Grace Robert. Advanced Blowout and Well Control
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16
Advanced
Blowout
and Well
Control
5
70
760
e.
=
513
psi
625
600
7.
Determine the pumping
schedule
for
a
simple drill string
pursuant
to
Equation 2.14:
STm 25(STB)
25psi
<-Pm
--
-
STXS
25(1420)
25psi 700-513
--
-
190
strokes
STKS
25psi
-=
Strokes Pressure
380
65
0
I
950
I
575
I
8.
Construct
Figure
2.7
-graph of pump schedule.
9.
Bring
pump
to
30
spm, keeping the
casing
pressure
constant at
300
psi.
Classic
Pressure
Control
Procedures
77
I
DRILLPIPE PRESSURE SCHEDULE
Wait and Weight Method
-
Example 2.3
700
6w
so0
400
3al
200
100
0
Figure
2.7
10.
Displace the kill-weight mud to the bit (1,420 strokes)
according to the pump schedule developed in Steps
7
and 8.
After
190
strokes, reduce the casing pressure observed at
that
moment by
25
psi. After 10 seconds, observe that
the drillpipe pressure
has
dropped to
675
psi.
After 380
strokes, reduce the casing pressure observed
at
that
moment by
25
psi. After
10
seconds, observe that the
drillpipe pressure
has
dropped to
650
psi. Continue
in
this manner until the kill-weight mud is at the bit and the
drillpipe pressure is
5
13 psi.
11.
With the kill-weight mud to the bit after 1,420 strokes,
read and record the drillpipe pressure equal to
5
13 psi.
12.
Displace the kill-weight mud to the surface, keeping the
drillpipe pressure constant at
5
13
psi.
13.
Shut in the well, keeping the casing pressure constant and
observe
that
the drillpipe and casing pressure are
0.
14. Check for flow.
I8
Advanced
Blowout
and Well
Control
15 Once the well is
confirmed
dead,
raise the mud weight
to
provide the desired trip margin and
drill
ahead.
Obviously, the most potentially confusing aspect of the Wait and
Weight
Method
is the development and application of the pumping
schedule used to circulate the kill-weight mud properly
to
the bit while
maintaining
a
constant bottomhole pressure. The development and
application of the pump schedule is firther illustrated
in
Example 2.5
to
provide additional clarity:
Example
2.5
Given:
Example 2.4
Required:
1.
2.
Solution:
1.
Assume that the kill speed established
in
Step 9
of
Example 2.4
was
actually 20 spm instead of the
anticipated
30
spm. Determine the effect on the pump
schedule and demonstrate the application of Figure 2.7.
Assume
that
the drill string is complex and composed of
16.6
#/e,
1,000 feet of 4 %-inch heavy weight drillpipe,
and
1,000
feet of 6-inch-by-2-inch drill collars. Illustrate
the effect of the complex
string
configuration on
Figure2.7. Compare the pump schedule developed for
the complex string with
that
obtained with the straight
line simplification.
4,000 feet Of 5-inch 19.5
#/ft,
4,000 feet of 4 %-inch
Pursuant
to
Figure 2.4, the surface pressure
at
a
kill
speed of 20 spm would be 240 psi. The initial
displacement surface pressure would be given
by
Quation 2.8
as
follows:
P,
=
240+200
P,
=
440
psi
Classic
Pressure
Control
Procedures
79
Therefore, simply locate 440
psi
on the
Y
axis
of
Figure 2.7
and
draw a line parallel
to
that ori@ly
drawn.
The new line
is
the
revised pumping schedule.
This
concept
is
illustrated
as
Figure 2.8.
380
570
760
950
1140
As
an
alternative, merely subtract 260 psi (700
-
440) from the
values listed
in
the
table in Step 7.
390
365
340
315
290
2. Equations 2.10, 2.12
and
2.13 are used
to
graph the new
pump schedule presented
as
Figure 2.9:
t
?
DRILLPIPE PRESSURE SCHEDULE
Pump Schedule
-
20 SPM
vs
30
SPM
700
600
500
400
3M)
m
1M)
00
P
0
200
400
600
800
Iwa
1200
1400
1600
Cumulativr
Stmkes
Figure
2.8
80
Advanced
Blowout
and Well Control
STB
=
{(
0.0
1776)( 4000)
+
(0.0
1422)(
4000)
+
(0.00743)(
1000)
+
(0.00389)(1000)}
+
0.10
SI73
=
1,392
strokes
The
graph
is
determined
from
Equations
2.12 and 2.13:
DRILLPIPE
PRESSURE
SCHEDULE
Custom
vs
SimplifEd Pump Schedule
700
600
500
400
300
200
100
n
I-
0
200
400
600
800
1000
12w
1400
1600
Cumulflve Stroke8
IeSimplid
SCheduC
+Customized
Schedule
I
Figure
2.9
Classic
Pressure
Control Procedures
81
(0.01 776)(4000)
0.1
STKS
1
=
STKS
1
=
710
strokes
(0.01776)(4000)
+
(0.01422)(4000)
0.1
sxs
2
=
STKS
2
=
1,279
strokes
SKS3
=
{(0.01776)(4000) +(0.01422)(4000)
+
(0.00743)(
1000))
+
0.10
SlXS
3
=
1,353
strokes
Similarly,
STKS
4
=
1,392
strokes
The circulating pressure
at
the
surface
at the end
of
each section
of
drill
string
is
given
by
Equation
2.13:
STKS
1
P
STB
82
Advanced
Blowout
and Well Control
4
=
700-0.052(10-9.6)(4000)+
4
=
627
psi
pZ
=P,-O.O52@,
-p)(ZdSl
+Ih2)+
STKS
2
P
Sll3
pZ
=
700-0.052(10-9.6)(4000+4000)+
Pz
=
552
psi
STKS
3
P
STB
P3
=
534
psi
Adding the the final section
of
drill collars
to
the above equation,
P,
=
513
psi
As illustrated
in
Figure
2.8,
changing
the pump speed at which
the kick
is
displaced merely moves
the
pump schedule to a parallel
position on the graph. As illustrated in Figure
2.9,
the complex pump
Classic
Pressure
Control
Procedures
83
schedule is slightly more difficult
to
construct. The simplified straight line
pump schedule approach will underbalance the well during the period that
the kill-weight mud
is
being displaced to the bit.
In
this
example the
underbalance is only
as
much
as
25 psi.
In
reality,
in
most cases the
annular frictional pressure
losses,
which are considered negligible
in
classical pressure control analysis, would more than compensate and an
additional influx would not occur. However, that may not be the case in
any specific instance and
an
additional influx could occur. In most
instances, the simplified pump schedule would suffice.
In
significantly
complex drill strings, this comparison should be made.
SUMMARY
The Driller’s Method was the first and most popular displacement
procedure. The crew proceeded immediately
to
displace the influx. The
required calculations were not difficult. The calculations were made, the
kill-weight mud was easily displaced and the drilling operation was
resumed. One disadvantage of the Driller’s Method is that at least two
circulations are required to control the well.
The Wait and Weight Method is slightly more complicated but
offers some distinct advantages. First, the well is killed in half the time.
Modern mud-mixing facilities permit barite to be mixed at rates up to
600
sacks per hour with dual mixing systems; therefore, time required to
weight up the suction pit is minimized and kill rate is not penalized. The
Wait and Weight Method results in kill mud in the well sooner and that is
always an advantage.
In
addition,
as
discussed and illustrated in
Chapter
4,
the annulus pressures are lower when the Wait and Weight
Method is used. The primary disadvantage is the potential for errors and
problems while displacing the kill-weight mud to the bit. With the
Driller’s Method, the procedure can be stopped and started easily.
Stopping and starting when using the Wait and Weight Method is not as
easy, especially during the period
that
the kill-weight mud is being
displaced
to
the bit. It is not uncommon that
good
drilling men get
conksed during displacement using the Wait and Weight Method.
In view of all considerations, the Wait and Weight Method
is
the
preferred technique.
CHAPTER THREE
PRESSURE CONTROL PROCEDURES
WHILE TRIPPING
22
June
Trip out
of
the hole.
Well began flowing. Trip in the
hole with the bottomhole assembly. Gained
60
bbls.
Circulated the hole. Pressure continued to increase.
Shut in well with
3000
psi. Drillpipe started coming
through the rotary table. Opened choke, closed pipe
rams above tool joint, and closed choke. Total gain was
140
barrels. Attempt to close safety valve without
success. Open choke, close safety valve, close choke.
Had
200
barrel total gain. Rigged up snubbing unit.
14
July
Began snubbing in the hole.
15
July
Continued snubbing to
4,122
feet. Circulated 18.5-ppg
mud. Surface pressure
is
3
700
psi.
16
July
Snubbed to
8,870
feet. Began to circulate 18.5-ppg
mud. Surface pressure increased to
5300
psi on casing.
84
Pressure
Control
Procedures Khile Tripping
85
Mud in is
540
bbls versus mud out
of
780
bbls.
Increasedpump rate from
3
bpm to
6
bpm. Drillpipe
pressure increased to 6700psi. Hammer union on rig
floor
washed out. Unable to close safety valves on rig
floor
due to excessive pressure and
jlow.
Hydrogen
sulJide monitors sounded. Ignited rig with flare gun.
The drilling report above is a good illustration of a disaster
resulting from complications during tripping operations at a well that was
under control only a few hours prior to the trip.
It
must be reasoned that
any well that is tripped is under control when the bit leaves bottom.
Therefore, operations subsequent
to
the beginning
of
the trip precipitate
the well control problem. As is often the case, due to operations
subsequent to the time
that
a
well control problem was detected, the
condition of the well deteriorated and the well control problem became
progressively more complicated.
The reason for
this
fiuniliar unfortunate chain
of
events is that the
industry has been and
still
is inconsistent under these circumstances. A
recent
survey
of the major well control schools revealed substantial
inconsistencies under the same given circumstances.
Actually, classical pressure control procedures apply only to
problems which occur during drilling
operations.
Unfortunately, there
is
no widely accepted procedure to
be
followed when a kick occurs during
a
trip. Further, procedures and instructions which apply
to
problems during
drilling are routinely posted on the rig floor. However, just
as
routinely,
there are
no
posted instructions which apply to procedures to be followed
if the kick occurs during
a
trip. A federal court in Pecos, Texas, found
a
major oil company grossly negligent because procedures for problcms
occurring while drilling were posted and procedures for problems
occurring while tripping were not. One purpose of this chapter is to
suggest that classical trip procedures
be
adopted, taught and posted.
CAUSES
OF
KICKS
WHILE
TRIPPING
Any well control problem which occurs during
a
trip
is
generally
the result
of
a
fbilure on the part of the rig crew to keep the hole
full
or
the
Mure
of
the crew
to
recognize
that the hole is not filling properly. The