deg. GAS LIFT;9,560.0 - -23 ph;Oriented 14 deg.CCW 11( 4 10,012.0 10,050.0 6,110.0 6,130.5 A-5,1L-23 6/19/1991 4.0 IPERF 4 1/2"Carrier;180 deg.ph; Oriented 12 deg.CCW 41 10,012.0 10,050.0 6,110.0 6,130.5 A-5,1L-23 3/29/2018 6.0 RPERF 2.0"OD POWERJET LOCATOR;9,816.9 OMEGA,6 SPF,60 DEG SEAL ASSY;9,617.9 PHASED. PBR;9,620.2 i 10,156.0 10,165.0 6,187.7 6,192.5 A-4,1L-23 6/19/1991 4.0 IPERF 4 1/2"Carrier;180 deg.ph; PACKER;9,633.6 "_ Oriented 12 deg.CCW II Frac Summary Start Date Proppant Designed(lb) Proppant In Formation(lb) 8/1/1991 NIPPLE;9,687.1 „,E;: Stg# Start Date Top Depth(ftKB) Btm(ftKB) 'Link to Fluid System I Vol Clean(bbl) 'Vol Slurry(bbl) 1 8/1/1991 10,012.0 10,050.0 4 Start Date I Proppant Designed(Ib) I Proppant In Formation(lb) II 8/1/1991 Stg# I Start Date I Top Depth(ftKB)I Btm(ftKB) 'Link to Fluid System I Vol Clean(bbl) 'Vol Slurry(bbl) 1 8/1/1991 10,156.0 10,165.0 Mandrel Inserts st ati on WEDGE ASSY;9,798.0 Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn P: 1 3,130.6 2,491.7 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,255.0 6/1/2018 NIPPLE;9,812.0 2 5,385.5 3,654.0 Camco MMG 11/2 GAS LIFT GLV RK 0.188 1240.0 6/1/2018 3 6,924.8 4,505.5 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1232.0 6/1/2018 WLEG;9,817.1 q 8,086.9' 5,097.5 Camco MMG 11/2 GAS LIFT GLV RK 0.188 1,225.0 6/1/2018 APERF;9,794.0.9,874.0 RPERF;9,7%.0.9,8740 5 8,964.9 5,556.0 Camco MMG 1112 GAS LIFT GLV RK 0.188 1,219.0 5/31/2018 WHIPSTOCK;9,845.0 Ce 6 9,560.0 5,867.0 Camco i MMG 11/2 GAS LIFT OV RK 0.250 0.015/26/2018 Notes:General&Safety End Date Annotation 10/5/2010 NOTE View Schematic w/Alaska Schematic9.0 RPERF;10,012.0-10,050.0 FRAC;10,012.0 ,' el (PERF;10,012.0-10,050.0 FRAC;10,156.0 I ,P IPERF;10,158.0-10,165.0 .1 I. PRODUCTION;43.2-10,342.9 • : . Operations Summary (with Timelog Depths) r 1L-23 ConocoPninips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/3/2018 5/3/2018 1.25 MIRU MOVE RURD P Work on check list to skid the rig floor. 0.0 0.0 15:30 16:45 Blow down rig floor steam and water lines. 1 5/3/2018 5/3/2018 1.00 MIRU MOVE RURD P PJSM-Skid the rig floor into moving 0.0 0.0 16:45 17:45 position. 5/3/2018 5/3/2018 3.75 MIRU MOVE MOB P Jack up and move rig off 1G-07.Stage 0.0 0.0 17:45 21:30 on 1G pad. 5/3/2018 5/3/2018 1.00 MIRU MOVE RURD P PJSM-Install rear booster axle 0.0 0.0 21:30 22:30 5/3/2018 5/4/2018 1.50 MIRU MOVE RURD P Install front booster axle. 0.0 0.0 22:30 00:00 5/4/2018 5/4/2018 4.00 MIRU MOVE RGRP T Change out hydraulic brake electric 0.0 0.0 00:00 04:00 motor on moving system. 5/4/2018 5/4/2018 1.00 MIRU MOVE MOB P Move down pad checking temps on 0.0 0.0 04:00 05:00 new motor and adding oil to hydraulic system 5/4/2018 5/4/2018 3.50 MIRU MOVE MOB P Move rig down 1G access road to 0.0 0.0 05:00 08:30 Spine road. 5/4/2018 5/4/2018 0.50 MIRU MOVE MOB P Stop at intersection of 1G access road 0.0 0.0 08:30 09:00 and Spine road and allow traffic to pass rig. 5/4/2018 5/4/2018 2.25 MIRU MOVE MOB P Move rig down Spine road and turn 0.0 0.0 09:00 11:15 onto 1L access road. 5/4/2018 5/4/2018 0.75 MIRU MOVE RGRP T Remove hydraulic lines on steering 0.0 0.0 11:15 12:00 ram due to hinge failure. 5/4/2018 5/4/2018 5.00 MIRU MOVE MOB P PJSM-Move rig down access road to 0.0 0.0 12:00 17:00 1F pad. 5/4/2018 5/4/2018 6.00 MIRU MOVE MOB P Turn rig around on 1F pad and 0.0 0.0 17:00 23:00 continue to move around 1F pad down access road to 1L pad. 5/4/2018 5/5/2018 1.00 MIRU MOVE MOB P Stage rig on 1L pad to remove rear 0.0 0.0 23:00 00:00 booster tires. 5/5/2018 5/5/2018 1.25 MIRU MOVE RURD P PJSM. Remove the rear booster tires. 0.0 0.0 00:00 01:15 5/5/2018 5/5/2018 0.50 MIRU MOVE RURD P Remove snow from the beams round 0.0 0.0 01:15 01:45 the bottom of the sub. 5/5/2018 5/5/2018 2.50 MIRU MOVE MOB P Move the rig onto the mats and spot 0.0 0.0 01:45 04:15 the rig over well 1L-23. 5/5/2018 5/5/2018 0.75 MIRU MOVE RURD P Shim under the rig. 0.0 0.0 04:15 05:00 5/5/2018 5/5/2018 0.75 MIRU MOVE RURD P PJSM. Skid the rig floor into drilling 0.0 0.0 05:00 05:45 position. 5/5/2018 5/5/2018 1.75 MIRU MOVE RURD P PJSM. RU lines udner the rig floor. 0.0 0.0 05:45 07:30 PU the beaver slide. Plug in the top drive. 5/5/2018 5/5/2018 4.00 MIRU MOVE RURD P Work on rig acceptance checklist. 0.0 0.0 07:30 11:30 SimOps: KDTH RU the kill tanks, choke house and hard line. Build transitions in the cellar at the cellar door entrances for safe egress into the cellar box. Accept rig at 11:30 hrs.5-5-18 Page 1/10 Report Printed: 5/16/2018 • ife et inik Operations Summary (with TimeloiRepths) 1L-23 CoirrocoPhilGips At.xti e Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/5/2018 5/5/2018 6.00 MIRU WELCTL RURD P Start taking on seawater into the pits. 0.0 0.0 11:30 17:30 Continue to build transitions in the cellar at the cellar door entrances for safe egress into the cellar box. RU circulating lines for the well kill operation. Well pressures: Tubing=2400 psi, IA =950 psi and OA=940 psi. 5/5/2018 5/5/2018 1.50 MIRU WELCTL RURD P PJSM-Blow air through circ lines to 0.0 0.0 17:30 19:00 kill tank.Flood lines and test to 3500 psi. 5/5/2018 5/5/2018 1.00 MIRU WELCTL KLWL P PJSM-Bleed tubing down from 1600 0.0 0.0 19:00 20:00 psi to 1000 psi.Bleed IA down from 1500 psi to 450 psi..Bleed OA down from 940 psi to 300 psi. 5/5/2018 5/5/2018 2.00 MIRU WELCTL CIRC P Circulate 365 bbls 8.5 ppg seawater 0.0 0.0 20:00 22:00 down tubing taking returns up IA to kill tank.3 bpm with 800 psi on tubing and holding 500 psi on IA. 5/5/2018 5/5/2018 0.50 MIRU WELCTL OWFF P Shut in well and monitor.Tubing=600 0.0 0.0 22:00 22:30 psi IA=600 psi.OA=800 psi bleed to 500 psi. 5/5/2018 5/6/2018 1.50 MIRU WELCTL CIRC P Circulate 8.5 ppg seawater down 0.0 0.0 22:30 00:00 tubing taking returns up IA,4 bpm, 1100 psi on tubing holding 600 psi on IA. 5/6/2018 5/6/2018 0.50 MIRU WELCTL CIRC P Continue to circulate 8.5 ppg seawater 0.0 0.0 00:00 00:30 down tubing taking returns up IA,4 bpm, 1100 psi on tubing holding 600 psi on IA. 5/6/2018 5/6/2018 2.00 MIRU WELCTL OWFF P Shut in the well with 780 psi trapped 0.0 0.0 00:30 02:30 pump pressure. Bleed the off to 600 psi. Pressure built up to 700 psi. Monitored for 30 and still 700 psi. Bleed off to 600 psi and pressure built back up to 700 psi. 5/6/2018 5/6/2018 1.50 MIRU WELCTL WAIT P Wait for 11.1 ppg KWF to arrive. 0.0 0.0 02:30 04:00 SimOps: Continue with BWM on the BOP stack. 5/6/2018 5/6/2018 1.50 MIRU WELCTL COND P Load the pits with 580 bbls 11.1 ppg 0.0 0.0 04:00 05:30 NaCI/NaBr brine. SimOps: Finish BWM on the BOP stack. 5/6/2018 5/6/2018 2.00 MIRU WELCTL KLWL P PJSM. Pump 355 bbls of 11.1 ppg 0.0 0.0 05:30 07:30 brine down the tuibng taking return up the IA to the kill tank at 4 BPM. 5/6/2018 5/6/2018 1.00 MIRU WELCTL KLWL T Kill tank#1 at 80%and attempt to 0.0 0.0 07:30 08:30 switch to kill tank#2 but the line was frozen. Shut down the pump and shut in the well. 5/6/2018 5/6/2018 0.50 MIRU WELCTL KLWL P Pump an addtional 23 bbls to get 11.1 0.0 0.0 08:30 09:00 ppg brine to surface. Shut in the well. 5/6/2018 5/6/2018 0.50 MIRU WELCTL OWFF P Observe the well for flow for 30 0.0 0.0 I 09:00 09:30 minutes and the well is static. SimOps: Blow down and RD the circulating lines. Page 2/10 Report Printed: 5/16/2018 • • Operations Summary (with Timeloitepths) 1L-23 ConoctiPhilI*p6 A4nka Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/6/2018 5/6/2018 0.50 MIRU WHDBOP MPSP P Install the 3"ISA BPV with dry rod. 0.0 0.0 09:30 10:00 5/6/2018 5/6/2018 1.50 MIRU WHDBOP NUND P ND the tree and tubing head adapter. 0.0 0.0 10:00 11:30 Clean and inspect the tuibng hanger lift threads. Install the blanking plug. 5/6/2018 5/6/2018 6.50 MIRU WHDBOP NUND P NU the 7-1/16"x 13-5/8"DSA. NU the 0.0 0.0 11:30 18:00 BOP stack. 5/6/2018 5/6/2018 0.50 MIRU WHDBOP RURD P Fill BOPE,lines and choke manifold 0.0 0.0 18:00 18:30 with water.Conduct shell test. 5/6/2018 5/7/2018 5.50 MIRU WHDBOP BOPE P Conduct initial BOPE test:All tests 5 0.0 0.0 18:30 00:00 minutes each.Test 3-1/2"x 6"VBR's (upper pipe rams)to 250/3000 psi with 3-1/2"and 4"test joints;test 2-7/8"x 5"VBR's(lower pipe rams)to 250/3000 psi with 3-1/2"and 4"test joints;test annular to 250/3000 with 3- 1/2"and 4"test joints;conducted Koomey drawdown test(all tested passed). The test was waived by AOGCC inspector Matt Herrera. Tests: 1) 2-7-/8"x 5"VBR's(lower pipe rams)with 4"test joint,upper IBOP (Passed) 2) Annular with 4"test joint,choke valves 12, 13, 14,lower IBOP,3" Demco(Passed) 3) 3 1/2"x 6"VBR's(upper pipe rams)with 4"test joint,choke valves 1,9, 11,kill line HCR(Passed) 4) Choke valves 5,8, 10,kill line manual valve(Passed) 5) Choke valves 4,6,7,HT-38 dart valve(Passed) 6) Choke valve 2,HT-38 TIW (Passed) 7) Blind rams,choke valve 3(Passed) 8) 2-7-18"x 5"VBR's(lower pipe rams)with 3-1/2"test joint (Passed) 9) Annular with 3 1/2"test join (Passed) 5/7/2018 5/7/2018 1.50 MIRU WHDBOP BOPE P Continue with initial BOPE test. 0.0 0.0 00:00 01:30 10) 3-1/2"x 6"VBR's(upper pipe rams)with 3-1/2"test joint,choke line HCR(Passed) 11) 3-1/2"x 6"VBR's(upper pipe rams)with 3-1/2"test joint,choke line manual valve(Passed) 12)Hydraulic and manual chokes Conduct Koomey Draw Down Test: Starting Accumulator Pressure=3000 psi Accumulator Pressure After Closer= 1625 psi Pressure Gain of 200 psi=42 seconds Full System=179 Seconds Average N2(6 Bottles)=2062 psi 5/7/2018 5/7/2018 0.50 MIRU WHDBOP RURD P Rig down test equipment.Blow down 0.0 0.0 01:30 02:00 lines. Page 3/10 Report Printed: 5/16/2018 • • Operations Summary (with Timelog-Depths) ',. - u i4T1L-23 ai ConocoPhiltips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/7/2018 5/7/2018 1.50 MIRU WHDBOP MPSP P RU and pull the blanking plug. Pull 0.0 0.0 02:00 03:30 the BPV with the dry rod. 5/7/2018 5/7/2018 0.50 COMPZN RPCOMP PULL P PJSM. MU the landing joint,BOLDS, 9,616.0 9,585.0 03:30 04:00 unseat the tubing hanger at 75K, continue to PU to 137K,then the weight dropped to 105K and pull the hanger to the rig floor. 5/7/2018 5/7/2018 1.00 COMPZN RPCOMP CIRC P Circulate bottoms up at 8.5 BPM= 9,585.0 9,585.0 04:00 05:00 2100 psi,started losing fluid therefore slowed the pumps down to 6 BPM. SimOps: RU 3-1/2"power tubing tongs and SLB control line spooler. 5/7/2018 5/7/2018 0.75 COMPZN RPCOMP PULL P Lay down the landing joint and tubing 9,585.0 9,582.0 05:00 05:45 hanger. 5/7/2018 5/7/2018 2.25 COMPZN RPCOMP PULL P POOH laying down 3-1/2"tubing 9,582.0 7,632.0 05:45 08:00 spooling control line from 9582'to 7632'MD. Lay down the SCSSSV. (recovered 34 of 35 stainless steel bands). 5/7/2018 5/7/2018 0.75 COMPZN RPCOMP RURD P RD SLB control line spooler and 7,632.0 7,632.0 08:00 08:45 offload from the rig floor. SimOps: Strap and unload tubing in the pipe shed. 5/7/2018 5/7/2018 1.75 COMPZN RPCOMP PULL P Continue to POOH laying down 3-1/2" 7,632.0 5,960.0 08:45 10:30 tubing from 7632'to 5960'MD. 1 5/7/2018 5/7/2018 0.50 COMPZN RPCOMP RURD P Strap and unload tubing in the pipe 5,960.0 5,960.0 10:30 11:00 shed. 5/7/2018 5/7/2018 2.50 COMPZN RPCOMP PULL P Continue to POOH laying down 3-1/2" 5,960.0 4,418.0 11:00 13:30 tubing from 5960'to 4418'MD. 5/7/2018 5/7/2018 0.50 COMPZN RPCOMP RURD P Strap and unload tubing in the pipe 4,418.0 4,418.0 13:30 14:00 shed. 5/7/2018 5/7/2018 2.00 COMPZN RPCOMP PULL P Continue to POOH laying down 3-1/2" 4,418.0 2,610.0 14:00 16:00 tubing from 4418'to 2610'MD. 5/7/2018 5/7/2018 0.50 COMPZN RPCOMP RURD P Strap and unload tubing in the pipe 2,610.0 2,610.0 16:00 16:30 shed. 5/7/2018 5/7/2018 3.00 COMPZN RPCOMP PULL P Continue to POOH laying down 3-1/2" 2,610.0 0.0 16:30 19:30 tubing from 2610'MD to surface. Make up to top drive on last full joint. 85K overpull pulling GLM through DSA at bottom of BOPE. Recover 306 full joints tubing, 1 cut joint tubing at 16.61',8 GLM's,SSSV w/pup joints, 34 SS bands. 5/7/2018 5/7/2018 1.50 COMPZN RPCOMP BHAH P Clear rig floor.Mobilize overshot BHA 0.0 0.0 19:30 21:00 #1 to rig floor.Sim-ops/Strap tubing and unload pipe shed. 5/7/2018 5/7/2018 0.50 COMPZN RPCOMP RURD P Set 6.375"ID wearring 0.0 0.0 21:00 21:30 5/7/2018 5/7/2018 0.50 COMPZN RPCOMP BHAH P PJSM-Make up overshot BHA#1. Pick 0.0 34.0 21:30 22:00 up 5 3/4"overshot with 3 1/2"grapple, bumper sub,oil jar,one 4 3/4"DC. 5/7/2018 5/7/2018 1.00 COMPZN RPCOMP BHAH T Tagging up at 34'with 5.75"OD 34.0 0.0 22:00 23:00 overshot.Drain BOPE.Pull wearring. Attempt to work overshot past 34'. 5/7/2018 5/8/2018 1.00 COMPZN RPCOMP BHAH T Lay down overshot BHA.Mobilize 0.0 0.0 23:00 00:00 string mill to rig floor. Page 4/10 Report Printed: 5/16/2018 • 0 0 , Operations Summary (with Timelog Depths) 01 L-23 ConocoPhiliips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/8/2018 5/8/2018 0.25 COMPZN RPCOMP BHAH T MU BHA#2-6-1/8"string mill and 0.0 33.5 00:00 00:15 RIH to tag at 33.5'RKB. 5/8/2018 5/8/2018 1.00 COMPZN RPCOMP MILL T Mill off the top of the casing at 60 33.5 33.5 00:15 01:15 RPM= 1-2K ft-lbs torque,3 BPM=40 psi. 5/8/2018 5/8/2018 0.75 COMPZN RPCOMP BHAH T Lay down BHA#2-6-1/8"string mill. 33.5 0.0 01:15 02:00 5/8/2018 5/8/2018 0.25 COMPZN RPCOMP BHAH T MU BHA#3-5-3/4"overshot with 3 0.0 24.0 02:00 02:15 1/2"grapple assembly,bumper sub and oil jar. 5/8/2018 5/8/2018 0.50 COMPZN RPCOMP BHAH P Continue to MU BHA#3-5-3/4" 24.0 316.0 02:15 02:45 overshot with 3 1/2"grapple assembly 5/8/2018 5/8/2018 1.25 COMPZN RPCOMP PULD P Change elevator. RIH with BHA#3 on 316.0 1,161.0 02:45 04:00 3-1/2"PH-6 work string from 316'to 1161'RKB. 5/8/2018 5/8/2018 0.75 COMPZN WELLPR MPSP P PU and MU the storm packer. RIH 1,161.0 1,251.0 04:00 04:45 from 1161'to 1251'RKB. Set the storm packer at 96'RKB(center of element= 104'RKB). Release from storm packer and stand back the stand. 5/8/2018 5/8/2018 1.00 COMPZN WELLPR MPSP P RU testing equipment. PT the storm 0.0 0.0 04:45 05:45 packer to 1000 psi for 5 minutes. RD testing equipment and blow down the kill lines. 5/8/2018 5/8/2018 1.25 COMPZN WELLPR NUND P PJSM. Drain the stack. ND the BOP 0.0 0.0 05:45 07:00 stack and set back on the stump. 5/8/2018 5/8/2018 1.75 COMPZN WELLPR NUND P Remove all the LDS. ND the annulus 0.0 0.0 07:00 08:45 vavle and remove studs. ND the VR plug flange and remove the studs. SimOps: Bleed gas off the OA (started at 200 psi). 5/8/2018 5/8/2018 2.00 COMPZN WELLPR RURD P RU the Hydratight system on the 0.0 0.0 08:45 10:45 tubing head. SimOps: Continue to bleed gas off the OA 5/8/2018 5/8/2018 2.25 COMPZN WELLPR WAIT P Continue to bleed gas off the OA(10 0.0 0.0 10:45 13:00 psi). SimOps: Changeout the swivel packing on the top drive. 5/8/2018 5/8/2018 0.50 COMPZN WELLPR WAIT P Continue to bleed gas off OA. 0.0 0.0 13:00 13:30 Sim-ops:MU BHA#4-7"casing spear. 5/8/2018 5/8/2018 2.00 COMPZN WELLPR NUND P PJSM. Rig up Hydratight system.ND 0.0 0.0 13:30 15:30 tubing spool.Casing growth=13". 5/8/2018 5/8/2018 1.50 COMPZN WELLPR CUTP P Remove packoff.Secure slips.Cut 0.0 0.0 15:30 17:00 off.23'extruded section of 7"casing. 5/8/2018 5/8/2018 2.00 COMPZN WELLPR CUTP P PU BHA#4-7"spear assy.Spear 7" 0.0 0.0 17:00 19:00 casing and pick up to 150K(strech= 6").Remove old slips. Dress casing stub and wellhead. Install new slips and land casing with 110K. Total casing growth with strech= 19". Page 5/10 Report Printed: 5/16/2018 • 0"ANA-- Operations Summary (with Timelog Depths) es4 40M14, „ 1 L-23 ConocoPhitiips F Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/8/2018 5/8/2018 2.00 COMPZN WELLPR CUTP P Rig up Wachs cutter.Cut off 1.85'of 0.0 0.0 19:00 21:00 excess 7"casing. 5/8/2018 5/8/2018 1.00 COMPZN WELLPR WWSP P Install new packoff. NU new tubing 0.0 0.0 21:00 22:00 spool. 5/8/2018 5/8/2018 0.50 COMPZN WELLPR WWSP P Rig up and test packoff to 3000 psi/15 0.0 0.0 22:00 22:30 mins. 5/8/2018 5/9/2018 1.50 COMPZN RPCOMP NUND P Nipple up DSA and BOPE. 0.0 0.0 22:30 00:00 5/9/2018 5/9/2018 2.50 COMPZN WELLPR NUND P Continue to NU the BOPE stack. NU 0.0 0.0 00:00 02:30 the kill line. Install the riser and air up the air boot. Install the mouse hole. 5/9/2018 5/9/2018 0.25 COMPZN WELLPR RURD P Install the wear ring. 0.0 0.0 02:30 02:45 5/9/2018 5/9/2018 0.75 COMPZN WELLPR BOPE P PJSM. PT the BOP stack break to 0.0 0.0 02:45 03:30 250/3000 psi(good test). 5/9/2018 5/9/2018 1.00 COMPZN WELLPR MPSP P PU MU and RIH with storm packer 0.0 1,161.0 03:30 04:30 retrieving head. Release the storm packer. Attempt to circulate but pressured up. POOH and lay down the storm packer. 5/9/2018 5/9/2018 0.50 COMPZN WELLPR CIRC P Circulate bottoms up at 4 BPM=140 1,161.0 1,161.0 04:30 05:00 psi. Blow down the top drive. 5/9/2018 5/9/2018 5.50 COMPZN RPCOMP PULD P PJSM. Continue to RIH with BHA#3- 1,161.0 7,628.0 05:00 10:30 overshot assembly for 3-1/2"tubing picking up 3-1/2"PH-6 work string from 1161'to 7628'RKB. 5/9/2018 5/9/2018 0.25 COMPZN RPCOMP RURD P Change elevator to 4"DP. MU 7,628.0 7,628.0 10:30 10:45 crossover from 3-1/2"PH-6 to 4"HT- 38. 5/9/2018 5/9/2018 2.25 COMPZN RPCOMP PULD P Continue to RIH with BHA#3 picking 7,628.0 9,581.0 10:45 13:00 up 4"HT-38 DP from 7628'to 9581' RKB. 5/9/2018 5/9/2018 0.50 COMPZN RPCOMP FISH P Obtain parameters: PU= 140K and 9,581.0 9,604.0 13:00 13:30 SO=90K. Tag the top of the tubing stub at 9604'RKB. Engage the overshot onto the tubing stub. PU to 200K and the seal assembly pulled free. Roll the pumps with no returns confirming the fish is engaged. PU 15' and established circulation. 5/9/2018 5/9/2018 1.25 COMPZN RPCOMP CIRC P Circulate bottoms up at 5 BPM=1200 9,604.0 9,589.0 13:30 14:45 psi and circulate until clean. 5/9/2018 5/9/2018 0.25 COMPZN RPCOMP OWFF P Observe the well for flow for 10 9,589.0 9,589.0 14:45 15:00 minutes and the well is static. 5/9/2018 5/9/2018 1.00 COMPZN RPCOMP TRIP P Blown down the top drive. TOOH with 9,589.0 8,500.0 15:00 16:00 BHA#3 from 9589'MD to 8500'MD. 5/9/2018 5/9/2018 1.00 COMPZN 'RPCOMP CIRC P CBU to balance fluid.4 bpm,660 psi. 8,500.0 8,500.0 16:00 17:00 20%FO. 5/9/2018 5/9/2018 4.50 COMPZN RPCOMP TRIP P Blown down the top drive. TOOH with 8,500.0 316.0 17:00 21:30 BHA#3 from 8500'MD to 316'MD. 5/9/2018 5/9/2018 0.25 COMPZN RPCOMP OWFF P Monitor well.Slight losses. 316.0 316.0 21:30 21:45 5/9/2018 5/9/2018 0.75 COMPZN RPCOMP BHAH P Stand back DC's.Lay down overshot 316.0 0.0 21:45 22:30 BHA#3. 5/9/2018 5/9/2018 0.50 COMPZN RPCOMP BHAH P Break off overshot and lay down fish. 0.0 0.0 22:30 23:00 Recover 14.62'cut joint and 18.92 of pup joint/seal assy. Page 6/10 Report Printed: 5/16/2018 • q ' _ Operations Summary (with Times Depths) y : 1L-23 ConocoPhilkips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (RKB) End Depth(ftK6) 5/9/2018 5/10/2018 1.00 COMPZN RPCOMP BHAH P Make up spear BHA#5-PBR spear 0.0 301.0 23:00 00:00 dressed with 3.947"grapple. 5/10/2018 5/10/2018 3.25 COMPZN RPCOMP TRIP P TIH with BHA#5-PBR spear 301.0 7,540.0 00:00 03:15 assembly on 3-1/2"PH-6 work string from 301'to 7540'RKB. 5/10/2018 5/10/2018 0.25 COMPZN RPCOMP RURD P Change elevators to 4"DP. 7,540.0 7,540.0 03:15 03:30 5/10/2018 5/10/2018 0.50 COMPZN RPCOMP TRIP P Continue to TIH with BHA#5 on 4"DP 7,540.0 9,521.0 03:30 04:00 from 7540'to 9521'RKB(PU=145K and SO=90K). 5/10/2018 5/10/2018 0.25 COMPZN RPCOMP FISH P PU 4 singles joints of 4"DP from the 9,521.0 9,628.0 04:00 04:15 pipe shed from 9521'to 9628'RKB. Turn the pumps on at 3 BPM=730 psi pressure increased to 770 psi as spear entered the PBR. Set 5K down, PU to 175K,SO 10K and PU to 200K. Pumps off. 5/10/2018 5/10/2018 0.25 COMPZN RPCOMP JAR P Begin jarring at 250K with straight pull 9,628.0 9,628.0 04:15 04:30 up to 275K(15 hits) 5/10/2018 5/10/2018 0.25 COMPZN RPCOMP SFTY P Derrick inspection. 9,628.0 9,628.0 04:30 04:45 5/10/2018 5/10/2018 1.00 COMPZN RPCOMP JAR P Continue jarring at 250K with straight 9,628.0 9,628.0- 04:45 05:45 pull up to 275K(25 hits) 5/10/2018 5/10/2018 0.25 COMPZN RPCOMP SFTY P Derrick inspection. 9,628.0 9,628.0 05:45 06:00 5/10/2018 5/10/2018 0.75 COMPZN RPCOMP JAR P Continue jarring at 250K with straight 9,628.0 9,628.0 06:00 06:45 pull up to 275K(30 hits) 5/10/2018 5/10/2018 0.25 COMPZN RPCOMP SFTY P Derrick inspection. 9,628.0 9,628.0 06:45 07:00 5/10/2018 5/10/2018 1.25 COMPZN RPCOMP JAR P Continue jarring at 250K with straight 9,628.0 9,628.0 07:00 08:15 pull up to 275K(43 hits) 5/10/2018 5/10/2018 0.25 COMPZN RPCOMP SFTY P Derrick inspection. 9,628.0 9,628.0 08:15 08:30 5/10/2018 5/10/2018 0.25 COMPZN RPCOMP JAR P Continue jarring at 250K with straight 9,628.0 9,628.0 08:30 08:45 pull up to 275K(9 hits)and pull free. Total jar hits=122. 5/10/2018 5/10/2018 3.25 COMPZN RPCOMP CIRC P Circulate bottoms up at 4 BPM= 1250 9,628.0 9,628.0 08:45 12:00 psi. At bottoms up had gas at surface. Continue to circulate the well clean. 5/10/2018 5/10/2018 0.25 COMPZN RPCOMP OWFF P Observe the well for flow and the well 9,628.0 9,628.0- 12:00 12:15 is static. 5/10/2018 5/10/2018 2.25 COMPZN RPCOMP TRIP P Lay down a single and blow down the 9,628.0 7,536.0 12:15 14:30 top drive. TOOH with BHA#5 from 9597'to 7536'RKB. 5/10/2018 5/10/2018 0.50 COMPZN RPCOMP RURD P MU crossovers to from 3-1/2"PH-6 to 7,536.0 7,536.0 14:30 15:00 4"HT-38 for 4"TIW. Change elvators to 3-1/2". 5/10/2018 5/10/2018 5.00 COMPZN RPCOMP TRIP P Continue to TOOH with BHA#5 from 7,536.0 319.0 15:00 20:00 7536'to 319'RKB. 5/10/2018 5/10/2018 0.25 COMPZN RPCOMP OWFF P Monitor well.Static. 319.0 319.0 20:00 20:15 5/10/2018 5/10/2018 1.25 COMPZN RPCOMP BHAH P Change out handling equipment.Lay 319.0 26.0 20:15 21:30 down intensifier and stand back DC's. 5/10/2018 5/10/2018 0.50 COMPZN RPCOMP BHAH P Lay down fish.Recover PBR,packer, 26.0 0.0 21:30 22:00 pup joint,D nipple,full joint tubing and shear out sub.Total length=63.22' Page 7/10 Report Printed: 5/16/2018 J • Operations Summary (with Timelag Depths) M)�1 1L-23 ConocoPhillips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (RKB) End Depth(ftKB) 5/10/2018 5/10/2018 0.50 COMPZN WELLPR BHAH P Clear rig floor. Mobilize cleanout BHA 0.0 0.0 22:00 22:30 to rig floor. 5/10/2018 5/11/2018 1.50 COMPZN WELLPR BHAH P Make up BHA#6-cleanout assembly 0.0 349.0 22:30 00:00 to 349'MD. 5/11/2018 5/11/2018 2.75 COMPZN WELLPR TRIP P RIH with BHA#6 from 349'MD to 349.0 7,568.0 00:00 02:45 7568'MD. 5/11/2018 5/11/2018 0.25 COMPZN WELLPR RURD P Change out handling tools. 7,568.0 7,568.0 02:45 03:00 5/11/2018 5/11/2018 0.50 COMPZN WELLPR PULD P Pick up 18 joints 4"HT-38 drillpipe 7,568.0 8,137.0 03:00 03:30 from 7568'MD to 8137'MD. 5/11/2018 5/11/2018 1.00 COMPZN WELLPR SLPC P PJSM-Slip and cut 80'(12 wraps) 8,137.0 8,137.0 03:30 04:30 drilling line. 5/11/2018 5/11/2018 0.50 COMPZN WELLPR SVRG P Service the draw works and grease 8,137.0 8,137.0 04:30 05:00 the crown. 5/11/2018 5/11/2018 0.50 COMPZN WELLPR TRIP P RIH from 8137'MD to 9550'MD. 8,137.0 9,550.0 05:00 05:30 5/11/2018 5/11/2018 1.25 COMPZN WELLPR WASH P Start rotating at 60 RPM=1K ft-lbs 9,550.0 9,750.0 05:30 06:45 torque,3 BPM=580 psi and wash down from 9550'to 9750'RKB. 5/11/2018 5/11/2018 0.75 COMPZN WELLPR WASH P Stop rotation and continue to wash 9,750.0 10,200.0 06:45 07:30 down from 9750'to 10200'RKB at 3 BPM=580 psi. 5/11/2018 5/11/2018 1.50 COMPZN WELLPR CIRC P Circulate bottoms up at 4 BPM=1000 10,200.0 10,200.0 07:30 09:00 psi. At bottoms up had gas at surface. Continue to circulate the well clean. 5/11/2018 5/11/2018 0.25 COMPZN WELLPR OWFF P Observe the well for flow and the well 10,200.0 10,200.0 09:00 09:15 is static. 5/11/2018 5/11/2018 3.00 COMPZN WELLPR PULD P Lay down 1 joint of 4"DP and blow 10,200.0 7,572.0 09:15 12:15 down the top drive. POOH with BHA #6-cleanout assembly laying 4"DP from 9742'to 7572'RKB 5/11/2018 5/11/2018 0.25 COMPZN WELLPR RURD P MU crossovers to from 3-1/2"PH-6 to 7,572.0 7,572.0 12:15 12:30 4"HT-38 for 4"TIW. Change elvators to 3-1/2". 5/11/2018 5/11/2018 3.50 COMPZN WELLPR PULD P POOH with BHA#6-cleanout 7,572.0 3,706.0 12:30 16:00 assembly laying down 4"DP and PH-6 workstring from 9742'to 3706'RKB. 5/11/2018 5/11/2018 1.00 COMPZN WELLPR RGRP T Repair the skate counter balance. 3,706.0 3,706.0 16:00 17:00 5/11/2018 5/11/2018 3.50 COMPZN WELLPR PULD P Continue to POOH with BHA#6- 3,706.0 351.0 17:00 20:30 cleanout assembly laying down PH-6 workstring from 3706'to 351'RKB. 5/11/2018 5/11/2018 0.25 COMPZN WELLPR OWFF P Monitor well.Static.Change out 351.0 351.0 20:30 20:45 handling equipment. 5/11/2018 5/11/2018 1.50 COMPZN WELLPR BHAH P Continue to POOH laying down BHA 351.0 0.0 20:45 22:15 #6. 5/11/2018 5/11/2018 0.50 COMPZN WELLPR RURD P Make up wearring running tool. Pull 0.0 0.0 22:15 22:45 wearring. 5/11/2018 5/12/2018 1.25 COMPZN WELLPR BHAH P Clean boot baskets.Clean and clear 0.0 0.0 22:45 00:00 rig floor of Baker tools. 5/12/2018 5/12/2018 0.75 COMPZN WELLPR WWWH P Make up stack washer. Flush BOPE. 0.0 0.0 00:00 00:45 5/12/2018 5/12/2018 0.50 COMPZN RPCOMP RURD P Rig up to run 3 1/2"9.3# L-80 EUE 0.0 0.0 00:45 01:15 8rd Mod completion. Page 8/10 Report Printed: 5/16/2018 • Operations Summary (with TimeR Depths)t 1L-23 ConocoPhillips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/12/2018 5/12/2018 14.25 COMPZN RPCOMP PUTB P PU and MU WLEG,wedge assembly, 0.0 9,780.0 01:15 15:30 nipple assembly and PBR/packer assembly(Baker Lok all connections). RIH with completion per tally on 3- 1/2",9.3#, L-80,EUE 8rd Mod tuibng to 9780'RKB. PU-108K SO=73K 5/12/2018 5/12/2018 0.25 COMPZN RPCOMP RURD P Send 3-1/2"thread protectors off the 9,780.0 9,780.0 15:30 15:45 rig floor. Mobilize the tubing hanger to the rig floor. 5/12/2018 5/12/2018 0.75 COMPZN RPCOMP ELOG P PJSM. RU Pollard E-line. 9,780.0 9,780.0 15:45 16:30 5/12/2018 5/12/2018 2.25 COMPZN RPCOMP FLOG P RIH with E-line for depth correlation. 9,780.0 9,780.0 16:30 18:45 Log from 9875'WLM to 9470'WLM. 5/12/2018 5/12/2018 0.75 COMPZN RPCOMP ELOG P Rig down E-line. Pick up joint#305. 9,780.0 9,805.0 18:45 19:30 RIH 25' to 9805'MD.(Top of Tandem Wedge at 9793'MD original KB.).Rig up E-line. 5/12/2018 5/12/2018 3.00 COMPZN RPCOMP FLOG P RIH with3 1/2"Standard WRP on E- 9,805.0 9,805.0 19:30 22:30 line and set in middle of full joint below packer at 9660'WLM.POOH and rig down E-line. 5/12/2018 5/12/2018 0.50 COMPZN RPCOMP RURD P Make up X-O's and make up top drive 9,805.0 9,805.0 22:30 23:00 to tubing. 5/12/2018 5/12/2018 0.75 COMPZN RPCOMP PACK P Pressure up tubing to 2000 psi. 9,805.0 9,805.0 23:00 23:45 Packer set at 1900 psi.Set 15K down weight to verify packer set.Pressure up to 2500 psi and hold for 5 mins. Bleed down top 1800 psi.Pick up and shear PBR at 125K. 5/12/2018 5/13/2018 0.25 COMPZN RPCOMP PRTS P Test IA to 1000 psi/10 mins. Bleed off 9,805.0 9,620.0 23:45 00:00 and pull seals clear of PBR. 5/13/2018 5/13/2018 2.75 COMPZN RPCOMP CRIH P PJSM. Pump 30 bbl hi-vis sweep at 4 9,620.0 9,620.0 00:00 02:45 BPM=250 psi,chase 290 bbls corrosion inhibited seawater at 4 BPM =60 psi followed by 119 seawater at 4 BPM=300 psi. 5/13/2018 5/13/2018 0.50 COMPZN RPCOMP OWFF P Monitor the well for 30 minutes. 9,620.0 9,620.0 02:45 03:15 5/13/2018 5/13/2018 1.00 COMPZN RPCOMP HOSO P Lay down 3 joints. MU 8.16'&6.36' 9,620.0 9,620.0 03:15 04:15 pups joints. MU joint#303. MU the tubing hanger and landing joint. 5/13/2018 5/13/2018 0.50 COMPZN RPCOMP THGR P Land the tubing hanger and RILDS. 9,620.0 0.0 04:15 04:45 SimOps: RU testing equipment. 5/13/2018 5/13/2018 1.00 COMPZN RPCOMP PRTS P PT the tubing to 3000 psi for 5 0.0 0.0 04:45 05:45 minutes,bleed the tubing to 1500 psi and PT the IA to 2500 psi for 30 minutes. Shear the SOV. 5/13/2018 5/13/2018 0.25 COMPZN RPCOMP CIRC P Circulate 1 bbl each way to confirm 0.0 0.0 05:45 06:00 clear circulating path through the SOV. 5/13/2018 5/13/2018 0.25 COMPZN RPCOMP RURD P RD testing equipment and lay down 0.0 0.0 06:00 06:15 the landing joint. 5/13/2018 5/13/2018 0.50 COMPZN WHDBOP MPSP P Install the 3"ISA BPV with dry rod. 0.0 0.0 06:15 06:45 5/13/2018 5/13/2018 1.00 COMPZN WHDBOP OTHR P Clean handling equipment and 0.0 0.0 06:45 07:45 crossover. Send handling equipment and crossovers off the rig floor. Page 9/10 Report Printed: 5/16/2018 Ilk ;'' r '. p, perations Summary (with Timeioepths) r. 1L-23 ConocoPhitlips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/13/2018 5/13/2018 2.25 COMPZN WHDBOP WWWH P MU the stack jetting tool and jet the 0.0 0.0 07:45 10:00 stack with fresh water. Flush the kill line,choke line,injection line,cement line and choke manifold with fresh water. Lay down the stack jetting tool. Blow down the top drive,injection line and cement line. 5/13/2018 5/13/2018 0.75 COMPZN WHDBOP OTHR P Suck out the BOP stack. Blow down 0.0 0.0 10:00 10:45 the,kill line,choke line,hole fill and choke manifold. 5/13/2018 5/13/2018 2.75 COMPZN WHDBOP NUND P PJSM. Pull the riser and mouse 0.0 0.0 10:45 13:30 holes. ND the BOP stack,set back on the stump and secure for transport. 5/13/2018 5/13/2018 0.75 COMPZN WHDBOP NUND P Bring the tree into the cellar. NU the 0.0 0.0 13:30 14:15 tubing head adapter. 5/13/2018 5/13/2018 0.50 COMPZN WHDBOP PRTS P PT the tubing hanger void to 5000 psi 0.0 0.0 14:15 14:45 15 minutes(good test) 5/13/2018 5/13/2018 0.75 COMPZN WHDBOP NUND P NU the tree. 0.0 0.0 14:45 15:30 SimOps: RU testing equipment. 5/13/2018 5/13/2018 0.25 COMPZN WHDBOP MPSP P Pull the 3"ISA BPV and install the tree 0.0 0.0 15:30 15:45 test plug with dry rod. 5/13/2018 5/13/2018 1.25 COMPZN WHDBOP PRTS P Fill the tree with diesel. PT the tree to 0.0 0.0 15:45 17:00 250/5000 psi(good test). 5/13/2018 5/13/2018 0.25 COMPZN WHDBOP MPSP P Pull tree test plug. 0.0 0.0 17:00 17:15 5/13/2018 5/13/2018 1.25 COMPZN WHDBOP FRZP P Rig up circ lines for pumping freeze 0.0 0.0 17:15 18:30 protect diesel. 5/13/2018 5/13/2018 1.25 COMPZN WHDBOP FRZP P Test lines to 3000 psi.Pump 80 bbls 0.0 0.0 18:30 19:45 down IA taking returns up tubing.2 bpm,500 psi. 5/13/2018 5/13/2018 1.00 COMPZN WHDBOP FRZP P Line up and u-tube diesel from IA to 0.0 0.0 19:45 20:45 tubing. 5/13/2018 5/13/2018 1.25 DEMOB MOVE RURD P Blow down lines.Dress and secure 0.0 0.0 20:45 22:00 the tree. Clean and clear the cellar. Release Doyon 14 at 22:00 hours. Page 10/10 Report Printed: 5/16/2018 • • a) 1 _c _ CNIox ` a t� M v E N > t C. O /� e� h0 73 D (6 S"� V) O E O C U N 4 E > ' i orP � V d O. C C cu � � O ) N a c c L i--/ Q 0 U E a p Q� w 03 CO CO CO CO 03 CO co a) E [� U' r !- ©o co co yr L a) U L J .0 . . . . . . E - o vi IC o R co. 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(t Q s H a a Q Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are av, ailable in the original file and viewable by direct inspection. /~/~"~)1~;¢2~ File Number of Well History File ' PAGES TO DELETE Complete RESCAN n Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED · [] ' Logs-of vadous kinds [] Other COMMENTS: Scanned by: Beverly Diann~ Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: Is~ STATE OF ALASKA ' • ALASKA. AND GAS CONSERVATION COMMISS• REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well r Plug Frrrforations r Stimulate r Other rc install Patch Alter Casing f Pull Tubing E Perforate New Pool r Waiver r Time Extension f` Change Approved Program E Operat. Shutdow n r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p Exploratory r - 191 -062 3. Address: Stratigraphic "" Service 6. API Number: 00 P. O. Box 100360, Anchorage, Alaska 99510 f 50- 029 - 22167 -00 " 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25664 + . 1 L -23 9. Field /Pool(s): _ Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 10346 feet Plugs (measured) None true vertical 6291 feet Junk (measured) 10060' Effective Depth measured 10226 feet Packer (measured) 8660, 8691, 9652 true vertical 6225 feet (true vertucal) 5397, 5413, 5916 Casing Length Size MD TVD Burst Collapse CONDUCTOR 82' 16 122 122 SURFACE 5263 9.625" 5306 3609 PRODUCTION 10300 7 10335 6285 RECEIVED SEP 2 0 2O1 Perforation depth: Measured depth: 9794'- 9874', 10012' - 10050', 10156' - 10165' True Vertical Depth: 5992'- 6035', 6111'- 6131', 6188' -6193' Alaska Oid & Gas Cans. Commission Ancnoraga Tubing (size, grade, MD, and TVD) 3.5, J -55, 9701 MD, 5942 TVD Packers & SSSV (type, MD, and TVD) PACKER - WEATHERFORD ER PACKER @ 8660 MD and 5397 TVD PACKER - WEATHERFORD PB PACKER @ 8691 MD and 5413 TVD PACKER - BAKER HB RETRIEVABLE PACKER @ 9652 MD and 5916 TVD SSSV - CAMCO TRDP -4A SSSV @ 1978 MD and 1833 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation 139 510 366 -- 206 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory 1'" Development J - Service r Stratigraphic E 15. Well Status after work: ,Oil � Gas f' WDSPL r Daily Report of Well Operations XXX GSTOR I WINJ r WAG f GINJ I°"" SUSP E SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact John Peirce ( 265 -6471 Printed Name John Peirce Title Wells Engineer Signature Phone: 265 -6471 Date III /� Form 10 04 R r 1 / .... Revised (/2010 RBDMS SEP 2 0 20 - > ubm i t Or Only W f/ 1L-23 Well Work Summary DATE , SUMMARY 5/11/11 PULL 2.75" CA -2 PLUG @ 9668' RI1103RUSH & FLUSH PATCH INTERVAL f/ '- 8700' SLM, TAG © 10,217' SLM. OBTAINED SAMPLE. READY FOR E -LINE. 5/19/11 SET WEATHERFORD ER PACKER MID-ELEMENT AT 8694' CCL STOP DEPTH WAS 8679.2'. THE CCL TO MID - ELEMENT LENGTH WAS 14.8'. 8/27/11 GAUGE 2.79" TO 8658' SLM, RAN 3 1/2 ER TEST TOOL TO 8659' SLM, GOOD 2500 PSI TEST ON ER PKR. SET 32' WEATHERFORD UPPER ER PATCH ON DPU SETTING TOQLe 8659' SLM, IN PROGRESS. 8/28/11 PASSING MITIA TO 2500 PSI, SET AVA CATCHER SUB @ 8632' SLM, PULLED STAs 1,3,5,6 © 2058', 4938', 6717' & 7707' RKB, IN PROGRESS. 8/29/11 SET OV @ 7707' RKB, SET GLVS @ 6717' RKB, 4938' RKB & 2058' RKB, PULLED AVA CATCHER @ 8632' SLM, COMPLETE. e KUP 1 L -23 w Conoc i Well Attributes Max Angle & MD TD b W Field Name Well Status Inc( ( °) MD KB) Act Btm B) 500292216700 KUPARUK RIVER UNIT PROD 62 82 I (ft (ftK 3,100.00 10.346. Comment H2S (ppn) Date ' i Annotation End Data KB-Grd (ft) Rig Release Date "' SSSV: TRDP 110 7/10/2009 ! WO: 8/24/1992 42.99 5/14/1991 1 ISn19 ,a3 A.. 21,,5/4121:11?4` 34'.1796..,... „�. ,....kt1M€05_,A41401, _...�._ _.._:...,.. notation Depth (ftKB) End Date Annotation Last Mod. End Date Last Tag' SLM 1 0,21 7 0 5/11/2011 / Rev Reason SET PATCH, GLV C/O ninam l 9/5/2011 Casin. Strin.s Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.060 39.0 78.0 78.0 62.58 H - 40 WELDED C i n _ ' -- - mmg Description iString 0... String ID ... Top (ftKB) Set Depth (f... Sat Depth (TVD) String Wt... Siring ... String Top Thrd HANGER, 39 2, ea" SURFACE I 9 5/8 8.921 43 0 5,306 3 3,609.3 36.00 J - 55 BTC Casing Description [/ String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) String Wt... String ... String Top Thrd PRODUCTION 7 6276 35 3 10 6785 26 00 J 55 BTC MOD TUBING Descnpnon String 2 String 2 - 992 I Tup 39.4 $e De (TVD) �TVD) String Wt... String - EUESrdABMOD ,Tubing Strings CONDUCTOR, 39-76 Completion Details It Top Depth (TVD) Top Intl Nomi... SAFETY VLV, _ Top (ftKB) (ftKB) (°) Item Description Comment -- _ID(in) 1,978 39.4 39.4 -0.02 HANGER FMC GEN IV TUBING HANGER 3.500 [[ 1,978.2 1,833.4 41.23 SAFETY VLV CAMCO TRDP-4A-R0 SAFETY VALVE 2.812 9,638.0 5,908.5 58.05 PBR BAKER PBR 3.000 GAS LIFT,_ 9,651.7 5,915.7 57.98 PACKER BAKER HB RETRIEVABLE PACKER 2.890 2,058 9,668.0 5,924.4 57.90 NIPPLE CAMCO D NIPPLE SEAL BORE NO GO (Trouble getting 20' Pert Guns 2.750 thin D- nipple 9/1/92; REPERF 9/2/92) GAS LIFT, 9,700.9 5,941.8 57.73 SOS BAKER SHEAR OUT SUB 2.992 3,780 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) GAS LIFT, Top Depth 4938 (TVD) Top Inc! Top (ftKB) (ftKB) (°) Descrpton Comment Run Date ID (in) 8,660 5,396.8 58.39 PACKER WEATHERFORD ER PACKER 8/27/2011 1.800 i] I i 8,662 5,398.0 58.39 PATCH SPACER PIPE, SNAP LATCH SEAL ASSEMBLY 8/27/2011 1.994 8,691 5,413.1 58.38 PACKER WEATHERFORD PB PACKER 5/19/2011 1.800 10,060 6,136.0 57.61 FISH 1 1/2" GLV Empty Pocket; Fell to Rathole 4/6/1995 0.000 SURFACE, 43 -5,306 Perforations & Slots Shot Top (180) Btm (TVD) Dans GAS LIFT, 11410 Two _(ftKB) aim (MKS) (f!KB) (f Zone Date (sh... TA. Commend _. 8 .915 - -- ! 9,794 9,874 5,991.9 6,035.2 C-4, 1L -23 8/17/1991 6.0 APERF 21/8" Flow Jet 0 deg. phasing 9,796 9,874 5,992.9 6,035.2 C-4, UNIT B, 9/2/1992 4.0 RPERF 2.5" Hollow Came; 180 deg. ph; GAS LIFT, ___ - - 1L-23 Oriented 14 deg. CCW 6'717 y '` 10,012 10,050 6,110.5 6,130.6 A -5, 1L -23 6/19/1991 4.0 IPERF 4 1/2" Carrier, 180 deg. ph; Oriented 12 deg_ CCW GAS LFT, 10,156 10,165 6,187.7 6,192.6 A-4, 1L -23 6/19/1991 4.0 IPERF 4 1/2" Carrier; 180 deg. ph; Oriented 7. 12 deg. CCW Notes: General & Safety 1,/ PACKER, 8,660 'A -- y- End Date Annotation ,• 10/5/2010 NOTE View Schematic w/ Alaska Schematic9.0 GASLIFT, 1 8,671 . PATCH, 8,662 -_- I � PACKER, 8,891 _. GAS LIFT, 9,588 PER, 9,638- - - ' - ' - ' { _ ..J _' PACKER, 9,652 m� NIPPLE, 9,668 - -- SOS, 9,701 APERF, 9,794 -9.874 RPERF, 9,796 -9,874 .. llAandrel Deta77 ,. - Top Depth Top Port IP ERF _ ._ -- (TVD) Inc! OD Valve Latch S TRO Run 10,012 - 1 0.050 Stn Top (ftKB) OWES) (°) Make Model (in) Snev TYpe TYPO (in) (Psi) Run Date Cam... 1 2,057.6 1,892.0 43.04 McMu... FMHO 1 GAS LIFT GLV BK 0.125 1,316.0 8/29/2011 2 3,779.8 2,805.1 60.79 McMu... FMHO 1 GAS LIFT DMY BK2 0,000 0.0 12/14/1992 FISH, 10,060 3 4,938.3 3,406.4 56.87 McMu... FMHO 1 GAS LIFT GLV BK 0.156 1,321.0 8/29/2011 4 5,815.0 3,900.4 56.27 McMu... FMHO 1 GAS LIFT DMY BK2 0.000 0.0 9/19/2005 IPERF, 10,156 5 5 6,716.5 4,397.2 58.81 McMu... FMHO 1 GAS LIFT GLV BK 0.188 1,339.0 8/29/2011 - 6 7,707.3 4,905.5 59.35 McMu... FMHO 1 GAS LIFT OV BK 0.188 0.0 8/29/2011 7 8,671.2 5,402.6 58.39 McMu... FMHO 1 GAS LIFT DMY BK2 0.000 0.0 8/8/2005 8 9,588.3 5,881.9 58.02 CAMCO MMG -2 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/22/2010 PRODUCTION, 35-10,335 TD, 10,348 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 20, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Settting: 1L-23 Run Date: 5/19/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1L -23 Digital Data in LAS format, Digital Log Image file cl )'"() 1 CD Rom 50- 029 - 22167 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood ; „f ,;:1Yi .L -J 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: 3 4----) 1 t Signed: 1 1 1- & • • Conoco Phillips Alaska P.O. BOX 100360 RECEIVED ANCHORAGE, ALASKA 99510 -0360 SEP 07 2011 Woke o & G caw Commission August 31, 2011 Angn r Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 AANNED SEP €t t 2,01 Dear Mr. Seamount, Enclosed please find the 10 -404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well 1L-23 (PTD 191 -062). The report is for a tubing patch set above the top packer. Please call Kelly Lyons or myself at 659 -7224 or M J Loveland / Martin Walters at 659- 7043 if you have any questions. Sincerely, Brent Rogers Problem Well Supervisor Attachments • STATE OF ALASKA ALASKA. AND GAS CONSERVATION COMMIS. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon fl Repair well IV Rug Perforations f Stimulate r Other r Alter Casing r Pull Tubing "" Ferforate New Pool r Waiver r Time Extension r Change Approved Program ]-' Operat. Shutdown E l rf orate r Re -enter Suspended Well 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r .. 191 - 062 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service • 50 029 - 22167 - 00 ■ Q 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25664 ALK473 ., 1 L - 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 10346 feet Plugs (measured) None true vertical 6291 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 8694, 9638, 9652 true vertical 0 feet (true vertucal) 5415, 5908, 5916 Casing Length Size MD TVD Burst Collapse CONDUCTOR 39 16 78 78 SURFACE 5263 12 5306 3609 PRODUCTION 10300 7 10335 6285 RECEIVED ED SEP 0 7 2011 Perforation depth: Measured depth: 9794 -9874, 9796 -9874, 10012 - 10050, 10156 -10165 Mike Oil & GU CO. 6vmmission True Vertical Depth: 5992 -6035, 5993 -6035, 6111 -6131, 6188 -6193 Antenatal?. Tubing (size, grade, MD, and TVD) 3.5, J -55, 9702 MD, 5942 TVD 32' 3.5" Weatherford retrievable patch 8662' -8694' Packers & SSSV (type, MD, and TVD) PBR - BAKER PBR @ 9638 MD and 5908 ND PACKER - BAKER HB RETRIEVABLE PACKER @ 9652 MD and 5916 ND 11. Stimulation or cement squeeze sump N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development J Service r Stratigraphic r 15. Well Status after work: . Oil iv Gas r WDSPL r Daily Report of Well Operations X GSTOR r WIND r WAG `" GINJ r SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Brent Rogers /Kelly Lyons Printed Name Brent Rogers Title Problem Well Supervisor Signature / 46-- Phone: 659 - 7224 Date: 08/31/11 Form 10 -404 Revised 10/2010 RBDMS SEP 07 201" , 1 , :' r74: 7 rl Submit Original Only 1L-23 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 05/19/11 SET WEATHERFORD ER PACKER MID - ELEMENT AT 8694'. CCL STOP DEPTH WAS 8679.2'. THE CCL TO MID - ELEMENT LENGTH WAS 14.8'. 08/27/11 GAUGE 2.79" TO 8658' SLM, RAN 3 1/2 ER TEST TOOL TO 8659' SLM, GOOD 2500 PSI TEST ON ER PKR, SET 32' WEATHERFORD UPPER ER PATCH ON DPU SETTING TOOL @ 8659' SLM, IN PROGRESS. 08/28/11 PASSING MITIA TO 2500 PSI, SET AVA CATCHER SUB @ 8632' SLM, PULLED STAs 1,3,5,6 @ 2058', 4938', 6717' & 7707' RKB, IN PROGRESS. PERFORM MITIA, T /I /0= 1300/2525/710, AFTER 15 MIN. T /I /O= 1300/2525/720, 30 MIN., SAME, PASS Summary 132' Weatherford retrievable patch set. MITIA passed following the patch set. KUP 1L -23 Conoco OIIOCoP illipps e° t lilell Attributes ax Angle & MD TD Welibore API /UWI Field Name Well Status Inc! (°) MD (RKB) Act Btm (MB) ra,,ylips 500292216700 KUPARUK RIVER UNIT PROD 62.82 3,100.00 10,346.0 " Comment H2S (ppm) Date Annotation End Date KB (R) Rig Release Date '° - - - SSSV: TRDP 110 7/10/2009 Last WO: 8/24/1992 42.99 5/14/1991 Well Confia. - 1L-23 95/2011 4'.57'.42 PM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 10,217.0 5/11/2011 Rev Reason: SET PATCH, GLV C/O ninam 9/5/2011 Casing Strings Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.060 39.0 78.0 78.0 62.58 H WELDED Casing Description String 0... String ID ... Top (f1KB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER, 39 MI 9 .: SURFACE 9 5/8 8.921 43.0 5,306.3 3,609.3 36.00 J - 55 BTC / 1 Casing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd II PRODUCTION 7 6.276 35.3 10,334.9 6,285.3 26.00 J -55 BTC -MOD Ilir Tubing Strings Tubing Description 'String 0... String ID ... Top ) Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR, TUBING I Str (RKB 31/2 2.992 I 39.4 I Set 9,701.8 I 5,942.3 I 9.30 J -55 EUE8rdABMOD 3g7B Completion Details L S Top Depth (TVD) Top Intl Nomi... SAFETY VLV, Top (MB) (RKB) ( °) Item Description Comment ID (in) 1,978 1 '''. , 39.4 39.4 -0.02 HANGER FMC GEN IV TUBING HANGER 3.500 1,978.2 1,833.4 41.23 SAFETY VLV CAMCO TRDP-4A-RO SAFETY VALVE 2.812 9,638.0 5,908.5 58.05 PBR BAKER PBR 3.000 GAS LIFT, 9,651.7 5,915.7 57.98 PACKER BAKER HB RETRIEVABLE PACKER 2.890 2 9,668.0 5,924.4 57.90 NIPPLE CAMCO D NIPPLE SEAL BORE NO GO (Trouble getting 20' Peri Guns 2.750 thru D- nipple 9/1/92; REPERF 9/2/92) GAS LIFT, 9,700.9 5,941.8 57.73 SOS BAKER SHEAR OUT SUB 1 2.992 3,780 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) GAS LIFT, Top Depth 4,938 Top De) Top Inc/ Top (RKB) (R KB ) ( °) Description Comment Run Date ID (In) 8,660 5,396.8 58.39 PACKER WEATHERFORD ER PACKER 8/27 /2011 1.800 8,662 5,398.0 58.39 PATCH SPACER PIPE, SNAP LATCH SEAL ASSEMBLY 8/27/2011 1.994 8,691 5,413.1 58.38 PACKER WEATHERFORD PB PACKER 5/19/2011 1.800 1 10,060 6,136.0 57.61 FISH 1 1/2" GLV Empty Pocket; Fell to Rathole 4/6/1995 0.000 SURFACE, / 43.5,306 Perforations & Slots Shot \ To (TVD Btm (TVD) Dens GAS LIFT, Top (ftKB) Btm (81(8) ( R KB) (rtK Zone D ate (sb... Type Comment 5,815 9, 794 9,874 5,991.9 6,035.2 C-4, 1L -23 8/17/1991 6.0 APERF 21/8" Flow Jet; 0 deg. phasing 9,796 9,874 5,992.9 6,035.2 C-4, UNIT B, 9/2/1992 4.0 RPERF 2.5" Hollow Carrie; 180 deg. ph; GAS LIFT, j 1L -23 Oriented l4 deg. CCW 8,717 i 10,012 10,050 6,110.5 6,130.6 A-5, 1L -23 6/19/1991 4.0 IPERF 41/2" Cartier, 180 deg. ph; Oriented 12 deg. CCW GAB 7L,70IFT, 7 10,156 10,165 6,187.7 6,192.6 A -4, 1L -23 6/19/1991 4.0 IPERF 4 1/2" Carrier; 180 deg. ph; Oriented 12 deg. CCW A 4 Notes: General & Safety PACKER, 8,650 End Date Annotation 10/5/2010 NOTE: View Schematic w/ Alaska Schematic9.0 GAS LIFT, 8,671 1C C PATCH, 8,662 _ PACKER, 8,691 GAS LIFT, 9,588 Il 1 PBR, 9,638 1 PACKER, 9,652 LLL NIPPLE, 9,668 ill SOS, 9,701 APERF, 9,7949,874 RPERF, 9,7965,874 4 Mandrel Details Top Depth Top Port IPERF, (TVD) Inc! OD Valve Latch Size TRO Run 10,012 - 10.050 II III Stn Top(ftKB) (RKB) ( °) Make Model (in) 5819 Type Typo (in) (psi) Run Date Com... 1 2,057.6 1,892.0 43.04 McMu... FMHO 1 GAS LIFT GLV BK 0.125 1,316.0 8/29/2011 2 3,779.8 2,805.1 60.79 McMu... FMHO 1 GAS LIFT DMY BK2 0.000 0.0 12/14/1992 FISH, 10,060 3 4,938.3 3,406.4 56.87 McMu... FMHO 1 GAS LIFT GLV BK 0.156 1,321.0 8/29/2011 4 5,815.0 3,900.4 56.27 McMu... FMHO 1 GAS LIFT DMY BK2 0.000 0.0 9/19/2005 IPERF, 10,15810,165 IN III 5 6,716.5 4,397.2 58.81 McMu... FMHO 1 GAS LIFT GLV BK 0.188 1,339.0 8/29/2011 6 7,707.3 4,905.5 59.35 McMu... FMHO 1 GAS LIFT OV BK 0.188 0.0 8/29/2011 7 8,671.2 5,402.6 58.39 McMu... FMHO 1 GAS LIFT DMY BK2 0.000 0.0 8/8/2005 8 9,588.3 5,881.9 58.02 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/22/2010 PRODUCTION, 35- 10,335\ + • 0D, 10,348 • ConocoPhllips P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360---- - - February 1, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Dan Seamount: • DECEIVED ~1AR 0 5 2010 Alaska 8+1 & Cas Cans. Commission Anchorage l~::d' ...ss~i' 1~f~~~~~ Enclosed please fmd a spreadsheet with a list of wells from the Kuparuk field (KRLI). 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 December 5th, 2009. The corrosion inhibitor/sealant was pumped December 22°d, 25th, 26th & 28th, 2009. 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, Kle~i ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 3/1/2010 1 G. 1 L 8~ 1 R Pad Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1G-17 50029229450000 1990620 SF n/a 17" Na 7.65 12/26/2009 1L-01 50029211960000 1841730 52' 7.7 31" 12/5/2009 10.15 12/22/2009 1 L-02 50029211930000 1841700 45' 5.7 35" 12/5/2009 10.15 12/22/2009 1 L-04 50029211790000 1841540 40' 3.9 24" 12/5/2009 5.8 12/22/2009 1 L-06 50029211640000 1841330 2'5" n/a 2'5" - n/a 7.22 12/26/2009 1 L-08 50029211750000 1841500 34' 3.7 40" 12/5/2009 10.2 12/26/2009 1L-09 50029220250000 1900340 11" n/a 11" n/a 1.27 12/26/2009 1 L-11 50029220340000 1900450 16" n/a 17" n/a 2.25 12/25/2009 1 L-12 50029220330000 1900440 7" n/a 15" n/a 3.4 12/25/2009 1 L-13 50029221500000 1910420 13' 2.2 27" 12/5/2009 5.52 12/26/2009 1 L-17 50029221510000 1910430 26' 4.0 18" 12/5/2009 9.35 12/26/2009 1 L-19 50029220490000 1900610 9' 2.5 19" 12/5/2009 4.25 12/25/2009 1 L=23 50029221670000 1910620 SF Na 17" Na 2.12 12/26/2009 1 L-26A 50029221730100 2000150 SF n/a 17" Na 2.97 12/25/2009 1 R-14 50029213860000 1851510 SF n/a 29" Na 5.95 12/28/2009 1 R-31 50029225380000 1941680 6" n/a 24" Na 7.22 12/28/2009 1 R-32 50029225230000 1941460 SF n/a 24" n/a 5.95 12/28/2009 1 R-33 50029225290000 1941560 SF n/a 24" n/a 4.67 12/28/2009 • • Page 1 of 1 Regg, James B (DOA) ~~ [~(-G62a From: NSK Problem Well Supv [n1617@conocophillips.com] , Sent: Thursday, November 12, 2009 9:51 AM ~~'T ~(~Z°t ~ C~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: CPF1 Prod Engr; CPF1 DS Lead Techs; NSK Problem Well Supv; NSK Well Integrity Proj; Glessner, Dana Subject: 1 L-23 (PTD# 191-062) Report Of TxIA Communication Attachments: 1 L-23 Wellbore Schematic.pdf; 1 L-23 TIO Plot.pdf Jim/Tom/Guy, Kuparuk gaslifted producer 1 L-23 (PTD# 191-062) is suspected of having TxIA communication based upon a failed shut in TIFL on 11/09/09. The well has been shut in since 03/02/08 and wi remai- n 'until the TxIA communication can be repaired. CPAI will add 1 L-23 to the SCP Report. Attached area 90 day TIO plot and wellbore schematic. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999~f~h ~~~~~ f~ U ~(j; Pager 907-659-7000 #909 11/27/2009 Well Name 1 L-23 Notes: End Date 12/1/2009 Days 120 Start Date 8/3/2009 Annular Communication Surveillance 1800 --__.___..___--.--._--_-___....___.__ ___-_. M_ ~.____T,~.~_.___~_._-___..---__---_-____ ~o WHP _ IAP 1600 OAP W HT 60 1400 50 1200 1000 -____ 40 LL .y ~ ~ Q. 800 - - - '~ 30 600 - 20 400 10 200 - 0 0 Aug-09 Sep-09 Oct-09 Nov-09 1 ~DGI os o 9 'MGI . o ~PWI ~ 0 .~ ° ~ . m SWI o ° ~ O ~BLPD . ~ ° 3 . 0.2 0.1 0 • ~" ~__ ~~~ KUP ~ 1L-23 ~ ~~ ( ~Ot't000PI IF~EI S `Nell Attributes -- -- - - x Angle & MD I a TD p I ~ Wellbore APl(UWI _ __ Fieltl Name Well Status Intl P) MD IftKB) Act Btm (RKB) " I / 500292216700 KUPARUK RIVER UNIT PROD 62.82 3,100.00 10,346.0 ' Comment H2S (ppm) Date Annotation End Deta KB-0rd (ft) Rig Release Date _. ~ "' - 9/5/0~ 12.4202 FM ~ Well C r 1L-23 SSSV: TRDP 95 6/18/2006 Last W0: 8/24/1992 42.99 5/14/1991 ~ __ - y.....~_ _ ~ Ac~uai _. A rt-rt'-. Depth (ttKB) End Date Annotation Last MOd By Entl Date Last ~ ELM 10,214.0 4/17/2009 _. Rev Reason: ADJUST PA_T_CH DATE _ - ___ Imosbor 9/5/2.009 -.. - _ - _- _ _ _- _ C_as_in_gStnn s __ -.--. _ J ~ { String O D Strang 10 Set Depth Set Oapth (ND) String Wt Slring t 1 Casing Description Onl IiN Top (RKB) (RKB) (RKB) Obs/rt) Grade String Top Thrd coNDUCroR CONDUCTOR 1 6 15 060 0 0 78.0 78.0 62.58 H-40 B I . . = SURFACE 9 5/ 8 8.525 0.0 5,306.0 3,609.1 36.00 J-55 a ~ PRODUCTION 7 6.151 0.0 10,335.0 6,285.4 26.00 J-55 _ SAFETY VLV, 978 1 ~. a _- _ -___ ___ -. __ _ , Tubing Stnngs ~ - f _ _ _ t g OD 57 g ID j Set Deplh Set Depth (TVD) Str rag Wt ' St ing ~ [ r ~ Tub nq De cr poon g Top Thrtl (~) ~ ( ) Top (RKB) (ftK8) (RKB) (Ibs/R) '. G d { ~ ~ 5 4 9 30'J SS~EUE8rdABMOD 942 onaLIFT, - .. ;r~. TUBINO _ __. . . 312, 2992 0.0i, __ ~ _ ___._ 2'058 w ~ a _ Other In Hole All Jewel :Tubing Run ~ Retnevable, Fish, etc. _...___- _ ..._ _ -T" Top Depth ~ (ND) Top Inc! Top (RKB) (RKB) (°) Description Comment Run Date ID (in) GAS LIFT, ~ 1,978 1,833.3 41.22 S AFETY VLV Camco TRDP-4A-RO' 8!24/1992 2.813 3.7so ~ 2 058 1 892 3 43 05 G AS LIFT MCMURRY/FMHO/1/DMYBK2/.125/1300/Commeni:STA 1 1/5/2006 2.859 , , . . 3,780 2,805.2 60.79 G AS LIFT MCMURRY/FMHO/1/DMYBK2///Comment:STA2 12/14/1992 2.859 4,938 3,406.3 56.87 G AS LIFT MCMURRY/FMHO/1/GLV/BK2/.156/1315/ Comment:STA 3 1/5/2006 2.859 Gras uFT, 4,938 r L~~ 5,815 3,900.4 56.27 G AS LIFT MCMURRY/FMHOl1/DMYBK2///Comment: STA4 6/19/2005 2.859 •~ 6,717 4,397.5 58.81 G AS LIFT MCMURRY/FMHO/1/DMY/BK2///Comment: STA 5 8/8/2005 2.859 ~ 7 707 4 905 3 59 35 G AS LIFT MCMURRY/FMHO/1/OV/BK2/.188// Comment: STA 6 1/5/2006 2.859 suRFACE. , , . . s,3os 8,666 5,399.9 58.39 P ATCH PATCH ASSEMBLY (UPPER @ 8664' & LOWER ECLIPSE 11/25/2005 1.440 ~. PACKER @ 8686' OAL 24'1 ") w/K-3 PACKOFF w/SLIPSTOP ON TOP OF K-3 PACKOFF -set 11/25/2005 GAS LIFT, s,e1s ..r. 8,671 5,402.5 58.39 G AS LIFT MCMURRY/FMHO/1/DMYBK2/// Comment: STA 7 8/8/2005 2.859 ' 9,588 5,881.8 58.02 G AS LIFT CAMCO/MMG-2/1.5/DMY/RK/// Comment: STA 8 8/8/2005 2.922 9,638 5,908.5 58.05 P BR Baker PBR 824/1992 3.000 GAS uFr. 6 717 ~ ~l 9,652 5.915.9 57.98 P ACKER Baker'HB' PACKER 8/24/1992 3.500 . - 9,668 5,924.3 57.90 N IPPLE CamCO'D' Nipple NO GO"*Trouble getting 20' Perf Guns 8/24/1992 2.750 ~- thru D-Nipple (9/1/92); REPERF 9/2/92" GAS LIFT i ~,. " '-'~ 9,701 5,941.9 57.73 S OS Baker 8/24/1992 2.992 , 7,707 :-. L-.] ...a.. 9,702 5,942.4 57.72 T TL 8/24/1992 2.992 1~ ~ , 10,060 6,136.0 57.61 F ISH 1 1/2" GLV Empty Pocket; Fell to Rathole 4/6/1995 Perforations 8 Slots _ _ _ _ - Sh t' ~ ~ T P (ND) Btm (ND) 0 n r ~ ~ Top (RKB) Btm ttKB) (RKB) (RKB) ?'one Date I h Type Comment GA886FT. F e g,79q g,g7q 5,991.9 6,035.2 C -4, 1L-23 8/17/1991 6 0 APERF 2 1/8" Flow Jet; 0 deg. phasing PATCH ss6s ~ 9,796 9,874 5,992.9 6,035.2 C -0, UNIT B, 92/1992 4.0 RPERF 2.5" Hollow Carrie; 180 deg. ph; , 1 L-23 Oriented 14 deg. CCW `ti 10,012 10,050 6,110.5 6,130.6 A -5, 1L-23 6/19/1991 4.0 IPERF 4 1/2" Carrier; 180 deg. ph; Oriented (: 12 deg. CCW ~y 10,156 10,165 6,187.7 6,192.6 A -4, 1L-23 6/19/1991 4.0 IPERF 4 1/2" Carrier; 180 deg. ph; Oriented Gras uFr, ~~ 12 deg. CCW y Safi e_ . ~ -- - - --- ~ ;' ~ ---- - -- - I ' Notes: General .. & Safe __-~ -_ ~ -_- - A t, End Date nnotatOn PBR, 9,638 8/282005 NOTE: LEAK FOUND @ 8679' I t PACKER, 9,fi52 f: ~',-:'.7.='. ~ - NIPPLE, 9.668 SOS, 9.701 ~ ~ l TTL. 9.702 APERF, ~ 9,7949,874 ~ ~ ~. RPERF, _~ 9,7968.874 IPERF, _ 10,012-10,050 FISH, 10,060 IPERF, ' 10,156-10,166 PRODUCTION, 70,335 TD, 10,346 ti1y/~ 1~4~r g57,F ~i 4~fi~;I F ~ ~~. _~''r• ~.J ( / Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~, , ~ ~~.~ Well Job # Log Description NO. 4914 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 10/14/08 i L-23 12097405 SBHP SURVEY J 07/17/08 1 1 2A-17 11975793 PRODUCTION PROFILE 9 - JL p L 09/10/08 1 1 3G-25X 12080437 LDL ~ - 3 C((o 09/21/08 1 1 2C-04 12100444 INJECTION PROFILE ~ ( 09/14/08 1 1 3M-13 12096541 LDL - (~[.( ( dC( 09/10/08 1 1 2Z-13A 12100446 LDL o7b(o- I'30 '~U 09/15/08 1 1 1 F-06 12096510 PRODUCTION PROFILE 07/17/08 1 1 3C-14A 12080436 SCMT - r 5-'~ 09/22/08 1 1 1C-111 12100451 INJECTION PROFILE '•t p ~- 09/20/08 1 1 30-15 12100452 LDL 'i~(- -~ 5(~ 09/21/08 1 1 iC-117 12100453 INJECTION PROFILE a r 09/23/08 1 1 i R-11 11966277 SBHP SURVEY S- (~ 09/25/08 1 1 1 R-35 11966279 SBHP SURVEY ~ 09/25/08 1 1 1 R-14 11966286 LDL - ( 09/29/08 1 1 2X-18 12080443 PRODUCTION PROFILE 09/30/08 1 1 iR-34 12080444 _ GLS gL ~ 10/01/08 1 1 2A-13 12096547 PRODUCTION PRO ILE .= L C/ 10/02/08 1 1 iD-01 12097422 GLS 10/03/08 1 1 1 R-07 12097425 PRODUCTION PROFILE ~°~= ( 10/06/08 1 1 iH-19 12096548 INJECTION PROFILE L 10/03/08 1 1 1 B-16 12097426 GLS ~ - =' 10/07/08 1 1 36-09 12100442 PRODUCTION PROFILE 09/12/08 1 1 3K-103 12096550 USIT 10/06/08 1 1 2X-05 12096551 INJECTION PROFILE - ~~ 10/07/08 1 1 1 B-04 12096552 INJECTION PROFILE - 10/08/08 1 1 1A-02 12096553. INJECTION PROFILE ~ 10/09/08 1 1 1 B-16 12096554 PRODUCTION PROFILE q C~ .r 10/10/08 1 1 2D-15 12096555 PRODUCTION PROFILE /'~C . 10/11/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~J 1. Operations Performed: Abandon D Alter Casing D t'<eCt:IVt:1.J STATE OF ALASKA e DEC 0 t; 2005 ALASKA Oil AND GAS CONSERVATION COMMISSION Alaska Oil & G.. Cona, Commission REPORT OF SUNDRY WELL OPERATIONS Anchorage D Time Extension D Re-enter Suspended Well D e Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: Repair Well 0 Pull Tubing D Ope rat. ShutdownD Plug Perforations D Stimulate D Waiver D Other Perforate New Pool D Perforate D 4. Current Well Status: Development 0 Stratigraphic D Exploratory D D Service 6. API 50-029-22167-00 P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 130' 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: 9. Well Name and Number: 1 l-23 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool Total Depth measured 1 0346' 6291' feet feet feet feet Plugs (measured) Junk (measured) true vertical Effective Depth measured true vertical Casing Structural CONDUCTOR SUR. CASING PROD. CASING Length Size MD TVD Burst Collapse 78' 5176' 10205' 16" 9-5/8" 7" 78' 5306' 1 0335' 78' 3609' 6285' Perforation depth: Measured depth: 9794-9874, 10012-10050, 10156-10165 {jCANNEf..J DEC 1 Ô 2005 true vertical depth: 5992-6035, 6110-6130, 6188-6193 Tubing (size, grade, and measured depth) 3-1/2" , J-55, 9702' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'HB' pkr= 9652' sssv= SSSV SSSV= 1978' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casin Pressure Tubin Pressure Prior to well operation N/A Subsequent to operation N/A 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development 0 Service D Daily Report of Well Operations _X 16. Well Status after proposed work: Oil0 GasD WAGD GINJD WINJ D WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: RBDMS 8Ft DEe 062003 Contact McConnell / Loveland Marie McConnell Title Phone Problem Well Supervisor 659-7224 Date 12/3/2005 Printed Name Signature Form 10-404 Revised 04/2004 0 RIG , f~ A L Submit Original Only ., e 1 L-23 DESCRIPTION OF WORK COMPLETED SUMMARY e Date Event Summary 7/6/2005ITIFL failed 8/28/2005ILDL found tbg leak at 8679' 9/27/2005ISet retrievable Eclipse patch from 8666' to 8686' 9/29/2005IMITIA failed 10/6/2005 Pulled top eclispe patch pkr and spacer pipe. Top and bottom eclipse pkr tested good, a ears atch was leakin at the seal between the ackers. 11/6/2005IReset top portion of patch with spacer pipe and eclipse packer at 8686 RKB. MITIA failed. 11/23/2005 Pulled top eclipse pkr and spacer pipe 11/24/2005 Reset top portion of patch with spacer pipe and K3 packoff at 8661'. Patch length = 24' 1". 11/25/2005 MITIA to 2500 psi passed. MITIA data: Pre TIIIO: 950/1100/500, Pressured up IA to 2500 si. Initial TIIIO: 950/2500/500,15 min TIIIO: 950/2475/500, 30 min TIIIO 950/2475/500. Og Og- ggFO 0 NOVEMBER 2 200 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF :SUNDRY WELL OPERATIONS; 1. Operations performed: Operation Shutdown __ Pull tubing x Alter casing Stimulate __ Plugging m Perforate _ Repair well Other Replace TIW Pkr 2. Name of Operator ARCO Alaska, Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 537' FNL,143' FEL, SEC 31, T11N, R10E, UM At top of productive interval 1351' FSL, 953' FVVL, SEC 6 , T10N, R10E, UM At effective depth 1609' FNL, 798' FWL, SEC 6, T10N, R10E, UM At total depth 1694'FNL, 746' FWL, SEC 6, T10N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 1 0345' feet Plugs (measured) 6290' feet 6. Datum elevation (DF or KB) RKB 130', PAD 87' 7. Unit or Property name Kuparuk River Unit 8. Well number 1L-23 9. Permit number/approval number . 91-62 (Conserv Order No, 10. APl number .. 50-029-22167 11. Field/Pool Kuparuk River Oil Pool 261.)_ Effective depth: measured 10226' feet Junk (measured) true vertical 6225' feet Casing Length Size Cemented Structural 8 0' 1 6" 235 SX AS I Conductor Surface 52 64' 9 - 5/8" 750SX PF E Intermediate & 600 SX CLASS G, Production 10293' 7" 250 SX CLASS G Measured depth True vertical depth 122 ' 122 ' 5306' 3608' 10335' 6284' 13. Liner Perforation depth: measured 9794'-9874', 10012'-10050', 10156'-10165' MD true vertical 5991'-6034',6109'-6130', 6187'-6192' TVD Tubing (size, grade, and measured depth) 3-1/2" 9.3# J-55 @ 9702' Packers and SSSV (type and measured depth) BAKER HB RETR PKR @ 9652', CAMCO TRDP-4A-RO SSSV @ 1978' MD Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED Alaska 0il & 6as Cons, Commissio~ Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Water Injector __ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Form 10-~03~ Rev Title Area Drilling Engineer Date SUBMIT I1~ DUI~LICATE ARGO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 1L-23 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER 50-029-22167 91-62 ACCEPT: 08/19/92 SPUD: RELEASE: 08/23/92 OPERATION: WORKOVER DRLG RIG: NONE WO/C RIG: NORDIC 1 08/20/92 ( 1) TD: PB: 08/21/92 ( 2) TD: PB:z 08/22/92 ( 3) TD: ~ - PB:. BOP TEST P~W: 9.8 NaCl/Br MVE RIG F/1L-13 TO 1L-23. RIG ACCEPTED 13:30 HRS 08/19/92. SITP=1550 PSI SICP=1550 PSI W/GAS HEAD. LEVEL RIG. PULL VR PLUG & INSTALL CSG 2" FLANGE. LOAD BRINE. RU HARD LINE TO TIGER TANK. PULL BPV PT HARD LINE TO 1000 PSI-OK. BLEED OFF GAS HEAD TO FLOWLINE: TBG @ 675 PSI, CSG @ 1150 PSI. BULLHEAD 22 BBL DN TBG. CIRC SW UP ANN @ 2 BPM & 750 PSI. WATER BRINE BACK TO 10.0 PPG. CIRC 10.0 PPG BRINE DN TBG & UP ANN, TAKING RTNS THROUGH CHOKE. MONITOR WELL-25 PSI ON TBG. DISPLACE TBG W/10.3 PPG BRINE. MONITOR WELL-NO FLOW, WELL DEAD. FREEZE PROTECT FLOWLINE TO MANIFOLD BLDG W/26 BBL DIESEL. SET BPV. ND TREE. SET BLANKING PLUG. NU BOP & FLOW NIPPLE. TEST BOP: ANNULAR, PIPE & BLIND RAMS, CHOKE & KILL LINES, HCR, CHECK, LOWER KELLY, BOP & FLOOR VALVES, & CHOKE MANIFOLD TO 3000 PSI-OK. AOGCC WITNESSING WAIVED BY LOU GRIMALDI 08/19/92. POOH W/PKR MW:10.1 NaCl/Br PULL TBG HGR ABOVE ROTARY TABLE. MONITOR WELL. POH W/3-1/2" 9.3# J-55 AB-MOD IPC TBG. TALLY AS. POOH & SPOOL CLINE. (31 OF 35 CLINE BANDS RECOVERED. CHANGE EQUIP TO RIH W/3-1/2" DP. SET WEAR BUSHING. MU BHA. RIH W/3-1/2" DP. TAG PKR @ 9625'. PULL PKR UP 10' STOP TO CIRC OUT GAS. UP WT 140K#, DN WT 52K#. PULL 60~# ON PKR TO RELEASE. SHUT IN & MONITOR WELL. WORK PKR FREE F/COLLAR. PULL 100K#. pOH SLOW, PKR TENDING TO HANG UP IN CSG COLLARS. POOH F/CLEAN-OUT RUN MW:10.2 NaCl/Br CONT TO POOH SLOW W/PKR ON 3-1/2" DP-PKR TENDING TO HANG UP IN COLLARS. BREAK BHA. LD SPEAR, PKR, TAILPIPE. SET WEAR BUSHING. MU BHA #2 F/CLEANOUT RUN. CONT RIH ON 3-1/2" DP. TAG FILL @ 10166'. TAKE GAS KICK, PU & SI, CIRC OUT & WT UP TO 10.3 PPG. WASH DOWN TO 10216'. DRILL WIPER PLUG. DRILL CMT F/10216'-10230'. UP WT 160K, DN WT 54K. CIRC HOLE CLEAN @ 4 BPM, 450 BBL TOTAL. LD SAME. POOH. LD 6 JTS DP. PIPE STUCK, WORK FREE. CONT POOH. LD 110 JTS DP. EXCESSIVE DH TORQUE. RECEIVED S E P 2,5 ' 992 Alaska Oil & Gas Cons. Commission Anchorage WELL · 1L-23 OPERATION: RIG : NORDIC 1 PAGE: 2 08/23/92 ( 4) TD' PB' RIG RELEASED MW:10.2 NaC1/Br CONT POH W/3-1/2" DP. LD BHA. SAND & METAL FRAGMENTS IN JB. PULL WEAR RING. RU TO RUN 3-1/2" TBG. LOAD JEWELRY & DRIFT GLMS. RIH W/COMPLETION STRING. RU TO CIRC DUE TO WET PIPE. CIRC 3-1/2 BBL OF 10.7 PPG SLUG DN TBG @ 4 BPM. CONT TO RIH. RD CIRC EQUIP. TEST CONTROL LINE TO 5000 PSI-OK. MONITOR WHILE FIN RIH. MU FMC TBG HGR & TEST CL TO 5000 PSI-OK. RAN TBG. UP WT 82K, DN WT 32 K. LAND HGR. PRESS TBG TO 2500 PSI & SET PKR. PRESS ANN TO 1000 PSI & HOLD. BLEED OFF TBG & ANN PRESS. BOLDS. PRESS TBG TO 1300 PSI. PU & SHEAR PBR @ 125K. RELAND TBG HGR. RILDS. PRESS ANN & TBG TO 1700 PSI & TEST SSSV BY CLOSING SAME & BLEED DN TBG TO 500 PSI-OK. REPRESS TBG & OPEN SSSV. TEST ANN & TBG TO 2500 PSI-OK. PRESS TBG TO 3950 PSI & SHEAR SOS. SET BPV. ND FLOW NIPPLE & BOP STACK. NU FMC TREE. PULL BPV, SET TEST PLUG. CAP WELL W/12 BBL DIESEL @ 1200 PSI. BULLHEAD 4 BBL DIESEL DN TBG @ 2000 PSI. CK VALVE HOLDING. (TBG TAIL @ 9702'). RIG RELEASED @ 02:00 HR 08/23/92 SIGNATURE: DATE: RECEIVED S E P 2 5 1992 ~laska Oi]& Gas Cons. Oommissio~' Anchorage ARCO Alaska, Inc. Date: February 21, 1992 Transmittal #: 8369 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. one signed copy of this transmittal. Please acknowledge receipt and return 3Q-03 - LIS Tape and Listing 1 -27-92 92095 3 R- 12 D LIS Tape .and Listing 2 - 4 - 9 2 92115 THE FOLLOWING LIS TAPES ARE STAMPED WITH A CORRECTED COPY STAMP. PLEASE REPLACE THE PREVIOUS COPY THAT YOU HAVE ALREADY RECEIVED WITH THIS ONE. THANK YOU. ?/""//~ 1R-17 :~/"/~ 1R-20 ~/_//] 1R-21 ,?,,,_/o?' 1R-22 ~/.../o/ 1R-23 ~,/.-. ~, $ I R-24 ff/...~,~ I R-26 ~,/.-/~-',- I R-27 -f,/- ?¢ 1R-29 ?/.--,~/ I R-19 ?/./~¢/ 2M-21 ~/.-./]~.2 M - 1 9 f~/--~';~ 1 L-23 ~'/---~'~' 1 L-24 ~/-?* 1 L-25 ~/---~'/1 L-26 Receipt LIS Ta )e and LIS Ta )e and LIS Ta )e and LIS Ta3e and LIS Taae and LIS Ta )e and LIS Ta 3e and LIS Ta 3e and LIS Ta3e and LIS Ta3e and LIS Ta3e and LIS Ta3e and LIS Ta3e and LIS Ta3e and LIS Ta~:)e and LIS Ta 3e and Acknowledged: Listing 9- 1 9-91 92026 Listing 9 - 9 - 9 1 92026 Listing 1 0 - 6 - 91 92026 Listing 9- 24- 91 92026 Listing I 0 - 2 2 - 91 92026 Listing 7- 3 0 - 91 92026 Listing 7 - 1 8 - 91 92026 Listing 8 - 31 - 91 92026 Listing 8- 1 4-91 92026 Listing ,~ 6 - 1 9 - 91 92026 Listing~~ 11-11-91 92026 Listing 1 I - 1 7 - 91 92026 Listing 5 - 9 - 9 1 92026 Listing 5 - 1 9 - 91 92026 Listing 5 - 2 6 - 91 92026 Listing 6 - 3 - 9 1 92026 ~~ Dc '-- -- ate R-EC--E VE D FEB 2 8 1992 DISTRIBUTION: Lynn Goettinger Alaska 0il & Gas Cons. Commission Anchorage State of Alaska ARCO Alaska, Inc. Date: February 7, 1992 Transmittal #: 8355 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. and return o. ne signed copy of this transmittal. ~j~ ! ~'~,~f2M'10 Litho-Density&Casing Neutron 11-29-91 " ' Porosity Data & 12-29-91 2 M - 1 0 Litho-Density & Casing Neutron I 1 - 29 - 91 Raw Data & 12-29-91 CCN ~/ 1-12-16-92 Pleaseacknowledgereceipt 7000-7756~~ 7000-7669 7000-7756 7000-7669 4517.7-7720 I3Q.04 3Q,04 CDR ,~ 1-12-16-92 4517.7-7720 ~3Q-03 CCN ~ 1-24-27-92 5090-9640 3Q-03 ~ ~ 1-24-27-92 5090-9640 THE FOLLOWING LOGS ARE CORRECTED COPIES. IT HAS BEEN REQUE~ THAT YOU THROW OUT THE pREVIOUS (UNCORREC~ COPY OF THIS LOG. ~HANK YOU. . ..... ~ ~ 5'9~'13~91 -- · 523~1047~ 1L-26d~-~~ 6-3-6-91 · 5225-10065 2M-1 9~ ~ 1 1'17-'91 3835-9250 2M-21~ ~ 1 1-1.1-91 3914-10599 1R-17~ ~ 9-15-19-91 5698-10345 · n-~/ ~ 6-19-23-91 ' 5390-9841 1R-20J ~ 9-9-91 5568-10080 1R-21~ ~ 10-6-11-91 5070-10180 ~,~'~1 R- 22 .~ ~ 9--24-29-91 6001-10813 ~,~ I R-23 ~/ ~, ~ 10-22-91 6330-12188 1R-24~ ~ ~ 7-30/8-5-91 6753-12972 ~1R-26, . ~ 7-18-21-91 5591-10218 ~1~1R-27~ ~ / 8-31-91 6547-9250 -1 -91 1L-24 ~' ~ J 5-19-22-91 5081-9241 1L-25 ~' ~ Z 5-26-29-91 4978 9352 ~ FEB 1 Alaska 0il & Gas Cens. Cemmission Anchorage STATE OF ALASKA AI.AoKA OIL AND GAS CONSERVATION COMM,,~olON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Pull tubing Operation Shutdown__ Stimulate __ Plugging 2. Name of Operator Alter casing Repair well ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 537' FNL, 143' FEL, Sec. 31, T11N, R10E, UM Perforate ~_ Other 6. Datum elevation (DF or KB) 130' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 1 L-23 feet At top of productive interval 1351' FNL, 953' FWL, Sec. 6, T10N, At effective depth 1608' FNL, 797' FWL, Sec. 6, T10N, At total depth 1694' FNL, 746' FWL~ Sec. 6, T10N, 12. Present well condition summary Total Depth: R10E, UM R10E, UM R10Ep UM measured 1 0345' feet true vertical -6290' feet Plugs (measured) 9. Permit number/approval number 91-62 10. APl number ,50-029-22167 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 1 0226' feet Junk (measured) true vertical 6225' feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 1 22' 1 6" 235 Sx AS I 5306' 9 5/8" 750Sx TypeE& 600 Sx Class G 1 033 5' 7" 250 Sx Class G Prem. Measured depth 122' 5306' 1O335' measured 9794'-9874',1 001 2'-1 0050',1 01 56'-1 01 65' true vertical 5991 '-6034' ,61 09'-61 30',61 87'-61 92' TIW HM-I~ 9670' Tubing (size, grade, and measured depth) 3 1/2" 9.3#, J-55, 9704' Packers and SSSV (type and measured depth) SSSV: Camco TRDP-4A-SSSV, 1978', Packer: 13. Stimulation or cement squeeze summary Perforated "C" Sand @ 6 SPF on 8/17/91 Intervals treated (measured) 9794'-9874' Treatment description including volumes used and final pressure N/A True vertical depth 122' 3608' 6284' 14. .Re_oresentative Daily Average Production or In!ection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 200 1 50 - 0 - - 0 - 700 J 400 20 1000 2OO 25O 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Water Injector ~ Oil X_.. Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Form 10-'404 Rev 09/12/90 ~ SUBMIT IN DUPLICATE ARCO Alaska, Subsidiary of Atlantic Richfield Company WELL SERVICE REPORT WELL PBDT //',NTRACTOR REMARKS FIELD- DISTRICT. STATE OPERATION AT REPORT TIM I DAYS ' DATE / I ~/,~/~l,- ,3 J __ CHECK THIS BLOCK If SUMMARY CONTINUED ON BACK Weather Temp. i Chill Factor i Visibility 'Wind Vel. Report °F °F miles ARCO Alaska, Inc. Date: October 4, 1991 Transmittal #: 8249 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATe-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. Please acknowledge receipt and return one signed copy of this transmittal. 1 L-23 CDR 5-9-1 3-91 5237-1 0476 Receipt Acknowledged '~~[~ -~-'t- -~- DISTRIBUTION: D&M Drilling Franzen Vendor Package(Johnston) NSK State of Alaska(+Sepia) ARCO Alaska, Inc. Date: August 16, 1991 Transmittal #: 8203 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 1 L- 1 3 Sub-Surface Directional 4- 1 9-9 1 74766 Survey 1L-23 Sub-Surface Directional 6-3-91 74764 Survey 1 L-24 Sub-Surface Directional 6-3- 9 1 74763 Survey 1R-19 Sub-Surface Directional 7- 4-91 74767 Survey Receipt Acknowledged: D&M State of Alaska Date' RECEIVED AUG "1,,.1 1991 Alaska 011 & Gas Cons. Commission Anchorage , .~--~, STATE OF ALASKA ALA ~ OIL AND GAS CONSERVATION COMk ,dON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL ~-~ GAS ~ SUSPENDED ~ ABANDONED D SERVICE r'~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 91-62 3 Address 8 APl Number P.O. Box 100360, Anchoracje, AK 99510-0360 50-029-22167 4 Location of well at surface 9 Unit or Lease Name 537' FNL, 143' FEL, SEC 31, T11 N, R10E, UM ~E'FiON r VE~,IFE~) KUPARUK RIVER At Top Producing Interval J ~ D/~,T~/ I '! Su '~"~/1,~~ 10 Wall Number 1351' FNL, 953' FWL, SEC 6, T10N, R10E, UM 1L-23 At Total Depth · 11 Field and Pool - 1694' FNL, 746' F"WL, SEC 6, T, 0N, RI.,0E, UM ~~------------____.~I KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Sedal No. KUPARUK RIVER OIL POOL RKB 130', PAD 87' GLI ADL 25664 ALK 473 12 Date Spudded5/3/91. 13 Date T.D. Reached5/11/91. 14 Date Comp. , Susp. ~ Aband.6/20/91. 115 watar Depth' 'f OffshOreNA feet MS ~ 16 No. of COml::Wetionsl 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set 21 Thickness of permafrost 10345' MD, 6290' TVD 10226' MD, 6225' TVD YES ~ NO m~I 1978, feet MD 1500' APPROX 22 Type Electdc or Other Logs Run CDN/CDR, GR, CNL, CET, CBL, GYRO 23 CASING, LINER AND CEMENTING RECORD 4 SEI-I'ING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 122' 24" 235 SX AS 1 ....... 9-5/8" 36# J-55 SURF 5306' 12-1/4" 750 SX TYPE E~, 600 SX CLASS G 7" 26# J-55 SURF 10335' 8-1/2" 250 SX CLASS G PREM. 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET IMD1 PACKER SET (MO1 3-1/2" 9704' 9652' 10012'-10050' W/4-1/2" CSG GUN @ 4SPF MD 6109'-6130' TVD 10156'-10165' W/4-1/ff' CSG GUN @ 4SPF MD 6187-6192' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD} AMOUNT & KIND OF MATERIAL USED SEE A'I'rACHED ADDENDUM 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I ,.= Date of Test Flours Tested PROOUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD m. Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE m. 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED AU G 1 9 1991 Alaska 0il & Gas Cons. Commisslen Anchorage Form 10-407 Submit In duplicate Rev. 7-1-80 CONTNJED ~ ~~ ~ GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP 9794' 5991' NA KUPARUK C BOTTOM 9868' 6031' KUPARUK A TOP 9974' 6089' KUPARUK A BOTTOM 10172' 6195' 31. LISTOF A'I-rACHMENTS GYRO,FRAC, & WELL HISTORY 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Sign Title AREA DRILLING ENGINEER Date 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 ADDENDUM WELL: 8/01/91 1 L-23 Frac KRU "A" sand perfs from10,012'-10050',10156'-10165' @ 4spf in 10 stages as follows: Stage 1. Prop 150 bbls YF240D XL GW @ 20 bpm 6750-4450 psi Stage 2 Pmp 96 bbls YF240D Non XLGW @ 20 bpm 4450-4426 psi ISIP: 1428 FRAC GRAD: .67 PERF FRIC: 7180 Stage 3 Pmp 700 bbls YF240D XL GW @ 20 bpm 4700-4220 psi Stage 4 Pmp 150 bbls YF240D XL GW w/2ppg 20/40 Carbolite @ 20 bpm 4220-3712 psi Stage 5 Pmp 125 bbls YF240D XL GW w/4ppg 20/40 Carbolite@ 20 bpm 3712- 3533 psi Stage 6 Pmp 100 bbls YF240D XL GW w/6ppg 16/20 Carbolite @ 20 bpm 3533- 3872 psi Stage 7 Pmp 75 bbls YF240D XLGW w/8ppg 16/20 Carbolite @ 20 bpm 3872- 4106 psi Stage 8 Pmp 50 bbls YF240D XL GW w/10ppg 16/20 Carbolite @ 20 bpm 4106- 4170 psi Stage 9 Pmp 28 bbls YF240D XL GW w/12ppg 16/20 Carbolite @ 20 bpm 4170- 4403 psi Stage 10 Pmp 20 bbls YF240D XL GW @ 20 bpm 4403-3355 psi Pmp 20 bbls YF240D Non XL GW @ 20 bpm 4403-3355 psi Pmp 54 bbls Slick Diesel Flush 4403-3355 psi Average Pressure: 4,100 psi Fluid to recover: 1,226 Sand in zone: 8,828 Sand in casing: 880# 16/20 Carbolite Drilling S~i~tendent ~ ARCO ALASKA INC. ~ DAILY OPE~ATiONS ---- PA~E: WELL: BOROUGH: UNIT: LEASE: API: PERMIT APPROVAL: AFE: WI: 1L-23 NORTH SLOPE KUPARUK RIVER UNIT ADL 25664 ALK 473 50-029-22167 91-62 AK6063 55.252072 SPUD: 05/04/91 RELEASE: 05/14/91 OPERATION: DRILLING RIG: POOL 7 05/04/91 ( 1) TD: 80' ( 80) SUPV: KKL 05/05/91 ( 2) TD: 2595' (2515) SUPV:KKL 05/06/91 ( 3) TD: 5327' (2732) SUPV:KKL 05/07/91 ( 4) TD: 5327'( SUPV:KKL 0) 05/08/91 (5) TD: 5327'( SUPV:KKL 0) PICKING UP BHA MW: 0.0 VIS: 0 MOVED RIG FROM 1L-20X TO 1L-23. NU DIVERTER SYSTEM. RU FLOWLINE. **RIG ACCEPT @ 03-MAY-91 1600 HRS** CHANGED 3.5" BREAKOUT HEAD TO 5". FILL PITS W/WATER TO MIX MUD. RU TO PU 5" DP. FUNCTION TEST DIVERTER SYSTEM. CHANGED SAVER SUB FROM 3.5" TO 5" ON TOP DRIVE. PU 5" DP, HWDP, JARS. LOAD BHA, PU BHA. DAILY:S51,205 CUM:$51,205 ETD:S51,205 EFC:$1,700,000 DRILLING AT 2595' MW:10.0 VIS: 52 STRAP AND PU BHA, ORIENT W/MWD, TAGGED AT 104' BREAK CIRCULATION, DRILL F/ 104'-2396' CIRC BU, DROP SURVEY, PUMP DRY JOB, BLOW DOWN TOP DRIVE. POH, RETRIEVE SURVEY, LD DD AND BENT SUB, PU DD W/1.25 DEG BH, ORIENT W/MWD, RIH. WASH AND REAM F/2157'-2396'. DRILL F/2396'-2595' DAILY:S92,841 CUM:$144,046 ETD:S144,046 EFC:$1,700,000 RIH MW:10.6 VIS: 50 DRILL F/2595'-5327', DIRECTIONAL CORRECTIONS AS REQUIRED. CIRC AND CONDITION MUD, WT UP TO 10.6 PPG. START SHORT TRIP TO HWDP, PULL TIGHT AFTER 39 STANDS AND START SWABBING, RUN BACK TO BOTTOM. DAILY:S55,788 CUM:$199,834 ETD:S199,834 EFC:$1,700,000 ND DIVERTER MW:10.9 VIS: 57 CBU. PUMPED DRY JOB, POH, WORKED THROUGH TIGHT SPOTS, 2401'-2034', SLM, LD BHA. RU AND RAN 131 JNTS 9-5/8" 36# J-55 BTC CASING TO 5306', LOST PARTIAL RETURNS WHILE RUNNING FULL RETURNS ON BOTTOM. FS @ 5306', FC @ 5220'. CIRC AND CONDITIONED MUD--FULL RETURNS. RU HOWCO, TESTED LINES TO 3000 PSI. PUMPED 40 BBL FRESH WATER, BOTTOM PLUG, 750 SX PF E MIXED @ 12.1 PPG, BOTTOM PLUG, 600 SX PREM G MIXED @ 15.8 PPG, TOP PLUG, DISPLACED W/404 BBL, BUMPED PLUG W/2000 PSI. HAD FULL RETURNS 15 BBL OF DISPLACEMENT, GOOD CEMENT RETURNS (APPROX 20 BBL) TO SURFACE. **CIP @ 0300 HRS** FLOATS HELD. WASH CEMENT OUT OF DIVERTER AND FLOW LINE. LD LANDING JOINT. ND DIVERTER SYSTEM. DAILY:S202,973 CUM:$402,807 ETD:S402,807 EFC:$1,700,000 TESTING 9-5/8" CASING MW: 0.0 VIS: 0 LD CASING TOOLS, CHANGED BAILS AND ELEVATORS. SCREWED ON FMC BRADENHEAD. NU BOP. CHANGED PIPE RAMS F/3.5" TO 5" IN BOTTOM SET, 4" TO 7" VARIABLE IN TOP SET. TESTED BOP, BLIND RAMS TO 500 PSI, 3000 PSI; TESTED MANUAL KILL AND CHOKE VALVES TO 500 PSI, 3000 PSI, HCR HYDRAULIC CHOKE VALVES, CHOKE MANIFOLD; TOP AND BOTTOM KELLY COX VALVE ON TOP DRIVE AND FLOOR VALVE TO 500 PSI, 3000 PSI; TESTED HYDRIL 500 PSI, 2500 PSI. PULLED TEST PLUG, SET WEAR RING, LD TEST JOINT. CUT DRILLING LINE. RIH, TAGGED CEMENT AT 5200'. DRILLED CEMENT AND FC, TESTED CASING TO 2000 PSI, BLED TO 600 PSI, RETESTED CASING. DAILY:S55,806 CUM:$458,613 ETD:S458,613 EFC:$1,700,000 WELL: 1L-23 OPERATION: DRILLING RIG: POOL 7 PAGE: 2 05/09/91 ( 6) TD: 5380' ( 53) SUPV:JRR TIH W/8.5" BIT, TURBINE MW: 9.2 VIS: 36 PRESS TEST 9-5/8" CSG TO 2000 PSI--LEAKED OFF. CIRC AND CONDITION MUD. PRESS TEST 9-5/8" CSG TO 2000 PSI--BLED OFF TO 325 PSI. TOH, P/U HOWCO RTTS PACKER, TIH TO 5198' TEST CSG BELOW PACKER, PRESS BLED TO 550 PSI--PROBABLY LEA~ING THRU CSG SHOE; CLOSE PIPE RAMS AND TEST CSG TO 2000 PSI--BLED TO 1950 PSI IN 30 MIN--GOOD CSG TEST. TOH AND L/D RTTS. TIH. DRLD FS AND 10' NEW FORM, LOT AT 5337', HELD 450 PSI WITH 9.2 PPG MUD--il.6 PPG EMW. DRLD 5337'-5380' TOH. P/U BHA, ORIENT MWD, LOAD SOURCE IN CDR. TIH. DAILY:S54,596 CUM:$513,209 ETD:S513,209 EFC:$1,700,000 05/10/91 ( 7) TD: 8610' (3230) SUPV:JRR DRILLING 8.5" HOLE DRLD F/5380'-8610' DAILY:S72,087 CUM:$585,296 MW: 9.8 VIS: 42 ETD: $585,296 EFC: $1, 700, 000 05/11/91 ( 8) TD: 9861' (1251) SUPV:JRR DRILLING 8.5" HOLE MW:10.6 VIS: 45 DRILLED F/8610'-9656'. SHORT TRIP, 15 STANDS. DRILLED F/9656'-9861'. DAILY:S54,360 CUM:$639,656 ETD:S639,656 EFC:$1,700,000 05/12/91 ( 9) TD:10345' ( 484) SUPV:JRR TOH MW:10.6 VIS: 42 DRILLED F/9861'-10345'. CIRC B/U. 10 STAND SHORT TRIP. CIRC AND CONDITION MUD. TOH. DAILY:S54,635 CUM:$694,291 ETD:S694,291 EFC:$1,700,000 05/13/91 (10) TD:10345' ( SUPV:JRR 0) RUN 7" CASING MW:10.8 VIS: 45 TOH. L/D BHA; UNLOAD RA SOURCE AND LOGS FROM LWD; NO RESISTIVITY LOGS, GR ONLY. P/U BHA AND NEW LWD TOOLS; TIH TO 5300'. SLIP AND CUT DRILLING LINE, ADJUST BRAKES. TIH; TIH LOGGING F/4885'-10345'. CIRC AND CONDITION MUD. TOH; L/D JARS AND BHA. UNLOAD LOGGING INFO; RESISTIVITY LOGS OK. PULLED WEAR RING. R/U GBR CASING EQUIPMENT. RUNNING 7" CASING. DAILY:S49,654 CUM:$743,945 ETD:S743,945 EFC:$1,700,000 05/14/91 (11) TD:10249' ( SUPV:JRR 0) RIG RELEASED TO 1L-24 MW:10.7 VIS: 43 RAN 125 JTS 7" 26# J-55 BTC-MOD R-3 CSG + 118 JTS 7" 26# J-55 BTC R-3 CSG + MARKER JT; FS @ 10335', FC @ 10249'; LOST CIRCULATION @ 9-5/8" SHOE. RU CMT EQUIPMENT, CIRC AND RECIPROCATE @ 2 BPM W/O RETURNS WHILE BATCH MIX CEMENT; TEST CEMENT LINES TO 4000 PSI; PUMP 10 BBL ARCO PREFLUSH AND DROP BTM PLUG #1; PUMP 35 BBL ARCO SPACER @ 11.0 PPG AND DROP BTM PLUG #2; PUMP 250 SX (54 BBL) CLASS G CMT W/1 GPS LATEX 2000 + 3% CAL-SEAL + 0.5% CFR-3 + 0.05% HR-5 + 0.05 GPS D AIR + 0.5% BENTONITE + 0.1 GPS C434B; DROP TOP PLUG AND DISPLACE W/392 BBL 10.7 PPG BRINE; BUMPED PLUG TO 3500 PSI (OK); FLOATS HELD (OK); CIP 1815 HRS, 5/13/91. RECIPROCATED THROUGHOUT JOB W/O RETURNS; HAD GOOD PRESSURE INCREASE AS CMT ROUNDED CSG SHOE INDICATING LOST CIRCULATION ZONE UPHOLE. P/U BOP STACK; SET CSG SLIPS W/200000#; CUT 7" CSG AND SET BACK BOP; NU FMC 11" 3M X 7-1/16" 5M TUBINGHEAD AND LOWER SEAL ASSEMBLY; INSTALLED 7-1/16 5M ADAPTOR FLANGE AND 3" 5M VALVE; TESTED TO 3000 PSI (OK). INJECTED MUD AND H20 FROM INJECTION TANK. DAILY:S314,996 CUM:$1,058,941 ETD:S1,058,941 EFC:$1,700,000 SIGNATURE: ~ ~ DRILLING SUPE~INTENDENT~ DATE: ' ARCO~ALASKA INC. .~-'~ DAILY OPERATIONS --- PAGE' WELL: 1L-23 BOROUGH: NORTH SLOPE UNIT: KUPARUK RIVER UNIT LEASE: ADL 25664 ALK 473 API: 50-029-22167 PERMIT 91-62 APPROVAL: AFE: AK6063 WI: 55.252072 ACCEPT: 06/19/91 RELEASE: 06/20/91 OPERATION: COMPLETION RIG: NORDIC 06/19/91 (12) TD:10249 PB:10249 SUPV:DB 06/20/91 (13) TD:10249 PB:10249 SUPV:DB/WM PERFORATING MW:10.7 NaCl/Br ACCEPT RIG @ 0130 HRS 6-19-91. NU AND TEST BOPE. RU SWS AND PREP TO PERFORATE WELL. DAILY:S19,537 CUM:$1,078,478 ETD:S1,078,478 EFC:$1,700,000 TESTING TREE MW:10.7 NaC1/Br CO ROLLERS ON PERF GUNS. PERFORATE WELL. RU AND RAN 3-1/2" SINGLE COMPLETION ASS'Y. SPACED-OUT. SET RETRIEVABLE PKR. SHEAR PBR. TEST SSSV. ND BOP'S AND NU TREE. ATTEMPT TO PRESSURE TEST TREE. DAILY:S46,873 CUM:$1,125,351 ETD:S1,125,351 EFC:$1,700,000 06/21/91 (14) TD:10249 PB:10249 SUPV:DB/WM RIG RELEASED MW:10.7 NaC1/Br SWAPPED OUT TREE AND TESTED. OK. FREEZE PROTECT AND SECURE WELL. RR @ 0930 HRS 6-20-91. DAILY:S159,081 CUM:$1,284,432 ETD:S1,284,432 EFC:$1,700,000 SIGNATURE: DATE: ORIGINAL SUB - S URFA CE DIRECTIONAL SURVEY r~ UIDANCE r~ ONTINUOUS ~ OOL R~EIVED AUG 1 9 1991 ~'1~;~'011 & ~as Cons. 'Anchorage Company ARCO ALASKA, INC. Well Name 1L-23 (537' FNL, 143' FEL, SEC 31, T11N, R10E) Field/Location KUPARUK, NORTH SLOP..E., ALASKA Job Reference No. 74764 Lo;Iqed By: SCHWARTZ Date: 3-JUN-91 Computed By: KRUWELL SCHLUMBERGER * GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA INC. 1L - 23 KUPARUK RIVER NORTH SLOPE, ALASKA SURVEY DATE: 03-JUN-91 ENGINEER: SCHWARTZ METHODS OF COMPUTATION TOOL LOCATION: INTERPOLATION: VERTICAL SECTION: TANGENTIAL- LINEAR HORIZ. DIST. Averaged ~eviation and azimuth PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 32 DEG 40 MIN WEST COMPUTATION DATE: 1-AUG-91 PAGE 1 ARCO ALASKA INC. 1L - 23 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 03-JUN-91 KELLY BUSHING ELEVATION: 130.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0 0 N 0 0 E -30.00 0 5 S 79 27 E 70.00 0 15 S 8 5 E 170.00 0 16 S 5 47 E 269.99 1 40 S 29 32 W 369.77 5 29 S 31 34 W 469.07 7 53 5 34 11 W 567.75 10 42 S 36 54 W 665.65 13 0 S 38 39 W 762.50 15 47 S 39 35 W 0 O0 -130.00 O0 O0 O0 99 77 O7 75 65 5O ENGINEER: SCHWARTZ 0.00 100.00 100 200.00 200 300.00 300 400.00 399 500.00 499 600.00 599 7O0.00 697 800,00 795 900.00 892 1000.00 988.09 858.09 18 16 1100.00 1082.34 952.34 20 47 1200.00 1175.09 1045.09 23 5 1300.00 1266.16 1136.16 25 44 1400.00 1355.44 1225.44 27 42 1500.00 1443.47 1313.47 28 58 1600.00 1529.89 1399.89 31 25 1700.00 1614.20 1484.20 33 47 1800.00 1695.67 1565.67 37 4 1900.00 1773.96 1643.96 39 42 2000.00 1849 78 1719.78 41 45 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WES7 DIST. AZIMUT~ FEET DEG/IO0 FEET FEET FEET DEG MIN 2100.00 1922 2200.00 1993 2300.00 2060 2400.00 2124 2500.00 2181 2600.00 2234 2700.00 2285 2800.00 2335 2900.00 2383 0 O0 0 04 0 14 0 43 1 62 7 83 19 59 35 73 55 99 80 69 S 38 1 w 109.83 S 34 17 w 143.16 S 33 7 W 180.51 S 32 46 w 221.80 S 30 3 W 266.81 S 28 18 w 314.16 S 28 44 W 364.31 S 30 36 w 417.99 S 33 9 w 475.94 S 32 44 W 538.13 S 31 3 w 603.31 S 30 28 w 671.44 S 28 34 w 742.43 S 27 53 w 816.33 S 28 7 W 893.16 S 28 2t w 974.51 S 29 19 w 1059.23 S 29 37 W 1145.24 S 29 29 w 1231.87 S 29 34 W 1319.03 .94 1792.94 44 6 23 1863.23 46 36 34 1930 3`4 49 6 O0 1994 O0 52 19 76 2051 76 56 40 57 2104 57 59 8 36 2155 36 59 56 09 2205 09 60 21 87 2253 87 61 15 S 29 53 W 1406 93 3000.00 2431.34 2301.34 62 12 3100.00 2477.28 2347.28 62 49 3200.00 2522.94 2392.94 62 43 3300.00 2568.94 2438.94 62 30 3400.00 2616.69 2486.69 60 17 3500.00 2666.67 2536.67 59 58 3600.00 2716.47 2586.47 60 16 3700.00 2765.57 2635.57 60 51 3800.00 2814.29 2684.29 60 47 3900.00 2863.96 2733.96 59 19 64 52 24 05 62 29 37 68 46 S 29 52 W 1495 S 30 18 W 1584 S 30 38 W 1673 S 3O 51W 1761 S 30 49 W 1847 S 30 52 W 1934 S 31 5 W 2021 S 31 43 W 2108 S 33 7 W 2195 0.00 0.00 N 0.00 E 0.53 0.04 S 0.00 W 0 0.21 0.14 S 0.03 W 0 0.04 0.54 S 0.04 E 0 2.60 1.70 S 0.35 W 1 3.2t 6.92 S 3.72 W 7 2.35 16.80 S 10.09 W 19 1.89 29.96 S 19.48 W 35 3. 17 46.03 S 31.94 W 56 2.00 ' 65.27 S 47.70 W 80 0 O0 N 0 0 E 04 S 5 57 w 15 S 13 32 W 54 S 4 16 E 73 S 11 38 W 86 S 28 14 W 60 S 31 0 w 73 S 33 2 W 02 S 34 46 W 84 5 36 10 w 2.76 2.53 2.34 231 1 92 2 15 2 25 3 65 3 23 2 44 88 06 S 115 13 S 85 146 24 S 106 180 86 5 128 219 29 S 152 260 74 S 175 305 05 S 199 351.81S 225 400.91S 256 452.96 S 290 66 14 W 110.13 S 36 55 W 68 W 143.51 5 36 39 W 36 W 180.82 5 36 2 W 85 W 222,06 S 35 28 W 31 W 267.00 5 34 47 W 39 W 314,24 S 33 56 W 19 W 364.32 5 33 9 W 71 W 417.99 S 32 41 W 49 W 475.94 S 32 37 W 54 W 538.13 S 32 41 W 2 67 251 251 2 22 5 35 3 70 1 10 1 19 0.74 0.79 508 34 S 324 93 W 603.31 S 32 35 W 566 89 S 359 628 83 S 394 694 16 S 429 762 27 S 465 834 21 S 5O4 908.56 S 545 983.55 S 587 1058.99 S 630 1135.00 S 673 82 W 671.44 S 32 24 W 74 W 742.46 S 32 7 W 76 W 816.43 S 31 46 W 90 W 893.37 S 31 26 W 40 W 974.85 S 31 10 W 40 W 1059.69 S 30 59 W 79 W 1145.81 S 30 52 W 64 W 1232.54 S 30 46 W 57 W 1319.82 S 30 41 W 1 .6`4 0.01 0.53 0.61 1 .40 0.56 0.5,4 0.60 0.43 3.70 1211.39 S 717.28 W 1407.82 S 30 38 W 1288.42 S 761.50 W 1496.63 5 30 35 W 1365.44 S 806.03 W 1585.59 S 30 33 W 1441.97 S 851.06 W 1674.39 S 30 33 W 1517.47 S 895.98 W 1762.24 S 30 34 W 1591.83 S 940.38 W 1848.85 S 30 34 W 1666.29 S 984.84 W 1935.57 S 30 35 W 1741.01 S 1029.63 W 2022.68 S 30 36 W 1815.55 S 1075.12 W 2110.00 5 30 38 W 1888.96 S 1121.42 W 2196.76 S 30 42 W COMPUTATION DATE: 1-AUG-91 PAGE 2 ARCO ALASKA [NC. 1L - 23 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 03-JUN-91 KELLY BUSHING ELEVATZON: 130.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECT[ON SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH DEPTH DEPTH DEPTH DEG M[N DEG M[N FEET DEG/IO0 FEET FEET FEET DEG 4000.00 2915.27 2785.27 59 18 S 34 32 W 2281 27 4100.00 2966.32 2836.32 59 6 S 35 1 W 2367 4200.00 3017.70 2887.70 59 2 S 35 7 W 2452 4300.00 3069,45 2939.45 58 34 S 35 38 W 2538 4400.00 3121.76 2991.76 58 30 S 36 0 W 2623 4500,00 3173.74 3043.74 58 42 5 36 12 W 2708 4600.00 3225.82 3095.82 58 26 S 36 27 W 2793 4700.00 3278.48 3148.48 58 8 S 35 15 W 2878 4800.00 3331.31 3201,31 58 7 S 32 30 W 2963 4900.00 3384.60 3254.60 57 15 5 32 57 W 3048 0.79 1960 08 S 1169 47 W 2282.45 S 30 49 W 19 0.67 203O 91 O.32 2100 38 0.84 2170 48 O.52 2239 76 0.45 2308 96 0.88 2377 8O 3.89 2446 68 0.14 2517 30 1,12 2588 69 S 1218 92 S t267 74 S 1317 82 S 1367 89 S 1417 70 S 1467 25 S 1518 05 S 1565 22 S 1610 54 W 2368.23 5 30 58 W 80 W 2453 81 S 31 7 W 28 W 2539 16 S 31 15 W 19 W 2624 12 S 31 24 W 46 W 2709 28 S 31 33 W 99 W 2794 36 S 31 41 W 26 W 2879 11 S 31 50 W 11 W 2963.97 S 31 52 W 87 W 3048.58 S 31 54 W 5000 O0 3439 10 3309.10 56 39 S 33 5 W 3132 14 5100 O0 3494 5200 O0 3549 5300 O0 3604 5400 O0 3661 5500 O0 3717 5600 O0 3775 5700 O0 3833 5800.00 3890 5900.00 3946 51 3364.51 56 18 S 33 52 W 3215 13 3419.13 57 4 S 34 32 W 3299 55 3474.55 55 36 S 34 37 W 3382 12 3531.12 55 43 S 34 21 W 3464 66 3587.66 55 11 S 33 27 W 3547 39 3645.39 54 29 S 32 19 W 3628 22 3703.22 55 6 S 32 18 W 3710 09 3760.09 55 23 S 32 16 W 3792 53 3816.53 55 47 S 32 41 W 3875 38 11 30 72 17 82 41 66 21 0.99 2658 60 S 1656.44 W 3132.40 S 31 56 W 1.44 2728 1.62 2797 1.57 2865 0.59 2933 1.67 3002 0.54 3070 1.55 3139 0.84 3209 0.33 3278 06 S 1702.32 W 3215.62 S 31 58 W 30 S 1749.46 W 3299.32 S 32 1 W 81 S 1796.74 W 3382.47 S 32 5 W 77 S 1843.44 W 3464.86 S 32 9 W 18 S 1889.51 W 3547.30 S 32 11 W 80 S 1933.76 W 3628.94 S 32 12 W 80 S 1977.29 W 3710.53 S 32 12 W 36 S 2021.18 W 3792.78 $ 32 12 W 97 S 2065.57 W 3875.33 S 32 13 W 6000.00 4003 13 3873.13 55 13 S 31 59 W 3957 64 6100.00 4059 6200.00 4115 6300.00 4170 6400.00 4224 6500.00 4279 6600.00 4334 6700.00 4387 6800.00 4439 6900.00 4491 99 3929 99 55 53 S 32 14 W 4039 58 3985 32 4040 70 4094 38 4149 40 4204 64 4257 45 4309 47 4361 58 56 24 S 32 33 W 4123 32 57 9 S 34 9 W 4206 70 56 55 S 33 46 W 4290 38 56 43 S 33 17 W 4374 40 56 43 S 33 2 W 4457 64 58 50 S 33 32 W 4542 45 58 42 S 33 8 W 4627 47 58 34 S 32 46 W 4713 90 02 70 60 32 81 45 97 38 1.18 3348 59 S 2109.70 W 3957.77 S 32 13 W 2.12 3418 0.95 3488 0.20 3558 0.53 3628 0.57 3697 1.05 3767 1.03 3838 0.43 3909 0.27 3981 44 S 2153.16 W 4040.03 S 32 12 W 57 S 2197.78 W 4123.15 S 32 13 W 42 S 2243.87 W 4206.82 S 32 14 W 01 S 2290.78 W 4290.70 S 32 16 W 83 S 2336.99 W 4374.41 S 32 18 W 75 S 2382.63 W 4457.90 S 32 18 W 49 S 2429.10 W 4542.53 S 32 20 W 94 S 2476.12 W 4628.05 S 32 21W 63 S 2522.53 W 4713.44 S 32 21W 7000.00 4543 73 4413.73 58 27 S 32 23 W 4798.63 7100.00 4596 7200.00 4648 7300.00 4698 7400.00 4748 7500.00 4798 7600.00 4849 7700.00 4900 7800.00 4951 7900.00 5001 08 4466.08 58 27 S 32 4 W 4883.84 19 4518.19 59 4 S 32 45 W 4969.18 51 4568,51 60 3 S 33 39 W 5055.58 54 4618.54 59 54 S 33 11 W 5142.16 85 4668.85 59 35 S 34 11 W 5228.58 64 4719.64 59 27 S 34 2 W 5314.68 56 4770.56 59 20 S 33 43 W 5400.73 45 4821.45 59 41 S 35 29 W 5486.77 75 4871.75 59 48 S 35 40 W 5573.08 0 28 4053.48 S 2568 43 W 4798.70 S 32 22 W 26 4125.57 S 2613 07 4197.81 S 2659 27 4269.92 S 2706 29 4342.20 S 2754 34 4414.28 S 2802 30 4485.54 S 2850 40 4557.00 S 2898 61 4628,05 S 2947 33 4698.22 S 2997 86 W 4883.91 S 32 21 W 29 W 4969.25 S 32 21 W 91 W 5055.65 S 32 22 W 59 W 5142.22 S 32 23 W 27 W 5228.63 S 32 24 W 66 W 5314.73 S 32 26 W 62 W 5400.76 S 32 28 W 22 W 5486.79 S 32 29 ~ 68 W 5573.09 S 32 32 W COMPUTATION DATE: 1-AUG-91 PAGE 3 ARCO ALASKA INC. 1L - 23 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 03-JUN-91 KELLY BUSHING ELEVATION: 130.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 8000.00 5052.24 4922.24 59 33 S 35 21 W 5659.29 8100.00 5103.03 4973.03 59 22 S 35 12 W 5745,34 8200.00 5154.25 5024.25 59 2 S 34 51 W 5831.15 8300.00 5205.85 5075.85 58 46 $ 34 24 W 5916.76 8400.00 5258,06 5128.06 58 20 $ 33 55 W 6002.02 8500.00 5310.84 5180.84 57 57 S 33 16 W 6086.95 8600.00 5364.11 5234.11 58 0 S 34 9 W 6171.57 8700.00 5416.77 5286.77 58 23 S 35 7 W 6256.51 8800.00 5469.24 5339.24 58 20 S 34 28 W 6341.58 8900.00 5521,35 5391.35 58 50 S 34 39 W 6426.89 0.52 4768.51 S 3047.77 W 5659 30 S 32 35 W 0.48 4838.83 S 3097.53 W 5745 0.38 4909.16 S 3146.82 W 5831 0.70 4979.64 S 3195,51 W 5916 0,60 5050.22 S 3243.39 W 6002 1.02 5120.98 S 3290.36 W 6086 2,69 5191.62 S 3336.97 W 6171 0.71 5261.28 S 3385.70 W 6256 0.43 5331.21 S 3434.25 W 6341 0.44 5401.53 S 3482.61 W 6426 34 S 32 37 W 15 $ 32 40 W 76 S 32 41W 03 S 32 43 W 95 S 32 43 W 57 S 32 44 W 52 S 32 46 W 60 S 32 47 W 91 5 32 49 W 9000.00 5573.29 5443.29 58 38 S 34 13 W 6512 30 9100.00 5625.40 5495.40 58 35 S 33 43 W 6597 63 9200.00 5677.68 5547.68 58 28 5 33 11 W 6682 86 9300.00 5729.88 5599.88 58 35 S 32 36 W 6768 16 9400.00 5782.10 5652.10 58 27 S 32 12 W 6853 44 9500.00 5834.53 5704.53 58 20 S 31 58 W 6938 59 9600.00 5887.30 5757.30 57 59 S 31 40 W 7023 52 9700.00 5940.42 5810.42 57 44 S 31 47 W 7108.23 9800.00 5994.12 5864.12 57 14 S 32 9 W 7192.59 9900.00 6048.40 5918.40 57 5 S 31 38 W 7276.56 0.36 5472 02 S 3530.93 W 6512 33 S 32 50 W 0.57 5542 0.42 5613 0 39 5685 0 34 5757 0 49 5829 0 18 5901 0 63 5974 0 65 6045 0 81 S 3578.60 W 6597 94 S 3625.58 W 6682 55 S 3671.91 W 6768 58 S 3717.58 W 6853 73 S 3762.80 W 6938 92 S 3807.56 W 7023 01 S 3852.08 W 7108 57 S 3896.74 W 7192 72 6116.85 S 3941.16 W 7276 66 S 32 51W 9O S 32 51W 19 S 32 51W 47 $ 32 51W 62 S 32 5O W 55 S 32 50 W 25 S 32 49 W 61 S 32 48 W 58 S 32 48 W 10000.00 6102.55 5972.55 57 21 S 31 9 W 7360.61 10100.00 6156.53 6026.53 57 25 S 30 47 W 7444.75 10200.00 6210.48 6080.48 56 56 S 30 51 W 7528.90 10300.00 6265.17 6135.17 56 50 S 30 51 W 7612.59 10345.00 6289.78 6159.78 56 50 S 30 51 W 7650.24 0.45 6188.64 S 3984.91 W 7360.63 S 32 47 W 0,45 6260.85 S 4028.18 W 7444.76 S 32 45 W 1.23 6333,19 S 4071.27 W 7528.91 S 32 44 W 0.00 6405.05 S 4114.23 W 7612.59 S 32 43 W 0.00 6437.39 S 4133.55 W 7650.24 S 32 42 w COMPUTATION DATE: 1-AUG-91 PAGE 4 ARCO ALASKA INC. 1L - 23 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 03-JUN-91 KELLY BUSHING ELEVATION: 130.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST D[ST, AZIMUT~ DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 1000.00 988 2000.00 1849 3000.00 2431 4000.00 2915 5000.00 3439 6000.00 4003 7000.00 4543 8000.00 5052 9000.00 5573 0 O0 -130,00 0 0 N 0 0 E 0,00 09 858.09 18 16 S 38 1 W 109.83 78 1719.78 41 45 S 31 3 W 603.31 34 2301.34 62 12 S 29 53 W 1406.93 27 2785 27 59 18 S 34 32 W 2281,27 10 3309 10 56 39 S 33 5 W 3132.14 13 3873 13 55 13 5 31 59 W 3957.64 73 4413 73 58 27 S 32 23 W 4798.63 24 4922 24 59 33 S 35 21 W 5659.29 29 5443 29 58 38 5 34 13 W 6512.30 0.00 0.00 N 0.00 E 0.00 N 0 0 E 2.76 88.06 S 66.14 W 110.13 S 36 55 W 2.67 508.34 S 324.93 W 603.31 S 32 35 W 1.64 1211.39 S 717.28 W 1407.82 S 30 38 W 0.79 1960.08 S 1169.47 W 2282.45 S 30 49 W 0.99 2658.60 5 1656.44 W 3132,40 5 31 56 W 1.18 3348.59 S 2109.70 W 3957.77 S 32 13 W 0.28 4053.48 S 2568.43 W 4798.70 S 32 22 W 0.52 4768.51 S 3047.77 W 5659.30 S 32 35 W 0.36 5472.02 S 3530.93 W 6512.33 S 32 50 W 10000.00 6102.55 5972.55 57 21 S 31 9 W 7360.61 10345.00 6289.78 6159.78 56 50 S 30 51 W 7650.24 0.45 6188.64 S 3984.91 W 7360.63 S 32 47 W 0.00 6437.39 S 4133.55 W 7650.24 5 32 42 W COMPUTATION DATE: 1-AUG-91 PAGE 5 ARCO ALASKA INC. 1L - 23 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 03-JUN-91 KELLY BUSHING ELEVATION: 130.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -130.00 0 0 N 0 0 E 130.00 130.00 0.00 0 5 N 12 45 W 230.00 230.00 100.00 0 14 5 15 26 E 330.00 330.00 200.00 0 22 S 4 4 W 430.03 430.00 300.00 2 43 5 34 13 W 530.39 530.00 400.00 6 19 S 32 0 W 631.25 630.00 500.00 8 43 S 34 45 W 732.86 730.00 600.00 11 18 S 37 31 W 835.33 830.00 700.00 13 59 S 39 16 W 939.06 930.00 800.00 16 45 S 39 14 W 1044.27 1030.00 900.00 19 18 1151.18 1130.00 1000.00 21 59 1260.05 1230.00 1100.00 24 42 1371.33 1330.00 1200.00 27 12 1484,63 1430.00 1300.00 28 43 1600.13 1530.00 1400.00 31 25 1719,05 1630.00 1500.00 34 23 1843.41 1730.00 1600.00 38 23 1973.62 1830.00 1700.00 41 9 2109.81 1930.00 1800.00 44 19 2254.14 2030 O0 1900.00 47 58 O0 2000 O0 52 50 O0 2100 O0 2200 O0 2300 O0 2400 O0 2500 O0 2600 O0 2700 O0 2800 O0 59 3 O0 60 16 O0 62 10 O0 62 4O O0 60 1 O0 6O 27 O0 6O 36 O0 59 25 ENGINEER: SCHWARTZ 2410.01 2130 2591.10 2230 2789.70 2330 2997.15 243O 3215.39 253O 3426.77 2630 3627.36 273O 3832.09 2830 4028.91 293O 4223.89 3030 O0 2900.00 58 58 4415.80 3130 O0 3000.00 58 36 4607.97 3230 O0 3100.00 58 23 4797.52 3330 O0 3200.00 58 7 4983.39 3430 O0 3300.00 56 47 5164.75 3530 O0 3400.00 57 11 5344.93 3630.00 3500.00 55 26 5521.53 3730.00 3600.00 54 57 5694.40 3830.00 3700.00 55 1 5870.61 3930.00 3800.00 55 47 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 0.00 N 0.00 E 0.00 N 0 0 E 0.00 0.47 0.02 S 0.02 E 0.03 S 48 56 E 0.23 0.11 0.27 S 0.01 W 0.27 S 1 8 W 0.56 0.51 0.70 S 0.04 E 0.70 S 3 29 E 2.75 3.87 2.65 S 0.96 W 2.82 S 19 58 W 10.97 2.13 9.59 S 5.36 W 10.99 S 29 13 W 24.10 3.11 20.52 S 12.65 W 24.10 S 31 39 W 41.98 1.98 34.94 S 23.27 W 41.98 S 33 39 W 64.20 2.27 52.45 S 37.14 W 64.27 S 35 18 W 91.53 3.69 73.70 S 54.63 W 91.74 S 36 33 W S 36 t W 124.05 S 33 35 W 161.81 5 33 4 W 204.81 S 30 49 W 253.62 S 28 32 W 306.77 5 28 44 W 364.38 S 31 12 W 428.63 S 33 23 W 502.50 5 31 28 W 585.86 S 30 21 W 678.24 S 28 9 w 782.05 S 28 7 W 901.15 5 29 15 W 1051.61 S 29 31 w 1222.93 5 29 53 W 1404.42 S 30 22 W 1598.18 S 30 53 W 1784.27 S 30 54 W 1958.06 S 31 58 W 2136.65 S 34 43 W 2306.12 2.41 2.27 2.88 2.35 1 .75 2.24 4.02 2.84 2.44 2.65 99,45 S 130 166 207 254 305 36O 423 493 572 74 72 W 124.40 S 36 55 W 60 S 96 08 W 162.14 S 36 20 W 61 $ 119 61 W 205.10 S 35 41 W 90 S 145 62 W 253.83 S 35 0 W 23 5 171 85 W 306.86 5 34 3 W 11 S 199 22 W 364.39 S 33 9 W 95 S 231 16 W 428.63 S 32 38 W 12 S 271 07 W 502.50 5 32 39 W 42 S 315.87 W 585.86 S 32 38 W 76 S 363.28 W 678.25 S 32 23 W 2.90 5.30 1 45 0 55 1 57 0 33 0 25 0 88 1 26 0 72 663 80 S 413.62 W 782 12 S 31 56 W 769 901 91S 541 1051 19 S 626 1209 21 S 716 1377 25 S 812 1537 41S 9O7 1686.69 S 997 1839.32 S 1089 1980.55 S 1183 34 S 469 67 W 901 67 W 1052 24 W 1223 02 W 1405 93 W 1599 89 W 1785 04 W 1959 88 W 2137 60 W 2307 37 S 31 24 W 06 S 30 59 W 59 S 3O 47 W 30 S 30 38 W 27 S 30 33 W 47 S 30 34 W 34 S 30 35 W 97 S 30 39 W 26 S 30 52 W S 35 11W 2473 36 S 36 0 W 2636 93 S 36 30 W 2800 73 5 32 30 W 2961 58 S 32 59 W 3118 24 S 34 23 W 3269 52 5 34 31 W 3419 31 5 33 10 W 3564.81 S 32 17 W 3705,82 S 32 41 W 3850.91 0.43 0.72 0.83 0.14 0.91 0.86 O.75 1 .58 1 .47 0.34 2117.67 S 1279.59 W 2474.24 S 31 9 W 2250.73 S 1375.11 W 2637.55 S 31 25 W 2383.16 S 1472.02 W 2801.12 S 31 42 W 2515.28 S 1563.97 W 2961.86 S 31 52 W 2646.94 S 1648.88 W 3118.51 S 31 55 W 2772.89 S 1732.71 W 3269.74 S 32 0 W 2896.30 S 1817.74 W 3419.47 S 32 7 W 3016,93 S 1899.19 W 3564.94 S 32 11 W 3135.92 S 1974.84 W 3705.94 S 32 12 W 3258.51 S 2052.45 W 3851,03 S 32 12 W ARCO ALASKA INC. 1L - 23 KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE: 1-AUG-91 PAGE 6 DATE OF SURVEY: 03-JUN-91 KELLY BUSHING ELEVATION: 130,00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 6047.06 4030,00 3900,00 55 11 6226,14 4130,00 4000,00 56 37 6409,71 4230,00 4100,00 56 55 6591,96 4330,00 4200,00 56 37 6781,80 4430,00 4300,00 58 43 6973.75 4530.00 4400.00 58 27 7164.89 4630.00 4500.00 58 34 7362.99 4730.00 4600.00 59 57 7561.36 4830.00 4700.00 59 26 7757.70 4930.00 4800.00 59 22 S 31 45 W 3996 28 S 32 58 W 4144 83 5 33 43 W 4298 74 S 33 2 W 4451 09 S 33 13 W 4612 42 S 32 29 W 4776 27 S 32 7 W 4939 15 S 33 21 W 5110 14 S 34 10 W 528t.42 $ 34 24 W 5450,34 0.88 3381.42 S 2130.08 W 3996.40 S 32 13 W 2.04 3506.90 S 2209.59 W 4144.95 S 32 13 W 0,54 3634.79 S 2295,29 W 4298.84 S 32 16 W 0.64 3762.tl S 2378.96 W 4451 17 S 32 lB W 0,45 .3896.92 S 2467,62 W 4612 50 S 32 21 W 0,39 4034,60 S 2556,44 W 4776 34 S 32 22 W 1,26 4172,46 S 2643,20 W 4939 22 S 32 21 W 0,52 4315,42 S 2737,02 W 5110 20 S 32 23 W 0,34 4457,99 S 2832.01 W 5281 47 S 32 26 W 2,60 4598,17 S 2926,33 W 5450 37 S 32 28 W 7956,04 5030,00 4900.00 59 39 8152,78 5130,00 5000,00 59 11 8346.43 5230.00 5100.00 58 31 8535.98 5330.00 5200.00 57 42 8725.24 5430.00 5300.00 58 23 8916.70 5530.00 5400.00 58 48 9108.82 5630.00 5500.00 58 33 9300.23 5730.00 5600.00 58 35 9491.37 5830.00 5700.00 58 21 9680.43 5930.00 5800.00 57 50 S 35 27 W 5621.41 S 35 2 W 5790.67 S 34 10 W 5956.40 S 33 9 W 6117.40 S 34 57 W 6277.98 S 34 36 W 6441.16 S 33 40 W 6605.15 S 32 36 W 6768.35 S 31 59 W 6931.25 S 31 44 W 7091.67 0 32 4737.60 S 3025.81 W 5621.42 S 32 34 W 0 53 4875.94 S 3123 62 W 5790.67 S 32 39 W 0 78 5012,40 S 3217 0 84 5146,47 S 3307 0 73 5278,88 S 3398 0 50 5413,29 S 3490 0 67 5549,07 S 3582 0,39 5685,72 S 3672 0.36 5823.50 S 3758 0.57 5959.93 S 3843 85 W 5956.40 S 32 42 W 04 W 6117.40 S 32 43 W 04 W 6278.00 S 32 46 W 72 W 6441.18 S 32 49 W 78 W 6605.19 S 32 51 W 02 W 6768,39 S 32 51 W 91 W 6931,28 S 32 50 W 36 W 7091,70 S 32 49 W 9866,13 6030,00 5900.00 57 6 10050,85 6130,00 6000,00 57 16 10235,71 6230.00 6100.00 56 50 10345,00 6289,78 6159.78 56 50 S 31 52 W 7248.13 S 30 55 W 7403.39 S 30 51 W 7558.79 S 30 51 W 7650.24 0.51 0,39 0.00 0,00 6092.67 S 3926.20 W 7248.15 S 32 48 W 6225.32 S 4006.97 W 7403.40 S 32 46 W 6358.84 S 4086.64 W 7558.80 S 32 44 W 6437.39 S 4133.55 W 7650.24 S 32 42 W COMPUTATION DATE: 1-AUG-91 PAGE 7 ARCO ALASKA INC. 1L - 23 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A LAST GCT READZNG PBTD 7" CASING TD DATE OF SURVEY: 03-JUN-91 KELLY BUSHING ELEVATION: 130.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 537' FNL & 143' FEL, SEC31 T11N RIOE MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 5306.00 9794.00 9868.00 9974.00 10172.00 10217.50 10226.00 10335.00 10345.00 3607.93 3477.93 5990.87 5860.87 6031.02 5901.02 6088.51 5958.51 6195.27 6065.27 6220.04 6090.04 6224.69 6094.69 6284.31 6154.31 6289.78 6159.78 2869.89 S 1799.56 W 6041.30 S 3894.06 W 6094.00 S 3927.03 W 6169.92 S 3973.57 W 6313.00 S 4059.22 W 6345.75 S 4078.82 W 6351.86 S 4082.47 W 6430.20 S 4~29.25 W 6437.39 S 4133.55 W ARCO ALASKA INC. 1L - 23 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A LAST GCT READING PBTD 7" CASING TD COMPUTATION DATE: 1-AUG-91 PAGE 8 DATE OF SURVEY: 03-JUN-91 KELLY BUSHING ELEVATION: 130.00 FT ENGINEER: SCHWARTZ SURFACE LOCATION = 537' FNL & 143' FEL, SEC31 TllN RIOE MEASURED DEPTH TVD BELOW KB FROM KB SUB-SEA 5306.00 9794.00 9868.00 9974.00 10172.00 10217.50 10226.0C 10335.00 10345.0O 36O7.93 5990.87 6031 O2 6088 51 6195 27 6220 O4 6224 69 6284 31 6289 78 3477.93 586O.87 5901.02 5958.51 6065.27 6090.04 6094.69 6154.31 6159.78 RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 2869 89 S 6041 30 S 6094 O0 S 6169 92 S 6313 O0 S 6345 75 S 6351 86 S 6430 20 S 6437 39 S 1799.56 3894.O6 3927.03 3973.57 4059.22 4078.82 4082.47 4129.25 4133.55 FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 10345.00 6289.78 6159.78 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 7650.24 S 32 42 W DIRECTIONAL SURVEY FIELD WEll ARCO ALASKA INC. 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H..~d ...... ~:i"'[:"[::": ::[::~:::!:: :!;: i::i:: i:' %1 :i:;! :%1: !:!: i: :i :;t iI i:::i:::~:::!::i' ~;: !:::!::i;::i::: ~::;i:::!:::!::::%J;::!:::i::l:::i::i:::i:::i::' ,.L: 1L-23 i J7' FNLo 143' FEL, SEC 31, T11N, R10E, ) VERTICAL PROJECTION O 0 1oo00 12OO0 PERMIT Ii C~{ · WELL NAME : ~-,,~. I L- '5 COMPLETION DATE CO. CONTACT... "~i~eck'O. or iis~ da~a' as it i's recei¥~d.*l!St received date for 407. ifnot required list as I~FI 40i I lA I driliin'~"hi"stow' ~' su~'evl ~ well [es~s D i ~Orc dcS'crirtio4~ cored int~a,~,~ core analysis ~, d~ ditch inte~als digital data ............. . .............. : , , ,,,, , ~ ,,, ,, , ,, ,,, ,, , ,,,,i ,. , ~ i . i , ,,, i 1, . , , , ~ , ~ ,~ , ,, ,, ,,,. , , , ,, , ~ , ,~ , ,. ~ , i ~ J[i i iiii iii iii j i i i ri i IIII I [1111 I ]1 II III I I I IIII I I II ........... LOG ~PE' ' ~ RUN ' INTERVALS SCALE NO. [to thc nearest' foot] ..... (inchll lnl ....................................... 111 i i i lit I I Illl II III I II I IIII . Jl lA' t I I III ,_ ,, Ill, , I I_J~ 1, PIU,II, , ', lip, 13i I J II I1'11 I II I I I I II II IIII 'U~ L _ _ i i -- J i , , ,,,~,,, , i iii , i JJ ii . i i ii ARCO Alaska, Inc. Date- June 14, 1991 Transmittal #: 8133 RETURN TO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Cased Hole items. return one signed copy of this transmittal. ~O-/~'~ 1A-20 1A-20 ~:~/-~1L-23 1L-23 I L-24 ~'t-~, 1L 24 L-25 Receipt Drilling Cement Bond Log ,/ Cement Evaluation & Thickness/' Cement Evaluation Log V Cement Bond Log v/ Cement Evaluation Log ¥' Cement Bond Log . ~ Cement Evaluation Log,/ Cement Bond Log v' 6-6-91 6-6-91 6-2-91 6-2-91 6-2-91 6-4-91 6-4-91 6-4-91 Acknowledge' State of Alaska(+sepia) Please acknowledge receipt and Date' 90-2274 I 00-2270 8850-10237 8850-10237 7500-9141 7500-9143 7800-9088 7800-9065 NSK ARCO Alaska, Inc. Date: June 7, 1991 Transmittal #: 8119 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 1L-23 Receipt LIS Tape and Listing 5 - 9 - 9 1 5 21 1.5 - 10345.5 Acknowledged: ~~--~~- Date' - ......... DISTRIBUTION: Lynn Goettinger State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 April 30, 1991 A. W. McBride Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 re: Kuparuk River Unit 1L-23 ARCO Alaska, Inc. Permit No. 91-62 Sur. Loc. 537'FNL, 143'FEL, Sec. 31, TllN, R10E, UM Btmhole Loc. 1753'FNL, 971'FWL, Sec. 6, T10N, R10E, UM Dear Mr. McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The Commission will advise you of· those BOPE tests that it wishes to witness. D~ ~'~' W. Chairman Alaska Ol~l~aa~J Gas Conservation Commission BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALA~d,~ OIL AND GAS ~SERVATION COMMI~>o~ON PERMIT TO DRILL 20 AAC 25.005 I la. Type of Work Drill X Redrill t I lb. Type of Well Exploratory..._. Stratigraphic Test _ Development Oil Re-Entry _ Deepen --I Service _ Development Gas __ Single Zone ~ Multiple Zone _ 2. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska. Inc. RKB 130', P~,d 87' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25664 ALK 473 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 537' FNL, 143' FEL, Sec. 31, T11N, R10E, UM Kupa, ruk River Unit Statewide ' At top of productive interval (TARGET) 8. Well number Number 1310' FNL, 1255' FWL, Sec. 6, T10N, R10E, UM 1L-23 #U630610 At total depth 9. Approximate spud date Amount 1753' FNL, 971' FWL, Sec 6, T10N, R10E, UM 01-MAY-91 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1 L-1 8 10396' MD 971' @ TD feet 30' at 400' MD feet 2560 6322' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 400' feet Maximum hole angle 58° Maximum surface 2120 ps,~ At total depth (TVD) 3485sicJ @ 6322 18. casing program setting Depth size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length IVD TVD IVD TVD linclude stac~e data) 24 16" 62.5# H-40 Weld 80' 43' 43' 115' 115' +200 Cu.Ft. 12.25 9.625 36.0# J-55 BTC 5215' 43' 43' 5258 3580' 750 sx Permafrost E & HF-ERW 600 SX Class G 8.5 7" 26.0# J-55 BTC 10353 43' 43' 10396' 6322' 220 sx Class G Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true verticaltrue vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Cu. Ft. r" surface Cu. Ft. ~ ~CE!~/Fp Intermediate Production Liner ~!,,['~'"~ ':!'~ i ~.~,~1~ ,J Perforation depth:true measuredvertical 5~,S~i" 0~ .~;:-;° ~aS CO~;i~.. ~'J.~IS$~)~. . 20. Attachments Filing fee ~ Property plat __ BOP Sketch .~. Diverter Sketch ~ Drilling program ~ Drilling fluid program X_ Time vs depth plot ~ Refraction analysis _ Seabed report _20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /~(.~ ~~/_ Title Area Drilling Engineer Date / - - ~ Commission Use Only Permit Number I APl number J Appro(~a~/d~/~)l J See cover letter for ~//-~'_~ 50- ~__,~-- ,~ ~_ ?~' ~ . other recjuiremenls Conditions of approval Samples required .._Y e s ~ N o Mud log required ~ Y e s N o Hydrogen sulfide measures ~ Yes ,~ N o _Directional survey required/~Yes ~ N o Required working pressure for BOPE ,...._...,~2M; .~ 3 M; ~ 5 M; ~ I 0 M' ~ I 5 M Othe~ by order of Approve Commissioner the commission Date '~' c-') Form 10-401 Re; Submit triplicate GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 1L PAD o . o , o . 7. . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. Move in and rig up Pool 7. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test. Drill 8-1/2" hole to logging point according to directional plan. Run open hole evaluation logs or LWD as needed. Run and cement 7" casing. Pressure test to 3500 psi. ND BOPE and install temporary production tree. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Change over to diesel Shut in and secure well. Clean location and release rig. DRILLING FLUID PROGRAM (1L-23) Spud to 9-5/8" surface casino -- Density 8.6-1 0.0 PV 1 5-35 YP 1 5-35 Viscosity 5 0 - 1 0 0 * Initial Gel 5- 1 5 10 Minute Gel 1 5 - 4 0 APl Filtrate I 0-1 2 pH 9-1 0 % Solids 10 +/- Drill out to weight UD 8.6-9.3 5-15 5-8 30-40 2-4 4-8 8-10 8.5-9 4-7 Weight up to TD 10.6 10-18 8-12 35-50 2-4 4-8 4-5 9.0-9.5 10-12 Drillino Fluid System: -- Tandem Brandt Shale Shakers Tandem Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuge, Degasser Centrifuge Pit Level Indicator (Visual and 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 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2120 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. - The nearest well to 1L-23 will be 1L-18. As designed, the minimum distance between the two wells will be 30' at 400' MD. The wells would diverge from that point. 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 of a previously drilled well. The annulus will be left with a non-freezing fluid during any extended shut down in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. - Spud mud should be adjusted to a funnel viscosity between 100-120 to drill gravel beds. ARCO ALASKA, Inc.[ Creoted by ; jones For; T BILLINGSLEY Dote plotted : 27-Apr--91 Plot Reference is 23 version Coordinates are in feet reference slot True Vertical Depths ore reference wellhead.~ i-7~]/~1] EA ST M A N IZ//J/IIIC H RISTE N S E N S 52 DEC 4O MtN W 7t91' (TO TARGET) o o o c~ · · 400 -5 soo 1200 _ O_ - 2000- 2400- U - 2g~- ~2~- _ 3g~-- - - - RKB ELEVATION: 130' <-- West oo.oo 4400 4000 5600 3200 2800 2400 20~0 1600 1200 800 4000 I,, I I I I I I I I t I I I I I I I I I I I I I SURFACE LOCATION: 537' FNL, 145' FEL SEC, 51, T11N, RIOE TARGET LOCATION: 1310' FNL, 1255' FWL SEC. 6, TION, RIOE - -1600 _ - 2000 - -2400 - - -3200 KOP TVO=400 TMD=400 OEP=O -4o0o 3.00 - 9.00 \ 15.00 BUILD 5 DEG/IO0' --4400 ,21.00 X27.00 480o X 33.00 - ~ ~o r~n B/ PERMAFROST -5200 ~ '~1.00 - 57.00 EOC TVO=2015 TM0=2525 DEP=891 -5600 ~ T/ UGNU SNOS TARGET - .. TVD=2295 TMD=284g DEP=1534 , %/0-59g0 -6000 ~ 4 TM~)~977~t T/ W SAK SNDS ~ ( SOUTH 6055 TVD=2885 TMD=.3955 DEP=2269 ~ ~ WEST 3882 -6400 B/ W SAK SNDS TVD--3580 TMD=4883 DEP=.3054~ [ TD LOCATION~--~'~ 680O B/ W SAK SNDS TVD=3580 TMD=4883 DEP=3054 ~ ~1753' FNL 971' FWLt 95/8 CS(; PT .TVD=5580TMD=52.58DEP=5371 ~.~-------- -------- ~ K-10 TVD=3880 TMD=5820 DEP=3846 57 OEO 45 MIN K-5 TVD=5120 TMD=8144 DEP=5812 B/ KUP SND$ TV0=6215 TM0=10196 0EP=7548 TD /7"UNER TV0=6322 TMD=10596 DEP=7717 i i i i i i t t i i i ] i i i i i i i i i i i i i i i i i i i i i i i i i i i 400 800 1200 1600 2000 2~00 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 8000 ' 200.00 Vertical Section on 212.67 ~z[muth with reference 0.00 N, 0.00 E from slot #23 2OO ! ]50 I 100 I 5O 0 50 100 I ! I 100 5O 5O ~00 ]50 2OO 25O ~00 4300 / / / / / / / / / i / 25OO / I III I ~ 23 '''"~ 1 500 , 200 1 50 1 O0 / / / / 21oe' / / 900 100 / 2300 1 700 I 1 900i I ! I 2100 ] I I i I I 50 0 50 100 _ 5O _ 100 _ 150 _ 2O0 _ 250 _ 300 7 6 5 4 I I I I II 13 5/8" 5000BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACKAND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3.CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PS1. 5. OPEN ANNULAR PREVENTORAND MANUAL KILLAND CHOKE LINE VALVES. CLOSE TOP PiPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMSAND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUTOF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMSAND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKSAND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" -5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PS1 ANNULAR SRE 8/22/89 KJPARUK RIVER UNI', 20" DIVERTER SCHEMATIC 5 HCR I ' 6 4 3 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE ~ OPI~RATION . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20"- 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20" - 2000 PSI ANNULAR PREVENTER SRE 2/6/90 ITEM (1) Fee (2) Loc ** CHECK LIST FOR NEW WELL PERMITS ** APPROVE DATE ' [2 ~hru ~. (3) Admin [~ thru 1'3'] ~'" [10 S 13] (4) Casg ,~<,'~.~'. ~-~¢-~ / [14 thru 22] (5) BOPE /-~.~/. ~/-Z,~- ,~/ [23 thru 28] (6) Other (6) Addl Company Is permit fee attached ............................................... Is well to be located in a defined pool .............................. Is well located proper distance from property line ................... Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party~ ................................. 8. Can permit be approved before 15-day'wait ............................ J 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease nL~nber appropriate ......................................... Does well have a unique name & nL~nber ................................ Lease & Well YES NO ,, Is conductor string provided ............................ , ............ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ..... · ........................ Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test'toe,cpm psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Additional requirements ............................................. REMARKS 0 ,--4 -rz ~0 f,.,n .-i rll z geo]ogy' en9 i neer i ng-;. DWd~~ MTM~ LCS "!:" RP,¢¢~- 8EW~,¢?'~.' RAD.~ JH~ rev 03/29/91 jo/6.011 INITIAL GEO1 UNIT ON/OFF POOL CLASS STATUS AREA ~ 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 APPENDIXi No special 'effort has been made to chronologically organize this category of information. COMPANY NAME { ARCO ALASKA, INC, FIELD NAME : KUPARUK RIVER UNIT BOROUGH ~ NORTH SLOPE API NUMBER ; 50-029'22167 REFERENCE NO t 92026 RECEIVED FEB ~ $1~_ Alaska 0il & Gas Cons. Commission Anchorage chlumberger Alaska ComPutin~ Center' 22-JAN-1992 I5:56 **.** REEL HEADER **** SERVICE NANE : EDIT DATEi : 92/01/22 ORIGIN : F6IC REEL NAME : 74347 CONTINUATION ~ : PREVIOUS REEL COMMENT : ARCO ALASKA INC,,, ~...L-23, KUP~RuK RIVER UNIT' 50-029-22167 SERVICE'NAME' : EDIT: DATE : 9 /01/22 ORICiN : TAP~ Na~E~ . : 74347 CONTINUATION # : ~ P~E~IOUS TAPE : COMPENT : ARCO ALASKA INC,, 1L-23, KUPARUK RIVER UNIT, 50-029-22167 FILE NAPE : EDIT SERVICE : FLIC VERSION : 00la06 DATE : 92/01/22 MAX REC SIZE : 1024 FILE TYPE : LO 5~ST FILE SCHLUMBERGER WEb5 SERVICES COMPANY NAME: ARCO ALASKA, INC, FIELD) KUPARUK RIVER UNIT BOROUGH: NORTH SLOPE STATE: ALASKA AP[ NUNBER: 50-029-22~67 LOCATION: 537' FNL & 143' FEI., SECTION: 31 TOWNSHIP: RANGE: IOE PERNANENT DATUN: PSL ELEVATIONI 0 IS Tape Verification List'ing chtumberger Alaska ComPuting Center 22-JAN-1992 !5:56 bOG MEASURED FROM RKB 130 ABOVE PERMANENT DATUM ELEVATIONS KB: 1]0 DF: 130 GL: 87 DATE bOGGED~ 09-MAY THRU 1B-MAY-91. RUN NUMBER: ONE TD DRILLER: 10476 CASING: 9 5/8" ]6 LB M DRILLER DEPTH OF 5237 FLUID DENSITY: I0.6 MUD RESIMTIVITY~ 2,26 FILTRATE RESISTIVITY: 3,6 MAXIMUM TEMP RECORDED~ 153 LOGGI~G DISTRICT: LOGGING ENGINEER: TOOL NUMBERS: RGS042 ~ 62 PRUDHOE BAY HUSBAND NOS037 F'!EbD REMARKS) BIT RUN ONE: DRILLED INTERVAL 5380' TO 10346'. GAMMA RAY READING 76FT BEHIND BIT. RESISTIVITY READING 66FT BEHIND BIT, DENSITY READING 133FT BEHIND BIT, NEUTRON READING 139FT BEHIND IT, DENSITY MATRIX: 2.65 G/CC, FLUID DENSITY: 1,0 G/CC, CDR /N 042 PUMP HOURS: 6],9, BIT RUN TWO~ WASHDOWN INTERVAL 8374' TO 10346' GAMMA RAY READING 37F..~ BEHIND BIT..RESISTIVITY READING 2EFT BEHIND BIT- ROP 6CALE CHANGED TO 4000 0 FPh DUE TO FAST SAMPLING RATE (2 AND LOGGING SPEED (1800 ~P~) ON WASHDOWN PASS. ANISOTROPIC EFFECTS'IN KALUBIK AND MILUVEACH SHALES ABOVE AND BELO~ KUPARUK SANDS MAXIMUM WELL DEVIATION= 63 DEGREES. GAMMA RAY P~ESENTED FROM DRILLED INTERVAL INVALID FROM 8500' TO 9550 COMPUTING CENTER ~EMARKS: CDR D~ILLING PASS DATA ONLY VALID FRO~ 53~4' TO 8460" (CDR FAILURE). CDR/GR ~ASHDOWN PASS DATA IS OVER INTERVAL 8]74' TO PAGE= DATE JOB STARTED: 2g-MAY-9! JOB REFERENCE NO: 74598 LDPtANA~ KOHRING~ ****************************************************************************** * FILE - ~DIT,O0! * * ARCO ALASKA INC, * KUPARUK RIVER UNIT * 15-23 :IS TaPe. verification Listing chlumberger AlasKa Computin~ Center 2:2~dkN-lg92 15.:56 DRILLING AND WASHDOWN PASSES LWD LOG DATA DATA SAMPLED EVERY'-,5000 FEET D!TA :INCLUDED - TOOL EXTENSION TOoL~ TYPE USeD NA~E NOS ,LWD ~OGG~NG WHILE DRIE~b'!NG N~UTRON/.DENSITY 5324' TO' 10222, RGS ,I,~D LOGGING. WHILE DRILLING RESISTI~ITY/GR 5324' TO' 8460' RGS ,WSH LWD WASHD. OWN PASS RESiSTIVITY/GR 8374' TO 10320' cOMPUTING:. CE.TERN ' REMARKS (20-JAN-92).:. THIS LIBRARY TAPE HAS BEEN REVISED TO INCLUDE RECA~I~?ATED CON DENSITY DATA, FROM T'D,= TO 8280' ONLY. DATA= PRESENTED IS FROM 'RHOB MA:~(', PAGE: 3 TABLE' TYPE : CONS TUNI VALU DEFI TYPE CN FN WN API~ FL SECT TOWN R~N~ COUN STAT NATI WITN SON PDAT EPD APO EKE EOF EGL TDL TLI OFT DFD FT FT FT FT FT FT FT FT FT G/C3 ARCO ALASKA, INC{ KUPARUK RIVER UN T 15-23 50-029-~2167 537' FNL & 143' FEL 31 10E NORTH SLOPE ALASKA USA 548980 0, RKB 130, 130, 130, 87. 10476, 10319, 5212, 10,6 Company Name, Field Name Well Name AP1 Serial Number Field Location Section Township Range CouLty State or Province Nation ~ltness' Name Service Order Number Permanent datum Elevation of Perm, Da Log ~easured From ABOVE PERMANENT DATU~ Elevation of [etl~ ~u Elevation of Derr c Elevation of Ground L Total Depth - Driller Total Depth - Logger Bottom Log Interval ToD Log Interval Drilling Fluid Type Drilling Fluid Den$it ZONE ZONE ~chlUm~erger AlasKa Co~Puttnq Center 22-JAN'I gg''2 15:56 PAGE: 4 TUNI VALU DEFI TYPE DFP~ Drll! ng ~u:IdPh ~u[ DFV CP Drill ng Fluid Viscos ZONE DFb F3 ZO~E R.~S OH~M 2,26 Resi. sfiVitY of Mud Sa ReSiStivity of~ mud 62' ~ud Sample. Tempera ur ~F$ 0~'~ MFST DEGF 6 , ~ud, Filt.rate. Samp!e RMCS OMMM Resistivity of ~ud Ca ZONE ~CST DEGF Mud Cake ~ampl~ Tempe ZONE BMT DEGF 153.' BOtto~ Hole Temperatu T~BLE: TYPE : ZONE. TUNI BDEP TDEP TDL DFT DFPH DFV DFL R~CS ~CST I FT O, 0.~ 0, 0, 0.~ 0, 0, .... 0, TABLE TYPE DEFI DEPT Depth Channel Name GR ~:amma Ray PEF Photoelectrlc~ Factor DPOR Density Porosity Output from an APpliCation Program DPH! Density Porosity ROS2 SS2 RHO Density - bDT RHOB Bulk Density D~HO Delta RHO DCAb Differential Caliper ROPE RATE OF DRILLING PENETRATION NCNL Near CNL Detector Counts FCNL Far CNL Detector Counts TNP~ Thermal Neutron P°r°sit¥s ATR RG$ BHC ATTENUATION RES TIVITY PS~ RGS BHC PHA~E SHIFT RESISTIVITY DER DIELECTRIC RESISTIVITY FRO~ RGS GR Gamma Ray ATR RGS BHC ATTENUATION RESISTIVITY PSR RGS BHC PHASE SHIFT RESISTIVITY DER DIELECTRIC ~ESISTIVITY FROM RGS ,IS Tape verification Listing ;¢hlumbergerAlas~a ComPutin~ Center 22-JAN-1992 15=56 PAGE{ FORMAT SPMCIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 80 4 66 5 66 6 73 7 65 8 68 0~5 9 65 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 0 mmmlm, mmmmmmmmmmmmmmmmmmmmmmm~) ** SET TYPE - CHAN ** NAME SERV UNIT ID mIm{mmmm~mmmmmmm~ DEPT FT GR LWD GAPI PEF [,WD DPOR LWD PU DPH! LWD PU ROS2 LWD G/C3 RHOB LWD G/C3 DRHO LWD G/C3 DCAL LWD IN ROPE LWD F/HR NCNL LWD CPS FCNL LWD CPS TNpH L~D PU ATR LWD OHMM PSR LWD OHMM DER bWO OHMN GR WSH GAPI ATR WSH OHMM PSR WSH OHMM DER WSH OHMM SERVICE API APl AP1 APi FILE NUMB NUMB SIZE. REPR PROCESS ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) 548980 O0 000 O0 0 I I 1 4 68 0000000000 548980 O0 000 O0 0 I I i 4 68 0000000000 548980 O0 000 O0 0 1 I 1 4 68 0000000000 548980 O0 000 O0 0 1 1 1 4 68 O000OO0000 548980 O0 000 O0 0 1 % I 4 68 O000OO0000 548980 O0 000 O0 0 I ~ ! 4 68 0000000000 548980 O0 000 O0 0 1 1 I 4 68 0000000000 548980 O0 000 O0 0 1 I 1 4 68 0000000000 548980 O0 000 O0 0 I ! 1 4 68 0000000000 548980 O0 000 O0 0 1 1 1 4 68 0000000000 548980 O0 000 O0 0 1 I I 4 68 0000000000 548980 O0 000 O0 0 ! ! ! 4 68 0000000000 548980 O0 000 O0 0 I I 1 4 68 0000000000 548980 O0 000 O0 0 1 I I 4 68 0000000000 548980 O0 000 O0 0 ! I ! 4 68 0000000000 548980 O0 000 O0 0 I 1 1 4 68 0000000000 548980 O0 000 O0 0 ! 1 1 4 68 0000000000 548980 O0 000 O0 0 I I 1 4 68 0000000000 548980 O0 000 O0 0 1 I ~ 4 68 0000000000 548980 O0 000 O0 0 I X 1 4 68 0000000000 ,chtumberger~ A!as!(a CompUtin~ center ** DATA DEPT.~ DPH~'~WD DCA[~,LWD T~PH,bWD DEPT. DCAE.LWD~ TMPM,LWD GR,WMH DEPT.~ DPM~,bWD DCA['LWD TNPH,LWD GR.WSH DPHI,~WD DCRL,LWD TNPM,LWD · GR,WSH DPHI,bWD DCAL.bWD ?NPH,bWD D~P~ DDHI'~WD DCA~bWD ?NpH,GWD GR.WSH D~?, DPHI.bWD INpHob~D GRoWtH DPHI.bWD DCA~.~WD tNpHo~WD DFPT DPHi:[wD DCA~.bWD INpHobWD GRoWSH i~345.500 ,999'250 :999,250' ~999,250 999'250 -999,250 -'999,250 -999'250 91'597 1020~045 10100,000 11.~02 0,~55 32'~34 73'290 10000000 14 54! 0 36 ~07 78 ~7 9900000 0,~94 31.~65 82'~99 9~00.000 20.950 0.439 37,671 69.298 9700.000 8.107 0 '° 69 114.369 9600.000 6.889 0.483 49.370 104.359 .GR.bWD ROS2jLWD ATR,bWD ATR.WSH GR'bWD RO$2,LWD ROPE'LWD ATR'L~D ATR,WSM ROS2,~WD ROPE,bWD ATR'LWD ATR..WSH GR*LWD RO$2.bWD ROPE*LWD ATR.SWD ATR"WSH GR*bWD ROS2,bWO ROPE,LWD ATR.LWD ATR,~$H GR LWD ROS2:bwD ROPE.LWD ATR.LWD ATR,WSH GR.LWD ROS2.LWD ROPE.LWD ATR.LWD ATR.WSH GR.LWD RO$2.LWD ROPE.bWD ATR.LwD ATR.WSH GR.LWD ROS2.LWD ROPE.LWD ATR.bwD ATR.W$H 22"dA'M,-1992 15::56 -999'20 21'699 -99g' -999,~5050 -999"250 -999' -999-~so 2'6!5 90,672 4 "999,250 2.692 73.639 2.4!0 74,162; -999.~50 4. 58 78 7§2 2!499 87 091 -999 250 6.064 60 462 2 996 20 503 -999 250 55 293 116.3~2 33 70 -999 50 2.225 110.518 2.536 53.083 -999.250 2.1~7 RHOB,b:u: NC:NL~,bWD PSR,~WD RHOB.bWD PSR"hWD PSR,WSH PEF'bWD ~HOB'LWD NCNb,bWD PSR.'b.WD PEF.bWD ~HOB.bWD NCNb,bWD PEF.bWD R. MOB,bWD NCNL,LWD PSR'LWD PSR,WSH PEF.LWD RHOS.LWD NCNL.LWD PSR,LWD PSR.WSH PEF'.LWD RHOS.LWD NCNL,bWO PSR,LWD PSR.WSH PEF.bWD RMOB.LWD NCNL.LWO PSR.LWD PSR,WSM PEF,bWD RHOS.LwD NCNL.LWO PSR.bWD PSR.WSH '999,~50 -999'~50 -999.:~50 '999'250 '999'!250 999,250 .999'250 ,999.250 999'250 3,312 2'616 ,208,.640 999':~50 3.500 ,464 2261,981 4 ~i0 ~5 o .236.544 609 18.416 ~'996 222.578 '999.250 36.819 3.739 2.516 204.728 -999.250 3.623 4.069 2.536 200.~29 -999 DPD~'SWD DRHO.~LWD FCNL,LWD DER,~WD DER.WSH DPOR.LWD DEHO'b~D FCN. b.~WD DER'LWD DER,WMH DPOR'LWD DRHO.LWD FCNL,LWD DER,5WD DER.WSM DPOR,bWD DRHO,LWD FCNL,LWD DER'LWD DER'WSH DPOR,.LWD DRHO,LWD FCNb.LwD DER,LwD DER,WSH DPOR:,LWD DRHO,LWD FCNL,LWD DER.LWD DER,WSM DPOR.LwD DRMO.LwD FCNL.LwD DER.LWD DER.~$H DPOR.LWD DRHO.LWD FCNL.LWD DER.LWD DER.WSH DPOR.LWD DRMO,LwD FCML.LWD DER.LWD D£R.WSH PAGe'= .-999'250 -999~250 -999'250 '999,250 "999.250 :999,250 .999~250 :~999.250 999'250 2,984 i'ot ':025 . 20,084 999~:50 3,112 0,033 26.;649 -999.250 5'648 14"541 0,009 . 25'393 999~250 5.155 . 28'~3~ -20.950 253 '999,2 0 40.~6 8.107 0.011 19.818 -999.~50 2.787 6,889 0.011 19264 -999~250 2.466 ,chlumbergerAlaSka comPuttn~ Center DEPT..~ DPB~'SWD DCA['LWD TNPH,LWD G~,WSH DEPT. DCAL'LWD TNpM'.LWD DPBI.LWD DCAS*SWD TNPH.LWD GR ,WSH DEPT DPHI, DCAL,L'WD DEPT.~ DPHI'L..D DCAL'LWD TNpH.LWD DEPT DCAb.~WD TNPH.LWD DEPT,~ DPMI,LWD DCAL,LWD TNPH.LWD DEPT.~ DPHI.LWD DCAL.LWD TNpH.LWD DEPT. DPWI.LWD DCAb. LWD TNPH.LWD GR.WSH 9500.000 !4,358 187.95! oo,Ooo 22,590 0'057 47~885 223'025 9300,000 16,239 0,336 49,448 196,350 9200 000 1~ ~0 0 265 48 228 !8! 289 9100,000 12,214' 0.215 35,736 89.434 9000.000 12 ~34' 0:~56 103 13 8900,000 ~0.~69 0,168 50,396 107.172 8800,000 17,306 0..186 4].3~4 t29,096 ~700.000 8,~27 0.325 36.899 118,997 RO$2,[,WD ROPE,LWD ATR,['WD ATR,WSH GR.LWD ROS2.LWD ~R'.bWD ATR.~$H GR ~WD ROS2 LWD ROPE LWD ATR LWD ATR WSH GR.LWD RO$2.LWD ROPE.~WD ATR.LWD ATR.~$H GR.SWD ROPE.LWD ATR.LWD ATR.WSH GR RO$2:LWD ROPE.LWD ATR.LWD ATR.WSH GR.LWD ROS2.LWD ROPE.~WD ATR.LWD ATR.WSH GR.LWD RO$2.LWD ROPE.~WD ATR.LWD ATR.WSH G~.LWD ROS2.LWD ROPE.LWD ATR.LWD ATR.WSH 22-~AN-1992 15::56 77.759 2 4 ! 3 170.911 -999. 250 3,446 999,~50 2. 47 80,455 2,382 53 ' 5 ~ ! -999,250 ~,847 73.2~2 999,~50 3.613 53.473 476 15 ,549 -999.250 4.420 37 2~314 158.245 -999.250 4.044 40.158 .364 18 .395 -999.250 4.027 11~ 5 6 ~22 -999 250 3.364 PEF:,bWD NCNL'LWD PSR,LWD PSR'WSH PEF,L~D RMOB,~WD NCNL:!,SWD P$.R,SWD PSR,WSH PEF.LWD RHOB'5WD NCNL-LWD PSR,SWD PSR.WSH. PEF,LWD ~HOB.LWD NCNL,LWD PSR'WSH PEF.LWD NCNL*LWD PSR,LWD PSR;,WSH PEF'LWD RHO.B.~WD NCNL.LWD PSR.SWO PSR,WSH PEF,LWD R~OB.LWD NCN5.LWD PSR,WSH PEF.~WD RHOB.LWD NCNL.SWD PSR.LWD PSR.WSH PEF.LWD RHOB.LWD NCNL.LWD PSR.LWD PSR.WSH 2'~13: 2.10.664 -999'250 4,553 4,425 2'277 99,.~50 3'951 63 ~9.250 3.663 999,2 5.105 4.0 226.495 703 22 888 -999.~50 5.393 4.024 2.3~4 205 192 -999:250 9.634 4 044 2il.J79 -999.250 5.051 3 ~93 . 70 -999.250 3.747 DPOR 5WD DR~O LWD FCNb LWD DER LWD DER DPOR.LWD DREO,bWD FCNL.LWD DER-LWD DER,WSH DPOR,LWD DRRO.LWD FCNS'LWD DER.LWD DER,WSH DPOR*~WD DRHO.L~D FCNL-LWD DER.LWD DER.WSH DPOR*LWD DRHO*SWD FCNS.LwD DER.LWD DER.WSH DPOR LWD DRBO:LWD DER.LWD DER.WSH DPO~,LWD DRHO.L~D FCNL,SWD DER,~WD DER.WSH DPOE.LWD DRHO.LwD FCNLoLWD DEE.bWD DER.~SH DPOR.LWD FCNL.~wD DER.LwD DER.~SH PAGE~- - 250 038 22,590 19'875: '999'~0 16"~9 0,013 '999,250 3'279 0'002 . 19,597 .999,250 4'~7t 12.214 0'005 :25.192 -999;250 4.066 12'i~34 -0. 09 25,548 -999,250 4.984 0 004 19~454 -999.250 8.467 17.306 ~0,009 1,~90 -999,250 4.590 8.i27 0.012 24,118 -999,250 3.697 ~chl i ' g r Alaska CompUting center 22-dAN-1992 15:56 PAGE: TNPM'LWO 35'738 GR.wSM 79°777 DEPT,~ 8400,000 DPH.I,L~WD 13'756 DCAL'LWD 0.223 TNP'H.L'WD ~:073 G.R.WSH 1 .570 DEPT, . 8300,000 TNPH ~D 46'425 GR:~$~ -999.~50 82?0,000 DPg!:LWD .-999'250 DCAL [WE 276 TNP": WD 4~:'774 ** END OF DATA GR.LWD RO$2.LWD ROPE.LWD ATR.LWD ATR,WSH GR'LWD RGS2,LWD ROP.E.LWD ATR.LWD ATR.~SH GR,LWD ROS2.LWD ROPE,LWD ATR.LWD ATR.~SH GR.LWD RO$~.LWD ROPE,LWD ATR'LWD ATR,WSH GR.LWD ROS2'LWD ROPE.'LWD ATR,~WD ATR.~$H · 44'304 PEF.bwD: 2,402 RHOB,LWD 180'849 NCNL*LWD '99912~0 PSR,LWD 2.9 8 PSR.WSH 14 :!, 766 2,423 129,670 3 · 693 3 · 715 162.443 2,435 170 ' 742 ., 2,0~9 999 "':25;0 . ! 22,041 999.250 210,706' . 2,136 999.250 PEF.LWD RHOB,LWD NCNL.LWD PSR,LWD PEF,L~D RHOB'bWD NCNL.LWD PSR*LWD ~PSR,WSH PEF,LWD RHOB,LWD NCNL,LWD PSR,bWD PEF,'~WD RHOB*LWD NCNb. LWD PSR,LWD PSR.WSH 2 2 2924 - 99 3 3 2 206 3 3 3 2 208 4 3 3 2 206 3 '999 '999 -999 207 -999 939 402 740 250 315 ,400 .423 ,44 3 ,977 · 61 $ 7"/ .850 '435 · 298 ,2 72 ,250 5O DPOR-LWD D~O.'Lw"D FCNL.LWD DER,~WD DER.~iSH DPOR*L~D DRBO'L~D FC~b,L~D DER*LWD DER,WSH DPOR.LWD DRHO.LWD FCNL'LWD DER'LWD DER.WSH DPOR.LMD DRHO,.L~D FCNb. LWD DER.LWD DER.WSH FCNL.LWD DER.LWD DER.WSM 250 180 13,753 -0"012 6!7 3.517 ,756 20.383 4.044 3,848 13,037 0.004 .20,308 2,561 "999-250 ~999,250 '999.250 19684 2:470 -999,250 **** FILE FILE NAME SERVICE VERSION DATE MAX REC SIZE Fibs TYPE LAST FILE TRAILER : EDIT ,00! : FLIC : O01A06 : 92/01/22 : ~024 **** TAPE SERVICE NAME DATF ORIGIN TAPE NANE CONTINUATION PREVIOUS TAPE COMMENT TRAILER **** : EDIT : 92/01/22 : FLIC : 74347 # : 1 : : ARCO ALASKA INC. , 1L=23, KUPARUK RIVER UNIT. 50-029-22167 chlumberget Alasga Computing center 22-JAN-1992 15:56 PAGE: **** REEl, TRAILER S~RVICE NAME : EDIT DATE : 92/0!/22 ORIGIN : FLIC REEL NAME. ~ 74347 CONTINUATION ~ : PREVIODS REEL COMMENT : ARCO AbASKA INC., lb:-2].~, KUPARUK RIVER [INIT, 50'029-22167
