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188-122
STATE OF ALASKA AL KA OIL AND GAS CONSERVATION COMM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon E Plug Perforations E Fracture Stimulate Pull Tubing F Operations Shutdown Performed: Suspend I— Perforate fl Other Stimulate 1— Alter Casing F Change Approved Program Plug for Redrill[ Perforate New Pool E Repair Well F Re-enter Susp Well r 1 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory E 188-122 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-103-20102-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25588 KRU 2K-01 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8540 feet Plugs(measured) 8078' l V ED true vertical 6352 feet Junk(measured) None �I MAR 14 2016 Effective Depth measured 8435 feet Packer(measured) 7892,8041 true vertical 6263 feet (true vertical) 5832, 5944 AOGCC Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115 115 0 0 PRODUCTION 1914 7 1945 1703 0 0 SURFACE 3684 9 5/8 3719 2930 0 0 PRODUCTION 8488 7 8521 6335 0 0 Perforation depth: Measured depth: 8260-8292 True Vertical Depth: 6117-6144 � t .E ria�; �� ,'`��: Tubing(size,grade,MD,and TVD) 3.5, L-80, 8003 MD, 5915 TVD Packers&SSSV(type,MD,and TVD) PACKER-7"X 3 1/2"BAKER FHL 4762 Retrievable Packer(Shear Release 60KLBS)@ 7892 MD and 5832 TVD PACKER-7"X 3 1/2"BAKER HB 4764 Retrievable Packer(Shear Release 60KLBS)@ 8041 MD and 5944 TVD SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): n/a Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory E Development F Service 1— Stratigraphic E Copies of Logs and Surveys Run E 16.Well Status after work: Oil F Gas E WDSPL Printed and Electronic Fracture Stimulation Data E GSTOR r WINJ WAG E GINJ E SUSP E SPLUG 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-009 Contact Diana Guzman @ 265-6318 Email Diana.Guzmanaconocophillips.com Printed Name Diana Guzman Title Sr. Wells Engineer h Signature 265-6318 Date 1V1 4(c )f- i ZO l b VTC 3/L /Ii Form 10-404 Revised 5/2015 ,..‘ ��.,//� RBDMS G�- Submit Original Only lMAR 1 2016 i • 2K-01 DTTMS'JOBTYP SUMMARYOPS 1/31/16 RECOMPLETION Continue to circulate until clean 8.7 ppg seawater to surface and shut in the well. Monitor the well pressures. Initial well pressures: Tubing = 15 psi and IA= 20 psi. Final well pressures: Tubing = 310 psi and IA= 305 psi. Load the pits with 11.0 ppg brine and mix with 8.7 ppg seawater to make 10.0 ppg brine. Circulate 10.0 ppg brine until clean 10.0 ppg and shut in the well. Observe the well for flow for 30 minutes; the well is static. Install 3" 'ISA' BPV. ND the tree, ND the tubing, head adapter, and install the blanking plug. NU the DSA and NU the BOPE stack. RU BOPE testing equipment. Conduct initial BOPE test to 250/2500 psi: test 7" solid body rams with 7" test joint(lower pipe rams); test 2-7/8" x 5"VBR's (upper pipe rams)with 3- 1/2"test joint; test annular to 250/2500 with 3-1/2"and 7"test joints; conducted Koomey drawdown test. The states right to witness was waived by AOGCC inspector Guy Cook via email on 1/30/16 at 11:23 hours. 2/1/16 RECOMPLETION Continue conducting initial BOPE test to 250/2500 psi: test 7" solid body rams (lower pipe rams) with 7"test joint; test 2-7/8" x 5"VBR's (upper pipe rams)with 3-1/2"test joint; test annular to 250/2500 with 3-1/2"and 7"test joints; conducted Koomey drawdown test(all tested passed). The states right to witness was waived by AOGCC inspector Guy Cook via email on 1/30/16 at 11:23 hours. RD BOPE testing equipment. Pull blanking plug, check for pressure under BPV(no pressure), and pull 3" 'ISA' BPV with dry rod. RU to pull completion. MU landing joint, BOLDS, unseat the tubing hanger, and pull to the rig floor. Circulate bottoms up at 6 BPM. POOH laying down 3-1/2" tubing to SCSSSV and lay down SCSSSV. Recovered all 31 stainless steel bands. RD Camco spooling unit. Continue POOH laying down 3-1/2"tubing from 6,204'to surface. Recovered all 7 GLM's, 254 joints and cut joint= 15.08'. RD Weatherford power tubing tongs. Install the wear ring. PU, MU, and RIH with "G" lock-set RBP to 739' RKB at midnight. 2/2/16 RECOMPLETION Set G Plug @ 3015 ft. Tested Plug to 2500 psi Spotted 80 ft of sand on top of plug. Slip &cut DL. POOH with setting assembly. ND BOPE. RU Hydro-tight grew casing 14 " Speared and stretched casing. Total of 35.5 " Landed at 140 K in E-slips. NU BOPE 2/3/16 RECOMPLETION RIH with bond log assembly logged well from 2942 to surface, Ran 6.11 gauge ring to 2500 ft. RIH with 5 3/4" Chem cutter. cut casing at 1924 ft. POOH with cutter. hanging up from 600 ft to 460 ft. pressured up to 500 psi. tools pulled free.RD slick line. Engaged spear into 7" casing stump. picked up on casing free @ 92K up wt. Begin circulating out artic pack. 2/4/16 RECOMPLETION Continue to circulate out artic pack. ND BOPE pulled E-slips from casing. NU BOPE and shell tested to 1000 psi for 5 min's. POOH with 7"casing good cut. RIH with 8 1/2"Tandem string mill assembly. got bottom mill thru damage at 725 ft un able to make any hole with second mill in damaged area. POOH with BHA# 1 2/5/16 RECOMPLETION Continue to dress up 9 5/8 damage from 725-737 ft W/8 1/2 &8 3/4"string mills. RIH to 1921 ft with 8 1/2 single mill assembly . RIH to 1080 ft with 8 3/4 Mill assembly. Fish flex jt and bull nose lost in the hole. 2/6/16 RECOMPLETION Contune to dress up damage from 725 to 745 ft with tandem 8 1/2" mill string. RIH to top of 7"at 1941 ft. RIH with 7"sizing mill assembly dress up the 7"top to 1942 ft. Pumped Hi-Vis sweep. POOH lay down BHA#8. Wash BOPE stack. Prep to run 7"tie back. 2/7/16 RECOMPLETION RIH with 7"tie back casing assembly. Engaged Bowen casing patch and set. PT casing to 600 psi for 5 Min's. ND BOPE . Install E-slips. land casing with 35 Tension. Cut casing. Nu and test Tbg spool to 250/3000 psi. NU BOPE. change lower rams to VBR's Test rams and break to 250 /2500 psi. RIH with Baker HM cup assembly. 2/8/16 RECOMPLETION Complete cementing in7"tie back with 157 BBL's of AS1 cement. staged last 10 bbls of neat final squeeze pressure=340 PSI Closed Baker HM Cementer assembly and PT to 1250 psi. for 5 min's. POOH with cup assembly. RIH with RCJB assembly clean out to 3005 ft. RIH released RBP @ 3014 ft. Begin laying down drill pipe • • 2/9/16 RECOMPLETION POOH laid down drill pipe and RBP. Load and tally new completion. RIH with Selective packer run. Packer stopped @ 5422 ft. POOH with packer assembly. 2/10/16 RECOMPLETION RIH with scraper to 8006 ft circulated well clean recovered frac sand and Carbolite. added safe lube to system and pumped down hole surface to surface. POOH with scraper. Start in hole with FHL packer assembly on drill pipe 2/11/16 RECOMPLETION RIH with packer and set on drill pipe @ 7895 C/of Elements. PT IA to 2500 psi. for 10 min's Laid down drill pipe. RIH with completion located PBR with seals. @ 7864 ft. RKB. 2/12/16 RECOMPLETION Circulate over to 270 BBL's of Conqor 303 A treated 10#brine. Engaged seals and land hanger. ND BOPE NU &Test tree. Hold operations due to weather 2/13/16 RECOMPLETION Ops on hold for weather condition. Went on phase III 2/14/16 RECOMPLETION Stand by on phase weather conditions 2/15/16 RECOMPLETION Continue to Standby for weather. RU wells cement pump. completed top job on OA/ IA. pull BPV. Freeze protect well with 85 BBLs of diesel. install BPV. Secure well. Rig released @ 23:59 h rs KUP lipD 2K-01 Conoco Phillips +&Dlia Well Attributes Max Angle D TD Alamo Inc " Wellbore API/UWI Field Name Wellbore Status incl(") MO(ftKB) Act Btm(ftKB) Carwcdlhigips 501032010200 KUPARUK RIVER UNIT PROD 50.85 1,800.00 8,516.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2661,3/14/20168.58.54 AM SSSV: NONE 42 11/22/2015 Last WO: 2/15/2016 39.99 5/28/1989 Vertical schematic(actual) • Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,229.0 6/1/2015 Rev Reason:WORKOVER lehallf 2/22/2016 HANGER,31.1 IIP,,ItNl Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread is CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED Casing Descnption OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread �.(y(Y{��! SURFACE 9 5/8 8.921 35.0 3,718.6 2,929.7 36.00 J-55 BTC ,e uprE3�®„y uuu Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7"TIE 7 6.276 31.1 1,945.0 1,703.0 26.00 L-80 563 7....... .........• BACK Casing Description 'OD(in) 'ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 33.0 8,521.0 6,335.5 26.00 J-55 BTC Tubing Strings M CONDUCTOR;38.0-115.0 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..I Set Depth(ND)I...Wt(Ib/ft) Grade Top Connection Tubing-Production 3112 2.992 -2,156.5 8,090.1 5,982.2 9.30 3-55 EUE-MOD Completion Details r Nominal ID I I ii BB Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) 8,027.6 5,933.8 39.81 PBR BAKER 10'80-40 PBR-4"SEAL BORE 3.000 8,041.3 5,944.4 39.61 PACKER 7"x 31/2"Baker HB 47B4 Retrievable Packer(Shear 2.890 F L ' ? Release 60klbs) 8,078.0 5,972.8 39.07 NIPPLE OTIS XN NIPPLE 2750 PRODUCTION 7'TIE BACK; Jl 8,089.3 5,981.5 38.90 SOS BAKER SHEAR OUT SUB 2.984 31.2-1,945.0 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection ila 3-1/2 Gas Lift 3 1/2 2.992 31.2 7,884.8 5,826.1 9.30 L-80 EUE 8rd GAS LIFT;3,104.4 Completion 2016 RWO Completion Details Nominal ID • Top(ftKB) Top(TVD)(ftKB) Top Inel(°) Item Des Com (in) SURFACE,35.x3,7/86-II 31.2 31.1 0.12 HANGER FMC Gen IV Tubing Hanger 3.000 7,862.2 5,809.4 42.35 LOCATOR Baker Locator sub w/7-ft space out 2.910 7,863.2 5,810.1 ' 42.34 ISEAL ASSY Baker 20'80-40 seal assembly w/Locator 2.990 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection GAS LIFT,4,805.9 STACKER PACKER 3 1/2 2.992 7,869.3 8,003.0 5,915.0 9.30 L-80 EUE 8rd II 2016 RWO Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB( Top Incl(a) Item Des Corn (in) .. 7,869.3 5,814.7 42.31 PBR Baker 20'80-40 PBR 4.000 GAS LIFT;8,151.2 7,892.0 5,831.5 42.18 PACKER 7"x 3 1/2"Baker FHL 47B2 Retrievable Packer(Shear 2.960 Release 60klbs) 7,945.5- 5,871.4 41.27 NIPPLE CAMCO 3.5 X 2813 DS nipple 2.813 7,994.8 5,908.7 40.32 OVERSHOT Baker Poorboy over shot W/7.8'swallow 3.630 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) (") Des Corn Run Date ID)in) GAS LIFT 7146.4 r'; 4 7,936.0 5,864.2 41.45 Tubing Plug Standard Ball 8 Rod w/1-3/8"Fishing Neck set in a 2/11/2016 2.812"CS lock with modified G fishing neck and short RHC-M plug body. 8,074.0 5,969.6 39.12 CATCHER -OAL 48.5" 1/17/2016 8,078.0 5,972.7 39.07 PLUG PXN PLUG 1/17/2016 Perforations&Slots Shot GAS LIFT;7,805.3 Dens Top(ND) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Corn 8,260.0 8,292.0 6,117.4 6,143.6 A-4,2K-01 4/2/1990 4.0'IPERF '180 deg.Phasing,4.5" HCS LOCATOR;7,862.2 1111 SEAL ASSY,7,863.2` -_ Mandrel Inserts - PBR,7,869.3 St - at, PACKER;7,892.0 on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sew Type Type (in) (psi) Run Date Corn 1 3,104.4 2,510.6 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 2/12/2016 2 4,805.9 3,692.3 Camco MMG 1 1/2 GAS UFT DMY RK 0.000 0.0 2/12/2016 Tubing Plug;7,936.0 _-, 3 6,151.2 4,603.3 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 2/12/2016 NIPPLE;7,045.5 4 7,146.4 5,293.9 Camco MMG 1 1/2 GAS UFT SOV RKP 0.000 0.0 2/12/2016 Shea red 5 7,805.3 5,7674 Camco MMG 11/2 GAS LIFT DMY RK 0.000 0.0 2/12/2016 Notes:General&Safety End Date Annotation 10/28/2010 NOTE:View Schematic w/Alaska Schematic9.0 10/23/2012 NOTE:IDENTIFIED PACKER LEAK @ 8041'w/TEMPERATURE OVERSHOT;7,094.7 fff[ 1, ,I PBR;8,027.6 PACKER;8,041.3 «.. CATCHER;8,074.0 ,Ill,/ NIPPLE;8,078.0 /� PLUG;8,078.0 SOS;8,089.3 i IPERF;8,260.68,292.0- PRODUCTION;1,941.68,521.0 • • Operations Summary (with Timelog Depths) ;_, &Nle 2K-01 r- ConocoPhillips AWka Rig: NABORS 7ES 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) 1/30/2016 1/30/2016 1.00 MIRU MOVE MOB P PJSM. Jack up pits,remove rig mats, 0.0 0.0 04:30 05:30 pull pits away from sub,and stage at the edge of the pad. . 1/30/2016 1/30/2016 1.00 MIRU MOVE MOB P PJSM. Jack up the sub,remove mats, 0.0 0.0 05:30 06:30 pull the sub off well 2K-25,and stage at the edge of the pad. 1/30/2016 1/30/2016 2.00 MIRU MOVE RURD P Clean up around well 2K-25,hang 2K- 0.0 0.0 06:30 08:30 01 tree in the cellar,set mats around 2K-01,and lay down herculite. 1/30/2016 1/30/2016 1.50 MIRU MOVE MOB P PJSM. Spot the sub over well 2K-01. 0.0 0.0 08:30 10:00 1/30/2016 1/30/2016 1.50 MIRU MOVE MOB P PJSM. Spot the pits to the sub,spot 0.0 0.0 10:00 11:30 the cuttings tank,and spot the mud shack. 1/30/2016 1/30/2016 3.50 MIRU MOVE RURD P Set up berming around the sub,pits, 0.0 0.0 11:30 15:00 and cuttings tank. Hook up interconnect. Finish rig acceptance check list. Rig accepted at 15:00 hours. 1/30/2016 1/30/2016 2.00 MIRU WELCTL RURD P Install secondary annulus valve,rig up 0.0 0.0 15:00 17:00 lines in the cellar,and take on 8.7 ppg seawater to the pits. 1/30/2016 1/30/2016 1.00 MIRU WELCTL MPSP P Bring lubricator to the rig floor, RU 0.0 0.0 17:00 18:00 lubricator,and PT to 1000 psi. The master valve is leaking. Call out the valve crew to service the master valve. 1/30/2016 1/30/2016 2.00 MIRU WELCTL WAIT T Wait for valve crew to arrive. Valve 0.0 0.0 18:00 20:00 crew serviced the master valve. 1/30/2016 1/30/2016 1.00 MIRU WELCTL MPSP P Pull the 3"'ISA'BPV. RD lubricator 0.0 0.0 20:00 21:00 and lay down lubricator. Initial well pressures: Tubing=500 psi, IA=500 psi,and OA=550 psi. 1/30/2016 1/30/2016 0.75 MIRU WELCTL RURD P RU circulating lines for well kill 0.0 0.0 21:00 21:45 operation. 1/30/2016 1/30/2016 0.25 MIRU WELCTL SFTY P PJSM with rig crew for well kill 0.0 0.0 21:45 22:00 operation. 1/30/2016 1/30/2016 0.50 MIRU WELCTL KLWL P PT lines to 3000 psi(good test). 0.0 0.0 22:00 22:30 Bleed the tubing and IA to 0 psi. Shut in the well to perform draw down test (DDT). The IA pressure increased 10 psi in 15 minutes. DDT failed. 1/30/2016 1/31/2016 1.50 MIRU WELCTL KLWL P Begin the well kill by circulating 8.7 0.0 0.0 22:30 00:00 ppg kw NaCL down the tubing taking returns out to the kill tank. Got 8.6+ ppg to surface(312 bbls and 298 bbls in the kill tank)and kill tank at 80% capacity(ICP=222 psi at 2 BPM and FCP=995 psi at 5 BPM). Shut down the pumps and blow down the line to the kill tank. 1/31/2016 1/31/2016 0.75 MIRU WELCTL KLWL P Line up to the pits and circulate back 0.0 0.0 00:00 00:45 to the pit through the gas buster at 3 BPM=320 psi. Got clean 8.7 ppg to the pits after 15 bbls pumped. Shut the well in. SimOps: Empty the kill tank. Page 1/13 Report Printed: 3/15/2016 • • Drilling Operations Summary (with Timelog Depths) Wells 2K-01 ConocoPhitlips 041;90:5 Rig: NABORS 7ES 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) 1/31/2016 1/31/2016 0.25 MIRU WELCTL OWFF P Monitor the well pressure: Tubing and 0.0 0.0 00:45 01:00 IA=40 psi. IA still has some diesel. 1/31/2016 1/31/2016 1.00 MIRU WELCTL KLWL P Line back up to the kill tank and 0.0 0.0 01:00 02:00 circulate 145 bbls of 8.7 ppg down the tubing taking returns out the IA to the kill tank(ICP =220 psi at 2 BPM and FCP=1030 psi at 5 BPM). Got good 8.7 ppg to surface. Shut in the well. 1/31/2016 1/31/2016 4.00 MIRU WELCTL OWFF T Monitor the well pressures. Initial well 0.0 0.0 02:00 06:00 pressures: Tubing=15 psi and IA= 20 psi. Final well pressures: Tubing= 310 psi and IA=305 psi. 1/31/2016 1/31/2016 5.00 MIRU WELCTL COND T Load the pits with 11.0 ppg brine and 0.0 0.0 06:00 11:00 mix with 8.7 ppg to make 10.0 ppg brine. SimOps: Service the top drive and work on PM's. 1/31/2016 1/31/2016 2.00 MIRU WELCTL KLWL T Bleed down tubing to 0 psi(fluid 0.0 0.0 11:00 13:00 packed),bleed down IA to 70 psi and got fluid back from the IA. Pumped 10.0 ppg Brine at 5 bpm until 10.0 ppg brine at surface(ICP=880 psi and FCP= 1215 psi). Blow down all circulating lines. 1/31/2016 1/31/2016 0.50 MIRU WELCTL OWFF P Observe the well for flow for 30 0.0 0.0 13:00 13:30 minutes;the well is static. 1/31/2016 1/31/2016 0.50 MIRU WHDBOP MPSP P Install 3"'ISA'BPV with dry rod. 0.0 0.0 13:30 14:00 1/31/2016 1/31/2016 2.00 MIRU WHDBOP NUND P ND Tree, ND the tubing head adapter, 0.0 0.0 14:00 16:00 clean top of the tubing hanger,and intsall blanking plug(10-1/4 turns). 1/31/2016 1/31/2016 5.50 MIRU WHDBOP NUND P NU DSA and NU the BOP stack. 0.0 0.0 16:00 21:30 Torque connections,install riser,air up the air boots,and center stack. Re -torque all connections due to the amount of pull needed to center the BOP stack. 1/31/2016 1/31/2016 0.50 MIRU WHDBOP NUND P Swap annular hoses with blinds and 0.0 0.0 21:30 22:00 function test then swap back to normal configuration. 1/31/2016 1/31/2016 1.00 MIRU WHDBOP RURD P PU 3-1/2"and 7"doughnut test joints 0.0 0.0 22:00 23:00 and mark positioning for testing. MU BOPE testing equipment. Fill testing equipment with fresh water. Shell test the BOP stack to 250/2500 psi. Page 2/13 Report Printed: 3/15/2016 • l A"Ill sg Operations Summary (with Timelog Depths) &Wells 2K-01 ConocoPhillips Rig: NABORS 7ES 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) 1/31/2016 2/1/2016 1.00 MIRU WHDBOP BOPE P Conduct initial BOPE test to 250/2500 0.0 0.0 23:00 00:00 psi: test 7"solid body rams(lower pipe rams)with 7"test joint;test 2-7/8" x 5"VBR's(upper pipe rams)with 3- 1/2"test joint;test annular to 250/2500 with 3-1/2"and 7"test joints; conducted Koomey drawdown test(all tested passed). The states right to witness was waived by AOGCC inspector Guy Cook via email on 1/30/16 at 11:23 hours. Tests: 1) Blind Rams,2"Demco Kill,Upper IBOP,Outer Test Spool,Chokes 1,2, 3,&16(Passed) 2) Blind Rams, HCR Kill, Inner Test Spool, Lower IBOP,Chokes 4,5,&6 (Passed) Page 3/13 Report Printed: 3/15/2016 • • Drilling Operations Summary (with Timelog Depths) &Wells 2K-01 Co oc iUU ps Rig: NABORS 7ES 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) 2/1/2016 2/1/2016 4.50 MIRU WHDBOP BOPE P Continue conducting initial BOPE test 0.0 0.0 00:00 04:30 to 250/2500 psi: test 7"solid body rams(lower pipe rams)with 7"test joint;test 2-7/8"x 5"VBR's(upper pipe rams)with 3-1/2"test joint;test annular to 250/2500 with 3-1/2"and 7" test joints;conducted Koomey drawdown test(all tested passed). The states right to witness was waived by AOGCC inspector Guy Cook via email on 1/30/16 at 11:23 hours. Tests: 3) Blind Rams, Manual Kill, Dart Valve, Inner Test Spool Valve,Chokes 7.8,&9(Passed) 4) Super Choke and Manual Adjustable Choke(Passed) 5) Blind Rams, Manual Kill, Inner Test Spool Valve,Chokes 8, 10,&11 (Passed) 6) Blind Rams,Manual Kill,Chokes 8, 12, 13,&15(Passed) 7) Annular with 3-1/2"doughnut test joint,3-1/2"EUE 8rd TIW, Manual Kill, Choke 14(Passed) 8) Upper Pipe Rams with 3-1/2" doughnut test joint,3-1/2"EUE 8rd TIW,Choke HCR, Manual Kill (Passed) 9) Lower Pipe Rams with 7"doughnut test joint,3-1/2"HT-38 TIW(Passed) 10)Annular with 7"doughnut test joint, Manual Choke(Passed) Conduct Koomey Draw Down Test: Starting Accumulator Pressure=3000 psi Accumulator Pressure After Closer= 1800 psi Pressure Gain of 200 psi= 15 seconds Full System=78 Seconds Average N2(5 Bottles)= 1985 psi 2/1/2016 2/1/2016 0.50 MIRU WHDBOP RURD P Blow down BOPE testing equipment 0.0 0.0 04:30 05:00 and RD BOPE testing equipment. 2/1/2016 2/1/2016 1.00 MIRU WHDBOP MPSP P Pull blanking plug with test joint,lay 0.0 0.0 05:00 06:00 down blanking plug,and lay down the test joint. Check for pressure under BPV(no pressure)and pull 3"ISA BPV with dry rod. 2/1/2016 2/1/2016 0.50 COMPZN RPCOMP RURD P RU Weatherford power tubing tongs 0.0 0.0 06:00 06:30 and Camco spooling unit. RU 3-1/2" tubing elevators. 2/1/2016 2/1/2016 0.50 COMPZN RPCOMP PULL P MU landing joint to tubing hanger, 0.0 8,012.0 06:30 07:00 BOLDS,unseat tubing hanger at 105K,and pull hanger to the rig floor (PU=95K and SO=80K). 2/1/2016 2/1/2016 1.00 COMPZN RPCOMP CIRC P Circulate bottoms up at 6 BPM=880 8,012.0 8,012.0 07:00 08:00 psi Page 4/13 Report Printed: 3/15/2016 • • [drilling Operations Summary (with Timelog Depths) &Wells 2K-01 ConocoPhillips Rig: NABORS 7ES 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) 2/1/2016 2/1/2016 0.50 COMPZN RPCOMP RURD P Blow down top drive and rig down 8,012.0 8,012.0 08:00 08:30 landing joint. 2/1/2016 2/1/2016 3.50 COMPZN RPCOMP PULL P POOH laying down 3-1/2"tubing from 8,012.0 6,204.0 08:30 12:00 8012'to 6204'RKB spooling control line. Recovered all 31 stainless steel bands. Lay down SCSSSV. 2/1/2016 2/1/2016 0.50 COMPZN RPCOMP RURD P Rig down Camco spooling unit. 6,204.0 6,204.0 12:00 12:30 2/1/2016 2/1/2016 0.50 COMPZN RPCOMP RGRP T Change out hydraulic hose on skate. 6,204.0 6,204.0 12:30 13:00 2/1/2016 2/1/2016 8.00 COMPZN RPCOMP PULL P Continue POOH laying down 3-1/2" 6,204.0 0.0 13:00 21:00 tubing from 6,204'to surface. Recovered all 7 GLM's,254 joints and cut joint= 15.08'. Clean and clear floor. 2/1/2016 2/1/2016 0.50 COMPZN RPCOMP RURD P RD Weatherford power tubing tongs. 0.0 0.0 21:00 21:30 Change elevators from 3-1/2"tubing to 3-1/2"DP. 2/1/2016 2/1/2016 0.50 PROD1 WELLPR RURD P MU wear ring running tool to a joint of 0.0 0.0 21:30 22:00 DP,install wear ring, lay down wear ring running tool,and lay down joint of DP. 2/1/2016 2/1/2016 1.50 PROD1 WELLPR BHAH P PU and MU"G"lock-set RBP and nine 0.0 298.0 22:00 23:30 4-3/4"DC's. 2/1/2016 2/2/2016 0.50 PROD1 WELLPR PULD P RIH with 3-1/2"DP from the pipe shed 298.0 739.0 23:30 00:00 from 298'to 739'RKB at midnight(PU =45K and SO=45K). 2/2/2016 2/2/2016 2.50 PROD1 WELLPR PULD P Continue RIH with 3-1/2"DP from the 739.0 3,009.0 00:00 02:30 pipe shed from 739'to 3009'RKB(PU =85K and SO=60K). 2/2/2016 2/2/2016 1.50 PROD1 WELLPR MPSP P Set"G"lock-set RBP at 3020'RBK 3,009.0 2,924.0 02:30 04:00 (center of element)with top at 3015' RKB. Release from RBP and stand back one stand of DP. PT the RBP to 2500 psi for 10 minutes(good test). Blow down the TD. 2/2/2016 2/2/2016 4.00 PROD1 WELLPR OTHR P Dump twenty 60 lb sacks of sand on 2,924.0 2,924.0 04:00 08:00 top of the RBP. 2/2/2016 2/2/2016 0.50 PROD1 WELLPR CIRC P Pumped a drill pipe volume to clear 2,924.0 2,830.0 08:00 08:30 pipe of any sand @ 2 BPM @ 110 psi. 2/2/2016 2/2/2016 1.50 PROD1 WELLPR SLPC P Slip and cut DL. 2,830.0 2,830.0 08:30 10:00 2/2/2016 2/2/2016 0.50 PROD1 WELLPR SVRG P Service and inspect top drive 2,830.0 2,830.0 10:00 10:30 2/2/2016 2/2/2016 2.50 PROD1 WELLPR TRIP P Tagged sand plug©2976'and 2,830.0 0.0 10:30 13:00 POOH W/DP 2/2/2016 2/2/2016 0.50 PROD1 CSGRCY RURD P Empty stack and pulled wear ring 0.0 0.0 13:00 13:30 2/2/2016 2/2/2016 2.50 PROD1 CSGRCY NUND P ND BOPE. 0.0 0.0 13:30 16:00 2/2/2016 2/2/2016 1.00 PROD1 CSGRCY RURD P RU PESI Hydro-tight system 0.0 0.0 16:00 17:00 2/2/2016 2/2/2016 2.00 PROD1 CSGRCY CUTP P Relieved casing buckling W/Hydro- 0.0 0.0 17:00 19:00 tight system. 14 inches of growth. Page 5/13 Report Printed: 3/15/2016 • • Drilling Operations Summary (with Timelog Depths) &Wells 2K-01 Conoccehitlips Rig: NABORS 7ES 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) 2/2/2016 2/2/2016 1.50 PROD1 CSGRCY CUTP P Speared casing and pulled 150 K 0.0 0.0 19:00 20:30 sting weight casing quit moving at 135K. Re-land on new slips.with 140 K Total growth after landing=35.5" Released spear assembly 2/2/2016 2/2/2016 1.00 PROD1 CSGRCY CUTP P Cut off 2 ft of 7"stump with sawsall 0.0 0.0 20:30 21:30 cutter 2/2/2016 2/3/2016 2.50 PROD1 CSGRCY NUND P NU BOPE stack 0.0 0.0 21:30 00:00 2/3/2016 2/3/2016 3.00 PROD1 CSGRCY NUND P Continue to NU BOPE and riser.Shell 0.0 0.0 00:00 03:00 test to 1000 psi for 5 min.Good test. 2/3/2016 2/3/2016 4.00 PROD1 CSGRCY DSL P PJSM. RU Schlumberger digital slick- 0.0 0.0 03:00 07:00 line and install Dutch riser 2/3/2016 2/3/2016 12.50 PROD1 CSGRCY DSL P Pick up Bond Log assembly and RIH 0.0 0.0 07:00 19:30 sat down at 2617 ft work down. Logged from 2942 ft to surface. Reviewed log for TOC @ 2700 ft good bond.Stringers to 1970',RIH with 6.11 gauge ring. to 2500 ft.RIH with 5 3/4" chemical cutter.made cut at 1924 ft. POOH with cutter. Began hanging up at 600 ft to 460 ft. Pressured up to 500 psi on well bore toll string came free. continue to POOH. 2/3/2016 2/3/2016 1.50 PROD1 CSGRCY DSL P Hung back slickline and pulled Dutch 0.0 0.0 19:30 21:00 riser. 2/3/2016 2/3/2016 1.50 PROD1 CSGRCY FISH P Pick up 5 3/4 Itco spear asssembly 0.0 1,924.0 21:00 22:30 engaged 7"casing stump.Pick up casing 92 K up wt. 2/3/2016 2/4/2016 1.50 PROD1 CSGRCY CIRC P Circulated out artic pack @ 3 BPM @ 1,924.0 1,924.0 22:30 00:00 220 psi.with 30 bbls 100+/Hi-Vis sweep.followed by 140°fresh water. 2/4/2016 2/4/2016 1.50 PROD1 CSGRCY CIRC P Continue to circulate out artic pack 1,924.0 1,924.0 00:00 01:30 with 140°fresh water.@ 5 BPM @ 150 psi. 2/4/2016 2/4/2016 1.50 PROD1 CSGRCY NUND P ND BOPE and pull E-slips. 1,924.0 1,924.0 01:30 03:00 2/4/2016 2/4/2016 2.00 PROD1 CSGRCY NUND P NU BOPE and shell test to 1000 psi. 1,924.0 1,924.0 03:00 05:00 for 5 min's 2/4/2016 2/4/2016 6.00 PROD1 CSGRCY PULL P POOH with 7"casing. Recovered 24 1,924.0 0.0 05:00 11:00 stabilizers 2/4/2016 2/4/2016 0.50 PROD1 CASING RURD P Installed wear bushing 0.0 0.0 11:00 11:30 2/4/2016 2/4/2016 1.00 PROD1 CASING PULD P Laid down 4 3/4 drill collars. 0.0 0.0 11:30 12:30 2/4/2016 2/4/2016 2.50 PROD1 CASING BHAH P Picked pu 8 1/2"tandem mill 0.0 228.0 12:30 15:00 assembly.BHA#1 2/4/2016 2/4/2016 1.00 PROD1 CASING TRIP P RIH with BHA#1.Tagged @ 732' 228.0 732.0 15:00 16:00 Mill depth at 725' 2/4/2016 2/4/2016 5.50 PROD1 CASING MILL P Est.parameters: 732.0 744.0 16:00 21:30 Circulation @ 9BPM @ 185 psi.F/TQ @ 80 RPM's=1.3-4.2 K W/3-5 K on mill.as per Baker rep.worked bottom mill thru 725-38 ft bull nose to 744' unable to make any hole with upper mill.putting up to 10 K on mill. circulated clean. Page 6/13 Report Printed: 3/15/2016 • • • - Operations Summary (with Timelog Depths) :,: &Welts 2K-01 ConocoPhillips Rig: NABORS 7ES 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) 2/4/2016 2/4/2016 1.00 PROD1 CASING TRIP P POOH with BHA#1 744.0 228.0 21:30 22:30 2/4/2016 2/5/2016 1.50 PROD1 CASING BHAH P Swap out BHA#1,8 1/2 tandem mill 228.0 22:30 00:00 assembly with 8 1/2 X 8 3//4"Milling assembly.BHA#3 2/5/2016 2/5/2016 0.50 PROD1 CASING BHAH P Continue to RIH with BHA#2: 238.0 238.0 00:00 00:30 Tandem milling assembly. 2/5/2016 2/5/2016 0.50 PROD1 CASING SVRG P Service and inspect Top drive 238.0 238.0 00:30 01:00 2/5/2016 2/5/2016 1.00 PROD1 CASING TRIP P RIH with BHA#2 238.0 707.0 01:00 02:00 2/5/2016 2/5/2016 4.00 PROD1 CASING MILL P Est Parameters: 707.0 754.0 02:00 06:00 Circulation @ 8.5 BPM @ 150 psi. F/TQ @ 85 RPM's=1500 Ft/LB's Up wt=56 K.Down wt=55 K Began milling operation.W/2-3 K on mill Torque @ 5.8 K-6.8 K Ft/LB's Increased wt to 8-10K with 8 3/4"mill bottom at 725 ft still unable to mill beyond 725'. Pumped 30 BBI hi vis sweep continue milling ops.with out success. 2/5/2016 2/5/2016 1.00 PROD1 CASING TRIP P POOH with BHA#2 754.0 238.0 06:00 07:00 2/5/2016 2/5/2016 1.50 PROD1 CASING BHAH P Stood back DC's.lost lower flex jt with 228.0 228.0 07:00 08:30 bull nose.Make 8 1/2 milling assembly mill assembly 2/5/2016 2/5/2016 0.50 PROD1 CASING TRIP P RIH to 707 ft.with BHA#3 228.0 707.0 08:30 09:00 2/5/2016 2/5/2016 3.00 PROD1 CASING MILL P Obtained parameters: 707.0 986.0 09:00 12:00 8 BPM @ 140 psi.up wt=50 K, Dwn wt=50 K Rotaion wt=50 k F/TQ @ 8 RPM's=2.5 K worked mill from 743 ft to 792'with 15 K on mill. slid mill to 986 ft. 2/5/2016 2/5/2016 1.00 PROD1 CASING TRIP P Continue to RIH with mill assembly to 986.0 1,923.0 12:00 13:00 1923.0 circulating down last 50 ft@ 4 BPM @ 110 psi. 2/5/2016 2/5/2016 1.00 PROD1 CASING TRIP P POOH with BHA#3 1,923.0 228.0 13:00 14:00 2/5/2016 2/5/2016 1.50 PROD1 CASING BHAH P Swap out 8 1/2 mill to 8 3/4 mill 228.0 228.0 14:00 15:30 assembly BHA#4 2/5/2016 2/5/2016 0.50 PROD1 CASING TRIP P RIH with BHA#4.Tagged at 735 ft. 228.0 735.0 15:30 16:00 2/5/2016 2/5/2016 1.00 PROD1 CASING MILL P Est Parameters:8 BPM @ 140 psi.80 735.0 1,080.0 16:00 17:00 RPM at 3.6 FT/Lbs torque.worked mill thru damage from 735 to 765 ft. with 1-3 K on mill.continue to RIH with 8 3/4 mill to 1080 ft. 2/5/2016 2/5/2016 0.50 PROD1 CASING TRIP P POOH with BHA#4 1,080.0 228.0 17:00 17:30 2/5/2016 2/5/2016 3.00 PROD1 CASING BHAH T Laid down BHA#4 and made up BHA 228.0 127.0 17:30 20:30 #5:8 1/8"Bowen overshot with 6 3/8"basket grapple on 4 3/4 Drill collars 2/5/2016 2/5/2016 1.00 PROD1 CASING TRIP T RIH with BHA#5 pushed thru 127.0 1,920.0 20:30 21:30 damage with 8 K down wt.continue to RIH. Page 7/13 Report Printed: 3/15/2016 i • Drilling Operations Summary (with Timelog Depths) &Webs 2K-01 Conti coPhitlips , Rig: NABORS 7ES 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(ftK8)f 2/5/2016 2/5/2016 0.75 PROD1 CASING FISH T Broke circulation @ 4 BPM @ 100 1,920.0 1,933.0 21:30 22:15 psi.Tagged @ 1923 ft. Increased rate to 8 BPM @ 250 psi.washed down to 1932 ft.worked overshot over the top of fish.pressure increased to 450 PSI. SDP.engaed over shot.Open jars. Pulled frish free @ 85 K.27K over string. 2/5/2016 2/5/2016 0.75 PROD1 CASING CIRC T Circulated 1.5 hole volume.recovering 1,933.0 1,933.0 22:15 23:00 artic pack 2/5/2016 2/6/2016 1.00 PROD1 CASING TRIP T 'POOH with BHA#5 1,933.0 127.0 23:00 00:00 2/6/2016 2/6/2016 1.00 PROD1 CASING BHAH T Laid down BHA#5 and fish. 127.0 0.0 00:00 01:00 2/6/2016 2/6/2016 1.00 PROD1 CASING BHAH P Make up BHA#6:8 1/2 Tandem 0.0 229.0 01:00 02:00 milling assembly. 2/6/2016 2/6/2016 0.50 PROD1 CASING TRIP P RIH with BHA#6 229.0 712.0 02:00 02:30 2/6/2016 2/6/2016 4.00 PROD1 CASING MILL P Est parameters: 712.0 745.0 02:30 06:30 Circulating @ 5.5 BPM @ 100 psi. F/TQ @80 RPM's= 1.3K. Began milling operations.W/3-5 K torque,3-5 K mill wt.worked mill @ 732 ft mill depth unable to make any hole. 2/6/2016 2/6/2016 0.50 PROD1 CASING TRIP P POOH with BHA#6 745.0 229.0 06:30 07:00 2/6/2016 2/6/2016 1.50 PROD1 CASING BHAH P Reconfigure tandem 8 1/2 mills 229.0 239.0 07:00 08:30 assembly with flex jt in between. 2/6/2016 2/6/2016 0.50 PROD1 CASING TRIP P RIH with BHA#7 239.0 720.0 08:30 09:00 2/6/2016 2/6/2016 1.50 PROD1 CASING MILL P Worked mils thru 735 ft thru 775 ft. 720.0 1,978.0 09:00 10:30 RIH with mill assembly to 1942 ft tagged with 5 K. Down drag @ 734-36 8K,743-745 15 K 2/6/2016 2/6/2016 0.50 PROD1 CASING CIRC P Circulated hole clean @ 10 BPM @ 1,978.0 1,978.0 10:30 11:00 380 psi. 2/6/2016 2/6/2016 1.00 PROD1 CASING TRIP P POOH with BHA#7 1,978.0 239.0 11:00 12:00 2/6/2016 2/6/2016 1.50 PROD1 CASING BHAH P Lay down BHA 7. 239.0 0.0 12:00 13:30 2/6/2016 2/6/2016 0.50 PROD1 CASING SVRG P Service and inspect top drive 0.0 0.0 13:30 14:00 2/6/2016 2/6/2016 1.00 PROD1 CASING BHAH P Picked up BHA#8 sizing mill 0.0 213.0 14:00 15:00 assembly. 2/6/2016 2/6/2016 1.00 PROD1 CASING TRIP P RIH with BHA#8 213.0 1,915.0 15:00 16:00 2/6/2016 2/6/2016 2.50 PROD1 CASING MILL P Est circulation @ 3 BPM @ 60 psi. 1,915.0 1,947.0 16:00 18:30 washed down to 1940 ft mill show depth to 1945 ft.dressed of 7"casing stump to 1942 ft.pumped Hi-Vis sweep. 2/6/2016 2/6/2016 1.00 PROD1 CASING TRIP P POOH with BHA#8 1,947.0 213.0 18:30 19:30 2/6/2016 2/6/2016 1.50 PROD1 CASING BHAH P Lay down BHA#8 and 6 1/4 drill 213.0 0.0 19:30 21:00 collars 2/6/2016 2/6/2016 1.00 PROD1 CASING WWWH P Pulled wear ring and flushed BOPE 0.0 0.0 21:00 22:00 stack Page 8/13 Report Printed: 3/15/2016 i • Drilling Operations Summary (with Timelog Depths) { &Wenis 2K-01 ConocoPhillips ,L.; Rig: NABORS 7ES 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) 2/6/2016 2/6/2016 0.50 PROD1 CASING RURD P RU Casing equipment. 0.0 0.0 22:00 22:30 2/6/2016 2/6/2016 0.50 PROD1 CASING SVRG P Service and inspect top drive 0.0 22:30 23:00 2/6/2016 2/7/2016 1.00 PROD1 CASING PUTB P PJSM.Begin running casing. 0.0 0.0 23:00 00:00 2/7/2016 2/7/2016 3.50 PROD1 CASING PUTB P Picked up Bowen casing patch and 0.0 1,945.0 00:00 03:30 HM cementer assembly. RIH with 563 Hydril 7"casing . installing 8 1/8" stabilizers on every jt except landing jt. Total count=44 Took 10 K down bumping patch thru 727 ft to 37' Engaged Patch at 1945 ft.with swallow. Pulled 30 over set patch.Up wt=72 K down wt=62 K Pressure tested to 500 psi for 5 Min's good test. 2/7/2016 2/7/2016 1.00 PROD1 CASING NUND P Pulled stack clear of fluids. ND BOPE 0.0 0.0 03:30 04:30 2/7/2016 2/7/2016 3.00 PROD1 CASING CUTP P Install E slips.and land casing.with 0.0 0.0 04:30 07:30 36K tension.Cut off stump.=23.34-ft 2/7/2016 2/7/2016 6.00 PROD1 CASING NUND P NU Tbg spool and test 250/3000 0.0 0.0 07:30 13:30 psi.for 10 min's good test. NU BOPE 2/7/2016 2/7/2016 3.00 PROD1 CASING BOPE P Changed lower rams from 7"to 2 7/8 0.0 0.0 13:30 16:30 X 5"VBR.Test lower rams and flange break to 250/2500. 2/7/2016 2/7/2016 1.00 PROD1 CASING RURD P RD testing equipment and install wear 0.0 0.0 16:30 17:30 ring 2/7/2016 2/7/2016 1.50 PROD1 CEMENT BHAH P PJSM:Pick up Baker 7"Cup tool W/ 0.0 128.0 17:30 19:00 RPC assembly.as per Baker. 2/7/2016 2/7/2016 4.50 PROD1 CEMENT TRIP P RIH with cup assembly. Installed dart 128.0 1,931.0 19:00 23:30 and pumped into place at 1/2 BPM. Shear off lower plug @ 1290 psi. Pressured up to 3 K shift sleeve. Tested cup assembly to 2800 psi.for 5 min's spaced out assembly and engaged tool into HMCV.Sheared HM cementer @ 2150. 2/7/2016 2/8/2016 0.50 PROD1 CEMENT CIRC P Circulated 30 BBL of sea water at 3.5 1,931.0 1,931.0 23:30 00:00 BPM @ 450 psi good circulation. Page 9/13 Report Printed: 3/15/2016 • • riii-rsg Operations Summary (with Timelog Depths) w &Wen 2K-01 CrkwcoPhiilips Rig: NABORS 7ES 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) 2/8/2016 2/8/2016 3.50 PROD1 CEMENT CMNT P PJSM. 1,931.0 1,931.0 00:00 03:30 Pumped 5 BBL's of fresh water ahead. Test lines to 4000 psi. Mix and pump 10 bbls of AS1 neat followed by 137 bbl's of AS1 pressure net, 10 bbls of AS 1 neat. 1 bbl of fresh SD pumps for 10 min's to let cement jell.displace 5 more bbls of fresh well pressure at 20 psi.let cement stand for 10 more min's.pumped 4 bbls of fresh @ 1 BPM @ 340 psi.DPP.CIP @ 02:25 hrs. Initial circulation @ 3.5 BPM 340 psi DP pressure.cement to surface with 81 bbls of cement pump.slowed rate to 2.5 BPM @ 350 psi DPP.slowed rate to 1.5BPM©70 psi.slowed rate to 1BPM @ 20 psi with 127 bbls of cement away. Closed HMCV and PT to 1250 psi for 5 min's Sheared out of cementer.Reversed circulated 25 bbls of Inhibited sea water followed by.75 BBL's of sea water. 2/8/2016 2/8/2016 2.50 PROD1 CEMENT TRIP P POOH with HMCV cup cementing 1,931.0 0.0 03:30 06:00 assembly. 2/8/2016 2/8/2016 1.00 PROD1 CEMENT RURD P Clear all lines from floor and cellar. 0.0 0.0 06:00 07:00 2/8/2016 2/8/2016 1.50 PROD1 WELLPR BHAH P PU BHA#9: RCJB 0.0 146.0 07:00 08:30 2/8/2016 2/8/2016 1.50 PROD1 WELLPR TRIP P RIH with BHA#9 146.0 2,889.0 08:30 10:00 2/8/2016 2/8/2016 0.50 PROD1 WELLPR SVRG P Service and inspect top drive 2,889.0 2,889.0 10:00 10:30 2/8/2016 2/8/2016 1.50 PROD1 WELLPR COND P Continue to load 10 ppg NaCI on rig 2,889.0 2,889.0 10:30 12:00 and blend for wt. 2/8/2016 2/8/2016 3.00 PROD1 WELLPR CIRC P Tagged top of sand at 2960 ft 2,889.0 3,005.0 12:00 15:00 Swapped well over to 10# brine. Cleaned out fill to 3005 ft.@ 7 BPM @ 1300 psi. 2/8/2016 2/8/2016 1.00 PROD1 WELLPR TRIP P POOH with BHA#9 3,005.0 146.0 15:00 16:00 2/8/2016 2/8/2016 2.00 PROD1 WELLPR BHAH P Laid down BHA#9: Recovered 146.0 0.0 16:00 18:00 casing chunks. 2/8/2016 2/8/2016 1.00 PROD1 WELLPR PRTS P Pressure test IA/Cmt to 1600 psi for 0.0 0.0 18:00 19:00 15 min's.lost 300 psi in the 15 min's. 100 psi drop per 5 min. We took 2 BBIs to fill Est TOC @ 68 ft. 2/8/2016 2/8/2016 1.50 PROD1 WELLPR TRIP P RIH with retrieving head for RBP. 0.0 3,008.0 19:00 20:30 Tagged sand 2/8/2016 2/8/2016 0.50 PROD1 WELLPR CIRC P broke circulation at 3 BPM @ 100 psi. 3,008.0 3,014.0 20:30 21:00 Increased rate to 8 BPM circulating down to 3014 ft.circulated hole clean. Page 10/13 Report Printed: 3/15/2016 • 0 t7lrlll Operations Summary (with Timelog Depths) ~:# &Wells 2K-01 ConocoPhillips Rig: NABORS 7ES 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), 2/8/2016 2/8/2016 1.00 PROD1 WELLPR MPSP P Engaged RBP and opened equalizing 3,014.0 3,030.0 21:00 22:00 valve.let stand 5 min's.Released plug and let equalized/relax elements. dropped past plug depth. 2/8/2016 2/9/2016 2.00 PROD1 WELLPR PULD P POOH with plug laying down drill pipe 3,030.0 800.0 22:00 00:00 2/9/2016 2/9/2016 1.00 PROD1 WELLPR PULD P Continue to lay down drill pipe and 800.0 0.0 00:00 01:00 RBP 2/9/2016 2/9/2016 1.50 PROD1 WELLPR WWWH P Pulled wear ring and wash BOPE 0.0 0.0 01:00 02:30 stack 2/9/2016 2/9/2016 3.50 COMPZN RPCOMP OTHR P Load and tally completion 0.0 0.0 02:30 06:00 2/9/2016 2/9/2016 3.50 COMPZN RPCOMP RURD P Clear Floor,RU Weatherford 0.0 0.0 06:00 09:30 equipment for 3-1/2". Make final inspection of completion jewelry and PJSM for running completion. 2/9/2016 2/9/2016 9.50 COMPZN RPCOMP PUTB P Running 3-1/2"completion. PU poor- 0.0 5,422.0 09:30 19:00 boy overshot, D-nipple,packer/PBR assembly and GLMs spaced out per procedure.Packer sat down at 5422 ft with 10 K down.unable to get to slide by. 2/9/2016 2/10/2016 5.00 COMPZN RPCOMP PULL T POOH with packer assembly standing 5,422.0 0.0 19:00 00:00 back 8 rd 2/10/2016 2/10/2016 2.50 COMPZN RPCOMP RURD T RD Tubing equipment,install wear 0.0 0.0 00:00 02:30 ring. RU DP handling equipment. 2/10/2016 2/10/2016 6.00 COMPZN RPCOMP PULD T Picked up BHA#10:7"Scraper 0.0 4,441.0 02:30 08:30 assembly and RIH picking up drill pipe to 4,441-ft 95K Up wt,70K Dn wt. 2/10/2016 2/10/2016 0.50 COMPZN RPCOMP SVRG T Service Top Drive 4,441.0 4,441.0 08:30 09:00 2/10/2016 2/10/2016 4.50 COMPZN RPCOMP PULD T Continue to PU and RIH w/ BHA#10: 4,441.0 7,976.0 09:00 13:30 7"Scraper assembly from 4,441-ft to 7,976-ft 175K Up wt,87K Dn wt 2/10/2016 2/10/2016 3.00 COMPZN RPCOMP CIRC T Washed down from 7997 ft to 8006 ft 7,976.0 8,006.0 13:30 16:30 @ 7 BPM @ 1375 psi. Pressure increased to 1954 psi going over the stump.Recovered frac sand and carbolite.added safe lube to system and circulate in at 8 BPM @ 1850 psi. Note saw no issues @ 5422 ft with scraper. 2/10/2016 2/10/2016 0.50 COMPZN RPCOMP PRTS T PT casing to 2500 psi.lost 100 psi in 8,006.0 7,990.0 16:30 17:00 15 min's. Bled off pressure. 2/10/2016 2/10/2016 4.50 COMPZN RPCOMP TRIP T POOH with BHA#10:scraper 7,990.0 0.0 17:00 21:30 assembly. 2/10/2016 2/10/2016 0.50 COMPZN RPCOMP SVRG T Service and inspect top drive 0.0 0.0 21:30 22:00 2/10/2016 2/10/2016 0.50 COMPZN RPCOMP RURD T RU Weatherford Tbg equipment. 0.0 0.0 22:00 22:30 2/10/2016 2/11/2016 1.50 COMPZN RPCOMP RCST T Picked up FHL packer assembly W/ 0.0 600.0 22:30 00:00 Poor boy overshot.RIH on drill pipe. 2/11/2016 2/11/2016 4.50 COMPZN RPCOMP RCST T RIH with packer assembly on drill pipe 600.0 8,000.0 00:00 04:30 Engaged OS and sheared with 10 K down. Page 11/13 Report Printed: 3/15/2016 • • Min ing Operations Summary (with Timelog Depths) =4 &Wens 2K-01 ir Ct pc t.lips t Rig: NABORS 7ES 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) 2/11/2016 2/11/2016 1.50 COMPZN RPCOMP CRIH P Spot 20 bbls of CI treated 10#brine. 8,000.0 8,000.0 04:30 06:00 displaced with 47 BBLs of 10#brine.+ 2/11/2016 2/11/2016 1.50 COMPZN RPCOMP PRTS P Dropped ball&rod,Locate with over 8,000.0 8,003.0 06:00 07:30 shot. 10 K down.Up wt= 150 K. Pressure up to 2500 psi.S/O to 90 k. continue to pressure up to 3000 K Bled off pressure to 1000 psi.Shear out of PBR. Test pack and IA to 2500 psi.for 10 min's Top of PBR @ 7870 ft,COE 7895 ft, Shoe 8003' 2/11/2016 2/11/2016 7.00 COMPZN RPCOMP PULD T POOH laying down drill pipe. 8,003.0 0.0 07:30 14:30 2/11/2016 2/11/2016 1.50 COMPZN RPCOMP RURD T Pulled wear ring, RD drill pipe 0.0 0.0 14:30 16:00 hangling equipment RU Weatherford tbg equipment. 2/11/2016 2/11/2016 5.42 COMPZN RPCOMP PUTB 'T RIH with with 3.5 EUE 8rd completion 0.0 5,422.0 16:00 21:25 as per detail. 2/11/2016 2/11/2016 2.08 COMPZN RPCOMP PUTB P RIH with with 3.5 EUE 8rd completion 5,422.0 7,664.0 21:25 23:30 as per detail. 2/11/2016 2/12/2016 0.50 COMPZN RPCOMP HOSO P Fully engaged seals.spaced out well 7,664.0 7,640.0 23:30 00:00 install hanger 2/12/2016 2/12/2016 3.00 COMPZN RPCOMP CRIH P Circulated in 270 bbls of CI treated 7,844.0 7,844.0 00:00 03:00 brine(Congor 303A)©2.5 BPM @ 160 psi. 2/12/2016 2/12/2016 2.00 COMPZN RPCOMP THGR P Empty stack.work seal assembly into 7,844.0 7,878.0 03:00 05:00 PBR. Land hanger RILDS 2/12/2016 2/12/2016 2.00 COMPZN RPCOMP PRTS P PT tubing to 3000 psi for 10 min's.PT 7,878.0 7,878.0 05:00 07:00 IA to 2500 psi for 30 min's.Shear SOV ©2,250-psi,circulate both directions @ 2 bpm @ 60 psi on IA and 200 psi on TBG. 2/12/2016 2/12/2016 0.50 COMPZN WHDBOP MPSP P Pulled landing jt, Install BPV 07:00 07:30 2/12/2016 2/12/2016 0.75 COMPZN RPCOMP OTHR P Pull landing joint,lift rotary table top 0.0 0.0 07:30 08:15 and clean from underneath. 2/12/2016 2/12/2016 1.75 COMPZN WHDBOP NUND P Blow down lines and BOP stack in 0.0 0.0 08:15 10:00 preparation for ND of BOPE. Pull riser,Turnbuckles and ND BOPE. Rack Back BOPE and secure. 2/12/2016 2/12/2016 1.50 COMPZN WHDBOP NUND P NU Adapter,Test Seal Neck void© 0.0 0.0 10:00 11:30 250/5,000 psi for 10 minutes-good test. NU Tree, 2/12/2016 2/12/2016 0.50 COMPZN WHDBOP MPSP P Pull BPV and install tree test plug. 0.0 0.0 11:30 12:00 2/12/2016 2/12/2016 2.00 COMPZN WHDBOP PRTS P Fill tree with diesel and pressure test 0.0 0.0 12:00 14:00 tree at 250/5,000 psi. Found Otis tree cap flange leaking-tighten and re test to 250/5,000 psi-good test. RD test equipment. Secure well 2/12/2016 2/13/2016 10.00 COMPZN WHDBOP WAIT T Stand by with crews while waitring on 0.0 14:00 00:00 weather. 2/13/2016 2/13/2016 16.25 COMPZN WHDBOP WAIT T Continue to stand by due to weather 00:00 16:15 conditions 2/13/2016 2/14/2016 7.75 COMPZN WHDBOP WAIT T Announced Phase III conditions as of 16:15 00:00 16:25 hrs for all of Kuparuk. Page 12/13 Report Printed: 3/15/2016 Operations Summary (with Timelog Depths) &Wens 2K-01 Conoco Ai xt' Rig: NABORS 7ES 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) 2/14/2016 2/15/2016 24.00 COMPZN WHDBOP WAIT T Standby on phase 3 weather 00:00 00:00 conditions. 2/15/2016 2/15/2016 6.00 COMPZN WHDBOP WAIT T Standby on phase weather 00:00 06:00 2/15/2016 2/15/2016 10.50 COMPZN CEMENT CMNT P Prep for cement top job on OA. Call 06:00 16:30 out Cement bulk truck, DHD Grout pump,and vac truck suppport. Held PJSM with all parties.Mixed up 2 BBL's of 15.4#cement.pumped cement down OA taking returns up OA displace sea water from OA with cement.flushed OA valves with water. RD COP Well tech Cmt unit. RE- install VBR plug on OA Driller side. PT cmt to 200 psi with diesel using test pump.held for 15 min's.SI OA with pressure still on it. 2/15/2016 2/15/2016 1.50 COMPZN WHDBOP MPSP P checked well pressure IA=8 psi 16:30 18:00 Tubing=0 psi.bled off IA and left open to monitor well. Pulled BPV. Had 1 cup 10#dirty brine spill during pull with dry rod due to thermal expansion. 2/15/2016 2/15/2016 5.50 COMPZN WHDBOP FRZP P RU LRS.PJSM. Freeze protected well 18:00 23:30 with 85 bbls of diesel.RD LRS. Let well equalize. 2/15/2016 2/15/2016 0.49 DEMOB WHDBOP MPSP P Installed BPV.Secured well Rig 23:30 23:59 released @ 23:59 hrs. Page 13/13 Report Printed: 3/15/2016 • • PT(7 / —1 2--z— Loepp, Victoria T (DOA) From: Regg,James B(DOA) Sent: Saturday, February 06, 2016 2:28 PM To: Guzman, Diana; Loepp,Victoria T(DOA); Schwartz, Guy L(DOA) Cc: Nabors 7ES Company Man; Packer,J.Brett; Rauchenstein, Rock D; Herbert, Frederick 0; Kanady, Randall B Subject: RE: KRU 2K-Ol - PTD# 188-122 - Sundry#316-009 - Possible BOPE Test Waiver Request Follow Up Flag: Follow up Flag Status: Flagged Yesterday AOGCC sent CPAI written approval to test BOPE on rig workovers at intervals not to exceed 14 days between tests. Authorized CPAI rigs are those currently under contract AND actively engaged in the BOPE between wells maintenance program. That should take care of your testing dilemma.No extension needed. If you have any questions contact me. Sent from my Samsung Galaxy smartphone. SCANNED MAY 1 9 201F Original message From: "Guzman, Diana" <Diana.Guzman@conocophillips.com> Date: 02/06/2016 2:00 PM (GMT-09:00) To: "Loepp, Victoria T(DOA)" <victoria.loeppa,alaska.gov>, "Regg, James B (DOA)" <jim.regg(2Ialaska.gov>, "Schwartz, Guy L (DOA)" <guy.schwartz_alaska.gov> Cc:Nabors 7ES Company Man<n2364@conocophillips.com>, "Packer,J.Brett" <J.Brett.Packer@conocophillips.com>, "Rauchenstein, Rock D" <Rock.D.Rauchenstein@conocophillips.com>, "Herbert, Frederick 0" <Frederick.O.Herbert@conocophillips.com>, "Kanady, Randall B" <Randall.B.Kanady@conocophillips.com> Subject: KRU 2K-01 - PTD# 188-122 - Sundry# 316-009 -Possible BOPE Test Waiver Request Good afternoon Victoria, I wanted to update you on the progress of the rig workover on 2K-01 because we're having difficulties with a subsided interval at 725'—750'that might force us to request a BOPE test waiver request. Nabors 7ES BOPE test is due Monday(February 8 at midnight). We started step#15 of the attached sundry procedure on February 4 at noon. Since then,we have been tagging a subsided interval at 725'and have made very slow progress.We have adjusted the BHAs in order to make them more flexible but we're still unable to make any hole. My concern is that since we lost the ability to pressure test our stack when we removed the tubing head to pull the 7"casing we won't meet our deadline for the BOPE test(due at midnight Monday)due to our slow progress. The current plan forward is to: • Continue to dress the 9-5/8" casing with a 8-3/4"and 8-1/2"tandem BHA. • RIH and dress off the 7" casing stump at 1924' • RU and RIH with the 7" casing tie back. • Land 7"casing and NU tbg spool and test. 1 The current barriers: • • • 7" Production Casing: o A"G" lock-set RBP set at 3020' pressure tested to 2500 psi. o Packer& PXN plug with a 10.0 ppg NaCI KWF • 3-1/2"Tbg: o Packer& PXN plug with a 10.0 ppg NaCI KWF I attached a copy of the sundry application for the 2K-01.As well as a copy of the 2K-01 Time Log Summary for your review and an updated schematic of the current status of the well. If you have any questions, please feel free to call me at 305-332-6332. I will update you with our progress on Monday. Unfortunately, an update Monday would provide less than 24 hours of notice since our test is due Monday at midnight; therefore my update today. Thank you so much for your time. Sincerely, Diana Guzman Senior Wells Engineer ConocoPhillips Alaska Inc. Drilling&Wells 700 G Street(ATO-1502) Anchorage,AK 99501 Main:907-265-6318 Cell:305-332-6332 Fax:918-662-1893 2 • • ✓ _ L 2K-01 ConocoPhillips r' Subsidence RWO coilapsea u-5/8"Csg 725'-750'--11"f 7"Casing Cut @ 1924' III I i TOC @ 2700'w/cement stringers up to 1970' $-1 7" RBP @ 3020' Casing-9-5/8"36#, J-55 BTC --pi. - - _'1 @3719'MD 10.0 ppg NaCI KWF Tubing Cut @ 8012' ,p —.sir , PBR @ 8027' MD I 7i Baker HB Retrievable Packer @ 8041' MD I Tubing-3-Y"9.3#, J-55, 8rd EUE .. 1 '4 2.75"XN-Nipple w/a PXN Plug @ 8078' MD @ 8090' I2.984'Shear Out Sub @8089' MD A-4 @ 8260'-8292' L1 Casing-7"26#, J-55 BTC @ 8521' Date: February 6,2016 1 Drawn By:Diana Guzman ti o>F TSF • • ,v THE STATE Alaska Oil and Gas oALAsKA Conservation Commission ItS _,_ 333 West Seventh Avenue ,;. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 1141;;;.-r �'�P Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Diana Guzman Sr. Wells Engineer SCANNED !i E { ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2K-01 Permit to Drill Number: 188-122 Sundry Number: 316-009 Dear Ms. Guzman: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 6Veio Cathy pFoerster Chair DATED this"ay of January, 2016. RBDMS`JAN I 1018 RECEIVED • STATE OF ALASKA • JAN 0 6 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION `� APPLICATION FOR SUNDRY APPROVALS 4,88 20 AAC 25.280 1.Type of Request: Abandon I— Plug Perforations I Fracture Stimulate I— Repair Well I✓ Operations Shutdown E Suspend 1...... Perforate ( Other Stimulate [ Pull Tubing Change Approved Program 1— Plug Plug for Redrill 1""" Perforate New Pool(-_. Re-enter Susp Well ( Alter Casing F Other: 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory P Development 188-122 • 3.Address: 6.API Number: Stratigraphic I— Service t P.O.Box 100360,Anchorage,Alaska 99510 50-103-20102-00 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a Will planned perforations require a spacing exception? Yes No iy7 ,/ KRU 2K-01 . 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25588 Kuparuk River Field/Kuparuk OillPool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVpt MPSP(psi): Plugs(MD): Junk(MD): ID 8,540' 6,352' .y 35 Co 1(03 2-1g e' none Casing Length Size MD . ND Burst Collapse Structural - Conductor 79' 16" 115' 115' Surface 3,684' 9 5/8 3,719' 2,930' Intermediate Production 8,488' 7" 8,521' 6,335' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8260-8292 • 6117-6143 31/2 J-55 8,090' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BAKER HB RETRIEVABLE PACKER . MD=8041 TVD=5944 SAFETY VLV-CAMCO TRDP-1A SSA SAFETY VALVE , MD=1809 TVD= 1613 12.Attachments: Proposal Summary j Wellbore schematic E 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory P Stratigraphic (— Development F, Service 14.Estimated Date for 1/19/2016 15.Well Status after proposed work: Commencing Operations: OIL 3 . , WINJ i...... WDSPL I ....._ Suspended 16.Verbal Approval: Date: GAS iWAG r.L, GSTOR r SPLUG r Commission Representative: GINJ - Op Shutdown P Abandoned 1- 17. I hereby certify that the foregoing is true and the procedure approved Diana Guzman herein will not be deviated from without prior written approval. Contact Email Diana.Guzmancop.com Printed Name Diana Guzman@265-.:18 Title Sr.Wells Engineer ....../...A.A.... Ali Allid 1 1 6Ilb Signature ' one Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test E Mechanical Integrity Test ❑ Location ClearanceleEl � Other: `5()/-7 trra- f• 746 2 5 acv ,2 ('1 5ia /7/2 P /S 27' �rSi'J 1--,r7 rt,./lair- p ry t/fr-)ty-v s / to 25-‘)0 P 5 • r Post Initial Injection MIT Req'd? Yes 1=1No b. Spacing Exception Required? Yes ❑ No g''' Subsequent Form Required: I 4a • APPROVED BY Approved by:iti , 2 COMMISSIONER THE COMMISSION �C^e 1 For 10-,03 Revise d/11/2015 o `!1 ah a4c nlis valid Tor 12 months trom the date of a ro al. R Ill . I VTL lel' !<6 O �p�l IN L i 11446, ik %�//'6 P ,: • S ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 January 4,2016 Commissioner Cathy Foerster State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby submits an Application for Sundry Approval to workover the Kuparuk Well 2K- 01 (PTD: 188-122). Well 2K-01 was originally drilled and completed as a Kuparuk A sand producer in 1989. The well was refractured in 1998. The packoffs were seal treated in 1999 after an IC packoff failure. A packer leak was identified at 8041' during a Leak Detect Log ran in 2012. In 2013, a gyro survey indicated subsidence risk around 700' on well 2K-01 which is consistent with the subsidence area on the 2K pad. The IC-POTs have failed numerous times and multiple seal-tite repairs have been unsuccessfully attempted. A waiver for IAxOA communication was submitted in 2015 after 2K-01 experienced sustained casing pressure of the OA.2K-O 1 drift problems found in 2013 have increased and now only special clearance plugs can drift the tight spots in the tubing.Well 2K-01 is currently flowing 170 BOPD. The purpose of this workover is to pull the existing gas lift completion, cut and pull the 7"production casing above the top of cement,tie in and cement a new 7"production casing from the casing stub,replace the packoffs and run a new 3 ''/z"gas lift with a stack packer completion. If you have any questions or require any further information, please contact me at 907-265-6318 or Diana.Guzman@conocophillips.com. Sincerely, 7.4014. 4-0DiGuz � Wells Eng ter CPAI Drilling and Wells • • 2K-01 Rig Workover Subsidence Repair (PTD #: 188-122) Current Status: This well is currently online and awaiting pre-RWO well work. Scope of Work: • Pull the existing gas lift completion. • Cut and pull the 7"production casing above the top of cement. • Tie in and cement the new 7"production casing. • Replace packoffs. • Install a new 3 '/2"gas lift with a stack packer completion General Well info: Well Type: Producer MPSP: 2186 psi using 0.1 psi/ft gradient(Most recent SBHP=2798 psi on 6/1/15) Reservoir Pressure/TVD: 2798 psi/6117' TVD(8.8 ppg)on 6/1/15 Wellhead type/pressure rating: FMC Gen IV/5M psi BOP configuration: Annular/Pipe Rams/Blind Rams/Flow Cross/Pipe Rams TIFL/MIT results: MIT—T passed October 7,2015 MIT—OA passed June 27,2015 Earliest Estimated Start Date: January 19,2016 Drillsite Petroleum Engineer: Mark Schulman Workover Engineer: Diana Guzman Work:265-6318 E-mail:Diana.Guzman@conocophillips.com Pre-Rig Work 1. Set plug with catcher on top.Perform DDT to confirm plug integrity and MIT-T.Dummy off all GLM's leaving bottom GLM open for circulation.Cut 3 '/2"tubing. 2. PT tubing and casing packoffs,FT LDS's. 3. Set BPV. Proposed Procedure: 1. M1RU 2. Pull BPV. Circulate workover fluid. Obtain SITP&SICP, if still seeing pressure at surface, calculate new KWF,weight up,and repeat circulation as necessary. Verify well is dead. 3. Set BPV&blanking plug,ND tree,NV BOPE and"test to 2500 psig. 4. Pull blanking plug&BPV. Screw inandmg joint,BOLDS's,and pull tbg hgr to the rig floor. 5. POOH laying down 3 'h"tubing.' 6. RIH on DP and 7' casing scraper tb the MIR.POOH 7. RU E-line.RIH with CAST-M to locate TOC.POOH 8. Set 7"RBP below TOC.PT/DDT the RBP.Dump sand.POOH with DP. 9. Cut the 7"casing above TOC. 10. Monitor OA for flow.ND BOPE.Remove tubing head.NU the BOPE to the casing head. 11. Spear casing and PU. 12. Reverse circulate out the Arctic Pack from the OA. 13. POOH laying down the 7"casing. 14. Set the test plug in the casing head. Shell test the BOPE. 15. RIH with 9%"casing scraper to the 7"casing stub. POOH with DP. 16. Run new 7"casing. PT the 7"casing. NU cement head. • • 2K-01 Rig Workover • Subsidence Repair (PTD #: 188-122) 17. RU SLB cementers. Run the inner cementing BHA.Pick up to ensure indicating collet is latched and inner string is in proper position for cementing.Open cementing valve and pump cement job. 18. PT cementing valve for 5 minutes and POOH. 19. ND cement head. 20. ND BOPE. Land 7" casing in the slips. Cut excess casing off. Install packoff. NU new tubing head and BOPE. Install BPV and blanking plug. Shell test BOPE. Pull BPV. 21. PT the casing. Record test on chart for 30 minutes. 22. RIH with wash string and circulate sand out from on top of the RBP. POOH with DP. 23. RIH with RBP retrieving assembly. Retrieve RBP. POOH laying down DP. 24. RIH with the fishing BHA to the tubing stub and jar seal assembly free from the packer. POOH with the fish. 25. Run new 3 '/2"gas lift, stack packer and poor boy overshot. 26. Engage the 3 '/2" tubing stub. Space out for subsidence, mark the pipe, and POOH two joints. Space out with pups. 27. MU tubing hanger. Swap the well over to corrosion inhibited seawater. Pressure up to set the packer. 28. Land the hanger and RILDS. 29. PT tubing.Pressure test the IA. 30. Bleed T and IA. Shear the SOV.Bleed tubing and IA pressures to zero. Monitor for flow. 31. Pull landing joint. Install TWC. Pressure test IA to test TWC from below. 32. ND BOP stack,NU tree. PT tree and tubing hanger packoffs. 33. Remove TWC. 34. Freeze protect w/diesel. Set BPV. 35. RDMO. Proposed Post-Rig Work: 1. Reset well house(s)and flowlines of adjacent wells. 2. Pull BPV. 3. RU Slickline.Pull catcher and plug. Run new gas lift design. Set up for production 4. Handoff to operations to put back on production. �►� • • • • — 2K-01 ConocoPhillips Proposed Completion Subsidence RWO Cemented OA from TOC-Surface Casing—7" 26#, L-80 Hydril 563 @—2,000' MD/1,825'TVD Casing—9-5/8" 36#, J-55 BTC @3719' MD i 3 1/2"x 1 1/2" MMG Production Mandrel 3 1/2"x 1 1/2" MMG Production Mandrel 4 3'/2"x 1 1/2" MMG Production Mandrel -, 4 3 1/2"x 1 1/2" MMG Production Mandrel -4111-- 3 1/2"x 1 1/2" MMG Production Mandrel Jf PBR f Baker FHL Packer @—7900' MD c ] f-- 2.812" DS-Nipple Over Shot/Tubing Stub @ 8011' MD PBR @8027' MD t 111 - Baker HB Retrievable Packer @ 8041' MD Tubing—3-W 9.3#, J-55, 8rd EUE ---► ❑ j 4 2.75"XN-Nipple @ 8078' MD @ 8090' N 4 2.984' Shear Out Sub @8089' MD A-4 @ 8260'- 8292' Casing—7"26#, J-55 BTC @ 8521' Date: January 4,2016 Drawn By: Diana Guzman , z KUP PROD • 2K-01 ConocoPhillips gf Well Attributes Max Angle&MD TD f,.4 -a.lit. Wellbore API/UWI Field Name Wellbore Status Incl(°) MD MKS) Act Btm(ftKB) l (.arnNOYfwlkp. 501032010200 KUPARUK RIVER UNIT PROD 50.85 1,800.00 8,516.0 ... Comment H25(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 29-01,7/4/2015 3.07.38 PM SSSV:TRDP 35 12/24/2013 Last WO: 39.99 5/28/1989 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,229.0 6/1/2015 Rev Reason:GLV C/O,PULL PLUG/CATCHER hipshkf 7/4/2015 fi01�I asing tangs HANGER;31.1 }}}iii 1 Caning Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...VW/Len(1..Grade Top Thread CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED rer Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtILen(I...Grade Top Thread SURFACE 9 5/8 8.921 35.0 3,718.6 2,929.7 36.00 J-55 BTC 1. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WIILen(I...Grade Tap Thread 'rl I'1 PRODUCTION 7 6.276 33.0 8,521.0 6,335.5 26.00 J-55 BTC „r.i.a.er.aatnta,.aa.a..ev.r„Le,... Tubing Strings in Tubing Description String Me...ID 00) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING 31/2 2.992 31.1 8,090.1 5,982.1 9.30 J-55 EUE-MOD nn"CONDUCTOR.36.0-115.0 _ Completion Details t Nominal ID Top(ftKB) Top(TVD)(ftKB) Top loci C) Item Des Com (in) 31.1 31.1 0.12'HANGER FMC GEN IV TUBING HANGER 3.500 1,808.6 1,612.6 50.57'SAFETY VLV CAMCO TRDP-1A SSA SAFETY VALVE 2.812 SAFETY VLV;1,808.6r 8,027.6 5,933.8 39.81 PBR BAKER 80-40 PBR- SEAL BORE 3.000 s 8,041.3 5,944.4 39.61 PACKER 4"BAKER HB RETRIEVABLE PACKER 2.890 8,078.0 5,972.7 39.07 NIPPLE OTIS XN NIPPLE 2.750 GAS LIF7;2,857.6 ^. 8,089.3 5,981.5' 38.90 SOS BAKER SHEAR OUT SUB 2.984 Perforations&Slots Shot Dens Top(TVD) Btm(ND) (shots/1 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 8,260.0 8,292.0 6,117.4 6,143.6 A-4,2K-01 4/2/1990 4.0 (PERF 180 deg.Phasing;4.5" HCS Mandrel Inserts SURFACE;35.03,718.6 St ati on Top(ND) Valve Latch Port Size TRO Run GAS LIFT:4,935.7 N Top(ftKB) (ftKB) Make Model OD(In) Bert/ Type Type (in) (psi) Run Date Com 1 2,857.6 2,329.8 MERLA TMPD 1 GAS LIFT GLV BK 0.156 1,260.0 7/1/2015 ili 2 4,935.7 3,779.2 MERLA TMPD 1 GAS LIFT GLV 'BK 0.156 1,264.0 7/1/2015 3 6,101.4 4,569.3 MERLA TMPD 1 GAS LIFT GLV BK 0.188 1,296.0 7/1/2015 GAS LIFT;6,101.4 = 4 6,638.9 4,937.1 MERLA TMPD 1 GAS LIFT OV BK 0.250 0.0 7/1/2015 5 7,082.6 5,248.3 MERLA TMPD 1 GAS LIFT DMY 'BK 0.000 0.0 3/19/2000 1111 6 7,537.4 5,572.6 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/23/1998 7 7,984.4 5,900.8 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/23/1998 GAS LIFT:6s38s irt. Notes:General&Safety End Date Annotation 10/28/2010 NOTE:View Schematic w/Alaska Schematic9.0 10/23/2012 NOTE:IDENTIFIED PACKER LEAK @ 8041'w/TEMPERATURE GAS LIFT;7,082.6 11 GAS LIFT;7.537.4 GAS LIFT;7,984.4 11'. • PBR;8,027.6 r O r. PACKER;8.041.3 •iQ. NIPPLE;8,078.0 SOS;8,089.3 si IPERF;8,280.0-8,292.0 PRODUCTION;33.0-8,521.0 • • • Bettis, Patricia K (DOA) From: Guzman, Diana <Diana.Guzman@conocophillips.com> Sent: Thursday,January 07, 2016 10:37 AM To: Bettis, Patricia K (DOA) Subject: RE: KRU 2K-01 (PTD No. 188-122): Sundry Application Patricia, Thank you so much for your help. I will share the information with the rest of the RWO group and our Well Admin. The current effective depth for 2K-01 is 8435' MD and 6263'TVD. I apologize about the confusion. Once again thank you so much for your help. Sincerely, Diana Guzman Senior Wells Engineer ConocoPhillips Alaska Inc. Drilling&Wells 700 G Street(ATO-1502) Anchorage,AK 99501 Main:907-265-6318 Cell:305-332-6332 Fax:918-662-1893 From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Thursday, January 07, 2016 9:56 AM To: Guzman, Diana Subject: [EXTERNAL]RE: KRU 2K-01 (PTD No. 188-122): Sundry Application Diana, On Form 10-403, Box 11, data provided lists the present well condition summary such as total depth of well and effective depth of the well. Effective depth may represent a plug-back depth, top of fill or top of fish that impedes the production/injection of fluid or utilization of the wellbore below that depth. Thanks, Patricia From: Guzman, Diana [mailto:Diana.Guzman@conocophillips.com] Sent:Thursday,January 07, 2016 9:40 AM 1 • • • CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 • • • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Thursday,January 07, 2016 9:14 AM To: 'Diana.Guzman@conocophillips.com' Subject: KRU 2K-01 (PTD No. 188-122): Sundry Application Good morning Diana, What is the current effective depth, both MD and TVD, for the KRU 2K-01 well. This information was missing from Form 10-403. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettisPalaska.gov. 1 RECEIVED JUL 012015 ConocoPhillips Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 JUL 1 '12015 June 29, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Cathy Foerster: Enclosed please find the10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. well 2K-01 PTD 188-122 surface casing starter head repair. Please call MJ Loveland or Martin Walters at 659-7043 if you have any questions. Sincerely, , ig//4J` MJ Loveland ConocoPhillips Well Integrity Projects Supervisor STATE OF ALASKA RECEIVED ALA 1 OIL AND GAS CONSERVATION COMM. ION REPORT OF SUNDRY WELL OPERATIONS JUL 0 12.015 1 Operations Abandon RugPerforations Pull Tubing r Operations shutdow n r r Fracture Stimulate r P r Performed. Suspend r Perforate r Other Stimulate r- Alter Casingg - fir` r Change A. Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other Starterhead weld j;e 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number. ConocoPhillips Alaska, Inc. Development r Exploratory r 188-1.22 3.Address: 6.API Number Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-103-20102-00 7.Property Designation(Lease Number): 8 Well Name and Number: ADL0025588 KRU 2K-01 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10 Field/Pool(s). NA Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8540 feet Plugs(measured) None true vertical 6352 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) 8041 true vertical 0 feet (true vertical) 5944 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115 115 SURFACE 3684 12 3719 2929 PRODUCTION 8488 7 8521 6336 Perforation depth: Measured depth: 8260-8292 True Vertical Depth: 6117-6143 Tubing(size,grade,MD,and TVD) 3.5,J-55, 8089 MD, 5982 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER HB RETRIEVABLE PACKER @ 8041 MD and 5944 TVD SAFETY VLV-CAMCO TRDP-1A SSA SAFETY VALVE @ 1809 MD and 1613 TVD 12.Stimulation or cement squeeze summary: NA Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 1 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25 070,25 071,&25 283) 15.Well Class after work: Daily Report of Well Operations r Exploratory r Development r Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt. I NA Contact MJ Loveland/Martin Walt s Email n1878@conocophillips.com Printed Name MJ Loveland Title WI Project Supervisor SignaturePh 9-7043 Date 6/29/2015 177-1- n e RBDMra JUL - 1 2015 77?//5 Form 10-404 Revised 5 201 Submit Original Only 2K-01 DESCRIPTION OF WORK COMPLETED SUMMARY Date 6/29/201 Event Summary 06/07/15 Cleaned SH with wire wheel for upcoming SH repair. 06/12/15 Removed the VR plug and installed purge jewelry on the OA. 06/26/15 Welders completed seal weld on Starter Head. 06/27/15 MIT OA (PASS), Initial T/I/O= SI/100/3, Pressurized OA to 1800 psi with 0.3 BBLS of diesel. Shut in for 60 min monitor. T/I/O= SI/200/1800, 15 min= SI/200/1780, 30 min= SI/200/1770, 45 min= SI/200/1770, 60 min= SI/200/1770, Bled OA to 0 psi in 7 min, Final T/I/O= SI/100/0 .fir •w !''''4'. `,y ° a`+ . i 1,,' " p .. 1 *: li' "t 1`. d 1` ,� , -.:..1, ; • . r ' *„ .r,r4. `� +y , - ' k ( f4 -*,x . . ��•i:fit ; " i %Y� t;' o . ;,t i x . :.‘: ,- :,- iT,,,,;*,„,..1.0",,,,,tf.-. .-'.--i,,.!, :.: ',,-,ii" std• .. _ - ' .N x +�` r tt , 4Ss 4 ' :r � ' . : ,ib`1 4R., r 'P4-.0"., "4 it J° [. der a rks •ai ti • M4' „ .yam '';'4''.1 .ca '' t.n _ g . f Vo- f II N - •' z 48t x. aj{stn g r ''' a., . ..z 4.0 ' ConocoPhillips ~as~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 29, 2008 • ~~IN~~ AlJ G ~ r~ X008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: l~l Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped June 30, July 4 and July 20, 2008. The corrosion inhibitor/sealant was pumped June 29, June 30, JulylO,and July 24, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, ,,G° M.J. Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk Field 7/29/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2K-01 188-122 SF NA 10" 6/30/2008 2 6/29/2008 2K-02 188-121 SF NA 10" 6/30/2008 2 6/29/2008 2K-03 188-120 24" NA 24" 6/30/2008 8.5 6/29/2008 2K-05 188-118 SF NA 10" NA 2.55 7!10/2008 2K-06 189-082 SF NA 15" NA 1.27 7/10/2008 3K-13 189-095 8'1" 1.00 25" 7/4/2008 6.38 7/10/2008 2K-15 189-089 SF NA 6" 6/30/2008 1 6/30/2008 2K-17 189-119 10" NA 10" 6/30/2008 23.8 6/30/2008 2K-18 189-108 SF NA 11" NA 2.12 .7/10/2008 2K-21A 198-158 20' 2.70 14" 7/4/2008 4.68 7/10/2008 2K-22 189-115 6" NA 6" 6/30/2008 5.1 6/30/2008 2K-25 190-012 SF NA 12" NA 2.55 7/10/2008 2K-26 190-015 SF NA 10" 6/30/2008 2 6/29/2008 2K-28 201-154 3'10" NA 3"10" 6/30/2008 23.8 6/30/2008 2M-04 192-093 SF NA 20" NA 3.4 7/10/2008 2M-27 192-071 9'9" 1.2 18" 7/4/2008 2.55 7/10/2008 26-07 184-024 20' 2.7 34" 7/4/2008 5.95 7/10/2008 2V-01 183-158 24" NA 24" NA 20.4 7/24/2008 2V-02 183-161 11" NA 11" NA 1.3 7/24/2008 2V-03 183-164 24' 6" 3.40 8" 7/20/2008 5.5 7/24/2008 2V-04 183-165 20' 4" 2.80 8" 7/20/2008 5.1 7/24/2008 2V-05 183-176 SF NA 4" NA 2.1 7/24/2008 ZV-09 185-037 SF NA 4" NA 1.7 7/24/2008 2V-11 185-049 SF NA 4" NA 1.7 7/24/2008 2V-12 185-050 40' 5.4 8" 7/20/2008 8.5 7/24/2008 2V-13 185-030 18" NA 18" NA 3.8 7/24/2008 2V-14 185-031 SF NA 4" NA 1.7 7/24/2008 2V-15 185-032 SF NA 4" NA 1.7 7/24/2008 01/27/04 Schlumberger NO. J100 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-5711 Attn: Lisa Weepie A TTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job# f Log Description Date BL Color CD tll '(:63 2A-04 10709682 INJECTION PROFILE 12/27/03 1 15~JìéJ.- 2T-28 10709867 STATIC SURVEY 01/15/04 1 fiLJ '~? 2A-04 10709691 RST 01/19/04 1 ~,)c?~ 2K-01 10696828 LDL 01/14/04 1 f()- )3 [ç 1D-140 10696827 LDL 01/13/04 1 (31-1\ \ 3H-03 10709688 PRODUCTION PROFILE 01/16/04 1 :l3'" ~5« 2P.447 10696819 SCMT 01/04/04 1 r:B~ JS3 2P-434 10709667 USIT/CBL 12102/03 1 2P-432 ,. ,\ Ú:~ --(:f.":¡ \ 10696818 PERF RECORD & SBHP 01/03/04 1 ( : -..- '" .... . \. II," - . .,., : r\C l..!t: I V ¡:;LJI '''''~'''''-'::::>' " "''''':..... Ji\ì'l 2; C 2004 SIGNED: \ Y"'ì \.~ 1 /"\1''\':'\'''') , \) ~ ~ (I"" /\/'-. DATE: '. l::"\a.5\U! OU & Gas Cons. Commisin\\~ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Af!~omge SCA¡\~¡¡~E!C FIEB @ 3 2004 ---""~--'::,:>~,.". r r", f'\ c:~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: / Abandon_ Sus'pend_ 6perational shutdown_ Re-enter suspended well _ SWAP WELL. FROM SWAP Well from Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ H20 to MI INJECTION H20 to MI (WAG) Change approved program _ Pull tubing _ Variance _ Perforate _ Other_X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__ RKB 92.0 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 196612 Stratigraphic __ Anchorage, AK 99519-6612 Service__X Prudhoe Ba~/Unit 4. Location of well at surface 8. Well number 714' FNL, 3665' FEL, Sec. 19, T11 N, R12E, UM (asp's 599008, 5959360) Z-31 At top of productive interval 9. Permit number / approval number 3029' FNL, 4420' FEL, SEC 07, T11N, R12E, UM (asp's 598111, 5967592) 188-122 At effective depth 10. APl number 2822' FNL, 4312' FEL, Sec. 07, T11 N, R12E, UM (asp's 598216, 5967801 ) 50-029-21871-00 At total depth 11. Field / Pool 2797' FNL, 4299' FEL, Sec 07 T11N, R12E, UM (asp's 598228, 5967826) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 13251 feet Plugs (measured) true vertical 9161 feet Effective depth: measured 13210 feet Junk (measured) true vertical 9131 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 110' 20" 72 c.f. 146' 146' Surface 2910' 13-3/8" 4101 c.f. 2946' 2693' Intermediate 12605' 9-5/8" 2765 c.f. 12641' 8707' Liner 870' 7" 300 c.f. 12381' - 13251' 8512° - 9161' Perforation depth: measured Open Perfs 12857' - 12897', 12914' - 12942', 12952' - 12967' Squeezed Perfs 12967' - 12992', 13002' - 13022', 13032' - 13046', 13058' - 13084' true vertical Open Perfs 8867' - 8898', 8911' - 8932', 8940' - 8951' Squeezed Perfs 8951'- 8970', 8978'- 8993', 9000'- 9010', 9019'- 9039' RE Tubing (size, grade, and measured depth 3-1/2", 9.2#, L-80 TBG @ 12139' MD. Tubing Tail @ 12429'. ~,,,., F ! Packers & SSSV (type & measured depth) 9-5/8" x 3-1/2" TIW H BBP Packer @ 12319' MD. 3-1/2" Otis SSSVLN @ 2102' MD.il j! 't 0 2002 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch _ 14. Estimated date for commencing operation// 15. Status of well classification as: ~l~,Ska Dii & Gas J. JoB$, October 2, 2002 x Anchorage 16. If proposal was verbally approved Oil __ Gas __ Suspended _ Name of approver Date approved Service WAG INJECTOR 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Amy Frankenberg @ 564-4503. Signed {.~~ ~.~ ..... ,~_(} ¢-'~-~- ....... ~,,,12%~...% .- . Title: Prudhoe Bay Petroleum Engineer Date July 10, 2002 Amy Frankenbu~c~ · Prepared by DeWayne R. Schnorr 564-5174 ,_) FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so represent~ive may witnessII Approval n°' "-~&~:::l '"". '"~/'"' ,os ocat,on c,.r nco__ Mechanical Integrity Test ~, Subsequent form required 10- Approved by order of the Commission ~gmal ~gn~ Sy , ~ ......... ~h5:5 T= ;{~- Commissioner ,, Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE bp BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 July 08, 2002 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Re' Sundry Notice for Z-31 Swap from Water to MI Injection BP Exploration Alaska, Inc. proposes fol.[[ewing wellwork to prepare to swap Z-31 from water injection to MI gas injection'(est. MI start-up Nov-02). This is the first time for Mlgas injection since the well was converted from a production well to an / injection well. 1 S Drift and Tag 2 C Acid Stim Establish injectivity into new perfs 3 MITA Witness byAOGCC, f" Well Z-31 was converted from a shut-in producing well to a water injection well last September (9/01/01). The well took one tubing volume of water and the formation locked up. This well needs a formation acid stimulation before MI is injected. ~"~' A copy of the wellbore diagram is attached. Please contact Amy Frankenburg at 564-4503 with any questions. Sincerely, Amy F~'ankenburg i'~'~i~ EWE Production Eng~neer...~z Pre-acid Slickline 1. RU slickline and drift and tag. Correct to ELM tubing tail. Coiled Tubinq acid stim 2. RU CT unit for acid stim.'Tag PBTD and corrected to ELM slickline tag. 3. Acid stim perforated interval./ 4. RDMO. Coiled Tubinq Acid Proc~ram 2. Trap 1500 psi on the 3-1/2" by 9-5/8" inner annulus. 3. MIRU CT. RU return line to adjacent well or returns tank. Be aware of the potential for H2S in the returns. 4. MU jetting nozzle and RIH. Pump at m,~. ~m, rate with slick water (your choice) while RIH. Circulate the tubing and liner clean of an~ stuff?hat may be floating around. \ / 5. Pump minimum rate and tag PBTD for dep'tfi' control. Circulate a bottoms-up volume prior to proceeding with the stimulation. any.. s~chmoo od bottom. Take care not to mash through and stir up ~" : 6. Pull above the top perfs and check l%r~jecfivity with a maximum WHP of 3000 psi. If the perfs are taking fluid then skip to step 7. If the perfs are too tight then pump 10 bbls of 7.5% HC1 as an attempt to establish injectivity. It may be necessary to take returns in order to stage acid to the nozzle. If the perfs are still too tight to p~ed with the remainder of the stimulation then contact the Well Ops Supervisor and Patti Barte ..... -i~1 ';~'f'iffe'h7. ....... 7. Make multiple passes across the perfs and pump. th!' a recommended maximum WHP of 2000 psi (*). to minimize acid contacting the squeeze per£s. Make o ' the overflush in case acid has swapped in the sump. Avoid stirrin~0H until the entire overflush has been pumped behind pipe in or ~ ~ up schmoo. 25 bbls 3% NH4C1 with 10% U-66 100 bbls 7.5% HC1 50 bbls 9% - 1% HC1-HF 150 bbls 3% NH4C1 with 10% U-66 and 0.2% Fl03 overflush (behind pipe) ~ Go to 3000psi during thefirst halfofthe HClstage if necessary to establish injection. Once mud acid is at thepeO the maximum treating pressure should be 2000 psi. ~l// f/uids should be fl/tered to 3 microns. Please note the initial and final injectivity in the WSR summary. Please note the rates and pressures in the WSR when each stage hits the perfs. Please run a cable so that the pump truck can record back side WHP on the treating report. Please e-mail the EXCEL treating report (5 minute readings) to the program author. 8. POOH. Bleed IAP. RDMO. Immediately put on injection ~ 3000 BWPD. Z31 a CTUATOR= OtiS KB. ELEV = 91.46' BF. ELEV = 55.46' KOP = 1500' I 2102' H3-1/2" OTIS SSSV LAND. NiP, D = 2.75" Max Angle = 57 @ 5500' ~ ! Datum MD = 12889' Datum TV D= 8800' SS GAS LIFT MANDRELS I 13'3/8"CSG'68#'L'80'ID=12'415" H 2946' ~-~ k ST MD 'I'VD DEV TYPE VLV LATCH SIZE DATE 6 3613 2997 53 OTIS LIVE RA 16 05/13/92i 5 7995 5555 51 OTIS LIVE RA 16 05/13/92 L] 4 10140 6968 51 OTIS LIVE RA 20 05/13/92 Minimum ID = 2.7,50" @ 2102' 3 11243 7662 49 OTIS LIVE RA .312 03/13/93 3-1/2" OTIS SSSV NIPPLE 2 12031 8184 46 OTIS DMY RA 0 03/30/93 1 12156 8271 46 OTIS OGLV RA 24 05/13/92 I 12303' H TIWPBRSEALASSBVIBLY I X ;><2 I 12319' Hg-5/8"x3'1/2"TIWI-BBPFKR, ID=2.992" I I -= ~ 3-1/2" OTiS X NIFt:I'E ID = 2'7§0" i I -'I 123~' H 3'l/2"OTIS×NIFt:l-EID=2'750"I ' 12426' 3-1/2' TBGTAL 3-1/Z' TBG, 9.2~, L-80, 0.0087 bpf, ID 2.992" 12426' I ~ I PERFORATION SUIVIVIA RY RE]= LOG: BHCS ON 11/11/88 - CBTON 11/15/88 ANGLEATTOPPERF:40@12914' '"' I' 12754' H MARKER JOINT I Note: Refer to R'oduclJon DB for hislDrical perf data Z' 6 12857- 12897' I O 09/06/01 2-1/8" 4 12914- 12942' ' .,~$ ...... 08/06/01 ! ! 2" 6 12914- 12942' O 09/06/01 ~ ~ i I I 2" 6 12952- 12967' O 09/06/01 2-1/8" 4 12952- 129ff2' S 08/06/01 5" 4 13002- 13022' S 08/06/01 i I 5" 4 13032- 13046' S 08/06/01 II 7" L~, 26#, L-~O, 0.03~3 ~pf, ~D = 6.27~' ~ 13251' I DATE REV BY COIVIVIENTS DATE REV BY COMIVENTS PRUDHOE BAY UNIT 11/16/88 ORIGINAL COIVPLETION 08/13/01 SRB/TP SQZ PERFS WELL: Z-31 03/12/01 SlS-QAA CONVERTED TO CANVAS 09/06/01 CWS/tlh ADDPEF~S PERMITNo: 88-1120 03/14/0'1 SIS-IVD FINAL APINo: 50-029-21871°00 05/19/01 RN/TP COllECTIONS ' Sec. 19, T11N, R12E 07/13/01 DAC/KAK UPDATE GLV INFO BP Exploration (Alaska) SIZE SPF INTERVAL Opn/Sqz DATE Z' 6 12857 - 12897' O 09/06/01 2-1/8" 4 12914- 12942' .,~$/'' 08/06/01 2" 6 12914- 12942' O 09/06/01 2" 6 12952 - 12967' O 09/06/01 2-1/8" 4 12952- 12992' S 08/06/01 5" 4 13002- 13022' S 08/06/01 5" 4 13032- 13046' S 08/06/01 2-1/8" 4 13058- 13084' S 08/06/01 DATE REV BY COIVIVIENTS DATE REV BY COMIVENTS 11/16/88 ORIGINAL COIVPLETION 08/13/01 SRB/TP SQZ PERFS 03/12/01 SIS-QAA CONVERTED TOCANVAS 09/06/01 CWS/tlh ADDPEI~S 03/14/01 SIS-IVE) FINAL 05/19/01 RN/TP COF~ECTIONS 07/13/01 DAC/KAK UPDATE GLV INFO DEPT. OF ENVIRONMENTAL CONSERVATION DI'vqSION OF ENVIRONMENTAL HE.~d_,TH SOLID WASTE PROGRAM 555 Cordova Street .Anchorage, ,AK 99501 TONY KNOWLE$, GOVERNOR Phone: (907) 269-765g Fax: (907) 26%7655 January, 2, 1997 Mr. Don Pucketl · Kupamk Production Manager ARCO (Alaska), Inc. P.O. Box 196105 ':&nchorage..AK 99519-6105 Dear Mr. Puckett: File No. 300.15.048 SENT CERTIFIED MAIL RETURN RECEIPT REQUESTED #P 190 115 561 ,~t~"IT-..L ~ z-F-'°1 Re- Approval for Final Closure-Kuparuk Drill Site 2K Drilling Waste Disposal Site Reserw'e (Pits); Permit #9036-BA007 The Alaska Department of Environmental Conservatiorr (ADEC) has completed review of the.. 1996 annual post-closure monitoring report for the Drill Site 2K reserve pits, dated November ! 4. 1996. and your request for final closure approval of the inactive drilling waste facility. This is the fifth and final annual report for post-closure monitoring, required by Solid Waste Permit #9036-BA007. Review of the submitted visual, water quality, and thermistor monitoring data for the 2K site demonstrates that the freezeback has been maintained, that the drilling ;vastes and overlying cap have remained stable and that no thermal de~adation has occurred. ARCO has complied with the stipulations of the closure plan defined in the Solid Waste Permit, and with all of the post closure monitoring requirements. CLOSURE APPROVAL The department approves final closure for this reserve pit at Drill Site 2K under the permit conditions and the authority, of the 1987 Solid Waste regulations 18 AAC 60.410(b)(3), 18 AAC 60.500(b), and 18AAC 60.520(g). This decision is supported by the Alaska Department of Natural Resources. Post closure monitoring and reporting obligations concerning the reserye,,pit facility are terminated. ~; ,, ~ ~.,, ~- Mr. Don Puckett ARCO (Alaska), Inc. January 2, 1997 TERMS AND CONDITIONS: This closure approval is subject to the following terms and conditions: 1) Inactive Reserve Pit Facility Closure: The approval granted by this letter is only for the inactive drilling waste reserve pits. Full site closure must be coordinated between the owner/operator and the appropriate state or federal agencies. Should any contamination from h/storic spills be found at the drill site (excluding the reserve pits), the ADEC Contaminated Sites Department (907-269-7659) must be notified immediately. 2) Restrictions on Site Use: 'ARCO may not use the site in any manner which may lead to degradation in the thermal regime or structural damage to the cap or facility.. 3) New Information: The department will require additional investigation, assessment, monitoring or remediation if new information regarding conditions at the reserve pit facility, indicates that further actions are necessary, to protect human health or the environment. Please contact Judd Peterson (26%7622) if vou have questions regarding this closure. Sincerely, Laura Ogar Solid Waste Program Manager Division of Environmental Health LO/JL/pea: (G:X£Q-CL ERLrL EZAK'XLT2 K.A_P R~ CC' Bob Elder/)d~.CO/Kuparuk Heather Stockard/ADEC/Juneau Chris Milles/ADNR/Fairbanks .4.10WADF&G/Tairbanks Jim Haynes/ADNR-DOG/Anch Keith Mueller/USFW/Fairbanks Ben Nageak/NSBfBarrow Joe Saumer/ADEC/Anch Judd PetersoWADEC/,~mch STATE OF ALASKA ALA..,.~A OIL AND GAS CONSERVATION COM~,~ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classificati6~'of ~rvi~e Well ~ !'~ ' OIL ~ GAS ~ SUSPENDED ~ ABANDONED ~ SERVICE ~ 2 Name of O~ator 7 Permit Number ARCO AI~, Inc 88-122/9-537 3 Address 8 APl Number P.O. ~x 1003~, Anchorage, AK 99510-0360 ~-103-20102 ~ ~ ~ ,. Z~ 9 Unit or Lease Name 4 Location ofwell atsurface ~ C~. . ~ ~' FSL, 94' FEL, SEC 2, T1ON, R8E UM ~~"[ ~;(~-;~(~ ?.~5-~~ ( 10 WeIIKUPARUK RIVERNum~r At Top Producing Intewal .... ..~,..,~:~.~ 1463' FNL, 1553' FEL,SEC 1, T10N, RSE UM, ~ ' ' ~~,~ :,c.r~ ~' ...... 2K-01 At To~I Depth ~ ~; 11 Field a~ Pool 1350' FNL, 1~4' FEL, SEC 1, T10N, RSE UM ~:~..~:.:~7~ KUPARUK RIVER FIELD 5 Elevation in f~t (indicate KB, DF, etc.) 6 L~se Designation and Serial ~. KUPARUK RIVER OIL POOL RKB 154' ADL: 25588 ALK: 2674 12 Date Spud~ 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Dep~, if offshore ~16 No. of Completions 5/19//89. 5/25/89. 5/21/~. NA feet MSLI 1 17To~IDep~(MD+~D) 18 Plug Back ~pth (MD+TVD) 19 DirectionalSuwey 120 Dep~whereSSSVset ]21 Thick~ssofper~frost 8540' MD &~TVD 84~' MD & ~VD YES ~ ~~~ 1809' f~t MDJ 1400' APPROX 22 Ty~l~t~c or Other Logs Run ~ DIUSFUGR/SPIFDC/CNUCAUCBUGYRO 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE ~. PER ~. GRADE[ TOP ~ ~LE SIZE CEME~ING RECORD AMOUNT PULLED 16" 62.5~ H-40 SURF 115' 24" 179 SX AS II 9 5/8" 36~ J-55 SURF 3719' 12-1/4" 650 SX AS III, 450 SX C~SS G 7" 26~ J-55 SURF 8516' 8-1/2" 220 SX C~SS G 24 Pedorations o~n to Production (MD+~D of Top and BoEom and 25 TUBI~ RECORD inte~al, size and numar) SIZE DEPTH SET (MD) PACKER SET 3-1/2" 8090' 8041' 8260'-8292' 41/2" ~4 SPF MD 6118' - 6144' TVD 26 ACID, FRACTURE, CEME~ SQUEEZE, ETC DEPTH I~ERVAL (MD} [ AMOUNT & KIND OF MATERIAL USED SEE A~ACHED ADDENDUM 27 PRODUCT~N TEST Date First Production [Method of Operation (Flowi~, gas li~ etc.) I Date of T~t Hours Test~ PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL ~TIO TEST PERIOD ~ FIowTubing Casing Pre~ure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVffY-API (coif) Press. 24-~UR ~TE ~ 28 CORE DATA Brief description of lithology, porosi~, fractures, ap~rent di~ and presence of oil, gas or water. Submit core chips. ~:~...~V~D,~.~ .... Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE Ji. 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ARCO Oil and Gas Company Well History- Initial Report- Dally Instmctione: Prepare and submit the "l.illll Rellelt" on the flret Wednesday after a well is spudded or workover operetlone are started. Daily work prior to Nxlddlltg altoald be summarized on the form giving Inclusive dates only. District ARCO ALRSKA INC. Field KUPARUK RIVER 'UNIT rCounty, parish or borough NORTH SLOPE Lease or Unit ADL: 25588 ALK: 2674 Title COMPLETIONS IState AK 2K_llWell .o. Auth. or W.O. no. A~3561 Operator RRCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a,m. 03/28/90 (10) TD: 8540 PB: 8435 SUPV: DB 03/29/90 (11) TD: 8540 PB: 8435 SUPV: DB 03/30/90 (12) TI): 8540 PB: 8435 SUPV:DB 03/31/90 (13) TD: 8540 PB: 8435 SUPV:DB IDate 0.5/19/89 IH°ur Complete record for each day reported NORDIC ~1 00:00 ARCO W,I. 55.8533 Prier status if a W.O. MONITOR WELL FOR FLOW 7"@ 8434' MW:11.3 NaC1/Br ACCEPT RIG @ 2000 HRS 3-27-90. ND TREE, NU BOPE.. PRESSURE TEST BOPE TO 3000 PSI. AOGCC WAIVED. WITNESS OF TEST. RU HALLIBURTON LOGGING SERVICES. RIH WITH PERF GUN AND SHOT 2' OF SQUEEZE PERFS, 8214'-8216' @ 6 SPF 60 DEGREES. POH WITH GUN, ALL SHOTS FIRED. WELL FLOWING, SHUT-IN WELL. NO PRESSURE, NO PIT GAIN. MONITOR WELL AND PREPARE TO PUM~ 5-10 BBLS BRINE. DAILY:S38,942 CUM:$970,575 ETD:S970,575 EFC:$1,566,000 HOLDING SQUEEZE PRESSURE 7"@ 8434' MW:11.3 NaC1/Br PUMPED 10 BBL BRINE INTO FORMATION @ 2 BPM, 1550 PSI. BLEED OFF, WELL DEAD. RUN GR TO 8400', SET EZSV @8241' RD HLS. RIH WITH CHAMP PKR ON DP. SET PKR @ 7916'. RU DOWELL CEMENTERS. TEST BACKSIDE TO 2500 PSI. MIX CHEMICALS, ESTABLISH INJ RATE @ 2.8 BPM, 1900 PSI. BATCH MIX 150 SX CLASS G, 0.4% D-59, 0.4% D-65, 0.2% D-46, 0.1% D-13. FLUID LOSS - 118 CC/30 MIN. PUMP 25 BBL WATER AND 29.5 BBL OF 15.7+ PPG CEMENT FOLLOWED BY 2 BBL WATER. CLOSE BYPASS AND TRAP 500 PSI ON BACKSIDE. PUMP CEMENT INTO FORMATION @ 1 BPM AND 900 PSI INCR TO 1260 PSI. SLOW TO 1/2 BPM @ 1100-1130 PSI. HESITATE WITH 30 MIN SHUT DOWNS BETWEEN 1/2 TO i BBL STEPS ON LAST 4 BBLS. FINAL STEP AFTER i HR SHUT-IN, 1/2 BBL @ 690-1570 PSI. SRUT IN PRESSURE DROPPED TO 1000 PSI AND HELD FOR 5 MIN. RD DO, ELL, CZP @ 0500 HRS. SZP-900 PSI @ 0515. DAILY=S43,941 CUM:$1,014,$16 KTD:$[,014,516 EFC:$1,566,000 CIRC HOLE CLEAN 7"@ 8434' MW:11.3 NaCl/Br HELD SQUEEZE PRESSURE OF 900 PSI FOR 4 HRS. BLED OFF PRESSURE AND ONSET CHAMP PKR. REVERSE OUT DRILL PIPE. POOH AND LAY DOWN PKR. RIH TO DRILL CEMENT. TEST CASING AND SQZ TO 2000 PSI, LOST 20 PSI IN 15 MIN. DRILL FIRM CEMENT FROM 8032' TO 8203' AND 1'-2' OF RATTY CEMENT. RETEST CASING TO 2000 PSI AND LOST 60 PSI IN 30 MIN. CONT DRILLING HARD CEMENT FROM 8205' TO 8225' AND DROP THRU TO EZSV @ 8229'. TEST SQZ PERES (8214'-8216') TO 2000 PSI AND LOST 600 PSI IN 5 MIN. ISOLATE SURFACE SYSTEM AND RETEST TO 2000 PSI AND LOST 450 PSI IN 5 MIN. CIRC TO CLEAN HOLE. ORDERED OUT MORE CEMENT FOR BRADENHEAD SQZ. DAILY:S58,540 CUM:$1,073,056 ETD:S1,073,056 EFC:$1,566,000 RIH WITH 6-1/8" BIT 7"@ 8434' MW:11.3 NaCl/Br CIRC HOLE CLEAN. POOH WITH BIT AND RIH WITH OPEN-ENDED DRILL PIPE. TAG EZSV @ 8236'. DOWELL MIXED 75 SX CLASS G (SECOND SQZ). FL-119 CC/30 MIN. SPOTTED BALANCED PLUG, PUMPED 10 BBL WATER AHEAD OF 15 BBL SLURRY, 2.5 BBL WATER The above is correct Signature For form preparation and distribution, see Procedures Manual, Section t0, Drilling, Pages 86 and 87. BEHIND AND 47 BBLS BRINE. HELD 500 PSI BACKPRESSURE WHILE SPOTTING CEME~tepOOH 10 STAN~S~'eCIP @ 2000 HRS. REVERSE OUT TO CLEAR D~. CLOSE ANNULAR AND SQUEEZE UP TO 2500 PSI, AR3B-459-1 -O Number all daily well history forms consecutively as they are prepared for each well. Page no. ARCO Oil an¢] Gas Company '~' ,, Daily Well His/dry--Interim . Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion, District Field ARCO ALASKA INC. KUPARUK RIVER UNIT Dote and depth Complete record for each day while drilling or workover in progress as of 8:00 a.m. NORDIC #1 04/01/90 ( 14 TD: 8540 PB: 8435 SUPV:DB 04/02/90 ( 15 TD: 8540 PB: 8435 SUPV:DB County or Parish J Stafe NORTH SLOPE AK Lease or Unit I Well no. 2K-1 HELD 5 MIN @ 1500 PSI AND 2000 PSI, NO BLEED OFF. 2.2 BBL TO PRESSURE UP TO 2500 PSI, HELD 15 MIN WITH MINIMAL BLEED-OFF. BLEED DOWN SQUEEZE PRESSURE TO 1000 PSI AND HOLD. RD DOWELL AND PRESSURE HOLDING AT 900 PSI. BLED DOWN SLOWLY AND RECOVERED TOTAL OF 2.2 BBL SQUEEZE VOLUME. POOH, MU BIT AND RIH TO DRILL OUT SQUEEZE. DAILY:S46,033 CUM:$1,119,089 ETD:$l,llg, 089 EFC:$1,566,000 PRMU CASING SCRAPER 7"@ 8434' MW:ll.3 NaCl/Br RIH WITH BIT, TAG CEMENT @ 7922' DRILL SOFT CEMENT TO 7950', FIRM CEMENT TO 8152', GOOD CEMENT TO 8183'. TEST CASING AND CEMENT TO 2000 PSI, LOST 50 PSI IN 15 MIN. DRILLED THRU SQZ PERFS (8209'-8211') TO 8222'. TEST SQZ TO 2000 PSI, LOST 90 PSI IN 30 MIN, GOOD TEST. DRILL TO EZSV @ 8236' AND RETEST TO 2000 PSI, LOST 80 PSI IN 30 MIN. DRILL OUT EZSV @ 8236', PUSH EZSV TO BOTTOM @ 8438' CIRC BU @ 3.5 BPM, POOH. MU 7" CASING SCRAPER. DAILY:S29,085 CUM:$1,148,174 ETD:S1,148,174 EFC:$1,566,000 MU PERF GUN #2 7"@ 8434' MW:ll.3 NaCl/Br RIH WITH CASING SCRAPER. WORK SCRAPER TO PBTD @ 8438' REVERSE CIRCULATE FILTERED BRINE. PUMP 25 BBL SLUG AND POOH WITH SCRAPER. RU HALLIBURTON AND RIH WITH PERF GUN. ORIENTED AND SHOT 8280'-8292' @ 4SPF, 180 DEGREE PHASING, ORIENTED @ 45 DEGREES CCW FROM HIGH SIDE. GUN FIRED OK, POOH. MU GUN #2 (20'). DAILY:S30,147 CUM:$1,178,321 ETD:S1,178,321 EFC:$1,566,000 The above is correct/~X For form preparation and dist.,fi~[ion ~) see Procedures Manual Secti~10, Drilling, Pages 86 and 87 AR3B-459-2-B Number all daily well history forms consecutively las hey are prepared for each well. IPage no ARCO C. ~nd Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Repel1" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted ai$o. whefl operatiOns are suspended for an indefinite or appreciable length of time, On workovers when an official test is not required upon completion, report complellOn~and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District ARCO ALASKA INC. Auth. or W.O. no. AK3561 Operator ARCO I County or Parish I NORTH SLOPE Field ILease or Unit KUPARUK RIVER UNIT I ADL: 25588 ALK: 2674 2K-1 Title I COMPLETIONS State AK IWell no. IA.R.Co, W.I. Date 55. 8533 05/19/89 Complete record for each day reported NOI~>IC 11 Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. 04/03/90 (16) TD: 8540 PB: 8435 SUPV:DB Iotalnumber of wells (active or inactive) on this cst center prior to plugging and J bandonment of this well I our J Prior status if a W.O. 00:00 RIG RELEASED 7"@ 8434' MW:ll.3 NaC1/Br ORIENT GUN 12, PERF "A" SAND 8260'-8280' POOH W/ GUN t2. CHECK HLS NAVIGA- TION TOOL WITH SPERRY MEMORY NAVIGATION TOOL: GUN II - HLS=37 DEGREES CCW, SPERRY-47 DEGREES CCW (TARGET WAS 45 DEGREES CCW) GUN 12 - HLS=44 DEGREES CCW, SPERRY=46 DEGREES CCW (TARGET WAS 45 DEGREES CCW) RD HLS. RIH WITH 3-1/2" COMPLETION INCL ONE 1-1/2" GLM AND FIVE 1" GLMS. DROP BALL AND PRESSURE TBG TO 2500 PSI TO SET PACKER. PRESSURE ANNULUS TO 1000 PSI TO ENSURE SETTING OF PKR ELEMENT. PU AND SHEAR PBR @ 22K LBS. RILDS, PRESSURE TEST SSSV, OK. SET BPV, ND BOPE, NU TREE, TEST TREE TO 5000 PSI, OK. PRESSURE TEST ANNULUS TO 2500 PSI, OK. SHEAR OUT SOS @ 3300 PSI. REVERSE 6 BBL DIESEL INTO ANNULUS AND PUMP 2 BBL DIESEL INTO TBG FOR FREEZE PROTECT. RD AND RELEASE RIG @ 0200 HRS, 4/3/90. MOVE TO 2K-26. DAILY:S186,156 CUM:$1,364,477 ETD:S1,364,477 EFC:$1,566,000 J 'PB Depth Old TD New TD Released rig Date IKind of rig I Classifications (oil, gas, etc.) Type completion (single, dual, etc,) Producing method I Off cia reservoir name(s) I Potentia~ test data Well no. Date Reservoir !Producing Interval Oil or gasTest time IProduction Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity 'Allowable Effective date corrected , , The above is correct iiii , , Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well. jPage no, DIvlNon 01 AllantlcRIchfleldCompeny ADDENDUM WELL: 5/21/90 2K-01 Frac KRU "A" Sand in 10 stages as follows: Stage 1. Stage 2 Stage 3 Stage 4 Stage 5 Stage 6 Stage 7 Stage 8 Stage 9 Stage 10 Pmp 200 bbls Gel/H20; Pre Pad @ 25 bpm 7000-5600psi Pmp 60 bbls Gel/H20; Pre Pad @ 20 bpm 5300-5200 psi Pmp 45 bbls Gel H20; Pre Pad @ 15 bpm 4900-5100 psi Pmp 30 bbls Gel/H20; Pre Pad @ 10 bpm 4450-4950 psi Pmp 74 bbls Slick Diesel 25 bpm 6000-4900 ISIP 2550 Frac gard .78 peal fraction Pmp Pmp Pmp Pmp Pmp Pmp Pmp Pmp Fluid to recover: Sand in zone: Sand in casing: 1100 bbls Gel H20; pad @ 25 bpm 5000-5200 psi 91.9 bbls G/W W/2# 16/20 @ 25 bpm 5200-5000 psi 93.5 bbls G/W W/4~ 16/20 @ 25 bpm 5000-4950 psi 102.8 bbls G/W w/6# 16/20 @ 25 bpm 4950-4785 psi 110.9 G/W W/8# 16/20 @ 25 bpm 4785-4890 psi 69.4 G/W W/10# 16/20 @ 25 bpm 4890-4920 39.2 G/W W/12# 16/20 @ 25 bpm 4940-5050 74 Slick Diesel Flush @ 25 bpm 5072-5182 2239 133,881 0 D~nt~ndent ~ Date SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE i ARCO ALASKA, INC. 2K-1 KUPARUK ALASKA COMPUTATION DATE: 7/19/89 DATE OF SURVEY: 07-18-89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90068 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE TRUE SUB-SEA COURS COURSE DLS TOTAL HEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 0 .00 -154.00 0 0 N .00 E .00 .00 .00 .00 100 100.00 -54.00 0 22 N 9.50 E .37 .32N .0SE .25 200 200.00 46.00 0 33 N 20.90 E .20 1.09N .28E .94 300 299.99 145.99 0 49 N 21.60 E .28 2.21N .72E 2.02 350 349.97 195.97 i 54 N 35.30 E 2.22 3.22N 1.33E 3.15 400 399.88 245.88 4 25 N 42.20 E 5.09 5.32N 3.10E 5.88 450 449.67 295.67 5 58 N 41.40 E 3.12 8.71N 6.12E 10.38 500 499.33 345.33 7 22 N 40.30 E 2.79 13.10N 9.91E 16.15 550 548.84 394.84 8 39 N 43.00 E 2.69 18.-30N 14.56E 23.09 600 598.09 444.09 11 0 N 44.80 E 4.74 24.44N 20.49E 31.61 650 646.96 492.96 13 18 N 47.20 E 4.71 31.74N 28.07E 42.13 700 695.55 541.55 13 56 N 46.80 E 1.27 39.78N 36.69E 53.91 800 791.56 637.56 18 27 N 49.20 E 4.57 58.38N 57.46E 81.79 900 885.95 731.95 20 4 N 49.10 E 1.62 79.96N 82.42E 114.78 1000 979.13 825.13 22 25 N 48.30 E 2.37 103.89N 109.64E 151.02 1100 1070.05 916.05 26 43 N 48.20 E 4.29 1150 1114.31 960.31 28 40 N 48.60 E 3.92 1200 1157.58 1003.58 31 27 N 48.60 E 5.58 1300 1241.48 1087.48 34 27 N 48.80 E 3.00 1400 1322.16 1168.16 37 55 N 48.80 E 3.47 131.58N 140.66E 192.59 147.00N 158.04E 215.83 163.57N 176.83E 240.87 199.47N 217.70E 295.26 238.36N 262.12E 354.29 1500 1399.20 1245.20 41 16 N 49.10 E 3.36 1600 1472.49 1318.49 44 26 N 48.70 E 3.17 1700 1541.87 1387.87 47 41 N 48.80 E 3.25 1800 1607.11 1453.11 50 50 N 48.30 E 3.18 1900 1672.40 1518.40 47 37 N 48.00 E 3.24 280.22N 310.20E 418.02 324.93N 361.44E 486.01 372.40N 415.58E 558.00 422.57N 472.36E 633.76 473.09N 528.78E 709.49 2000 1740.76 1586.76 46 6 N 48.30 E 1.53 2100 1810.73 1656.73 45 5 N 49.20 E 1.21 2200 1881.68 1727.68 44 31 N 49.10 E .57 2300 1949.98 1795.98 49 17 N 48.10 E 4.83 2400 2015.33 1861.33 49 5 N 48.80 E .57 521.77N 583.13E 782.46 568.88N 636.84E 853.89 614.97N 690.14E 924.33 663.27N 744.89E 997.32 713.47N 801.53E 1073.00 2500 2081.46 1927.46 48 6 N 49.10 E 1.01 2600 2148.91 1994.91 47 3 N 49.40 E 1.07 2700 2217.77 2063.77 45 53 N 49.50 E 1.17 2800 2288.35 2134.35 44 18 N 50.30 E 1.68 2900 2360.38 2206.38 43 32 N 50.50 E .78 762.73N 858.09E 1147.99 810.92N 914.02E 1221.79 858.06N 969.11E 1294.26 903.68N 1023.28E 1365.03 947.90N 1076.73E 1434.32 OF ' MED ARCO ALASKA, INC. 2K-1 KUPARUK ALASKA COMPUTATION DATE: SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA 7/19/89 TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN 3000 2433.41 2279.41 3100 2507.32 2353.32 3200 2579.69 2425.69 3300 2647.50 2493.50 3400 2713.24 2559.24 3500 2780.19 2626.19 3600 2847.96 2693.96 3700 2916.72 2762.72 3800 2986.65 2832.65 3900 3057.16 2903.16 4000 3127.93 2973.93 4100 3198.94 3044.94 4200 3269.88 3115.88 4300 3340.60 3186.60 4400 3411.28 3257.28 4500 3481.63 3327.63 4600 3551.23 3397.23 4700 3620.04 3466.04 4800 3688.19 3534.19 4900 3755.36 3601.36 5000 3822.07 3668.07 5100 3889.34 3735.34 5200 3957.11 3803.11 5300 4025.40 3871.40 5400 4093.71 3939.71 5500 4161.36 4007.36 5600 4228.69 4074.69 5700 4296.33 4142.33 5800 4364.17 4210.17 5900 4432.13 4278.13 PAGE 2 6000 4500.13 4346.13 6100 .4568.22 4414.22 6200 4636.47 4482.47 6300 4704.57 4550.57 6400 4772.87 4618.87 42 37 42 4 45 13 49 22 48 24 DATE OF SURVEY: 07-18-89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90068 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. N 50.70 E .93 991.25N 1129.51E N 51.10 E .61 1033.73N 1181.78E N 46.20 E 4.63 1079.37N 1233.50E N 42.60 E 4.92 1131.90N 1284.84E N 43.00 E 1.02 1187.19N 1336.03E 1502.53 1569.78 1638.75 1712.08 1787.16 47 31 47 8 45 58 45 16 45 3 N 43.50 E .96 1241.29N 1386.93E N 43.90 E .49 1294.45N 1437.73E N 43.40 E 1.22 1346.99N 1487.84E N 43.00 E .77 1399.09N 1536.77E N 42.50 E .41 1451.16N 1584.91E 1861.21 1934.57 2006.99 2078.25 2148.90 44 50 44 40 44 56 45 2 45 I N 41.80 E .54 1503.54N 1632.32E N 41.70 E .17 1556.07N 1679.21E N 43.00 E .95 1608.15N 1726.68E N 43.50 E .37 1659.65N 1775.12E N 43.50 E .00 1710.96N 1823.82E 2219.22 2289.26 2359.43 2429.92 2500.48 45 32 46 14 46 47 47 16 48 20 N 44.10 E .68 1762.25N 1873.01E N 46.30 E 1.72 1812.83N 1923.96E N 47.20 E .86 1862.55N 1976.81E N 48.90 E 1.33 1911.46N 2031.23E N 48.80 E 1.07 1960.21N 2087.01E 2571.37 2643.10 2715.65 2788.81 2862.88 47 57 47 30 47 9 46 42 47 7 N 48.80 E .38 2009.27N 2143.06E N 48.90 E .47 2057.96N 2198.78E N 49.00 E .35 2106.25N 2254.22E N 49.00 E .46 2154.18N 2309.36E N 49.10 E .44 2202.04N 2364.52E 2937.36 3011.34 3084.85 3157.88 3230.89 47 43 47 38 47 13 47 20 47 2 N 50.50 E 1.19 2249.57N 2420.76E N 50.60 E .11 2296.55N 2477.86E N 50.70 E .42 2343.25N 2534.81E N 50.70 E .11 2389.78N 2591.67E N 50.80 E .31 2436.20N 2648.48E 3304.47 3378.32 3451.87 3525.24 3598.5C 47 16 46 54 47 1 47 8 46 42 N 50.70 E .24 2482.59N 2705.25E N 50.70 E .37 2528.97N 2761.93E N 49.60 E .81 2575.81N 2818.04E N 48.30 E .96 2623.90N 2873.26E N 48.20 E .45 2672.53N 2927.75E 3671.71 3744.84 3817.8{ 3891.07 3964.1C SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ARCO ALASKA, INC. 2K-1 KUPARUK ALASKA COMPUTATION DATE: 7/19/89 DATE OF SURVEY: 07-18-89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90068 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DGMN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 6500 4841.49 4687.49 46 38 N 48.10 E .09 6600 4910.20 4756.20 46 32 N 48.00 E .12 6700 4978.87 4824.87 46 43 N 47.80 E .22 6800 5048.26 4894.26 45 23 N 46.90 E 1.48 6900 5118.74 4964.74 44 58 N 46.30 E .59 2721.06N 2981.93E 4036.84 2769.63N 3035.97E 4109.49 2818.37N 3089.91E 4182.19 2867.14N 3142.86E 4254.18 2915.88N 3194.41E 4325.11 7000 5189.52 5035.52 44 54 N 46.40 E .10 7100 5260.63 5106.63 44 25 N 46.30 E .48 7200 5332.17 5178.17 44 13 N 45.90 E .35 7300 5403.46 5249.46 44 50 N 45.20 E .79 7400 5474.26 5320.26 45 i N 44.50 E .53 2964.64N 3245.52E 4395.73 3013.17N 3296.39E 4466.01 3061.62N 3346.74E 4535.86 3110.73N 3396.79E 4605.94 3160.79N 3446.60E 4676.48 7500 5545.58 5391.58 43 58 N 44.50 E 1.05 7600 5617.67 5463.67 43 46 N 44.20 E .28 7700 5690.23 5536.23 43 11 N 44.20 E .59 7800 5763.45 5609.45 42 39 N 44.00 E .55 7815 5774.48 5620.48 42 36 N 43.80 E .97 3210.78N 3495.72E 4746.45 3260.34N 3544.17E 4815.64 3309.68N 3592.15E 4884.33 3358.58N 3639.54E 4952.30 3365.90N 3646.59E 4962.44 7900 5837,28 5683.28 42 8 N 44.10 E .60 8000 5912.55 5758.55 40 13 N 48.10 E 3.26 8100 5989.75 5835.75 38 44 N 52.80 E 3.33 8200 6068.79 5914.79 36 50 N 56.70 E 3.05 8300 6150.06 5996.06 34 24 N 55.70 E 2.51 3407.15N 3686.34E 5019.61 3452.81N 3733.73E 5085.39 3493.30N 3782.70E 5148.86 3528.69N 3832.69E 5209.65 3561.07N 3881.09E 5267.22 8400 6233.44 6079.44 32 34 N 56.30 E 1.85 8500 6317.71 6163.71 32 34 N 56.30 E .00 8540 6351.41 6197.41 32 34 N 56.30 E .00 3591.92N 3926.82E 5321.82 3621.80N 3971.62E 5375.05 3633.75N 3989.54E 5396.35 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. HORIZONTAL DISPLACEHENT = 5396.35 FEET AT NORTH 47 DEG. 40 MIN. EAST AT MD = 8540 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 47.67 DEG. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 ARCO ALASKA, INC. 2K-1 KUPARUK ALASKA COMPUTATION DATE: 7/19/89 DATE OF SURVEY: 07-18-89 JOB NUMBER: AK-BO-90068 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 0 .00 -154.00 1000 979.13 825.13 2000 1740.76 1586.76 3000 2433.41 2279.41 4000 3127.93 2973.93 · 00 .00 .00 103.89 N 109.64 E 20.87 20.87 521.77 N 583.13 E 259.24 238.36 991.25 N 1129.51 E 566.59 307.35 1503.54 N 1632.32 E 872.07 305.48 5000 3822.07 3668.07 6000 4500.13 4346.13 7000 5189.52 5035.52 8000 5912.55 5758.55 8540 6351.41 6197.41 2009.27 N 2143.06 E 1177.93 305.85 2482.59 N 2705.25 E 1499.87 321.95 2964.64 N 3245.52 E 1810.48 310.61 3452.81 N 3733.73 E 2087.45 276.97 3633.75 N 3989.54 E 2188.59 101.14 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. 2K-1 KUPARUK ALASKA COMPUTATION DATE: 7/19/89 DATE OF SURVEY: 07-18-89 JOB NUMBER: AK-BO-90068 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 0 .00 54 54.00 154 154.00 254 254.00 354 354.00 -154. -100. . 100. 200. 00 00 00 00 00 .00 .00 .04 N .01 E .68 N .13 E 1.60 N .48 E 3.33 N 1.41 E .00 .00 .00 .00 .00 .01 .00 .03 .02 454 454.00 300. 555 554.00 400. 657 654.00 500. 760 754.00 600. 865 854.00 700. 00 00 00 00 00 9.05 N 6.42 E 18.88 N 15.09 E 32.87 N 29.30 E 50.55 N 48.52 E 72.31 N 73.60 E .35 .32 1.22 .87 3.23 2.01 6.60 3.37 11.98 5.38 972 954.00 800. 1082 1054.00 900. 1195 1154.00 1000. 1315 1254.00 1100. 1440 1354.00 1200. 00 00 00 00 00 96.99 N 101.90 E 126.30 N 134.75 E 162.15 N 175.22 E 205.20 N 224.25 E 255.09 N 281.28 E 18.82 6.83 28.10 9.28 41.83 13.72 61.25 19.43 86.75 25.49 1574 1454.00 1718 1554.00 1872 1654.00 2019 1754.00 2161 1854.00 1300. 1400. 1500. 1600. 1700. 00 00 00 00 00 313.16 N 348.02 E 381.29 N 425.71 E 459.37 N 513.52 E 530.93 N 593.40 E 597.15 N 669.57 E 120.30 33.55 164.13 43.84 218.44 54.31 265.10 46.65 307.19 42.09 2306 1954.00 1800. 2458 2054.00 1900. 2607 2154.00 2000. 2751 2254.00 2100. 2891 2354.00 2200. O0 O0 O0 O0 O0 666.39 N 748.36 E 742.67 N 834.94 E 814.48 N 918.17 E 882.13 N 997.39 E 944.05 N 1072.06 E 352.17 44.98 404.86 52.69 453.47 48.61 497.88 44.41 537.21 39.32 3027 2454.00 2300. 3163 2554.00 2400. 3309 2654.00 2500. 3461 2754.00 2600. 3608 2854.00 2700. 00 00 00 00 00 1003.25 N 1144.17 E 1062.11 N 1214.94 E 1137.48 N 1289.97 E 1220.54 N 1367.23 E 1299.14 N 1442.24 E 573.98 36.77 609.91 35.93 655.99 46.08 707.21 51.22 754.88 47.67 3753 2954.00 2800. 3895 -3054.00 2900. 4036 3154.00 3000. 4177 3254.00 3100. 4318 3354.00 3200. 00 00 00 00 00 1374.95 N 1514.25 E 1448.83 N 1582.77 E 1522.87 N 1649.60 E 1596.56 N 1715.88 E 1669.38 N 1784.36 E 799.57 44.69 841.53 41.97 882.77 41.24 923.57 40.80 964.96 41.39 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 6 ARCO ALASKA, INC. 2K-1 KUPARUK ALASKA COMPUTATION DATE: 7/19/89 DATE OF SURVEY: 07-18-89 JOB NUMBER: AK-BO-90068 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 4460 3454.00 3300.00 4604 3554.00 3400.00 4749 3654.00 3500.00 4897 3754.00 3600.00 5047 3854.00 3700.00 1742.02 N 1853.41 E 1006.54 41.58 1814.83 N 1926.05 E 1050.00 43.47 1887.08 N 2003.45 E 1095.65 45.65 1959.20 N 2085.86 E 1143.96 48.31 2032.56 N 2169.67 E 1193.64 49.68 5195 3954.00 3800.00 5341 4054.00 3900.00 5489 4154.00 4000.00 5637 4254.00 4100.00 5784 4354.00 4200.00 2104.05 N 2251.69 E 1241.42 47.78 2174.09 N 2332.27 E 1287.71 46.29 2244.41 N 2414.51 E 1335.05 47.35 2314.16 N 2499.30 E 1383.56 48.51 2382.79 N 2583.13 E 1430.99 47.43 5932 4454.00 4300.00 6079 4554.00 4400.00 6225 4654.00 4500.00 6372 4754.00 4600.00 6518 4854.00 4700.00 2451.05 N 2666.68 E 1478.10 47.11 2519.35 N 2750.17 E 1525.19 47.09 2588.00 N 2832.36 E 1571.72 46.52 2659.19 N 2912.82 E 1618.49 46.77 2729.91 N 2991.80 E 1664.22 45.73 6663 4954.00 4800.00 6808 5054.00 4900.00 6949 5154.00 5000.00 7090 5254.00 5100.00 7230 5354.00 5200.00 2800.63 N 3070.34 E 1709.73 45.50 2871.12 N 3147.11 E 1754.18 44.45 2940.21 N 3219.88 E 1795.84 41.67 3008.67 N 3291.69 E 1836.71 40.87 3076.40 N 3361.99 E '1876.46 39.75 7371 5454.00 5300.00 7511 5554.00 5400.00 7650 5654.00 5500.00 7787 5754.00 5600.00 7922 5854.00 5700.00 3146.34 N 3432.39 E 1917.34 40.89 3216.57 N 3501.41 E 1957.69 40.35 3285.25 N 3568.39 E 1996.27 38.58 3352.32 N 3633.49 E 2033.15 36.88 3417.84 N 3696.87 E 2068.47 35.32 8053 5954.00 5800.00 8181 6054.00 5900.00 8304 6154.00 6000.00 8424 6254.00 6100.00 8540 6351.42 6197.42 3475.29 N 3759.94 E 2099.95 31.48 3522.50 N 3823.42 E 2127.48 27.54 3562.59 N 3883.32 E 2150.78 23.30 3599.21 N 3937.75 E 2170.39 19.62 3633.75 N 3989.54 E 2188.58' 18.19 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROMRADIUS OF CURVATURE) POINTS SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 7 ARCO ALASKA, INC. 2K-1 KUPARUK ALASKA COMPUTAT, I ON DATE: 7/19/89 DATE OF SURVEY: 07-18-89 JOB NUMBER: AK-BO-90068 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE INTERPOLATED VALUES FOR SPECIAL SURVEY POINTS TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST MARKER 3718 2929.22 2775.22 1356.39 N 8177 6050.43 5896.43 3520.99 N 8184 6056.01 5902.01 3523.36 N 8224 6087.99 5933.99 3536.59 N 8370 6208.17 6054.17 3582.96 N 1496.74 E CSG 3821.17 E TOP KUPARUK C 3824.68 E BASE KUPARUK C 3844.72 E TOP KUPARUK A 3913 · 38 E BASE KUPARUK A 8400 6233.44 6079.44 3591.92 N 8434 6262.09 6108.09 3602.08 N 8516 6331.19 6177.19 3626.58 N 8540 6351.41 6197.41 3633.75 N 3926.82 E SURVEY DEPTH 3942.05 E .PBTD 3978.79 E CSG 3989.54 E TD mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm ARCO ALASKA, INC. 2K-1 S'II~TIGR~PHIC S~Y MEASURED ....... MARKER ....... DEPTH ........ TVD ........ , BKB BKB SUB-SEA COORDINATES WITH REF. TO WELLHEAD ORIGIN: 296FSL 94FEL SEC 02 T10N R08E OSG 3718 2929.22 2775.22 1356.39N 1496.74E '-TOP KUPARUK C 8177 6050.43 5896.43 3520.99N 3821.17E BASE KUPARUK C 8184 6056.01 5902.01 3523.36N 3824.68E TOP KUPARUKA 8224 6087.99 5933.99 3536.59N 3844.72E BASE KUPARUK A 8370 6208.17 6054.17 3582.96N 3913.38E PBTD 8434 6262.09 6108.09 3602.08N 3942.05E CSG 8516 6331.19 6177.19 3626.58N 3978.79E TD 8540 6351.41 6197.41 3633.75N 3989.54E mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm~mmmmmmmmmmmmmmmmmmmm COMPUTER PROGRAM - SPERRY-SUN THREE DIMENSION RADIUS OF CURVATURE mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm, DATE OF SURVEY: 07-18-89 COMPUTATION DATE: 7/19/89 JOB NUMBER: AK-BO-90068 KELLY BUSHING ELEV. = 154.00 FT. SPERR,-SUN DRL G. '-'~S VCS. 2K-1 KUPARUK ALASKA 07-18'-89 HORTZONTAL PROJECT'[ON . START FZNZSH TVD - SCALE ZS 1000 TVD - 0 6351.41 FEET/TN if 0000 SO00 4000 80~0. 2000 IOO0 1oho oobo DEPARTURE 8540 4oho soho 2K-1 KUPARUK ALASKA 07-18.69 SPERR.'T-SUN VERTICAL DRL G. ~SVCS. PROJECT_TON START TVD -0 FINISH TVD m 6351.41 SCALE IS 1000 FEET/IN 1000 2000 8000 400o SO00 8000 1000 5308.35 1oho ~obo oobo 4oho VERTICAL SECTION soho soho AOGCC G~EOLOGICAL MAI'EHIALS INVENTORY LIST FOR DEVELOPMENTAL WELLS PERMIT # ¢P,~ - /"~--~ WElL NAME COMPLETION DATE ,,~ ! .~ !,~" CO, CON'I"ACT Ill J! J' S~ALE -J I I i I I' ! STATE OF ALASE^ " ALASi~ Oil. A OA,q COI;SERVAT1OI{ C(ff.fi.li$,qlPl! .. §,O.F.E. {riel, err. ton llepo~C Trip i'tc Gause Gas Da{:ec:ors ACUUHULAIOR $¥$1~EH Pump incr. clos, pres. 200 Full Cl,at{e Fre~su~, Attni,,ed:~mi~see. Upper l~lly Test Pressure ...... , ..... __._ Low, r Kelly,_ ~_.le;~ rressure~~ ....... ~sI1 rype~Test Pre~sure.=:~O0_ = · _ _ Inside BOP Test rres~ur~ .... -_-_- ...... _ _ Choke l.[nnifold~%est Pressure ,o. ~,.{,_ ._ ~ ~ .... ' ~ _ ,, , J, , _- .... · . _: :- - ... .... ., Repair or Rep2acemen: o£ iatled equipment co ba mede within. . days aud In~recto~/ Co~ia~ton office no~i~ted. ~: : ~ ~'' ~ '. :'= ...... ~ _ _ ........ _ ~ .~:~ - _ - a .. ., i ., "ori8 - AO&GCC 'co - Opera:ur cc - Supervi;ot ARCO Alaska, Inc. Date: December 6, 1989 Transmittal #: 7620 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2 K - 1 2 Acoustic Cement Bond Log 9 - 2 4 -~ 8 9 4 5 8 8 - 6 9 0 6 2 K - 1 I Acoustic Cement Bond Log 9 - 2 3- 8 9 4 9 9 8 - 6 7 7 0 2 K - 0 6 Acoustic Cement Bond Log 9 - 2 2 - 8 9 5 5 0 2 - 7 9 2 0 2 K - 0 5 Acoustic Cement Bond Log 9 - 2 6 - 8 9 5 3 5 6 - 7 8 0 3 2 K - 01 Acoustic Cement Bond Log 9 - 2 3 - 8 9 5 8 3 8 - 8 4 4 0 Receipt Acknowledged: R 'CEiVED DISTRIBUTION: NSK Drilling State of Alaska(+sepia) ARCO Alaska, Inc. Date: November 20, 1989 Transmittal #: 7608 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2K-01 PET Log 7-1 7-89 5400-8445 Receipt Acknowledged' DISTRIBUTION: Date: Drilling NSK State of Alaska(+sePia) RECEIVED NOV22].989 ~laska 0ii & Gas Cons. Commissio~ Anchorage KUPARUK ENGINEERING TRANSMITTAL # 1310 TO John Boyle - State FROM: Ken Griffin/l:'. S. Baxter DATE: October 5, 1989 WELL NAME: KRU 2K- 1 CONFIDENTIAL TRANSMITFED HEREWITH ARE ONE COPY OF THE FOLLOWING: One copy of sepia film each: 2K-1 Halliburton Temperature Log 9/23/89 run 1 PLEASE RETURN RECEIPT TO: ARCO Alaska, Inc. ~~,~.~ ATTN: P. S. Baxter, ATO-12(p~V"~~)J~,~ P. O. Box 100360 ~-- · ,, ...... "---. Anchorage, Alast-~e~h'h'~h~/~la$1ia 011 & taa~ ou.~ W~.~ Anchorage RECEIPT ACKNOWLEDGED: DATE: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION _ APPLICATION FOR SUNDRY APPROVAl]St{ 1. Type of Request: Abandon __ Suspend __ Operation shutdown .,~ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing __ Variance __ Perforate __ Other __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 296' FSL, 94'FEL, Sec. 2, TION, RCE, UM At top of productive interval 1265'FNL, 1556'FEL, Sec. 1, TION, R8E, UM (Approx) At effective depth 1322' FNL, 1491' FEL, Sec. 1, TION, R8E, UM (Approx) At total depth 1299'FNL~ 1465'FEL, Sec. 1~ TION, R8E, UM (Approx) 12. Present well condition summary Total depth: measured 8540' MD feet true vertical 6392' TVD feet Effective depth: measured 8434' MD feet true vertical 6293' TVD feet 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) RKB 154' 7. Unit or Property name Kuparuk River Unit Welt number 2K-1 9. Permit number 88-122 10. APl number 50-- 103-20102 11. Field/Pool Kuparuk River 0il pool Plugs (measured) None Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 16" 3679 ' 9-5/8" 8488 ' 7" measured None true vertical Cemented Measured depth 179 sx Arctic Set II 650 sx Arctic Set II!, 450 sx Class G, +85 sx AS I 220 sx Class G 115' MD 3718' MD 8516' MD RECEIVED True vertical depth 115' TVD 2946' TVD 6363' TVD Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None JUI-j 2 0 i989 A~aska Oil & Gas Cons. Commissio~ Anchorage feet 13. Attachments Description summary of proposal __ Detailed operations program ~ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: 16. If ~roposal was verbally approved Oil X Gas __ Name of approver ~/~ Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~J~,~~~~~Title Area Drilling Engineer /// ,/_/ ' ~ F.O~~MISSION USE ONLY (SRE) SA1/6 Conditions of approval! Notif~fCommission so represen"t~tive may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- 0o~¥ ORIGINAL SIGNED BY Approved by order el the Commission i. ONNIE C. SMFFH Commissioner Suspended__ Date I Approval No. ¢.. ~, ..~ Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ARCO Oil and Gas Company Well History - Initial Report- Daily Inatructienl: Prepare and submit the "lnitlll Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ICounty, parish or borough I ARCO ALASKA INC. I NORTh[ SLOPE Field ~Lease or Unit I KUPARUK RIVER UNIT IT,fie ADL: 25588 Auth. or W.O. no. I ' AK3561 I DRTT'T'TN~ State 2K-'[ tWell no. Operator IARCO W.I. ARCO APl: 50-103-~010[2H Spudded or W.O. begun Date Prior status if a W.O. SPUD 05/19/89 . 22;30 Date and depth as of 8:00 a.m. 05/20/89 ( TD: 798'( SUPV:CD 05/21/89 ( TD: 3570'( 2 SUPV:CD 05/22/89 ( TD: 3738'( SUPV:CD 05/23/89 ( . TD: 5477' ( 1' SUPV:CD 05/24/89 ( i TD: 7900'( 2. SUPV:CD 05/25/89 ( TD: 8520'( SUPV:CD 05/26/89 ( TD: 8540'( SUPV:CD Complete record for each day reported DOYEN 14 .) DRILLING SURFACE HOLE MW: 9.1 VIS: 63 ~98) MOVE RIG, NIPPLE UP DIVERTER SYSTEM, MU BHA, FUNCTION TEST DIVERTER, SPUD IN AND DRILL SURFACE, REPAIR LEAKING DIVERTER VALVE AND CONVEYOR LEAK, KICKOFF AT 300' AND DRILL AHEAD DAILY=S159,924 CUM:$159,924 ETD=S159,924 EFC=$1,565,700 !) TOH FOR WASHOUT MW: 9.5 VIS=110 ~72) DRILL 798-2680, REPAIR CUTTINGS CONVEYOR, CLEAN UP MUD SPILL, DRILL 2680-3570, TOH FOR WASHOUT. DAILY:S53,225 CUM:$213,149 ETD:S213,149 EFC:$1,565,700 ~) DOING TOP JOB ON 9-5/8" 9-5/8"~ 3716' MW: 9.7 VIS= 60 .68) CHANGE BIT, WASHED OUT CENTER JET, TIH, DRILL 3570-3738,CBU, SHORT TRIP, CBU, TOH, LD BHA, TIGHT 1750-2000,RU AND RUN 96 JTS 9-5/8" 36# J55 CSG, SET AT 3716, RU DOWELL, PUMP 80 BBLS WATER, 650 SX ASIII, 450 SX G, BUMP PLUG, FLOATS HELD,FULL RETURNS, NO CEMENT TO SURFACE, NIPPLE DOWN DIVERTER, DO TOP JOB. DAILY:S209,772 CUM:$422,921 ETD:S422,921 EFC:$1,565,700 ) DRILLING 8-1/2" HOLE 9-5/8"~ 3716' MW: 9.3 VIS: 34 39) MU BRADENHEAD, NU BOP'S, TEST BOP STACK, PU BHA, TIH, TEST CSG TO 2000 PSI, DRILL OUT FLOATS, 10' FORMATION, DISPLACE TO MOD, TEST SHOE TO 12.7 PPG EMW, NO LEAKOFF, DRILL AHEAD 3748-5477. DAILY:S70,207 CUM:$493,128 ETD:S493,128 EFC=$1,565,700 ) TOH FOR CONV BIT & BHA 9-5/8"~ 3716' MW=10.5 VIS= 34 23) DRILL 5477-7900 ,WEIGHT UP TO 10.5 PPG WHILE DRILLING 7600-7900, CIRC AND ~ SURVEY, DROP SINGLE SHOT, TOH TO LD TURBINE AND PCD BIT PRIOR TO DRILLING INTO KUPARUK. DAILY:S53,738 CUM:$546,866 ETD:S546,866 EFC:$1,565,700 ) DRILLING IN KUPARUK 9-5/8"~ 3716' MW:11.1 VIS: 51 20} CONTINUE TOOH, LD TURBINE, PU CONV BHA, TIH, SLIP LINE, TIH, REAM 60' TO BTM, DRILL 7900-8520, INC MW TO 11.0 PPG WHILE DRILLING, WELL FLOWING ON CONNECTIONS, INC MW TO 11.1 PPG. DAILY:S72,526 CUM:$619,392 ETD:S619,392 EFC:$1,565,700 ) TOH LD DRILL' PIPE 9-5/8"~ 3716' MW:11.2 VIS: 47 20) DRILL 8520-8540,CBU,SHORT TRIP 20 STDS,CIRC, INC MW TO 11.2,DROP SINGLE SHOT, TOH, RU SCHLUMBERGER, LOG WITH TRIPLE COMBO, TIH W/ BHA, CIRC,SPOT DIESEL PILL, H TOH, LD DP FOR CASING. DAILY:S110,805 CUM:$730,197. ETD=S730,197 EFC=$1,565,700 For form preparatigj~d distribution, see Procedures tyl~n,al, Section 10, Drilling, Pages 8%..add 87. AR3B-459-1 -O Number all daily well history forms consecutively Page no. as they are prepared for each well. ~ I ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of ail cores. Work performed by Producing Section will be reported on "Interim'* sheets until final completion. Report official or representative test on "Final" form. 1) Submit "lltterlm" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin6 until completion. District ARCO ALASKA INC. IState ICounty or Parish NORTH SLOPE Field ~Lease or Unit KUPARUK RIVER UNIT I 2K-1 Date and deptll Complete record for each day while drilling or workover in progress as of 8:00 a.m. DOYON 14 no. 05/27/89 ( TD: 8434'( SUPV:CD NU TUBING SPOOL 7"@ 8434' MW:11.3 VIS: POOH LD DP, RU AND RUN 217 JTS 7 "26# J55BTC CSG, LOST RETURNS WHILE RUNNING PIPE, BRK CIRC, NO RETURNS, CEMENT CSG W/ 220 SX CLASS G, DISP W/ 11.3 PPG BRINE, BUMP PLUG, ATTEMPT TO TEST CSG TO 3500,N0 TEST, SET 7" SLIPS, ND BOP STACK, NU TBG SPOOL. DAILY:S197,782 CUM:$927,979 ETD:S927,979 EFC:$1,565,700 RE:CEIVED The above is correct Sign~J - For f'orr~ preparatio~a~d ~istribution ~ see Procedures M n~_~.ual Section 10, Drilling, Pages 86-~nd 87 · AR3B-459-2-B INumber all daily well history forms consecutively IPage no. as they are prepared for each well. I ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time, On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "FInsl Report" form may be used for reporting the entire operation if space is available, District County or Parish Field Lease or Unit ARCO ALASKA INC. I NORTH SLOPE Auth. orW.O, no. ITitle ADL: 25588 KUPARUK RIVER UNIT 2K-1 AK3561 DRILLING Operator Spudded or W.O. begun ARCO Date and depth as of 8:00 a.rn.sp, gD 05/28/89 ( TD: 8434'( SUPV:CD IAccounting cost center code State Well no. A.R.Co. W.I. [Total number of wells (active or inactive) on this~ Icost center prior to plugging and 1 I.l_bandonrnent of this well IPrior status if a W.O. Date A~I= 50-103-201~;°ur ~56. 0000 Complete record for each day reported 05/19/89 22:30 DOYON 14 RELEASED RIG 7"@ 8434' MW: 0.0 VIS: NO TBG SPOOL AND LOWER TREE,TEST PACKOFF TO 3000,SECURE WELL, BLOW DOWN BRINE, RELEASE RIG AT 0700, 5-27-89. DAILY:S3,654 CUM:$931,633 ETD:S931,633 EFC:$1,565,700 Old TD New TD PB Depth Released rig Date K nd o r g Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The abov~x~s ...... t ~' ID~-~///~ Signatur~ t ('/ ~ For form preparati,e~nd distribution. / / 0 see Procedur~ Mgn~l, Section 10, Drilling, Pages 86~nd 87. Number all daily well history forms consecutively I Page no. a as they are prepared for each well. I AR3B-459-3-C Olwlalon of AtlantlcRichfleldCompan¥ ARCO Alaska, Inc. Date: June 16, 1989 Transmittal #: 7492 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2 K - 0 3 OH EDIT Tape and Listing 6 - 0 8 - 8 9 # 7 3 3 6 0 2 K - 01 OH EDIT Tape and Listing 6 - 0 3 - 8 9 # 7 3 3 5 0 Receipt Acknowledged: DISTRIBUTION: Lynn Goettinger State of Alaska ARCO AlaSka, Inc. Date: June 2, 1989 Transmittal #: 7485 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2 K - 01 2" Dual Indcution - SFL 5 - 25 - 89 1 000 - 8528 2K-01 5" Dual Indcution - SFL 5-25-89 1 000-8528 2K-01 Cyberlook 5-25-89 7950-8450 2K-01 2" & 5" Raw FDC 5-25-89 3742-8502 2K-01 2" & 5" Porosity FDC 5-25-89 3742-8502 Receipt Acknowledged: ........................... Date: ............ DISTRIBUTION: NSK Drilling State of Alaska(+sepia) Franzen D&M L. Johnston(vendor package) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM MISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program ~ 2. NameofOperator ARCO Alaska, Inco 3. Address P. 0. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 296' FSL, 94' FEL, Sec. 2, T10N, R8E, U.M. At top of productive interval 1320'FNL, 1580'FEL, Sec. 1, T10N, R8E, UH At effective depth At total depth 1174'FNL, 1429'FEL, Sec. 1, TION, R8E, 12. Present well condition summary Total depth: measured true vertical Operation shutdown __ Re-enter suspended well ~ Plugging __ Time extension __ Stimulate __ Pull tubing __ Variance __ Perforate ~ Other 5. Type of Well: Development Exploratory Stratigraphic Service UM Well has not spudded feet Plugs (measured) feet Effective depth' measured feet Junk (measured) true vertical feet Casing Length Size Cemented Structural Conductor Surface 3639 ' 9-5/8" To surface Intermediate Production 8557 ' 7" 500 ' above Liner Kuparuk Perforation depth: measured 7. Unit or Property name Kuparuk River Unit 8. Well number 214-1 9. Permit number 88-122 10. APl number 50-- 103-20102 11. Field/Pool K. ELE! V gl~ MAY 1 0 1989 Alaska 0tl & Gas Cons. Commission Anchorage Measured depth True vertical depth 3675 'MD 2942 'TVD 8592'MD 6328'TVD truevertical Thi~ sundry.reqqes~.revi~e~ the.~arg~t ~or subject well resulting in revised casing setting oeptns ano oirectlona~ p~an. Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 13. Attachments Description summary of proposal __ Detailed operations program __ Revised directional plan, conductor as built survey for 2K BOP sketch __ 14. Estimated date for commencing operation May 18, 1989 16. If proposal was verbally approved Oil ~ Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~, "~', ~,~x.~.~ Title Area Drilling Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance ~ Mechanical IntegrityTe~t __ Subsequent form required 10- /)~/. Approved C.opy Returned ORIGINAL SIGNED BY Approved by order oftheCommission LONNiE C SMITH Commissioner Date '~'-/¢//~ '~ ('r~M)SA1/2 5/9/89 I^ .rova 15. Status of well classification as: Gas__ Suspended__ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE 6. Datum elevation (DF or KB) RKB 154' feet ARCO' ALASKA. I no. Pad 2K, Wel I No, 1 Revised Pr-oposal Kupar'uE Field. Nor'~:h Slope, Alasl<a ! 1000 _ 2000_ 5000_ 4000 _ 5000_ 6000 _ 7000 ,, RKB ELEVATION~ 154.' KOP TVD=300 TMD=300 DEP=O 3 ~ 9 BUILD 3 DE(~ , 15 PER 100 FT '% 33 B/ PERHAFROST TVD=I 424 THD=I 502 DEP=366 '% 39 T/ UGNU SNDS TVD=1546 THD 1657 DEP=462 '~ COO TVD=1685 THD=1850 DEP'-'595 '~ B/ W SAK SNDS TVD 2742 THD 3385 DEP 1708 '~,~ 9 5/8' CSG PT TVD=2942 THD-3675 DEP=1919 ",~ K-lO TVD=3191 THD=4037 DEP,'2181 AVERAGE_ANGLE ~ 46 DEG 29 HI N ~ RECEIVED K-5 TVD=4584 THD--6060 DEP=3648 ~ ~AY' I 0 ]gSg Alaska 011 & Gas Cons. Commission Anchorage T/ ZONE A TVD--6066 THD--8212 DEP=5209 TARGT CENTR TVD--6128 THD=8302 DEP=5274 ~.i ~ '.. B/ KUP SNDS TVD=6190 THD=8392 DEP=5340 TD (LOG PT) TVD=6328 TMD=8592 DEP=5485 I I I I I I 1 000 2000 3000 4000 5000 6000 VERTICAL SECTION HORI'-']NTAL PROJECT ION SCALE 1 IN. = 1000 FEET ARCO ALASKA, !ne. Pad 2K. We I I No ~ ] Rev Ieed Propoeal Kuparuk Field' North SI ope. Aleska 1 000 4000 5000 _ 2OOO _ 1 000 _ ~ 1000 _ SURFACE LOCATION 2g~' FSL. g4' FEL SEC. 2. T!ON. RSE ~/EST-EAST 0 1 000 2000 I I I TD LOCATION' 1174' FNL, 1429' FEL SEC. I. TION. RGE TARGET LOCATION' 1,320' FNL. 1580' FEL SEC. I. T 1 ON. RGE 3000 I 4000 I TARGET CENTER TYD=6!28 TMD=8302 DEP-5274 NORTH 3664 EAST 3794 RECEIVED MAY 1 o D&9 Alaska Oil & Gas Cons. Commission Ancl~orage N 46 DE(:; E 5274' (TO TARGET) , i i ~i SECTION 2, T' lO N'~ R' 8 E'~ ~ ~ ~j i UMIAT MERIDIAN. ~ ~d ~ SECTION II,lION., R. 8 E., ION , .~ UMIAT MERIDIAN. N.~S. ' O:O SECTION I ~ ~ ~ D.S. 2K .tS } ~RACTED ~tes: VICINITY MAP I"= ImL ~ ~ ~5 SECTION CORNER I. CO0~INATES ARE ~R ZONE 4. ~6:~1 ~. ALL DI~ANC~ SHOWN ARE TRUE. SECTION II t~t9 SECTION I~ i ' ~t 3. ELEVATIONS ARE B.P.M.S.L. : ~..o.~zo,~ ,osmo, ~s~ o. z-~ co,~,o~ ~ .o.u.~.~s PE. ~NS~U.~ S ~OC~S. MAY 1 0 ]989 ~..~.~.c~ ~.~ ~oo~= ~..-~,.~. ~.~. ~ Naska Oil & Gas Cons. Commissio~ 5e, 59, 65 ~ Well ,y ASP's ~cnorage Dist. Dist. : O.G. ~d ' ' ' ~TITUDE ~NGITUDE ES.L. EE.L. i Elev. Elev. N~. X ; ,, I i 5,938,600.18 498~310.17 ~ 70Ol4'36.519 150°00'49.133'' 296' 94' 114.0 118.5 2 ~ 5,938,575.14 498,310.28 ~ 70° 14' 36.27~" 150°00'49.130'' 271' i 113.9 ~' 9" o' 3 ~ 5,938,550.~0 498,310.35 70° 14, 36.02 15000 49.128" 246' 113.8 4 i 5,938~525.46 498,310.06 70°1 35.784" 150°00'49.136" 222' 113.8 4' 5 ~ 5,938,500.19 498,310.12 70° 14, 35.5~6" 150°00'49.134'' 196' 11~.8 6 ~ 5,938,475.14 498,310.3~ 70°1 ~5.289" 150°00'49.128'' 171' 113.8 i 35.0~" 150°00' 49.127'' 146' 113.8 , , 8 5,938~425.30 ~ 498~310.18 70Ol4,4'34.799'' 150°00'49.132'. 121' 113.8 ~ ~,.~.,~oo.~o ~..,~o..~. ~oo,,,.~,, ,~oooo,~.,~},,,, ~, ,,~.~ I0 i 5,938,375.19 i 498,510.14 70°! 34.306'J ~ 150°00'49.15 71' t 113.9 ' . " , 46, ~ 113.9 II 5,938,350.22 498,310 14 70°14'34.061 i 150°00 49.133" . , 12 5,938,325.20 498,310.17 70Ol4'33.815.' ~ 150°00'49.131'' ~1' 94' 113.9 118.5 ' i I EN.L. 13 5,938,235.31 498,310.37 70014'32.930'' 1150 °o0'49.125'' 69' 94' 113.7 118.5 14 5,938,210.14 498,310. i6 70014'32.683'' ~ 15o° 0o' 49.131'' 94' 113.7 15 5,938,185.12 498,310.16 70Ol4' 32.437'' i 150°00'49.131'' 119' 113.8 I 16 5,938,160.11 ~ 498,310.20 70Ol4' 3Z. 191'' i 150° 00' 49. 130'' 144' 113.8 17 5,938, 135.21 498,310.18 70°14'31.946'' ~150°00'49.130" 169' ' 113.9 ~18 5,938, 110.19 498,310.29 70°14'31.700'' 150°00'49.127'' 194' 114.0 i 19 5,938,085.20 498,310.27 70014' 31.454" 150°00'49.127'' 219' , 114.0 i20 5,938,060.14 498,310.22 70°14'31 207" 150°00'49.128'' 244' ~ 1'14.1 ~, ~.~.o~.,~ ~.~,o.,~ ~oo,~:~o.e~" ,~0ooo'~..,~o" z~' , ,,~.o ~22 5,938,010.40 498,310.19 70°1w 30.718" 150°00'49.129" 294' : 94' 114.0 5,937,985.32 498,310.13 70°14'30.471'' 150°00'49.130'' 319' 95' i 114.0 5t9~7,960.29 , 498,310.08 70o14' 30.225" 150° 00'49. 132" 344' 95' 113.9 118.5 I HEREBY CERTIFY THAT I AM ~ ... ' ~o ,,~c~,~ .~.~ ~.v~,,~ ,, ~.~:..,.~ ,~,. ~ ARCO" A~ska. STATE OF ALASKA AND THAT THI~ ~eeeeeoeeeeeeeeeeeeee ...... BY ME OR UNDER MY DIRECT SUPER- · DRILL SITE 2-K co. uc o. AND OTHER DETAILS ARE CORRECT ~...0 =.. AS OF NOVEMBER ZO, ,988. -,'~.'.......* ~' ~ & ~[~ ~ev. OX Oofe Oea~ri~fio~ ~te.'11/21/88 !~. N~RSK 6.211. d 4 J Well ,y ASP's , , Anchorage Dist Dist. O.G. i~3d N(~ ' X LATITUDE LONGITUDE F.S.L. EE.L. Elev. Elev. I 5,938,600.18 498,310.17 70Ol4'36.519" 150°00'49.153'' 296' 94' 114.0 118.5 2 5,958,575.14 498,310.28 70° 14' 36.273" 150o00'49.130" 271' 113.9 i $ 5,938,550.30 498,;510.35 70° 14.' 36.029" 150°00'49.128" 246' I 1:5.8 I 4 5,938,525.46 498,510.06 70Ol4'35.784'' 150°00'49.156'' 222' 11:5.8 5 5,9:58,500.19 498,310.12 70014' $5.556" 150°00'49.154'' 196' 113.8 6 5,9:38,475.14 498,$10.35 70014'35,289" 150°00'49.128" 171' 11;5.8 55.046" 150000' 49.127'' 146' 113.8 7 5,93,8,450.36 498,310.36 70014. , 8 5,9:38,425.30 498,310.18 70Ol4' :54.799" 150000'49.132'' 121' 113,.8 9 5,9:58,400.30 498,3,09.98 70°14' 34.553" 150°00'49.137'' 96' I 1:3.8 I0 5,958,$75.19 498,510.14. 70014' 34.306'; 150000' 49. 1:55'' 71' t 113,.9 I I 5,9:58,550.22 498,510.14 70° 14' :54.061 " 150° 00' 49. 135" 46' 't 113.9 12 5,938,325.20 498,310.17 70014'35.815 '~ 150°00'49.131" 21' 94' 113.9 118.5 EN.L. 1.3 5,938,235.31 498,310.$7 70 o 14' ;52.930" 150 °o0' 49.125'' 69' 94' 113.7 118.5 14 5,938,210.14 498,$10. i6 70014'32.683'' 15o°0o'49.151'' 94' 113.7 15 5,938,185.12 498,$10.16 70Ol4' 32.457' 150° 00' 49. 131'' 119' 113.8 16 5,938,160.11 ! 498,310.20 70°14' :32. 191 " 150°00'49. 1.30" 144' 113.8 17 5,9:58, 1:55.21 498,510.18 70°14' 51.946" 150°00' 49.150'' 169' ' 115.9 18 5,958,110.19 498,310.29 70°14'51.700'' 150000'49.127'' 194' 114.0 19 5,958,085.20 498,310.27 70014' :51.454" 150°00'49.127'' 219' 114.o 20 5,958,060.14 498,310.22 70Ol4'31.207" 150° 00'49. 128'' 244' 1'14.1 21 5,938,035.16 498,310.16 70o 14' $0.962'' 150° 00'49. 130" 269' 114.0 22 5,958,010.40 498,;510.19 70Ol4'50.718" 150°0o'49.129" 294' 94' 114.0 25 5,9:37,985.32 498,310.13 70Ol4'30.471" 150°00'49.1:50" 319' 95' 114.0 24 5 t957,960.29 498,510.08 70o14' 50.225" 150° 00'49. 132" 344' 95' 113.9 118.5 ARCO Alaska, Inc. Post Office BoX '100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 12, 1988 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Conductor As-Built Location Plat- 2K Pad (Wells i - 24) Dear Mr. Chatteron' Enclosed is an as-built location plat for the subject wells. any questions, please call me at 263-4618. Sincerely, If you have D. Martin Engineering Aide DM'hf Enclosure RECEIVED DEC 1 :f 1988 Alaska 0il & Gas Cons. C0mmissim] Anchorage GRU13/010 ARCO Alaska, Inc. is a Subsidiary of AllanlicRichfieldC~)mpany N.T.S. SECTION fECTION 6 ! I, WELLS 1'12 ARE LOCATED IN SECTION 2, T. I0 N., R. 8 E., UMIAT MERIDIAN. WELLS 13-24 ARE LOCATED IN SECTION I I, T. I0 N., R. 8 E., UMIAT MERIDIAN. SECTION I PROTRACTED SECTION CORNER Notes: I. COORDINATES ARE A.S.P. ZONE 4. T ION SECTION 12 2. ALL DISTANCES SHOWN ARE TRUE. 3. ELEVATIONS ARE B.P.M.S.L. RECEIVED DEC 1 ;f 1988 4. O.G. ELEVATIONS FROM CED- RIXX-$311, re~4. 5. HORIZONTAL POSITION BASED ON 2-K CONTROL MONUMENTS PER LOUNSBURY $ A~OClATES. 6. REFERENCE FIELD BOOK: L 88-40, p~s. 55,56, 58,59, 65 I~ 66. Well ASP's AlaSlia oil & ~.%~*~ Con:.,. ;.;on' ,,'~;:::;;'::; Dist. Dist. O.G. ~d ~. 'Y' 'X' ~M~ ~NGITUDE ES.L. EEL. Elev. Elev. ,., I 5,938,600.18 498,310.17 70014'36.519" 150°00'49.133" 296' 94' 114.0 118.5 2 5,938,575.14 498~310.28 70° 14' 36.273" 150°00'49.130'' 271' 113.9 3 5,938,550.30 498,310.35 70° 14' 36.029" 150°00'49.128'' 246' 113.8 4 5~938~525.46 498,310.06 70o14' 35.784" 150°00'49.136" 222' 113.8 5 5,938,500.19 498,310.1Z 70°!4' 35.536" 150° 00'49.134'' 196' 113.8 6 5,938,475.14 498,310.33 70014' 35.289" 150°00'49.1~8" 171' 11~.8 1 ii ii 7 5,938,450.36~i 498,310.36 70014,35.046 150°00'49.1~7 146' 113.8 8 5,938,425.30 498,310.18 70°1 34.799" 150°00' 49.13~'' 121' 113.8 9 5,938,400.30 ~ 498,309-98 70°14'34.553'' 150o00'49.137" 96' 113.8 ~ I0 5,958,375.19 498~ 510.14 70014, 34.306 150°00,49.133" 71' 113.9 II 5~938~350.22 498~310.14 70°1 34.061 " 150o0 49.133" 46' 113.9~ 12 5,938,325.20 498,310.17 70°14'33.815'' 150°00'49.131" 21' 94' 113.9 118.5 FN.L. 13 5,938,235.31 498,310.37 70° 14' 32.930" 150°00'49.125'' 69' 94' 113.7 118.5 14 5,938,210.14 498,310.16 70°14' 32.683'' 150°00'49.131" 94' ~ 113.7 15 5,938,185.1Z 498,310.16 70°14' 32.437'' 150°00'49.131" 119' ~ 113.8 16 5,938, 160.11 498,310.20 70°14' 32. 191" 150° 00' 49. 130'' 144' ~ 113.8 17 5,938, 135.21 498,310.18 70°14'31.946" 150°00'49.130'' 169' 113.9 18 5,938, 110.19 498~310.29 70°14'31.700'' 150°00'49.127" 194' ~; 114.0 19 5~938,085.20 ~ 498~310.27 70014' 31.454" 150 ° 00' 49.12T'' 219' 114.0 20 5,938,060.14 ~ 498,310.22 70°14'31.207'' 150° 00'49. 128" 244' 1'14.1 21 5,938,035.16 ~ 498~310.16 70° 14' 30.962'' 150°00'49.130" 269' 114.0 22 5,938,010.40 498,510.19 70o14' 30.718" 150° 00'49. 129" 294' 94' 114.0 23 5,937,985.32 498,310.13 70 °14' 30.471" 150° 00'49. 130'' 319' 95' 114.0 24 5~937~960.29 498,310.08 70°14'30.225" 150°00'49.132'' 344' 95' I 113.9 118.5 I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED ,. STATE OF ALASKA AND THAT THIS oOoeeeeeeoeoeeeeeoeee~eeo ~ BY ME OR UNDER MY DIRECT SUPER- · p~- · DRILL SITE 2.K viSION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT '~"' ~-6~ ."~,~ CONDUCTOR AS-BUILTS ~ , ~ A,q~ , ~,'E ~ Dr. b~,.' M.O'D SAt. I ~f I 13efe.'ll/?l/88 D~'~./Vo. NSK 6.211. d 4 October 19, 1988 Telecopy No. (907) 276-7542 J B Kewin Regional Drilling Engineer ARCO Alaska, Inc P O Box 100360 Anchorage, AK 99510-0360 Re' Kuparuk River Unit 2K-1 ARCO Alaska, Inc Pe~it # 88-122 FSi, , , , , Surf Loc 300' T 90'FEL Sec 2 T10N RSE UM Btmhole Loc ].i72'FNL, 1677'FEL, Sec 1, T10N. RSE, UM Dear Mr Kewin: Enclosed is' the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other govern- mental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled, Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. VeF~ truly yours, Chairman Alaska Oil and Gas Conservation Commission BY ORDER OF THE COi~R4ISSiON jo Enclosure Department of Fish & Game, Habitat Section - w/o encl Department of Environmental Conservation - w/o encl STATE OF ALASKA ,. ALASKA O,,_ AND GAS CONSERVATION CO,,..vllSSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill';~ Redrill []] lb. Type of well. Exploratory [] Stratigrap/hic Test [] Development Oil Re-Entry [] DeepenF11 Service [] Developement Gas [] Single Zone ~ Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, inc. RKB 136',PAD 101'GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oi 1 Po P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25588 ALK 2674 4. Location of well at surface_ ,, 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 300'FSL, 90'FEL,Sec.2,TION,R8E,UM~Z[ipp/"Oy,_.) Kuparuk River Unit Statewide At top of productive interval (~ target) 8. Well nu .mber Number 1320 ' FNL, 1820' FEL,Sec. 1 ,T10N,RSE,UM 2K-1 #8088-26-27 At total depth 9. Approximate spud date Amount 11 72 ' FNL, 1 677 ' FEL,Sec . 1 , T1 ON, R8E, UN 11/01/88 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth~MD and TVD) property line ~ 2K-2 Conductor 8452 'MD 1172' ¢TD feet 25' [a~ Surface feet 2560 6312'TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 300 feet Maximum hole angle JFN° Maximum surface 1 731 psig At total depth (TVD) 2873 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16:: 62.5# H-~O ~/elo uu db db' i15 115' +200 # cf 12-1/4 9-5/8"36.0# J-55 BTC 3582 55 38' 58] / Z~Z~' 650 sx A5 I I I & :F ZRI 450 sx Class 8-1/2 7" 26.0# J-55 BTC 8418 34 34' 8452 6312' HF-ER~ 200 sx Class G tail 19. To be completed for Redrill, Re-entry, and Deepen Operations. Top of G 500' above Present well condition summary Kuparuk Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Surface Intermediate i :. ; . Production Perforation depth: measured Note; 2K-1 i s the fi rst ~el 1 on 2K pad. true vertical 20. Attachments Filing fee ~ Property plat :~ BOP Sketch ~ Diverter Sketch Z,~ Drilling program,~ Drilling fluid program ~ Time vs depth plot [] Refraction analysis ~ Seabed report .~ 20 AAC 25.050 requirements 21. l hereby cert, fy~that the foreg/p~[ng is true and correct to the best of my knowledge ~j~/'~~,./~//// Title Regional Drilling Engineer .. Signed .i. P m~er' - Commission Use Only~l.2¢~ (T E M )PD3 / 021~'~ /ermit Nu I Apl number I Approval date I See '~o'v~r letter ~'¢- /~ J 50--,/O~- ~o/O ~ I '[0/1_9/88 J for other requirements Conditions of approval Samples required [] Yes ~No Mud Icg required C Yes ~'No Hydrogen sulfide measures [] Yes ~No Directional survey required ~Yes ~ No Required working ~rescure for BOP~ ~.2M; ~ 3M; [] 5M; [] 10M; ~ 15M Other: ~~,,/~~, ~,~. · by order of Approved by Commissioner the commission Date Form 10-401Rev.'"~-~5 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1) MIRU. 2) Install FMC diverter system. 3) Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. 4) Run and cement 9-5/8" casing. 5) Install and test BOPE. Test casing to 2000 psig. 6) Drill out cement and 10' new hole. Perform leak off test. 7) Drill 8-1/2" hole to loggi'ng point according to directional plan. 8) Run open hole logs. 9) Continue drilling 8-1/2" hole to provide 100' between PBTD and bottom of Kuparuk sands. 10) Run and cement 7" casin!). Pressure test to 3500 psig. 11) Downsqueeze Arctic pack'and cement in 7" x 9-5/8" annulus. 12) ND BOPE and install temporary Xmas tree. 13) Secure well and release rig. 14) Run cased hole logs. 15) Move in Workover rig. NU BOPE. 16) PU 7" casing scraper and tubing, TIH to PBTD. Circulate hole with : clean brine and TOH standing tubing back. 17) Perforate and run completion assembly, set and test packer. 18) ND BOPE and install Xmas tree. 19) Change over to diesel. 20) Flow well to tanks. Shut in. 21) Secure well and release rig. 22) Fracture stimulate. OEGASSER -------- MIlD CLEANER SHALE SHAKERS STIR STIR TYPICAL MUD SYSTEM SCHEMATIC Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" .Surf. ace Casins to Weight Up 9.6-9.8 8. ?-9.2 Weight Up to TD 10.3 PV 15-30 5-15 9-13 yp 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 '- 5-12 Filtrate APl 20 10-20 pH 9-10 9.5-10.5 9.5-10.5 Solids 10~ 4-7 9-12 Drilling Fluid Sy!t. em: Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Desasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators No res: 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 .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from will operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluid disposal. L~/ih '":' "=" '~KUPARUK : ~:-"--': RIVER UNIT ."~ ..... ". · 20' DIVERTER $CHEHATIC I I 4 DESCI:II DTIOM C~ 1'1.11S DIVERTER SY~ AS A VARI~ FROI*I 20AA~I~.~) M_AI NTENANCE & OPERATION UPON IN~ TI AL INSTALLATION. CLOee~ ~ENTER VERIFY 2. CLO~E ANNULAI~ i)I~rV~)I'~R ~ BI, C}q~f AIR I'HRO, O~vERTER LINES EVERY 12 3. CLOSE ANNULAR P~rVEN~ IN TIE EVENT TH,~ T ~: iNFLUX OF WELLB01~ FLUIDS 0g OAS IS DETECTED OPEN APPROPRIATE VALVE TO ACHIEVe: DOWNW~N~ DIVERSION. DO NOT SHUT IN WI:LL - I < i i i DZA(R/~ #1 1~-5/8' 5000 PSI RSRRA 8CP STACK .,EJ L_ EJ , I 2 ACCt. JM.,~AT~ C.,iN~ACI~ TEST I. O.~CI( ~ FILL ~TCR RESiRVOIR TO ~ ~ WITH ~IC FLUID. 2. ~ THAT AC(1,MA. ATCR ~ IS 313(X) PSI N]TH 1500 PSI IXIg~TI~.AM ar TI-E RE:Gt, LATCR. 3. ~ TillS,., TI-EN ~ ALL UN[TS 5IhU. T.e/~aJSLY ~ RE:~ ~ TII'~[ ~ ~ REI4~INING AFTER ALL UNITS AI~ CLOSED ~TH CHARGING ~ CFF. 4. RE(:Oa3 ON ~ REPORT. TI-Ii ~ABLE LCI~Oi:R LIMIT I$ 45 sEca~ CLCISlI~ TII~ AI~ 1200 PSI I~INING 13-5/8' BCP STACK TEST FILL BCP STACK AM) ~ kgtNIF~ WITH ARCTIC DIESEL. O'E~ THAT ALL LOQ( DO~ ~ IN ~E1.LFEAD ARE FLLLY RETRACTED. SEAT TEST PLLK; IN PE1.L~ WI]~I liU~l~lll~l~ JT ~ RI~ IN LO(3(DOI~ 3. CLQSE ~ PI~'VENTER AN3 ~ KILL N~) ~ LII~[ VALVES ADJACENT TO B(P STACX. AI.J, VALVES AM) CNOKES SHOLLD BE 4. P~E~ UP TO 250 PSI AM) HOLD FOR IO MIN, IN- CREAS[ PRE~ TO 3000 PSI AM) H3.D FOR IO ~LEED F~E~ TO 0 PSI. 5, CPEN ~ PEEVENTE]~ AM) ~ Kill AN) Lib[ VALVES CLOSE TCP PIPE ~ Nq) HCR VALVES CN Kill AM) C~CKE LI~S, 6, TEST TOaSOPSI AAI)~(:I3OPSl A5 INDTEP4. 7. CCNTIN.E TE53I~ ALL V~I. VE~ LI~.S, ~ WITH ~ ~ PSI LOW AM) 3000 PSl HIGH, TEST /~i IN b"TEP 4, BO M3T l:~Rcal~ Tlr.Crt ~ Ci4Od~ TI~T NOT A FULL CLO~ING POSITIVE SIAL a~KE. C~LY FLN;;IICN ILSI CI-I~I~ IHAI lID ~ FULLY CLOSE. 8, (33EN TCP PIPE RAMS AN3 CLOSE BOT30M PIPE RAMS. TEST BOTTCM PIPE ~ TO 250 PSl ~ 343(30 I~I. 9, CPEN BOTTOM PIPE RNv~ B~(]< OUT ~NG JT AM) I0, CL091~ BLIN) ~ AN:I TEST TO 250 PSI AN:) 3000 PSl, MI~IFCLD AN3 LIliES ARE FLU. 0F NCN-FI~EZING FLUID, SET ALL VALVES IN DRILLING POSlTICI~ 12, TEST STAM:PIPE VALVE~ KELLY, KELLY C0(X~ DRill PIPE 5AIrETY VALVE~ AM) II~IEE BCP TO 250 PSI 3000 PSl, 13, EECCI~ TEST II~'~TICN CN BL~ PREVENTER 3EST FORI~ SlGI~ AM) SEM) TO CRILLING SLPERVISI:R, i~O(I.Y TklD~EAFTER FLNDrI(:NALLY OFF. RATE B(13E ARCO ALASKA. Ins, Pad 2K. Well No~ I Proposed Kuparuk Field. North Slops, Alaska 1000 2000 RKB EL£VATIO#~ 136' KOP TVD-300 TMD-300 DEP-O 3 g BUILD 3 DEG 15 PER IOOFT 2! 27 33 B/ PERHAFROST TVD'1406 THD'1480 DEP'353 3e T/ UONU SNDS TVD-1528 TMD-1634 DEP-447 45 EOC TVD-1662 TMD-1817 DEP-571 T/ 14 SAK SNDS TVD-2153 THD-251Z DEP-1071 m 3000 ~ 4000 r'rl K-12 TVD-2724 Tt'ID-3332 DEP-1652 g 5/8' CSG PT TVD-2924 Tt'ID-3617 DEP-1856 K-lO TYD-3173 Tt'ID-3973 DEP-210g AVERAGE ANGLE 45 DEC 31 lIIN K-5 TVD-4566 THD-5g60 DEP-3527 5000 6000 T/ ZONE C TVD-6002 TMD-8OOg DEP-4989 T/ ZONE A TVD-6048 TMD-8075 DEP-5036 TARGET CNTR TVD-61!O Tt'ID-8163 DEP-5099 B/ KUP SNDS TVD-6172 Tt'ID-8252 DEP-5162 TD (LOG PT) TVD-6312 TMD-8452 DEP-5305 ?000 1000 2000 3000 VERT I CAL SECT I ON 4000 I 5000 ! Sooo HC~I ZONT AL PROJECT ! O~ SCALE I IN. = 1000 FEET ARCO ALASKA. Ine- Pad 2K, Well No~ 1 Propoeed Kupeeuk Field. North Slope. Aleeke 1000 5000 .., WEST-EAST 0 1 000 2000 I I I 3000 I 4000 I 4000 3000 z m 2000 - 1 000 - I TARGET CENTER TVD=6110 THD=81S3 OEP-5099 NORTH 3660 EAST 3550 TARGET LOCATIONs 1320' FNL. 1820' FEL SEC. 1. TtON. R8E 1000 SURFACE LOCATION 300' FSL. 90' FEL bEC. 2. 1'10N. RSE N 44 DEG 8 HI N E 5099' (TO TARGET) TD LOCATIONs 11r2' FNL. 1677' FEL SEC. I. TtON. RSE: 550 . 500 . 450 . 250 I I I I I 400 _ I 350 I 300 -~ 250 _ 200 . 150 . 200 ~1 400 ",1,3oo %,,1 200 "' .1.400 """'4 300 I I I I 1 50 1 O0 I \1300 \ \ \ ~\1 200 \ \ ~1100 \ \ ',, Uoo ~ ~oo ~ 1 000 \ \ ~ 900 \ o~)o .nn"""," 500 '~,ooo .,~o~O,,~oo "",900 ~600 I 3od "',800 ~ 12O0 '" t.~ oo ',{,oo ~°",10003~0 "',eo.,o ! ooo 1300 50 0 ~ 1800 I I I I I 1 I ~700 I I I I J 1600 I / I I / 1 000 i '~ 1 50/0w' 900 I I / i / "800 50 55( 50( ,,. /,~ 45( ~'1100 I 40( I I I 35C I I 30( I I I 25,~ I I 20( I I [ 15( 250 200 1 50 1 O0 50 0 50 IT~ ~PRO~ DATE ~ YES NO (1)~ee ~f~ /o/~s/~ i i ch p h d ' ~ -- . s e e~t fee a==ac e .......................................... (2) Lpc ~P~ 8~ (2 thru (8) (3) Admin f/~(- ~ 9. '() ffhru'~ )~2Y~ I0. (10 and 13) 12. 13. (4) (14 thru 22) (5) BOPE (23 thru 28) 14. 15. 16. 17. 18. 19. 20. 21. '22. 23. 24. 25. 26. 27. 28. 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included., .............. L 7. Is operator the only affected party .................... '~. ........... ~ -__ 8. Can permit be approved before fifteen-day-wait ....................... /~ _ · Does operator have a bond in force .................................. Is a conservation order needed ...................................... _ Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~-- Does the well have a unique name and number ........................ 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 and surface ......... ~ ,, Will cement tie in surface and intermediate or production strings ... wf~ , Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this 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 the drilling fluid program schematic and list of equipment adequate W~ . . Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~ooo psig .. Does the choke man/fold comply w/APT RP-53 (May 84) .... ' ............. Is the presence of H2S gas probable ................................. .,, (29-thr~ 3'1) (6) Add: Geology: LPC En~i~ering:: .... :ev: 08/11/88 i.01I For 29. ~0. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. Additional Remarks: INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE 9'?o/oo r3=.~,. 1- o;/ ?~o ///Go ~,~J ...... 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 roadability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX~ ,. No special'effort has been made to chronologically organize this category of information. · <" SCHLU M~ :R G E ~ -'" WELL ~aPE : 2K-I ~CRCUGH : NORTH SLORE ST~lE : ~L~SK~ .~PI NLfqBER : .50-1D~-20102 REFERENCE NC : 73350 INC. .~$ T~iOE V:ERI~ICAT.!CN L]STING iCHLU~:.BERGER ~L~SK~ CC~!PtJff~NG C~N~ER .6-JUN-~?S9 05'28 SERVICE NAb:'E · E[ZT ORIGIN : ~LiC REEL N~H~ CO~TINUATZCN f ' PREVIOUS qE~L : CONMENI ' .~RCC ~L~S~4, INC. 2K-l~ API f5 O- ! 03-201C 2 INC., KUP ,~RUK , 2K-1, ~PI ~50-10~- 201C 2 .... ~ F IL ': HE fig,_r-~ .¢".~, -,-"'"'-,- FILE NAME : EgIT .00! SERVICE : FL'lC VERSION : OClA02 CATE : 8~/051 6 MA)< REC SIZE : lC96 FILE TYPE : LC LAST FILE INC. LOCATION: ZC. 6' FSL ~ $4' FEL S=CTiO.k: 2 TCW~,SHIF: FER~aNEN'T C~TU~: ~SL ELEV41I£~: RANGE: ~E iS T/~PE VERiFtC~TTCN LISTING 'HLUI~&E~GER ~L~SI(A C[~PUT~NG CENTER 6- JUN- 19,89 08:28 P/tOE: LOG PEASLRED ?RO~ RK~ 154 ABOVE F~R~4~NENT EATUN ELEV~TIJ~ S K~:, 't54 CF'. 1~..,: .~ GL'. I1~ RUN NUM'~ ,~ R: ONE 'ID DRILLER: 8540 TO LCGGE6: 8E36 CASING : c, 5/E' '36 LE ~ £RiLL~,~ DEPTH C~ 371~' AkD LCGG'E~ ~E~TH CF 3lZ4' BIT SIZE ' ~ ~/2" ~ ~5¢£ l'¥DE FLUID HOLE,' 'S Z T Y ' LSNn PC' I1.2 VISCOSITY: 53 ~ FLUiC, LOSS: 3.8 PUD ~ESr~TTV ~'TY ~' FIL'TRATE RE:S]STZ~ ~IY' PUS CAK~ RES~ST~'TY: 4,3 1 ~ 71 ~.~7 ~ 7t T gu-'" L NUMBERS: CIS ~!40 ESS EOB SGC ~1C9 INLN 1378 [IC 2191 CNC 1238 I E .~ 1 34 ? F'IELC REI~ 4RKS I C S P 4 " STfiNOC=~S a~g Z' FgLEFINOER USED [N DIT. 4T~,IX ,.DENSITY = 2.6.F.. C.../C3 , =LUID 9ENSiTY = NL F'ITRIX = S~HE ~ P~LE C~R~ECTIDN = C~LZPE~. PIKING GR ~ HI-RES P~SS gUE TO HIG~ StiPPLING R~TE. AS R~SULT~ NZ-RES P2S~ ~fiS NOT USED PER REPEAT S~CTIOh. ZGH 3R COUNTS (~478' - 8460') ON REPE~T P~SS ~UE TO CTIV~TICN OF Fg[~'~TIO~, ~Y DENSITY SO~JRCE. So NC'ISE ABOV~ 500' ~TTRI3LTE9 TO FO~K LI~T ~UNNING ~VER SF LI~E W~ICH ~S ~M~gEC. SP SHIFTS ~7196', ~162', 4514', ~ 4038'. E4TE JCB ST.IFTED: 02-JUI~-89 ~.EFE:EKCE NO: 7335C, LDP/,~NA: J. KOHPING 6-JUN-lgSg 0~:28 $CHLL:',4~E~GER LeGS INCLUDED WITH THIS ~ILE (E~'IT.C01): <SEE ~!LE ~AL IN~UCTI3~ SPF'E~ICALLY F3CUSE~ FCRYAT~ON DENSITY CEHPENS~TED LOG (.FCC) FiRSt TO L~ST ~E~D!NG: 8502' TC 7949' &ND {500' TO ,3724' CC~,~F'E~S~,~T:ED NEUTRCN L~G (.CNL) F IRS~ TO L~ST R~.~.D!NG' 84:86~ TO 7948~ ~ZRST TO L~S'T READING: 3740~ T.g 990" TABLE TYPE : CCNS TU~ I V~LU £:EFI C N a, FN K W N 2 NATI U S T/~ T Z~ COI.., N N F L .2 SECT 2 T ~!~, N 1 RAnG 8 ENG~'-~ T SO~, E RC'3 a, tASiK~, INC. K-! OR'TH SLC:PE :96' FSL E 94' PEt !NKk~N 49126 0-10!-201~2 CC MFA~Y N~ME FIL{LO NAM,_. NELL N~ T l Oh ST~T:= DR PROVINCE C£UNT~ ~ :ELD LCC~TZON SE CT ZC N TEWNSEIP RSNG: ENGINEEP~S NAPE SERVICE ORDER NUMBER AFI SERIAL NUMBER TABLE TYPE : CLRV ,IS T~P~ VERIFiCA'TSON LISTING ~$- JUN-19 89 08:28 ,CHLUNBERGER ~L:~SXA CCNPU~!NG CENTER FFCC-. 'F~ F~C ~!J~T q~TE NF££ N~A'~ FDC C~LNT ~T~ C~LI CALIPER GR ~.~ A ~ A R.~.Y TEN S TENE !C N NP~I NEUTRON TNFH THED *' '~.~L NEUTRCN P~RCS~T~ TNR~ C:~L]BRA'TED THERYAL ~SUT~DN NPCR NEUTRON P~CSITY ~!.JlP~T ~RON ~N ;~PPL'IC~TION RCNT RAW CCR~ECTED RCFT :RAW CC~ECTED ~R TEE'R~aL CCUNTS CNTC COR'~ECTED NEAR THERFAL COUNTS CFIC COREEC'TEO F~R T~ED~4~L CCUNTS C AL I CALl PER GR G.AM~ A TENS TENSZCN PROGraM ~# DflT~ FOrMaT SPECIF!CATICN RECCR£..~=i-= ~"'-,- .SET T~oE: - 64=~:~.~ ~.¢ TYPE REFR CCDE V~LUE 1 6~ 2 6d 0 3 72 112 · 4 66 1 5 ~ 6~ ~ 5 S 67 ~T 11 6d ' 2 6 ~ 13 5~ 0 15 6~ 68 O ~ .iS T~PE YERIFICATION LISTiNS ;CHLUF BERG ER ~LASKA CC~,IPUTING C~NiE~ 6-JUN-1989 0~'28 P ~ G E: NAF:~ SERV LMI'T SERVICE APl &FI ~P'l A°I, .F*LE~ NU~~::~, NUMB .~!Z:_ REP~ ID mROEP ~ ~ LOG %YFE CL~S,~ ~D,, NijM~ SA~P. EL~_ _ CODE FRGCESS (PE~) DEFT FT 549126 O0 0~0 Eg 0 1 I 1 4 68 TE~S OIL lB 549126 07 6E5 21 0 I i 1 4 68 IL£ Oit CHF~,.! 54'9~26 07 120 46 0 1 1 I 4 68 ILF OIL ~H~M 549126. 0'7 120 44 O ! 1 I ~ 6B SFLU OIL CHF~ 549126 07 220 ~l g I 1 ~ 4 68 SP DIE MV 549126 OT 010 ~i 0 I I 1 4 68 GR D![ 6A~I 5~26 07 310 Ct 0 1 1 1 4 68 TE~S F~C [8 549126 OT 6~5 21 0 ! 1 1 4 68 DPPI EEC FU 549!26 07 6~5 21 0 1 ! 1 4 68 RHCB EEC ~/C3 549126 07 350 ~2 0 ! 1 1 4 68 ORI,O F~C ~/03 549126 07 3E5 C1 0 1 1 ] 4 68 FF~C FEC CPS 54~126 07 3~4 C2 0 ] I I 4 68 NF~C F~C CPS 549126 07 3~4 ~! 0 1 1 ~ 4 68 CALl F~C IN 54912~ 07 ZEO Cl 0 I 1 ~. .4 68 GR FCC ~FI 5491 2~ 07 310 C;1 0 I I 1 4 68 TE~S C~L LB 549126 07 625 21 0 I I I ~ 68 NPFI C~L FU 54'gi 26 07 850 CO 0 !, ! I 4 ~8 'TNFH CNL ~U 549~26 '07 850 CO 0 ! 1 I 4 68 TNRA CNL 549126 07 420 Cl 0 I 1 I 4 68 NPCR CkL FU 549126 07 890 ~0 0 I I 1 4 68 RC~T CkL CPS 549~ 26 07 420 C1 O 1 1 i 4 68 RCFT CNL CPS 549126 07 420 ~1 0 I 1 1 4 68 CNTC CNL CPS 549! 2,~ 07 420 C1 0 1 1 1 .4 6~ C~lC C~L CPS 549]26 07 420 C1 0 ! 1 1 4 68 CALI C~L IN 549126 07 ZEO C1 0 I 1 I 4 6~ GR CNL (6FI 549!2~ 07 310 CI 0 ! ! I 4 68 TE~S CS$ LB 549~ 2~ 07 6~5 2! 0 1 1 1 4 68 GR CSG ~API 549126 07 310 C1 0 I I I 4 68 ocrJOOCO00O OC~O00CO000 OCO00CO00O OCO00CO000 O(~ O0 0~0000 OC, O00C gOOO OOOOOCO00O OCO00CO00O O~ 000~ 0000 OC O00C O00O OC OOOCO000 OC OOOCO00O O(~OOO~O000 OC900COOOO OCOOOCOOOC OC O00C 0000 OC OOOCO00O O~ OOOCOOO0 OCOOOCO00t] OCO00COO00 Ol~ O00COOOO OR OOOCO000 OeO0 OCO0 O0 OCO00CO000 OCO00CO000 OCOOOCO000 OCO00CO00O OCOOOCOOOO DEFT. 8554.000 TENS.£IL 2054.000 ILD.CiL SFLU. OIL 2.5 20 S~.[ IL -,~4. gO0 GR.C IL llZ. '938 CPPI.FCC 1~.10! R~D~.FDC 2.351 DPHC.~DC 0.0~9 Nm[C-=CC ~72.000 C~LI.FDC ~.109 GR.FDC 112.9~8 NPEI.ChL 54.469 T~PP.CNL 51.115 TNR~.CNL 4.083 RC~T.C~L 1752.C21 RCFT.CNL 397.447 CNTC.CNL 178~.60B CALI.C~L 8.109 GR.CNL 112.93B TENS.CSG -999.250 EFT. ~500.COg TENS.£IL 6332.000 ILC.CIL 2.27B SFLU.OIL 2,~ ,-q7 SF.[ IL -z,O. 500 GR.C IL 107.06,3 PI' I ~C ~' - '~ 17.555 RPO~.FDC 2.360 ORHG.FDC O.O~3 EEC.FCC ~7.500 C~LI.FOC 8.281 S~.FDC 107.063 NPP!.CkL 52.C00 TkPP.CNL 49.262 TNRa. CN[ 3.962 RC~T.CNL 1745.a73 ~[FT.CNL 393.832 CkTC.CNL 1759.802 C,ALI.CNL 8.2~1 GR,CNL 107.063 TENS.CSG -999.253 ILM.DIL TEAS.~DC FFEC.FCC TE~S.CkL NP£R.CNL C~lC.CNL C-R.CSG Il ,:'~. gl L TE~S.,~CC F~[C.FCC TEBS.CNL NPCR.CNL C:IC.CNL GR.CSG 2,309 2054.000 ~59.~00 2054 51.115 -999.250 2.384 6~32 .COO 668.C00 63]32 .CO0 47.753 4~8.465 -e~99.250 D~FT 3200 nog ~:,N~ [iL SFLU O~L ~ ~16 S= EIL g°~I-~EC 12 C32 RFn~ FDC NF~C.FEC ~l. CO0 C~LZ.FDC NP~'Z.CEL 35.70~ RC~T.C~L 22 15.2 el RC FT.CNt CALI.C~L 9.219 G~.CNL 5-.JUN-1989 08:;28 6264.000 ILC.CIL .-.52. 500 ~R . ~, 'IL 2.432 ORHC. F DC 8. B67 GR.FOC 40. TO1 TNR~.CML 5]7.448 CNTC.CNL 98.18~ TENS.CSG 5932.000 Itg.Clt -49. OOO Ggi.OIL 2.,404 ORHC. FDC 9.109 SR.FDC 32.821 TN,R~.CNL 759.902 CNTC.CNL 79.688 TENS.CSG 6040.000 'ILD.E It -63.000 $R.CIL 2.383 DRHg. FDC 9. 158 GR. ~ DC 47.495 TNRa.CNL 408.90~ CNTC.CNL I15.918 TENS.CSG 2. 9 8.188 0.013 9~.18B 3.409 1959.~26 7.945 79.688 O. 001 79.688 2.927 2461.005 -999.250 4.21,8 86.375 0.016 86.375 3.149 2308.420 -999.250 1.546 115. 938 0.016 115.938 3.788 1768.174 -999.250 5832.000 ItD.git 2.725 -64.000 GR.£IL 129.375 2.384 ORHC.FOC 0.024 9.461 GR.FDC 129.375 42. 096 TNRA.CNL 3.468 470.~77 CNTC.CNL 1827.952 129.375 TENS.CSG -999.250 5989.000 ILO.CIL 2.104 -20.500 GR.CII 189.500 -999.250 ORH~.FDC -999.259 - 999. 250 GR. F DC - 99). 250 -999.250 TNR~.CNL -999.25,,9 -999.250 CNTC.CNL -999.250 -999.250 TENS.CSG -999.259 5712.000 ILD.C iL -77- ~'CO GR.CIL -999.250 DRHC.FOC -999. 250 GR.=DC -999.250 TN~.C.NL -999.250 CI~TC.CNL 3.129 Z 1 6.375 -999.250 -999.250 -999.250 -999.250 iLM.OIL TEh S. T Eh S. CN t NPCR.CNL CFTC.CNL 6R.CSG ILM.DIL T Eh S. FE C FFEC.FgC TEB, S.CNL NPCR.CNL CF'fC.C~L 6 R. C S G ILM.OIL TEI~ S.FCC FFEC.FDC T:Eh S .CNL NPCR.CNL CFIC.CKL ~e. CSG ILM.OIL T Eh S. FEC F F[ C. FD C TEbS.CNL NPCR.CNL CFlC.CNL 6R.CSG I1 M. 01 L TEhS.FDC FmEC.FCC TEhS.CNL No[R.CNL CFIC.CNL 6R.CSG iLM.DIL TEhS.FCC FF£C.~=~C TShS.CNL NoCR.CNL CFTC.CNL 6R.CSG !LM.DIL TEBS.FCC F=£C.=CC TEhS.CNL NPCR.CNL CFIC.CNL P~GE: 3.005 6254.000 495.250 6254.~00 40.344 587.201 -999.250 7.~43 5932.000 ~14.500 5932.000 33.739 852 .~24 '-9 99.250 4.272 6120. C O0 475.750 61ZO.CO0 36.F, 63 747.847 -999.250 1.733 6040.000 562.500 6040.000 47.045 463.C21 -999.250 2.847 5832.C00 571.500 5832.C00 ,41. O 65 522.202 -999.250 2.345 -999.250 -999.250 -g99.25C -999.2 50 -q99.250 -999.250 3.225 -999.250 -999.250 -999.250 -999.25C -999.25C .IS TAPE VERIF'ZCATZO,'4 LISIINS ;CHLUPBERGER /~L.~SK~ CC~FUTIh'G CENIER CALI. Cl~ L -9 99.,2 gO G~. C NL DEFT. 7~00.C00 T~E NS.t~IL SFLU.DiL 5.077 SF.C IL DPl-I.FCC -cs 99.250 RI-O~.FDC NFCC. FCC -999.250 C~LI.FDC ~P~ I. C~L -S $9.2 50 T~ PW.C NL R C~T. C~L -S 9~. 2 S 0 RC ;l .C NL C AL i. C~ L -~ 99.2 50 G~ .C NL DEFT. 7200.r~0~ TI NS.£ IL SFLU.DIL 3.344 SF.EiL C PF !. F~. C -9 99.2 50 ~I- ~e . F DC NFCC.F2C -S99..~50 C~LI.FDC NP~ I.CNL -~ 99.2 50 T~, P~ .CNL RC~T.CkL -~99.2 50 PC FT.CNL CALI.CNL -999.2 50 GR.CNL 6.-JUN-1989 08:28 -999.250 TENS.CSG -999.250 5644.000 ILD.EIL 3,422 -56, gOO GR.~ IL 152,750 -999.250 DRH~,FDC -~999..Z50 -999.250 GR. FDC -999,250 -999.250 T~R/~.CNL -999.250 -999.250 CNTC.CNL -999.250 -999.250 TENS.6SG -999.250 5520.000 ILD.CIL 4.21B -75.500 GR.I] !t 94. 625 '-999.250 D~HO,~DC -999.250 - 999.25 O GR. F DC -99 9.250 -999.250 TI~/1. C NL -999,250 -999.250 CNTC.CNL -999.250 -999.250 TE~S.CSG -999.250 5480.000 iLD.CIL -7! .500 $R.CIL -999.250 DRH£.FDC -999. 250 GR.FOC -999.250 T~..CNL -999.250 CNTC.CNL -999.250 TENS.CSG 5350.000 ILD.CIL -70.000 GR.CIL -999. 250 ORHO.FDC - 999. 250 GR.F DC -999. 250 'TNR~.CNL -999. 250 CNTC.CNL -999.250 TENS.CSG ¢. 096 104.375 -999.250 -999.250 -999.250 -999.250 -999.250 ,2.537 101.813 -999.250 - 999. 250 -999.250 -999.250 -999.250 5304. 000 IL.,r,'. E I L 4.467 -72. O00 gR. £ IL 13.9.250 -999.250 ORHO.FOC -999.250 - 999.250 GR . F DC - 99 9.250 -999.2~0 TI~R~.CNL -999.250 -999.250 CNTC,CNL -999.250 -999.250 TENS.CS(: -999.250 51~4.000 ILD.£1L 3.342 -8 I. 250 GR. C IL 1t 7.875 -990.259 ORHC.FDC - .a99.250 -999. 250 GR.FOC -999.250 -999.250 TNR/1.CNL -999.250 -999.2:50 CNTC.CNL -999.2_50 -999.2~50 TENS.CSG -999.250 5164,000 ILC.EIL 3.973 -&4. 500 GP.[ IL 87,000 -999.250 ORH~.FDC -~99.250 -':::)9'9.250 GR.F DC - 999. gl0 -999.2~0 T~Ra,CNL -999.250 (~R.CSG IL M. DIL T E~ S. FEC FF£C.FEC TE~ S. CNL NP£R.CNL CF1~,. . C~L C-R.CSG !LM. DIL TEh S. FCC FF[;C.FSC TE~S.CNL NDCR.CNL CFIC.CNL 6~.CSG ILM. DIL TE~S.F~C FFEC.Fr~C TEhS.CNL NPCR.CNL CFIC.CNL 6R.CSG ILM.DIL TE.~ S. FDC FF£C.F&C TE~S.CNL NP£R.CNL C ~l' C. C~ L (-R.CSG ILM.DIL TE~S.FCC FFEC.FEC TE~S.CNL NPCR.ClkL C- R.CSG ILM.DIL tE~S.~£C F~EC.FCC TEI~S.CNL NPCR.CNL CFIC.CNL G.R.CSG ILM.DIL 'T :1', S. FEC F F£ C. FCC TE~S.CNL kPER.CNL P~GE: -999.2:50 3.54~ -999.250 -999.250 -999.250 -999.250 -999,250 -999. 250 4.286 -999.250 -999.250 -999.250 -999.250 -999.2 50 -999.250 4.250 -9'99.250 -999.250 -999.250 -999.250 -999.250 -9 '99.2.50 3.079 -999.250 .-999.250 -999.250 -999.250 -999.250 -999.250 4.568 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.411 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.S32 -999.250 -S99.250 -999.250 -999.250 .IS T.~PE VERiFICAIiC,.'~ L~S!ING ;CHLUFSERGER ~L~SK~ CC~P!JIINr~ DENIER RC~.T.CNL -999.250 RC=T.CNL CAL Z.CK L -S 99.2 _::~ GR. C NL DEFT. 6E OC.~ OO TE NS.C IL S F L U. D I L ~.~. ,..= 51 S P .~r l L O PF ii. F~ C -S 99.2 50 RF O~. F OC NFEC.F~C -999.250 C~"LI.FDC NPbi,CkL -9 99,2 50 T~ ~,C NL R C~ T. C~ t ,-S :9~. 2 50 RC ~=T. C NL CAt Z.CkL --S 99.2 50 GP.CNL DEFT, 6E O0,COO T~NS.,£iL SFLU.D]L 3.599 SP,£1L ~P~I :CC -~9~ 2~0 RF'O~ FDC ' ' ~ ~ I ,' ~, ~ NF~C. 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CNL -9 99.2 50 GR.CNL 5- jUN- i9B$ 0~:28 276.469 CNTC.CNL 5~. 250 TENS.C :SG ] 37 7. 975 2740.000 -999.250 ILC.CIL -999.250 - 999. 250 GR.[ IL -999. 250 -999.250 ORHO.FQC -999.250 - 999. 250 GR.F DC - 999. 250 -999.250 TN~.CNL -99'9.250 -999.250 CNTC.CNL -999.250 -999.250 TENS.CSG 2680.000 -'99:9.250 ILD.CiL -999.250 -999. 250 GR.C IL - 99 9.,250 -999.250 D~HO.FDC -999.259 -999.250 GR.FOC -999. 250 -999.250 TNR~.CNL -9'99,250 -999.250 ChTC.CNL -999.250 -999.250 'TENS.CSG 2624.000 -999.2.50 ILC.CIL -9~9.250 -9~,~.250 SR CIL -999.250 -'999.250 D~HC.FOC -999.250 · -999. 250 GR. F 9C '-999. 250 -999.250 TNRA.£NL -999.250 -9~9.2~0 CNTC./NL -999.250 -999.!50 T5NS.ESG 2520.009 -999.250 ILD.EIL -999.250 -999. 250 GR.£ IL -999.250 -999. 250 DRHC.FDC -999.250 -999. !50 ~R.FOC -999.250 -999.250 TNRa.CNL -999.250 -999.250 CNTC.CNL -999.250 -999.250 TENS.CSG 2414.000 -999.250 ILO.ElL -999.250 -999.2~0 SR.C IL -99 9. !50 -999.250 gRHC.FDC -999.250 - 999.2 ~ O ~R. F DC - 99 9. 250 -999.250 TNR~.CNL -999.~50 -999.250 CNTC.CNL -999.250 -999.250 TENS.CSG 2450.000 -999..250 ILC.EIL -999.250 -999.250 GR.[ IL -999.259 -999.250 DRHG.FDC -999.250 -999. 250 GR. FDC -999.2~0 -999.250 T~R8.CNL -999.250 -999.2~0 CNTC.CNL -999.250 -999.250 TENS.CSG 2384.000 -999.250 ILD.C IL -999. Z50 -999. 250 ~5P.£ iL -999. 250 -)9g.250 DRH~.FDC -999.250 -99'9. 250 GR.F DC -999.2.50 C F 1 'C. C I~ L 6R.CSG ILM.DIL TEI~ S.FCC FF£C.FCC TESS.CNL NPCR,.CNL CFIC.CNL [-R. CS,S ILM.DIL TEhS.FOC FFEC.FDC T EB S. CNL NP'ER.CNL C~IC.CkL GR .CSG IL~.DIL TEhS.FCC F~£C.FCC TE), S. CNL NPER.CNL C F l C. C N L C-R.CSG ILM.DIL TE~S.FCC FF£C. FCC TE~S.CNL NPCR.CkL CFIC.C~L GR.CSG ILM.DIL T Eh S. FD C FF£C.FCC TE~S.CNL NP£R.CNL CFlC.CNL ER .CSG ILM.DIL TEIkS.~CC FFCC.FDC TE)S.CNL NP£R.CNL CFTC.CNL C- R.CSG ILM.DIL TEb S. FCC FF[C.FCC TEI~ $.ChL P~GE: 319.122 54.:75 -9 99.250 -999.250 --999.250 --999.250 -9 99.2 50 -999.250 51.375 -999.250 -999 · 250 -999. 250 -99'9.250 -999.250 -999.250 57.125 -999.2 50 -999.250 -999.250 -999.250 -999.250 -999.250 55.125 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 59.250 -999.2 50 -999.250 -999.250 -999.250 -999.250 -999.2 50 49.563 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 .46.O 31 -999.250 -999.250 -999.250 -999.250 13 ,IS TAPE V ER IF IC,&T !ON LISTING ,CHLU~BE~GER ~L~SKA CCMPUT!KG CENlE~, NP~ I.CNL -599.2 SO T~ PF .CNL RC~T. CNL -S 99 . 2 50 RC FT .CNL CAL I.CNL -S 99,2 ~O G~ . C NL 6--JU N- 19.$9 08:2.8 -999.250 T~R~.CNL -999.250 CNTC.CNL -999.2~0 TENS.CSG -999.250 -999.250 2310.000 -999.250 ILD.DIL -999.250 - 999.2S0 GR..C IL -99 9.250 -99'~.250 D~HO.FDC -999.250 - 999. 259 GR. F DC - 999.250 -999. 250 TNRfi.CNL '-999.250 -999.250 CNTC.CNL -999.250 -999.!50 TENS.CSG 2250..000 -999.250 ILD.C. iL -999.2S0 -999. 250 GR.CIL -999.250 -999.2~0 DRHO.~OC -999.250 -999. 250 GR,,, F 30 - 999. 250 -999.250 TN~fi.CNL -999.250 -999. Z50 CNTC.CNL -999.250 -999.250 TENS.CS6 2154.000 -999.250 ILD.~IL -999.Z50 -999. 250 GR.C IL -999. 250 -999.250 DRHO.F~C -959.250 -999. 2~;0 GR.~DC -999.250 -999.2.50 TNR~.CNL -999.250 -999.2~0 CNTC.CNL -999.2.59 -999.250 TENS.CSG 21!0.000 -999.250 ILO.£IL -999.250 - 999.,250 GR.C IL -99 9.250 -9'99.250 ORHC,FDC -999.250 -999. 250 GR.F 9C -999.250 -999.250 T~RA.CNL -999.250 -~9'9. 250 CNTC.CNL -999.250 -~99.250 'r~NS.C Sg 1990.000 -~99 Z=O ~ £ £IL 999.750 , I ..~ .&. ~ t -- _. - 999.25 O OR.£ IL - 95 9. 250 -~q9 Z:,O ]~HC FDC -999 2=0 -999.250 GR.FDC -999.250 -999.250 TNR~.CNL -999.250 -9q9 *~ . . ~_ ;, 0 CNTC.CNL -999.250 -999.250 TENS.CS6 1970.000 -999.290 ILD.£IL -999.250 '-999. 250 ,3R.E iL - ~99. 250 -999.2~0 DRHC.FDC '-999.250 -999. 250 GR.FDC -999.250 -999. Z~O TN~.CNL -999.250 -999.250 C~TC.ENt -)99.2~0 -999.250 TENS.CSG 1880.000 NPCR.CNL CFTC.CNL Gq. CSG iLM.DIL TE~S. FDC TE. hS.CNL NPCR.CNL C FT C. CN L C-R.CSG ILM.OIL T EB S. FCC FFCC.FDC TE~S.CNL NPCR .CNL CFTC.ChL C-R.CS G I L M. D I L TE~S.FGC FF£C.FCC TE~S.CkL N PC R. :Cra L C F1 C. CNL 6R.CSG ILM.DIL TEI~ S. FF[C.FCC TE~S.CNL NPCR.CNL CFIC.CNL C-R.CSG ILM.DIL TEllS.FCC FF£C.FEC TE~S.CNL NP£R.CNL CFIC.CNL 6R.CSG ILM.OIL TE~S.FCC T2~S.CNL NPCR.CNL CF'fC.CNL GR.CS,S P~GE: -999.250 46.~75 -999.250 -999.250 - 9 99.250 -999.250 -999.250 -S 99.250 64.438 -999.250 -999.250 -999.250 -S 99.250 -9.99.250 -999.250 · 42. 813 -999.250 -999.250 -999.250 '- 999.2 50 -999.250 -~ 99.250 42.125 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 55.656 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 54.438 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 27.250 14¸ IS T~PE YERZFZC&"tTn .... ',.,,N LISTING ;CHLU~3ERGER ~L~SKA CC~FUT'SNG C~NTER DEFT. 2200.000 S:FLU. gI L -~ 9S. 2 50 SP .C IL CP~ i. F~ C _c, 99. :2150 R~ O~. F CC N~EC.P~C -999.250 C~LI.~DC N~P I.Ckt -999,2 50 T~ ~.CNL RC~T. CNt -9 99.2 50 RC FT .C Nt CALI.CNL -999.2 50 6-JUN- 198~ 08:Z8 -999.250 tLC.CIL -999.250 -999. Z50 GR..C IL -999.250 -999.2.=0 ORHC.FOC -999.250 -'.~99. ;250 GR. F DC -999. Z50 -999,250 TNR~.CNL -999,250 -999,250 CNTC,CNL -'999.250 -999,2~0 TENS,CSG 1810,009 -999.250 !LC,£IL -9S9,250 -999,250 GR,C IL - 999,250 -999,250 DRHC.FDC -999,250 - ~99.250 GR. F DC - 99 9. 250 -999,250 TNR~.CNL -999.250 -999,250 CNTC,CNL -999,250 - 999. 250 T6NS,C SG i g30, OOO -999.250 ILD.C'IL -999.250 -999.2EO gR.C IL -999. 250 -999.2~0 ORHC.FDC -999.250 - 999 . 250 GR . F DC- -99 9 . 250 - "999. 250 TNR~,CNL -999, 250 --999.250 CNTC,CNL -9'99,250 -999,250 T.ENS.CSG 1800,000 -999.250 ILG.CIL -999.250 -999.250 GR.C iL -99 9. 250 -999,250 DRHC.FDC -999,250 - 99'9.250 GR, F DC - 99 9. 250 -999,2.50 'TKRA,CNL -999,Z50 -999.250 CNTC.CNL -999,250 -9a9.250 TENS.CS~ ~:$90.000 -999.250 ILE.CIL -999.250 - 999.250 GR.C IL - 999. 250 -999,250 DRHC.FDC -999,250 -999· ~'50 ~R . FDC - 999.250 -999.250 TkR~.CNt -999.250 -999.250 CNTC.CNL -999.250 -999,250 TENS.CSG 1620.000 -999. 2:,0 ILD.CIL -999.250 -99q. 250 .SR, C IL - 99 9. 250 -999.250 ORH~.FDC -999.250 - 999, lEO SR, F DC - 99 9,250 -999.250 TNR/~.CNL -999.250 '-999.250 CNTC.CNL -999,250 -999.2~0 TENS.CSG 1530,000 -999.250 IL~.CIL -999.250 -999. Z50 SR.CIL -999.250 -999.2~0 DRHO.FOC -999.250 -999.2~0 GR .FDC -999. 250 -999.!~0 TI~RA.CNL -999.250 -999. ZF9 CNTC.CNL -999.250 -~79.Z50 T~NS.CSG 1535.000 !LX.DIL TEhS.FCC FFfC.FDC T E h :S. C Ik t NP£R .CNL CFIC.CNL GR,CSG ILM.O!L ? Eh S. =£ C F F£ ~C. ,,=C C TEBS.CNL NP£R.CNL C~IC.CNL GR.CSG ILM,DiL TShS.F~C FFCC.FCC TESS.CNL NPCR,CNL C:IC,CNL C-R,CSG IL~.DIL T Eh S. FD C F F£ C, FCC TEB S.CNL NDER.CNL C:IC.CNL GR,CSG ILM,DiL TEbS,FCC F :[ C, FCC TEh S,CNL hiP[ R. CNL £F1C.CNL C-R,CSG IL M, D! L TEhS,FCC FFEC,F[3C TEhS.CNL NPCR,CNL CFIC.CNL E.R.CSG ILM.DIL TEhS,FCC F F[ C. ,=C C TE)S.CNL NP[R.CNL CFIC.Ckt 6R.CSG P,~GE: 15 -999.250 -999.250 '-999.250 -999.250 -999.250 '-999.250 49.344 ,-999.2 50 -999.250 -999.2 50 -999.250 -999.250 -999,250 38 .~63 -999.250 -999.250 -999.250 · -999.250 -999.250 -999.250 46.750 -999.250 '-999.250 -999.250 -999.250 -999.250 -999.250 30.422 -999.250 -999.250 -999.250 -999.250 -999. :250 · -999.2 50 45.438 -999.250 -999.250 -999.250 -999.250 -999.25~ -999.250 31.3!3 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 .35.34& ..IS T~P[ VERZFZCATIeN LIS?ING ;CHLU~'BERGER ~L~SK~ C[mPU!'ZNG CENTER DEFT. 1300.C00 TENS.SiL SFLU. OIL -S 9S. 250 SF. CIL DPP I. FCC -S 99.2 50 R~ O~ .F gC N ~C C. F~ C -S 99.2 SO Ca LI. F gC NPPZoCNL -599.250 T~PH.CNL R C~ T. C~ L -S 99.2 50 RC :~. C NL C AL Z. C~ L -~ 9~. 2 50 gE .C NL DEFT. I1 O0.CO0 TE NS.C IL S FLU. gI L -S 99.2 50 SF .C IL C P~ I. FCC '-S'99.2 50 RP gB. F DC N =[C. F£ C -S 9~. 2 50 CE L I. F 9C NPI'I.,.rNL -cga. ~ · 250 T~o~, . CNL RC~T.CNL -S99.250 RCFT.CNL C ~L Z. CNL -~ 9S. 2 50 SR. C ~'~L 6-JUN-1989 03:28 -9q9.250 iLD.EiL -999.250 '-999.250 GR.EIL -999.250 -999. 250 DRHC.FDC -999.250 -9q9.250 GR.FDC -999. 250 -999.250 TNR~.CNL -999.250 -999.250 CNTC.CNL -999.250 -999.250 T~NS.CSG -9S9.Z50 ILD.CIL -999.250 -999. 259 GR.g IL -999. 250 -999. !50 DRHC.FDC -999.250 -999. ZSO GR.FDC -999.250 -999.250 'TNP~.CNL -999.250 -999.250 CNTC.CNL --999.250 -999.250 TENS.CSG 1.455.000 -999.Z:50 ILD.EIL -999.250 -999. 250 gR.DIL -999. 250 -999..Z50 DRHC.FDC -999.2.50 -999.2.50 GR. F DC -99 9. 250 -999.250 TNRA.CNL -959.Z50 -999.250 CNTC.CNL -999.250 -999.290 T~NS.CSG 1460.000 -999.250 ILD.CIL -999.250 -99'9. 250 GR.~IL -999.250 -999. 250 DRHC.FDC -999.250 - 99 g. 250 GR . F DC - 99 9.250 -999.Z50 TNR~.CNL -999.250 -999.250 CNTC.CNL -999.250 -999.250 TENS.CSG 1400.000 -999.250 ILD.DIL -999.250 -999. 250 GR.E IL - 99'9. 250 -999.250 DRHC.FDC -999.250 -999. 250 GR.F DC - 99 9. ZSO -999.Z50 'T~R~.CNL -999.Z50 -999.Z50 CNTC.CNL -999.Z50 -999.250 TENS.CSG 1345.000 -999.250 ILD.£iL -'99-2.250 -999. 250 GR.C IL -99 9. 250 -999.250 gRHC.FDC -999.250 -999.Z'qO SR.FOC -999.250 -999.250 TNR~.CNL -999.250 -999.250 CNTC.CNL -9S9.250 -999.2q0 TENS.CSG 1290.900 - 999.7_50 ILC. E IL - 99 9. 250 -999. 250 GR.C iL - 999. 250 -999.259 DRHO.'; DC -999.250 -999. 250 GR.FDC -999. 250 -999.250 TNR~.CNL -999.250 -999.250 CNTC.CNL -999.250 ILM.DIL T Eh S. FCC F F£ C. :F~rC T Eh S. Ck L NPER.CNL CFIC.CNL C-R. CS G ILM.OIL TEh S. FCC F~EC.FDC TEhS.CNL N~CR.CNL CFIC.CNL [-R.CSG iLM.OIL TE~S.~CC F F[ C. FCC TEhS.CNL NPCR..CNL CF~C.CkL GR.CSG ILM.DIL TEh S. FCC FFEC.F£C TEh S.CNL NPER.CNL CFIC.C~L C-R.CSG ILM.DIL TE~S.FCC F F~ C. FCC TEhS.CNL NPER.CNL CFlC.CNL C-R. CSG iLM.OIL TEhS.FCC FFCC.FCC TE~S.CNL NPER.CNL CFIC.CNL C.R.CSG IL~.DIL TEhS.;CC FFEC.FCC TEh S.CNL NPCR.CNL CFIC.CNL P~GE: 1~ -S 99.250 -999.250 -999 ,. 2 50 -~99.250 -S99.250 -999.250 34.4 59 -999.250 -$99.250 -999.250 -999.2 $ O -999 · 250 -999.250 46.156 -999.250. -999.250 -999.2 50 -999.250 .-999.250 -999.250 48.063 -999.250 -999.250 -999.250 -9 99.250 -999.250 -999.250 31.266 -999.250 -S99.250 -999.250 -999.250 -999.250 -999.250 34.500 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 31.125 -~.99.250 -999.250 -S99.250 -S99.250 -999.250 -999.2 50 IS 'T,~:mE, VCRZ:~CZTTON,,. , ~ LISTING CHLU.PDERG=_R SLUSHY. C£MP!.JTI~:G CE:N~ER C AL "'I. ~CN L _c. 97.2 50 g,~ . C NL · 5- JUN-1989 08:28 -!~99.2SO TENS.C SC- 1240.000 BEFT. c. B9.~O0 TENS.CIE -999.Z50 ILB.CIL -999.250 SFLUoDIL .-S 99.2 50 ;SF.E ZL -999. ZDO GR.S tL -999. DPP I,.,=EC -999.250 REDE.CDC -999.250 ORHC.FDC -999.250 NFEC.FCC -S 99.2 50 C~LI.FDC -999. 250 GR.FDC -999.Z50 NP~ I. CNL -S 99.2 50 T~ ~F.C NE - 999.250 T~:R~,. C NL - 99 9.2 PCk'T.CNL -S99.250 .RCFT.CNL -999.250 CNTC.CNL -999.250 CALZ.C~L -999.250 GR.CNL -999.~50 TENS.CSG 1250.000 C-R.CSG ~LM.DZL TEl,, S. F£'C F ~I:: C. FCC T Et',, S. CN L NPI[ ~.CNL C':lC. C~L C-~.CSG P ~ G E: 17 49.094 -99'9.250 -999.250 -999.250 -999.250 -999.250 -999°250 39..531 .... ~.. FIL=,. r~A~L~R, ~ .~.-'- FILE N~E : E~S~T .SERVICE ' 'FLIC VErSiON : 061~02 DATE : 59/06/ ~ REC SZIE : 1,096 FILE T~PE : LC LA~'T ~ILE : ~~qCHLL)q~':RG'~,- ECSq. INCLL3=S- ,_ WI'H THI~ =It=~ . (:[rT ~ <SEE FZL~ EgZl.O0~ FO~ .~" S.~PLED DILI~DCICNLIGR ., ~-,- =C=~&~CN, , , DFNSiTY CCMP:t,IS~T~D~_ LOG (.CCH), ~, FIRST TO L~ST ~aDING: 8502' TC ~ CC*~PE~S~TEg t'IEUT2C~ L~G (.CN:q) ~ F!PSI T3 L~ST PEaOi~4G: 8486' TC .S T~PE VERZFZCATiCN LISTING CHL!JFBERGER SLaSF,~ CCMPUTZNG CENTER 6- JUN- !9 ~9 08:28 T AB LE CN FN NN NATZ ST~ T COL N FL SECT TOt~N RAI~G E NC-Z SO~,. 'TYPS · CCNS TUI~I VALU ~RCO ~LASK~, iNC. K!JP ~UK 2K-! U S ~a NORTH SLgP~ 29~' ~SL ~ 94~ 2 10N N 50-103-20102 COMPanY NSME FIELD WELL hAME N~TIO~ STATE OR PROVINCE C~ UNT¥ :I~Lg LgC~TiON SECTIEN TCWNSP R ~ N g E ENGINEER'S NA~E S~RVIC,~ AFI S~I~L NUmBeR TAELE TYP~ : CLRV DEFZ DEFT DEPTH CP~NNEL N.qME TE~S TENSION DPEi O'EN~ ITY PCR£SITY RH[~, BULK O~g gELT ~, FFCC SAR ~CC COU~T NFCC NE~ FDC CgLNT C~l! C~LIOE~ TEflS TENSIEN NPEI NEUTRCN °ORCSITY TN~H THE~}~4~L qEUTRCN PORCSITY NPER NEUTRCN PORCSITY CUTPUT SRO~ ~N ~POIIC4TICN RC~T ~AW CC~CTEO NEaR THEqP~L C3LNTS RCFT 2~W C~RF~CTED ~$R TEER~L CCU~TS CNTC CGR~ECTE2 N~4P THER~4L COUNTS CFTC CCq~ECTEO n~q TH~R~$L CCUNTS C~LI CALIPER GR G~MD ~ ~Y .IS TAPE VSR!FZCAIZgN LISTIN$ ;CHLUNSERGER ~L~SK~ CCMPUTINr~ CENTED 6-JUN-1989 08:28 P~GE: Ie. FOrMaT SP2CIFICATICN -..-.- SET T,fDE - TYDE REFR CEDE V-~LUE 1 6~ O 2 ~ 0 '7 65 8 68 0.099 9 6~ FT 1.2 68 13 6~ 0 ! 4 :65 = l 15 66 68 16 6~ t 0 6~ 1 NAN:E SERV LNIT SERYTCE APl ~F,! ~PI ~P! 'mILE NUNB NLM~ SIZE REPR ID OR'DER '~ LOg TYFE CL6, SS MOD NUH~ SflYP ELEM CDDE F R 0 C E 'S S DEFT FT 54912.6 CO OCO CO 0 2 1 I 4 68 TEKS FCH L3 569126 0'? .6~5 21 0 2 I 1 4 68 DPPI FEH FU 549116 07 635 21 0 2 1 I 4 68 RHC3 FCH 6/C3 549126 07 350 62 n 2 1 I 4 68 DR~O FCH E/C3 5491Z6 07 355 C! ~ 2 1 1 ~ 68 FFCC FCH C~5 5~9126 07 354 ~2 O 2 1 1 4 68 NF[C FEH CPS 549126 0'7 354 Cl 0 2 I 1 4 68 CALl FCH IN 54912¢ OT 2EO Ol 0 2 I 1 4 68 G~ FCH ~A~i 549126 07 310 C! O 2 1 1 ,4 68 TE~S CNH LB 549116 07 675 2t 0 2 1 I 4 68 hPbl CNH FU 549126 07 8~0 CO 0 Z 1 1 4 68 TNPH ChH FU 549126 07 8~0 CO O 2 1 1 4 68 TN~ ChH 549126 Q7 420 C1 0 2 1 I ~ 68 NPC'R CNH FU 549126 07 8~9 CO 0 2 I 1 4 68 RChT ChH CPS 549126 07 420 C1 0 2 ! 1 4 68 RCFT C~H CDS E4g126 GT 429 C1 ~ 2 1 I 4 68 CNTC ChH CPS 549126 07 420 Cl 0 2 1 1 4 68 CFTC CNH CPS 5aglZ6 07 420 C! O 2 1 1 4 68 C~LI ChH l~l 543126 07 280 C1 O 2 1 ] 4 63 GR CNH G~Pl 569126 07 310 C1 O 2 I 1 4 68 OCO00CO00C OCO00CO000 Oa O00C 0000 0(~ O00CO000 OCO00CO000 OCOOOCO000 OCO00COOOO OCOOOCO00O OCOOOCO000 OCO00COOOO OCOlDOCO000 OCO00CO00O OCOOOCOOOC OCO00CgO00 OCOOOCO000 OCO00CO000 OCO00COO00 0C000C9000 OCO00CO000 OCOOOCO00O -,- DAI A ~ <~ DEFT, 8400.C0g T~NS.FDH gRPD.=EH 0,C32 =FDC.F'DH ~ R, F~ H I O.E, 313 TE NS, C NH lN~ ~,C~H ~, 218 NFOR,CNN CNTC. CNH 209~. 4 72 CFTC .CNW DEFT. 8300. C O0 TI NS. F DH D RP O. Fg H O. O !5 FF DC . 6R,F£H 88,2 50 TN~A,CNH 2,~00 CNTC.CNH 25!6,110 CFTC.CNN 6-,JUN- 19 89 08:28 1730.000 9PHI.FDN 741.000 NFDC.FDN 1730.000 NPHi.CNH 48. 829 RCNT,CNH 491.893 C~LI.CNH 6112.000 DFHI.FD~ 6~4.:500 NFDC.FDH 6:1!2.000 NPHI,CNF 45. 730 RCNT.CNH 504.9~6 C~Li.CNH ~160.000 DPHI,FDN 492,500 NFDC.~DN 6160,000 NPHI.CNN 37,675 RCNT ,CNN 658. 541 C~LI.CNH ~'748o000 DPHZ.FDN 526.000 NFDC,FOP~ 5748,000 NPHI,CNH 31,602 RCNT,CNH 917.802 C.~LI.CNN 5924~000 DPHI.FDN ~61.500 NFDC.FDN 5924.000 NPHI,CNH 37.655 RCNT.CNH 708.347 C~L'I.CNN 55E~.000 DPHI.FOH 554.000 NFOC.FDH 5 668. 000 NPHI.CNH 43.04 ! RC NT . C NH. 490.068 C~LI.CNH 5500.000 DFHI.FDH 545.500 NFDC.FOH 5500.000 NPHI.CNN 43.803 RCNT.CNN 52B.100 C~LI.CNH 5908.000 DPH!.FDN 529.500 .NFDC,FDH 5009,000 NPHI,CNH 4Z.440 RCNT.CNH 567.!62 C~LI.CNH 1 8.519 731.500 ~=0.394 I 8 ! 2.356 7.508 17.499 701.500 49,602 1760.533 7.66,4 11.924 602.000 37.523 2096.415 8.852 14.604 59 7. 000 30.223 2487.286 9.063. 11.963 564.500 38.017 2060.443 9. 156 15,690 609.500 46,529 1653.445 9.078 15.360 606.000 42.606 1774.374 9.367 15,875 574.000 44,521 ~967 361 9.273 RHEB.FCH CAt I. FCH TNFH.CkH Rr~'~ CNH r~R,CkH RHE B, F£H CAL I.FOH TNFH,CNH PCFT.CNH F~R,CNH CALI.FDH TNFH.CNH RCFT.CNH 6R.CINH RHCB,F£H C~LI.~OH TNFH,CNH RCFT,CNH 6R,CNH RH£B.FCH C~LI.FCH TNFH.CNH RCFT.CNH C-q.CNH R HE ~. FC H C~,LI.FEH TNFH.CNH RCFT.CNH C-R, CNH RHEB.FCH C'4LI.FCH TNFH.CNH RCFT.CkH C-R.CNH RH[B.FCH C~LI.FCH TNFH.CNH RC~T.CNH 6R,CNH P,~ GE: 2,344 7,508 -4 6.8 29 439,720 101,250 2.361 7.664 44.947 446.267 97.C00 2,453 8,852 37,458 5 0, :563 06.3 13 2.409 9.063 30.39~; 778.318 88.250 2.453 9.156 37.204 626. ~ 85 127.875 2,391 9, (]78 43 ,~13 430.955 125,125 2.397 9.367 43.292 479.750 135.750 2.388 9.273 41.576 526.54S 206.750 2O S T/~E ¥~RZF'ZCATZON Li!S'TI~G HLUP;SERGER /~L~S~ Cr_MFUT'I~:G CENIER 8-JU~t-19"3S 08:2~ 21 ~""'-'-X~ TAr: ~ T~, .:~!LE R -"~""~"' :SERVICE N~F E : ECZT CAlE ' 8~/061 6 ORIGIN ' =LIC TAFE NAME ' 7~350 CDNTINUATZCN ~ : PREVIOUS T~PE : CONMENT ' ~C0 ~L~SK~, INC., KUP~RUK~ 2K-1, ~5 O- 107- ZO IC 2 INC. , KUP~RUK , 2K-1, ~50-10:'-Z01C2.,
