Transcript
Compressor control menu
Cost of operating turbo compressors
Maintenance cost
Operating cost
Commissioning cost
Putting it in perspective
Compressor operation
Centrifugal compressors
Axial compressors
Compressor system classifications
Developing the compressor curve
The surge phenomena
Compressor control
Acrobat
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Repairs are expensive
Costs of repairs - materials and labor
3,000 hp
Process gas compressor
20,000 hp
Axial air blower
Seals
$20,000
$50,000
Bearings
$10,000
$25,000
$200,000
$750,000
Rotor Assembly
Compressors
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Operating costs are large
Cost to operate one turbo compressor per year:
Plant air compressor
1,000 HP (746 kW)
$457,000
Wet gas compressor
4,000 HP(2,984 kW)
$1,830,000
Propylene refrigeration comp.
40,000 HP(29,480 kW)
$18,300,000
Assumes power at $.07 per kilowatt hour or $457 per horsepower per year.
Energy costs vary due to local conditions.
Energy Saving Examples
Energy Savings Predictions
Compressors
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Energy savings examples
resulting from reduced recycle or blow-off
Compressor
application
Compressor
shaft power
Actual achieved
savings
Actual Energy
Savings Result
From
Propylene
refrigeration
40,000
hp ( 29 MW)
$1,200,000
Improved Antisurge Protection and Capacity Control
FCCU air blower
Centac air compressor
15,000 hp (11.2 MW)
$155,000
1,500 hp (1.1 MW)
$78,000
Energy Savings Predictions
Compressors
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Available energy savings can be predicted
Less than one year pay-backs* typical by reducing recycle of blow-Off
Pay-back 12
Period 11
(Months)
10
Pay-back less than 10
Months with 15% Reduction
9
8
7
Pay-back less than 6
Months with 15% Reduction
6
5
1000 HP
4
3
3,500 HP
Pay-back approximately 1
Month with 15% Reduction
2
1
20,000 HP
0
5
10
15
20
25
30
35
Reduced Recycle
(Per Cent of Maximum Compressor Flow)
*Assumes electro motor power At $0.05 US per kilowatt hour or turbine power at $327
per horsepower per year. Tax consequences are not considered in pay-back period
due to varying tax policies around the world.
Energy Saving Examples
Compressors
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Downtime costs can be enormous!
• 60,000 BPD Cat Cracker: $90,000 per hour, lost sales plus
fixed expenses. The biggest units are twice this size!
• Natural Gas Production, 100 MMSCFD: $12,500 per hour
lost sales plus fixed expenses.
• Consequences of downtime: Lost profit, lost customer
goodwill, repair costs, attention of top management.
Compressors
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Commissioning costs are large
Process
Start-up Cost Per Day
100 MMSCFD
Natural Gas Plant
$375,000
60,000 BPD
Cat Cracker
$2,300,000
•
Includes lost sales plus fixed operating expenses.
•
Most turbo compressor control system design problems are
discovered during commissioning.
•
Delays due to turbomachinery control problems are not unusual.
•
Startups are faster with a properly designed turbomachinery
control system.
Compressors
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Putting it in perspective
30-year life cycle costs for a 20,000 hp compressor
Maintenance Costs
$4.5 Million
Initial Cost
$1.5 Million
97%
of total costs
Energy Costs
$180 Million
Costs in constant dollars
Source: Experiences in Analysis and Monitoring Compressor Performance
Ben Duggan & Steve Locke
E.I. du Pont, Old Hickory, Tennessee
24th Turbomachinery Symposium
Compressors
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Putting it in perspective
30-year cost per 1,000 hp
$ Millions
15.0
What can we control?
10.0
Uncontrollable
Controllable
?
5.0
0.0
Initial Cost
Maintenance
Energy
Costs in constant dollars
Lost
Production
Source: Experiences in Analysis and Monitoring Compressor Performance
Ben Duggan & Steve Locke, E.I. du Pont, Old Hickory, Tennessee
24th Turbomachinery Symposium
Compressors
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Centrifugal compressors
•
Widespread use, many applications
•
Gas is accelerated outwards by rotating impeller
•
Can be built for operation as low as 5 psi, or operation
as high as 8,000 psi (35 kPa or 55,000 kPa)
•
Sizes range from 300 hp to 50,000 hp
DIFFUSERS
Cross Section of Horizontal Split
Picture of Horizontal Split
Cross Section of Barrel Type
Picture of Barrel Type
Cross Section of Integrally Geared
Picture of Integrally Geared
IMPELLERS
Single Case Compressor
Centrifugal Impeller
Compressors
Picture of Gear and Impellers
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Cross section of horizontal split
Discharge volutes
Impeller inlet labyrinth seals
Impellers
Shaft and labyrinth seal
Drive coupling
Journal bearing
Casing
(horizontally split flange)
Thrust bearing
Compressor discharge nozzle
Compressor inlet nozzle
Picture of Horizontal Split
Centrifugals
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Picture of horizontal split
Cross Section of Horizontal Split
Centrifugals
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Cross section of barrel type compressor
Picture of Barrel Type
Centrifugals
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Picture of barrel type compressor
Cross Section of Barrel Type
Centrifugals
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Cross section of bull gear compressor
Labyrinth seals
Drive coupling
Impellers
Main gear
Journal bearing
Inlet guide vanes
Pinion shafts
Gear casing
Compressor volutes
Picture of Gear and Impellers
Picture of Integrally Geared
Centrifugals
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Picture of bull gear compressor
Picture of Gear and Impellers
Cross Section of Integrally Geared
Centrifugals
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Picture of (bull) gear and impellers
Picture of Integrally Geared
Cross Section of Integrally Geared
Centrifugals
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Axial compressors
•
Gas flows in direction of rotating shaft
•
Can be built for lower pressures only
10 to 100 psi (0.7 to 6.8 Bar)
•
High flow rate
•
Efficient
•
Not as common as centrifugals
Stator Blades
Shaft
Rotor Blades
Casing
Rotor
Blades
Stator
Blades
Casing
Cross Section of Axial
Picture of Axial
Compressors
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Cross section of axial compressor
Guide-vane actuator linkage
Labyrinth seals
Compressor rotor
Rotor blades
Adjustable guide vanes
Thrust bearing
Compressor inlet nozzle
Compressor outlet nozzle
Picture of Axial
Axials
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Picture of axial compressor
Cross Section of Axial
Axials
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Compressor system classifications
Single-Section, Three-Stage
Parallel Network
Single-Case, Two-Section, Six-Stage
Two-Case, Two-Section, Six-Stage
Series Network
Compressors
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Developing the compressor curve
R
Pcdpc c
DP
R
H
DischargeRatio
Differential
Pressure
Polytropic
Pressure
Head
Pressure
(Pd/P(P
) 2or
) -(P
PR
)process,2
or
s(P
d
s/P
2
1) (P2 - P1)
Rprocess,1
Rc2
Rc1
Compressor curve
for a specific
speed N1
Q2
Q1
Compressors
Qs,
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normal
mass
vol
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Developing the compressor curve
process limit
Rc
adding control
margins
maximum speed
surge limit
power limit
stonewall or
choke limit
Actual available
operating zone
stable zone
of operation
minimum speed
Qs,
Compressors
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How an airplane wing develops lift
v1, p1
v2, p2
Bernoulli’s law
•
pstatic + 1/2rv2 + rgH = Constant
•
The term rgH is negligible for the wing
•
Then: pstatic + 1/2rv2 = Constant
•
•
•
Lift
Due to the shape of the
wing: v2 < v1 thus p2 > p1
As a result there is Dp or
lift
And the plane can
fly
Compressors
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How the airplane develops stall
Lift
Lift
Lift
Lift
•
As the wing tilts back the Dv changes and thus the Dp
•
This leads to more lift
•
When the wing is tilted too much the streaming profile
suddenly changes from laminar to turbulent
•
The air no longer “sticks” to the wing and the lift is lost
•
The plane starts to fall down
Compressors
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Developing the surge cycle on the compressor curve
Pd
•
Compressor reaches surge point A
• • From
A to B
20 - 50
ms
Drop
into surge
Compressor
looses
itsstarts
abilitytotobuild
make
•
Compressor
pressure
pressure
•
From
C•to DCompressor
20 - 120“rides”
ms
Jumptowards
out of surge
curve
surge
•
Suddenly
P
drops
and
thus
P
>
P
d
v
d
•
Point
A
is -reached
• • A-B-C-D-A
0.3
3
seconds
Surge
cycle
Plane• goes
tosurge
stall -cycle
Compressor
surges
The
is complete
B
Pv
Rlosses
Pd
Pd
= Compressor discharge pressure
Pv
= Vessel pressure
Rlosses = Resistance losses over pipe
A
•
•
•
•
Pressure builds
•
System pressure is going down
D
Resistance
goes
up
•
Compressor is again able to overcome Pv
Compressor
“rides”
the curve “jumps” back to
C
•
Compressor
performance curve and goes to point D
Pd = Pv + Rlosses
Electroflow
motor
is started
• • Forward
is re-established
•
Because Pv > Pd the flow reverses
•
Result
of
flow
reversal
is
that
pressure
goes
•
Machine accelerates to nominal
•
Compressor operating point goes to point B
down
speed
•
Pressure goes down => less negative flow
•
Compressor reaches performance
curve
•
Operating point goes to point C
•
Machine shutdown
no flow, no pressure
Qs,
Note: Flow goes up faster because
pressure is the integral of flow
vol
Compressors
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Major process parameters during surge
FLOW
1
2
TIME (sec.)
2
TIME (sec.)
2
TIME (sec.)
•
Rapid pressure oscillations
with process instability
•
Rising temperatures inside
compressor
3
TEMPERATURE
1
Rapid flow oscillations
Thrust reversals
Potential damage
3
PRESSURE
1
•
•
•
3
Compressors
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Surge description
•
Flow reverses in 20 to 50 milliseconds
•
Surge cycles at a rate of 0.3 s to 3 s per cycle
•
Compressor vibrates
•
Temperature rises
•
“Whooshing” noise
•
Trips may occur
•
Conventional instruments and human operators
may fail to recognize surge
Compressors
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Some surge consequences
•
Unstable flow and pressure
•
Damage in sequence with increasing severity
to seals, bearings, impellers, shaft
•
Increased seal clearances and leakage
•
Lower energy efficiency
•
Reduced compressor life
Compressors
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Factors leading to onset of surge
•
Startup
•
Shutdown
•
Operation at reduced throughput
•
Operation at heavy throughput with:
-
•
Trips
Operator errors
Load changes
Cooler problems
Driver problems
-
Power loss
Process upsets
Gas composition changes
Filter or strainer problems
Surge is not limited to times of reduced throughput. Surge
can occur at full operation
Compressors
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Compressor control
Objectives
Performance control
Major challenges of compressor control
Loadsharing for parallel compressors
Location of the surge limit
Compressor networks
High speed of approaching surge
Base loading parallel compressors
Control loop interactions
Equal flow division system
Loadsharing of multiple compressors
CCC’s equidistant Loadsharing system
Antisurge control
Other topics
Basic antisurge control system
Fall-back strategies
Protection #1: PI control
Limiting control
Protection #2: Recycle Trip
Pressure Override Control (POC)
Protection #3: Safety On
Flow Measuring Devices (FMD’s)
Output linearization
Antisurge control valve
The tight shut-off line
Piping lay-out considerations
Influence of controller execution time
Dynamic simulation single compressor
Dynamic simulation parallel compressors
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Major control system objectives
(user benefits)
1. Increase reliability of machinery and process
• Prevent unnecessary process trips and
downtime
• Minimize process disturbances
• Prevent surge and surge damage
• Simplify and automate startup and shutdown
2. Increase efficiency of machinery and process
Energy Saving Examples
•
•
•
•
Operate at lowest possible energy levels
Minimize antisurge recycle or blow-off
Minimize setpoint deviation
Maximize throughput using all available
horsepower
• Optimize loadsharing of multiple units
Compressor control
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Calculating the distance between the Surge
Limit Line and the compressor operating point
The Ground Rule
– The better we can measure the distance to surge, the closer we can
operate to it without taking risk
The Challenge
– The Surge Limit Line (SLL) is not a fixed line in the most commonly used
coordinates. The SLL changes depending on the compressor inlet
conditions: Ts, Ps, MW, ks
Conclusion
– The antisurge controller must provide a distance to surge calculation that
is invariant of any change in inlet conditions
– This will lead to safer control yet reducing the surge control margin which
means:
• Bigger turndown range on the compressor
• Reduced energy consumption during low load conditions
Compressor control
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Commonly used (OEM provided) coordinate
systems of the compressor map
•
Typical compressor maps include: (Qs, Hp), (Qs, Rc), or (Qs, pd)
coordinates, where:
Qs = Suction flow and can be expressed as actual
or standard volumetric flow
Hp = Polytropic Head
Rc = Compressor Ratio (pd / ps)
pd = Discharge pressure of the compressor
ps = Suction pressure of the compressor
ks = Exponent for isentropic compression
•
These maps are defined for (1) specific set of inlet conditions:
ps, Ts, MW and ks
Compressor control
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The problem with commonly used (OEM provided)
coordinate systems of the compressor map
•
These coordinates are NOT invariant to suction conditions as shown
•
For control purposes we want the SLL to be presented by a single
curve for a fixed geometry compressor
Compressor control
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Developing invariant coordinates
•
•
The following variables are used to design and to characterize
compressors
Through dimensional analysis (or similitude) we can derive two
sets of invariant coordinates
Fundamental variables
characterizing compressor
operation
Hp = f0(Q, w, m, r, a, d, a)
Invariant coordinates
Set 1
Set 2
hr
qr
Ne
a
jr
Re
Rc
qr
Ne
a
jr
Re
Dimensional analysis
or Similitude
J = f1(Q, w, m, r, a, d, a)
where:
• Hp
• J
• Q
w
m
r
• a
• d
a
= Polytropic head
= Power
= Volumetric flow rate
= Rotational speed
= Viscosity
= Density
= Local acoustic velocity
= Characteristic length
= Inlet guide vane angle
where:
• hr
• qr
• Ne
a
• jr
• Re
• Rc
Compressor control
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= Reduced head
= Reduced flow
= Equivalent speed
= Guide vane angle
= Reduced power
= Reynolds number
= Pressure Ratio
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Coordinates (Hp, Qs) and (hr, qr2)
(Hp, Qs)
(hr, qr2)
NOT invariant coordinates
Invariant coordinates
where:
• Hp
• Qs
• hr
• qr2
= Polytropic head
= Volumetric suction flow
= Reduced head
= Reduced flow squared
Compressor control
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Coordinates (Rc, Qs) and (Rc, qr2)
(Rc, Qs)
(Rc, qr2)
NOT invariant coordinates
Invariant coordinates
qr2
where:
• Rc
• Qs
• qr2
= Pressure ratio
= Volumetric suction flow
= Reduced flow squared
Compressor control
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Coordinates (Rc, jr) and (Rc, Ne2)
where:
• Rc
• jr
• Ne2
(Rc, jr)
(Rc, Ne2)
Invariant coordinates
Invariant coordinates
= Pressure ratio
= Reduced power
= Equivalent speed squared
Compressor control
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Representing the SLL as a single curve
using reduced coordinates
•
A coordinate system that is invariant to suction conditions is:
Hp
hr
(ZRT)s
•
and
qr
Qs
( ZRT)s
Squaring the flow will still keep coordinates invariant:
Hp
hr
(ZRT)s
and
2
Q
s
qr2
( ZRT)s
hr
2
qr
Design
Nitrogen Off-gas
MW
MW
MW
Ps
Ps
Ps
Ts
Ts
Ts
ks
ks
ks
Compressor control
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Calculating qr2 (reduced flow squared)
qr
2=
Qs 2
(ZRT)s
•
•
•
•
•
•
•
where:
R
Ru
R
MW
ps
K
Dpo,s
• Ts
• Zs
K . Zs . Ru . Ts Dpo,s
.
MW
ps
=
(ZRT)s
Dpo,s
=
ps
= Ru / MW
= Universal gas constant
= Specific gas constant
= Molecular Weight of the gas
= Suction pressure
= Orifice plate constant
= Differential pressure across orifice plate
= Temperature of the gas in suction
= Compressibility of gas in suction of compressor
• The antisurge controller calculates qr2 using ps and Dpo,s transmitters
Compressor control
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Calculating hr (reduced head)
hr =
Hp
(ZRT)s
Zs . Ru . Ts
Rcs-1
.
MW
s
=
(ZRT)s
Rcs-1
=
s
log(Rt)
• For polytropic compression Rt = Rcs thus s =
log(Rc)
• R
= Ru / MW
• Rt
= Td / Ts
Temperature ratio
• Rc
= pd / ps
Pressure ratio
where:
• Ru
= Universal gas constant
• R
= Specific gas constant
• MW
= Molecular Weight of the gas
• pd
= Discharge pressure
• ps
= Suction pressure
• Zs
= Suction compressibility
s
= Exponent for polytropic compression
• The antisurge controller calculates hr using pd, ps, Td and Ts transmitters
Compressor control
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Building the Surge Limit Line
• Any curvature of the Surge Limit Line can be characterized as a
function of the ordinate hr
• The surge parameter is defined as:
f1(hr )
Ss 2
qr ,op
• The function f1 returns the value of qr2 on the SLL for input hr
hr
hr
2
2
qr,SLL
qr
Compressor control
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The surge parameter Ss
2
• The function f1 returns the value of qr on the SLL for input hr
• As a result:
Ss =
q2r,SLL
q2r,op
hr
Ss > 1
• Ss < 1
:
stable operating zone
• Ss = 1
:
surge limit line (SLL)
• Ss > 1
:
surge region
OP
hr
Ss < 1
2
2
qr,SLL
2
qr,op
qr
OP = Operating Point
Compressor control
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Introducing the distance between the operating
point and the Surge Control Line
•
Step 1:
Introduce parameter
d = 1 - Ss
•
Step 2:
Introduce parameter
DEV = d - surge margin
•
The parameter DEV is independent of the size of the compressor
and will be the same for each compressor in the plant
hr
d =0
Ss = 1
Benefits:
d <0
DEV = 0
•
One standard surge parameter
in the plant
•
No operator confusion:
Ss > 1
DEV < 0
Ss < 1
•
DEV > 0
Good
d >0
•
DEV = 0
Recycle line
DEV > 0
•
DEV < 0
Bad
2
Surge margin
qr
Compressor control
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Simplifying the surge parameter
by replacing hr with Rc
• Reduced Head hr can be replaced by Rc while keeping the
coordinate system invariant to suction conditions
• The surge parameter Ss now becomes
Ss =
f1(Rc)
2
qr,op
2
where the function f1( ) returns the value of qr,SLL
on the SLL for the input Rc
• This eliminates the need for Td and Ts transmitters for control
Important Note: CCC still strongly recommends Td and Ts
transmitters as well as rotational speed N for compressor
monitoring purposes
Compressor control
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The simplest CCC surge parameter
• An antisurge algorithm can be designed around two transmitters:
Dpo and Dpc
• The parameter Ss =
f1(Rc)
2
qr
is invariant to inlet conditions and speed
• For two transmitters choose the function f1 to be (Rc - 1)
f1(Rc)
Ss =
2
qr
Rc - 1
= Dp
o
ps
(
=
pd
-1
ps
Dpo
)
.
ps
pd - ps
=
Dpo
=
Dpc
Dpo
• Selecting the specific function for f1(Rc) to be (Rc - 1) keeps the
map invariant to inlet conditions and speed
Compressor control
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Disadvantage of the Dpc /Dpo surge parameter
• The SLL is rarely a straight line in the coordinates qr2 and Rc
• The parameter Dpc /Dpo represents a straight line in the invariant
coordinates qr2 and Rc
• The Dpc /Dpo approach results in loss of turn down and
unnecessary recycle
Rc
loss of operating envelope
Actual Surge Limit Line (SLL)
SLL calculated by antisurge
controller using
Dpc /Dpo = constant
2
qr
Compressor control
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Actual field data showing disadvantage of
Dpc /Dpo surge parameter
Compressor control
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Surge parameter for compressor with sidestream
Problem definition
1
Dpo,1
P1
T1
2
3
Dpo,2
P2
T2
q3 and T3 are internal to the compressor and cannot be measured
Compressor control
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Derive a new surge parameter for compressor with
sidestream: qrNe
•
Any combination of invariant parameters results in another
invariant parameter
•
Derive equation for surge parameter that does not require
measurement of T and qr at point 3
Step 1:
Reduced flow
Step 2:
Equivalent speed
.
m
ZRT
qr
p
N
Ne
ZRT
.
Step 3:
Combine qr and Ne
where:
.
•
m
•
Z
•
R
•
Ne
•
qr
•
N
•
p
•
T
= mass flow
= Compressibility
= Gas constant
= Equivalent speed
= Reduced flow
= Rotational speed
= Pressure
= Temperature
.
qrNe m ZRT .
p
Compressor control
mN
N
=
ZRT
p
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Calculating the invariant parameter qrNe
1
Dpo,1
p1
.
T1 m1
q3 Ne,3
2
3
Dpo,2
p2
.
m2 T2
p
p
1
2
N
A1 Dpo,1
.
.
.
A
D
p
2
o,2
.
T1
m3 . N
T2 (m1 + m2 ) N
=
=
p2
p2
p3
Compressor control
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Developing invariant surge patameter
Rc vs. qrNe
r
Compressor control
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The approach to surge is fast
Pd
1 SEC.
100%
D
Qs
0
Pd
100%
•
Typically, performance curves are
extremely flat near surge
•
Even small changes in compressor
pressure differential cause large
flow changes.
•
The speed of approaching surge is
high. In only 0.4 seconds, DPO
dropped by 14%, with a 2% change
in DPc
ABC
D
DPo
0
100%
AB C
DPc
0
A
Compressor control
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The approach to surge is fast - another example
100%
DPo
0
1 sec.
100%
DPc
0
For a 2% increase in pressure differential
(DPc), flow rate DPo dropped 9% in 0.3 sec.
Compressor control
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Basic antisurge control system
•
The antisurge controller UIC-1 protects the compressor against surge by
opening the recycle valve
•
Opening of the recycle valve lowers the resistance felt by the compressor
•
This takes the compressor away from surge
Rprocess
Rc
Rprocess+valve
VSDS
Compressor
FT
1
PsT
1
PdT
1
2
qr
Discharge
Suction
UIC
1
•
Surge parameter based on invariant
coordinates Rc and qr
– Flow measured in suction (DPo)
– Ps and Pd transmitters used to
calculate Rc
Compressor control
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Antisurge controller operation
Protection #1: The Surge Control Line (SCL)
Rc
SLL = Surge Limit Line
SCL = Surge Control Line
•
When the operating point
crosses the SCL, PI control
will open the recycle valve
•
PI control will give adequate
protection for small
disturbances
•
PI control will give stable
control during steady state
recycle operation
•
Slow disturbance example
B
A
2
qr
Compressor control
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Adaptive Gain
Enhancing the effectiveness of the PI controller
Rc
•
When the operating point
moves fast towards the SCL,
adaptive gain moves the SCL
towards the operating point.
•
This allows the PI controller
to react earlier
•
As a result a smaller steady
state surge control margin
can be achieved without
sacrificing reliability
•
Fast disturbance example
B
A
2
qr
Compressor control
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Antisurge controller operation
Protection #2: The Recycle Trip® Line (RTL)
SLL = Surge Limit Line
Rc
RTL = Recycle Trip® Line
SCL = Surge Control Line
•
•
•
Total response
Disturbance
When
Operating
the
OP hits
operating
point
arrives
SCL
of
keeps
Moves
controller
the
the
point
PI
moving
back
Operating
controller
hits
is
tothe
the
the
Pointside
opens
towards
Recycle
safe
sum
of(OP)
valve
the
Trip
surge
ofmoves
PIthe
based
Line
control
and
RTL
(RTL)
towards
on
hits
and
proportional
Recycle
the
Recycle
the SCL
and
conclusion
Trip
integral
LineRT(RTL)
action
is:
actiondecays out the
– The
function
–
–
step
response
We are
close to surge
PI
controller
integrates
to stabilize
The
PI controller
is too slow
to
Benefits:
OP
on
SCL
catch the disturbance
– Get
Energy
due to smaller
–
out savings
of the dangerous
zone
surge margin
An open loop response is
– Compressor has more turndown
triggered
before recycle or blow-off
– Surge can be prevented for
virtually any disturbance
2
Output
to Valve
qr
Recycle Trip®
Action
PI Control
Total Response
PI Control Response
+
Recycle Trip® Response
To antisurge
valve
Time
Compressor control
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Improving the accuracy of Recycle Trip®
open loop control
•
Recycle Trip® is the most powerful method known for antisurge
protection
•
But, open loop control lacks the accuracy needed to precisely
position the antisurge valve
•
Open loop corrections of a fixed magnitude (C1) are often either too
big or too small for a specific disturbance
•
The rate of change (derivative) of the compressor operating point
has been proven to be an excellent predictor of the strength of the
disturbance and the magnitude required from the Recycle Trip®
response
•
Therefore, the magnitude of actual step (C) of the Recycle Trip
response is a function of the rate of change of the operating point
or d(Ss)/dt
Compressor control
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Recycle Trip® based on derivative of Ss
Recycle Trip®
Response calculation
C = C1Td
where:
• C
• C1
• Td
• d(Ss)/dt
Output
to valve
Benefits
•
Maximum protection
– No surge
– No compressor damage
d(Ss)
dt
•
Minimum process disturbance
– No process trips
= Actual step to the valve
= Constant - also defines maximum step
= Scaling constant
= Rate of change of the operating point
Medium disturbance
Output
to valve
Large disturbance
100%
Total
PI Control
Total
PI Control
Recycle Trip®
Recycle Trip®
0%
Time
Time
Compressor control
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What if one Recycle Trip® step response is not enough?
•
After time delay C2 controller checks if Operating Point is back to
safe side of Recycle Trip® Line (RTL)
– If Yes:
Exponential decay of Recycle Trip® response
– If No:
Another step is added to the Recycle Trip® response
Output
to valve
Output
to valve
One step response
Multiple step response
100%
Total
PI Control
Total
PI Control
Recycle Trip®
0%
Time
C2
Recycle Trip®
Time
C2 C2 C2
Compressor control
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Antisurge controller operation
Protection #3: The Safety On® Line (SOL)
Rc
SOL = Safety On® Line
SLL = Surge Limit Line
RTL = Recycle Trip® Line
SCL = Surge Control Line
®Recycle
® will
•• Additional
PI
The
If Operating
control
Safetyand
safety
On
Point
response
or
crosses
surge
Trip
shifts
margin
the
Safety
theis
SCL
added
stabilize
RTL
to the
onright
the
new
SCL
On® and
Linethe
themachine
compressor
is in
surge
Compressor can surge due to:
• Transmitter calibration shift
• Sticky antisurge valve or actuator
• Partially blocked antisurge valve or
recycle line
• Unusual large process upset
New SCL
New RTL
Additional surge margin
2
qr
Benefits of Safety On® response:
• Continuous surging is avoided
• Operators are alarmed about surge
Compressor control
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Built in surge detector
Pressure and Flow Variations
During a Typical Surge Cycle
100%
• Surge signature is recorded during
commissioning
• Rates of change for flow and pressure
during surge are determined
• Thresholds are configured slightly more
conservative than the actual rates of
change during surge
Pd
0%
1 TO 2 SECONDS
100%
DPo
0%
20 to 50
milli-seconds
• Surge is detected when the actual rates of
change exceed the configured thresholds
• The following methods can be used:
• Rapid drops in flow and pressure
• Rapid drop in flow or pressure
• Rapid drop in flow only
• Rapid drop in pressure only
• When surge is detected a Safety On®
response is triggered
• A digital output can be triggered upon a
configurable number of surge cycles
Compressor control
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Increase compressor system reliability and
availability with fall-back strategies
•
Over 75% of the problems are in the field and not in the controller
•
The CCC control system has fall-back strategies to handle these field
problems
•
The controller continuously monitors the validity of its inputs
•
If an input problem is detected the controller ignores this input and
automatically switches to a fall-back mode
•
Benefits
– Avoids nuisance trips
– Alarms operator of latent failures
– Increases machine and process availability
Compressor control
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Fall-back strategies for the antisurge and
performance controller
•
Antisurge controller
– If a pressure transmitter fails, a minimum q2r algorithm is used
– If a temperature transmitter fails, hr is characterized as a function
of compression ratio
– If the speed transmitter fails, a conservative speed setting is used
– If the flow transmitter fails
• Redundant transmitter is used
• Output is driven to:
– Last value OR
– Last Value selected: If Last Value >Pre-selected fixed value OR
Pre-selected fixed value selected: If Pre-selected fixed value>Last
Value
•
•
Performance controller
– Switches to redundant transmitter upon primary transmitter
failure
– Output goes to pre-selected value if all transmitters fail or is
frozen
All transmitter failures are alarmed
Compressor control
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Output linearization
• Controller
Dynamic
Existing
Linear
For antisurge
valve
valve
flow
output
gives
control
response
hasisthe
equal
quick
characterized
asame
linear
becomes
percentage
opening
valveas
as
linear
trim
dynamic
is preferred
mirror
mirror
image
flow
image
in
response
the
in the
linear
linear
over
valve
valve
its line
line
complete stroke
Flow rate
through
valve
Controller output
Valve trim
quick opening
Valve trim
Controller
output
equal percentage
Controller
output
Notes
• Used to improve controllers operation when non-linear valves are
used
• Used on retrofits to avoid additional investment in new valve
• Works well with equal percentage characteristics
• Works less satisfactory with quick opening characteristics
Compressor control
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The Tight Shut-off Line (TSL)
Dynamic control range
Flow rate
through
valve
Controller
output
PI Control
Controller
output
Low clamp on controller output
0% to the valve
Rc
SOL SLL RTL
C
SCL
TSL = Tight Shut-off Line
B
A
A
B
Time
C
• At
CCC
The
For
When
Many
the
dynamic
5%
controller
antisurge
antisurge
the
low
oroperating
controller
low
clamp
control
is
clamp
controller
valves
now
value
point
crosses
we
value
“ready
have
the
want
has
isvalve
represents
to
the
the
to
to
a the
Tight
go”
use
TSL
Shut-off
the
right
following
when
closed
range
output
of
the
the
Line
operating
characteristic:
5%
of
position
TSL
the
-(TSL)
100%
the
controller
for
controller
points
that
on
control
the
eliminates
hits
jumps
valve
closes
theto
• Usually
still
leaks
which
results
the
purposes
SCL
disadvantages
valve
low
- energy
point
clamp
at C
0%
value
- point
- point
A value
B the
• in
from
0%
towaste
low
clamp
• This
flow
is below
rate
the low the
clamp
valve
value
is
• Makes
anthrough
annoying
noise
Benefits
(almost) zero and does not
•• Typical
for worn
valveswhen
and valves
No leakage
and noise
controller
change
with
Teflon
seat
is• far
away
from
point
A
Once
the
lowsurge
clamp- is
reached
• Eliminates
noise and energy
the characteristic
is linearwaste
• Eliminates
time in
the response
• Typical dead
low clamp
value
can be
of the
valve
when
thethe
5%antisurge
- we will use
the
5% as
operating
point is close
to the
SCL
value throughout
in this
example
2
qr
Compressor control
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Compressor performance control
•
Also called:
– Throughput control
– Capacity control
– Process control
•
Matches the compressor throughput to the load
•
Can be based on controlling:
– Discharge pressure
– Suction pressure
– Net flow to the user
Compressor control
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Performance control by blow-off or recycle
Pd
Rprocess
B
A
Process
Rprocess + Rvalve
PIC - SP
PT
1
Curve 1
PIC
1
Curve 2
Shaft
power
P1
P2
Notes
2
• •Q
Compressor
Pressure
Point
Required
Power
represents
B2
loss
represents
is
power
is
controlled
operates
P1 energy
in
-P
point
the
by
point
waste
A
B
point
blow-off
is that
P1A
loss
2 in
2
Most
inefficient
control
method
qr
Curve
represents:
would deliver the pressure for Rprocess
Qloss
• Regularly
foundon
in plant
air speed
systems
• Lower speed
variable
systems
• Rare
in other systems
Curve 1
• IGVs
closed on variable geometry
• Not
recommended
compressors
Curve 2
• Inlet throttle valve closed on fixed
speed compressors
2
qr
Compressor control
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Performance control by discharge throttling
Pd
A
Pressure loss
across valve
Rprocess + Rvalve
Rprocess
Process
PIC - SP
PT
1
Curve 1
Curve 2
PIC
1
2
Shaft
power
qr
P1
P2
Curve 1
Curve 2
2
Notes
• Power
Compressor
Required
Pressure
Opening
Lower
resistance
loss
of
is
power
is
valve
controlled
operates
P1 is
-would
would
PP21 in
byreduce
require
point A
• Curve
2 represents:
pressure
resistance
less
speed
drop
to
and
Rover
power
valve
process
• Lower speed on variable speed
Notes
systems
• Extremely inefficient (consumes
• IGVs closed on variable geometry
approx. the same power for every load)
compressors
• Rarely used
• Inlet throttle valve closed on fixed
• Not recommended
speed compressors
qr
Compressor control
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Performance control by suction throttling
Pd
Rprocess
Process
A
PIC - SP
PT
1
Suction valve open
Suction valve throttled
PIC
1
•
2
Shaft
power
qr
P1
2
qr
Required
Inlet
Changing
Pressure
Compressor
valveis
power
suction
manipulates
controlled
operates
is pressure
P1 in
by
suction
point
inlet A
pressure
generates
valve
for
given
position
Raprocess
family of curves
Notes
• Common on electric motor machines
• Much more efficient than discharge
throttling
• Power consumed changes proportional
to the load
• Throttle losses are across suction valve
Compressor control
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Performance control by adjustable guide vanes
Pd
Rprocess
Process
A
PIC - SP
amin
aOP
PT
1
amax
PIC
1
Required
Different
Pressure
Compressor
geometry
is
power
controlled
operates
is
Pmeans
by
point
inletaA
Change of
guide
vanes
angle
1 in
different
guide
for
given
vane
Rdifferent
positioncompressor
curve
results
inperformance
process
Notes geometry
• Improved turndown
• More efficient than suction throttling
• Power consumed is proportional to the
load
• Power loss on inlet throttling is
eliminated
•
2
Shaft
power
qr
P1
2
qr
Compressor control
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Performance control by speed variation
SIC
1
Pd
Rprocess
Process
A
PIC - SP
PT
1
Nmax
NOP
PIC
1
Nmin
•
2
Shaft
power
qr
P1
2
qr
Required is
Changing
Pressure
Compressor
power
speed
controlled
operates
is
generates
P1 in
bypoint
speed
a A of
family
rotation
for
given
of curves
Rprocess
Notes
• Most efficient (Power f(N)3)
• Steam turbine, gas turbine or variable
speed electric motor
• Typically capital investment higher than
with other systems
• No throttle losses
Compressor control
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Limiting control to keep the machine in its stable
operating zone
•
While controlling one primary variable, constrain the
performance control on another variable
CONTROL
•
•
BUT DO NOT EXCEED
Discharge Pressure
Max. Motor Current
Suction Pressure
Max. Discharge Pressure
Net Flow
Min. Suction Pressure
Suction Pressure
Max. Discharge Temperature
Exceeding limits will lead to machine or process damage
Performance controller controls one variable and can limit
two other variables.
Compressor control
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Power limiting in the performance controller
an example
Rc
•
•
Power limit
R1
R2
•
R3
A
D
B
PIC-SP
However
Primary
Limiting
Compressor
Machine
Process
PIC
will speed
would
variable
variable
resistance
hits
power
like
operates
power
machine
tolimiting
PPower
speed
changes
limit
inup
loop
point
to
d decreases
A
from
N
further
machine
takes
in R
order
control
to
atup
RR
Nto
to
and
control
N4 and
controls
pressure
operate
Compressor
operates
in point
2for
11to
32
1
P
in
machine
point
atNspeed
N3
Bdfor
R2 D
at
2
Compressor will operate in
point C for R3 at N3
C
N4
N
N2 3
N1
Benefits
•
Maximum protection
– No machinery damage
•
Qs,
vol
Maximize production
– Machine can be pushed to the
limits without risk of damage
Note: Same approach for other variables (pressures, temperatures, etc.)
Compressor control
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Limiting Ps or Pd using the antisurge controller
VSDS
Compressor
FT
1
Suction
•
•
PsT
1
PdT
1
UIC
1
Discharge
The antisurge controller can be configured to limit:
• Maximum discharge pressure (Pd)
• Minimum suction pressure (Ps)
• Both maximum Pd and minimum Ps
This does NOT conflict with antisurge protection
Compressor control
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Interacting antisurge and performance loops
•
Interaction starts at B
•
Performance controller on
discharge pressure reduces
performance to bring
pressure back to setpoint
•
Unless prevented, PIC can
drive compressor to surge
•
Antisurge controller starts to
operate at B
•
Even if surge is avoided,
interaction degrades pressure
control accuracy
•
Results of interaction
Rc
B
C
A
DPo
Ps
PIC-SP
– Large pressure deviations
during disturbances
– Increased risk of surge
Compressor control
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The performance controller interacts with
the antisurge controller
•
Both controllers manipulate the same variable - the
operating point of the compressor
•
The controllers have different and sometimes
conflicting objectives
•
The control action of each controller affects the other
•
This interaction starts at the surge control line - near
surge - and can cause surge
Compressor control
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Ways to cope with antisurge and
performance loop interactions
•
De-tune the loops to minimize interaction. Result is
poor pressure control, large surge control margins and
poor surge protection
•
Put one loop on manual so interaction is not possible.
Operators will usually put the Antisurge Controller on
manual. Result - no surge protection and often partially
open antisurge valve
•
Decouple the interactions. Result - good performance
control accuracy, good surge protection and no energy
wasted on recycle or blow off
Compressor control
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Interacting antisurge control loops
VSDS
Section 1
Section 2
UIC
1
UIC
2
PIC
1
Disturbance
Rc,1
R
R
R
Rc,2
R
2
2
qr,1
•
•
qr,2
• The
system
is oscillating
of controller
recycle
on
section
Antisurgeofcontroller
Opening
recycle
valve
UIC-1
on
will
section
open
2 •• Opening
Disturbance
Antisurge
comesvalve
from
UIC-2
the
will
open1
caused
Pd,1side
= Ps,2 lead
to decrease
caused
the
recycle
Ps,2 valve
= P•d,1to
to
protect
increase
section
1 controller
discharge
the
recycle
valve
protect
Slowing
down
the
tuning
would
to: section 2
• Pd,2 increases
• Increased risk of surge
against
against
surge
• Result:
Result: surge
••
••
••
••
• Compressor damage
P
decreases
• ••
Pd,1
d,1 increases
• Process trips
P
increases
• ••
Ps,1
s,1 remains constant
• Bigger surge margins • ••
R
decreases
Rc,1
c,1 increases
• surge
Energy
Section
from
surge waste
••
Section 1
1 moves
moves away
towards
remains
constant
Ps,2s,2
decreases
PP
d,2decreases
increases
c,2remains
Pd,2
increases
PR
constant
s,2
Section
2
moves
towards surge
R
decreases
Rc,2c,2increases
Section22moves
movestowards
away from
surge
Section
surge
Compressor control
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Loop decoupling between multiple antisurge controllers
VSDS
Section 1
UIC
1
Section 2
Serial
network
UIC
2
Serial
network
•
All CCC controllers are connected on a serial network
•
This allows them to coordinate their control actions
•
When UIC-2 opens the recycle valve:
•
Section 2 will be protected against surge
•
Section 1 will be driven towards surge
PIC
1
•
How much section 1 is driven towards surge depends on how much the
recycle valve on section 2 is opened
•
The output of UIC-2 is send to UIC-1 to inform UIC-1 about the
disturbance that is arriving
•
UIC-1 anticipates the disturbance by immediately opening its valve
Note: The same applies when the antisurge
valve on section 1 is opened first
Compressor control
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Loop decoupling simplified block diagram
Benefits
VSDS
Section 1
•
•
Section 2
Serial
network
UIC
1
Analog Inputs
UIC
2
®
Each
controller
itshas
PI
and
its
own
Recycle
values
gain
to
M
toPI
Antisurge
UIC-2
UIC-1
Loop
decoupling
reports
is protecting
controller
PI
and
block
value
values
section
UIC-2
Recycle
is
multiplies
ofadded
opens
other
1decoupling
against
TripTrip
to
controllers
its
reported
output
output
valve
surge
to
to
PI
using
UIC-1
protect
and
nUIC-2
• Avoids
control
system
oscillations
®
®
allow
for
tuning
relative
loop
between
section
and
Recycle
antisurge
(performance
Recycle
2Trip
against
valve
Trip
and
values
1ofsurge
antisurge)
with
aregains
added
gain
to output
M2
to
Same
decoupling
takes
place
• Allows
faster
tuning
ofdecoupling
control
system
different controllers
antisurge
valve 1
• Reduced risk of surge
• Allows closer operation to surge limits
without taking risk
From other
controllers
FA
Mode
FA
Mode
DEV1
PI
From other
controllers
Analog Inputs
RT
PIn . Mn
+
RTn . Mn
+
Antisurge
Controller 1
To antisurge valve 1
PI2 . M2
+
RT2 . M2
DEV2
PI
RT
+
Loop
Decoupling
PI1 . M1
+
RT1 . M1
+
PIn . Mn
+
RTn . Mn
+
Loop
Decoupling
Antisurge
Controller 2
To antisurge valve 2
Compressor control
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Compressor networks
•
Compressors are often operated in parallel and, less
frequently, in series
•
The purposes of networks include:
– Redundancy
– Flexibility
– Incremental capacity additions
•
Usually, each compressor is controlled, but the network is
ignored
•
Compressor manufacturers often focus on individual
machines
•
Control of the network is essential to achieve good surge
protection and good performance control of the network
Compressor control
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Control system objectives
for compressors in parallel
•
Maintain the primary performance variable (pressure or flow)
•
Optimally divide the load between the compressors in the
network, while:
– Minimizing risk of surge
– Minimizing energy consumption
– Minimizing disturbance of starting and stopping individual
compressors
Compressor control
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Process Flow Diagram for base load control
VSDS
Compressor 1
Swing machine
UIC
1
PIC
1
Suction
header
HIC
1
Process
VSDS
Compressor 2
UIC
2
Base machine
Notes
• All controllers act independently
• Transmitters are not shown
Compressor control
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Parallel compressor control by base loading
Rc,1
Compressor 1
Rc,2
Compressor 2
Swing machine
Base machine
PIC-SP
QP,1 + QP,2 = QP,1 + QP,2
2
2
qr,1
qr,2
QP,1 QC,1 QP,1
QP,2 QC,2= QP,2
Notes
• Load
Machines
Base
Swing
load
machine
could
machine
operate
one
be is
or
re-divided
can
fully
more
atbe
same
loaded
running
compressors
toReliminate
since
with
runs
suction
recycle
and
recycle
without
letand
therecycle
discharge
other(s) absorb
of both
the
c and
• Base loading is inefficient
machines
load
swings
are tied together
• Base loading increases the risk of surge since
compressor #1 will take the worst of any disturbance
where:
• QP
= Flow to process
• Base loading requires frequent operator intervention
• QC
= Total compressor flow
• Base loading is NOT recommended
• Q -Q
= Recycle flow
C
Compressor control
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P
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Process Flow Diagram for equal flow division
VSDS
RSP
Compressor 1
out
UIC
1
FIC
1
RSP
out
PIC
1
Suction
header
Process
VSDS
RSP
Compressor 2
out
UIC
2
FIC
2
Notes
• Performance controllers act
independent of antisurge control
• Higher capital cost due to extra
Flow Measurement Devices (FMD)
• Higher energy costs due to
permanent pressure loss across
FMD’s
Compressor control
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Parallel compressor control by equal flow division
Rc,1
Compressor 1
Rc,2
Compressor 2
PIC-SP
QP,1 = QP,2
Equal flow
Equal flow
2
2
qr,1
QP,1
qr,2
QP,2QC,2
Notes
Machine
Equal
Machines
Bias
relay
flow
2are
operate
on
operates
division
remote
never
atmight
with
identical
same
setpoint
recycle
work
Rc except
since
would
ifin
while
both
suction
by
only
machines
machine
coincidence
work
andif1discharge
are
curves
still-identical
different
hashave
turn
of both
• •Requires
additional
capital
investment
FMD’s
machines
down
resistance
same
steepness
are
duetied
to piping
together
arrangments
• Requires additional energy due to permanent pressure
loss across FMD’s
where:
• Poor pressure control due to positive feedback in
• QP
= Flow to process
• QC
= Total compressor flow
control system (see next)
• QC - QP = Recycle flow
• Equal flow division is NOT recommended
Compressor control
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Dynamic control problem with pressure to flow
cascade system
•
Rc
•
•
R2
C
R1
B
D
PIC-SP
A
disturbance
isthe
amplified
Pressure
The
In
Process
As
Since
Only
aatypical
FIC
PIC
machine
result
as
the
the
provides
reacts
is
disturbance
controller
PIC
the
the
master-slave
PIC
is
is
master
fast
machine
operating
starts
slow
and
(PIC)
causes
RSP
itand
todoes
will
moves
control
reduce
in
provides
for
the
try
point
the
not
the
FIC
to
toitsis
A
Remote
speed
the
scheme
resistance
point
move
maintain
output
slave
B
its
controller,
toSetPoint
the
output
its
control
toslave
SP
change
yet
suction
pressure
needs
(RSP)
which
from
for
to
throttle
is
R
the
be
Flow
the
toFICR
FICPositive
feedback
system
This
is the
intersection
of 4 1lines:2
controller
valve
approx.
SP comes
or 5guide
times
(FIC)
down
vanes
faster
and the
than
pressure
the
is
The
FIC will speed
the machine to
– Resistance
line Rup
1
master
restored
point
C at speedcurve
N 3 N1
– Performance
–
–
PIC-SP
FIC-SP = Output of PIC
N3
N1
N2
2
FIC-SP
PIC OUT
1
Master
RSP
FIC
1
OUT
Slave
RSP
SIC
1
qr
Notes
• Requires additional capital
investment in FMD’s
• Requires additional energy due to
permanent pressure loss across
FMD’s
• Poor pressure control due to positive
feedback in control system
• Equal flow division is NOT
recommended
Compressor control
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Process Flow Diagram for equidistant control for
parallel compressors
VSDS
RSP
Compressor 1
out
UIC
1
Serial
network
LSIC
1
Serial
network
MPIC
1
Suction
header
Process
VSDS
RSP
Compressor 2
out
UIC
2
Serial
network
LSIC
2
Notes
• All controllers are coordinating
control responses via a serial
network
• Minimizes recycle under all
operating conditions
Compressor control
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Parallel compressor control by equidistant operation
Rc,1
Compressor 1
Rc,2
SCL = Surge Control Line
.1
.2
Compressor 2
DEV = 0
.1
.2
.3
.3
PIC-SP
Dev2
Q1 Q2
N1 N2
2
Dev1
2
qr,1
qr,2
DEV1
•
•
•
DEV2
Notes
Since
The
Machines
DEV
DEV
isare
operate
is
a dimensionless
kept at
at same
the same
Rcnumber
all
since
relative
sorts
suction
representing
ofdistance
machines
and discharge
to the
can
the distance
be
Surge
mixed:
of Control
both
between
small,
Line
the
• Maximum turndown (energy
savings) without recycle or blow-off
machines
operating
(SCL)
big,
axials,
point
are
centrifugals
tied
and
together
thewhen
Surge
Line
Recycle
will
only
start
allControl
machines
are on their SCL
• Minimizes the risk of surge since all machines absorb part of the
Lines
This
The
DEV
means
of equal
willinbe
practice
DEV
the can
same
the
befor
plotted
same
all machines
DEV
on the
for both
performance
but machines
they willcurves
operateasatshown
disturbance
different
speeds and
flow rates
• Automatically
adapts
to different size machines
• CCC patented algorithm
Compressor control
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Compressors in parallel - the primary response
•
•
•
•
•
•
•
If DEV
Master
The
In
When
the
output
primary
the
<=
controller
0machine
of
apply
the
response
loadsharing
controls
master
is close
block
controller
the
to the
gain
main
the SCL
controller
PID
Process
the
goes
Variable
to
checks
master
the primary
controller
if(PV)
the machine
via
response
its
will
PID
no
iscontrol
block
close
longerin
toblock
reduce
the
the SCL:
Output goes to antisurge valve
loadsharing
performance
controller
to
control
the primary
variable
Yes: to
don’t
reduce
capacity
- keepisoutput
In– order
check
if the
machine
close
to
constant
the
the controller
primary response
needs
TheSCL
master
will startblock
to open
the
–
No:
reduce
capacity
as
necessary
the
DEV
recycle valve to control the primary variable
Apply loadsharing gain M0
The DEV is reported by the antisurge
The
output of the master controller goes via
controller
the primary response block directly to the
performance control element
Master Controller
PV
PID
SP
Analog Inputs
Don’t change
output
FA
Mode
No
DEV <
>0
DEV
DEV
DEV
Yes
PI
Apply loadsharing
gain
Primary
response
RT
Primary
response
x
+
+
Antisurge
Controller
Primary response
To
Toantisurge
performance
valve
control element
Loop
Decoupling
Loop
Decoupling
To antisurge valve
Compressor control
Loadsharing
Controller
To performance
control element
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The load balancing response
•
•
This
In
Other
The
order
fast
antisurge
loadsharing
master
average
loadsharing
to
master
balance
controller
DEV
controller
controller
controller
is
controllers
the
sent
calculates
machines
reports
out
controls
reports
to
also
all
the
the
they
this
report
the
actual
need
The
load
balancing
block
is
a
slow
primary
to
DEV
their
average
loadsharing
bePV
to
DEV
kept
the
also
process
ofPV
at
all
load
controllers
the
to
to
reported
the
the
balancing
same
variable
master
master
DEV
DEV
toby
block
become
controller
controller
PV’s
directly
in the SP
controller
that
will
equalize
all
DEV’s
for all
manipulating
loadsharing
for
all load balancing
controller
the finalblocks
control elements
parallel compressors
This reported DEV becomes the Process
Its
output(PV)
is added
the balancing
total output
to
Variable
for thetoload
PID
the
loopperformance control element
DEV from other
loadsharing controllers
Master Controller
PV
PID
SP
Average
Analog Inputs
DEV
•
•
FA
Mode
DEV
DEV
DEV
PV
PI
Primary
response
RT
SP
Load
balancing
Primary
response
+
+
Antisurge
Controller
Loop
Decoupling
Loop
Decoupling
To antisurge valve
Compressor control
Loadsharing
Controller
To performance
control element
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The Pressure Override Control (POC) response
Benefits
• The
When
There
Opening
As
soon
operating
CCC
primary
a
islarge
aas
of
master
high
the
PID
disturbance
point
antisurge
chance
operating
loop
controller
rides
will
to valve
point
stabilize
exceed
the
occurs
has
curve
is
drops
a Pressure
the
it
much
the
can
and
relief
under
the
•
DEV from other
loadsharing controllers
Rc
PV
PID
PV
SP
PI
(One-Sided)
SP
Average
Analog Inputs
Relief valve
setting
POC-SP
DEV
•
•
Master Controller
operating
happen
pressure
valve
Override
faster
the
POC-SP
setting
than
that
Control
rises
point
aline
the
reduction
and
sharply
on
performance
the
(POC)
trip
the
antisurge
the
PIC-SP
in
mode
process
speed
control
that
line
valves
willstart
open
Fast
response
during
fast
upsets
element
the
to
close
antisurge
again
(e.g. valve
speed)
toisget
toothe
slow
disturbance
to keep the
Avoid process trips due to lack of
pressure
under
control
under
quickly
control
response in performance control elements
Allows closer operation to process limits
without taking risk
FA
Mode
DEV
DEV
DEV
PIC-SP
PV
PI
Primary
response
RT
SP
Load
balancing
Primary
response
+
+
Antisurge
Controller
Loop
Decoupling
Loop
Decoupling
Loadsharing
Controller
2
qr
To antisurge valve
Compressor control
To performance
control element
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Loadsharing for multi-section compressors
VSDS
RSP
Train A
Section 1
Section 2
out
UIC
1A
Serial
network
UIC
2A
Serial
network
LSIC
A
Serial
network
MPIC
1
Suction
Header
VSDS
Process
RSP
Train B
Section 1
Section 2
out
UIC
1B
•
Serial
network
UIC
1B
Serial
network
LSIC
B
How
Select
By
Share
selecting
tothe
per
operate
load
train
the--equidistant
--section
equal
in theDEV’s
loadsharing
closest
from
forto
the
both
the
controller
Surge
trains
SCL Control
it--ison
--guaranteed
the
the
Line
section
section
(SCL)
that
closest
closest
when
the other
there
totothe
theis
more
section
SCL
than
on one
the same
section
train
perismachine
not in recycle
???
Compressor control
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Selecting the section closest to SCL for parallel operation
Master Controller
PV
PID
PV
SP
PI
•
Both
The selected
lowest
antisurge
DEV
DEV
controllers
is is
selected:
report
the section
reported
their
to:closest
DEV to the
to the
loadsharing
SCL
• Primarycontroller
control
response blocks
(One-Sided)
SP
DEV from other
loadsharing controllers
•
Load balancing block
•
Master controller
averaging block
Average
Analog Inputs
FA
Mode
FA
Mode
DEV1
DEV1
PI
PV
RT
Primary
response
To antisurge valve-1
DEV2
DEV2
SP
Load
balancing
Primary
response
+
Antisurge
Controller
<
PI
+
Loop
Decoupling
Loop
Decoupling
Primary
response
RT
+
Loadsharing
Controller
To performance
control element
Compressor control
Antisurge
Controller
Loop
Decoupling
To antisurge valve-2
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Flow Measuring Device (FMD) selection criteria
•
Main selection criteria for FMD in antisurge control system:
– Repeatability
– Sufficient signal-to-noise ratio
•
Accuracy of the FMD is not critical
•
FMD delays must be absolutely minimal
•
Present state-of-the-art limits the choice of FMD to head flow meters
or to other devices that are based on the principle of velocity
measurement:
–
–
–
–
Orifice plates
Venturi’s
Pitot tubes
etc.
•
Recommended flow range for FMD and transmitter is maximum
compressor flow
•
Recommended Dp corresponding to Qmax, compressor is 10” WC (250
mmH2O) or more
Compressor control
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Flow Measuring Device (FMD) location
VSDS
Compressor
minimum possible
minimum possible
Suction
•
The preferred location of the FMD:
• Suction of compressor
• As close to the inlet flange as
possible
•
Discharge
•
Less preferable location of the FMD:
• Discharge of compressor
• As close to the discharge flange as
possible
Selection of the location should be based on:
• Necessity of surge detection
• Often more difficult with flow measured in discharge
• Capital cost of flow measuring device
• Operating cost of the FMD (permanent pressure loss)
Compressor control
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Response time of the FMD transmitter
•
The speed of approaching surge is high
•
The transmitter type and brand should be
selected based on two major factors:
– Reliability
– Speed of response
•
Desired rise time for Dp (flow) transmitters
is 200 ms or less
– Pressure step is 100%
– The first order response (63%) is less
than 200 ms
•
1 SEC.
100%
0
Ps
100%
ABC
D
Desired rise time for pressure transmitters
is 500 ms or less
0
DPo
Actual
pressure
Transmitter
output
63% response
100%
AB C
1- (1/e)
DPc
•
0
In only 400 ms, DPO dropped by 14%,
with a 2% change in DPc
Time
t1 is less than 200 ms
Compressor control
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The effect of damping the Dpo (flow) transmitter
•
Knowing the flow is essential to determine the distance between the
operating point and the SCL
•
Damping the Dpo (flow) transmitter destroys essential information
Start of Surge
Flow 50
t = 16.0 s
t = 1.70 s
t = 0.03 s
t = 0.20 s
0
Actual Flow
-50
0
1.25
2.50
3.75
Time (seconds)
5
Damping the Dpo (flow) transmitter can paralyze the
complete antisurge control system!!!
Compressor control
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Sizing the antisurge control valve
•
Criteria for antisurge valve sizing based on CCC’s experience
– Provide adequate antisurge protection for worst possible disturbances
– Provide adequate antisurge protection in all operating regimes
– Sized to provide flow peaks greater than what is required in steady state to
operate on the Surge Control Line
– Sized to avoid choke zone
– Not be oversized from controllability point of view
Rc
A
•
Take point A at the intersection of the
maximum speed performance curve and
the Surge Limit Line (SLL)
•
Calculate Cv,calc (or equivalent) for point A
•
Select standard valve size using the
following criteria:
1.8 . Cv, calc < Cv,selected < 2.2 . Cv, calc
Qvol
Compressor control
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Sizing the antisurge control valve - alternative method
•
Rc
A
B
Qvol
An alternative method yielding
excellent results is:
•
Take design point of the compressor
point A
•
Draw a horizontal line through the design
point
•
Take point B at intersection of maximum
speed performance curve and the
horizontal line
•
Calculate Cv,calc in point B
•
Select standard valve size using the
following criteria:
0.9 . Cv, calc < Cv,selected < 1.1 . Cv, calc
Compressor control
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Stroke speed and characteristic of the antisurge valve
Antisurge valve stroke speed
•
Antisurge valve must have speed of response adequate for antisurge
protection for all disturbances
•
Recommended full stroke times:
– Size
Close to open
– 1” to 4”
1 second
– 6” to 12”
2 seconds
– 16” and up
3 seconds
•
Open to close
< 3 seconds
< 5 seconds
< 10 seconds
Closing time needs to be the same order of magnitude to assure the same
loop gain in both directions
Antisurge valve characteristic
•
Normally control valves are selected to be open 80% to 90% for design
conditions
•
Antisurge valves can operate anywhere between 0% and 100%
•
In order to have an equal loop-gain over the whole operating range a linear
valve is required
•
This will allow for the fastest tuning leading to smaller surge margins
Compressor control
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Improving the performance of the antisurge valve
•
Most normal control valves can be made to perform as required for
antisurge control
•
The following steps help improve the performance of the valve
–
–
–
–
–
–
–
Install positioner
Minimize tubing length between I/P and valve positioner
Install volume booster
Minimize volume and resistance between volume booster and actuator
Increase air supply line to 3/4” or more
Increase size of air connection into the actuator
Drill additional holes in actuator - avoids pulling a vacuum
Compressor control
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Piping lay-out consideration when designing an
antisurge control system
•
Piping lay-out influences the controllability of the the total system
•
The primary objective of the antisurge controller is to protect the
compressor against surge
•
This is achieved by lowering the resistance the compressor is feeling
•
The resistance is lowered by opening the antisurge valve
•
Dead-time and time-lag in the system needs to be minimized
•
This is achieved by minimizing the volume between three flanges
– Discharge flange of the compressor
– Recycle valve flange
– Check valve flange
VSDS
Compressor 1
volume to be
minimized
Compressor control
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Using a single antisurge valve increases recycle lag time
Large volume
Section 1
•
•
•
•
Section 2
In order to protect section 1 the antisurge valve needs to be opened
The volume between compressor discharge, check valve and
antisurge valve determines the dead time and lag time in the system
Large volume significantly decreases the effectiveness of the
antisurge protection
Result
Note
–
–
–
–
Poor surge protection
Large surge margins
Energy waste
Process trips because of surge
•
This specific piping layout is found on
many wet gas compressors in FCCU’s
Compressor control
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Sharing recycle coolers degrades surge protection
Section 1
Section 2
Small volume
•
•
The piping lay-out for section 2 is excellent for surge protection
Minimum volume between the three flanges
•
•
The piping lay-out for section 1 is not ideal
Large volume to be de-pressurized decreases ability of the control system to
protect the machine against surge
•
Result
•
•
•
•
Poor surge protection
Large surge margins
Energy waste
Process trips because of surge
Compressor control
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Installing recycle valve upstream from
cooler improves control response
Compressor 1
Increased
volume due
to cooler
Compressor 2
Minimum
volume
•
•
Compressor 1 has ideal piping lay-out for surge protection
Minimum volume between the three flanges
•
•
The piping lay-out for compressor 2 is commonly found in the industry
The cooler creates additional volume and decreases the effectiveness of the
antisurge control system
•
The piping lay-out for compressor 2 can be acceptable if the additional
volume does not create excessive dead time and lag in the system
•
Result
•
•
Increased surge margins
Energy waste
Compressor control
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Recycle lines configured for optimum surge protection
Section 1
Section 2
Section 3
Suction
Process
Minimum
volume
• Compressor has ideal piping lay-out for surge protection
• Minimum volume between the three flanges for all sections
Compressor control
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Which antisurge piping configuration do you choose???
Lay-out #1: Compressor with recycle lines optimally configured for antisurge control
Section 1
Section 2
Section 3
Suction
Process
Lay-out #2: Compressor with coolers upstream of recycle take-off
Section 1
Section 2
Section 3
Suction
Process
•
When selecting
lay-out
the most
residence
time
of
the
gas
in
the
“surge”
volume
Lay-out
These
two
#1
#2 piping
has
requires
minimum
lay-outs
one#2
cooler
volume
are
less
between
common
and thus
thefor
the
flanges
antisurge
capital
and
investment
is
control
the
bestislay-out
lower
should
be verified
to purposes
check acceptable time delays are not exceeded
for
antisurge
control
•
Lay-out #2 will require bigger surge control margins
Compressor control
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Influence of controller execution time
•
Analog controller
100%
SCL
SLL
Operating
point
•
•
0%
Time
•
100%
•
Controller
output
0%
Time
•
•
Leading engineering contractor
performed evaluation of execution
time influence on ability to protect
compressor from surge
Dynamic simulation of compressor
was built
Digital controllers are compared
against analog controller on
simulation
Analog controller has no execution
time and is immediate
Analog controller tuned for minimum
overshoot
Digital controllers get exact same
tuning parameters
Digital controllers get exact same
disturbance
Compressor control
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Analog vs digital controller at 2 executions per second
Analog controller
Digital controller
(2 executions per second)
100%
100%
SCL
SLL
Operating
point
0%
SCL
SLL
Operating
point
0%
Time
100%
Time
100%
Controller
output
0%
Time
Controller
output
0%
Tuning same as analog controller
•
Compressor surged
•
Large process upset would have resulted
Compressor control
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Analog vs digital controller at 3 executions per second
Analog controller
Digital controller
(3 executions per second)
100%
100%
SCL
SLL
Operating
point
0%
SCL
SLL
Operating
point
0%
Time
100%
Time
100%
Controller
output
0%
Time
Controller
output
0%
Tuning same as analog controller
•
Compressor surged
•
Large process upset would have resulted
Compressor control
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Analog vs digital controller at 10 executions per second
Analog controller
Digital controller
(10 executions per second)
100%
100%
SCL
SLL
Operating
point
0%
SCL
SLL
Operating
point
0%
Time
100%
Time
100%
Controller
output
0%
Time
0%
Tuning same as analog controller
Time
Controller
output
•
Compressor almost surged
•
Control system would have to be set up with bigger surge margins
Compressor control
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Fwd
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Analog vs CCC controller at 25 executions per second
Analog controller
CCC antisurge controller
(25 executions per second)
100%
100%
SCL
SLL
Operating
point
0%
SCL
SLL
Operating
point
0%
Time
100%
Time
100%
Controller
output
0%
Time
0%
Tuning same as analog controller
Time
Controller
output
•
Response of CCC controller nearly indentical to analog controller
•
Adding Recycle Trip® to PI control will allow even smaller surge margins
Compressor control
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Dynamic simulation single compressor
VSDS
Compressor
Note: Speed transmitter for
indicating purposes only
ST
1
Load
FT
1
PsT
1
TsT
1
PdT
1
Td T
1
PIC
1
HIC
1
UIC
1
Suction
Process
Serial
network
•
•
•
Compressor is controlled on Pd by PIC-1
HIC-1 controls the process load and can be used to create process disturbances
Controllers communicate via serial communication to computer running the
simulation
MODBUS
Start simulation
Compressor control
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Dynamic simulation parallel compressors
VSDS
RSP
Compressor 1
out
UIC
1
Serial
network
LSIC
1
Serial
network
Load
MPIC
1
HIC
1
Process
VSDS
RSP
Compressor 2
out
UIC
2
MODBUS
Serial
network
Start simulation
LSIC
2
Compressor control
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Fwd
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