Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout186-107 STATE OF ALASKA
• ALIPA OIL AND GAS CONSERVATION COMMIION
•
REPORT OF SUNDRY WELL OPERATIONS
1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown ❑
Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑
Plug for Redrill ❑ 'erforate New Pool ❑ Repair Well 0 Re-enter Susp Well❑ Other: ❑
2.Operator 4.Well Class Before Work: 5.Permit to Drill Number:
Name: ConocoPhillips Alaska, Inc. Development p Exploratory❑ 186-107
3.Address: P. O. Box 100360, Anchorage,Alaska Stratigraphic❑ Service❑ 6.API Number:
99510 50-103-20068-00
7.Property Designation(Lease Number): 8.Well Name and Number: KR 2T-06
ADL 25569
9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s):
Kuparuk River Field/Kuparuk River Oil Pool
11.Present Well Condition Summary:
Total Depth measured 8,214 feet Plugs measured None feet
true vertical 6,180 feet Junk measured None feet
Effective Depth measured 8,024 feet Packer measured 7337, 7490, 7643 feet
true vertical 6,017 feet true vertical 5460, 5577, 5700 feet
Casing Length Size MD TVD Burst Collapse
CONDUCTOR 83 feet 16 " 115'MD 115 TVD
SURFACE 3,416 feet 9 5/8" 3,448' MD 2767 TVD
Production Tie Back 2,284 feet 7 " 2,312' MD 2034 TVD RECEIVED
PRODUCTION 5,794 feet 7 " 8,106' MD 6088 TVD y
AUG 1 6 2017
AOGCC
Tubing(size,grade,measured and true vertical depth) 2 7/8 L-80/J-55 7,668' MD 5,720'TVD
Packers and SSSV(type,measured and true vertical depth) FH PACKER- PACKER, BAKER,4762 7,337' MD 5,460'TVD
PACKER- BAKER FHL PACKER 7,490' MD 5,577'TVD
PACKER- BAKER HB-1 PACKER 7,643' MD 5,700'TVD
12.Stimulation or cement squeeze summary:
Intervals treated(measured): N/A Nov
Treatment descriptions including volumes used and final pressure: N/A SCANNED No N 01
13. Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure
Prior to well operation: 0 0 o 1100 170
Subsequent to operation: 412 817 1754 1250 • 232
14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work:
Daily Report of Well Operations El Exploratory ❑ Development El Service 0 Stratigraphic ❑
Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil (] GaQ WDSPL ❑
Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUS❑ 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:
N/A
Contact Name: Sara Heskin
Authorized Name: Sara Heskin
Contact Email: Sara.E.Heskin@cop.com
Authorized Title: Assoc. ells Engineer
/p� Contact Phone: (907)265-1027
Authorized Signature: W�lik * Date: eh(Pf i i'
V`TL /0/6 / /7-' Rp
Form 10-404 Revised 4/2017 , /0/`07
RBDMS (ii/ AUG 2 3 2017 Submit Original Only
• •
Operations Summary (with Timelog Depths)
x
2T-06
ConocoPhillips
if:rk�
Rig: DOYON 14 Job: RECOMPLETION
Time Log
Start Depth
Start Tune End Time Cur(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(ftKB)`
7/17/2017 7/17/2017 0.75 MIRU MOVE RURD P PJSM. Skid the rig floor into moving 0.0 0.0
10:00 10:45 position.
7/17/2017 7/17/2017 1.75 MIRU MOVE MOB P Move the rig off well 2T-203 and 0.0 0.0
10:45 12:30 stage on rig mats.
7/17/2017 7/17/2017 1.25 MIRU MOVE RURD P Shuffle mats from around well 2T-203 0.0 0.0
12:30 13:45 to around 2T-06.
7/17/2017 7/17/2017 1.00 MIRU MOVE MOB P Spot the rig over well 2T-06. 0.0 0.0
13:45 14:45
7/17/2017 7/17/2017 0.75 MIRU MOVE RURD P Shim and level the rig. 0.0 0.0
14:45 15:30
7/17/2017 7/17/2017 0.75 MIRU MOVE RURD P Skid the rig floor into drilling position. 0.0 0.0
15:30 16:15
7/17/2017 7/17/2017 1.75 MIRU MOVE 'RURD PRUthe linesbeaver underslidethe rig floor and RU 0.0 0.0
16:15 18:00 .
7/17/2017 7/17/2017 2.50 MIRU WELCTL RURD P Rig accepted at 18:00 hours. Load 0.0 0.0
18:00 20:30 the pits with seawater and RU
circulating lines in the cellar.
7/17/2017 7/17/2017 0.25 MIRU WELCTL SFTY P PJSM on pressure testing lines to kill 0.0 0.0
20:30 20:45 tanks and circulating the diesel out of
the tubing and IA.
7/17/2017 7/17/2017 0.25 MIRU WELCTL SEQP P PJSM. PT lines with air and no leaks. 0.0 0.0
20:45 21:00 PT lines with fresh water to 2500 psi
(good test).
7/17/2017 7/17/2017 0.25 MIRU WELCTL WAIT T The rig lost power. Start up the 0.0 0.0
21:00 21:15 generator.
7/17/2017 7/17/2017 1.75 MIRU WELCTL MPSP P PU and MU the lubricator. PT to 0.0 0.0
21:15 23:00 250/1000 psi. Pull the 3"H BPV and
RD the lubricator.
7/17/2017 7/17/2017 0.75 MIRU WELCTL KLWL P Circulate diesel out of the well by 0.0 0.0
23:00 23:45 pumping 15 bbls down the IA followed
by 75 bbls down the tubing taking
returns to the kill tanks.
7/17/2017 7/18/2017 0.25 MIRU WELCTL OWFF P Observe the well for flow and the well 0.0 0.0
23:45 00:00 is static.
7/18/2017 7/18/2017 0.50 MIRU WHDBOP MPSP P PU and MU the dry rod,install the 3" 0.0 0.0
00:00 00:30 HP BPV,and lay down the dry rod.
Pressure up on the IA to 1000 psi to
test the BPV from below in the
direction of flow for 10 minutes(good
test).
7/18/2017 7/18/2017 0.50 MIRU WHDBOP RURD P Blow down and RD circulating lines. 0.0 0.0
00:30 01:00
7/18/2017 7/18/2017 1.50 MIRU WHDBOP NUND P ND the tree and tubing head adapter. 0.0 0.0
01:00 02:30 Inspect the lift threads and install the
plug off tool into the BPV.
7/18/2017 7/18/2017 3.50 MIRU WHDBOP NUND P NU double stud adapter,DSA and 0.0 0.0
02:30 06:00 spacer spool.
7/18/2017 7/18/2017 3.00 MIRU WHDBOP NUND P NU the BOP stack and NU the kill line. 0.0 0.0
06:00 09:00 Center the BOP stack,install the riser
and air up the air boot.
7/18/2017 7/18/2017 1.75 MIRU WHDBOP NUND P PJSM. Change the upper pipe rams 0.0 0.0
09:00 10:45 to 2-7/8"x 5"VBR's.
7/18/2017 7/18/2017 0.50 MIRU WHDBOP RURD P RU BOPE testing equipment. 0.0 0.0
10:45 11:15
Page 1/5 Report Printed: 8/16/2017
• •
Operations Summary (with Timelog Depths)
2T-06 •
comoccophinips
,4irA:m
Rig: DOYON 14 Job: RECOMPLETION
Time Log
Start Depth
Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-x Operation (ftKB) End Depth(ftK8)'
7/18/2017 7/18/2017 4.00 MIRU WHDBOP BOPE P Conduct initial BOPE test: test 2-7/8" 0.0 0.0
11:15 15:15 x 5"VBR's(upper pipe rams)to
250/2500 psi with 2-7/8"test joint;test
2-7/8"x 5"VBR's(lower pipe rams)to
250/2500 psi with 2-7/8"test joint;test
annular to 250/2500 with 2-7/8"test
joint;conducted Koomey drawdown
test(all tested passed). The test was
witnessed by AOGCC inspector Matt
Herrera.
Tests:
1) 2-7/8"x 5"VBR's(upper pipe
rams)with 2-7/8"test joint,2"Demco,
choke valves 1, 12, 13&14(Passed)
2) HCR kill,HCR choke(Passed)
3) Manual kill,manual choke
(Passed)
4) 2-7/8"x 5"VBR's(lower pipe rams)
with 2-7/8"test joint(Passed)
5) Annular with 2-7/8"test joint,choke
valves 9&11 (Passed)
6) Blind rams,upper IBOP,choke•
valves 5,8&10(Passed)
7) Lower IBOP,choke valves 4,6&7
(Passed)
8) 4"HT-38 dart,choke valve 2
(Passed)
9) 4"HT-38 FOSV valve,choke valve
3(Passed)
10) Super choke and manual choke
(Passed)
Conduct Koomey Draw Down Test:
Starting Accumulator Pressure=3050
psi
Accumulator Pressure After Closer=
1725 psi
Pressure Gain of 200 psi=44
seconds
Full System=197 Seconds
Average N2(6 Bottles)=2150 psi
7/18/2017 7/18/2017 0.75 MIRU WHDBOP RURD P PJSM. Blow down the choke manifold 0.0 0.0
15:15 16:00 and all lines. RD BOPE testing
equipment.
7/18/2017 7/18/2017 0.75 COMPZN RPCOMP RURD P Suck out the BOP stack. Mobilize 2- 0.0 0.0
16:00 16:45 7/8"handling equipment to the rig
floor.
7/18/2017 7/18/2017 0.50 COMPZN RPCOMP RURD P PU and MU the dry rod,pull the plug 0.0 0.0
16:45 17:15 off tool,pull the 3"HP BPV and lay
down the dry rod. Observe the well
for flow for 5 minutes and the well was
static.
7/18/2017 7/18/2017 0.75 COMPZN RPCOMP PULL P MU the landing joint with crossover to 0.0 0.0
17:15 18:00 the top drive. MU landing joint to the
tubing hanger. Set down 5K and
BOLDS.
SimOps: RU circulating line to the kill
tanks.
7/18/2017 7/18/2017 1.00 COMPZN RPCOMP PULL P Pull the hanger free(PU=80K and 7,419.0 7,415.0
18:00 19:00 SO=67K). Pull the tubing hanger to
the rig floor and lay down. MU the
landing joint to the tubing string and
MU the top drive.
Page 2/5 Report Printed: 8/16/2017
•
•
Operations Summary (with Timelog Depths)
-
2T-06
Conohiifiips
_ Ftrsk;x
Rig: DOYON 14 Job: RECOMPLETION
Time Log
Start Depth
Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation {ftKB)r End Depth(ftKB)
7/18/2017 7/18/2017 1.25 COMPZN RPCOMP WAIT T Wait for seawater to arrive(Vac truck 7,415.0 7,415.0
19:00 20:15 had a flat tire)for displacing corrosion
inhibited seawater.
7/18/2017 7/18/2017 0.75 COMPZN RPCOMP WAIT T Take on 290 bbls of seawater. 7,415.0 7,415.0
20:15 21:00
7/18/2017 7/18/2017 1.25 COMPZN RPCOMP DISP P Close the annular and displace the 7,415.0 7,415.0
21:00 22:15 well from corrosion inhibited seawater
to seawater and 8 BPM=2890 psi.
Open the annular,observe the well for
flow for 5 minutes and the well is
static.
7/18/2017 7/18/2017 0.25 COMPZN RPCOMP RURD P Lay down the landing joint and break 7,415.0 7,383.0
22:15 22:30 out the 3-1/2"x 2-7/8"crossover. MU
3-1/2"x 2-7/8"crossover and 3-1/2"x
4"HT-38 crossover to 4"HT-38 •
FOSV.
7/18/2017 7/19/2017 1.50 COMPZN RPCOMP PULL P POOH laying down 2-7/8",6.5#,L-80 7,383.0 5,942.0
22:30 00:00 EUE 8rd Mod tubing removing jewelry
from 7383'to 5942'MD at midnight.
7/19/2017 7/19/2017 5.50 COMPZN RPCOMP PULL P Continue to POOH laying down 2-7/8", 5,942.0 0.0
00:00 05:30 6.5#,L-80 EUE 8rd Mod tubing
removing jewelry from 5942'MD to
surface. Recovered 230 joints of 2-
7/8"tubing,5 GLM's, 1 DS nipple and
cut joint=14.29'.
7/19/2017 7/19/2017 0.75 COMPZN RPCOMP RURD P Clean and clear the floor. Empty the 0.0 0.0
05:30 06:15 pipe shed pulled tubing.
7/19/2017 7/19/2017 1.00 COMPZN RPCOMP RURD P Mobilize air slips to the rig floor. RU 0.0 0.0
06:15 07:15 air slips. Review completion in the
pipe shed.
7/19/2017 7/19/2017 8.00 COMPZN RPCOMP PUTB P PU,MU and RIH with stacked packer 0.0 7,419.0
07:15 15:15 completion on 2-7/8",6.5#, L-80,EUE
8rd Mod tubing to the top of the tubing
stub at 7419'MD.
7/19/2017 7/19/2017 0.50 COMPZN RPCOMP PUTB P Tag shear pins and set down 15K to 7,419.0 7,409.0
15:15 15:45 shear. Continue to SO to no-go with
10K down. PU 10'off the tubing stub.
7/19/2017 7/19/2017 0.50 COMPZN RPCOMP RURD P PJSM. RU to circulate to the kill tank. 7,409.0 7,409.0
15:45 16:15
7/19/2017 7/19/2017 2.25 COMPZN RPCOMP CRIH P Pump 275 bbls of corrosion inhibited 7,409.0 7,409.0
16:15 18:30 seawater down the tubing taking up
the IA to the kill tank at 2 BPM=500
psi.
7/19/2017 7/19/2017 1.50 COMPZN RPCOMP PACK P Drop the ball&rod and allow time to 7,409.0 7,426.0
18:30 20:00 fall to seat. Pressure up to 2600 psi
for 5 minutes to set FH packer. Bleed
the tubing to 2000 psi,PU and shear
the PBR.
7/19/2017 7/19/2017 1.50 COMPZN RPCOMP HOSO P RIH,locate out and mark the pipe for 7,426.0 7,275.0
20:00 21:30 space out. Space out,MU crossover
and MU a joint of 3-1/2",9.3#,L-80
EUE 8rd Mod tubing.
7/19/2017 7/19/2017 1.00 COMPZN RPCOMP THGR P PU and MU the McEvoy tubing 7,275.0 7,331.0
21:30 22:30 hanger. MU the landing joint(PU=
85K and SO=65K). Land the tubing
hanger and RILDS.
Page 3/5 Report Printed: 8/16/2017
• •
Operations Summary (with Timelog Depths)
4:543
2T-06
ConocoPhillips
Rig: DOYON 14 Job: RECOMPLETION
Time Log
Start Depth
Start Time End Time Our(hr) Phase Op Code Acwity Code Time P-T-X Operation (ftK6)' End Depth(EKE)'
7/19/2017 7/19/2017 1.00 COMPZN RPCOMP PRTS P PT the tubing to 3000 psi for 10 7,331.0 0.0
22:30 23:30 minutes(good test),bleed the tubing
to 1500 psi,PT the IA to 2500 psi for
30 minutes(good test)and shear the
SOV.
7/19/2017 7/20/2017 0.50 COMPZN RPCOMP CIRC P Circulate 2 bbls down the IA and 0.0 0.0
23:30 00:00 tubing to confirm circulation through
the SOV.
7/20/2017 7/20/2017 0.50 COMPZN WHDBOP MPSP P PU and MU the dry rod. Install the 3" 0.0 0.0
00:00 00:30 HP BPV and lay down the dry rod.
Pressure up on the IA to 1000 psi for
10 minutes to test the BPV from below
in the direction of flow(good test).
Bleed the pressure to 0 psi.
7/20/2017 7/20/2017 1.00 COMPZN WHDBOP OTHR P Rig down testing equipment,blow 0.0 0.0
00:30 01:30 down lines and suck out the BOP
stack. Prep for BWM.
7/20/2017 7/20/2017 1.00 COMPZN WHDBOP SVRG P Perform CPAI Between Wells 0.0 0.0
01:30 02:30 Maintenance(BWM)on the BOP
stack: Break bolts on the upper ram
doors,open doors,and function ram
pistons to the closed position.Inspect
rams,ram cavities,sealing surfaces,
and door seals.Close the upper ram
doors and tighten the bolts(photos
taken of all components and of stack
cavities).
7/20/2017 7/20/2017 1.00 COMPZN WHDBOP SVRG P CPAI BWM on the BOP stack: Break 0.0 0.0
02:30 03:30 bolts on blind ram doors,open doors,
and function ram piston to the closed
position.Inspect ram cavities,sealing
surfaces,and door seals. Inspect blind
upper seal and front packer assembly.
Change out the top seal on the blind
rams(photos taken of all components
and of stack cavities).
7/20/2017 7/20/2017 1.00 COMPZN WHDBOP SVRG P CPAI BWM on the BOP stack: Break 0.0 0.0
03:30 04:30 bolts on the lower ram doors,open
doors,and function ram pistons to the
closed position. Inspect rams,ram
cavities,sealing surfaces,and door
seals.Close the lower ram doors and
tighten the bolts(photos taken of all
components and of stack cavities).
7/20/2017 7/20/2017 1.00 COMPZN WHDBOP SVRG P CPAI BWM on the BOP stack:Pull the 0.0 0.0
04:30 05:30 riser. Function the annular checking
for excessive wear and overall
condition(photos taken of annular).
7/20/2017 7/20/2017 1.50 COMPZN WHDBOP NUND P ND the BOP stack,set back on the 0.0 0.0
05:30 07:00 stump and secure for transport.
7/20/2017 7/20/2017 0.75 COMPZN WHDBOP NUND P Install the plug off tool into the BPV. 0.0 0.0
07:00 07:45 NU the tubing head adapter.
7/20/2017 7/20/2017 0.75 COMPZN WHDBOP PRTS P PT the tubing hanger void to 250/5000 0.0 0.0
07:45 08:30 psi for 10 minutes(good test).
7/20/2017 7/20/2017 1.50 COMPZN WHDBOP NUND P NU the tree(tree orientation verified 0.0 0.0
08:30 10:00 by 2T pad operator).
7/20/2017 7/20/2017 0.75 COMPZN WHDBOP PRTS P PT the tree to 250/5000 psi for 10 0.0 10.0
10:00 10:45 minutes(good test).
Page 4/5 • Report Printed: 8/16/2017
Sa • •
Operations Summary (with Timelog Depths)
. 2T-06
ConocoPhi tiips
•
Rig: DOYON 14 Job: RECOMPLETION
Time Log
Start Depth
Start Time End Time Dvr(hr) Phase Op Code Activity Cade Time P-T-X- Operation (5KB) End Depth(ftKB)
7/20/2017 7/20/2017 0.25 COMPZN WHDBOP MPSP P Pull the plug off tool and BPV. 0.0 0.0
10:45 11:00
7/20/2017 7/20/2017 0.50 COMPZN WHDBOP FRZP P RU to freeze protect.. 0.0 0.0
11:00 11:30
7/20/2017 7/20/2017 1.25 COMPZN WHDBOP FRZP P PJSM. Spot LRS. PT lines to 2500 0.0 0.0
11:30 12:45 psi. Pump 82 bbls of diesel at 1.5
BPM
7/20/2017 7/20/2017 1.00 COMPZN WHDBOP FRZP P Place the tubing and IA in 0.0 0.0
12:45 13:45 communication and allow to u-
tube/equalize. RD LRS.
SimOps: Prep for rig move.
7/20/2017 7/20/2017 0.50 COMPZN WHDBOP MPSP P PU and MU the dry rod. Install the 3" 0.0 0.0
13:45 14:15 H BPV and lay down the dry rod.
7/20/2017 7/20/2017 0.75 DEMOB MOVE RURD Remove 1502 flanges and install 0.0 0.0
14:15 15:00 gauges. Blow down and RD all the
line in the cellar.
•
Page 5/5 Report Printed: 8/16/2017
Iv'
KUP PD 2T-06
Conocii � Well AttributelOPF Max Angle TD
Alaska,Inc,
• ,F Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB)
Opg,pCtiyhlg;ps 501032006800 KUPARUK RIVER UNIT PROD 51.32 3,500.00 8,208.0
°.. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) ''Rig Release Date
27-06,.ens/2017:56:06 AM SSSV:NONE 25 11/20/2015 Last WO: 7/20/2017 40.00 8/22/1986
,..,
Vertical srbeme5c(artval) 'Annotation Depth(ftKB) End Date Annotation Last Mod By End Date
HANGER;28.3 Last Tag:RKB 7,781.0 5/14/2017 Rev Reason:PULL BALL n'ROD,PLUG& pproven 8/3/2017
CATCHER&GLV C/0
Casing Strings
41 ;',,; Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread
„Mt,iii„i,1.I,.,arnn,,,to..,1.,,e1,1,,.,,,, .d. CONDUCTOR 16 15.062 32.0 115.0 115.0 62.50 H-40 WELDED
Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread
SURFACE 95/8 8.765 32.0_ 3,448.1 2,767.0 36.00 J-55 BTC
Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...'Wt/Len(I...Grade Top Thread
PRODUCTION Tie-Back 7 6.276 28.3 2,312.0 2,034.4 26.00 L-80 TCII
-iv.,CONDUCTOR;32.0.115.0 -Casing Description SOD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I.. Grade Top Thread
PRODUCTION Post 7 6.276 2,312.0 8,105.5 6,087.8 26.00 J-55 BTC
WO
Tubing Strings
Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft.. Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection
Tubing-RWO 2017 2 7/8 2.441 28.3 7,425.9 5,527.1 6.50 L-80 EUE 8rd Mod
PRODUCTION To-Bacz28
Zo 0 i Completion Details
Ai
Nominal ID
Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (ie)
MANDREL;3,024.8 Ir. 28.3 28.3 0.09 HANGER Tubing Hanger,McEvoy,DP-1-D-S-3 Gen 4,7-1/16"x 3- 2.992
4 1/2"EUE 8rd top x bottom,3"H BPVG
I 7,310.3 5,439.9 42.08'LOCATOR Locator Sub,Baker(Bottom of locator space out 5.45') 2.430
7,311.3 5,440.7 42.06'SEAL Seal Assemby,Baker,80-32(Total seal assembly length 2.400
ASSEMBLY =19.77')
SURFACE;32.0-3,448.1-• • 7,316.1 5,444.3 41.98 PBR PBR,Baker,20'80-32 3.250
7,337.0 5,459.9 41.62 FH PACKER Packer,Baker,4782 FH(Shear release=40K) 2.420
GAS LIFT,4,778.0 7,379.3 5,491.6 40.90 NIPPLE Nipple,Halliburton,2.313 X Profile 2.313
7,418.5 5,521.4 40.04 OVERSHOT Poorboy Overshot,Baker(Swallow=6.93') 2.980 .
Tubing Description String Ma...ID(in) Top(ftKB) 'Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection
GAS LIFT,6,503.6 i' Tubing-RWO 2010 27/8 2.441 7,419.0 7,600.0 5,664.7 6.50 L-80 EUE8rd
1-1 Completion Details
Nominal ID
Top(ftKB) Top(TVD)(RKB) Top Incl C) Item Des Com (in)
7,442.3 5,539.8 39.39 SEAL ASSY Baker Seal Assemby for 20 PBR spaced out 6.5'off fully 2.410
GAS LIFT;8,815.9 located
7,449.9 5,545.6 39.19 PBR Baker 20'PBR(pinned 40M8 shear) 3.250
7,489.5 5,576.6• 38.11 PACKER BAKER FHL PACKER 2.430
GAS LIFT;7,253.3 ', 4 7,543.0 5,619.0 37.17 NIPPLE CAMCO'X'NIPPLE 2.313
7,586.1 5,653.5 36.51 Centralizer CENTRALIZER 2.441
7,587.8 5,654.9 36.48 LOCATOR LOCATOR SUB 2.500
LOCATOR;7,310.3 7,588.5 5,655.4 36.48 SEAL ASSY Baker DUMMY SEAL ASSEMBLY wo/seals Spaced 1'off 2.500
SEAL ASSEMBLY;7,311.3 fully located
PBR;7,316.1 } Tubing Description String Ma...ID(in) Top(ftKB) 'Set Depth(ft..JSet Depth(TVD)(...Wt Ob/R) Grade Top Connection
FH PACKER;7,337.0 TUBING Original 27/8 2.441 7,599.7 7,668.51 5,720.2 6.50 J-55 EUE8rdABMOD
Completion Details
Nominal ID
NIPPLE;7,379.3 Top(ftKB) Top(TVD)(RKB) Top Incl Cl Item Des Corn (in)
7,626.8 5,686.3 36.03 PBR BAKER PBR 3.625
7,643.4 5,699.8 35.87 PACKER BAKER HB-1 PACKER 2.347
7,657.9 5,711.5• 35.72 NIPPLE CAMCO'D'NIPPLE 2.250
OVERSHOT;7,418.5 7,667.8 5,719.6 35.62 SOS BAKER SHEAROUT SUB 2.441
Perforations&Slots
SEAL ASSY;7,442.3 I Shot
PBR;7,448.9 4 { Dens
Top(TVD) Btm(TVD) (hots/
WI Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com
PACKER,7,489.5 7,770.0 7,774.0 5,803.3 5,806.6 A-4,2T-06 '10/5/1986 1.0 IPERF 4"Schlum.HyperJet
7,778.0 7,782.0 5,809.9 5,813.2'A-3,2T-06 '10/5/1986 1.0 IPERF 4"Schlum.HyperJet
7,785.0 7,814.0 5,815.7 5,839.8 A-3,2T-06 10/5/1986 4.0 IPERF 90 deg.Ph;4"Schlum.
NIPPLE 7,54301E3HyperJet
7,851.0 7,854.0 5,870.8 5,873.4 A-2,2T-06 •10/5/1986 4.0 IPERF 90 deg.Ph;4"Schlum.
HyperJet •
Stimulations&Treatments
Centralizer,7,588.1 Proppant Designed iib) Proppant In Formation(Ib) Date
LOCATOR;7,587.8 7/18/1988
SEAL ASSY,7,588.5 Stimulations&Treatments
Vol Clean Pump
Stg# Top(MB) Btm IRKS) Date StmmlTreat Fluid (bbl) Vol Slurry(bbl)
1 7,770.0 7,854.0 7/18/1988
PBR;7,626.8 Mandrel Inserts
PACKER;7,643.4 St
it atm
NIPPLE,7,667.9 iN Top(TVD) Valve Latch Port Size TRO Run
Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn
SOS,7,3828 . 1 3,024.8 2,494.3 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,276.0 7/27/2017
2 4,778.0 3,652.8 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,258.0 7/27/2017
3 6,003.6 4,500.5 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,250.0 7/27/2017
4 6,845.9 5,101.0 Camco 'MMG 1 1/2 GAS LIFT GLV RK 0.188 1,238.0 7/27/2017
5 7,253.3 5,397.8 Camco MMG 11/2 GAS LIFT OV RKP 0.250 0.0 7/26/2017
IPERF;7,770.0-7,774.0 Notes:General&Safety
End Date Annotation
IPERF;7,778.0-7,782.0 9/26/2010 NOTE:"'SURFACE ANNULUS CEMENTED FROM 2312'TO SURFACE"`
9/26/2010 NOTE:WORKOVER w/NEW TUBING,NEW PROD CSG TOP SECTION due to Subsidence
IPERF;7,7135.67,814.0 10/3/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0
FRAC;7,770.0
IPERF;7,851.0-7,854.0
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ConocoPhillips
Alaska
P.O.BOX 100360
ANCHORAGE,ALASKA 99510-0360
Zg15
31
March 25, 2015 SC 0*V' 14°'\C0*DMPR
Commissioner Cathy Foerster
Alaska Oil & Gas Commission ...- (0 17
333 West 7th Avenue, Suite 100 �4J
Anchorage, AK 99501 �� N
Commissioner Cathy Foerster:
Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of
these wells was found to have a void in the conductor. These voids were filled with cement and
corrosion inhibitor, engineered to prevent water from entering the annular space. As per
previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the
treatments took place and meets the requirements of form 10-404, Report of Sundry Operations.
The attached spread sheet presents the well name,top of cement depth prior to filling and
volumes used on each conductor.
Please call MJ Loveland or Martin Walters at 907-659-7043, if you have any questions.
Sincerely,
l/7
MJ Loveland
ConocoPhillips Well Integrity Projects Supervisor
ConocoPhillips Alaska Inc.
Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off
Report of Sundry Operations(10-404)
Kuparuk Field
Date 3-22-2015 2N&2T PAD
Corrosion
Initial top Vol.of cement Final top of Cement top off Corrosion inhibitor/
Well Name API# PTD# of cement pumped cement date inhibitor sealant date
ft bbls ft gal
2N-315 50103202700000 1981900 6" N/A 13" N/A 4 3/22/2015
2N-339 50103202610000 1981000 8" N/A 25" N/A 8.5 3/22/2015
21-06 50103200680000 1861070 3' 0.30 25" 8/13/2014 8.5 3/22/2015
Image Project Well' History File Cover Page
XHVZE
This page identifies those items that were not scanned during the initial production scanning.
They are available in the original file, may be scanned during the rescan activity or are viewable
by direct inspection of the file.
/ ~;~- ~_~ Z Well History File Identifier
Organization (done) ,,~Two-Sided
RESCAN
[] Color items:
[] Grayscale items:
DIGITAL DATA
[] Diskettes, No.
[] Other, No/Type
Poor Quality Originals:
Other:~°~ ~
TOTAL PAGES: ~ ~
ORGANIZED BY: BEVERLY
NOTES:
BREN VINCENT SHERYL MARIA LOWELL
OVERSIZED (Scannable)
[] Maps:
[] Other items scannable by
large scanner
OVERSIZED (Non-Scannable)
[] Logs of various kinds
[] Other
DATE: /SI
Project Proofing
[] Staff Proof
By: Date:
PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE:
Is~
PAGES: ?{~ (at the time of scanning)
SCANNED BY; BEVERLY BR~HERYL MARIA LOWELL
DATE
RESCANNEDBY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL
DATE:
Is~
General Notes or Comments about this file:
PAGES: ~
Quality Checked (done)
•
•
~~Q~~ 0~ p~a~~{Q /.E,.,.w.E..oo~w.~
Howard Gober
Wells Engineer -~
ConocoPhillips Alaska, Inc. ~'
P.O. Box 100360
Anchorage, AK 99510
Re: Kuparuk River Field, Kuparuk River Oil Pool, 2T-06
Sundry Number: 310-273
Dear Mr. Gober:
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 Commission grants for good cause shown,
a person affected by it may file with the Commission 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,
Daniel T. Seamount, Jr.
~ ~ Chair
DATED this2 day of September, 2010.
Encl.
STATE OF ALASKA
ALASK~L AND GAS CONSERVATION COMMISS• r ~!
APPLICATION FOR SUNDRY APPROVALS ~'
20 AAC 25.280
1. Type of Request: Abandon ~ Rug for Redrill ~ Perforate New Pool Repair w ell (/ Change Approved Program
Suspend ~"' Rug F~rforations Perforate ~' Full Tubing (/', - Time Extension ~""'
Operational Shutdow n Re-enter Susp. Well ~ Stimulate Alter casing ' Other:
2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number:
ConocoPhillips Alaska, Inc. Development Exploratory ~'"""' 186-107 '
3. Address:
Stratigraphic ~"°"
Service "' 6. API Number:
P. O. Box 100360, Anchorage, Alaska 99510 50-103-20068-00
7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number:
where ownership or landownership changes:
Spacing Exception Required? YeS ~~ No ~'. 2T-O6
9. Property Designation: 10. Field/Pool(s):
ADL 25569 Kuparuk River Field / Kuparuk River Oil Pool
11. PRESENT WELL CONDITION SUMMARY
Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured):
8214 6180 8024' 6017'
Casing Length Size MD TVD Burst Collapse
CONDUCTOR 80 16 115' 115'
SURFACE 3416 9.625 3448' 2767'
PRODUCTION 8106 7 8106' 6088'
Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft):
7770'-7774', 7778'-7782', 7785'-7814', 7851'-7854' 5803'-5807', 5810'-5813', 5816'-5839', 5871'-5873' 2.875 J-55 7669
Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft)
PACKER -BROWN HB-1 PACKER MD= 7643 TVD= 5699
TRDP - CAMCO TRDP-IA-SSA MD= 1791 TVD= 1661
12. Attachments: Description Sunmary of Proposal r'', 13. Well Class after proposed work:
Detailed Operations Program ~` BOP Sketch ~"" Exploratory '~'" Development i/`, Service °'
14. Estimated Date for Commencing Operations: 15. Well Status after proposed work:
9/3/2010 Oil ~ Gas ~"` WDSPL Suspended ;
16. Verbal Approval: Date: WINJ ~ GINJ ~' WAG ~ Abandoned ""
Commission Representative: GSTOR ~~ SPLUG "`
17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Howard Gober @ 263-4220
Printed Name HOWarCI Gober Title: Wells Engineer
i
~~ ~~~/
te
Signature Phone: 263-4220 a
Date
mm' i nl
Sundry Number:~~~1~^~ "`~.~
~
e~
Conditions of approval: Notify Commission so that a representative may witness .•+
Plug Integrity ~" BOP Test Mechanical Integrity Test [` Location Clearance ~"`
~ 3ocx~ ~ 5~ ~3o P l ~-
Other.
~~ ~~
Subsequent Form Required:
Q ~l
a-
l
y
APPROVED BY /}/ //
Aooroved bv: COMMISSIONER THE COMMISSION Date: l
Form 10-403 0 ~ J'' ~ ~ ~ ~ L '`~ ~`-~(-l ~ Submit in DupTica~~/ ~
~ ~P 0-2 ~~~ ~ /v
~R ~2~
~~a~tiPhilli~rs
~ :Isk.~l, lnc.
CONDVCTOR,
115
sAFETy vLV,
1.791
GAS LIFT,
3,113
GAS LIFT. __ _ _-
5,270
GAS LIFT, -
6.2]T
GAS LIFT. _ _ _
6.62]
GAS LIFT,
6,9]]
GAS LIFT, _-__
T.325
GAS LIFT, _ ____.-
7,581
PBR, 7.62] - -
PACKER, ],663 -
NIPPLE, 7,658
SOS. 7,668
TTL, 7,669
IPERF.
] 1]0-].]T4
IPERF,
],T/8-7,T82
IPERF,
zTes-zela
IPERF.
z6s+.-7.esa
~ KUP
ell Attributes
Ibore APVUWI Field
501032006800 KUP/
nment
SV: TRDP
2 1/8
Jewel
Inc!
3,113
5,270
~ 6,277
6,627
~~ 6,977
ntl 7,325
7,581
7,6691 5,
rforatior
(ftKB) Btrn
7,77011
7,778
- 2T-06
Max Angle & MD TD
' Well Status Inc! (°) MD (HKB) Act Btm (kKB)
( RIVER UNIT ',PROD 51.32 I 3,500.00 8.214.0
25 (pPm) (Date I Annotation End Date KB-Grtl (tt) Rig Release Date
60 U71/2009 40.00 8/2211986
id Date Annotation Last Mod By ',End Date
3/4/2006_IRev Reason: Tag obstruction (o7 380' ELM Imosbor ' 7/20/2009
Siring ID Set Depth Set Depth (ND) String Wl String 'I
(in) Top (ftKB) (ft KBj (fiKB) (Ibslft) Grade String Top Thrd
15.062 0.0 115.0 115.0 62.50 H-00
8.765 0.0 3 448 0 2,76Z4T 36.00 J-66
6.151 0.0 8,10fi.0 6.088 2 26.00 J-55
String ID Set Depth Set Deplh (NDI ~~ String Wt String
(in) Top (kKB) (ftKB) (ftKB) it (Ibs/H) Grade String Top Thrd
2 441 0.0 7.669 0 5, 720 fi ~ 6.50 J-55 ABM SRD
ry: Tubing Run & Retrievable, Fish, etc.)
]escription Comment Run Dale ID (in)
fE1Y VLV Camco TRDP-IA-SSA 10/15/1986 2.312
,S LIFT CAMCO/KBMG71/GLV/BK/.756/13061 Comment: STA 1 5/7/1997 2.371
.S LIFT ~~CAMCO/KBMG/1/GLVIBK/.188/1344! Comment STA2 5/7/1997 2.371
,S LIFT CAMCO/KBMG/7IDMY/BK/// Comment: STA 3 10/15/1986 2.371
,S LIFT CAMCO/KBMG/1lGLV/BK/_788/1341/Comment STA4 6/8/2006 12.371
,S LIFT CAMCO/KBMG11/DMY/BK/// Comment: STA 5 10/1517986 12.371
,5 LIFT CAMCO/KBMG/1/GLV/BK1.25/1434/ Comment STA 6 5!7/1997 2.371
IS LIFT MMH/2.875x1/LS/OV/RK/.3130 Comment STA 7 5!7/1997 2347
~R Brown PBR 10/15/1986 2.500
.CKER Brown HB-1 PACKER 10!15/1986 2441
'PLE Camco'D' Nipple NO GO 10175/1986 2250
)S BFOW^ 10/15/1986 2441
L ~ 10/15/1986 2447
snot'
Btm (TVD) Dens
(fiKB) Zone Date (s h... Type Comment
5,806.I~A4, 21-06 10/5/1986 I 1.0 IPERF 4" Schlum. HyperJet
5,813.3~A-3, 2T-06 10/5/1986 1.0 IPERF 4" Schlum_ HyperJet
5,839.0 A-3, 2T-O6 ~~ 10/5/1986 4.0 IPERF 90 deg. Ph; 4" Schlum HyperJet
5,873.1IA-2, 21'-06 110/5/1986 4.0 IPERF ',90 deg. Ph; 4" Schlum. HyperJet
PRODUCTION,
6.106 ~-
TD, 6,214
•
ConocoPhillips
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
August 30, 2010
Commissioner Dan Seamount
State of Alaska
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue Suite 100
Anchorage, Alaska 99501
Dear Commissioner Seamount:
•
ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the
Kuparuk Well 2T-06 (PTD 186-107).
2T-06 was originally completed in 1986. The well is a single gas lifted producer located in an
area with surface subsidence. The well currently cannot be drifted with slickline, so a workover is
necessary in order to access the gas lift mandrels in the tubing. The well passed a TIFL (tubing
integrity by fluid level on 6/27/10. The surface casing failed aMIT-OA with a leak rate of 1 bpm at
600 psi.
The well is currently shut in. The current estimate for SBHP is 2363 psi. On 8/25/10 the tubing
was loaded with diesel down to the perforations, and the tubing pressure at the end of the
pumping operation was 300 psi. Taking the diesel gradient plus the surface pressure yields a
mid-pert SBHP of 2363 psi. Utilizing this calculated SBHP, KWF is estimated to be 8.2 ppg with a
125 psi overbalance. The MASP is 1780 psi based upon the SBHP estimate.
The objective of this workover is to replace the corkscrewed/buckled tubing, cut & pull a portion of
the 7" casing, re-run new 7" casing, and circulate cement into the 9-5/8" x 7" annulus. The 7" ,/
casing work is not required to fix an existing problem, but it will be done while the rig is on the well
as a proactive measure.
If you have any questions or require any further information, please contact me at 263-4220.
Sincerely,
Howard B. Gober
Wells Engineer
CPAI Drilling and Wells
06 Expense Rig Workover
(PTD #: 186-107)
Current Status
The well is currently shut in awaiting a Workover to replace the corkscrewed tubing and to proactively
repair the 7" production casing. This well is located in an area with surface subsidence. Due to the
corkscrewed tubing, we are unable to access the tubing tail with slickline. The production casing appears
to be competent due to a passing TIFL. The surface casing has a leak of 1 bpm at 600 psi. The leak °
depth is estimated to be at 360'.
Scope of Work
Pull the tubing, proactively cut & pull a portion of the 7" casing, re-run new 7" casing, circulate cement into
the 9 5/8" x 7" annulus, and run new 2-7/8" tubing.
General Well info
MASP: 1780 psi
Reservoir pressure/TVD: 2363 psi / 5,838' TVD Mid pert
Wellhead type/pressure rating: Cameron KRU Gen 4 11" 3K btm x 7-1/16" 5K top flange
BOP configuration: Annular /Pipe Rams /Blind Rams /Mud Cross /Pipe Rams
IA / OA Status: TIFL passed 6/27/10, OA leak rate 1 bpm at 600 psi depth estimated at 360'
Well Type: Producer
Estimated Start Date: September 3, 2010
Production Engineer: Mike Balog /Evan Reilly
Workover Engineer: Howard Gober (263-4220 / howard.gober@conocophillips.com)
Pre-Rig Work
1. Bleed IA and OA to 0 psi.
2. Set BPV.
Proposed Procedure
1. MIRU Nordic 3.
2. Pull BPV. Load tubing with seawater down to the perforations. Load IA with seawater. Verify well is
dead by watching for flow from the tubing and IA for a minimum of 30 min. Best estimate of KWF
requirement is 8.2 ppg based on 300 psi surface pressure after loading the well with diesel on ~'
8/25/10. Set HP-BPV. ND tree: Install Cameron plug off tool in HP-BPV. NU 11" 5M BOP and
adapter spool. Pressure test BOP including annular to 250/3000 psi. Maximum potential surface
pressure is calculated to be 1,780 psi based upon the SBHP obtained on 8/25/10 and using a 0.1
psi/ft gas gradient.
3. Pull BPV and plug off-tool. Pull tubing out of PBR and circulate hole clean. Pull and lay down tubing.
A. If tubing does not pull free..set tubing in tension, RU slickline and set plug in 2.25" D nipple at
7,658' RKB. Set catcher sub on top of plug. RU E-line and cut tubing at +/- 7,604'. RKB. ~,
POOH laying down tubing. If slickline was unable to set a plug, RIH and set IBP or RBP just
above tubing cut. ;~. '1" `r~ • i s~ P14~ .
B. If tubing pulls free. RU slickline prior to pulling tubing out of the hole and set plug in 2.25" D
nipple at 7,658' RKB. Set catcher sub on top of plug.
4. Run 7" scraper on drillpipe to top of PBR. Circ hole clean. POOH.
5. RU E-Line: Run caliper log, gyro survey, and cement bond log in 7" casing from PBR to surface.
Based on cement top, determine depth of 7" collar to back off following casing cut. RIH and fire string
shot across that collar. RD E-Line.
6. Set RBP or IBP below top of cement. Pressure test to 2500 psi and drawdown test to 0 psi.
7. RIH w/ muleshoe on drillpipe and spot 50' of sand on top of RBP/IBP. POOH.
w ~
06 Expense Rig Workover
• (PTD #: 186-107)
Proposed Procedure Continued
8. ND BOP. Install long all-thread bolts on wellhead. Begin ND tubing head allowing 7" casing to grow.
9. Remove tubing head and packoffs. Spear 7" csg and pull in tension and re-land in slips. Tack weld
slips to casing. RU Wachs cutter and cut off casing so it does not interfere with BOP stack.
10. NU 11" 5M BOP on casing head. BOPE is now considered a diverter due to surface casing leak-
suspected to be at 360' RKB. A pressure test cannot be performed at this time.
11. RIH w/ multi-string cutter and cut 7" casing above TOC.
12. Spear casing and circulate out Arctic Pack in the 9 5/8" x 7" annulus using hot diesel followed by hot
seawater.
13. POOH laying down 7" casing.
14. Set test plug and test BOP to 250/3000 psi.
15. Run 9-5/8" casing scraper to top of 7" stub. Circulate clean.
16. RU E-Line: Run GR, caliper, and gyro in 9-5/8" casing. RD E-Line.'
17. Run back off tool and back off casing stub. ,
18. Run tandem string mills to gauge the 9 5/8" csg for the ES cementer.'
19. Make a dummy drift run for the 7" casing & ES cementer.
20. Spear and recover backed off 7" casing stub.
21. Change lower pipe rams to 7". Pressure test BOP to 250/3000 psi.
22. RIH with new 7" casing and Halliburton ES cementer. Screw into top of 7" casing. PT casing to 3000
psi.
23. Open ES cementer and pump cement into 9-5/8" x 7" annulus. Close the IA once cement returns at
surface and squeeze cement into SC leak. Continue to pump cement until plug closes cementer.
WOC.
24. ND BOP, pull 7" casing in tension and land in slips. Cut excess 7" casing and install packoff. NU '
new tubing head.
25. NU 11" 5M BOP, change out lower pipe rams to VBR's. PT rams and break to 250/3000 psi. -
26. Drill out cement and ES cementer down to top of sand. Pressure test casing to 2500 psi.
27. RIH w/ reverse circulating junk basket and string magnets to clean up wellbore.
28. RIH w/ retrieving tool on work string. Release RBP/IBP and POOH.
29. If IBP/RBP was run in step 3A, RIH and recover plug. -
30. RIH with seal assembly without seals, stack packer, PBR, and new 2-7/8" tubing. Circulate well full of
corrosion inhibited fluid. Stab into PBR, space out and land. Pressure test tubing and IA to 3000 psi.
Shear SOV.
31. Set 2-way check. ND BOP. NU tree and pressure test.
32. Pull 2-way check. Freeze protect well. Set BPV. -
33. RDMO Nordic 3. ,
Post Rig Work
1. RU Slickline: Pull ball and rod. Pull SOV and run new gas lift design. Pull RHC body. If necessary,
pull catcher sub and plug from D nipple.
Z. Return well to production.
KRU 2T-06 (PTD# 186-107) R~rt of TxIA Communication • Page 1 of 1
Regg, James B (DOA)
From: NSK Problem Well Supv [n1617@conocophillips.com] ; E~f 7( V~
Sen t: Sa tur day, June 2 0, 2 0 0 9 1 0: 0 7 A M /~~
To: Regg, James B(DOA); Maunder, Thomas E(DOA)
Cc: NSK Well Integrity Proj; NSK Problem Well Supv; CPF2 Prod Engrs; CPF2 DS Lead Techs
NSK
Subject: KRU 2T-06 (PTD# 186-107) Report of TxIA Communication
Follow Up Flag: Follow up
Flag Status: Orange
Attachments: 2T-06 Wellbore Schematic.pdf; 2T-06 TIO Plot.pdf
Jim/Tom,
Kuparuk gaslifted roducer 2T-06 (PTD# 186- 07) is suspected of TxIA communication based upon a failin
TIFL. ConocoPhillips in ends to shut in and freeze protect the well and submit a 10-403 to plug the perforations
with cement.
Attached is a weilbore schematic and 90 day TIO plot.
/
«2T-06 Wellbore Schematic.pdf» «2T-06 TIO Plot.pdf»
Please contact me at your convenience if you have questions or comments.
Martin
Martin Walters / Brent Rogers
Problem Wells Supervisor
ConocoPhillips Alaska Inc.
Office 907-659-7224
Cell 907-943-1720 / 1999
Pager 907-659-7000 #909
~ri ~~,~~r~ ~~..i ~ t ~ ~ ~ ~ ~,~~1~
~~, ~z ,,~t:'' . 2,~; ,,, , _
8/6/2009
~~ ~~lo~
(~i 1~ ig~--~u~
End Date
Days
1400
1200
1000
800
.~
Q.
600
400
200
0
7/112009
90
4/2/2009
Annular Communicaton Surveillance
Notes:
WHP
IAP
OAP
WHT
~~
Apr-09
soa
eoo
~oo
o soo
a
m 500
~ 600
U
~ 300
200
700
0
May-09
Jun-09
~DGI
~MGI
~PWI
~Sw~
~so
160
140
120
10~
~
d
~
80
60
40
20
0
•
•
Apr-09 May-09 Jun-09
Date
~ ~
k e KRU 2T-06
v C~an~c~Ph~I~~p~ ~Rt~r~ka, 1r~~.
2T-O6
API: 501032006800 Well T e: PROD An le TS: 35 de 7708
sss SSSV Type: TRDP Orig
Com letion: 8/22/1986 Angle @ TD: 31 deg @ 8214
v
~~~s~-~~s2, Annular Fluid: Last W/O: Rev Reason: GLV C/O
OD:2.875) Reference Lo : Ref Lo Date: Last U date: 6/25/2006
Last Ta : 7773 TD: 8214 ftK6
Last Ta Date: 3/4/2006 Max Hole An le: 51 de 3500
Casin Strin - CONDUCTO R
Gas Lift
Ma~dr~iNai~re ~
< Descri tion Size To Bottom ND Wt Grade Thread
~ CONDUCTOR 16.000 0 115 115 62.50 H-40
(3113-3114, C8SI11 Strin - SURFACE
Descri tion Size To Bottom NQ Wt Grade Thread
SUR. CASING 9.625 0 3448 2767 36.00 J-55
Gas Lift Casin Strin - PRODUCTION
~
MandrelNalve
2 ~
~
; ~At
~~ Descri tion Size To Bottom
~ TVD Wt Grade Thread
(52~0-52~~, . ~
. . PROD. CASING 7.000 0 8106 6088 26.00 J-55
Tubin Strin - TUBING
Size To Bottom ND Wt Grade Thread
Gas ~ift 2.875 0 7669 5721 6.50 J-55 ABM 8RD
andrel/Dummy
~ P6rf0[8t10I13 Su~I1Rla
vai~re 3
~s2n-s2~e r~ Interval ND Zone Status Ft SPF Date T e Comment
,
OD:4.750) 7770 - 7774 5803 - 5807 A-4 4 1 10/5/1986 IPERF 4" Schlum. H erJet
7778 - 7782 5810 - 5813 A-3 4 1 10/5/1986 IPERF 4" Schlum. H erJet
Gas Lift 7785 - 7814 5816 - 5840 A-3 29 4 10/5/1986 IPERF 90 deg. Ph; 4" Schlum.
MandrelNalve - FI erJet
a
~ss2~-ss2s, 7851 - 7854 5871 - 5874 A-2 3 4 10/5/1986 IPERF 90 deg. Ph; 4" Schlum.
H erJet
Gas Lift MandrelsNalves "
cas ~in
~
~ St MD ND Man
Mfr Man Type V Mfr V Type V OD Latch Port TRO Date
Run Viv
Cmnt
andrel/Dummy
Valve 5 1 3113 2551 CamCO KBMG GLV 1.0 BK 0.156 1306 5/7/1997
~ss~~~s~s, 2 5270 3993 Camco KBMG GLV 1.0 BK 0.188 1344 5/7/1997
OD:4.750) 3 6277 4692 Camco KBMG DMY 1.0 BK 0.000 0 10/15/198
4 6627 4942 Camco KBMG GLV 1.0 BK 0.188 1341 6/8/2006
Gas LiR 5 6977 5196 Camco KBMG DMY 1.0 BK 0.000 0 10/15/198
MandrellVa~ve 6 7325 5451 CamCO KBMG GLV 1.0 BK 0.250 1434 5/7/1997
6
(7325-7326 7 7581 5649 MMH 2.875x1 OV 1.5 RK 0.313 0 5/7/1997
,
Other lu
s e ui . etc. - JEWELRY
De th TVD T e Descri tion ID
G 1791 1661 SSSV Camco TRDP-IA-SSA 2.312
as Lift
Mandrel~valve ~ 7627 5687 PBR Brown 2.500
~ ~' 7643 5700 PKR Brown HB-1 ~ 2.441
(7581-7582, 7F)SH 5712 NIP Camco'D' Ni le NO GO 2.250
7668 5720 SOS Brown 2.441
7669 5721 TTL 2.441
PBR
(7627-7628,
OD:2.875)
P ~
KR
(7843-7644,
OD:6.151)
4~t
NIP
(7658-7659,
OD:2.875) I
TUB
ING
(0-7669,
OD:2.875,
, ,. ~ ~-
ID:2.449)
Pert ----
(7770-7774)
Pert
(7778-7782)
Perf -..---
(7785-7814) --
_._...._..
Pert ----
(7851-7854) __.._ -
-
.-
-
__ -
-
- ---
-
-
---.......
---
__
MICROFILMED
9/11/O0
DO'NOT PLACE
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations Performed: Operation Shutdown Stimulate X Plugging
Pull tubing Alter casing Repair well
Perforate
Other
2. Name of Operator
ARCO Alaska, Inc.
3. Address
P. O. Box 100360, Anchorage, AK
99510
5. Type of Well:
Development X
Exploratory _
Stratigraphic _
Service
--
4. Location of well at surface
302' FSL, 556' FWL, SEC 1, T11N, R8E, UM
At top of productive interval
1397' FNL, 1392' FEL, SEC 1, T11N,
At effective depth
1351' FNL, 1428' FEL, SEC 1, T11N,
At total depth
1281' FNL, 1350' FEL, SEC 1, T11N,
RSE, UM
R8E, UM
RSE, UM
6. Datum elevation (DF or KB)
RKB 117 feet
7. Unit or Property name
Kuparuk River Unit
8. Well number
2T-06
9. Permit number/approval number
86-107
10. APl number
50-103-20068-00
11. Field/Pool
Kuparuk River Field/Oil Pool
12.
Present well condition summary
Total Depth: measured
true vertical
8208 feet
61 82 feet
Effective depth: measured 8 0 2 4 feet
true vertical 6 0 3 1 feet
Plugs (measured) None
Junk (measured) None
ORIGINAL
Casing Length Si{,e
Structural
Conductor 8 0' 1 6"
Surface 3416' 9 5/8"
Intermediate
Production 81 06' 7"
Liner
Perforation depth: measured
7770'-7774',
true vertical
5802'-5806',
Cemented
Measured depth True vertical depth
235 Sx CS II 115'
810 Sx AS III & 3448'
360 Sx Class G w/125 Sx AS I top job
400 Sx Class G 8106'
7778'-7782',
5809'-5812',
115'
2788'
6098'
7785'-7814', 7851'-7854'
5815'-5839', 5872'-5873'
Tubing (size, grade, and measured depth)
2.875", 6.5#/ft., J-55 @ 7669'
Packers and SSSV (type and measured depth)
Packer: Brown HB-1 @ 7643'; SSSV: Camco TRDP-1A-SSA @ 1791'
13. Stimulation or cement squeeze summary ~_.I!.]!"! 2.0 1997
Fracture stimulate 'A' sands on 4/30/97.
Intervals treated (measured)
7770'-7774', 7778'-7782', 7785'-7814', 7851'-7854' ~ ~'_A~8~f~..'a~' ' ~ '
Treatment description including volumes used and final pressure
Pumped 202.8 Mlbs of 20/40 and 12/18 ceramic proppant into formation, final pressure = 5405 psi.
14. Representative Daily Average Production or Injection Data
OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure
Prior to well operation 9 4 2 643 105 1075 289
Subsequent to operation
1 1 86 748 1 32 1 082 3 1 0
15. Attachments
Copies of Logs and Surveys run
Daily Report of Well Operations
16. Status of well classification as:
Oil X Gas Suspended Service
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Signed(,~_~~~~.,~j Title Wells Superintendent
Form 1 ~/4~04 ~R~v/6~¢~'1 ~;/~
Date
SUBMIT IN DUPLICATE
ARC6) Alaska, Inc. KUPARUK RIVER UNIT
'~ WELL SERVICE REPORT
'~ K1(2T-06(W4-6))
WELL JOB SCOPE JOB NUMBER
2T-06 FRAC, FRAC SUPPORT 0419971948.8
DATE DAILY WORK UNIT NUMBER
04/30/97 PUMP "A" SANDS RE-FRAC
DAY OPERATION COMPLETE ~ SUCCESSFUL KEY PERSON SUPERVISOR
5 (~D Yes O NoI (~ Yes O No DS-GALLEGOS JOHNS
ESTIMATE KD1785 230DS28TL $1 30,950 $153,042
Initial Tb.cl Press Final Tb.cl Press Initial Inner Ann Final Inner Ann J Initial Outer An~ I Final Outer Ann
86 PSI 1491 PSi 1000 PSI 500 PSII 100 PSII 100 PSI
DALLY SUMMARY
'1 PUMPED A SAND REFRAC - TOTAL 2028144f PROP IN PERF'S - 545# PROP IN PIPE. 13.8# PPA OF 12/18 PROP @ PERF'S. I
TIME LOG ENTRY
07:00 MIRU DOWELL FRAC EQUIP., APC SUPPORT AND LITTLE RED PUMP.
09:00 HELD JOB SITE SAFETY MEETING
09:40 INITIAL WHP 86 PSI, PRESSURE TEST TREATING LINE TO 10340 PS1.09:45
09:45 PUMP BREAKDOWN STAGE AT 30 TO 15 BPM AND 9200 PSI TO 3506 PSI.
09:49 PUMP 1PPA 20/40 PROP STAGE 15 BPM AND 3400 PSI. 2000# PROP.
09:53 PUMP FLUSH WITH 10 BBLS XL-GEL AND 80 BBLS STRAIGHT SEAWATER, 15 BPM AND 3451 PSI.SHUT DOWN FOR
ISIP 910 PSI. PUMP 2 PULSE PUMP-IN'S.
10:25 PUMP DATA FRAC & FLUSH W/160 BBLS FLUIDS 5 TO 15 BPM. SHUT DOWN FOR ISIP AND CLOSURE
CALCULATIONS.
11:26 PUMP PAD - 55 BBLS - 5 BBL/MIN - 1450 PSIG
11:36 PUMP ADDITIONAL PAD - 495 BBL - 15 BBL/MIN 4421PSIG
12:09 PUMP 20/40 SAND @ 2PPA - 100 BBL- 4295 PSI 15 BBL/MIN
12:16 PUMP 12/18 SAND @ 6 PPA- 10 PPA-5200 PSI MAX 15 BBL/MIN
13:15 PUMP 12/18 SAND @ 11-13.8 PPA-5405 PSI MAX 15-13.5 BBL/MIN
13:19 FLUSH W/DELAY XL GELLED WATER 46 BBL 13.4 BPM @ 4348 PSIG
13:23 FLUSH W/SLICK DIESEL 10 BBL 2777 PSIG, SHUT DOWN
15:00 RDMO DS
SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL
$0.00 $1,052.00
APC $4,500.00 $8,375.00
ARCO $350.00 $350.00
DIESEL $0.00 $200.00
DOWELL $124,350.00 $129.,859.00
HALLIBURTON $0.00 $6,946.00
LIq-FLE RED $1,750.00 $6,260.00
TOTAL FIELD ESTIMATE $130,950.00 $153,042.00
STATE OF ALASKA
ALASKA oIL AND GAS CONSERVATION CL~MMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1. Status of Well Classification of Service Well
OIL~ GAS [] SUSPENDED [] ABANDONED [] SERVICE []
2. Name of Operator 7. Permit Number
ARCO Alaska, Inc. 86-107
-~. Address 8. APl Number
P. 0. Box 100360, Anchorage, AK 99510 50- 103-20068
4. Location of well at surface 9. Unit or Lease Name
302' FSL, 556' FWL, Sec. 1, T11N, R8E, UM Kuparuk River Unit
At Top Producing Interval 10. Well Number
1454' FNL, 1521' FEL, Sec. 1, T11N, R8E, UM 2T~6
At Total Depth 11. Field and Pool
1304' FNL, 1300' FEL, Sec. 1, T11N, R8E, UN Kuparuk River Field
5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool
RKB 117' ADL 25569 ALK 2667
i2. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions
08/14/86 08/20/86 1 2/20/86* N/A feet MSL 1
17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost
8208'MD 6174'TVD 8024'MD 6017'TVD YES~] NO[-]I 1791' feetMD 1550' (Approx)
22. Type Electric or Other Logs Run
D I L/GR/SP/SFL, FDC/CNL,CAL,CBL,Gyro
23. CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD
CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED
16" 62.5~ H-40 Surf 115' 24" 235 sx CS II
9-5/8" 36.0~ J-55 Surf 3448' 12-1/4" 810 sx AS Ill & 360 sx Class G
Performed top job w/12~ ~x.A$ I
7" 26.0~ J-55 Surf 8106' 8-1/2" 400 sx Class G & 175 sx ~S I
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)
2-7/8" 7669 ' 764~ '
7770'-7774'MD 5802'-5806'TVD w/1 spf, 90° phasin~ 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC.
7778'-7782'MD 5809'-5812'TVD w/1 spf, 90° phasin~ DEPTH INTERVAL(MD) AMOUNT& KIND OF MATERIAL USED
7785'-7814'MD 5815'-5839'TVD w/4 spf, 90~ phasin~ See attached Adderdum, dated 1/13/87.
7851'-7854'MD 5870'-5873'TVD w/4 spf, 90~ phasin~ for fracture data
27. N/A PRODUCTION TEST
Date First Production ~ Method of Operation (Flowing, gas lift, etc.)
DateofTest Ho~rSTested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO
TEST PERIOD ~
Ftow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr)
Press. 24-HOUR RATE ~
28. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.
~Note: Dril]ed RR 8/22/86. We]] perforated & tuhlnq r~n lfl/1A/RR
Form 10-407 WC2:01 :DAN I Submit in duplicate
Rev. 7-1-80 CONTINUED ON REVERSE SIDE
GEOLOGIC MARKERS - , : ' '¢:ORMATIONTESTS :
·
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 7707~ 5751~ N/A
(Truncated)
Base Kuparuk C 7707~ 5751~
Top Kuparuk A 775:3~ 5788~
Base Kuparuk A 7919~ 5928~
31. LIST OF ATTACHMENTS
Addendum (dated 1/1:3/87)
32. I hereby certify that the foregoing is true and correct to the best of my knowledge
//
INSTRUCTIONS
General: This form is designed for submitting a complete and correct well completion report and Icg on
all types of lands and leases in Alaska.
Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt
water disposal, water supply for injection, observation, injection for in-situ combustion.
Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements
given in other spaces on this form and in any attachments.
Item 16 and 24: If this well is completed for separate production from more than one interval (multiple
completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported
in item 27. Submit a separate form for each additional interval to be separately produced, showing the
data pertinent to such interval.
Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.).
Item 23' Attached supplemental records for this well should show the details of any multiple stage cement-
ing and the location of the cementing tool.
.- .
Item 27: Meth'°d of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In-
jection, Gas Injection, Shut-in, Other-explain.
Item 28' if no cores taken, indicate "none"
:~.
Form 10-407
ADDENDUM
WELL:
8/31/86
12/20/86
2T-6
Arctic Pak w/175 sx AS I, followed by 60 bbls Arctic Pak.
Tst to 1000 psi, bled to 880 psi/1 hr. Left 200 psi on
ann.
Frac'd Kuparuk "A" sand perfs 7770'-7774', 7785'-7814' &
7851'-7854' in 8 stages per 12/17/86 revised procedure
using diesel, Musol, gelled diesel, 100 mesh sand & 20/40
mesh sand. Press'd ann to 2300 psi w/diesel. Tst Ins to
8000 psi; OK.
Stage 1: 30 bbls diesel w/5% Musol, 1.75 BPM, 3000 psi
Stage 2: 46 bbls diesel, 1.75 BPM, 2650 psi
Stage 3: Pmp'd 75 bbls gelled diesel, 20 BPM, 6900 max
press w/avg press of 4880 psi
Stage 4: 20 bbls gelled diesel w/l ppg, 100 mesh sand,
20 BPM, 4650 psi
Stage 5: 70 bbls gelled diesel spacer, 21.4 BPM, 4310
psi
Stage 6: 25 bbls gelled diesel w/3 ppg 20/40 mesh sand,
21BPM, 4280 psi
Stage 7: 44 bbls gelled diesel w/8 ppg 20/40 mesh sand,
20 BPM, 6300 psi
Stage 8: 45 bbls gelled diesel flush, 15 BPM, 6700 psi
to 6480 psi, 19 BPM final.
Pmp'd 12,690# 20/40 mesh sand in formation leaving 1310#
20/40 mesh sand in csg.
Load to recover 340 bbls of diesel/gelled diesel. Jo__~b
complete @ 1858 hrs, 12/20/86.
CO FIDE 'I'IAIL
RECEIVED
JAN 2 ]987
Alaska Oil & Gas Cons. Commission
Anchorage
Date
Form to be inserted in each "Active" well folder to check
for timely compliance with our regulations.
Reports and Materials to be received by.. /-/~T~
'Date
Required Date Received~ Remarks
Compleiion Report
Well Hzstory /
, ,
Samples
Hud Log
Core Ch~ps
Core Description
Registered Survey Plat ~~ ,:
Inclination Survey .
Directional Survey
--
Production Test Reports t'~'~ /J~ lk~['~' 'lk ~' 'r ~1 .," t..;
Digitized Data
Ye ,::: ... 7- ::'-? "~:::.~' i, {,-'.
October 22, 1986
Mr. Randy Ruedrich
ARCO Alaska, Inc.
P.O. Box 360
Anchorage, Alaska
99510
Re: Our Boss Gyroscopic Survey
Job No. AK-BO-60073
Well: 2T-6
Field: Kuparuk, Alaska
Operator: E. Sellers
Survey Date: October 13, 1986
Mr. Ruedrich:
Please find enclosed the "Original" and one (1) copy of our
Boss Gyroscopic Survey on the above well.
Please note that a magnetic tape of the survey will be sent
to Standard AK Prod. Co., Exxon, and Arco as per request of
Jo Ann Gruber.
Thank you for giving us this opportunity to be of service.
Sincerely,
NL SPERRY-SUN, INC.
Ken Broussard
District Manager
Enclosures
NL Sperry-Sun/NL Industries, Inc.
RO. Box 190207, Anchorage, Alaska 99519-0207, Tel. (907) 522-1737
I
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:L /-, :-4 :'-': . 78 E 975..54 48.79
1. 707.44 E 1. 02::.--_.:, 5::3 4,"_-.. 84
.1. '77:i:. :.5'.-;' E l 067:3:':: 4,-1. ":~
· · · 7- .,_l
1 :i: 4,/_-,. 89 E 1110. 71 4:3. :.5:8
..................................................................................................................................................................................
191:3.55 E 115:3.2A 42.49
AR C 0 A L. A :E:l< A ~ I hl C.
2]'-6
KUPARUK
AI_A:31<A
M E A S I_.1R E Ii"
I]E P l" H
:.'.:.'; P E R R Y-- S IJ N WI:ii [,.. L :~i; ... r~ v ~: Y I N G 17:1-1 FI F:'A N Y I::'A [; E 7
DATE OF :~URVEY I-uT:TOBER 13, 1~*-"
COMPIJTATION OATE
...................................... Z,Y;2_Z_'; ........................ 'Z l'2 .......................... ' '
. . UL. IUBER 14, 1~o6 _ _ ,JOB NUMBER AKr-~O-600~:~ ............. ..:~..,~ .........................
TRUE ~. o . ......................................' ........
..... ~,UB-.;,EA 'tOTAL .
VERT I CAI .... VERT I CAL.. RE('::T'ANGLIL. AR COORD I NATES MO-.TVD VERI" I CAL
...................................
.......
DEF::'T'H DEF"T'H NORTH / SOLI'T'H EAST/WEST 01 F:'F:ERE:NCE~: CORREC:T I ON
...............................................
..........
5 0.1. 5 :381 7. C)
5 / 61 :B'.:;' 1 '7.
!5 :.:.: (') 4 40 i '7 ,, C)0
5 4 49 41 ! '7. C) 0
":1.":; 9 :':', 4 '2' .1. '7. ()0
':'"' '" "" "' Zl-3
...,/..:, 7 1 7. ()C)
5:387: 44.17.00
/:.C)2::: 4517. C)0
61 '7:2 ;~ .61 '7.0 0
/r'.' :.31 :':: 4' 7 1
(54' 5 4 4 :E" 1 7. 0 0
./:'5'ii) 2 4'':"> 1 7. C)0
6, 7:31 5 01 '7.0 0
6 8 6 L--:: ..51 1 7.0 0
7 (') (') 7 =;'":' 1 '7
. . -_ .,%. ~
714 4 5:31 7.0 ()
'7:2:','.:.: C.)541. 7. C)('-)
74.1 :.-.-.", 551 7., 0('.)
7._4_'l :[7 ..
:7: ::: 0 o 0 0 ":' .1. 9'::. 7:2! N
........ n ~.. ·
::: ..... 9 (") c) . o. ('). :227:3 . .,.."" ,::,"" N
4 0 () 0 ,, 0 0 '2:'-;:5 2.9:3 N
41 C)('). C) 0 24-32:. 46 Iq
..... ::-; J= ;::,, ;.-; ' ...:, '.4
4 -~-': (:) (') . IC) C.) .,;~...I ; ..:,..".:, N
4 4 (30. 0 0 2 6 72.99 N
. Ii - . ,-i' ,~'"'~
4500 (')(') ,. 7._ .1. 6/: N
'7. C) C) 46 () C). ()0 N
4. '70 C). 0 (.') 2 9 03.85 ~.1
477,0 0.00 :3 0 50. 2 0 N
5C)C)0.00 :5:1. 22.63 N
.... 10 0.0 ('-) .:, 1 ':~.=,. :37 N
.
5:2; C: 0.0 0 :3 26, 7. :..:.:(3 N
%"::,, (3 r') (_') (') ":' ':' "-'"-' /-, 3 N
· ~.._ _ .~ · .. .._~ ._, .Z~ (], . _ .
~-~ 4' ("") ("') ' ("')(:) .i~!4.(;)_1~'? ". :-'"~'":4 .N.
.~ ~C)(') ' i:.)0 3 4 6:3.7 7 N
. ~ 0
12:44 06 4 .....
1 :.?.::;ii:2.4 :;3 44.5:3
'i? 4 E 1 :;!! 7/:,. 6,5 44.22
66 E 14. 2(). 5.1. 4. :3. ::',6
.._,; E 1465.9'F~ 45 48
:::c: E 1 ='11 47 45 48
1.,.,o.~)1 4.: .... ,4
........ -'Z .T ......... .' ...................................... z ..............................................................................
1. 5'? 6.8 4 41.. ',q :B
1/'.,:37 .1./-, 4 0 ":'"':'
... ~ .. # .._l .~:..
'2521.:32 E
";i: .... : ..... ':.!:4-[ii:
26,fl- !;). !5 :B E
. J ?'-,7 ..... /-, .-,,-',. ,-,()
2712 J. '2 E "~': "" ""'-' """
:27'72.94 E 1714.0:3 :.38.07
2:3:7..: 4.44 Ii:' 17."51.98 37.95
-7 ::,::~,i.. :---: 5 E 17 l~ (]) . 49 38 51
295'7, 16 E 1182:'7.6,4 :37. 16
:.3 C) 14. ::::5: E 1 -36.,:':. :.3 ~::, 35.72
:.7.::]-: :3 7
::c) 7 o. :::(3 E ] ::: 9/-,. 7:7: .
:3126. ':::9 E 19:24.5 7: 27.80
ARCO ALA_K.A INC
21'--6 COMPUTAT I ON DATE
I<L~F'ARLIK ........................................................................................................................................................................... FiC]'7.~.uBER~i..-'. .............. 14, 1 '-:.,c,/:,
ALASI<A
M E A '..:_'; I..I R EL]
I]EF:'TH
::':i;F:' [.'.:.'i F:;~ F;~ ¥-' Fi; LIN W E I.... L.. S I_IR V E Y I N G C O1't PAI',I Y
DATE OF SURVEY OCTOBER
13, 1986
,JOB NLIMBER AK-'BO-600:,~.~.~S,?i!:i?:~.i,~::.: .......... K E L. L. Y B I_l'....];I.--i I N A E I_ El V. = 11 '7.00 F T.
O F' E R A ]Il ~]iR--- E. S E I... L E R~--;
TR LIE SUB- SEA TCI"I"AL_
VE-i:F:~'i"~"i3AI .... -7,/ERT I C--';-~-].'] ......... i~iEii~!"]"'Fi, Ni~i'i]L.';L'~'F;; i~.!0'0RD'I N~'TE'.~; ........MI)-TV[~ VER'I'I CAI ....
[) E F:' T I.-'1 D E P ]" I--I N I.'.;i R 'T' H / '.-":i; 0 [.I T H E A S'T'/1,4 E '.!i!; "1" ]]I F' F E R E N C E C 0 R I::;: E C T I O N
7/:. 6 !5 5 '71 '7.00
7'787 5817.00
7'.:) C) 6 ='".? . _
· ~,:. 1'7 (')0
8023 ./::. 017 ,. 0 ()
8 :l 4 C.) 6 :[ 1 '7. C) 0
:!ii:2 0 ::-'it .4 174.. 4. :2:
'.'::24(') 41 E 197C). 57 ":' 1. '- '"'
........ .~
::-:'".:":~":: 11 E 1c>':'':'~ ""
.............. ,. ..... :, 7 18.8 C)
.... 4 :--i i, 'i!:::?'; ' -E ........ .......... '?'i:';iS-'/::'FPT-4 .................................................. 17 Y-:L7 ..........................................................
:3:}.':? 4 ,, 6 C) lie :2'C) 2:3.71 1 7. 1 '7
::ii'. 4. 2:3.74 E 20 :L:::3.5'7 9.86
THE F':ALCLiI_ATION PROCEDLIRES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FL-U]T MI] (FROM RADILI'..::; OF Ci...IRVATLIF~E) F'OINTS
E!;F:'EF:~F?Y--E;L.IN WEI.,..I.,. E;URVEY'I NG COIdF:'ANY F'AGE '.::"/
A 1'4 C I-~10 R A G E A I_ A E;I< A
. "' ...... ' ,-',, 1986
ARCri ALASKA-, INC DATE OF' .:,LIRVEY OCTUBER 1'"
2T-6 COMF'UTATION DATE
!<UF'A~UK ................................... ,'. ..... OCTOBER 14, 1'-'"' ............
Y,=,6 ,..lOB NUMBER Ak.-B.O-600~,.~,.~;:.?~,,:~::.=.~.::~.'. .......
ALA'.~;KA ...... KELLY
0 P Ei: R A T 0 R-- E. '..--.;E I_ L E R S
MEASUREi:D VEER T' I CAI.._ VERT ~ CAL RE.'CTANEd..II...AR COORD I NAT'ES
iE~EP]"H ]FIE:'F'T'H ......... ' ' DE:P'i:H I',IC~R]"H/'.::;FH ITH EAST/WEi'.!ii;'I" I IARF..E.R~" '"" ..... ' .............................
7707
'7707
7753
'7':..'/ 0 0
7 !;) :1 ?
8024
8208
· J6.:,.~,. 7(~ .-,. ,.,..-,, ,-,7 N .-,,.-(L~-. 96 E '/RUNC TOF' I<I_IF'ARIJK C
:32()2.96, E
:3224 -'~
.7._ E
::ii: 2'il) (). :35 E
· ':":"::~ 8 '=',,'-"" E
· ..., ,,~_ .. . ....
::3:34 4 ,, () 5 E
:342:3. '74 E
BASE: KUF'ARL;K C:
TOP KLIPARLIK A
:_:;L. II:~VE Y [)E;f:'TH
B A'.E; E I< U F'A R U i.::: A
I:::' L.. I...I ('~i B A I.','::l,::: "1" [I
TO'FALl DEF"I'H DRIL_L. ER
2T-6
:iii;TRATI GRAF'H I C SLIMMARY
DERIVED I "" I"' """ '-' ' ] .=,LRVEY DATA
J,..:, I NG D I L E EF I H.:, (:,NE '._-';PERRY '.-';UN '-' I'"' ,.,,. ~
........
............................
...... C:00'~'~i'~"N ~ TE'.i~:
.......................... MAI:;:KEF;: ........................... ' 'MERSI. JF-iEt] !.)E;F"I"H ............................TVF. J .......................... THIC:KNE"SS WI TH REF, TO
~:=..4. ~= ~. "",-" ' .... E:' .:"-::C:~'i ..... '",":'"",'"'*
_, / ._., (). / i) -., C', :,..:,. 7 0 . .
. :,._,..-:...:, :z:'7N :~ 2 0 2. '.:.~ ('.-., E
T'RI...INC T()P I<IJPAI:;,'I...IK C 7707
BAEi;IE I<LIF:'AFict...II< (7: 7707
TOF' i'::]JI'::'ARIJI'::: A
BASE KLIF'ARI...IK A 7919
F:'L UO BA C K T L] 8 0:2 4
T 0 'I"A L D E F:'-I" H D R I I.... I_. E' R 8:2 0 8
5'75 (). 70 5/: :3:3. '7 ()
5 '7 :i.:.': 8.2:3 56 '71.28
5927.7:_:: SE: 10. 78
6017. :3'i.:) 5900, 39
/:, 174.4:3 6 (},57.43
.
.:: 523. E:'7 Iq :F.: 2 ()2. '.-.:' 6 I.:.'iZ
.......
""'~.-"'"'"" ?.;'.!i:h ' :i~2::.':'4 ........
..:, ._~ ..:, ,: .... 7-:: I:::.
............................................................. · .:.::"]'~';":-:-'.J ~ 0 ..... :E;:g".~ N ........ ._",':"]:¥';~'~'"~¥~" ................... ib c, E..':
:3620. '77N :3:7::44.05E:
· -'/' . 2N '"' '-"-'
.:, .:, 74 1 .:, 4..,:: .:,. 74 E
1.) F:ROM LINE:AR I.:.':_'XTRAF'OI....ATi'ON BEI_CIW IZ)E:EF'EE;'I- ff.;TA'I"ICIN.
2) COMF'LITER F'ROGRAM - :-':-;F'E;RRY Fa_IN THREE. DIMEN:-~IONAL" RADILI:--; 'i']F 'Ci]i~VAi:'LIRE':
_ _ . I E F'l¢ '"- CIN I OF I-:LIRVATLIRE
DATA F:AL.C:LILAT I tIN AND I N - R ],..m| I BY RAIl I_1.'_-'; _
F:O M F'L T'A T I 0 N D A'I'E
oc!TC~BER 14',- ~1
]]ATE OF E;LIF~VE:Y (]C'T'OBE:R 1.3, .1'.:.)E:6
,_lOB Iq El ~'IB ~'F~-"P~'~'~- B ri- 6 c} 07 :---: ....................
KELLY BUSHING ELEV, = 117.(}0 FT,
9ab '
'2'~ '
'b~8bTb
O'O00~
¼PbbdF~
/ O0 000i @L KONZ I -~ ~q~DS
O0.:OQO t-
.
SCALE
Kj~q~JK
qK-~-CCCCS
8 [50O, O0 /
~500.0
qflCO aLaSKa, !NC.
OCTOBEq 13.
8000'00'
6174.
/
. ..
".. ..... .... '::'.'..'- :. :.:,..-/,,, ,, ".~.; _/~:~::,,,?, ·
%.
~,, ,":... ',:.%:;.../,.,;:. :.:~ :. :'
',. ~.
\
\
~8208
DEPT. OF NATURAL RESOURCES
DIVISION OF OIL AND GAS
April 12, 1991
D. W. Johnston, AOGCC
Commissioner
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, AK 99501-3192
Subject: Release of ARCO Kuparuk River Unit 2T Well Data
WALTER J. HICKEL, GOVERNOR
PO. BOX 107034
ANCHORAGE, ALASKA 99510-7034
PHONE: (907) 762-2553
..
',
.
' -Cit'.';~'t'-'.
::.:i':--.;,,',:,.3T '
!'. 71 r -(_~_
-- ... '--~7~b',- __' '
i- :: .'_) L ~,>O,
._ _- % ~
.... .
" . ".'..-~; ' ~l
.... '
I..~, - -. -'
i~;.,~ ..-.
Dear Commissioner Johnston:
On August 5, 1988 1 granted extended confidentiality for the Kuparuk River Unit 2T wells.
The Kuparuk River Unit 2T-2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 12A, 13, 14, 15, 16, and
17 wells were granted extended confidentiality until 90 days after the unleased land in
TI 1N R7E Umiat Meridian could be offered for lease.
The unleased land in this township was offered for lease in Sale 70A which was held on
January 29, 1990. Therefore, the wells no longer qualify for extended confidentiality and
the well data should be released on April 30, 1991.
By copy of this letter I am notifying ARCO Alaska Inc. of the upcoming release of the
above listed wells.
Sincerely,
/J~.mes E. Eason
'Director
cc: J. L. Dees, ARCO Alaska Inc.
RECEIVED
APR 1 6 199t
Alaska 0ii & Gas Cons. Commission
i~nchomga
fr ,
/STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMI~ION
REPORT OF SUNDRY WELL OPERATIONS
1. Type of Operation:
Operation Shutdown
Pull tubing Alter casing
Stimulate X Plugging ~ Perforate m
Repair well Other
2. Name of Operator
AROO Alaska, Inc.
3. Address
P. O. Box 100360, Anchorage, AK 99510
5. Type of Well:
Development X
Exploratory _
Stratigraphic _
Service
4. Location of well at surface
302' FSL, 556' FWL, Sec. 1, T11N, R8E, UM
At top of productive interval
6. Datum elevation (DF or KB)
RKB 117
7. Unit or Property name
Kuparuk River Unit
8. Well number
2T-06
9. Permit number/approval number
1454' FNL, 1521' FEL, Sec. 1, T11N, R8E, UM
At effective depth
1357' FNL, 1380' FEL, Se¢.1, T11N, R8E, UM
At total depth
1304' FNL, 1300' FEL, Sec. 1, T11N, R8E, UM
112. Present well condition summary
Total Depth: measured
true vertical
8 2 0 8' feet
Plugs (measured)
feet
61 8 2' feet
86-107 / verbal
lO. APl number
50-103-20068
11. Field/Pool Kuparuk River Field/
Kuparuk River Oil Pool
Cement: 8024'-8208'
Effective depth: measured
true vertical
8024' feet Junk (measured)
6 031 ' feet Norle
Casing
Structural
Conductor
Surface
Intermediate
Production
Liner
Perforation depth:
Length Size
80'
3146'
1 6"
9 5/8"
8106' 7"
measured
7770'-7774', 7778'-7782'
7785'-7814', 7851 '-7854'
true vertical
5802'-5806', 5809'-5812',
Tubing (size, grade, and measured depth
2 7/8" J-55 set at 7669'
Packers and SSSV (type and measured depth)
HB-1 @ 7643', Camco TRDP-1A-SSA @ 1791'
Cemented
Measured depth True vertical depth
235 Sx CS II 1 15' 1 15'
810 Sx AS III & 3448' 2766'
360 Sx Class G
400 Sx Class G & 81 0 6' 6 0 8 7'
175 Sx AS I
1 SPF 90 degree phasing
4 SPF 90 degree phasing
5815'-5839', 5870'-5873' TVD
13. Stimulation or cement squeeze summary
Refracture A Sand with gelled diesel frac.
Intervals treated (measured)
7770'-7774', 7778'-7782', 7785'-7814', 7851 '-7854'
Treatment description including volumes used and final pressure
976 bbls gelled diesel, 81,234 lbs 20/40 Carbolite, final pressure 3668 psi.
14. Representative Daily Average Production or Iniection Data
OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure
' "'e'~o4
Tubing Pressure
Prior to well operation
1000 1450 1 975
206
Subsequent to operation
1972 2393 0 1050
292
15. Attachments
Copies of Logs and Surveys run
Daily Report of Well Operations
16.
Status of well classification as:
Water Injector
Oil X Gas Suspended
Service
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Signed 0~ x~- ~ Tit,e Senior Operations Encjineer
Form 10-404 Rev 09/12/90
Date I" ~'' ¢1 I
SUBMIT IN DUPLICATE
ARCO Alaska, In
Subsidiary of Atlantic Richfield Compar,~
WELL
IPBDT
IOPERATIONAT REPORT TIME
FIELD - DISTRICT- STATE
WELL SERVICE REPORT
DAYS i DATE
CONTRACTOR
,'~EMARKS
/0 '. /2o ,.
[-'] CHECK ThiS BLOCK IF SUMMARY CONTINUED ON BACK
Weather Temp. I Chill Factor I Visibility
Report °F °F miles
Wind Vel.
I
Signed //~ z~ ~7'J
knots .~. ~' ."~/~
ARCO Alaska, Inc.
Date: August 12, 1988
Transmittal #: 7257
RETURN TO:
ARCO Alaska, Inc.
Attn: Brenda K. Miernyk
Kuparuk Records Clerk
ATO-1119
P.O. Box 100360
Anchorage, AK 99510-0360
Transmitted herewith are the following items. Please acknowledge receipt and return
one signed copy of this transmittal.
31 - 1 2 Kuparuk Well Pressure Report 6 - 1 5 - 8 8 Amerada
1 G-04 Kuparuk Well Pressure Report 7- 1 6 - 8 8 Amerada
2 T- 0 6 Post Frac Job Report 7- 1 8 - 8 8 AIIo Frac A-10
3Q-15 Kuparuk Stimulation Summary 8-07-88 #230DS36QL
3J-10 kuparuk Stimulaiton Summary 8-08-88 #230DS36JL
2V-1 1 Kuparuk Stimulation Summary 8-03-88 #230DS28VL
1 R- 1 5 Kuparuk Fluid Level Report 8 - 0 9 - 8 8 Tubing
I F- 0 7 Kuparuk Fluid Level Report 8 - 0 9 - 8 8 .Casing
2 D- 1 3 Kuparuk Fluid Level Report 8 - 0 9 - 8 8 Casing
Receipt Acknowledged:
DISTRIBUTION:
D&M State of Alaska SAPC Chevron Unocal Mobil
DEPART~iENT OF NATUI~AL I'~ESOURCES
August 5, 1988
Jon Wood, Area Landman
ARCO Alaska, Inc.
P.O. Box 100360
Anchorage, AK 99510-0360
Dear Mr. Wood:
In your July 8 letter and in our August 3 meeting, you requested extended
confidentiality for the data from the Kuparuk River Unit "drillsite 2T"
wells. You indicated that reports and information from these wells contain
significant information relating to the valuation of unleased land in
Township ll North, Range 7 East, U.M. This unleased land is currently
scheduled to be offered for lease in Sale 70A in September 1989.
Following your written request, the August 3 meeting and further review of the
well data by my staff, I agree to extend the confidentiality of the data from
the ARCO Kuparuk River Unit 2T-2, 3, 4, 5, 6, 7, 8, 9, 10, ll, 12, 12A, 13,
14, 15, 16 and 17 wells. The data from these wells will be released after the
aforementioned land is offered for lease.
In your letter and supporting data, you requested confidentiality for data
from a "2T-16A" well. The Alaska Oil and Gas Conservation Commission (AOGCC)
has advised the division that they have no record of a "2T-16A" well. The
2T-16 well was side-tracked but no new number was assigned to the well.
Therefore, all of the data from the well are filed under 2T-16 at AOGCC.
The first 2T well scheduled to be released is the 2T-12 Well (August 6, 1988)
and the last 2T well release date is the 2T-8 Well (January 15, 1989). The
division is making a special exception to our policy of considering extended
confidentiality no sooner than 90 days prior to a release date because it is
prudent to, in this case, grant the extension of confidentiality for the 2T
wells as a group.
By copy of this letter I am requesting that AOGCC keep confidential the data
from all of the Kuparuk River Unit 2T wells until further notice.
Sincerely,
ames E Eason
i recto~ .
cc' C.V. Chatterton, Commissioner, AOGCC
Judith H. Brady, Commissioner, DNR
ARCO Alaska, Inc.
Post Office Br.,. ,00360
Anchorage. Alaska 99510-0360
Telephone 907 276 1215
REI~JP~N TO:
ARCO ALASKA, INC.
ATTN: Kuparuk Records Clerk
ATO 1119
P. O. Box 100360
7unchorage A/< 99510-0360
DATE December 23, 1986
TRANSMITTAL # 5861
Trans~gtted herewith are the following items. Please acknowledge receipt and
return one signed copy of this transmittal.
Open Hole Final Logs (1 bluetine unless specified otherwise)
2T~6 ~ 5" DIL 8-21-86 1000-8206
~ 5" FDC Raw 8-2]-86 7390-8181
'Cyberlook 8-2i-86 7390-8181
~"2" FDC Porosity 8-21-86 7390-8181
~-5" FDC Porosity 8-21-86 7390-8181
~k" DIL 8-21-86 1000-8206
%2" ~DC Porosity 8-26-86 6449-6934
%5" FDC Porosity 8-26-86 64&9-6934
-Cyberlook 8-26-86 6449-6934
"-2" FDC Raw 8-26-86 64~9-6958
~2" DIL 8-26-86 6449-6958
%5" DIL 8-26-86 6449-6958
~'5" FDC Raw 8-26-86 6449-693~
2T-7
Receipt Acknowledged:
Distribution:
NSK Drilling
Vault (film)
Date:
Rathmell D & M
k. Johnston (vendor Package)
State of Alaska (.+ Sepia)
A~CO AlaJkJ. Inc :$ a ,~ubiJd~3ry Of AllJnl~cl~lfchl~eldComD~ny
STATE OF ALASKA
ALASK,, iL AND GAS CONSERVATION COMMI, ~ON
REPORT OF SUNDRY WELL OPERATIONS
1. Operations performed: Operation shutdown ~ Stimulate ~ Plugging --_- Perforate~ Pull tubing
Alter Casing ~ Other ~ Coml:)]_ete
2. Name of Operator 5. Datum elevation (DF or KB)
ARCO Alaska~ Inc RKB 117' Feet
3. Address 6. Unit or Property name
P. O. Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit
4. Location of well at surface 7. Well number
302' FSL, 556' FWL, Sec. 1, T11N, R8E, UM ?.T-6
At top of productive interval 8. Approval number
1454' FNL, 1521 ' FEL, Sec. I , T11N, R8E, UM 380
At effective depth 9. APl number
1357' FNL, 1380' FEL, Sec. 1, T11N, R8E, UH 50-- 103-20068
At total depth e 10. Pool
1304' FNL, 1300' FEL, Sec. 1, T11N, R8E, UM Kuparuk River Oil Pool
11. Present well condition summary
Total depth: measured 8208 'MD feet Plugs (measured) None
true vertical feet
61 74 'TVD
Effective depth: measured feet Junk (measured)
true vertical 8024 'I'4D feet None
601 7 ' TVD
Casing Length Size Cemented Measured depth True Vertical depth
Conductor 80' 16" 235 sx CS I I 115'MD 115'TVD
Surface 3416' 9-5/8" 810 sx AS Ill & 3448'MD 2766'TVD
360 sx Class G
Top job w/125 sx AS I
Production 8106' 7" 400 sx Class G & 8106'MD 6087'TVD
175 sx AS I
Perforation depth: measured
7770 ' - 7774 'MD 7785 ' - 7814 'MD
7778 ' - 7782 'MD 7851 ' - 7854 'MD
true vertical 5802' - 5806'TVD 5815' - 5839'TVD
5809' - 5812'TVD 5870' - 5873 'TVD
Tubing (size, grade and measured depth)
2-7/8", J-55, tbg w/tail @ 7669' ~ "i.=~..:Li~..-~ !~ ~.: ~'. "
Packers and SSSV (type and measured depth)
HB-1 pkr ~ 7643' & TRDP-1A-SSA SSSV @ 1791'
12. Stimulation or cement squeeze summary ... i../ ~ .,~]i
N/
IntervaAls treated (measured) ',-.1,<?-.. (iii & { ;-:'~ (;u~,o.
Treatment description including volumes used and final pressure
13. Representative Daily Average Production or .njectio~'~! : "~1[
N/A OiI-Bbl Gas-Mcf Water-Bbl C a s i ~.g,,l~.re~ ~"~ !
Prior to well operation i . N'~ ~' iii ~'* 'i' ~,,i~
Subsequent to operation t
14. Attachments (Completion Well History, w/Addendum, dated 9/12/86)
Daily Report of Well Operations :~ Copies of Logs and Surveys Run
15. I hereby certify that the foregoing is true and correct to the best of my knowledge c~f,~,
Signed &~9(-,' ~ Title Associate Engineer Date //-/~-~__,~
Form 10-404 Rev. 12-1(~.5
(DAM) 5W0/115 Submit in Duplicate
ARCO Oil and Gas Company
Daily Well History-Final Report
Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold.
"Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not
required upon completion; report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire
operation il space is available.
Accounting coat center code
State
Alaska
no.
2T-6
District ICounty or Parish
Alaska I North Slope Borough
Field ~Lease or Unit
Kuparuk River I ADL 25569
Auth. or W.O. no. ~Title
AFE AK0731 I Completion
Nordic 1 API 50-103-20068
Operator
ARCO Alaska, Inc.
Spudded or W.O. begun
Complete
Date and depth
as of 8:00 a.m.
10/15/86
10/16/86
A.R.Co. W.I.
56.24%
Date 10/14/86
Complete record for each day reported
I otal number of wells (active or inactive) on this
est center prior to plugging and
bandonment of this well
our I Prlor atatus if a W.O.
I
1700 hrs.
7" @ 8106'
8024' FC, Rn'g tbg
10.8 ppg Brine
Accept rig @ 1700 hrs, 10/14/86. ND tree, NU & tst BOPE. RU
Schl, perf f/7770'-7774', 7778'-7782' @ 1SPF, 7785'-7814' &
7851'-7854' @ 4 SPF, RD Schl. RU & begin rn'g 2-7/8" compl
string.
7" @ 8106'
8024' FC, RR
10.8 ppg Diesel
Rn 240 its, 2-7/8", J-55 EUE 8RD AB Mod IPC tbg w/SSSV @ 1791',
HB-1Pkr @ 7643', TT @ 7669'. Tst ann to 2500 psi; OK. Tst
SSSV ok. ND BOPE, NU & tst tree; OK. Displ well to diesel.
RR @ 1645 hrs, 10/15/86.
Old TD
New TD
PB Depth ......... ,' :.,
8024'
Released rig Date Kind of rig
1645 hrs. 10/15/86 Rotary
Classifications (oil, gas, etc.) Type completion (single, dual, etc.)
Oil Single
Producing method Olficial reservoir name(s)
Flowing Kuparuk Sands
Potential test data
Well no. Date Reservoir Producing Interval Oil or gas Test time Production
Pump size, SPM X length Choke size
C.P. ] Water %
The above is correct
Sign~__~///~ _ // / Date ITitle
:r
For form preparation and distribution,
see Procedures Manual, Section 10,
Drilling, Pages 86 and 87.
0{I on test
GOR Gravity Allowable
corrected
IGas per day
Effective date
i, i'i-i [
Drilling UJllrlPIZi , l !/4L
iI IDEFI]' Ii'ELY
ADDENDUM
WELL:
8/31/86
2T-6
Arctic Pak w/175 sx AS I, followed by 60 bbls Arctic Pak.
Tst to 1000 psi, bled to 880 psi/1 hr. Left 200 psi on
ann.
DXrilling Suporvisor
ARCO Alaska, Inc.
Post Office BOX 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 12'15
RETURN TO'
ARCO ALASKA, INC.
ATTN' Kuparuk Records.Clerk
AT0-1119
P.O. Box 100360
Anchorage, AK 99510-0360
DATE' 11-7-86
Transmittal #5819
Transmitted herewith are the following items. Please acknowledge
receipt and return one signed copy of this transmittal.
2T--2 CBL 10-12-86 7000-8786 Run 1
2T-3 CBL 10-12-86 3135-7780 Run 1
2T-5 CBL 10-11-86 3842-7548 Run 1
2T-6 CBL .10-13-86 3400-8007 Run 1
2T-8 CBL 10-10-86 5100-7475 Run 1
2T-9 CBL 10-10-86 2900-6174 Run i
Receipt Acknowledged:
Distribution:
BPAE( 1 b 1 ) Unoc~
Mobil(1 bl+l se
,Drilling(1 bl)
E
(~as Cons.
Anchorage
bl+ ) Chevron(1 bl+l se) NSK(1 bl)
i bl+l se)~~
L. Johnston(1 bl+l se) Vault(1 film)
CONFID[ !'IIAL
ARCO Alaska, Inc.
Extension Exploration
TRANSMITTAL
TO: B i I 1 VanA1 en - AOG£
ADDRESS: 3001 Porcupine Dr,
FROM: ,. Craiq Moselev - Arch
DATE: oct.
Transmitted herewith are the following: Well Data
ARCO: Kuparuk 2T-3(K-lO sands)
y9-12-86 I~js Tape Open Hole 3160.0 - 4100.0
Kuparuk 2T-6(K-lO sands)
~8-21-86 Lis Tape Open Hole 3874 - 4210
Kuparuk 2T-8(K-lO sands)
~7-22-86 Lis Tape Open Hole 2948.5 - 4000.0
RECEIPT
ACKNOWLEDG~NT'
Return receipt to:
ARCO Alaska, Inc.
E×tenstlon Exploration
ATTN' Lucille Johnston
P. O. Box 100360
Anchorage, Alaska 99510
RECEIVED
DEC 2 4 1986
Alaska 011 & Gas Cons. Commission
Anchora.qe
T'I LY
ARCO ALASKA, INC.
Development GeoSc|ence
TRANSM I TTAL-
·
Transmitted herewith are the following:.
,~, ,~n ? ?- ~ d'/<- / ~ s~ ,~ ~ )
1-~1 ~ ~ ~/~ ,, ~~ /
.
z- ~/ - ~ ~/~2- ~ s',~ /~ ~ .
Return receipt to: ARCO Alaska, Inc ~Oli&Gas ~?~s.~C0mm~ssmn :. -
Extenstion Expiation ~~( Anch g ~..
ATTN: Lucille [Johnsto~ ANO-~E. ."'
P. o. ~ox ~oo~a,o / -
AnchoraEe, AIas'~~510
DATE 09-10-86
TRANSMITTAL ~ 5753
:~.'-/.;"--: ~_-'.?' -.~-* -_?__ ARCO Alaska. In(::. - : . :-.;
-:'"'-:~-~=:'~--:~':-.:=' "::~ ~'-'~ :;-:' --~.- ~' Post Office Uu~ 100360-';-..~--
:' -:;~ :' ::':/' ~::_?-:- :_~:-::--::;_::--~-'~: Anchorage. Alaska 99510-0360
_:-~/'::. ~::::_ '- -'.~ ':' Telephone 907 276 1215 :-: .
. . _.-_ -- - _-_ . -.. - . .. .
-_ - ..- .... ....--: _-_ __, :~.:_ '.-; -: :_. _.;.:_~-:-~' -. ,:_/_...
?"~/ ':: :-- - ' :: ~CO ~S~,'- INC. : -_: ---:--"/. --'
':--: "- --'' AT~: Kupa~ Records clerk '
. .: ~ , ' . . _
.- ..... _' A~ 1119 ::-.'-~-:-~ - '- '
_ ...~- _ . -
;'-:- '- '- - P. O. Box~--- 100360 -
-_
-- ;:- ' ' -- - ~chorage :: -'~ 99510-0360
Transmitted' herewith 'are the following items.. Please acknowledge receipt and
return, one signed cop o~is transmittal. ~'; -
Open. Hole ~ Tapes_~.~u~Listing~i: chl' One of each
~3K, i7
08-27-86 Run #1
3K-16. 08-19-86 Run #1
08-12-86 Run #1
08-21-86 Run #1
08-12-86 Run #1
09-03-8'6 Run #1
'~3K-15
2T-6
2T-4
~2T-5
-
__
0992.5-9606.0~ l /¢'-.~ "~pe/¢ ,.~'¢/~n_ ~,~ ¢2/~
0059. o-907z. 9~r3/¢¢-~-¢en-~-¢¢~/
0968 0-9302 0~0~I~1~-~~ ¢~
._. ~~
0987 5-8235 5~V~~--S-O~n-¢~¢_~.
0991/0-7694. ~~/~~-~~.- ~/_ y~
Receipt Acknowledged: ' /~"f ~~~5 fO~ a :
~ / Alaska 011 & Gas Cons. Commissicn _
~ate. of~ Arzhorage
DE AL
·
· MCO ~lmmkm. Inc. ~
STATE OF ALASKA
ALASK/-, 4)IL AND GAS CONSERVATION COMM,..,.;ION
APPLICATION FOR SUNDRY APPROVALS
1. Type of Request: Abandon - Suspend -- Operation Shutdown ~ Re-enter suspended well -- Alter casing -;
Time extension- Change approved program ~ Plugging ~. Stimulate ~- Pull tubing- Amend order--- Perforate ' Other '
2. Name of Operator
ARCO Alaska, Inc,
3. Address
P. O. Box 100360 Anchorage, AK 99510
4. Location of well at surface
302' FSL, 556' FWL, Sec 1, T11N, R8E, UM
At top of productive interval
1397' FNL, 1392' FEL, Sec. 1, T11N, R8E, UM (Approx)
At effective depth
1351' FNL, 1428' FEL, Sec. 1, TllN, R8E, UH (Approx)
At t(~t2~11 ~tep~th
~-r~L, 1350' FEL, Sec. 1, T11N, R8E, UH (Approx)
5. Datum elevation (DF or KB)
117' RKB
6. Unit or Property name
K~J.nar,~k River IJni~
7. Well number
2T-6
8. Permit number
86-107
9. APl number
50-- 103-20068
10. Pool
Kuparuk River Oil Pool
feet
11. Present well condition summary
Total depth: measured
true vertical
Effective depth:
measured
true vertical
Casing
Conductor
Surface
8208 'MD feet
6182 'TVD feet
8024 'MD
feet
6031 ' TVD
feet
Production
Length Size
80 ' 16"
3416' 9-5/8"
8106' 7"
Plugs (measured) None
Junk (measured)
No ne
Cemented Measured depth
235 sx CS II 115'MD
810 sx AS III &
360 sx Class G 3448 'MD
Top job w/125 sx AS I
400 sx Class G 8106'MD
~ue Vertical depth
115'TVD
2788'TVD
6098'TVD
Perforation depth: measured None
true vertical None
Tubing (size, grade and measured depth) None
Packers and SSSV (type and measured depth)
None
RECEIVED
S E P 0 9 1986
Alaska 0ii & Gas Cons. Commission
Anchorage
12.Attachments
Description summary of proposal
Well Hi story
13. Estimated date for commencing operation
0ctober, 1986
14. If proposal was verbally approved
Name of approver
Date approved
15. I hereby certify that the foregoing is true and correct to the best of my knowledge
Signed ~f/~/')(..Y ~L,L,L~k...J Title Associate Engineer
~ Commission Use Only (DAM) SA/107
Date
Conditions of approval
Approved by
Notify commission so representative may witness
~ Plug integrity ~ BOP Test r-q., Location clearance
I Approval No. ..~? (?
by order of
Commissioner the commission Date ¢-/~ '~
Form 10-403 Rev 12-1-85 Submit in triplicate
ARCO Oil and Gas Company
Well History - Initial Report - Daily
Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started.
Daily work prior to spudding should be summarized on the form giving inclusive dates only.
District
Alaska
Field
Kuparuk River
Auth. or W.O. no.
AFE AK0731
Rowan 34
Operator
ARCO Alaska, Inc.
Spudded or W.O, begun
Spudded
Date and depth
as of 8:00 a.m,
8114186
8/15/86
8/16/86
thru
8/18/86
ICounty, parish or borough
North Slope Borough
ILea~e ADL 25569
or
Unit
ITi.e Drill
IState
API 50-103-20068
8/19/86
8/20/86
JOate IHour
8/14/86
Complete record for each day reported
0100 hrs.
ARCO W.I.
JPr or status if a W.O.
16" @ 115'
480', (375'), Drlg
Wt. 9.1, PV 20, YP 30, PH 8.5, WL 12, Sol 6
Accept rig @ 2000 hrs, 8/13/86. NU diverter sys.
8/14/86. Drl 12¼" hole to 480'.
Alaska
16" @ 115'
1932', (480'), RIH
Wt. 9.3, PV 20, YP 22, PH 9, WL 8, Sol 8
Drl & surv 12¼" hole to 1932'.
647', 4.9°, N39.9E, 647 TVD, 12 VS, iON, 8E
1101', 19.9°, N45.8E, 1087 TVD, 118 VS, 88N, 78E
1564', 35.4°, N43.7E, 1495 TVD, 334 VS, 233N, 240E
1877', 45.4°, N40.2E, 1733 TVD, 536 VS, 385N, 373E
JWell no,
2T-6
56.24%
Spud well @ 0100 hrs,
9-5/8" @ 3448'
4396', (2464'), Drlg
Wt. 9.7, PV 20, YP 12, PH 10.5, WL 9, Sol 8
Drl 12¼" hole to 3440', make wiper trip. Drl to 3470', CBU,
POOH. RU & rn 86 jts, 9-5/8", 36#, J-55 BTC csg w/FS @ 3448',
FC @ 3365'. Cmt w/810 sx AS III w/10#/sx Gilsonite & 360 sx Cl
"G" w/2% S-1 & .2% D-46. Displ using rig pmps, bump plug. ND
diverter. Perform 125 sx AS I top job. NU & tst BOPE. RIH
w/8½" BHA, DO cmt to TOF (hammer) @ 3367' & chase junk to
3367', POOH. PU globe bskt, RIH, core over junk & flt colr,
POOH w/fsh; full rec'y. RIH w/8½" BHA, DO flt equip &
formation to 3485'. Conduct formation tst to 12.8 ppg EMW.
Drl & surv 8½" hole to 4396'.
440,
2953', 50°, N42.3E, 2470 TVD, 1319 VS, 966N, 899E
3735', 50.5°, N42.4E, 2972 TVD 1919 VS, 1405N, 1307E
4112', 48.5°, N43.6E, 3217 TVD, 2206 VS, 1615N, 1503E
9-5/8" @ 3448'
6940', (2544'), Drlg
Wt. 9.9, PV 12, YP 7, PH 9.5, WL 6.8, Sol 12.4
Drl & surv 8½" hole to 6940'.
4478', 46.7°, N42.4E, 3463 TVD, 2476 VS, 1812N, 1687E
5417', 46.5°, N4OE, 4104 TVD, 3161VS, 2335N, 2131E
6436', 44.4°, N40.SE, 4810 TVD, 3896 VS, 2894N, 2609E
9-5/8" @ 3448'
RECEIVED
S E P 0 9 1986
8060', (1120'), Drlg Alaska Oil & Gas Cons. Cu~mission
Wt. 10.8, PV 16, YP 12, PH 9, WL 6.2, Sol 15 Anchorage
Drl & surv 8½" hole to 8060'. ,
6949', 44.1°, N40.1E, 5178 TVD, 4253 VS, 3166N, 2841E
7269', 42.5°, N35.9E, 5411TVD, 4472 VS, 3339N, 2976E
T?ez~o~e is correct
see Proced~ Manual, Section 10, '
Drilling, Pages 86 and 87.
Date I Title
Drilling Supervisor
ARCO Oil and Gas Company
Daily Well History-Final Report
Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold.
"Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not
required upon completion, report completion and representative test data in blocks provided. The "Final Reporl" form may be used for reporting the entire
operation if space is available.
District
Alaska
IAccounting cost center code
ICourffy or Parish State
North Slope Borough Alaska
JL ...... Unit JWe,, no.
ADL 25569 2T-6
JTitle Drill
Field
Kuparuk River
Auth. or W.O. no.
AFE AK0731
Rowan #34
API 50-103-20068
Operator
ARCO Alaska, Inc.
Spudded or W.O. begun
A.R.Co. W.I.
56.24%
Date 8/14/86
Spudded
Date and depth
as of 8:00 a.m.
Complete record for each day reported
I otal number of wells (active or inactive) on this
cst center prior to plugging and
bandonment of this well
our I Prior status if a W.O.
I
0100 hrs.
8/21/86
8/22/86
8/23/86
9-5/8" @ 3448'
8208', (148'), Logging
Wt. 11.3+, PV 16, YP 8, PH 8.5, WL 6.4, Sol 17
Drl 8½" hole to 8208', 10 std short trip; pit gain. SI well,
circ & raise mud wt to 11.3 ppg. Open well, circ, 15 std short
trip, circ, TOH. RU Schl & TIH to log.
8178', 27°, N60E, 6157 TVD, 4988 VS, 3686N, 3361E
9-5/8" @ 3448'
8208', (0'), Rn'g 7"
Wt. 11.3+, PV 17, YP 8, PH 8.5, WL 6.8, Sol 18
Rn DIL/GR/SP/SFL/FDC/CNL f/8208'-7400' & 4200'-3850'; cont w/GR
to 1000'. Rn CAL f/8208'-6400' & 4200'-3850'. RD Schl. Make
cond'g rn. RU & begin rn'g 7".
Old TD
8208 ' TD
Released rig Date Kind of rig
2230 hrs. 8/22/86 Rotary
Classifications (oil, gas, etc.) Type completion (single, dual, etc.)
Oil Single
Producing method Official reservoir name(s)
Flowing Kuparuk Sands
Potential test data
7" @ 8106'
8208' TD, RR
10.8 ppg Brine
Rn 7" to 8106', FC @ 8024'. Cat w/400 sx 50/50 Flyash C1 "G"
w/4% D-20, .2% D-46, .5% D-65. Displ w/10.8 ppg brine, bump
plug. ND BOPE, instl lower tree, tst pack-off to 500Rt~.' F4!/ F D
@ 2230 hfs, 8/22/86.
S¢.? 0 9 1986
A~.~K~ UH ~, u~s tu~s. Comm~ss~oD
New TD PB Depth Anchorage
Well no. J Date
I
Pump size, SPM X length
The able-is correct
Drilling, Pages 86 and 87.
Reservoir
Choke size
Producing Interval
C.P. Water %
Oil or gas
Test time
Production
Gravity
corrected
Oil on test
Gas per day
GOR Allowable Effective date
L o Nl-iU,
Drilling Supe _ .
TIAL
June 5, 1986
Mr. J. B. Kewin
Regional Drilling Engineer
ARCO Alaska, Inc.
P. O. Box 100360
~nchorage, Alaska 99510-0360
.Telecopv:
_ .-
(907) 276-7542
Re: Kuparuk River Unit 2T-6
ARCO Alaska, Inc.
Permit No. 86-107
Sur. Loc. 302:FSL, 556'~U~, Sec. I, TI!N, RgE,
Btmhole Loc. l!34'FNL, lI47'FEL, Sec. 1, TllN, RSE, UM.
Dear Mr. Kewin:
Enclosed is the approved application for permit to drill the
above referenced well.
The permit to drill does not indemnify you from the probable need
to obtain additional permits required by law from other
governmental agencies'prior to commencing operations at the well
site.
To aid us in scheduling field work, please nOtify this office °4
hou~.s przor to com~nencing installation of the blowout prevention
equipment so that a representative of the Commission may be
present to witness testing of the equipment before the surface
casing shoe is drilled. ~ere a diverter system is required,
please also notify this office 24 hours prior to commencing
equipment installation so that the Commission may witness testing
before drilling below the shoe of the conductor pipe.
~erv-~ truiv ~ours, ~
Chai~an of
Alaska Oil and Gas Conservation Co~ission
BY ORDER OF THE CO~ISS!ON
dlf
Enclosure
Department of Fish & Game, Habitat Section w/o enc!.
Department of Environmental Conservation w/o encl.
Mr. Doug L. Lowery
STATE OF ALASKA
ALASKA -_ .,_ AND GAS CONSERVATION CO,,,MISSION
PERMIT TO DRILL
20 AAC 25.OO5
la. Type of work Drill Z Redrill ~1 lb. Type of well. Exploratory ,~ Stratigraphic Test ~ Development Oil
Re-Entry ~ Deepen_, Service ?, Developement Gas ~ SingleZone,~ Multiple Zone
2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool
ARCO Alaska, Inc. RKB 117', PAD 82' feet Kuparuk River Field
3. Address 6. Property Designation Kuparuk Ri vet Oi 1 Poo
P.O. Box 100360 Anchorage, AK 99510 ADL 25569 ALK 2667
4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025)
302'FSL, 556'FWL, Sec.1, T11N, R8E, UN Kuparuk River Unit Statewide
At top of productive interval 8. Well nu .tuber Number
1397'FNL, 1392'FEL, Sec.1, T11N, R8E, UM 2T-6 #8088-26-27
At total depth 9. Approximate spud date Amount
1134'FNL, 1147'FEL, Sec.1, T11N, R8E, UM 07/11/86 $500,000
12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD andTVD}
property line feet 8320 'MD
1134' ¢TD feet 2T-7 25'(~ ,surface 2560 ('6085'TVD) feet
16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2))
Kickoff depth 500 feet Maximum hole angle 48 0 Maximum surface 1 670 psig At total depth (TVD) 3250 psig
18. Casing program Setting Depth
size Specifications Top Bottom Quantity of cement
Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data)
24" 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' +200 cf
12:~" 9-5/8" 36.0# J-55 BTC 3411 ' 35' 35' 3446' 2821 ' 810 sx AS I I I &
HF-ER'V 360 sx Class G blend
8~_" 7" 26.0# U-SS BTC g2R6' 34' ~b,, 8320' 6085' 200 sx Class G fminimun
HF-ER~/ TOC 500' above top .of
19. To be completed for Redrill, ReIentry, and Deepen Operations. Kupa ruk.
Present well condition summary
CO[ iEiDE
true vertical feet
Effective depth: measured feet Junk (measured) i i
true vertical feeti ~, ~ l"~' !'"~1"'" i]~,~i-'. ~
Casing Length Size Cemented MoasLi~.,~.~t~?I, .~, ~ irked( Idepth
Structural
Conductor
Surface RECEIVED
Intermediate
ProductionMAY 2 8 1986
Liner
Perforation depth: measured Alaska Oil & Gas Cons. oommission
true vertical Ap, ch0rage
20. Attachments Filing fee ~ Property plat ~ BOP Sketch ~ DiverterSketch ~ Drilling program ~
Drilling fluid program .~ Time vs depth plot ~J Refraction analysis ~.' Seabed report ~ 20 AAC 25,050 requirements~'?
21. I hereby certify that the foregoing is true and correct to the best of my knowledge
..7, g '
Signed ,. rt ~,.)/ TitleRegional Drilling Engineer D~te~'/~/',~,
mmission Use Only ~1~/P1~271
,,,~ APl number~ ., ~,~ J Approval date See cover letter
Permit Number ~.,'~[~[ 50-- [o.. ~-~:~:~-~,¢ 06/05/86 for other requirements
I
Conditions of approval Samples required [] Yes [~ No Mud Icg required ~ Yes E~ No
Hydrogen sulfide measures '~ Yes Fi No Directional survey required '~ Yes ~% No
Required worki sureto~4;z~2,~, /~3M; ,~ 5M; ~ 10M; .m 15M
Other: n~B'~
( /',.~, ( ~ byorderof
Approved by Commissioner the commission Date
Form 10-401 Rev.~
Sub/~ ~ triplicate
TOOO.
). ' ) 000
~'oo -
i
¢000
~000
i~ooo
' ._ :--L-:_LLT- _. PAD' 2T~'-_~NO, .6-'___P,~D . ._-'.-.
KUP-~-F I ELD. NORTH~ SLOPE,~- AL ASKA- -
_
i
' [ ' I
___
i
1
000~
KUP~RUK R I VER UN I T
20" O I VERTER SCHEMRT I C
DESCRIPTION
1. 1~" CONDUCTOR.
2. TANKO STARTER HEAD.
3. TANKO SAVER SUb.
4. TANKO LONER QUICK-CONNECT ASSY.
S. TANKO UPPER QUICK-CONNECT ASSY.
6. 20" 2000 PSI ORILLINQ SPOOL
N/lO" OUTLETS.
7. 10" HCR BALL VALVES N/lO"
OIVERTER LINES, A SINQLE
VALVE OPENS AUTOMATICALLY UPON
CLOSURE OF ANNULAR PREVENTER.
VALVES CAN BE REMOTELY CONTROLLED
TO ACHIEVE DOWNWIND DIVERSION.
8. 20" 2000 PSI ANNULAR PREVENTER.
7 6 7
ARCO ALASKA, INC., REQUESTS
APPROVAL OF THIS DIVERTER
SYSTEM AS A VARIANCE FROM
20 AAC2S · 035 (b)
MR I NTENRNCE & OPERRT I ON
1. UPON INITIAL INSTALLATION, CLOSE
PREVENTER AND VERIFY THAT VALVE
OPENS PROPERLY.
CLOSE ANNULAR PREVENTER AND BlOW
A I R THROUGH D I VERTER L I NES
EVERY 12 HOURS.
3, CLOSE ANNI, A_AR PREVENTER IN THE
EVENT THAT AN INFLUX OF NELLBORE
FLUIDS OR GAS IS DETECTED. OPEN
APPROPRIATE VALVE TO ACHIEVE
DOMINO DIVERSION.
DO NOT SHUT IN WELL
UNDER ANY C I RCUMSTRNCES.
CONFIDE )TIA[
'
RI(
I
:. -
i
7
6
DIAGRAM #1
1~-5/~' 5CX:X:) PSI R~RRA BOP ~TAC~
I. 16" - 2000 1:~SI TAINi<CO STARTING i-F_AD
2. Il' - ~ 1:"3I CA~ING HE. AD
3. Il' - 3000 PSI X I3-5/8' - 5000 PSI S~ACIE~
4. I3'-5/8' - 5000 PSI PIPE
5. 13-S/8' - 5000 PSI DRILLING SI~ W/C~
KILL LI~,E5
6. 13--5/8' - ~ P~I D(3L.~I.E RAM N/PIPE RAMS CN TC~,
?. 13-5Y8' - 5000 PSI
ACQJVtJLATOR CAPACITY TEST
I. OEO( ~ FILL ACO. M. LATOR RESERVOIR TO ~
LEVEl. WITH NYCRNA. IC FLUID.
2. ASSlJRE THAT A~TCR PRESSLRE IS 3000 PSI WITH
3. ~ TINE, TI-EN CLOSE ALL UI~TS SI~ii. TAI~EOUSLY
ALL LI~TS ~ CLOSED WITH O4AROIN~ ~ CFF.
4. REC~ ON NADC I:~:la~, TIE AO:EPTABLE LCTA~ LIMIT
IS 4S Sii~ CLOSING TINE ~ 1200 PSI RE)4AINING
PRESS. RE.
ii
Iii
5
4
3
2
I
,
JJ..
13-5/0" BOP STAQ< TEST
I. Fill ~ STA(]( AbD C3-1a(E MANIFOLD WITH ARCTIC
DIESEL.
2. CIE(I( THAT ALL LCX:X [X]MI~ ~ IN ViELL~F. AD ERE
FULLY RETRACTEd. SEAT TEST PLUG IN ~
WITH ~IN~ JT ~ ~ IN LO(](I:X:)f~ SOi~'lMS.
3. CLOSE ~ ~ AI~ MANJAL KILL AN:) a-IO<E
LIllE VALVES ADJACENT TO B(~ b-'TAC~, ALL
4, 13RF...~I.I~ UP TO 2S0 P~! ~ H(lD FOR I0 MIN.
~ PRE~ TO 3000 PSI AJ~) HClD FOR I0 MIN.
BL~m3 PRESSURE TO 0 PSI.
5. CPt~ ~ PR~'ENTER A~ MANJAL KZLL A~ a-~KE
LII~ VALVES. CLOSE: TCP PIPE ~/~ AIND HOR VALVES
e. TEST TO 2~0 PSI A~ ~0 PSI AS IN STEP 4.
7. ca~rI~ TESTZNG ALL VALVES, LI~_S, MN)cMa<ES
WITH A 250 PSI LC~ AN) 300:} PSI HIGH. TEST AS iN
ST~ 4..m~ NOT ~ T~.~T ANY CNm~cN_T~TyZS
Nor A ~'ULL CLOSING PC~TZV[ ~ ~iC~.
~ZCI~I TE. ST a-lCKi[S THAT [~) ~ ~Y CLCI~.
e. oP~ TOP PIPE R~S AN~ CLC~ ~m'FC~ PIP~
TEST ~TTC~ PZPE ~ TO Z~O PSI A~ ~ PSZ.
I0. CL__r~E_ 81.1N~ RAM8 AI~ TEST TO 250 PSI A/~ 3000
PSI,
MAN~FOLD AN3 LI~ES AI~ FULL CF ~ING
FLUID, ~ ALL VALVES IN DRILLING POSITIClN.
12.- TEST STAN~IPE VALVES, KFT_LY, KELLY CCO(S, ~ILL
PIPE SAFETY VALVE. AN:) INSIEE BCP TO 250 PSI
3000 PSI.
RE~ TEST II~FCI~MATICI~I CIq BLCINOJT PRL~/ENTER TEST
FCRMo SIGN, AAD ~ TO DRILLING SUI:~I~1SOR.
PERFORM ~ BCPE TEST AF'rER NIPPLING LP
V~EXLY THEREAFTER F1JNCTICNAI. LY OPERATE BCPE DAILY.
CONFIDEN
i AL
INDEFINITELY
5 ! 0084001 REV. 2
~Y 15, 19~5
GENERAL DRILLING PROCEDURE
KUPARUK RIVER FIELD
DEVELOPMENT WELLS
1. Move in rig.
2. Install Tankco diverter system.
3. Drill 12¼" hole to 9-5/8" surface casing point according to directional
plan.
4. Run and cement 9-5/8" casing.
5. Install and test blow out preventer. Test casing to 2000 psig.
6. Drill out cement and 10' new hole. Perform leakoff test.
7. Drill 8½" hole to logging point according to directional plan.
8. Run open hole logs.
9. Continue drilling 8½" hole to provide 100' between plug back total depth
and bottom of Kuparuk sands.
10. Run and cement 7" casing. Pressure test to 3500 psig.
11. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus.
12. Nipple down blow out preventer and install temporary Xmas tree.
13. Secure well and release rig.
14. Run cased hole logs.
15. Move in workover rig. Nipple up blow out preventer.
16. Pick up 7" casing scraper and tubing, trip in hole to plug back total
depth. Circulate hole with clean brine and trip out of hole standing
tubing back.
17. Perforate and run completion assembly, set and test packer.
18. Nipple down blow out preventer and install Xmas tree.
19. Change over to diesel.
20. Flow well to tanks. Shut in.
21. Secure well and release rig.
22. Fracture stimulate.
,SHALE
SHAKERS
CLEANER
STIR .~.
IMUD
CLEANER
STIR _~ STIR
CENIRIFUO[
LWK4/ih
TYPICAL MUD SYSTEM SCHEMATIC
DRILLING FLUID PROGRAM
Spud to
9-5/8" Surface Casin~
Density 9.6-9.8
PV 15-30
yp 20-40
Viscosity 50-100
Initial Gel 5-15
10 Minute Gel 15-30
Filtrate API 20
pH 9-10
% Solids 10±
Drill out
to Weight Up
8.7-9.2
5-15
8-12
35-40
2-4
4-8
10-20
9.5-10.5
4-7
Weight Up to TD
10.3
9-13
8-12
35-45
3-5
5-12
9.5-10.5
9-12
Drillin~ Fluid System:
- Triple Tandem Shale Shaker
- 2 Mud Cleaners
- Centrifuge
- Degasser
- Pit Level Indicator (Visual & Audio Alarm)
- Trip Tank
- Fluid Flow Sensor
- Fluid Agitators
Notes:
Drilling fluid practices will be in accordance with the
appropriate regulations stated in 20 AAC 25.033.
Maximum anticipated surface pressure is calculated using a
surface casing leak-off of 13.5 ppg EMW (Kuparuk average) and
a gas gradient of .11 psi/ft. This shows that formation
breakdown would occur before a surface pressure of 3000 psi
could be reached. Therefore, ARCO Alaska, Inc. will test our
BOP equipment to 3000 psi.
LWK5/ih
CONFIDE !TIA[
After 200' of departure, there are no well bores within 200'
of this proposed well.
ARCO Alaska, Inc. -
Post Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
January 31, 1986
Mr. C. V. Chatterton
Commissioner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT- Conductor As-Built Location Plat - 2T Pad
(Wells 2- 17)
Dear Mr. Chatterton'
Enclosed is an as-built location plat for the subject wells.
you have any questions, please call me at 263-4944.
Sincerely,
Gruber
Associate Engineer
JG/tw
GRU13/L44
Enclosure
If
RECEIVED
FFB 0 5 ],:..c.::.
,,-- ?' f-; ,-,
Ak,.,,~, Oil E Gas Oon~. uu;; ........
ARCO Alaska, Inc. is e Subsidiary o! AtlanticRichfieldCompany
LOCATED IN PROTRACTED LOCATED IN PROTRACTED
SEC. I~ Tl l N~E8E~ U.M. SEC. I ~ TI I N,RSE~ U.M.
~ - Y = 5,970,382,43 LAT. 70~19'49.1287" 10 - Y = 5,970,132.65 LAT. 70°19'46.6719"
X = 498,944.93 LONG. 150000` 30.807" X = 498,945.27 LONG. 150°00' 30. 796"
~2' FSL, 556' ~L OG = 77' PAD = 81.5 152'FSL, 556' FWL OG ' 76.0 PAD = 81.7
3 - Y = 5,970,357.42 ~T. 70~19'48.8828'' 11 = Y = 5,970,107.71 LAT. 70°19'46.4267''
X = 498,944.91 LONG. 150000"30.808" X = 498,945.10 LONG.150°DO'30.801"
377' FSL, 556' FWL OG = 77' PAD = 81.5 127' FSL, 556' FWL OG = 75.9 PAD = 81.7
4 - Y = 5,970,332.46 LAT. 70~19'~.6372" 12 - Y = 5,970,082.58 ~T. 70°19'46.1794"
~ ,
X = 498,944.84 LONG. 150=O0'30.809" ~ x = 498,944.98 LONG.150oO0 30.804"
352" FSL, 556' FWL OG = 77' PAD = 81.6 .c~ i02' FSL, 556' FWL OG = 75.7 PAD = 81.7
5- Y = 5,970,307.52 LAT. 70°19'48.3919" ~ 13- Y = 5,970,057.59 ~T. 70°19'45.9336"
X = 498,944 91 LONG. 150°00' 30.808" ~ ~ X = 498,945.08 LONG. 150°00' 30· 801''
' o 77' FSL 556' FWL OG = 75.5 PAD = 81 6
327' FSL, 556' FWL OG = 77' PAD = 81.6 LO ~ ' '
6 - Y = 5,970,282.50 LAT. 70°19'~.1459" ~ ~ 14 - Y = 5,970 032 60 LAT. 70°19'45.6879"
X = 498,944.95 LONG. 150°D0' 30. 806" ~ ~ o6 c> ' ·
~ ~ ~ X = 498,944.91 LONG.150°O0'30.806"
o ~ 52' FSL, 556' FWL OG = 75.3 PAD = 81.7
302' FSL, 556' FWL OG = 77' PAD = 81.7 ~ ~ ~ ~;
c~ ~ 15 -'Y = 5,970,007.69 LAT. 70°19'45.442B"
7 - Y = 5,970,257.54 LAT. 70°19'47.9003'' ~ O ~ ~ X 498,944.93 LONG.150°O0'30.806''
X = 498,944.95 LONG'150°O0'30'806" ~ ~ 27' FSL, 556' FWL OG = 75 2 PAD = 81.6
277' FSL, 556' FWL OG = 77' PAD = 81.6 ~ ·
~ 16 - Y : 5,969,982.85 LAT. 70°19'45.1985"
8 - Y = 5,970,232.63 LAT. 70019'47.6553" ~ ~' ~ 498,944.88 LONG 150~00'30 807"
X : 498,944.96 LONG. 150000' 30.806" ~ X = · ·
252' FSL, 556' FWL OG : 76.9 PAD : 81.6 ~ 2' FSL, 556' FWL OG = 75.1 PAD : 81.7
9 - Y = 5,970.207.62 LAT. 70019'47.4093'' ~j LOCATED IN PROTRACTED
x = 498,945.01 LONG.150°O0'30.804'' ~ SEC.I~ , ~l ~ N, RBE, U.M.
227' FSL, 556' FWL OG : 76.3 PAD = 81.6 17 - Y = 5,969,957.72 LAT. 70°19'44.9514"
X = 498,944.94 LONG. 150000, 30.805"
23' FNL, 556' FWL OG = 75.0 PAD = 81.6
4. VERT. POSITIONS BASED 0N TBM's 2T-6 ~ NI9+75, Eli+ 52 PER F.R.B. ~ ASSOC.
5.0. G. ELEVATIONS INTERPOLATED FROM S/C DRAWING CED- RIXX-3140 rev.
m
iCERTIFICATE OF SURVEYOR: i HEREBY CE~ [~Y T~AT I AM ~ROPERLY
REGISTERED ~D LICENSED TO PRACTICE L~ND
) M~DE BY ME OR UNDER MY SUPERVISION, AND ~ ~ ~ em
THAT A' ' D~MENS IONS AND OTHER DETAILS
I:.~ ARCU A,O,~O, Inc.
m m;~ SURVEYED FOR:
~cK~ SH
8SSDG, ~ F.,.e. esz, AS- BUILT LOCATIONS
Arctic Bou/evard, Suite 201, Anchorage, A/aska ~503 S~LE N.T.S.
11
JOB ~.
'" .: ..,'; (:AP~ROVE · DATE: ' · . ~ ,
' 6~V~.*~(' 1' is 'the permit fee attached ....... '. ............... ..
Loc' ~ c..~.., rr.~-~C ... 2 Is Well to be located in a defined pool . :... .......
i (-2/thru 8) 3' Is well loCated proper distance from property line .
4 Is well located proper distance from other wells ...
5 .Is sufficient undedicated acreage available in this
'(10' and I3);/
(14 thru 22)
· (23 thr ~
(6) OTHER
6. Is well to be deviated and is wellbore plat included ............
7. Is operator the only affected party .............................
8. Can permit be approved before ten-day wait ......................
·
10.
11.
12.
13.
14.
15.
16.
17.
18.
19.
20.
21.
22.
23.
For
.N&,
(29 thru-31) 30.
~ 31.
(6) Add:
Ge°logx_:
WVA~
JAL
Engi~e~ering:
LCS ~_~ B-~!~~
MTM _ HJH ~
32.
rev: 04/03/86
6,011
· ·
· ·
· ·
YES
_
Does operator have a bond in force ......................... . .........
Is a conservation order needed ......................................
Is administrative approval needed ........ , .............. ............
Is the lease number appropriate .....................................
Does the well haVe a unique name and number .........................
Is conductor string provided ........................................ ~
.
Will surface casing protect fresh water zones .......................
Is enough cement used to circulate on conductor and surface .........
Will cement tie in surface and intermediate or production strings ... .~.
Will cement cover all known productive horizons ..................
Will all casing give adequate safety in collapse, tension !?~ ~!s~.
Is this well to be kicked off from an existing wellbore ..
Is old wellbore abandonment procedure included on 10-403 ............
Is adequate wellbore separation proposed ............................
Is a diverter system required .......................................
Is the drilling fluid program schematic and list of equipment adequate ~
Are necessary diagrams and descriptions of diverter and BOPE attached·
Does BOPE have sufficient pressure rating - Test to .~OOO psig ..
Does the choke manifold comply w/API RP-53 (May. S4).. ....... : .........
Is the presence of H2S gas probable ........................
exploratory and Stratigraphic wells:
Are data presented on potential overpressure zones? .................
Are seismic analysis data presented on shallow gas zones ............
If an offshore loc., are survay results of seabed conditions presented
Additional requirements .............................................
INITIAL GEO. UNIT ON/OFF
POOL CLASS STATUS AREA NO. SHORE
·
NO
REMARKS
Well History File
APPENDIX
Information of detailed nature that is not
particularly germane to the Well Permitting Process
but is part of the history, file.
To improve the readability of the Well History file and to
simplify finding information, information of this
nature is accumulated at the end of the file under APPENDIX.
No special effort has been made to chronologically
organize this category of information.
CONFIDEN'I'IAE
INDEFINITELY
VERi[.','I~TI O~P~ISI'ING
bYP OIO'H02 VERIFICATION bISTING PAGE
HEADER
iON
I f~D! T
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** [.ILE TRAILER
FILE NANE IEDZT .,OOl
SgRVIC'E NAME
VZRSION l'
FXLZ TYPE :
M~XT FILE NAME
SERVICE ~R
'A :i67t
CO'N,~XNUATION # SOl
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NEXT ~T$ :
COflME LIBRARY TAPE
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28,6293 NC.Nb
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IND [FINIIIELY
_V; O!O.HO2 VE;(I':iC,&T'ON LiSTiNG PAGE 1
SERViC:~ NA~!E :EDIT
3,&TE :85/0B/27
3 R l G 'l N :
qEft NAME :149426
SONiINUATION a
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SERVICE NAME :EDIT
DATE :86/08/27
SRIGIN :0000
TAPE N~,M~ :1672
CONTINUATION ~ :Ol
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FiLE NAME :EDIT
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VERSION ~ :
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~,'! h E ,',1 C :3 N T E N T S
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UNIT
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TYPE
000
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000
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065
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CODE
055
AL~SK~
SCHLUME,~RGER
OiVZS~CN C!Sf,~PUTZNG C,EN'T,~R
C:2!4P~NY = ARC~3 AL~SK~
W ELL = 2T-5
FIELD =' KU?~RUK
CCUNTY = N.SLCPE
STATE = AL ~SK
S ~ECT ION' = 1
'TSWNS~ZP = 11~q
~NG~ : gE
! N C
DATE LOGGED 21-~UG-85
BOTI'SM LOG 'ZNTERV,a,L
TOP LOG ZNTERV.aL
~' ,'h S IN,3-LnSGER
BiT SiZ~
TYPE HF3LE FLUIS
DENSZTY
¥'ZSC,3SZTY
LeG: DZL , RUN ~ 1
820,5 FT.
990 FT.
= 9.525 IN.
= 8.500 ~N.
= LSND
: Ii.30
= 38.00
3450 ~=T.
.V:' OiO.H02 VE,RI=iC,~TIO',q LISTINS P,~GE 3
PH = 3.5O
FLUID LOSS = 5°40
R,q ,~ MEA$. 'TEMPo = 2.780 ~ 65. F
RMF ~ NE~S. TEMP. = 2.940 Z~ 6~ F
RMC 3 MEAS. T~MP. = 2.610 ~ 53 F
RM ~ 5HT = ~ 34~ '=~ 14; =
M~TR!X = S~NDSTENE
LDP: R. SZNzS
':NTRY ~LGCKS
TYPE SIZE
I 1
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SP -39.03t3 GR
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RNRA 3.9785 NPHI
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.'J E P T 8209.0000 SFLU
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FCNL 592,0000
DE, mT 7900,000C S~LU
SF -55,2~00 GR
CALI ~,5!,~5
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PCNL 5~9.0000
]~RT '7300.0000 SRLU
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C~LI 8,15.52
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0. 0894 NRAT
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2,5566 ILM
389~.0000 G~
0,1177 NRAT
21,1727 NCNL
2.9082 ILM
3684.0000 GR
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