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192-101
Originated: Delivered to:18-Jun-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 2B-02A 50-029-21154-01 910106459 Kuparuk River Multi Finger Caliper Field & Processed 14-Jun-25 0 12 2B-03B 50-029-21151-02 n/a Kuparuk River Radial Bond Record Field- Final 8-Mar-25 0 13 2F-09 50-029-21090-00 910080198 Kuparuk River Plug Setting Record Field- Final 23-May-25 0 14 2F-09 50-029-21090-00 910010602 Kuparuk River Radial Bond Record Field- Final 2-May-25 0 15 2G-17 50-029-23134-00 910106461 Kuparuk River Plug Setting Record Field- Final 9-Jun-25 0 16 2K-23 50-103-20125-00 910099510 Kuparuk River Multi Finger Caliper Field & Processed 2-Jun-25 0 17 2K-34 50-103-20688-00 910096425 Kuparuk River Multi Finger Caliper Field & Processed 15-Jun-25 0 18 2M-08 50-103-20184-00 910027001 Kuparuk River Multi Finger Caliper Field & Processed 9-May-25 0 19 2M-25 50-103-20152-00 910106929 Kuparuk River Plug Setting Record Field- Final 12-Jun-25 0 110 2M-25 50-103-20152-00 910106929 Kuparuk River Tubing Cut Record Field- Final 13-Jun-25 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:216-087223-080184-036202-243190-014214-026192-101191-021T40589T40590T40591T40591T40592T40593T40594T40595T40596T405966/20/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.06.20 08:42:29 -08'00'192-1012M-0850-103-20184-00 910027001Kuparuk RiverMulti Finger CaliperField & Processed9-May-2501 STATE OF ALASKA AAA OIL AND GAS CONSERVATION COMM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon f Plug Perforations E Fracture Stimulate 1- Pull Tubing F Operations Shutdown Performed: Suspend E Perforate E Other Stimulate E Alter Casing I-••••.. Change Approved Program 1.- Plug Plug for Redrill r Perforate New Pool 1 Repair Well F Re-enter Susp Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory E 192-101 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-103-20184-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25589 KRU 2M-08 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 12151 feet Plugs(measured) None true vertical 6476 feet Junk(measured) None Effective Depth measured 12046 feet Packer(measured) 11539 true vertical 6397 feet (true vertical) 6016 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 121 121 SURFACE 4211 9 5/8 4253 2744 PRODUCTION 12099 7 12138 6466 RECkEWFD Perforation depth: Measured depth: 11721-11750, 11784-11807 True Vertical Depth: 6153-6175,6200-6217 U C 7 2 ; 2016 Tubing(size,grade,MD,and ND) 3.5, L-80, 11761 MD,6183 ND G & Packers&SSSV(type,MD,and ND) PACKER=BAKER FHL RETRIEVABLE PACKER @ 11538 MD and 6015 TVD SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): none Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut-in Subsequent to operation Shut-in 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory r Development F Service r-- Stratigraphic Copies of Logs and Surveys Run f 16.Well Status after work: Oil F Gas E WDSPL 1.- Printed Printed and Electronic Fracture Stimulation Data I® GSTOR r WINJ E WAG fl GINJ fl SUSP E SPLUG E 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Danny Kane @ 265-6048 Email Daniel.Kanea,conocophillips.com Printed Name Danny Kane Title Sr. Wells Engineer Signature ,,, Phone:265-6048 Date 2-4. -OCT-2-0514, V'TL /o72- //& Form 10-404 Revised 5/2015 # (072.0i RBDMS L V OCT 2 8 2016 Submit Original Only • • , :: ‘,,,,,,,„, .., ., Operations Summary (with Timelog Depths) ' 2M-08 coPhi ps Rig: NABORS CDR2-AC Job: RECOMPLETION Time Log Start Depth Start Time-. End Time Dur(hr)'. Phase Op Code Activity Code Time P-T-XOperation (EKE) End Depth(ftKS)'.. 8/31/2016 8/31/2016 5.00 MIRU MOVE WAIT P Wait for roads and pads to lay mats on 0.0 0.0 04:00 09:00 road. Sim-ops: 8/31/2016 8/31/2016 12.25 MIRU MOVE MOB P Move rig to 2M-pad 0.0 0.0 09:00 21:15 8/31/2016 9/1/2016 2.75 MIRU MOVE MOB P Rig on location,stage equipment in 0.0 0.0 21:15 00:00 cellar,hand new tree in cellar,prep well for rig,contact DSO,for spotting rig subs,remove jeeps and stage on edge of pad.Spot rig over well 08. 9/1/2016 9/1/2016 5.00 MIRU MOVE MOB P Spot pits module and tiger tanks. 0.0 0.0 00:00 05:00 Completed post rig move check list. 9/1/2016 9/1/2016 7.00 MIRU WELCTL RURD P Begin taking 411 bbls 11.5 ppg 0.0 0.0 05:00 12:00 NaCI/NaBr KW fluid into pits 1,2,3 (active system). RU hardline and choke house from tiger tanks to circ manifold in cellar.Break down and re- build circ manifold RU circulating lines from circ manifold to IA and tubing via wing valve.Install blind flange on MPD line.Additional 457 bbls KW fluid into pits 7,8. **Rig accept @ 0500" 9/1/2016 9/1/2016 2.00 MIRU WELCTL MPSP T PJSM,RU BPV lubricator,had to 0.0 0.0 12:00 14:00 adjust bolts on lubricator for clearance through bell nipple. 9/1/2016 9/1/2016 3.00 MIRU WELCTL MPSP P PT lubricator to 2500 psi(good).Pull 0.0 0.0 14:00 17:00 BPV(OA 60psi,IA Opsi,Tbg Opsi).RD BPV lubricator. 9/1/2016 9/1/2016 1.50 MIRU WELCTL RGRP T Verify lined up to reverse circulate,PT 0.0 17:00 18:30 circ lines to 3500 psi.Shock hose on rig floor leaking.Torque up connection. 9/1/2016 9/1/2016 1.50 MIRU WELCTL SEQP P Re-do PT to 3500 psi.Good test. 0.0 0.0 18:30 20:00 9/1/2016 9/1/2016 1.00 MIRU WELCTL KLWL P Start pumping 11.5ppg NaCl/NaBr 0.0 0.0 20:00 21:00 down IA taking returns up the tubing out to the tiger tanks to remove diesel from the tubing.4 BPM @ 900 psi pump pressure. Pumped 69 bbls.Shut down pumps,SI well. 9/1/2016 9/1/2016 2.50 MIRU WELCTL KLWL P Line up&start pumping 11.5ppg 0.0 0.0 21:00 23:30 NaCl/NaBr the long way around(down tubing,up IA).Pumped 520 bbls,4 BPM @ 850 psi initial pump pressure. 9/1/2016 9/2/2016 0.50 MIRU WELCTL OWFF P Shut down pumps,observe SICP& 0.0 0.0 23:30 00:00 SITP. 11.3 ppg fluid sample out. Continue pumping after tower change. 9/2/2016 9/2/2016 2.50 MIRU WELCTL KLWL P Tower change.SITP 35 psi,SICP 20 0.0 0.0 00:00 02:30 psi.Emptied 290 bbls from CDR-2 TT (much easier to strap than Rain for Rent tank).Continued circulating the long way another 100 bbls. 9/2/2016 9/2/2016 0.50 MIRU WELCTL OWFF P Watched SICP&SITP/30 mins. 0.0 0.0 02:30 03:00 Opened whitey in cellar,U-tubed tbg to IA to verify dead well. Page 1/13 Report Printed: 10/26/2016 Operations Summary (with Timelog Depths) 2M-08 Ccnorest't ifflps. Rig: NABORS CDR2-AC Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(Er) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB). 9/2/2016 9/2/2016 1.50 MIRU WHDBOP MPSP P PJSM,set BPV(3"'ISA'#336).PT 0.0 0.0 03:00 04:30 BPV from below to 1000 psi/10 mins. Good test. 9/2/2016 9/2/2016 6.50 MIRU WHDBOP NUND P PJSM,ND tree.30k to free tree,lay 0.0 0.0 04:30 11:00 down same,inspect threads,good shape,install blanking plug, 12 right hand turns, 16.5"from center of LDS to top of plug,9.5 Left hand turns to fully engage retrieving tool,secure cellar,continue bleeding down OA. 9/2/2016 9/2/2016 7.00 MIRU WHDBOP NUND P PJSM, NU BOPE,measure and fit 0.0 0.0 11:00 18:00 flow riser,RKB's to stack component lengths.Function tested RAMs to verify correct hydraulic hose alignment. 9/2/2016 9/2/2016 4.00 MIRU WHDBOP RURD P Pre-SPUD presentation with new night 0.0 0.0 18:00 22:00 crew,rig inspection.Grease BOP valves prior to starting initial BOP test. Trouble-shoot stuck B1 valve(closed). 9/2/2016 9/3/2016 2.00 MIRU WHDBOP BOPE T Pressure up to 250 psi for BOP shell 0.0 0.0 22:00 00:00 test,small leak from BOP door seal. Tightened door bolts,pressured up to 3500 psi,door still leaking. Drain BOP stack,remove/replace extruded door seal. State witness was waived by AOGCC Inspector Louis Grimaldi via e-mail on 8/31/2016 @ 06:57. 9/3/2016 9/3/2016 2.50 MIRU WHDBOP BOPE T Continue with BOPE test.Installed 2" 0.0 0.0 00:00 02:30 test joint.Upper 2"blind shears failed. 9/3/2016 9/3/2016 7.50 MIRU WHDBOP BOPE P Continued BOPE testing 0.0 0.0 02:30 10:00 #10,11,12,13,retest 2"blind rams, pass,B1 HCR working and tested good,PU 2-7/8"test joint,MU XO's to floor valve,leak between floor valve and 3-1/2"IF XO,unable to torque up due to floor valve 20'above floor. 9/3/2016 9/3/2016 1.00 MIRU WHDBOP BOPE T Lay down test joint,break off floor 0.0 0.0 10:00 11:00 valve and crossovers,send to Doyon 142 to have torqued to spec.Hang rig tongs,clean and clear floors. 9/3/2016 9/3/2016 1.25 MIRU WHDBOP BOPE T PU/MU 2-7/8"test joint again,attempt 0.0 0.0 11:00 12:15 test again with same results,leak at same place,lay down test joint and take floor valve and crossovers back to Doyon 142 to get doped&re- torqued. 9/3/2016 9/3/2016 1.00 MIRU WHDBOP BOPE T Change out rig tongs for wider range 0.0 0.0 12:15 13:15 tongs. 9/3/2016 9/3/2016 0.75 MIRU WHDBOP BOPE T PU/MU 2-7/8"test joint again,attempt 0.0 0.0 13:15 14:00 test again with same results,leak at same place. Page 2/13 Report Printed: 10/26/2016 • Operations Summary (with Timelog Depths) 2M-08 ConocoPhiilips Rig: NABORS CDR2-AC Job: RECOMPLETION Time Log Start Depth Start Time:. End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (RKB) End Depth(RKB) 9/3/2016 9/3/2016 4.00 MIRU WHDBOP BOPE T Lay down 2-7/8"test joint,get rid of 0.0 0.0 14:00 18:00 leaking XO.Send new 3-1/2"IF XO over to Doyon 142 for MU to floor valve. In the meantime,MU 3-1/2"test joint,test VBR's,Dart and TIW valve, Lay down 3-1/2"test joint,Perform Koomy draw down, 9/3/2016 9/3/2016 2.00 MIRU WHDBOP BOPE T PU/MU 2-7/8"test joint to the new XO 0.0 0.0 18:00 20:00 +floor valve.Pressure test,leaking between test joint&lower XO(2-7/8" EUE conn).LD test joint.Break out leaky connection,damaged seal.No extra seal on location,wrap threads in teflon. 9/3/2016 9/3/2016 1.50 MIRU WHDBOP BOPE T MU test joint again.Pressure test, 0.0 0.0 20:00 21:30 leaking between two XOs(3-1/2"IF conn).Break out leaky connection, wrap threads in teflon.MU test joint again.Passing high/low pressure tests achieved.Drain stack. RD BOPE equipment. 9/3/2016 9/3/2016 1.00 MIRU WHDBOP OTHR P Rig-up for pulling upper completion. 0.0 0.0 21:30 22:30 Install elevators.With tugger,pick up 3-1/2"IF DP joint to retrieve blanking plug. 9/3/2016 9/4/2016 1.50 MIRU WHDBOP MPSP P Retrieve blanking plug to surface.Use 0.0 0.0 22:30 00:00 tongs to break out plug from DP. Verify no pressure on IA,dry rod equalizing tool to confirm no pressure below BPV.Retrieve BPV to surface with dry rod. 9/4/2016 9/4/2016 1.50 COMPZN RPCOMP RURD P PJSM,MU landing joint+floor valve in 0.0 0.0 00:00 01:30 mouse hole.Use pipe skate to latch with elevators.RIH,MU to tbg hanger with 11.5 RH turns. 9/4/2016 9/4/2016 1.00 COMPZN RPCOMP RURD P MU hose with swivel to top of landing 0.0 0.0 01:30 02:30 string.Pressure test rig-up against closed TIW.Good test.BOLDS(4). 9/4/2016 9/4/2016 0.25 COMPZN RPCOMP PULL P Un-seated tubing hanger with 28k 11,548.0 11,505.7 02:30 02:45 overpull.Pulled hanger to surface confirming tubing cut.Hookload= 90klbs with hanger at surface. Maximum hookload pulling through stack= 110klbs(including 15k topdrive weight),immediately prior to breaking over to 70klbs. 9/4/2016 9/4/2016 3.25 COMPZN RPCOMP CIRC P Circulate BU.4 BPM @ 770 psi. 11,505.7 11,505.7 02:45 06:00 11.5ppg fluid returns.well static,lay down landing joint,TIW and tubing hanger. SimOps:Bring SLB control line spooler to rig floor. 9/4/20116 9/4/2016 0.50 COMPZN RPCOMP SFTY P PJSM-crew change,laying down 11,505.7 11,505.7 06:00 06:30 tubing, 9/4/2016 9/4/2016 3.35 COMPZN RPCOMP PULL P POOH laying down 3-1/2"tubing 11,505.7 9,731.0 06:30 09:51 spooling control line from 11,548 ft RKB to SCSSSV at 9,731 ft RKB(PU 90K and SO=70K). Lay down SCSSSV. Recovered 32 of the 33 stainless steel bands. Page 3/13 Report Printed: 10/26/2016 • • = T4s • Operations Summary (with Timelog Depths) F 2M-08 ConocoPh,illi Rig: NABORS CDR2-AC Job: RECOMPLETION Time Log Start Depth Start Time'.. End Time Our Mr)'.. Phase Op Code Activity Code Time P-T-X Operation (ftKE) End Depth(ftK6) 9/4/2016 9/4/2016 0.40 COMPZN RPCOMP RURD P RD Camco control line spooling unit. 9,731.0 9,731.0 09:51 10:15 Off load spooling unit and tools off the rig floor. 9/4/2016 9/4/2016 5.00 COMPZN RPCOMP PULL P Continue POOH laying down L-80 3- 9,731.0 5,932.0 10:15 15:15 1/2"tubing and GLM#4 from 9,731 ft to 5,932 ft RKB.All L-80 tubing out of hole(177 jts). Internal pitting noticed, but no indication of expected leaks in Jts168-170 or 177-179. 9/4/2016 9/4/2016 4.00 COMPZN RPCOMP PULL P Continue POOH laying down J-55 3- 5,938.5 3,938.0 15:15 19:15 1/2"tubing from 5,932 ft to 3,938 ft RKB.Secure well. 9/4/2016 9/4/2016 0.75 COMPZN RPCOMP RURD P Clean and clear rig floor. 3,938.0 0.0 19:15 20:00 9/4/2016 9/5/2016 4.00 COMPZN WELLPR MPSP P PJSM,PU,MU,trouble getting screw 0.0 0.0 20:00 00:00 out of twin thread, RIH with storm packer,release from storm packer,set packer TOP @ 98.03'- center of element @105.36',Release from storm packer,LD,DP and running tool 9/5/2016 9/5/2016 1.50 COMPZN WELLPR MPSP P PT storm packer to 1150 psi for 10 3,938.0 3,938.0 00:00 01:30 min(good test),Break down Landing joint 9/5/2016 9/5/2016 3.25 COMPZN WELLPR NUND P Vac out stack,RD,riser,ND stack, 0.0 0.0 01:30 04:45 disconnect Choke line,move stack back on stump,and secure for casing growth work 9/5/2016 9/5/2016 1.25 COMPZN WELLPR RURD P Load Hydratight equipment into cellar, 0.0 0.0 04:45 06:00 remove valves from tubing head. 9/5/2016 9/5/2016 3.50 COMPZN WELLPR NUND P PJSM-RU Hydratight system to the 0.0 0.0 06:00 09:30 tubing head and ND the tubing head using Hydratight to control the casing growth.Initial pressure 20k.The casing grew 30". RD the Hydratight system and remove the tubing head. 9/5/2016 9/5/2016 1.00 COMPZN WELLPR BHAH P PJSM-Bring in,PU/MU 7"casing 0.0 0.0 09:30 10:30 spear. 9/5/2016 9/5/2016 1.25 COMPZN WELLPR CUTP P Engage spear into the 7"casing,Stag 0.0 0.0 10:30 11:45 up from 50k to 150k(50k over neutral weight 100k)stretched the casing an addtional 15.5",pull 200k and back down to 150k,total stretch 18.25", install new emergency slips,and release the spear. 9/5/2016 9/5/2016 1.00 COMPZN WELLPR BHAH P Make service breaks on the 7"casing 0.0 0.0 11:45 12:45 spear and lay the spear down.Clean and clear floors. 9/5/2016 9/5/2016 1.50 COMPZN WELLPR CUTP P PJSM-RU the Wachs cutter,cut off 0.0 0.0 12:45 14:15 the excess 7"casing(cut off 4.0')RD the Wachs cutter. 9/5/2016 9/5/2016 1.75 COMPZN WELLPR WWSP P Install new 7"casing packoff. 0.0 0.0 14:15 16:00 9/5/2016 9/5/2016 1.00 COMPZN WELLPR WWSP T Snapped 1 of 12 energizing bolts at 0.0 0.0 16:00 17:00 400 lbs torque as per FMC procedure, further investigation It's 200 lbs torque required,remove pack-off while another one on its way from warehouse. Page 4/13 Report Printed: 10/26/2016 e • e ` Operations Summary (with Timelog Depths) ,_ . � 2M-08 oPhitilps Rig: NABORS CDR2-AC Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(IT) Phase Op Code Activity Code Time P-T-X Operation (5Kt3) End;Depth(ftKB) 9/5/2016 9/5/2016 2.75 COMPZN WELLPR WWSP P Install new 7"pack-off and NU new 0.0 0.0 17:00 19:45 tubing head. 9/5/2016 9/5/2016 1.25 COMPZN WELLPR WWSP P PT void to 3000 psi for 30 minutes 0.0 0.0 19:45 21:00 (good test), install annulus valve, 9/5/2016 9/6/2016 3.00 COMPZN WELLPR NUND P PJSM,NU BOP stack,choke line,and 0.0 0.0 21:00 00:00 install riser. 9/6/2016 9/6/2016 1.50 COMPZN WELLPR RURD P Finish installing riser boots, 0.0 0.0 00:00 01:30 PU/MU/Set test plug 9/6/2016 9/6/2016 1.00 COMPZN WELLPR BOPE P PJSM,line up,shell test 250/3,500 0.0 0.0 01:30 02:30 psi, RD testing equipment,Pull test plug. 9/6/2016 9/6/2016 3.00 COMPZN WELLPR MPSP P PJSM,MU storm packer retrieving 0.0 0.0 02:30 05:30 head,RIH,engage the storm packer and open up the equalizing valve(no- pressure on tubing).Close annular, PU 4'to release the storm packer, check for pressure(no-pressure),and open up the annular,POOH laying down 3 joints of DP,LD storm packer. 9/6/2016 9/6/2016 12.00 COMPZN RPCOMP PULL P Continue pulling out of the hole and 0.0 0.0 05:30 17:30 laying down 3-1/2"9.3 ppf J-55 EUE tubing.Pull joints 242 through 366. Hole taking proper fill. External corrosion observed on the coupling of joint 283.Minimal external corrosion observed after joint 300.No significant external corrosion noted on the pipe bodies. Cut joint strap= 14.71 ft. 9/6/2016 9/6/2016 3.00 COMPZN RPCOMP RURD P PJSM, Displace coil to 11.5 ppg brine 0.0 0.0 17:30 20:30 (36 bbl),clear rig floor of tongs,move INJH cart over to rig floor sump,line up and pump 2.0 bpm,wire started moving,pull 155 ft of E-line from reel 9/6/2016 9/7/2016 3.50 COMPZN RPCOMP RURD P 'PJSM,vac out and remove riser from 0.0 0.0 20:30 00:00 stack,cut and dress coil and install BOT external grapel CTC,pull test 42k, PT CTC and inner reel valve 4,500 psi(charted),install 7-1/16" adaptor flange,spaceout and install 7.00 inch lubricator sections, 9/7/2016 9/7/2016 1.00 COMPZN RPCOMP RURD P finish spacing out lubricators, 0.0 0.0 00:00 01:00 9/7/2016 9/7/2016 5.00 COMPZN RPCOMP RURD P Load Thru-tubing and Baker fishing0.0 0.0 01:00 06:00 equipment on to rig,installed the quick test sub,stabbed the INJH,PT the riser and pac-off to 1,500 psi, unstabbed INJH,switched 3-1/2 to 2- 7/8"elevators,prepped the rig floor for MU BHA 9/7/2016 9/7/2016 2.75 COMPZN RPCOMP BHAH P MU overshot fishing BHA. 0.0 0.0 06:00 08:45 Troubleshoot little jerk tongs. 9/7/2016 9/7/2016 0.50 COMPZN RPCOMP BHAH T Pick up and confirm MU torque on 0.0 0.0 08:45 09:15 connections made with little jerks. All connections made up to spec. 9/7/2016 9/7/2016 1.75 COMPZN RPCOMP BHAH P Continue MU overshot fishing BHA. 0.0 301.0 09:15 11:00 Bump up and set counters. 9/7/2016 9/7/2016 2.50 COMPZN RPCOMP TRIP P RIH with fishing BHA.Slight weight 301.0 11,200.0 11:00 13:30 bobble at 9,625 ft.Continue in the hole. Page 5/13 Report Printed: 10/26/2016 • S Operations Summary (with Timelog Depths) 2M-08 ConocoPhillips Rig: NABORS CDR2-AC Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (MKS) End.Depth(ftKD)'. 9/7/2016 9/7/2016 0.50 COMPZN RPCOMP TRIP P Slow running speed to 20 fpm from 11,200.0 11,528.0 13:30 14:00 11,200 ft. PUW at 11,500 ft=36 Klbs. SOW=13KIbs down. Tag fish 11,528 ft(CT depth). 9/7/2016 9/7/2016 1.00 COMPZN RPCOMP FISH P Set down on fish with 3 Klbs(10KIbs 11,528.0 11,528.0 14:00 15:00 surface weight).Continued to set down to zero surface weight engaging fish. Work pipe up in 10klbs increments from 36Klbs.Tubing stub appeared to break over at 78 Klbs.PUH,RBIH and tag at 11511 ft.Continue in the hole, tubing seal assembly looks to be entering the PBR.Tag bottom and PUH.Saw seals exit PBR.Continue out of the hole. 9/7/2016 9/7/2016 2.00 COMPZN RPCOMP TRIP P POOH with fishing BHA. 11,528.0 301.7 15:00 17:00 9/7/2016 9/7/2016 1.00 COMPZN RPCOMP SFTY P 4 year recognition for safety 301.7 301.7 17:00 18:00 performance,with day and night shift. pretour with night crew. 9/7/2016 9/7/2016 2.25 COMPZN RPCOMP PULL P PJSM,with rig team for LD BHA with 301.7 0.0 18:00 20:15 fish(14.71').Full engagement of overshot,(24") --Note:Fish lengths Cutoff-16.58' Seals -16.87' Overall-33.45' 9/7/2016 9/7/2016 2.25 COMPZN RPCOMP BHAH P PJSM,MU PBR fishing BHA,bump up 0.0 304.4 20:15 22:30 and set counters 9/7/2016 9/8/2016 1.50 COMPZN RPCOMP TRIP P RIH 304.4 7,035.0 22:30 00:00 9/8/2016 9/8/2016 1.00 COMPZN RPCOMP TRIP P Continue RIH with spear to fish PBR, 7,035.0 11,562.0 00:00 01:00 RIW 15k,PUW 36k 9/8/2016 9/8/2016 5.00 COMPZN RPCOMP JAR P Entered PBR 11,555'set down to Ok 11,562.0 11,562.0 01:00 06:00 CTSW,jar hit down 5k weight back, set down to Ok CTSW, 11562.6',PUH see over pull @ 11,551', 19 cycles working up to 76k straight pull to 80k. Let jars cool down. "Note:Adjust hydraulic pump to max pressure 3,000 psi,chains slipping, clean INJH chains 9/8/2016 9/8/2016 1.00 COMPZN RPCOMP OTHR P Clean and inspect injector chains. 11,562.0 11,562.0 06:00 07:00 9/8/2016 9/8/2016 2.00 COMPZN RPCOMP JAR P Continue jarring up on PBR/Packer. 11,562.0 11,562.0 07:00 09:00 Slack off to neutral weight. Precautionary inspection of injector, cart,and CT. No issues. 25 total jar hits as of 9:00am. SIMOPS Discuss forward plan with town. 9/8/2016 9/8/2016 2.00 COMPZN RPCOMP JAR P Continue jarring up on PBR/Packer. 11,562.0 11,562.0 09:00 11:00 Slack off tol OKlbs surface weight.PU at 30 fpm to 76Klbs,fire jars.Straight pull to 80KIbs. Repeat. 50 total jar hits. Page 6/13 Report Printed: 10/26/2016 • ' Operations Summary (with Timelog Depths) 0 2M-08 ConocoPhitilps Rig: NABORS CDR2-AC Job: RECOMPLETION Time Log Start Depth Start Time > End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE). End Depth(EKE) 9/8/2016 9/8/2016 2.00 COMPZN RPCOMP JAR P Continue jarring up on PBR/Packer. 11,562.0 11,562.0 11:00 13:00 Slack off tol OKlbs surface weights. PU at 60 fpm to 76Klbs,fire jars. Straight pull to 80KIbs. Repeat. 100 total jar hits. 9/8/2016 9/8/2016 3.50 COMPZN RPCOMP JAR P Continue jarring up on PBR/Packer. 11,562.0 11,562.0 13:00 16:30 Slack off tol OKlbs surface weight.PU at 60 fpm to 76KIbs,fire jars.Straight pull to 80Klbs. Repeat. 150 total jar hits. Last 2 straight pulls were to 100KIbs with no chain slipping. No movement of the fish. Discuss plan forward with town.Made decsion release the fish and POOH to cut cil and reconfigure fishing BHA. 9/8/2016 9/8/2016 2.50 COMPZN RPCOMP TRIP P Set down on fish.Bring pumps up to 11,562.0 304.4 16:30 19:00 1.6 BPM.Pick up off fish with pumps on.Released from fish.POOH *"*Note:Check well for flow @ 11,525'(no flow) 9/8/2016 9/8/2016 0.25 COMPZN RPCOMP OWFF P At surface,check well for flow 15 304.4 304.4 19:00 19:15 mins, 9/8/2016 9/8/2016 3.00 COMPZN RPCOMP BHAH P LD fishing BHA#2 304.4 0.0 19:15 22:15 9/8/2016 9/8/2016 1.00 COMPZN RPCOMP SVRG P Inspect BOPE and INJH 0.0 0.0 22:15 23:15 9/8/2016 9/9/2016 0.75 COMPZN RPCOMP RURD P Clean up rig floor for crew change, 0.0 0.0 23:15 00:00 load pipeshed with addtional DP and collars. 9/9/2016 9/9/2016 0.50 COMPZN RPCOMP SFTY P PJSM,with rig crew,valve alignment 0.0 0.0 00:00 00:30 check list 9/9/2016 9/9/2016 4.00 COMPZN RPCOMP BHAH P MU fishing BHA, BHA#3 0.0 479.9 00:30 04:30 9/9/2016 9/9/2016 2.00 COMPZN RPCOMP TRIP P Tag up,reset counters,RIH with 479.9 479.9 04:30 06:30 fishing BHA#3 9/9/2016 9/9/2016 6.25 COMPZN RPCOMP JAR P PUW=38Klbs. RIH and tag fish.Hit 11,500.0 11,562.0 06:30 12:45 jars 15 times.Gripper blocks beginning to slip at up-weights of >8OKlbs. Pump off of GS and clean CT and gripper blocks. Latch back into GS and hit jars 3 more times.Gripper blocks slipping at up-weights of >75Klbs. 9/9/2016 9/9/2016 2.00 COMPZN RPCOMP RGRP T Pump off of GS and change out 11,562.0 11,562.0 12:45 14:45 gripper blocks. 9/9/2016 9/9/2016 1.00 COMPZN RPCOMP FISH P RBIH and latch into GS profile. 11,562.0 11,562.0 14:45 15:45 Straight pull to 90KIbs.Slack off,PU and fire jars 5 more times.Observed chain stalling on reel side. 9/9/2016 9/9/2016 2.25 COMPZN RPCOMP RGRP T Trouble shoot injector chain slipping. 11,562.0 11,562.0 15:45 18:00 Mobilize Hydrarig Tech.Discuss plan forward with town. Page 7/13 Report Printed: 10/26/2016 • • 0 Operations Summary (with Timelog Depths) 1 2M-08 Phillips P,f:r:k.n Rig: NABORS CDR2-AC Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr)', Phase Op Code Activity Code Time P-T-X Operation (ftKS) End Depth(ftKE)', 9/9/2016 9/9/2016 4.00 COMPZN RPCOMP JAR P Pumped off of GS and PUH.Caliper 11,562.0 11,562.0 18:00 22:00 CT section of pipe that was working across the injector.Readings 1.97 OD -2.03 OD discuss with rig crew,RBIH engage fish,jar on fish,hit jars 30 times pulling to 85k-99k,pump off fish PUH 11,460',inspect coil,pictures on S:drive,inspect INJH,clean chains. 9/9/2016 9/10/2016 2.00 COMPZN RPCOMP WAIT P Discuss with town team plan forward, 11,562.0 11,562.0 22:00 00:00 decision was made to spot 150 bbl lube pill(776)Load addtional fluid from transport,mix pill Simops: Inspect INJH and clean chains. 9/10/2016 9/10/2016 1.00 COMPZN RPCOMP COND P Finish mixing lube pill. 11,562.0 11,562.0 00:00 01:00 9/10/2016 9/10/2016 2.00 COMPZN RPCOMP CIRC P Displace 150 bbl, 1%lube 776 11,562.0 11,562.0 01:00 03:00 9/10/2016 9/10/2016 3.00 COMPZN RPCOMP FISH P Continue jarring on fish at 75k-80k, 11,562.0 11,562.0 03:00 06:00 after every 10 hits pulling up to 85k. 9/10/2016 9/10/2016 3.50 COMPZN RPCOMP TRIP P No movement of fish. Pump off of GS 11,562.0 480.0 06:00 09:30 and PUH. Inspect CT that was working across the injector.Flow check was static.Continue POOH. 9/10/2016 9/10/2016 1.00 COMPZN RPCOMP OWFF P Flow check was static.Continue 480.0 0.0 09:30 10:30 POOH.At surface.Flow check,static. 9/10/2016 9/10/2016 3.00 COMPZN RPCOMP BHAH P LD fishing BHA. 0.0 0.0 10:30 13:30 9/10/2016 9/10/2016 2.00 COMPZN RPCOMP BHAH P Clean and clear rig floor.Offload 0.0 0.0 13:30 15:30 Baker fishing tools from rig.Remove Baker equipment from pipe shed. 9/10/2016 9/10/2016 2.50 COMPZN RPCOMP RURD P RD lubricator from annular.Install riser 0.0 0.0 15:30 18:00 in preparation for upcoming drill pipe operations. 9/10/2016 9/10/2016 3.50 COMPZN WHDBOP RURD P PJSM,valve check list,prep test 0.0 0.0 18:00 21:30 joints,grease choke and BOPE,fluid pack 9/10/2016 9/11/2016 2.50 COMPZN WHDBOP BOPE P Start BOP test 250/3500 psi,Witness 0.0 0.0 21:30 00:00 waived by Brian Bixby 9/10/16 @ 6:43am by email. 9/11/2016 9/11/2016 6.00 COMPZN WHDBOP BOPE P Continue BOP testing 250/3500 psi, 0.0 0.0 00:00 06:00 2500 psi annular,Witness waived by Brian Bixby 9/10/16 @ 6:43am by email. 9/11/2016 9/11/2016 2.00 COMPZN WHDBOP RURD P RD from BOPE testing.Break off TIW 0.0 0.0 06:00 08:00 valves from test joints.Clean and clear rig floor,mezzanine and pipe shed. 9/11/2016 9/11/2016 5.00 COMPZN RPCOMP RURD P Bring Baker fishing tools to the rig 0.0 08:00 13:00 floor.Spot Weatherford tongs on rig floor.Spot remaining DP handling equipment on the rig floor.RU rig tongs. Bring in drill pipe and drill collars to the pipe shed.Strap and tally. Page 8/13 Report Printed: 10/26/2016 • • Operations Summary (with Timelog Depths) .0 2M-08 ConocoP'hiigps Rig: NABORS CDR2-AC Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr)', Phase Op Code Activity Code. Time P-T-X Operation MKS) End Depth(ftK8)', 9/11/2016 9/11/2016 5.00'COMPZN RPCOMP BHAH P PJSM.MU fishing BHA on drill pipe 0.0 245.0 13:00 18:00 including 5-7/8"overshot,rattler, bumper sub,jar,DC X6,and intensifier. 9/11/2016 9/12/2016 6.00 COMPZN RPCOMP TRIP P Single in the hole with fishing BHA on 245.0 4,113.0 18:00 00:00 2-7/8"DP. 9/12/2016 9/12/2016 4.25 COMPZN RPCOMP PULD P Continue running DP 4,113.0 7,403.6 00:00 04:15 9/12/2016 9/12/2016 3.00 COMPZN RPCOMP OTHR P Install openTlW valve,load and strap 7,403.6 7,403.6 04:15 07:15 160 DP 9/12/2016 9/12/2016 4.50 COMPZN RPCOMP PULD P Continue singling in the Baker fishing 7,403.6 10,026.0 07:15 11:45 BHA on 2-7/8"drill pipe. 9/12/2016 9/12/2016 0.75 COMPZN RPCOMP EQRP T Repair hydraulic leak on Weatherford 10,026.0 10,026.0 11:45 12:30 tongs. 9/12/2016 9/12/2016 2.25 COMPZN RPCOMP PULD P Continue singling in the Baker fishing 10,026.0 10,939.0 12:30 14:45 BHA on 2-7/8"drill pipe. 9/12/2016 9/12/2016 0.25 COMPZN RPCOMP EQRP T Repair second hydraulic leak on 10,939.0 10,939.0 14:45 15:00 Weatherford tongs, 9/12/2016 9/12/2016 1.50 COMPZN RPCOMP PULD P Continue singling in the Baker fishing 10,939.0 11,473.0 15:00 16:30 BHA on 2-7/8"drill pipe. 9/12/2016 9/12/2016 2.50 COMPZN RPCOMP RURD P RD Weatherford tongs, RU rig tongs 11,473.0 11,473.0 16:30 19:00 and 3-1/2"DP handling equipment. 9/12/2016 9/12/2016 2.25 COMPZN RPCOMP PULD P Single in the hole with 3-1/2"DP. 11,473.0 11,540.0 19:00 21:15 PUW=100 Klbs.SOW=58 Klbs. 9/12/2016 9/12/2016 1.75 COMPZN RPCOMP JAR P Stabbed onto fish,straight pull to 195k 11,540.0 11,540.0 21:15 23:00 5 times.Jarred 15 times starting at 160K and working up to 185K pulled free.Work pipe up and down 4 times. 9/12/2016 9/13/2016 1.00 COMPZN RPCOMP CIRC P Line up to bullhead down the kill line 11,540.0 11,540.0 23:00 00:00 2.8 bbls,2000 psi,shutdown pump, make call to town,plan forward pull packer a few joints to see if we can release packer element and/or remove debris. 9/13/2016 9/13/2016 3.25 COMPZN RPCOMP PULD P Rattling packer up through 7"collars. 11,540.0 11,447.0 00:00 03:15 9/13/2016 9/13/2016 2.00 COMPZN RPCOMP RURD P PJSM,reconfigure TIW valves and 11,447.0 11,447.0 03:15 05:15 head pins. 9/13/2016 9/13/2016 1.50 COMPZN RPCOMP CIRC P Verify line up.Bull head 40 bbls 11,447.0 11,447.0 05:15 06:45 11.5ppg NaBr working up to1 bpm and 430 psi surface pressure under the VBR's. 9/13/2016 9/13/2016 0.75 COMPZN RPCOMP OWFF P Observe well for flow. Losses 11,447.0 11,447.0 06:45 07:30 observed at 18 bph. 9/13/2016 9/13/2016 10.50 COMPZN RPCOMP PULD P RU and begin singling 2-7/8"DP out of 11,447.0 7,982.0 07:30 18:00 the hole.PUW=100KIbs starting out of the hole.No drag seen pulling packer fish past 7"collars. 9/13/2016 9/13/2016 1.00 COMPZN RPCOMP SVRG P Service/Inspect top drive and crown. 7,982.0 7,982.0 18:00 19:00 9/13/2016 9/14/2016 5.00 COMPZN RPCOMP PULD P Continue singling DP out of the hole. 7,982.0 4,512.0 19:00 00:00 No drag seen,continue monitoring hole fill. 9/14/2016 9/14/2016 6.00 COMPZN RPCOMP PULD P Continue singling 2-78"DP out of the 4,512.0 400.0 00:00 06:00 hole.to joint 1. Losses steady at 10 bph. 9/14/2016 9/14/2016 0.50 COMPZN RPCOMP OWFF P Flow check at surface.No flow. 400.0 400.0 06:00 06:30 Losses steady at 10 bph. Page 9/13 Report Printed: 10/26/2016 Operations Summary (with Timelog Depths) 0 2M-08 Conoco,` fillips A3:xA: Rig: NABORS CDR2-AC Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(ftKB) 9/14/2016 9/14/2016 2.50 COMPZN RPCOMP BHAH P PJSM.LD Baker fishing BHA.Pull 400.0 0.0 06:30 09:00 overshot above the rig floor. Recovered bait sub and empty spear with grapples in the release position. No PBR or packer fish. 9/14/2016 9/14/2016 3.00 COMPZN RPCOMP RURD P Discuss plan forward with town. 0.0 0.0 09:00 12:00 SIMOPS:RD Weatherford tongs,air slips,elevators and clear their job box off of the rig floor. 9/14/2016 9/14/2016 1.00 COMPZN WHDBOP RURD P PU running tool, RIH and recover 0.0 0.0 12:00 13:00 wear bushing.Dress test plug with o- ring seals,RIH and set. 9/14/2016 9/14/2016 5.00 COMPZN WHDBOP BOPE P Line up valves,MU test joints,fill 0.0 13:00 18:00 stack.Greave valves.Re-test test plug,VBR's,and annular. 9/14/2016 9/14/2016 1.00 COMPZN WHDBOP RURD P LD BOP test equipment.Losses have 0.0 0.0 18:00 19:00 decreased to 4.5 bph. 9/14/2016 9/14/2016 3.00 COMPZN RPCOMP RURD P Rig up for coil operations,change riser 0.0 0.0 19:00 22:00 configuration. 9/14/2016 9/15/2016 2.00 COMPZN RPCOMP CTOP P Rehead coil,pull test external head to 0.0 0.0 22:00 00:00 40K,PT to 3,500 psi.PT QTS. Losses remain at 4.5 bph. 9/15/2016 9/15/2016 2.25 COMPZN RPCOMP PULD P PJSM. PU/MU BHA#6 packer fishing 0.0 192.0 00:00 02:15 assembly.Check pack-off.Losses remain at 4.5 bph. 9/15/2016 9/15/2016 3.50 COMPZN RPCOMP TRIP P RIH w/fishing assembly.Clean trip in 192.0 11,721.0 02:15 05:45 the hole.PUW=33 Klbs,SOW=13 Klbs. 9/15/2016 9/15/2016 0.25 COMPZN RPCOMP FISH P Tag up and enagage fish at 11721 ft. 11,721.0 11,721.0 05:45 06:00 Set down 10KIbs at the fish. No movement. 9/15/2016 9/15/2016 3.00 COMPZN RPCOMP PULL P PUH with fish.PUH dragging 45-53 11,721.0 11,400.0 06:00 09:00 Klbs. Stabilized at 46KIbs.Work fish up and down. Continued to POOH with fish. Saw heavy pulls at 11,470 ft, 11,430 ft,and 11,390 ft. Suspect 7" casing collars. Reciprocate fish working past collars. 9/15/2016 9/15/2016 4.00 COMPZN RPCOMP PULL P Continue pulling out of the hole.Had 11,400.0 9,500.0 09:00 13:00 to work through 7"collars up to 9500 ft. 9/15/2016 9/15/2016 10.00 COMPZN RPCOMP PULL P Continue pulling out of the hole.No 9,500.0 0.0 13:00 23:00 issues pulling through 7"collars. Increase pulling rate from 20 fpm to 30 fpm.Tag up at surface and perform a no flow check.Packer on surface,all slips accounted for.Left two rubber elements in the hole. 9/15/2016 9/15/2016 0.25 COMPZN RPCOMP SFTY P Safety meeting to MU and RIH with 0.0 0.0 23:00 23:15 cleanout BHA#7. 9/15/2016 9/16/2016 0.75 COMPZN RPCOMP PULD P MU 6.180"mill,3.13 Extreme motor, 0.0 0.0 23:15 00:00 jars and 2 jts Pac pipe. 9/16/2016 9/16/2016 4.50 COMPZN WELLPR TRIP P MU&RIH with 7"casing drift BHA#7. 0.0 11,892.0 00:00 04:30 Tagged up at 11,892'. Losing 10 BPH RIH with minimum pump rate.Tight spot at 11,660'while pulling up hole. 9/16/2016 9/16/2016 0.75 COMPZN WELLPR REAM P Polish packer setting depth from 11,850.0 11,525.0 04:30 05:15 11,525'to 11625'. Page 10/13 Report Printed: 10/26/2016 • • Operations Summary (with Timelog Depths) ►Ft • 2M-08 ConocoPhillips r Rig: NABORS CDR2-AC 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(ftK6)' 9/16/2016 9/16/2016 7.75 COMPZN WELLPR TRIP P RBIH and drift back down to 11,850 ft. 11,525.0 95.0 05:15 13:00 PUH,working through tight spot at 11,733 ft. Precautionary ream through the interval. Drift back down to 11,733 ft.PUH pumping minimum rate. 9/16/2016 9/16/2016 0.50 COMPZN WELLPR OWFF P Flow check at surface.Static losess 4 95.0 95.0 13:00 13:30 BPH. 9/16/2016 9/16/2016 2.00 COMPZN WELLPR BHAH P Lay down Baker cleanout BHA.Mill in 95.0 0.0 13:30 15:30 good shape.No excessive wear. 9/16/2016 9/16/2016 0.50 COMPZN WELLPR BHAH P Clean and clear rig floor. 0.0 0.0 15:30 16:00 9/16/2016 9/16/2016 3.50 COMPZN WELLPR CTOP P PJSM.Pump slack management.Cut 0.0 0.0 16:00 19:30 252'of coil. 9/16/2016 9/16/2016 2.65 COMPZN WELLPR CTOP P Rehead coil tubing,pull test to 35K 0.0 0.0 19:30 22:09 and pressure test to 4000psi.Pump slack forward. 9/16/2016 9/17/2016 1.85 COMPZN RPCOMP PUTB P PJSM and PU lower completion. 0.0 0.0 22:09 00:00 9/17/2016 9/17/2016 2.00 COMPZN RPCOMP PUTB P PU lower completion. 0.0 294.0 00:00 02:00 9/17/2016 9/17/2016 3.00 COMPZN RPCOMP RCST P RIH with lower completion.Pumping 294.0 11,700.0 02:00 05:00 minimum rate at 0.25 BPM losses are 20 BPH while RIH. 9/17/2016 9/17/2016 2.00 COMPZN RPCOMP DLOG P Log down with GR. Tie-in to K1 11,700.0 11,700.0 05:00 07:00 marker for a+44 ft correction.PU and re log K1 and confirm correction.PUH and log CCL down and confirmed CBUCCL is on depth with the PDC. 9/17/2016 9/17/2016 1.50 COMPZN RPCOMP CRIH P Position lower completion on depth 1 1,761.0 11,761.0 07:00 08:30 (Mule shoe at 11,761 ft),Line up and pump 20 bbl corrosion inhibited brine pill,levaing 5 bbls inside coil.Close EDC and bullhead 10bbls away to place CI pill across lower completion. 9/17/2016 9/17/2016 0.50 COMPZN RPCOMP PACK P Line up and pressure up down CT to 11,761.0 11,761.0 08:30 09:00 1,500 psi and set packer per Baker rep. 9/17/2016 9/17/2016 2.00 COMPZN RPCOMP PRTS T Line up on IA and pressure up to 3000 11,761.0 11,761.0 09:00 11:00 psi to test packer.At 3,000 psi, communication was observed between the CT and the IA. Attempt to pull and pump the seals out of the PBR.51 Klbs CTW and up to 1,600 psi. Verified communication between the CT and IA. Cycle EDC open and closed.Attempt to pressure up CT.Returns seen at surface. Straight pull with no pumps to 30KIbs over string weight(53Klbs CTW). seals sheared from PBR. 9/17/2016 9/17/2016 0.50 COMPZN RPCOMP PRTS P Line up and perform combo PT on the 11,761.0 11,500.0 11:00 11:30 packer and plug lower completion to 3,000psi for 10 minutes. 9/17/2016 9/17/2016 1.50 COMPZN RPCOMP CIRC P Pump 20 bbls viscosified pill followed 11,500.0 11,500.0 11:30 13:00 by seawater. 9/17/2016 9/17/2016 6.00 COMPZN RPCOMP TRIP P Chase viscosified pill to surface 11,500.0 72.0 13:00 19:00 Page 11/13 Report Printed: 10/26/2016 4 II 4 Operations Summary (with Timelog Depths) r" 2M-08 .Ccitrps Rig: NABORS CDR2-AC Job: RECOMPLETION Time Log Start Depth Start Time+ End Time Our(hr)', Phase Op Code Activity Code Time P-T-X Operation (5KB) ,End',Depth(ftKS)' 9/17/2016 9/17/2016 2.50 COMPZN RPCOMP BHAH P PJSM and LD lower completion 72.0 0.0 19:00 21:30 setting BHA. Inspect seal assembly. Checked good. 9/17/2016 9/18/2016 2.50 COMPZN RPCOMP BHAH P Clean and prep floor to run 3-1/2" 0.0 0.0 21:30 00:00 tubing.RU Weatherford. 9/18/2016 9/18/2016 6.00 COMPZN RPCOMP PUTB P MU and RIH with 3-1/2"upper 0.0 5,000.0 00:00 06:00 completion. 130 joints in the hole. Including seal assembly and 4 GLM's. 9/18/2016 9/18/2016 0.50 COMPZN RPCOMP SFTY P Crew change. PJSM for running 5,000.0 5,000.0 06:00 06:30 uppper completion. 9/18/2016 9/18/2016 4.00 COMPZN RPCOMP PUTB P Continue running upper completion 5,000.0 6,900.0 06:30 10:30 joints 131-218. 9/18/2016 9/18/2016 3.00 COMPZN RPCOMP PUTB P PU and stab Orbit valve.Position 6,900.0 6,900.0 10:30 13:30 control line spooler on the rig floor. Hang sheave and string control line. Set out cannon clamps.Head up control line and install in Orbit valve. PT each line for 10 minutes at 5,000psi.Function test Orbit valve. Good test. 9/18/2016 9/19/2016 10.50 COMPZN RPCOMP PUTB P PJSM,continue running in the hole 6,900.0 8,500.0 13:30 00:00 with upper completion joints 219-257. Install cannon clamps to secure control lines at every joint. Monitor control line pressure to verify integrity while RIH. 9/19/2016 9/19/2016 2.00 COMPZN RPCOMP HOSO P Continued running upper completion 11,500.0 11,500.0 00:00 02:00 and dual control lines.PUW=80KIbs. SOW=57KIbs. Landed upper completion on Baker locator sub.Marked tubing 28'up on jt 359. Laid down jts 358 and 359. Pulled Jt 357 and set aside.Made up 3 pups(6.17,6.16&10.24)and made them up to jt 356 still in the hole.Then MU jt 357. 9/19/2016 9/19/2016 2.75 COMPZN RPCOMP THGR P Installed the tubing hanger on top of 11,500.0 02:00 04:45 that.Teminated the Orbit valve control lines to the bottom of the tubing hanger. Install control lines to hanger body.Test same to 5000 psi. 9/19/2016 9/19/2016 3.00 COMPZN RPCOMP CRIH P Line up and circulate CI seawater 11,500.0 11,500.0 04:45 07:45 down the tubing and spot in the IA. 9/19/2016 9/19/2016 0.50 COMPZN RPCOMP THGR P Land hanger.RILDS.LDS even all 11,500.0 11,530.0 07:45 08:15 around. 9/19/2016 9/19/2016 2.00 COMPZN RPCOMP PRTS P Line up and PT tubing to 3,000psi. 11,530.0 11,530.0 08:15 10:15 Good test. Bleed tubing to 2,000 psi. Line up and test IA to 3,000 psi for 30 minutes.Good test. Dump tubing pressure.Good indication SOV sheared.Bleed pressure in tubing and IA to 0.Negative test on barriers. Good test.Test Orbit valve in the direction of flow.Good test. 9/19/2016 9/19/2016 3.00 DEMOB WHDBOP FRZP P RU Little Red.Pump 70bbls FP into 11,530.0 0.0 10:15 13:15 the IA. Page 12/13 Report Printed: 10/26/2016 • J Op0 erations Summary (with Timelog s Depths) 2M-08 CI I c+ ociiliips. Rig: NABORS CDR2-AC Job: RECOMPLETION Time Log Start Depth Start Time.. End Time our(hr) Phase Op Code Activity Code Time P-T-X : Operation (ftKE) End Depth(ftKB) 9/19/2016 9/19/2016 8.25 DEMOB WHDBOP OTHR P Rig down BOT and Weatherford. 0.0 0.0 13:15 21:30 Crane ops to clear rig floor of control line spooler,tongs and other RWO equipment.Clean rig floor.Take squeeze manifold apart and remove from cellar. 9/19/2016 9/20/2016 2.50 DEMOB WHDBOP NUND P ND BOBE and MU tubing head. 0.0 0.0 21:30 00:00 9/20/2016 9/20/2016 2.00 COMPZN WHDBOP PRTS P ND BOBE and MU tubing head and 0.0 0.0 00:00 02:00 PT to 250/5000 psi. 9/20/2016 9/20/2016 1.00 COMPZN WHDBOP NUND P NU BOPE. 0.0 0.0 02:00 03:00 9/20/2016 9/20/2016 1.25 COMPZN WHDBOP PRTS P Test Tree and pull test plug. 0.0 0.0 03:00 04:15 9/20/2016 9/20/2016 4.00 DEMOB MOVE NUND P Install orbit valve manifold and 0.0 0.0 04:15 08:15 pressue test. 9/20/2016 9/20/2016 9.75 DEMOB MOVE NUND P Install second swab valve.Change out 0.0 0.0 08:15 18:00 BOP rams.Finish NU BOPE.Check tree bolts.Rig release at 18:00. Page 13/13 Report Printed: 10/26/2016 KUP OFID • 2M-08 ConocoPhiDDips Z Well Attribu Max Angle&MD TD S Alaskd Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) CanocoDhigipp' 501032018400 KUPARUK RIVER UNIT PROD 68.17 7,756.40 12,151.0 .-- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2M-08,10/27/201610.35.52 AM SSSV:NONE 55 11/21/2015 Last WO: 9/20/2016 46.21 11/9/1992 Vertical echemaec(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ,� r Last Tag:SLM 11,842.0 3/2/3016 Rev Reason:SET HEX PLUG pproven 8/29/2016 Hanger:39.2 1 I Casing Strings i II. �I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 42.0 121.0 121.0 62.58 H-40 WELDED ,aaa Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE _ 95/8 8.921 41.8 4,252.8 2,743.9 47.00 L-80 AB-MOD Casing Description OD(in) ID lin) Top(ftKB( Set Depth(ftKB) Set Depth(ND)...Wt/Len(L..Grade Top Thread PRODUCTION 7 6.276 39.2 12,138.0 6,466.1 26.00 J-55 BTC .4,..ti CONDUCTOR;42.0-121.0- 's-Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(lb/ft) Grade Top Connection Upper Completion 3 1/2 2.995 39.2 11,530.2 6,009.6 9.30 L-80 EUE 8rd M Completion Details Mandrel;3,639.9 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top!net(*) Item Des Com (in) 39.2- 39.2- 0.24 Hanger 'FMC Gen IV Tbg Hanger(3-1/2"EUE BxP) 2.995 4,484.6' 2,843.4 64.58 Orbit Valve -Baker Orbit Valve w/2 Control Lines 2.880 11,507.5' 5,992.9 42.74 Locator Baker GBH-22 Locator Sub(bottom of locator spaced out 2.990 7') SURFACE,41.8-a,252.8 11,508.5 5,993.6 42.71 Seal Baker 80-40 20'Seal Assembly(21.5'OAL) 2.990 Assembly Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(IbM) Grade Top Connection Lower Completion set 41/2 3.958 11,516.2 11,761.0 6,183.0 12.60 H-40 STC Orbit vows;+484.6tIT'. on Coiled Tubing I Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Inel C) Item Des Com (in) 11,516.2 5,999.3 42.61 PBR Baker 80-40 PBR(40k shear release) 2.980 11,538.6 6,015.8 42.46 Packer Baker 7"x 3-1/2"FHL Ret.Packer(60k shear release) 2.940 Mandrel,6.334.8 ' 4. 11,592.1 6,055.6 41.26 Nipple 3.5"x 2.812"X Nipple 2.812 11,678.0 6,120.4 41.06 Wearsox 2 x 4-1/2"12.64 H-40 STC w Wearsox Stabilizers Pre- 3.958 Tailpipe Perfed Joints il 11 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Inel Mandrel,8,410.8 Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 11,745.0 6,171.0 41.17 WHIPSTOCK 3.5 X 4.5 Gen II Whipstock 9/23/2016 0.000 THRU TBG Perforations&Slots Mandrel;9,917.9 , Shot Dens Top(ND) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 11,721.0 11,750.0 6,152.9 6,174.8 A-5,A-4,2M- 12/26/1992 4.0 IPERF 180 deg.phasing;41/2" 08 Csg Gun Mandel.10.922.5 / 44 11.784.0 11,807.0 6,200.3 6,217.5 A-3,2M-08 4/6/2013 6.0 APERF 2.5"HSD Gun,60 degree phase Mandrel Inserts iiii St Mandel 11.4525 ati N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type _ Type (in) (psi) Run Date Com 1 3,639.9 2,490.6 Camco KBMG 1- DMY BK-5 9/19/2016 2 6,334.8 3,608.4 Camco KBMG 1 DMY BK-5 9/19/2016 Locator;11,507.5 3 8,410.8 4,445.2 Camco KBMG 1 DMY BK-5 9/19/2016 4 9,917.9 5,071.1 Camco KBMG 1 .. SOV BK-5 9/19/2016 Seal Assembly;11,508.5 ll 5 10,922.5 5,591.9 Camco KBMG 1- DMY BK-5 9/19/2016 PBR;11,518.2MP 6 11,452 5 5,953.2 Camco KBMG 1 DMY BK-5 9/19/2016 Packer;115399 Notes:General&Safety End Date Annotation 11/11/2010 NOTE:View Schematic w/Alaska Schematic9.0 • • Nipple.17592.1 X. e. Ir 11 ilk Wearsox Tailpipe;11,678.0 I IPERF;11,721 0-11,750.0-� 11 (' WHIPSTOCK-THRU TBG, 11,745.0 PERF;11,794.0-11,907.0 1 La • PRODUCTION;39.2-12,138.0 • i6. CTD L1-01 Liner;11,745.7- 14,499.0 CTD L1 Liner,11,984.9-15,650.0 ° • • Carlisle, Samantha J (DOA) 1 101 0 From: Loepp, Victoria T(DOA) Sent: Thursday, October 27, 2016 9:15 AM To: Carlisle, Samantha J (DOA) Subject: FW: Sundries and PTD's for withdrawal Please handle these withdrawals- Thanx, Victoria From: Haggerty-Sherrod, Ann (Northland Staffing Services) [mailto:Ann.Haggerty- ..,.._. Sherrod@contractor.conocophillips.com] Sent:Wednesday, October 26, 2016 3:24 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc: Kanady, Randall B<Randall.B.Kanady@conocophillips.com> Subject: Sundries and PTD's for withdrawal NAMED FEB 2 12017 Hi Victoria, This email is to follow up our verbal conversation about 2M-08. We would like to withdraw: 2M-08, 10-403 "Plug for Re-drill" approved Sundry#316-116 We would als. e to withdraw each of the followin: ' D's 2M-08A approved PTD# .-032 2M-08AL1 approved P 2 #216-033 ak%AV' ' 2 M-08AL1-01 : ••rov;• PTD#216-034 31A\\ 9 2M-08AL2 a.• . .-d PTD#216-035 We are withdrawing these app'cations due • a change in our scope of work described below which was submitted with our new PTD applicationsrM-08L1 and 2M-08L1-01. The t.ope of work and window exit type for KRU 2M-06 e been modified from a cement pilot-hole casing .,e a to a big tail-pipe casing exit. For this reason, please cane e previously issued sundry(316-116)and permits to drill 216-032, 216433,216-O34, and 216-035 for 2M-0; Thanks so much for your help in pointing me in the right directions with getting this ,-II completed with all the necessary forms. Let me know if there is something else needed. Thanks, Ann 1 RBDMSrnit -/ c€Jim pro rg2- -I , / Loepp, Victoria T (DOA) From: Kane, Danny <Danny.Kane@conocophillips.com> Sent: Sunday, September 18, 2016 8:45 AM To: Regg,James B (DOA) Cc: Nabors CDR2 Company Man;Starck, Kai; Rauchenstein, Rock 0; Schwartz, Guy L(DOA); Loepp,Victoria T(DOA) Subject: RE:CPAI KRU 2M-08 - PTD#192-101 - Nabors CDR-2 AC Waiver Request of BOPE One- Week Test Cycle Follow Up Flag: Follow up Flag Status: Flagged Jim, Here's an update on the KRU 2M-08 RWO being performed on Nabors CDR-2 AC with regards to the BOPE test waiver. We started running the Upper Completion at midnight(last night) &have run 5,400'of our 11,500' MD Upper Completion as of 08:30 this morning. I estimate that we will be landing the tubing hanger between 20:00 to 22:00 hrs tonight and therefore, Nabors CDR-2 AC is acting in compliance with the waiver granted. As stipulated below, if we are forced to TON with the Upper Completion,we will notify the AOGCC in preparation for a full BOPE test. Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1509 �ANNE� 2G�� Office: +1907 265-6048 Mobile:+1907 227-6037 danny.kane@conocophillips.com From: Kane, Danny Sent: Friday,September 16, 2016 3:31 PM To:'Regg,James B(DOA)'<jim.regg@alaska.gov> Cc:Nabors CDR2 Company Man<NaborsCDR2CompanyMan@conocophillips.com>;Starck, Kai <Kai.Starck@conocophillips.com>; Rauchenstein, Rock D<Rock.D.Rauchenstein@conocophillips.com>;Schwartz,Guy L (DOA)<guy.schwartz@alaska.gov>; Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject: RE:CPAI KRU 2M-08-PTD#192-101-Nabors CDR-2 AC Waiver Request of BOPE One-Week Test Cycle Jim, Thank you for your approval of this one-time requirement waiver. If we have to add any work outside of the scope below OR we have to trip out with the Upper Completion after starting to run in hole with it,we will notify the AOGCC (field inspectors&yourself) immediately that we will be performing a BOPE test. Regards, 1 • - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1509 Office: +1907 265-6048 Mobile:+1907 227-6037 danny.kane@conocophillips.com From: Regg,James B(DOA) [mailto:iim.regg@alaska.gov] Sent: Friday,September 16, 2016 3:08 PM To:Kane, Danny<Danny.Kane@conocophillips.com> Cc: Nabors CDR2 Company Man<NaborsCDR2CompanyMan@conocophillips.com>;Starck, Kai <Kai.Starck@conocophillips.com>; Rauchenstein, Rock D<Rock.D.Rauchenstein@conocophillips.com>;Schwartz,Guy L (DOA)<guy.schwartz@alaska.gov>; Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject: [EXTERNAL]RE:CPAI KRU 2M-08-PTD#192-101-Nabors CDR-2 AC Waiver Request of BOPE One-Week Test Cycle If I understand the remaining work scope,this request is to waive the requirement to test BOPE (due 9/18). That is approved conditioned on not tripping the upper completion back to surface once started in the hole. If the tubing hanger cannot be landed (requiring upper completion trip back to surface), a full BOPE test will be required before it is rerun. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 oriim.reggc alaska.gov. From: Kane, Danny [mailto:Danny.Kane@conocophillips.com] Sent: Friday, September 16, 2016 1:16 PM To: Regg,James B (DOA) Cc: Nabors CDR2 Company Man; Starck, Kai; Rauchenstein, Rock D; Schwartz, Guy L(DOA) Subject: CPAI KRU 2M-08 - PTD #192-101 - Nabors CDR-2 AC Waiver Request of BOPE One-Week Test Cycle Importance: High Mr.Jim Regg, ConocoPhillips would like to request a one-time waiver from the one-week BOPE test cycle for Nabors CDR-2 AC while performing RWO operations. As it stands now,the rig will need to re-test the BOPE on Sunday(September 181 to remain in compliance with AOGCC regulations. Currently the Nabors CDR-2 AC is finishing up a RWO of KRU 2M-08 and has almost completed the TOH with a clean-out assembly on coiled tubing. With the remaining work-scope, I expect that the rig will land the tubing hanger within 48- 2 • 60hrs assuming no significant trouble time(landing the tubing hanger Sunday afternoon-Sunday night). For reference, the remaining work-scope is as follows: • Finish TOH with coiled tubing clean-out assembly. L/D same. • Re-head coiled tubing for CoilTrak(E-coil)operations. • M/U lower completion w/production packer&tubing tail plug,TIH on coiled tubing, log on depth,&set production packer. Pressure-test from above&displace well to seawater to get negative test on the production packer/plug. TOH coiled tubing running assembly, L/D same,& R/D coiled tubing equipment. • R/U to run Upper Completion. TIH w/3-1/2" upper completion,space-out,displace well to corrosion-inhibited seawater,&land tubing hanger. Pressure-test&once complete, ND BOPE, NU tree. I estimate that we'll land the tubing hanger in^'48 hrs and if include some trouble time for this rig being new to RWOs (12hours),it may take up to 60 hours to land the tubing hanger, before midnight on Sunday(when BOPE test is due). However, if encounter any unforeseen trouble(other than 'typical'trouble time),we may exceed the one-week BOPE test cycle for RWOs on Nabors CDR-2 AC. Given the above circumstances,ConocoPhillips would like to request a one-time waiver from the one-week RWO BOPE test cycle on Nabors CDR-2 AC just in case we run into unanticipated trouble time. With the weekend coming up, I wanted to be proactive&have this discussion now instead of last minute if the extension were needed at that time. Please contact me if you have any questions or would like to discuss this further. FYI, Nabors CDR-2 AC did send in a 24- hour BOPE test notification earlier today in anticipation of doing a BOPE test before we start running the Upper Completion(BOPE test to start tomorrow afternoon). Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1509 Office: +1907 265-6048 Mobile:+1907 227-6037 danny.kanec conocophillips.com 3 _ • • O (9 v ► ,n ~ T ca- in: tNi X co - cJ & _cc' 'a h ci, Y / . 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N N N N N N N N N N N N d a Z OA O 0) 0) 0) O O 0) 0) O8) a) N O N N N N N N N N N N 3 ON- O O O O 0 0 0 0 00 0 41 `" 6 0 0 0 0 0 0 0 0 0 0 O a V Y oD In U) U) U) In U) 1[) U) N U) U) 11) U aa µY�uJ Ln C y CD F- E C C C-▪ W u o � t6 lL ac+ C 2.1 MI - d Q Q' IA CO O 0) V O0 O N co F- O Ir Co E `, tl Z Z., p O O O O Z to Co II 17 N m m LL LL m W y1 H y C = p, a 4 N J, m N N N M M N M M • C 4'' f0 v) O y�. , C C 61 f0 OV of ,-I ' j a` a Pm E Tzw►o Regg, James B (DOA) From: Nabors CDR2 Company Man <NaborsCDR2CompanyMan@conocophillips.com> Sent: Tuesday, September 13, 2016 3:24 PM To: DOA AOGCC Prudhoe Bay 12efC� (1151/0 Cc: Kane, Danny; Starck, Kai; Rauchenstein, Rock D t Subject: KRU 2M-08 Notification of Planned BOPE Usage on Nabors CDR-2 AC. As per AOGCC Industry Guidance Bulletin No. 10-003, this is notification of BOPE usage on Nabors CDR2. While the BOPE was not used to prevent the flow of fluids from the well (instead to divert pumped fluids downhole), this report is being submitted to let the state know that BOPE was used during the course of the KRU 2M-08 RWO. Time of BOPE Use: 9/12/2016 at 23:00 hours Well Location: KRU 2M-08 sCANNED N 2 7E0T!, API Number: 50-103-20184-00 ' Rig Name: Nabors CDR2 PTD Number: 192-101 " Operator Contact: Danny Kane: (o) 907-265-6048, (c) 907-227-6037, or Danny.Kane@conocophillips.com Operations Summary: On 12-Sep-2016, Nabors CDR2 latched on to &jarred free a retrievable production packer with a tubing tail plug beneath it. As a precaution,the annular was closed, there was no pressure observed, and an attempt was made to bullhead the casing volume beneath the packer into the perforations in case there was any packer gas trapped beneath the packer. Because of debris above and/or the packer elements not relaxing,the casing pressured-up and no fluid was being pushed past the packer. The rig then bled off the pressure under the annular, observed it was at 0 psig, &then tripped out three joints of drill pipe to open up flow-by area past the packer. With a reduction in drag,the 2-%" x 3-W'VBRs were closed and the rig successfully bullhead the casing volume beneath the packer into the perforations. The well was flow-checked (static), and shortly thereafter started losing fluid downhole (18 bph). BOPE Used: Annular and 2-%" x 3-Y2"Variable-Bore Pipe Rams Clave tAL e Reason for BOPE Use: Planned bullheading of fluid beneath packer into the perforations. Actions to Be Taken: Once the trip-out with the packer&tubing tail pipe fish is completed, the annular&the 2-%" x 3-%2 VBRs will be retested. Post testing, the rig will return to the original scope of the workover. Thank you, -Mike Winfree Mike Winfree/ Rory Ober Scott Kiser/Mike Freeborn CDR2 Company Man (907)659-3990 1 • • Kr,ik apt_ce liz (Oto Regg, James B (DOA) From: Nabors CDR2 Tool Pusher <d14t1@conocophillips.com> G )�� Sent: Wednesday, September 14, 2016 10:38 PM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Subject: CDR2 Retest of valves after bullhead Attachments: BOP Test chart.pdf ,— From: Nabors CDR2 Tool Pusher [mailto:dl4tl@conocophillips.com] Sent: Wednesday, September 14, 2016 7:28 PM To: Nabors CDR2 Tool Pusher<d14t1@conocophillips.com> Subject: ` . ' ' • • x •oe 0..Ile:.°10•i•No to 0•.....°010.6" ..7.......willo=m7•,no.....in,4 Wan:gara P 4 tra'111%,. i)65 5 0...WAS&V..-..r'''ma'''''.....°.ft..,,"'a•..4.... .' '!"' 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' / has CDez - QasS ) 2-L( Z.M-c6 ware = T-1-67,s i__ &E use_d. 9( VI'(049 /-770 /92 —/o / • • Loepp, Victoria T (DOA) From: Schwartz,Guy L(DOA) Sent: Monday,August 22, 2016 8:19 AM To: Loepp,Victoria T(DOA) Subject: FW:CPAI KRU 2M-08 - RWO Draft Procedure to be Performed by Nabors CDR2-AC (PTD 192-101) Attachments: KRU 2M-08 - 2016 RWO ATT#06 -Current Well Status.pdf; KRU 2M-08 -2016 RWO ATT#07- Proposed RWO Schematic.pdf; KRU 2M-08- P&R Tubing IC PO Change RWO Procedure v3.1 - DRAFT 20160818.pdf Follow Up Flag: Follow up Flag Status: Flagged Guy Schwartz sotit4E0 FEB 1 HIT Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Kane, Danny[mailto:Danny.Kaneconocophillips.com] Sent: Thursday,August 18, 2016 4:28 PM To: Regg,James B(DOA); Schwartz, Guy L(DOA) Cc: Starck, Kai; Eller,J Gary; Ohlinger,James J; Burke,Jason; Buck, Brian R Subject: CPAI KRU 2M-08 - RWO Draft Procedure to be Performed by Nabors CDR2-AC(PTD 192-101) Jim &Guy, Please see the attached Draft Procedure for the KRU 2M-08 RWO planned to be performed by Nabors CDR2-AC shortly. While this well does not require a sundry for the proposed scope of work, I understand that we are sharing a copy of the procedure so that you may better see what our expectations are for performing this RWO using Nabors CDR2-AC. The attached procedure is a draft copy as I am ironing out some minor details but it is wholly representative of what we expect Nabors CDR2-AC to do. Please feel free to contact me if you have any questions regarding the procedure. Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1509 Office: +1907 265-6048 1 • ConocoPhillips philli Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 July 26, 2016 1:::() 0 Commissioner-State of Alaska •Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill a dual-lateral out of the KRU 2M-08 (PTD 192-101) using the coiled tubing drilling rig, Nabors CDR2-AC or Nabors CDR3-AC. The scope of work and window exit type for KRU 2M-08 have been modified from a cement pilot-hole casing exit to a big tail-pipe casing exit. For this reason, please cancel the previously issued sundry(316-116)and permits to drill 216-032, 216-033, 216-034, and 216 -035 for 2M-08. / To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. The work is scheduled to begin September 11, 2016. The objective will be to drill laterals KRU 2M-08L1 and 2M- 08L1-01 targeting the Kuparuk A-sands. Attached to this application are the following documents: 10-401 Applications for 2M-08L1 and 2M-08L1-01 SCANNED �� L0'1 ) - Detailed Summary of Operations - Directional Plans for 2M-08L1 and 2M-08L1-01 - Proposed CTD Schematic If you have any questions or require additional information, please contact me at 907-263-4112. Sincerely, i Jeff onnely ConocoPhillips Alaska Coiled Tubing Drilling Engineer RBDMS LL AUG Z 5 2016 • JUN 08 'aka 2-.12:1 5 AOGGC WELL LOG TRANSMITTAL# To: Alaska Oil and Gas Conservation Comm. June 3, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 tn(.K/BEND R RE: Leak Detect Log with ACX: 2M-08 Run Date: 4/27/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2M-08 Digital Data in LAS format, Digital Log file, Interpretation Report 1 CD Rom 50-103-20184-00 Leak Detect Log with ACX (Processed Log) 1 Color Log 50-103-20184-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton ��� 1 ,H € tl� ' Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: 7)jvai-44-oze.<... ..eitzat Gcr2-to ‘ VIcs MAY 17 2U1'6 WELL LOG TRANSMITTAL#903188904 BOO ( To: Alaska Oil and Gas Conservation Comm. May 13, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchora g e, Alaska 99501 5 M. K.BENDER R RE: Leak Detect Log: 2M-08 Run Date: 4/24/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2M-08 Digital Data in LAS format, Digital Log file, Interpretation Report 1 CD Rom 50-103-20184 Leak Detect Log (Processed Log) 1 Color Log 50-103-20184 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: " Halliburton Wireline & Perforating Attn: Chris Gullett ShWED 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: / ,,aLa'ytcv - / ..eAea'`''"C MAY 06 20Ito WELL LOG TRANSMITTAL#903188904 AOGCC To: Alaska Oil and Gas Conservation Comm. April 28, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 nn5`BENDER SCOW RE: Multi Finger Caliper: 2M-08 Run Date: 3/13/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2M-08 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20184-00 Multi Finger Caliper(Field Log) 1 color log 50-103-20184-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: / w • • PTD l9 2- —1 1 Loepp, Victoria T (DOA) From: Phillips, Ron L <Ron.L.Phillips@conocophillips.com> Sent: Wednesday, February 17, 2016 8:44 AM To: Loepp,Victoria T (DOA) Subject: RE: KRU 2M-08(PTD 192-101, Sundry 316-116) Plug for Redrill - BOP test pressure Follow Up Flag: Follow up Flag Status: Flagged Victoria, On 2M-08 we plan to pressure test the pipe rams,blind rams and the CT pack off to 250 psi and 4500 psi. In the past I have not put this on the Sundry Application, but I have submitted the Sundry and PTD at the same time. Thanks, Ron L. Phillips Senior CTD Engineer ConocoPhillips Alaska Stale APR 2 1 2016 Phone 265-6312 Cell 317-5092 From: Loepp, Victoria T(DOA) [mailto:victoria.loepp(aalaska.gov] Sent: Friday, February 12, 2016 9:15 AM To: Phillips, Ron L Subject: [EXTERNAL]KRU 2M-08(PTD 192-101, Sundry 316-116) Plug for Redrill - BOP test pressure Ron, What will you be testing the BOPs to? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepq@alaska.gov 1 • • • A Z--‘o1 VOF7.4 40\��\�1/7- ,t THE STATE Alaska Oil and Gas Al.) ►,;"1�� Of A T A 1 Conservation Commission _,.,,,,,_____ __=___:. ..,_______„.:-....r ff itt a--�_ 333 West Seventh Avenue "" ." r GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 SFA SSP Fax: 907.276.7542 www.aogcc.alaska.gov Ron Phillips CTD Engineer , - I ?J ConocoPhillips Alaska, Inc. ' P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field,Kuparuk River Oil Pool, KRU 2M-08 Permit to Drill Number: 192-101 Sundry Number: 316-116 Dear Mr. Phillips: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy .Foerster IC Chair DATED this hod day of February,2016. RBDMS LL Fcd 1 6 2016 • STATE OF ALASKA • RECEIVED ALASKA OIL AND GAS MMI I CONSERVATION N FEB 10 2016 COMMISSION O APPLICATION FOR SUNDRY APPROVALS ���/6/A 20 PAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations 2, Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑., . Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska Inc • Exploratory ❑ Development Q• 192-101 • 3.Address: 6.API Number. Stratigraphic ❑ Service ❑ PO Box 100360,Anchorage AK 99510 50-103-20184-00 . 7. If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? NIA Will planned perforations require a spacing exception? Yes El No 2/ KRU 2M 08 9.Property Designation(Lease Number): 10.Field/Pool(s): • ADL 25589, ALK 2675 Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): ✓' Plugs(MD): Junk(MD): 12151' 6476' 12046' 6397' 4041 None None Casing Length Size MD TVD Burst Collapse Conductor 79' 16" 121' 121' 1640 670 Surface 4211' 9-5/8" 4253' 2744' 6870 4760 Production 12099' 7" 12138' 6466' 4980 4320 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11721'-11750' • 6153'-6175' 3-1/2" 9.3#,J-55 Tbg 11610'MD,6069'TVD 11784'-11807' - 6200'-6218' Packers and SSSV Type: Packer-Baker HB Retrievable Packer Packers and SSSV MD(ft)and TVD(ft): r 11582'MD and 6048'TVD SSSV-Camco TRDP-4A • 1807'MD and 1655'TVD 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Q' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 2/23/2016 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended LI 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown 0 Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Ron Phillips @ 265-6312 Email Ron.L.Phillipst conocophillips,com Printed Name Ron Philli s Title CTD Engineer 010 1 Signature 4 -6312 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. / 3 � — \ `Le LJ Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: 3P ft5-f h7 *SOUpa-J cl 14nv14e pr‘v«fr� f f -a oped-5 f� �o��� z�, JJZ ( L ) �l f-rvnaic p t p 6ac r app re; P Post Initial Injection MIT Req'd? Yes LI No Mr Z Spacing Exception Required? Yes ❑ No Subsequent Form Required: /0 4 c 7 RBDMS Lt—FEB 1 6 2016 /Q APPROVED BY Approved by: yy ,2 COMMISSIONER THE COMMISSION Date: 2-/6_/,� F/r� � ! TTT999'��'"'^�����, � A *?`•' tl' • l)IK. Submit nForm and Form 10-403 Rbvised 11/20 5Ov d I id for 12 months from the date of approval. iIA _I "Attachments in Duplicate V TL 27/6//.6 . -P.- .‘4-.' • • KRU 2M-08 CTD Summary for Plugging Sundry (10-403) Summary of Operations: Well 2M-08 is a Kuparuk A-sand producer equipped with 31/2" tubing and 7" production casing. The CTD sidetrack will utilize four laterals to target the A3 and A4 sands to the north and south of 2M-08. The laterals will recover resources in the 2K-27 and 2M-08 drainage area. Prior to CTD operations, the 3-1/2" tubing tail will be perforated and the D nipple at 11,598' MD will be milled out to a 2.80" ID. The existing A-sand perfs will be squeezed with cement to provide a means to kick out of the 7" casing. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the A-sand perfs in this manner. Following the cement squeeze Nabors CDR2-AC will drill a pilot hole to 11,770' MD and set a mechanical whipstock in the 2.80" pilot hole to kick off at 11,745' MD. All four laterals will be completed with 2-3/8" slotted liner from TD with the fourth lateral lin -re to,n In ted inside the 3- 1/2" tubing tail. Using the maximum formation pressure in the area of 4,658 psi in 2M-35, the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 4,041 psi. CTD Drill and Complete 2M-08 Lateral: March 2016 Pre-CTD Work 1. RU Slickline: dummy off gas lift mandrels and pressure test. 2. RU E-line: Shoot 2' of holes in the 31/2" tubing tail at 11,593' MD. 3. RU Pumping Unit: perform injectivity test down the tubing. 4. RU Service Coil: Mill out D nipple and cement squeeze the A sand perforations up to the perforations in the tubing tail. 5. RU Slickline: Tag top of cement and log. 6. Prep site for Nabors CDR2-AC and set BPV. Riq Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. -114�5 2. 2M-08A Sidetrack (A4 sand - South) a. Drill 2.80" high-side pilot hole through cement to 11,775' MD b. Caliper pilot hole c. Set top of whipstock at 11,745' MD d. Mill 2.80" window at 11,745' MD. e. Drill 3" bi-center lateral to TD of 16,000' MD. f. Run 2%" slotted liner with an aluminum billet from TD up to 12,100' MD. 3. 2M-08AL1 Lateral (A4 sand - North) a. Kick off of the aluminum billet at 12,100' MD. b. Drill 3" bi-center lateral to TD of 14,200' MD. c. Run 2%" slotted liner with an anchored billet from TD up to 12,400' MD. p ,TP 4. 2M-08AL1-01 Lateral (A3 sand - North) a. Kick off of the anchored billet at 12,400' MD. b. Drill 3" bi-center lateral tg TD of 14,450' MD. redr,•'// r0 CyOr'^r� I Coecvr, 2-4e eas °( ti el' p(Pf�'� , / //ow T 4 Aa/a/' '/ re le rk( serus ( iart� j'€ q /ecoe*3-. r , w0// �///Yo / Page 1 of 2 1e��'�� i�� �� �� 2/9/2016 • with aluminumbilletfr•TD 11 0' MD. c. Run 2/8 slotted linerwt an alums u o up to ,90 5. 2M-08AL2 Lateral (A3 sand - South) a. Kick off of the aluminum billet at 11,900' MD. b. Drill 3" bi-center lateral to TD of 14,150' MD. c. Run 2%" slotted liner with up deployment sleeve from TD to 11 600' MD. , 6. Freeze protect, set BPV, ND BOPE, and RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain SBHP 3. Install gas lift design 4. Return to production Page 2 of 2 2/9/2016 • 0 0 y 0 0 { CD Lo - C c)M Z (gƒ <'D/ 7 S,, & (\s ) g (%* )}\ \pm ® b )\/ \\) o— _ \RG ( \§f 43 ]/« / §a% / / \R/ 0 co 2 QD (_Sico 0 / ) - ) _ _ // 1 k \ \ k -o t6 C� 0 g , a £ - \ 7 \) % z ° § \ j k a� © I- ƒ] 0 0 k E / §_ @_ §/ f \\ \ j\ \\ \/ \ ` \ AB A A= 2) A A ( \ / ! 1 ƒ m , J/ 41 t \] . -- ._=-L\ . . R \ c= ::- / O r 0 . < 2 \ 7 !!!!!! CL ©T 1 \ 2 �� a \ o- ` 77 \k \c 9w / {/ /\ , 2 /@ �@ 4t N / - �� )\ §\§ Lo 0 c � ( \j \\ %,- 22 KUP PROD • 2M-08 Conoc PhiIIIps i Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act atm(ftKB) • map, 501032018400 KUPARUK RIVER UNIT PROD 68.17 7,756.40 12,151.0 ••• Comment 825(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2M-08,9/1920132:58:12 PM SSSV:TRDP 80 12/20/2012 Last WO: 46.21 11/9/1992 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 11,889.0 3/31/2013 Rev Reason'DRILLING DEPTHS/DATES osborl 9/19/2013 HANGER;39.2 TI 11 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread r- ` h CONDUCTOR 16 15.062 42.0 121.0 121.0 62.58 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread III SURFACE 9 5/8 8.921 41.8 4,252.8 2,743.9 47.00 L-80 AB-MOD Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread PRODUCTION 7, 6.276 39.2 12,138.0 6466.1 26.00 J-55 BTC Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING 3 1/2 2.992 39.2 11,610.5 6,069.4 9.30 J-55 ABM-EUE .nnf CONDUCTOR,42.o-1z1.o- Completion Details Nominal ID I Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 39.2 39.2 0.24 HANGER FMC GEN IV TUBING HANGER 3.500 SAFETY VLV;1,806.9 a 1,806.9 1,655.5 46.56 SAFETY VLV CAMCO TRDP-4A-R0 SAFETY VALVE 2.812 4 Ili 11,568.1 6,037.7 41.88 PBR BAKER PBR 3.000 11,581.9 6,047.9 41.50 PACKER BAKER HB RETRIEVABLE PACKER 2.870 11,598.0 6,060.1 41.14 NIPPLE CAMCO D NIPPLE 2.750 11,609.6 6,068.8 40.94 SOS BAKER SHEAR OUT SUB,TTL ELMD @ 11605'SWS 3.015 • PPROF 6/3/2007 Perforations&Slots Shot Den Top(ND) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 11,721.0 11,750.0 6,152.9 6,174.8 A-5,A-4,2M- 12/26/1992 4.0 IPERF 180 deg.phasing;41/2" SURFACE;41 8 ,252.0 & 08 Csg Gun 4 11,784.0 11,807.0 6,200.3 6,217.5 A-3,2M-08 4/6/2013 6.0 APERF 2.5"HSD Gun,60 _ degree phase GAS LIFT;4,384.9 Mandrel Details S[ atii O No Top(ND) Valve Latch Port size TRO Run mo Top(ftKB) (ftKB) Make Model OD(in) Sent Type Type (in) (psi) Run Date 1 4,384.9 2,800.6 CAMCO KBUG 1 GAS LIFT GLV BTM 0.188 1,344.0 8/11/2010 I 2 8,855.3 4,627,8 CAMCO KBUG 1 GAS LIFT GLV BTM 0.188 1,323.0 8/10/2010 3 11,039.0 5,669.0 CAMCO KBUG 1 GAS LIFT GLV INT 0.188 1,303.0 7/24/2013 4 11,520.6 6.002.5 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.250 0.0 7/24/2013 Notes:General&Safety GAS LIFT;8,855.3 -• End Date Annotation 11/11/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT;11,039.0 t-: GAS LIFT;11,520.6 8^ I 1 PBR;11,568.1 --- PACKER;11,581.9 m; ° •1Q 1 NIPPLE;11,598.0 g R I l T, I SOS;11,609.5 J IPERF;11,721.0-11,750.0 APERF;11,784.0-11,807.0 - PRODUCTION;39.2-12,138.0 A Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box Geologist in the upper left corner of Form 10-403 is checked. If the "Abandon" or 10) "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Geologist ;la. work) the initial reviewer will cross out that erroneous entry and initial then/ it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended"box and initial that change. Drilling Engineer „ / The drilling engineers will serve as quality control for steps 1 and 2. (QC) �" 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding"user query in RBDMS to ensure that all of the Plug for Redrill wells have been Geologist handled properly. At this same time, they will also review the list of suspended wells for accuracy. k°t7,-\ot r WELL LOG TRANSMITTAL DATA LOGGED 1n4/2015 M.K.BENDER To: Alaska Oil and Gas Conservation Comm. July 15, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 c„, AUG 1 z4;ii Resubmit E-Set#25960 �~ RE: Multi Finger Caliper(MFC) : 2M-08 Run Date: 2/19/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2M-08 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20184-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LEITER TO THE AF1'ENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: � , , ,/, • x.59 C 0 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 4, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100DATA LOGGED Anchorage, Alaska 99501 RECEIVED IVED K.BENDER JUN 18 20 RE: Multi Finger Caliper(MFC): 2M-08 Run Date: 2/19/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2M-08 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20184-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari cANNEE3 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed:c ✓ ____' _ XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: n Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: Other - Pages: DIGITAL DATA Diskettes, No. n Other, No/Type OVERSIZED · [3 ' Logs-of various kinds . Other COMMENTS: Scanned by: Oianna Vincent Nathan Lowell TO RE-SCAN Notes:- Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ Cc~nacoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Apri117, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 F, ~~~ ,~, , , i ,, ~~~ u ~~~~~ r~PR 2 7 2010 ,~aska 0~I t~ Gas Cons. ~ommissicr ~nchc~aq x,101 ~ a~.o~ Dear Mr. Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRLn. 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 January 16, March 21, 2010. The corrosion inhibitor/sealant was pumped Apri115, 16 and 17, 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field 4/77/2010 2B. 2E. 2G. 2H. 2K. 2M. 2V. 2W. 2X. 2Z ~ 3S PAD's Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 28-05 50029210670000 1840040 24" n/a 24" n/a 4.2 4/162010 2B-08 50029210790000 1840260 21" 3.30 7" 1/162010 2.5 4/162010 2B-16 50029211460000 1841140 92" 0.65 3/212010 2.5 4/162010 2E-10 50029212460000 1842300 SF n/a n/a Na 5.9 4/162010 2E-17 50029224190000 1931740 8'9" 1.50 19" 1/162010 3.4 4/162010 2G-13 50029211600000 1841290 SF n/a 22" n/a 3.4 4/162010 2H-07 50103200450000 1851700 SF n/a 17" n/a 2.1 4/152010 2H-09 50103200500000 1852590 SF Na 17" Na 2.5 4/152010 2H-15 50103200340000 1840860 SF n/a 17" n/a 2.5 4/152010 2H-16 50103200350000 1840870 SF n/a 17" Na 2.5 4/152010 2K 19 50103201180000 1891090 53" 0.50 9" 1/16/2010 2.1 .4/152010 2M-07 50103201780000 1920800 SF n/a 17" n/a 3.4 4/152010 2M-OS 50103201840000 1921010 SF Na 17" Na 2.1 4/152010 2M-20 50103201690000 1920480 SF n/a 17" Na 2.5 4/152010 2M-22 50103201700000 1920490 SF n/a 17" n/a 2.5 4/152010 2M-28 50103201740000 1920700 SF n/a 18" Na 2.1 4/152010 2V-06 50029210540000 1831790 SF n/a 19" Na 7.6 4/16/2010 2V 10 50029213100000 1850480 SF Na 19" Na 2.5 4/16/2010 2V-16 50029212960000 1850330 SF Na 21" Na 5.1 4/16/2010 2W-03 50029212740000 1850110 SF Na 3T' Na 4.2 4/16/2010 2X-11 50029211880000 1841640 SF Na 17" Na 6 4/17/2010 2Z-11 50029213790000 1851380 SF n/a 19" n/a 2.5 4/15/2010 2Z-12A 50029213800100 1951480 SF Na 19" n/a 2.5 4/15/2010 2Z-13A 50029213600100 2061700 SF Na 22" n/a 4.25 4/15/2010 2Z-19 50029218820000 1881300 SF n/a 16" n/a 2.1 4/15/2010 3S-09 50103204320000 2022050 SF Na 45" Na 23 4/17/2010 ~ / / p~~`_, 06/10/08 ~i7~i~u~~~i~ I~ NO. 4741 Schlumberger -DCS 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 ~~~tnN~~ ~UN ~. ~ 208 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 2W-13 11970689 GLS/PROD PROFILE - 05/27/08 1 1 3J-17 11970690 GLS/PROD PROFILE /~ - (~ 05/28/08 1 1 2M-08 11996642 PROD PROFILE/DEFT / C( 06/03/08 1 1 1 B-10 11994672 PROD PROFILE/DEFT G 05/31/08 1 1 1 A-20 11994673 PROD PROFILE/DEFT - / 06/01/08 1 1 iG-13 11994674 PROD PROFILE/DEFT 3.. ~~D~S/8 06/02/08 1 1 1A-03 11994673 PROD PROFILE/DEFT /~c.(~y 06/04/08 1 1 2W-17 11996644 PROD PROFILE/DEFT .( /~G( 06/05/08 1 1 iC-125 11994677 INJECTION PROFILE ~ cj!lLo~13(0 06/05/08 1 1 1C-127 11994675 INJECTION PROFILE _ G 6~~-/~~ 06/03/08 1 1 1F-09 11994671 PROD PROFILE/DEFT --/ /~~/~ 05/30/08 1 1 iC-27 11994679 SBHP SURVEY -t ®~C_/ 06/07/08 1 1 • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging_ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 114' FSL, 109' FWL, Sec. 27, T11N, R8E, UM At top of productive interval 3890' FNL, 4536' FWL, Sec. 4, T10N, R8E, UM At effective depth At total depth 4189' FNL, 4511' FWL, Sec. 4, T10N, R8E, UM 5. Type of Well: Development _X Explorato~__ Stratigraphic__ Service__ (asp's 487949, 5948986) (asp' s 487098, 5939704) (asp' s 487073, 5939404) 6. Datum elevation (DF or KB feet) RKB 147 feet 7. Unit or Property name Kuparuk Unit 8. Well number 2M-08 9. Permit number / approval number 192-101 10. APl number 50-103-20184 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical 12151 feet 6476 feet Effective depth: measured 11806 feet true vertical 6217 feet Plugs (measured) Casing Length CONDUCTOR 121' SURF CASING 4106' PROD CASING 11986' Junk (measured) Size Cemented 16" 250 Sx AS II 9-5/8" 660 Sx PFE & 760 Sx G 7" 198 Sx Class G Tagged Fill (5~30~00) @ 11806' MD. Measured Depth 121' 4253' 12133' True vertical Depth 121' 2744' 6462' Perforation depth: measured 11721 - 11750' true vertical 6153 - 6175' (size, grade, and measured depth) Packers & SSSV (type & measured depth) OIRI61NAL 3.5", 9.3#, L-80/J-55 Tubing @ 11610' MD. Baker 'HB' Retry. Packer @ 11582' MD. Camco 'TRDP-4A' Mod @ 1807' MD. RECEIVED It, l IR 7 2001 Alaska Oil & Gas Cons. Commission Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. OiI-Bbl Prior to well operation 595 Subsequent to operation 879 Representative Daily Averaqe Production orlnjection Data Gas-Md W~er-Bbl 251 350 385 417 Casing Pressure - Tubing Pressure 211 2O8 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations .._X 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~ ~/~ Title: Form 10-404 Rev 06/15/88 · Date ~/;~_. ~.~ / Prepared b~/John Peirce SUBMIT IN DUPLICATE 2M-08 DESCRIPTION OF WORK COMPLETED HYDRAULIC REFRACTURE TREATMENT 5~28/00: MIRU & PT equipment. Pumped a Hydraulic Re-Fracture Treatment using 12/18 mesh proppant, through the perforation interval at: 11721 - 11750' MD Pumped Breakdown stage: a) Pre-Pad stage @ 31 bpm, followed by b) Shutdown. ISIP @ 1580. Resumed pumping Scour stage: c) 150 bbls Gelled Pad, followed by d) 50 bbls of 50# Gelled Scour stage w/lppa proppant @ 25 bpm, followed by e) 160 bbls Flush, followed by f) Shutdown. ISIP @ 1785. Resumed pumping Data Frac stage: g) 200 bbls 50# Crosslinked Gel, followed by h) 20# Linear Gel Flush @ 25 bpm, followed by i) Shutdown. ISIP @ 1973. Resumed pumping Frac Treatment: j) 280 bbls Crosslinked Pad stage @ 25 bpm, followed by k) Crosslinked Slurry stages w/proppant ramped in stages from 1 to 12 ppa, followed by I) 55 bbls Flush, followed by m) Shutdown. Placed 144,000 lbs of proppant into the formation. RD. 5/29/00: RIH w/CT & jetted a proppant fill cleanout to 11900' MD. 5130/00: RIH & tagged fill at 11806' MD. Returned well to production w/gas lift & obtained a valid well test. THE MATERIAL -UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE NOVEMBER J 3, 2000 PL EW M A TERIA L U N D E THIS M A R K ER R C:LORI,MFiLM DOC GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 A'i-rN: Sherrie NO. 9463 Company: 5/12/95 Alaska Oil & Gas Cons Comm Attn- Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk ~D.s. 2.18" ~--c~ ~ CNT-D 042595 I I .... D.S. 3-19 ~'3--=]~... PERFRECORD 042095 I 1 D.S. 5-6 (31-6-10-15) ~5-~) PRODPROFI!.E 042095 I . 1 D.S. 6-04 ~ ~--~ DUAL BURST TDT-P 042095 I 1 ~.s. ~-~0 s~~ '~ ~.~.~ 0~~ ~ ~ D.S. 12-21 ~-~ PERFRE~RD . 042695 I I .. D,S. 12-34 ~ ~7 PERFRE~RD 042495 I 1 D.S. 16-1 ~- {.~ ~:~RFRE~RD 042395 I . 1 D.S. 17-15 ~=~ .~-/~:~~FRE~RD 042595 .... I 1 , , ,, ,,,, , ........ ,,, , , ~ ' .......... , . ............ , , , [ ........... I.. SIGNED' Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. I,/tAY 1 5 19.95.. ~as~ 0il & Gas C~s.comm~ss~on .Mc~o,~ Commission sssv GLM 11~7.,0 DV or GLV KUPARUK FLUID LEVEL REPORT CC: DS Engr. NSK Files OP Engrg. Files Prod. Foreman Fluid Level Shot Down: Casing V'iTubing CSG Press During Shot = # TBG Press During Shot= ./3~z"~ # Reason For Shooting FL: To Determine Operating Valve Well Status: On Continuous GL Operating CSG Press= ~ # GL Rate (If Available) MCFD On Intermittent GL Fluid Level On Time=~ Min. Off Time = Hr. Min. Delta Time From End Of On Cycle No GL Min. Found Comments: ?;50 ~AOGCC Individual Well Geological Materials Inventory PERMIT DATA T DATA_PLUS Page: 1 Date: 11/16/94 RUN DATE_RECVD 92-101 5895 T 10990-12050 CH/HLDT 1 92-101 5466 T 4155-1250 OH/CDR/HLDT 1-3 92-101 SURVEY R 0.00-12151 92-101 SURVEY R 0.00-12151 92-101 DAILY WELL OP R 10/31-12/27/92 92-101 407 R COMP DATE: 12/27/92 92-101 HLDT L 11000-12060 1 92-101 CET L 9000-12040 1 92-101 CET L 9000-12040 92-101 CDR-DC L 4253-12151 1-3 92-101 CDR L 4253-12151 COMP 92-101 CBT L 9000-12023 Are dry ditch samples required? ye~And received? Was the well cored? yes~nalz~is & description received? Well is in compliance Initial COMMENTS _ 11/22/93 12/07/92 01/22/93 12/07/92 01/22/93 01/22/93 11/20/93 11/20/93 11/20/93 05/14/93 11/16/92 12/07/90 ARCO Alaska, Inc. Post Office ,9(~;.~ ,,~0350 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 11, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 'Dear Mr. Johnston' Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION %,.--- ~.~3 2M-01Stimulate ~ 2M-05 Stimulate ¢7~- ~( 2M-08 Stimulate o/~-ffo 2M-12 Stimulate 9 z,.,qi 2M-27 Stimulate 9'z.--7¢ 2M-28 Stimulate ,~z-ioff 2M-32 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering ~ ..... Anch0rage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany !: i STATE Of ALASKA ~'"'h ALA§~' OIL AND GAS CONSERVATION COMMI~,,JN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed' Operation Shutdown Stimulate X Pull tubing Alter casing Repair well 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 114' FSL, 109' FWL, SEC 27, T11N, R8E, UM At top of productive interval 3890' FNL, 4536' FWL, SEC 4, T11N, R8E, UM At effective depth 4235' FNL, 4517' FWL, SEC 4, T11N, R8E, UM At total depth 4189' FNL, 4511' FWL, SEC 4, T11N, R8E, UM 5. Type of Well: Development Exploratory Stratigraphic Service Plugging Perforate _ Other -- 6. Datum elevation (DF or KB) 12. Present well condition summary Total Depth: measured true vertical 12151' 6476' feet feet X Plugs (measured) 147' RKB feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2M-08 9, Permit number/approval number ~,.~ --/~ 1 10. APl number 5o-1 03-201 84 11. Field/Pool Kuparuk River Oil Pool Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 1 2 0 4 6' true vertical 6397' Length Size 121' 16" 4253' 9 5/8" 12133' 7" measured 11 727' 11 756' true vertical 6166'- 6187' feet feet Junk (measured) Cemented 250 SX AS II 660 SX PR E & 760 SX CLASS G 198 SX CLASS G Tubing (size, grade, and measured depth) 3 1/2" 9.3# L-80 @4391' & 3 1/2" 9.3# J-55 @11610' Packers and SSSV (type and measured depth) Baker HB retrievable @ 11582', Camco TRDP-4A-RO SSSV @1807' 13. Stimulation or cement squeeze summary Intervals treated (measured) Measured depth 121' Refer to attached summary 4253" 12133' True vertical depth 121' 2744' 6462' R£CEIVF..D I $ 1994 Anchorage Treatment description including volumes used and final pressure 14. Pressure Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Prior to well operation Subsequent to operation (stabilized) 21 0 8 1 4 0 9 6 8 940 psi 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil X Gas Suspended 17, I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed "~~~, ~ Title Senior Engineer Form 10-404 Rev 06/15/88 Service 216 psi SUBMIT IN DUPLICATE June 24, 1993 2M-08 GSW DATAFRAC W/DS 140D. PUMP 2 SLK WTR PI/SI'S & GSW MINIFRAC @ 25 BPM. DATA AS FOLLOWS: STEP VOLUME FWHTP ISIP CLOS P FG PERF/XS FRIC PI/SI#1 150 4967 1540 3950 .68 1337 PI/SI#2 100 4514 1520 4000 .68 904 MINIFRAC 300 4761 1615 4060 .70 650 EFFICIENCY CALC. AT 55% BY C MATCH, 49% BY EFF. CURVE, 50 % BY G FUNCTION. SMART COMP INCORRECTLY READ DESIRED ADDITIVE RATES FOR L-10 QC BAR. PROBABLE CHANNEL REFERENCE PROBLEM, WILL CHECK. GSW FRAC W/DS 140D. PUMP 230 BBL PAD @ 25 BPM, LAST WHTP=4825 PSI. PUMPED 20.0 MLBS 16/20 CL IN 1, 2 & 4 PPA STAGE & 134.7 MLBS 12/18 CL IN 4-12 PPA STAGES. PUMPED TO FLUSH PER DESIGN. TOTAL SLURRY (WITH PAD) 1242 BBLS. PAD SLURRY RATIO 0.185. TOT PROP: DESIGN=160 MLBS, IN FORM=154.1 MLBS W/13.3 PPA @ PERFS. ESTIMATE 0.6 MLBS LEFT IN WELLBORE. TOT FLUIDS: WATER=1498 BBL, DSL(FLA)=55 BBL, ADD'S=131 BBL. (COOPER/CRABTREE/STOISITS) RECEIVED ~,,, Oii& Gas Cons. Commisstor; Anchora?, ARCO Alaska, Inc. qS--qk Date: November 19, 1993 Transmittal #: 8932 RETURN TO: .. ARCO Alaska, inC. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 ,.'..-' P.O. Box 100360:-: Anchorage, AK 99510-0360 Transmitted here.' with am the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~F~e-G°py~LCD R Data---''' 2M-12 cW LIS Tape and Listing: 11-09-93 93507 4~ 5~?.- HLDT Depth Shift-3 passes and Lat Avg. 5'~f-7cc~' 2M-32 cH LIS Tape and Listing: !1-11-93 93505 ~ ~ ~HLDT Depth Shift-5 passes and Lat Avg, 2M-04 cP~ LIS Tape and Listing: 11-12-93 93508 ~c(. HLDT Depth Shift-3 passes and Lat Avg. ~/2M-08 cR- LIS Tape and Listing: 11-12-93 93506 ~r-~c~c~ HLDT Depth Shift-3. passes and Lat Avg. ~2M-08 ~LIS Tape and Listing: 8-12-93 93301 DIT~DT/CNT~ LDWG Fo~at Receipt Acknowledged' ~_~ ~ z .. DISTRIBUTION: Bob Ocanas Date: ~. · *I//F/' Alaska'S,, ~,e~' cbe,,.. ft P, or~ \ ~:qq~- ~'b"/I,~' "~ol5~ ~5~1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown __ Stimulate __ Plugging __ Pull tubing x Alter casing __ Repair well __ Other Perforate 2. Name of Operator ARCO Alaska Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 114' FSL, 109' FWL, SEC 27, T11N, R8E, UM At top of productive interval 3890' FNL, 4536' FWL, SEC; 4 , T11N, R8E, UM At effective depth 4235" FNL, 4517' FWL, SEC 4, T11N, R8E, UM At total depth 4189' FNL, 4511' FWL, SEC; 4, T11N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 12151' 6476' feet feet 6. Datum elevation (DF or KB) RKB 147', PAD 106' 7. Unit or Property name Kuparuk River Unit 8. Well number 2M-08 9. Permit number/approval number 92-101 (Conserv Order NO. 261). 10. APl number 50-103-20184 11. Field/Pool Kuparuk River Oil Pool Plugs (measured) Effective depth: measured 1 2046' true vertical 6397' feet feet Junk (measured) Casing Length Size Structural 1 21 ' I 6" Conductor Surface 4253' 9-5/8" Intermediate Cemented 250 SX AS II 660 SX PF E . & 760 SX CLASS G, Measured depth 121' ' True vertical depth 121' ' 4253' 2744' Production 1 21 33' 7" 198 SX CLASS G 12133' 6462' 13. Liner Perforation depth: measured 11727'- 11756' M D true vertical 6166'-61 87',TVD Tubing (size, grade, and measured depth) 3-1/2" 9.3# L-80 @ 4391' & 3-1/2" 9.3# J-55 @ 11610' Packers and SSSV (type and measured depth) BAKER HB RETR PKR @ 11582', CAMCO TRDP-4A-RO SSSV @ 1807' MD Stimulation or cement squeeze summary Intervals treated (measured) RECEIV£D JUN 2 199 Alaska 0il & Gas Cons. c0mm~ss~O~ n .,~h~Paflq r~liVilV ~ Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Water Injector Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /~J/~~~ Form 10-404 Rev 05/17/89 Title Area Drilling Engineer D at e ~/~.//~ SUBMI'IfIN ~UPLICATE WELL: API: PERMIT: 2M-08 50-103-20184 Workover-Nordic 05/27/93 (16) TD:12151 PB:12046 05/28/93 (17) TD:12151 PB:12046 05/29/93 (18) TD:12151 PB:12046 05/30/93 (19) TD:12151 PB:12046 MONITOR WELL PRESS 7"@12132' MW: 8.5 FSW MOVE RIG F/2G-02 TO 2M-08. ACCEPT RIG @ 1900 HRS 05/26/93. LEVEL RIG. PULL BPV & VR PLUG. RU KILL LINES. FILL PITS W/SW. CONT FILLING PITS W/SW. TEST KILL LINES. SICP=300 PSI, SITP=850 PSI. RU ON ANN & PMP 100 BBLS OF SEA WATER TAKING RETURNS DOWN THE FLOW LINE(SHOULD BE 100 BBLS IN TBG). SWITCH RETURNS TO RIG PITS. DIVERT DIESEL/BRINE INTERFACE TO JUNK TANK. TAKE BRINE RETURNS TO PITS. BRINE WT ABOUT 10 PPG. CIRC SW AROUND. DIVERT DIESEL/BRINE INTERFACE RETURNS DOWN THE FLOW LINE. BULLHEAD 8 BBLS OF SW. SI WELL. REVERSE A TOTAL OF 460 BBLS OF SEA WATER. RECOVER 205 BBLS OF 10 PPG BRINE. MONITOR WELL PRESS TO DETERMINE KILL WT REQUIRED. SICP=800 PSI, SITP=800 PSI. POH W/3-1/2" TBG 7"@12132' MW:10.9 NaCl/Br MONITOR WELL PRESSURES. BLEED PRESS DOWN TO 350 PSI. SI FOR ONE HOUR. INCREASED TO 520 PSI ON ANN & 660 PSI ON TBG. START TRANSFERRING FLUIDS TO PITS FOR WT UP. WEIGHT UP BRINE TO 10.9 PPG. LOAD 3-1/2" DP IN THE PIPE SHED DURING WT UP. CIRC KILL WT BRINE DOWN TBG TAKING SW RETURNS DOWN THE FLOW LINE. CIRC @ 3 BPM @ 700 PSI. MONITOR WELL. NO FLOW. PUMP 25 BBLS OF DIESEL DOWN FLOW LINE & SHUT IN. SET BPV. ND TREE. NU 7-1/16" STACK & FLOW NIPPLE. TEST BOP. TEST CHOKE MANIFOLD, LOWER KELLY, & INSIDE BOP. PULL BLANKING PLUG. PULL BPV. BACK OUT LOCKDOWN SCREWS. MU LANDING JT. PULL HGR. CBU @ 4 BPM @ 700 PSI. LD HGR. POH & STAND BACK 3-1/2" TBG. DRIFT, STRAP, & CHANGE OUT SEAL RINGS. CBU 7"@12132' MW:10.9 NaCl/Br POH & STAND BACK 3-1/2" TBG. DRIFT, STRAP, & CHANGE OUT SEAL RINGS. (171 STDS). RD FLOOR EQUIP. STRAP JEWELRY & TBG. LD 25 JTS OF 3-1/2" TBG. SET WEAR BUSHING. STRAP CAMCO RETREIVING TOOL. MU TOOL & BHA. RIH. PU 3-1/2" DP & RIH. TAGGED PKR @ 11566'. PUW=174K. SOW=66K. PU & PULL 180K. SO & PKR WOULD NOT TAKE WT. WORK PKR. CIRC FOR 15 MIN. CONT TO WORK PKR. ROTATE 4 TURNS TO THE RIGHT. PU & PULL UP TO 240K. WORK & JAR ON PKR. WORKED FREE. CBU. POH 7"@12132' MW:10.9 NaC1/Br CBU @ 3 BPM @ 975 PSI. WT UP 100 BBLS OF BRINE TO 10.9 PPG. RU TO POH. POH W/3-1/2" DP & STAND BACK IN DERRICK. TGHT SPOT @ 2550' POH & LD ?KR & TAILPIPE ASSY. RESET WEAR BUSHING. MU & STRAP BHA FOR SCRAPER RUN. RIH W/BIT & SCRAPER. SLIP & CUT 50' OF DRLG LINE. RIH & TAG PBTD @ 12030' (12045' PARKER 245 RKB). CLEAN PIT #3. RU & FILTER BRINE & CIRC HOLE CLEAN. POH & LD 76 STDS OF DP IN PREP FOR MOVING. RECEIVED d U N 2 199) Alaska Oil & Gas Cons. Gommissior~ Anchorage WELL: API: PERMIT: 2M-08 50-103-20184 Workover-Nordic 05/31/93 (20) TD:12151 PB:12046 06/01/93 (21) TD:12151 PB:12046 06/02/93 (22) TD:12151 PB:12046 RIH W/SCRAPER 7"@12132' MW:10.9 NaCl/Br SERVICE RIG. FIN POH W/3-1/2" DP. PULL WEAR BUSHING. RU TO RERUN 3-1/2" TBG. MU TAILPIPE ASSY & BAKER PKR. RIH ON 3-1/2" J-55 9.3# TBG. SET DOWN ON SOLID OBSTRUCTION @ PKR DEPTH OF 3142'. CIRC W/CHARGE PMP. OBSTRUCTION CLEARED. RIH W/2-1/2 MORE STDS OF TBG & SET DOWN AGAIN. ABLE TO PU CLEAN, NO DRAG OR STICKNESS. POH W/3-1/2" TBG. CHANGE OUT SEAL RINGS & DRIFT. RD TBG RUNNING EQUIP. RU DP EQUIPMENT. RACK & TALLY 168 JTS OF DP. SET WEAR BUSHING. TALLY BHA. MU SCRAPER & TRI STATE MILL. RIH W/3-1/2" DP TO MAKE ANOTHER CLEAN OUT RUN. RUNNING 3-1/2" COMPLETION 7"@12132' MW:10.9 NaCl/Br SERVICE RIG. PU 3-1/2" DP & RIH. TAGGED BTM @ 12028'. RU & CIRC @ 4 BPM @ 1500 PSI. POH & LD 168 JTS OF DP. STAND REMAINDER BACK IN DERRICK. SLIP & CUT 50' OF DRLG LINE. POH W/BHA. PULL WEAR BUSHING. RU TO RUN 3-1/2" TBG. MU TAILPIPE ASSY & BAKER PKR. RIH ON 3-1/2" J-55, 9.3# TBG. MU CAMCO SSSV & CONTROL LINE. TEST CONTROL TO 5000 PSI. CONT RIH. TAGGED TIGHT SPOT @ STAND #158. PU & GO BACK DOWN WITHOUT ANY PROBLEM. 'CONT RIH. MU HGR. UP WT=88K, DOWN WT=40K. USED 33 SS BANDS ON THE CONTROL LINE. RIG RELEASED 7"@12132' MW:10.9 NaCl/Br LAND TBG, RILDS. BALL SEATED @ 0730 HRS. PRESS TBG TO 2500 PSI-SET PKR/10 MIN TEST. HOLD 2500 PSI TBG PRESS & PRESS ANN TO 1000 PSI FOR 10 MIN. BLEED OFF ANN. BOLDS. HOLD 2500 PSI ON TBG & PU l18M LBS TO SHEAR PBR. RELAND TBG. RILDS. PRESS ANN TO 1000 PSI, CLOSE SSSV. BLEED TBG PRESS 500 PSI. TEST SSSV 15 MIN. OPEN SSSV. PRESS ANN TO 2500 PSI & TEST CSG & TBG FOR 15 MIN. HOLD ANN PRESS @ 2500 PSI & PRESS TBG TO 3000 PSI-BALL SHEARED. LD LANDING JT, SET BPV. ND BOP'S. NU TREE. TEST PACKOFF & FLANGE TO 5000 PSI. TEST TREE TO 250/5000 PSI. DISPLACE WELL W/DIESEL. CIRC 12 BBLS INTO ANN, BULLHEAD 4 BBLS DOWN TBG @ 1 BPM, 850 PSI. RD LINES, SECURE WELL. SITP=0, SICP=0. RIG RELEASED @ 1200 HRS 06/01/93. SIGNATURE: su~~r£nten~ent ) DATE: RECEIVED d UN 2 3 1993 Alaska Oil & Gas Cons. oommissioo Anchorage ARCO Alaska, inc. Date: May 07, 1993 Transmittal #: 8732 RETURN TO: ARCO Alaska, Inc. Attn: Nikki Stiller Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. Please acknowledge receipt and return one signed copy of this transmittal. H-16 ~'~,~ H-lO H-19- H-17 ~@~ M-O 1 .7.~-.-ZU_--2 M- 12 ~/'~-~'5 PM-04 c~..e~ 2M-14 ~~M-08 c~_~,/'2_ U-02 '~'"~---'~. M-02 CDN-LWD/Depth CDR-LWD/Depth CDN-LWD/Depth CDR-LWD/Depth CDN-LWD/Depth CDR-LWD/Depth CDR-LWD/Depth CDR-LWD/Depth CDR-LWD/Depth CDR-LWD/Depth CDR-LWD/Depth CDN-LWD/Depth CDR-LWD/Depth Corrected 1/8-10/93 2671-7510 Corrected 1/8-10/93 2671-7510 Corrected 12/13-16/92 5364-8990 Corrected 12/13-16/92 5364-8990 Corrected 1/2-5/93 4981-8185 Corrected 1/2-5/93 4981-8185 Corrected 10/25-29/92 3347-9800 Corrected 9/6-8/92 2801-4766 Corrected 9/23-26/92 4260-12370 Corrected 7/14-17/92 3664-9811 Corrected 11/3-7/92 4253-12151 Corrected 8/31 to 9/3/923437-10003 Corrected 8/31 to 9/3/923437-10003 Receipt Acknowledged: DISTRIBUTION: D&M Drilling Alaska 011 & Gas Cor~. Anchorage ~mmiSslon .Vendo~a~age(John~on) NSK State of Alaska(+Sepia) Kathy Worley(Geology) ! ' STATE OF ALASKA ~ 0 ~ i ~ IN A [ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Glessil~ of Sewice Well OIL ~-~ GAS ~ SUSPENDED [-~ N~N~D ~--~ SERVICE r~ 2 Name of Operator 7 Permil Number ARCO Alaska, Inc 92-101 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20184 4 Location of well at surface ~ ~)CATIONS 9 Unit or Lease Name 114' FSL, 109' FWL, SEC 27, T11N, R8E, UM i DATE, 1[ ~I~IFIED KUPARUK RIVER 3890' FNL, 4536' FWL, SEC 4, T10N, R8E, UM~. ~VEf:iIFtl~ ii ~ 2M-08 4189' FNL, 4511' FWL, SEC 4, T10N, R8E, UM KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) J 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 147', PAD 106' GLI ADL 25589, ALK 2675 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, il offshore 116 No. of Completions 10/31/92. 11/06/92. 12/26/92.I NA feet MSLI 1 17TotalDOPth(MD+TVD) 18 Plug Back Depth (MD+TVD) 19 DirectionalSuwey 20 DeplhwhereSSSVsat 21 Thiclmees of permafrost MD, 6476' TVD 12046' MD, 6397' TVD YES I~1 NO I-'-I 1774' feet MD 1400' APPROX 12151' 22 Type Electric or Other Logs Run CDR,CDN, GR, CET,CBT, HLDT, GYRO 23 CASING, ENER AND CEMENTING RECORD I SE'rrlNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BoI-rOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 62.5# H-40 I SURF 121' 24' 250 SX AS II 16' 9-5/8' 47#/36~ L-80/J-55 SURF 4253' 12-1/4' 660 SX PF E, 760 SX CLASS G 7' 264f J-55 SURF 12133' 8-1/2' 198 SX CLASS G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE IDEPTH SET (MD) PACKER SET (MD) 3-1/2' 9.3~ J-55/L-80 116'16' · 11585' 11727' -11756' W/4-1/2" CSG GUN O 4 SPF MD 6166,.6187, 'rVD J 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST ,Date First Production IMathod of Operation (Flowing, gas lilt, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE J GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (con') Press. 24-HOUR RATE .I. -- /" C t 28 CORE DATA ~) ~ ~ ~,, t Brief description ol lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ~% ~ Form 10-407 Submit in duplicate Rev. 7-1-80 ~NUEDON REVERSESE)E GEQL~ IVlARKERS FORMATION 'JESTS NNVE Include intewal tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP 11696' 6134' NA KUPARUK C BOTTOM 11714' $148' KUPARUK A TOP 11714' !6148' KUPARUK A BOTTOM 11880' 6272' '.. 31. LIST OF ATTACHMEN~-,~5 GYRO, REPORT OF OPERATIONS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO ALASKA INC. DAILY OPERATIONS PAGE: I WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 2M-08 NORTH SLOPE 50-103-20184 ACCEPT: 10/31/92 03:30 SPUD: 10/31/92 08:30 RELEASE: 12/26/92 04:00 OPERATION: DRLGRIG: PARKER 245 WO/C RIG: NORDIC I 10/31/92 ( 1) TD: 121'( 121) 11/01/92 (2) TD: 2730'(2609) 11/02/92 (3) TD: 4270'(1540) 11/03/92 (4) TD: 4270'( 0) PREP TO PU BHA MN: 0.0 VIS: 0 MOVING RIG F/2M-01 TO 2M-08. RIG ACCEPTED @ 03:30 HRS 10/31/92. MIXING SPUD MUD. NIPPLE UP DIVERTER. FUNCTION TEST DIVERTERBAG & VALVES, FILL STACK & CHECK FOR LEAKS. STATE WITNESSING WAIVED BY JOHN SPAULDING, AOGCC INSPECTOR. DRILL & liND SURVEY 9-5/8"6 4252' MN: 9.7 VIS: 62 HOOK UP DIVERTER LINES. CIRC THROUGH MUD LINES TO CLEAR LCM F/PREVIOUS WELL. PU BHA, ORIENT TOOLS. TAG @ 112', CLEAN OUT TO 121'. DRILL & SURVEY W/MND & SPERRY SUN GYRO F/121'-287'. GYRO SURVEYS @ 197' & 287'. SERVICE RIG & TOP DRIVE. DRILL & SURVEY W/M~D & SPERRY SUN GYRO F/287'-2730'. GYRO SURVEYS @ 378', 472', 562', 925'. RIH W/9-5/8" CSG 9-5/8"6 4252' MN: 9.6 VIS: 54 DRIL & MND SURVEY F/2730'-3717'. SERV RIG & TOP DRIVE. DRILL & MWD SURVEY F/3717'-4270'. CIRC & COND MUD. PMP DRY JOB. WIPER TRIP TO HWDP. WORK THROUGH TIGHT SPOTS F/1675'-1595'. RIH, NO FILL. SLM. CIRC & COND FOR CASH. POOH. LD MOTOR & MWD. RU GBRCASING EQUIP. HELD PRE-JOB SAFETY MEETING. RUN 9-5/8" CASING TO 1684'. HIT BRIDGE. WORK THROUGH BRIDGE. RIH F/CSG TEST & LOT 9-5/8"6 4252' MN: 8.5 VIS: 30 MU CIRC SWEDGE. WASH THROUGH TIGHT SPOTS @ 1684', 1745', 1789'. CIRC HOLE CLEAN @ 1789'. WASH CSG THROUGH TIGHT SPOTS F/1846' T/1965'. RUN 9-5/8" CSG TO 4253'. MU HOWCO CEMENTING HEAD & CIRC CSG 700 BBL @ 10 BPM W/FULL RETURNS. CMT CSG W/SHOE @ 4253', FC @ 4168'.(660 SX PF E, 760 SX CLASS G) BMP PLUG W/2000 PSI FOR 30 MIN-OK. FLOATS HELD. 10.3 PPG CMT RETURNS IN CELLAR. LD LANDING JT, CMT HEAD, & CSG TOOLS. RU RIG TONGS. ND & WASH OUT STACK. TOP JOB: RUN IN 90' DN ANN W/l" LINE, FLUSH W/23 BBL WATER, & PMP 45 BBL PF "C" SLURRY. CLEAN CMT RETURNS TO SURF. INSTALL 11-3/4" X 11" 3 KSI CSG HEAD & 9-5/8" PACKOFF. NU 13-5/8" 5 SKI BOP STACK. CIRC CHOKE MANIFOLD LINES & OTHERS TO CHECK FOR FREEZING. TEST ALL BOPE. TEST ACCUM SYSTEM-ALL OK. INSTALL WEAR BUSHING. BLOW DN CHOKE MANIFOLD & MUD LINES. PU BHA. ASSEMBLE TURBINE, ORIENT TOOLS & PROGRAM LWD. TEST MWD @ FIRST STAND HWDP. RIH. WELL : 2M-08 OPERATION: RIG : PARKER 245 PAGE: 2 11/04/92 (5) TD: 5900'(1630) 11/05/92 (6) TD: 9820'(3920) DRLG 8.5" DIRECT HOLE 9-5/8"@ 4252' MW: 9.0 VIS: 32 SLIP & CUT 115' DRLG LINE. RESET & TEST DUO-O-MATIC. CONT RIH W/8.5" BHA. TAG CMT @ 4162'. CLEAN OUT CMT. DRILL CMT PLUGS & FLOAT COLLAR @ 4168'. CLEAN OUT CMT TO 4230' . PRESS UP CSG TO 2000 PSI. BLEED DOWN TO 500 PSI IN 3 MINS. CHECK SURF EQUIP-OK. PRESS UP TO 1500 PSI, PMPING AWAY. BLEED OFF. MIX & PMP SLUG. BLOWDOWN LINE. POH W/8.5" BHA. SERV RIG & TOP DRIVE. CONT POH. LD BHA. PU RTTS & BY-PASS. RIH TO 4225'. SET RTTS @ 4225'. CLOSE PIPE RAMS. PRESS TEST CSG TO 2000 PSI FOR 30 MINS. POH W/RTTS. LD SAME. PU 8.5" M-383K BIT. MU BHA. SURF TEST MWD & FORMATION RECORDING TOOL. RIH W/8.5" BHA. BREAK CIRC. CLEAN OUT CMT. DRILL FLOAT SHOE. CLEAN OUT RATHOLE & DRILL TO 4280'(10' NEW HOLE). CIRC BU. PERFORM FIT W/8.65 PG MUD. PRESS UP TO 560 PSI-NO LEAK OFF. EMW-12.5 PPG. DRILL & SURVEY 8.5" DIRECTIONAL HOLE F/4280'-5900'. DRILLING 8.5 DIRECT HOLE 9-5/8"@ 4252' MW: 9.1 VIS: 35 DRILL & SURVEY 8.5" DIRECTIONAL HOLE F/5900'-9820'. 11/06/92 (7) TD:11682' (1862) 11/07/92 (8) TD:12151' ( 469) 11/08/92 (9) TD:12151'( 0) DRILLING 8.5" DIRECT HOLE 7"@12132' MW:10.0 VIS: 38 DRILL & SURVEY 8.5" DIRECTIONAL HOLE FROM 9820'-10515' ORIENT/STEER TURBINE AS REQUIRED. SERVICE RIG & TOP D~IVE. DRILL & SURVEY 8.5" DIRECTIONAL HOLE FROM 10515'-11682'. ORIENT/STEER TURBINE AS REQUIRED. COND HOLE FOR 7" CSG 7"@12132' MW: 9.9 VIS: 42 DRIL, LOG & MWD SURVEY. POH, DOWNLOAD LWD INFO, BREAK OFF BIT. PMP THROUGH NEYRFOR TURBINE. LAY TURBINE DOWN. PU NAVI-DRIL, MU BIT, ORIENT TOOLS, RIH TO HWDP, TEST LWD & MWD. RIH TO 9-5/8" SHOE. CUT DRLG LINE 140', SET & TEST DUO-MATIC. RIH TO 11606'. WASH & REAM FROM 11606' TO 11709'(PACKING OFF AND BRIDGE @ 11660'). REAM SLOW FROM 11670' TO 11709' FOR LWD LOGS. DRILL, LOG, & SURVEY. CIRC BTMS UP @ 12151'. MAKE 10 STDS SHORT TRIP TO 11264', HOLE IN GOOD SHAPE. CIRC & COND HOLE FOR 7" CSG. CIRC PRIOR TO CTM 7" CSG 7"@12132' MW: 9.9 VIS: 43 FIN CIRC COND HOLE TO RUN 7" CSG. POH TO RUN 7" CSG. LD 100 JTS S-135 DP. CONT POH. LD 60 JTS G DP. DOWNLOAD MEMORY FROM LWD TOOL. LD MW]), LWD, NAVIDRILL & BIT. PULL WAR BUSHING. RU 7" CSG HANDLING EQUIP. HOLD SAFETY MEETING. RUN 7" CSG. WORK ON LAY DOWN MACHINE. CONT RUN 7" 26% CSG TO 9-5/8" SHOE. CBU @ 6 BPM. NO LOSSES. CONT RUN 7" 26% CSG. RU CIRC HEAD. WASH DOWN LAST SINGLE TO BTM. CIRC SLOWLY @ BTM. GET RETURNS @ SURF. WELL : 2M-08 OPERATION: RIG : PARKER 245 PAGE: 3 11/09/92 (10) TD:12151' ( 0) 11/10/92 (11) TD:12151' ( 0) 12/26/92 (14) TD:12151 PB:12046 12/27/92 (15) TD:12151 PB:12046 BLOWDOWN 7" CSG 7"612132' MW:IO.O VIS: 41 · CIRC SLOWLY @ 1.6 BPM, 400 PSI. HOLE TRY TO PACK OFF. RECIPROCATE PIPE WHILE SLOWLY INCREASE PMP RATE. GRADUALLY GET FULL RETURNS @ SURF. CIRC @ 5 BPM, 650 PSI UP, 1000 PSI DOWN. CMT 7" CSG( 198 SX CLASS G CMT). BMP PLUG, TEST CSG TO 3500 PSI. ANN FLOW. SHUT IN. MONITOR PRESS. PMP 300 BBL FW IN 9-5/8" X 7" ANN @ 10 BPM, 1300 PSI. SHUT IN ANN, PRESS~550 PSI. HOOK UP HOWCO CMT LINE. TEST TO 2000 PSI. MIX & PMP 337 SX PFC CMT 15.6 PPG(56.4 BBLS SLURRY). DISPLACE W/53.6 BBLS ARCTIC PACK @ 6.4 BPM, 900 PSI. ESTIMATED TOP OF PERMAFROST C @ 2044' TMD(1800' TVD). SHUT IN ANN~250 PSI. MONITOR SAME. WOC. PREPARE TO MVE. RIG RELEASED 7"612132' MW:10.0 VIS: 0 MANUAL CUT 7" CSG. LD LANDING JT. RD CSG EQUIP. STAND BOPS ON STUMP. NU TREE. TEST PACK-OFF TO 3000 PSI. RIG RELEASED @ 09:30 HRS 11/09/92. RIH W/3-1/2" COMP 7"612132' MW: 0.0 MVE RIG F/2M-04 TO 2M-08. ACCEPT RIG @ 10:00 12/25/92. ND FMC TREE & LEVEL RIG. NU BOPE STACK. INSTALL TEST PLUG. INSTALL DRIP PAN UNDER RIG FLOOR. FUNCTION TEST BOP, PT BLINDS & HCR TO 3500 PSI. PULL TEST PLUG. TEST CSG @ 3500 PSI F/30 MIN, NO LOSS. RIH & PERF IN 2 RUNS F/11727'-11756'. LOAD PIPE SHED W/TBG, DRIFT & TALLY. RU RUNNING TOOLS. PU CAMCO RET PKR/PBR & RIH W/3-1/2" J-55 & L-80 SC STRING. RIG RELEASED 7"612132' MW: 0.0 CONT RIH. TEST SSSV CL TO 5000 PSI WHILE RIH & BEFORE LANDING HGR-OK. RAN 30 SS BANDS. DROP BALL TO SHEAR OUT SUB 25 JTS BEFORE HGR. LAND HGR, RILDS. CIRC DN BALL F/20 MIN. PRESS TGB TO SET CAMCO PKR. SEALS SET @ 800, SLIPS @ 1300 PSI; PRESS TO 2500 PSI & HOLD F/30 MIN. BLEED TBG TO 1700 PSI. BOLDS. PU & SHEAR PBR @ 79K. RELAND HGR. RILDS. PRESS ANN & TBG TO 1000 PSI, CLOSE SSSV, BLEED TBG TO 500 PSI & TEST SSSV F/10 MIN-0K. EQUALIZE & OPEN SSSV. PRESS ANN & TBG TO 2500 PSI F/15 MIN, LOST 20 PSI-OK. PRESS TBG TO 3000 PSI, LOST 30 PSI IN 15 MIN. HOLD ANN PRESS & SHEAR OUT BALL W/4400 PSI. BLEED OFF PRESS & CLOSE SSSV. PULL LJT. INSTALL BPV. ND BOP STACK. NU TREE. PULL BPV. INSTALL TEST PLUG. TEST TREE TO 250 PSI & 5000 PSI, PACKOFF TO 5000 PSI. PULL TEST PLUG. OPEN SSSV. RU PMP LINES. DISPLACE ANN W/12 BBLS DIESEL, TAKING RETURNS THROUGH CHOKE. BULLHEAD 4 BBL DIESEL DN TBG, i BPM @ 1200 PSI. (NOTE: CIRC VALVE NOT HOLDING; PROB CIRC TRASH INTO VALVE AS WAS HOLDING DURING TBG TEST). SHUT IN WELL. RD PMP LINES & SECURE WELL. RELEASE RIG @ 1600 12/~6/92. MOVING RIG TO 2M-32. WELL : 2M-08 OPERATION: RIG : PAGE: 4 S I GNATURE: (dr~ ~int ende~ ) DATE: SUB - S URFA CE DIRECTIONAL SURVEY r~ UIDANCE M ICltOFILMED Company Well Name Field/Location ARCO ALASKA, INC. i i i ml i~-08 (114' FSL, 109' FWi., SEC 27, T11N, RSE, U~) KUPARUK, NORTH SLOPE, ALASKA i i Job Reference No. 92684 Locjc~ed By: ,JOHNSON Date 16-N0¥-92 ComPuted By: SINES I · SCHLL&4BEROER · GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. 2M-08 KUPARUK RIVER NORTH SLOPE, ALASKA SURVEY DATE: 16-NOV-1992 ENGINEER' G. JOHNSON METHODS OF COMPUTATION TOOL LOCATION' TANGENTIAL- Averaged deviation and azimuth INTERPOLATION' LINEAR VERTICAL SECTION' HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 6 DEG 7 MIN WEST COMPUTATION DATE' 25-NOV-g2 PAGE 1 ARCO ALASKA, INC. 2M-08 KUPARU~ RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 16-NOV-lg92 KELLY BUSHING ELEVATION' 147.00 FT ENGINEER' G. JOHNSON INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 900 O0 0 O0 -147 O0 100 O0 -47 200 O0 53 299 98 152 399 79 252 499 14 352 597 71 450 694 93 547 791 22 644 886 77 739 0 0 N 0 0 E O0 0 27 S 57 32 E O0 0 35 S 25 37 E 98 2 3 S 22 29 W 79 4 53 S 19 39 W 14 8 3 S 9 55 W 71 11 33 S 11 20 W 93 14 46 S 13 42 W 22 16 28 S 17 54 W 77 18 19 S 17 56 W 0 O0 0 10 0 65 2 47 8 15 19 30 36 02 59 23 85 81 114 61 0 O0 0 O0 0 21 3 11 3 24 3 5O 4 55 1 15 I 8O 3 23 O00N 0 13S 0 74S 254S 7 99 S 18 93 S 35 42 S 58 22 S 84 17 S 112 14 S 0 O0 E 0 19 E 077 E 0 53 E I 94 W 4 46 W 7 50W 12 53 W 19 84 W 29 0.00 N 0 0 E 0.23 S 56 58 E 1.07 S 46 11E 2.60 S 11 53 E 8.22 S 13 38 W 19.45 S 13 16 W 36.21 S 11 58 W 59.56 S 12 9 W 86.48 S 13 16 W 21W 115.88 S 14' 36 W 1000 O0 1100 O0 1073 1200 O0 1164 1300 O0 1253 1400 O0 1339 1500 O0 1422 1600.00 1502 1700.00 1578 1800.00 1650 1900.00 1717 980 93 72 926 96 1017 54 1106 46 1192 53 1275 54 1355 82 1431 72 1503 71 1570 833 93 20 45 72 22 44 96 25 56 54 29 16 46 32 30 53 35 16 54 38 50 82 42 10 72 46 16 71 50 7 S 12 39 W S 9 11W S 7 23W S 5 23W S SlOW S 548W S 4 19 W S S 56W S 5 50W S 649W 147 82 184 95 225 82 272 19 323 31 378 98 438 93 503 54 573 01 647 23 2 56 1 34 3 45 3 68 4 17 4 O4 4 42 5 54 4 26 2 97 144.60 S 181.21S 44 221.67 S 50 267.77 S 55 318.71S 6O 374.11S 65 433.81S 71 498.24 S 76 567.31S 83 641.10 S 91 38 02 W 149 51 S 14 44 W 88 W 186 75 W 227 86 W 273 28 W 324 73 W 379 24 W 439 36 W 504 85 W 573 77 W 647 68 S 13 55 W 41 S 12 54 W 53 S 11 47 W 36 S 10 43 W 84 S 9 58 W 62 S 9 2O W 06 S 8 43 W 47 S 8 24 W 63 S 8 9 W 2000 O0 1779.58 1632 58 53 34 2100 2200 2300 2400 2500 2600 2700 2800 2900 O0 1837.30 1690 O0 1891.34 1744 O0 1941.22 1794 O0 1986.84 1839 O0 2028.06 1881 O0 2067.79 1920 O0 2108.25 1961 O0 2147.92 2000 O0 2187.58 2040 30 55 52 34 58 37 22 61 27 84 64 3 06 66 26 79 66 29 25 66 7 92 66 57 58 66 15 S 8 24 W S 9 10 W 807 S 8 3 W 891 S 6 37 W 977 S 5 41W 1066 S 5 26 W 1158 S 5 26 W 1249 S 5 19 W 1341 S 5 11W 1433 S 5 3 W 1524 725 74 3O 33 97 94 O4 8O 24 03 81 2 17 1 42 1 65 2 18 3 11 0 35 1 79 0.48 O. 05 O. 97 718 98 S 101 92 W 726 16 S 8 4 W 799 882 968 1057 1147 1239 1330 1421 1513 65 S 114 81S 127 78 S 138 24 S 147 93 S 156 29 S 164 33 S 173 74 S 181 17 S 190 47 W 807 20 W 891 06 W 978 57 W 1067 22 W 1158 92 W 1250 50 W 1341 88 W 1433 07 W 1525 81 S 8 9 W 92 S 8 12 W 57 S 8 7 W 49 S 7 57 W 51 S 7 45 W 21 S 7 35 W 60 S 7 26 W 33 S 7 17 W 06 S 7 10 W 3000 O0 2228.44 2081 44 65 32 3100 3200 3300 3400 3500 3600 3700 3800 3900.00 2596 O0 2270 51 2123 O0 2313 O0 2355 O0 2395 O0 2435 O0 2474 O0 2514 O0 2555 51 64 51 43 2166 43 64 16 93 2208 93 66 25 27 2248 27 66 42 28 2288 28 66 12 91 2327 91 66 57 56 2367 56 66 16 26 2408.26 65 42 51 2449.51 65 37 S 4 52 W 1616 06 S 4 44 W 1706 S 4 38 W 1797 S 5 41W 1887 S 5 39 W 1979 S 5 25 W 2071 S 6 12 W 2162 S 5 43 W 2254 S 5 25 W 2346 S 5 46 W 2437 76 O5 54 48 12 93 73 O7 16 0 93 0 67 1 41 3 57 1 06 0 40 0 33 0 61 0 78 0 46 1604 10 S 197 95 W 1616 27 S 7 2 W 1694 1784 1874 1966 2057 2148 2240 2330 2421 50 S 205 52 S 212 70 S 220 16 S 230 39 S 238 72 S 248 02 S 257 93 S 266 60 S 275 58 W 1706 95 W 1797 75 W 1887 07 W 1979 82 W 2071 17 W 2163 74 W 2254 58 W 2346 36 W 2437 93 S 6 55 W 19 S 6 48 W 65 S 6 43 W 57 S 6 40 W 20 S 6 37 W O0 S 6 35 W 80 S 6 34 W 13 S 6 31W 21 S 6 29 W COMPUTATION DATE: 25-NOV-92 PAGE 2 ARCO ALASKA, INC. 2M-08 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 16-NOV-1992 KELLY BUSHING ELEVATION: 147.00 FT ENGINEER: G. JOHNSON INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH RUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPAR~IJRE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 4000 O0 2638 31 2491.31 64 57 S 5 49 W 2528 O0 4100 O0 2680 4200 O0 2721 4300 O0 2764 4400 O0 2807 4500 O0 2849 460O O0 2892 4700.0O 2935 4800.00 2978 4900.00 3020 08 2533.08 65 39 S 7 28 W 2618 62 2574.62 65 15 S 7 17 W 2709 23 2617.23 64 25 S 6 22 W 2800 08 2660.08 64 37 S 6 13 W 2890 99 2702.99 64 34 S 6 9 W 2980 95 2745.95 64 35 S 6 2 W 3071 72 2788.72 64 46 S 6 2 W 3161 21 2831.21 64 56 S 6 7 W 3252 39 2873.39 65 12 S 7 9 W 3342 I 12 2511.99 S 284 50 W 2528 05 S 6 28 W 85 0 79 0 25 0 6O 0 93 0 23 0 62 0 14 0 80 0 17 2602.22 S 295 53 2692.43 S 306 67 2782.25 S 317 22 2872 06 S 327 O0 2961 86 S 337 36 3051 65 S 346 27 3141 54 S 356 43 3231 57 S 365 44 3321 62 S 376 08 W 2618 76 W 2709 59 W 2800 46 W 2890 19 W 2980 78 W 3071 28 W 3161 78 W 3252 31W 3342 9O S 6 28 W 85 S 6 30 W 32 S 6 31W 67 S 6 30 W 99 S 6 3O W 29 S 6 29 W 68 S 6 28 W 20 S 6 27 W 87 S 6 28 W 5000 O0 3062.43 2915 43 65 17 S 7 7 W 3433 53 5100 5200 5300 5400 5500 5600 5700 5800 5900 O0 3104.15 2957 O0 3145.65 2998 O0 3187.11 3040 O0 3228.45 3081 O0 3269.74 3122 O0 3310.77 3163 O0 3351.55 3204 O0 3392.03 3245 O0 3432.12 3285 1S 65 24 S 7 11W 3524 65 65 33 S 7 13 W 3615 11 65 31 S 7 12 W 3706 45 65 38 S 7 16 W 3797 74 65 39 S 7 19 W 3888 77 65 51 S 7 23 W 3979 55 66 2 S 7 26 W 4070 03 66 13 S 7 28 W 4162 12 66 30 S 7 29 W 4253 39 35 34 38 44 61 90 31 9O 0.69 3411 65 S 387 62 W 3433.60 S 6 29 W 0.52 3501 82 S 398 1.27 3592 08 S 410 0.63 3682 37 S 421 0 51 3772 71 S 433 0 48 3863 05 S 444 0 19 3953 50 S 456 0 62 4044 05 S 468 0 41 4134.71 S 479 0 74 4225.55 S 491 96 W 3524.47 S 6 30 W 35 W 3615.45 S 6 31 W 74 W 3706.44 S 6 32 W 15 W 3797.49 S 6 33 W 67 W 3888.56 S 6 34 W 29 W 3979.75 S 6 35 W 06 W 4071.05 S '6 36 W 93 W 4162.47 S 6 37 W 82 W 4254.08 S 6 38 W 6000 O0 3472 29 3325.29 65 58 S 7 22 W 4345 45 6100 6200 6300 6400 6500 6600 6700 6800 6900 O0 3513 O0 3553 O0 3593 O0 3635 O0 3676 O0 3718 O0 3759 O0 3801 O0 3842 05 3366 05 66 2 S 7 24 W 4436 54 3406 98 3446 SO 3488 88 3529 02 3571 15 3612 13 3654 99 3695 54 66 12 S 7 25 W 4528 98 65 46 S 7 21 W 4619 50 65 25 S 7 18 W 4710 88 65 38 S 7 24 W 4801 02 65 47 S 7 19 W 4892 15 65 14 S 6 8 W 4983 13 65 9 S 5 23 W 5074 99 65 22 S 5 18 W 5165 74 16 59 54 56 69 82 58 39 0 26 4316 36 S 503 66 W 4345 64 S 6 39 W 0 39 4406 0 52 4497 2 41 4588 0 88 4678 0 56 4768 I 17 4859 3 28 4949 0 74 5040 0.82 5130 92 S 515 60 S 527 29 S 538 52 S 550 82 S 562 22 S 573 68 S 584 02 S 593 45 S 602 40 W 4436 12 W 4528 94 W 4619 52 W 4710 11W 4801 75 W 4892 91W 4984 67 W 5074 12 W 5165 96 S 6 40 W 38 S 6 41W 84 S 6 42 W 80 S 6 43 W 83 S 6 43 W 98 S 6 44 W 12 S 6 44 W 87 S 6 43 W 66 S 6 42 W 7000.00 3884 71 3737.71 65 23 S 5 19 W 5256 26 7100.00 3926 7200.00 3967 7300.00 4006 7400 O0 4046 7500 O0 4085 7600 O0 4123 7700 O0 4161 7800 7900 10 3779.10 65 36 S 5 7 W 5347 28 14 3820.14 66 20 S 3 55 W 5438 43 98 3859.98 66 41 S 3 46 W 5530 08 30 3899.30 67 0 S 3 46 W 5621 94 10 3938.10 67 18 S 3 46 W 5714 04 49 3976.49 67 31 S 3 39 W 5806.29 57 4014.57 67 51 S 3 37 W 5898.67 O0 4199.17 4052.17 67 27 S 3 38 W 5991.24 O0 4238.59 4091.59 66 41 S 3 40 W 6083.06 1 62 5220.94 S 610 51 W 5256 51 S 6 40 W 1 06 5311.59 S 618 0 72 5402.51S 625 0 13 5494.02 S 631 0 78 5585.77 S 638 0 71 5677.73 S 644 0 59 5769.88 S 650 1 22 5862.16 S 655 2.79 5954.64 S 661 2.00 6046.35 S 667 86 W 5347 52 S 6 39 W 84 W 5438 64 S 6 36 W 97 W 5530 25 S 6 34 W 01 W 5622 09 S 6 31 W 09 W 5714 15 S 6 28 W 06 W 5806 38 S 6 26 W 92 W 5898 74 S 6 23 W 71 W 5991.29 S 6 20 W 55 W 6083.09 S 6 18 W ARCO ALASKA, INC. 2M-08 KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE: 25£NOV-92 PAGE 3 DATE OF SURVEY: 16-NOV-1992 KELLY BUSHING ELEVATION: 147.00 FT ENGINEER: G. JOHNSON INTERPOLATED VALUES FOR eVEN 100 FeET Of MeaSURED DEPTH TRUE SUB-SEA COLE{SE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG ~IN 8000 O0 4278 13 4131 13 66 43 S 3 37 W 6174 82 8100 8200 8300 8400 8500 8600 8700 8800 8900 O0 4317 O0 .4357 O0 4399 O0 4440 O0 4481 O0 4522 O0 4564 O0 4605 O0 4646 17 4170 57 4210 29 4252 77 4293 69 4334 84 4375 42 4417 50 4458 01 4499 17 67 8 S 3 35 W 6266 57 65 19 S 3 33 W 6358 29 65 27 S 3 39 W 6448 77 65 40 S 3 32 W 6539 69 66 2 S 3 16 W 6631 84 65 17 S 3 7 W 6722 42 65 28 S 3 7 W 6812 50 66 7 S 3 8 W 6903 80 18 97 88 02 O4 87 91 01 65 23 S 2 59 W 6995.21 1.81 6138 02 S 673 37 W 6174 85 S 6 16 W 0.46 6229 1.33 6321 0 73 6411 0 88 6502 1 05 6593 0 59 6684 0 31 6775 I 36 6866 3 99 6957 90 S 679 19 S 684 89 S 690 71S 696 79 S 701 78 S 7O6 60 S 711 63 S 716 92 S 721 13 W 6266 85 W 6358 56 W 6448 28 W 6539 76 W 6631 83 W 6722 77 W 6812 75 W 6903 65 W 6995 81 S 6 13 W 18 S 6 11W 97 S 6 9 W 88 S 6 7 W O2 S 6 4 W 05 S 6 2 W 88 S 6 0 W 94 S 5 58 W 25 S 5 55 W 9000 O0 4688 62 4541 62 64 44 S 2 59 W 7085 54 9100 9200 9300 9400 9500 9600 9700 9800 9900 O0 4731 O0 4772 O0 4813 O0 4855 O0 4897 O0 4938 O0 4979 O0 5021 O0 5063 14 4584 91 4625 86 4666 73 4708 66 4750 93 4791 89 4832 75 4874 55 49~6 14 65 0 S 2 58 W 7175 91 65 42 S 2 51 W 7266 86 65 54 S 2 41W 7357 73 64 59 S 2 27 W 7448 66 65 26 S 2 27 W 7538 93 65 50 S 2 20 W 7629 89 65 36 S 2 10 W 7720 75 65 14 S 2 1 W 7811 55 65 11 S 1 56 W 7902 92 63 71 34 94 83 85 45 06 10000 O0 5105 72 4958 72 65 3 S 1 47 W 7992 48 10100 10200 10300 104O0 10500 10600 10700 10800 10900 O0 5149 O0 5195 O0 5242 O0 5291 O0 5342 O0 5395 O0 5453 O0 5514 O0 5577 21 5002 65 5048 74 5095 55 5144 32 5195 91 5248 18 5306 10 5367 40 5430 21 63 0 S 2 22 W 8082 65 62 8 S 2 30 W 8170 74 61 17 S 2 39 W 8258 55 60 12 S 3 29 W 8345 32 58 24 S 4 17 W 8431 91 56 9 S 2 59 W 8516 18 53 29 S 2 49 W 8598 10 51 32 S 3 19 W 8677 40 50 6 S 3 33 W 8754 30 68 73 87 95 31 13 31 64 0 84 7048.27 S 726 36 W 7085 60 S 5 53 W 16 7138.66 S 731 17 7229.40 S 735 80 7320 53 S 740 36 7411 25 S 744 O0 7501 95 S 747 93 7592 96 S 751 59 7684 11S 755 13 7774 87 S 758 50 7865 66 S 761 O4 W 7175 65 W 7266 04 W 7357 04 W 7448 87 W 7539 67 W 7630 26 W 7721 57 W 7811 72 W 7902 gg S 5 51 W 73 S 5 49 W 84 S 5 46 W 50 S 5 44 W 14 S 5 42 W 07 S 5 39 W 14 S 5 37 W 79 S 5 34 W 46 S 5 32 W 0.37 7956 29 S 764 67 W 7992 95 S 5 29 W 3.28 8046 0.47 8134 2 21 8222 3 62 8310 2 45 8395 1 75 8480 2 37 8562 1 15 8641 0 27 S 767 74 S 771 88 S 775 04 S 780 98 S 786 20 S 791 07 S 795 26 S 799 51 8718.52 S 804 94 W 8082 78 W 8171 65 W 8259 16 W 8346 04 W 8432 81W 8517 79 W 8598 94 W 8678 64 W 8755 83 S 5 27 W 27 S 5 25 W 38 S 5 23 W 58 S 5 22 W 70 S 5 21W 09 S 5 20 W 97 S 5 19 W 20 S 5 17 W 57 S 5 16 W 11000 O0 5642.95 5495 95 48 21 S 3 27 W 8830 07 11100 11200 11300 11400 11500 11600 11700 11800 11900 O0 5710.50 5563 O0 5778.48 5631 O0 5846.38 5699 O0 5915.87 5768 O0 5987.42 5840 O0 6061.57 59~4 O0 6137.06 5990 O0 6212.25 6065 O0 6287.07 6140 50 47 10 S 4 23 W 8903 48 47 12 S 4 23 W 8977 38 46 55 S 4 29 W 9050 87 45 13 S 5 34 W 9122 42 43 I S 6 21 W 9192 57 41 6 S 5 46 W 9259 06 40 58 S 5 28 W 9324 25 41 32 S 5 16 W 9390 07 41 37 S 4 53 W 9457 75 06 43 33 18 27 85 77 10 0 75 8793.89 S 809 21 W 8831.04 S 5 15 W 56 8867.44 S 814 45 8940.56 S 820 73 9013 76 S 825 48 9085 40 S 831 66 9154 86 S 839 08 9221 56 S 846 06 9286 83 S 852 28 9352 47 S 858 64 9418 55 S 864 39 W 8904.76 S 5 15 W O0 W 8978 09 S 5 14 W 56 W 9051 49 S 5 14 W 85 W 9123 40 S 5 14 W 27 W 9193 25 S 5 14 W 48 W 9260 33 S 5 15 W 87 W 9325 91 S 5 15 W 96 W 9391 83 S 5 15 W 87 W 9458 18 S 5 15 W COMPUTATION DATE: 2S-NOV-92 PAGE 4 ARCO ALASKA, INC. 2M-08 KUPARUK RIVER NORTH SLOPe, ALASKA DATE OF SURVEY: 16-NOV-1992 KELLY BUSHING ELEVATION: 147.00 FT ENGINEER: G. JOHNSON INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH 'FRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 12000.00 6362.08 6215.08 4! 3 S 4 32 W 9523.22 12100.00 6437.47 6290.47 41 3 S 4 26 W 9588.99 12151.00 6475.93 6328.93 41 3' S 4 26 W 9622.47 1.49 9484.47 S 870.26 W 9524.31 S S 15 W 0.00 9550.10 S 875.13 W 9590.11 S $ 14 W 0.00 9583.49 S 877.71 W 9623.60 S 5 14 W COMPUTATION DATE: 25-N0V-g2 PAGE ARCO ALASKA, INC. 2M-08 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 16-NOV-1992 KELLY BUSHING ELEVATION: 147.00 FT ENGINEER: G. JOHNSON INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 1000 2000 3000 4000 5000 6000 7000 8000 9000 0 O0 -147 O0 0 0 N 0 0 E O0 980 93 833 O0 1779 58 1632 O0 2228 44 2081 O0 2638 31 2491 O0 3062 43 2915 O0 3472 29 3325 O0 3884 71 3737 O0 4278 13 4131 O0 4688 62 4541 0 O0 93 20 45 S 12 39 W 147 58 53 34 S 8 24 W 725 44 65 32 S 4 52 W 1616 31 64 57 S $ 49 W 2528 43 65 17 S 7 7 W 3433 29 65 58 S 7 22 W 4345 71 65 23 S 5 19 W 5256 13 66 43 S 3 37 W 6174 62 64 44 S 2 59 W 7085 82 74 06 O0 53 45 26 82 54 0 O0 2 56 144 2 17 718 0 93 1604 I 12 2511 0 69 3411 0 26 4316 1 62 5220 I 81 6138 0 84 7048 0 O0 N 60 S 38 98 S 101 10 S 197 99 S 284 65 S 387 36 S 503 94 S 610 02 S 673 27 S 726 0 O0 E 02 W 149 92 W 726 95 W 1616 50 W 2528 62 W 3433 66 W 4345 51W 5256 37 W 6174 36 W 7085 0 O0 N 0 0 E 51 S 14 44 W 16 S 8 4 W 27 S 7 2 W 05 S 6 28 W 6O S 6 29 W 64 S 6 39 W 51 S 6 40 W 85 S 6 16 W 60 S S 53 W 10000.00 5105.72 4958.72 65 3 S I 47 W 7992.48 11000.00 5642.95 5495.95 48 21 S 3 27 W 8830.07 12000.00 6362.08 6215.08 41 3 S 4 32 W 9523.22 12151.00 6475.93 6328.93 41 3 S 4 26 W 9622.47 0.37 7956.29 S 764.67 W 7992.95 S 5 29 W 0.75 8793.89 S 809.21W 8831.04 S 5 15 W 1.49 9484.47 S 870.26 W 9524.31 S 5 15 W 0.00 9583.49 S 877.71W 9623.60 S 5 14 W ARCO ALASKA, INC. 2M-08 KUPARU~ RIVER NORTH SLOPE, ALASKA COMPUTATION DATE: 25-NOV-92 PAGE 6 DATE OF SURVEY: 16-NOV-1992 KELLY BUSHING ELEVATION: 147.00 FT ENGINEER: G. JOHNSON INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 0 O0 -147.00 0 0 N 0 0 E 147 O0 147 O0 0.00 0 29 S 49 22 E 247 01 247 O0 100.00 0 55 S 2 48 W 347 08 347 O0 200:00 3 21 S 26 39 W 447 44 447 O0 300 O0 6 23 S 13 5 W 548 43 547 O0 400 O0 9 34 S 10 18 W 650 53 647 O0 500 O0 13 40 S 12 11 W 753 98 747 O0 600 O0 I5 44 S 16 2 W 858 26 847 O0 700 963 80 947 O0 800 0 O0 0 1 4 12 26 47 73 O0 17 10 S 18 53 W 102 O0 20 5 S 14 28 W 135 30 19 54 73 69 O7 27 22 3O 0 O0 0 O0 1 64 2 39 3 44 3 28 2 89 2 11 1 59 3 35 O00N 0 1 4 12 26 46 71 100 132 0.00 E 35 S 0.51 E 0 29 S 0.88 E 1 52 S 0.44 W 4 47 S 3 19 W 12 23 S 5 74 W 26 3O S 9 76 W 47 97 S 16 12 W 73 11 S 25 18 W 103 31 S 35 08 W 136 0 O0 N 0 0 E 62 S 55 16 E 56 S 34 16 E 54 S 5 32 W 87 S 14 22 W 85 S 12 2O W 31 S 11 55 W 75 S 12 38 W 23 S 14 7 W 89 S 14 51W 1071 07 1047 O0 900 O0 22 22 S 9 41W 173 88 1180 1292 1408 1530 1657 1794 1946 2117 08 1147 51 1247 94 1347 15 1447 73 1547 64 1647 28 1747 36 1847 2312 16 1947 O0 1000 O0 25 17 S 7 42 W 217 O0 1100 O0 29 0 S 5 34 W 268 O0 1200 O0 32 51 S 5 17 W 328 O0 1300 O0 36 6 S 5 42 W 396 O0 1400 O0 40 16 S 4 17 W 475 O0 1500.00 46 0 S 5 52 W 569 O0 1600.00 51 29 S 7 13 W 683 O0 1700.00 56 12 S 9 8 W 821 O0 1800.00 61 45 S 6 32 W 988 22 55 13 58 72 15 06 68 67 I 39 3 6O 3 68 3 69 2 13 3 76 5.40 4.89 2.56 2.93 170 27 S 43 06 W 175 63 S 14 12 W 213 264 323 391 470 563 676 813 979 14 S 49 14 S 55 51 S 60 62 S 67 53 S 73 46 S 83 67 S 96 87 S 116 41 S 139 63 W 218 52 W 269 72 W 329 49 W 397 86 W 476 45 W 569 10 W 683 76 W 822 28 W 989 85 S 13 6 W 91 S 11 52 W 16 S 10 38 W 39 S 9 47 W 3O S 8 55 W 61 S 8 25 W 46 S 8 5 W 21 S 8 10 W 26 S 8 6 W 2547 60 2047 O0 1900 O0 66 39 S 5 28 W 1201 70 2797 3044 3278 3529 3779 4020 4260 4493 65 2147 42 2247 03 2347 15 2447 89 2547 57 2647 07 2747 04 2847 O0 2000 O0 2100 O0 2200 O0 2300 O0 2400 O0 2500 O0 2600 O0 2700 4726 48 2947 O0 2800 O0 66 57 S 5 11 W 1430 O0 65 6 S 4 50 W 1656 O0 65 30 S 5 16 W 1867 O0 66 25 S 5 36 W 2097 O0 65 48 S 5 27 W 2327 O0 65 3 S 6 2 W 2546 O0 64 38 S 6 49 W 2764 O0 64 34 S 6 9 W 2974 86 40 47 8O 73 64 22 64 O0 64 49 S 5 59 W 3185.57 0.49 1191 40 S 160 37 W 1202.15 S 7 40 W 0 03 1419 0 62 1644 5 32 1854 1 50 2083 0 39 2312 1 78 2530 2 75 2746 0 09 2955 0 17 3165 59 S 181 31S 201 71S 218 95 S 241 68 S 264 53 S 286 46 S 313 61S 336 37 S 358 68 W 1431.17 S 7 18 W 37 W 1656.60 S 6 59 W 83 W 1867.58 S 6 44 W 37 W 2097.88 S 6 36 W 85 W 2327.79 S 6 32 W 42 W 2546.69 S 6 27 W 50 W 2764.29 S 6 31 W 52 W 2974.71 S 6 30 W 79 W 3185.64 S 6 28 W 4963.28 3047 O0 2900.00 65 5 S 7 9 W 3400.21 5203.25 3147 5444.89 3247 5688.80 3347 5937.38 3447 6183.81 3547 6427.70 3647 6670.70 3747 6909.63 3847 7150.51 3947 O0 3800.00 65 40 S 4 15 W 5393 O0 3000.00 65 32 S 7 13 W 3618.31 O0 3100.00 65 37 S 7 14 W 3838.25 O0 3200.00 66 I S 7 26 W 4060 67 O0 3300.00 66 29 S 7 28 W 4288 17 O0 3400.00 66 9 S 7 24 W 4513 35 O0 3500.00 65 30 S 7 18 W 4735 74 O0 3600.00 65 41 S 6 56 W 4957 16 O0 3700.00 65 21 S 5 19 W 5174 14 25 0 06 3378 59 S 383 48 W 3400 28 S 6 29 W 12 3595 07 3813 61 4033 27 4259 65 4482 24 4703 09 4923 69 5139 O1 5357 O1S 410 26 S 438 91S 466 55 S 496 91S 525 52 S 553 20 S 581 16 S 602 41S 622 72 W 3618 30 W 3838 74 W 4060 28 W 4288 21W 4513 72 W 4736 86 W 4957 93 W 5174 63 W 5393 40 S 6 31W 37 S 6 33 W 82 S 6 36 W 36 S 6 39 W 57 S 6 41W O1 S 6 43 W 46 S 6 44 W 40 S 6 41W 47 S 6 38 W COMPUTATION DATE: 25-NOV-92 PAGE 7 ARCO ALASKA, INC. 2M-08 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 16-NOV-1992 KELLY BUSHING ELEVATION: 147.00 FT ENGINEER: G. JOHNSON INTERPOLATED VALUES FOR EVEN 1OO .FEET OF SUB-SEA DEPTH 3'RUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG 7401.78 4047 O0 3900 O0 67 0 S 3 46 W 5623.58 7661.59 4147 7921.24 4247 8174.63 4347 8415.14 4447 8658.08 4547 8902.38 4647 9137.62 4747 9379.43 4847 9619.71 4947 O0 4000 O0 4100 O0 4200 O0 4300 O0 4400 O0 4500 O0 4600 O0 4700 O0 4800 O0 67 38 S 3 38 W 5863 17 O0 66 40 S 3 39 W 6102 O0 65 28 S 3 36 W 6335 O0 65 42 S 3 30 W 6553 O0 65 28 S 3 7 W 6774 O0 65 18 S 2 59 W 6997 O0 65 13 S 2 57 W 7209 O0 64 49 S 2 27 W 7429 O0 65 49 S 2 19 W 7647 0 79 5587,40 S 638 12 W 5623 72 S 6 31 W 1 54 2 14 0 66 1 79 0 37 4 98 1 75 0 77 0 08 5826 69 S 653 47 6065 18 6298 13 6516 41 6737 37 6960 58 7172 17 7392 42 7610 81S 668 18 S 683 48 S 697 53 S 7O9 09 S 721 73 S 732 64 S 743 92 S 752 67 W 5863 79 W 6102 42 W 6335 13 W 6553 70 W 6774 77 W 6997 79 W 7210 25 W 7429 39 W 7648 25 S 6 24 W 57 S 6 18 W 15 S 6 12 W 66 S 6 6 W 8O S 6 I W 41 S 5 55 W 06 S 5 50 W 91 S 5 44 W 02 S 5 39 W 9860.51 5047.00 4900 O0 65 21 S 2 0 W 7866 29 10095 09 5147.00 5000 10308 10508 10689 10852 11006 11153 11300 11443 85 5247.00 5100 92 5347.00 5200 59 5447.00 5300 47 $547.00 5400 09 5647.00 5500 67 5747.00 5600 90 5847.00 5700 85 6947.00 5800 O0 63 9 S 2 21W 8077 O0 61 8 S 2 44 W 8266 O0 58 16 S 4 19 W 8439 O0 53 42 S 2 50 W 8589 O0 50 34 S 3 28 W 8718 O0 48 19 S 3 29 W 8834 O0 47 8 S 4 25 W 8943 O0 46 53 S 4 29 W 9051 O0 44 32 S 6 11 W 9153 92 46 54 77 14 61 08 09 21 0 89 7829 82 S 760.50 W 7866 67 S 5 33 W 97 8041 78 8230 61 8403 81 8553 97 8682 96 8798 39 8906 72 9014 47 9116 89 S 767.76 W 8078 62 S 776.02 W 8267 55 S 786.61 W 8440 70 S 795.38 W 8590 06 S 802.38 W 8719 43 S 809.48 W 8835 68 S 817.40 W 8944 42 S 825.61 W 9052 11 S 835.03 W 9154 45 S 5 27 W 12 S 5 23 W 29 S 5 21W 60 S 5 19 W 05 S 5 17 W 59 S 5 15 W 11 S 5 15 W 15 S 5 14 W 28 S 5 14 W 11580 61 6047 O0 5900 O0 41 32 S 6 1 W 9246.47 11713 16 6147 O0 6000 O0 40 55 S 5 22 W 9333.48 11846 41 6247 O0 6100 O0 41 34 S 5 6 W 9421.53 11979 97 6347 O0 6200 O0 41 17 S 4 42 W 9510.04 12112 63 6447 O0 6300 O0 41 3 S 4 26 W 9597.29 12151 O0 6475 93 6328 93 41 3 S 4 26 W 9622.47 2 91 9208.83 S 845 17 W 9247.53 S 5 15 W 1 12 9295.42 S 853 69 W 9334.54 S 5 15 W 0 62 9383.11 S 861 76 W 9422.60 S 5 15 W 0 95 9471.32 S 869 20 W 9511.12 S 5 15 W 0 O0 9558.37 S 875 77 W 9598.41 S 5 14 W 0 O0 9583.49 S 877 71 W 9623.60 S 5 14 W COMPUTATION DATE: 25-NOV-92' PAGE 8 ARCO ALASKA, INC. 2M-08 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK a BASE KUPARUK A GCT LAST READING PB'FD 7" CASING DATE OF SURVEY: 16-NOV-1992 KELLY BUSHING ELEVATION: 147.00 FT ENGINEER: G. JOHNSON INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = , SEC27 TllN R8E MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 4253 O0 11696 O0 11714 O0 11714 O0 11880 O0 12010 O0 12046 O0 12133 O0 12151 O0 2743 97 6134 04 6147 63 6147 63 6272 12 6369 60 6396 75 6462 36 6475 93 2596 97 5987 04 6000 63 6000 63 6125 12 6222 60 6249 75 6315 36 6328 93 274O 12 S 9284 22 S 9295 96 S 9295 96 S 9405 32 S 9491 17 S 9514 74 S 9571 71S 9583 49 S 312.75 W 852 62 W 853 74 W 853 74 W 863 72 W 870 57 W 872 39 W 876 80 W 877 71W COMPUTATION DATE' 25-NOV-92 PAGE 9 ARCO ALASKA, INC. 2M-08 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK ¢ TOP KUPARUK a BASE KUPARUK A PBTD 7" CASING DATE OF SURVEY' 16-NOV-1992 KELLY BUSHING ELEVATION' 147.00 FT ENGINEER' G. JOHNSON ************ STRATIQRAPHIC SUMMARY SURFACE LOCATION = , SEC27 TllN RSE MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 4253.00 11696.00 11714 O0 11714 O0 11880 O0 12046 O0 12133 O0 12151 O0 2743 97 6134 04 6147 63 6147 63 6272 12 6396 75 6462 36 6475 93 2596 97 5987 04 6000 63 6000 63 6125 12 6249 75 6315 36 6328 93 274O 12 S 9284 22 S 9295 96 S 9295 96 S 9405 32 S 9514 74 S 9571 71S 9583 49 S 312.75 W 852 62 W 853 74 W 853 74 W 863 72 W 872 39 W 876 80 W 877 71W FINAL WELL LOCATION AT TD- TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 12151.00 6475.93 6328.93 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 9623.60 S 5 14 W DIRECTIONAL SURVEY COMPANY ARCO ALASKA, INC. FIELD KUPARUK RIVER WELL 2M-08 COUNTRY USA RUN I DATE LOGGED 16 - NOV - 92 DEPTH UNIT FEET REFERENCE 92684 All interpretations are opinions baaed on inferences from electrical or other measurements and wa cannot, and do not guarantee the accuracy or correctness of any Interpretations, and we shall not. except In the case of gross or wilfull negligence on our part. be liable or responsible for any loss, coats, damages or expenses Incurred or su~&lnld by anyone resulting from any interpretation made by any of our offlc®re, agents or employees. These Interpretations are also subject to our General Terms and Conditions as set out tn our cun'ent price Schedule. ~IELL' 2H-08 ~ ' , (114' FSL, 109' FilL, SEC 27, ~11N, R8E,UN) HOR~,C~NTAL PRO~IECTION NORTH 4000 lIEF 92684 2000 -2000 -4000 -6000 -8000 SOUTH -1 -6000 WEST SCALE = '~ / 2000 IN/FT -6000 -4000 -2000 0 2000 4000 6000 6000 EAST E'ELL: 2N-08 ~ (114' FSL, 109' FWL, SEC ,-.~, T11N, R8E, UN) ~RTICAL PROdECTION 6.00 -4000 -2000 0 0 2000 4000 6000 8000 10000 12000 186.00 .. 0 PROJECTION ON VERTICAL PLANE 6.00 186.00 ~:~AL. ED IN VERTICAL DI=PTI-'I$ I-IORIZ ~CALE = 1 / 2000 IN/PT AOGCC GEOLOGICAL MATERIALS INVENTORY LIST PERMIT # ~'L - I O t WELL NAME ~,~. ~I'~--C~ COMPLETION DATE ..~.Z.. / Z.? /, ¢17_.. CO. CONTACT' j:~~ ~C. check off or list data as it,.!S receiv~d.*list received dat,e for 407. if not required list as NR ' 4oz I*' 'drilling history cored i,,nt~a.!,,~core analysis l~ ,,,d,,f~ ditch intervals digita! data i i i ii i iiiii i i i i i i ii i ii L iii i ii ii i i i i i i i LOG T'YPE '" RUN INTERVALS SCALE ........ NO. [to the nearest foot] : [inchl! 00'] i ii ii ii ii i i ii ii ii Illl i i i i i i II II II Ill I I I II II II I Illll I Illll I I ~1 .... . i i iii i i iii i i I i i ii i ......... .................. I I II IIIII I I I I I I.I I II I I II I I I I I I I I I ARCO Alaska, Inc. Date: December 4, 1992 Transmittal #' 8611 RETURN TO: ARCO Alaska, Inc. ATTN: Nikki Stiller Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 2M-08 2M 08 Receipt Drilling Transmitted here with are the following Cased Hole items. return one signed copy of this transmittal. Cement Evaluating Log '''''/ 1 1 - 1 5 - 9 2 Cement Bond Log ~ 1 1 - 1 5 - 9 2 Acknowledge' ~-~ Date' State of Alaska(+sepia) Please acknowledge receipt and 9000-12023 9000-12040 ..R-E.C.EIV E D NSK DEC 0 7 1992 Alaska 011 & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: December 4, 1992 Transmittal #' 8614 RETURN TO: ARCO Alaska, Inc. Attn: Nikki Stiller Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and 'return one signed copy of this transmittal. 17~ 5-¢~'~' 2 MM ~ 0 1 LIS Tape and Listing O~ 1 1 - 1 9- 9 2 9 2 4 0 9 2 ~ '5'¢~r' LIS Tape and Listing e~ 1 1 - 2 5 - 9 2 9 2 6 4 0 M 3~, 3~92 92667 2 -0 8,~ ~'~' LIS Tape and Listing ok/' 1 1; Receipt Acknowledged: - ' Date' i~-E-C~IV E D -- DEC 07 1992 DISTRIBUTION: Alaska 011 & Gas Cons. Commission AnGhorage Lynn Goettinger State of Alaska ARCO Alaska, Inc. Date: December 4, 1992 Transmittal #: 8609 RETURN TO: ARCO Alaska, Inc. Attn: Nikki Stiller Kuparuk Records Clerk ATO-111 9 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2M-01 -/ 2M-08 / Receipt Sub-Surface Directional 1 1 - 0 3 - 9 2 Survey Sub-Surface Directional 1 1 - 1 6 - 9 2 Survey Acknowledged :-~-~- DISTRIBUTION: D&M State of Alaska (2 copies) 92661 92684 RECEIVED D a t e :D-EC- -0- 7- -19.9 2 Alaska 0il & Gas Cons. Con, mission Anchorage ARCO Alaska, Inc. Date: November 13, 1992 Transmittal #: 8601 o/ RETIJ~TO: ARCO Alaska, Inc. Attn: Nikki Stiller Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following OI3en hole items. Please acknowledge receipt and return one signed copy of this transmittal. 2M-08 CDR 1 1/3-7/92 4253-12151 ~Receipt Acknowledged: DISTRIBUTION: D&M Drilling RECEIVED Date: .......... NOV 1 co ~992 Alaska 0tl & {3a~ Cons. Commt~lon Ar~chora~ Vendor Package(Johnston) NSK State of Alaska(+Sepia) ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HIGKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 995.01-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 October 6, 1992 A W McBride Area Drilling Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 2M-08 ARCO Alaska, Inc. Permit No: 92-101 Sur. Loc. ll4'FSL, 109'FWL, Sec. 27, TllN, RSE, UM Btmhole Loc. 4185'FNL, 4363'FWL, Sec. 4, T10N, RSE, UM Dear Mr. McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Si Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA Ai_/-~,~ ,,~ OIL AND GAS CONSERVATION COMMISS, PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill r-I lb Type of Well Exploratory r~ Stratlgraphlc r-=] Development OII X Test Re-Entry r'! DeaDen r-I Service I--I DeveloDmentGas r'i sin¢lle Zone X aultil31e Zone r-I 2.. Name of Operator 5. Datum Elevation (DF or KB) 10, Field and Pool ARCO Alaska, Inc. RKB 147', Pad 106' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchoracje, AK 99510-0360 ADL 25589, ALK 2675 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 114' FSL, 109' FWL, Sec. 27, T11N, R8E Kuparuk River Unit Statewide At top of productive interval (O TARGET ) 8. Well number Number 3954' FNL, 4388. FWL, Sec. 4, T10N, R8E 2M-08 #UG630610 At total depth 9. Approximate spud date Amount 4185' FNL, 4363' FWL, Sec. 4, T10N, R8E 1 0/1 2/1 992 $200~000 12. Distance to nearest 13. Distance to nearest well 14. Number o! acres in properly 15. Proposed depth (MD and 'I'VD) property line 2M-09 12151' MD 917 @ TD feet 14.9' @ 325 feet 2560 6444' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(a)(2)) Kickoff depth 300 feet Maximum hole angle 65.88° Maximum ,urfa~ 1620 osio At total d®oth ~TVDI 3100 o,io 18. Casing program Settin~ Depth size Specifications Top Bottom Quantlt}/ of cement Hole Casin~l Wei~lht Grade coupIin~l Len~lth MD TVD MD TVD (include sta~le dataI 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +200 CF 12.25" 9.625" 4,9-~# L-80 BTC 4153' 41' 41' 4194' 2737' 310 Sx Permafrost E & ~ J~/~-~ ~/¢z./,,~ ,z~7'O HF-ERW 760 Sx Class G 7~' '~:26.0# L-80 BTCMOD 5469' 41' 41' 5510' 3275' 8.5" HF-ERW 8.5" 7" 26.0# L-80 BTC 500' 5510' 3275' 6010' 3479' HF-ERW 8.5" 7" 26.0# J-55 BTC 6141' 6010' 3479' 12151' 6444' 1606xClassG HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operaons. Present well condition summary Total depth: measured f eat Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing ConductorStructural Length Size Cemented~E~Ei depth True Vertical depth Surface Intermediate Production LinerS E P 2 5 1992 Perforation depth: measured Alaska 0il & Gas Cons. Comn~is$[Ot~ true vertical Anchorage 20. Attachments Filing fee X Property plat [~] BOP Sketch X . Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot r'~ Retraction analysis D Seabed report r~ 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ///~'~'~~'~t Title Area Drilling En~]ineer Date - ' I -- Commission Use Onl~ ~r ~ Permit Number I APl number I Approval _date .~ I See cover letter for ~'..~_--'?~,/' 50- ~o~ - .2.(:~/'~'~'/' /~) _.. ~ ~ ~7~.~ other ,requirements Conditions o! approval Samples re(luireU [~ Yes ~' No Mud Iot3 re(lulreU r'! Yes No Hydrogen sulfide measures? r~ Yes ,~ No Directional survey required? ~ Yes r'l No Re(~uired working pressure for BOPE r'l 2M ~ 3M D 5M [~] 1OM r"l 15M Other: by order o! Approved b)/ Commissioner the commission Date 10-401 )v. 7-24-89 Submit in triplicate C*~T[D W~ : MS For: B MATIIEWS EASTMAN ARCO ALASKA, IIIC. Structure : Peal 2M Field : Kuporuk River Unit Well Location : North Slope, Alaska SURFACE LOCATION: 114' FSL, 109' FWL SEC. 27, T11N, RBE (-- West .... 1 '*00 ~ OOO ~000 I I I I I I I S 6.11 DEG W 9401' (TO TARGET) TARGET LOCATION: 3954-' FNL, 43BB' FWL SEC. 4., TI ON, RBE TARGET TMD=6167 TMD=11789 DEP=9401 SOUTH 9348 WEST 1001 MAXIMUM ANGLE 65.88 DEG i i i i i ! ! i i i I I 0 ~00 100~ ! SOO2000 2~00 SCALE 1 : 250.00 TO LOCATION: RKB ELEVATION: 147' 4185' FNL, 4363' FWL SEC. 4, TI ON, RBE KOP TVD=300 TMD--'IO0 DEP=O 3.00 9.00 15.00 BU#.D 3 DEG / lo0' 21 .OO 27.00 33.00 B/ PERMAFROST TVD=1397 TMD=1469 DEP=34-6 39.00 T/ UGNU SNDS TVD=14-27 TMD=IS05 OEP=368 4-5.00 51.00 ~7 DO T/ W SAK SNDS TVD=1987 TMD=2369 DEP=1015 63.00 EOC TVD=2043 TMD=24.96 DEP=! 129 B/ W SAK SNDS TVD=2537 TMD=3704 OEP=2232 9 $/8"CSG PT TVD=2737 TMD=4194 OEP=2679 K-tO T~0=2997 TMD=4830 DEP=3260 A/B MODIFIED CSG PT TVD=3275 TMD=5510 DEP=3BBO K-5 TV0=4322 TMD=8072 DEP=6218 BEGIN ANGLE DROP TV0=5136 TMD=lO064- OEP=8036 OROP 1.5 DEG / 100' TAI~GET - T/ k-dP SNDS 1'VD=6167 TMD=II789 DEP=9401 T~GET ANGLE T/ zo.E A TVD=6,76 TUD:IIe01 DEP=9*09 40 DEG e/ [UP SNOS TVD=6291 TUD=l1951 DEP=9505 ~ / ~]NG ~ ~=6444 ~D=12ISI D~=9834 i I I I I 1 I I I I 1 I I I I I I' I I I I I mi I ' 1 ] ~00 3~0 40~ ~00 5~0 SS~ ~ &~O 7~0 7~ ~ ISO0 %~ ~e~icol ~ecflon on 1~6.11 ozimufh with reference 0.00 N, 0.00 [ from slof ~8 SOO ... .. - O o 'I EBEIVED S EP 2 5 1992. Oil & Gas Oons. Gom~m~'m~ · ,.5o Anohora~o 4-6.50 43.50 ~- 40,50 I I I I 9~0o toooo I . . e . o 10. 11. 12. 13. 14. 15. 16. 17. 18. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 2M-08 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4' hole to 9-5/8" surface casing point (4194')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (12151') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7' casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) Pressure test to 3500 psi. ND BOPE and install lower production tree assembly. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. RECEIVED s E P 2 5 1992 Alaska Oil & Gas Cons. Commissio~ Anchorage DRILLING FLUID PROGRAM Well 2M-08 'Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8' surface casing 9.0-9.6 15-25 15-35 50-100' 5-15 15-40 10-12 9.5-10 _+10% Drill out to- weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 10.0 10-22 8-20 35-50 2-4 4-8 4-6 thru Kuparuk 9.5-1~3 <12% Drilling Fluid System; Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulationS stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1620 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 2M-08 is 2M-09. As designed, the minimum distance between the two wells would be 14.9' @ 325' MD. The wells would diverge from that point. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4hr) in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 80-100 sec/qt to drill gravel beds. RE( EIV£D S E P 2 5 1992 Alaska Oil & Gas Oons. Oomm'tss~On Anchorage 20" DIVERTER SCHEUATIC 6 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES 5 4 5 5 IV~INTENANCE & OPERATIC~ 3 1. UPON INITIAl. INSTN/ATIC~. CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. . DIVERSION. ARC, O ~ elC.. F:EOUEST S APPROVAl. OF THIS DIVERTF~ SYSTEM AS A VAI:UANC~ ~ 20AAC2S.O3S(b) 1. 16' CONEXJCTOR 2. SUP~ WELD START1NG HEAD 3. FMC OlVERTER ASSEMBLY wrrH TWO 2-1116'- 2000 PSI BALL VALVES 4. 20' . 2,000 PSI DRILLING SPOOL Wn~ TWO10' OUTLETS, 5. 10' HCR GATE VALVES WITH 10' DIVERTER UNES, A SINGLE VALVE OPENS AUTOMA~Y UPON CLOSUFIE'OF ANMJLAfl PflEVENTE~ VALVES CAN BE REMOTELY CONTI:K~LED TO ACHI~ DOWNWIND D~ERSK:~. sEPt 5 't9°~ Alaska,0il h Gas Cons. - 'AnchOrage 7 , 6 5 4 2 1 1.CHECK AND RLL ACCUMJU~TOR RESERVOIR TO ~ LEVEL WITH HYORAUUG R.UID. 2. ASSURE THAT ACCUMUU~TOR PRES~,URE IS 3000 I~1 ~ 3 C~SERVE TIME. TI. IEN ~ ALL UNIT~ StMIA. TANEO. I~Y ANO RECORD THE TIME AND PRESSURE REMAINING AFTER NJ. UNII~ ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTAEt. E LOWER UMT PRESSURE. ~ ST~,CK ~ST 1. FILL BOP STACK AND MANI~ WITH ARCTIC DIESEL 2. CHECK THAT ALL HOLD-DO~ SCREWS ARE FULLY RETRACTED. PREDETER~NE OEPTH THAT TEST PLUG WILL SEAT ANO SEAT IN WELLHEAD. RUN IN LOCK-OOWN SCREWS IN HEN). 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. & TEST AU. ~ENT~ TO 250 I:)SI AND H(:X.D FC:X:110 MINUTES. INCREASE PRE~SURE TO ~ ~ AND HOlD FOR ~ MINUTE~. BLEED TO ZERO P~ ~ OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVE[ & CLOSE TOP PIPE RAMS ANO HCR VALVES ON KlM. AND CHOKE UNE[ 7. TEST TO 250 P~ ANO 3{XX) P~I A~ IN STEP 4. CONTINUE TESTING ALL VALVES, UNE~ AND CHOKES WITH A 250 ~ LOW AND'3{X~ P~ HIGH. TEar A~ IN STEP 4. 00 NOT PRESSURE TEST & ANY CHOKE TI~AT I~ NOT A FULL C.,I.C~ING I~O~TIVE SEAL CHOKE. OPEN TOP PIPE ~ ANO CLOSE BOTTC~ PIPE RAMS. TEST BOTTOM ~ RAMS TO 250 ~ AND 3~0 PS[ OPEN PIPE RAMS. BACKOFF RUNNING JT AND PUM. OUT OF HOLF_ tO CL~ BLIND RAMS AND TF. ST TO ~ ~ F(~R 10 I~NUTES. BLEED TO OPEN BUND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD 11. AND 12. UNES ARE FULL OF AJ:lCTIC DIE~'L ANO AU. VALVES ~ SET IN THE TEST STANDPIPE VAlvES TO ~ PSI. TEST KELLY COCKS ANO INSIDE ~ TO ~ I~1 wrrH ~ PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORI~ AND SEND TO ORII.LING SUPERVISOI~ PERFORM COM~ BOPE TEST ONCE A WEEK AND FUNCTIONALLY I ECEIVE, D S E P 2 5 ;992 Alaska 0ii & Gas Cons. Commission Anchorage Casing Design/Cement Calculations 24-Sep-92 WellNumber:'---: ................ 2M-08 J Surface Csg MD: 4,194 ft Surface Csg TVD: Production Csg A MD: Production Csg A TVD: Production Csg B MD: Production Csg B TVD: Top of West Sak, TMD: Top of Target, TMD: Top of Target, TVD: Estimated Mud Weight: Surface Casing Choice: Production Csg A Choice: Production Csg B Choice: Production Casing Frac. Pressure 2,737 ft 6,010 ft 3,479 ft 12,151 ft 6,444 ft 2,368 ft 11,789 ft 6,167 ff 10.0 ppg ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: *ar Ii~f[i~!~[~[~[ii~::ii~i~[~i~!~[!~ii~i~i~![i~i~[~ii~[~i~i~ See Page 4 i~iiiiilili?=i=:i:=i::iiiiiii::iiiiiiiiiiiiliiiii ifil ii ii ii iiiii ~For Casing Choices 3,500 psi Maximum anticipated surface pressure TVD surface shoe = 2,737 ft {(13.5'0.052)-0.11}*TVDshoe =[ 1,620 psiI Estimated BH pressure at top of target zone Anticipated Mud Weight = Top of Target Zone, TVD = 100 psi Overbalance = :[ 10.0 ppg 6,167 ft 3,207 psi 3107 psiI Surface lead: Top West Sak, TMD = 2,368 ft Design lead bottom 500 ft above the Top of West Sak = 1,868 ft Annular area = 0.3132 cf/If Lead length * Annulus area = 585 cf Excess factor = 15% Cement volume required = 673 cf Yield for Permafrost Cmt = 2.17 Cement volume required =[ 310 sxJ Surface tail: TMD shoe (surface TD - 500' above West Sak) * (Annulus area) Length of cmt inside csg Internal csg volume Cmt required in casing Total cmt Excess factor Cement volume required Yield for Class G cmt Cement volume required = 4,194 ft = 729 cf = 80 ft = 0.4257 cf/If = 34 cf = 763 cf = 15% = 877 cf = 1.15 =1 7so sxl Casing Design/Cement Calculations 24-Sep-92 Production tail: TMD = 12,151 ft Top of Target, TMD = 11,789 ft Want TOC 500' above top of target = 11,289 ft Annulus area (9" Hole) = 0.1745 (TD-TOC)*Annulus area = 150 cf Length of cmt wanted in csg = 80 ft Internal csg volume = 0.2148 Cmt required in casing = 17 cf Total cmt = 168 cf Excess factor = 15% Cement volume required = 193 cf Yield for Class G cmt = 1.23 Cement volume required =[ 160 sxJ TENSION - Minimum Design Factors are: T(_ob)=l.5 and T0s)=l.8 Surface (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =1 916000 lb 4,194 ft 40.00 Ib/ft 167760.0 lb 24952.6 lb 142807.4 lb 6.4] Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ 979000 lb 4,194 ft 40.00 Ib/ft 167760.0 lb 24952.6 lb 142807.4 lb Production A (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =1 604000 lb 12,151 ft 26.00 Ib/ft 315926.0 lb 47648.2 lb 268277.8 lb 2.3] Production A (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ S EP ?- 5 1992 Alaska 0ii & Gas Cons. 2 'Anchorage 667000 lb 12,151 ft 26.00 Ib/ft 315926.0 lb 47648.2 lb 268277.8 lb 2.5! Casing Design / Cement Calculations Production B (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = 'Tension (Pipe Body) = Design Factor =[ Production B (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 BURST-Minimum Design Fa~t~r = 1~ E ~ E IV E Surface Casing: Burst = .Maximum surface pressure S E P 2 5 1992 Casing Rated For: Max Shut-in Pres = Design Factor Alaska Oil & Gas Cons. Commiss'too Production Csg A: Anchorage 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For: Inside pressure = Outside Pressure = Net Pressure = Design Factor =[ Production Csg B: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For: Inside pressure Outside Pressure Net Pressure Design Factor COLLAPSE - Minimum Design Factor = 1.0 Surface Casing 1. Worst Case - Lost circulation and casing pressure = 0 2. External pressure =Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =[ · Production Csg A1. Worst Case- Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For.' Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 Production Csg B 1. WOrSt Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =[ 24-Sep-92 415000 lb 6,141 ft 26.00 Ib/ft 159666.0 lb 24081.0 lb 135585.0 lb 3.1J 490000 lb 6,141 ft 26.00 Ib/ft 159666.0 lb 24081.0 lb 135585.0 lb 3.6] 5750 psi 1620.3 psi 3.5J 7240 psi 5309 psi 1610 psi 3699 psi 2.01 4980 psi 6851 psi 2982 psi 3869 psi 1.3J 3090 psi 0.520 Ib/ft 1423 psi 2.2J 5410 psi 0.520 Ib/ft 1809 psi 3.01 4320 psi 0.520 Ib/ft 3351 psi 1.3J ,Casing Design / Cement Calculations 24-Sep-92 Surface Casing Choices OD ID I b/ft Grade Metal X-Section Jt Strength Body Strength Collapse 1 9.625 8.681 47 L-80 13.5724 sq. in. 1161000 lb 1086000 lb 4750 psi 2 9.625 8.835 40 L-80 11.4538 sq. in. 979000 lb 916000 lb 3090 psi 3 9.625 8.921 36 J-55 10.2545 sq. in. 639000 lb 564000 lb 2020 psi 4 10.750 9.950 45.5 J-55 13.0062 sq. in. 931000 lb 715000 lb 2090 psi Burst 6870 psi 5750 psi 3520 psi 3580 psi ProductiOn Casing Choices OD ID I b/ft Grade Metal X-Section Jt Strength Body Strength Collapse I 7.000 6.276 26 L-80 7.5491 sq. in. 667000 lb 604000 lb 5410 psi 2 7.000 6.276 26 J-55 7.5491 sq. in. 490000 lb 415000 lb 4320 psi Burst 7240 psi 4980 psi RECEIVED SEP 2 § 1992 Alas~ Oil & Gas Cons. C0mmissi0. N~h0rage ITEM (1) Fee (2) Loc , ** CHECK LIST FOR NEW WELL PERMITS ** APPROVE DATE '['2 thru · 2. 3. 4. 5. 6. 7. 8. (3) Admin Ex¢¢/¢~.r 9. '[~ -~h u 10. 11. [ 10 & 13] 12. 13. , 14. [14 thru 22]' ~ 15. [ 23 thru (5) BOPE 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Company YES Is permit fee attached ............................................... Is well to be located in a defined pool .............................. Is well located proper distance from property line ................... Is well located proper distance from other wells ..................... Is sufficient undedicated acreage available in this pool ............. Is well to be deviated & is wellbore plat included ................... Is operator the only affected party .................................. Can permit be approved before 15-day wait ............................ ~ , Lease & Well NO Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease ntrnber appropriate .......................................... Does well have a unique name & ntrnber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old well bore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~ .~r_lP .psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... REMARKS (6) Other /~?¢'c). [ 29 th (7) Contact ~~/~3 (8) Ad,dl d geo 1 ogy' eng i neet i ng: B~ JDH~~ LAG rev 08/18/92 jo/6.011 29. 30. 31. 32. 33. FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones .............. If offshore loc, are survey results of seabed conditions presented... Name and phone number of contact to supply weekly progress data ...... /- / ,/ Add i t i ona 1 requ i rements ....................... ..................... Additional remarks' INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA # SHORE ,, Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special'effort has been made to chronologically organize this category of information. ****************************** COMPANY NA~E = ARCO AbASKA F~ELD NANE : KUPARUK BOROUGH ~ NORTH SEOPE STAT~ ~ ~LAS~A AP! NUMBER : 501032018400 ~EFERENCE NO ~ 93506 INC. IS Tape Verification Listing chlum'ergerb Alaska ComPuting Center 12-NOV-1993 1!:16 **** REEL HEADER SERVICE NAME : EDIT D~TE : g3/11/12 ORIGIN : FbIC REEL NAME : g3506 CONTINUATION # PREVIOUS REEL : COMMENT : ARCO ALASKA, INC,, KUPARUK RIVERw 2M-08, 50-103-20184-00 ~*~* TAPE HEADER SERVICE NAME : EDIT DATE : 93/11/]2 ORIGIN : F~IC TAP~ NAME : 93506 CONTINUATION ~ : PREVIOUS TAPE COMMENT : ARCO ALASKA, INC,, KUPARUK RIVER, TAPE HEADER KUPARUK RIVER CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: L~GGING COMPANY~ T PE CREATION DATE: JOB NUMBER, LOG~!NG~ ENGINEER: OPERATOR WITNESS: SURFACE 50CATION SECTION~ TOWNSHIP~ RANGE: FNL: FSL: FE~: F~L: EL~V~TION(FT FROM ~$b O) KELLY BUSHINg: DERRICK FLOOR: GROUND hEVEb~ WELL CASING RECORD 1 ST STRING 2ND STRING ,]RD STRING PRODUCTION STRING 01032018400 ARCO S~LUMBERGER WELl SERVICES 12NOV~9~ 93506 G, JOHNSON D, PETRA~H 27 11N 114 109 147 O0 147 O0 106 O0 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (iN) DEPTH (FT) WEIGHT (LB/FT) 8,500 .,000 12!3 ,0 26;00 URVE SHIFT DATA ,, Abb PASSES TO STANDA. RD(~EASURED DEPTH) PAGE: IS Tape Verification Distlng chlumberger Alaska Computing Center BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: CET LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBERJ 1 DATE LOGGEDJ 15-N0¥-92 LOGGING COMPANY: SCHLUMBERGER 12009 11972 11927 11884 11849 11805 11786 5 11729 0 11707 0 11689 5 !164 5 !160~ 5 11584 0 0 1151~0 1 I~,422.0 1. 400.5 11379;0 1.1373'0 1,1366.5 11161;0 11308;5 11264~0 11251'0 112~4,5 !1~19 5 11175 5 1156 5 11133 5 11097 0 11087 5 !10~g 0 100 0 NE DEPTH $ 0 0 RE~ARKS: 12-NOV-1gg3 wELL S~RVICE$ ----------EQUIVALENT UNSHIFTED GRCH 88887.0 12008.5 11~72.0 !1 26.5 11884.5 11848,5 1! 6.0 11728.0 11705,5 1168~,5 1164 .5 11600.0 11582'~0 11518.0 11489'5 1 1420.0 ~1466'0 1398,5 1377'0 :i I371'5 1364'0 ~1359'5 1306..~ 1262' 1249.'0 1233'5 !1217,5 I173,5 i1153'5 11135'5 11131.5 11095.0 26,5 97,5 11:16 DEPTH---------- THE DE. TH ADJUSTMENTS SHOWN AB~)VE RRFbECT THE GRCH OF PASS 1 TO THE CASED HOLE C_ET/GR- ALL OTHER HLDT CURVES INCLUDING THE LATERAL AVERAGED~CURV'ES WERE CAREIED WITH THIS SHIFT. PREVIOUSLY. PASS 2 AND PASS 3 WERE SHIFTED. TO P~SS 1 WHEN THE CU~VE~ WERE~CORRECTED. THU S. SHIFTING BETWEEN PASSES'WAS NOT REQUIRED AT THIS TIME, PAGE{ Tape Verification Listing chlumberger AlasKa Computing Center 12-NOV-1993 11{16 PAGES **** FILE HEADER **** FILE NAME t EDIT ,001 SERVICE t FbIC VERSION : O01CO1 DATE : 93/11/12 MAX REC SIZE { !024 FiLE TYPE : LO LAST FILE ~ FILE HEADER FILE NU~BER~ EDITED CURVES De th shifted and clipped curves for each pass in separate ~iles, PASS ~UMBER.~ 0,5000 DEPTH INCREMENT{ # FILE SUMMARY LDWG TOOL CODE ~LOT $ START DEPTH I~04 0 STOP DEPTH ~o~9~.e o # CURVE SH[FT DATA - PASS TO PASS(MEASU~ED~ DEPTH) BASELINE CURVE FOR SHIFTS ~DW~ CURVE CODES GRCH PASS NUMBER~ 1 # -'--~.'''--EOUIVALE,T UNSHIFTED DEPTH---''---'- BASELINE DEPTH GRCH HL~T. $ THIS rthE CONTAINS THE FIRST P~SS OF TME HLDT' AND REM~EKS~ :NO PASS TO'PASS'SHIFTS ~ERE APPLIED- TO THE DATA, THE GECh,CET IS CONTAIHED IN THIS PASS, LIS FORMAT DATA DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB.** TYPE REP~.COD~ vAhUE i 66 0 2 66 0 3 73 28 IS Tape Verification Listing ChlUmberqer Alaska Computing Center 12-NOV-lg93 1]~t6 PAGE: TYPE REPR CODE ALUE 4 66 1 5 66 6 73 7 65 9 65 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API AP1 API APl FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # bOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 440633 O0 000 O0 0 1 I 1 4 68 0000000000 RHOB HSDN G/C3 440633 00 000 00 0 1 I 1 4 68 0000000000 DRHO HSDN G/C3 440633 O0 000 00 0 I I I 4 68 0000000000 PEr HSDN BN/E 440633 O0 000 O0 0 I I I 4 68 0000000000 TENS HSDN bB 440633 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH HSDN GAPI 440633 O0 000 O0 0 1 I I 4 68 0000000000 GR CET GAPI 440633 O0 000 O0 0 1 1 I 4 68 0000000000 ** DATA ** TENS:~HSDN 999~ 50 GRCH,HSDN -999:~. : 0 GR,CET 6t,28! H, DM -.0 492 P:EF,HSDN 33,954 TENS.HSDN 374~,,:000 RHOB,HSDN 2- 'S . ~ENS:;HSDNDEP?. 1~*: 000 RHOB.HSDN . ~ DRHO,HSDN '0' 579. PEF.HSD~ 40,.000 DEPT.:~i ~0000.000 RHOB*:HSDN -999.250. DRHO,::HSDN -999-250 PEF.HSDN -999-!250 TENS'HSDN '999,250 GRCH.HSDN -999*250 GR:.Cg? 8~.063 9000,000 RHOB.,HSDN -999.250 DRHO,HSDN -999'250 PEF.HSDN ~:~999.250 TEEs.DEPT'HSDN. -999.250 GRCH.HSDN -999.:250 GR.CET ~09'500' DEPT' 89841':000 RHOB.:HSDN -999.250 DRHO.HSDN -999.250 PEF.HSDN -999.:250 TENS:HSDN -999.250 GRCH*.HSD~ -999'.250 GR.CET 100,688 Tape Verification Listing chlumberger AlasKa Computing Center 12-NOV-lEg3 11:16 PAGE: ** END OF DATA *~** FILE TRAILER FILE NAME : EDIT ,001 SERVICE : FbIC VERSION : O01COI DATE : 93/11/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 93/11/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER FIbE NUMBERi 2 EDITED CURVES Depth shifted and clipped curves for each pass in. separate files, 2 0.5000 pASS NUMBER: DEPTH INCREMENT: #I F~'L~ SUMMARY LDWG TOOL CODE GRCH HLDT START DEPTH 12038,0 12064.0 STOP DEPTH t~998,0 1.998,0 CURVE SHIFT DATA = PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SWIFTS LDWG CURVE CODE: GRCH PASS. NUMBER{ 1 ----------EOUIVALENT UNSHEFTED DEPTH'------.--- BASELIN~ DEPTH GRCH HLDT $ REMARKS*, THIS FILE CONTAINS THE SECOND PASS O.F THE HbDT,. AND NO PASS TO PASS SHIFTS WERE APPLIED TO THE DATA, $ IS Tape Verification bistina cblumberger Alaska Computin~ Cester 12-NOV-!g93 11:16 PAGE.{ # LiS FORMAT DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VAbUE 1 66 0 2 66 0 3 73 24 4 66 1 5 66 6 73 7 65 tl 66 42 1~ 68 !3 66 0 14 65 FT 15 66 68 16 66 1 o 66 1 ** SET TYPE - CMAN ** NAME SERV UNIT SERVICE APl AP1 AP,I API FIbE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EbBS CODE (HEX) DEPT FT 440633 O0 0.00 O0 0 2 I ! 4 68 0000000000 RMOB ~SDN G/C3 440633 O0 000 O0 0 2 I 1 4 68 0000000000 DRHO ~SDN G/C3 440633 O0 000 O0 0 2 I I 4 68 0000000000 PEF HSDN BN/E 440633 O0 000 O0 0 2 1 I 4 68 0000000000 TENS HSDN LB 440633 O0 000 O0 O 2 1 I 4 68 0000000000 G~CH HSDN GAPI 440633 O0 000 O0 0 2 1 ,1 4 68 .0000000000 DRHO,HSDN ,,0,302 PEF'HSDN 25' 938 iis ?ape Verification Listing chlumberger Alaska ¢omputinq Center DEPT 110o0 000 TENS~HSDN 3215'.000 12-NOV-199) !1~16 DEPT. 109B5.500 TENS.HSDN -999.250 ** END OF DATA ** · RHOB.HSDN 2.396 DRHO.HSDN GRCH.HSDN 76.000 RHOB.HSDN -999.250 DRHO.HSDN GRCH,HSDN -999.250 -999.250 PEF.HSDN PEF.HSDN PAGE= 37.594 '999.250 **** FILE TRAILER FILE NAME : EDIT ,002 SERVICE : FDIC VERSION : O01CO1 DAT~ : 93/11/1,2 MAX REC SIZE : 1024 FIDE TYPE : LO **** FILE HEADER FIb~ NAME : EDIT .003 SERVICE : FDIC VERSION : 001C0i DATE : 93/11/t2 ~AX REC SIZE : t024 FILE TYPE : LO LAST FILE FILE HEADER FIbE NUMBERI 3 EDITED CURVES Depth shifted and, clipped curVeS' for each Pass ~n separate files,?~ P~SS NUMBER: 3 ' DKPTH INCRfMEN?: 0,5000 # Flbg SUMMARY 5DWG TOOL CODE GRCH ~LDT $ START DEPTH 12020.0 12048,0 STOP DEPTH 10998,0 10998 ,:0 CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 ---=------E~UIVALENT UNSHIFTED BASELINE DEPTH GRCH HLDT IS Tape Verification Listing chlumberger Alaska Computing Center $ # ~EMARKS: THIS FILE CONTAINS THE NO PASS TO PASS SHIFTS LIS FORMAT DATA 12-NOV-~993 ~1:!6 THIRD PASS OF THE HbDT WERE APPLIED TO THE DA~A. PAGES ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 2 66 0 3 73 24 4 66 { 5 66 ? 65 8 68 0 5 1~ 66 42 1~ 68 13 66 0 ~4 65 FT 15 66 68 16 66 ~ 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API APl API FILE NUMB NUMB SiZE REPR PROCESS ID ORDER ) bOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 440633 O0 000 O0 0 3 ! I 4 68 O000000OO0 R. HOB HSDN G/C3 440633 00 000 00 0 3 1 1 4 68 0000000000 DRHO HSDN G/C3 440633 O0 000 O0 0 3 1 I 4 68 0000000000 PEF HSDN BN/E 440633 00 000 O0 0 3 I ! 4 68 0000000000 TENS HSDN 5B 440633 00 000 00 0 ) 1 1 4 68 0000000000 GRCH HGDN GAPI 440633 O0 000 00 0 3 1 I 4 68 0000000000 ** DATA ** DEPT,: 1~064-000 RMOB'HSDN -999,~50 T~NS,MSDN '999,250 GRCM'HSDN -999,~50 -999.250 PEF.HSDN -999-25~0 IS Ta~e Verification Listing Chlum erqer Alaska Computing Center l~-NOV-~993 11:~6 PAGE; DEPT. !2000.000 RHOB.HSDN 2.378 DRHO.HSDN -0 ]17 PEF HSDN 29.O78 TENS,HSDN 3225,000 GRCH.HSDN 62.482 DEPT' 11000,000 RHOB.HSDN 2.407 DRHO,HSDN -0,368 PEF HSDN 40,000 TENS,HSDN 3010,000 GRCH,HSDN 73.375 DEPT, i0985.500 RHOB.HSDN '999.250 DRHO.HSDN -999.250 PEF HSDN '999'250 TEN$.HSDN -999.250 GRCH.HSDN -999o250 END OF DATA **** FILE TRAILER FILE NAME ~ EDIT SERVICE : FLIC VERSION : 001C0! DATE : 93/!1/!2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE _**** FILE HEADER **m, FILE NAME ~ EDIT ,004 SERVICE : FLIC VERSION : OOiCO FILE TYPE : bO LAST FILE : FILE HEADER FILE NUMBER: 4 AVERAGED CURVES ~o~pe~sated Neutron~ Arithmetic average of edited:passes for all curves u~$ed Neutron, Unaveraqed~ edited. PaSf ~ Gamma Ray and baCkround coUntS~ arithmetic average _ of editedstatfc base ~e passes for all Other curves., ' - PASSES !NCLUDED~ IN AVERAGE LDWG TOOL CODE PASS NUMBERS MLDT ~, 2, 3, $ REMARKS: THIS FILE CONTAINS THE LATE~RAL .A¥~RAGE DATA, LIS FORMAT DATA Tape Yerification Listing chlumberger Alaska Computing Center 12-NOV-lgg3 11:16 PAGE:. 10 DATA FORMAT SPECIFICATION RECORD SET ~memm T TYPE - 64EB ** YPE REPR CODE VALUf 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 ? 65 1! 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 1 ** SET TYPE - CHAN ** DEPT FT 44063 00 000 00 0 4 1 I 4 6.8 0000000000 RHOB MLAV G/C3 440633 00 000 00 0 4 I I 4 68 0000000000 DRHO ~LAV G/C3 440633 O0 000 00 0 4 1 1 4 68 0000000000 G~CH HSDN GAP! 440633 O0 000 O0 0 4 I I ,4 68 0000000000 DATA DEPT. DEPT, DgPT, D£PT, 12064.000 ooo.ooo 1 1000,000 10985,500 GRCH.HSDN GRCH.H$.DN GRCH, HSDN GRCH,HSDN 6 6.6.2 5 60. 659 79,125 74,000 Tape Verification f, lsting ChlUmberger AlasKa Computing Center 12-NUV-1993 11:16 PAGE: **~* FII, B TRAILER FILE NAME : EDIT ,004 SFRVICE : FLIC VERSION : O01CO1 DATE : g3/11/12 ~X RFC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT ,005 S~RVICE : FLIC VERSION : 001C01 DAT£ : 93/11/12 MAX R£C SIZE : 1024 [I~E TYPE : LO AST FILE : F!LE HEADER FILE NUMBER 5 RAW CURVES Curves and log header data for each pass in separate PASS NU~BER~ 1 DEPTH INCREMENT: 0,5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH GRCH 12065.0 HLDT 12050,0 $ LOG HEADER DATA DATE LOGGED: To. BOTTO~ ~OG iNTER , ., F): LOGGING SPEED (~PHRI: DEPTH CONTROL U ED YES/NO): STOP DEPTH 1098 ~, 0 10990,5 TOOt STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE HLDT CASING COLLAR LOG HLDT TELEMETRY CARTRIDGE HLDT GAMMA RAY H~DT HLDT HLDT ~LDT files; re. back,round, pess in lest. fi 15-N0¥-92 !oo 45,0 o0;,0 15-Nov-g2 TOOL NUMBER CAb'YA' 29 TCC-B-2~6 SGC-SA-59 HLDV-A.A-19 HLDC-AA-20 IS Tape Verification Listing chlumberqer AlasKa Computing Center 12-NOV-1903 11:16 PAGE= 12 HLDT HLDT $ HLDS-BA-20 BOREHOLE AND CASING DATA OPEN HOLE BlT SIZE (IN): DRILLERS CASING DEPTH LOGGERS CASING DEPTH (FT); 12 25 4 s °.o BOREHOLE CONDITIONS FLUID TYPE: BOTTOM HOLE TEMPER T RE (DEGF)= FLUID LEVEb FLUID RATE AT WELLHEAD CHO~E BRINE 10.00 -10.0 163,0 NEUTRON TOOL TOOL TYPE (EBITHERMAL OR THERMAL): NEITHER MATRIX: SANDSTONE MATRIX DENSITY{ 2,65 HOLE CORRECTION (IN): BLUELINE COUNT RATE. NORMALIZATION IN OIL zONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT BLUELiNE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE FAR COUNT RATE HIGH SCALE NEAR COUNT RATE LOW SCALE (CPS TO0~ STANDOFF (IN): RE~ARK$= PRIMARY DEPTH CONTROL USED: MAGNETIC MARKS RAN THREE PASSES AT 900 FPH CALIPER MOT OPEN FOR $ LIS FORMAT DATA Tape Verification Listing chlumberger Alaska Computing Center 12-NOV-lgg] 11:16 ** DATA FORMAT SPECYFICATION RECORD ** ** SET TYPE = 64EB ** '''''''''''''''~.''~'''''''''''TYPE RE V~LUE 66 2 66 0 3 73 92 4 66 5 66 6 73 7 65 8 68 0,5 9 65 FT 11 66 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 ** SET TYPE - CHAN ** · NAME SERV UNIT SERVICE AP1 API &PI API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL£M CODE (HEX) DEPT FT 440633 O0 000 O0 0 5 I 1 4 68 0000000000 LSRH Hbl G/C3 440633 O0 000 O0 0 5 1 I 4 68 000000'0000 SSRH Hbl G/C3 440633 O0 000 O0 0 5 1 1 4 68 0000000000 PEFL HLI 440633 O0 000 O0 0 5 1 1 4 68 0000000000 PEFS HL1 440'633 O0 000 O0 0 5 1 I 4 68 0000000000 PEF HL.t 440633 O0 000 O0 0 5 I I 4 68 0000000000 LSW1 Hbl CPS 440633 O0 000 O0 0 5 1 I 4 68 0000000000 LSW2 Hbl CPS 440633 O0 000 O0 0 5 1 ! 4 68 0000000000 LSW] Hbl CPS 440633 O0 000 O0 0 5 1 I 4 68 0000000000 bSW4 Hbl CPS 440633 O0 000 O0 0 5 I 1 4 68 0000000000 LSW5 HLI CPS 440633 O0 000 O0 0 5 1 i 4 68 0000000000 SSWI HL1 CPS 440633 O0 000 O0 0 5 I I 4 68 0000000000 $SW2 Hbl CPS 440633 oo 000 O0 0 5 I i 4 68 0000000000 S$W3 Hbl CPS 440633 O0 000 O0 0 5 1 I 4 68 00~00000000 SSW4 HL1 CPS 440633 00 000 O0 0 5 I I 4 6'8 0000000000 SSW5 HL1 CPS 440633 O0 000 O0 0 5 1 I 4 68 0000000000 RHOB HL1 G/C3 440633 O0 000 O0 0 5 1 I 4 68 0000000000 DRHO Mb! G/C3 440633 O0 000 O0 0 5 1 1 4 68 00000.00000 CS HL1 F/HR 440633 O0 000 O0 0 5 1 I 4 68 0000000000 T~N5 HLI LB 4406]3 O0 000 O0 0 5 1 I 4 68 0000000000 CAUZ .Ul I~ 440633 oo 000 oo 0 $ I I 4 68 0000000000 oR .ui GAPI 4406,~3 oO 000 O0 0 5 I 1 4 68 0000000000 CCh Hbl V 44063,3 O0 000 O0 0 5 I 1 4 68 0.000000000 PAGEt 13 IS Tame verification ListinO chlumberger Alaska Computing Center ** DATA DEPT 12065,000 LSRH,HLI PEFS~HL1 -999,250 PEF.HLI SSW2:HL! -999.~50 SSW3,HL1 RHOB,HL1 -999.250 DRHO,HLI CALI,HL1 -999.250 GR,Hb! DEPT, 12000,000 PEFS,HL1 37 064 PEF,HL1 LSW3.HL1 609~969 SSW2.HL1 1839.031 SSW3,HL! RHOB,HL1 2,221 DRHO,HL1 CAL~.HL1 6.002 GR,Hbl DEPT 11000'000 LSRH,Hb! PEF$iHLI 40.000 PEF.HL1 LSW3 HL! 390,250 LSW4,HL1 $SWi,HL1 1100.000 SSW3.Hbl RHOB.HLI ~,261 DRHO,.Hhl CALX,HL1 ,969 GR,HL1 DEPT', 10985,500 LSRH,HL! PEFS,HL! 40,000 PEF,H51 LSW3'H.LI. 625,000 LSW4.Hhl SSW'2~HL1 'I508'000 SSW3.HLI RHOB,HL! 2,148 DRHO,HL1 CAL~I,HLI 6-004 GR'HLX END OF DATA FILE NA~E ~ EDIT ,005 SERVICE { FLiC VERSION : 001C01 DAT~ : 9~/11/12 FILE TYPE : LO **** FiLE FILE SERVICE VERSION DATE ~aX REC SiZE FILE TYPE LAST FILE HEADER **** : BD!T .006 : Fb~C : 001C01 : 93/11/12 : !:024 12-NOV-1993 11:16 -999 250 $SRH.HLi -999:250 LSWi.HL1 -999.250 LSWL.HL1 -999.250 '999.250 CS.Hbl 66,625 CCL,HL1 2.712 SSRH.Hbl 33.984 I, SW1,HLI 435,141 LSW5,Hbl 4826,141 $$W4,HLI '0.492 C$,HLI 59.938 CCL.HLI 2.840 SSRH.HL1 40,~00 bSWI.HL1 322. O0 LSW5 HLI 3750,0~0 $$W4 -0,5 9 C$.HLI 79.438 CCL.HL1 2,~2 SSRH.Hbl 40, 0 L$~I.HL1 483'750 LSW5,HL! 4660'000 SSW4.'HLI '0,525 '999.250 CCL'HLI 99 250 -999.250 .999.250 999,250 3..413 126,766 388,813 2029,063 886,500 -0.044 3 662 10.3 125 364 500 !903 000 888 500 0 :!2.3 3 .500 '250 2029.000 881.,500 -0'014 PEFL.HLI LSWI.HLI SS~I.HI,,1 TENS.HLI PEFb. Hbl LSW2.HLI $$W5,Hbl TENS,HbX PEF[,..HLI LSW2.HbX SSWI:,Hi~I SSWL,Hbl TEN$'Hbl PEF~.Hbl DSW2'Hbt SSWL:'HbI TENS,ab! PAGE~ 14 '999,250 -999.250 -999,~50 -999, 50 -999,.250 33.984 29!,359 53 ,625 20 374 .563 40~000 160,125 430,000 189,875 3140'000 40,000 272,250 513' 000 IS Tape Verification Listinq chlumberger AlasKa Computlnq Center 12'NOV-1993 11:!6 PAGEt 15 FILE HEADER FILE NUMBER 6 RAw CURVES Curves and log header data for each Pass in separate PASS NUNBER= DEPTH INCREPENT= 0.5000 # FILE SUNMARY VENDOR TOOL CODE START DEPTH GRCH ~2061,5 HLDT 12061.5 LOG HEADER DATA DATE ~OGGED~ SOFTWARE VERSION~ TINE LOGGER ON BOTTONt TD DRILLER TD LOGGER(FT)= TOP LOG INTERVAL (FT)~ ~OTTO~ L~G INTERVAL LOGGING SPEED (FPHR)~ DEPTH CONTROL USED (YES/NO): STOP DEPTH 10990.5 10990,5 15-NOV-g2 2100 12045,0 12046 0 11000~0 04~ 0 I~0o NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOl.., TYPE TOOL NUMBER mmmmm~mmmmmmmmmm mmmm~m~mm~ b LDT CAS! O CO',LAn 0G , ~bO.T TELEMETRY CARTRIDGE TCC-B-2?6 HLDT *GAMMA RAY SGC-SA-59 ,bDT HLDT HLDV-AA'19 HbDT HLDT H~DC~AA-20 HLDT HLDT HLDS BA-20 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH CFT): files; raw backoround pass in last-f~ BOREHOLE CONDITIONS FLUID TYPE~ FL:UID DENSITY (LB/G): , SURFACE TEMPERATURE (DEGF),, . BOTTO~ HOLE TEMPERATURE (DEGF): FLUID SALINITY FLUID LEVEL FLUID RATE AT WELLHEAD (BPS): WATER CUTS (PCT){ GAS/OIL RATIOt CHOKE ~EuTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL)I 15-NOV-92 1.2,250 4253,0 BRINE !0.00 ',1 _0,00 163 ' NMITMER ?ape verification bistinq chlumverger Alaska Computinq Center 12-NOV-lg93 11:16 MATRIX: MATRIX DENSITY: HOLE CORRECTION SANDSTONE 2,65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW BASE NORMALIZING WINDOW BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CP$)~ FAR COUNT RATE HIGH SCALE NEAR COUNT RATE bOW SCALE (CPS), NEAR COUNT RATE HIGH SCALE TOOL STANDOFF ~EM~RK$~ PRIMARY DEPTH CONTRO~ USED~ MAGNETIC NARKS RAN THREE PASSES AT 900 FPH CALIPER NOT OPEN FOR lST 45' ON PASS $ FORNAT DATA ** DA~A F~RMAT SPECIFICATION RECORD I 66 0 66 0 ] 73 92 4 66 5 66 6 73 7 65 8 68 0~5 9 65 F' 11 66 12 68 ii 66 0 1 65 FT 15 66 68 16 66 0 66 I PAGEI 16 IS Tape Verification Listing Chlumberger Alaska Computing Center 12-NOV-1993 11:16 PAGE: 17 ** SET N~E SERV UNIT SERVIC~ ID ORDER # DEPT FT 440633 LSRH HL2 G/C3 440633 SSRH HL2 G/C3 440633 PEFL HL2 440633 PEFS HL2 440633 PEF HL2 440633 LSWl HL2 CPS 440633 LSW2 HL2 CPS 440633 LSW3 HL2 CPS 440633 bSW4 HL2 CPS 440633 LSW5 HL2 CPS 440633 SSW1, HL2 CPS 440633 SSW2 HL2 CPS 440633 $8W3 Mb2 CPS 440633 SSW4 Mb2 CPS 440633 SSW5 HL2 CPS 440633 RHOB HL2 G/C3 440633 DRHO HL2 G/C3 440633 CS HL2 F/HR 440633 ?~NS HL2 bB 440633 CALl HL2 IN 440633 G~ HL2 GAPI 440633 CCL HL2 V 440633 API API APl AP1 FILE NUMB bOG TYPE CLASS MUD NUMB SAMP m~mm~m~mmmm~m~mmm~mmmmmmmmmmmmm NUMB SIZE REPR P~OCESS EbEM CODE (HEX) O0 000 O0 0 6 1 I 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 I ! 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 I 4 68 0000000000 O0 000 O0 0 6 I 1 4 68 0000000000 O0 000 O0 0 6 1 I 4 68 0000000000 O0 000 O0 0 6 I I 4 68 0000000000 00 000 O0 0 6 1 I 4 68 0000000000 O0 000 O0 0 6 1 I 4 68 0000000000 00 000 00 O 6 1 1 4 68 O000000000 00 000 O0 O 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 00 000 00 0 6 I I 4 68 0000000000 00 000 00 0 6 I I 4 68 0000000000 00 000 00 0 6 ! t 4 68 0000000000 00 000 00 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 I 1 4 68 0000000000 00 000 00 0 6 1 I 4 68 0000000000 00 000 O0 0 6 I ! 4 68 0000000000 00 000 00 0 6 1 1 4 68 0000000000 O0 000 00 0 6~ 1 .I 4 68 0000000000 ** DATA DEPT LSW3.HL~ SS'W2,HL2 RHOB,Hb2 CALI,~HL2 DEPT. PEF$,H'b2 LSW3.HL2 SSW2.Hb2 CA6 .H6 D'T 68W} H~2 RHO8 CA6! H62 : oo 202!.100 1 5.473 12000.000 22,:~734 821.,O00 1972,000 2',072 5,465 11000.000 40 ~084 000 5.97 LSRH HL2 PEF HL2 ~SW4 HL2 ,SW3 ~L2 DRHO HL2 GR H62 LSRH Hb PEF HL~ LSW4 HL2 SSW3 HL2. DRHO .HL2 GR HL2 6SPH.H62 PEF..HL2 6$~4~HL2 SSW3 HL2 DRHO:HL2 GRoHL2 596 SSRH.H62 3.273 549.000 LSWS.HL2 579.000 s{s .6 -o ssw4 .ooo sswS.H 5 CS.HL2 4 .000 . TENS.Hb2 607 5132 -O 61 384 3700 ~]~ SSRH.HL2 ~ 31! PEF~.H62 LSWI.HL2 19 :!25 LSW2.HL2 ooo sws.. 2 s4 .soo sswl.. g~O $SW4,HB2 2003'000 SSW5,,L2 2 CS,HD2 8~.500 TENS;.HL2 soo ccu..u .oi 7 SSRH.HL2 LSW5.HL2 · SSW4.HL2 .~25 CS'.Hb2 . 00 CCLo.HL2 3 66~ 115 68 40.5:500 1804 000 904 000 0 239 PEF~ HL2 H6 sw2 SSWl SSW5 HL2 TENS Hb2 37'12:5 42,4~250 561.000 286-000 ! ss ooo ~6,,250 179:;000 256,000 36~0'000 t95,750 187'000 32i5,000 IS TaPe Verification bisting chlumberqer AlasKa Computinq Center 12-NOV-1993 11:16 18 DEPT, bSW3 Hb2 S$W2 Hb2 RHOB Hb2 CAb! HL2 10990.500 !,SRH.HL2 40.000 PEF.HL2 615,500 bSW4.HL2 1438.000 SSW].HL2 2.124 DRHO.HL2 6.000 GR,HL2 2.668 SSRH HL2 40.000 bSWl:Hb2 484.500 LSW5,HL2 4504.000 SSW4eHL2 -0.545 C$.HL2 75.750 CCL,HL2 LSW2.HL !! SSWl,HL SSW5,HL 40.000 263,750 496,500 199,750 3280,000 END OF DATA ***~ FILE TRAILER **** FILE NAME : EDIT ,006 SERVICE : rblC VERSION : 001C01 DATE : 93/11/12 MAX REC SIZE : 1024 FIL~ TYPE : bO bAST FILE : **~* FILE HEADER FILE NAME : EDIT ,007 SERVICE : FLIC VERSION : 001C01 DATE : 93/1!/12 MAX AEC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NUMBER RAW CURVES Curves and log header data for each Pass in separate PASS NUMBER: 3 DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GRCH 12050,0 1098890,5 HLDT 12065,0 10988,0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTD~: TD DRILLER (FT) TD LOGGER(FT]I files:;* raw ~ack'qround 'pass in last "ti 15-NOV-92 12046 I$ Tame Verification Llstlnq chlumbe~ger AlasKa Computln~ Center 12-NOV-!g93 11:16 PAGEI 19 HLDT HLDT HLDT HLDT HLDT HLDT $ TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CASING COLLAR LOG TELEMETRY CARTRIDGE GAMMA RAY H5DT HLDT HLDT BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G){ SURFACE TEMPERATURE (DEGF) BOTTOM HOLE TEMPERATURE (DEGF) FLUID SALINITY (PPM){ FLUID LEVEL (FT)~ FLUID RATE AT WELLHEAD WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEL): NEUTRON TOOL TOOL TYPE CEPITHERMAL OR THERMAL) MATRIXI '~ ~ ' MATRIX DE. SITYI HOLE COR~RECTION (IN): ~MARKS: 1000,O ]204t.0 900.0 NO TOOL NUMBER CAL-YA-229 TCC-B-276 $GC-$A-59 HLDV-AA-19 HLDC-AA-20 HLDS-BA-20 12 25 BRINE 10,00 10,0 ]'63.0 NEITHER SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZINO WINDOW (FT): BASE NORMALIZING WINDOW BLUELIN~ COUNT RATE,SC LES SET BY F!E~D ENGINEER FAR COUNT RATE LOW &CANE (CPS): F~R COUNT RATE HIGH, SCALE' NEAR COUNT RATE LOW SCA,LE (CP~}~, NEAR COU~ RAT~ HIGH SCALE (CPS). TOOL STANDOFF (IN): PRIMARY DEPTH CONTROL USED: MAGNETIC MARKS RAN THREE PASSES AT 900 FPH CALIPER NOT OPEN FOR IST 45' ON PASS #2 $ ,IS Tape Verification Listing ,chlumberger AlasKa Computing Center 12-NOV-J993 I~:16 PAGE{ ¸.20 # bis FOR~.AT DATA DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB *~ TYPE REPR CODE VALUE mmmNmmmmmmmmm~m~memmmmmmmmmmmm i 66 0 2 66 0 3 73 92 4 66 5 66 6 73 ? 65 8 68 0,5 9 65 FT 12 68 13 66 0 ~ 66 68 66 66 ** SET TYPE - CHAN ** ' NA~E SERV UNIT SERVICE API API API AP1 FILE NUMB NUmB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUmB SAMP~ ELE~ CODE (HEX) O0 000 O0 0 ? 1 i 4 6.8 0000000000 ' 0000000000 DEPT LSRH HL3 SSRH HL3 PEF Hb3 LSW! .b3 LSW2 HL3 LSW3 HL3 LSW4 Mb3 bSW5 HL3 SSW4 Mb3 S$W5 DRHO HL3 CS FT 440633 G/C3 440633 O0 00.0. O0 0 G/C3 440633 O0 000 O0 0 440633 O0 000 O0 0 4406~ O0 000 O0 0 440633 O0 000 O0 '0 CPS 440633 O0 00'0 O0 0 CPS 440633 O0 000 O0 0 CPS 440633 O0 000 O0 0 CPS 440633 O0 000 O0 0 CPS 440633 O0 000 O0 0 CPS 440633 O0 000 O0 0 CPS 440633 O0 000 O0 0 CPS 4406.33 O0 000 O0 0 CPS 440633 O0 000 O0 0 CPS 440633 O0 000 O0 0 G/C3 440633 O0 000 O0 0 G/C3 440633 O0 000 O0 0 F/HR 440633 O0 000 O0 0 LB 440633 O0 000 O0 0 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 6¸8 8 68 68 68 68 68 68 68 68 68 68 68 68 68 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 000000000:0 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 IS TaPe Verification Listing chlumberger AlaSKa Computing Center 12-NOV-1993 11:16 PAGE~ 21 ID ORDER # LOG TYPE CLASS MOD NUmB SAMP ELEM CODE (HEX) '~;~'"'.~i"" i;"' ;;;~'"'"'"'"'""'"'""'"""'""'""""""'"'"'"'"'"'o oo o 7 ~ ~ ~ oooooooooo ~ .~ ~ ~o~ oo ooo oo o 7 ~ ~ ~ 6~ oooooooooo cc~ .~ ~ ,~o~ oo ooo oo o 7 , t ~ ~ oooooooooo DATA DEPT. PEFS.HL3 LSW3 Hb3 SSW2 HL3 RHOB HL3 CALl HL3 EPT, EF$.HL3 bSW3.HL3 SSW2.~h3 RHOB,HL3 CALI,HL3 DEPT,~ PEFS,H~3 SSW2.HL3 R. HOB.HI~) CAhI,HL3 P~FS'HL3 SSW2,HL3 RH. OB.'Hb) CAL!,Hh. 3 12050.000 bSRH.Hb3 32.063 PEF.Hb3 575.500 LSW4.Hb3 1888.000 $$W3,HL3 · 2,270 DRHO.HL3 5-934 GR,HL3 12000 000 LSRH..HL3 622'500 LSW4.HL3 1857'000 SSW3'HL3 11000.000 LSRH,HL3 40.000 P~r. Hb3 446'750 bSW4.Hb) 1096,000 SSW3'Hb3 2,~53 DRHO.HL3 6,..)63 GR.HL3 1091~,500 LSRH.Hb3 · 000 PEF,HL3 593~000 LSW4,HL3 i425'000· 88W3*BL3' 2.736 SSRH.Hb3 6.438 bSWi.Hb3 379.250 LSWS.HL3 4904.000 $$W4.HL3 -0'468 CS,Hb3 56.313 ¢CL.Hh3 2.7i3 SSRH,Hb3 29~O78 bSWX.HL3 44 .000 LSWS,Hb3 48~.'ooo ssw4.a~3 ,487 C$~Hb3 61,406 CCL'Hb3 2.~70 SSRH,Hb3 40..00 LSWI.Hb3 3398,500 LSW5,.HL3 778,000 88W4'Hb3 '0..:617 CS,Hb3 80.688 CCL'Hb3 2.680 $$RH'Hb 40.000 LSWI.Hbl 466'000 LSW5'Hb3 45~4.000 SSW4.Hb3 0,543 CS,HL3 73.313 CCL*HL3 3.404 PEFb'HL3 130.125 bSW2.HL3 412,500 SSW1,HL3 2070,000 3~6°500 TENSoHb3 0.O17 3,406 PEFb,HL3 147,.375 LSW2'Hb3 397,000 SSWl.,Hb3 2034~000 SSW5,Hb3 881.500 TEN$'Hb~ 0,089 98'!88 LSW2*Hb3 390'250 1809.000 SSWS-Hb3 902.000 TENS.Hb3 0':t74. 3,453 pEFb,HL3 144~125 LS~2,Hb3 495:.500 SSW1.HL3 1986.000 SSWS'Hb3 903.500 TENS,Mb3 0.055 ,250 553,000 222,625 1355.000 29,078 304:'~50 559,000. 215,875. 3225;000 40'000 184,~75 42b:,.~50 189.'000 30i0.000 40'000 267'500 503,000 194'250 3055.000 END OF DATA **** FIBE TRAILER **** FIb~ NA~E : EDIT ,007 SERVICE I FblC V~RSlON : 001C01 D .TE : 93/11/!2 ~AX REC SlZ~ : 1024 F!hf TYPE ~ LO LAST FILE : IS Tame Verification bistln~ chlumberqer Alaska ComPutin..~ Center 12-NOv-1993 11:16 PAGE: 22 ~** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 93/11/12 ORIGIN : FLIC TAP~ NAME : 93506 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA, INC,, KUPARUg RIVER, 2~-08, 50-103-20184-00 **** R~EL TRAILER SERVICE NAME : EDIT DATE : 93/11/~2 ORIGIN : FbIC REEL NAmE : 93506 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA, INC,, KUPARUK RIVER, 2M-08, *''''''' SCHLUMBERGER FIELD NAME { KUPAR~UK RIVER BOROUGH { NORTH SLOPE RECEIVED DEC 0 7 1992 Alaska Oil & Gas Cons. Commission Anchorage IS TaPe Verification Listing chtumberger Alas~ca CompUting Center 24-N0¥-1992 09~50 **** REEL HEADER SERVICE NAM~ : EDIT DATE : 92/11/23 ORIGIN ~ FLIC REEL NAME ~ 92667 CONTINUATION # : PREVIOUS REEL COMMENT : ARCO ALASKA, INC,,KUPARUK RIVER $~RVICE NAME : EDIT DATE : 92/11/23 TAP~ NAME : 92667 CONTINUATION # P~VIOUS TAPE COMMENT TaPE HEADER KUP~RUK RIVER UNIT MWD/MRD LOGS # WELL NAMES API NUMBER~ OPERATO~ LOG~I, NG coMPANY~ TAP~ CREATION DATE) ~OB DhT~ JDOB NUMBER) OGLING ENGINEER: OPERATOR WITNESS) $.IRFACE BOCATION SECTION: TOWNSHIP~ PEG:' ~L,EVATION(FT FROM MSL O) KELLY BUSHING~ DERRICK FLOOR; GROUND LEVELS' 2~-08 50tO32018400 ARCO ALASKA · ~L£ $~RVICES 23-NoV-g2 # W~I~L cASInG RECO~D STRING STRING 9~667 92667 92667 JACKSON J~CK$ON JACKSON BERRY BERRY BERRY 27 lIN 114 !09 147.00 147.00 106.00 OpEN HOLE CASING DRILLERS BlT SIZE (IN) SIZE (iN) DEPTH (FT) 9,625 4253,0 PAGE~ IS Ta~e Verification 61st~n~ ChlUmber~er Alaska Computino Center 24-NOV-1992 09:50 ]RD STRING PRODUCTION STRING EM~RKS~ FIELD ENGINEER'S REMARKS: RUN ~ --> RGS READOUT PORT TO BIT: 68.9'. GR TO BIT 76,9 o RES TX BiT 6~,6'; CASING DID NOT PASS TEST' fid~0TAGE DRILLED. *** NO LOG GENERATED RUN 2 --) RGS READOUT PORT TO BIT{ 68.9', GR TO BIT 76,2'. RES TO BIT 65.6'. FOOTAGE DRILLED FROM 4253' TO li909'. RON.] --) RGS READOUT PORT TO BIT 48"0', GR TO BIT 76.2'~ RES TO BIT 44,8'. WASHDOWN FROM 11689' TO li709 , ~OOTAGE DRILLED FROM 11709' TO 12151'- GAMMA ~AY INTERMITTENTLY ~AILED FROM OCK$ ENCOUNTER TO ~1790' DUE TO HIGH DOWN MOLE S WHILE D~ILLING THE BOTTOM OF THE A SAND. DOWNHOLE DATA RECORDED AT 20 SECONDS' DATA FROM DDWNHOL~ MEMORY, SOFTWARE V2.~D/4,0C $ FILE NAME : EDIT .00! SERVICE ~ FLIC V~RSION : 00lA07 D~T~ ~ 92/1!/23 ~AX REC SIZE , ~0~4 FI~ TYPE ~ LO PAGEI FILE ~E~DER~ Oeoth shifted and clkpped Curvesl al! b~t runs merqed. ~wD 4~5).0 1215!,0 $ # ~VE S~IFT DATA'"(M~ASUR~D DEPT ' · ' '. -.= ---'-- UIVALENT UNSHIFTED DEPTH ~ASELINE DEPTH 88888,0 !1999'0 1~931,0 11888 5 I 26 0 11793 0 MWD 888g5 ooo:s 1933,0 .189~.0 1848,5 .!83~,5 11798.5 IS Tape Verification Listing cblumberger Alaska Computing Center ]1780 5 ]1724 5 ]1702 5 ~1700 0 ~1643 0 11613 5 ~1584 0 ~1576 0 11546 0 1146! 5 11449 0 ~435 5 ~1410 0 ~1~79 0 11358,0 !~48,0 11309 5 295~0 1276,0 I1241.5 il!SO It 126,0 t092,0 I1080,5 .1020,5 I0962 0 ~0896 5 10852 0 ~083~ 0 ~0787 5 10 5 1050 ,0 10281;0 !0215,,0 !0128 0 Igo, o OO8 0 9977 0 9833 9718 0 9606 5 94950 93940 9338 5 11786,0 1173~,0 1170 ,0 11705,5 11688,5 11648,5 11620 0 11589i5 11582 5 11552,0 11468,0 11455,0 11441.0 11416 0 11385:0 1137i,5 11364,0 11354 0 11324~5 11313 0 1129915 !!2 ,5 .° 1249.5 ~!210'0 11 !1131,5 !1096,0 1085 5 !024 5 0967 0 ~0900 0 10854 0 t0B37,0 10~ 5 10596,5 !0562'0 10511 0 10491 5 038! 5 ~028! 5 10220 5 10134 5 10069 5 10013 0 988 9840 5 9724~0 9612,5 9500,0 9402 0 9~4~:5 24-NOV-1992 09:50 PAGE{ IS Taue Verification Listing chlumbercerAlaslce ¢omputlnO Center 24-NDV-1992 09:50 9313 5 9115 0 9099 0 90?7 0 9004 0 100 0 $ ~ERGED DATA 80URCE KRU TOOL CODE WWD MWD REMARKS) 9319,5 912~ 0 9010,0 106.0 BIT RUN NO, MERGE TOP 2 4253,0 3 I1709,0 MERGE BASE 11709,0 1215i.0 THE DEPTH SRIFT$ ABOVE REFLECT MWD GR TO CASED HOLE GR FROM CET/CBT RUN ON 15-NOV-g2 PER DON WObCOTT.. Abb OTHER CURVES WERE CARRIED WITH THE GR SHIFT. THIS FILE CONTAINS THE GR AND RESISTIVITY SAMPLING TICKS GTCK & RTCK, THE SAMPLING TICKS ARE MEASURED AT A VARIABLE RATE. HOWEVER. THE TICKS IN THiS FILE ARE REPRESENTED AT .5 FT DUE TO DEPTH ADJUSTING THE DATA IN THIS FILE.!"THE T ICKS WILL APPEAR IN THE NEXT FILE AT 'I FT WHICH WILL MORE CLOSELY REPRESENT THE ACTUAL SAMPLE RATE.: THIS MODIFIED LDWG FORMAT WAS DISCUSSED WITH DON WOLCOTT, S FOR A? pAGEI DATA FORMAT SPECIFICATION RECO~D ** ** SET TYPE - 64EB ** , TYPE . REPR.CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 ! 5 66 6 73 7 65 8 68 0 5 11 66 36 1~ 6~ 13 66 0 14 65 FT 15 66 68 16 66 0 66 0 ,IS Tape Verification Listing ~Chlumberger AlasKa Computing Center I~ OR~ER # LOG TYP D~P? FT 618978 O0 000 O0 RTCK MWD $ 618978 O0 000 O0 GTC~ MWD S 618978 00 000 00 RR ~WD OHMM 618978 O0 000 O0 RP MWD OH~ 618978 O0 000 O0 ~OP ~WO F/HP 618978 O0 000 O0 GR ~WD GAP! 618978 O0 000 O0 24-NUV-1992 09~50 PAGEI mmmmmm--mmm~'mm#mm~mmemm.mmmmm.emee~MNmm~M~#.)#e~mmmm! I API AP1 FIL~ NUMA NUMB $IZg R~PR PROCES& E C5A$$ MOD NUMB $~MP EL£M .CODE (HEX) 0 t 1 1 4 6B 0000000000 0 1 ! 1 4 68 0000000000 0 I 1 ! 4 68 0000000000 0 I 1 i 4 68 0000000000 0 1 1 ! 4 68 0000000000 0 I ! 1 4 68 0000000000 0 I I I 4 68 0000000000 mmmmmmm~m--m'~#mm~mm.~mmmmmmmmm~m~mmmm~~mm~m~mm R.. -999~50 ROP MWD DEPT i2000.000 RTCK.NWD AP:MWD ~.156 ROP,MWD OEPT 1180~.000 ~TCK.~WD ~P:MWD .748 ROP.MWD DE~T. 1~600,000 RTCK.MWD RP,MWD ~.430 ROP.~WD Of P?, 11400 000 RTCK'MWD R . wo 2:85! ' ~200,000 RTCK,MWD DeP?-MWO 3.546 ROP MWD AP, DEPT · 11000.000 RTCK,MWD RP~MWD 3.680 ROp~MWD DEPT, 10800,000 RP.MWD 2'81! ROP.MWD D~PT' 10600,:000 RTCK'MWD RP.MWD 3,454 ROP,NWD DE~T. !0400,000 RTCK,MWD R~,MWD 2,'305 ROP,~WD DEPT !0200,000 RTCK,~WD RP:MWD 4.524 ROP~MWD DEPT. 10000.000 RTCK'~WD RP.MWD 4,579 ROP'~WD -999,~50 GTC~ MWO -999.250 RA'MWD -999 250 MWO i.O00 RA.,WD 2,272 -g99,250 GTCK,Mwo 200,016 GR, 98.758 , ,~WO 76.082 ' t3. '070 · .MWD 207~875 !45, GR:MWD 274'745 · '999.250 GTCK.MWD -999'250 RA MWD ],417 99.969 GR.MWD 106.844 ,.ooo 15 . GR.MWD 116.238 ' ' 15~.00:0 GTCK.~WD -999.2.50 RA.ffWD 2,503 .889 GR,MWD !41.980 1.000 OTCK MWD '999 250 RA'MWD 4'460 259.539 " :MWO I0 : 76 ' -999,250 GTCK,MWD -999,250 RA,~WD 3,834 167,656 GR'MWD 120,656 IS Ta~e Verification Listing chlUmbeTger Alaska Computing Center 9800,000 RTCK,MWD 3,655 ROP,~WD 9600,000 RTCK,~WD 3,344 ROP,MWD 9400,000 RTCK,MWD 4.056 ROP,MWD 9200,000 RTCK.MWD 3,990 ROP,MWD 9000.000 RTCK.MWD 5.338 ROP.MWD 8800.000 ~TCK.MWD 5.368 ROP.MWD 8600.000 RTCK.MWD 2.573 ROP.MWD 8400.000 RTCK.MND 3.257 ROP. 8200.000 RTCK MWD 2,383 ROP:MWD 8000.000 RTCK,MWD 5,112 ROP.MWD 097 R'OP.MWD 7600.000 RTCK.MWD 4.053 ROP.~WD 7400 000 RTCK.MWD 7200 000 RTCK.MWD 4:294 ROP.MWD 7000.000 RTCK.MWD 3.361 ROP.~WD 6800.000 RTCK MWD 3.268 ROP:~WD 6600.000 RTCK.MWD 3.239 ROP,MWD 4oo ooo .Tc DEPT, RP,MWD DEPT. RP,~HD DEPT. RP.MWD RP.MWD R DE~T. RP.MWD DEPT. RP.MWD DEPT, RP,MWD DEPT, RP,~WD DgPT, RP,MWD RP.MWD DDPT, RP.MW'D D~PT, RP,MWD DFPT. RP,MWD DEP?. RP.MWD RP,MWD 24-NDV-t992 09.'50 -999.250 GTCK MWD 148,988 18 836 GR,MWD -999.250 GTCK.MWD 292.309 GR.MWD 1.000 GTCK.~WD 195.492 GR.MWD 14~.000 GTCK.MWD ,783 GR,MWD 23~.~0 GTCK,MWD , 3 GR,MWD .000 GTCK MWD 32 ,598 GR:MWD l.ooo CTCK 211.22V OR: WU -999.250 438.214 GR,.MWD '999,250 GTCK.MWD 367.056 GR.MWD MWD -99 . 6 GR,MWD -999,250 GTCK,~WD ~88,968 GR,MWD -999,250 GTCK,MWD 272.358 GR'MWD -999 2~0 GTC'K.~WD 269:4.3 GR,MWD -999,~50 GTCK,MWD 71. oo . 59 GR,~W~ 1,000 95,035 -999.250 97,823 -999.250 130,605 -999,250 i30,622 -999,250 149.103 -999,250 131.:109 -999,250 13~,390 =999,250 !18.072 1 ~000 1.ooo 86.498 .999'250 135,783 l:.O00 89.282 '999.250 100'596 !.000 96.969 ~ O0 1 ~00 RA.MWD RA.MWD RA.MWD RA.MWD RA,MWD RA.MWD RA.MWD RA,MWD RA,MWD R~,MWD RA.MWD RA,MWD RA'MWD RA'MWD RA.MWD EA.MWD RA,MWD PAGE{ 3.775 3,503 ; 3,528 3.915 4,279 4,299 2,571 2.890 2,259 s'oSs 3.56'! 3.800 4,129 3,~488 3,142 IS TaPe Verification t, isting chlumberger AlasKa Computing Center DEPT 6200.000 RTCK,MWD ~P:MWD 3,247 ROP.MWD DEPT, 6000,000 RTCK,MWD RP,MWD ),9~7 ROP,MWD D~PT. 5800,000 RTCK,MWD RP,~WD 4,059 ROP,MWD D~P? s4oo.ooo RTCK MWD DEPT, 5200,000 RTCK,MWD RPoMWD 4,356 ROP,MWD DEPT. 5000 000 RTCK.MWD D~PT 4BO0,O00 RTCK MWD RP~WD ' . 43 ~OP,~WD DEPT, 4400,000 RTCK,MWD R~,MWD 4,454 RO~,MWD DEPT 4200'000 RTCK'MWD DEPT, 416!,000 RTCK'MWD RP,MWD ~999,~50 ROP,MWD END OF' DATA ****. FILE TRAILER FIL~ NAME : EDIT ,00! V~R$ION : O0~A07 DATE : 92/l!/~3 MAX REC SIZE : I0~4 FIL~: TYPE : LO LAST'FILE 24-N0¥-~992 09:50 -999 ~50 GTCK,~WD ~99:119 GR,~WD 44 649 GR,~WD 1.000 GTCK,MWD 155.8~9 ~R,MWD -999,~50 GTCK,MWD 316.877 GR,MWD -999 2so cTc~ .w~ -9 o -999 150 GTCK,MWD 398:99 GR,MWD ~09~ 54 GR,~WD -999,~50 GTCK'MWD 600,80~ GR'MWD -999, ~TCK,MWD 0 GR,MWD -999,~50 'GTCK,MWD ~999,250 -999.250 95.t07 t.000 78.325 -999.250 88,898 -999.250 89.734 1.000 96.581 1.000 !28.070 1,000 102.236 -999250 9~:.o~ 1.000 92.366 .~..~So 50.085 -999'250 RA,MWD RA.MWD RA.MWD RA.MWD RA.MWD RA.HWD RA.MWD RA.MWD RA,MWD ,, RA,MWD RA,MWD RA.MWD PAGE: 3.075 3,773 4,006 3'562 3,755 4.234 3,592 3,537 4,5i6 0~'053 '999,250 Tape Verification Listing chlumberger Alaska Computing Center 24-NOVo1992 09:50 $*~ FILE HEADER ~*** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001A07 DAT~ : 92/11/23 MAX AEC SIZE : 10~4 FYLE TYPE : LO LAST FILE : FILE HEADER rILE NUMBER 2 RAW MWD Curves and log header data for each bit run In separate files, BIT RUN NUMBER: DEPTH INCREMENT: 0.1000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH CDR 4253.0 $ LOG HEADER DATA DATE LOGGEDI SOFTWARE SURFACE SOFTWAR~ DOWNHOLE SOFTWARE V~RSIONI DATA TYPE (MEMORY OR REAL-TIME): TD LOG~ER~FT)I(FT TOP LOG INTERVAL (FT):T( 80TTOM LOG INTERVAL PIT ROTATIONAL SPEED NOLE INCLINATION (DEG) ~INIMUM ANGLE~ PAXI~U~ A~GLEI TOOL STRING (TOP TO BOTTOm) VENDOR TOOL CODE TOOL TYPE CDR RESISTIVITY $ AND CASING DATA. D~ILLERS CASING DEPTH ~T)~ BOREHOLE CONDITIONS ~UD TYPE: DENSITY (LB/G): VISCOSITY PH~ STOP DEPTH 12151,0 FAST 2-3D 0 ~0 TOOL NUMBER RG$058 5OO I0,00 IS Tare verili¢~tlo~ Listin~ ,ChlUmbergerA. laska Computing Center 24-NOV-lEg2 09:50 MUD CHLORIDES FLUID LOSS M~XIMUM RECORDED TEMPERATURE (DEGF): 145.0 RESISTIVITY (OHMS) AT TEMPERATURE (DEGF): MUD AT MEASURED TENPERATURK (MT): 2,650 72.0 MUD AT NAX CIRCULATING TEMPERATURE: MUD FILTRATE AT (MT): 2,950 72.0 MUD CAKE AT NEUTRO~ TOOt MATRIX: SANDSTONE ~ATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 8,500 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: THIS FILE CONTAINS THE GR AND RESISTIVITY SAMPLING TICKS FOR RUNS 2 & $ LIS FORMAT DATA DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64ES ** TYP~ REPR CODE VALUE ! ~6 0 · 7~ !2 4 66 255 5 66 6 7 65 8 68 0 1 ~! 66 85 12 68 t3 66 0 !4 65 FT 15 66 68 16 66 1 0 66 I ,IS TaPe Verification Listing 'ChlUmberger AlasKa Computing Center 24-NOV-1992 09~50 PAG£1 ** SET TYPE - CHAN *~ mm~mNmmmmmmmmmmmmmmmmmmmmmmmmm~mmmmmm~mmm~mm~m~mmmm~m~mmm~mm~m~m~m~m~m~mmmmmm 8ERV UNIT SERVICE APl API APl API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EbEM CODE (HEX) ~,~,8~7. ooooo oo o ~ , , ~ ~ oooooooooo 001 $ 61"978 O0 000 O0 0 2 ~ 1 4 68 0000000000 ~I ~ ~78 oo ooo oo o ~ ~ ~ 4 ~, oooooooooo m~m, mmmm mmmmmm~mmmmmmmmmNmm~mmmmmmm~mmmmmm~ mm~m~mmmmmmmmmmm~mmmmm~s~mmmmmmmm ** DATA ** DEPT, 4182,800 RTCK,00! =999,250 GTCK,001 1.000 DEPT, 4199.900 RTCK.O01 -999,250 GTCK,OOi -999,250 DEPT. 42o0.10! RTCK.O01 -999.250 ~TCK.O0i DEPT, 4399.900 RTCK,OO1 -999,250 GTCK.O01 1,000 D~PTo 4400,!01 RTCK.O01 -999.250 GTCK,O01 1,000 DEPT. 4599.900 RTCK.O0! -999,250 GTCK,O01 '999.250 DEPT. 4600.101 RTCK.O0! -999.250 GTCK,O01 '999.,250 D~PT, 4799,900 RTCK,O01 -999,~50 GTCK.O01 -999.250 D~PT, 4800,101 RTCK,O0! -999,~50 ~TCK.O01 -999.250 DEPT, 4999,900 RTCK,O01 -999,250 GTCK,O0! -999,,250 DEPT. 5000,101 RTCK,O0! -999.250 GTCK,O01 1.000 DEPT' 5199.900 RTCK.001 1.000 GTCK.001 1.000 DEPT. 5200.101 RTCK'001 1.000 GTCK.00i ~.000 DEPT" 5399,900 RTCK,O01 -999.250 GTCK'O01 1,000 DEPT, 5400.10i RTCK"O01 -999,250 GTCK,O0! 1.,000 .' DEPT. 5599.900 RTCK.O0~ '999,250 GTCK,O01 -999~250 DEPT. 5600,!0! RTCK.00! -999,250 GTCK,O01 '999.~50 DEPT. 5799,900 RTCK'OOi -999,~50 GTCK.O01 1.000 D~PT, 5800,i01 RTCK"O01 '999,250 GTCK'.OOX 1,000 DEPT, 5999'900 RTCK'O01 -999,~50 GTCK.O01 '999,250 10 IS Tape Verification bistlng chlumber~er Alaska Computing Center DEPT, 6000,101 RTCK,O01 D~PT. 6199,900 RTCK,O01 DEPT, 6200.101 RTCK,O01 DEPT, 6399,900 RTCK,O01 DEPT, 6400,I01 RTCK.O0~ DEPT. 6599,900 RTCK,OOI D~PT, 6600,101 RTCK,O0~ D~PT, 6799.900 RTCK.O0! DEPT, 6800.101 RTCK.O01 D~PT. 6999,900 RTCK.O01 DEPT. 7000.101 RTCK.OOI DEPT. 7199,900 RTCK.O0! D~PT, 7200.101 PTCK.O01 DEPT. 7399,900 RTCK,O01 DEPT, 7400,10! RTCK.O01 DEPT, 7599,900 RTCK.O01 DEPT, 7600.101 RTCK.O01 DEPT, 7799'900 RTCK,O01 DZP'T, 7800,101 RTCK.O01 D~PT, 7999,900 RTCK.O0! D~PT, 8000,!01 RTCK,O0! DTPT. 8199'900 RTCK,O0t DEPT, 8200,100 RTCK,O01 D~PT, 8399,900 RTCK.O01 DEPT. 8400.I00 RTCK,O0! D~PT, 8599,900 RTCK,O01 24-NOV-1992 09:50 -999.250 GTCK,O0! 1.000 GTCK,O01 =999,950 GTCK,O01 -999,250 GTCK,O01 -999,250 GTCK,O0! -999,250 GTCK.O0i -999,250 GTCK.O0! -999,250 GTCK,O01 -999.250 GTCK,00~ -999,250 GTCK.O0~ -999,250 GTCK,O0! -999,250 GTCK,00! -999.250 GTCK,O0~ -999,950 GTCK,O01 -999,250 GTCK,OO! -999,250 GTCK,OOI -999,250 GTCK,001 1,000 GTCK,O01 1,000 GTCK,O0! -999.250 GTCK,O01 '999,250 GTCK,O0! -999. o TC .O0 -999,250 GTCK,O0! 1,000 GTCK,O0! -999,250 GTCK,O0! -999,~50 GTCK.O0! =999.250 1.000 1.000 1.000 1.000 1.000 -999.~50 -999.250 -999,250 -999.250 -999.250 -999,250 1,000 1,000 -999.250 -999.250 '999,250 -999,~50 i.O00 1'000 '999.250 '999.250 1,000 i,O00 '999'250 PAGEI ii Tape Verification Listlng chlumberger Alaska Computing Center DEPT, D~PT. DEpT. DEPT. DEP?, D~PT. DEPT, D~PT. DEPT. D~PT. DEPT, DEPT. DEPT. DEPT. D~PT, D~PT, D~PT, DEPT, D~PT' DEPT, ~600.100 RTCK.O01 8799.900 RTCK.O0! $g00.100 RTCK.O01 8999.900 RTCK,O0~ 9000.100 RTCK.O0! 9199.900 RTCK.O01 9200.100 RTCK.001 9399.900 RTCK.001 9400.100 RTCK.O01 9599.900 RTCK.O01 9600.100 RTCK.O0! 9799.900 RTCK.O01 9800.100 RTCK,O0! 9999,900 RTCK.001 !0000,100 R?CK.O0~ X0!99,900 RTCK.O0~ 10200,100 RTCK.O0! 10399.900 RTCK,O01 10400.100 RTCK.O0! 10599.900 RTCK,OO1 10600,100 RTCK.O01 10799,900 RTCK'O01 10800,!00 RTCK.O01 10999,900 RTCK,O01 1!000,!00 RTCK.O01 11199,900 RTCK.O0! 24-NOV-1992 09:50 -999.250 GTCK,O01 -999.250 GTCK,O01 -999.250 GTCK,O0! -999.250 GTCK,O0~ -999.~50 GTCK.00! -999.~50 GTCK.O01 -999.250 GTCK,O01 -999.~50 GTCK,O0! -999.~50 GTCK.O01 -999.~50 ~TCK,O01 -999.~50 GTCK.O0! '999.~50 GTCK,O01 -999,~50 GTCK,001 '999.~50 GTCK,O01 -999,~50 GTCK.00~ 1,000 GTCK,O0! 1,000 ~TCK,O0! -999.250 OTCK,O01 -999.250 GTCK,O0! -999.250 GTCK'O0I -999,250 GTCK,O0! '999,~50 GTCK.O01 -999.~50 GTCK.O01 '999,250 GTCK.OO! -999,~50 GTCK,O0! -999,250 -999,250 -999.250 -999.250 1.O00 -999.250 -999.250 -999.250 -999.250 -999.250 1.ooo -999.~50 -999.250 -999.250 -999.250 -999.~50 1.ooo !.oO0 '999.250 -999.250 i.O00 PAGE{ 12 IS Tape Ver~.ficatlon basting chlumbergerAlasKa Computing Center D~PT. 11200.100 RTCK,001 D~PT. 11399,900 RTCK,001 DEP~, I1400,100 RTCK.001 D~PT, 11599,900 RTCK,O01 DEPT, 11600.100 RTCK,O01 D~PT, I1799.900 RTCK,O01 DEPT. 11800,100 RTCK.O0! D~PT. 1!999.900 RTCK,O01 D~PT. 12000,100 RTCK.O0! DEPT, 12104,000 RTCK,O0! END OF DATA 24-NOV=1992 09:50 '999.250 GTCK,O01 1,000 GTCK,O01 -999,250 GTCK,O01 -999,250 GTCK,O01 -999,250 GTCK,001 1.000 GTCK,O0! 1,000 GTCK,O01 -999,250 ~TCK,O01 1.000 GTCK,001 1,000 GTCK,O01 1.000 1.000 i,O00 1.000 1.000 -999.250 =999,250 =999.250 '999.250 PAGEI 3 **** FILE TRAILER **** FILE NAME : EDIT ,002 SERVICE : FLIC VERSION : O01A07 DAT~ : 92/11/23 MAX REC $IZ~ : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER FILE NAME : EDIT .003 SERVICE : FLIC V~R:~ION ~ O0~A07 DAT~ : 92/11/23 MAX REC SIZE : 1024 FILE TYP~ : LO F~hE HEADER Curves and log header data for each bit run in seUarate fileS, BIT RU~ NUMBER: ~ DEPTH INCREMENT: O,$O00 IS Tape verification Listing chlumberger Alaska Computing Center 24'NOV-1992 09:50 PAGEi VENDOR TOOL CODE 8TART D~P?H CDR 4253,0 LOG H~ADER DATA PATg bOGGED: SOFTWARE SURFACE SOFTWARE VERSIONS. DOWNHObE SOFTWARE VERSIONI DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER TD LOGGER(FT): TOP LOG INTERVAL (FT): BOTTO~ LOG INTERVAL (FT)~ ~IT ROTATIONAL SPEED (R HOLE INCLINATION (DEG) MINTMUM ANGLE: MAXIMUM STOP DEPTH 11709,0 06-NOV-92 FAST 2.3D V4.0 MEMORY 1~709.0 ~1709.0 425~,0 1t70 .0 TOOL STRING (TOP TO BOTTOM) V£NDOR TOOL CODE TOOL.TYPE CDR R~SIST!VITY BOREHOhE AND CASING DATA OPEN HOLE BIT $IZ~ ~N~ DRILLERS CASING DEP~- ,rT)~ BORE!HOLE CONDITIONS ~UD TY~E: MUD DENSITY MUD VISCOSITY ~UD ~AXI~U~ RECORDED T:E~PERATURE (DEAF RESISTIVITY (OHM'P) AT TEMPERATURg DEGF)' MUD AT MgASURED TEMPERATURE MUD AT MAX CIRCULATING TE"PERATURE: MUD FILTRAT~ AT (~T)~ MUD CAKE AT (MT): NEUTRON TOOL MATRIX~ MATRIX DENSITY: ~OLE CORRECTION TOOL STANDOFF EWR FREQUENCY (HZ): REMARKS: TOOL NUMBER RG$058 8 5 .0 BRINE 10.00 145.0 2,650 2.950 'SANDSTON~ 2.65 8,500 72.0 FIELD ENGINEER'S REMARKS: RUN ~ --> RGS EADOUT 'PORT TO BIT{ 68.9' GR TO BIT 76,~ , RES TO RBIT 65.6'. CASING DID NOT ~ASS TEST.~ IS Te~e Verificetion Listinq Chlumber~er ~lesk8 Co~putin~ Center 24-NOV-1992 09~50 ND FOOTAGE DRILLED. *** NO 60G GENERATED RUN 2 --> RGS READOUT ~ORT TO DIT~ 68,9', GR TO BIT 76,2'. RES TO BIT 65.6 , FOOTAGE DRILLED FROM 4253' TO 11709', RUN 3 --> RGS_READOUT.PORT TO BIT 48.0', GR TO BIT 76.2' RES TO MIT 44,8', WASHDOWN 11689' TO 117095. FOOTAGE DRILLED FROM 11709' TO 12151', GAMMA RAY INTERMITTENTLY FAILED FROM 11731' TO 11790' DUE TO SIGN DOWN MOLE SHOCKS ENCOUNTER WHILE DRILLING THE BOTTOM OF THE A SAND, DOWNWObE DATA RECORDED AT 20 SECONDS. D~TA FRO~ DOWNHObE MMMORY, SOFTWARE V~,~D/4,0C $ FORMAT DATA PAGE~ 15 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE, VALUE 1 66 0 2 66 0 3 73 20 5 66 6 7 8 68 0 5 9 65 F~ 1I 66 51 12 68 !~ 66 0 14 65 FT 15 66 68 16 66 0 66 ** SET TYPE - CHAN ** N~ME ~ER SERVICE APl AP! . A FILE NUmB NUM'B SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EbEM CODE (HEX) o~, r. ~,,~ooooo oo o , , , ~ ~ oooooooooo ,~t. ~w~ o.~ ~,~ ooooo oo o , , , ~ 6~ oooooooooo ,s. ~w~ o... ~1,~8 ooooo oo o , , 4 6~ oooooooooo I$ Tape Verification Listing chlumberger AlasKa Computing Center ** DATA DEPT. 11708.500 ATR.LW2 G~.LW2 -999.250 DEPT, 11600,000 ATR,SW2 G~,LW2 237,211 DEPT, 11400,000 ATR,LW2 GR.LW2 234,622 D£PT, 11200,000 ATR,LN2 DEPT. 1t000.000 GR.~W2 !12,359 D~PT, 10800,000 GR,LW2 106.667 DEP' 10600 000 ATR.LW2 DEPT. 10400 000 ATR,LW2 DEPT,~ I0000 000 ATR,LW2 GR,LW2 117:567 D~T,~ 9800,.000 GR'SW2 95,388 D~PT, 9600,000 ATR,5W2 GR'bW2 97,609 DEPT, 9400,000 ATR,LW2 G~.bW2 9200 O0 ATR.L~2 D~PT, 14~,924 G~.SW2 9000.000 ATR.SW2 og: oo GR'Lw2 14. 44 oo: oo 24-NOV-1992 09~50 =99g,250 PSR,bW2 -999'250 1,603 PSR,SW2 1,776 2.433 PSR,LW2 2.893 3,075 PSR.bW2 3.t30 4,299 PSR,LW2 4'351 2,592 PSR,bW2 2.621 4,369 PSR,LW2 4.681 2.446 PSR,bW2 2.511 4.554 PSR,LW2 4,909 4.055 PSR,bW2 4'354 3,6~3 PSR'bW2 3.406 3.175 PSR,bW2 3'!7t 3,943 PSR,LW2 5.07~ 3.856 PSR,LW2 4,052 4,335 PS~,LW2 5.416 4,164 PSR,LW2 4'995 3,945 PSR,bW2 4,68t ROPE.LW2 ROPE.LW2 ROPE,LW2 ROPE.LW2 ROPE.LW2 ROPE,LW2 ROPE.LW2 ROpE.L~2 ROPE,bW2 ROPE,bW2 ROPE.~W2 ROPE'L~2 ROpE.L~2 ROpE,LW2 ROpE'~w2 ROPE,bW2 PAGEi 16 12,848 79,900 138,456 166,692 312,.024 I96,049 203'9.79 208,816 2~2,694 206'293 93.',:186 257,973: IS Tape Verification Listing chlumberger Alaska Computing Center D~PT. 8400,000 GW,LW2 139,764 DEPT, 8200,000 G .Lw2 ozP?. sooo.ooo ATR.SW2 T. ?S00.000 D~R.L~2 94,17! DZ~T 7600.000 ATR.LN2 G :[,w2 4 .050 O p? 4oo.ooo GR~LW2 87,356 DEPT, 7200,000 ATR,LW2 GR.LW2 100.028 DEPT. 7000.~00 AT~.SW2 D~PT 6800.000 ATR.LW2 DE~T,hW2 6600,000 ATR,BW2 G~, 98,545 D~PT~ 6400,000 ATR,LW2 DEPT, 6200,000 ATR,LW2 GR,SW2 99,443 DEPT, 6000,000 GR,LW2 81,630 OR,~W2 93. 1. DEPT, 560~ OO0 ATR.LW2 G~,LW2 8:745 ' O~l: 5400,000 ATR'LW2 .''SW~ 99'46! DEPT,.' !36'599 GR,Lw2 5200,000 ATR,LW2 DEPT, 5000,000 ATR.LW] GR.LW9 96.7t$ 24-NOV-Ig92 0g~50 2,907 PSR.LW2 2.045 PSR,LW2 5.161 PSR,LW2 3.440 PSR,bW2 4.292 PSR,LW2 3.69! PSR,~W2 4,030 PSR,LW2 3.382 PSR,bW2 3.244 PSR,LW2 3,09! PSR,bW2 2,962 PSR,~W2 3.056 PSR,bW2 3,745 PSR,hW2 4,06! PSR,LW2 3,587 PSR,bW2 3,718 PSR,LW2 4,656 PSR,bW2 3,745 PSR,LW2 3.t32 2.080 5.187 3.594 3,777 4.032 3'53! 3,405 3.214 3.236 3,816 4 .i 3'6 3.715 5 ' :004 ROPE.LW2 ROpE,LW2 ROPE.bW2 ROPE,LW2 ROPE,bW2 ROPE,LW2 ROPE,bW2 RoP£.LW2 ROPE.LW2 ROpE,LW2 ROPE*~2 ROpE.bW2 ROPE.LW2 aOPE*bW2 ROP~,LW2 ROPE,LW2 PAGE! 1? 416,793 346,943 402.325 421,303 253,535 . 370,949 267,862 333,g55 35t'563 409,773 428,970 431,980 I:75,,:!.42 23i'040 330,035 IS Taoe Verlflcation Listlnq chlumberger AlasKa ¢omputlnq Center 24-NOV-lEg2 09:50 18 DEPT 4800,000 ATR.LW2 GP:L~2 90.601 DEPT 4600.000 ATR.LW2 GR:bW2 90.149 DEPT, 4400,000 ATR.LW2 G~.LW2 90,991 D~PT. 4200,000 ATR,LW2 G~.LW2 51,174 DEPT, 4155,000 ATR,LW2 GR.LW2 -999.250 END OF DATA 3.804 PSR.LW2 5.884 PSR,LW2 4.610 PSR,LW2 0,063 PSR,LW2 -999.250 PSR,bW2 4.161 ROPE,LW2 5.824 ROPE,LW2 4.379 ROPE,LW2 3,040 ROPE,LW2 -999.250 ROPE.LW2 387.508 681,450 441,881 '999.250 -999.250 **** FILE TRAILER **** FILE NAME : EDIT ,003 SERVICE : FLIC V~R~ION : 001A07 DATE : 92/11/23 MAX REC $IZ~ : 10~4 FILE NAME : EDIT .004 SERVICE : Fb!C VERSION i 001A07 DAT~ ~ 9 /23 MAX AEC SIZE : 1~1 'FIL~ TYPE : LO LAST FILE FILE H~ADER FI.L~ NUMO~R 4 RAW MWD Curves and lo0 header data for each bit run in seuarate files, BIT RUN NUMBER: 3 D~PTH INCRE~ENT~ 0,5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH $ TaPe Verification Listing ;chlumberqer Alaska ComDutinq Center 24-NOV-1992 09,50 PAGEt ¸19 # bOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSIONI DATA TYPE (~EMORY OR REAL-TIME): TO DRILLER TD LOGGER(FT)I TOP LOG INTERVAL (FT), BOTTOM LOG INTERVAL (FT), 8IT ROTATIONAL SPEED (RPM), ROLE INCLINATION (DEG) MINIMUM ANGLE, MAXIMUM ANGLE{ TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ~N~mmmmmm~mm~mmmm mmmmmmmsm CDR ~$ISTIVITY 07=NOVm92 FAST 2,3D V4,0 MEMORY 12151.0 12151.0 4253.0 12151.0 TOOL NUMBER '~mmmmmmmm~mmmmmm RGSO$8 BOREHOLE AND CASING DATA OPEN HO S SIZE CZ'N) DRILLERS CASINO DEPTH (FT), BOREHOLE CONDITIONS MUD TYPE) BRINE MUD DENSITY (LB/G), !0.00 MUD VISCOSITY MUD CHLORIDES FLUID 5088 (C3). MAXIMUM RECORDED TEMPERATURE (DE~F):)E _ 145.0 RESISTIVITY (OHMM) AT TEMPERATURE (D. GF)' ,UD AT MAX CIRCULATING TEMPE~AT ,UD FILTRATE AT (MT), 2'950 NEUTRON MATRIX: MATRIX D~N$IT~ HOLE CDRR~C?ION TOOL STANDOFF EWR'FREQUENCY [INHzI, 8.500 4253.0 SANDSTONE 2.65 8,500 ~EMARKS, 72,0 72. :0 RUN:! -.-k RGS READOUT pORT TO ~IT{ 68-9'- GR TO BIT 76.2'. RES TO BIT 65.6',. ~A~iNG DID ~0~ PA~S TEST. NO FOOTAGE DRILLED. *** ~0 LOG GENERATED ***, RUN ~--> RGS READOUT PORT TO BIT, 68,~'. GR TO BIT 76,2 . RES TO BIT'65.6'. F~OTAGE'"DRILhED FROM 425.~' TO 11709'. RUN ] .-> RGS READOUT PO~ TO BIT 48.0', Tape Verification Listing chlUm.ber~qerAlasKe Computing Center 24-NOV-!992 09550 GR TO BIT 76.2'~ RES TO BIT 44,8'. WASHDOWN FRON 11689' TO 11709 , FOOTAG~ DRIL},ED FROM 11709' TO 12151'' GAMMA RAY INTERMITTENTLY FAILED FROM 11731' TO 11790' DUE TO HIGH DOWN HOLE SHOCKS ENCOUNTER WHILE DRILLING THE BOTTOM OF THE A SAND. DOWNHOLE DATA RECORDED AT 20 SECONDS. DATA FROM'DOWNHOLE MEMORY, SOFTWARE V2.]D/4.0C $ LIS FORMAT DATA PAGE~ 2O DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB TYPE REPR.CODE i 66 0 2 66 0 3 73 20 4 66 5 66 7 65 8 68 0 5 I~ 66 51 i 68 13 66 0 I4 65 FT 15 66 68 16 66 1 0 66 I ** SET TYPE - CHAN ** NAM~ SERV UNIT SERVICE API API APl API FILE NUMB NUmB $IZE~ REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUmB SAMP ELE~ CODE CHEX) O~P? FT 618978 00 000 O0 0 4 I I 4 68 0000000000 ATR 5W3 OHMM 6t8978 00 000 00 0 4 I 1 4 68 0000000000 PSR 5~3 OH~M 6i8975 00 000 00 0 4 I { 4 68 0000000000 ROP~ 5~3 F/HR 615978 00 000 00 0 4 ~ ~ 4 68 0000000000 G~ 5W3 GAP! 618978 O0 000 O0 0 4 I I 4 68 0000000000 IS Tape verification Listing chlumberger A!as~a Computing Center DEPT. 12150.500 ATR.LW3 GR.LW3 -999.250 DEPT. 12000.000 ATR.LW3 GR,LW3 I01.016 DEPT. 11800.000 ATR.LW3 GR.LW3 70.460 D£PT 11613.500 ATR.LW3 GR~[,W] 94.240 END OF DATA 24-NOV-1992 09:50 -999.250 PSR.SW3 2.225 PSR.bW3 7.964 PSR,LW3 '999.250 PSR,LW3 -999.250 ROpE.LW3 2,099 ROPE,LW3 9,621 ROPE.LW3 -999.250 ROPE.LW3 PAGE~ 21 187.$25 199,995 85.715 '999,250 *$** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE ~ FLIC VERSION ~ 001A07 D~TE { 92/ii/23 MiX REC SIZE : 1024 FILE TYPE : LO FiL~'NAME : EDIT ,005 SERVICE : FLIC VERSION : 00lA0? DATE : 92/1!/23 M~X EEC SIZE : t024 FihE TYPE' m LO LAST FILE R.AN CURVES Curves and log header data for each pass in separate ~:iles; raw background pass in DEPTH INCREMENT: -'5000 # FILE VENDOR TOOL CODE 8TART.DEPTH ~LDT L~ G HEADER DATA DATE LOGGED: SOFTWARE VERSION{ sTOP DEPTH 11000,0 15'NOV"92 CP IS ta.~ Verification ~istin~ chlumberaer AlasKa Computing Center 24-NOV-1992 09~50 PAGEI 22 TIME LOGGER TD DRILLER TD LOGGER(FT)I TOP LOG INTERVAL (FT) BOTTOM LOG INTERVAL LOGGING SPEED DEPTH CONTROL USeD (Y TOOL STRING CTOP TO VENOOR TOOL CODE NLOT HLDT HLDT HbDT HLDT HLDT HLDT HLDT ON BOTTOMI rT)l ES/NO)I BOTTOM) TOOL TYPE COLLAR LOCATOR TElEmETRY C~RTRIDG£ GAMMA RAY HLDT HI VOLTAGE HLDT CARTRIDGE RL~T SONDE GAMMA RAY SOURCE DOWMHOLE TELEMETRY 2100 12045,0 12046,0 11000.0 12043.0 900,0 YES TOoL NUMBER mmmmmmmmmmm CAL=YA'22g TCC-B-276 SGC-SA-59 HLDV-AA-~9 HLDC-AA-20 HbDS-BA-20 GSA-Z-n72 TCM-AB-g5 15-NOV'g2 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN)I . DR~LLER$ CASING DEPTH bO~GERS CASING DEPTH (FT)I BOREHObE CONDITIONS FLUID TYPEI GASlOIb RATIOI C~OK~ NEUTRON TOOb TOOL TYPE (~PiTHERMAb OR THERMAb)I MATRIX~ M~TRZX OENStTY) . 'HOLE CORRECTIO~ BLUEbINE COUNT RATE NORMALIZATION iN OIL TOP NORMALIZING WINDOW BASE NORMALIZING WINDOW (FT)~ BLUELINE COUNT RATE SCALES SCT BY FIELD FAR COUNT RATE bOW SCALE (CPS)~ FAR COUNT RATE M!G~ SCALE NEAR COUNT RATE bOW SCALE (CP~)~ ~EAR COUNT RATE HIGH SCALE # TOoL STANDOFF (IN)= 53,0 lO O0 SANDSTONE 2.65 zON IS Ta~e Verification Listing chlUmberger AlasKa Computin~ Center 24-NOV-1992 09:50 PAOLI 23 REMARKS: PRIMARY DEPTH CONTROb USEDI MAGNETIC MARKS RAN THREE PASSES AT 900 FPH CAbXPER NOT OPEN FOR 1ST 45' ON PASS COMPUTING CENTER REMARKS~ THE HLDT DATA IS PRESENTED IN THIS FILE TO ACCOMPANY THE MWD RESISITIVITY DATA, (AS NO CDN WAS RUN WITH THE CDR)' PASSES 2 & 3 WERE DEPTH CORRECTED TO .ATCH PASS !. THE~ THE PASSES WERE AVERAGE~ TO YXELD THE DATA PRESENTED HERE, $ bXS FORMAT DATA ** DATA FOR~T SPECIFICATION RECORD ** ** SET TYPE - 64E~ ** TYPE REPR CODE VALUE I 66 0 66 0 3 73 28 4 66 5 66 6 7 65 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 I ** SET TYPE - CHAN ** , NAMM SERV UNIT SERVICE API AP! API APl FILE NUMB NUMB SIZE REPR PROCESS ID aRDER # bOG TYPE CLASS MOD NUmB SIMP ELEM CODE CHEX) ~PT ~T 618978 O0 000 O0 0 $ ! I 4 68 0000000000 RHO~ HLDT G/C3 618978 O0 000 O0 0 5 I I 4 68 0000000000 DRHO HbDT G/C3 618978 O0 000 O0 0 5 ! ! 4 68 0000000000 ~$RH HLDT G/C3 618978 O0 000 O0 0 5 ! I 4 68 0000'000000 SSR" HLDT G/C~ 618978 O0 000 O0 0 5 ! ! 4 68 0000000000 CC~ HLDT V 618978 O0 000 O0 0 5 t I 4 68 0000000000 G~ HLDT GAPI 618978 O0 O00 O0 0 5 I 1 4 68 0000000000 IS Tape Veriftcatlon Listing chlumberget AlasKa Co,~puting Center 24-NOV-~992 09150 PAGE: 24 ~w$m~mmm#mmmmmmmmmmmmmmmmmm~mmm~mmm~mmm~m~mmmmmm~m~#m~m~m#~m~m~m~~~! DEPT. 12065.000 RHOB.HLDT 2.414 DRHO.HLDT -0.~15 6$RH.HLDT SSRH.HLDT 3'557 CCL.HbDT 3.447 GR.H~DT 2. 6 DEPT. 12000.000 RHOB.HLDT 2.32B DRHO.HLDT -O.31B LSRH.HLDT $8RH.HLDT 3.4B3 CCL.HLDT 3.408 GR.HLDT 2.701 DEPT ~lBO~.O00 RHOB,HLDT 2.467 DRHO.HLDT -0.357 6$RH.HLDT SSRH:HLOT .754 CC6.HLDT 3.49B GR.HLDT 2.801 DEPT. 1!600 000 RHOB.HLDT 2.285 DRHO.HLDT .0.]60 LSRM'HLDT SSRH.HLDT 3:594 CCL.HbDT ~.563 GR.H6DT 2.678 SBRN.HEOT '~ 50 CC6.HbDT 4,3 7 GR;HLDT 3- DEPTssRN:HLDT 1120~:413. CCb,HLDT 3.311 GR,HLDT 2:1 97 ' , 672 2,729 2.647 2'834 2.647 3.155 · 2,67B END OF DATA **** FI'LE TRAILER **** FILE,NAME ~ EDIT ,005 ERVICE { F6IC ~ERSlON : O01A07 DATE , : 92/11/23 MAX REC SIZE : 1024 FISE TYPE : LO LAST FILE **** TAP~ TRAILER **** SERVICE NAME : EDIT ORIGEN : FLIC TAPE NAME ~ 92667 ~ONTINUATION # g~EVIOUS TAPE CO~ENT ~ ARCO ALASKA, INC',KUPARUK RIVER UNIT,2M-08,50'"!03.,20184-O0 chlumberoer AlasKa Computing Ceater 24-NOV-1992 09:50 PAGEs 25 *t** REEL TRAILER **~* SERVICE NAME : EDIT ORIGIN : FLIC R~EL NA~E : 92667 CONTINUATION # : CO~ENT i ARCO ALASKA, INC,,KUPARUK RIVER U~IT,2~-08,50-10~-~O184-O0
