General Flashcards
1
Q
When killing a well using drillers method what should happen to mud pit volume during second circulation
A
The volume should not change
2
Q
Most kicks are caused by drill crew not
A
Ensuring the hole takes the correct fill on trips
3
Q
Which part of pressure loss acts on bhp
A
Annular pressure loss
4
Q
What 2 variables are considered for calculating hydrostatic pressure
A
Column length and density
5
Q
It’s good practice to keep
Trip records
Pump output figures
Scr
Training records
All the above
A
All the above
6
Q
Scr should be taken every tour using
Sidpp on choke manifold
Drill pipe gauge on drillers console
Gauge on choke manifold
Pump gauge
Mud loggers
A
Dp gauge on choke panel
7
Q
Hydrostatic pressure is the pressure exerted by a column of fluid at rest
True false
A
True
8
Q
Which method of well control has only one circulation and pumps kill mud from the start
Driller
W &W
Volumetric
Bull heading
A
w & w
9
Q
Which method circulates the influx out of the well before kill mud is circulated round the system
A
Drillers
10
Q
Which method of well control would you use if you could not pump and gas migration was suspected
A
Volumetric
11
Q
Primary prevention of blow outs is
A
Correct mud weight
12
Q
Secondary method of well control is
A
Closing bop
13
Q
As gas migrates up the well bore during shut in conditions
Each pressure will increase
A
All pressures increase apart from the bubble pressure which will remain the same
I
C
I
14
Q
If proper dp pressure is not maintained during a kill operation then Bhp will crease or decrease causing losses or another influx
True false
A
True
15
Q
The u tube is balanced when the well is shut in regardless of the difference between sidpp and sicp
A
True
16
Q
A large pit gain will give higher Sidpp & Sicp
A
The bigger the pit gain the higher the Sicp
Sidpp is not effected
17
Q
A long volume of kick will result in a higher or lower annulus pressure
A
Higher
18
Q
Why is the Sicp higher than the Sidpp
A
Influx is less dense there fore the pressure is higher
19
Q
After circulating out the influx using the drillers method should the Sidpp and Sicp be the same
A
Yes
20
Q
If the pump was brought up to kill speed and the casing pressure was allowed to increase above Sicp
What would happen
A
Bhp would increase
Sicp should be kept constant whilst bring the pumps up to speed
21
Q
A larger pit gain will give higher SIDPP & SICP.
A
False Influx is in the annulus
22
Q
When killing a well using the Drillers Method what should happen to the mud pit
A
The volume will not change
23
Q
A larger pit gain will give higher SIDPP & SICP.
A
False
24
Q
Circulating pressure of several thousand psi at the pump leaves the circulating system i.e. at the shakers, with little or no pressure. Which part of the pressure lost acts on the bottom of the hole?
A
Annular pressure loss
25
When killing a well using the Drillers Method what should happen to the mud pit volume during the second circulation?
The volume will not change
26
Which of the following is the first reliable indication that the well is kicking?
Increase in flow rate
27
If the mud volume displaced is not equal to pipe displacement, what should you do prior to flow checking the well?
Stop tripping & install a full opening safety valve
28
During drilling operations your derrickman informs you of an unusual pit level increase.What is the safest response
Pull up, shut off pumps & check for flow
29
Which of the following best describes the Hard Shut In?
With the Remote choke closed; close a BOP; open a side outlet
30
Which of the following best describes the Soft Shut In?
With the HCR open; open a side outlet; close the BOP; close the HCR
31
What should the driller do when he experiences a drilling break?
Flow check
32
The purpose of shutting in a well is to:
Stop further influx coming into the wellbore
AND Allow pressures to be determined
33
If total losses occurred while drilling with water based mud what would you do?
Stop drilling & fill the hole with water
34
Which of the following causes of well kicks is totally avoidable and due to lack of attention
Not filling the hole with the right amount of mud
35
What do you do if the hole stays full but does not take the correct amount
Go back to bottom; circulate bottoms up
36
If the well does not flow while circulating but flows when the pumps are shut down
An amount equal to pressure loss in the annulus
37
If connection gas is noticed while drilling a reservoir what would be considered to be a good drilling practice if an increase in mud weight is not an option at this time?
Control drilling rate to ensure only one slug of gas in annulus at any one time AND Try & minimise connection time
38
When the pipe is off bottom and the well kicks the recommended practice is to:
Install safety valve; secure well & strip to bottom
39
Which of the following can cause a well to kick?
All of these can
Lost circulation
Swabbing
Not keeping the hole full
Insufficient mud weight
40
Why should the well be closed in quickly after a kick has been detected?
Minimise the influx into the wellbore
Pressures will be lower on the annulus side
41
When encountering gas cut mud we should immediately increase the mud weight
You may have to increase the mud weight but first of all you should determine whether or not this will be possible without causing losses.
42
What is SIDPP with the bit on bottom used to calculate?
Mud weight increase needed to kill the well
What type of influx has entered the wellbore
43
After shutting in on a kick the SIDPP & SICP have been stable for a while.
Both have now started to slowly increase by the same amount.
What is the probable cause?
The influx is migrating up the wellbore
44
A larger pit gain will give a higher SIDPP?
False
45
A larger pit gain will give a higher SICP but SIDPP will remain the same regardless of kick size.
True
46
The main reason for calculating the influx gradient is:
To make arrangements to handle the kick on surface
47
If a gas kick is taken in a horizontal well what would you expect SICP to read?
A: SICP would be a lot higher than SIDPP
B: SICP would be a lot lower than SIDPP
C: SICP would about the same as SIDPP
D: SICP would be the same as in a vertical well
E: You cannot read SICP in a horizontal well
SICP would about the same as SIDPP
48
After a kick has been shut in and pressures have stabilised then
Formation Pressure = Mud Hydrostatic Pressure in the String + SIDPP.
True
49
When should MAASP be re-calculated?
A: After every bit change
B: After every 1000 feet drilled
C: After every mud weight change
D: After a successful BOP test
E: After all of the above
After every mud weight change
50
Surface line volume does not have to be taken into consideration when pumping
Kill Mud down the string.
False
51
The Leak Off Test shows the amount of surface pressure added to the column of
mud hydrostatic to cause a formation break down.
True
52
A Leak Off Test is used to determine the maximum mud weight or maximum
surface pressure before lost circulation is likely to occur at the shoe.
True
53
In order to get accurate leak off test information you need:
A: Known shoe TVD
B: Known and consistent mud weight in the well
C: An accurate pressure gauge
D: All of the above
E: None of the above
D: All of the above
54
When killing a well using the Wait & Weight Method what will happen to the pit volume
the moment gas starts to enter the choke?
A: The pit volume will increase
B: The pit volume will decrease
C: The pit volume will stay the same from now on
D: The pit volume will fluctuate erratically
E: The pit volume should not be monitored during a kill
As gas is circulated out the well through the choke the pit level will fall.
55
As gas is circulated up the annulus to surface what will happen to the pit volume?
A: The pit volume will increase
B: The pit volume will decrease
C: The pit volume will stay the same from now on
D: The pit volume will fluctuate erratically
E: The pit volume should not be monitored during a kill
A: The pit volume will increase
56
The two common kill methods, Drillers and Wait & Weight, both have
one thing in common:
A: Both kill the well in one circulation
B: Both have a minimum non-circulating time
C: Both minimise pressure at the casing shoe
D: Both keep bottom hole pressure constant
E: Both need two pumps on the hole
D: Both keep bottom hole pressure constant
57
When circulating out a gas kick the greatest applied pressure to the casing shoe
happens when the gas bubble is:
A: At surface
B: At the casing shoe
C: At the bottom
D: The pressure remains the same during the kill
B: At the casing shoe
58
The most important reason we want to know where an influx is in the annulus is because:
A: Drill pipe pressure is adjusted according to bubble position
B: Casing pressure is adjusted according to bubble position
C: We need to maintain a constant drill pipe pressure
D: We want to know when the bubble is at the shoe
E: None of the above are correct
If you have not exceeded MAASP by the time the bubble enters the shoe
then you won't for the remainder of the kill as long as you continue to do
things correctly.
It is, therefore, useful to know when the bubble is inside the shoe.
59
Pump speed should vary during a kill operation to maintain constant BHP.
False
60
How many circulations are there in the Drillers Method?
A: One
B: Two
C: Three
D: The Drillers Method does not involve circulation
B: Two
61
How many circulations are there in the Wait & Weight Method?
one
62
How do you bring a pump up to speed for a kill operation on a surface stack?
A: Open the choke to maintain drill pipe pressure constant until up to speed
B: Open the choke to maintain casing pressure constant until up to speed
C: Both A & B can be used for a start up
D: Neither A & B can be used for a start up
Casing pressure should always be held constant during the start up.
63
Whilst circulating out a kick the mud pump fails.
What is the first thing you should do?
A: Fix the pump as soon as possible
B: Change over to the other pump
C: Shut the well in
D: Use the Volumetric Method
E: Make preparations to start bullheading
C: Shut the well in
64
When making adjustments to the Remote Choke during a kill operation what responses
would you expect to see if the choke was closed slightly?
A: Casing gauge decrease followed by Drillpipe gauge decrease
B: Drillpipe gauge increase followed by Casing gauge increase
C: Casing & Drillpipe gauges will drop together
D: Casing gauge increase followed by Drillpipe gauge increase
E: Casing & Drillpipe gauges will rise together
D: Casing gauge increase followed by Drillpipe gauge increase
65
What pressure is kept constant while filling the annulus with Kill Mud?
A: Initial Circulating Pressure
B: SICP minus Choke Line Friction
C: Final Circulating Pressure
D: Original SICP
E: Original SIDPP
Drillpipe pressure should be held constant at FCP as Kill Mud
fills the annulus.
66
On a surface stack rig how can you find ICP when a kick has occurred
and the slow circulating rate pressure loss is not known?
A: Bring the pump up to speed holding casing pressure constant
B: Bring the pump up to speed adding 200 psi to casing pressure for safety
C: Add 100 psi safety to drillpipe pressure & circulate the influx out
D: Bring the pump up tp speed holding drillpipe pressure constant
E: Circulate at desired SPM holding 200 psi safety on drillpipe
A: Bring the pump up to speed holding casing pressure constant
67
FCP is reached when:
A: The influx has been removed from the well
B: Kill mud reaches the bit
C: Kill mud reaches the shoe
D: Kill mud returns at surface
E: The pit level has stopped fluctuating
FCP is reached when kill mud is at the bit.
68
While circulating out a kick pump speed is increased while holding drillpipe
pressure constant.
What happened to BHP?
A: It increased
B: It stayed the same
C: It decreased
C: It decreased
69
After the first circulation of the Drillers Method SIDPP & SICP should be:
A: Zero
B: SICP should be slightly higher than SIDPP
C: The same
D: SIDPP should be slightly higher than SICP
E: None of the above are correct
C: The same
70
A gas kick is being circulated from a well at 30 SPM with 750 psi being held constant on the drillpipe pressure gauge. The pump speed is increased to 40 SPM while continuing to
hold drillpipe pressure constant.
The bottom hole pressure will:
A: Decrease
B: Increase
C: Remain constant
D: Drop to zero
E: Insufficient data for the calculation
A: Decrease
If the pump speed is increased then drillpipe pressure should
also increase. You have not allowed it to increase therefore
you are holding it at a lower reading than it should be at.
The result is that BHP will fall.
In this example drillpipe pressure should rise to approximately 1333 psi.
71
Which of the following methods will result in the lowest casing shoe pressures
if open hole volume is considerably larger than string volume?
A: Drillers
B: Wait & Weight
C: Concurrent
D: Volumetric
E: Company Man's
Wait & Weight method.
72
Which of the following kill methods would you use if you could not circulate
and you suspected gas migration was taking place?
A: Drillers
B: Wait & Weight
C: Concurrent
D: Volumetric
E: Company Man's
Volumetric.
73
What happens to the pressure below a gas bubble as it is circulated from
the well during a kill operation?
A: It remains constant
B: It decreases
C: It increases
D: It rises at first then remains constant
E: It falls at first then remains constant
All pressures below a gas bubble remain constant.
74
What happens to casing shoe pressure as a gas bubble is circulated from a well
during a kill operation?
A: It remains constant
B: It decreases
C: It increases
D: It rises at first then remains constant
E: It falls at first then remains constant
Casing shoe pressure will rise as the gas bubble travels towards it
and then remain constant once it has passed.
75
What happens to the pressure inside a gas bubble as it is circulated from
a well during a kill operation?
A: It remains constant
B: It decreases
C: It increases
D: It rises at first then remains constant
E: It falls at first then remains constant
As the gas bubble expands the pressure inside it falls.
76
What happens to the pressure on the casing gauge as a gas bubble is circulated
from a well during a kill operation?
A: It remains constant
B: It decreases
C: It increases
D: It rises at first then remains constant
E: It falls at first then remains constant
Casing pressure will rise as the gas bubble is circulated up to surface.
77
What happens to bottom hole pressure as a gas bubble is circulated from a well
during a kill operation?
A: It remains constant
B: It decreases
C: It increases
D: It rises at first then remains constant
E: It falls at first then remains constant
BHP reamins constant through the kill operation.
78
Why will a 20 bbl kick in a small annulus be more significant than a
20 bbl kick in a large annulus?
A: The kill weight mud cannot be calculated as easily
B: The kicks are usually gas
C: The pipe may become stuck in the smaller annulus
D: It results in higher annulus pressures
E: It results in higher drillpipe pressure
The influx will be longer in a smaller annulus and this will lead to
higher pressures in the annulus.
79
The reason SICP is usually higher than SIDPP is:
A: The cuttings in the annulus are lighter than the mud weight
B: The influx fluid is usually less dense than the mud weight
C: The casing pressure depends on the rig type
D: The difference is in the type of gauges used
E: This is a red herring as SIDPP is usually higher than SICP
SICP is usually higher due to the lighter influx being in the annulus
and clean mud being in the drill string.
80
After the first circulation of the Drillers Method the well is closed in. The following
pressures were recorded on the surface gauges:
SIDPP = 700 psi SICP = 700 psi
Is this the type of reading you would expect?
A: Only if the influx is a fluid
B: Only if the influx is a gas
C: Yes
D: No
E: Never
After the first circulation of the Drillers Method you should have
removed the influx from the well. Once shut back in SIDPP and
SICP should be reading approximately the same.
81
On a surface stack rig what would happen if when bringing the pump up to kill
rate speed you allowed the casing pressure to increase above SICP?
A: BHP would increase
B: BHP would stay the same
C: BHP would decrease
D: It will be OK as drillpipe pressure will rise by the same amount
E: As long as SIDPP remains constant everything will be fine
Casing pressure should be held constant while brining the pump
up to kill rate speed. By allowing it to increase you will also
increase the pressure on the bottom of the hole.
82
When a gas kick is circulated out through the choke the pit volume will:
A: Increase
B: Decrease
C: Stay the same
Pit volume will decrease.
83
During a kill operation the choke operator notice drillpipe pressure shoots up rapidly while
casing pressure remains pretty much constant. He decides to live with the new reading
on the drillpipe pressure gauge which is 400 psi higher than it had been.
What effect will this have on bottom hole pressure?
A: Bottom hole pressure will increase
B: Bottom hole pressure will decrease
C: Bottom hole pressure will remain constant
D: There is not enough information to tell
The indications here are that a nozzle has plugged. The new pumping
pressure is correct for the new conditions.
By doing nothing bottom hole pressure will remain constant.
84
During a kill operation the choke operator notices a sudden increase in casing pressure
followed by a comparable increase in drillpipe pressure. He decides to live with the new
reading on the drillpipe pressure gauge which is 200 psi higher than it had been
What has happened to bottom hole pressure?
A: Bottom hole pressure will increase
B: Bottom hole pressure will decrease
C: Bottom hole pressure will remain constant
D: There is not enough information to tell
The indications here are that the choke has plugged. Ideally you should
change chokes but if that is not possible then you should attempt to
maintain drillpipe pressure at it's original value.
By doing nothing bottom hole pressure has increased.
85
During a kill operation the choke operator finds he is continually closing the choke to
maintain drillpipe pressure as it should be. A short time later the derrickman calls to
say the rig pump has developed a serious leak and he has just noticed.
What effect has the continual closing of the choke had on bottom hole pressure?
A: Bottom hole pressure will increase
B: Bottom hole pressure will decrease
C: Bottom hole pressure will remain constant
D: There is not enough information to tell
The serious leak the pump has developed means less mud is now
going down the hole - in effect you are pumping at a slower rate.
The slower you pump the lower your pumping pressure should be.
By maintaining the old higher pumping pressure the choke
operator has increased bottom hole pressure.
86
After well is shut in on kick SIDP and SICP slowly increase
What is the cause of this
The influx is migrating up the well bore
87
A larger pit gain will give a higher SIDP
True or false
False
88
The surface line volume does not have to be taken into consideration when pumping kill mud down the hole
True or False
False
89
When killing a well using w&w method what will happen to the pit volume the moment gas starts to enter the choke
Increase
Decrease
Stay the same
Fluctuate
No need to monitor
As gas is circulated out of the well through the choke the pit level will fall
90
As Gas is circulated up the Annulus to surface what will happen to the pit volume
Increase
Decrease
Stay the same
Fluctuate
Increase
As gas is circulated to surface it will expand in volume
91
When circulating out a gas kick the greatest applied pressure to the casing shoe is
Gas at surface
At casing shoe
At bottom
Pressure remains constant
At the casing shoe as the top of the bubble reaches the shoe
92
The most important reason for needing to know where the influx is in the well is
Adjust Dp pressure to bubble position
Sicp adjusted to bubble position
To maintain constant dp pressure
We want to know when the bubble is at the shoe
We want to know when bubble is at the shoe if you have not exceeded Maasp by the time the bubble reaches the shoe then you won’t for the remainder of the kill
93
Pump speed should vary during kill ops
True
False
False
94
How do you bring pumps up to kill speed for a kill operation
Open the choke to maintain sicp constant until up to speed
95
What pressure is kept constant whilst filling the annulus with kill mud
Drill pipe pressure at FCP as kill mud fills the annulus
96
FCP is reached when
The influx is removed from the well
Kill mud reaches the bit
Kill mud at surface
FCP is reached when kill mud reaches the bit
97
When circulating out a kick pump speed is increased what happens to BHP
Increase
Decrease
Stay the same
As you have not allowed for this increase in dp pressure
Therefore you will be holding a lower pressure and BHP will be reduced
98
First circulation of the drillers method sidpp and sicp should be
Zero
Sicp should be slightly higher
The same
Sidpp should be slightly higher
They should both be reading the same original sidpp
99
Which method results in lowest casing shoe pressure if open hole volume is considerably larger than string volume
Wait and weight
Drillers
Wait and weight
100
What happens to the Pressure below the gas bubble as it is circulated from the well during kill ops
Increase
Decrease
Stay the same
Stays the same
101
What happens to casing shoe pressure as the gas bubble is circulated from the well
Increase
Decrease
Stay the same
Rise then then remain constant
Fall then remain constant
Casing shoe pressure will rise as the bubble approaches then remain constant once it is above the shoe
102
What happens to the pressure inside the bubble as it is circulated from the well
Increase
Decrease
Stay the same
As the bubble rises the pressure inside will fall
103
What happens to the pressure on the casing gauge as a gas bubble is circulated from the well
Increase
Decrease
Stay the same
Rise then remain constant
Fall then remain constant
Increase as the gas bubble rises
104
What happens to bottom hole pressure as the gas bubble is circulated from the well
Increase
Decrease
Stay the same
It will remain the same
105
Why will a 20 bbl kick in a small annulus be more significant than a 20 bbl kick in a large annulus
It will be longer resulting in higher pressures
106
The reason sicp is higher than sidpp is
Cuttings in annulus are lighter
Influx fluid is less dense than mud
Influx fluid is less dense than mud
107
After the first circulation of the drillers method the sicp is 700psi and sidpp is 700psi
Is this the type of reading you would expect if
Only if the influx is fluid
Only if the influx is gas
Yes
No
Yes as the influx is out and mud is now all the way round
108
What would happen if you brought the pump up to kill rate speed and allowed the casing pressure to increase above sicp
BHP would increase
BHP would stay the same
BHP would decrease
BHP would increase
109
During kill operation the choke operator notice drill pipe shoots up rapidly whilst casing pressure remains constant
He decided to live with the new reading on the drillpipe pressure gauge which is 400psi higher than it had been
What effect will this have on BHP
Increase
Decrease
Stay the same
Possible nozzle plugging the new pump pressure is correct
By doing nothing bottom hole pressure will remain constant
110
During a kill operation the choke operator notices a sudden increase in sicp follows by and increase in sidpp of 200psi on the sidpp
He decides to live with the increase what will happen to BHP
Increase
Decrease
Stay the same
Indication of the choke plugging
Swap chokes if possible if not attempt to maintain sidpp at its original value
By doing nothing BHP has increased
111
During kill operation the choke operator finds he is continually closing the choke to maintain sidpp as it should be
A short time later the derrickman calls to say the pumps are leaking
What effect will this have on BHP
Increase
Decrease
Stay the same
Less mud going in the well which is the same as the pump going slower
Resulting in a lower pressure by trying to maintain the older higher pressure the choke operator has increased the BHP
112
The reason sicp is higher than sidpp is
Cuttings in annulus are lighter
Influx fluid is less dense than mud
Influx fluid is less dense than mud
113
After the first circulation of the drillers method the sicp is 700psi and sidpp is 700psi
Is this the type of reading you would expect if
Only if the influx is fluid
Only if the influx is gas
Yes
No
Yes as the influx is out and mud is now all the way round
114
What would happen if you brought the pump up to kill rate speed and allowed the casing pressure to increase above sicp
BHP would increase
BHP would stay the same
BHP would decrease
BHP would increase
115
During kill operation the choke operator notice drill pipe shoots up rapidly whilst casing pressure remains constant
He decided to live with the new reading on the drillpipe pressure gauge which is 400psi higher than it had been
What effect will this have on BHP
Increase
Decrease
Stay the same
Possible nozzle plugging the new pump pressure is correct
By doing nothing bottom hole pressure will remain constant
116
During a kill operation the choke operator notices a sudden increase in sicp follows by and increase in sidpp of 200psi on the sidpp
He decides to live with the increase what will happen to BHP
Increase
Decrease
Stay the same
Indication of the choke plugging
Swap chokes if possible if not attempt to maintain sidpp at its original value
By doing nothing BHP has increased
117
During kill operation the choke operator finds he is continually closing the choke to maintain sidpp as it should be
A short time later the derrickman calls to say the pumps are leaking
What effect will this have on BHP
Increase
Decrease
Stay the same
Less mud going in the well which is the same as the pump going slower
Resulting in a lower pressure by trying to maintain the older higher pressure the choke operator has increased the BHP
118
Name two positive indicators of a kick
Flow rate increase
Pit volume increase
119
Name warning signs of a kick
Pump pressure decrease
Pump stroke increase
Drilling break
Increase in torque and drag
Incorrect hole fill volume
Splinter cuttings
120
Causes of kicks
Fail to fill hole
Swabbing
Insufficient mud weight
Abnormal pressure
Excessive rop in gas bearing sands
121
Soft shut in
Pick up with pumps running
Space out
stop rotating
Stop pumps
Open HCR
Close bop
Close remote choke
Record sidpp sicp TVs pit gain
122
Hard shut in
Pick up pumps running
Space out stop rotating
Stop pumps
Close bop
Open HCR
Record sidpp sicp TVD pit gain
123
What are the advantages of the Drillers method
Little or no calculations, only need to know kill mud weight asap
Minimizes the chance of gas migration
Can get going as soon as pressures stabilize
124
What are the disadvantages of the Drillers Method
Highest annular pressures for the longest period of time
Longest on choke time due to two circulations
125
First Circulation of Drillers method of start up is-
1.Bring pumps up to speed maintaining a constant BHP using the CHOKE & SICP
2.Once up to kill speed, switch attention to the DP GAUGE and maintain ICP until the kick is out of the hole
3. Shut down the pumps and SICP should = SIDPP. If not, then the influx is not fully out of the hole or a secondary influx may been taken, continue circulating.
126
Second Circulation of Drillers Method is
1. Bring pumps up to speed, monitor CASING GAUGE, maintaining a constant BHP as before
2. Once up to speed maintain a constant CASING PRESSURE whilst kill mud is being pumped to bit
3. Once kill mud reaches the bit then switch attention to the DP gauge and keep FCP constant by operating choke until well is circulated to kill mud
127
What are the Disadvantages with Wait and Weight
More Calculations
Bigger chance of Gas Migration (whilst mixing kill mud)
Settlement of cuttings, potential for annulus pack-off (due to above)
More Waiting
128
What are the advantages of Wait and Weight
Less time on choke
One Circulation
Will give the lowest casing shoe pressure when the open hole capacity is greater than the drill string volume!
129
What is the steps taken during Wait and Weight Method
1. Bring pumps up to kill speed maintaining a CONSTANT CASING PRESSURE using the CHOKE & CASING GAUGE. Watch Casing gauge and keep BHP constant as kill mud is pumped to bit to maintain pressure drop from ICP to FCP
2. When kill mud reaches the bit switch attention to the DP gauge and hold FCP constant until kick is pumped to surface, followed by the DP contents and the kill mud.
3. Shut down the pumps, check for flow. SICP and SIDPP should read zero
130
List indications of increasing formation pressure
Drilling break / increase in ROP
Increased torque & drag, fill on connections
Increase in total gas levels
Gas cut mud
Increase in flow-line mud temperature
Increase in mud salinity (salt dome or salt water invasion)
Heaving shale's (sloughing) increased cavings, splintery or elongated cuttings
Shale density changes from normal compaction
132
When closing in a well on a casing string should the annulus or string be closed first
Close in the smaller path of fluid first in this case it would be the Annulus closed in first then the casing string
133
When does cement stop applying hydrostatic force
During the setting phase
134
How to combat H2S
Keep PH high
135
Is H2S soluble in WBM
Yes
136
What Drill pipe should be used for H2S wells and why
X95 due to its high carbon content
137
As gas migrates SIDPP and SICP will climb. How do you maintain constant BHP
Bleed off pressure via choke to maintain SIDPP to original shut in value .this is a short term fix
138
How to find out how much the base of the influx has migrated
Divide the pressure increase by the mud gradient
139
How to find the pressure at the shoe
Remove all hydrostatic pressure from below the shoe from the formation pressure
140
How long are test charts kept for
2 years
141
If ICP is less than calculated value what should you do
Stop and investigate discrepancies
142
During first circulation If a nozzle was blown out during well kill operation and SICP remained constant what would happen to BHP
Stay the same
143
What are the advantages of the Drillers method
Minimum Calculations
Minimum waiting time
Minimum Information required
144
What are the Disadvantages of the Drillers method
Highest Annular Pressure Produced
Maximum Well under pressure time
Longest onchoke time
145
What are the start up and shut down steps During the first circulation of the Drillers method
Maintain constant choke pressure as the pump is being brought up to kill rate
Once at kill rate maintain the drill pipe pressure constant this is ICP
Once the influx has been circulated out maintain constant Casing pressure using the choke as the pump is switched off. SIDPP is now the same as SICP
146
What are the start up and shut down steps during the second stage of the Drillers Method
Line up both pumps to kill mud
Bring the pump up to kill speed using the choke to maintining SICP constant
Zero strokes when kill mud is at rig floor
Maintain sidpp step down asKill mud is pumped to the bit ( SIDPP will decrease)
Once the kill mud is at the bit maintain SIDPP constant at foppish
Once kill mud is exiting the choke
maintain SICP whilst switching off pump SIDP and SICP should be zero
147
Steps to take if pump speed is required to be adjusted if the mud weight in the string is constant
Note SICP
Maintain SICP whilst adjusting the choke
As soon as the pumps are at new pump speed
Note new SIDPP Swap back to SIDPP and maintain this new pressure
148
Advantages of W&W
Lowest well bore pressure
Lowest surface
Minimum on choke time
149
Disadvantages of W&W
Long waiting times weighing up mud Gas migration
Large increase in Mud weight
150
What are the steps to carry out W&W method
Line up Both pumps on Kill mud
Start pump and bring up to kill speed using choke to maintain SICP
Zero strokes when kill mud at rig floor
Once at kill rate
Drill pipe pressure will steadily drop
Once the Kill mud reaches the bit SIDPP is maintained at FCP using the choke untill Kill mud is observed at the choke
SICP is held constant using choke whilst pump is shut down
SIDP and SICP should be zero unless pressure is trapped in system
151
Well control events can have an impact on
Result in over regulation
152
What is Iwcf gauge question tolerance
70psi
153
Calculating hydrostatic pressure when two fluids of different density exist
Work out the different hydrostatic pressures and add them together
154
What is permeability
Permeability is the ability of a porous medium to transmit fluids (To permit fluid to pass through a formation)
155
What is porosity
Much like a sponge it is how much fluid is contained inbetween the rock grains
156
What situations can exist where SIDPP is greater than SICP
The bit is above the influx
Horizontal wells
Formation fluid has entered the Drill string
Heavy brine kick
Well packed off
157
What do IWCF call a TIW
DPSV Drillpipe safety valve
158
What will SICP and SIDPP be if a swabbed kick is circulated out and the pump is shut down
Current MW is adequate so both gauges will read zero
159
Will H2S dissolve in WBM
Yes
160
As a rule of thumb gas reaches it bubble point at what depth
2000ft. To 3000ft
161
What are kick indicators
Flow rate increase
Pit volume increase
Incorrect hole fill when tripping
162
Who needs to sign well barrier pressure test charts
Toolpusher
Drilling/ well intervention supervisors
Pump operator
163
What information needs to be included on the chart
Type of test
Test pressure
Component tested
Estimated volume of system pressurised
Volume pumped
Authorised person’s signature
164
Definition of an influx test
A test in which the hydrostatic pressure is reduced such that the net differential pressure is from the formation into the well
Also referred to as a negative test
165
If gas starts to migrate and the choke is kept closed what will happen to BHP
Increase ICI
166
After a gas kick has been shut in and pressures stabilised if gas starts to migrate and SIDPP is kept at original Sidpp what will happen to BHP
I’m will stay the same
167
If the choke is adjusted to maintain original SICP as the gas migrates what will happen to BHP
BHP will decrease
168
How to find the pressure at the casing shoe once the influx is out of the annulus and the pump is shut down
Hydrostatic pressure above the shoe including the sicp
169
What happens to casing shoe pressure as kill mud enters the annulus
Casing shoe pressure decreases
170
Total accumulator volumes refers to what
Total volume of nitrogen and hydraulic fluid
171
An koomey system should be equipped to recharge in how many minutes
2 minutes
172
What are blowdown lines used for
To prevent overloading the poor boy
173
Where are blowdown lines located
Downstream of the choke
174
What is the recommended capacity of the bop hydraulic reservoir on a koomey unit
Two times the usable fluid capacity
175
What should the BOP stack be tested to during initial acceptance test
150% of rated capacity
176
What is the api recommendation for testing BOP
Prior to installation on well
After BOP repair
Within 21 days
177
After installation of BOP on well a sensible precaution is to -
Function test all items on the stack
178
Prior to installing BOP on the well it is advisable testing the BOP to -
100% of its rated pressure
179
What should be done to prevent corrosion of BOP components when dealing with H2S
Maintain high PH
Drill with OBM
An addition of zinc carbonate to the mud
180
During a BOP test test water is observed exiting the weep hole what action should be taken
Replace the mud seal
181
What is the preferred method to operate a diverted
Automatic system that will close the diverted once the vent line valve is open
182
What piece of equipment can function as a diverted with pipe in the hole
Rotating head or rotating BOP
183
If the vent line had no valve where should it be located
Above the flowline
184
Which annular is NOT wellbore assisted
Cameron D
185
Which annular is commonly used as a diverted
Hydril MSP
186
What is the maximum closing pressure of pipe rams
3000psi
187
What chemicals can damage the annular element
Methanol and nitrogen
188
When should a BOP be tested
Prior to to being put into operation
After repair
Every 21 days
In accordance with local laws
189
When should a diverted be function tested
Upon installation and every 7 days
190
What pressure should the diverted be tested to
250psi for 5 mins with no visual leaks
191
Diverted closing times are
20 inch and smaller 30 seconds
Above 20 inch 45 seconds
192
What ID should a choke hose have
MASP up to 5000psi 2” above 5000psi 3”
193
How to remove and prevent hydrates
Inject glycol to prevent it and inject methanol to remove it
194
What effects the value of the SICP
Hole or Annulus capacity
Pore pressure
Kick volume
195
When does a salt water kick give the most surface casing pressure
Immediately after the well has been shut in
196
If the influx is in the horizontal section of the well would the sidpp and SICP be the same
Yes
197
If the influx is below the bit will sidpp and SICP be the same
Yes
198
When does gas cut mud reduce BHP the most
When it is at surface
199
If a a kill has been delayed and pressures start to increase what is the safest way to keep BHP constant
Bleed off mud keeping Drill pipe pressure constant
200
What is meant by abnormal pressure relating to fluid pressure in the reservoir
Formation fluid pressure that exceeds formation water hydrostatic pressure
201
What indicates the well may be going under balance
A change in shape and cutting size
Increase background gas levels
202
If a shallow gas flow is detected what should you do regarding pump speed as the flow is diverted
Increase pump speed
203
If there is a wash in the string what will it effect regards pressures
BHP and SCR
204
Is SICP is usually higher than SIDPP if large amounts of cuttings are in the annulus
No SICP will be lower
205
Kicks are circulated out slower so as not to overload the ?….
MGS
206
If SICP and SIDP are not equal at after first circulation of Drillers method what action should be taken
Restart kill using w & w method
207
When does kill mud effect SICP
As it enters the annulus
208
If there is a wash in the string what kill method is used
Volumetric
209
What three indicators are there that formation fluid pressure is increasing
Connection gas
Increase in cuttings size
Increase in torque and drag
210
What is the supply pressure and closing pressure of a Diverter
Supply pressure is 3000psi
Closing pressure is 750psi to 1200psi
211
What is used to close a BOP function
Stored hydraulic pressure
212
When should Annular closing pressure be adjusted to ensure a positive seal has been achieved in preparation for stripping
Once SICP has stabilised
213
What is the main disadvantage with using a flapper valve in the string
It is not a tested barrier
214
What is the minimum air pressure which will allow a remote function to be carried out on the koomey
90psi
215
Why does the accumulator have stored fluid
To ensure API closing times can be achieved
To secure the well in a power outage
216
According to API what is the minimum diameter of the choke manifold bypass line
At least equal to the choke line diameter
217
What are blowdown lines used for
To prevent the MGS overloading
218
Why is a MGS used to remove gas from the mud instead of a vacuumed degassed
MGS can handle more flow
219
When selecting a test pump to pressure test a BOPwhat ration must the pump provide
1.1to 1
220
Why is the kill line placed below the lower pipe rams
To monitor the well or bullhead with the lower pipe rams closed
221
How will casing pressure react as the drill string is stripped into the influx
The sicp will increase due to the influx getting longer
As sicp is the hydrostatic difference between the mud weight grad and the influx grad multipled by the influx height
222
What will happen to BHP when you strip through a gas bubble
BHP will decrease
223
Does low permeability formation drilled with OBM make it harder to detect the well flowing
Yes
224
According to API 16D what is the time limit which charge pumps must fully recharge the accumulator system
2 mins
5 mins
10 mins
15 mins
15 mins
