WELL CONTROL Test 05 English
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Transcript of WELL CONTROL Test 05 English
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WELL
CONTROL
Examples
(English)
05
WELL
DATA
The
well
has
been
shut
in
after a
kick
The
wellwill
be
killed
using
the
wait
and weight
Method
at
30
spm
Answer
the
I'ollowing
nine
questions
from
the
data
above.
The
attached
kill
sheet
may
be
used
to
assist
you
with
youn
catculations
Hole
size
12-114.
Capacity:
36.61
l/m,
(0.0702
bbl/ft)
Hole
depth
(lyukm6lvs6q)
2012m
TVD,2391
m. MD
Casing
13-3/8
inch,
Shoe:
1463
m
TVD.
1579
MD
Drill
Pipe
5 ,
19,5lb/ft.
Capacitv
=
9.23 l/m
Heavy
Weight
Pipe
(HW)
Drill
Collar
(DC)
8
x
3 inch,
CapacitV=
4.50llm,
Lenqth:162m
Pump
(szivattv()
18.9
liter/stroke
Kill Pump
Rate
30 bar
at 30
SPM
Volume
Open
Hole
to,
Collars
(oH-DC)
43.6llm
Volume
Open
Hole
to
Drill Pipe
/
HWDP
(OH-DP/HW)
63,4llm
Volume
Casing
to Drill
Pipe
(CSG-
DP)
70.6
l/m
Mud
Weiqht
LA
kstl
Leak-off
test
at 13-3/8'
casing
shoe
(with
1.27
koll
densitv)
69
bar
Pit
Gain
1900
lires
Shut
in Drill
Pipe
Pressure
(srDPP)
23bar
Shut
in
Casinq
Pressure
(SICP)
28bar
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WI=LL
CONTROL
Examptes (Engtish)
05
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WELL
CONTROL
Examples
(English)
05
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WELL
CONTROL
Examptes
Engtish)
0b
1
What
is
the
kill
mud
weight?
kg/
2
How
many
strokes
are
required
to
pump
kill
mud
from
surface
to
bit?
strokes
3
How
many
strokers
are
required
to
pump
from
the
bit
to
casing
shoe?
strokes
4
What
is
the total
arnnular
volume?
litre
1.
What
is
the
MAASP
at
the
time
the
well
is
shut in?
bar
2.
What
is
the
Initial
Ciirculating
pressure?
bar
3.
what
is
the Final cinculating pressure when
kill
mud
is at
the
bit?
bar
4.
what
is
the
MMSP
at
the
time
the well
is
killed
with
heavy
mud?
bar
bar/100
strokes
10
The
following
statelment
describes
one
of the
differences
in
behaviour
between
drilling
with
Oil-bar;ed
and
Water-based
mud.
While
circulating
out
a kiclk,
gas
expansion
occurs
in
the
annulus
at
the
same
rate
in
oil
and
water-based
mud.
tr
False.
E True.
5.
What
is
the drill
pipe
pressure
reduction
per
100
strokes
as
kill
mud
is
being
pumped
to
the bit?
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WEILL
CONTROL
Examples
English)
05
11
Which
of the following
drilling
practices
should be considered when
connection
gas
is
noticed?
TWO
ANSWERS)
tr
Control
drilling
rate
so that
only one
slug of connection
gas
is in
the
hole at
z
afry
one time.
Minimise
the
tinre during
a
connection when
the
pumps
are switched
off.
Raise
the
mud
yield point.
Pump
a low viscosity
pill
around
bit
to assist in reduction
of balled bit or
stabilisers.
Pull
out
the
hole
to
change
the
bit.
tr
tr
tr
12
How
should the
choke manifold
be set up for
the HARD SHUT lN
procedure
while
drilling?
tr
BOP
side outlet
Hydraulic
Valve
Closed.
Auto
Choke
Opren.
Valve
Upstrearn
Mud-Gas
Separator
Open.
tr
BOP
side
outlet Hydraulic
Valve
Open.
Auto
Choke
Opren.
Valve
Upstrearn
Mud-Gas
Separator
Closed.
BOP
side outlet Hydraulic
Valve
Closed.
Auto
Choke
Closed.
Valve
upstreanr
Mud-Gas
Separator
Open.
BOP
side
outlet Hydraulic
Valve
Open.
Auto
Choke
Closed.
Valve
Upstrearn
[t/Iud-Gas
Separator
Closed.
tr
13
Shut in Drill
Pipe
Pressure
is required
to calculate which
of the following
pre-ssures?
VFormation
pressure.
tr
Shoe
pressure.
tr
Hydrostatic
pressure.
E
Fracture
pressure.
14
It
is
known
that
the
solubility
of
gas
in
oil based or
water
based
mud can lead
to
a
difference
in shut
irr well
data
following
a kick under
identical
conditions.
Which
of
the following
statements
is correct
if
this ditference
in well
data occurs
when using OIL
BI\SED
DRILLING MUD?
ryvo
ANSWERS)
EI
The
shut in
casing
pressure
will
be lower.
tr
The
shut in
casing
pressure
will be higher.
in
casing
pressure
compared
with water
tr There
will be no difference
in
pit gain
compared with
water based drilling
mud.
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WE:LL
CONTROL
Hxamptes
(English)
05
15
What
is
tne
pntn4,
tr
The slow circulating rate pressure
used
in
the
kiil
process.
tr
The
use
of
BOlps
to shut
in
a
wellthat
is
flowint.
*Il ^:::
glpit
capacity
and
flow
rate
measuring
devices
to
recognise
a
kick.
E4
Ine
use
of
mud
hydrostatic
to
balance
fluid
pressure
in
the
formition.
16
A
vertical
well
has
been
drilled
to
a
depth
of 2,500
metres.
Overbalance:
Mud
gradient:
Casing
capacity:
11bar
r-----
J
--
ll'e:
-kflir^s
0,1666
barlm
\
64,
3,r^ i
Fr,n * n ..
,,
\
\)
w/,
J/qr' h .n
r:::
-----r
V
o/.,8
4t*
t/
)8
4/i
2llm
Drill
pipe
metal
displacement:
4.pVm
/x.--
/,G=
r,o3lr' y
-_)/=
4,6
-q.oto?T4
How
many
complete
stands
can
be
puiled
dry
before
the
weil
flows?
(Assume
one
stand
equals
27
m\.
@r-G-.t no,
D
46
stands
-@--
47
stands
\
---=-
fr\G
f
Oa.r.t
q4
t_n.
's
p
6
WELL
DATA
I
Pipe
Capacity
Drill
Pipe
Metal
Disprlacement
Average
Stand
Length
9.3l/m
4:3llm
28.3
m
calculate
the
mud
nlquired
to fill
the
hole
per
stand
when
pulled
'dry'?
18
A
well
is
being
killerd.
I
gng:::yf l:
f,.pt
ant.at.31
bar
and
the
pump
speed
at
30
SpM.
Halfway.through
this.rrrst
crrculation,
the
operator
on
the
choke
observes
a
sudden
increase
in
drill
pipe
pressure.
There
is
no
signifi. nt.n nge
in
choke
pressure
and
the
pump
speed
is
still
30
SpM.
What
could
have
hiappened?
(TWO
ANSWERS)
tr
Pressure
has
bruilt
up
in
the
mud/gas
separator.
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WELL
CONTROL
Examples
(English)
05
19
which
of
the following
actions
taken
whilst stripping
driil
pipe
into
the hole
will
help
maintain
ern
acceptable
bottom
hole
pressure?
(Assume that
therer
is
no influx
migration),
d
aeea
offthe
drill
pipe
closed
encl
displacement
at regular
internvals.
tr
Pump
a volume
of mud
into
the well,
equal
to the
drill
pipe
steel
displacement,
at regular
intervals.
tr
Pump
a
volume
of mud
into
the well,
equal
to the
drill
pipe
closed
end
displacement
at regular
intervals.
tr
Bleed
otf
the
drill
pipe
steel
displacement
at regular
intervals.
20
Which
of
the following
conditions
increase
the risk
of creating
surge
pressure
when
running
a drill string
into
a well?
(TWO
ANSWERS)
E-
Large
annular
clearance.
Efl
Small
annular
c;learance.
E-Low
viscosity
and
gel
srength
of the drilling
mud.
El-
High
viscosity
and
get
strength
of
the drilling
mud.
tr
Large
sized
no:zzles
in the
drill
bit,
tr
Running-in
Sp€€d
greatly
reduced.
21
The following
statement
describes
one of the
differences
in behaviour
between
drilling
with
Oil-based
and
Water-based
mud.
Gas
is more
soluble
in
water
based
mud than
oil based
mud.
{ra .
tr True.
22.What
are
the main
conrditions
to
determine
the kill
pump
rate?
(FO,R
ANSWER)
Et,
Barite
mixing
ciapacity
M
The
capacity
ol'mud-gas
separator
tr
The
casing
burst
prsesups,
ErThe
mud volume
in
the trip
tank,
V-The
choke
capiacity,
Ef
The
annulus
pressure
loss.
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WI=LL
CONTROL
llxamptes
(Engtish)
05
23
Calculate
tne
reduc
the
following
well:
Verticaldepth,
Surface
to
200
m,
200 -
400
m,
400
m
to
bottom,
Original
mud
density,
1,900
m
tr
Tbar
E,2bar
Msbar
A.well is being
kilhed.using
the
Drillers
method.
At
a
given
moment
the
Standpipe
pressufe
is
60
bari
at
30
SpM.
The
pressure
insicle
the
Mud/Gas
Separator
is
increasing
and
it
is
decided
to
reduce
the
pump
rate.
what
is
the
effect
on
bottom
hole
pressure
if
60
bar
is
maintained
on
the
Standpipe
while
the
pump
rate
is ieduced?
=
Bottom
hole
pressure
will
remain
unchanged.
I
Bottom
hole
pressure
will
decrease.
M
Bottom
hole pressure
will
increase.
Which
of
the
follornrin
formation
strenght
at
hoe?
proximailey
100
ft.
below
the
well
head.
26
A
kill
operation
is
rea
The kill mud is
reacly
rokes
to displace
surface
lines.
What
action
has
to
be
taken?
tr
lgnore
the
130
strokes.
lt
will
not
affegt
the
drill
pipe
pressure
graph,
and
if
J filing,
it
will
ty
factor.
EI
Re-Zero
stroke
Et
suostraciitre'i
:t?T[ir:1"s
and
r+draww
drirl
pipe
pressure
graph.
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WEIIL
CONTROL
Examples
(English)
05
while
circulating
out a
kick,
the
mud
pump
fails.
what
is
the
FIRST
action
to
take?
E
-Divert
the well.
E(
Sfrut
the
well
in.
tr
Change
the
purnp
as
soon
as
possible.
28
while
drilling
along
at a
steady
rate
the
Derrickman
asks
if
the
pumps
can
be
slowed
down
so
that
the
shakers
can
handle
the
increase
in
cuttings
coming
back
in
the
mud
returns.
What
would
be
the
safest
course
of action?
tr
Chek
for
flow
-
if none
then
continue
at the
same
rate
allowing
the
excess
to
bypass the shakers
and
get caught
in
the sand traps that
caribe
dumped
later,
tr.check
for
flow
-
if
none
then
return
to
the original
drilling
parameters.
M
Check
for flow
- if none,
then
circulate
bottoms
up
at a rebuced
rate
so
that
shakers
can
handle
cuttings
volume,
frow-check
periodically
during
circulation.
tr
slow
down
the
mud
pump
untilthe
shakers
can
handle
the
capacity
of
cuttings
in
the
returns,
as
requested
by
the
Derrickman.
29
which
of
the
followiing
situations
ls
Nor
a warning
sign
that the
well may
be kicking
while
drillling?
El,Pit
gains.
Ef
Decrease
in
pump
strokes.
tr
Decrease
in
purnp
pressure.
tr
Flow
rate
increase.
A
Driller
is
preparing
to
pull
out
of
the
hole
and
has lined
up to
the slug
pit.
He intends
to
pump
a 3000
litres
heavy
slug,
followed
by 1500
liter
ot-Oiitting
muO
from
the
active
pit.
Calculate
how
far
below
the
surface
the
level
will
drop
insie
the
drill string
after
the
slug
has
been
erllowed
to fall
and the
weil
has
equalised.
WELL
DATA
Depth of hole (RKB)
Drilling
mud
weight
Heavy
slug weight
Drill
pipe
capacity
Surface
line
volumel
2800
m
1.46
kg/l
1.74
kgll
9,.1 l/m
1000
|
4
-/
)-
6Z,A
56m
63m
335
m
80m
c)
D)
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WIELL
CONTROL
Examples
(Engtish)
05
31
lf
mud
flows
from
a
the
pump
is
starteld,
what
is
the
problem?
_E
The
pump
needs
to
be
repaired.
5f,ylp
pressurc
is
greaterthan
mud
hydrostatic
pressure
Elr
-rne
annurus pressure
losses
are
creating
an
overbalance
against
the
formation.
tr
Mud
hydrostatic
pressure
is
greater
than
formation
pressure.
32
Does
a kick
alway's
occu
ight
reduction
noted
on
the
weight
and
the formation
pressure.
ial
kick
zone.
33
In
order
to
maintai
the
mud
weight.
How
will
this
affect
the
MAASp?
tr
MASSP
will
stiay
the
same.
trr'
MASSP
will
inr:rease.
Ef
MASSP
will
dercrease.
34
Under
which
of
thel following
conditions
should
a Driller
consider taking
a
slowcirculation rate
prerssure?
(TWO
ANSWERS)
e.
35
Indicate
whether
the.following
statement
relates
to
the Driller,s
Method
or
the
Wait
and
Weight
lVtethod.
It
removes
the
infrurx
from the
hore
before
pumping
kiil
mud.
{
Drill r' Methocl,
tr
Wait
and
Weight
Method.
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WELL
CONTROL
Examples
(English)
05
36
What
is
the
safest
action
a
E-lncrease pump
speed.
M
Flow
check.
tr
Circulate
bottoms
up.
tr
Reduce
weight
on
bit.
Driller
can take
after recognising
a drilling
break.
Which
of the
follornring
increase
the
risk
of
swabbing?
(THREE
ANSWEFIS)
Ef-Viscous
mud.
d
gatteO
up
Stabilisers.
tr
Low
permeabiliity
formation.
tr
_Spiral
drill
collarrs
in
the
BHA.
ff
Tripping
out
too fast.
^
(TWO
ANSWERS)
ff
Pump
out
of
thr: hole
on
trips.--
9 Flaf
a+
mvA
nqLi
E,.Use
a heavy
wreight
mud
to
crate
maximum
overbalance.
'
Ef
Drill
a
pilot
holer
at
a slow
controlled
rate.
tr
Maintain
high
rate
of
penetration
to ensure
mud
viscosity
level
is as
high
as
possible.
tr
Use
an
oil
based
mud.
which
one
of
the following
well
contror
probrems
requires
the
pump
to
be
shut
down
quickly
to
prevent
over-pressuring
open
hole
formaiion6?
tr
A
pump
liner
wiashout.
tr
A
washout
in
thre
choke
manifold,
tr
A
washout
in
the drill
pipe.
tr-A
plugged
bit
nozzle.
Ei
A
plugged
cholle.
tr
A
lost bit
nozzle,
37
39
40
ls
it
true
that shallow
gas
kicks
are
easier
to
handle
than
those
taken
after
deep
drilling?
{*o.
tr
Yes.
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WELL
CONTROL
Examptes
(Engtish)
05
@
(TWO
ANSWERS)
tr_olprbory
Methyt
Celtutose
(CMC).
Ef
Methanot.
tr;
Diesel
oil.
#Gtycot.
tr
Water.
42
W i9
gril. r9: whir:h
of
the
following
situations
make
kick
detection
with
a
P.v.T.
(pit
Vorurne
Totalizer)
moie
difficutt
toitne
Jritterz
kers.
43
which
of
the
foilowing
may
be
an.
earry
warning
of
abnormar
pressure
at
constant
notary
RF'M,
constant
woB
ino
consiani pump
ratez
ns.
hakers.
A kick
has
been
tal<en
and
it
is
known
that
a
potential
lost
circulation
zone
exists
in
the
open
hole.
select
the
correct
actions
that
can
be
taken
to
minimise
pressure
in
the
annulus
during
the
kill
operation.
choke
for
safety.
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WELL
CONTROL
Examples
English)
0S
45
lf
a shallow
gas
flow
is
detected,
which
of the following
steps
should
be
taken
as
the flow is diverted?
./
Ef
Increase
pump
rate.
tr
Decrease
pump
rate.
tr
Maintain pump
rate,
46
why
is
pressure
build
up
in
the
Mud
Gas
separator
poor
Boy
Degasser)
dangerous
while
circulating
out
a kick?
tr
Pressure
build
up
will
increase
the risk
of lost
circulation.
tr
Pressure
build
up will
affect
ability
to
make
choke
adjustments.
trrPressure
build up may allow gas
to
be
brow up
the dbrrick vent line.
Ef
Pressure
build
up may
allow
gas
to enter
the
shale
shaker
area.
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1.
WELL
CONTROL
Examptes
(Engtish)
05
EQUIPMENT
Using
the
BoP
configuration illustrated
in
Figure below
answer
the
following
six
questions
by
ticking
the
yES
or
NO
box.
1 ,
With
the
wellahut
in
Gder
pressnre
on
s
the side outlets
of
the drilling
ipool?
ONo
{r
With
no
drillpipe
in
t
change
the
3-112',
rams
to
S
rams?
d
y .
ONo
With
the
well
shut
i
safety valve
in
the
ms
to
variable
bore
rams?
ONo
C ,
4
With
the
well
shut'n
blind
rams
to
5
pipre
rams?
'
d
.
ONo
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WELL
CONTROL
Examples
(Engtish)
05
with
the well
shut
in on
5
pipe
rams
under
pressure,
can
the
annular
element
be
replaced?
Q/Y t
ONo
with
the well
shut
in
on 5
pipe
rams
under
pressure,
can
the
manual valve
on
the
choke
line
be
rreplaced?
O
Yes
e/rtro
Figure
420-0008
illustrates
a Bop
Hydraulic
control
Unit.
some
components
have
been
numbered
Match the correct numbers to the component descriptions below
O
4O
Annular
preventer
reducing
and regulating
valve
O
4
Accumulator
pressure
gauge
O
,6
Automatic
hydro-pneumatic pressure
switch
O
4
4-wary
valves
O
4?
Annular
Preventer
UniURemote,,switch
o
t{
By-pass
valve
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WELL
CONTROL
Examples
(Engtish)
05
what
is
the
usabre
fluid
vorume
of an accumurator botfle, according to
Apl
requirements?
./
@f
fte
volume
of
fluid
recoverable
from
an
accumulator
bottte,
between
the
accumurator
.perating
pressure
and
200
psi
iuo*1ne-nottre
pre_charge
pressure.
o
The
volume
otf
fruid
recoverabre
from
an
accumurator
botile,
between
the
accumulator
operating
pressure
minus
zoo
psiano-
pr --.i., rg
pressure.
o
The
total
vorurne
to
be
stored
in
the
accumurator
botfle.
I
During
a
routine
tr
one
of
the blowout preventer bonnets
is
leaking flui
What
action
should
be
taken?
o
Ram
packing
erements
on
the
ram
body
are
worn
out,
reprace
immediatery.
O
A
leak
here
is
normal
because
the
metalto
metal
sealing
face
in
the
bonnet
needs
some
lurbrication
to
minimise
damage.
---
--- v
o
The
weep
horer
only
checks
the
crosing
chamber
seals,
reave
it
tillthe
next
maintenance
schedule.
O
Energise
emergency.packing
with
plastic.
lf
leak
stops,
leave
it
till
the
next
maintenance schedule
I Primary
ram
shaft
sear
is
leaking,
secure
the
weil
and
reprace
immediatery.
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WELL
CONTROL
Examples
(English)
05
10
which
of
the
folloraring
dimensiones
is
the
primary
factor
in
limiting
the
maximum
working
pressure
of
the mud/gas
separator
in Figure
n+l-ooolz
MUD/GAS
INLET
MAIN
BODY
SHAKER
TANK
i
O
),
-
the
height
of
the
main
body.
G/
H2
-
the
height
of
the
dip
tube.
O
H3
-
the
total
hr:ight
of
the
vent
line.
O D4 -
diameter
of
the
inlet
pipe.
DERRICK
VENT
LIINE
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WELL
CONTROL
Examples
(English)
05
11
Figure
Al
l-0001
illustrates
a U-Type
Ram
BoP.
Some
components have
beennumbered.
Figure
A11-0001
Match
the
correct
numbers
to
the
component
descriptions
below.
O
^L_
Ram
change piston
O
8-
Ram
change
cytinder
O
S
Bonnetseal
O g_
Lockiing
Screw
housing
O
b_Bonnet
bott
O
40
Interrnediate
flange
A
BoP
hydraulic
control
unit
accumulator
bank
has
g
cylinders:
-
Cylinder
capacity ('Nitrogen
Fluid)
-
37.g
liter.
Accumulator
pre-charge
pressure
-
69
bar.
Accumulator
opererting
pressure
-
2A7
bar
Minimum accumulator operating pressure
-
g27
bar?
calculate
the
total
usable
fluid
volume
for
the
accumulator
bank?
A)
167
liter
B)
252liter
C)
102
liter
D)
151
liter
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WELL
CONTROL
Examples
(English)
05
13
what
is
the
main
function
of the
choke
in
the
overall
Bop
system?
I To
hold
back
pressure
while
circulating
out a
kick.
O
To
shut
the
welll
in
softly.
O To
direct
wellbore
fluids
to the
mud/gas
separator.
O To
direct
hydrocarbons
to
the
flare.
14
lflhe
air
pressure
gauge
on
the remote
Bop
control
panel
reads
zero,
which
of
the
following
steltements
is
true?
O
All
stack
functions
can
be
operated
from
the
remote
panel.
O
choke
and
kill
line
valves
can
stiil be
operated
from
the
remote
panel.
orThe
annular
preventer
can
still
be
operated
from
the
remote
panel.
d tto
stack
function
can
be
operated
from
the remote
panel.
On
a Driller s
air
oprerated
panel
on a
surface
installed
BOP
a ram
close
function
was
activated
and
lthe
following
observations
were
made:
_
Green
light
went
out.
Red light came
on.
Annular
pressure
did not
change.
Manifold
pressure
decreased
and
after
a
while
returned
to
its
original
position.
Accumulator pressure
decreased
to
2500
psi
and remained
steaiy,
What
is
the
cause
of
thre
problem?
The.
selector
(opererting)
valve
(3
position/4
way
valve)
is
stuck in
the
open
position.
Th.ere
is
a blockage
in
the
hydraulic
line
connecting
the BOP
to
the BOp
control
unit.
There
is
a leak
in
the
hydraulic
line
connecting
the
BOP
to
the BOp control
unit.
Electric
position
switches
are
malfunctioning.
The
pressure
switch
or
the
pumps
on
the
BOP
control
unit
are
malfunctioning.
t
b
o
o
o
o
o
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WI=LL
CONTROL
l-xamptes
(Engtish)
05
16
what
is
the
purpos"
9r^t q
"by-pass"
button
on
the Drillers
remote
control
panel
on a surface
BOp
intallation?
o To
increase
the
annular
pressure
to
the
existing
accumulator
pressure.
dto
increase
tl"re
manifold
pressure
to
the
existing
accumulator
pressure.
O To
increase
tl"re
manifold
pressure
to 2,000 psi.
O
To
inorease
the
accumulator
prelssure
to
3,000
psi.
which
of
the
follouving
statements
about
ring
gaskets
are
correct?
(TWO
ANSWERS)
O
Ring
gaskets
may
be
used
severaltimes.
drtyo"RX
and
l3X
ring
gaskets
provide
a
pressure-energised
sear.
I
Only
BX
ring gaskets
can
be
used
with
BX
type
flanges.
o
The
same
material
speciflcations
apply
to
ring
gaskets
as
to
ring
grooves
17
18
What
is
the
purpose
of
the
master
control
valve
on
an
air
operated
remote
Bop
control
panel?
O
Adjusts pipe ram closing
pressure.
o
Activates
the
erectric
circuit
for
the
open/crose
rights.
O
Activates
the
air
circuit
at
the
panel.
@
Activates
the
hydraulic
fluid
circuit
at the
panel,
.--)
(
19
when
annular
Bops
are.
hydraulically
pressure
tested,
if
often
happens
that
the
test
pressure
cannot
be
kept
steady
ituring
the
first
attbmpt.lrrey
have
to
be
charged
up
two
or
more
times
before
an
aiceptable
test
is
obtained.
Why
is
this?
@
Annular
BoPs
always
leak
until
the
packing
element
finds
its
new
shape.
This
motion
can
take
several
minutes.
The
packing
urrit
elastomer
is flowing
into
a
new
shape
because
the
rate
of
flow
is
influenced
by
the
applied
preisure.
The
compressibility
of
the
hydraulic
fluid
from
the
hydraulic
control
unit
below
the
closing
piston
causes
the
test
pressure
to
drop.
o
o
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WELL
CONTROL
Examples
Engtish)
05
20
When
closing
the
upper
rams
from
the remote
control
panel
on
the rig
floor
the
green
light
indicator
goes
out
but
the
red
light
indicator
does
not
Jome
on.
The Accumulator pressure
and
the
Manifold pressure readings decrease and
then
return
to nornral.
/
What
could
be
the
reason
for
this?
\
i
O
The
4-way
valves
on the
BOP
hydraulic
control
unit
did not
move.
-
O There
is
a leakage
on the
hydraulic
circuit.
O
There
is
an
electricalfault
with
the
lights.
O
The rams
did
not
close.
21
Wltglit
the
primary
function
of a weep
hole
drain
or vent
hole)
on a
ram
type
BOP?
orTo
show
that
the
closing
chamber
operating
pressure
is
too high.
I To
show
that
the
mud
seal
on the
piston
rod is
leaking
O To
show
that
the bonnet
seals
are
leaking
O To
show
that
the
ram
body
rubbers
are leaking
22
A
conventional
flaprper
type
float
valve
is installed
in
the
bit
sub in
the
closed
position.
What
effect
does
the float
valve
have
on the
drill
string when
tripping
into
the
well?
TWO
ANSWERS)
line.
c collapse
of
the drill
pipe
-
if not
filled.
O
lt
reduces
surge
pressure
on the
formation.
O
lt
allows
reverse
circulation
at any
time.
O lt increases
flow-back
through
the drill
string.
23
What
equipment
should
be
made
up
onto the
string
in
order
to
perform
the
stripping
operation
safely,
assuming
there is
no
floit
sub
or dart
sub in
the
string?
,-\
O
The
inside
BOP
with
a
drill
pipe
safety
valve
closed)
Installed
on
top.
{
o
The
drill
pipe
safety
valve
open)
with an
inside
BoP
installed
on top.
.
O
Only
the
drill
pipe
safety
valve
in the
open
position.
O Only
the
inside
BOp.
O
Only
the drill
pipe
safety
valve
in
the closed
position.
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WI=LL
CONTROL
Examptes
Engtish)
05
Which gas
is
used
to
Control
Unit?
O
Air.
O
Carbon
Dioxide
O,
Oxygen.
U Nitrogen.
O
Methane.
25
What
is
the
closing
time
for
a ram
ty
O Less
than
45
s;econds.
O,Less
than
2
minutes,
S
Less
than
30
s;econds.
Figure
413-0002
illlustrates
the
profile
of an
API
6BX
type
flange.
Some
critical
dimensionr;
are
numbere
1,
2,
3 and
4.
APlType
6BX Flange
Which number indicates the
Nominalflange
dimension?
O Dimension
No.,4
O Dimension
No.l3
O Dimension
No.i2
@
Dimension
No.1
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WELL
CONTROL
Examples
(English)
0S
27
Why
should
the
side
outlet
valves
below
the
plug
be
kept
in the
open
position
while testing
a
surlace BOp
stack with
a
test
plug?
...1
(TWO
ANSWERS)
i
O
Otherwise
reverrse
circulation
will
be needed
to
release
the
plug.
O
To
observe
for
well
flow
from
the
annulus.
IJ
O
To
prevent
potrential
damage
to the
casing
or
formation.
O Because
the
terst
will
create
extreme
hook load.
28
What
is
the most
common
action (and
considered
as
good practice)
that
should
be
taken after connecting the open and close hydraulic
lines
to
a surface
installed
tsOP
staclk?
O
Drain
the
accumulator
cylinders
irnd
check
the
nitrogen
pre-charge
pressure.
O
Perform
accurrulator
unit
pump
capacity
test.
O Function
test
alll
items
on
the
stack.
O Place
allfunctions
in
neutral
position
and
start
pressure
testing
the
Bop
stack.
29
What
is
a7-1116 ,10,000 psiflange?
O
lt
is
designed
f<lr
RX
ring
gasket
type.
o
lt has
a
10,000
psitest
pressure
and
5000
psiworking
pressure.
O
lt has
a
10,000
psiworking
pressure
and
7-1116
lD.
O
lt has
a7-1116
OD
and
a
10,000
psi
working
pressure.
30
On
the
remote
BOP
control
panel
on the
rig floor,
the
master
control
valve
handle/button
musll
be held
depressed
for five
seconds
then released
before
operating a
BOP
function,
O False,
O True.
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WELL
CONTROL
Examples
English)
05
31
Figure
illustrates
ian
inside
blowout preventer.
The
lower
kelly
cock,.upper
keily
cock,
driil
pipe
safety
varve
and
inside
Bop
are
some
tools
userd
to
prevent
flow
inside
thi
oritt
string.
-
To
what pressure
s;hould
these components
be
tested?
o
Two
times
the
rated
working pressure
of
the
toor
used up
to
s,000
psi).
o Test
to
a
pressure
at least
equal
to
the
maximum
anticipated
surface
pressure,
but
lirnited
to
the
maximum
rated
working
f;;.rre
of
the
Bop
stack
in
use.
O
Always
use
a
pressure
equalto
10,000
psi.
o
one
and
a
harf
times
the
rated
working pressure
of
the
toor
used.
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WELL
CONTROL
Examples
(English)
05
33
What
is
the
purposie
of
a
Vaccum
Degasser?
O
lt is
mainly
us€,d
to
remove gas
from
mud
while
drilling.
O
lt
is
only
used
rrvhile
circulating
out
a kick.
O
lt is
mainly
used
to
separate gas
from
liquids
while
testing.
o
lt is
a
standby
in
the
event
of
the Mud/Gas
separator
(poor
Boy)
failing.
34
What
are
the
main
components
of
a
diverter
system?
(TWO
ANSWERS)
O
A
vent line
of sufficient diameter
to
permit safe venting using the mud-gas
separator.
o
A
high
pressure
ram
type
preventer
with
a large
internal
diameter.
O A
vent
line
of
snrall
diameter,
sufficient
to
create
a
back
pressure
on
bottom
while
circulatinlg,
O
A
vent line
of
sufficient
diameter
to
permit
safe
venting
and
proper
disposal
of
flow
from
the
well.
o A
low
pressure
annular
preventer
with
a targe
internat
diameter.
35
There
is
only
one
inside
BOP
with an NC50
(4-112
inch lF) pin connection
on
the
rig.
The
drill
string
conriists
of:
S-inch
Heavy
Weight
driil
pipe
(NCSO)
8-inch
(6-5/8
Reg.)
driil
coilars.
Which
of the
following
crossovers
must
be
on
the
rig
floor
while
tripping?
O 6-5/8
inch
Reg.
Box
x 7-blg
inch
Reg.
pin
O NC50
(4-1lZ
inr:h
tF)
Box
x
7-518
inch
Reg.
pin.
O NC50
(4-112
inch
tF)
box
x 6-5/8
inch
Reg.
pin.
O
NC50
(4-112
inch
lF)
Box
x 6-b/8
inch
Reg.
box.
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WELL
CONTROL
lixamples
(English)
05
36
After
observing
a
kick
the
wett
rt
cto
preventer.
After stabilistation
of
shut in pressules
the
casing
gauge
reads
1,000
psi
(69
bar)
104.5
r-eal
'
C
losing
pressures
are
average
and
will
vary stighily
wrtn
6ach
past(in9
unit.
U9e
closing
pressure
shown
at initialclosure
to
€stabllsh
sealofi,
and
reduce
ctosing
pressure
proportionally
as
well
preBsure
is
incr€ased.
Well pressure will maintain closure
after
exceeding the.
required lever,
'Close
CEutiorrsly
To
prevent
Collapse
Of Casino,
\\\\.
>\ \\.
\-
? X'z).'
r_N?rt:
,
..rre-
orrNi
.N}N'M
:39.\
I
]:r\-
l\
\---\,j
-
\. r-
\-,-
f
NfTtAL
69'
138
2O7
276
34s
CLOSURE
WELL
PRESSURE
-
Bar
L
tg
cl
U6e
f
v,
u,
lrJ
t
o-
(9
z
v,
o
d
sa.s
To
which
hydra-ulit;
pressure
should
the
annular
closing
pressure
be adjusted
to
meet
the
manufacturer's
recommendations?
O
21-28bar
O 35
bar
or
above
O
28-35
bar
O
14-21bar
37
Most
of
the conventional
front
pacfe
between
steel
platres,
what
are
the
main
reasons
for
this
type
of
design.
(TWO
ANSWERS)
o
To
prevent
any'swelling
when
used
during
high
temperature
operations.
o
To
feed
new
rubber
into
selaing
contact
with
the
pipe
when
the
sealing
facebecomes
vvorn.
o
To
prevent
the rubber
extruding
top and
bottom
when
the
rams
are
crosed.
O
To
support
the
weight
of
the
drillstring
during
hang_off.
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WELL
CONTROL
Examples
(English)
05
A
leak-off
test is
to
be
performed
using
the high-pressure
cement
pump.
Standpipe
Gauge
Mud/Gas
Separator
I
c.'
/.23
Mud
Flare
Tanks
Vent
Llne
\22
Pressure
Gauge
,i
19
'T
I
-L
Manual
Choke
)(
ta
-T-
I
J,
I.13
t-*J
16
11
14
Choke
Manifold
Blind/Shear
select
the correct
sequence
for
valve
Nos. 1
,2,3
and
4 Figure
when
pumping
down
the
drillstring
and
reading
the
pressure
from
the standpipe
mlnifold
gauge?'
Note:
The
bottom
pipe
rams
are
closed.
O
1=Closed,
2=Open, 3=Closed, 4=Open.
O 1=Open,
2=Open,
3=Open,
4=Closed.
O 1=Open,
2=Clo'sed,
3=Open,
4=Closed.
O 1=Closed,
2=Open,
3=Open,
4=Closed.
('
.,
'\
Y./
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WI=LL
CONTROL
Examptes
(Engtish)
05
SUPERVISORY
1.
A
kick
was
detecte<l
while
drilling
ahead
and
the
well
shut
in.
The
long
open
hole
section
andihe
low
leak
off
test
value
indicate potential
lost
circulation
during
thre
well
control
operation.
Which
of
the
following
methods
should
be
used
to minimize the
well
bore pressure
below
the casing
sl roe?
A.
Wait
and
Weight
method.
B.
Bullheading.
C.
Driller's
method.
D.
Volumetric
rnethod.
2.
Which
of
the
following
statements
are
true?
(TWO
ANSWERS)
A)
The surface
line
volume will
affect
the
time
at
which
the
kill
mud
will increase
bottom
hole
pressrure.
B)
Maintain
the
driil
pipe
pressure
constant
when
bringing
the
pumps
up
to
kill
speed.
C)
The
surface
line
volume
(pump
to swivel)
does
not
need
to
be
considered
when
starting
the
kill.
D)
The
pumps
must
be
brought
up
to
speed
holding
the
casing
pressure
constant.
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WELL
CONTROL
Examples
(Engtish)
05
3. GAUGE
PROBLEMS
KILL
SHEET CALCULATIONS:
VOLUMES:
Surface
to
bit
g4g
strokes
Bit
to shoe
640
strokes
Bit
to
surface
2440
strokes
KICK
DATA:
SIDPP
42
bar
SICP
65
bar
f
CP
79
bar
FCP
45
bar
KILLING
METHOD:
Driiler s
method
PUMP
SPEED:
40 stks/min
3/a.
Use
the
information
from
the above
given
KILL
SHEET
CALCULATIONS
to
answer
the
following
6
questions.
The
circulation
starts
through
the choke
with
the
original
mud.
which
pressure
is
held
constant
while
bringing
the
fumps
up
to
speed?
A.
65 bar
casing
pressure.
B.
79
bar
casing
pressure.
C,
79
bar
drill
piipe
pressure.
D.
65
bar
drill
piipe
pressure.
3/b
After
3 minutes
of
cinculation
the following
gauge
readings
are
observed:
Drill
pipe
pressure,
89
bar
Casing
pressure,
75
bar
Pump
speed,
40
spm
Strokes
circulated,
100
strokes
A.
Increase
the
pump
rate.
B.
Close
the choke
more.
C.
Reduce
the
pump
rate.
D.
Continue
-
E yerything
is
OK
E.
Open
the
choke
more.
what
action
should
be
tak,en?
A.
Increase
the
pump
rate.
B.
Close
the
choke
more.
C.
Reduce
the
pump
rate.
D.
Continue
-
Everything
is
OK
E.
Open
the
choke
more.
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WI=LL
CONTROL
Examptes
(English)
05
3lc
After
30
minutes
of
circ
Drill
pipe
pressure,
100
bar
Casing pressure,
8,0
bar
Pump
speed,
40
sprm
Strokes
circulated,
1,200
strokes
What
action
should
be
talken?
Increase
the
pump
rate.
Open
the
choke
more.
Reduce
the
pump
rate.
Continue
-
Evefihing
is
OK
Close
the
choke
more.
A.
B.
c.
D.
E.
3/d.
The
first
circulation
contin
was
started.
The
stroke
counter
was
set
to zero
after
displacing
the
kill
lines
with
mud
at
40
spm.
After
500
strokes
theJoilowing
gauge
readings
are
observed:
-
Drill
pipe
pressure,
g0
bar
Casing
pressure,
gi
bar
Pump
speed,
40
sprm
What
action
should
be
taken?
A.
B.
c.
D.
E.
Increase
the
pump
rate.
Continue
-
Everything
is
OK
Open
the
choke
more.
Reduce the pump
rate.
Close
the
choke
more.
3/e.
As
kill
mud
is
being
circulated,
both
casing
and
drill
pipe
pressureffi
increasing:
Drill
pipe
pressure,
105
bar
Casing pressure,
gr8
bar
Pump
speed,
40
spm
Strokes
circulated,
100g
strokes
What
is
the
problem?
A.
B.
c.
D.
E.
F.
A
plugged
bit
nozzle.
A
pump
problem,
A
plugged
choke.
A
washout
in
the
drill
pipe.
A
washout
in
the
choke
manifold,
A
lost
bit
nozzle.
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WEILL
CONTROL
Examples
English)
05
3lf
Later
on
the followirrg
the following gauge
readings
are
observed:
Drill pipe pressure,
41bar
Casing
pressure,
60
bar
Pump
speed,
40
spm
Strokes
circulated,
2530
strokes
What
action
shoulcl
be
taken?
A.
Close
the choke
more.
B,
Reduce
the
pump
rate.
C.
Increase
the
pump
rate.
D,
Continue
-
Everything
is
OK
E.
Open the
choke more..
3lg
The
drill
pipe
pressure
suddenly
increased
from
45
to 54
bar
then
remained
constant.
The casing pressure has remained
constant.
Drill
pipe pressure,
54bar
Casing
pressure,
60 bar
Pump
speed,
40 spm
Strokes
circulated,
2,600
strokes
What
is
the
problem?
A.
A
pump
problem.
B.
A washout
in the
drill
pipe.
C.
A
plugged
bitnozzle.
D.
A washout
in
the choke
manifold.
E.
A
lost
bit nozzle.
F.
A
plugged
choke.
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