Pump Selection and Process Sizing _PROTEC Dept. April 2014_draft 6.ppt

Saipem Contracting Nigeria limited
PORT HARCOURT - May 2014
PROTEC Department
Pump Selection and Process Sizing

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Pump selection & Process Sizing
WHAT IS A PUMP
Is a mechanical device used to transfer liquids from a lower pressure
region to a higher pressure region by transferring externally provided
energy to the liquid in the form of pressure. In other words a pump make
the pumped liquid able to flow up a pressure gradient.
The externally provided energy can be electrical, steam, etc.

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8. Calculation example
7. Engineering details
6. Pump control
5. Effects of fluid’s properties
4. Process sizing
3. Positive displacement pumps
2. Kinetic-Centrifugal pumps
1. Pumps classification
9. Process Data sheet preparation

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Pump selection & Process Sizing Pumps’
Pumps’
classification
classification
The types of pumps commonly used in oil and chemical plants fall into the following
categories:
Kinetic pumps
Positive-displacement pumps
Kinetic pumps are mainly divided into:
Centrifugal pumps (which in turn can be radial, axial or mixed flow)
Regenerative pumps (turbine)
Positive-displacement pumps are divided into:
Reciprocating pumps
Rotary pumps

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The following graphic presents the different pump categories and types
Pumps’
classification
classification

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In general all types are characterized by different parameters:
Performance characteristic:
Curve reporting the pump head in function of the fluid flowrate.
Net Positive Suction Head (NPSH) :
Absolute inlet total head above the head equivalent to the vapour pressure referred
to the NPSH datum plane.
Brake Horse Power (BHP) :
Power absorbed at shaft defined as theoretical hydraulic power increased by internal
losses due to friction of seals and bearings.
Efficiency (ηp) :
Pump’s Total Efficiency is the ratio between the work given from the pump to the
liquid and the work spent from the driver to allow the pump to run and perform their
characteristics
Pumps’
classification
classification

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8. Calculation example
7. Engineering details
6. Pump control
5. Effects of fluid’s properties
4. Process sizing
3. Positive displacement pumps
2. Kinetic-Centrifugal pumps
1. Pumps’ classification
9. Process Data sheet preparation

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Pump selection & Process Sizing Kinetic-Centrifugal pumps
Kinetic-Centrifugal pumps
The energy is yielded to the liquid in the form of kinetic energy and then
transformed into pressure at the pump outlet
In general:
• Lower efficency than positive-displacement type
• higher speed
• higher flowrate in relation to the size of the pump
• less maintenance than positive-displacement type
KINETIC PUMPS
Centrifugal Regenerative
Radial flow
Axial flow
Mixed flow
Turbine single-
stage
Turbine multi-
stage

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Are the most common type used in most process plant
The kinetic energy is transferred to the liquid thrusting it out of the pump casing
tangentially to the rotation at higher pressure by rotary motion of one or more
IMPELLERS.
The impeller “absorb” the energy supplied to the pump shaft through the driver,
and transform it partially into pressure and partially into energy of motion of fluid
(kinetic energy). The DIFFUSER (or casing volute) transform other kinetic energy
into pressure energy an the outlet section of the casing.
KINETIC PUMPS - Centrifugal
Their operation is confined between two flow limits, the “low flow” that might
cause re-circulation problems and the “high flow” rate where the pump can
cavitate than became a very serious problem.
Selection of the right pump is fundamental to save a lot of trouble and to minimize
potential problems and maintenance cost.

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Centrifugal Pumps can be divided according to the following:
a) Shaft Position
Horizontal Pumps
OH / BB Type (see API 610)
Vertical pumps
VS type (see API 610)
b) Number of impellers
Single Stage: one impeller
Multistage: two or more impellers in series
c) Casing split
Axially split: split with the principal joint parallel to the shaft centreline
Radially split: split with the principal joint perpendicular to the shaft centreline
Classification of Centrifugal pumps

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Classification of Centrifugal pumps
Vertical pumps:
•Normally used in services where the Horizontal cannot be used (for low NPSHa or
cryogenic services (-150°C))
•Are normally 2 pieces construction; one barrel under the ground (to recover NPSH)
and one driver above the ground
•Due to this arrangement the advantage is the outline dimension
•This pumps can have different shape according to the different services.
Horizontal Pumps:
•Is the most common family due for all process application
•Cover a huge range of pressure , temperature, capacity and viscosity
•Common characteristic is the horizontal shaft
•Normally are installed on base plate with its own driver and necessary auxiliary

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A centrifugal pump is a machine consisting of a set of rotating vanes enclosed
within a casing.
The vanes impart energy to the fluid through a centrifugal force.
Basic fluidodynamic of Centrifugal pumps

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1) Centrifugal force due to
pumped fluid rotation
2) High pressure and high
velocities at impeller outlet
3) Fluid velocity converted in
pressure inside volutes (spiral
shaped stationary components
with sections gradually rising in
area) or diffuser (ring equipped
with blades)

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c = absolute velocity of the pumped fluid
for an hard-set observer
w = relative velocity for an observer which
rotates together with impeller
u = w*r (with w rotational speed and r
impeller radius)
 C1 (radial direction) depends from inlet
capacity and the inlet area.
 C2 (velocity of fluid enter into diffusor)
will be the lower the greater is the
transformation into pressure energy in
the impeller.
Inlet
section
Outlet section

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 Centrifugal pumps can develop heads up to 4000 m @ 20000 m3/h
 Although this pumps are available for low low flow rates up to 0.5 m3/h, different
selection is suggested below 10 m3/h due to strong decreasing in their efficency
 Due to their very large range of applicability they satisfy nearly all the needs in oil
and gas plants
 Head, BHP, efficency and NPSH of a centrifugal pump vary with the flow rate as
represented in the characteristic curves specific for each pump
General characteristics

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The centrifugal pump can operate at any point of its curve (within limits
imposed by Vendor).
The minimum, normal and rated operating point are defined by the
system in which it is installed.
General
characteristic curves
of a centrifugal
pump

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The characteristic curve can be modified by changing the impeller tip speed
acting on:
Speed of rotation (N)
Diameter (D) Note: a pump is normally designed to contain impellers of different diameters
Q [m3/h]
H [m]
Performance curve’s modification by varying N or D
D,N

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Pump’s Vendor usually provides performance curve referred to design case and
others at different impeller speed or diameter.
Affinity Laws can be used to estimate modified performance with reasonable
accuracy:

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Advantages Disadvantages
Head curve approximated by a parabola Unsuitable for high viscosity liquids
No pulsation in flow Limited head
Variable capacity without variable speed
Limited capability with liquids containing
dissolved vapours
Able to handle solids
Low maintanance required

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API 610
In the Oil & gas industry, almost all process pumps are designed, manufactured and
tested in accordance to the API610.
This International Standard specifies requirements for centrifugal pumps, including
pumps running in reverse as hydraulic power recovery turbines (HPRT), for use in
petroleum, petrochemical and gas industry process services.
 Non API 610 pumps can be used for process services if allowed by contract or
required by client.
 Non API610 are normally used for utilities and general services and are in
accordance to the followings codes:
 More used on European Market
• ISO 5199 – specification for centrifugal pump Class II
 More used on US standard and Market
• ASME B73.1 – Horizontal end suction centrifugal pump for chemical process
• ASME B73.2 – Vertical in line centrifugal pump for chemical process
• ASME B73.3 – Sealless Horizontal end suction centrifugal pump for chemical process.

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API 610 PUMP CLASSES
Centrifugal pumps are classified by API 610 as indicated in the following table:

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CENTRIFUGAL PUMPS – Single Stage pumps
OH1
OH2
 Most commonly used
 Casing supported on the centerline
 Double wear rings on the impeller and
casing
 Possibility of water-cooling on the
pedestal, the seal housing and the
bearings
 High temperature
 Easy removal of the rotor and the
casing support for maintenance
without dismantling pipe flanges
 Safety in handling inflammable liquids

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CENTRIFUGAL PUMPS – Single Stage pumps
 Most commonly used
 Axially split casing
BB1

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CENTRIFUGAL PUMPS – Single or multi-stage with impeller on double support
 Horizontal multistage pump with axially
split casing
BB3

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CENTRIFUGAL PUMPS – Single or multi-stage with impeller on double support
 Horizontal multistage pump with double casing
 Impellers mounted on shaft with bearings at the ends
 2 seal housings
 Single stage : Head up to 350 m
 Multi-stage : Head up to 4000 m
BB5

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CENTRIFUGAL PUMPS – In line pumps
 Wet pit, vertically suspended, single casing diffuser pump
with discharge through the column
 Multistage
VS1

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 Wet pit, vertically suspended, single casing volute pump
with discharge through the column
 Single stage
VS2

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VS4
 Vertically suspended, single casing volute, line-shaft
driven sump pumps
 Single stage
 External lubricating and sealing systems

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VS6
 Double-casing diffuser, vertically suspended pump
 Multi-stage
 Process fluid used as lubricating systems
 Used for systems having limited NPSHA

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VS3
 Wet-pit, vertically suspended, single casing, axial flow
pump with discharge through the column
 Single-stage
 Special arrangement for sea water in-take
 Very high flowrate

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CENTRIFUGAL PUMPS
 In general the choice between a conventional horizontal pump and an
in line pump doesn’t depend on the total costs (installation +
maintenance) but on the specific installation situations.
 The in line pumps are normally preferred if available space is limited.
For details on different kinetic pumps please refer to the Saipem Standard
CR-COR-ENG-PRC-003

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In general:
• Lower speed than kinetic pumps
• physically larger than kinetic pumps for a given capacity
POSITIVE DISPLACEMENT PUMPS
Reciprocating Rotative
piston
plunger
diaphragm
screw
lobe
gear
Pump selection & Process Sizing Positive displacement pumps
Positive displacement pumps

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 Positive displacement pump moves a fixed volume of fluid per stroke cycle by
imparting a propelling force to a fixed volume of liquid from the inlet conditions to
the outlet conditions
 This take place intermittently (reciprocating pumps) or continuously (rotary
pumps)
 Can be simplex (one pumping chamber) or multiplex (many pumping chambers)
 All positive displacement pumps must have a safety valve on the outlet.

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 As this type of pump delivers constant capacity against variable discharge
pressure, theoretically an infinite discharge pressure could be developed
In general the real performance curve of a positive
displacement pump deviates from the theoretical trend
due to intrinsic factors
The maximum head is actually limited by the
safety valve installed

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The mandatory satefy valve on the outlet of these pumps has a double purpose:
• protect the pump and the discharge system from over pressure
• protect the motor from excessive load
 The safety valve must be located before the pump’s isolation valve
 Its discharge line shall be rerouted to the suction vessel in order to avoid
overheating
 In some pump’s models the PSV can be incorporated in the pump casing (solution
not acceptable for process services)
 The PSV set pressure is below the design pressure of the pump but well above its
normal operating pressure.
Safety valve on discharge line

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 Reciprocating pumps use a piston, a plunger or a diaphragm to pump a constant
volume of fluid for each stroke of the element
 High shutoff pressure
 Can operate under low NPSHA conditions
 Pulsating flow
Reciprocating pump
The pulsation can generate vibration on both suction and discharge
lines.
Two solutions can be adopted to minimize or eliminate this problem:
1)Increasing of number of piston or plungers
2)Installation of a dampers system on suction or discharge line

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Reciprocating PISTON PUMP
 The piston moves forwards and backwards inside
the chamber
 In and Out Valves allow the fluid entering and
leaving the chamber.
 The opening and closing of the valves is induced
by the DP between the chamber and the suction
and discharge lines
 Can be single or multi-chamber
 High efficency and high pressure
 The piston pump seal is located on the piston
itself

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Triplex vertical
pump
Multi plunger
horizontal pump
 Work like the piston type
 Can be single or multi-chamber
 High pressure pumps are generally single-
piston type
 The most common type use three pistons
 High efficency and high pressure
 The plunger pump seal is stationary and is
mounted on the plunger shaft
Reciprocating pump

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Reciprocating DIAPHRAGM PUMP
 Operate by the reciprocating movement of a flexible
diaphragm
 Absence of sealing system
 Used for zero leakage
 Used for critical, toxic and inflammable fluids
 Performances limited to 40m3/h and 300 m
 Need frequent maintenance
 Diaphragm is normally
made in SS or PTFE

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Reciprocating METERING PUMP
 Are reciprocating pumps that allow low flow rates to be
regulated with extreme precision.
 Can be piston or diaphragm type
 are normally used for dosing additives
 The flow in metering pumps can vary from a few cm3/h
to 2 m3/h

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Rotary pump
 Rotary pumps are positive displacement pumps which force a fixed volume of
liquid through the pump by rotating action of an internal component.
 The rotating component can be gears, lobes, screws or vanes.
 Are constant speed and constant capacity pumps.
 Are available for up to 100 m3/h with a differential pressure up to 200 bar.
 Usually have a maximum operating temperature of 180°C
 Are used for high viscosity fluids (fuel oils, lubricating oils, greases or asphalts)
not managable by centrifugal pumps or for low viscosity fluid at very low flowrate
 NPSHR is similar to centrifugal pumps
 Generally not suitable for high solids content fluids

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Rotary GEAR Pump
 Are the most often used rotary pumps
 This uses two meshed gears rotating in a
closely fitted casing. Fluid is pumped around
the outer periphery by being trapped in the
tooth spaces
 Used for flowrates of 150-200 m3/h and a
differential pressure of 25-35 bar
 Cheaper and more efficient than screw type

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 Consist of 1, 2 or 3 threaded screws in a
pump housing
 Require less maintenance and have lower
cost than reciprocating type of comparable
capacity but lower efficiency and differential
pressure
 Twin-screw type are available for head up to
20-30 bar and triple-screw up to 200-250 bar
Single screw
pump
Double screw
pump
Screw detail
Rotary SCREW Pump

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Pump selection & Process Sizing Process sizing
Process sizing
The process design of a pump takes place in the following main phases:
Step 1:
Selection of pump type
(preliminary)
Step 2:
Definition of flow scheme
(i.e. flow circuit)
Step 3:
Definition / calculation of
process characteristics and
data
Pump Design
These analisys and calculations must be performed for all significant pump scenarios or distinct delivery
circuits

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The following figures show the general ranges of application of the different pumps:
Step 1 - PUMP SELECTION
Process sizing

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This chart shall be used when the estimated pump head is lower than 300 m
Process sizing

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This table indicates the
various pump types normally
used in oil and chemical
plants, together with their
main characteristics and
fields of application
NOTE
The values of the
characteristics shown are
typical ones and are only
indicative of performance
Process sizing

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 It is very important to identify and to deeply investigate the relevant process
circuit in-between the upstream and downstream controlled pressure points
(usually vessels)
 The two points may coincide to form a closed loop
Step 2 - SCHEME DEFINITION
 Main information to be indicated on the simplified hydraulic sketch of the process
circuit are:
Process sizing
Simplified equipment layout showing components which create head losses (e.g. valves,
orifices, equipment) including TAGs and pressure drops at rated flow
Datum position
Suction & discharge vessel min & max liquid levels (i.e. high-high and low-low levels)
Suction & discharge vessel elevations
Downstream maximum elevation to which the liquid is to be pumped
Piping arrangement including sizes, length, elevations and relative pressure drops
Operating pressures for the upstream and downstream controlled pressure points

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Elevation is positive if the liquid level is above the pump datum, while elevation is
negative if the liquid level is below the pump datum
Process sizing
Step 2 - SCHEME DEFINITION

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Step 2 - PUMP DATUM POSITION
Is the elevation to which values of NPSH are referred to
Typical datum elevation:
First approximation values: Pump capacity (m3/h) Datum elevation (m) (*)
Up to 50 0.6 a.g.
Up to 250 0.9 a.g.
Up to 2300 1.25 a.g.
 2300 0.5 + half pipe diameter
(*) basement included
Process sizing

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Step 2 - FITTINGS AND PIPING LENGHT
Has to be based on pipe routing (lenght and fittings) as per Saipem Standard:
CR-COR-ENG-PRC-002
If the information related to actual piping and system layout are not yet available,
designer shall proceed by assumptions based on plot plan and agreed with Piping
function.
For very preliminary estimation:
Li = ki * Lplot plan
Li = line lenght
Ki = correction coefficient
K value Note
1.5 Lines Inside the process unit
1.2 Lines Outside BL
50 m
Min. preliminary value for
suction line
General rule:
K increases with line diameter
K decreases with line lenght
Different K value can be proposed
in case of special services
Process sizing

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Step 3 - PROCESS DATA
Following the process data required for pump sizing and DS preparation:
To be available To be defined
Min/Max operating T Min/Max Suction P@rated capacity
Fluid properties@all different scenarios (density, viscosity,
Vp, pour point, etc.)
Max discharge P @rated capacity
Min/norm/max and rated capacity Pump DP and head
Upstream and downstream controlled point design P or PSV
set point (if different)
NPSHA
Design discharge P (shutoff P)
Nr of running/stand-by pumps
Utilities available @pump BL
Data have to be defined for all different scenarios (different circuit, different
density, etc) !!!
Process sizing

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Step 3 – Flowrates and rated capacity
 Normal flowrate: normal volume of liquid pumped per unit of time @ op. cond.
 Minimum (1)
& Maximum flowrate: lowest and highest volume of liquid pumped per unit of
time @ all foreseeable operating conditions (including start-up and shut-down)
 Rated capacity: Maximum flowrate + over-design factor (see below):
(1) The minimum flow rate is not to be confused with the minimum continuous stable flow required by the pump and
specified by pump’s Vendor. If the minimum flow required by the process is lower than that required by the pump, a
recirculation bypass line shall be provided to the suction vessel.
Different values or no
over-margin can be required
by Client, Licensors or
Regulatory
Process sizing

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Step 3 – Suction pressure
STATIC
Is composed by 2 components:
DYNAMIC
• is indipendent of the flowrate
• P1 : pressure in the suction vessel or upstream controlled pressure point
• Psh1 : static pressure due to elevation between suction vessel level and pump
datum
•  (flowrate)2
• Pf1 : pressure drop through the suction line (piping+fittings) @ rated flowrate
• PE1 : pressure drop through the equipment installed on the suction line @ rated
flowrate
Psh1 = f (, g, h) where:
g = gravity acceleration
h = elevation difference between vessel level and pump datum
= density of pumped fluid.
When the pump can handle liquids with different densities, each density shall be treated as a separate case. When a pump is
handling a single liquid with different densities, the lowest density is used for head calculation while the highest density is
used for shutoff pressure calculation and BHP estimation
Process sizing

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Step 3 – Suction pressure
Minimum (bara)
Maximum (bara)
Dynamic component is
not taken in
consideration because
it is assumed that max
suction pressure
occurs when the flow
through the pump is
null.
Process sizing

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Step 3 – Discharge pressure
STATIC
Is composed by 3 components:
DYNAMIC
• is indipendent of the flowrate
• P2,max : max op. pressure in the discharge vessel or downstream controlled pressure
point
• Psh2 : static pressure due to elevation of the discharge point and pump datum
•  (flowrate)2
• Pf2 : pressure drop through the discharge line (piping+fittings) @rated flowrate
• PE2 : pressure drop through the equipment installed on the discharge line @rated
flowrate
Process sizing
Psh2 = f (, g, h) where:
g = gravity acceleration
h = elevation difference between vessel level and pump datum
= density of pumped fluid.
When the pump can handle liquids with different densities, each density shall be treated as a separate case. When a pump is
handling a single liquid with different densities, the lowest density is used for head calculation while the highest density is
used for shutoff pressure calculation and BHP estimation

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VARIABLE • is given by the pressure drop of the control valve (PCV) modulated according to process
requirements
When control valve is not yet defined it’s possible preliminarly estimate its minimum pressure drop as sum of 2
components:
•20% of the circuit’s dynamic pressure drop (lines and equipment) @ the maximum rated flow
•PST : is based on the circuit static pressure drop (differential pressure between discharge and suction vessel and
differential pressure due to static level) determined as follows:
Process sizing

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Process sizing

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Step 3 – Differential pressure
Is the difference between the discharge pressure (PD) and the minimum suction
pressure (PS , min) @ rated capacity.
Process sizing

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Step 3 – Head
Is the differential pressure converted in meters calculated with the minimum density
@rated flowrate:
 It is always appropriate repeat the DP and
H calculation using congruent max. density
and viscosity to check that the maximum
head required for different cases is not
higher that the maximum one calculate as
above described.
 When pump curve is available or when
existing pump verification is required, the
pump head shall be read on the curve @
required flowrate
For vertical pumps in wet pits also the lift
contribute from min. op. level must be
considered:
Process sizing

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Step 3 – Available Net Positive Suction Head (NPSHA)
Is the difference between the effective P @ the pump’s datum and the vapor
pressure of the pumped liquid @ max. pumping T converted in meters of pumped
liquid head.
It’s specified @rated flowrate
P1: abs. P in the suction vessel
PV : abs. Vapor P @ op. T in pump suction
Pf1 : pressure drop in suction line @rated flowrate
: density @ op. T
(h1LL  hP) : vertical abs. Distance between min. level and pump datum
va : liquid velocity @ pump intake flange
Process sizing

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Usually
negligible !
 If pumped liquid is @ boiling point and there isn’t variation of T in suction line Pv=Pop
 For vertical pumps from atm. tanks and flare KOD at min. level from ground the NPSH value
is provided by Vendor
 For FF, BFW or on-off services without control valve NPSH is calculated @ 120% rated
flowrate
SPECIAL ATTENTION SHALL BE PAID TO:
Pumps that occasionally operate beyond rated flowrate
2 or more pumps that sometimes operate with suction line sized for 1 pump only
Pumps operating at higher flowrate due to the stop of 1 pump in a circuit with 2 or more
pumps running in parallel
Process sizing

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If NPSHA is  3 meters:
Special pump could be required with costs increase
Verify the possibility of suction system modification:
• Increase op. P of suction vessel
• Increase suction vessel elevation
• Increase diameter of suction line or reduce its equivalent lenght
• Cooling on the suction line (reducing the Vp)
• Chose different pump type
• Insulation on suction line to avoid fluid heating up (for liquids @ boiling point)
• Booster pump with common motor with main pump
Process sizing

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Step 3 – NPSHA in Reciprocationg pumps
For this kind of pump an additional factor shall be considered for the calculation due
to cyclical fluid acceleration and deceleration during each stroke:
Lg: total geometrical lenght of suction piping in meter
v : mean velocity in suction line
N : Pump speed (stroke/min, rpm)
g: acceleration of gravity
C :
K :
Process sizing

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Step 3 – NPSHA and NPSHR
NPSH Available • Depends on the suction system
NPSH Required • Depends on the pump’s design
• It’s defined by Vendor
As general rule: NPSHA = (NPSHR + 0.61.0) m (referred to the same system)
If NPSHA NPSH
≤ R CAVITATION !
Process sizing

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Step 3 – Design discharge pressure
 is the highest pressure created by the pump
 allows defining the minimum mechanical design pressure of pump casing and
discharge section (piping + equipment)
 It is differently defined according to pump type
Step 3 – Shutoff pressure for centrifugal pump (PSO)
 Is the highest DP occurring at zero flowrate.
 Is used to define the mechanical design pressure of the discharge system (piping
+ equipment)
 Is defined @rated flowrate, max, maximum speed (if applicable)
Process sizing

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When PSO minimization is required (minimum costs or revamping) it is calculated considering the
maximum of the following:
 Suction vessel PSV set P and pump H
 Suction vessel max op. P and pump shutoff head (first assumption 120% its head)
The max of these values
is the selected shutoff
pressure
P1,DES: Design suction vessel pressure
P1,max: Maximum suction vessel operating pressure
h1HL - hp: Maximum suction static height
H: pump head
Only if explicitly requested in project
design basis the following will be used:
Process sizing

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 For centrifugal vertical pumps maximum head can be assumed as 1.3 times head @ rated
flowrate
 It is recommended to avoid selection of pumps having a max head lower than 110% of the
rated (flat curve)
 In case of centrifugal pumps operating in series, the PSO of the second one is calculated using
the PSO of the first as P1,DES
Step 3 – Design discharge pressure for positive displacement pump
Is equal to the set pressure of the associated PSV (mandatory on discharge line!)
Process sizing

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Step 3 – Pump Shaft power (BHP)
The Brake Horse Power is the actual power delivered to the pump shaft:
BHP: Brake Horse Power (kW)
Q : Rated volumetric flowrate (m3/h)
H : Pump head (m)
 : pump efficency (0, xx)
Centrifugal : Pump efficency is given by Vendor. As first approximation the following values can
be used:
Reciprocating : 75% can be taken as first approximation value to be checked when Vendor data
are available
Process sizing

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Step 3 – Estimated installed power and estimated motor efficency
These values shall be estimated by process in order to evaluate the power consumption to be
indicated on Utility summary and Electrical load list. The following steps should be applied:
Required motor power calculation
BHP Required motor power
≤ 18 kW 1.25 * BHP
18 – 55 kW 1.15 * BHP
≥ 55 kW 1.1 * BHP
Motor nameplate power definition
For required motor power 160 kW
≤ it is the standard motor power immediately above the calculated one as
listed in the following table:
For required motor power  160 kW it is the calculated required motor power
Electrical power consumption estimation @ rated power
Is calculated as the ratio of BHP and motor efficency
For electrical power consumption at different operating cases (i.e. different heat and material balance),
calculation to be done according to effective motor load and relative efficiency
Process sizing

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All the calculation performed using assumptions and
approximations shall be ALWAYS verified once the
Vendor and the relevant engineering documentation is
finalized (Isometrics, pump’s performance curve, etc
etc.)
SYSTEM’S HYDRAULIC VERIFICATION
Process sizing

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Variations in fluid properties can affect the performances of the selected pump
as well as its design as below described:
Pump selection & Process Sizing Effects of fluid’s properties
Effects of fluid’s properties
Temperature
• Mechanical design
• Materials
• Suction and discharge
systems
• Water-cooling to prevent excessive heating of fluid
• Pump casing heat tracing to mantain the fluid above its pour point
• Discharge check valve hot by-pass to mantain the pump ready for start-up (if the op.
T is at least 150°C)

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Vapor pressure
• NPSH available
• Insulation of suction line for subcooled fluid to avoid heating
• Cooling or insulation of suction line for fluid at boiling point and ambient T or lower

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Density
• Pump Head required
• Maximum value to determine the shutoff pressure
• Minimum value to determine the required Head

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Viscosity
• Pump type
• Drop in performances
General guidelines for pump type selection according to fluid viscosity

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Pour point
• Pump type
• Pump arrangement
• Heating system when the PP is higher than the ambient T

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Centrifugal pumps – Type of control
Pump selection & Process Sizing Pump control
Pump control
Three methods of control can be adopted:
1)Control valve on the discharge line
2)Variable speed unit to vary the impeller speed
3)Recycle of a part of the outlet flow to the suction vessel
 Control valve is the most used due to low costs and high reliability
 Control 3 is typically used when the pump requires a minimum stable flow

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Centrifugal pumps – Control valve
As the duty point of a centrifugal pump is defined by the intersection point of the
performance curve with the resistance curve of the circuit, the effect of the control
valve can be represented as below:
During the CV closure the op. point moves along the
curve:
the flowrate decreases
the differential pressure provided by the pump
increases
Pump control

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Centrifugal pumps – Control valve
The pressure drop to be associated to the control valve can be evaluated by the pump
performance curve and the relevant system resistance curve:
Sufficient control valve DP is necessary to
mantain stable condition but:
High DP means higher pump head
High DP means better control
The designer must define the best
compromise between technical and
economical constrains !
This solution is suggested for:
Fine regulation
Flat pump characteristic curve
Technical care required for regulation
Pump control

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Centrifugal pumps – Speed control
 Is based on the affinity law.
 When the speed of the impeller is reduced the pump flow and head can be reduced:
• without decreasing the efficiency
• reducing the adsorbed power.
Reducing plant operating costs and pump total
life costs
System curve highly dependent on hydraulic
losses
Stress reduction
Noise and vibration reduction
Pump control

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Centrifugal pumps – By pass control
 A fraction of fluid is recycled to the suction vessel in order to make the pump able work within
its operating range.
 The resistance circuit is not modified but the pump works at higher flow and the excess is
recicled.
Low power (decreasing total efficiency)
Recirculating capacity can be controlled (duty point modification)
Pump control

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Pump selection & Process Sizing Engineering
Engineering
details
details
Installation of stand-by pumps
The designer shall evaluate the opportunity to install stand-by units based on the
project requirements and the reliability required for the service where the pump
operates. In the following table are indicated the general guidelines:
Typically spare units
are only required
for critical services

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Installation of pumps in parallel
This configuration is usually adopted when:
the required capacity of one or more existing pumps increases
the required flow needs a drive of non-standard dimensions
different types of drive power are required
costs saving are needed (1X100% more expensive than 2X50%)
high safety and reliability level are required
When this configuration is selected attention must by given to the following issues:
The shutoff P and performance curve must be similar for all the units
Identical pumps having different motors
Centrifugal pumps in parallel with positive displacement ones
Suction system arrengement shall be as much as possible symmetrical (same NPSHA)
Low-flow alarms to notify the operator that the pump can be stopped
Ammeters (for electrical motors) or flowmeters (for turbine drive) indicating the distribution
load among the units
Engineering
details
details

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Installation of pumps in parallel
Also the analysis of the circuit is important considering the resultant of the performance curves of
the different pumps:
Increased flowrate leads to higher head due to higher
fluid velocity
Due to the higher head losses the
flowrate is less than twice the
flowrate achieved by using a single
pump
It is important also to consider the operation of a single pump in case of trip of the other one
(high flowrate than normal condition)
Engineering
details
details

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Installation of pumps in series
This configuration can be adopted when:
The required head is too high for a single pump and the flowrate is beyond the convenience
range of a reciprocating pump
NPSH available is low and a booster pump is needed
Due to the erosive properties of the fluid a multi-stage pump is not reliable
The main disadvantages related to pumps installed in series are:
High costs
Low reliability because the service depends on both pumps and motors operational continuity
System more complicated due to the dependance on both pumps
Sealing system of the first pump affected by high DP of the second one
Engineering
details
details

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Installation of pumps in series
Engineering
details
details
two identical pumps operating at the
same speed with the same flowrate
contribute the same head
The total head is the sum of the single
heads
The volumetric flowrate remains the
same

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Centrifugal pumps minimum flow
A recirculation by-pass can be required if the flowrate can drop below critical values that
cause cavitation etc.
Typically the min. operating flow is equal to 10-25% of the flow at max. efficency level up to 50%
in particular cases
As the minimum flow is provided by Vendor, it is possible to assume a value of 40% during the
early stage of the design or 40-50% for big size pump
Minimum flow regulation in the bypass line can be achieved by calibrated orifice or control
valve depending on costs and pump size (CV preferred for pumps above 35 kW)
Temperature increasing over time shall be investigated
Engineering
details
details

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Choice of drive type
The factors that influence the choice of the type are:
Emergency philosophy
Steam and electrical energy balance requirements
Simplicity of operation
Maintenance requirements
The most common types are:
Gas turbine for oil pump service and water injection pump
Diesel motor for fire water pumps
Hydraulic turbines when it’s possible to recover energy by reducing the liquid pressure
In general:
Electrical motor is extensively used
Steam turbine is more expensive for power below 225 kW then they are preferred for
higher power
Engineering
details
details

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Choice of drive type
Engineering
details
details
In general:
The same type of drive in normally used for main and stand by pumps except when high
level of reliability is required.
In this case for process pumps that cannot be stopped due to safety reasons, turbine
drive can be used

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Automatic reacceleration of electrical motor
This option is required:
to avoid equipment damages and safety valves triggering
for service to be kept in running with on-specification even in case of short time power trip
This option can have a significant impact on the sizing of the electrical system so an accurate
analisys must be carried out before.
Engineering
details
details

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Automatic start-up of standby pump
 The majority of process devices don’t need automatic start-up as the time required by
operator to manually start the standby unit is tolerate
 If the stoppage of the operating pump is critical for safety or operating issues this option can
be required
 The automatic start-up can be controlled by low-flow or low-pressure signal
Engineering
details
details
Here below are some typical cases in which the automatic start-up is required:
• BFW – to guarantee the steam production
• Extraction of condensate from surface condenser of turbines
• Cooling water – fluids cooling can generate hazardous scenarios
• Furnace feeds – overheating of system
• Oil for forced lubrification – bearing problems

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Drainage and vent of pump casing
 Due to the nature of the fluids, many pumps can require draining from casing to a safe place
before they are opened for maintanance
 Typical services requiring draining are:
• Operation above the self ignition temperature (bottom of atm and vacuum column)
• Operation with light hydrocarbons immediately vaporizing when discharged into
atmosphere
• Operation with highly corrosive, toxic or irritant fluids
 Venting of pump casing to atmosphere or safe location can be required to evacuate vapours
before the start-up
Engineering
details
details

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Pump suction strainers
TEMPORARY FILTERS:
are used to protect the pumps during fluxing and the initial period of operation of new
plants, and collect welding residues, pipe scales and any other type of foreign material that might
be present
PERMANENT FILTERS:
are used in services where solids or foreign materials are normally present in the liquid to be
pumped.
Are provided with cleaning system operating when the pressure drop across them reaches the
maximum allowed value
The mesh size is defined during the detail engineering phase
The associated maximum pressure drop shall be taken into account for NPSH calculation
Engineering
details
details

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Cooling water
Is typically required for cooling of bearing and sealing housing.
Here below the amount of water to be considered for preliminary consumption estimation:
Engineering
details
details

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Pump selection & Process Sizing Calculation example
Calculation example
Example
Objective of this example is the sizing of the pump P-01

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Flowrate (m3
/hr)
QMIN 15
QNORM 60
QMAX 65
ITEM P (bar)
@norm. flowrate
PF-01 0,5
PFE-01 0,25
PHX-01 0,7
Fluid Properties
Density (Kg/m3
)
750
850
900
Vapor pressure (bar) 0,06
Vessel Pressure (barg)
Op. Des.
V-01 2,0 4,0
V-02 7,0 9,0
Elevation (m)
h1LL 3,0
h1HL 6,0
h2LL 12,0
h2HL 16,0
hnoz 17,0
Piping P (bar)
@norm. Flowrate
PA 0,8
PB 0,2
PC 0,6
PD 0,8
PE 0,8
Example
Calculation example

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Example
Datum elevation
Qnorm = 60 m3
/hr
hp = 0,9 m
Rated flowrate
Qmax = 65 m3
/hr
Qrated = Qmax + over-design factor
over-design factor = 10% Qmax
(by contract)
Qrated = 65 + 6,5 = 71,5 m3
/hr
Calculation example

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Example
Suction pressure
P1,min = PV-01 op.
Pf1 = (PA + PB )@ Qrated
PE1 = PF-01 @ Qrated
min = 750 kg/m3
h1LL - hp
Calculation example
= 2 barg = 3 bara
= 1.14 + 0.3 = 1.34 bar
= 0.7 bar
= 3.0 – 0.9 = 2.1 m

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Example
Suction pressure
P1,des = PV-01 des.
max = 900 kg/m3
h1HL - hp
Calculation example
= 4 barg = 5 bara
= 6.0 – 0.9 = 5.1 m

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Example
Discharge pressure
P2,max = PV-02 op.
Pf2 = (PC + PD + PE)@ Qrated
PE2 = (PFE-01 + PHX-01)@ Qrated
min = 750 kg/m3
h2HL - hp = hnoz - hp
@ Qrated
Calculation example
= 7 barg = 8 bara
= 0,9 +1.14 +1.14 = 3.2 bar
= 0.4 + 1.0 = 1.4 bar
= 17.0 – 0.9 = 16.1 m

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Example
Discharge pressure
Pst = 0.6 bar
PCV =
Calculation example
0.2*(1,34+3,2+0,7+1,4)+0.6= 1.9 bar

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Example
Differential pressure
Pump Head
Calculation example

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Example
NPSHA
P1 = PV-01 op.
 = max = 900 kg/m3
Pf1 = (PA + PB )@ Qrated
h1LL - hp
Pv = 0,06 bar  0
Calculation example
= 2 barg = 3 bara
= 1.14 + 0.3 = 1.34 bar
= 3.0 – 0.9 = 2.1 m

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Example
Shutoff pressure
The max of these values
is the selected shutoff
pressure
Only if explicitly requested in project
design basis the following will be used:
Calculation example

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Example
BHP
Q = Qrated = 71,5 m3/hr
H = 198 m
 = 0,68
Calculation example

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Example
Required motor power
BHP Required motor power
≤ 18 kW 1.25 * BHP
18 – 55 kW 1.15 * BHP
≥ 55 kW 1.1 * BHP
BHP = 51 kW
Req. Motor power = 1,15*51 = 59 kW
Motor nameplate
Electrical consumption estimation
Calculation example

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Pump selection & Process Sizing Process Data sheet preparation
Process Data sheet preparation
1
2
3
4
5
6
7
outdoor
single
(parallel-single-other)
FREQUENCY Hz
INSTALLATION: indoor - outdoor - other
OPERATION: (continuous-discontinuous-other) continuous
FOR UNITS
/
DATA SHEET No.
ITEM
ELECTRICAL SUPPLY: VOLTAGE V
No. OF MAIN / STAND-BY UNITS
PHASES No.
FOR UNITS
TYPE OF DRIVER
stand-by
electric motor
electric motor
GENERAL DATA
SERVICE
TYPE OF DRIVER DATA SHEET No.
main
Item: specify the
ID code of the
pump Number of
Main/Stand-by Units:
specify the number of
pumps operating
respectively as main
ones and stand-by ones
Service: brief
description of
service

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1
2
3
4
5
6
7
outdoor
single
FREQUENCY Hz
FOR UNITS
/
DATA SHEET No.
ITEM
PHASES No.
FOR UNITS
TYPE OF DRIVER
stand-by
electric motor
electric motor
GENERAL DATA
SERVICE
main
Installation:
indicate the
type of
installation
Operation:
Indicate the type
of operation Single: only one
pump in operation
Parallel: two or more
pumps operated
simultaneously
Check that, in case of
auto-start of the 2nd
pump, the other pump
will not operate below
the NPSHr

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1
2
3
4
5
6
7
outdoor
single
FREQUENCY Hz
FOR UNITS
/
DATA SHEET No.
ITEM
PHASES No.
FOR UNITS
TYPE OF DRIVER
stand-by
electric motor
electric motor
GENERAL DATA
SERVICE
main
Type of driver: specify the
type of driver (electric motor,
steam turbine or gas turbine)
of the main / stand-by pump
Electrical Supply: indicate
the characteristic of the
available electrical supply
(readable from BEDD)

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8
9
10 / /
11 / /
12 / /
13
14 /
15
16 / /
17 / /
DENSITY AT TEMPERATURE
VISCOSITY AT TEMPERATURE
TYPE OF HANDLED LIQUID
cP
kg/m³
PUMPING TEMPERATURE:
mm
no no
TYPE / DIMENSIONS / VOLUME %
SUSPENDED SOLIDS:
CORROSIVE / EROSIVE / HAZARDOUS AGENTS (yes-no) no
DISSOLVED GAS (yes-no) no
FREEZING POINT / POUR POINT °C
MIN / NORM / MAX
VAPOUR PRESSURE AT MAX PUMPING TEMPERATURE kgf/cm²
MIN / NORM / MAX
MIN / NORM / MAX °C
CHARACTERISTICS OF HANDLED LIQUID
Type of Handled
Liquid: indicate the
type of pumped
liquid
Pumping
Temperature:
indicate the min.,
normal and max.
operating
temperature
Density @
Temperature:
indicate the density
value at min.,
normal, max.
operating
temperature

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8
9
10 / /
11 / /
12 / /
13
14 /
15
16 / /
17 / /
cP
kg/m³
mm
no no
SUSPENDED SOLIDS:
MIN / NORM / MAX
MIN / NORM / MAX
Viscosity @
temperature:
indicate the viscosity
at the min, normal
and max operating
temperature
Vapor Pressure:
indicate the vapor
pressure at
maximum pumping
temperature (to be
used for NPSH
calculation)
Freezing / Pour
Point: indicate the
freezing and pour
point temperature of
the pumped liquid

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8
9
10 / /
11 / /
12 / /
13
14 /
15
16 / /
17 / /
cP
kg/m³
mm
no no
SUSPENDED SOLIDS:
MIN / NORM / MAX
MIN / NORM / MAX
Dissolved Gas:
indicate if
dissolved gasses
are present (NPSH
problems)
Corrosive/Erosive/Hazardous
Agents: indicate the presence of
dangerous compound and specify
their nature and percentage by
weight in the notes
Suspended
Solids: indicate
the presence of
suspended solids,
their dimension
and percentage

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18
19 / /
20
21
22 / /
23
24
25
26
27
28 /
29 closed
m³/h
HEAD AT RATED CAPACITY
REACCELERATION / AUTOMATIC START-UP
MAX ALLOWABLE PRESSURE AT SHUT-OFF
ESTIMATED ABSORBED POWER AT PUMP SHAFT
FLOW CONTROLLED BY (pressure controller-level controller-flow controller-other)
(open - closed)
START-UP WITH DELIVERY VALVE
no no
(yes-no)
m
m
kgf/cm²(g)
kW
level controller
NPSH AVAILABLE
CAPACITY: MIN / NORM / RATED
DIFFERENTIAL PRESSURE AT RATED CAPACITY kgf/cm²
MIN / NORM / MAX kgf/cm²(g)
DISCHARGE PRESSURE AT RATED CAPACITY kgf/cm²(g)
OPERATING CONDITIONS
SUCTION PRESSURE:
Suction Pressure: indicate
the pump min., normal, max
suction pressure calculated as
explained above
Discharge Pressure @ Rated
Capacity: indicate the pump
discharge pressure

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18
19 / /
20
21
22 / /
23
24
25
26
27
28 /
29 closed
m³/h
(open - closed)
no no
(yes-no)
m
m
kgf/cm²(g)
kW
level controller
NPSH AVAILABLE
SUCTION PRESSURE:
Differential Pressure at Rated
Capacity: insert the differential
pressure calculated as discharge
pressure @ rated capacity minus
minimum suction pressure
Capacity: specify the
minimum, normal and
maximum pump flowrate
obtained as specified in
the previous points

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18
19 / /
20
21
22 / /
23
24
25
26
27
28 /
29 closed
m³/h
(open - closed)
no no
(yes-no)
m
m
kgf/cm²(g)
kW
level controller
NPSH AVAILABLE
SUCTION PRESSURE:
Head at Rated Capacity: insert
the head calculated as the
differential pressure of line 21
divided by the density (if a
density range has been specified
use the lower one)
NPSH Available: insert the
value of the NPSH calculated as
per previous point (specify in the
notes the assumed pump center
line elevation)

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18
19 / /
20
21
22 / /
23
24
25
26
27
28 /
29 closed
m³/h
(open - closed)
no no
(yes-no)
m
m
kgf/cm²(g)
kW
level controller
NPSH AVAILABLE
SUCTION PRESSURE:
Max Allowable Pressure @ Shut Off: insert the maximum pressure
allowed in the discharge line / equipment .
In case pump casing can be subjected to pressure higher than the
S.O. one, due to other process condition (e.g. other pump S.O. or
fluid vaporization – as NH3 or LPG) indicate also this condition as a
note

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18
19 / /
20
21
22 / /
23
24
25
26
27
28 /
29 closed
m³/h
(open - closed)
no no
(yes-no)
m
m
kgf/cm²(g)
kW
level controller
NPSH AVAILABLE
SUCTION PRESSURE:
Estimated Absorbed Power @ Shaft:
insert the estimated power consumption
calculated as the hydraulic required power
divided by pump expected efficiency (add a
note specifying the used efficiency)

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18
19 / /
20
21
22 / /
23
24
25
26
27
28 /
29 closed
m³/h
(open - closed)
no no
(yes-no)
m
m
kgf/cm²(g)
kW
level controller
NPSH AVAILABLE
SUCTION PRESSURE:
Flow Controlled
By: specify the type
of the flow controller
Reacceleration /
Automatic Start-Up:
indicate if pump motor
shall be specified for
reacceleration and
automatic start-up
Start-Up with Delivery
Valve: start-up with
delivery valve open is
required if automatic
start has been specified

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33
34
35
36
37
38
LEAKS ALLOWED (yes-no)
CONTAMINATION OF LIQUID HANDLED ALLOWED (yes-no)
ANTIFREEZING PROTECTION (yes-no) no
yes
AIR ENTRAINMENT ALLOWED (yes-no) no
no
SEAL TYPE
MECHANICAL DATA
The filling of this section shall be made in conjunction with Machinery
dept.
Seal Type: the seal
type can be Packing or
Mechanical
Packing: filling the ring between the
rotating shaft and the inside of the
seal housing with braided rope or
metal rings (used only for pumps
handling water at low pressure and
temperature).
Mechanical: composed of a rotating
element and a stationary one.

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Mechanical Seal: this seal can be divided into 2 different types
Single: used when small
leakage are allowed (non
hazardous fluid handled)
Double: used when
leakage are not allowed
(hazardous fluid handled)
Back to Back: normally used
either to avoid leakage of
pumped fluid outside (toxic
fluids) either to avoid contact
between pumped fluid and
seal’s parts (abrasive fluid)
Tandem: normally used
to avoid leakage of
pumped fluid outside (toxic
fluids); in this case a
contamination of the handled
fluid is allowed

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MECHANICAL
DOUBLE (tandem)
yes
no
no
MECHANICAL
DOUBLE (back to back)
no
no
no
MECHANICAL
SINGLE (with N2 press.)
-
no
no
LEAKS ALLOWED
CONTAMINATION OF LIQUID HANDLED ALLOWED
yes
AIR ENTRAINMENT ALLOWED no
-
SEAL TYPE
MECHANICAL
SINGLE
The definition of the different seal types shall be based on process consideration
regarding to handled fluid (hazardous or not – ref to API 682) and economical
considerations.
Particular attention shall be paid to the definition of the battery limits between
pump vendor, piping dept. and AUS in order to avoid problems regarding to
auxiliary connections and scope of supply.

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1
2 x / /
3 x / /
4 /
5
6
7
8
9
10 / /
11 / / /
12 / / /
13
(minimum requirement)
VENT / DRAIN REQUIRED (yes-no)
CASING CORROSION ALLOWANCE mm
MATERIAL IN CONTACT WITH LIQUID HANDLED
PUMP CASING MATERIAL
PUMP INTERNAL PARTS MATERIAL
PUMP IMPELLER MATERIAL
°C
HEATING FLUID: TYPE / DESIGN PRES. / OPER. TEMP. kgf/cm²(g)
yes yes
DISCHARGE LINE: DIAMETER / RATING / FACING ANSI NPS
SUCTION LINE: DIAMETER / RATING / FACING ANSI NPS
MECHANICAL DATA
MINIMUM DESIGN METAL TEMP. / AT A PRESSURE OF
kgf/cm²(g)
°C
kgf/cm²(g) °C
COOLING FLUID: TYPE / DESIGN PRES. / OPER. TEMP.
Suction / Discharge Lines:
insert diameter, rating and
facing of the suction and
discharge lines (not pump
inlet/outlet flange)
Vent / Drain Required:
specify pump required
casing vent and drain

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1
2 x / /
3 x / /
4 /
5
6
7
8
9
10 / /
11 / / /
12 / / /
13
°C
yes yes
MECHANICAL DATA
kgf/cm²(g)
°C
kgf/cm²(g) °C
Pumps Material: specify the minimum
material requirement for the different
pump’s components (material selection
shall be done in conjunction with Metallurgy
and Machinery specialist – check
consistency with MSD)

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1
2 x / /
3 x / /
4 /
5
6
7
8
9
10 / /
11 / / /
12 / / /
13
°C
yes yes
MECHANICAL DATA
kgf/cm²(g)
°C
kgf/cm²(g) °C
Casing Corrosion Allowance:
specify the min. corrosion
allowance required (selection
shall be done in conjunction with
Metallurgy specialist – check
consistency with MSD)
API std (par 5.3.7) requires a
minimum corrosion allowance of 3
mm; as a consequence specify the
c.a. only if the pump is not
designed as per API std or if the
required c.a. is higher then 3 mm

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1
2 x / /
3 x / /
4 /
5
6
7
8
9
10 / /
11 / / /
12 / / /
13
°C
yes yes
MECHANICAL DATA
kgf/cm²(g)
°C
kgf/cm²(g) °C
Minimum Design
Metal Temp.: specify
the minimum design
temperature (readable
from project BEDD or to
be calculated in case of
fluid depress.)
Cooling Fluid: specify
(if needed) the type of
the available cooling
medium (i.e. cooling
water) and its design and
operating conditions
Heating Fluid: specify
(if needed) the type of
the available heating
medium (i.e. steam) and
its design and operating
conditions

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14
15
16 / /
17 / /
18 / /
19
20 /
21 (yes-no)
VAPOUR PRESSURE AT MAX TEMPERATURE
HAZARDOUS AGENTS
MPa
Kg/m
3
TEMPERATURE: MIN / NORM / MAX °C
DENSITY AT TEMPERATURE: MIN / NORM / MAX
PRESSURE: MIN / NORM / MAX MPa(g)
FLUSHING FLUID
TYPE
In case of high viscosity handled fluids that require a flushing fluid before
maintenance, specify type and all available information of the flushing medium
(normally information readable from BEDD)

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23
24
25
26
NOTES
Notes: area dedicated to explanatory notes or information concerning special
conditions that can affect the design of the pump, or which necessitate checks to
be made after pump purchasing that might cause revisions in the detailed
engineering phase.

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PROCESS Data Sheet MAC Data Sheet
VENDOR
PUMP SELECTION
Click here

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CONCLUSIONS
Keep always track of your assumptions and calculation!
Procedures and standard are helpful but cannot
substitute engineers!
Tools and calculation sheets are useful but produce
results that shall be analyzed with…engineer cold eye!

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Pump selection & Process Sizing REFERENCE DOCUMENTS
REFERENCE DOCUMENTS
International Standards
API STD 610 Centrifugal Pumps for Petroleum, Petrochemical and
Natural Gas Industries
API STD 674 Positive Displacement Pumps – Reciprocating
API STD 675 Positive Displacement Pumps – Controlled Volume
API STD 676 Positive Displacement Pumps – Rotary
API STD 682 Pumps – Shaft Sealing Systems for Centrifugal and Rotary
Pumps
Hydraulic Institute Standards for Centrifugal, Rotary and Reciprocating
Pumps
Saipem Standards
CR-COR-ENG-PRC-002 Process Pipe sizing
CR-COR-ENG-PRC-003 Pump selection and process sizing
CR-COR-ENG-PRC-005 Control Valve Process Sizing
STD-EL-ESY-0003 IEC Standard Low Voltage motors with anticipated
conventional ratings and characteristics for calculations
STD-EL-ESY-0004 IEC Standard Medium Voltage motors with anticipated
conventional ratings and characteristics for calculations
References
GPSA Engineering Data Book
I.J. Karassik Pump Handbook

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All Corporate Standard are available on Intranet Area at the following
address:
http://sharepoint.saipem.pri/default.aspx

Pump Selection and Process Sizing _PROTEC Dept. April 2014_draft 6.ppt

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