L 041U DOK. SEN R

enne rapport
tilhører
L041U DOK. SEN
NR.
KODE
131
Returneres etter bruk
RAPPORT
FRA
PRODUKSJONS,TEST NR 2
AV OLJE SONE
BRØNN:
RIG:
31/2-2
WEST VENTURE
KARL GJERDE
R
MPPORT
FRA
PRODUKSJONS,TEST NR 2
AV OLJE SONE
BRØNN: 31/2-2
RIG: WEST VENTURE
KARL GJERDE
INNHOLD:
-
Rekompleterings
prograin for
"Oil-zone` og IIMJcaceous-zone"
-
tisub-surfacell
kompletering
skjematisk
-
side
`Gas lift`
"Gas
generelt
lift
picket
side
fldw-controler"
mandrel,
and side
skjematisk
side 4
s-lde.
"Flow-controlerl'
-
-
"Flow-controler
USide -
side
latch.assy."
side
pocket - mandrel`
-
"Kick-over-tool"
-
`Sequence
side
side/O
of events"-.
-cutting
of CP-liner
-preparing
-running
of well
for
sidell
prod.string
of packer and prod.string
sideJ
sidei'
-press.
test
of surface equipment
side/9
-press.
test
of prod.
string
sidé/5
-press.
test
of equp.
from x-mas
tree
to
-third
oil
burners
sidet
re-acidizing-job
on the
zone
-
Well
fl owi,ng data
-
Otis well testing
-
Problemer
sidet
from Otis
side
safety
side. HT
system.
side H
jr
N
Welt venture
$h t't t --'t ane
Om
ngejr ep
eppd eø
-urgent -t o west te n t u r e' ep d/2 'epp
topy ta
Stavanger.-attn. f. åa od I
-ref tan140801
t'eCb
t
14.08.80.
Ptetion of 31122
..I o r ot
o n.e a n d #Di c.a Ce o us - 5 a
tts
f ol Cowl Ing 4istussions between noske
s
as
partiieri-and
npd, it a's -heen agréed i_o pro.c e e d -a'
'r i'fi and openi x a-&r> d. cl.rcutate-wett with brine..' pick up 't o
pti t 1. sea[ tti Inger- out of packr
then. tircutate
-we t t wikh
brine aga i n..
(2)
poh vith 3-1121'
(3)
rig up schLuffiberger and run cctIgr f rom bottoffi inside gp
tiner to I 350 ip to ob* a in sch Lumberger, dtpths, 'f or the gp
tiner cottars. (n.b. througbout this., progra*me tetex, a t L
depths witt be quoted with reference to isf/sonie
run 3
of 1114180, dritier's
depths must be corrected- to make
atLowance for the 2 m d'e e p e r teadings obtai'n'eid by
(4)
rih with cutting
btank pipe at 1578 r.
(5)
tubing string.
oh 511
dp and cut-5-1i21 I
poh.
rtrieve
cut off btank pipe and sc-l 9 p packer es per
age 17, steps (5),
(6) and (7)
programme. p
(in
t h e.
the safety joint sears- during-programme, page -.17
$t
the reinalning cut off portion'of btank pipe mus,t be r
t
ove red
(6)
rih with 30 m, 2-71811 tubing on 511 dp._st'ab into
tiner and reverse hote cLean froin
t
ové any.,.,.
and -f rotn inside the tiner
reverse ircu,ø t
gp 5
etean littereo
bririe-then poh:
(7)
perforete. intervat,1570
1575
with 2-1 IV-1: hy.perdoié
scattop guns 4 spf , 0 degree pha'sing vsin4`the Ø- r for
procedure outtined in the programme, page. 2 8.p s t e p s... Cl
2
4)
adjurt perforating depths -_and
tasing scraper with 2 5P,-.? '7
tubing betow, using .59 '1 dp/6-1/41 t dtls ål.- 'ruii'nirig '£.tri
scråpe intervat 154
I 578 ffi (i
'to o ø. ,Of 'cut 6 f,f
gp tiner)
then
reverié
cte
when
s,craper
1578.i-A'i>VtIK
81. tubi n 9-.tait'øi P e. shoe --at 1 59 0 .3_4",# l s,_.&
't taboVe
tett
8') -rih with 9-5181
9
,up
shtL
g.-ø t 1f, r:
:'t'
Oh
16,6 f i t
un ..,gaugé
db.¥
ae t
w
ch 1~
i,
vNn
2,' x 2
su v^m
4.
ui 2.53
53 3C
KA-SSD
t570.17 n
1029
27/8
di
5.21
sc
2. 3
-i
?kcjccp.
2
x
UPPG;L
2.;.6
152 .7 6 m
6,4
ISN. 5%2E
2.50
E p-
b.16
is,
644 M
3y
-1531.20
M
> Yli'
'3* ]B
VAII
6.6o
E u )L
lP-LINER
4
1- 4 i - c
M C
n.3i
A'
-1
5
6, ri
15 13 '3 -M
14 UTi AT l s 8 a.
c15 IhlQ
C49
R
11
VAM 13-CC
0
G A S
L
r
F T
GENERELT
utfØrt -Med enkel
kompletering andre produksjonstest ble utfØrt med dobbel
kompletering.
Gas ble injisert fra overliggende gas sone.
Det ble brukt to "packers", og `side pocket mandrel` me(llom
disse.
Som `flow controler` ble det brukt en `chemical
injection valve`.
Den Øverste del-av denne ventilen er en
fj<,rbelastet port som åpner for gas ved et bestemt minstetrykk.
Denne ble justert til
et åpningstrykk på null for å
få minst mulig trykktap på gassen.
Ventilen består av to enheter:
- en choke-enhet for gass injeksjonen.
Ventilen leveres
med `choke` stØrrelser på 3/16" og 5/16".
- en `check-valve` for å hindre retur av eventuell olje
med hØyt trykk gjennom "flow controler` og ut i
annulus.
Etter avsluttet produksjonstest av olje sone, setter en
plug i `S-1"-nipple, åpner 2 7/V XO SSD og 32` XA SSD for
produksjon kun fra `Micaceous sand zone`.
GAS-LIFT
`FLOW-CONTROLER`
SIDE POCKET MANDREL no.
;1BK,11 LATCH no.
211-RW'30209-4
210-B0-5
CASING
VEE-PACKING
FLOW-CONTROLER no.
WEL
221-RCV-1000
GAS
CHOKE:,
3/26 OR 5/16
VEE-PACKING
411
CHECK VALVE
GAS
OIL
T.
Gas Lift Equipment and Systems
P~R
TYPE RCV CHEMICAL INJECTION VALVES
ASSEMBLY NUMBER
221RCVlooo-l
22-1RCV`1001-*
Sizelinches
Port Sizellnches
DETAIL
PART NAME
0.187 (311&)
0.312515/Ii.
Q`Ty
PART NO.
PART NO.
i
i
221Sl300
412SS555
221Sl300
412SS555
21OF4
9lV352
21OF4
9lV352
11
2
Upper Packing Sub
Sel Screw
3
4
Female Adapter
Vec-Packing
5
5
0-Ring
Lock Nut
2
i
9101210-H
221Sl301
910121 0-H
221Sl301
7
8
Nose
Retainer
i
i
22IS1208
221Sl302
221Sl208
221Sl302
9
10
Spring,
Spring Body
i
i
Sce Table*
221Sl303
See Table*
221Sl303
11
12
Stem
Spacer
i
221Sl304
None
221Sl305
221Sl307
13
14
Seat
0-Ring
i
i
221Sl311
9101016-S
221Sl312
9101016-S
15
16
Back-Up Ring
0-Ring
i
i
glTll14
9101114-S
glTll14
9101114-S
17
18
Packing Mandrel
0-Ring
i
i
221SI036
9101019-S
221Sl036
9101019-S
20
Seat
0-Ring
i
i
221Sl117
9101018-S
221 1
9101018-S
21
22
pin
Pin
i
i
221Sl213
22IS1187
221 1
221SI187
23
24
pring
Valve Housing
1
i
1011216
221Sl091
N266
S1091
25
0-Ring
i
91OV1113-S
2
16
See Table
19
glOV1113-s
lindicate spring setting when ordering by adding letters as shown in following tables.
SPRING SELECTION CHARTS
VALVE 22iRCV1000
221ncvlooo-
VALVE 22iRCV1001
DIFFERENTIAL
SPRING
SETTINGSI
INCHES
SPRING
221RCVlool-
221RCV1000-A
221RCV1000-B
500
1000
90CN2035
90CN2035
221RCV1001-A
221RCV1001-B
500
1000
90CN2038
90CN2038
221RCV1000-C
221RCV1000-D
1500
2000
90CN2035
90CN2036
2211`lcvlool-c'
221RCV1001-0
1500
2000
90CN2038
90CN2035
221RCV1000-E
22IRCV1000-F
2000
3000
90CN2036
90CN2036
221RCV1001-E
221RCV1001-F
2500
3000
-90CN2035
90CN2035
221RCV1000-G
22IRCV1000-H
3500
4000
90CN2036
90CN2037
221RCV1001-G
221RCV1001-H
3500
4000
90CN2035
90CN2036
221RCV1000-J
221RCV1000-K
4500
5000
90CN2037
90CN2037
221RCV1001-J
22IRCV1001-K
4500
5000
90CN2036
90CN2036
221RCV1000-1
221RCV1000-M
5500
6000
90CN2037
90CN2037
221 RCV1001-L
221RCV1001-M
5500
6000
90CN2036
90CN2036
-Valve
DIFFEREMIIAL
SPRNG
SM NGI
INCHES
requires one spacer.
47
SPRING
20
5-1z
Gas lift Equipment and Systems
GAS LIFT VALVE LATCHES AND DUMMIES
'ype M Latches - used in all '1pe RW Mandreis. Type T2
.atches - used in Type RL Mandrels. These are collet-type
atches desioned so that a niinimum force is required to pass
he collet into the lock recess. This feature is very important
vhere deviated wells prevent forceful downward jarring.
)uring installation, the collet moves up and deflects as it
asses the lock recess. Upward movement is designed
hear the running tool, causing the collet to nlove into pos
ion and be securely locked. When retrieving, a pin
;heared, allowing the latch body to move upward and t e
-ollet to defect. passing out of the lock recess.
well, expensive gas lift vaIves, installed above the fluid
level, can be replaced with dummies, blc>ck-ing off injecdon
gas. Dumn-lies are available in special materials, so indicate
service when specifying.
OTIS LATCHES
rype BK Latch - used in aU 1-inch lpe RW Side-Pocket
4andrels. This is a spring-loaded, ring-style latch. The lockng mechanism used is a spring-loaded ring that is designed to
ock i
pocket-locking recess of the mandrel. Latch can
)e inst*d with a rninimum of force. When retrieving, a pin
s sheared, allowing the ring to move upward and perrffltting
he valve to be pulled from the pocket.
rypes R and RA Latches-used in all sizes of RL mandrels,
-xcept Type RLF that uses Type R Latches only. Tbe locking
mechaffism for these latches is a spring-loaded rotating cam
hat is desi£!rted to lock in die pocket-locking recess of the
mandrei. They may be installed with a "nimurn of force.
When retrieving, a pin is sheared, and the latch-release pin
lifted to allow the latch cam to rotate frcely out of the way.
Both latches are identical in fun'ction: Type RA contains two
-xterior 0-rino seals and a shorter cam nose than the Type R.
In the Type RLC, RLE and RLS Ported Mandrels, the Type
n Latch is often used due to its inherently stronger 360' latch
retention.
o
2:
Type m
o
Type T2
Type R
OTIS GAS LIFT VALVE DUMMIES
Dummy valves are installed in side-pocket, gas lift mandrel
ireline to block the mandrel's injection gas ports.
Dumwcan be run prior to or after completion for testin9
tubing, packers and other equipment. In new installations,
dumrnics can be retained in the niandrel until gas lift valves
are required to maintain producfion. Dumrnies are pulled and
gas lift valves installedby wireline. Also during the life of the
Type RA
Type BK
GUIDE TO TYPE M, BK, T2, RA and R OTIS LATCHES
Otis
Assembly
Humber
Type
Material
Pulling Neck
Diameter/
lnches
Running Neck
Diameter/
Inches
Maximum
0.0.1
lnches
Pulling
Tool
Hunning
Toci
96MO2
210BOS
210803
m
BK
BK
Standard
Standard
Monel
.875
.875
.875
.750
.750
.750
1.328
1.358
1.358
40SM4
40SM4
96MO38
96MO38
96MO38
96CO5
96MOS
21OR03
BK
T2
RA
Standard
Standard
Standard
.875
1.375
1.375
.750
1.000
1.359
1.358
1.750
1.750
40SM4
40SM1
40SM1
96MO38
96MO37
96MO20
21OR01
210RO,1
21OR02
RA
R
R
Monel
Standard
Monel
1.375
1.375
1.375
1.359
1.359
1.359
1.750
1.750
1.750
40SM1
40SMI
40SM1
96MO20
96MO20
96MO20
NOTE: Caii OLs or s.z--s ad types not kste or write Dallas direct.
35
l
Gas Lift Equipment and Systems
CODE DESCRIPTION FOR OTIS WIRELINE SIDE-POCKET MANDRELS
Example: 211R
20401-1
Class number for mandrels
Wireline mandrel
Size valve to be set in pocket:
W - 1-in. 0.D. gas lift valve
L-
LJ L J
L
i. - withmi
poitioning sleeve and deflector
2. - With positioning sleeve only
3. - With deflector only
4. -With both positioning sleeve and defledor
11/2-in. 0.D. gas lift valve
5. -Two-pock-et
mandrel with both positioning
This space used to designate following:
C - Ported mandrel
F - Waierfi ood mandrel
S - Special external port outlet
X - Special clearance
sleeve and deflector
6. - Side-strin.- mandrel with both positioning
sleeve and deflector
Type threads (SeeThread Code)
Material and coating (See Material Code)
NOTE: When mandrels cannot fit this code due to variations
or features requested, a partially coded number will be assigned Aith a complete description of side-pocket mandrel
appearing on drawing or speeification shett.
Norninal size
20 - 2 inch
25 - 2112 i nch
30 - 3 inch
And other sizes sce Drift Code.
TYPE RW OTIS OVAL-0-D MA NDRELS - Dimensions and Code Drawings
c
A
_RTL_B_f
D
Drift
E
SIZE:
2-318-in..
2-71"n. 3-112-in.
CODEand2
CODE 1-,*ithout deflector or posnioninv -,Qeeve.
A
Defiéctor
CODE4-witIldeljectorandpositioningsieeve.
112,1
NPT
PORTING
VARIATIONS
11/2-
NPT
CODE F-waterflood mandrel. no pores.
11/2-
CODE C-ported ffiandrel.
NP-I
C00ES-ehamberliftniandrel.s~I~Iports.
DIMENSIONS
Type RW
Dimensions-inches
Tubing
0.D.Anches
Mandreil
Å(EU)
2-318 NU2-318
2-318
(With Posifioning Sieeve)
64
63
73
3.875
4.25
4.25
2-718
2-718
(With Posifionina Steeve)
63
73
3-112
3-112
(Wiih Positioning Sieeve)
4
Weight/
Pounds
D
E
F
2.90
2.90
2.90
1.901
1.901
1.901
1.027
1.027
1.027
1.027
1.027
1.027
60
64
74
4.75
4.75
3.56
3.56
2.375
2.375
1.027
1.027
1.027
1.027
90
106
64
73
5.62
5.62
4.37
4.37
2.
2.875
1.027
1.027
1.027
1.027
117
142
75
5.85
5.00
3.
1.027
1.027
185
4-112
75
6.05
5.00
3.375
1.027
1.027
185
4-112
77
6.62
5.35
3.833
1.027
I
1.027
185
'When specifying, ineludeport data. driftl.D.. material,thread typeandaccessoryitems. -Positioning sieevenotavailable. NOTE- Theaddition ofdefleclordoes nolaiter ;mensions.
For availability of additional sizes no'. isted, contact your local Ns Specialist or write Dallas direct.
32
-11
Gas lift Equipment and Systems
ul
il 21
l
OTIS TRU-GUiDE SIDE-POCKET TUBING MANDREL AND KICKOVER TOOL
The Otis Tru-Guide Side-Pocket Tubin- Nlandrel is designed for installing gas lift valves in tubin.- and still permits
a relative full opening through the mandrel. The Otis TruGuide Kickover Tool bas many exclusive features for ii3stal]ing gas lift valves and other subsurface controls iii deviated
wells by pumpdown as well as wireline techniques. Quite
often, several trips can be eliminated by running kickover
tools in tandem to pull and install gas lift valves.
0 Transfer guide rails are designed to prevent other service
tools from lodging on top of pocket.
0 Patented muleshoe alignment assembly is designed for
cngagement and orientation of kiekover tool.
0 Continuous stop shoulder is designed to prevent accidental
travel past mandrel.
0 Gas lift valves can be run in tandem with Tru-Guide kickover tools.
BENEFITS OF DESIGN PRINCIPLE
APPLICATION
* Full-opening, side-pocket tubing mandrel.
Side-pocket mandrels (with lensile strength greater than
the tubing) can be run in the initial tubing string of a flowing
well completion, so well can be converted to gas lift at a
future date without a major workover. Using pumpdown or
siandard wirelinemethods, kickovertoolscanberuntoinsert
or pull gas lift valves. Unique transfer guide rails in mandrel
and the pivot arm of the kickover tool are designed to insert or
pull gas lift valves straight in or out of the pocket to proteet
valves from bending.
0 Unique, flexible kickover tool for going around five-foot
radius loops in pumpdown instafiations.
0 Gas lift valves may be serviced by either pumpdown or
wireline methods.
-%
0 Exclusive full-length transfer guide rails in mandrel allow
gas lift valves to be installed and removed, utilizing
straight forces to help keep the kickover tool from bending
the valve.
ACTIVATOR
SHOUIDER
Step 1
Step 2
Step 3
Step 4
OPERATING DESIGN PRINCIPLE
These drawings illustrate how simple it is to install
a gas lift valve with Otis Tru-Guide equipment. Similar steps are used to retrieve the valve from the
side-pocket landing nipple.
Step 1 -After the kickover tool has moved through
the Tru-Guide Mandrei, it is reversed and moved
back up through the mandret. The spring-loaded
alignment key on the kickover tool orientation assembly (A) is designed to align the kickover tool and
hold it in the proper position to be activated.
B"
C.
Step 2 - Upward movement shears the first shear
fing on the actuator assembly (13), permitting the
pivot arm (C) to move out and lock at right angles to
the carrier tray assembly (IJI)for positioning on the
center line of the side-pocket landing nipple for setting or pulling the gas lift valve.
D
Step 3-Downward movement of the gas lift valve is
controlled by the transfer guide rails for a straight line
into or out of the landing nipple. A no-go on -the
locking mandrel locates the gas lift valve in the nipple. Continual downward movement releases lthe
locking keys, locking the valve in the nipple. When
pulling a gas lift valve, this downward action engages the pulling tool on the fishing neck of the
valve.
Z;
A.
B.
C.
D.
IRANSFER
-GUIDE RAIL
Step4-Aftersettingthe gas liftvalve (installing)or
engaging the valve with a pulling tool (reteving),
upward movement shears a second shear ring in the
actuator assembly (121),
unlatching the pivot arm and
allowing the kickover tool to move up and out of the
mandrei.
Kickover Tool Odentation Assembly
Aduator Assembly
Pivot Arm
Carrier Tray Assembly
SIDE-POCKET
LANDING
NIPPLE
-MULESHOE
otis
Tru-Guide
Side-Pocket mandret
34
SEQUENCE OF EVENTS
WELL 31/2-2.-KEST VENTURE
P.T.
DATE
T:1ME
CUTTING OF 5k"
15/8
no.
2
OPERATI:0N
GP-LINER AND RETR=ING OF SC-1 GP PACKER
00:00
POOH 3k` tubing and prod-. assy.
05:30
Rig up Schlumberger
06:00
Run Schlumberger CCL/GR-loggers,
Located
at
top of Production packer at
Rig down Schlumberger
09:00
Make up servco cutter
12:3k
Cut 5"
13:30
POOR cutter
liner
at
Continue POOH all
tool,
A set
of jars,
3 stands 6k`
Drill
collars,
5 STD HW and
Engage tool
into
pick up cut-off
POOH.
1564 m.
Overpull to work free.
Maké up packer retrieving
pipes.
RIB-
same hung up at
låy down cutting
Took 80 000 LBS.
21; 30
-
3 knives broken
5` drill
20:30
and assy.
1578.5 m
assy.
Took 70 000 lbs.
17:30
1550 m
30 cm low tide
08:30
14:30
T.D.1588.8 m.
RIHpacker.
overpull to
section.
tool
SEQUENCE OF EVENTS
WELL 31/2-2r
P.T.
DATE
TIME
OPERATION
16/8
01:00
Got all
WEST VENTURE
no.
2
cut-offs
-
including packer
01:00
Lay down jars.
a total
of 27.3 m
length.
packer and cut-off
PREPARING OF WELL BEFORE RUNNING GAS LIFT PROD.
03:00
of production equipment:
Replace
swivel on Otis
and replace
RIH with 2 7/8,
HW drill
hole
surface
connections
X-mas
on lubricator
valve.
30 m stinger,
pipe and 5` drill
pipe t6
clean out
from sand.
07:30
Rig up Dowell and filtercleaners
08:00
Tag sand at
circulate
Hydril
3 -
section.
STRING:
Service
tree
05:00
liner
1583 m -
shut hydril
and wash down to 1589 m with
closed.
4 bbl/min and 400 -
and cleaning brine
50 litre
and reserve
25 -
480 pump press.
5 -
2 microns
approx.
sand retn.
17:00
Rig down Dowell,
POOH and lay down 2
19:00
Rig up Schlumberger
19:30
Load perfo.
20:30
Perforated
7/V
guns.
interval
2 118` hyperdome
1570.scallop
22:30
Rig down Sdhlumberger
23:00
Make up 9 5/V
1575 m with
guns,
casing scrapper
4 SPF.
stringer.
13
SEQUENCE OF EVENTS
WELL 31/2-2,
P.T.
WEST VENTURE
n6.
2
DATE
TIME
OPERATION
17/8
00:00
RIH with scrape and 2 7/8` tail
02:00
Scrape interval 1540 -
02:30
Rig Up chicksand and circ.
03:00
Lower string with tail
pipe below
1576 m
head
pipe to 1589 m.
Reverse out with 400 psi pump pressure.
No more sand returns
04:00
POOH
06:00
Rig up Schlumberger
06:30
Schlumberger run gauge ring and junk basket
to 1579 m.
Than pull out same
RUNNING OF PACKERS AND PRODUCTION STRING:
07:30
Pick up model "DB` packer and run it
with
Schlumberger.
Set it
at 1576 m
09:30
Rig down Schlumberger
10:00
Make up tail
pupe for SC-1 packer.
te'st to 3000 p!si for 15 min.
Pressure
Rig up Otis
wire-line and retrieve S-1 plug
14:00
Rig down Otis wire-line
15:30
RIH with SC-1 padker and tail
17:00
Make up circ.
head and chicksand.
slowly with 50 psi.
assy.
into "DB` packer.
Pressure increase to
Bled off same.
out tUbing to get tubing in
BOP-stack drop ball.
stages:
1800 psi.,
800 psi,
Circulate
Obsurve entry of seal
200 psi upon entering.
in
pipe assy.
the right position
Pressure test
1000 psi,
Space
1300 psi,
in
1500 psi,
SEQUENCE OF EVENTS
WELL 31/2-2,
WEST VENTURE
P.T.
DATE
T=
OPERATION
17/8
17:00
Shear tool.
no.
2
.....
Packer is
set
at
loggers and 1518.5 m Drl.
Pressure test
release
-
of setting
tool
500 psi
14 x
for
ri.ght for
15 min.
retracting
tool
19:00
POOH and lay down setting
20:30
Mak,e up 201,
shoe,
depth
annulus to
setting
1520.5 m.
32"
tool
G22 locator
seal
tubi,ng,, 3"
assy.
"XA-SSD`
with mule
and 5"
VAM
tubing.
18/8
00:00
Continue RIRwith 5` VAM tubing on 5` drill
pipe to
SC-1 packer to
05:00
Pressure test
05:30
POOH with 5` drill
06:00
Space out 5"
annulus too 500 psi.
pipe
VAM tubing.
Adding 1 PUP-joint.
release
test
3000 psi,
space out same.
Pressure up EZ tree
and pressure
test
lines
for
to
.
RIH with 4k"
rise-r with control
lines.
Testing every tubi.ng conn.
Kooke up X-mas
15:00
Stabe into
and surface lines.
SC-1 pc-cker.
Landed EZ-tree
casing to
tree
in
well head
and pressure
test
500 psi.
PRESSURE TESTING OF SURFACE. EQUIPMENT ON RIG FLOOR.
18:00
Pressure test
line
BOP.
wire-line
Difficulties
lubricator
and wire-
due to leaks.
SEQUENCE OF EVENTS
WELL 31/2-2r WEST VENTURE
P.T.
no.
2
DATE
TIME
OPERATION
PRESSURE
TESTING OF PRODUCTION STRrNG
19/8
00:30
Rig up Otis wire-line
00:45
RIH with 2` drift
01:30
Rig up N-type
test
01:45
Pressure
wire-line
02:00
RIH with N-type
POOH.
03:00
03:30
test
with 2.2` drift.
to 1590 m
tool
test
Hang up in
tool
tools
Covere in
pipe dope
Hang up in
Diam.
diam.
04:30
RrH with S-1 plug
valve
rD obstruction
Loadcell stucy when pull
Set at
1580 m in
Ri.g up pulling
tool
05:45
Pressu-re test
tubing
over 250 LBS.
for
S-1 plug
S-1 plug leakihg at
1500 psi
RIH with 2`
retrieve
`RS` to
S-1 plug stuch at
Jaring
1580 m
with 750 LBS and shear off
11:00
POOH with `RS`
tool
11:30
Make up 2.313`
"B"
To close
"XO
= 2.74".
S-1 nipple
05:30
06:00
EX-tree valve
valve.
of impression:
Rig up S-1 plug
to 3000 psi
2.78".
lubricator
04:00
stuch in
lubricator
Recovere
RIH with lib.
lubricator
SSD"
shifting
tool.
`RS` tool
RIR.
14
SEQUENCE OF EVENTS
WELL 31/2-2,
P.T.
DATE
TIME
O.PERATrON
19/8
13:30
Pressure test
WEST VENTURE
no.
2.
production string
against S-1 plug to 3000 psi
14:00
RIH with 2` `RS',
hyd.jars.
PRESSURE TESTING OF EQUIP.
prong,
101
latch on S-1 plug.
x stem and
POOH
FROM X-MAS TREE TO BURNERS:-
17:10
Pressure test
against choke manifold,
linlet
and b'
ves:
5000 psi.
.ypass val
17:17
Pressure test
against sandtrap outlet and
bypass valves:
17:30
Pressure test
5000 psi
against Thornton manifold inlet
and by-pass valves:
17:40
Pressure test
Pressure test
5000 psi
bypass sand trap.
choke manifold
18:08
Pressure test
valve:
18:17
18:30
Pressure test
valves:
19:05
and by-pass
heater coils against outlet
1400 psi
Pressure test
Pressure test
in
5000 psi
heater inlet
separator inlet,
and gas bypass valve:
18:40
back to
3000 psi
Pressure test
valve:
5000 psi
against Thornton manifold
body complete:
18:00
5000 psi
against Thornton manifold inlet
and outlet valves:
17:50
sandtrap
oil
by-pass
2000 psi
automatic high pressure pilot
automatic shut down system.
Pressure test
separator vessel against oil
and gas outlet valves:
1300 psi
SEQUENCE OF EVENTS
WELL 31/r2-2,
P.T.
WEST VENTURE
2
DATE
TIME
OPERATION
19/8
19:11
Pressure test separator safety valves
19:12
Lift at 1500 psi
Retest separator vessel to check valve
19:28
seating:
1300.psi
Pressure test oil-lines against burner head
valves.
19:38
Leak at.Weco-union
Retest oil lines:
1500 psi
Waiting to start acidizing.
Will start
t6 f low well in day-light and
do azidizing just before.
THIRD RE-ACIDIZATION JOB ON THE OIL ZONE:
20/8
00:45
Rig up wireline and RIH with `B` shifting
tool.
Open W' XA-SSD at 1553.46 m.
POOH
Wireline operator open up SSD at 1553.46 m
instead of SSD at 1506.93 m.
after order from
Shell services supervisor
02:00
Change `B` shifting tool.
RIffand close bottom 3k` XA SSD
03:45
POOH
Rig up 'W' shifting tool
RIH and open top 3," XA SSD.
05:05
POOH
Pump 10 BBLS diesel, 21 galls tretolite and
42 galls UGG initial/final
pump pressure = 500 psi
Fluid rate = 1.5 BBLS/min.
05:12
Pumpe 20 BBLS 15% HCL
84 galls UGG and 9 galls A-200 initial/final
pump pressure = 20,0 psi
Fluid rate
0.8 BBLS/min
SEQUENCE OF EVENTS
WELL 31/2-2,
WEST VENTURE
P.T.
no.
2
DATE
TIME
OPERATION
20/8
05:30
Pumpe 10 bbls diesel
initial/final
= 1.2 BBLS/min.
Pump 37 BBLS diesel
initial/final
pump pressure =
Fluid rate
Static
650 psi
= 4.5 BBLS/min
THP =
close
550 psi
upper 3k` XA-SSD
Pressure
06:35
UGG.
pump pressure = 400 psi
Fluid rate
05:38
and 42 galls
test
annulus to
500 psi
Dicplåce and bullhead fluid
After
17 BBLS of diesel,
from a
steady rate
to
800 psi
It
came back to
for
15 min.
with 62 BBLS diesel
the pressure drop
of 1625 psi
and 0.5 BBLS/min.
over 45 seconds.
1624 psi
with same rate
0.5 BBLS/mi.n.
Pumpe a
total
of 40 BBLS with 0.5 BBLS/min and
pump pressure =
The excess of
1625 psi.
22 BBLS with 1 BBLS/min and
final
pump pressure
Start
to
= 1700 ps,i
FIRST FLOW PERIOD:
09:35
flow
next pagel
(See "Otis field
readings` on
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C>O
OTIS
`SAFETY SHUT DOWN"
SYSTEM PÅ WEST VENTURE
4
V5b
SEM 12A-r0 ?C
7=7)
SF-fAJM-TOk
WPICAU-115 k
ir-
k)
p P,-4 U L-
i5
~TAK
Do
4 VF7'-
k-,
Vrs
Stiger
trykket
ved inntaket
åpner high-pressure-pilot
trykk
det
fØrer
reservoaret
vil
da
at
flow
st-enge.
Otis test
automatisk
til
fra
til
kontroll
head
(Di.sse
separator,
til
atmoferisk
ventilen
åpner
`flow-valve`
og
ventilene
må
til
`master
ha
trykk
en
stenge
valve
for
å
åpnes).
På
`rig-floor"
og ved
SIKKERHETSYSTEM
Det
er
ventiler
ventilene
etter
av
typen
skal
det
montert
kan
manuelt.
PÅ OTIS'SEPARATOR:
Ønske'fra
"Rupture-disc`
er
separator
Shell
"Farris`
åpne
på
på
1460
på
separator
en
3"
instalert
linje
to
sikkerhets-
separatoren.
psi.
fra
Det
Begge
er
incjen
sikkerhetsventilene
med uttak
under
platformen.
PROBLEMER MED OTIS S-1 PLUG
Ved nedkjØring av S-1 plug,
det
påvist
Pluggen ble
testes
til
feil
for
test
av prod.
ved dybde-indikatoren
så satt
i
3000 psi.
S-1 nippelen.
i
string,
110tis W/L winch".
Strengen skulle
En oppn4dde kun et
deretter
S-1 plugen igjen.
trykk Økningen.
Etter
en tid
steg
FØr denne trykktesten
En påviste
da en del forurensing.
pluggen.
på 750 LBS.
Uten å oppnå den forventede
3000 psi.
Dette kan muligens være
trykk--
trykk på 1500 psi.
Ved trekking av pluggen måtte en bruke en jar-kraft
Satte
ble
trykket
ble det
årsaken til
og en oppnådde
kjØrt
"Drift-run
Blant annet en del DOP.
problemene'med
S-1
PROBLEMER MED FLOPETROLS
SSTT fra
Flopetrol
er
SSTT
utstyrt
med injiserings-system
for
Glykol.
Etter
oppstart
En antar
at
utaksventilen
e,tter
at
fikk en problemer med pumping av Glykol.
grunnen kan være forurensningi`linjen
i
Glykol
plugget
SSTTr
linjen
har fått
skade ved ned-kjØring.