Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout200-204200-204
T38916
Gavin Gluyas
Digitally signed by Gavin
Gluyas
Date: 2024.06.12 14:59:56
-08'00'
Originated: Delivered to:19-May-24
Alaska Oil & Gas Conservation Commiss 19May24-NR
ATTN: Meredith Guhl
333 W. 7th Ave., Suite 100
600 E 57th Place Anchorage, Alaska 99501-3539
Anchorage, AK 99518
(907) 273-1700 main (907)273-4760 fax
WELL NAME API #
SERVICE ORDER
#FIELD NAME
SERVICE
DESCRIPTION
DELIVERABLE
DESCRIPTION DATA TYPE DATE LOGGED
1A-03 50-029-206150-00-00 181-088 Kuparuk River WL Plug FINAL FIELD 3-Feb-24
3S-22 50-10320446-00-00 203-011 Kuparuk River WL IBC-CBL FINAL FIELD 5-Feb-24
3M-05 50-103-20875-00-00 223-126 Kuparuk River WL Isealate FINAL FIELD 10-Feb-24
2F-15 50-029-21048-00-00 183-172 Kuparuk River WL Isealate FINAL FIELD 13-Feb-24
MT7-14A 50-103-20856-01-00 223-064 Greater Mooses Tooth WL PPROF FINAL FIELD 20-Feb-24
MT7-03A 50-103-20830-00-10 223-084 Greater Mooses Tooth WL PPROF FINAL FIELD 29-Feb-24
3G-27 50-103-20801-00-00 219-039 Kuparuk River WL TTiX IPROF FINAL FIELD 2-Apr-24
2W-17 50-029-23370-00-00 207-135 Kuparuk River WL PPROF FINAL FIELD 9-Apr-24
1E-23 50-029-20858-00-00 182-184 Kuparuk River WL IPROF FINAL FIELD 10-Apr-24
1E-01 50-029-20464-00-00 180-039 Kuparuk River WL IPROF FINAL FIELD 11-Apr-24
1D-37 50-029-22992-00-00 200-204 Kuparuk River WL PPROF FINAL FIELD 12-Apr-24
3G-09 50-103-20129-00-00 190-067 Kuparuk River WL Punch-Cut FINAL FIELD 13-Apr-24
2P-420 50-103-20391-00-00 201-182 Kuparuk River WL CIBP-Cut FINAL FIELD 15-Apr-24
CD4-536 50-103-20863-00-00 223-079 Colville River WL TTiX Sampling FINAL FIELD 18-Apr-24
Transmittal Receipt
________________________________ X_________________________________
Print Name Signature Date
Please return via courier or sign/scan and email a copy to Schlumberger.
Nraasch@slb.com SLB Auditor -
TRANSMITTAL DATE
TRANSMITTAL #
A Delivery Receipt signature confirms that a package (box, envelope,
etc.) has been received. The package will be handled/delivered per
standard company reception procedures. The package's contents have
not been verified but should be assumed to contain the above noted
media.
# Schlumberger-Private
Eset #
T38800
T38801
T38802
T38803
T38816
T38817
T38818
T38819
T38820
T38821
T38822
T38824
T38823
T38825
1D-37 50-029-22992-00-00 200-204 Kuparuk River WL PPROF FINAL FIELD 12-Apr-24
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.05.20 12:41:13 -08'00'
STATE OF ALASKA
Alt OIL AND GAS CONSERVATION COMM ON
• REPORT OF SUNDRY WELL OPERATIONS
1.Operations Abandon E Plug Perforations Fracture Stimulate r Pull Tubing )✓ Operations Shutdown E
Performed: Suspend Perforate fl Other Stimulate
p E Alter Casing F Change Approved Program
Plug for Redrill 1 Perforate New Pool r Repair Well F Re-enter Susp Well r" Other:Install Liner to Surface
2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number
ConocoPhillips Alaska, Inc. Development F Exploratory E 200-204 _
3.Address: 6.API Number:
Stratigraphic 1Service r
P.O. Box 100360,Anchorage,Alaska 99510 50-029-22992-00
7.Property Designation(Lease Number): 8.Well Name and Number:
ADL 25661 KRU 1 D-37
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 11003 feet Plugs(measured) 9991
true vertical 6606 feet Junk(measured) 10750
Effective Depth measured 10633 feet Packer(measured) 9927, 10624
true vertical 6463 feet (true vertical) 6202,6459
Casing Length Size MD TVD Burst Collapse
CONDUCTOR 86 20 120 120
SURFACE 5047 9 5/8 5081 4380
PRODUCTION 10060 7 10093 6262
LINER 1083 31/2 11003 6606
LINER 9910 51/2 9946 6208
RECEIVED
Perforation depth: Measured depth: 10585-10605, 10605-10615, 10705-10720 JAN 2 7 2017
True Vertical Depth: 6445-6452,6452-6456,6490-6496
AOGCC
Tubing(size,grade,MD,and TVD) 3 1/2,L-80,9889,6188
Packers&SSSV(type,MD,and TVD) PACKER-BAKER ZXP LINER TOP PACKER @ 9927 MD and 6202 TVD
PACKER-WEATHERFORD WS-R-BB PACKER @ 10624 MD and 6459 TVD
SSSV -NONE
12.Stimulation or cement squeeze summary: �V �qt�1}ry.�, ��y}
Intervals treated(measured): N/A SC�NtEt' t`PR 1 8 L1 i7
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 0 0 0 0
Subsequent to operation Shut-In 0 o o 0
14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work:
Daily Report of Well Operations 17 Exploratory E Development F Service I- Stratigraphic E
Copies of Logs and Surveys Run fl 16.Well Status after work: Oil F Gas r WDSPL E
Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ E WAG fl GINJ f SUSP E SPLUG
17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt:
316-602
Contact Andrew Beat(a,265-6341 Email Andrew.T.Beataconocophillips
Printed Name Andrew Beat Title Sr. Wells Engineer
Signature t � g� Phone:265-6341 Date
cbla6<46-t- 24-SAN-Zm r4--
Form 10-404 Revised 5/2015 V TL 3/2'
Diii1S VFE3 - 3 LiJ i/ Submit Original Only
• •
0:t"
Operations Summary (with Timelog Depths)
1D-37
Conoco
Rig: DOYON 142 Job: RECOMPLETION
Time Log
Start Depth
Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)
12/18/2016 12/19/2016 5.00 MIRU MOVE MOB P Moving Rig from 2S Pad to 1D Pad.
19:00 00:00
12/19/2016 12/19/2016 12.00 MIRU MOVE MOB P Moved Rig from 2S-13Ato 1D-37.Rig
00:00 12:00 on 1D at 0500 Hrs.Prep well and Spot
Modules.Sub over well @ 1100 Hrs.
Set Stompers and Skided Rig Floor.
12/19/2016 12/19/2016 7.00 MIRU MOVE RURD P Continue Skiding Rig Floor.Spotted
12:00 19:00 Pit Module.Spotted Pump and Motor
Modules.Continued Spotting Rock
Washer and Pipe Shed.Rigging up
and Connecting Lines.
12/19/2016 12/19/2016 1.00 MIRU MOVE OWFF P Picked up T Bar and checked Poppet
19:00 20:00 on BPV to see if there was any
Pressure below BPV.No Pressure.
12/19/2016 12/19/2016 0.50 MIRU MOVE OWFF P OWFF IA 30 Min.No Flow.
20:00 20:30
12/19/2016 12/19/2016 2.50 MIRU WHDBOP MPSP P RU and tested BPV From Direction of
20:30 23:00 Flow 1000 psi for 10 Min.Good Test.
Bled off Diesel to Drums.
12/19/2016 12/19/2016 0.25 MIRU WHDBOP OWFF P OWFF Static.
23:00 23:15
12/19/2016 12/20/2016 0.75 MIRU WHDBOP NUND P RU and Nipple Down Tree.
23:15 00:00
12/20/2016 12/20/2016 2.25 MIRU WHDBOP NUND P As per FMC representative ND
00:00 02:15 production tree and MU test dart&
ACME 3-1/2"XO(ACME 9-1/4 LH
turns)(EUE 14 turns)
12/20/2016 12/20/2016 6.75 MIRU WHDBOP NUND P NU BOPE: 11x13.625"DSA,adapter
02:15 09:00 spools,BOP stack,dutch riser nipple,
chocke and kill hoses.
12/20/2016 12/20/2016 1.50 MIRU WHDBOP RURD P RU to test BOPE
09:00 10:30
12/20/2016 12/20/2016 1.50 MIRU WHDBOP BOPE P Test gas alarms
10:30 12:00 Conduct initial BOPE test to 250/3500
psi with 3-1/2"test Jt.Test was
witnessed by AOGCC inspector
Matthew Herrera.
Test 1.Annular,CV#1, 12, 13, 14,4"
Kill Valve on mud manifold and XT39
dart valve.
Test 2.Top Pipe rams(3-1/2"x 6"
VBR's),CV#9, 11,Mezz kill valve and
XT39 FOSV.
Test 3.HCR Kill.
Page 1/11 Report Printed: 1/27/2017
• •
0 Operations Summary (with Timelog Depths)
est
1D-37
Conoco011446
Rig: DOYON 142 Job: RECOMPLETION
Time Log
Start Depth
Start Time End:Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)
12/20/2016 12/20/2016 6.00 MIRU WHDBOP BOPE P Continue with initial BOPE test to
12:00 18:00 250/3500 psi with 3-1/2"test Jt.
Test 4. Manifold Valve#4
Test 5. Manifold Valves#8, 10
Test 6.Manifold Valves#6,7 and
manual kill
Test 7.Manifold Valve#2
Test 8.Bottom Pipe rams(3-1/2"x 6"
VBR's),
BOPE test to 250/3500 psi with 5-1/2"
test Jt
Test 1.Blind rams
Test 2.Super choke.
Test 3.Manual Choke
Test 4.Annular and HCR choke.
Test 5.Top Pipe rams(3-1/2"x 6"
VBR's),and HCR choke.
Test 6.Bottom Pipe rams(3-1/2"x 6"
VBR's)
Test 7.Upper IBOP
Test 8.Lower IBOP
Conduct Koomey Draw Down Test
Starting Accumulator pressure=3040
psi
Manifold pressure=1500 psi
Annular psi=1150 psi,
Pressure Gain of 200 psi attained in 8
secs.
Full pressure gain attained in 59 secs.
Average N2(6 bottles)=2554 psi.
COP test-2 elec mtrs 20 secs,2 Air
pumps 79 secs.
Test PVT's
12/20/2016 12/20/2016 0.50 MIRU WHDBOP BOPE P Install Riser
18:00 18:30
12/20/2016 12/20/2016 0.75 MIRU WHDBOP RURD P Pull blanking plug,BRK XO,S,LD test
18:30 19:15 Jt
12/20/2016 12/20/2016 0.25 MIRU WHDBOP RURD P Blown down choke and kill line
19:15 19:30
12/20/2016 12/20/2016 0.50 MIRU WHDBOP MPSP P Pull BPV with tee bar
19:30 20:00
12/20/2016 12/21/2016 4.00 MIRU WHDBOP BOPE T PJSM&C/O upper and lower IBOP
20:00 00:00 and saver sub
12/21/2016 12/21/2016 0.50 MIRU WHDBOP BOPE T Test upper and lower IBOP to
00:00 00:30 250/3500 psi for 5 minutes
12/21/2016 12/21/2016 2.25 MIRU WHDBOP BOPE T Continue change out of IBOP's and
00:30 02:45 saver sub.SIMOPS RU squeeze
manifold to flow back tank.
12/21/2016 12/21/2016 1.75 COMPZN RPCOMP RURD P PJSM.RU GBR tubing handling
02:45 04:30 equipment.MU XOs to FOSV. Install
4'bail extensions and 3 1/2"elevators.
12/21/2016 12/21/2016 1.00 COMPZN RPCOMP RURD P PU and MU landing Jt with 4 x 10'pup
04:30 05:30 jts.MU landing Jt to hanger.MU
XO's/FOSV to top drive,FMC BOLDS
12/21/2016 12/21/2016 4.00 COMPZN RPCOMP PULL T Pull hanger free,attempt to pull seals
05:30 09:30 free.Work string from 113k-227k lbs.
Decision made to call E-line at 6:30
am
Page 2/11 Report Printed: 1/27/2017
• 0
'' Operations Summary (with Timelog Depths)
0
1D-37
ConocoPhillips
Rig: DOYON 142 Job: RECOMPLETION
Time Log
Start Depth
Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)
12/21/2016 12/21/2016 3.50 COMPZN RPCOMP CIRC T Displace freeze protect:pump 87 bbls
09:30 13:00 of 8.5 ppg seawater down the tubing.
Pump down the IA 30 bbls of a deep
clean pill.Chase it 283 bbls 8.5 ppg
sea water.Clean seawater observed
at tiger tank after 400 bbls pumped at
7 BPM(1520 psi).E-line crew heading
to location at 12:40.
12/21/2016 12/21/2016 0.50 COMPZN RPCOMP RURD T RU and blow down lines to tiger tank
13:00 13:30
12/21/2016 12/21/2016 0.75 COMPZN RPCOMP PULD P Space out for E-line ops.Lay down
13:30 14:15 two pup jts and MU 6'pup.Set string
at 138k lbs. E-line on location at
13:45.
12/21/2016 12/21/2016 0.75 COMPZN RPCOMP RURD P Drain stack,blow down lines and suck
14:15 15:00 out tank with vac truck.
12/21/2016 12/21/2016 3.50 COMPZN RPCOMP RURD P Spot SLB E-line truck and RU wireline
15:00 18:30
12/21/2016 12/21/2016 1.00 COMPZN RPCOMP SFTY P PJSM.Bring E-line equipment to the
18:30 19:30 rig floor
12/21/2016 12/21/2016 4.00 COMPZN RPCOMP PERF P Make up string shot toolstring and
19:30 23:30 perform hot check.Test E-line PIS to
1000 psi.RIH.On btm and correlating
at 21:45.Confirm depths with Town
Engineer. 10'loaded string shot to
prepare tbg for chem cut.Shot interval
(9892'-9902').Top shot depth at
9892'.CCL to top shot 2.9'.CCL stop
depth at 9889.1'.POOH and lay down
tools.At surface at 23:30.SIMOPS
load 100 jts of DP in the shed.
12/21/2016 12/22/2016 0.50 COMPZN RPCOMP PERF P Confirmation at surface that the string
23:30 00:00 shot fired.Make up E-line chem cutter
for 2nd run.
12/22/2016 12/22/2016 1.00 COMPZN RPCOMP ELNE P RIH at 00:05 with SLB E-line and 0.0 100.0
00:00 01:00 chem cutter.
12/22/2016 12/22/2016 0.50 COMPZN RPCOMP ELNE P Clean tag at GLM#5.Worked 100.0 9,525.0
01:00 01:30 toolstring at different speeds to
attempt to rotate the toolstring
downhole.Toolstring getting hung up
at top centralizers.While informing
Town Engineer made it through GLM
#5 with chem cutter.Continue RIH.
12/22/2016 12/22/2016 2.50 COMPZN RPCOMP ELNE P Performed correlation and pull to 9,910.0 0.0
01:30 04:00 cutting depth at 2:00 am.CCL cut
depth=9899',CCL to middle of cutter
= 13.8',CCL stopping depth=9885.2'.
Good indication at surface of firing.
POOH with toolstring.At surface at
3:35 am.Lay down E-line toolstring,
PSI and packoff.
12/22/2016 12/22/2016 0.25 COMPZN RPCOMP PULL P MU XOs FOSV to top drive.Pull string
04:00 04:15 free from cut(BO=128K lbs)UW=
110K lbs and DW=82K lbs
12/22/2016 12/22/2016 0.50 COMPZN RPCOMP ELNE P RD and release SLB E-line;SIMOPS
04:15 04:45 BO XO.Remove FOSV and MU to top
drive.
12/22/2016 12/22/2016 1.50 COMPZN RPCOMP SLPC P Cut and slip 132'(9 wraps)of drilling
04:45 06:15 line.SIMOPS:Circulate BU at 3.5
BPM(260 psi),F/O=5%
Page 3/11 Report Printed: 1/27/2017
• •
=' Operations Summary (with Timelog Depths)
0
1D-37
Corioccsthillips
Rig: DOYON 142 Job: RECOMPLETION
Time Log
Start Depth
Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)
12/22/2016 12/22/2016 0.50 COMPZN RPCOMP RURD P Blow down top drive and XOs.RU
06:15 06:45 GBR tubing tongs and handeling
equipment.Bring thread protectors to
the rig floor.
12/22/2016 12/22/2016 5.25 COMPZN RPCOMP PULL P PJSM.POOH from 9899'to 6582'with 9,899.0 6,582.0
06:45 12:00 3-1/2",9.3#,L-80 EUE completion.
Lay down jt,hanger,pup jts and rack
back 5 stands in the derrick.Strapping
tubing out of the hole and inspect it for
corrosion or holes.
12/22/2016 12/22/2016 8.50 COMPZN RPCOMP PULL P Continue POOH from 6582'with 3- 6,582.0 0.0
12:00 20:30 1/2",9.3#, L-80 EUE completion.
Strapping tubing out of the hole and
inspect it for corrosion or holes.
12/22/2016 12/22/2016 0.50 COMPZN RPCOMP RURD P Clear rig floor
20:30 21:00
12/22/2016 12/22/2016 1.00 COMPZN RPCOMP RURD P PU WR and running tool.MU joint
21:00 22:00 pipe,pup,XO and running tool.Set 9"
ID WR.RD running tool.SIMOPS
loading 4"drillpipe in the pipeshed.
12/22/2016 12/23/2016 2.00 COMPZN WELLPR OTHR P Continue loading and strapping 4"DP
22:00 00:00 in pipeshed.SIMOPS PU Baker tools.
12/23/2016 12/23/2016 0.25 COMPZN RPCOMP OTHR P Continue to load 4"DP in the pipe
00:00 00:15 shed.
12/23/2016 12/23/2016 0.75 COMPZN RPCOMP BHAH P MU 5-3/4"Baker overshot as per
00:15 01:00 Baker representative
12/23/2016 12/23/2016 0.50 COMPZN RPCOMP PULD P RIH to 397'with 12 Jts of 4"HWDP 0.0 397.0
01:00 01:30 from pipe shed.UW=55k,DW=55k,
drift=2"
12/23/2016 12/23/2016 4.50 COMPZN RPCOMP PULD P RIH from 397'to 4501 with 4"DP from 397.0 4,501.0
01:30 06:00 pipe shed. UW=114K,DW= 102K,
drift=2".
12/23/2016 12/23/2016 4.25 COMPZN RPCOMP PULD P RIH from 4501'to 9197'with 4"DP 4,501.0 9,197.0
06:00 10:15 from pipe shed.UW=150K,DW=
108K,drift=2".
12/23/2016 12/23/2016 0.50 COMPZN RPCOMP SFTY P Hold safety standup with day crew
10:15 10:45
12/23/2016 12/23/2016 1.25 COMPZN RPCOMP PULD P RIH from 8197'to 9082'with 4"DP 8,197.0 9,082.0
10:45 12:00 from pipe shed. UW= 159K,DW=
110K.
12/23/2016 12/23/2016 0.50 COMPZN RPCOMP PULL P Continue RIH from 9082'to 9440'with 9,082.0 9,440.0
12:00 12:30 4"DP.PU=160k,DW=110K,SDW=
25K at 9440'.Broke free at 215K PU.
Circulated @ 6 bpm(710 psi).Re-
tagged at 9440'with 15K lbs.
12/23/2016 12/23/2016 0.50 COMPZN RPCOMP CIRC X SDW=25K at 9440'.Fire jars and 9,440.0 9,440.0
12:30 13:00 brake free at 215K PU.Circulated @ 6
bpm(710 psi).Re-tagged @ 9440'
with 15K lbs attempting to wash down.
12/23/2016 12/23/2016 1.50 COMPZN RPCOMP CIRC X Continued circulating @ 6 BPM(705
13:00 14:30 psi), 12%F/O. Increased rate to 15
BPM(3780)and continued attempting
to wash down unsuccessfully.Total
strokes pumped=8400.
12/23/2016 12/23/2016 0.25 COMPZN RPCOMP OWFF X Monitor well for 5 minutes.The hole
14:30 14:45 was static.Blow down the top drive.
Page 4/11 Report Printed: 1/27/2017
�► •
Operations Summary (with Timelog Depths)
0151.
1D-37
c c it hps
Af.,xcAg
Rig: DOYON 142 Job: RECOMPLETION
Time Log
Start Depth
Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)
12/23/2016 12/23/2016 1.75 COMPZN RPCOMP TRIP X LD 2 singles and POOH from 9440'to 9,440.0 5,986.0
14:45 16:30 5986'.Monitor displacement via trip
tank.PU=132K DW=104K.
Discussed plan forward with Town
Engineer.
12/23/2016 12/23/2016 2.75 COMPZN RPCOMP TRIP X Continued POOH from 5986'to 405' 5,986.0 405.0
16:30 19:15 while monitoring the displacement in
the trip tank.
12/23/2016 12/23/2016 0.25 COMPZN RPCOMP TRIP X Racked back 4 stands of HWDP from 405.0 0.0
19:15 19:30 397'MD.Calculated the displacement
from trip=56.3 bbls.Actual
displacement from trip=56.5 bbls
12/23/2016 12/23/2016 0.75 COMPZN RPCOMP BHAH X Inspected and broke down the
19:30 20:15 overshot assembly as per Baker
representative.Damage observed.
Pictures taken and put in the well
folder.Discussed with Town Engineer
the findings of the inspetion.
12/23/2016 12/23/2016 0.50 COMPZN RPCOMP BHAH X MU 6-1/8"Baker smooth OD string
20:15 20:45 mill as per Baker representative
12/23/2016 12/23/2016 0.25 COMPZN RPCOMP TRIP X RIH with HWDP to 405'while 0.0 405.0
20:45 21:00 monitoring the displacement in the trip
tank
12/23/2016 12/24/2016 3.00 COMPZN RPCOMP TRIP X Continued to RIH from 405'to 6751' 405.0 6,751.0
21:00 00:00 while monitoring the displacement in
the trip tank
12/24/2016 12/24/2016 2.00 COMPZN RPCOMP TRIP X continue TIH from 6751'TO 9449'. 6,751.0 9,449.0
00:00 02:00 Monitor displacement via trip tank.DW
=116K,UP 154K,RT=131K,80
RPM,Torque=7K free.6 BPM(715
psi)Set down 8K at 9439'milling
depth
12/24/2016 12/24/2016 1.00 COMPZN RPCOMP MILL X milled from 9439'to 9440'@ 80 RPM 9,439.0 9,450.0
02:00 03:00 iwth 12K torque.At 9440'observed
free torque of 7K.Continue to ream
down to 9450'. Reamed back up and
observed no obstruction.Shut down
rotary and washed down with no
obstructions.Shut down pump and
worked through it again.Observed no
obstructions.UW=156K DW=116K
12/24/2016 12/24/2016 1.50 COMPZN RPCOMP MILL X continue TIH from 9450'.Observed 9,450.0 9,646.0
03:00 04:30 obstruction at 9646'mill depth.Ream
through @ 80 RPM,Torque=7-12K,
6 BPM(765 psi)to 9647'and
confirmed clean.Observe additional
obstruction at 9836'mill depth.Set 8K
down.Reamed through with no
issues.Tagged up top of the stump at
9887'set 5k down.PU and
established parameters at 8 RPM with
Torque=7-12k,6 BPM(803 psi).
Tagged up at 9887'with no torque
increase.
Page 5/11 Report Printed: 1/27/2017
• •
`='4.4
Operations Summary (with Timelog Depths)
0
._-
1D-37
ConocoPhillips
Rig: DOYON 142 Job: RECOMPLETION
Time Log
Start Depth
Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)
12/24/2016 12/24/2016 1.00 COMPZN RPCOMP CIRC X Pumped high vis sweep around at 530 9,646.0 9,887.0
04:30 05:30 GPM(2572 psi).UW=160K, DW=
102K.Confirmed tag depth at 9887'.
Observed 250 psi increase with 5K
down.Shut down the pumps and blew
down the top drive.Monitor the well
for 10 minutes.Well static.
12/24/2016 12/24/2016 2.00 COMPZN RPCOMP TRIP X POOH from 9887'to 6478'while 9,887.0 6,478.0
05:30 07:30 monitoring the well on trip tank.UW=
160K,DW=106K.
12/24/2016 12/24/2016 0.50 COMPZN RPCOMP SFTY X Drill:Kick while tripping.Safety stand
07:30 08:00 up meeting with DDI crew.
12/24/2016 12/24/2016 2.75 COMPZN RPCOMP TRIP X continue to POOH from 6478'to 405' 6,478.0 405.0
08:00 10:45 while monitoring the well on trip tank.
UW= 130K,DW=100K.
12/24/2016 12/24/2016 0.75 COMPZN RPCOMP BHAH X Racked back HWDP and LD mill 405.0 0.0
10:45 11:30 assembly.
12/24/2016 12/24/2016 1.00 COMPZN RPCOMP BHAH P MU 5-3/4"overshot(BHA#3)
11:30 12:30
12/24/2016 12/24/2016 0.25 COMPZN RPCOMP BHAH P RIH with HWDP to 397' 0.0 397.0
12:30 12:45
12/24/2016 12/24/2016 4.00 COMPZN RPCOMP TRIP P TIH from 397'to 9871'while 397.0 9,871.0
12:45 16:45 monitoring displacement in the trip
tank.UW= 156K,DW=112K,
calculated displacement from trip=
60.1 bbls,actual displacement from
trip=61.9 bbls.
12/24/2016 12/24/2016 0.25 COMPZN RPCOMP FISH P Obtained parameters above the fish at 9,871.0 9,887.0
16:45 17:00 3 bpm(175 psi),20 RPM,Torque=
6k.PU=156K,DW=112K,ROT=
130K.Ran in and tagged top of stump
at 9886'.Packed off pressure up 400
psi at 9887'.Bled off and continued
shallowing fish to 9881'.PU 15k over
to ensure fish was engaged.PU to
200K and fired jars.Continued picking
up to 259K(pulled free).Rolled pump
with 480 psi and picked up to 9866'
12/24/2016 12/24/2016 0.75 COMPZN RPCOMP CIRC P Circulated btms up at 9866'with 10 9,887.0 9,866.0
17:00 17:45 bpm(1820 psi), 16%F/O.Increased
rate to 12 bpm(2120 psi).Total
strokes pumped=3350.
12/24/2016 12/24/2016 0.25 COMPZN RPCOMP OWFF P Racked back 2 stands to 9773'.Blew 9,866.0 9,773.0
17:45 18:00 down the top drive and monitored the
well for 5 minutes.Well static
12/24/2016 12/24/2016 4.00 COMPZN RPCOMP TRIP P TOH from 9773'to 397'while 9,773.0 397.0
18:00 22:00 monitoring the displacement in the trip
tank.Calculated displacement from
trip tank=60.1 bbls,actual
displacement=59.9 bbls.
12/24/2016 12/24/2016 1.00 COMPZN RPCOMP TRIP P Racked back 4 stands of HWDP and 397.0 0.0
22:00 23:00 LD seal assembly. Calculated
displacement from trip tank=60.1
bbls,actual displacement=59.9 bbls.
12/24/2016 12/24/2016 0.75 COMPZN WELLPR BHAH P PU overshot and broke down overshot
23:00 23:45 and tbg stub.Length of 3 1/2"tbg stub
=17.6'.Length of seal assembly=
44.97'
12/24/2016 12/25/2016 0.25 COMPZN WELLPR BHAH P MU 7"casing clean out BHA
23:45 00:00
Page 6/11 Report Printed: 1/27/2017
Operations Summary (with Timelog Depths)
1D-37
Citliips
o
r
Rig: DOYON 142 Job: RECOMPLETION
Time Log
Start Depth
Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)
12/25/2016 12/25/2016 1.00 COMPZN WELLPR BHAH P Continue MU 7"casing clean out BHA 0.0 81.0
00:00 01:00
12/25/2016 12/25/2016 4.50 COMPZN WELLPR TRIP P RIH from 81'to 9829'while monitoring 81.0 9,829.0
01:00 05:30 well on trip tank. UW= 156K,DW=
114K
12/25/2016 12/25/2016 1.25 COMPZN WELLPR WASH P Wash in hole from 9829'to 9944.11'at 9,829.0 9,944.0
05:30 06:45 2 bpm(95 psi),at 4 bpm(325 psi)and
at 6 bpm(716 psi).UW=156K,DW=
114K.No go on 6-1/8"mill at
9903'(top of packer).Confirm 3 times
with 5K set down weight and psi
increase.
12/25/2016 12/25/2016 0.75 COMPZN WELLPR CIRC P Pump high vis sweep at 12 bpm(2350 9,944.0 9,940.0
06:45 07:30 psi)at 9940'.Shut down mud pumps
and blow down top drive. Monitor well
for flow.Well static.
12/25/2016 12/25/2016 4.50 COMPZN WELLPR PULD P LD 4"DP from 9940'to 3767'.Shuffle 9,940.0 3,767.0
07:30 12:00 3-1/2"tbg in derrick to the front.
Calculated trip in displacement=59.5
bbls,actual=60.3 bbls.
12/25/2016 12/25/2016 1.50 COMPZN WELLPR TRIP P Continue TOH from 3767'to 450' 3,767.0 450.0
12:00 13:30 while monitoring well on trip tank.
12/25/2016 12/25/2016 0.50 COMPZN WELLPR BHAH P LD 12 jts of HWDP from 450'to 81'. 450.0 81.0
13:30 14:00
12/25/2016 12/25/2016 1.50 COMPZN WELLPR BHAH P LD 7"csg clean out BHA.Clean and 81.0 0.0
14:00 15:30 clear floor.
12/25/2016 12/25/2016 0.50 COMPZI RPCOMP RURD P MU Johnny Wacker and wash stack at
15:30 16:00 15 bpm(60 psi).LD Johny Wacker.
12/25/2016 12/25/2016 0.50 COMPZ1 RPCOMP RURD P Pull wear bushing and lay it down.
16:00 16:30
12/25/2016 12/25/2016 0.50 COMPZ1 RPCOMP RURD P RU to run 5-1/2"liner. RU power
16:30 17:00 tongs,slips,elevators.Verify pipe
count on location.
12/25/2016 12/25/2016 0.50 COMPZI RPCOMP SVRG P Service top drive and crown.
17:00 17:30
12/25/2016 12/25/2016 0.50 COMPZI RPCOMP SFTY P PJSM with GBR
17:30 18:00
12/25/2016 12/25/2016 0.25 COMPZ1 RPCOMP PUTB P MU seal assembly and seal bore
18:00 18:15 extension
12/25/2016 12/25/2016 2.75 COMPZ1 RPCOMP WAIT T Wait on XO for 5-1/2"HYD 563.
18:15 21:00 Record OD/ID measurements and MU
XOs
12/25/2016 12/26/2016 3.00 COMPZ1 RPCOMP PUTB P RIH with 5-1/2", 15.5#,L-880 HYD 0.0 3,258.0
21:00 00:00 563 liner to 3258'TQ connections to
6200 FT/LBS.UW=91K and DW=
84K
12/26/2016 12/26/2016 6.50 COMPZ1 RPCOMP PUTB P RIH with 5-1/2", 15.5#,L-80 HYD 563 3,258.0 9,723.0
00:00 06:30 liner from 3258'to 9723'.TQ
connections to 6200 FT/LBS.UW=
165K and DW= 101K
12/26/2016 12/26/2016 1.00 COMPZ1 RPCOMP RURD P PU tools from beaver slide needed to
06:30 07:30 complete run. Install bail extensions
and hold PJSM with crew for locating
and space out.
Page 7/11 Report Printed: 1/27/2017
• •
Operations Summary (with Timelog Depths)
1D-37
> onocoPhifiips
Ai:rs+k:a
Rig: DOYON 142 Job: RECOMPLETION
Time Log
Start Depth
Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)
12/26/2016 12/26/2016 1.25 COMPZI RPCOMP PUTB P Continue to RIH from 9723'to 9919'. 9,723.0 9,919.0
07:30 08:45 UW=173K,DW=101k.Wash down
to 9930.71'at 1 bpm(100 psi).
Observed pressure increased to 300
psi.Shut down pump and hold
pressure to confirm lower seal is
inside the top of the SBE AT 9930.71'.
Bleed off pressure and continue in the
hole to 9947.39.Fully locate,set 3k
down.Locator depth=9910.73'.PU
out of seals.
12/26/2016 12/26/2016 1.75 COMPZ1 RPCOMP CIRC P Circulate at 1 bpm(100 psi).Build
08:45 10:30 corrosion inhibited brine in pits and off
load to vac truck.Spot LRS for
pumping.Work on space out.
12/26/2016 12/26/2016 1.50 COMPZI RPCOMP HOSO P LD Jt#250 to 9919.2'.UW=170K, 9,919.0 9,947.0
10:30 12:00 DW=101K.MU space out pups=
10.08', 10.09',4.31'and 8.19'.Wash
down at 1 bpm(100 psi)and confirm
top of seal SBE at 9930.71'.Shut
down pump and continue to fully
locate at 9947.39'.Locator depth=
9910.73'PU out of SBE
12/26/2016 12/26/2016 1.00 COMPZ1 RPCOMP CIRC P Continue circulating at 1 bpm(100
12:00 13:00 psi).Check lineup and hold PJSM with
LRS
12/26/2016 12/26/2016 1.50 COMPZ1 RPCOMP CRIH P Pump 74.9 bbls of corrosion inhibited
13:00 14:30 12.0 ppg brine at 1.5 bpm(960 psi).
Chase with 18 bbls diesel at 1.5 bpm
(1010 psi).Hold back pressure on tbg
as per pressure schedule.93 bbls
returned to pits.
12/26/2016 12/26/2016 0.50 COMPZI RPCOMP HOSO P Strip through annular to re-engage
14:30 15:00 seals.Bleed off tbg and annulus.
Remove XOs and blow down top
drive. PU to 1.7'above.Locate and
set slips with 140K. Break off 8'pup.
UW=176K, DW=101K
12/26/2016 12/26/2016 2.50 COMPZ1 WHDBOP MPSP P PJSM&MU G-plug and running tools.
15:00 17:30 RIH with 5 stands of 3-1/2"tbg. Lay
down running tool.
12/26/2016 12/26/2016 1.50 COMPZ1 WHDBOP PRTS P RU to 5-1/2"liner and flood lines.Test
17:30 19:00 G-plug to 3000 psi for 10 minutes and
chart it.Blow down lines and break
apart XOs with power tongs.
12/26/2016 12/26/2016 0.50 COMPZ1 WHDBOP PULD P TIH with 3-1/2"tbg to 368' 0.0 368.0
19:00 19:30
12/26/2016 12/26/2016 0.50 COMPZ1 WHDBOP PULD P TOH with 3-1/2"tbg from 368' 368.0 465.0
19:30 20:00
12/26/2016 12/26/2016 2.00 COMPZ1 WHDBOP NUND P ND BOPE,break off kill and choke
20:00 22:00 lines. Break connections below stack.
PU stack 3'from clearance.Install 5-
1/2"emergency slips and slack off
with 135K in slips.
12/26/2016 12/27/2016 2.00 COMPZ1 WHDBOP CUTP P RU Wachs cutter and cut 5-1/2"jt.LD
22:00 00:00 cut It.
12/27/2016 12/27/2016 0.50 COMPZ1 WHDBOP WWSP P Set pack off as per FMC.
00:00 00:30
Page 8/11 Report Printed: 1/27/2017
• •
0.0,2.
Operations Summary (with Timelog Depths)
*:1
1D-37
C ce P`hitlips
Rig: DOYON 142 Job: RECOMPLETION
Time Log
Start Depth
Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)
12/27/2016 12/27/2016 3.00 COMPZ1 WHDBOP NUND P ND 2'spacer spool from the BOPE
00:30 03:30 stack.NU new 11"tbg spool to
wellhead.NU DSA and spacer spool
to tbg spoo.
12/27/2016 12/27/2016 4.00 COMPZ1 WHDBOP NUND P NU BOPE. MU kill and choke line.
03:30 07:30 Doyon 142 RKB to:
Annular= 18.52'
Upper rams=22.29'
Blinds=24.78'
Lower Rams=28.70'
Tbg Spool LDS=32.92'
Csg Head Upper LDS=35.18'&
Lower LDS=37.4'1
12/27/2016 12/27/2016 0.50 COMPZ1 WHDBOP WWSP P Test pack off as per FMC to 3000 psi
07:30 08:00 for 10 minutes.
12/27/2016 12/27/2016 1.00 COMPZ1 WHDBOP OTHR P RU to conduct shell test on the BOPE
08:00 09:00 and tbg spool.Set test plug and test to
250/3500 psi for 5 minutes each.RD
test equipment.
12/27/2016 12/27/2016 0.50 COMPZ1 WHDBOP OTHR P PU 5 1/2"cut jt.Break out cut jt and
09:00 09:30 pups and LD. Pull test plug.
12/27/2016 12/27/2016 1.25 COMPZ1 WHDBOP TRIP P RIH with 3-1/2"tbg to retrieve G-plug 0.0 479.0
09:30 10:45 at 479'.UW=49K,DW=41K.
Engage plug and release.
12/27/2016 12/27/2016 1.25 COMPZ1 WHDBOP MPSP P LD 15jts of 3-1/2"EUE tbg.LD G-plug 479.0 0.0
10:45 12:00 and retrieval tool.
12/27/2016 12/27/2016 0.25 COMPZ1 WHDBOP BHAH P Lay G-plug and running tool down
12:00 12:15 beaver slide
12/27/2016 12/27/2016 0.75 COMPZ1 RPCOMP PRTS P RU and test 5-1/2"liner to 2500 psi for
12:15 13:00 15 minutes(Chart good test).RD and
blow down lines
12/27/2016 12/27/2016 0.50 COMPZ1 RPCOMP SFTY P RU to run 3-1/2"completion.Hold
13:00 13:30 PJSM with all parties involved.
12/27/2016 12/27/2016 5.00 COMPZN RPCOMP PUTB P RIH with 3-1/2",9.3#L-80 HYD 511 0.0 4,027.0
13:30 18:30 tbg as per detail to 4027'.Torque
connections to 1400 fUlbs while
monitoring displacement via trip tank.
12/27/2016 12/27/2016 0.50 COMPZN RPCOMP SVRG P Service rig
18:30 19:00
12/27/2016 12/27/2016 0.50 COMPZN RPCOMP WAIT T Wait on 3-1/2"elevators
19:00 19:30
12/27/2016 12/28/2016 4.50 COMPZN RPCOMP PUTB P Continue to RIH with 3-1/2",9.3#L-80 4,027.0 7,729.0
19:30 00:00 HYD 511 tb as per detail from 4027'to
7729'.Torque:
Hydril 511 connections=1400 fUlbs
EUE connections=2240 fUlbs
PU=98K,DW=76K
12/28/2016 12/28/2016 3.25 COMPZN RPCOMP PUTB P Continue to RIH with 3-1/2"tbg from 7,729.0 9,861.0
00:00 03:15 7729'to 9861'.UW=115K, DW=
81K.MU EUE connection to 2240
fUlbs.Change out jt#297 with Jt#
334(31.15')and#298 w/jt#335
(31.55')due to bad collar
12/28/2016 12/28/2016 0.75 COMPZN RPCOMP CIRC P MU head pin and circulate assembly
03:15 04:00 to string.Establish circulation at 1 bbl
(77 psi)
12/28/2016 12/28/2016 0.50 COMPZN RPCOMP CIRC P Observe 100 psi pressure increase at
04:00 04:30 9874'. Disengage pump. No go tag at
9874'. Mule shoe depth at 9892'.
Page 9/11 Report Printed: 1/27/2017
• •
0Operations Summary (with Timelog Depths)
>.2:
1 D-37
Ccn o Ptniflips
Rig: DOYON 142 Job: RECOMPLETION
Time Log
Start Depth
Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)
12/28/2016 12/28/2016 1.00 COMPZN RPCOMP HOSO P Lay down jts#309,308,and 307 to
04:30 05:30 9803'.UW=115K,DW=81K.Space
out with pups 4.13',4.27'and 8.15'.
PU Jt 307 and MU hanger and landing
jt.
12/28/2016 12/28/2016 1.00 COMPZN RPCOMP CRIH P Pump 120 bbls of CI seawater
05:30 06:30 followed by 87 bbls of sea water at
9851'@ 3 BPM(530 psi),@ 6 BPM
(1860 psi).Slow pump down to 1 BPM
with 60 psi and engage seals.Confirm
seals with 100 psi increase.Bleed off
pressure and pump out the stack to
observe running in with the hanger.
12/28/2016 12/28/2016 0.50 COMPZN RPCOMP THGR P RIH with hanger,run in LDS as per
06:30 07:00 FMC.Torque to 450 ft/lbs
12/28/2016 12/28/2016 2.00 COMPZN RPCOMP PRTS P RU to pressure test the tbg and IA.
07:00 09:00 Pressure test the tubing to 3000 psi
for 30 minutes.Bleed off pressure to
1500 psi.Pressure test IA to 2500 psi
for 30 minutes.Bleed off tubing and
shear out SOV.Pump down the IA to
confirm shear @ 1 BPM(280 psi).
Pump down the tbg and confirm shear
@ 1 BPM(260 psi).RD and blow
down circulation equipment.
12/28/2016 12/28/2016 0.75 COMPZN WHDBOP MPSP P Set BPV as per FMC.Pressure test to
09:00 09:45 1000 psi for 10 minutes in direction of
flow.Bleed off and blow down test
lines.
12/28/2016 12/28/2016 2.25 COMPZN WHDBOP NUND P B/D choke,kill,injection line and mud
09:45 12:00 line.ND BOPE.
12/28/2016 12/28/2016 1.50 COMPZN WHDBOP NUND P Continue ND BOPE and R/B,set back
12:00 13:30 spacer spools.
12/28/2016 12/28/2016 1.00 COMPZN WHDBOP NUND P Clean and dress up hanger and neck.
13:30 14:30 Install SBMS.
12/28/2016 12/28/2016 2.00 COMPZN WHDBOP NUND P NU adapter flange and tree
14:30 16:30
12/28/2016 12/28/2016 0.50 COMPZN WHDBOP MPSP P Pull BPV and install TWC
16:30 17:00
12/28/2016 12/28/2016 1.00 COMPZN WHDBOP PRTS P Test hanger void to 5000 psi.Fill and
17:00 18:00 test tree to 250/5000 psi for 5 minutes
each(charted)
12/28/2016 12/28/2016 0.25 COMPZN WHDBOP MPSP P Pull TWC
18:00 18:15
12/28/2016 12/28/2016 0.75 COMPZN WHDBOP FRZP P RU to freeze protect
18:15 19:00
12/28/2016 12/28/2016 1.00 COMPZN WHDBOP WAIT P Wait on vac truck for returns. LD skate
19:00 20:00 rail&secure in pipeshed
12/28/2016 12/28/2016 1.25 COMPZN WHDBOP FRZP P PJSM,pump 80 bbls of diesel down IA
20:00 21:15 to freeze protect.PT all lines to 2500
psi.
Initial circulating pressure:@ 2 bpm=
1500 psi
@ 2 bpm= 1600 psi(20 bbls away)
@ 2 bpm=1700 psi(40 bbls away)
@ 2 bpm=1600 psi(60 bbls away)
@ 2 bpm=1500 psi(80 bbls away).
Final circulating pressure= 1500 psi.
12/28/2016 12/28/2016 1.00 COMPZN WHDBOP FRZP P U-tube for 1 hr.0 psi in the tbg and IA
21:15 22:15
Page 10/11 Report Printed: 1/27/2017
Operations Summary (with Timelog Depths)
0
a
1D-37
C o:Whitlips
Rig: DOYON 142 Job: RECOMPLETION
Time Log
Start Depth
Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)
12/28/2016 12/28/2016 1.00 COMPZN WHDBOP MPSP P Dry rod BPV. Install tree cap and all
22:15 23:15 gauges.Final Pressures=0/0/0/420
psi Tbg/IA/OA/OOA
12/28/2016 12/29/2016 0.75 DEMOB MOVE RURD P Disconnect electrical interconnects.
23:15 00:00 RD Doyon 142.Clean cellar&
wellhead.'""Rig Release @ 23:59 hrs
Page 11/11 Report Printed: 1/27/2017
KUP D 1 D-37
ConocoPh lips y ; Well Attribu Max AnglaD TD
Alaska JnC Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB)
e Cgnoco`itligips 500292299200 KUPARUK RIVER UNIT PROD 69.65 6,925.85 13,087.0
A
°°° Comment H2S(ppm) Date Annotation End Date 1KB-Grd(ft) Rig Release Date
10-37,1/27/20178.11 56 AM SSSV:NONE 50 11/23/2015 Last WO: 1/1/2017 1/15/2001
Vertical schematic(actual)
Annotation Depth(ftKB) End Date Annotation Last Mod By End Date
HANGER;bzsi-�0 f Last Tag: 10,633.0 11/20/2006 Rev Reason:RECOMPLETION,GLV C/O,PULL pproven 1/26/2017
1= CATCHER&EVO TRIEVE(PLUG)
+',.. Casing Strings
J', Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread
CONDUCTOR 20 19.052 34.0 120.0 120.0 91.50 H-40 WELDED
al.
Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread
SURFACE 9 5/8 8.835 33.9 5,081.0 4,380.2 40.00 L-80 BTC 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 32.9 10,093.0 6,261.9 26.00 J-55 BTC MOD
CONDUCTOR;34.0-120.0 I. I.titi;Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) 'Set Depth(TVD)... Wt/Len(I...Grade Top Thread
LINER 2016/WO 5 1/2 4.900 35.2 9,945.7; 6,208.3 15.50 L-80 Hyd 563
Si Liner Details
GAS LIFT;2,387.8
II
Nominal ID
Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in)
9,872.3 6,181.5 68.14 XO Reducing Crossover 5.5"x 5",12.6 ppf L-80 Hyd 563 box x 5" 4.490
It Hyd 521 box pin
GAS LIFT;3,670.3 Z
11 9,874.0 6.182.2 68.17 SBE Baker Seal Bore extension 80-40(4.00"ID)Hyd 521 4.000
P x Hyd 521 box
9,895.7 6.190.2 68.46 XO Reducing Crossover 4.5"12.6 ppf IBT-m box x 3.5"9.3 ppf L- 2.930
80 EUE pin
I
9,907.9 6,194.7 68.62 LOCATOR Baker GBH-22 Locating Seal Assembly 80-40 3.5" 2.990
Hyd 511 box-above located
SURFACE;33.05,081.0-.s U 9,909.0 6,195.1 68.64 SEAL ASSY Baker GBH-22 Locating Seal Assembly 80-40 3.5" 2.990
mule shoe pin-below located
1111
GAS LIFT;5,1366.8 '17Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread
WINDOW L2 4 3.000 10,594.0 10,604.0 6,451.7
raiCasing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) 'Set Depth(TVD)...-Wt/Len(I...Grade Top Thread
WINDOW L1 4 3.000 10,741.0 10,751.0 6,507.7
Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...'Grade Top Thread
GAS LIFT;7,913.4 t; LINER 3 1/2 2.992 9,920.0 11,003.0 9.30 L-80 SLHT
!RI Liner Details
Nominal ID
Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in)
GAS LIFT;6,763.7I Kt-t.'
9,920.0 6,199.1 68.79 TIE BACK BAKER TIE BACK SLEEVE 5.250
9,927.4 6,201.7 68.89 PACKER BAKER ZXP LINER TOP PACKER 4.408
9,934.9 6,204.4 68.94 HANGER BAKER FLEX-LOCK LINER HANGER 4.400
NIPPLE;9,820.7 9,947.0 6,208.8 68.90 SBE BAKER 80-40 SBE 4.000
igi 10,006.3 6230.2 68.72 NIPPLE CAMCO'DS'NIPPLE w/2.75"NO GO PROFILE 2.750
Tubing Strings
Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft.../Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection
LOCATOR;9,870.8 aaa UPPER 31/2 2.992 32.9 9,889.3 6,187.8 9.30 L-80 EUE 8rd
COMPLETION RWO
2016
SEAL ASSY;9,871.0 7; Completion Details
Nominal ID
-,. Top(ftKB) Top(ND)(ftKB) Top Ind(°) Item Des Com (in)
32.9 32.9 0.00 HANGER FMC Gen V Tubing Hanger-Will land in new added 2.920
tubing spool
9,820.7' 6,162.1 67.74 NIPPLE Camco 2.813"DS Profile Landing nipple EUE-m B X P 2.818
At 9,870.8 6,181.0 68.12 LOCATOR Baker GBH-22 Locating Seal Assembly 80-40 3.5"Hyd 2.910
I:»'em,,a 511 box-above located
- 9,871.0 6,181.1 68.13 SEAL ASSY Baker GBH-22 Locating Seal Assembly 80-40 3.5"mule 2.900
'If shoe pin-below located
LINER 2016/wo;35.2-9,945.7ii( Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.)
TopTop Incl
Top(ftKB) (ftKB)KB) CI Des Com Run Date ID(in)
10,624.0 6,459.3 67.78 PACKER WEATHERFORD WS-R-BB PACKER,BETWEEN 6/17/2005 1.250
tA LATERAL LEGS L1&L2 WINDOWS
10,741.0 6,503.8 67.41 WHIPSTOCK FLOW-THRU WHIPSTOCK SET BELOW L2 LEG 6/17/2005 2.500
10,750.0 6,507.3 67.38 FISH 'Pert Gun Plug E-LINE PERF GUN ARMING POINT 3/25/2005
PLUG LEFT IN HOLE 1.23"x.588"
PRODUCTION;32.9-10,093.0+
Perforations&Slots
APERF;10,585.0-10,605.0 Shot
WINDOW L2;10,594.0-10,604.0 ' Dens
Top(ND) Btm(ND) (shots/
Top(ftKB) 81m(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com
10,585.0 10,605.0 6,444.6 6,452.1 C-4,1D-37 3/18/2005 6.0 APERF 2.5"HSD,60 deg phase
APERF;10,605.0-10,615.0
10,605.0 10,615.0 6,452.1 6,455.9 C-4,1D-37 3/19/2005 6.0 APERF 2.5"HSD,60 deg phase;
•
random orient
10,705.0 10,720.0 6,490.0 6,495.8 C-4,1D-37 2/25/2001 6.0 IPERF 2.5"HSD,60 deg phase
•
PACKER;10,624.0 - Stimulations&Treatments
IPERF;10,705.0-10,720.0Proppant Designed(lb) Proppant In Formation(Ib) Date
FRAC;10,705.0 ' I I 3/11/2001
Stimulations&Treatments
° ,. Min Top Max Btm Top(TVD) Btm(TVD) Vol Clean Vol Slurry
IPERF;10,735.0-11,053.0 Depth(ftKB) Depth(ftKB) (ftKB) (ftKB) Stg tl Date StimRreat Fluid Pump(bbl) (bbl)
LINER L1;10,7342-12,256.7
WHIPSTOCK;10,741.0 It 10,705.0 10,720.0 6,490.0' 6,495.8 1 3/11/2001
FISH;10,750.0 Mandrel Inserts
WINDOW L1;10,741.0-10,751.0
(PERF;10,611.0-10,928.0 I!1 St
ati
on Top(ND) Valve Latch Port Size TRO Run
NTop(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com
el
1 2,387.8 2,385.7 Camco KBG-29 1 GAS LIFT GLV INT 0.188 1,226.0 1/4/2017
2 3,670.3 3,587.2 Camco KBG-29 1 GAS LIFT OV INT 0.188 0.0 1/4/2017
I 3 5,656.8 4,601.2 Camco KBG-29 1 GAS LIFT DMY INT 0.000 0.0 12/28/2016
LINER;9,920.0-11,003.0 4 7,913.5 5,431.5 Camco KBG-29 1 GAS LIFT DMY INT 0.000 0.0 12/28/2016
5 9,763.7 6,140.6 Camco KBG-29 1 GAS LIFT DMY INT 0.000 0.0 12/28/2016
(PERF;11,054.012,037.01 r
LINER L2;10,608.1-12,968.3 1 L
KUPD • 1D-37
ConocoPhillips / ;'
Alaska,Inc.
canoc 4hilliips
....,
••• 1D-37,1/27/20178'11'56 AM I
Vertical schematic(actual)
HANGER 329 ' Am ;a@ I
Notes:General&Safety
II i,; End Date Annotation
7/1/2005 NOTE:MULTI-LATERAL WELL:MAIN LEG 1D-37,LATERAL LEGS 1D-37L1 81D-37L2
1/27/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0
1I. I s
CONDUCTOR;34.0-120.0
GAS LIFT:2,387.8 z.
ii
GAS LIFT,3,670.3 - ;
lz
SURFACE;33.9-5,081.0-�
GAS LIFT;5,656.8
16111.1
GAS LIFT,7,9134 'tg+i.
RI
11
GAS LIFT;9,763.7 '
III
NIPPLE;9,820.7
LOCATOR;9,870.8 mem.
SEAL ASSY;9,871.0 ®.
AM
33
I t
oAI a
LINER 2016/WO;352-9,945.7 1,6161
,.
tll"
PRODUCTION;32.9-10,093.0 -
APERF,10,585.0-10605.0
WINDOW L2;10,594.0.10,604.0
APERF;10,605.0.10,615.0 -41,
PACKER,10,624.0
IPERF;10,705.0-10,720.0
FRAC;10,705.0I :
IPERF,10,735.0-11,053.0 '.
LINER L1;10,7342-12,256.7
WHIPSTOCK 10,741.0 I
FISH;10,750.0
WINDOW L1;10,741.0-10,751.0
(PERF;10,611.0-10,928.0 �1
I I
LINER;9,920.0-11,003.0
(PERF;11,054.0.12,037.0` I
LINER L2;10,506.1-12,988.3
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RECEIVED 200- 2D1
FEB 0 3 2017
WELL LOG TRANSMITTAL#903622664
AOGCC
To: Alaska Oil and Gas Conservation Comm. January 9, 2017
Attn.: Makana Bender
333 West 7th Avenue, Suite 100 DATA LOGGED
Anchorage, Alaska 99501 iG/2017
N. K.BENDER
RE: EM Pipe Xaminer: 1D-37
Run Date: 10/26/2016
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
1D-37
Digital Data (LAS), Digital Log file, Casing Inspection Report 1 CD Rom
50-029-22992-00
EM Pipe Xaminer(Processed Log) 1 color log
50-029-22992-00
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:(4,444100414.0 ....ei.at
• •
y or 7 Alaska Oil and Gas
g*� ����j,�sTHE STATE
e
is ALASKA Conservation Commission
':---r-----
ti �� 333 West Seventh Avenue
' Anchorage, Alaska 99501-3572
' �-42,77GOVERNOR BILL WALKER g Main: 907.279.1433
OF
ALAS ' Fax: 907.276.7542
www.aogcc.alaska.gov
Andrew Beat
Sr. Wells Engineer
ConocoPhillips Alaska, Inc. SCANNEDP U IL
P.O. Box 100360
Anchorage, AK 99510
Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1D-37
Permit to Drill Number: 200-204
Sundry Number: 316-602
Dear Mr. Beat:
Enclosed is the approved application for sundry approval relating to the above referenced well.
Please note the conditions of approval set out in the enclosed form.
As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further
time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC
an application for reconsideration. A request for reconsideration is considered timely if it is
received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if
the 23rd day falls on a holiday or weekend.
Sincerely,
1,0-4.6;2
04 L"----
Cathy '. Foerster
Chair
DATED this Z' day of November, 2016.
RBDMS ti' DEC - 6 2016
1
• STATE OF ALASKA •
•
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
1.Type of Request: Abandon U Plug Perforations❑ Fracture Stimulate U Repair Well U • Operations shutdown❑
Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Q Change Approved Program❑
Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing Q Other: Install Liner to Surface❑
2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number:
ConocoPhillips Alaska,Inc. ' Exploratory ❑ Development ❑✓ 200-204 •
3.Address: Stratigraphic ❑ Service ❑ 6.API Number:
P.O.Box 100360,Anchorage,Alaska 99510 50-029-22992-00
7.If perforating: 8.Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool? n/a
Will planned perforations require a spacing exception? Yes ❑ No 0 KRU 1D-37 .
9.Property Designation(Lease Number): 10.Field/Pool(s):
ADL025661 ' 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):
11003' • 6606' - 10633' . . 6463' 2629 9879' none
Casing Length Size MD TVD Burst Collapse
Structural
Conductor 86' 20" 120' 120' RECEIVED
Surface 5043' 9.625" 5079' 4380'
Intermediate
Production 10057' 7" 10092' 6261' N O V 2 2 2016
Liner 1027' 3.5" 11001' 6605' 0J5 III- r/i‘
Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: A$, :Iv,..Cli
• 10585'-10605' 6445'-6452' 3.5 L-80 9961'
' 10605'-10615' 6452'-6456'
' 10705'-10720' 6490'-6496'
Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft):
PACKER-Baker ZXP PACKER ' MD=9927 TVD=6202
PACKER-WFT WS-R-BB Packer • MD=10624 TVD=6459
12.Attachments: Proposal Summary ❑ Wellbore schematic ❑ 13.Well Class after proposed work:
Detailed Operations Program ❑ BOP Sketch ❑ Exploratory Li Stratigraphic❑ Development L• Service Li
14.Estimated Date for 15.Well Status after proposed work:
Commencing Operations: 12/7/2016 OIL ❑✓ + WINJ ❑ WDSPL ❑ Suspended ❑
16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑
Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑
17. I hereby certify that the foregoing is true and the procedure approved
herein will not be deviated from without prior written approval. Contact Andrew Beat @ 265-6341
Email Andrew.T.Beat@conocophillips.com
Printed Name Andrew Beat 265-6341 Title Sr.Wells Engineer
Signature Date I V22./E 6
COMMISSION USE ONLY
Conditions of approval: Notify Commission so that a representative may witness Sundry Number:
Plug Integrity ❑ BOP Test V/ Mechanical Integrity Test ❑ Location Clearance ElOther: A4 3 --0t p$i.. /SC l'c' /e St-
RBDMS Lt- DEC - 6 2016
Post Initial Injection MIT Req'd? Yes ❑ No ❑
Spacing Exception Required? Yes ❑ No 2/ Subsequent Form Required: f U — L/ O q
/, APPROVED BY
Approved by: G ..?v..1....4„..2 COMMISSIONER THE COMMISSION Date: // Z?l- /
�^, " SUbntlt'Furrn 2
Form 10-403 evised 11/2015 V INtiiAtaml,id for 12 monthsfro a date of approval. Attachments in Duplicate
17/4 1I��3�1 iv !l A3116
• •
ConocoPhillips
Alaska
P.O. BOX 100360 E I 'M!
ANCHORAGE,ALASKA 99510-0360
November 21,2016 NOV 2 2 2016
Commissioner AOGCC
State of Alaska
Alaska Oil&Gas Conservation Commission
333 West 7th Avenue Suite 100
Anchorage,Alaska 99501
Dear Commissioner:
ConocoPhillips Alaska,Inc.hereby submits an Application for Sundry Approval to work over Kuparuk Producer
1D-37(PTD#200-204).
cS
1D-37 was originally drilled and completed between 2000 and 2001 as a"C"sand,dual lateral producer in Kuparuk.
The well produced from the rotary drilled laterals until 2005 when it was sidetracked by CTD. 1D-37 continued to
produce until it failed a TIFL on 6/3/2016 and was shut in on 6/25/2016.A production casing leak was found at
4,323' MD via an acoustic leak detect log.The well failed a CMIT-TxIA on 9/3/2016 but all annuli passed a DDT
on 6/24/2016.
The proposed workover scope for 1D-37 is to remove the existing production tubing,clean out the well down to the ,/
existing liner packer, install a 5-1/2"liner to surface,install new production tubing.
This Sundry is intended to document the proposed well work, including the modifications to the production casing,
and request approval to work over the well. If you have any questions or require any further information,please
contact me at 265-6341.
Sincerely,
A.
Andrew Beat
Wells Engineer
CPAI Drilling and Wells
•
1D-37 Rig Workover
P&R Tubing&Install Liner to Surface
(PTD#:200-204)
Current Status: This well was shut in on June 25,2016 and is currently waiting to be worked over to repair a
casing leak. 413.-z3
Scope of Work: Pull the existing 3-1/2"tubing, install a 5-1/2"liner to surface,install new 3-1/2"tubing.
General Well info:
Well Type: Producer
MPSP: .%2,629 psi using 0.1 psi/ft gradient
Reservoir Pressure/TVD: 3,237 psi/6,087' TVD(10.3 ppg EMW)measured on 07/08/2016 —
Wellhead/Pressure Rating: FMC Gen V, 11"5M psi top flange
BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams-
MIT results: CMIT-TxIA failed-09/03/2016(Prod.C g. leak at—4323')
MIT-T passed-07/25/2016
Earliest Estimated Start Date: December 7,2016
Production Engineer: Dana Glessner
Workover Engineer: Andreeat(263-6341/Andrew.T.Beat@ConocoPhillips.com)
Pre-Rig Work
1. Inspect pad and work area for hazards. Complete the PJSM.
2. RU Slickline.Pull plug and catcher at 9,877' MD.
•,,riocz, 3. Set plug in nipple at 1,Q41.06:-MD and set catcher sub on top of plug.
4. RIH and pull DV from GLM#5. • • O
•
5. RD Slickine.
6. PT POs and FT LDS. •
Set BPV w/i 24 hrs of rig arrival.
Proposed Procedure
1. MIRU. ki r--
2.
-2. Pull BPV.Reverse circulate seawater.Obtain SITP&SICP,if still seeing pressure at surface,calculate new
KWF,weight up, and repeat circulation as necessary.Verify well is dead. , S/44 �L
3. Set BPV,ND tree,NU BOPE&test to 250/3 si.
,5 4_ u�3�� r�
�p ��O'U
a. If the lower pipe rams are unable to be tested because of the blanking plug position,the lower pipe
rams will be tested upon pulling the completion.
4. Pull BPV, screw in landing joint,BOLDS's,unland tubing hanger.
5. POOH laying down 3 '/2"tubing.
a. On TOH, set a storm packer.RU Hydratight equipment, if necessary.NDBOP&Tbg head,grow casing,
and land in slips.Add casing spool.NU BOP,SL tfest.Pull storm packer.
6. MU cleanout BHA and cleanout well down to SSE.POOH laying down DP.
7. MU&RIH with 5-1/2"casing down to SBE.Circulate corrosion,inhibited fluid up the annulus.Engage seal
bore. �--�) f=r .5(, �' �ft+,^w. /tea<:, e�� �r-sE' �.•U�' ,%� c/z°
8. ND BOPE.Land casing in slips and cut off excess.NU tubing head and BOP and test. .� 1/41
9. RIH with new tubing to just above the SBE in the 5-1/2"casing.
10. Slowly cycle the charge pump and look for pressure increases or lack of returns as the seals engage. Shut down
charge pump. Space out,mark the pipe,and pull out of the SBE.
11. Install space out pups below the hanger,MU hanger.Load the IA with corrosion inhibited fluid.Land the
hanger,RILDS.
1
• •
1D-37 Rig Workover
P&R Tubing&Install Liner to Surface
(PTD#:200-204)
12. PT the tubing,bleed tubing,PT the IA,and record.Bleed the IA to zero,then tubing.Ramp up the IA pressure
quickly to shear the SOV. /Lem
C-1-w6.4). el c'
13. Pull the landing joint, install BPV.
I A- LS-tit re)S t
14. ND BOPE.
15. NU tree.Pull BPV and install tree test plug.Test tree and pull test plug.
16. Freeze protect well with diesel. Set BPV.
17. RDMO.
Post-Rig Work
1. Pull BPV.
2. RU Slickline:
a. Pull SOV and run GL design.
b. Pull catcher sub and plug. (0)pp(,
3. RD Slickline.
4. Reset well house(s)and flowlines of adjacent wells.
5. Turn well over to operations.
2
KUP PROD • 1D-37
ConocoPhillips iii Well Attributes Max Angle&MD TD
Ai l..M1,_I ,it. Wellbore APINWI Field Name Wellbore Status eel(1MD(ftKB) Act Blm(ftKB)
• pq<oRea115 500292299200 KUPARUK RIVER UNIT PROD 69.65 6,925.85 11,003.0
... Comment H25(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date
10-37,8/29/2016 1127134 AM SSSV:NIPPLE 55 11/10/2014 Last WO: 1/15/2001
Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date
......._..........._.....__...._....._.............. li, - Last Tag: 10,633.0 11/20/2006 Rev Reason:PULLED CA-2 PLUG pproven 8/29/2016
HANGER;28.8 =�:''=11
Casing Strings
Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WllLen(I...Grade Top Thread
ii 7 I I CONDUCTOR 20 19.052 34.0 120.0 120.0 91.50 H-40 WELDED
Casing DescriptionOD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread
I I`. SURFACE 95/8 8.835 33.9 5,081.0 4,380.2 40.00 L-80 BTC 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 32.9 10,093.0 6,261.9 26.00 J-55 BTC MOD
'MfrCONDUCTORp34.0-120.0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread
WINDOW L2 4 3.000 10,594.0 10,604.0 6,451.7
Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...1111./Len(I...Grade Top Thread
NIPPLE;521.8 WINDOW L1 4 3.000 10,741.0 10,751.0 6,507.7
Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread
LINER 31/2 2.992 9,920.0 11,003.0 9.30 L-80 SLHT
• Liner Details
GAS LIFT;2,577.3 Nominal ID
a Top(ftKB) Top(TVD)(ft8B) Top Incl(°) Item Des Cam (in)
9,920.0 6,199.1 68.79 TIE BACK BAKER TIE BACK SLEEVE 5.250
9,927.4 6,201.7 68.89 PACKER BAKER ZXP LINER TOP PACKER 4.408
GAS LIFT;4,300.8 - 9,934.9 6,204.4 68.94 HANGER BAKER FLEX-LOCK LINER HANGER 4.400
• 9,947.0 6,208.8 68.90 SBE BAKER 80-40 SBE 4.000
10,006.3 6,230.2 68.72 NIPPLE CAMCO'DS'NIPPLE w/2.75"NO GO PROFILE 2.750
Tubing Strings
Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection
SURFACE;33.9-5,081.0- TUBING 31/2 2.992 28.8 9,961.4 6,214.0 9.30 L-80 EUE 8rd
. Completion Details
GAS LIFT;6,742.6 Nominal ID
Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in)
28.6 28.8 0.00 HANGER FMC GEN V TUBING HANGER 3.500
al 521.6 521.7 1.96 NIPPLE CAMCO'DS'NIPPLE w/2.875"NO GO PROFILE 2.875
al
GAS LIFT;6,617.111 9,877.7 6,183.6 68.22 NIPPLE CAMCO'DS'NIPPLE w/2.812"NO GO PROFILE 2.812
9,922.5 6,200.0 66.82 LOCATOR BAKER NO GO LOCATOR(LANDS 6'BELOW TOL) 3.000
9,923.8 6,200.4 68.84 SEAL ASSY BAKER GBH-22 35'SEAL ASSEMBLY 3.000
GAS LIFT;9,825.4 9,958.8 6,213.0 68.87 SHOE 3.000
Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.)
Top(ND) Top Incl
•ir Top(ft8B) (ftKB) (°) Des Corn Run Date ID(in)
9,878.0 6,183.7 68.22 CATCHER 2.79"CATCHER 7/9/2016 0.000
NIPPLE;9,877.7 9,879.0 6,184.0 68.23 PLUG 2.81"CA-2 7/8/2016 0.000
CATCHER;9,878.0
10,624.0 6,459.3 67.78 PACKER WEATHERFORD WS-R-BB PACKER,BETWEEN 6/17/2005 1.250
PLUG;9,879.0 LATERAL LEGS L1&L2 WINDOWS
10,741.0 6,503.8 67.41 WHIPSTOCK FLOW-THRU WHIPSTOCK SET BELOW L2 LEG 6/17/2005 2.500
10,750.0 6,507.3 67.38 FISH Pert Gun Plug E-LINE PERF GUN ARMING POINT 3/25/2005
PLUG LEFT IN HOLE 1.23"x.588"
LOCATOR;9,922.5 Perforations&Slots
Shot
Dens
Top(TVD) Btm(TVD) (shotslf
ASSY,9,923.8 '1
71.tl Top(ftKB) Btrn(ftKB) (ftKB) (ftKB) Zone Date t) Type Com
MI 10,585.0 10,605.0 6,444.6 6,452.1 C-4,1D-37 3/18/2005 6.0 APERF 2.5"HSD,60 deg phase
g. 10,605.0 10,615.0 6,452.1 6,455.9 C-4,1D-37 3/19/2005 ' 6.0 APERF 2.5"HSD,60 deg phase;
II random orient
I10,705.0 10,720.0 6,490.0 6,495.8 C-4,1D-37 2/25/2001 6.0 (PERF 2.5"HSD,60 deg phase
d - Stimulations&Treatments
)( )'7UC� Min Top Max Btm
/` Depth Depth Top(ND) Btm(TVD)
(ftKB) _ (ftKB) (ftKB) (ftKB) Stg# Type Date Com
10,705.0 10,720.0 6,490.0 6,495.8 1 FRAC 3/11/2001
PRODUCTION;32.9-10,093.0- Mandrel Inserts
APERF;10,585.0-10,605.0
WINDOW L2:10,594.0-10,804.0 Top(ftKB) T(ftKB)°) Make Model OD(in) Sere Type Type PortSire TRO si))un Run Date Com
IQ®� INZMIIIIZMUJII ll M 0.000 7/20/2016 11=f e 4,300.8 4,030.0 CAMCO KBUG Gas Lift DMY 0.000 0.0 7/20/2016 ■
APERF;10,805n 10,615.0lin
6,742.6 5,007.6 CAMCO KBUG Gas Lift DMY 0.000 0.0 6/17/2007
0mizion 5700.0 nriggimisgimmagmiziggim 0.000 mu 6/4/2005
I 5 9,825.4 6,163.9 CAMCO KBUG 1 1/2 Gas Lift DMY RK 0.000 0.0 7/10/2016
Notes:General&Safety
PACKER;10,624.0 End Date Annotation
(PERF;10,70AC;5.0-10,
10,705.720.001 UI 1 1.:
7/1/2005 NOTE:MULTI-LATERAL WELL:MAIN LEG 1D-37,LATERAL LEGS 1D-37L1&1D-37L2
FR
I 1/27/2009 NOTE:VIEW SCHEMATIC w/Alaska Schemetic9.0
IPERF;10,735.0-11,053.01
LINER L1;10,7342-12,256.7 I
WHIPSTOCK:10,741.01
FISH:10,750.0
WINDOW LI:10,741.0-10,751.0,
(PERF;10,611.0-10,928.0•
LINER;9,920.0-11,003.0
LINER L2;10,608.1-12,988.31
• - - - - - - •
D-37
onocoPhuIIip KRU Producer
P&R Tubing
w/ Liner to Surface
PROPOSED
COMPLETION
Well Details:
API: 50-029-22992-00
PTD: 200-204
Wellhead: FMC Gen V 5M
Tree: FMC 3-1/8" 5M
s —4,323'- Production Casing Leak
Casing/Tubing Details:
20" 91.5# H-40 Conductor to 120' MD
9-5/8"40# L-80 Surface to 5,081' MD
7"26#J-55 Production to 10,093' MD
5-1/2" 15.5# L-80 Liner to 9,924' MD
3-1/2" 9.3#L-80 Tubing to-9,915' MD
Misc Details:
Max Inclination: 69.7°
Max Dogleg: 4.5°/100'
Last Tagged Fill: 10,614' MD
Total Depth: 11,003' MD
Perforation Details:
10,585'-10,615' MD-C4 Sand
10,705'-10,720' MD-C4 Sand
MID
ENO
5-W to 3-W XO and SBE
if
Existing Liner Packer and SBE
etT
Camco DS Nipple w/ Plug
C Sand Perfs
Date: November 21,2016 I Drawn By: Andrew Beat
• •
. Schwartz, Guy L (DOA)
From: Beat,Andrew T <Andrew.T.Beat@conocophillips.com>
Sent: Monday, November 28, 2016 8:58 AM
To: Schwartz,Guy L(DOA)
Cc: Bettis, Patricia K(DOA)
Subject: RE: KRU 1D-37 RWO (PTD 200-204)
Attachments: 1D-37 Wellhead Sketch.pdf; FMC Gen 5_Standard.pdf
Follow Up Flag: Follow up
Flag Status: Flagged
Guy,
1. We will be using Doyon 142 for the RWO.
2. The plug set at 10,006'will be pressure tested to 1,000'psi as well as negatively tested with a DDT.
3. A few documents are attached. FMC does not have a stock drawing for the proposed stack up so I have included
a schematic of the existing well head stack and a rough sketch of what is proposed.The added spool will have
11"x 5000 psi flanges.
4. We will most likely use the 4"drill pipe that is currently on D141 but that has not been finalized.
5. We will use KWF for the corrosion inhibited fluid in Step 7 and set a 5-1/2"storm packer just before N/D BOPE.
6. The breaks will be tested against the storm packer to 250/3,000 psi.
7. Tubing to 3,000 psi and IA to 2,500 psi.
Let me know if you need any additional information.
Thanks,
Andrew
From:Schwartz,Guy L(DOA) [mailto:guy.schwartz@alaska.gov]
Sent:Wednesday, November 23,2016 1:27 PM
To: Beat,Andrew T<Andrew.T.Beat@conocophillips.com>
Cc: Bettis,Patricia K(DOA)<patricia.bettis@alaska.gov>
Subject: [EXTERNAL]KRU 1D-37 RWO(PTD 200-204)
Andrew:
In reviewing the sundry application to install a 5 W liner in 1D-37 I have a couple of questions:
1) What rig is being used to do the RWO?
2) Are you pressure testing the SL set plug at 10006' in step 3(pre-rig Work)?Well passes a MIT-T recently so
should be able to test it.
3) Provide a before and after schematic of the new wellhead showing the added casing spool .
4) What size drillpipe are you using for the cleanout run on step 6?
5) When you land the 5 IA"casing in the wellhead what are your barriers when you ND BOPE to set slips?
6) How are you testing(method and pressure)all the new flange breaks internally after BOPE and tubing head are
nippled up in step 8?
7) What are your proposed test pressure for the tubing and IA in step 12?
Regards,
1
• •
Guy Schwartz
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).
2
S ,0
ConocoPhillips
. Calculations Chart
Subject !b- 7 poSheet number
File G 1II: / of
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41/16 5000 (0-39) IhIC
MONITOR PORT
8.59° -
(217.3 mm) SCSSV EXIT TEST PORT
(ONE% AND ONE%)-\ r---_- MI—
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(577.8 mm)
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(231.9 mm) i Br
2%16-5000 MODEL 120 CV
TEST PORT
TITITITI
5.08'
(129.0 mm)
i I i
LANDING RING
:r
-TEST POP.T
16 OD CASING �% "
ARCO ALASKA
95/8 OD CASING 4 ‘101r 0
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7 OD CASING 11-5000 THROUGH BORE SYSTEM 0
r— 16 X 9 5/8 X 7 X 4 1/2 0
41/2 OD TUBING 0
COLOR •0000DM1032273 O
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� wEtil
a.�.., „,�', .n�,,.�,,.E„K CASING PROGRAM ',m.o.: 1.039,000000!023235
Im; Project Well History File Coverage
XHVZE
This page identifies those items that were not scanned during the initial production scanning
phase, They are available in the original file, may be scanned during a special rescan activity or
are viewable by direct inspection of the file.
Organizing ~:~;~ []
RESCAN
¢~/r Color items:
[] Grayscale items:
D Poor Quality Originals:
E] Other:
NOTES:
BY:
Two-Sided
DIGITAL DATA
Diskettes, No.
[] Other, No/Type
OVERSIZED (Scannable)
D Maps:
Other items scannable by
large scanner
OVERSIZED (Non-Scannable)
Logs of various kinds
BEVERLY ROBIN VINCENT SHERY~WINDY
Other
Project Proofing
BY:
BEVERLY ROBIN VINCENT SHERY~~IC/INDY
ScaifningPreparation ~ x 30 = "~"(~
BY: BEVERLY ROBIN VINCENT SHER~INDY
Production Scanning
Stage I PAGE COUNT FROM SCANNED FILE:
PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ._~_'. YES
NO
B'f': BEVER(-'F(. RoBIN) VINCENT___ ............ , SHERYL MARIA WINDY
Stage2 IF NOIN STAGE 1, PAGE(S)DISCREP?~~ ~~--¢ ----'-'"'~
FOUND: YES NO
BEVERLY ROBIN VINCENT SHERYL MARIA~ DATE:
(SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN I~ PAGE BASIS
DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES )
RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE:
General Notes or Comments about this file:
lsl
Quality Checked
12/10/02Rev3NOTScanned,wpd
.
.
Conoc~hillips
Alaska
RECEIVED
AUG 1 3 2007
Alaska Oil & Gas Cons. Commission
Anchorage
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
August 9, 2007
Mr. Tom Maunder
Alaska Oil & Gas Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
JðO- :¡O4-
SCANNED AUG 1 42007
Dear Mr. Maunder:
Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of
these wells was found to have a void in the conductor. These voids were filled with a corrosion
inhibiter, RG2401, 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 corrosion inhibitor/sealant was pumped August 8, 2007. The attached spreadsheet presents
the well name, top of cement depth prior to filling, and volumes used on each conductor.
Please call me at 907-659-7043, if you have any questions.
Sincerely,
~-
ConocoPhillips Well Integrity Projects Supervisor
~
.
.
ConocoPhillips Alaska Inc.
Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off
Report of Sundry Operations (10-404)
Kuparuk Field
Corrosion
Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitorl
Well Name pro # cement pumped cement date inhibitor sealant date
ft bbls ft oal
1 0-32 200-173 10" n/a n/a n/a 6.8 8/8/2007
1 0-36 200-130 20" n/a n/a n/a 4.2 8/8/2007
1 0-37 200-204 20" n/a n/a n/a 4.2 8/812007
1 0-38 200-077 24" n/a n/a n/a 4.2 8/8/2007
1 0-39 200-216 27" n/a n/a n/a 7.6 8/8/2007
1 0-40 200-190 13" n/a n/a n/a 3.4 8/8/2007
10-41 205-188 12" n/a n/a n/a 1.7 8/8/2007
10-42 200-164 16" n/a n/a n/a 3.4 818/2007
10-131 198-110 6" n/a n/a n/a 2 8/8/2007
Date
8/9/2007
.
.
II ...,.... "'''QIn,''''
! I
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BAKEl
MUGHU
Transmittal Form
INTEQ
Anchorage GEOScience Center
To:
AOGCC
333 West 7th Ave, Suite 100
Anchorage, Alaska
99501
Attention:
Helen Warman
Reference:
1D-37L2PB1
'¡ll'
¡
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i'
II
II
Contains the following:
,-
i ¡¡~::;,ü I
_~'f'__""'_ .,'..o¡.u >''''':,1
"";", ",,,..w . . ..1
. ~'U'~'''\::W' :''r
i:::"'> , ~ :'. ,0> ;"~I
I~::~:~¡ ~..,'=
1 LDWG Compact Disc
(Includes Graphic Image files)
1 LDWG lister summary
.__..___.m~
1 blueline - GR Measured Depth Log
1 blueline - GR TVD Log
--.-..-"..-
I
,
¡
I
I,
'I
II
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1,·1
,
,
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-----.
..--._---------~------
SCANNEfJ¡ AUG ~i 1 2.006
, LAC Job#: 919593
II
Sent By: Deepo Jlelmr
Received By: ~'" £ A _______
Date: Aug.23, 2006
Date: ~<?o¿l~
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING
OR FAXING YOUR COpy
FAX: (907) 267-6623
Baker Hughes INTEQ
7260 Homer Drive
Anchorage, Alaska
99518
Direct: (907) 267-6612
FAX: (907) 267-6623
goo - ~oL.f
J4öo. 'd ~
F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc
MICROFilMED
04/01/05
DO NOT PLACE
ANY NEW MATERIAL
UNDER THIS PAGE
~.",
". ~. ß
.< '
)
)
Mike Mooney
Wells Group Team Leader
Drilling & Wells
ConocJ'Phillips
P. O. Box 100360
Anchorage, AK 99510-0360
Phone: 907-263-4574
April 8, 2005
Commissioner
State of Alaska
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue Suite 100
Anchorage, Alaska 99501
Rt:Ct:IVED
APR
1 2 2005
Alaska Oil & G
as Cons. CD '.
AnChorage rntniss10n
Subject: Report of Sundry Well Operations for 1 D-37 (APD # 200-204)
Dear Commissioner:
ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations
for the recent perforation operation on the Kuparuk well 1 D-37.
If you have any questions regarding this matter, please contact me at 263-4574.
Sincerely,
)111 f1~
M. Mooney
Wells Group Team Leader
CPAI Drilling and Wells
MM/skad
NNEr APQ 1: 4: 2DDS
-. ""',H..I .' n - -
blrrt· . '-.-' .
1. Operations Performed:
)
)
RECEIVE[)
APR 1 2 2005
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
Abandon D
Alter Casing D
Repair Well D
Pull Tubing D
Operat. ShutdownD
~~iI 0i1 8t§ëtS COliS. Gomrn. S~
Time Extension ~chorage
Re-enter Suspended Well D
Stimulate D
Waiver D
Plug Perforations D
Perforate New Pool D
Perforate [2]
4. Current Well Status:
Development [2]
Stratigraphic D
Change Approved Program D
2. Operator Name:
ConocoPhillips Alaska, Inc.
3. Address:
P. O. Box 100360, Anchorage, Alaska 99510
7. KB Elevation (ft):
RKB 29'
5. Permit to Drill Number:
200-204
6. API Number:
50-029-22992-00
Exploratory D
Service D
9. Well Name and Number:
10-37
8. Property Designation:
ADL 25661 & 25650, ALK 471
11. Present Well Condition Summary:
10. Field/Pool(s):
Kuparuk River Field 1 Kuparuk Oil Pool
Total Depth
Effective Depth
Casing
Structura I
CONDUCTOR
SURF CASING
PROD CASING
LINER
Perforation depth:
measured 11003' feet
true vertical 6606' feet
measured 1 0721' feet
true vertical 6496' feet
Length Size MD
80' 20" 120'
5053' 9-5/8" 5081'
10065' 7" 10093'
1083' 3-1/2" 11003'
Plugs (measured)
Junk (measured)
1 0740'
TVD
Burst
Collapse
120'
4380'
6262'
6606'
Measured depth: 10585'-10615',10705'-10720'
true vertical depth: 6445'-6456', 6490'-6496'
Tubing (size, grade, and measured depth) 3-1/2" , L-80, 9961' MD.
Packers & SSSV (type & measured depth) pkr= BAKER ZXP PACKER & 9927'
SSSV= Cameo OS Nipple @ 522'
12. Stimulation or cement squeeze summary:
Intervals treated (measured)
N/A
RBDMS 8Ft Ml412005
13.
Treatment descriptions including volumes used and final pressure:
Representative Daily Average Production or Injection Data
Gas-Met Water-Bbl
942 294
2116 578
15. Well Class after proposed work:
Exploratory D Development [2] Service D
16. Well Status after proposed work:
Oil0 GasD WAG 0 GINJD WINJ 0
17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt:
Oil-Bbl
206
419
Casinç¡ Pressure
Tubinç¡ Pressure
283
303
Prior to well operation
Subsequent to operation
14. Attachments
Copies of Logs and Surveys run _
Daily Report of Well Operations _X
Contact
Printed Name
Signature
WDSPL 0
Mike Mooney @ 263-4574
Mike Mooney
f1 J, 14~
Title
Phone
Wells Group Team Leader /. 1/
Date 4 'yO>
Preoared bv Sharon AI/suo-Drake 263-4612
ORIGINAL
Submit Original Only
Form 10-404 Revised 04/2004
)
1 D-37 Well Events Summary
)
Date Summary
03/18/05 PERFORATE THE INTERVAL 10605-10615 USING 2.5" HSD GUN LOADED 10' IN ONE
RUN. API CHARGE DATA: 2506 POWERJET HMX 6 SPF, 60 DEG PHASING,
RANDOM ORIENTATION. PENETRATION: 25.2"; ENTRANCE HOLE: 0.32". WELL
LEFT SHUT IN & FREEZE PROTECTED.
03/19/05 TAGGED BTM AT 10681'. PERFORATE THE INTERVAL 10585-10605 USING 2.5" HSD
GUNS LOADED 6 SPF, 60 DEG PHASING WITH 2506 POWERJET HMX CHARGES IN
TWO RUNS. API CHARGE SPECS: 25.2" PENETRATION, 0.32" ENTRANCE HOLE.
ON THE THIRD GUN RUN, THE TOOLSTRING WAS STUCK IN THE HOLE AT 7890'.
PULL OUT OF ROPE SOCKET AND RECOVER WIRE. OVERALL LENGTH: 34.6'. MAX
OD: 2.68" (ROLLERS). WELL LEFT SHUT IN.
03/21/05 PULL FISH UP TO 7459' SLM. HUNG UP. DROP CUTTER. FISHING STRING LEFT IN
HOLE. JOB IN PROGRESS.
[Fish]
03/25/05 PULL CUTTER BAR @ 7429' SLM. BEAT FISH DOWN TO 7468' SLM. PULL E-LlNE
FISH. BRUSH TBG. TAG @ 10,721' RKB. RDMO. GIVE WELL BACK TO BOL WHEN
READY.
[Fish]
NIP (522-523,
00:4 520)
Gas Lift
MandrelNalve
1
(2577-2578,
Gas Lift
MandrelNalve
2
(4301-4302,
Gas Lift
MandrelNalve
3
(6742-6743,
Gas Lift
MandrelNalve
4
(8617-8618,
NIP
(9878-9879,
00:4.520)
TUSING
(0-9961,
00:3.500,
10:2.992)
SEAL
(9924-9925,
00:4.000)
PKR
(9927-9928,
00:7.000)
LINER
(9920-11003,
00:3.500,
Wt:9.30)
SSE
(9947-9948,
00:5.000)
NIP
'10006-10007,
. 00:4.520)
Perf
: 10585-10605)
Perf
:10605-10615)
Perf
: 1 0705-1 0720)
')
ConocoPbUlips Alat..k. Inc.
1D~37
I
~
~1;;;¡::;:i,;:;I;:;TI;;~
;;-
~
""
>
;>
-7
""
~
~
L-L.
TVD Wt Grade Thread
120 91.50 H-40 WELDED
4380 40.00 L-80 BTC MOD
6262 26.00 J-55 BTC MOD
11003 9.30 L-80 SLHT
Wt I Grade I Thread
9.30 L-80 EUE 8rd
Date Type Comment
3/18/2005 APERF 2.5"HSD, 60 deg phase
3/19/2005 APERF 2.5"HSD, 60 deg phase;
random orient
6 2/25/2001 IPERF 2.5"HSD, 60 deg phase
API: 500292299200
SSSV Type: NIPPLE
Well Type: PROD
Orig 1/15/2001
Completion:
Last W/O:
Ref Log Date:
TD: 11003 ftKB
Max Hole Angle: 70 deg (ã> 6926
Annular Fluid:
Reference Log:
Last Tag: 10721
Last Tag Date: 3/25/2005
Casing String ~ .CASING
Description
CONDUCTOR
SURF CASING
PROD CASING
LINER
TubihgString ~ TUBING
Size I Top
3.500 0
Pérlorations. Sum mary
Interval TVD
10585 - 10605 6445 - 6452
10605 - 10615 6452 - 6456
Top
o
o
o
9920
Bottom
120
5081
10093
11003
Size
20.000
9.625
7.000
3.500
Bottom TVD
9961 6214
Zone Status Ft SPF
C-4 20 6
C-4 10 6
10705 - 10720 6490 - 6496
Stirnulations& Treatments
Interval I Date I Type
10705 -10720 3/11/2001 FRAC
GaS Lift· MaridrelsNålves
St MD TVD Man Man Type V Mfr
Mfr
1 2577 2574 CAMCO KBUG CAMCO
2 4301 4030 CAMCO KBUG CAMCO
3 6742 5007 CAMCO KBUG CAMCO
4 8617 5700 CAMCO KBUG CAMCO
5 9825 6164 CAMCO MMG CAMCO
Other :pluQs, equip., etc.)~ JEWELRY
Depth TVD Type
522 522 NIP
9878 6183 NIP
9922 6200 NIP
9924 6200 SEAL
9927 6202 PKR
9947 6209 SBE
¡ 10006 6230 NIP
111001 6605 SHOE
Fish - FISH
Depth Description
10740 Perf Gun Plug
C-3
15
V Type VOD Latch
GLV 1.0 BK
GLV 1.0 BK
GLV 1.0 BK
OV 1.0 BK
DMY 1.5 RK
Description
Camco DS Nipple wINo Go Profile
Camco DS Nipple wINo-Go Profile
Baker Locater
Baker GBH-22 Seal Assembly; 35' long
Baker ZXP Packer, w/5" TKC coupling
Baker SBE 80-40, w/TKC couplings & XO
Camco DS Nipple w/2.75" No-Go
Baker Float Shoe
KRU
1)·37
Angle @ TS: 68 deg (ã> 10573
Angle @ TD: 67 deg @ 11003
Rev Reason: Tag fill, PERFS
Last Update: 3/31/2005
Comment
Port TRO Date Vlv
Run Cmnt
0.156 1226 3/23/2001
0.188 1261 3/23/2001
0.250 1355 3/23/2001
0.250 0 3/23/2001
0.000 0 2/19/2001
ID
2.875
2.812
3.000
3.000
5.000
4.000
2.750
0.000
Comment
E-LlNE PERF GUN ARMING POINT PLUG LEFT IN HOLE 1.23" x
.588" 3/25/2005
Permit to Drill 2002040
DATA SUBMITTAL COMPLIANCE REPORT
41112003
Well Name/No. KUPARUK RIV UNIT 1D-37 Operator CONOCOPHILLIPS ALASKA INC
APl No. 50-029-22992-00-00
MD 11003 J TVD 6606 ~' Completion Dat 2125/2001 ~ Completion Statu 1-OIL Current Status 1-OIL UIC N
REQUIRED INFORMATION
Mud Log N._~o sample N._.~o Directional Survey
DATA INFORMATION
Types Electric or Other Logs Run:
Well Log Information:
Log/
Data Digital Digital
TypeMep;IhM 'a Fmt Name
ED "~ ./. --V~r LIS Verification--"-
ED~ Cn See Notes
Interval
Log Log Run
Scale Media No Start Stop
OH I
CH
(data taken from Logs Portion of Master Well Data Maint)
fi'"'" 5054 10977 Open
1 120 11003 Open
Dataset
Received Number Comments
1/3/2002 '"~04~~'~
I
211/2002 ~ 1205/~,D~gital Well Log data ~...~ v-~~.
NOTE: No paper copies of
logs were received M.~D_..
well
AND 'I'VD
Well Cores/Samples Information:
Name
Start
Interval
Stop
Sent Received
Dataset
Number
Comments
ADDITIONAL INFORMATION
Well Cored? Y
Chips Received?
Analysis
R ~.r~.ive. d '~
Daily History Received?
Formation Tops
~)/N
Comments:
Compliance Reviewed By: Date:
(
WELL LOG TRANSMITTAL
To: State of Alaska January 25, 2002
Alaska Oil and Gas Conservation Comm.
Attn.: Lisa Weepie
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
RE: MWD Formation Evaluation Logs 1D-37, AK-MM-00321
The technical data listed below is being submitted herewith. Please address any problems or concerns
to the attention of:
Jim Galvin, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518
11)-37:
Digital Log Images
50-029-22992-00
1 CD Rom
RECEIVED
F:~3 0 1 2002
Alaska Oil & Oas Cons. Commi~on
~cbor~e
WELL LOG TRANSMITTAL
To:
State of Alaska
Alaska Oil and Gas Conservation Comm.
Attn.: Lisa Weepie
333 West 7~ Avenue, Suite 100
Anchorage, Alaska
December 18, 2001
RE: MWD Formation Evaluation Logs 1D-37, AK-MM-00321
1 LDWG formatted Disc with verification listing.
APl#: 50-029-.22992-00
PLEASE ACKNOWLEDGE RECEI~ BY SlGlqNG AND liE~G A coPY OF 'l'li~ ;rRANSl~IITTAL
L~rI~a ;O ~ ~rr~o~ Or:
Sperry-Sun Drilling Service
Attn: Jun Galvin
6900 Arctic Blvd.
Anchorage, Alaska 99518
Date:
RECEIVED
JAI',I 0 3 2002
Alaska 0il & Gas Gon~ ~,oltii'r, lsSlO,
PHILLIPS Alaska, Inc.
A Subsidiary of PHILLIPS PETROLEUM COMPANY
Post Office Box 100360
Anchorage, Alaska 99510-0360
J. Trantham
Phone (907) 265-6434
Fax: (907) 265-6224
April 5, 2001
Commissioner
State of Alaska
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue Suite 100
Anchorage, Alaska 99501
Subject: Completion Report for 1D-37 (200-204)
Dear Mr. Commissioner:
Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the
Kupamk well 1D-37.
If you have any questions regarding this matter, please contact me at 265-6434 or Todd Mushovic at
265-6974.
· Si~cerely,~_...~ ~'~
Drilling Engineering Supervisor
PA1 Drilling
JT/skad
RECEIVED
APR 06 2001
Alaska 0il & Gas Cons. CoiltrrtJssJor
(' STATE OF ALASKA ('
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1. Status of well Classification of Service Well
Oil ~] Gas [~ Suspended D Abandoned r~ Service
2. Name of Operator 7. Permit Number
Phillips Alaska, Inc. 200-204
3. Address 8. APl Number
P. O. Box 100360, Anchorage, AK 99510-0360 50-029-22992-00
4. Location of well at surface , ~ ~ 9. Unit or Lease Name
FNL, 421' FEL, Sec. 23, T11N, R10E, UM (ASP: 560670, 5959174)-''-.''C:'.'''''-'- ' '-';":i"i"'~".q' '~' "" '
Kuparuk
River
Unit
492'
At Top Produdng Interval ! ,Z ;":'"' :: i ~ 10. Well Number
At
lota~
D~th
285' FNL, 926' FEL, Sec. 25, T11 N, R10E, UM (ASP: 565489, 5954144),~.~.275 ....... i..-~;::::', ~ Kuparuk River Field
5. Elevation in feet (Indicate KB, DF, etc.) 16. Lease Designation and Serial No. Kuparuk River Pool
RKB 29 feetI ADL 25661 & 25650 ALK 471
12. Date Spudded 13. Date T.D. Reached 14. Date C...0rpP., Susp. O_r Aband. 115. Water Depth, if offshore 16. No. of Completions
December 23, 2000 January 8, 2001 ~z~d'l ~ I N/A feet USE 1
17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + T. VD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness o! Permafrost
11003' MD / 6606' TVD 10968' MD / 6592' TVD YES ~] No D'1 N/A feet MD 1418'
22. Type Electric or Other Logs Run
GR/Res/Neu Dens
23. CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD
CASING SIZE WT. PER FT. GRADE TOP BO'I-rOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED
20" 91.5# H-40 Surface 121' 24" 460 sx AS I
9.625" 40# L-80 Surface 5081' 12.25" 612 sx AS III LW, 403 sx LiteCRETE
7" 26# J-55 Surface 10093' 8.5" 170 sx Class G
3.5" 9.3# L-80 9920' 11003' 6.125" 243 sx Class G
24. Perforations open to Production (MD + TVD of Top and Bottom and 25.. TUBING RECORD
Interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD)
3.5" 9961' 9927'
10705'-10720' MD 6490,-6496' TVD 6 spf
26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
10705'-10720' MD 96M# 16/20 LDC in formation~ left 29M# proppant
in wellbore
27. PRODUCTION TEST
Date First Production Method of Operation (Flowing, gas rift, etc.)
March 27, 2001 Flowing
Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO
3/28/2001 5 hours Test Period > 938 1626 0 176I 1769
Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (con')
press. 250 psi not available 24-Hour Rate > 4404 7790 1 not available
28. CORE DATA
Brief description of Ilthology, porosity, fractures, apparent dips and prsssence of oi1, gas or water. Submit core chips.
"'^ RECEIVED
APR 06 2001
Form 10-407 Rev. 7-1-80
GEOLOGIC MARKERS FORMATION TESTS
NAME Include interval tested, pressure data, all fluids recovered and gravity.
MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase.
Top Kuparuk C 10573' 6440'
Base Kuparuk C 10811' 6531'
Top Kuparuk A 11003' 6606'
Base Kuparuk A 11003' 6606'
Annulus left open - freeze protected with diesel.
31. LIST OF ATTACHMENTS
Summary of Daily Operations, Directional Survey
32. I hlreby certify that the following Is true and con'ect to the best of my knowledge. Questions? Call Todd Mushovic 265-6974
!
Slgne~. 0 ~ Title Drlllln,q En,qineerin,q Supervisor Date
J. Trantham
Prepared by Sharon AIIsup-Drake
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 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 cementing and the location
of the cementing tool.
Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection,
Shut-in, Other-explain. REceIVED
Item 28: If no cores taken, indicate "none".
Form 10-407
Operations Summary 1 D-37 ~'
Rpt No
12/22/00
12/22/00
12/22/00
12/22/00
12/22/00
12/22/00
1 2/22/00
1 2/23/00
1 2/23/00
1 2/23/00
1 2/23/00
1 2/23/00
1 2/23/00
12/23/00
1 2/23/00
1 2/24/00
12/24/00
12/24/00
12/24/00
1 2/24/00
12/25/00
1 2/25/00.
1 2/25/00
12/25/00
1 2/2'5/00
1 2/25/00
12/25/00'
12/25/00
12/25/00
12/25/00
12/25/00
12/25/00
12/26/00
1 2/26/00
1 2/26/00
1 2/26/00
12/26/00
12/27/00
1 2/28/00
12/28/00
12/28/00
12/28/00
12/28/00
12/28/00
12/28/00
12/28/00
12/28/00
Comments
Prep. to Move Rig
Move Rig out of way to make room for Veco to dig 1 D-39 Conductor
Stand-By for Veco to finish 1 D-39 Conductor, Button up cellar, Place rig mats under rig
Service Iron Roughneck,clean out suction screen, change oil in drawworks & rotary table,clean
magnetic filters on both pumps,change sock filters
Change oil on both pumps, work on Top Drive,Swivel Auger, Perform Safety Audit & Derrick
inspection
Raise Rig ,Pull matts,Move Rig over 1D-37,Place Rig matts
Latters to cellar area
Rig up & Berm Cellar,Spot & Rig BallmilI,Finish changing oil in Mud Pumps,Iron
roughneck,Auger in pits
Nipple up Diverter System, Install Mouse hole. Rig Accepted on 1 D-37 @ 0200 hrs.
Install Kelly hose,5" Elevators,P/U Std. of 5"DP
Function Test Diverter System as per AOGCC
Rig up Floor,Thaw, Meas.&Caliper BHA, Mix spud mud
Change Rotary table oil,Complete prespud check list (Held prespud meeting)
Pick up & stand back 8"DC's(Rabbit same), Make up BHA,Tag BTM @ 130', Fill hole & check
for leaks
Drill f/130' to 300' ART=3 hrs
Run GYRO to check MWD-OK
Drill 12-1/4" Hole f/300' to 1646' ART= 6hrs, AST= 5 hrs
Pump Sweep, Plugged screens in pump - clean out same
Drill f/1646' to 2106' ART= 3hrs
Circ. Btm up, Pump sweep & circ hole clean f/wiper trip
Circ. hole clean, Monitor well, Pump dry job, Blow down top drive
Short trip to HWDP (800') - OK
Service top drive & Blocks
R.I.H., Break Circ.-OK
Drill f/2106~ to 2116' ART= 1/2hrs (Top drive shut down)
Circ.& Work pipe (Trouble shoot problem w/Top drive- Found Bad blower motor in SCR)
Pump dry job, POOH, Down load MWD, Change bits
Slip & Cut Drlg. line
RIH to 2116'-OK
Circ. Btm's up & Hole clean
Change control card for top drive
Drill f/2116' to 2765'MD / 2758'TVD ART=3.5hrs AST=2hrs
Drill from 2765' to 3530'
Circ hole clean.
Monitor well. Blow down mud lines, Short trip from 3530' to 2100'. RIH. No problems.
Circ hole clean
Drill from 3530' to 3808'
Drill from 3808' to 4932'
Drill from 4932' to 5096'
Pump sweep and circ. Monitor well.
Short trip to 3430' w/no problems
Service rig and topdrive. Change swivel packing
RIH w/no problems
Circ and pump dry job
POOH
Stand back hwdp w/jars
Stand back 2 stds 87" d.c.'s
Operations Summary 1 D-37 (
12/28/00
12/28/00
12/29/00
1 2/29/00
12/29/00
12/29/00
12/29/00
12/30/00
12/30/00
1 2/3O/OO
12/30/00
12/30/00
1 2/30/00
12/30/00.
12/30/00
1 2/30/00
12/31/00
12/31/00
12/31/00
12/31/00
12/31/00
12/31/00
12/31/00
12/31/00
1/1/01
1/1/01
1/1/01
1/1/01
1/1/01
1/1/01
1/1/01
1/2/01
1/3/01
1/3/01
1/3/01
1/3/01
1/3/01
1/3/01
1/3/01
1/3/01
1/3/01
1/4/01
1/4/01
1/4/01
1/4/01
1/4/01
1/4/01
1/4/01
1/4/01
R/U casers and hold safety meeting
P/U float equipment and check. Run casing.
Run 9-5/8" casing. M/U hanger and landing jt.
Circ and condition mud for cement job
Hold safety meeting. Pump 10 bbl water, PT lines to 3000 psi. Pump 20 bbl preflush, 50 bbl
Mudpupsh, 462 bbl Lead @ 10.7 ppg, Drop bottom plug. Pump 171 bbl Tail @ 12.0 ppg. Drop
top plug and pump 10 bbl water. Displace w/371.5 bbl mud. Bump plug @
R/D cement head. L/D landing jt. and casing equipment. Attach kelly hose to topdrive. Flush
diverter.
P/U diverter and prep speedhead
N/U speed head and test to 1000 psi
N/U BOPE, riser, koomey lines, kill/choke lines
M/U test joint and test plug. R/U to test BOPE
Thaw choke and kill lines
Test BOPE to 250/5000 psi, annular to 250/3500 psi.
Blow down lines. Pull test plug and set wear ring
P/U bha and orient
RIH w/hwdp and jars
P/U additional 5" d.p. from shed
Continue RIH P/U 5" d.p. RIH tag cmt @ 4990'
Circ and condition mud
R/U and test casing to 2500 psi for 30 min-OK. R/D
Drill cement, float equipment, and new hole to 5124'
CBU
Perform LOT to 14.1 ppg
Perform PWD baseline test
Drill from 5125' to 5960'
Drill from 5960' to 7561'
Circ sweep around till hole clean
POOH to shoe. Tite 20K over @ 5930'. Good hole fill
Service rig and topdrive
RIH w/no problems
CBU
Drill from 7561' to 7566'
Drill from 7566' to 9790'
Drill from 9790' to 9980'
Changeout breaker to MWD unit
Drill from 9980' to 10110'
Circ and condition mud.
POOH to 7500'
Service rig and top drive
RIH
Circ sweep and condition mud
POOH for casing
POOH
L/D jars, accelerators. Download MWD and L/D.
Pull wear ring and clear floor
R/U to run 7"
Run 7" to 5026'
Circ and condition mud
Run 7" to 7050'
Circ and condition mud
Operations Summary 1 D-37 I~
1/4/01
1/4/01
1/4/01
1/4/01
1/5/01
1/5/01
1/5/01
1/5/01
1/5/01
1/5/01
1/5/01
1/5/01
1/5/01
1/5/01
1/5/01
1/5/01
1/5/01
1/6/01
1/6/01
1/6/01
1/6/01
1/6/01
1/6/01
1/6/01
1/6/01
1/6/01
1/6/01
1/7/01
1/7/01
1/7/01
1/7/01
1/7/01
1/7/01
1/8/01
1/8/01
1/8/01
1./9/01
1/9/01
1/9/01
1/9/01
1/9/01
1/9/01
1/9/01
1/9/01
1/9/01
1/10/01
1/10/01
Run 7" to 8850'
Circ and condition mud
Run 7" to 10092'. M/U hanger and landing jt.
Circ and condition mud
Circ and condition mud. L/D Fillup tool. R/U cmt head hold safety meeting. Circ while
cementers prime up.
Pump 10 bbl water. Test lines to 3300 psi. Pump 20 bbl preflush, 30 bbl Mudpush and drop
bottom plug. Mix and pump 35 bbl slurry and drop top plug. Pump 10 bbl water to flush lines
and displace w/276 bbl mud w/rig pump. Did not bump plug. Check fl
R/D cement head. L/D landing it. Drain stack and washout. Change bales and elevators
Install packoff and test to 5000 psi-OK
Change lower PR's to 4" Run test plug
Change topdrive and iron roughneck from 4-1/2" IF to 4" HT-38
R/U test jt and valves. Fill stack
Test BOPE to 250/5000, Annular to 250/3500 psi.
Blow down lines pull test plug set wear ring L/D test jt.
L/D excess 5" out of derrick
Attach kelly hose to Top drive slide strip-o-matic into place
P/U 11 stands of 4" d.p. and stand back
M/U bha
P/U bha and orient,
Program MWD, load sources,
P/U flex collars and test mwd. P/U jars
RIH P/U 4" d.p.
Circ W/R 9953' to 9960'
L/D single and cut drilling line
Test casing to 3500 psi 30 min.- OK.
R/D test equipment
Drill cement top plug float collar shoe rathole and new hole to 10137'.
Circ and displace hole w/new mud
Circ
Perform LOT to 16.1 ppg EMW
Perform PWD baseline test
Drill from 10137' to 10857'
Circ and condition mud
Drill from 10857' to 10953'
Drill fro.m 10953' to 11003'
Circ hig vis sweep. Circ hole clean
Circ and reciprocate. Weather at phase III.
Circ.& Work pipe, Weather @ Phase III
Wipe hole, Hole packed off @ 10,500', Work pipe to 10,790' still packed off, RIH to 11,003'
Work pipe & Regain minimal circulation
Work pipe & Circ. slow while adding 5 ppb Barofibre, Slowly regained full circ. @ full pump rate,
Pump sweep
Back ream to shoe, 10-15K drag @ 10,614',10,482',10,461'10,365', Good hole fil
Circ. Btm's up
Monitor well, Service Top drive
RIH, No tight spots
Circ. & Work pipe. Pump sweep. Build 150 bbls mud volume while bypassing shakers &
maintaining 5 ppb Barofibre. Note: total mud lost in hole this day 120 bbls.
Monitor well, PJSM, Pump out to shoe @ 10,092'
Pump dry job, Drop rabbit, POOH (SLM- no correction)
..
Operations Summary 1 D-37
1/10/01
1/1 O/01
1/10/01
1/10/01
1/10/01
1/10/01
1/10/01
1 / 10/01
1/11/01
1/11/01
1/11/01
1/11/01'
1/11/01
1/11/01
1/11/01
1/11/01
1/11/01
1/12/01
1/12/01
1/12/01
1/12/01
1/12/01'
1/1 2/01
1/12/01
1/1 2/01
1/12/01
1/13/01
1/13/01
1/13/01
1/13/01
1/13/01
1/13/01
1/13/01
1/13/01
1/13/01
1/13/01
1/13/01
1/13/01
1/14/01
1/14/01
1/14/01
1/14/01
1/14/01
1/14/01
1/14/01
1/14/01
1/15/01
1/15/01
1/15/01
1/15/01
Lay down Jars and Flex collars
Down load LWD
H2S alarm sounded- Evac. rig, secure pad, mask up & check alarm- found faulty gas detector
Lay down mud motor, Change BHA, Program LWD
Repair lay down machine (Hydralic leak)
Surface test LWD
Finish repairing lay down machine
Finish P/U BHA. RIH to 10237'
Circ. @ 10237'- attempt to survey- found LWD not responding
TIH to 11003'
Pump Sweep, Circ hole clean
Monitor well, Pump out to shoe @ 10092'
Pump dry job, Drop rabbit, POOH
Reprogram LWD
TIH to shoe, Surface test LWD @ 300'
TIH, Check surveys @ 10136',10232',10328', Wash to 10700'
Perform mad pass w/LWD f/10700' to 10960' Lost 14 bbls while circ.
Perform Mad pass f/10960' to 11003'
Pump sweep, Circ. & Cond f/3.5" liner
Monitor well, Pump out to 7" shoe
Pump dry job~ Drop rabbit, POOH
Lay down BHA
Down load LWD
Rig to run 3.5" csg.
PJSM, Run 3.5" csg.
RIH w/3.5" liner (slow)-fill pipe every 2000'
Circ. & cond. mud @ 7" shoe
RIH tag Btm. @ 11003'
Pick up cmt. head & rig to circ.
Circ. & Cond. mud, Run mud over shakers to remove LCM
PJSM, Cmt. 3.5" liner as per detail. Bump Plug
Pree up & set hanger, attempt to release f/liner, Can not get off liner. Pulled liner uphole
approx. 20'. Mechanically release f/hanger & set packer
Circ. out excess cmt.& pipe clean-est. 10 bbls cmt.returns
Monitor well, Pump dry job, Lay down 4" drill pipe
Slip & cut drlg line 140' Service top drive & drawworks
Work on lay down machine (hydralic pumps)
Lay down 4" D.P.
PJSM-Lay down 4" D.P. using air hoist
Lay down 4" D.P. using air hoisl
Pull wear bushing, Clean floor
RIH w/4" D.P. f/derrick; Lay down same
Rig & Run 3.5" completion string to 9919'- Perform injectivity test on 9 5/8"X 7"ann.
Circ. Btm's up
Tag T.O.L check spacing
Rig & Test Csg. f/30 min.-OK
Circ. & change over to Sea water
Circ. & change over to Sea water
Pick up Tbg pups & Hanger, Land Tbg as per detail., Rig pump lines
Test Tbg.15 min.-OK, Test 3.5" X 7" ann. 15 min.-OK, Shear DCR valve w/3500 PSI
Pump 80 bbls. Diesel down 3.5" X 7" ann. & Let U-Tube to Tbg.
i'" Operations Summary 1 D-37 (~"
1 / 15/01
1/15/01
1/15/01
1/15/01
Install 2 way check valve, Change rams to 4 1/2"X 7", Change top drive to 5"
Nipple down B.O.P., Nipple Tree, Test same to 250 PSI Iow 5000 PSI high
Pull 2 way check, Install B.P.V.
Inject remaining drlg fluids, Move ball mill & tanks, Break down injection lines. Rig released
from 1D-37 @ 1800 hours 01/15/01 to move to 1D-39.
Well Service Report (
Well IIJob S~op~
1D-37
IIDRILLING SUPPORT-CAPITAL
Date IIDaily Work
02/25/2001 IIDRILLXNG SUPPORT-CAPITAL: CTUfrCP
I]job Number
1[o214011843.3
[Unit Number
DayIIoperation Complete IIsu~f~
oII ~ II '"~a~
I o II 2600 II ~ooo
II r>s-~ow~ II RAUCHENSTEINI]~
I1 1075 II 300 II 250
II
Daily RIH WITH 1 11/16" WEA~'HERFORD MHA, SCHLUMBERGER 2.125 FIRING
Summary HEAD, 2 1/2" HSD. ALL SHOTS FIRED FROM, 10705'-10720'. POWER JET 6
SPF 60 DEG. WELL FREEZE PROTECTED TO 2300'. [Perf]
I~ime IILog ~.ntry
09:00 AOL MIRU/SAFETY MEETING, DISCUSS PERF GUN INSTALATION
PROCEEDURES. ISOLATE CONSTRUCTION CREWS ON PAD UNTIL GUN IS
DOWN HOLE. INSTALL 2 1/2"- 31.1- UJ - RDX - EXPL. LOAD=10.5GPM- ENT
HOLE=0.29" - PEN.=17.32"- 3 1/2" CASING. 2-1/2" - 35B - UP- RDX - EXPL.
LOAD= 10.5GM - ENT. HOLE=0.62" - PEN = 5.8" - 3 1/3" CASING. 2 1/2" - 2506
- PJ - HMX- EXPL. LOAD=10.5 GM - ENT.HOLE=0.32" - PEN.=0.25" - 3 1/2"
CASING. 6 SPF 2506 PJ.
10:00 PREP.TO PT ALL SURF EQUIP WITH TRIPLEX PUMP ON THE BACKSIDE.
PT TO 4000g
10:10 ' LEAK ON LUBRICATOR O-RING, CHANGE OUT--RE-PREP FOR PT WITH
TRIPLEX ON THE BACK SIDE.
~o:~ IIrr ALL SU~ EQUIP TO ~00 Pax, GOOD TEST P~P TO ~. I
a0:~ lira 0 WHP a000 XA ~00 OA urr ~SmCT~ON A~OU~D ~D-~7 I
13:25 PULL UP TO FLAG DEPTH COUNTER READS, 10812' CORRECT DEPTH TO
10806' TO BOTTOM SHOT. PUH TO 10720' TO FIRE GUNS. LAUNCH 1/2"
BALL
13:37 BALL ON SEAT @ 19.9 BBLS AWAY STAY AT MIN RATE TILL 27.5 BBLS.
RAMP RATE TO ENGAGE SHEAR ACTION. GUNS APPEAR TO HAVE SHOT
AT 4200 PSI CTP 1650 WHP. IA=1075 OA=250
14:13 ATTEMPT TO INJECT AT .3 BPM TO CONFIRM GUNS FIRED. FORMATION
OPENED AT 3100 PSI WHP. 3100g WHP + 2383 HSP = 5483# FRAC PRESS
EST. WATCH PRESSURE FALL OFF TO 1375# EST BHP 3758# PRESS STILL
BLEEDING OFF EXTREMELY SLOW AFTER 30 MIN WATCH.
14:42 [IPOOH SIWHP = 1300 PSI. MAINTAIN WHP WHILE POOH.
16:02 OOH SWAP CHECKS. 0 WHP. PULL OFF WELL AND CHECK GUNS. ALL
SHOTS FIRED.
16:45 STAB BACK ON WELL PUMP 20 BBLS STRAIGHT DIESEL DOWN WELL @
1BPM. WELL FREEZE PROTECTED TO 2300'
16:53 SIWHP= 950 PSI WHILE CHANGING TOOLS TO FREEZE PROTECT WELL.
BPM @ 300 WHP.
IIFREEZE PROTECTED.
I-'age I oI 2
Well Service Report
Well I]Job Scope IlJob Number
1D-37 IID~x~o SUPPORT-CAPrrAL 1[02~40~ 1843.3
o~t~ Ilo~ay Work light Number
03/11/2001 IIDRXmNG SUPPORT-CAPITAL: INITIAL FRAC STIM I
IlI)~y IIop~r~tao. Complete IIsu~c~e~i I1~ P~r~o. IIs~p~or
0 IITra~l[ False II DS-YOAKUM II ODEgmmD~-g I
Init Tbg Press IIFin~'Tbg Press IIInit Inner Ann IIFinal Inner Ann IlInit Outer Ann IIFinal Outer Ann
1220 II 0 II 20 II ~00 II 350 II 450
Daily PUMPED INITIAL FRAC TREATMENT. HAD NEAR WELLBORE
Summary SCREENOUT IN 4-12 PPA RAMP. PLACED 96M# 16/20 LDC IN FORMATION,
LEFT 29M# PROPPANT IN WELLBORE. 65% OF DESIGN PLACED. [Frae-
Refrac]
Time [[Log Entry
l1:00 IIMIRU DS FRAC EQUIPMENT. PRE RIG-UP SAFETY MEETING.
13:30 TAILGATE SAFETY MTG, (10 DS, 2 PAI, 2 LRS, IAPC). JOB REVIEW,
MUSTER AREA, CONGESTION BY WELL, ACTIVITY ON PAD.
13:40 IIPR~m UP PUMPS, TEST GEL, 2:30 X-LINK TIME.
14:15 SET TREE SAVER. PRESSURE TEST LINES/MANIFOLD 9000 PSI. MAX
PRESSURES 7900 PSI, 3700 BACKSIDE.
14:30 PUMP 197 BBL BREAKDN. PERFS BROKE DN AT 7800 PSI @ 32 BPM. ISIP
1875 PSI. PERFORMED SDT, XS FRIC = 775 PSI AT 15 BPM, ELIMINATE
SCOUR STAGE. MAKE GEL FOR DATAFRAC.
15:00 START DATA FRAC. PUMPED 100 BBL DATA FRAC, 95 BBL FLUSH, 2100
ISIP. DECLINE DATA NOT ANALYZABLE, STRANGE PRESSURE
FLUCTUATIONS. RE-PUMP DATA FRAC.
15:30 PUMP DATA FRAC 2. 100 BBL XL,. 100 BBL FLUSH, ISIP 2050. ANALYZE DF,
GO WITH 250 BBL PAD AND RE-DESIGNED PROPPANT STAGES TO LESS
AGRESSIVE 4-12 PPA RAMP.
16:30 PUMP FRAC. SAW TSO AT 56 MINUTES INTO JOB, HAD NWBSO IN 4-12
PPA STAGE W/96,000 LBS IN FORM, 9.1 PPA ON PERFS, 29,000g LEFT IN
TBG. 125,000 TOT PUMPED. 65% OF DESIGN' PUT AWAY.
. ag:00 IIFLUSH LI~ES, PI)MO F~C EQMT. RETRmVED ALL TREE SAVER CUPS.
20:00 DS RIGGED OFF OF WELL, WELL SECURED. TREE WILL BE WRAPPED
AND A HEATER INSTALLED TO KEEP TREE FROM FREEZING.
DEFINITIVE
Kuparuk River Unit
.
. Phillips Alaska
Kuparuk fD, Slot ~D-37
"~D-37
Surveyed: 11 January, 2001
S UR VEY REPORT
1.February, 2001
Your Ref: AP1500292299200
Surface Coordinates: 5959174.03 N, 550670.65 E (70° 17' 56.3585" N,
Kelly. Bushing: 104.90ft above Mean Sea Level
149° 30' 31.1956"
ORILLINI~
A Halliburton Company
Survey Ref: $vy9377
Kuparuk River Unit
Measured
Depth
(ft)
~ncl..
230.00 0.250
295.59 0.280-
383.09 0:220
475.43 0.840
572.23 3.170
664.28' -5.430
-753.62 5.600
849.09. -6.010
.942.57 4.210
1033.69 2.990
1128.22 1.320
1220.90 0.590
1312.47- 0.430
1405.40 0.420
1501.20 0.390
1596.23 0.370
1688.08 0.370'
i782.50 0.410
1877.07 0.460
1972.81' 0.340
2068.16 0.440
2162.22 ' 0.520
2255.97 2.410
2349.79 3.930
'2446.06 5.010
.2540.83 -7.060
'2633.39 9.610.
2725.58 12.100
2821.79 -13.470
2911.93 14.900
Azim.
78.000-
76.270
303.770
295.990.
290.240
'287.550
288.170.
281.440-
292.790
297.780
290.050
296.880
286.660
279.450
278.470
260.670
265.460
262.030
271.000
259.120
278.5O0
271.600
87.540
92.72Q
'98.370
i06.520
i13.580
116.650
116.470
116.600
Sub-Sea
Depth
(ft)'
125.10
190.69
-278~19
370.52
467.26
559.04
647.97'
742.95
836.06'
927.00
1021.46
1114.12
1205.69
1298.62
1394.41
1489.44
1581.29
1675.71
1770.28
1866.01
1961.36
2055.42
2149.15
2242.82
2338.80
2433.04
2524.61'
2615.15
2708.97 .
2796.36
Sperry. SUn Drilling ServiCes
Survey Report for f D-3'
"Your Ref: AP1'500292299200
Surveyed: 11 January, ~001
Phillips 'Alaska
Kuparuk 1D
VertiCal
Depth
.(ft)
230.00
295.59
383.09
475.42
572.16
663.94
.752.87
847.85
940.96
1031.90
1126.36
1219.02
1310.59
1403.52
1499.31
1594.34
1686.19
1780.61
1875.18
1970.91
2066.26
2160.32
2254.05
2347.72
2443.70
'2537.94
2629.51
2720.05
2813.87
2901.26
Local Coordinatee Global Coordinatee
Northings Eaetings Northinge Eaetings
(ft) (ft) (ft) - (ft)-
0.05 N 0.23 E
0.12 N- 0.53E
0.26 N 0.60 E
0.66 N 0.16 W
1.89 N 3.31 W
4.09 N
6.72 N
9.17N
11.47. N
13.87 N
5959174.08 N 560670.88 E
15.39
-15.97
16.29
16.44
16.55
5959174.15 N 560671.18 E
.5959174.30 N 560671.25 E
5959174.69 N 560670.49 E
5959175.90 N 560667.33 E
16.54
16.47
16.40
16.36
16.31
9.85W 5959178.04 N 560660.77 E
18.02W 5959180.61N 560652.58 E
27.34W .5959182.97 N 560643.23 E
35.31W 5959185.21N 560635.25 E
40.49W. 5959187.57 N 560630.05 E
16.32
16.38
16.48
16.41
15.84
43.70W
45.12W
45.87W
.46.54W
47.21W
13.38 N.
8~67 N
1.26 N
8.26 S
18.13S-
47.84W'
48.42W
49.06W
49.78W
50.44W
51.08W
51.86W
50.32W
45.14W
37.68W
28.00 W
15.47 W
0.22 E
19.27 E
39.03 E
5959189.07 N 560626.83 E
5959189.84 N 560625.40 E
5959189.94 N 560624.65 E
5959190.09 N 560623.97 E
5959190.19 N 560623.30 E
5959190.19 N 560622.68 E
5959190.11N 560622.09 E
5959190.04 N 560621.46 E
5959189.99 N 560620.74 E
5959189.94N 560620.08 E
5959189.93 N 560619.44 E
5959189.99 N 560618.65 E
5959190.10 N '560620.20 E
5959190.07.N 560625.38 E
5959189.37 N 560632.84 E
5959187.19 N 560642.54 E
5959182.58 N 560655.11E
5959175.29 N 560670.86 E
5959165.93 N 560689.98 E
5959156.22 N 560709.82 E
Dogleg
Rate
('/t00ft)
0.05
0.52
0.67
2.41
2.46
0.20
0.83
2.20
1.38
1.79
0.80
0.20
0.06
0.03
0.13
0.03
0.05
0.09
0.15
0.17
0.10
3.12
1.65
1.21
2.34
2.96
2.77
1.42
1.59
Vertical
Section
0.12
0.28
0.22
-0.59
-3.64
-9.72
-17.23
-25.40
-32.52
-37.82
-41.12
-42.53
-43.27
-43.84
-44.37
-44.80
-45.15
-45.53
-45.99
-46.41
-46.85
-47.44
-46.45
-42.85
-37.19
-28.92 ·
-16.91
-0.77
19.21
39.93
Comment
Tie on point
AK-6 BP_IFR-AK
DrillQuest 2.00.06
'1 February, 2001 - 10:26 Page'2 of 6
. .
Kuparuk River Unit
Measured
Depth
fit)
3009.37
3102.30
3197.54
3291.28
3387.45
3475.60
3566.82
3660.41
3754.48
385O.95
Incl.
Azim.
sub.sea.
Depth-
(ft)
3946.05
4042.83
4136.10
4229.54
4324.17
4418:39
4509.28
4603.93
4693.59
4790.63
4884.20
4981.86
504724
5139.59
5234.22
5325.54
5415.57
5508.70
5593,38
5690.65
16.750 116.330 '2890.10
18.340 119,390 2978.71
21.220 '121.510 "_ 3068.32
24.060 121.890 3154.83
26.640 124.350 3241.73
29.670
32.830
36.520
39,270
40.63O
44.710
46.460
~49.520
51.970
53.340
55.850
59.450
- 63.O80
67.000
67.310
67.630'
'67.180
-67.070
67.350.
66.440
66.180
68,180
68,400
68.100
67.710
126.320
128.510
128.960
-129.370
'130.610
'132.620
132.080
134.000
135.580
136.450
135.400
136.070
i38.070
138.380
139.480
138.520
138.530
138.340
137.400
'138.670
137.750
'138.680.
138.380
137.530
138.910
3319.45
3397.42
3474,38
3548.61
3622,56
3692.47
3760.20
3822.62
3881.74
3939.15
3993.73
4042.36
4087.86
4125.68
4163,36
4199.21
4236.73
4262.27 -
4297.92
4335.06
'4371.75
4406.67
4441.12
4472.49
45O9.08
Sperry-Sun Drilling Services
Survey Report for 1D-37-
Your Ref: AP1 500292299200'
Surveyed: fl 'January, 200~
Vertical
Depth
2995.00
3083.61
3173.22
3259.73
3346.63
.
3424.35
3502.32
3579,28
3653.51
-3727.46
3797.37.
'3865.10
'3927.52
3986,64
4044.05
4098.63.
4147.26
4192.76
4230.58
4268.26
4304.11-
4341.63
4367.17
44O2.82
4439.96
4476.05
4511.57
4546.02
4577.39
4613.98
· .
Local Coordinates'
Northings
(ft)'
29.97 S
43.08 S
.59.45 S
78.41 S
100.94 S
Global COOrdinates
125.02 S
153.79 S
187.11 S
223.60 S
..
263.42 $
3O6.24 S
352.81 S
400,12 S
451.10 S
505,23 S
..
560.39 S
615.37 S
676.14 S
736.75 S
804.17 S
869.40 $
936.95 S
982.23 S
1045.17 S
1109.88 S
1172.23 S
1234.11 S_
1298.94 S
1357.35 S
1424.55 S
Easfings Northings Easfings
.(ft) (ft) (ft)
62.82 E 5959144.57 N 560733.71 E
87.56 E 5959131.66 N 560758.55 E
115.32 E 5959115.52 N 560786.44 E
146.01 E . 5959096.80 N 560817.29 E
180.46 E 5959074.55 N 560851.92 E
214.37 E 5959050.75 N 560886.02 E
251.92 E' ' 5959022.27 N 560923.80 E
- 293.44 E 5958989.29 N 560965.59 E
338.23 E 5958953.16 N 561010.67 E
385.68 E 5958913.73 N 561058.44 E
..
433.82 E 5958871.30 N 561106.93 E
464.91 E 5958825.15 N 561158.39 E
-535.53 E 5958778.25 N 561209.40 E
586.86 E 5958727.68 N 561261.14 E
639.10 E 5958673.98 N 561313.81 E
69Z52 E 5958619.25 N 561367.68 E
746.10 E 5958564.70 N 561421.70 E
802.60 E 5958504,39 N 561478.68 E
856.74 E 5958444.22 N 561533.31 E
915.49 E 5958377,28 N 561592.60 E
972.19 E 5958312.51 N 561649.83 E
1031.91 E 5958245.44 N. 561710.09 E
'1072.05 E 5958200.49 N 561750.60 E
1128.98 E '5958138.01 N 561808.03 E
1187.18 E 5958073.77 N 561866.76 E
1242.91 E 5958011.87 N 561922.98 E
-1298.20 E 5957950.45 N 561978.77 E
' 1355,50 E 5957886.08 N 562036.59 E
1408.17 E 5957828.10 N 562089.73 E.
1468.22 E 5957761.38 N 562150.32 E
Dogleg
Rate
(°ll00ff)
1.90
1.98
3.12
3.03
2.90
3.60
3.68
3.95
2.94
1.63
4.52
1.85
3.62
2.93
1.62
2.81
4.01
4.26
4.38
1.09
1.01
0.46
0.31
0.99
1.56
0.97
2.42
0.38
1.00
1.37
Vertical
Section
64.84
91.33
122.26
157.09
197.09
237.85
284.53
337.24
394.50
456.00
520.18
589.09
658.23
730.53
805.75
882.53
959.29
1042.26
1123.50
1212.87
1299.23
1389.36
1449.85
1534.70
1621.71
1705.31
1788.27
1874.75
1953.39
2043.48
Phillips Alaska
Kuparuk 1D
Comment
DrillQuest 2.00.06
. f February, 2001 - 10:26 Page 3 of 6
..
SperrY'Sun Drilling ServiCes
Survey Report for 1D-37
yoUr Ref: AP1 500292299200
Surveyed: 11 January, 2001 .
Kuparuk River Unit
Measured
Depth
(ft)
5780.12
5878.19
5973.74'.
6072.57
6168.06
Incl.
67.480_
68.910
68.960
68.430
68.130
6262.55 .'67.700
6356.49 67.300
6452.40 67.000
6543~10 66.970
6640.53 69.120
6738.10.- 68.570
6829.49 68.720
6925.84 69.650
7020.96 69.440
7113.68 69.240
-7205.26 69.050
7301.88 68.970
739641 68.720
'7489.68 68.490
7582.17 68.430
Azim.
139.130
-137.980
138.820
138.580
138.770.-
137.840
137.650
138.520.
139.380-
138.500
1391880
137.650
136.670
136.990
137.970
i36.450
136.250
137.590
136.830
137.930
Sub-Sea
Depth
(ft)
4543.19
4579.61
4613.96
· 4649.87
4685.20
4720.73
4756.68
4793.92'
4829.39
4865.81'
4901,02
4934.31
4968.55
5001.79
5034~50
5067.11
5101.72
5135.83
5169.86
52O3.82
-7677.27 68.210 137.950 5238.95
7770.98 68.200 136.960 5273.74
7864.23- 68.190 '136.840' 5308.38
7958.45 68.330 '137.060 5343.28
8052.78 67.790 137.470 5378.52
18146.45 67.440 -136.950
8239.48 66.940 '136.890
8333.71 66.610 -137.960
8428.30 67.720 136.750
8524.33 . 68.250 137.100
54i4.20
-- 5450.26
5487.42
'5524.13
5560.13
Vertical
Depth.
·
Local CoOrdinates
Northings Eastings
(ft) (ft)
4648,09 1487,00S 1522A6 E
4684.51 1555.24S 1582,73 E
4718'.86 1621.92 S 1641,93 E
4754.77 1691,09 S -1702,70E
4790, i0 1757,71S 1761,28 E
4825.63 1823,09 S 1819,52 E
4861,58 1887,33 S 1877,87 E
.4898,82 1'953,10 S 1936,92 E
4934,29 2016,05 S 1991,74E
4970.71 2084,18 S 2051,09E
5005.92 2153.05 S 2110.56E
5039.21 2217.05 S 2166.66 E
5073.45 2283.08 S 222~90 E
5106.69 2348.08 S 2288.88 E
5139.40' 2412.03 S 2347.51E
5172.01
5206.62
- 5240.73
5274.76
5308.72
· 5343.85
5378.64
5413.28
5448.18
5483.42
5519,10
· 5555,16
5592,32
5629,03
5665.03.
Global Coordinates Dogleg
Northings Easfings Rate
(ft). (ft). (°ll00ft)
5957699.37 N 562205.07 E
5957631.62 N 562265.89 E
5957565.42 N 562325.62 E
5957496.74 N 562386.95 E
'5957430.59 N ·562446.06 E
5957365.69 N 562504.82 E
5957301.92N 562563.70 E
5957236.64N 562623.27 E
5957174.13 N 562678.60 E
.
5957106.48 N 562738.50 E
5957038.09 N 562798.53 E
5956974.55 N 562855.14 E
5956909.01N 562916.91E
5956844.50 N 562978~41E
5956781.04N 563037.56 E
2474.83 S 2405.64E 5956718.71N 563096.19 E
2540.10 S -2467.91E 5956653.94N 563158.99 E .
.2604.49 S 2528.12 E 5956590.04 N 563219.72 E
2668.22 S 2587.12 E 5956526.79 N 563279.22 E
2731.52 S-. 2645.37E 5956463.95 N -563337.98 E
2797.13 S
2861.24S
.2924.45S
2988.41S
3052.68 S
3116.24S
3178.87S
3242.64S
3306.75 S
3371.79 S-
2704,57 E 5956398,82 N 563397,71E
2763,40 E 5956335,20 N 563457,06 E
2822,56E 5956272,46 N . 563516,73 E
2882,30 E- 5956208,99 N '563576,99 E
2.941,68 E 5956145,20 N 563636,88 E
3000,52 E 5956082,12 N 563696,23 E
3059,09 E 5956019~96N 563755.30 E
31i7,67 E 5955956,67 N 563814,40 E
3176,73 E 5955893,03 N 563873,97 E'
3237,53 E 5955828,49N 563935,30 E
0.34
1.82
0.82
0.58
0.36
1.02
0.47
0.89
0.87
2.36
1.43
2.28
1.35
0.38
1.01
1.56
0.21
1.35
0.80
1.11
0.23
0.98
0.12
0.26
0.7O
0.63
0.54
1.10
1.66
0.65
Vertical
Section
2126.14
2217.15
2306.28
2398.30
2486.97
2574.49
2661.27
2749.63
2833.O5
2923.35
3014.26
3099.32
3189.38
3278.50
3365.25
3450.83
3541.03
3629.19
3716.03
3802.05
3890.41
3977.41
4063.99
4151.51
4239.00
4325.61
4411.37
4497.96
4585.12
4674.15
Phillips Alaska
Kuparuk 1 D
Comment
DrillQuest 2.00.06
1 February, 200f - 10:26 Page 4 of 6
Sperry-Sun Drilling Services
Survey Report for tD.37
Your Ref: AP1500292299200.
Surveyed: 11 January, 2001
. .
Kuparuk River' Unit-
Measured'
Depth
eft)
8615.81
8709.11
8800.36
8895.59'
8989.13
9082.66
9177.24
9271.83
9364.32'
9458.27
InCl.
67.530
67.450
67.100
66.690
67.480
67.550
67.270
67.20O
67.040
66~81o
9551.42
9645.O7
9743.23
9837.17
9931.98
10025:19
10194.84
10294.22,
10390.22
10485.97"
'68.080
- 68.160
: 68.060
-67.670
68.950
68.660
68.150
68.24O
68.050
68.410
10578.14
10674.34
10771.45
10866.87.'
10961.55
67.880
67.680
.67.290
66,670
67.270
Azim.
136.600
137.110
137.4oo
137.62o
137.26o
138.520
139.340
139.120
138,780
138.950
138.'e!o
137.99o
136.32o-
137.71o
138.o3o
138.74o
138.19o
137.45o
136.24o
136.1oo
136.190
137.280
137.250
138.640
t38.610
11003.00 67.270 138.610
Sub-Sea'
Depth
(ft) '
5594.56
5630.28
5665.53
5702.90
5739.32
5775.09
5814.42
5848.03
5883.99
5920.81
5956.54
5991.44
6028.04
- 6063.43.
.- 6098.47
6132.!7
6194.61
6231.53
6267.26
6302.78
6337.09
6373.47
6410.65
6447.97
6485.01
-6501.02
. Vertical
Depth
(ft)
5699.46
5735.18
5770.43
5807.8O
5844.22
5879.99
5916.32
5952.93
5988.89
-6025.71
6061.44 _
-6096.34
6132.94
6168.33
6203.37
6237.07
6299.51
6336.43
6372.16 -
6407.68
6441.99
6478.37 .
6515.55
6552.87
6589.91
_.
6605.92 -
Local Coordinates
Northings
(ff)'
3433.62 S
.'. 3496.51S
3558.32 S
3622.91S
3686.37 S.
3750.48 S
3816.31S
3882.36 S
3946.63 S
4011.72S
Eastings
(ft)
Global Coordinates
Northings Eastings
(ft) (ft)
3295.50 E 5955767.13 N 563993.76 E
3354.44 E 5955704.72 N 564053.21 E
3411.56 E 5955643.37 N 564110.83 E .
3470:73 E 5955579.26 N 564170.51 E
3529.00 E 5955516.28 N 564229.30 E
4076.53 S
4141.51S
4208.29 S
4271.95 $
4337.28 S
3586.95 E 5955452.64N 564287.76 E
3644.32E 5955387.27 N 564345.66 E
-3701.28 E 5955321.67 N 564403.15 E
3757.24E 5955257.87 N 564459.63 E
3814.10 E 5955193.23 N 564517.01E
4402.25 S
4520.33 S
4588.70 S
4653.70 S
4717.85 S
4779.53 S
4644.38 S
4910.27 S
4975.48 S
5040.86 S
3870.67 E
3928.37E
3990.30 E
4049.63 E
4108.72 E
4166.44E
4271.03 E
4332.99 E
4393.93 E
4455.51E
4514.78E
4575.81E
4636.69 E
4695.52 E
4753.11 E
5069.54 S 4778.39 E
5955128.88 N 564574.10 E
5955064.37 N 564632.32 E
5954998.09 N 564694.80 E
5954934.92 N 564754.64 E
5954870.06N 564814.26 E
5954805.56 N 564872.49 E
5954688.33 N 564978.04 E'
5954620.46 N 565040.54 E
5954555.95 N 565102.01 E
5954492.31 N 565164,10 E
5954431.10 N 565223.87 E
5954366.75 N- 565285.42 E
5954301.35 N 565346.83 E
5954236.62 N 565406.18 E
5954171.71 N 565464,30 E
5954143.23 N 565489.81 E
Dogleg
Rate
('/lOOff)
0.94
0.51
0.48
0.48
0.92
1.25
0.85
0,23
0.38
0.30
1.37
0.82
1.58
1.43
1.39
0.78
0.43
0.70
1.19
0.40
0,58
1.07
0.40
1.49
0.63
0:00
Vertical
Section
4758.90
4845.10
4929.26
5016,84
5103.00
5189.40
5276.66
5363.81
5448.96
5535.34
5621.31
5708.18
5799.25
5886.27
5974.35
6061.22
6218.89
6311.15
6400.25
6489.16
6574.70
6663.76
6753.46
6841.26
6928.35
Phillips Alaska
Kuparuk 1D
Comment
6966.56 Projected survey
1 February, 200f - 10:26
..
Pagesof6
DrillQuest 2.00.06
Sperry-Sun Drilling ServiCes
.. Survey Report for 1D.37
Your Ref: APl 500292299200
Surveyed: 11 January: 200t
.
.
Kuparuk River Unit
All data'is in feet unless otherwise stated. Directionsand coordinates are relative to True North.
Vertical depths are relative to Well.' Northings and Eastings are relative to Well.
Magnetic Declination at Surface is 26.341°..(23-Dec-00)
The Dogleg SeveritY is in Degrees per 100 feet.. --
-Vertical Section is from Well and calculated along an Azimuth of 136.820° (True).
Based'upon Minimum Curvature type'calculations, at a Measured Depth of i 1003.00ft.,
The Bottom Hole Displacement is 6966.58ft., in the Direction of t36.693° (True).
Phillips Alaska
Kuparuk 1D
Comments
Measured
Depth
(ft)
230.00
' 11003.00
Station Coordinates
TVD -Northings EastJngs
(ft) (ft)
230.00 0.05 N -0.23 E
6605.92 5069.54 S 4778.39 E
'Comment
Tie on point .
'Projected survey.
Survey tool program for 1D-37
. .
From To
Measured'Vertical Measured- Vertical
. .
-Depth- Depth Depth Depth
.. (ft) -(ft) (ft) (ft)
0.00 0.00 -230.00- 230.00-
230.00 230.00 11003.00- 6605.92
Survey Tool Description
TOlerable Gyro (1D-37 GYRO)
AK-6 BP_IFR-AK (1D~37).
1 February, -2001 - 10:26 Page 6 of 6 DrillQt~est 2.00.06
ALASKA OIL AND
CONSERYA~ION
James Trantham
Drilling Engineering Supervisor
Phillips Alaska, Inc.
P O Box 100360
Anchorage, AK 99510-0360
Re:
Kupamk River Unit ID-37
Phillips Alaska, Inc.
Permit No: 200-204
Sur Loc: 492'FNL~ 420.5'FEL, Sec. 23, T11N, R10E, UM
Btmhole Loc. 297'FNL, 946'FEL, Sec. 25, TI 1N, R10E, UM
TONY KNOWLES, GOVERNOR
3001 PORCUPINE DRIVE
ANCHORAGE, ALASKA 99501-3192
PHONE: (907) 279-1433
FAX: (907) 276-7542
Dear Mr.' Trantham:
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. ..
Annular disposal has not been requested as part of the Permit to Drill application for Kuparuk River Unit
Well No. ID-37. Please note that any disposal of fluids generated from this drilling operation which aTM
pumped down the surface/production casing annulus, of a well approved for annular disposal on drill site
1D must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to ..
drill, does not authorize disposal of drilling waste in a volume greater than 35,.000 'barrels. through the.
amaular space of a single well or to use that well for disposal purposes for a period longer.than.one year.
The blowout prevention equipment (BoPE) must be tested in accordance with 20 AAC 25.035; and the
mechanical integrity (MI) of the injection wells, must be demonstrated under 20 AAC 25.412 and 20/LAC
25.030(g)(3).. Sufficient notice (approximately 24 hOUrs) of the MI test before, operation, and of the
BOPE test performed before drilling below flae surface casing shoe, must be given so that a representative
. of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum
field inspector"on the North Slope pager at 659-3607.
Sincerely,
Daniel T. Seamount, Jr.
Commissioner
BY ORDER OF..~HE .COMMISSION
DATED this ' 7_ ?._ '~'~/' day of December, 2000
dlf/Enclosures "
CC:
Department of Fish & Galne, Habitat SeCtion w/o encl.'
. Department of EnvirOnmental Conservation w/o encI.
STATE OF ALASKA {'"
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
la. Type of work: Drill r~! Redrill D I lb. Type of well. Exploratory D Stratigraphic Test D Development Oil r~i
Re-entry J--J Deepen aJ sewice D Development Gas r"l single zone r~l Multiple Zone D
2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool
Phillips Alaska, Inc. RKB 34 feet
3. Address 6. Property Designation Kuparuk River Field
P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25661 & 25650 ALK 471 Kuparuk River Pool
4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2O AAC 2S.02Sl)
492' FNL, 420.5' FEL, Sec. 23, T11N, R10E, UM Kuparuk River Unit Statewide
At top of productive intewal 8. Well number Number
16' FNL, 1197' FEL, Sec. 25, T11N, R10E, UM 1D-37 #59 52 180
At total depth 9. Approximate spud date Amount
297' FNL, 946' FEL, Sec. 25, T11 N, R10E, UM December 15, 2000 $200,000
12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres In property 15. Proposed depth (MD and 'rVD)
16 @ Target feet.I 1D-36 14.4' @ 414' feet 2560 11003' MD/6600' TVD
16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 2S.03S (e)(2))
Kickoff depth: 2300 MD Maximum hole angle 67.9° Maximum surface 2908 psig At total depth (TVD) 3630 psig
18. Casing program Settin~l Depth
size specifications Top Bottom Quant~ of Cement
Hole Casin~l Wel~lht 'Grade CoupIin~l Len~lh MD TVD MD TVD (include stage data)
30" 20" 91.5# H-40 Weld 86' 34' 34' 120' 120' 230 sx ASl
12.25" 9.625" 40# L-80 BTCM 5032' 34' 34' 5066' 4366' 520 sx AS III Lite & 400 sx UteCRETE
,
8.5" 7" 26# J-55 BTCM 10105' 34' 34' 10139' 6275' 170 sx Class G
6.125" 3.5# 9.3# L-80 SHLT 1014' 9989' 6218' 11003' 6600' 220 sx Class G w/Gasblook
19. To be completed for Redrill, Re-entry, and Deepen Operations.
Present well condition summary RECEIVED
Total Depth: measured feet Plugs (measured)
trueve.,ce, feet D£C 04 000
Effective Depth: measured feet Junk (measured) JtJ~l~J(a 0il & Gas Cons. Commission
true vertical feet
Anch0ra~e
Casing Length Size Cemented Measured depth True ~ertlcal depth
Conductor
Surface
Production
Liner
Perforation depth: measured
true vertical
20. Attachments Filing fee r~. Property Plat D BOP Sketch D Diverter Sketch D Drilling program [~]
Drilling fluid program r~ Time vs depth plot [--~Refractlon analysis r'~ Seabed report r'~ 20 AAC 25.050 requirements D
21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Call Todd Mushovic 265-697~
Signed Title: Drilling Engineering Supen, isor Date
j. Tranthafff"--~'{~ ~J~'
Pret~ered by ~heron AIIsu~-Drelr~
Commission Use Onl}
Permit' N umber ,~..~_,'~-~.,,,,/_.¢;~ I APInumber I Approv.al date ... ISee cover letter
50- O ~c~.. ~ ~_, ~.,._ ~ /~ "~ C~" ~ Ifor other requirements
Conditions of approval Samples required r'! Yes jl~ No Mad log required r-'l Yes [] No
Hydrogen seffid, measures ~ Yes D No Directional sawey required [] Yes D No
RequlredworidngpressureforBOPE O2M; O 3M; '~~ D 10M;rl O
Other:.
ORIGINAL SIGNED BY
Approved by D Taylor Seamount by order of
Commissioner the commission Date ___ ""
ORIGINAL
Form 10-401 Rev. 12/1/85 · Submit in triplicate
GENERAL DRILL AND COMPLETE PROCEDURE
EBA PRODUCER
KRU 1 D-37
General Procedure:
1. Excavate cellar, install cellar box, set and cement 20" conductor to +/- 150' RKB. Weld
landing ring on conductor.
2. Move in / rig up Nabors Rig 16E Install diverter & function test same.
3. Spud and directionally drill 12-1/4" hole to 9-5/8" surface casing point (+/5066 MD') according
to directional plan. Run MWD / LWD logging tools in drill string as required for directional
monitoring and formation data gathering.
4. Run and cement 9-5/8" 40.0# L-80 BTCM casing to surface using lightweight permafrost
cement lead slurry to assure cement returns to the surface. Adequate excess cement will be
pumped to ensure cement reaches the surface during the first stage cement job. Displace
cement with mud.
5. Nipple down diverter and install wellhead. Nipple up BOPE and test to 5000 psi. Record
results.
6. Shut in BOP's and pressure test casing to 3000 psi for 30 minutes per AOGCC regulations.
Record results.
7. Drill out cement and 20' to 50' of new hole. Perform formation integrity test not to exceed 16.0
ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe
per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW).
8. Directionally drill 8-1/2" hole to base HRZ (10139' MD) according to directional plan. Run
MWD / LWD logging tools in drill string as required for directional monitoring and formation
data gathering. Perform second LOT at to evaluate long string option. If LOT is adequate to
long string, drill to well total depth (11003' MD), run 7" 26.0# J-55 BTCM casing to surface and
cement, and continue with step #~'. ~
Note: If significant hydrocarbon zones are present above the Kuparuk, sufficient cement
will be pumped for isolation in accordance with Rule 20 AAC 25.030
9. If LOT is inadequate to long string, Run 7" 26.0# J-55 BTCM casing to surface and cement.
Note: If significant hydrocarbon zones are present above the Kuparuk, sufficient cement
will be pumped for isolation in accordance with Rule 20 AAC 25.030
10. Nipple up BOPE and test to 5000 psi. Record results.
11. Shut in BOP's and pressure test casing to 3000 psi for 30 minutes per AOGCC regulations.
Record results.
12. Drill out cement and 20' to 50' of new hole. Perform formation integrity test not to exceed 16.0
ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe
per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW).
13. Drill 6-1/8" hole to well total depth (+/- 11003' MD) according to directional plan, running LWD
logging equipment as needed. Circulate and condition hole. POOH
14. Run open hole e-line or drill pipe conveyed logs as needed.
15. Run and cement 3-1/2" 9.3# L-80 SHLT liner and Baker ZXP/Flexlock hanger/packer
assembly. Set packer +/- 150' above intermediate casing shoe to provide appropriate liner
lap.
16. RIH with clean out BHA. Scrape casing. Displace well to completion brine.
17. Run and land 3-1/2" tubing with gas lift completion. R E C E IV E D
DEC 04 2000 TJM, 12/2/00, vl
Alaska Oil & Gas Cons. Commission
Anchorage
18. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up production tree. Pull
BPV. Install test plug. Pressure test production tree. Pull test plug. Secure well.
19. Freeze protect well. Set BPV. Release rig and turn well over to production.
20. Clean location and RDMO in preparation for coiled tubing cleanout and perforating.
RE'CEIVED
D£C 04 000
*aJaska Oil & Gas Cons. Commission
Anchorage
TJM, 12/2/00, vl
DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, &
DRILLING AREA RISKS
KRU 1 D-37
Drilling Fluid Properties:
Density
PV
YP
Viscosity
Initial Gel
10 Minute Gel
APl Filtrate
pH
% Solids
Spud to 9-5/8"
Surface Casin[I
8.5-10.2
16-26
25-50
100-200'
10-20
15-40
7-15
9.5-10
6-8%
Drill out to 7"
Intermediate Casing
8.8-9.8
5-25
8-25
35-55
3-10
10-15
5-15
8.5-9.5
6-8%
Drill Out
to TD
11.1-13.0
25-35
20-30
50-65
4-7
4-8
8-10
8.0-8.5
4-7%
Drilling Fluid System - Nabors 16E
3 - Derrick Shale Shakers
Desander
Desilter
Mud Cleaner
Centrifuge
Degasser
Pit Level Indicator (w/visual and audible alarms)
Trip Tank
Fluid Flow Sensor
Fluid Agitators
*Spud mud should be adjusted to a FV between 180-250 sec/qt to drill gravel beds
Notes:
Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033.
Maximum Anticipated Surface Pressure:
Two possibilities exist for the possible maximum anticipated surface pressure (MASP) seen by the surface
casing string along the 1 D-37 well path.
1)
MASP can be calculated using an expected leak-off of 13.2 ppg EMW (0.69 psi/ft) and a gas gradient of 0.11
psi/ft. This shows that formation breakdown would occur at a surface pressure of 2532 psi. The leak off
EMW was chosen based on an open hole LOT on well, 1 D-32, taken to 13.2 ppg at 4596' TVD (0.69 psi/ft).
MASP = (4366 ft)(0.69 - 0.11)
= 2532 psi
RECEIVED
DEC 04 2000
Alaska 0ii & Gas Cons. C0mlllJssJorl
Anchorage
2)
If surface shoe LOT is higher than expected and the well is drilled out of surface casing to TD, the MASP can
be calculated based on a reservoir pressure of 3550 psi at 6600' TVD (0.55 psi/fi) and a gas gradient of
0.11 psi/ft. In this case, MASP would occur at,~l~4 psi.
MASP = (6600 ft)(0.55 - 0.11) = 2908 psi
Phillips Alaska, Inc. will test the BOP equipment to 5000 psi prior to drilling out of surface casing.
In the event that the well has to be topset above the Kuparuk, the maximum anticipated pressure for the
intermediate casing string would continue to.,3~ psi as calculated previously.
Phillips Alaska, Inc. will test the BOP equipment to 5000 psi prior to drilling out of intermediate casing if an
intermediate string is needed.
Based the anticipated pressures shown, a maximum mud weight requirement for this well is established based
on the potential charging of the D-shale sands. Assuming a 150 psi overbalance is required to safely drill and
trip in this formation, then a required mud weight of 11.0 ppg can be predicted as the maximum mud weight
needed to safely conduct rig operations, assuming a TVD of 6600'.
MW = [(6600 ft)(0.55)+150]/6600/.052
= 11.0 ppg
In order to allow for a long string design, the minimum LOT in the HRZ or surface casing shoe must be greater
than ECD (equivalent circulating density) with a 14.0 ppg drilling fluid as modeled or as measured with the
Pressure While iDrilling (PWD) sub, plus adequate safety margin..
Well Proximity Risks:
· The nearest existing well to 1 D-37 iS1D-36. As designed, the minimum distance between the two wells would
be '14.4' at 414' MD.
. .
Drilling Area Risks:
Risks in' the 1D-37 drilling area include surface interval hydrates, lost. cimulation, and potential borehole instability
in and below the permafrost zone as well as through the.intermediate shales. Hydrate risks will .be minimized by
the use of ~ufficient mud weights to allow for tripping of Pipe, controlled drilling rates,' and rheological properties
which safely appropriate gas breakout.. Lost circulation will be addressed with' lost circulation material (LCM),
reduced circulating rates, and reduced' mud weights as needed. Shale instability will be controlled, primarily with
the planned fluid densities. Additional risk exists with unpredictable charging of the D-shale sands during historic
gas injection. These gas pressure risks are mitigated with mid-HRZ LOT's and a top set option above the D-
shale based upon 'those results...
Annular' Pumpin_cl Operations:
Incidental fluids developed from drilling operations will be either injected into an approved a·nnulus on the same
pad or hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be injected
down the dedicated dispOsal well but will be recycled or held for an open annulus.) The open annulus Will be left.'
with .a non-freezing fluid during 'any extended shut down (> 4 hr) in pumping Operations. 'The 1D-37
surface/production casing annulus will be filled with diesel after setting production, casing and prior to the drilling
rig moving off. of the well.. If isolation is required per regulations over significant, hydrocarbons, then sufficient
cement volume will be pumped during the production cement job to cover those formations.
RECE.I'V'E'D ,
DEC 04 2000
Alaska .0ii & Gas Cons. Commission
. Anchorage
At the end of drilling operations, a request for 1D-37 to be permitted for annular pumping of fluids occurring as a
result of future drilling operations on 1D pad, per regulation 20 AAC 25.080, will be submitted. Any zones
containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's
open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the
enclosed directional drilling plan for other formation markers in this well.
Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500'
thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface
casing shoe will be set a minimum of 200' vertically below the base of the West Sak into the heart of the shales.
The surface and production casing strings exposed to the annular pumping operations have sufficient strength
by using the 85% collapse and burst ratings listed in the following table:
Wt Connection 85% of 85% of
OD (ppf) Grade Range Type Collapse Collapse Burst Burst
9-5/8" 40 L-80 3 BTC 3,090 psi NA 5,750 psi 4,888 psi
7" 26 J-55 3 BTCM 4,320 psi 3,672 psi 4,980 psi 4,233 psi
3~/2''* 9.3 L-80 2 8rd EUE Mod 10,530 psi 8,951 psi 10,160 psi 8,636 psi
*ifneeded
Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in
20 AAC 25.080 (h).
RECEIVED
DEC 04 2000
Alaska Oil & Gas Cons. Commission
Anchorage
KRU 1 D-37 Prod[/ - r
Proposed Completion Schematic
Long String Base Case
pHiLLIPS Alaska, Inc.
A Subsidiary'of PHILLIPS PETROLEUM COMPANY
20" 91.5# H-40
@ +/- 120' MD
Depths are
based.on
Nabore 16E.
RKB
Surface csg.
9-5/8' 40.0# L-80 BTCM
(+/- 5066' MD / 4366' TVD)
Future Perforations
Production csg.
7' 26.0# J-55 BTCM .
'(+/- 11003' MD/6600' TVD)
3-112' FMC Gen V Tubing Hanger, 3-1/2" L-80 EUE8RD pin down
3-1/2' 9.3# L-80 EUE8RD Spaceout Pups as Required
3-1/2' 9.3# L-80 EUE8RD Tubing to Surface
3-1/2' Camco 'DS' nipple w/2.875' No-Go Profile. 3-1/2' x 6' L-80 pup installed
above. 3-1/2' x 6' L-80 flow coupling installed below, EUE8RD
set at +/- 500' MD
3-1/2" 9.3# L-80 EUE8RD tubing to landing nipple
3-1/2" x 1" Camco 'KBUG' Mandrels w/DV's and RK latch's (Max. OD 5.390', ID
2.867'), 6' L-80 handling pups installed above and below on GLM. Spaced out w/
3-1/2' 9.3# L-80 EUE8RD tubing as follows:
GLM # TVD-RKB MD-RKB
GLM spacing tO be determined
RECEIV'ED'
'DEC 04 2000'
Alaska 0il & Gas Cons. COmmission
Anchorage
3-1/2" x 1-1/2' CamcO 'MMG* Mandrel w/shear valve and latch (Max OD 5.968",
ID. 2.92"),' pinned for 3000 psi shear (casing to tubing differential), 6' L-80 handling
pups installed above and below on GLM. Set at +/? 10300' MD.
1 jt 3-1/2' 9.3# L-80 EUE8RD tubing
3-1/2' Camco 'DS' nipple w/2.813' No-Go profile. 3-1/2' x 6' L-80 EUE8RD
handling pups installed above and below
1 jt 3-1/2" 9:3# L-80 EUE8RD tubing
7" x 3-i/2' Baker 'SAB-3' permanent packer wi KBH-22 seal aSsembly, 3:1/2' X 6'
L-80 EUE8RD handling pup on top ..
1 .jt 3-1/2" 9.3# L-80 EUE8RD tubing
3-1/2" camco 'D' nipple.w/2.75" No-Go Profile. 3-1/2' x 6' L-80 EUE8RD handling
pups installed above and below ' '
. .
3-1/2' x 10~ L-80 EUE8RD pup joint ..
3-1/2" Baker Shear Out Ball Seat Sub.. Tubing tail +/- 50' above top of proposed.
perforations "
.' ..
,,
.,
TJM, 12/2/00~ vl
KRU 1D-37 Prodd ar
Proposed Completion Schematic
Topset Contingency Case
PHILLIPS Alaska' Inc.
A Subsidiary of PHILLIPS PETROLEUM COMPANY
20' 91.5# H-40
@ +/- 120' MD
Depths are
based on
Nabors 16E
RKB
Surface csg.
,9-5/8' 40.0# L-80 BTCM
(+/- 5066' MD / 4366' TVD)
Intermediate. csg.
7' 26.0# J-55 BTCM
(+/- 10139' MD / 6275' TVD)
Future Perforations
Production Liner
3-1/2' 9.3# L-80 SLHT
(+/- 11003' MD / 6600' TVD)
3-1/2" FMC Gert V Tubing Hanger, 3-1/2' L-80 EUE8RD pin down
3-1/2" 9.3# L-80 EUE8RD Spaceout Pups as Required
3-1/2' 9.3# L-80 EUE8RD Tubing to Surface
3-1/2" Camco 'DS' nipple w/2.875' No-Go Profile. 3-1/2' x 6' L-80 pup
installed above. 3-1/2' x 6' L-80 flow coupling installed below, EUE8RD
set at +/- 500' MD
3-1/2" 9.3# L-80 EUE8RD tubing to landing nipple
3-1/2" x 1' Camco 'KBUG' Mandrels w/DV's and RK latch's (Max. OD 5.390', ID
2.867'), 6' L-80 handling pups installed above and below on GLM. Spaced out w/
3-1/2' 9.3# L-80 EUE8RD tubing as follows:.
RECEIVED
GLM Spacing t° be determined
DEC 04 2000
..
'" Alaska 0il & Gas Cons. C0mmissio~
Anchorage
.3-1/2" x 1-1/2" Camco 'MMG' Mandrel w/shear valve and latch. (Max OD 5.968, ID
2.867"), pinned for3000 psi shear (casing to tubing differential), 6' L-80 handling
pups installed above and below on GLM. Set at +/-9899' MD.
1 jt 3-112" 9.3# L-80 EUE8RD tubing
3-1/2' Camco 'DS' nipple w/2.813" No-Go profile. 3-112, x 6' L-80 EUE8RD
handling pups installed above and below
. ,
1 jt 3-1/2' 9.;~# L-80 E'UE8RD tubing
5.125" x 3" 'Baker Iocator sub
4-1/2" Baker GBH-22 casing seal assembly w/12' stroke, 3-1/2' L-80
EUE8RD box up
Liner Assembly (run on drillpipe), set @ +/- 9989' MD
Baker 7" x 5" 'ZXP" Uner Top Isolation Packer with HR profile
Baker 7" x 5' ~Flexlock' Liner Hanger
"Baker 20' Seal Bore Extension
XO Sub, 5' StubAcme box x 3-1/2' SLHT pin
I jt 3-1/2" 9.3# L-80 SLHT tUbing
3-1/2' Halliburton 'XN' nipple w/2.75' No-Go Profile, 3~1/2" SLHT box x pin
3-1/2' 9.3# L-80 SLHT liner as needed
.,.
.3-1/2' Baker Landing Collar '
1 jt 3-1/2" 9.3# L-80 SLHT tubing
"3-1/2" Baker Float Collar
'1 jt 3-112' 9.3# L-80 SLHT tubing
3-1/2' Baker Float Shoe
TJM, 12/2/00, v!
For: T Mushovic I
Phillips Alaska, Inc.
Struature: Pad 1D Well: 37
Field: Kuparuk River Unit Loaation: North Slope, Alaska
500
lOOO
1500
2000
2500
3000
5500
4000
4500
5000
5500
6000
6500
7000
5O0
~ RKB Elevation: 106'
_B_egrn Nudge
'_5_OBegin Drop
.uu
£0C
Base Permafrost
136.8E AZIMUTH
6586' (TO TARGET)
***Plane of Proposaleee
KOP
1.50 Build 5/100
6.00
Build/Turn
11.84
16.86
Top Ugnu Sands
22.55
28.05 DLS: 5.00 deg per 100 ft
53.84
39.69 Top West Sok
45.58
51.48
57.40 Base West Sak
66.50
5~a~ asin9 Pt
~mp Sondstone
RECEIVED
DEC 04 2000
Alaska Oil & Gas Cons. Commission
Anchorage
TANGENT ANGLE
67.90 DEG
C50
C40
7 Csg Pt./Bose
! i
500
i i i i i i i i i i ii i ii i ii i
1000 1500 2000 2500 5000 5500 4000 4500 5000 5500
Vertical Section (feet) ->
Azimuth 156.82 with reference 0.00 N, 0.00 E from slot#57
C30
C20
K-1 Marker
Top
c~ c2 ,
~oPp~ Shole
TD - Csg Pt
i i i i i i
6000 6500 7000
D
Phillips Alaska, Inc.
Struafure: Pad 1D Well: 37
Field: Kuparuk River Unit Lo,arian : North Slope, Alaska
400
4OO
800
1200
1600
2000
~ 2400
e- 2800
.,,k-
O
(fi 3200
I
¥
3600
40OO
440O
~800
5200
5600
6000
6400
East (feet) ->
400 0 4.00 800 1200 1600 2000 2400 · 2800 5200 3600 4000 4~.00 4.800 5200 5600 6000
I I I I I I I I ! I I I I I I I I I I I I I I I I I I I I I I I I
/:~TIMAT£D SURFACE
LOCATION:
· 92' FNL, 420.5' F£L
g0 AZ aec~n .Nudge .SEC. 25, T11N, RIOE
ue ,n_ urop
~ ~_ Bu..jlc~ 5/1 O0
-~ uudd/Turn
'~Top West Sak
Base West Sak EOC
9.5/8 Casing Pt
Camp Sandstone
C80
136.82 AZIMUTH
0580' (TO TARGET)
***Plane of Proposal***
TRUE
C50
C40
C30
TARGET LOCATION: I TargetTop C4
16' FNL, 1197' FEL
I
SEC. 25, T11N, RIOE
7 Csg Pt./Base HRZ
K-1 Marker
3aruk D
C2
Top C1
Top B Shale
TD - Csg Pt
DEC 04 000
g/aSka Oil & Gas Cons. Commission
Anchorage
TD LOCATION: I
297' FNL, 946' FEL
SEC. 25, T11N, RIOE
Phillips Alaska, . g
Structure: Pad 10 Well: 5 :~ ~
Fleld: Kuparuk River UnJf Looaflo.: North Slope, AlaskaI co ~ ~ ~
Point
Begin Nudge
Begin Drop
EOC
Bose Permafrost
KOP
Build 3/100
Build/Turn
Top Ugnu Sends
Top West Sok
Bose West Sok
EOC
9 5/8 Casing Pt
Comp Sandstone
C80
C50
C40
C30
C20
7 Csg Pt./Bose HRZ
K- 1 Marker
Top Kuporuk D
Target
Top C4
Top C3
Top C2
Top C1
Top B Shale
TD - Csg Pt
MD
300.00
650.00
1000.00
1417.98
2300.00
2450.00
27OO.OO
3122.96
3820.48
4558.75
4755.91
5066.31
5297.51
5536.68
8050.63
8736.25
9557.41
9955.37
0139.59
0367.95
0583.18
0596.45
0596.47
0662.91
0716.06
0777.18
0803.75
1003.06
PROFILE COMMENT DATA"
Inc Dir TVD North East V. Sect
0.00 0.00 500.00 0.00 0.00 0.00
5.25 315.00 649.51 11.55 - 11.33 - 16.02
0.00 315.00 999.02 22.66 -22.66 -52.05
0.00 315.00 1417.00 22.66 -22.66 -32.03
0.00 315.00 2299.02 22.66 -22.66 -52.05
2.25 90.00 2448.98 22.66 - 19.72 -30.02
9.75 90.00 2697.44 22.66 6.40 -12.15
20.20 119.98 3106.00 - 13.98 105.89 82.66
40,29 152.26 3706.00 -228.22 380.21 426.60
62.10 157.29 4166.00 -653.54 785.20 997.95
67.90 158.24 4248.44 -764.46 902.01 1174.70
67.90 138.24 4366.00 -980.57 1094.77 1464.05
67.90 138.24 4453.00 - 1140.1 6 1237.43 1678.18
67.90 138.24 4543.00 -1305.46 1385.01 1899.71
67.90 138.24 5489.00 -3042.92 2936.22 4228.16
67.90 138.24 5747.00 -3516.78 3359.28 4863.19
67.90 138.24 6056.00 -4084.30 3865.96 5623.75
67.90 138.24 6205.00 -4357.96 4110.28 5990.50
67.90 138.24 6275.00 -4486.53 4225.07 6162.79
67.90 138.24 6361.00 -4644.48 4366.09 6374.47
67.90 138.24 6442.00 -4793.25 4498.91 6573.84
67.90 138.24 6446.99 -4802.42 4507.09 6586.13
67.90 138.24 6447.00 -4802.43 4507.11 6586.15
67.90 138.24 6472.00 -4848.35 4548.10 6647.68
67.90 138.24 6492.00 -4885.08 4580.89 6696.91
67.90 138.24 6515.00 -4927.32 4618.61 6753.52
67.90 138.24 6525.00 -4945.69 4635.01 6778.13
67.90 138.24 6600.00 -5083.44 4757.99 6962.74
Deg/lO0
0.00
1.50
1.50
0.00
0.00
1.50
3.00
3.00:
3.00
3.00
3.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0,00
0.00
0,00
0.00
0.00
0.00
500
gOO
700
7oo.-~.-~
900 v v v
Phillips Alaska, Inc.
Structure: Pad 1D Well : 57
Field: Kuparuk River Unit Location: North Slope, Alaska
TRUE NORTH
550 0 10
tO0
2O
°eco
/~nChorage C°rn~ission
50
1900
4(
5O
290
7O
280
8O
270 2
-F
9O
260
25O
900
lO0
110
240
190
100
160
1300
140
1500
Normal Plane Travelling Cylinder - Feet
All depths shown are Measured depths on Reference Well
Phillips Alaska, Inc.
Structure: Pad 1D Well: 57
Field: Kuparuk River Unit Loaaflon: North Slope, Alaska
m
East (feet) ->
80 100 120
60
40
20
0
20
60
~0
~40
80 60 40 20
80 60 40 20 0 20 40 60 140 160 180 200 220 240 260
80 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I
z=~Td~-~600 700 800 0
~ -- - '~"~ 900. 1000~
~0 1200
2700 2800 ~ ~ '
eoo,~ .... -- ~. .....
700 \ ~ ~., .~zuuu 800 go0 1000 ~ 11 O0
60~0. ~uu 800 700 ·- ~. " ' · ~. · __ . 1200
--....,o.oo
. 1300 1400 1500 ~ .,.
~ 1000 ~' ~ .... ~.
~ ~00 ~ ~ ~2700 ~ ,,?700
"~'~_~,~ 14aD .~.30.0'~ 700
0
i i i i i i i i i i i i ii i I i i i i i i i I i i i i I i i i i i
280
80
6O
4O
2O
2O
4O
8O
lO0
120
140
0 20 40 60 80 1 O0 120 140 1 §0 1 BO 200 220 240 260
Easf (feet) ->
160
280
Phillips Alaska, Inc.
Structure: Pad 1D Well: ;57
Field: Kuparuk River Unit Location: North Slope, Alaska
I
v
r'n
200 240 280 520 360 400
80
120
160
200
240
250
520
560
400
440
480
520
560
200
1700
~3oo
%%1500
\
\
\
\
1700
:100
\
%
%
3500
\
\
\
\
2100
East (feet) ->
440 480 520 560 600 640 6BO
2900
2500
\
\
\
240 280 520 360 400 440
2500
700
2700
25OO
3100
\
\
\ \
450 520 560 §OD
East (feet) ->
250O
72O
720
76O
2500
76O
8OO
2700
O0
84O
B40
2900
92O
80
120
160
2OO
240
2BO
320
56O
400
440
480
52O
56O
92O
Phillips Alaska, Inc.
Structure: Pad 1D Well: 37
Field: Kuparuk River Unit Looafion: North Slope, Alaska
200
4OO
6oo
8oo
1000
~ 1200
-+- 1400
0
160o
V
1800
East (feet) ->
400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 ;;3000 3200 3400 3600 ,3800 4000
2600
3000
3400
4000
4200
\ \
\\
\\
\\
2ooo
4200
4200
4600
3000
\ 4600 \
\
\
\
\
\
\
\
\ \ 3000
2600
\
\
540O
5600
3400
3000
3400
\
\
\
\
\
4200
3000
3000
3800
4000
5000
,~0(
200
400
600
800
1000
0
1200
1400 '-~
1600
I
V
1800
2000
2200
2400
2600
400 §00 800 1000 1200 1400 1GO0 1600 2000 2200 2400 2600 2600 ;~000 ;}200 3400 3600 ~600 4000
East (feet) ->
Phillips Alaska, Inc.
Structure: P.d 1D Well: 57
Field: Kup.ruk Rlver Unlf Loc.flon: North Slope,
1600
2000
24D0
2800
4000
4400
4800
East (feet) ->
2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 8000 8400 8800
\
\
\
\
3800 \
3000
X5400
3400
3800
O0
\5000
\
,%
\
\
\
\:
34OO
\ \
\ \
\ \
\ \
5000 \ \
\ %54OO
~ 3800\
5400 ~ 4000 \
~ 42O0 ~ 5800
4600
3800
0~~620o
4000
\
\
% 3800
6200\
\
4600
5400
5000
5800
5400
6200
6600
2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 8000 8400 8800
East (feet) ->
1600
2000
2400
2800
320O
3600
4000
4400
4800
5200
5600
6000
6400
Phillips Alaska, Inc.
Pad 1D
37
slot #37
Kuparuk River Unit
North Slope, Alaska
PROPOSAL LISTING
by
Baker Hughes INTEQ
Your ref : 37 Versional
Our ref : prop1840
License :
Date printed : 30-Nov-2000
Date created : 16-0ct-1996
Last revised : 30-Nov-2000
Field is centred on n70 16 18.576,w150 5 56.536
Structure is centred on n70 18 1.316,w149 30 18.908
Slot location is n70 17 56.477,w149 30 31.166
Slot Grid coordinates are N 5959174.175, E 560670.437
Slot local coordinates are 492.00 S 420.50 W
Projection type: alaska - Zone 4, Spheroid: Clarke - 1866
Reference North is True North
RECEIVED
DEC 04 2000
Alaska Oil & Gas Cons. Commission
Anchorage
Phillips Alaska, Inc.
Pad 1D,37
Kuparuk River Unit,North Slope, Alaska
Measured Inclin. Azimuth True Vert R E C T
Depth Degrees Degrees Depth C 0 0 R
ANGULAR
DINATES
PROPOSAL LISTING Page 1
Your ref : 37 Version~l
Last revised : 30-Nov-2000
Dogleg Vert
Deg/lOOft Sect
0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00
300.00 0.00 0.00 300.00 0.00 N 0.00 E 0.00 0.00
400.00 1.50 315.00 399.99 0.93 N 0.93 W 1.50 -1.31
500.00 3.00 315.00 499.91 3.70 N 3.70 W 1.50 -5.23
600.00 4.50 315.00 599.69 8.33 N 8.33 W 1.50 -11.77
Begin Nudge
650.00 5.25 315.00 649.51 11.33 N 11.33 W 1.50 -16.02 Begin Drop
700.00 4.50 315.00 699.33 14.34 N 14.34 W 1.50 -20.26
800.00 3.00 315.00 799.11 18.96 N 18.96 W 1.50 -26.80
900.00 1.50 315.00 899.03 21.74 N 21.74 W 1.50 -30.72
1000.00 0.00 315.00 999.02 22.66 N 22.66 W 1.50 -32.03 EOC
1417.98 0.00 315.00 1417.00 22.66 N 22.66 W 0.00 -32.03 Base Permafrost
1500.00 0.00 315.00 1499.02 22.66 N 22.66 W 0.00 -32.03
2000.00 0.00 315.00 1999.02 22.66 N 22.66 W 0.00 -32.03
2300.00 0.00 315.00 2299.02 22.66 N 22.66 W 0.00 -32.03 KOP
2400.00 1.50 90.00 2399.01 22.66 N 21.35 W 1.50 -31.14
2450.00 2.25 90.00 2448.98 22.66 N 19.72 W 1.50 -30.02 Build 3/100
2475.00 3.00 90.00 2473.96 22.66 N 18.57 W 3.00 -29.23
2575.00 6.00 90.00 2573.64 22.66 N 10.73 W 3.00 -23.86
2675.00 9.00 90.00 2672.77 22.66 N 2.32 E 3.00 -14.93
2700.00 9.75 90.00 2697.44 22.66 N 6.40 E 3.00 -12.15 Build/Turn
2800.00 11.84 101.56 2795.67 20.61 N 24.92 E 3.00 2.03
2900.00 14.26 109.48 2893.09 14.44 N 46.59 E 3.00 21.35
3000.00 16.86 115.07 2989.42 4.19 N 71.33 E 3.00 45.76
3100.00 19.57 119.18 3084.41 10.12 S 99.09 E 3.00 75.20
3122.96 20.20 119.98 3106.00 13.98 S 105.89 E 3.00 82.66
3200.00 22.35 122.32 3177.78 28.46 S 129.79 E 3.00 109.58
3300.00 25.19 124.78 3269.29 50.77 S 163.35 E 3.00 148.80
3400.00 28.05 126.78 3358.69 76.99 S 199.67 E 3.00 192.78
3500.00 30.94 128.43 3445.72 107.05 S 238.64 E 3.00 241.37
3600.00 33.84 129.82 3530.16 140.86 S 280.18 E 3.00 294.45
3700.00 36.76 131.02 3611.76 178.34 S 324.16 E 3.00 351.87
3800.00 39.69 132.06 3690.31 219.38 S 370.46 E 3.00 413.48
3820.48 40.29 132.26 3706.00 228.22 S 380.21E 3.00 426.60
3900.00 42.63 132.98 3765.59 263.87 S 418.95 E 3.00 479.11
4000.00 45.58 133.81 3837.39 311.69 S 469.50 E 3.00 548.57
4100.00 48.53 134.55 3905.52 362.70 S 521.98 E 3.00 621.68
4200.00 51.48 135.23 3969.79 416.77 S 576.24 E 3.00 698.23
4300.00 54.44 135.86 4030.02 473.75 S 632.13 E 3.00 778.02
4400.00 57.40 136.44 4086.05 533.47 S 689.49 E 3.00 860.83
4500.00 60.36 136.99 '4137.73 595.79 S 748.18 E 3.00 946.43
Top Ugnu Sands
Top West Sak
4558.75 62.10 137.29 4166.00 633.54 S 783.20 E 3.00 997.93 Base West Sak
4600.00 63.33 137.50 4184.91 660.52 S 808.02 E 3.00 1034.59
4700.00 66.30 137.99 4227.46 727.49 S 868.86 E 3.00 1125.06
4753.91 67.90 138.24 4248.44 764.46 S 902.01 E 3.00 1174.70 EOC
5000.00 67.90 138.24 4341.05 934.54 S 1053.86 E 0.00 1402.63
5066.31 67.90 138.24 4366.00 980.37 S 1094.77 E 0.00 1464.05 9 5/8" Casing Pt
5297.51 67.90 138.24 4453.00 1140.16 S 1237.43 E 0.00 1678.18 Camp Sandstone
5500.00 67.g0 138.24 4529.20 1280.11 S 1362.38 E 0.00 1865.74
5536.68 67.90 138.24 4543.00 1305.46 S 1385.01E 0.00 1899.71 C80
6000.00 67.90 138.24 4717.35 1625.67 S 1670.90 E 0.00 2328.84
RECEIVED
O£c°
Oil a co.s.
An*horage Commission
All data is in feet unless otherwise stated.
Coordinates from slot #37 and TVD from est. RKB(Nabors 16E) (106.00 Ft above mean sea level).
Bottom hole distance is 6962.74 on azimuth 136.89 degrees from wellhead.
Total Dogleg for wellpath is 81.87 degrees.
Vertical section is from wellhead on azimuth 136,82 degrees.
Calculation uses the minimum curvature method.
Presented by Baker Hughes INTEQ
Phillips Alaska, Inc.
Pad 1D,37
Kuparuk River Unit,North Slope, A1 aska
Measured Inclin. Azimuth True Vert R E C T A N G U L A R
Depth Degrees Degrees Depth C 0 0 R D I N A T E S
PROPOSAL LISTING Page 2
Your ref : 37 Version~l
Last revised : 30-Nov-2000
Dogleg Vert
Deg/lOOft Sect
6500.00 67.90 138.24 4905.50 1971.24 S 1979.42 E 0.00 2791.95
7000.00 67.90 138.24 5093.65 2316.80 $ 2287.94 E 0.00 3255.05
7500.00 67.90 138.24 5281.80 2662.37 S 2596.46 E 0.00 3718.16
8000.00 67.90 138.24 5469.95 3007.93 S 2904.98 E 0.00 4181.27
8050.63 67.90 138.24 5489.00 3042.92 S 2936.22 E 0.00 4228.16
C50
8500.00 67.90 138.24 5658.10 3353.50 S 3213.50 E 0.00 4644.37
8736.25 67.90 138.24 5747.00 3516.78 S 3359.28 E 0.00 4863.19 C40
9000.00 67.90 138.24 5846.25 3699.06 S 3522.02 E 0.00 5107.48
9500.00 67.90 138.24 6034.40 4044.63 S 3830.54 E 0.00 5570.58
9557.41 67.90 138.24 6056.00 4084.30 S 3865.96 E 0.00 5623.75 C30
9953.37 67.90 138.24 6205.00 4357.96 S 4110.28 E 0.00 5990.50 C20
10000.00 67.90 138.24 6222.55 4390.19 S 4139.06 E 0.00 6033.69
10139.39 67.90 138.24 6275.00 4486.53 $ 4225.07 E 0.00 6162.79 7" Csg Pt./Base HRZ
10367.93 67.90 138.24 6361.00 4644.48 S 4366.09 E 0.00 6374.47 K-1 Marker
10500.00 67.90 138.24 6410.70 4735.76 S 4447.58 E 0.00 6496.80
10583.18 67.90 138.24 6442.00 4793.25 S 4498.91E 0.00 6573.84 Top Kuparuk D
10596.45 67.90 138.24 6446.99 4802.42 S 4507.09 E 0.00 6586.13 Target
10596.47 67.90 138.24 6447.00 4802.43 S 4507.11 E 0.00 6586.15 1D-37 Tgt Rvsd 28-Nov-O0
10662.91 67.90 138.24 6472.00 4848.35 S 4548.10 E 0.00 6647.68 Top C3
10716.06 67.90 138.24 6492.00 4885.08 S 4580.89 E 0.00 6696.91 Top C2
10777.18 67.90 138.24 6515.00 4927.32 S 4618.61E 0.00 6753.52 Top C1
10803.75 67.90 138.24 6525.00 4945.69 S 4635.01E 0.00 6778.13 Top B Shale
11000.00 67.90 138.24 6598.85 5081.32 S 4756.10 E 0.00 6959.90
11003.06 67.90 138.24 6600.00 5083.44 S 4757.99 E 0.00 6962.74 TD - Csg Pt
RECEIVED
0£¢ ooo
Alaska Oil & 6as COns. Commissiot~
Anchorage
All data is in feet unless otherwise stated.
Coordinates from slot#37 and TVD from est. RKB(Nabors 16E) (106.00 Ft above mean sea level).
Bottom hole distance is 6962.74 on azimuth 136.89 degrees from wellhead.
Total Dogleg for wellpath is 81.87 degrees.
Vertical section is from wellhead on azimuth 136.82 degrees.
Calculation uses the minimum curvature method.
Presented by Baker Hughes INTEQ
Phillips Alaska, Inc.
Pad 1D,37
Kuparuk River Unit,North Slope, Alaska
PROPOSAL LISTING Page 3
Your ref : 37 Version#1
Last revised : 30-Nov-2000
Comments i n wel 1 path
MD TVD Rectangul ar Coords. Comment
....... ....... ...................................................
650.00 649.51 11.33 N 11.33 W Begin Drop
1000.00 999.02 22.66 N 22.66 W EOC
1417.98 1417.00 22.66 N 22.66 W Base Permafrost
2300.00 2299.02 22.66 N 22.66 W KOP
2450.00 2448.98 22.66 N 19.72 W Build 3/100
2700.00 2697.44 22.66 N 6.40 E Build/Turn
3122.96 3106.00 13.98 S 105.89 E Top Ugnu Sands
3820.48 3706.00 228.22 S 380.21E Top West Sak
4558.75 4166.00 633.54 S 783.20 E Base West Sak
4753.91 4248.44 764.46 S 902.01E EOC
5066.31 4366.00 980.37 S 1094.77 E 9 5/8" Casing Pt
5297.51 4453.00 1140.16 S 1237.43 E Camp Sandstone
5536.68 4543.00 1305.46 S 1385.01E C80
8050.63 5489.00 3042.92 S 2936.22 E C50
8736.25 5747.00 3516.78 S 3359.28 E C40
9557.41 6056.00 4084.30 S 3865.96 E C30
9953.37 6205.00 4357.96 S 4110.28 E C20
10139.39 6275.00 4486.53 S 4225.07 E 7" Csg Pt./Base HRZ
10367.93 6361.00 4644.48 S 4366.09 E K-1 Marker
10583.18 6442.00 4793.25 S 4498.91E Top Kuparuk D
10596.45 6446.99 4802.42 S 4507.09 E Target
10596.47 6447.00 4802.43 S 4507.11E 1D-37 Tgt Rvsd 28-Nov-O0
10662.91 6472.00 4848.35 S 4548.10 E Top C3
10716.06 6492.00 4885.08 S 4580.89 E Top C2
10777.18 6515.00 4927.32 S 4618.61E Top C1
10803.75 6525.00 4945.69 S 4635.01E Top B Shale
11003.06 6600.00 5083.44 S 4757.99 ETD - Csg Pt
Casing positions in string 'A'
Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing
0.00 0.00 O.OON O.OOE 10139.39 6275.00 4486.53S 4225.07E 7" Casing
Targets associated with this wellpath
Target name Geographic Location T.V.D. Rectangular Coordinates Revised
1D-37 Tgt Rvsd 28-No 565216.000,5954409.000,2.0000 6447.00 4802.43S 4507.11E 28-Nov-2000
RECEIVED
DEC 04 2000
Alaska Oil & Gas Cons. Commission
Anchorage
Phillips Alaska, Inc.
Pad 1D
37
slot #37
Kuparuk River Unit
North Slope, Alaska
PROPOSAL LISTING
by
Baker Hughes INTEQ
Your ref: 37 Version#1
Our ref: prop1840
License :
Date printed : 30-Nov-2000
Date created : 16-Oct-1996
Last revised : 30-Nov-2000
Field is centred on n70 16 18.576,w150 5 56.536
Structure is centred on n70 18 1.316,w149 30 18.908
Slot location is n70 17 56.477,w149 30 31.166
Slot Grid coordinates are N 5959174.175, E 560670.437
Slot local coordinates are 492.00 S 420.50 W
Projection type: alaska - Zone 4, Spheroid: Clarke - 1866
Reference North is True North
RECEIVED
DEC 04 2000
41aska 0il & Gas Cons. COmrnissior
Anchorage
Phillips Alaska, Inc.
Pad 1D.37
Kuparuk River Unit,North Slope, Alaska
Measured Inclin Azimuth True Vert R E C TAN G U L A R
Depth Degrees Degrees Depth C 0 0 R D I N AT E S
0.00 0.00 0.00 0.00 O.OON O.OOE
300.00 0.00 0.00 300.00 O.OON O.OOE
400.00 1.50 315.00 399.99 0.93N 0.93W
500.00 3.00 315.00 499.91 3.70N 3.70W
600.00 4.50 315.00 599.69 8.33N 8.33W
650.00 5.25 315.00 649.51 11.33N 11.33W
700.00 4.50 315.00 699.33 14.34N 14.34W
800.00 3.00 315.00 799.11 18.96N 18.96W
900.00 1.50 315.00 899.03 21.74N 21.74W
1000.00 0.00 315.00 999.02 22.66N 22.66W
RECEIVED
PROPOSAL LISTING P~_~.
DEC 042000
Your ref : 37 Ver~'f~ 0//&
Last revised : 30- Nov- 2000 An'~°~ageGas~-~- Cons. Co~a~i$$io
GRID COORDS GEOGRAPH 1~,
Easting Northing C 0 0 R D I N A T E S
560670.44 5959174.18 n70 17
560670.44 5959174.18 n70 17
560669.50 5959175.09 n70 17
560666.71 5959177.85 n70 17
560662.04 5959182.43 n70 17
560659.02 5959185.41 n70 17
560655.99 5959188.39 n70 17
560651.33 5959192.98 n70 17
560648.53 5959195.73 n70 17
560647.59 5959196.65 n70 17
1417.98 0.00 315.00 1417.00 22.66N 22.66W 560647.59 5959196.65 n70 17
1500.00 0.00 315.00 1499.02 22.66N 22.66W 560647.59 5959196.65 n70 17
2000.00 0.00 315.00 1999.02 22.66N 22.66W 560647.59 5959196.65 n70 17
2300.00 0.00 315.00 2299.02 22.66N 22.66W 560647.59 5959196.65 n70 17
2400.00 1.50 90.00 2399.01 22.66N 21.35W 560648.90 5959196.66 n70 17
2450.00 2.25 90.00 2448.98 22.66N 19.72W 560650.54 5959196.67 n70 17
2475.00 3.00 90.00 2473.96 22.66N 18.57W 560651.68 5959196.68 n70 17
2575.00 6.00 90.00 2573.64 22.66N 10.73W 560659.53 5959196.75 n70 17
2675.00 9.00 90.00 2672.77 22.66N 2.32E 560672.58 5959196.85 n70 17
2700.00 9.75 90.00 2697.44 22.66N 6.40E 560676.65 5959196.89 n70 17
2800.00 11.84 101.56 2795.67 20.61N 24.92E 560695.19 5959194.98 n70 17
2900.00 14.26 109.48 2893.09 14.44N 46.59E 560716.90 5959188.99 n70 17
3000.00 16.86 115.07 2989.42 4.19N 71.33E 560741.73 5959178.94 n70 17
3100.00 19.57 119.18 3084.41 10.12S 99.09E 560769.60 5959164.86 n70 17
3122.96 20.20 119.98 3106.00 13.98S 105.89E 560776.42 5959161.06 n70 17
3200.00 22.35 122.32 3177.78 28.46S 129.79E 560800.45 5959146.77 n70 17
3300.00 25.19 124.78 3269.29 50.77S 163.35E 560834.18 5959124.74 n70 17
3400.00 28.05 126.78 3358.69 76.99S 199.67E 560870.70 5959098.82 n70 17
3500.00 30.94 128.43 3445.72 107.05S 238.64E 560909.92 5959069.08 n70 17
3600.00 33.84 129.82 3530.16 140.86S 280.18E 560951.73 5959035.61 n70 17
3700.00 36.76 131.02 3611.76 178.34S 324.16E 560996.00 5958998.49 n70 17
3800.00 39.69 132.06 3690.31 219.38S 370.46E 561042.63 5958957.83 n70 17
3820.48 40.29 132.26 3706.00 228.22S 380.21E 561052.46 5958949.08 n70 17
3900.00 42.63 132.98 3765.59 263.87S 418.95E 561091.48 5958913.74 n70 17
4000.00 45.58 133.81 3837.39 311.69S 469.50E 561142.41 5958866.34 n70 17
4100.00 48.53 134.55 3905.52 362.70S 521.98E 561195.30 5958815.76 n70 17
4200.00 51.48 135.23 3969.79 416.77S 576.24E 561249.99 5958762.14 n70 17
4300.00 54.44 135.86 4030.02 473.75S 632.13E 561306.33 5958705.63 n70 17
4400.00 57.40 136.44 4086.05 533.47S 689.49E 561364.18 5958646.38 n70 17
4500.00 60.36 136.99 4137.73 595.79S 748.18E 561423.36 5958584.54 n70 17
4558.75 62.10 137.29 4166.00 633.54S 783.20E 561458.69 5958547.09 n70 17
4600.00 63.33 137.50 4184.91 660.52S 808.02E 561483.72 5958520.31 n70 17
4700.00 66.30 137.99 4227.46 727.49S 868.86E 561545.10 5958453.84 n70 17
4753.91 67.90 138.24 4248.44 764.46S 902.01E 561578.55 5958417.14 n70 17
5000.00 67.90 138.24 4341.05 934.54S 1053.86E 561731.76 5958248.32 n70 17
56.48 w149 30 31.17
56.48 w149 30 31.17
56.49 w149 30 31.19
56.51 w149 30 31.27
56.56 w149 30 31.41
5066.31 67.90 138.24 4366.00 980.37S 1094.77E 561773.04 5958202.83 n70 17
5297.51 67.90 138.24 4453.00 1140.16S 1237.43E 561916.98 5958044.22 n70 17
5500.00 67.90 138.24 4529.20 1280.11S 1362.38E 562043.05 5957905.31 n70 17
5536.68 67.90 138.24 4543.00 1305.46S 1385.01E 562065.88 5957880.15 n70 17
6000.00 67.90 138.24 4717.35 1625.67S 1670.90E 562354.34 5957562.29 n70 17
56.59 w149 30 31.50
56.62 w149 30 31.58
56.66 w149 30 31.72
56.69 w149 30 31.80
56.70 w149 30 31.83
56.70 w149 30 31.83
56.70 w149 30 31.83
56.70 w149 30 31.83'
56.70 w149 30 31.83
56.70 w149 30 31.79
56.70 w149 30 31.74
56.70 w149 30 31.71
56.70 w149 30 31.48
56.70 w149 30 31.10
56.70 w149 30 30.98
56.68 w149 30 30.44
56.62 w149 30 29.81
56.52 w149 30 29.09
56.38 w149 30 28.28
56.34 w149 30 28.08
56.20 w149 30 27.38
55.98 w149 30 26.40
55.72 w149 30 25.35
55.42 w149 30 24.21
55.09 w149 30 23.00
54.72 w149 30 21.72
54.32 w149 30 20.37
54.23 w149 30 20.08
53.88 w149 30 18.95
53.41 w149 30 17.48
52.91 w149 30 15.95
52.38 w149 30 14.37
51.82 w149 30 12.74
51.23 w149 30 11.07
50.62 w149 30 09.36
50.25 w149 30 08.34
49.98 w149 30 07.61
49.32 w149 30 05.84
48.96 w149 30 04.87
47.29 w149 30 00.45
46.84 w149 29 59.25
45.26 w149 29 55.10
43.89 w149 29 51.46
43.64 w149 29 50.80
40.49 w149 29 42.46
All data in feet unless otherwise stated. Calculation uses minimum curvature method,
Coordinates from slot #37 and TVD from est. RKB(Nabors 16E) (106.00 Ft above mean sea level).
Bottom hole distance is 6962.74 on azimuth 136.89 degrees from wellhead.
Total Dogleg for wellpath is 81.87 degrees.
Vertical section is from wellhead on azimuth 136.82 degrees.
Grid is alaska - Zone 4.
Grid coordinates in FEET and computed using the Clarke - 1866 spheroid
Presented by Baker Hughes INTEQ
Phillips Alaska, Inc.
Pad 1D,37
Kuparuk River Unit,North Slope, Alaska
Measured Inclin Azimuth True Vert R E C TAN G U LA R
Depth Degrees Degrees Depth C 0 0 R D I NAT E S
6500.00 67.90 138.24 4905.50 1971.24S 1979.42E
7000.00 67.90 138.24 5093.65 2316.80S 2287.94E
7500.00 67.90 138.24 5281.80 2662.37S 2596.46E
8000.00 67.g0 138.24 5469.95 3007.93S 2904.98E
8050.63 67.90 138.24 5489.00 3042.92S 2936.22E
8500.00 67.90 138.24 5658.10 3353.50S 3213.50E
8736.25 67.90 138.24 5747.00 3516.78S 3359.28E
gO00.O0 67.90 138.24 5846.25 3699.06S 3522.02E
9500.00 67.90 138.24 6034.40 4044.63S 3830.54E
9557.41 67.90 138.24 6056.00 4084.30S 3865.96E
9953.37 67.90 138.24 6205.00 4357.96S 4110.28E
10000.00 67.90 138.24 6222.55 4390.19S 4139.06E
10139.39 67.90 138.24 6275.00 4486.53S 4225.07E
10367.93 67.90 138.24 6361.00 4644.48S 4366.09E
10500.00 67.90 138.24 6410.70 4735.76S 4447.58E
10583.18 67.90 138.24 6442.00 4793.25S 4498.91E
10596.45 67.90 138.24 6446.99 4802.42S 4507.09E
10596.47 67.90 138.24 6447.00 4802.43S 4507.11E
10662.91 67.90 138.24 6472.00 4848.35S 4548.10E
10716.06 67.90 138.24 6492.00 4885.08S 4580.89E
10777.18 67.g0 138.24 6515.00 4927.32S 4618.61E
10803.75 67.90 138.24 6525,00 4945.69S 4635.01E
11000.00 67.90 138.24 6598.85 5081.32S 4756.10E
11003.06 67.90 138.24 6600.00 5083.44S 4757.99E
PROPOSAL LISTING Page 2
Your ref : 37 Version#1
Last revised : 30-Nov-2000
GRID COORDS GEOGRAPHIC
Easting Northing COORDINATES
562665.63 5957219.28 n70 17
562976.91 5956876.27 n70 17
563288.20 5956533.26 n70 17
563599.49 5956190.24 n70 17
563631.01 5956155.51 n70 17
37.09 w149 29 33.47
33.69 w149 29 24.49
30.29 w149 29 15.50
26.89 w149 29 06.51
26.55 w149 29 05.60
563910.78 5955847.23 n70 17
564057.87 5955685.16 n70 17
564222.07 5955504.22 n70 17
564533.36 5955161.21 n70 17
564569.10 5955121.82 n70 17
23.49 w149 28 57.52
21.88 w149 28 53.28
20.09 w149 28 48.54
16.69 w149 28 39.55
16.30 w149 28 38.52
564815.62 5954850.19 n70 17
564844.65 5954818.19 n70 17
564931.43 5954722.57 n70 17
565073.72 5954565.78 n70 17
565155.94 5954475.18 n70 17
13.61 w149 28 31.41
13.29 w149 28 30.57
12.34 w149 28 28.06
10.79 w149 28 23.96
09.89 w149 28 21.59
565207.73 5954418.12 n70 17
565215.99 5954409.01 n70 17
565216.00 5954409.00 n70 17
565257.36 5954363.42 n70 17
565290.45 5954326.96 n70 17
09.32 w149 28 20.09
09.23 w149 28 19.85
09.23 w149 28 19.85
08,78 w149 28 18.66
08.42 w149 28 17.70
565328.50 5954285.03 n70 17
565345.05 5954266.80 n70 17
565467.23 5954132.17 n70 17
565469.13 5954130.07 n70 17
08.01 w149 28 16.61
07.83 w149 28 16.13
06.49 w149 28 12.60
06.47 w149 28 12.55
RECEIVED
DEC 04 000
Alaska Oil & 8as Cons. Commission
Anchorage
All data in feet unless otherwise stated. Calculation uses minimum curvature method.
Coordinates from slot #37 and TVD from est. RKB(Nabors 16E) (.106.00 Ft above mean sea level).'
Bottom hole distance is 6962.74 on azimuth 136.89 degrees from wellhead.
Total Dogleg for wellpath is 81.87 degrees.
Vertical section is from wellhead on azimuth 136.82 degrees.
Grid is alaska - Zone 4.
Grid coordinates in FEET and computed using the Clarke - 1866 spheroid
Presented by Baker Hughes INTEQ
Phillips Alaska, Inc.
Pad 1D,37
Kuparuk River Unit,North Slope, Alaska
PROPOSAL LISTING Page 3
Your ref : 37 Version#1
Last revised : 30-Nov-2000
Comments in wellpath
MD TVD Rectangular Coords. Comment
300.00
650.00
1000.00
1417.98
2300.00
2450.00
2700.00
3122.96
3820.48
4558.75
4753,91
5066,31
5297.51
5536.68
8050 63
8736 25
9557 41
9953 37
10139 39
10367 93
10583 18
10596.45
10596.47
10662.91
10716.06
10777,18
10803,75
11003,06
300 O0
649 51
999 02
1417 O0
2299 02
2448 98
2697.44
3106.00
37O6.OO
4166.00
4248.44
4366.00
4453.00
4543.00
5489.OO
5747.00
6056.00
6205.00
6275.00
6361.00
6442.00
6446.99
6447.00
6472.00
6492.00
6515.00
6525.00
6600.00
O.OON
11.33N
22.66N
22.66N
22.66N
22.66N
22.66N
13.98S
228.22S
633.54S
764.46S
980.37S
1140.16S
1305.46S
3042.92S
3516.78S
4084.30S
4357.96S
4486.53S
4644.48S
4793,25S
4802.42S
4802.43S
4848.35S
4885.08S
4927,32S
4945.69S
5083.44S
O.OOE
11.33W
22.66W
22.66W
22.66W
19.72W
6.40E
105.89E
380.21E
783.20E
902 01E
1094 77E
1237 43E
1385 01E
2936 22E
3359 28E
3865,96E
4110.28E
4225,07E
4366.09E
4498,91E
4507.09E
4507,11E
4548,10E
4580,89E
4618,61E
4635.01E
4757.99E
Begin Nudge
Begin Drop
EOC
Base Permafrost
KOP
Build 3/100
Build/Turn
Top Ugnu Sands
Top West Sak
Base West Sak
EOC
9 5/8" Casing Pt
Camp Sandstone
C80
C50
C40
C30
C20
7" Csg Pt./Base HRZ
K-1 Marker
Top Kuparuk D
Target
1D-37 Tgt Rvsd 28-Nov-O0
Top C3
Top C2
Top C1
Top B Shale
TD - Csg Pt
Casing positions in string 'A'
Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing
0.00 0.00 O.OON O.OOE 5066.31 4366.00 980.37S 1094.77E 9 5/8" Casing
0.00 0.00 O.OON O.OOE 10139.39 6275.00 4486.53S 4225.07E 7" Casing
Targets associated with this wellpath
Target name Geographic Locati on T.V.D. Rectangul ar Coordi nates Revised
1D-37 Tgt Rvsd 28-No 565216.000,5954409.000,2.0000 6447.00 4802.43S 4507.11E 28-Nov-2000
RECEIVED
DEC 04 2000
Alaska Oil a ~as Cons. Comrnissio~
Anchorage
Phillips Alaska, Inc.
Pad 1D
37
slot #37
Kuparuk River Unit
North Slope, Alaska
PROPOSAL LISTING
INCLUDING POSITION UNCERTAINTIES
Baker Hughes INTEQ
Your ref : 37 Version~l
Our ref: prop1840
License :
Date printed : 30-Nov-2000
Date created : 16-0ct-1996
Last revised : 30-Nov-2000
Field is centred on n70 16 18.576,w150 5 56.536
Structure is centred on n70 18 1.316,w149 30 18.908
Slot location is n70 17 56.477,w149 30 31.166
Slot Grid coordinates are N 5959174.175, E 560670.437
Slot local coordinates are 492.00 S 420.50 W
Projection type: alaska - Zone 4, Spheroid: Clarke - 1866
Reference North is True North
RECEIVED
DEC 04 2000
Alaska Oil & Gas Cons. Commission
Anchorage
Phillips Alaska, Inc.
Pad 1D,37
Kuparuk River Unit,North Slope, Alaska
PROPOSAL LISTING Page 1
Your ref : 37 Version#1
Last revised : 30-Nov-2000
Measured Inclin. Azimuth True Vert R E C T A N G U L A R
Depth Degrees Degrees Depth C 0 0 R D I N AT E S
Vert
Sect
Ellipse Semi Axes Minor
Major Minor Vert. Azi.
0.00 0.00 0.00 0.00 0.00 N 0.00 E
300.00 0.00 0.00 300.00 0.00 N 0.00 E
400.00 1.50 315.00 399.99 0.93 N 0.93 W
500.00 3.00 315.00 499.91 3.70 N 3.70 W
600.00 4.50 315.00 599.69 8.33 N 8.33 W
0.00 0.00 0.00 0.00 N/A
0.00 1.43 1.43 0.77 N/A
-1.31 2.11 1.91 1.03 45.00
-5.23 2.99 2.39 1.29 45.00
-11.77 3.94 2.87 1.56 45.00
650.00 5.25 315.00 649.51 11.33 N 11.33 W
700.00 4.50 315.00 699.33 14.34 N 14.34 W
800.00 3.00 315.00 799.11 18.96 N 18.96 W
900.00 1.50 315.00 899.03 21.74 N 21.74 W
1000.00 0.00 315.00 999.02 22.66 N 22.66 W
-16.02 4.42 3.11 1.69 45.00
-20.26 4.91 3.35 1.82 45.00
-26.80 5.90 3.84 2.09 45.00
-30.72 6.90 4.31 2.35 45.00
-32.03 7.20 4.79 2.60 45.00
1417.98 0.00 315.00 1417.00 22.66 N 22.66 W
1500.00 0.00 315.00 1499.02 22.66 N 22.66 W
2000.00 0.00 315.00 1999.02 22.66 N 22.66 W
2300.00 0.00 315.00 2299.02 22.66 N 22.66 W
2400.00 1.50 90.00 2399.01 22.66 N 21.35 W
-32.03 8.68 6.78 3.68 45.00
-32.03 8.97 7.17 3.89 45.00
-32.03 10.97 9.56 5.17 45.00
-32.03 12.24 10.99 5.95 45.00
-31.14 12.43 11.47 6.21 52.65
2450.00 2.25 90.00 2448.98 22.66 N 19.72 W -30.02 12.55 11.71 6.34 57.17
2475.00 3.00 90.00 2473.96 22.66 N 18.57 W -29.23 12.62 11.83 6.40 59.62
2575.00 6.00 90.00 2573.64 22.66 N 10.73 W -23.86 12.95 12.30 6.67 70.58
2675.00 9.00 90.00 2672.77 22.66 N 2.32 E -14.93 13.34 12.78 6.94 83.07
2700.00 9.75 90.00 2697.44 22.66 N 6.40 E -12.15 13.45 12.90 7.01 86.34
2800.00 11.84 101.56 2795.67 20.61 N 24.92 E 2.03 13.88 13.38 7.29 99.39
2900.00 14.26 109.48 2893.09 14.44 N 46.59 E 21.35 14.34 13.86 7.59 112.42
3000.00 16.86 115.07 2989.42 4.19 N 71.33 E 45.76 14.84 14.34 7.90 124.51
3100.00 19.57 119.18 3084.41 10.12 S 99.09 E 75.20 15.37 14.83 8.24 134.76
3122.96 20.20 119.98 3106.00 13.98 S 105.89 E 82.66 15.51 14.95 8.32 136.59
3200.00 22.35 122.32 3177.78 28.46 S 129.79 E 109.58 15.95 15.34 8.60 142.72
3300.00 25.19 124.78 3269.29 50.77 S 163.35 E 148.80 16.56 15.87 8.99 148.35
3400.00. 28.05 126.78 3358.69 76.99 S 199.67 E 192.78 17.22 16.42 9.42 151.79
3500.00 30.94 128.43 3445.72 107.05 S 238.64 E 241.37 17.91 17.00 9.88 153.18
3600.00 33.84 129.82 3530.16 140.86 S 280.18 E 294.45 18.67 17.62 10.37 152.74
3700.00 36.76 131.02 3611.76 178.34 S 324.16 E 351.87 19.50 18.26 10.91 150.81
3800.00 39.69 132.06 3690.31 219.38 S 370.46 E 413.48 20.42 18.91 11.49 147.98
3820.48 40.29 132.26 3706.00 228.22 S 380.21 E 426.60 20.64 19.05 11.62 147.36
3900.00 42.63 132.98 3765.59 263.87 S 418.95 E 479.11 21.47 19.57 12.11 144.95
4000.00 45.58 133.81 3837.39 311.69 S 469.50 E 548.57 22.68 20.22 12.77 142.26
4100.00 48.53 134.55 3905.52 362.70 S 521.98 E 621.68 24.05 20.86 13.48 140.14
4200.00 51.48 135.23 3969.79 416.77 S 576.24 E 698.23 25.62 21.49 14.22 138.60
4300.00 54.44 135.86 4030.02 473.75 S 632.13 E 778.02 27.38 22.09 15.00 137.55
4400.00 57.40 136.44 4086.05 533.47 S 689.49 E 860.83 29.35 22.68 15.83 136.87
4500.00 60.36 136.99 4137.73 595.79 S 748.18 E 946.43 31.54 23.25 16.69 136.46
4558.75 62.10 137.29 4166.00 633.54 S 783.20 E 997.93 32.94 23.56 17.21 136.33
4600.00 63.33 137.50 4184.91 660.52 S 808.02 E 1034.59 33.93 23.79 17.58 136.25
4700.00 66.30 137.99 4227.46 727.49 S 868.86 E 1125.06 36.51 24.31 18.50 136.17
4753.91 67.90 138.24 4248.44 764.46 S 902.01 E 1174.70 37.97 24.58 19.01 136.17
5000.00 67.90 138.24 4341.05 934.54 S 1053.86 E 1402.63 44.84 25.83 21.35 136.28
5066.31 67.90 138.24 4366.00 980.37 S 1094.77 E 1464.05 46.78 26.16 21.98 136.32
5297.51 67.90 138.24 4453.00 1140.16 S 1237.43 E 1678.18 53.54 27.31 24.18 136.47
5500.00 67.90 138.24 4529.20 1280.11S 1362.38 E 1865.74 59.45 28.32 26.11 136.61
5536.68 67.90 138.24 4543.00 1305.46 S 1385.01 E 1899.71 60.56 28.50 26.46 136.63
6000.00 67.90 138.24 4717.35 1625.67 S 1670.90 E 2328.84 74.52 30.79 30.86 136.87
All data is in feet unless otherwise stated.
Coordinates from slot#37 and TVD from est. RKB(Nabors 16E) (106.00 Ft above mean sea level).
Bottom hole distance is 6962.74 on azimuth 136.89 degrees from wellhead.
Vertical section is from wellhead on azimuth 136.82 degrees.
Calculation uses the minimum curvature method.
Presented by Baker Hughes INTEQ
~ 0 oo
Phillips Alaska. Inc.
Pad 1D,37
Kuparuk River Unit,North Slope, Alaska
Measured Inclin. Azimuth True Vert R E C T A
Depth Degrees Degrees Depth C 0 0 R D
PROPOSAL LISTING Page 2
Your ref : 37 Version#1
Last revised : 30-Nov-2000
N G U L A R Vert
I N A T E S Sect
E11 i pse Semi Axes Mi nor
Major Minor Vert. Azi.
6500.00 67.90 138.24 4905.50 1971.24 S 1979.42 E 2791.95 89.81 33.23 35.61 137.07
7000.00 67.90 138.24 5093.65 2316.80 S 2287.94 E 3255.05 105.24 35.64 40.36 137.23
7500.00 67.90 138.24 5281.80 2662.37 S 2596.46 E 3718.16 120.74 38.04 45.11 137.34
8000.00 67.90 138.24 5469.95 3007.93 S 2904.98 E 4181.27 136.29 40.42 49.86 137.44
8050.63 67.90 138.24 5489.00 3042.92 S 2936.22 E 4228.16 137.87 40.66 50.34 137.44
8500.00 67.90 138.24 5658.10 3353.50 S 3213.50 E 4644.37 151.88 42.79 54.61 137.51
8736.25 67.90 138.24 5747.00 3516.78 S 3359.28 E 4863.19 159.25 43.90 56.85 137.54
9000.00 67.90 138.24 5846.25 3699.06 S 3522.02 E 5107.48 167.49 45.14 59.36 137.58
9500.00 67.90 138.24 6034.40 4044.63 S 3830.54 E 5570.58 183.12 47.49 64.11 137.63
9557.41 67.90 138.24 6056.00 4084.30 S 3865.96 E 5623.75 184.92 47.76 64.65 137.64
9953.37 67.90 138.24 6205.00 4357.96 S 4110.28 E 5990.50 197.31 49.61 68.41 137.67
10000.00 67.90 138.24 6222.55 4390.19 S 4139.06 E 6033.69 198.77 49.83 68.86 137.68
10139.39 67.90 138.24 6275.00 4486.53 S 4225.07 E 6162.79 203.14 50.48 70.18 137.69
10367.93 67.90 138.24 6361.00 4644.48 S 4366.09 E 6374.47 210.30 51.55 72.35 137.70
10500.00 67.90 138.24 6410.70 4735.76 S 4447.58 E 6496.80 214.43 52.17 73.60 137.71
10583.18 67.90 138.24 6442.00 4793.25 S 4498.91 E 6573.84 217.04 52.55 74.39 137.72
10596.45 67.90 138.24 6446.99 4802.42 S 4507.09 E 6586.13 217.45 52.61 74.52 137.72
10596.47 67.90 138.24 6447.00 4802.43 S 4507.11 E 6586.15 217.45 52.61 74.52 137.72
10662.91 67.90 138.24 6472.00 4848.35 S 4548.10 E 6647.68 219.54 52.92 75.15 137.73
10716.06 67.90 138.24 6492.00 4885.08 S 4580.89 E 6696.91 221.20 53.17 75.66 137.73
10777.1B 67.90 138.24 6515.00 4927.32 S 4618.61 E 6753.52 223.12 53.46 76.24 137.73
10803.75 67.90 138.24 6525.00 4945.69 S 4635.01E 6778.13 223.95 53.58 76.49 137.74
11000.00 67.90 138.24 6598.85 5081.32 S 4756.10 E 6959.90 230.10 54.49 78.35 137.75
11003.06 67.90 138.24 6600.00 5083.44 S 4757.99 E 6962.74 230.20 54.51 78.38 137.75
POSITION UNCERTAINTY SUMMARY
-
Depth Position Uncertainty
From To Survey Tool Error Model Major Minor Vert.
1. Ellipse dimensions are half axis.
2. Casing dimensions are not included.
3. Ellipses are calculated on 2.58 standard deviations,
4, Uncertainty calculations start at drill depth zero,
5. Surface position uncertainty is not included.
6. Where two surveys are tied together the errors of one are considered
to have a systematic relationship to the corresponding errors of the other.
7. Detailed description of the INTEQ error models can be found
in the Ec*Trak manual.
All data is in feet unless otherwise stated.
Coordinates from slot#37 and TVD from est. RKB(Nabors 16E) (106,00 Ft above mean sea level).
Bottom hole distance is 6962.74 on azimuth 136.89 degrees from wellhead.
Vertical section is from wellhead on azimuth 136.82 degrees.
Calculation uses the minimum curvature method.
Presented by Baker Hughes INTEQ
Phillips Alaska, Inc.
Pad 1D,37
Kuparuk River Unit,North Slope, Alaska
PROPOSAL LISTING Page 3
Your ref : 37 Version#1
Last revised : 30-Nov-2000
Comments in wellpath
MD TVD Rectangular Coords. Comment
300.00
650.00
1000.00
1417.98
2300.00
2450.00
2700.00
3122.96
3820.48
4558.75
4753.91
5066.31
5297.51
5536.68
8050.63
8726.25
9557.41
9953.37
10139.39
10367,93
10583.18
10596.45
10596.47
10662.91
10716.06
10777.18
10803.75
11003.06
300 O0
649 51
999 02
1417 O0
2299 02
2448 98
2697.44
3106.00
3706.00
4166.00
4248.44
4366.00
4453.00
4543.00
5489.00
5747.00
6056.00
6205.00
6275.00
6361.00
6442.00
6446.99
6447.0O
6472.00
6492.00
6515.00
6525.00
6600.00
0.00 N 0.00 E Begin Nudge
11.33 N 11.33 W Begin Drop
22.66 N 22.66 W EOC
22.66 N 22.66 W Base Permafrost
22.66 N 22.66 W KOP
22.66 N 19.72 W Build 3/100
22.66 N 6.40 E Build/Turn
13.98 S 105.89 E Top Ugnu Sands
228.22 S 380.21E Top West Sak
633.54 S 783.20 E Base West Sak
764.46 S 902.01 E EOC
980.37 S 1094.77 E g 5/8" Casing Pt
1140.16 S 1237.43 E Camp Sandstone
1305.46 S 1385.01 E C80
3042.92 S 2936.22 E C50
3516.78 S 3359.28 E C40
4084.30 S 3865.96 E C30
4357.96 S 4110.28 E C20
4486.53 S 4225.07 E 7" Csg Pt./Base HRZ
4644.48 S 4366.09 E K-1 Marker
4793.25 S 4498.91 E Top Kuparuk D
4802.42 S 4507.09 E Target
4802.43 S 4507.11 E 1D-37 Tgt Rvsd 28-Nov-O0
4848.35 S 4548.10 E Top C3
4885.08 S 4580.89 E Top C2
4927.32 S 4618.61 E Top C1
4945.69 S 4635.01 E Top B Shale
5083.44 S 4757.99 ETD - Csg Pt
Casing positions in string 'A'
Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing
0,00 0.00 O.OON O.OOE 5066.31 4366.00 980.37S 1094.77E 9 5/8" Casing
0.00 0.00 O.OON O.OOE 10139.39 6275.00 4486.53S 4225.07E 7" Casing
Targets associated with this wellpath
Target name Geographic Location T.V.D. Rectangular Coordinates Revised
1D-37 Tgt Rvsd 28-No 565216.000,5954409.000,2.0000 6447.00 4802.43S 4507.11E 28-Nov-2000
Phillips Alaska. Inc.
Pad 1D
37
slot #37
Kuparuk River Unit
North Slope, Alaska
SUMMARY CLEARANCE REPORT
by
Baker Hughes INTEQ
Your ref : 37 Version#1
Our ref : proplB40
License :
Date printed : 30-Nov-2000
Date created: 16-0ct-1996
Last revised : 30-Nov-2000
Field is centred on n70 16 1B.576,w150 5 56.536
Structure is centred on n70 18 1.316,w149 30 18.908
Slot location is n70 17 56.477,w149 30 31.166
Slot Grid coordinates are N 5959174.175, E 560670,437
Slot local coordinates are 492.00 S 420.50 W
Projection type: alaska - Zone 4, Spheroid: Clarke - 1866
Reference North is True North
Object wellpath
PMSS IFR <O-16053'>,,34,Pad 1D
PMSS <0-5015'>,,135,Pad 1D
PMSS <O-5354'>,,102PB1,Pad 1D
PMSS <5181-6454'>,,102PB2,Pad 1D
PMSS <6143-6767'>,,102PB3,Pad 1D
PMSS <6527-7378'>,,102,Pad 1D
L1 PMSS <4338-7400'> Sperry,,lO2L1,Pad 1D
PMSS <O-1288'>,,138PB1,Pad 1D
PMSS <O-6543'>,,138,Pad 1D
41 Version#O.a,,41,Pad 1D
PMSS IFR <0-11660'>,,36,Pad 1D
PMSS IFR <O-14324'>,,38,Pad 1D
Closest approach with 3-D Minimum Distance method
Last revised Distance M.D.
23-0ct-2000 44.7 500.0 9900
2-Jun-lgg8 86.5 1400.0 4940
28-Jul-2000 129.6 2552.8 4860
27-Jul-2000 129.6 2552.8 4860
27-Jul-2000 129.6 2552.8 4860
28-Jul-2000 129.6 2552.8 4860
27-Jul-2000 129.6 2552.8 4633
18-May-2000 237.4 20.0 20
18-May-2000 236.9 557.1 7700
lO-Oct-2OOO 61.0 300.0 300
2-0ct-2000 14.5 414.3 6900
2-0ct-2000 15.0 120.0 120
Diverging from M.D.
PGMS <0-8850'> 2B-May-81,,MP I 17-ii-II,Pad 1D 23-Apr-1999
PMSS IFR <0-12044'>,,30,Pad 1D
28 Version~4,,28,Pad 1D
PGMS <0 - 6400'>,,WS-B,Pad 1D
PMSS <0 - 7340'>,,lO,Pad 1D
PMSS <4674'-5639'>,,125A,Pad 1D
PMSS <O-5142'>,,115,Pad 1D
PMSS <0 - 6270'>,,114,Pad 1D
PMSS <293 - 6866'>,,113,Pad 1D
PMSS <294 - 8250'>,,112,Pad 1D
PMSS <556-7024'>,,9,Pad 1D
PMSS <O-8702'>,,14,Pad 1D
PMSS <O-9250'>,,12,Pad 1D
PMSS<O-7045'>,,lll,Pad 1D
PMSS <O-4850'>,,109,Pad 1D
6474.7 7460.0 . 7460
2-0ct-2000 92.9 714.3 6500
2-0ct-2000 131.2 600.0 600
27-Apr-2000 202.4 1900.0 1900
28-Apr-1998 134.9 957.1 5100
24-Apr-2000 263.7 700.0 700
2-Jun-1998 465.7 160.0 160
2-Sep-1998 456.5 800.0 800
22-Sep-1998 493.6 100.0 100
21-Sep-1998 507.3 100.0 100
29-Apr-1998 372.2 985.7 985
6-0ct-1999 703.8 971.4 971
21-Jan-2000 691.7 1380.0 1380
3-Sep-1998 547.0 585.7 585
2-Jun-1998 578.3 ,100.0 500
PMSS <0 - 7150'>,,108~'., 1D
PMSS <291 - 5795'>,,125,Pad 1D
PMSS <O-5047'>,,124,Pad 1D
PMSS <290-6245'>,,116,Pad 1D
GSS <0-175'>,,116,Pad 1D
PMSS <287-6055'>,,123,Pad 1D
GSS <0-173'>,,123,Pad 1D
PMSS <0 - 5445'>,,122,Pad 1D
PMSS <0 - 6580'>,,128,Pad 1D
PMSS <0 - 7432'>,,127,Pad 1D
PMSS <0 - 6716'>,,126,Pad 1D
PMSS <O-4530'>,,120,Pad 1D
PGMS <O-8070'>,,3,Pad 1D
PMSS <O-4515'>,,119,Pad 1D
PMSS <O-5462'>,,129,Pad 1D
PMSS <0-4778'>,,130,Pad 1D
PMSS <0 - 6472'>,,131,Pad 1D
PMSS <467 - 5802'>,,132,Pad 1D
PGMS <0-9783'>,,2,Pad 1D
PMSS <381-6092'>,,105,Pad 1D
PGMS <O-8930'>,,5,Pad 1D
PMSS <O-4590'>,,118,Pad 1D
139 <PMSS 515 - 4838'>,,139,Pad 1D
PGMS <0-8610'>,,6,Pad 1D
PMSS <O-11234'>,,11,Pad 1D
PMSS <0-4414'>,,121,Pad 1D
MSS <3311-8200'>,,7,Pad 1D
136 PMSS <519 - 5680'>,,136,Pad 1D
PMSS <O-5205'>,,117,Pad 1D
141PMSS <0-9550'>,,141,Pad 1D
141L1 PMSS<5475'-9480'>,,141L1,Pad 1D
PMSS <256 - 5973'>,,1lO,Pad 1D
PMSS <377 - 6224'>,,134,Pad 1D
PMSS <5155'- 5905'>,,110A,Pad 1D
PMSS <1957-5265'>,,133,Pad 1D
PMSS <O-3252'>,,133PB1,Pad 1D
PMSS <O-5126'>,,106,Pad 1D
PGMS <0-8365'>~,l,Pad 1D
PGMS <0-7502'>,,4,Pad 1D
137 PMSS <0 - 5615'>,,137,Pad 1D
PMSS IFR <O-12225'>,,40,Pad 1D
140 Sperry,,140,Pad 1D
PMSS <3682-7663'>,,140L1,Pad 1D
PMSS IFR <548-4120'>,,140,Pad 1D
PMSS <4168-6156'>,,140PB1,Pad 1D
PMSS <5493-8117'>,,140,Pad 1D
32 Version ~5,,32,Pad 1D
PMSS <0- ???'>,,32,Pad 1D
37 GSS <0 - 503'>,,101,Pad 1D
37 PMSS <567 - 6100'>,,101,Pad 1D
16 Wp2 Sperry,,lO1,Pad 1D
107 PMSS <0 - 6550'>,,101,Pad 1D
PMSS (IFR) <O-8660'>,,42,Pad 1D
40A Version~2,,4OA,Pad 1D
40 PMSS IFR<O-12225'>,,40,Pad 1D
39 Version O.c,,39,Pad 1D
28-0ct-1998
19-Aug-1998
2-Jun-1998
17-Sep-1998
8-Sep-1998
13-Sep-1998
4-Sep-1998
29-Aug-1998
17-Aug-1998
6-Ju1-1998
1-Ju1-1998
2-~un-1998
13-Aug-1998
2-~un-1998
2-~un-1998
2-~un-1998
23-Ju1-1998
6-Aug-1998
4-Aug-1992
2-~un-1998
13-Nov-1997
2-~un-1998
18-May-2000
13-Nov-1997
30-Dec-1999
2-~un-1998
6-Nov-1997
5-2un-2000
2-Jun-1998
6-Sep-2000
26-Sep-2000
24-Apr-2000
3-Aug-1998
17-May-2000
2-2un-1998
21-Sep-2000
2-2un-1998
10-Dec-1997
4-Aug-1992
2-2un-2000
2-0ct-2000
20-Sep-2000
13-Nov-2000
13-Nov-2000
13-Nov-2000
13-Nov-2000
3-Nov-2000
29-Nov-2000
28-Nov-2000
29-Nov-2000
5-0ct-2000
29-Nov-2000
6-Nov-2000
29-Nov-2000
15-Nov-2000
29-Nov-2000
592.6
263.8
263.0
451 9
451 9
331 2
332 1
344 9
227 4
250 7
261.4
315.5
492.4
364.7
205.9
182.0
193.0
188.0
621.8
647.7
222.6
392.8
247.6
82.0
187.4
252.1
175.3
206.8
434.4
383.1
1825.4
564.0
181.1
564.0
176.6
176.6
596.3
722.6
379.6
228.5
44.6
593.7
590.6
590.6
590.6
590.6
72.7
74.3
703.3
697.4
585.4
584.7
74.6
3281.4
44.6
31.0
100.~
700.0
900.0
100.0
100.0
280.0
160.0
500.0
771.4
100.0
100.0
1600.0
957.1
942.9
2O0.O
714.3
100.0
100.0
742.9
528.6
1720.0
914.3
120.0
1800.0
771.4
2357.1
637.5
1040.0
687 5
1418 0
7560 0
100 0
260 0
100 0
675.0
675.0
957.1
1000.0
985.7
220.0
314.3
2300.0
1760.0
1760.0
1760.0
1760.0
528.6
542.9
542.9
785.7
871.4
900.0
240.0
6860.0
314.3
300.0
100.0
700.0
900.0
100.0
100.0
280.0
160.0
500.0
771.4
100.0
100.0
1600.0
957.1
942.9
200.0
714.3
100.0
100.0
742.9
528.6
1720.0
914.3
5160.0
5700.0
4880.0
2357.1
637.5
6540.0
687.5
7560.0
756O.0
100.0
6120.0
100.0
5080.0
675.0
957.1
iOO0.O
985.7
6180.0
314.3
2300.0
2486.1
2486.1
2486.1
2486.1
11003.1
11003.1
542.9
785 7
871 4
900 0
240 0
6860 0
314 3
2080.0
PHILLi['i S Alaska, Inc.
A Subsidiary of PHILLIPS PETROLEUM COMPANY
Phillips Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510
December 3, 2000
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, AK 99501
(907) 279-1433
Re: Application for Permit to Drill:
KRU 1 D-37
Surface Location:
Target Location:
.Bottom Hole Location:
492' FNL, 420.5' FEL, Sec. 23, T11N, R10E
16' FNL, 1197' FEL, Sec. 25, T11 N, R10E
297' FNL, 946' FEL, Sec. 25, T11 N, R10E
Dear Sire:
Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore development well KRU 1 D-37.
The well will be drilled and completed using Nabors 16E. Please utilize documents on file for this rig.
Subject to AOGCC approval, fluids and cuttings .generated from drilling the well will be pumped down an
approved and existing annulus on Drillsite 1D, or hauled to an approved Prudhoe or GKA Class II disposal
well.
Also note that Phillips Alaska, Inc. does not anticipate the presence of H=S in the formations to be
encountered in this well. However, there will be H=S and combustible gas monitoring equipment
functioning on the rig as is the standard operating procedure in the Kuparuk River Unit drilling operation.
The following people are the designated contacts for reporting responsibilities to the Commission:
A) Completion Report Sharon AIIsup-Drake, Drilling Technologist
(20 AAC 25.070) 263-4612
B) Geologic Data and Logs
(20/LAC 25.071)
Stacy Waggoner, Geologist
265-1391
If you have any questions or require further information, please contact Todd Mushovic at (907) 265-6974
or James Trantham at (907) 265-6434.
Sincerely,
Todd Musho¥ic
Operations Drilling Engineer
RECEIVED
DEC 04 000
Oil & Gas Cons. Commission
~ch0raoe
WELL PERMIT CHECKLIST C'OMPANY J
FIELD & POOL z.//~-(~/~") INIT CLASS ' '~' L-'/ ~/~-, GEOL AREA ~>~)
ADMINISTRATION
APPR
1. Permit fee attached .......................
2. Lease number appropriate ...................
3. Unique well name and number ..................
4. Well located in a defined pool ..................
5. Well located proper distance from drilling unit boundary ....
6. Well located proper distance from other wells ..........
7. Sufficient acreage available, in drilling unit ............
8. If deviated, is wellbore plat included ............. ...
9. Operator only affected party ...................
10. Operator has appropriate bond in force .............
11. Permit can be issued without conservation order ........
12. Permit can.be issued without administrative approval ......
13. Can permit be approved before 15-day wait ...........
ENGINEERING
14. Conductor string provided ...................
15. Surface casing protects all known USDWs.... ........
16. CMT vol adequate to circulate on conductor & surf csg .....
17. CMT vol adequate to fie-in long string to surf csg ........
18. CMT will cover all known productive horizons ..........
19. Casing designs adequate for C, T, B & permafrost .......
20. Adequate tankage or reserve pit .................
21. If a re-drill, has a 10-403 for abandonment been approved... '
22. Adequate weilbore separation proposed .............
23. If diverter required, does it meet regulations ..........
24. Drilling fluid program schematic & equip list adequate .....
25. BOPEs, do they meet regulation '. ...... .=.,~..,., ..... .
26. BOPE press rating appropriate; test t° ~[,.) psig.
27.. Choke manifold complies w/APl RP-53 (May 84) ........
Work will occur without operation shutdown. ; .' ........
Is presence of H2S gas probable ............. ' .....
J reddl
(B) will not contaminate freshwater; or cause drilling waste ' ..
(C) will not. impair mechanical integrity of the'Well used for dispoSal;
(D) will not. damage producing formation or impair recovery from a
(E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412.
Y-~Y,,~ N
N
serv wellbore seg
UNIT# ~'///'~ ~'~
ann. disposal para req
ON/OFF SHORE ~.~.
N
GEOLOGY 30. Permit can be issued wlo hydrogen sulfide measures...
---'---'--' " 31 Data oresented on ootentialoverpressure zones .~l~ . ' y(~
" ' ~' ~-:-~i .... I-sis o~ shallow -as zones ' ' ....
I~ ,Z.~oO 34. Conta~name/phoneforweeklyprogressrepo,s/;~
. · . ~ ' v-- ~ , , v , II
ANNU~R DISPOSAL35. W~h proper ~menting re~s. this plan . ."
~ ' ' (A) will ~ntain waste in a suitable receiVing zone; ........ Y N
' . . . . ,
JJAPPR . DATE (B) ~llnotcontam~natefresh~ater;or~use aste... Y N ~ ~~7 ~ (~;,o~ O, ~~t~60P~ -~ ~e I~ ~ ~r~ '
il. (C) will n,}t. impair mechanical integd~ of the I for disposal; Y. P~b, ' ' ' ' '
~ ~ (D) will n,)t. damage pmducin~ formation or ir ~ve~ from a Y N_ ~ .... ' . ' "
. . pool; and , . . ' ' ' .' '
~ ~ (E) will n: : mumvent 20 ~(, 25.252 or 20. .12. Y N . .'
Il ' GEOL~ ENGINEERING.; UlCIAnnular 'COMMISSION:" ' '. Commen~llnstructions:
II'. ' ,
c:~nsoffice\wordian~diana\checklist (rev. 11101//00)
O
Z
O
.--I
,(._
.
.
Well History File
APPENDIX
Information of detailed nature that is not
particularly germane to the Well Permitting Process
but is part of the history file.
5CANNED AUG 31200b
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.
* Some material in this section may not have been microfilmed.
.
.
**** REEL HEADER ****
MWD
06/08/18
BHI
01
LIS Customer Format Tape
RECEIVED
**** TAPE HEADER ****
MWD
05/06/23
919593
01
2.375" CTK
AUG 3 0 2006
AlllkaOll & Gas Cons. Commission
Anchorage
SCANNED AUG 3 1 2006
*** LIS COMMENT RECORD
!!!!!!!!!!!!!!!!!! !
!!!!!!!!!!!!!!!!!! !
-Version Information
VERSo
WRAP.
~Well Information Block
#MNEM.UNIT Data Type
#--------- -------------
STRT.FT 10600.0000:
STOP.FT 11546.0000:
STEP.FT 0.5000:
NULL. -999.2500:
COMPo COMPANY:
WELL. WELL:
FLD . FIELD:
LOC . LOCATION:
CNTY. COUNTY:
STAT. STATE:
SRVC. SERVICE COMPANY:
TOOL. TOOL NAME & TYPE:
DATE. LOG DATE:
API . API NYUMBER:
-Parameter Information Block
#MNEM.UNIT Value
#--------- -------------------------
***
Remark File Version 1.000
Extract File: 1dwg.las
1. 20:
NO:
CWLS log ASCII Standard -VERSION 1.20
One line per frame
Information
-------------------------------
Starting Depth
Ending Depth
Level Spacing
Absent Value
ConocoPhillips Alaska, Inc.
1D-37L2PB1
Kuparuk River Unit
70 deg 17' 56.476"N 149 deg 30' 31.160"W
North Slope Borough
Alaska
Baker Hughes INTEQ
2.375" CTK
23-Jun-05
500292299270
-------------------------------
Description
SECT.
TOWN.N
RANG.
PDAT.
EPD .F
LMF .
FAPD.F
DMF
EKB .F
EDF .F
EGL .F
CASE.F
OSl .
~Remarks
GCO-dO(( .,., 14D4d
23
llN
10E
MSL
o
RKB
106
KB
106
N/A
o
N/A
DIRECTIONAL
Section
Township
Range
Permanent Datum
Elevation Of Perm. Datum
Log Measured from
Feet Above Perm. Datum
Drilling Measured From
Elevation of Kelly Bushing
Elevation of Derrick Floor
Elevation of Ground Level
Casing Depth
Other Services Line 1
.
.
(1) All depths are Measured Depths (MD) unless otherwise noted.
(2) All depths are Bit Depths unless otherwise noted.
(3) All Gamma Ray data (GRAX) presented is real time data.
(4) Baker Hughes INTEQ utilized CoilTrak downhole tools and the
advantage surface
system to log this well.
(5) Tools ran in the string included Casing Collar Locator, an
Electrical
Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and
Outer
Downhole Pressure and Downhole Weight on Bit), a Directional and Gamma
Sub,
Ultra Slim Resistivity Sub and a Hydraulic Orienting Sub with a Near
Bit
Inclination Sensor.
(6) Data presented here is final and has not been depth adjusted to a
PDC (Primary
Depth Control)log. The INTEQ MWD Gamma Ray is the PDC for this
wellbore.
(7) The sidetrack was drilled from 1D-37 through a milled window in 3
1/2" liner.
Top of Window 10595 ft.MD (6342 ft.SSTVD)
Bottom of Window 10600 ft.MD (6344 ft.SSTVD)
(8) The interval from 11522 ft. to 11546 ft.MD (6460 ft to 6476
ft.SSTVD) was not
logged due to sensor bit offset.
(9) Tied to 1D-37 at 10573.0 ft.MD (6334.0 ft.SSTVD)
(10) The wellbore 1D-37L2 was kicked off this wellbore 1D-37L2PB1 at
11130
ft.MD (6374.19 ft.SSTVD)
MNEMONICS:
GRAX -> Gamma Ray MWD-AAPI [MWD] (MWD-API units)
ROPS -> Rate of Penetration, feet/hour
TVD -> Subsea True Vertical Depth, feet
Tape Subfile: 1
65 records...
Minimum record length:
Maximum record length:
14 bytes
132 bytes
**** FILE HEADER ****
MWD .001
1024
*** INFORMATION TABLE: CONS
MNEM VALU
----------------------------------
WDFN
LCC
CN
WN
FN
COUN
STAT
1D-37L2PB1 5.xtf
150
ConocoPhillips Alaska Inc.
1D-37L2PB1
Kuparuk River Unit
North Slope
Alaska
*** LIS COMMENT RECORD ***
!! !!!!!!!!! !!!!!!!! Remark File Version 1.000
.
.
The data presented here is final and has not been depth shifted
*** INFORMATION TABLE: CIFO
MNEM CHAN DIMT CNAM
ODEP
----------------------------------------------------
GR
GRAX
0.0
GR
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 8 bytes
Logging direction is down (value= 255)
Optical Log Depth Scale Units: Feet
Frame spacing: 0.500000
Frame spacing units: [F ]
Number of frames per record is: 127
One depth per frame (value= 0)
Datum Specification Block Sub-type is: 1
FRAME SPACE =
0.500 * F
ONE DEPTH PER FRAME
Tape depth ID: F
1 Curves:
Name Tool Code Samples Units
Size Length
1
68
AAPI
4
1
GR
MWD
-------
Total Data Records: 15
Tape File Start Depth
Tape File End Depth
Tape File Level Spacing
Tape File Depth Units
10600.000000
11546.500000
0.500000
feet
**** FILE TRAILER ****
Tape Subfile: 2 23 records...
Minimum record length:
Maximum record length:
54 bytes
4124 bytes
**** FILE HEADER ****
MWD .002
1024
*** INFORMATION TABLE: CONS
MNEM VALU
--------------------------------
WDFN
1D-37L2PB1.xtf
4
4
.
.
LCC
CN
WN
FN
COUN
STAT
150
ConocoPhillips Alaska In
1D-37L2PB1
Kuparuk River Unit
North Slope
Alaska
*** LIS COMMENT RECORD ***
!!!!!!!!!! !!! !!! !!! Remark File Version 1.000
This file contains the raw-unedited field data.
*** INFORMATION TABLE: CIFO
MNEM CHAN DIMT CNAM
ODEP
----------------------------------------------------
GRAX
GRAX
GRAX
0.0
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 8 bytes
Logging direction is down (value= 255)
Optical Log Depth Scale Units: Feet
Frame spacing: 0.250000
Frame spacing units: [F ]
Number of frames per record is: 127
One depth per frame (value= 0)
Datum Specification Block Sub-type is: 1
FRAME SPACE =
0.250 * F
ONE DEPTH PER FRAME
Tape depth ID: F
1 Curves:
Name Tool Code Samples Units
Size Length
1
GRAX MWD
68
1
AAPI
4
4
-------
4
Total Data Records: 30
Tape File Start Depth
Tape File End Depth
Tape File Level Spacing
Tape File Depth Units
10600.000000
11546.250000
0.250000
feet
**** FILE TRAILER ****
Tape Subfile: 3 38 records...
Minimum record length:
Maximum record length:
54 bytes
4124 bytes
**** TAPE TRAILER ****
MWD
05/06/23
919593
01
.
**** REEL TRAILER ****
MWD
06/08/18
BHI
01
Tape Subfile: 4
Minimum record length:
Maximum record length:
.
2 records...
132 bytes
132 bytes
.
.
Tape Subfile 1 is type: LIS
Tape Subfile 2 is
DEPTH
10600.0000
10600.5000
10700.0000
10800.0000
10900.0000
11000.0000
11100.0000
11200.0000
11300.0000
11400.0000
11500.0000
11546.5000
.
type: LIS
GR
71. 6767
76.8700
89.3300
97.3733
97.9000
89.3300
106.7200
103.8700
105.6800
104.9000
197.5900
-999.2500
Tape File Start Depth
Tape File End Depth
Tape File Level Spacing
Tape File Depth Units
.
10600.000000
11546.500000
0.500000
feet
~
.
Tape Subfile 3 is type: LIS
DEPTH
10600.0000
10600.2500
10700.0000
10800.0000
10900.0000
11000.0000
11100.0000
11200.0000
11300.0000
11400.0000
11500.0000
11546.2500
GRAX
71. 6767
74.2733
89.3300
97.3733
97.9000
89.3300
106.7200
103.8700
105.6800
104.9000
197.5900
-999.2500
Tape File Start Depth
Tape File End Depth
Tape File Level spacing
Tape File Depth Units
.
10600.000000
11546.250000
0.250000
feet
.
.
Tape Subfile 4 is type: LIS
Sperry-Sun Drilling Services
LIS Scan Utility
SRevision: 3 $
LisLib SRevision: 4 $
Mon Dec 10 14:09:42 2001
Reel Header
Service name ............. LISTPE
Date ..................... 01/12/10
Origin ................... STS
Reel Name ................ UNKNOWN
Continuation Number ...... 01
Previous Reel Name ....... UNKNOWN
Comments ................. STS LIS Writing Library.
Tape Header
Service name ............. LISTPE
Date ..................... 01/12/10
Origin ................... STS
Tape Name ................ UNKNOWN
Continuation Number ...... 01
Previous Tape Name ....... UNKNOWN
Comments ................. STS LIS Writing Library.
RECEIVED
JA[',I 0 3 2002
Alaska Oil & Gas Cons. Commission
Anchorage
Scientific Technical Services
Scientific Technical Services
Physical EOF
Comment Record
TAPE HEADER
Kuparuk River Unit
MWD/MAD LOGS
WELL NAME:
API NUMBER:
OPERATOR:
LOGGING COMPANY:
TAPE CREATION DATE:
JOB DATA
JOB NUMBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
SURFACE LOCATION
SECTION:
TOWNSHIP:
RANGE:
FNL:
FSL:
FEL:
FWL:
ELEVATION (FT FROM MSL 0)
KELLY BUSHING:
DERRICK FLOOR:
GROUND LEVEL:
WELL CASING RECORD
MWD RUN 3
AK-MM-00321
T. MCGUIRE
G. WHITLOCK
1D-37
500292299200
PHILLIPS Alaska, Inc.
Sperry Sun
10-DEC-01
MWD RUN 4 MAD RUN 5
AK-MM-00321 AK-MM-00321
P. SMITH P. SMITH
G. WHITLOCK F. HERBERT
23
liN
10E
492
421
.00
104.90
70.90
OPEN HOLE CASING DRILLERS
BIT SIZE (IN) SIZE (IN) DEPTH (FT)
1ST STRING 12.250 20.000 120.0
2ND STRING 8.500 9.625 5091.0
3RD STRING 6.125 7.000 10102.0
PRODUCTION STRING
REMARKS:
1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE
NOTED.
2. MWD RUNS l&2 ARE DIRECTIONAL ONLY, AND NOT
PRESENTED.
5~D RUN 3 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR)
UTILIZING
GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC
WAVE
RESISTIVITY PHASE-4 (EWR4). THE MEDIUM PHASE
RESISTIVITY CHANNEL
(SEMP) FAILED AT 6710'MD, 4996'TVD, AND IS NOT
PRESENTED BELOW
THAT POINT.
4. MWD RUN 4 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR)
UTILIZING
GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE
RESISTIVITY PHASE-4 (EWR4), COMPENSATED THERMAL
NEUTRON
POROSITY (CTN) AND STABILIZED LITHO-DENSITY (SLD).
GAMMA RAY
DATA IN THE INTERVAL 10718'MD, 6495'TVD TO 10977'MD,
6596'TVD
WAS ACQUIRED ON A MEASUREMENT AFTER DRILLING (MAD)
PASS PERFORMED
WHILE RUNNING IN THE HOLE ON MAD RUN 5 (FILLS IN AN
INTERVAL OF GAMMA RAY
TOOL FAILURE).
5.
MAD RUN 5 IS DIRECTIONAL WITH DGR AND EWR 4, AND IS
PRESENTED AS A
REPEAT PASS AT THE TAIL OF THIS LOG.
6. DEPTH SHIFTING STATUS OF MWD DATA IS PENDING.
7.
MWD RUNS 1-5 REPRESENT WELL 1D-37 WITH API#:
50-029-22992-00. THIS WELL REACHED A TOTAL DEPTH
(TD)
OF l1003'MD, 6606'TVD.
SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING.
SGRC = SMOOTHED GAMMA RAY COMBINED.
SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA
SHALLOW SPACING).
SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY
(SHALLOW SPACING).
SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM
SPACING).
SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP
SPACING).
SFXE = SMOOTHED FORMATION EXPOSURE TIME.
TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SS MATRIX,
FIXED HOLE SIZE).
CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE.
CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE.
SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW COUNT
BIN).
SCO2 = SMOOTHED STANDOFF CORRECTION (LOW COUNT BIN).
SNP2 = NEAR DETECTOR PHOTOELECTRIC ABSORPTION FACTOR
(LOW COUNT BIN).
PARAMETERS USED IN POROSITY LOG PROCESSING:
HOLE SIZE: 6.125"
MUD WEIGHT: 10.9 PPG
MUD SALINITY: 600 PPM CHLORIDES
FORMATION WATER SALINITY: 15000 PPM CHLORIDES
FLUID DENSITY: 1.0 G/CC
MATRIX DENSITY: 2.65 G/CC
LITHOLOGY: SANDSTONE
$
File Header
Service name ............. STSLIB.001
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 01/12/10
Maximum Physical Record..65535
File Type ................ LO
Previous File Name ....... STSLIB.000
Comment Record
FILE HEADER
FILE NUMBER: !
EDITED MERGED MWD
Depth shifted and clipped curves; all bit runs merged.
DEPTH INCREMENT: .5000
FILE SUMMARY
PBU TOOL CODE START DEPTH STOP DEPTH
ROP 5000.0 11003.0
GR 5054.5 10977.0
RPX 5071.0 10966.5
RPS 5071.0 10966.5
RPM 5071.0 10966.5
R?D 5071.0 10966.5
FET 5071.0 10966.5
FCNT 10040.0 10931.5
NCNT 10040.5 10931.5
NPHI 10040.5 10931.5
PEF 10055.0 10946.5
RHOB 10105.0 10946.5
RHOB 10105.0 10946.5
$
BASELINE CURVE FOR SHIFTS:
CURVE SHIFT DATA (MEASURED DEPTH)
EQUIVALENT UNSHIFTED DEPTH
BASELINE DEPTH
$
MERGED DATA SOURCE
PBU TOOL CODE BIT RUN NO MERGE TOP
MWD 3 5000.0
MWD 4 10150.0
$
REMARKS: MERGED MAIN PASS.
$
Data Format Specification Record
Data Record Type .................. 0
Data Specification Block Type ..... 0
Logging Direction ................. Down
Optical log depth units ........... Feet
Data Reference Point .............. Undefined
Frame Spacing ..................... 60 .liN
Max frames per record ............. Undefined
Absent value ...................... -999
Depth Units .......................
Datum Specification Block sub-type...0
MERGE BASE
10150.0
11003.0
Name Service Order Units Size Nsam Rep Code Offset
DEPT FT 4 1 68 0
ROP MWD FT/H 4 1 68 4
GR MWD API 4 1 68 8
RPX MWD OHMM 4 1 68 12
RPS MWD OHMM 4 1 68 16
RPM MWD OHMM 4 1 68 20
RPD MWD OHMM 4 1 68 24
FET MWD HOUR 4 1 68 28
NPHI MWD PU-S ~ 1 68 32
FCNT MWD CNTS 4 1 68 36
NCNT MWD CNTS 4 1 68 40
RHOB MWD G/CM 4 1 68 44
DRHO MWD G/CM 4 1 68 48
PEF MWD B/E 4 1 68 52
Channel
1
2
3
4
5
6
7
8
9
10
11
12
13
14
Name Service Unit Min Max
DEPT FT 5000 11003
ROP MWD FT/H 0.15 5729.54
GR MWD API 25.56 481.91
Mean Nsam
8001.5 12007
152.289 12007
138.548 11846
First
Reading
5000
5000
5054.5
Last
Reading
11003
11003
10977
RPX 55~D OHMM 1.17 1871.78
RPS MWD OHMM 1 . 51 1821 . 72
RPM MWD OHMM 0.6 2000
RPD MWD OHMM 1.73 2000
FET MWD HOUR 0 . 22 93 . 04
NPHI MWD PU-S 19.8 52.29
.FCNT MWD CNTS 127.9 787.7
NCNT MWD CNTS 15029.9 33347.5
RHOB MWD G/CM 2.189 3.155
DRHO MWD G/CM -0.425 0.412
PEF MWD B/E 2.6 16.53
First Reading For Entire File .......... 5000
Last Reading For Entire File ........... 11003
File Trailer
Service name ............. STSLIB.001
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 01/12/10
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.002
4.27972 11730
4.90209 11730
15.4251 5029
9.99635 11730
1.39112 11730
35.8811 1783
287.042 1784
20768.9 1783
2.47772 1684
0.0685499 1684
6.64644 1784
5071
5071
5071
5071
5071
10040.5
10040
10040.5
10105
10105
10055
10966.5
10966.5
10966.5
10966.5
10966.5
10931.5
10931.5
10931.5
10946.5
10946.5
10946.5
Physical EOF
File Header
Service name ............. STSLIB.002
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 01/12/10
Maximum Physical Record..65535
File Type ................ LO
Previous File Name ....... STSLIB.001
Comment Record
FILE HEADER
FILE NUMBER: 2
EDITED MERGED MAD
Depth shifted and clipped, curves; all MAD runs merged using earliest passes.
DEPTH INCREMENT: .5000
FILE SUMMARY
PBU TOOL CODE START DEPTH STOP DEPTH
RPM 10309.0 10983.5
RPS 10309.0 10983.5
RPX 10309.0 10983.5
FET 10309.0 10983.5
RPM 10309.0 10983.5
RAT 10621.5 11004.5
GR 10718.5 10977.0
$
MERGED DATA SOURCE
PBU TOOL CODE MAD RUN NOi MAD PASS NO. MERGE TOP MERGE BASE
MWD 5 0 10309.0 11004.0
$
RE~RKS: MERGED MAD PASS.
$
Data Format Specification Record
Data Record Type .................. 0
Data Specification Block Type ..... 0
Logging Direction ................. Down
Optical log depth units ........... Feet
Data Reference Point .............. Undefined
Frame Spacing ..................... 60 .liN
Max frames per record ............. Undefined
Absent value ...................... -999
Depth Units .......................
Datum Specification Block sub-type...0
Name Service Order
Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
RAT MAD FT/H 4 1 68 4 2
GR MAD API 4 1 68 8 3
RPX MAD OHMM 4 1 68 12 4
RPS MAD OHMM 4 1 68 16 5
RPM MAD OHMM 4 1 68 20 6
RPD MAD OHMM 4 1 68 24 7
FET MAD HOUR 4 1 68 28 8
Name Service Unit Min Max
DEPT FT 10309 11004.5
RAT MAD FT/H 0 3136.13
GR MAD API 37.26 99.78
RPX MAD OHMM 2.02 24.64
RPS MAD OHMM 2.21 22.91
RPM MAD OHMM 2.63 21.84
RPD MAD OHMM 2.8 34.2
FET MAD HOUR 95.73 110.31
Mean
10656.8
359.662
73.3102
6.42601
6.65439
7.1813
7.83633
103.773
First Reading For Entire File .......... 10309
Last Reading For Entire File ........... 11004.5
File Trailer
Service name ............. STSLIB.002
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 01/12/10
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.003
Nsam
1392
765
518
1350
1350
1350
1350
1350
First
Reading
10309
10621.5
10718.5
10309
10309
10309
10309
10309
Last
Reading
11004.5
11004.5
10977
10983.5
10983.5
10983.5
10983.5
10983.5
Physical EOF
File Header
Service name ............. STSLIB.003
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 01/12/10
Maximum Physical Record..65535
File Type ................ LO
Previous File Name ....... STSLIB.002
Comment Record
FILE HEADER
FILE NUMBER: 3
RAW MWD
Curves and log header data for each bit run in separate files.
BIT RUN NUMBER: 3
DEPTH INCREMENT: .5000
FILE SUMMARY
VENDOR TOOL CODE START DEPTH STOP DEPTH
ROP 5000.0 10150.0
GR 5054.5 10067.5
RPX 5071.0 10060.5
FET 5071.0 10060.5
RPM 5071.0 10060.5
RPS 5071.0 10060.5
RPM 5071.0 6710.0
$
LOG HEADER DATA
DATE LOGGED: 03-JAN-01
SOFTWARE
SURFACE SOFTWARE VERSION: Insite
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME):
TD DRILLER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
65.44
Memory
10110.0
66.4
69.4
TOOL STRING (TOP TO BOTTOM)
VENDOR TOO1, CODE TOOL TYPE TOOL NUMBER
DGR DUAL GAMMA RAY PB01755HWRG6
EWR4 ELECTROMAG. RESIS. 4 PB01755HWRG6
$
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
8.500
5091.0
BOREHOLE CONDITIONS
MUD TYPE: LSND
MUD DENSITY (LB/G): 9.70
MUD VISCOSITY (S): 42.0
MUD PH: 8.5
MUD CHLORIDES (PPM): 600
FLUID LOSS (C3): 4.8
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT): .450
MUD AT MAX CIRCULATING TERMPERATURE: .254
MUD FILTRATE AT MT: 1.980
MUD CAKE AT MT: .800
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
REMARKS:
$
Data Format Specification Record
Data Record Type .................. 0
Data Specification Block Type ..... 0
Logging Direction ................. Down
Optical log depth units ........... Feet
Data Reference Point .............. Undefined
Frame Spacing ..................... 60 .liN
Max frames per record ............. Undefined
Absent value ...................... -999
Depth Units .......................
Datum Specification Block sub-type...0
Name Service Order Units Size Nsam Rep
DEPT FT 4 1 68
ROP MWD030 FT/H 4 1 68
GR MWD030 API 4 1 68
RPX MWD030 OHMM 4 1 68
RPS MWD030 OHMM 4 1 68
RPM MWD030 OHMM 4 1 68
RPD MWD030 OHMM 4 1 68
FET MWD030 HOUR 4 1 68
Code Offset Channel
0 1
4 2
8 3
12 4
16 5
20 6
24 7
28 8
68.0
125.7
68.0
68.0
Name Service Unit Min Max
DEPT FT 5000 10150
ROP MWD030 FT/H 0.32 5729.54
GR MWD030 API 25.56 481.91
RPX MWD030 OHMM 1.17 1871.78
RPS MWD030 OHMM 1.51' 1821.72
First
Mean Nsam Reading
7575 10301 5000
167.363 10301 5000
143.635 10027 5054.5
3.93903 9980 5071
4.27073 9980 5071
Last
Reading
10150
10150
10067.5
10060.5
10060.5
R?M MWD030 OHMM 1.69 2000
RPD MWD030 OHMM 1.73 2000
FET MWD030 HOUR 0.22 84.02
First Reading For Entire File .......... 5000
Last Reading For Entire File ........... 10150
File Trailer
Service name ............. STSLIB.003
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 01/12/10
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.004
13.5929
7.36946
1.10472
3279
9980
9980
5071
5071
5071
6710
10060.5
10060.5
Physical EOF
File Header
Service name ............. STSLIB.004
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 01/12/10
Maximum Physical Record..65535
File Type ................ LO
Previous File Name ....... STSLIB.003
Comment Record
FILE HEADER
FILE NUMBER: 4
RAW MWD
Curves and log header data for each bit run in separate files.
BIT RUN NUMBER: 4
.5000
DEPTH INCREMENT:
FILE SUMMARY
VENDOR TOOL CODE
ROP
FCNT
NPHI
NCNT
PEF
GR
RPD
RPX
RPM
FET
RPS
RHOB
DRHO
$
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
START DEPTH STOP DEPTH
10000.0 11003.0
10040.0 10931.5
10040.5 10931.5
10040.5 10931.5
10055.0 10946.5
10068.0 10718.0
10092.0 10966.5
10092.0 10966.5
10092.0 10966.5
10092.0 10966.5
10092.0 10966.5
10105.0 10946.5
10105.0 10946.5
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME):
TD DRILLER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
08-JAN-01
Insite
65.44
Memory
11003.0
67.7
68.4
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE TOOL NUMBER
DGR DUAL GAMMA RAY 1777GR/1589NL
EWR4 ELECTROMAG. RESIS. 4 1777GR/1589NL
CTN COMP THERMAL NEUTRON 1777GR/1589NL
SLD
$
STABILIZED LITHO DEN
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
1777GR/1589NL
6.125
10102.0
BOREHOLE CONDITIONS
MUD TYPE: LSND
MUD DENSITY (LB/G): 10.90
MUD VISCOSITY (S): 50.0
MUD PH: 8.8
MUD CHLORIDES (PPM): 600
FLUID LOSS (C3): 4.2
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT): 1.850
MUD AT MAX CIRCULATING TERMPERATURE: .907
MUD FILTRATE AT MT: 1.400
MUD CAKE AT MT: 2.200
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
REMARKS:
$
Data Format Specification Record
Data Record Type .................. 0
Data Specification Block Type ..... 0
Logging Direction ................. Down
Optical log depth units ........... Feet
Data Reference Point .............. Undefined
Frame Spacing ..................... 60 .liN
Max frames per record ............. Undefined
Absent value ...................... -999
Depth Units .......................
Datum Specification Block sub-type...0
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
ROP MWD040 FT/H 4 1 68 4 2
GR MWD040 API 4 1 68 8 3
RPX MWD040 OHMM 4 1 68 12 4
RPS MWD040 OHMM 4 1 68 16 5
RPM MWD040 OHMM 4 1 68 20 6
RPD MWD040 OHMM 4 1 68 24 7
FET MWD040 HOUR 4 1 68 28 8
NPHI MWD040 PU-S 4 1 68 32 9
FCNT MWD040 CNTS 4 1 68 36 10
NCNT MWD040 CNTS 4 1 68 40 11
RHOB MWD040 G/CH 4 1 68 44 12
DRHO MWD040 G/CH 4 1 68 48 13
PEF MWD040 B/E 4 1 68 52 14
60.0
129.4
6O.0
55.0
Name Service Unit Min Max Mean Nsam
DEPT FT 10000 11003 10501.5 2007
ROP MWD040 FT/H 0.15 187.39 66.7984 2007
GR MWD040 API 45.69 259.45 125.314 1301
RPX MWD040 OHMM 1.58 267.08 6.22265 1750
RPS MWD040 OHMM 1.51 1771.75 8.50262 1750
RPM MWD040 OHMM 0.6 1990.45 18.8581 1750
RPD MWD040 OHMM 2.1.7 1885.19 24.9772 1750
FET MWD040 HOUR 0.43 93..04 3.02442 1750
NPHI MWD040 PU-S 19.8 52.29 35.8811 1783
FCNT MWD040 CNTS 127.9 787.7 287.042 1784
NCNT MWD040 CNTS 15029.9 33347.5 20768.9 1783
RHOB MWD040 G/CH 2.189 3.155 2.47772 1684
First
Reading
10000
10000
10068
10092
10092
10092
10092
10092
10040.5
10040
10040.5
10105
Last
Reading
11003
11003
10718
10966.5
10966.5
10966.5
10966.5
.10966.5
10931.5
10931.5
10931.5
10946.5
DRHO MWD040 G/CH -0.425
PEF MWD040 B/E 2.6
0.412 0.0685499 1684
16.53 6.64644 1784
First Reading For Entire File .......... 10000
Last Reading For Entire File ........... 11003
File Trailer
Service name ............. STSLIB.004
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 01/12/10
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.005
10105
10055
10946.5
10946.5
Physical EOF
File Header
Service name ............. STSLIB.005
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 01/12/10
Maximum Physical Record..65535
File Type ................ LO
Previous File Name ....... STSLIB.004
Comment Record
FILE HEADER
FILE NUMBER: 5
RAW MAD
Curves and log header data for each pass of each run in separate files.
DEPTH INCREMENT: .5000
MAD RUN NUMBER: 5
MAD PASS NUMBER: 0
FILE SUMMARY
VENDOR TOOL CODE START DEPTH STOP DEPTH
RPD 10309.0 10983.5
RPM 10309.0 10983.5
RPS 10309.0 10983.5
RPX 10309.0 10983.5
FET 10309.0 10983.5
ROP 10621.5 11004.5
GR 10718.5 10977.0
$
LOG HEADER DATA
DATE LOGGED: 12-JAN-01
SOFTWARE
SURFACE SOFTWARE VERSION: Insite
DOWNHOLE SOFTWARE VERSION: 65.44
DATA TYPE (MEMORY OR REAL-TIME): Memory
TD DRILLER (FT): 11003.0
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE: 66.7
MAXIMUM ANGLE: 67.3
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE TOOL NUMBER
DGR DUAL GAMMA RAY 1752/1748
EWR4 ELECTROMAG. RESIS. 4 1752/1748
$
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN): 6.125
DRILLER'S CASING DEPTH (FT):
BOREHOLE CONDITIONS
MUD TYPE: LSND
MUD DENSITY (LB/G): 10.90
MUD VISCOSITY (S): 49.0
MUD PH: 9.0
MUD CHLORIDES (PPM): 600
FLUID LOSS (C3): 3.8
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT): 2.100
MUD AT MAX CIRCULATING TERMPERATURE: 1.086
MUD FILTRATE AT MT: 1.350
MUD CAKE AT MT: 2.600
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
REMARKS:
$
Data Format Specification Record
Data Record Type .................. 0
Data Specification Block Type ..... 0
Logging Direction ................. Down
Optical log depth units ........... Feet
Data Reference Point .............. Undefined
Frame Spacing ..................... 60 .liN
Max frames per record ............. Undefined
Absent value ...................... -999
Depth Units .......................
Datum Specification Block sub-type...0
Name Service Order
DEPT FT 4 1 68
RAT MAD050 FT/H 4 1 68
GR MAD050 API 4 1 68
RPX MAD050 ,OHMM 4 1 68
RPS MAD050 OHMM 4 1 68
RPM MAD050 OHMM 4 1 68
RPD MAD050 OHMM 4 1 68
FET MAD050 HOUR 4 1 68
Units Size Nsam Rep Code Offset Channel
0 1
4 2
8 3
12 4
16 5
20 6
24 7
28 8
65.0
132.0
65.0
65.0
Name Service Unit Min Max
DEPT FT 10309 11004.5
RAT MAD050 FT/H 0 3136.13
GR MAD050 API 37.26 99.78
RPX MAD050 OHMM 2.02 24.64
RPS MAD050 OHMM 2.21 22.91
RPM MAD050 OHMM 2.63 21.84
RPD MAD050 OHMM 2.8 34.2
FET MAD050 HOUR 95.73 110.31
Mean
10656.8
359.662
73.3102
6.42601
6.65439
7.1813
7.83633
103.773
Nsam
1392
765
518
1350
1350
1350
1350
1350
First
Reading
10309
10621.5
10718.5
10309
10309
10309
10309
10309
Last
Reading
11004.5
11004.5
10977
10983.5
10983.5
10983.5
10983.5
10983.5
First Reading For Entire File .......... 10309
Last Reading For Entire File ........... 11004.5
File Trailer
Service name ............. STSLIB.005
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 01/12/10
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.006
Physical EOF
Tape Trailer
Service name ............. LISTPE
Date ..................... 01/12/10
Origin ................... STS
Tape Name ................ UNKNOWN
Continuation Number ...... 01
Next Tape Name ........... UNKNOWN
Comments ................. STS LIS Writing Library.
Reel Trailer
Service name ............. LISTPE
Date ..................... 01/12/10
Origin ................... STS
Reel Name ................ UNKNOWN
Continuation Number ...... O1
Next Reel Name ........... UNKNOWN
Comments ................. STS LIS Wri'ting Library.
Scientific Technical Services
Scientific Technical Services
Physical EOF
Physical EOF
End Of LIS File
