API STD*bLO 95 m 0 7 3 2 2 9 0 054bl107 945 m
Centrifugal Pumps for Petroleum,
Heavy Duty Chemical, and
Gas Industry Services
API STANDARD 61O
EIGHTH EDITION, AUGUST 1995
American Petroleum Institute
1220 L Street, Northwest
Washington, D.C. 20005
11)
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
Centrifugal Pumps for Petroleum,
Heavy Duty Chemical, and
Gas Industry Services
Manufacturing, Distribution and Marketing Department
API STANDARD61O
EIGHTH EDITION, AUGUST1995
American
Petroleum
Institute
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
SPECIAL NOTES
1 . API PUBLICATIONS NECESSARILY ADDRESS PROBLEMS OF A GENERAL
NATURE. WITH RESPECTTO PARTICULAR CIRCUMSTANCES, LOCAL, STATE,
AND FEDERAL LAWS AND REGULATIONS SHOULD BE REVIEWED.
2. API IS NOT UNDERTAKINGTO MEET THE DUTIESOF EMPLOYERS, MANUFACTURERS, OR SUPPLIERS TO WARN OR PROPERLY TRAIN AND EQUIP
THEIR EMPLOYEES, AND OTHERS EXPOSED, CONCERNINGHEALTH AND
SAFETY RISKS AND PRECAUTIONS,
NOR UNDERTAKING THEIR OBLIGATIONS
UNDER LOCAL, STATE, OR FEDERAL LAWS.
3. INFORMATION CONCERNING SAFETY AND HEALTH RISKS AND PROPER
PRECAUTIONS WITH RESPECTTO PARTICULAR MATERIALS AND CONDITIONS SHOULD BE OBTAINED FROMTHE EMPLOYER, THE MANUFACTURER
OR SUPPLIEROF THAT MATERIAL, ORTHE MATERIAL SAFETY DATASHEET.
4. NOTHING CONTAINED IN ANY API PUBLICATION TO
IS BE CONSTRUED AS
GRANTING ANY RIGHT, BY IMPLICATION OR OTHERWISE, FORTHE MANUFACTURE, SALE, OR USEOF ANY METHOD, APPARATUS, OR PRODUCTCOVERED BY LETTERSPATENT NEITHER SHOULD ANYTHING CONTAINED THE
IN
PUBLICATION BE CONSTRUED AS INSURING ANYONE AGAINST LIABILITY
FOR INFRINGEMENT OF LETTERS PATENT.
5. GENERALLY, API STANDARDS ARE REVIEWED AND REVISED, REAFFIRMED, OR WITHDRAWNAT LEAST EVERYFIVE YEARS. SOMETIMES A ONETIME EXTENSION OF UPTO TWO YEARS WILL BE ADDED TO THIS REVIEW
CYCLE. THIS PUBLICATIONWILL NO LONGER BE IN EFFECT FIVE YEARS AFTER ITS PUBLICATIONDATE AS AN OPERATIVE API STANDARD, OR WHERE
AN EXTENSION HAS BEEN GRANTED, UPON REPUBLICATION. STATUS
OF THE
PUBLICATION CAN BE ASCERTAINED FROM THE API AUTHORING DEPARTMENT [TELEPHONE (202) 682-8000]. A CATALOG OF API PUBLICATIONS AND
MATERIALS IS PUBLISHED ANNUALLY AND UPDATED QUARTERLY BY API,
1220 L STREET,N.W., WAS'"WTON, DC 20005.
Copyright O 1995 American Petroleum Institute
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
~
A P I STDMblO 95
m 0732290
0 5 4 b l l O 43T
m
FOREWORD
This standard covers the minimum requirements
for centrifugal pumps, including pumps
running in reverse as hydraulic power recovery turbines, for use in petroleum, heavy-duty
chemical, and gas industryservices.
This standard is based on the accumulated knowledge and experience
of manufacturers
and usersof centrifugal pumps. Theobjectiveof this standardis to providea purchase specification to facilitate the manufacture and procurement of centrifugal pumps for use in
petroleum, chemical, and gasindustry services.
The primary purpose ofthis standard is to establish minimum mechanicalrequirements.
This limitation in scope is one of charter as opposed to interest and concern. Energy conservation is of concern and has become
increasingly important in all aspects of equipment
design, application, and operation. Thus, innovative energy-conserving approaches should
be aggressively pursued by the manufacturer and the user during these steps. Alternative
approaches that may result in improved energy utilization should be thoroughly investigated and broughtforth. This is especially true of new equipment proposals, sincethe evaluation of purchase options will be based increasingly on total life costs as opposed to
acquisition cost alone. Equipment manufacturers,in particular, are encouraged to suggest
alternatives to those specified when such approaches achieve improved energy effectiveness and reduced total lifecosts without sacrifice of safety or reliability.
This standard requires the purchaser to specify certain details and features. Although it
is recognized that the purchaser may desire to modify, delete, or amplify sections of this
standard, it is strongly recommended that suchmodifications,deletions, andamplifications
be madeby supplementing thisstandard, rather than by rewritingor incorporatingsections
thereof into another completestandard.
API standards are published as an aid to procurement of standardized equipment and materials. These standardsare not intendedto inhibit purchasersor producers from purchasing
or producing products made to
other standards.
API publications may be used by anyonedesiring to do so. Every effort has been made
by the Instituteto assure the accuracy and reliability
of the data contained in them; however,
the Institute makes no representation, warranty, or guarantee in connection with this publication and hereby expressly
disclaims any liabilityor responsibility for loss or damage resulting from its use or for the violation of any federal, state, or municipal regulation with
which this publication may conflict.
The listing of any proprietary products in this publication does not imply any endorsement by the American PetroleumInstitute.
Suggested revisions are invited and should be submitted
to the director of the Manufacturing, Distribution, and Marketing Department, American Petroleum Institute, 1220 L
Street, N.W., Washington, D.C. 20005.
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
CONTENTS
Page
SECTION 1-GENERAL
1.1 Scope .....................................................................................................................1-1
1.2
I .3
1.4
1.5
Alternative Designs ...............................................................................................
Conflicting Requirements......................................................................................
Definition ofTerms ...............................................................................................
Referenced Publications........................................................................................
1~1
1-1
1-1
1-8
SECTION 2-BASIC DESIGN
2.1General ...................................................................................................................
2-1
2.2 Pressure Casings ....................................................................................................
2-3
2.3 Nozzle and Pressure Casing Connections .............................................................
2-4
2.4 External Nozzle Forces and Moments ................................................................... 2-5
2.5 Rotors ...................................................................................................................... 2-5
2.6 Wear Rings and Running Clearances ....................................................................
2-9
2.7 Mechanical Shaft Seals........................................................................................ 2-10
2.8 Dynamics ............................................................................................................. 2-13
2.9 Bearings and Bearing Housings ..........................................................................
2-17
2.10 Lubrication ...........................................................................................................
2-20
2.11 Materials .............................................................................................................. 2-21
2.12 Nameplates and Rotation Arrows........................................................................
2-23
SECTION 3-ACCESSORIES
3.1 Drivers ...................................................................................................................
3.2 Couplings and Guards ...........................................................................................
3.3 Baseplates ..............................................................................................................
3.4Instrumentation ......................................................................................................
3.5 Piping and Appurtenances .....................................................................................
3.6 Special Tools..........................................................................................................
3-1
3-2
3-3
3-4
3-5
3-8
SECTION 4”INSPECTION. TESTING. AND PREPARATION
FOR SHIPMENT
4.1General ...................................................................................................................
4.2 Inspection...............................................................................................................
4.3 Testing ...................................................................................................................
4.4 Preparation for Shipment.......................................................................................
SECTION S”PECIF1, C PUMP TYPES
5.1 Single Stage Overhung Pumps ..............................................................................
5.2 Between Bearings Pumps ......................................................................................
5.3 Vertically Suspended Pumps .................................................................................
4-1
4-1
4-2
4-4
5-1
5-2
5-6
SECTION 6-VENDOR’S DATA
6.1 General...................................................................................................................
6.2 Proposals................ .....,. .........................................................................................
6.3 Contract Data .........................................................................................................
6-1
6-1
6-2
APPENDIX A-REFERENCED PUBLICATIONS AND
INTERNATIONAL STANDARDS...................................................
APPENDIX B-PUMP DATA SHEETS ......................................................................
APPENDIX C-STUFFING BOXES FOR PACKING ...............................................
APPENDIX D-MECHANICAL SEAL AND PIPING SCHEMATICS....................
A- 1
B- 1
C-1
D- 1
V
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Page
APPENDIX &HYDRAULIC POWER RECOVERY TURBINES...........................
E-1
APPENDIX F Z R I T E R I A FOR PIPING DESIGN..................................................... F-1
APPENDIX G-MATERIAL CLASS SELECTION GUIDE......................................
G- 1
APPENDIX H-MATERIALS AND MATERIAL SPECIFICATIONS
FOR CENTRIFUGAL PUMPPARTS ..............................................
H- 1
APPENDIX I-LATERAL ANALYSIS ........................................................................ I- 1
APPENDIX J-PROCEDURE FOR DETERMINATION OF
RESIDUAL UNBALANCE.................................................................
J-1
APPENDIX K-SEAL CHAMBER RUNOUT ILLUSTRATIONS...........................
K-1
................................ L- 1
APPENDIX L-BASEPLATE AND SOLEPLATE GROUTING
APPENDIX M-STANDARD BASEPLATES ...........................................................
M- 1
APPENDIX N-INSPECTOR'S CHECKLIST ........................................................... N-1
APPENDIX " V E N D O R DRAWING ANDDATA REQUIREMENTS.................. O- 1
APPENDIX P-PURCHASER'S CHECKLIST ...........................................................
P- 1
APPENDIX Q-STANDARDIZED ELECTRONIC DATA EXCHANGE
FILE SPECIFICATION.....................................................................
Q- 1
APPENDIX R-SI TO U.S. UNITS CONVERSION FACTORS. SYMBOLS.
DEFINITIONS. AND ABBREVIATIONS
........................................ R-1
APPENDIX SXALIBRATION AND PERFORMANCE VERIFICATIONOF
TRUE PEAK AND RMS MEASUREMENT INSTRUMENTS
USED FOR TEST STAND ACCEPTANCE......................................
S- 1
APPENDIX T-TEST DATA SUMMARY .................................................................. T-1
APPENDIX U-SEAL CHAMBER DIMENSIONS-BASIC PHILOSOPHY
FOR STANDARDIZATION............................................................. U- 1
Figures
1-1-Pump Classification Type Identification...........................................................
1-2
1-2-Basic Pump Types .............................................................................................
1-3
2-1-Machined Face Suitable for Gasket Containment When Using
Cylindrical Threads ...........................................................................................
2-4
2-2"Coordinate System for the Forces and Moments in Table2.1A (2.1B):
Vertical In-Line Pumps ..................................................................................... 2-5
2-34oordinate System for the Forces and Momentsin Table 2.1A (2.1B):
Vertical Double-Casing Pumps.........................................................................
2-5
2-Moordinate System for the Forces and Momentsin Table 2.1A (2.1B):
Horizontal Pumps withSide Suction and Side Discharge Nozzles.................. 2-7
2-5"Coordinate System for the Forces and Moments in Table 2.1A (2.1B):
Horizontal Pumps with End Suction and Top Discharge Nozzles
....................
2-8
2-6"Coordinate System for the Forces and Momentsin Table 2.1A (2.1B):
Horizontal Pumps with Top Nozzles
.................................................................
2-9
2-7-Relationship Between Flow and Vibration ..................................................... 2-15
2-SA-Locations for Taking VibrationReadings on Horizontal Pumps ................. 2-15
2-SB-Locations for Taking Vibration Readings on Vertical Pumps
...................... 2-16
2-9-Rotating Component Dimensions to Determine When Single Plane
Balancing Is Allowable...................................................................................
2-17
3-1-Vertically Suspended Pump Drivers: Tolerances Required for the
Driver Shaft and Base....................................................................................... 3-2
5-1-Decision Tree for Rotor LateralAnalysis .........................................................
5-3
5-2-Maximum Spacing BetweenShaft Guide Bushings (Vertical Pumps)
.............5-7
D- 1-Typical Mechanical Seal Arrangements..........................................................
D-4
D-2-Piping for Single Seals and the Primary Seals of Unpressurized
Dual Seal Arrangements
D-2A-API Plan 1 .................................................................................................... D-5
D-2A-API Plan 2 ....................................................................................................
D-5
vi
COPYRIGHT American Petroleum Institute
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~
~
A P I STD*bLO 95
m 0732290 0546LL3 149
Page
D-2B-API Plan 11...................................................................................................
D-2C-API Plan 13...................................................................................................
D-2C-API Plan 14...................................................................................................
D-2D-API Plan 21 ..................................................................................................
D-2D-API Plan 23 ..................................................................................................
D - 2 L A P I Plan 31 ...................................................................................................
D-2E-API Plan 32.................................................................................................
D-2F-API Plan 41 .................................................................................................
D-3-Piping for Throttle Bushings, Auxiliary Seal Devices, and DualSeals
D-3A-API Plan 52.................................................................................................
D-3B-API Plan 53.................................................................................................
D-3B-API Plan 54.................................................................................................
D-3C-API Plan 6 .................................................................................................
1
D-3C-API Plan 62 .................................................................................................
D-4-Cooling Water Pipingfor Overhung Pumps
D4A"API Plan A..................................................................................................
D-4A-API Plan B..................................................................................................
D-4A-API Plan D...................................................................................................
D-4A-API Plan K ..................................................................................................
D4B"API Plan M.................................................................................................
D-5-Cooling Water Pipingfor Between Bearings Pumps
D-5A-API Plan A..................................................................................................
D-SA-API Plan B..................................................................................................
D-5A-API Plan D..................................................................................................
D-SA-API Plan K ..................................................................................................
D-SB-API Plan M.................................................................................................
D-6-Typical Pressurized Lube Oil System ...........................................................
E- 1-Typical HPRT Arrangements ...........................................................................
E-2-HPRT Test Performance Tolerances................................................................
I- 1-Rotor Lateral Analysis Logic Diagram..............................................................
I-2-Damping Factor Versus Frequency Ratio ...........................................................
I-3-Typical Campbell Diagram................................................................................
J- 1-Residual Unbalance Work Sheet ........................................................................
J-2-Sample Calculations for Residual Unbalance....................................................
K- 1-Seal Chamber Concentricity............................................................................
K-2-Seal Chamber Face Runout.............................................................................
M-1-Schematic For API 610 Standard Baseplates.................................................
M-2-Anchor Bolt Projection ..................................................................................
S-1-Instrument Test Setup .......................................................................................
S-2-Sine Wave Signal Showing True Peak.............................................................
S-3-Pulse Signal Showing True Peak......................................................................
S-+Sine Wave Signal Showing RMS.....................................................................
S-5-Pulse Signal Showing RMS..............................................................................
T-1-Test Curve Format-IS0 Style .........................................................................
T-2-Test Curve Format-U.S. Style ........................................................................
D-6
D-7
D-7
D-8
D-8
D-9
D- 10
D-10
D-11
D- 12
D-12
D- 13
D- 13
D- 14
D- 14
D-14
D- 14
D- 15
D-16
D-16
D-16
D-16
D-17
D-18
E-3
E-4
1-2
1-3
1-5
J-2
J-4
K- 1
K- 1
M-3
M-3
S- 1
5-2
5-2
5-3
5-3
T-3
T-4
Tables
1-1-Special Design Considerationsof Particular Pump Types................................
1-6
2-l A-Nozzle Loadings (SI Units)............................................................................ 2-6
2-1 B-Nozzle Loadings (U.S. Units) ........................................................................
2-6
2-2-Minimum Running Clearances .......................................................................
2-10
2-3-Standard Dimensions for Seal Chambers, Seal Gland Attachments, and
Cartridge Mechanical Seal Sleeves .................................................................
2-11
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Page
2-&Floating Throttle Bushing Diametral Clearances............................................
2-5-Vibration Limits for Overhung and BetweenBearings Pumps.......................
2-&Vibration Limits for Vertically Suspended Pumps..........................................
2-7-Bearing Selection ............................................................................................
3- 1-Power Ratings for Motor Drives .......................................................................
3-2-Maximum Coupling End Floats ........................................................................
3-3-Stiffness Test Acceptance Criteria ....................................................................
3-&Minimum Requirements for Piping Materials ..................................................
4- 1-Maximum Severity of Defects in Castings .......................................................
4-2-Performance Tolerances ....................................................................................
5-1-Shaft and Rotor Runout Requirements.............................................................
5-2-Rotor Balance Requirements............................................................................
5-3-Maximum Number ofParticles.........................................................................
6-1-Recommended Spare Parts................................................................................
A-l-corresponding International Standards...........................................................
A-2-Piping Components-Corresponding International Standards .....................
F-1A-Nozzle Sizes and LocationCoordinates for Example 1A .............................
F-2A-Applied Nozzle Loadings for Example 1A ...................................................
F-3A-Proposed Applied Nozzle Loadingsfor Example 2A ....................................
F- 1B-Nozzle Sizes and LocationCoordinates for Example 1 B
..............................
F-2B-Applied Nozzle Loadings for Example 1B....................................................
F-3B-Proposed Applied Nozzle Loadingsfor Example 2B ....................................
G- 1-Material Class Selection Guide .......................................................................
H- 1-Materials for Pump Parts................................................................................
H-2-International Materials for Pump Parts ...........................................................
H-3-Miscellaneous Materials..................................................................................
H-&Fourth Letter of Mechanical SealClassification Code ...................................
H-5-Fifth Letter of Mechanical SealClassification Code ......................................
H-&Temperature Limits on Mechanical Seal Gaskets and Bellows.......................
M-1-Dimensions of API 610 Standard Baseplates ................................................
R-1-SI to U.S. Units Conversion Factors
................................................................
viii
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2-13
2-18
2-18
2-19
3-1
3-3
3-3
3-6
4-2
4-2
5-2
5-4
5-5
6-3
A-4
A- 10
F-2
F-3
F-4
F-5
F-5
F-6
G-2
H-2
H-4
H-6
H-7
H-7
H-7
M-3
R-2
Centrifugal Pumps for Petroleum, Heavy Duty Chemical,
and Gas Industry Services
SECTION 1-GENERAL
Scope
1.1
1.3ConflictingRequirements
1.1.1 This standard covers the minimum requirements for
centrifugal pumps, including pumps running in reverse as
hydraulic power recovery turbines, foruse in petroleum,
heavy duty chemical, and gasindustry services.
In case of conflict between this standard and the inquiry
or
order, the information included inthe order shall govern.
Note: A bullet (o) at the beginning of a paragraph indicates that either a
decision or further information is required. Further information should be
shown on the data sheets(see Appendix B) or stated in the quotation request
and purchase order.
Terms used in this standard are defined in 1.4.1 through
1A.56.
1.4DefinitionofTerms
1.1.2 The pump types covered by this standard can be
broadly classified as overhung, betweenbearings, and vertically suspended (see Figure 1 - 1). To aid the use ofthis standard, Sections 2, 3, 4, and 6 cover requirements that are
applicable to two or more of these broad classifications.Section 5 is divided into 3 subsections and covers requirements
unique to each of the broad classifications.Figure 1-2 shows
the various specific pump types within each broad
classification and lists the identification assigned to each specific type.
1.1.3 The pump types listed in Table 1-1 have special design characteristics and shall be furnished only whenspecified by the purchaser and whenthe manufacturer has proven
experience for the specific application. Table 1-1 lists the
principal special considerations for these pump types and
shows in parentheses the relevant paragraph(s) of API Standard 610.
1900 kPa
(275 psig)
Maximum
suction
pressure
500 kPa
(75 p i g )
Maximum pumping
temperature
150°C
(300°F)
Maximum impeller diameter,
pumps
overhung
1.4.8 critical speed, wet: A rotor natural frequency calculated consideringthe additional support and damping produced by the action of the pumped liquid within internal
running clearances at the operating conditions and allowing
for flexibility and damping withinthe bearings.
( 1 3 in.)
Note: Pumps that do not comply with API Standard 610 shall, as a minimum, meet the requirementsof the standard for service life, materials, shaft
stiffness, mechanical seals, bearing, and auxiliary piping. The purchaser
shall state in the inquiry those requirements that can be relaxed.
1.4.9 design: Term used by the equipment designer and
manufacturer to define various parameters, for example, design power, design pressure, design temperature, or design
speed. Purchaser’s specifications should avoid using this term.
1.4.10 double casing: Typeofpumpconstruction in
which the pressure casing is separate from the pumping elements (such as, diffuser diaphragms, bowls, and volute inner
casings) contained in thecasing.
1.2AlternativeDesigns
1.2.1 The vendor may offer alternative designs.
o 1.2.2 The purchaser will specify whether pumps supplied
to this standard shall have SI dimensions and comply with
applicable IS0 standards or haveU.S. dimensions and comply with applicable U.S. standards.
1.4.1 1 drive train components: Items of equipment,
such as motor, gear, turbine, engine, fluid drive, and clutch,
used in series to drive the pump.
1-1
COPYRIGHT American Petroleum Institute
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1.4.4 BEP: Abbreviation for best eficiency point; the
point or capacity at which a pump achieves its highest efficiency.
1.4.7 critical speed, dry: A rotor natural frequency calculated assuming that therotor is supported onlyat its bearings and that the bearings are of infinite stiffness.
(400ft.)
330 mm
1.4.3 barrier fluid: Fluid introduced between pressurized
dual (double) mechanical seals to completely isolate the pump
process liquid from the environment. Pressureof the barrier
fluid is always higher than the process pressure being sealed.
1.4.6 critical speed: Rotative speed corresponding to a
lateral natural frequencyof a rotor.
Maximum
rotative
RPM
3600
speed
m 120
head
Maximum
total
rated
1.4.2 barrel pump: A horizontal pump of the doublecasing type.
1.4.5 buffer fluid: Fluid used as a lubricant or buffer between unpressurized dual (tandem) mechanical seals. The
fluid is always ata pressure lower thanthe process pressure
being sealed.
1.1.4 For nonflammable, nonhazardous services notexceeding anyof the limits below, purchasers
may wish to consider pumps that do not comply with API Standard610.
Maximum
discharge
pressure
1.4.1 axially split: Casing or housingjoint that is parallel to the shaft centerline.
1-2
API STANDARD
610
0
- Eaf,
B
COPYRIGHT American Petroleum Institute
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-
A P I STD*bLO
95
m 0732290 054bLL7
CENTRIFUGAL PUMPS FOR PETROLEUM,
89V
m
HEAVY
DUTY CHEMICAL, AND GASINDUSTRY
SERVICES
-~
BASIC TYPE
(ROTOR)
CODE
Overhung
OH1a
Foot mounted
OH2
Centerline mounted
OH3
Vertical in-line
separate bearingframe
OH4a
SPECIFIC
CONFIGURATION
Vertical in-line
rigidly coupled
OH!ja
Vertical in-line
closed coupled
OH6
High speed integral gear
' S e e 1.1.3.
Figure 1-2-Basic Pump Types
COPYRIGHT American Petroleum Institute
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ILLUSTRATION
-~
1-3
A P I STD*bLO 95 M 0 7 3 2 2 9 0 054bLLB 7 2 0
BASIC TYPE
(ROTOR)
CODE
m
SPECIFIC CONFIGURATION
ILLUSTRATION
n
Between
Bearings
BB1
Axially split, 1 and 2 stage
BB2
Radially split, 1 and 2 stage
883
Radially split, multistage:
Single casing
Double casing
B84
BB5
Vertically
Suspended
Axially split, multistage
VSl
Wet pit, diffuser
vs2
Wet pit, volute
Figure 1-2-Basic
COPYRIGHT American Petroleum Institute
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Pump Types (Continued)
A P I S T D J b l O 75
m 0732290 054bLL7 667 m
CENTRIFUGAL PUMPS
FOR PETROLEUM, HEAVY CHEMICAL,
Dur,
AND GASINDUSTRY SERVICES
~~
"
BASIC TYPE
(ROTOR)
Vertically
Suspended
(continued)
CODE
vs3
SPECIFIC CONFIGURATION
vs5
VS6
Double casing diffuser
vs7
1-5
~~
ILLUSTRATION
Wet pit, axial flow
Vertical sump:
Line shaft
Cantilever
vs4
~
Double casing volute
Figure 1-2-Basic Pump Types (Continued)
1.4.14 hydraulic power recovery turbine:
A turbo1.4.12 element: The assembly of the rotor plus the intermachine designed to recover power from a fluid stream.
na1 stationary parts of a centrifugal pump; also known as
Power recovery is generally achieved by the reduction of
a bundle.
fluid
pressure, sometimes with a contribution from vaporor
1.4.13 element,
type:
The
assembly
of all
gasevolution during the pressure
A
theparts of thepumpexcept for the casing.Fordoublecasing
pumps, a cartridgetypeelementincludesthecasingcover.powerrecovery
turbine maybe a pumpoperatedwith re-
COPYRIGHT American Petroleum Institute
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API STD*bLO 95 W 0732290 0546320 389 W
API STANDARD
610
1-6
Table 1-1“Special Design Considerations
of Particular Pump Types
PUmD TVOe
Princioal S~ecialConsiderations
I. Motor construction (3. I .7; 3. I .8)
Close Coupled (impeller
mounted on motor shaft)
2. Motor bearing and winding temperature at high
pumping temperatures
3.Sealremoval
1.
Rigidly Coupled
Vertical In-line
(2.7.3.1)
Motorconstruction(3.1.7; 3.1.8)
2. Rotor stiffness (2.5.7; 5.1.2.9)
3. Productlubricatedguidebearing (2.5.7)
4. Shaftrunoutat seal (2.5.6)
Horizontal
Mounted
Foot
overhung
I.
Pressure
rating
(2.2.2)
2. Centerlinesupportedcasing (2.2.9)
Two Stage Overhung
1. Rotorstiffness(2.5.7; 5.1.1.2)
Double SuctionOverhung
I.
Rotor stiffness (2.5.7;5.1.1.2)
Ring Section Casing (multistage)
I.
Pressurecontainment (2.2.7; 2.2.8)
2. Dismantling (2.1.25)
Built-in
Mechanical
(no
Seal
separable seal gland)
1.
verse flow. Consequently, for the nozzles of such turbines,
all references in this standard
to suction and discharge apply
to the outlet and the inlet, respectively. Appendix
E provides
additional information on hydraulic power recovery turbines.
1.4.15 hydrodynamic bearings:Bearings that use the
principles of hydrodynamic lubrication. Their surfaces are
oriented so that relative motion forms an oil wedge to support the load withoutjournal-to-bearing contact.
Seal removal (2.7.3.1)
1.4.20maximumdischargepressure:
The maximum suction pressure plus the maximum differential pressure the pump is able to develop when operating with the
furnished impeller at the rated speed, and maximum specified relative density (specific gravity).
1.4.16maximumallowablespeed
(inrevolutions
per minute): The highest speed at which the manufacturer’s design will permitcontinuous operation.
1.4.21maximumdynamicsealingpressure:
The
highest pressure expected at the seals during any specified
operating condition and during start-up and shut down. In
determining this pressure, consideration should be given to
the maximum suction pressure, the flush pressure, and the
effect of internal clearance changes.
1.4.17 maximum allowable temperature: The maxihas demum continuoustemperam for which the manufacturer
signed the equipment
(or any part to which the term is referred)
when handling the specified liquid at the specified pressure.
1A.22 maximum static sealing pressure: The highest pressure, excluding pressures encounteredduring hydrostatic testing, to which the seals can be subjected while the
pump is shut down.
1.4.18maximum
allowable working pressure
(MAWP): The maximum continuous pressure for which the
manufacturer has designed the equipment (or any part to
which the term isreferred) when theequipment is operating
at the maximumallowable temperature.
1.4.23 maximum suction pressure: The highest suction pressure to which the pump is subjected during operation.
1.4.19 maximum continuousspeed (in revolutions per minute):The speed at least equal to105 percent
of the highest speed required
by any of the specifiedoperating conditions.
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
1.4.24minimumallowablespeed(inrevolutions
which the manufacturer’s
per minute):The lowest speed at
design will permitcontinuous operation.
1.4.25 minimum continuous stable flow:
The lowest flow at which the pump can operate without exceeding
the vibration limits imposed by this standard.
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A P I STD*blO 95
~
0732290 054bL2L 215 W
CENTRIFUGAL PUMPS FOR PETROLEUM,
HEAVYDUTY CHEMICAL, AND GASINDUSTRY
SERVICES
-"_
1-7
1.4.26 minimum continuous thermal flow: The lowest flow at which the pump canoperate without its operation
being impaired bythe temperature riseof the pumped liquid.
1.4.39 overhung pump: Pump whose impeller is cantilevered from its bearing assembly. Overhung pumps may
be horizontal or vertical.
1.4.27minimumdesignmetaltemperature:
The
lowest mean metal temperature (throughthe thickness) expected in service. Considerations shall include operation u p
sets, auto refrigeration, and temperature of the surrounding
environment.
1.4.40
pressure
casing:
The composite of all
stationary pressure-containingparts of the pump, including
all nozzles, seal glands, seal chambers, and other attached
parts but excluding the stationary and rotating members of
mechanical seals (see Figure D-1, AppendixD).
1.4.28 net positive suction head (NPSH): The total
absolute suction head, in meters (feet)
of liquid, determinedat
the suction nozzle and referred
to the datum elevation, minus
the vapor pressureof the liquid, in meters(feet) absolute. The
datum elevation is the shaft centerlinefor horizontal pumps,
the suction nozzle centerline for vertical in-line pumps, and
the top of the foundation for other vertical pumps.
1.4.41 purchaser: Individual or organization that issues
the purchase order and specificationsto the vendor. The purchaser maybe the owner of the plant in which the equipment
is to be installed or the owner's appointed agent.
1.4.29 net positive suction
head
available
(NPSHA): The NPSH, in meters(feet) of liquid, determined
by the purchaser for the pumping system with theliquid at
the rated flow and normal pumpingtemperature.
1.4.30
net
positive suction
head
required
(NPSHR): The NPSH, in meters(feet), determined by vendor testing with water. NPSHR is measured at the suction
flange and correctedto the datumelevation. NPSHR at rated
and other capacities is equal to the NPSH that produces a 3
percent head drop(first stage head in multistage pumps) due
to cavitation within the pump.
1.4.42 radially split: Casing or housing joint that is perpendicular to the shaft centerline.
1.4.43 rated operating point: The point at which the
vendor certifies that pump performance is within the tolerances stated in this standard (see 4.3.3.3.3).
1.4.44 relative density: Property of a liquid; ratio of the
liquid's density to that of water at 4°C (39.2"F).
1.4.45 rotor: The assembly of all the rotating parts of a
centrifugal pump. When purchased
as a spare, a rotor usually
does not include the pump half couplinghub.
1.4.46 specific gravity (SG): Property of a liquid; ratio
of the liquid's density to that of water at4°C (39.2"F).
1.4.47 specific speed: Anindex relating flow, total
1.4.31 normal operating point: The point at which the
head, and rotativespeed for pumps of similar geometry. Spepump is expected to operate under normal process conditions. cific speed is calculated for the pump's performance at best
efficiency point with the maximum diameterimpeller. Spe1.4.32 normal wear parts:
Those parts normally recific speed is expressed mathematically by the following
stored or replaced at each pump overhaul, typically wear
equation:
rings, interstage bushings, balancingdevice, throat bushing,
seal faces. bearings, and all gaskets.
1.4.33 oil mist lubrication: A lubrication systemthat
employs oil mist produced
by atomization ina central supply
unit and transported to the bearing housing
by compressed air.
1.4.34 pure oil mist lubrication (dry sump): The
mist both lubricates the bearing and purges thehousing.
1.4.35 purge oil mist lubrication (wet sump):
The
mist only purges the bearinghousing. Bearing lubrication is
by conventional oil bath, flinger, or oil ring.
1.4.36 operating region: The portion of a pump's hydraulic coverage over which the pump
operates.
1.4.37operatingregion,preferred:
Regionover
which the pump's vibration is within the base limit of this
standard (see 2.1.12).
1.4.38 operatingregion,allowable: Regionover
which the pump is allowed to operate, based on vibration
within the upper limit of this standard or temperature rise or
other limitation; specified by the manufacturer (see 2. l . 12).
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
Where:
nq
N
Q
H
n4 = N(Q)0.5/(M0.75
= specific speed.
= rotative speedin revolutions perminute.
=
total pump flow in cubic meters per second.
= headper stage in meters.
Note: Specific speed derived using cubic meters per second and meters
multiplied by a factorof 5 1.6 is equal to specific speed derived usingU.S.
gallons per minute and feet. The usual symbol for specific speed in U.S.
units is Ns.
1.4.48 standby service: A normally idle or idling piece
of equipment thatis capable of immediate automaticor manual start-up and continuousoperation.
1.4.49 suction specific speed: An index relating flow,
NPSHR, and rotative speed for pumps of similar geometry.
Suction specific speed is calculated for the pump's performance at best efficiency point with the maximum diameter
impeller and provides an assessment of a pump's susceptibility to internal recirculation. It is expressed mathematically
by the following equation:
A P I STDxbLO 95
0732290 0 5 4 b 1 2 2 L51
API STANDARD
61O
1-8
nqS = N(Q)o.5/(NPSHR)o.75
Where:
nqs
N
Q
NPSHR
= suction specific speed.
= rotative speed in revolutions perminute.
= flow per impeller eye, in cubic meters per
second,
= total flow for single suction impellers,
= one half total flow for double suction
impellers.
= net positive suction head required (see
1.4.27) in meters
Note: Suction specific speed derived using cubic meters per second and
demeters, multipliedby a factorof 5 1.6, is equal to suction specific speed
rived usingU.S. gallons per minute and feet. Theusual symbol for suction
specific speed in US units is S.
1.4.50 throat bushing: A device that formsa restrictive
close clearance around the sleeve (orshaft) between the seal
(or packing) and the impeller (see Figure
D- 1, Appendix D).
1.4.51 throttle bushing: A device that forms a restrictive close clearance around the sleeve (or shaft) at the outboard end of a mechanical seal gland (see Figure D- 1,
Appendix D).
1.4.52
total indicated runout (TIR), also known as
total indicator reading:The runout of a diameter or face
determined by measurement witha dial indicator. The indicator implies an eccentricity equal to half the reading or an
out of squarenessequal to the reading.
such as the power requirements, speed, direction
of rotation,
general arrangement, couplings, dynamics, lubrication, material test reports, instrumentation, piping, and testing of
components, etc., shall be included.
1.4.55 vendor: The manufacturer of the pump, or the
manufacturer’sagent.
1.4.56 vertical in-line pump: A pumpwhose suction
and discharge connections have
a common centerline that
intersects the shaft axis. The pump’s driver is generally
mounted directly on the pump.
1.4.57 vertically suspended pump: A vertical axis
pump whose liquid end is suspended from a column and
mounting plate.The pump’s liquid endis usually submerged
in the pumped liquid.
1.5
ReferencedPublications
1.5.1 Referenced publications, U.S. and SI, are listed in
Appendix A. The U.S. publications are the base documents.
The corresponding international publications and standards
may be acceptable as alternatives with the purchaser’s approval. In allcases, the editions that are in effect at the time
of the publication ofthis standard shall, to the extent specified herein, form a part of this standard. The applicability of
changes in standards, codes, and specifications that occur after the publicationof this standard shall be mutually agreed
upon between thepurchaser and the vendor.
1.5.2 The purchaser and the vendor shall mutually deter1.4.53 trip speed (in revolutions per minute): The
speed at which the independent emergency overspeed device mine the measures that must be taken to comply with any
governmental codes, regulations, ordinances, or rules that
operates to shut down a prime mover.
are applicable to the equipment.
1.4.54 unit responsibility: Refers to the responsibility
for coordinating the technical aspects of the equipment and
all auxiliary systems includedin the scope of order. Factors
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
1.5.3 It is the vendor’s responsibility to invoke all applicable specifications to each subvendor.
~~
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SECTION 2-BASIC DESIGN
2.1
General
2.1.1 The equipment (including auxiliaries) coveredby this
standard shallbe designed and constructed for a minimum service life of20 years (excluding normal wear parts
as identified
in Table6-1) and at least3 years of uninterrupted operation. It
is recognized that this requirement
is a design criterion.
2.1.2 The vendor shall assume unit responsibility for all
equipment and allauxiliary systems included in the scope of
the order.
2.1.3 The purchaser will specify the equipment’s normal
and rated operating points. The purchaser will also specify
any other anticipated operating conditions. The purchaser
will specify when fluids are flammable or hazardous.
2.1.4 Pumps shall be capable of at least a 5 percent head
increase at rated conditions by replacement of impeller(s)
the
with one(s) of larger diameter or different hydraulic design.
Note: The purchaser should consider an appropriate NPSH margin in addition to the NPSHR specified in 2.1.8 above. An NPSH margin is the
NPSH that exists in excess of the pump’s
NPSHR (see 1.4.30). It is usually
desirable to have an operating NPSH margin that is sufficient at all flows
(from minimum continuous stable flow to maximum expected operating
flow) to protect the pump from damage caused by flow recirculation, separation, and cavitation. The vendor should
be consulted about recommended
NPSH margins for the specific pump type and intended service.
In establishingNPSHA (see 1.4.29), the purchaser and the vendor should
recognize the relationship between minimum continuous stable flow and the
pump’s suction specific speed. In general, minimum continuous stable flow,
expressed as a percentage of flow at the pump’s best efficiency point, increases as suction specific speed increases. However, other factors, such
as
the pump’s energy level and hydraulic design, the pumped liquid, and the
NPSH margin, also affect the pump’s ability
to operate satisfactorily over a
wide flow range. Pump design that addresses low-flow operation
is an evolving technology, and selection of suction specific speed levels
andmarNPSH
gins should take into account current industry and vendor experience.
2.1.9 When specified by the purchaser, the pump suction specific speed shall be limited as stated on the data
sheet.
Note: The purchaser may consider the use of variable speed drive capability and/or the use of blank stages
(to add impellers in thefuture) for multistage pumps to meet this requirement.
2.1.10 Pumps that handle liquids more viscous than water
2.1.5 Pumps shall be capableof operating continuously up
shall have their water performance corrected in accordance
with the Centrifugal Pump Sectionof the Hydraulic Institute
Standards.
to at least 105 percent of rated speed andshall be capable of
operating briefly, under emergency conditions, up to the
driver trip speed.
2.1.6 Pumps shall use throat bushings, wear rings, impeller balance holes and/or flushing line arrangements for
the following:
a. To maintain a seal chamber pressure greater than atmospheric pressure.
b. To maintain a seal chamber pressure sufficient to prevent
vaporization at the seal faces under all specified operating
conditions.
c. To otherwise increase or decrease seal chamber pressure.
d. To isolate the seal chamber fluid.
e. To provide continuous flow through
the seal chamber under all specified operating conditions.
f. To otherwise control the flow into
or out of the seal chamber.
2.1.7 The conditions in the seal chamber requiredto maintain a stable film at the seal faces, including temperature,
pressure, and flow, as well as provisions
for assuring the adequacy of the designfor sealing against atmospheric pressure
when pumps are idle in vacuum service, shall be mutually
agreed upon by the pump vendor and the
seal manufacturer,
approved by the purchaser, and noted onthe data sheet.
Note: Provision for sealing against atmospheric pressure in vacuum service is especially important when handling liquids near their vapor pressure
(such as liquified petroleum gases).
2.1.8 The vendor shall specify on the data sheets the
NPSHR based on water(at a temperature of less than 65°C
(150°F))at the rated capacity and rated speed.
A reduction or
2.1.I1 Pumps that have stable headcapacity curves (continuous head riseto shutoff)are preferredfor all applications
and are required when parallel operation is specified. When
parallel operation is specified, the head rise shall be at least
1O percent ofthe head at rated capacity. aIfdischarge orifice
is used as a means of providing a continuousrise to shutoff,
this use shall be stated in the proposal.
2.1.12 Pumps shall have a preferred operating region (see
2.8.3, Vibration) of 70-120 percent of best
efficiency capacity of the furnished impeller. Rated capacity shall be within
the region of 80-1 10 percent of best efficiency capacity of
the furnished impeller.
Note: Setting specific limits for the preferred operating region and thelocation of rated capacity is not intendedto lead to the development of additional sizes of small pumps or preclude the use of high specific speed
pumps. Small pumps, which are known to operate satisfactorily at flows
outside the specified limits, and high specific speed pumps, which may have
a narrower preferred operating region than specified, should be offered
where appropriate, and their preferred operating region clearly shown on the
proposal curve.
2.l. 13 The best efficiency pointfor the furnished impeller
shall preferably be between rated
the point and the normal
point.
2.1.1 4 Control of the sound level of all equipment furnished shall bea joint effort of the purchaser and the vendor.
The equipmentfurnished by the vendor shall conform to the
maximum allowable soundlevel specified by the purchaser.
Note: I S 0 Standards 3740, 3744, and 3746 may be consulted for guidance.
2- 1
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
correction factor for liquids other than water (suchas hydrocarbons) shall not be applied.
API STDxbLO 95
m 0732290 0546324
T24
m
API STANDARD
610
2-2
Maximum outlet temperature 50°C
( I2OoF)
2.1.1 5 Pumps with heads greater than 200 m (650 ft) per
Maximum temperaturerise
stage and with more than 225 kW
(300 hp) per stage may re20°C
(30°F)
quire special provisionsto reduce vane passing frequency
viMinimum temperature rise
10°C
(20’F)
bration and low-frequency vibration at reduced flow rates.
Fouling factoron water side
0.35 m* . “CikW (0.002hr ft* . OF/Btu)
For these pumps, the radial clearance between the diffuser
3.0 mm
(O. 125 in.)
Shell corrosion allowance
vane or volute tongue (cutwater) and the periphery of the imProvisions shall be made for complete venting and draining
peller blade shall be at least 3 percent of the maximum imof the system.
peller blade tip radius for diffuser designs and atleast 6
Note
1 : The vendor shall notify the purchaser if the criteria for minimum
percent ofthe maximum bladetip radius for volute designs.
temperature
rise and velocity over heat exchange surfaces result in aconThe maximum impeller blade tip radius is the radius of the
flict. The criterion for velocity over heat exchange surfacesis intended to
largest impeller that can
be used within the pump casing
(see
minimize waterside fouling; the criterion for minimum temperature rise
is
intended to minimizethe use of cooling water. The purchaser will approve
paragraph 2.1.4). Percent clearance is calculated as follows:
the final selection.
P =lo0 (R3 - R2 )/R2
Where:
P
R3
R2
Note 2:
0
2.1.21 The arrangement of the equipment, including piping and auxiliaries, shall be developed jointly by the purchaser and the vendor. The arrangement shall provide
adequate clearance areas and safe access for operation and
maintenance.
= percent clearance.
= radius of voluteor diffuser inlet tip.
= maximum impeller blade tip radius.
The impellers of pumps coveredby this paragraphshall not
be modified after test to correct hydraulic performance by
underfiling, overfíling, or “V” cutting without notifying the
purchaser prior to shipment. Any such modifications shall
be
documented in accordance with6.3.5.1.
See Appendix R for key to abbreviations.
0
2.1.22 Motors, electrical components, and electrical installations shall be suitable for the area classification
(class, group, division, or zone) specified by the purchaser
and shall meet the requirements of local codes (such as
NFPA 70, Articles 500,501, and 502) specified by the purchaser.
2.1.16 Pumps of significantly higher energy levels than
those specified in 2. l. 15 mayrequire even larger clearances
and other special construction features. For these pumps,
2.1.23 Oil reservoirs and housings thatenclose moving luspecific requirements should
be mutually agreed upon by the
bricated
parts (such as bearings, shaft seals, highly polished
purchaser and the vendor, considering actual operating expeparts,
instruments,
and control elements) shall
be designed to
rience with the specific pump types.
minimize contaminationby moisture, dust, and other foreign
2.1.17 The need for cooling shall be mutually agreed upon
matter during periods of operationor idleness.
by the purchaser and the vendor. Whencooling is required,
2.1.24 All equipment shall be designed to permit rapid
the type, pressure, and temperature
of the cooling liquid will
and economical maintenance. Major parts such as casing
be specified by the purchaser. The vendor shall specify the
components
and bearing housingsshall be designed (shoulrequired flow (see AppendixD).
dered or doweled) and manufactured to ensure accurate
Note: To avoid condensation, the minimum inlet water temperature to
alignment on reassembly.
The mating facesof the pump casbearing housings should be above the ambient air temperature.
ing and the bearing housing assembly shall be fully ma2.1.18 Cooling jackets, if provided, for seal chambers and
chined to allow the parallelism of the assembledjoint to be
bearings shall have clean out connections arranged so that
gauged. If fully machined matingfaces cannot be achieved
be mechanically cleaned,flushed,
the entire passageway can
in the design, four mating machined areas with a minimum
and drained.
arc lengthof 25 mm (1 in.) located 90 degrees apart shallbe
provided.
2.1.19 Jacket cooling systems,if provided, shall be designed
to positively prevent the process stream from leaking into the 2.1.25 Except for vertically suspended pumps, casings
coolant. Coolant passages shall not open into casing joints. shall be designedto permit removalof the rotoror inner element without disconnecting the suction
or discharge piping
or moving the driver.
2.1.20 Unless otherwise specified, cooling water systems
shall be designed for the following conditions:
Velocity over heat
exchange
surfaces
I S-2.5 d s
(5-8 fIJS)
Maximum allowable
working
pressure
(MAWP)
2650 kPa
( 2 1 O0 psig)
Test hessure
21.5 xMAWP
(21.5 xMAWP)
Maximum pressure drop
Maximum inlet temperature
1 0 0 kPa
(15 psi)
30°C
(90°F)
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
2.12 6 The pump and itsdriver shall performon their test
stands and on their permanent foundation withinthe acceptance criteria specifiedin 2.8.3. After installation, the performance of the combined unitsshall be the joint responsibility
of the purchaser and the vendor.
0
2.1.27 Many factors (such as piping loads, alignment at
operating conditions, supporting structure, handling during
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A P I STD*blO 95 W 0732290 0546325 760 W
CENTRIFUGAL PUMPS
FOR PETROLEUM,
HEAVYDUTY CHEMICAL,
AND GAS INDUSTRY
SERVICES
shipment, and handling and assembly at the site) may adversely affect site performance. When specified,
to minimize
the influence of these factors, thevendor shall do oneor
more of the following:
2-3
2.2.3 The pressure casing shall be designed with a corrosion allowance to meet the requirements of 2.1.1. Unless
otherwise specified the minimum corrosion allowance shall
be 3 mm (0.12 in.).
O 2.2.4
The maximum allowable working pressure shallapa. Review and comment on the purchaser’s piping and founply
to
all
parts referredto in the definitionof pressure casing
dation drawings.
(see
1.4.40)
except for vertically suspended, double-casing,
b. Observe a check of the piping, performed by parting the
and
horizontal
multistage pumps (pumps with
three or more
flanges after installation.
are
subject
only to sucstages).
Regions
of
these
pumps
that
c. Be present during the
initial alignment check ofthe pump
tion
pressure
need
not
be
designed
for
the
maximum
allowand drive train.
able
working
pressure.
(The
purchaser
should
consider
d. Recheck the alignment of the pump anddrive train at the
installation of relief valves onthe suction side of such instaloperating temperature.
lations.) The purchaser will specify whether these pump re2.1.28 Spare and all replacement parts for the pump and
gions are to
be designed for the maximum allowable working
as a minimum, meet all the cri- pressure.
all furnished auxiliaries shall,
teria of this standard.
2.2.5 The inner casing of double-casing pumps shall be
2.1.29 The purchaser will specify whether the installadesigned to withstand the maximum differential pressure or
tion is indoors (heated or unheated) or outdoors (with or
350 kPa (50 psig), whichever is greater.
without a roof), as well as the weather and environmental
2.2.6 Pumps with radiallysplit casings are required if any
conditions in which the equipment must operate (including
of the followingoperating conditions are specified:
maximum and minimum temperatures, altitude, unusual
a. A pumping temperature of 200°C (400°F) or higher. (A
humidity, and dusty or corrosive conditions). The unit and
lower temperature limit should beconsidered when thermal
its auxiliaries shall be designed for operation under these
shock is probable.)
specified conditions.
b. A flammable or hazardous pumpedliquid with a relative
density (specific gravity) of less than 0.7 at the specified
2.2 Pressure Casings
pumping temperature.
2.2.1 The stress usedin design for any given material shall
c. A flammable or hazardous pumped liquid at a rated disnot exceed the values given
for that material in SectionII of
charge pressureabove 10 MPa (1450 psi).
the ASME Code. For cast materials, the factor specified in
Section VIII, Division 1, ofthe ASME Code shall be applied. 2.2.7 Radially split casings shall have metal-to-metal fits,
with confined controlled compression gaskets, such
as an 0Pressure casingsof forged steel, rolled and welded plate,or
ring
or
a
spiral
wound
type.
seamless pipe with welded cover shall comply
with the applicable design rulesof Section VIII, Division 1,of the ASME
2.2.8 The pump’s pressure casing shall
be capable of withCode. Manufacturers’ data report forms, third party inspecstanding twice the forces and moments
in Table 2-1A(2-1B)
tions, and stamping, as specified in the code, are not required. applied simultaneously to the pump through each nozzle,
plus internal pressure, without distortion that would impair
2.2.2 The pressure casingand flanges shallbe designed for
operation of the pump or seal.
the maximum discharge pressure plus allowances for head inNote:
This is a pump casing design criterion and is not to be used for pipcreases (see 2.1.4 and 2.1S ) at the pumping temperatures.
ing design nozzle loads.
Unless otherwise specified, the pressure casing, as a mini2.2.9 Centerline supported pumpcasings shall be used for
mum, shallbe designed for the following:
horizontal pumps.
a. For axially split one- and two-stage between bearings pumps
and single casing
vertidy suspended pumps: a pressure rating 2.2.10 O-ring sealing surfaces, including all grooves and
bores, shall have a maximurn surface roughness average value
equal to that of an IS0 7005-2 PN20 (ANSI /ASME B 16.1
(Rd of 1.6 pm (63 pin.)for static O-rings and
0.8 pm (32 pin.)
Class 125) cast iron
or IS0 7005-1 PN20(ANSUASME B16.5
for
the
surface
against
which
dynamic
O-rings
slide. Bores
Class 150) steel flange of a material grade corresponding
to
shall
have
a
minimum
3
mm
(0.12
in.)
radius
or
a minimum
that of the pressure casing.
1.5
mm
(0.06
in.)
chamfered
lead-in
for
static
O-rings
and a
b. For overhung and between bearings radially
split pumps,
minimum
2
mm
(0.08
in.)
chamfered
lead-in
for
dynamic
0multistage horizontal pumps and double casing vertically susrings.
Chamfers
shall
have
a
maximum
angle
of
30
degrees.
pended pumps: a pressure rating
equal to that ofan IS0 70051 PN50 (ANSUASME B16.5
Class 300) flange of a material
2.2.11 Cylindrical dowels or rabbeted fits shall be emgrade correspondingto that of the pressure casingor 4 MPa
ployed to align casing components, or the casing and cover,
(600psig), whichever is less.
and to facilitate disassembly and reassembly.
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
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A P I STD*bLO 95
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API STANDARD 610
2.2.12 Jackscrews shall be providedto facilitate disassembly of the casing. One of the contacting faces shall be relieved (counter bored or recessed) to prevent aleaking joint
or an improper fit caused by marring of the face.
2.3.2.3 Unless otherwise specified,flanges other than cast
iron shall as a minimum conform
to the dimensional requirements of I S 0 7005-1 (ANSVASME B16.5).
2.3.2.4 Flat face flanges with full raisedface thickness are
acceptable on casings of all materials.Flanges in all materials that are thicker
or have a larger outside diameter than that
required byI S 0 (ANSI) are acceptable.
2.2.13 Bolting shall be furnished as specified in 2.2.13.1
through 2.2.13.7.
2.2.13.1 The details of threading shall conform to IS0
262 (ANSVASME B 1.1).
2.3.2.5 Flanges shall befull or spot faced on the back and
shall be designed for through bolting.
2.2.13.2 The use of tapped holesin pressure parts shallbe
minimized. To prevent leakage in pressure sections of casings, metal, equal in thickness to at least half the nominal
bolt or stud diameter,in addition to the allowance for corrosion, shallbe left around and below
the bottom of drilled and
tapped holes.The depth of the tapped holes shall be at least
1.5 times the nominalbolt or stud diameter.
2.3.2.6 Raised face flange finish shall have serrated spiral
or concentric grooves machined with a 0.8 mm (0.03 in.)
nominal radius round-nosed tool toproduce a groove pitch
of 0.35 to 0.45 mm (0.014 to 0.018 in.). The resulting surface roughness shallbe between R, 3.2 and 6.3 Fm (125 and
250 pin.) and shall bejudged by visual andtactile comparison against a surface finish comparator block (ANSVASME
B46.1).The gasket contact surface shall not have mechanical
or corrosion damage which penetrates the ofroot
the grooves
for a radial length
of more than30 percent of the gasket
contact width.
2.2.13.3 Internal bolting shall be of a material fully resistant to corrosive attack bythe pumped liquid.
2.2.13.4 Studs shall be supplied on all main casing
joints unless cap screws are specifically approved by the
purchaser.
2.3.3PRESSURECASINGCONNECTIONS
2.3.3.1 For nonflammable and nonhazardous liquids, auxiliary connections to the pressure casing
may be threaded.
2.2.13.5 Adequate clearance shall be provided at bolting
locations to permit the use ofsocket or box wrenches.
2.2.13.6 Internal socket-type, slotted-nut, or C-type spanner boltingshall not be used unless specifically approved by 2.3.3.2 Unless otherwise specified, pipe threads shall be
tapered threads conforming to ANSIJASME B 1.20.l .
the purchaser.
Tapped openings and bosses for pipe threads shall conform
2.2.1 3.7 Metric fine and UNF threads shall not be used.
to ANSVASME B 16.5.
2.3
O
Nozzle and Pressure Casing
Connections
2.3.3.3 If specified, cylindrical threads conformingto IS0
228, Part 1 may be used.If cylindrical threads are used, they
shall be sealed with a contained
face gasket, and theconnection boss shall have a machinedface suitable for gasket containment (see Figure 2-1).
2.3.1CASINGOPENING
SIZES
2.3.1 -1 Openings for nozzles and other pressure casing con2.3.3.4 For flammableor hazardous liquids, auxiliary connections s h d be standard nominal pipe sizes
(NPS). Openings
nections
to the pressure casing shall be socket welded,butt
of 11/4,2'J2,31h,
5,7 and 9 N P S shall notbe used.
welded, or integrally flanged. Fieldconnections shall termi2.3.1.2 Casing connections other than suction and disnate in a flange.
charge nozzles shall be at least 'J2 NPS for pumps with discharge nozzle openings 2 NPS and smaller. connections
shall be at least 3/4 NPS for pumps with discharge nozzle
openings 3 NPS and larger,except that connections for seal
flush piping, lantern rings and gauges may be NPS regardless of pump size.
'h
2.3.2SUCTIONANDDISCHARGENOZZLES
2.3.2.1 Suction and discharge nozzles shall be flanged.
One- and two-stage pumps shall have
suction and discharge
flanges of equal rating (2.2.2).
2.3.2.2 Cast iron flanges shall be flat face and shall, as a
minimum, conform to the
dimensional requirements of IS0
7005-2 (ANSVASME B16.1).
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
Figure 2-1-Machined Face Suitable for
Gasket Containment When Using
Cylindrical Threads
____
A P I S T D + b L O 95
~
~~~
0732290 054bL27 733
CENTRIFUGAL
PUMPSFOR PETROLEUM, HEAVY DUTY CHEMICAL,
AND GASINDUSTRY
SERVICES
2-5
~~
2.3.3.5 Connections welded to the casing shall meet the
2.5 Rotors
material requirements of the casing, including impact values, 2.5.1 Unless otherwise approved by the purchaser, imrather than the requirements of the connected piping.
pellers shall be of the fully enclosed type andconstructed as
single piece castings. Fabricated impellers require the pur2.3.3.6 Pipe nipples welded to the casing should not be
chaser's specific approval.
more than 150mm (6 in.) in length and shall be aminimum
of Schedule 160 seamlessfor sizes 1 NPS and smaller and a
Shafl centerline
minimum of schedule 80 for sizes 1'/2 NPS and larger.
r
2.3.3.7 Tapped openings not connectedto piping shall be
plugged. Plugs shall conform to paragraph 3.5. l. 14.
2.3.3.8 Machined and studded customer connections shall
conform to the facing and drilling requirements
of IS0 70051 or 2 (ANSUASME B 16.1 or B16.5). Studs and nuts shall
be furnished installed. The first 1.5 threads at both ends of
each stud shall be removed.
2.3.3.9 All connections shall be suitable for the hydrostatic test pressure of the region of the casing to which they
are attached.
2.3.3.10 Unless otherwise specified, all pumps shall be
provided with vent and drainconnections. Vent connections
may be omitted if the pump is made self-venting by the arrangement of the nozzles.
Note: As a guide, a pump is considered self-venting if the nozzle arrangement and casmg configuration permit adequate venting of gases from the
first-stage impeller and volute area to prevent
loss of prime during the starting sequence.
2.3.3.11 When specified, pressure gauge connections shall
be provided.
2.4 External Nozzle Forces and
Moments
2.4.1 Steel and alloy steel horizontal pumps, and their
baseplates, and vertically suspended pumps shall be designed for satisfactory performance when subjected to the
forces and moments in Table 2-1A (2-1B). For horizontal
pumps, two effectsof nozzle loads are considered: Distortion
of the pump casing (see 2.2.8) and misalignment of the
pump and driver shafts (see 3.3.5).
Figure 2-2-Coordinate System for the Forces
and Moments in Table 2.1A (2.1B)
Vertical ln-Line Pumps
r
Shan centerline
I
2.4.2 Allowable forces and moments for vertical in-line
pumps shall be twice the values in Table 2-1A (2-1B) for
side nozzles.
2.4.3 For pump casings constructedof materials other than
steel or alloy steel or for pumps with nozzles larger than 16
NPS, the vendor shall submit allowable nozzle loadscorresponding to the format in Table 2-1A(2-1B).
2.4.4 Thecoordinatesystem(s) shown in Figures 2-2
through 2-6 shall be used to apply forces
the and moments in
Table 2-1A (2-1B).
Note: The coordinate systems have changed since the 7th Edition of this
standard.
2.4.5 Appendix F defines the method used by the piping
designer to determine allowable pipingloads.
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
Figure 2-3"Coordinate Systemfor the
Forces and Moments in Table 2.1A (2.16)
Vertically Suspended Double-Casing Pumps
API STANDARD
61O
2-6
Table 2-1A-Nozzle
Loadings (SI Units)
Note: Each value shown below indicatesa range from minusthat value to plusthat value; for example710 indicates a range from -710 to +710.
Nominal Size of Flange (NPS)
Forcehloment
2
3 16
4
14
6
12 8
10
Each Top Nozzle
FX
FY
n
FR
710
580
890
1280
1070
890
1330
1930
1420
1160
1780
2560
2490
2050
3110
4480
3780
3110
4890
6920
5340
4450
6670
9630
8Ooo
8900
11700
12780
8450
6670
10230
14850
710
890
580
1280
1070
1330
890
1930
1420
1 780
1160
2560
2490
3110
2050
4480
3780
4890
3110
6920
5340
6670
4450
9630
6670
8000
5340
11700
7120
8900
5780
12780
8450
10230
6670
14850
890
710
580
1280
1330
1070
890
1930
1780
1420
1160
2560
3110
2490
2050
6670
5340
4450
9630
8Ooo
4480
4890
3780
3110
6920
6670
5340
11700
8900
7120
5780
12780
10230
8450
6670
14850
460
230
350
620
950
470
720
1280
1330
680
lo00
1800
2300
1180
1760
3130
3530
1760
2580
4710
5020
2440
3800
6750
6100
2980
4510
8210
6370
3120
4750
8540
7320
3660
5420
9820
6670
5340
7120
5780
Each Side Nozzle
FX
FY
FZ
FR
Each End Nozzle
FX
FY
n
FR
Each Nozzle
MX
MY
Mz
MR
Note 1: F = force in Newtons;M = moment in Newton meters;R = resultant. See Figures 2-2- 2-6 for orientationof nozzle loads(X, and
Y,Z).
Note 2: Coordinate system has been changed from API Standard 610,7th Edition, convention toI S 0 1503 convention.
Table 2-1B-Nozzle
Loadings (U.S. Units)
Note: Each value shownbelow indicates a range from minusthat value to plus that value; for example160indicates a range from -160 to +160.
Nominal Size of Flange (NPS)
ForceMoment
2
3 16
4
14
6
12 8
10
Each Top Nozzle
FX
240
160
FY 200
130
Fz
200
2200 FR 1560
1010 290570
320
260
2600
300
430
1500
m1100
460
700
700
1000
I200
2000 1800
1600
1300
1900
1 500
2300
3300
Each Side Nozzle
320
1010
FX
FY
Fz
FR
570
240
430
160
200
130
260
290
1600
1800
300
200
1500 4001100
1200
700
460
1000
1500
2000
1300
700
1900
2300
1500
3300
Each End Nozzle
FX 300
FY320
0
260
1010
Fz
FR
570
200
430
200
160
130
290
1500
240
1100
400
1200
700
1000
460
1800
2000
1600
1300
700
2300
1900
1500
3300
Each Nozzle
980 M X
700
340
70
M Y500
170
2800 MZ1900
1300 260740
M R 3500 23104601330
6100 5000
4500
350
530
950
3400
4700
2300
3500
Note 1: F = force in pounds; M = movement in foot-pounds;R = resultant. See Figures 2-2- 2-6for orientatin of nozzleloads (X, and
Y,Z).
Note 2 Coordinate system has beenchanged from API Standard 610,7th Edition, convention to I S 0 1503 convention.
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
5400
2700
4Ooo
7200
CENTRIFUGAL PUMPS FOR PETROLEUM,
HEAVYDUTYCHEMICAL, AND GASINDUSTRY SERVICES
~_
~...
"
"
.
"
".
2-7
.
~
. .
-
~
~.
.~
Figure 2-4-Coordinate System for the Forces and Moments in Table 2.1A
(2.18)
Horizontal Pumps with Side Suction and Side Discharge Nozzles
2.5.2 Impellers shall be keyed to the shaft; pinning of impellers isnot acceptable. With the purchaser's approval,collets may be used on vertically suspended pumps. Overhung
impellers shall be securedto the shaft by a cap screw or cap
nut that does not expose shaft threads. The securing device
shall be threaded to tighten by liquid drag on the impeller
during normal rotation, and a positive mechancial locking
method (for example, a staked and corrosion resistant set
screw or a tongue-type washer) is required. Cap screws shall
have fillets and a reduced diameter shank todecrease stress
concentrations.
2.5.3 Impellers shall have solid hubs. Impellers
made from
a cored pattern are acceptableif the core is completely filled
with a suitable metal that has
a melting pointof not less than
260°C (500°F) for pumps with cast iron casings
and not less
than 540°C (1OOO"F) for pumps with cast steel casings.
Note: The requirement to fill cored impeller hubs is intended to minimize
the dangerto personnel when impellers are removed by heating.
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
2.5.4 For shafts that require sleeve gaskets to pass over
threads, at least 1.5 mm (0.06 in.) radial clearance shall be
provided between the threads and the internal diameter
of the
gasket, and the diameter transition shall be chamfered in accordance with 2.2.10.
2.5.5 Shaft sleeves shallbe positively securedto the shaft,
shall have a minimum radial thickness of 2.5 mm (0.1 in.)
and shall be relieved along the bore leaving
a locating fit at
or near each end.
2.5.6 Except for vertically suspended pumps (see 5.3.2.2),
shafts shallbe machined and finished throughout their length
so that the TIR is not more than
25 ym (0.001 in.).
2.5.7 To obtain satisfactory seal performance, the shaft
stiffness shall limit the total deflection under the most severe
dynamic conditions over the allowable operating range of
the pump-with maximum diameter impeller(s) and the
specified speed and fluid-to 50 pm (0.002 in.) at the primary seal faces.This shaft deflection limit may be achieved
A P I STDmbLO 95
m
0732290 O546330 228
m
API STANDARD 610
2-8
..:
Figure 2-5 -Coordinate System for the Forces and Moments in Table2.1A (2.16)
Horizontal Pumps with End Suction and Top Discharge Nozzles
by a combinationof shaft diameter, shaft spanor overhang,
and casing design (including the use of dud volutes or diffusers). For one and two stage pumps,
no credit shallbe taken
wear rings. For mulfor the fluid stiffening effects of impeller
tistage pumps,fluid stiffening effects shall
be considered and
calculations shallbe performed at both
one and two times the
nominal design clearances.The fluid stiffness of product lubricated bearings and bearing bushings shall
be calculated at
both one and two times the nominal design clearances.
2.5.8 When noncontacting vibration probes are
furnished in
to be obaccordance with3.4.3.1, the rotor shaft sensing areas
served by radial vibration probes shall be concentric the
with
bearing journals. All shaft sensingareas (both radial vibration
and axial position) shall free
be from stencil and scribe marks
or any other surface discontinuity, such
as an oil hole
or a keyway, for a minimum distance of one probe tip diameter on
each side of the probe. These areas shall notbe metallized,
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
sleeved, or plated. The final surface finish shall
be a maximum
of 1.0 pm (32 pin.) R,, preferably obtained by honing
or burnishing. These areas shall be properly demagnetized to the
levels specifiedin API Standard 670, or otherwise treatedso
that the combined total electrical and mechanical runout does
not exceed the following:
a. For areas to be observed by radial vibration probes, 25
percent of the allowed peak-to-peak vibrationamplitude or
5 pm (0.25 mil), whichever is greater.
b. For areas to be observed by axial position probes,15 pm
(0.5 mil).
2.5.9 Electrical and mechanical runout of the rotor surfaces to be observedby vibration probes shallbe determined
and recorded. The runout shall be determined by rolling
the rotor supported by V-blocks positioned atthe centerline
of the bearing journals while measuringrunout with a noncontacting vibration probe and a dial indicator simultane-
CENTRIFUGAL
PUMPS FOR PETROLEUM,
HEAVYDUN CHEMICAL,
AND GAS INDUSTRY SERVICES
2-9
Figure 2-6-Coordinate System for the Forces and Moments
in Table 2-1A (2-1B)
Horizontal Pumps with Top Nozzles
ously. The measurements shall be taken at the centerline
of the installed probe location and one probe tip diameter to
either side.
2.5.10 When noncontactingvibration probes arefurnished, accurate records of electrical and mechanical runout
for the full 360 degrees at each probe location shall be included in the mechanical test report.
2.6 Wear Rings and Running
Clearances
2.6.1 Unless otherwise specified, renewable wear rings
shall be furnished on boththecasingandtheimpeller.
Front and back wear rings shall be furnished, if required,
for axial balance. Pumping vanes shall not be used to establish axial balance.
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
Note:Integralimpellerwearsurfaces
approval.
may be supplied with purchaser’s
2.6.2 Mating wear surfaces of hardenable
shall
materials
have a difference in Brinell hardness number ofat least 50
unless both the stationary and the rotating wear surfaces
have Brinell hardness mmbers of at least 400.
2.6.3 Renewable wear rings shall be held in place by a
press fitwith locking pinsor threaded dowels (axialor radial)
or by flanged and screwed methods. Other methods, including tack welding, require the purchaser’s approval.
The diameter ofa hole in a wear fing for a
pin or threaded dowe.
shall not be
than one thirdthewidth of the wear ring.
2.6.4 Running clearances shall meet the requirements of
2.6.4.1and 2.6.4.2.
2-1
o
API STANDARD
610
Table 2-2-Minimum
Minimum
Diametral
Clearance
010
at
Diameter of
Rotating
Member
Clearance
(mm)
<2.0004 0
50 to 64.99
65 to 79.99
80 to 89.99
90 to 99.99
4.000
0.38
100 to 114.99
115 to 124.99
125 to 149.99
150 to 174.99
175 to 199.99
200 to 224.99
225 to 249.99
250 to 274.99
275 to 299.99
300 to 324.99
325 to 349.99
13.000 0.63
350 to 374.99
14.000 0.65
375 to 399.99
400 to 424.99
425 to 449.99
450 to 414.99
0.75
415
0.78
to 499.99
500 to 524.99
525 to 549.99
22.000 0.85
550 to 574.99
575 to 599.99
0.88
600to 624.99
625 to 649.99
0.95
Running Clearances
Minimum
Diametral
Clearance
(mm)
2.000
4.500
at
0.25
0.28
0.30
0.33
0.35
Diameter of
Rotating
Member
Clearance
(in.)
to 2.499
2.500 to 2.999
0.012
3.000 to 3.499
3.500 to 3.999
0.014
to 4.499
to 4.999
5.000 to 5.999
6.000 to 6.999
7.000 to 7.999
8.000 to 8.999
9.000
0.02 to 9.999
10.000 to 10.999
11.000to 11.999
12.000
0.024to 12.999
0.025to 13.999
0.026to 14.999
15.000 to 15.999
16.000 to 16.999
17.000
0.029to 17.999
18.000to 18.999
19.000 to 19.999
20.000 to 20.999
21.000 to 21.999
0.034 to 22.999
23.000 to 23.999
24.000 to 24.999
25.000 to 25.999
0.40
0.43
0.45
0.48
0.50
0.53
0.55
0.58
0.60
0.68
0.70
0.73
0.80
0.83
0.90
(in.)
0.011
0.013
0.015
0.016
0.017
0.018
0.019
0.020
1
0.022
0.023
0.027
0.028
0.030
0.031
0.032
0.033
0.035
0.036
0.037
Note: For diameters greater than649.99 mm (25.999 in.) the minimum diametral clearances shallbe 0.95 m m
(0.037 in.) plus 1 km for each additional 1 mm of diameter or fraction thereof (0,001in. f6r each additional in.).
2.6.4.1 When running clearances are established between
wear rings and between other moving parts, consideration
shall be givento pumping temperatures, suctionconditions,
the character of the liquid handled, the thermal expansion
and galling characteristics of the materials, and pump efficiency. Clearances shall be sufficient
to assure dependability
of operation and freedom from seizure under all specified
operating conditions.
O
2.7.3 When it is specified that seals not comply with API
Standard 682, seals shall meet the requirements of 2.7.3.1
through 2.7.3.23.
2.7.3.1 Unless otherwise specified, all standard mechanical seals, regardless of type or arrangement, shall be of the
cartridge design. For this standard, a cartridge design consists of a mechanicalseal unit, including sleeve, gland, primary seals, secondary seals, etc., that can be testedas a unit
2.6.4.2 For cast iron, bronze, hardened 11-13 percent
and installed as a unit. Hook sleeve cartridge units are not
chromium steel, and materials with similarly low galling ten- considered to be a cartridge seal for this standard. The seal
dencies, the minimumclearances given in Table 2-2 shall be cartridge shall be removable withoutdisturbing the driver.
used. For materials with higher galling tendencies for
andall
2.7.3.2 The standard single (one rotating face per seal
materials operating at temperatures above 260°C (500°F),
chamber) mechanical seal shall be an inside balanced seal.
125 pn (0.005 in.) shall be added to these diametral clearances.
2.7.3.3 The standard unpressurized dual mechanical seal
(previously referredto as a tandem mechanicalseal) shall be
2.7 Mechanical
Shaft
Seals
balanced
a
seal (with
two
flexible elements and
two
mating
rings
in
series).
Unpressurized
dual
mechanical
seals be
shall
2.7.1 Mechanical seals shallbe furnished unless otherwise
designed
to
withstand
pressurization
of
the
buffer
fluid
to
specified. When packing is specified for nonflammable or
275 Wa (40psig).
nonhazardous services, refer to Appendix C.
2.7.2 Unless otherwise specified, seals and sealing systems
shall be furnished in accordance with API Standard 682.
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
2.7.3.4 The standard pressurized dual mechanical seal
(previously referred to as a double mechanical seal) shall be
A P I S T D * b l O 95 W 0732290 054b133 T37
CENTRIFUGAL PUMPS FOR PETROLEUM,
m
HEAWDUTY CHEMICAL, AND GASINDUSTRY
SERVICES
2-1 1
Table 2-*Standard Dimensions for Seal Chambers, Seal Gland
Attachments and Cartridge Mechanical Seal Sleeves (mmlin.)
r(4) Gland Studs
SINGLE
SEAL
To Nearest Obstruction
DUAL
OPTIONAL OUTSIDE
GLAND RABBET
(Note
(Note
I)
Shaft
Chamber Diameter
Seal
(Maximum)
Chamber
(dl)
mdin.
Size
Seal
Stud
2)
(Note
Clear
Gland
Total
Circle
2)
Outside
(Note 3)
(Minimum)
(C)
mdin.
(Minimum)
(E)
mdin.
Stud
Size
(SI Std)
Stud
Size
(US.Std)
Bore
(d2)
mdin.
(d3)
mdm.
Rabbet
(d4)
d i n .
3)
(Note
1
20.0010.787
70.0012.756
10514.13
85.0013.346
15015.90
10013.94
M12x 1.75
112”-13
2
30.0011.181
80.00/3.150
11514.53
95.0013.740
15516.10
10013.94
M12 x 1.75
112”-13
3
40.0011.575
90.0013.543
12514.92
105.0014.134
16016.30
10013.94
M12 x 1.75
112”-13
4
50.0011.968
100.0013.937
14015.51
115.00/4.528
16516.50
11014.33
M16 x 2.0
518-1 I
5
60.0012.362
120.0014.724
16016.30
135.0015.315
17016.69
11014.33
M16 x 2.0
518”-11
6
70.0012.756
130.0015.118
17016.69
145.0015.709
17516.89
11014.33
M16 x 2.0
5/8”-11
7
80.0013.150
140.00/5.512
I 80/7.O9
155.0016.102
18on.w
11014.33
M16 x 2.0
5/8”11
8
90.0013.543
160.00/6.299
20518.07
175.0016.890
185n.28
12014.72
M20 x 2.5
314”-IO
9
100.0013.937
170.0016.693
21518.46
185.0017.283
19017.48
12014.72
M20 x 2.5
314”- 1O
10
110.0014.331
180.0017.087
22518.86
195.0017.677
19517.68
12014.72
M20 x 2.5
314“-1 O
Note 1: Dimensions to tolerance grade G7/h6. Reference:
I S 0 286 (ANSVASME B4.1).
Note 2: Dimensions to tolerance gradeH7h6; for axially split pumps, an additional tolerance to allow for gasket thickness:
f 75 pm 1,0.003 in.
Note 3: Shaft deflection criteria(see 2.5.7) may require (C) and (E) dimensions on size 1 and 2 seal chambers to be reduced below
the minimum values
listed, depending on specific pump construction and casing design.
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
~~
A P I STDxbbO 95
2-1 2
m
0732290 05qhL3q 773
m
API STANDARD
610
than 125 pm (0.005 in.) (Appendix K). Centering of mechanical seal components
by the use of seal gland bolts is not
acceptable.
a balanced seal (with two flexible elements and two mating
rings in series). The inner seal shall have an internal (reverse) balancefeature designed and constructed to withstand
reverse pressure differentials without opening.
2.7.3.12 A shoulder at least 3 mm (O. 12 in.) thick shall be
provided in the sealgland to prevent the stationary element
2.7.3.5 This standard doesnot cover the designof the component parts of the mechanical
seals; however, the design and of the mechanical seal from dislodging as a result of chammaterials of the component parts shall be suitable for the spec-ber pressure.
ified service conditions. The maximum allowable working
2.7.3.13 Mechanical seal performance depends on the
pressure shall apply to all parts referred
in the
to definition of
runout conditions at the mechanical seal chamber. Seal
pressure casing.The seal manufacturer shall
state when preschamber face runout is a measure ofthe perpendicularity of
sure ratings of sealsdo not meet this requirement, and shall
this face to the pump shaft axis. This runout (TIR) shall not
advise the purchaser of the maximum sealing pressure and the
exceed 10 pm per 20 mm (0.0005 inlin.) of seal chamber
seal’s maximum dynamic andstatic pressure ratings.
bore (Appendix K).
2.7.3.6 The seal chamber shall conform to the minimum
2.7.3.14 Specified seal and pump connections shall be
dimensions shown in Table2-3. W
i
t
h these dimensions, the
identified by symbols permanently marked into the compominimum radial clearance between the rotating member(s)
nent (such as stamped, cast, or chemically etched) and
of the mechanical seal and the
bore of the seal chamber and
shown on the seal drawing. The symbols shown
in Appendix
gland shall be 3 mm (0.12 in.) (see AppendixU).
D shall be used.The suffix letters shall be used in conjuncNote: For pumps with flange and pressure ratings in excess of the minition with these markings where appropriate. When a steam
mum values in 2.2.2, the gland stud size and circle may increase. Larger
quench
is specified by the purchaser, the inlet connection
studs shall be furnished only if required to meet the stress requirements
of
(QI)
shall
be located in the top quadrant of the seal gland,
Section VI11 or Section II of the ASME Code, or to sufficiently compress
spiral wound gaskets in accordance with manufacturer’s specifications.
and the outlet connection (QO) shall be located to prevent
the formation of liquid pockets.
2.7.3.7 Mechanical seal materials shall be furnished
in accordance with AppendixH. Seal faces and gaskets shall be
2.7.3.15 Seal glands and seal chambers shall have provicoded in accordance with TablesH 4 and H-5.
sion for only those connections
required by the seal flush plan.
are specified andare not
If
additional
tapped
connection
points
2.7.3.8 Mechanical seal sleeves shall meet the following
used,
they
shall
be
plugged
with
solid
round
or solid hexagon
criteria:
head plugs furnishedin accordance with the requirements
of
a. Be of wear, corrosion, and erosion resistant material.
ANSUASME B 16.11, When cylindrical threadsare specified
b. Be sealed at one end.
in 2.3.3.3, pipe plugs shallbe solid hexagon head plugs furc. Extend beyond theouter face of the seal gland(so leakage
nished in accordance withDIN 910. These plugs shall be of
between the shaft and the sleeve cannot be confused with
as the seal gland
or seal chamber. An anaerthe same material
leakage across the seal faces).
obic (or other suitablehigh temperature) lubricant/sealant shall
d. Be of one-piecedesign.
be used to ensure that the threads
are vapor tight.
e. Have a shaft-to-sleeve diametral
clearance corresponding
2.7.3.1 6 The seal chamber shallbe provided withan interto G7h6 to allow easy assembly and removal while
providnal passage or external connection to permit complete venting required runoutcontrol.
ing ofthe chamber before start-up.
Note: G7h6 is nominally equivalent to
25 to 75 pm (0.0010.003
to in.) but
varies as a functionof diameter.
2.7.3.9 Unless otherwise specified, seal chambers
and seal
glands shall be designed for the same pressure and temperature as the pump pressure casing and shall have sufficient
rigidity to avoid anydistortion that would impair seal operation, including distortion that may occur during tightening
of the bolts to set gasketing.
2.7.3.10 Seal glands shallbe provided with bolt holes rather
than slots, except where theease of dismantling pumps with
axially split casings makes slotted construction desirable.
2.7.3.11 Provisions shall be made for centering the seal
gland and/orchamber with either an inside or outside diameter register fit.The register fit surface shall be concentric to
the shaft and shall have a totalindicated runout of not more
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
O
2.7.3.17 When specified, jackets or cooling inserts shall
be provided on seal chambers. Cooling (or heating) requirements shall be mutually agreed upon by the purchaser, vendor, and seal manufacturer.
Note: The use of water cooling is discouraged because of the danger of
fouling and subsequent loss of effectiveness during operation. Forced-air
cooling shouldbe considered as an alternative. As a guide, coolingor heating maybe considered for the conditions andservices listedin the following
be mutually a p e d
items a throughe. If provided, piping requirements shall
upon by the purchaser, vendor, andseal manufacturer. No specific piping
plan is listed in FigureD-4for seal chambercooling (or heating).
a. Pumping temperatures above 150°C (300”F),depending on mechanical
seal materials selected.
b. Boiler feed pumps.
c. Dead-ended seal arrangements.
d. Low-flash-point liquids.
e. High-melting-pointproducts (heating).
-
A P I STD*bLO 95 9 0732290 0 5 4 6 3 3 5 B O T
CENTRIFUGAL PUMPS FOR
PETROLEUM, HEAVYDUTY CHEMICAL, AND GASINDUSTRY SERVICES
2.7.3.1 8 Throat bushings shall be provided unless otherwise specifiedby the purchaser or otherwise recommended
by the vendor.Throat bushings canbe used forthe following
purposes:
a. To function as a replaceable wearing part.
b. To establish differential hardness between rotating and
stationary parts.
2.7.3.19 The vendor shall furnish all mechanical seal
piping and appurtenances specified by the purchaser. Mechanical seal piping shall be in accordance with the appropriate plan of Appendix D, and the plan shall be indicated
on the data sheets. During operation, the pressure at the
seal faces shall be maintained at or above atmospheric
pressure. In vacuum service, the seal design shall be adequate to seal against atmospheric pressure when the pump
is not operating.
2.7.3.20 For single seals, and when specified for dual
seals, a non-sparking floating throttle bushing shall be installed in the seal gland and positively retained against
pressure blowout to minimize leakage if the seal fails. The
diametral clearance at the bushing bore shall be as specified
in Table 2-4. Floating throttle bushings shall have a minimum radial displacement capability of at least 0.75 mm
(0.030in.).
2.7.3.21 Where seal face leakage of the pumped fluid to
the atmosphere mustbe controlled, one of the following arrangements may be utilized (see Appendix D):
a. Auxiliary sealing devices, such as a close-clearance float(see 2.7.3.20). (Auxiliary sealing devices
ing throttle bushing
may require a quench or sealing fluid; see Appendix D.)
b. Dual seals which use a buffer fluid maintained at a pressure lower than the pressure being sealed.
c. Dual seals which use a barrier fluid maintained at a pressure higher thanthe varying pressure being sealed.
d. Dual seals which use a dry running outer seal with no
buffer or banierliquid. The space between the seals shall be
piped toa suitable vapor recoverysystem.
Table 2-4-Floating Throttle Bushing
Diametral Clearance
Sleeve
Clearance
Maximum
Diameter
G 5 0 m m (0-2.00 in.)
51-80 mm (2.01-3.00 in.)
81-120 m m (3.01-4.75 in.)
over 120 mm (4.75 in.)
180 prn (0.007 in.)
225 pm (0.009 in.)
280 pm (0.011 in.)
2.5 p d l . 0 mm diameter
(0.0025 in./in. diameter)
Note: Bushings must be sized to allow for thermal growth of the shaft.
The clearances in Table2-4 are based upon carbon bushings at pumping
temperature. Other materials may require other clearances. Axial space limfit floating bushings on dualseals.
itations may make it impractical to
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
m
2-1 3
The purchaser will specify the characteristics of the barrier
or buffer fluid. Where the required flow, pressure, and temperature are factors, they shall be jointly established by the
vendor and the seal manufacturer and shall be noted onthe
data sheets. When dual seals (as in Items b and c above) are
provided, the banier or buffer fluid shall be circulated by
means of a circulating device such as a pumping ring or a
flow-through system from an external source (see Appendix D).
2.7.3.22 Mechanical seals and glands for all pumps, except vertically suspended pumps shipped without drivers
mounted, shallbe installed in the pump before shipment and
shall be clean and readyfor initial service. On pumps whose
seals require final adjustment or installation in the field, the
vendor shallattach a metal tag warning of this requirement.
2.7.3.23 The mating joint between the seal gland and the
seal chamberface shall incorporatea confined gasket to prevent blowout.The gasket shallbe of thecontrolled compression type (for example,an O-ring or a spiral wound gasket)
with metal-to-metaljoint contact. Where spaceor design limitations make this requirement impractical,an alternative seal
gland design shallbe submitted to the purchaser
for approval.
2.8
Dynamics
2.8.1 The topics of critical speed and lateral analysis are
covered in each specific pump type section.
2.8.2TORSIONALANALYSIS
2.8.2.1 Unless otherwise specified, a torsional analysis
shall be performed by the manufacturer having unit responsibility when the driver is one of the following:
a. Electric motor, or turbine, through gear rated 1500 kW
(2000 hp) or higher.
b. Internal combustion engine rated 250 kW (335 hp) or
higher.
c. Synchronous motorrated 500 kW (670 hp) or higher.
d. Electric motor with variable frequency
drive (W)
rated
IO00 kW (1350 hp) or higher.
The analysis shall be for the train as a whole unless the train
includes a device thathas weak dynamic coupling, for example, a hydraulic coupling or torque converter.
2.8.2.2 Excitation at the following frequencies shall be
evaluated:
1 and 2 x RF" of either shaft
nxRPM
n X slip frequency, 1 and 2 x
line frequency
d. Variable frequency drive: n X RI", 1 and 2 X line
frequency
a. Train with gear(s):
b. Engine drive:
c. Synchronous motor:
Where:
RPM = Rotor speed.
~~
A P I S T D x b L O 95
m
073229005YbL3b74b
W
API SiANDARD 610
2-1 4
n
= An integer determined by the drive
manufacturer:
-for engines: derived from the number
of powerstrokes per revolution.
-for motors: derived from the number
of poles.
The excitation frequencies for motor drives, items c and d,
include transient and steady state conditions.
2.8.2.3 The undamped torsional natural frequencies of
the
complete train shall be at least 10 percent above or 10 percent below any possible (steady state) excitation frequency
within the specified operating speed range (from minimum
to maximum continuous speed).
2.8.2.4 When torsional natural frequencies are calculated
to fall within the margin specified in 2.8.2.3 (and the purchaser and the vendor have agreed that all efforts
to remove
the critical from within the limiting frequency range have
been exhausted), a stress analysis shall be performed to
demonstrate that the resonances have no adverseon
effect
the
complete train.The acceptance criteriafor this analysis shall
be mutually agreed upon by the purchaser and the vendor.
2.8.2.5 Whenever a torsional analysis is performed, a
Campbell diagramshall be furnished to the purchaserfor information only.
o 2.8.2.6
When specified, the manufacturer shall furnish a
detailed report of the analysis. The report shall include the
following:
a. A description of the method used to calculate the natural
frequencies.
b. A diagram of the mass elastic system.
c. A table of the mass moment and torsional stiffness
each
of
element of the mass elastic system.
d. ACampbell diagram.
e. A modeshape diagram with peakstresses shown for each
resonant frequency.
2.8.3.1 The preferred operating region and location of rated
capacity shallbe as specified in 2.l .12. The allowable operating region shall
be stated in the proposal. When the allowable
operating regionis limited by a factorother than vibration, that
factor shall also be stated
in the proposal.
2.8.3.2 During the performance test, unfiltered vibration
measurements and a Fast
Fourier Transform (m)
spectrum
shall be made
at each test point except shutoff.
The measurements shall be as follows:
a. The bearing housing(s) or equivalent location(s) of all
pumps, at the positions shown on Figures 2.8A and 2.8B.
b. The shaft of pumps with hydrodynamicjournal or guide
bearings and furnished with proximity probes,at a position
adjacent to the bearing. Measurements made using a shaft
stick are not acceptable.
2.8.3.2.1 The FIT spectra shall include the range of frequencies from 5 Hz to 22 times runningspeed (where Z is the number of impeller vanes; in multistage pumps w i e different
impellers, Z is the highest number of impeller vanes in any
stage).
Note: The discrete frequencies 1.0,2.0, and Z times running speed are associated withvarious pump phenomena, and are therefore
of particular interest in the spectra.
2.8.3.2.2 The plotted spectra shall be included with the
pump test results.
2.8.3.3 Bearing housing overall vibration measurements
( W S )velocity and, when
shall be made in root mean square
U.S. dimensions are specified, in both FUVISand True Peak
velocity, &sec (in./sec).
2.8.3.4 Instrumentationused to measure bearing housing
vibration shall meet the following requirements:
2.8.3.4.1 RMS velocity shall be determined by a circuit
which performs the square of the waveform, averages
the result, then computesthe square root of that value, mathematically described as:
Note: Item e is required only when a stress analysis is performed; see
2.8.2.4.
RMS =
2.8.3
-
[$I
I
'f(t)'clt]'
VIBRATION
Note: Centrifugal pump vibration varies with flow, usually being a minimum in the vicinity of best efficiency point flow and increasingas flow is
as isvaried from best
increased or decreased. The change in vibration flow
efficiency point flow depends upon the pump's energy density,its specific
speed, and its suction specificspeed. In general, the change in vibration increases with increasing energy density, higherspecific speed, and higher
suction specific speed.
With these general characteristics, a centrifugal pump's operatingflow
range can be dividedinto two regions, onetermed the best efficiency or
preferred operating region,over which thepump exhibits lowvibration,
the other termed theahwable operating region,with its limits definedas
those capacitiesat which the pump's vibration reaches a higher
but still
"acceptable" level. Figure 2.7 illustrates the concept. (Note that factors
other than vibration, forexample, temperature rise with decreasingflow
or NPSHR with increasingflow, may dictate anarrower allowable operating region).
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
Verification that the instrument
is measuring RMS velocity
shall be carried out in accordance with AppendixS .
2.8.3.4.2 True peak velocity shallbe determined by dividing the true peak-to-peak value of the vibration (velocity)
signal by two. The true peak-to-peakvalue of the vibration
signal shallbe measured by an instrument having positive
and
negative peak detector circuits. These circuits shall determine
the maximumpositive and negativeexcursion of the signal
during four consecutive shaft revolutions. Measurement
of a
shaft revolution shallbe determined from consecutive pulses
from the phase reference transducer (API
670). The charging
time constantof these detectors shall not exceed
30 microsec-
m 0732290 0546337 682
A P I STDxbLO 95
Allowable
I
I
J
Maximum
allowable
O flow limits
BEP
Flow
Figure 2-7-Relationship Between Flow and Vibration
V
7
v
25 mm
h
1.O i n ì
<
, i
?
2mm
r(0.08in.)
for
arranaement
ODtional
mounting vibrati& measuring
equipment (see 2.9.2.11 and2.9.2.12)
\\\'
Dimple (see 2.9.2.10)
Figure 2-8A-Locations for Taking Vibration Readings on HorizontalPumps
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
-
~~~~
API STD*bLO 95 m 0732290 0546138 519 H
API STANDARD
61O
2-1 6
!f
I A
Optional arrangementfor
mounting vibration measuring
equipment (see 2.9.2.1 1 and 2.9.2.12)
-1
Dimple (see 2.9.2.10)
Pumps
Figure 2-8B-Locations for Taking Vibration Readings on Vertical
onds. The outputs ofthe peak detectors shall
be sampled, held
and then reset at the end
of each four shaft revolutions.Verification that the instrument is measuring true peak velocity
shall be carried outin accordance with Appendix
S.
2.8.3.5 The units for shaft vibration measurement shallbe
peak-to-peak displacement in pm (mils).
2.8.3.6 If the vendor can demonstrate that there is electrical or mechanical runout of the
rotor surfaces at the proximity probes (see 2.5.9), a maximum of 25 percent of the
measured value or 6 microns (0.25 mils), whichever is
greater, may be vectorially subtracted from the vibration
signal measuredduring the shop test.
2.8.3.7 The vibration measured during the performance
test shallnot exceed the values shown inthe following:
a. Table 2-5 for overhung and between bearing pumps.
b. Table 2-6 for vertically suspended pumps.
Pumps furnished with proximity probes shall meet both
bearing housing andshaft vibration limits.
Note: Bearing housing overall vibration limits are defined for RMS measurements only.True peak values are for i n f o d o n and diagnosticpurposes
only andare not to be used to determine the acceptability ofthe equipment.
2.8.3.8 At any speed greater than the maximum continuous speed, up to and including the trip speed of the driver,
the vibration shall notexceed 150 percent of the maximum
value recordedat the maximum continuous speed.
2.8.3.9 Variable speed pumps shall operate over their
specified speed range without exceeding
the vibration limits
of this standard.
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
BALANCING
2.8.4
2.8.4.1 Impellers, balancingdrums, and similar major rotating components shall
be dynamically balancedto grade G1.O
of I S 0 1940 (4WIN) or 7 @mm (0.01 oz-in.), whichever is
greater. The weight of the arbor used
for balancing shall not
exceed the weight
of the component being balanced.
Note: Unbalance is expressed in U.S. units as the following:
U = KWIN
Where:
U
=
K
=
W
=
=
unbalance per plane,oz-in.
constant.
componentweight,whenbalancingcomponents,
pounds.
load per balancing macbinejournal when balancing
rotors, pounds.
rotative speed,
RPM.
N =
or in IS0 termsas a balance quality gradeof IS0 1940. Each of the IS0 balance quality grades covers a range of unbalance.
The nominally equivalent
U.S. unit limits given throughout
this standard correspond approximately
to
the midpointof the IS0 range.
With modem balancing machines,it is feasible tobalance components
mounted ontheu arbors to V = 4WIN (nominally equivalentto IS0 grade
G1.0),or even lowerdepending upon the weight of the assembly, and to
verify the unbalance of the assemblyawith
residual unbalance check. However, the mass eccentricity,e, associated with unbalance
less than U = 8WIN
(nominally equivalentto IS0 grade (32.5) is so small (e.g.U = 4WIN gives
e = O.ooOo70 in. for an assembly intendedto run at 3600 RPM) thatit cannot be maintained if the assembly is dismantled and remade. Balance grades
below 8WIN (G2.5) are, therefore, not repeatablefor components.
2.8.4.2 Component balancing may be single plane when
the ratio D / B (see Figure 2.9) is 6.0 or greater.
2.8.4.3 Rotor balancing shall be performed as required in
the specific pump sections.
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A P I STDxblO 75
0732290 0546337 455
CENTRIFUGAL
PUMPS
FOR PETROLEUM,
HEAWDUTYCHEMICAL,
AND GASINDUSTRY
SINGLE SUCTION IMPELLER
SERVICES
2-1 7
DOUBLE SUCTION IMPELLER
."
BALANCING DRUM
THRUST COLLAR
Figure 2-9"Rotating Component Dimensions to Determine
When Single Plane Balancing Is Allowable
2.9
BearingsandBearingHousings
2.9.1 BEARINGS
2.9.1.1 Bearings shall be one of the following arrangements: rolling element radial and thrust, hydrodynamic radial and rolling element thrust, or nydrodynamic radialand
thrust. Unless otherwise specified, the bearing type and arrangement shall be selected in accordance with the limitations in Table2-7.
2.9.1.2 Thrust bearings shallbe sized for continuous operation under all specified conditions, including maximum
differential pressure. All loads shall be determined at design
internal clearances and alsoat two times design internal
clearances. In addition to thrust from the rotor and anyinternal gear reactions due to the mostextreme allowable conditions, the axial force transmitted throughflexible couplings
shall be considered a part of the duty of any
thrust bearing.
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
Thrust bearings shall provide full load capabilities if the
pump's normaldirection of rotationis reversed.
2.9.1.2.1 For gear-type couplings,the external force shall
be calculated from the following formula:
F = (0.25) (9,550) P,
(NP)
In U.S. units:
F = (0.25) (63,000) P,
(N$)
Where:
F
P,
N,
D
Note:
= external force, kN (lbs)
= rated power, k W (hp)
= rated speed, in revolutions per mibute.
= shaft diameter at the coupling, mm (in.)
Shaft Liameter is an approximation of the coupling pitch radius.
API STANDARD
61O
2-1 8
Table 2-&Vibration Limits for Overhung and Between Bearings Pumps
Location of
Item
Pump bearing type
bration Measurement
Bearing Housing
(see Figure 2-SA)
Pump Shaft
(adjacent to bearing)
All
Hydrodynamic
iournal bearings
V, < 3.0 mm/sec RMS
A,, < (5.2X106)OS pm pk/pk
Vibration at any flow within
the pump’s preferred
operating region:
Overall
N
(O. 12 in./sec RMS)
((SOOO/N)05 mils
Discrete frequencies
Increase in allowable
vibration at flows beyond
the preferred operating
region but within the
allowable operating region
(0.08 in./sec RMS)
pk/pk)
Not to exceed:
A,, 50 pm pk/pk
(2.0 mils pk/pk)
for Ar 2 N : 75% of A,,
for Af < N : 33% of A,,
30%
30%
VJ< 2.0 mmlsea RMS
Note: Values calculated from the basic limits shall be rounded off to two(2) significant figures.
Where:
V,
VJ
A,,
= unfiltered
velocity.
A,
= velocity.
filtered
N
= unfiltereddisplacementdetermined by FFT.
= filtered
displacement
determined
by
= rotational speed (RPM).
FFT.
Table 2-6-Vibration Limits for Vertically Suspended Pumps
Location of
Item
Pump bearing type
bration Measurement
Pump Thrust Bearing
Housing
or
Motor Mounting Flange
(see Figure 2-SB)
Pump Shaft
(adjacent to bearing)
All
Hydrodynamic guide bearing
adjacent to accessible
region of shaft
V,, < 5.0 mm/sec RMS
A,, < (6.5x106)Os pn pk/pk
Vibration at any flow within
the pump’s preferred
operating region:
Overall
(0.20 i d s e c RMS)
N
(( 1O,OOO/N)O5 mils pk/pk)
Not to exceed:
A,, < 1 0 0 pm pk/pk
(4.0 mils pk/pk)
Discrete frequencies
Increase in allowable
vibration at flows beyond
the preferred operating
region but within the
allowable operating region
Vf< 3.4 mm/sec RMS
(O. 13 in./sec RMS)
AJ :75% of A,,
30%
30%
Note: Values calculated from the basic limits shall be rounded off to two (2) significant figures.
Where:
V,,
VJ
= unfiltered
velocity.
=velocity.
filtered
A,,
= unfiltereddisplacementdetermined by F R .
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
AJ = filtered
displacement
determined
by
N = (RPM).
rotational
speed
FFT.
A P I STD*bLO 95
0732290 054bl14L 003
CENTRIFUGAL PUMPS FOR PETROLEUM, HEAWDUTY
CHEMICAL,
AND
m
GASINDUSTRY SERVICES
2-1 9
Table 2-7-Bearing Selection
Arrangement and
Type
BearingCondition
Radial
and
thrust
bearing
speed
and
life
Rolling
within limits for rolling element bearings
and
Pump energy density below limit
or life outside
limits
Hydrodynamic
radial
and
rolling
element
Radial
bearing
speed
thrustbearings
element
for rolling
thrust
element radial
and
thrust
and
bearing
Thrust
spxd and lifelimits
within
for rolling element bearings
and
radial
Hydrodynamic
and
Pump energy density below limit
or
Radial
and
thrust
bearing
speed
or life
Hydrodynamic
radial
and
thrust
outside limits for rolling element bearings
or
Pump energy density above limit
Note: Limits are as follows:
a. Rolling element bearing speed:
Factor, Nd, not to exceed500,000
Where:
dm
N
= meanbearing diameter (d+D)/2,mm
= rotativespeed,RPM
b. Rolling element bearing life:
Basic rating Lloh per IS0 281 (ANSUABMA Standard 9) of at least 25,000 hours with continuous operation
at rated conditions, andat least 16,000 hours at maximum radial and axial loads and rated speed.
c. Energy density:
When the product of pump rated power,kW (hp), and rated speed, RPM,is 4.0 million (5.4 million) or
greater, hydrodynamic radial and thrust bearings
are required.
2.9.1.2.2 Thrust forces for flexible metal element couplings shall be calculated on the basis of the maximum allowable deflection permittedby the coupling manufacturer.
2.9.1.2.3 If a sleeve bearing motor (withouta thrust bearing) is directly connectedto the pumpshaft with a coupling,
the coupling transmitted thrust will be assumed to be the
maximum motor thrust.
ries). Unless otherwise specified, bearings shall be installed
back-to-back. The need for bearing clearance or preload
shall be determined by the vendor to suit the application and
meet the bearinglife requirements of 2.9.1 . l .
2.9.2 BEARING HOUSINGS
2.9.2.1 Bearing housings shall be arranged so that bearings can be replaced without disturbing pump drives or
mountings.
2.9.1.3 Rolling element bearings shall be located on the
shaft using shoulders, collars, or other positive locating devices; snap ringsand spring-type washersare not acceptable. o 2.9.2.2 Bearing housings for oil-lubricated nonpressurefed bearings shall be provided with tapped and pluggedfill
Rolling element bearings shallbe retained on the shaft with
and drain openings at least NPS. The housings shall be
an interferencefit and fitted into the housing
with a diametral
equipped with constant level sight feed oilers at least 0.12
clearance, both in accordance with the recommendationsof
liter (4 oz) in size, witha positive level positioner (not an exIS0 286 (ANSUABMA Standard 7). Bearings shall be
ternal screw), heat-resistant glass containers, and protective
mounted directlyon the shaft; bearing carriers
are not acceptwire cages. When specified, the oilers shall meet the purable. The device used to lock ball thrust bearings to shafts
chaser's preference. Means shall be provided for detecting
shall be restricted toa nut with a tongue-type lock washer.
overfilling of the housings. A permanent indication of the
2.9.1.4 Except for the angular contact type, rolling element
bearings shall have greater than Normal internal clearance ac- proper oil level shall be accurately located and clearly
marked on the outside of the bearing housing with permacording to I S 0 5753 Group 3 (ANSUABMA Symbol 3, as
nent metal tags, marks inscribed in the castings, or other
defined in ANSUABMA Standard20). Single- or double-row
durable means.
bearings shall beof the Conrad type(no filling slots).
'h
2.9.1.5 Ball thrust bearings shall be of the duplex, single
row, 40 degree (0.7 radian) angular contact type (7000 se-
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
2.9.2.3 Sufficient cooling, including an allowance for
fouling, shall be provided to maintain oil and bearing tem-
A P I S T D t b L O 95
2-20
m
0732290 05qb1112 T 4 T
m
API STANDARD
610
~
peratures as follows, based on the specified operating
conditions and anambient temperature of 43°C(1 10°F):
~~
~
type bearings shall have the ventlocated near the endof the
, housing.
2.9.2.7.3 Shielded or sealed bearings shall not be used.
a. For pressurized systems, oil outlet temperature below
7 1°C (160°F) and bearing metal temperatures (when bearing2.9.2.7.4 When pure oil mist lubrication is specified, oil
temperature sensors are supplied) less than 93°C (200°F).
rings or flingers (ifany) and constant level oilers shall
not be
During shop testing,
the bearing oil temperature rise shall not provided, anda mark indicating the oil level isnot required.
exceed 28°C(50°F).
When purge mist lubrication is specified, these items shall be
b. For ring oiledor splash systems,oil sump temperature beprovided andthe oiler shall be piped so that it is maintained
low 82°C (180°F). During shop testing, the sump oil temper- at the internal pressureof the bearing housing.
ature rise shall not exceed 39°C (70°F).
Note: At pumping temperatures above
300°C (570’F). bearing housings
with pure oil mist lubrication may require special features to reduce heating
of the bearing races by heat transfer from the pumpage. Typical features are
as follows:
Note: Pumps equipped with ring oiled or splash lubrication systems may
not reach temperature stabilization during hydraulic performance testsof
short duration. If the purchaser desires temperature stabilization testing,
this
requirement shouldbe stated in the inquiry and addressed by the vendor in
the proposal.
2.9.2.4 Where water cooling is required, water jackets
shall have only external connections between upper and
lower housing jackets and shall have neither gasketed nor
threaded connection joints which may allow water to leak
into the oil reservoir.If cooling coils (including fittings) are
used, they shall be of nonferrous material
or austenitic stainless steel and shall have no internal pressurejoints. Tubing
or pipe shall have a minimum thickness of 1.0 mm (0.040
in.) and shall be at least 12 mm (0.50 in.) outside diameter.
2.9.2.5 For pumpshandlingflammable or hazardous
liquids, bearing housings, load-carrying bearing housing
covers, and brackets between the pump casing or head and
the bearing housings shallbe steel. Driver supports for vertical pumps which utilize thrust bearings
in the driver to support the shaft shall be steel.
a. Heat sink type flingers.
b. Stainless steel shafts having low thermal conductivity.
c. Thermalbarriers.
d. Fan cooling.
e. Purge mist lubrication (in place of pure mist) with oil (sump) cooling.
2.9.2.7.5 The oil mist supply and drain fittings will be
provided by the purchaser.
2.9.2.8 Housings for ring oil lubricated bearings shall be
provided with plugged ports positioned to allow visual inspection of the oil rings whilethe pump is running.
0
2.9.2.9
When specified, the vendor shall furnish oil heaters.
2.9.2.10 All bearing housings shall be dimpled at the locations shown on Figures 2-8A
and 2-8Bto facilitate consistent vibration measurements. The dimples shall be suitable
for accurate location of a hand-held vibration transducer
with an extension “wand.” Dimples
may be castor machined
and shall be nominally 2 mm (0.080 in.) deep with an included angle of 120 degrees.
2.9.2.6 Bearing housings shall be equipped with replace0 2.9.2.11
When specified, bearing housings shall have a
able labyrinth end seals and deflectors where the shaft passes
threaded connection(s) for permanently mounting vibration
through the housing; lip seals shall not be used. The seals
transducers in accordance with API 670. When metric fasand deflectors shall be made of nonsparking materials. The
teners are supplied, the threads shall be M8.
design of the seals and deflectors shall effectively retainoil
in the housing and prevententry of foreign materialinto the O 2.9.2.12 When specified, a flat surface at least 25 mm
housing.
(1 in.) in diameter shall be supplied for the location of
magnetic based vibration measuring equipment.
2.9.2.7 Bearings and bearing housings shall meet the requirements of 2.9.2.7.1 through 2.9.2.7.5 when oil mist lubrication is specified (see 2.10.3).
2.10
2.9.2.7.1 An oil mist inlet connection, ‘/4 NPS, shall be
provided in the top half of the bearing housing.The pure or
purge oil mist fitting connections shall be located so that oil
mist will flow through rolling element bearings. On puremist systems, there shall be no internal passage
to short circuit oil mist from inlet to vent.
2.9.2.7.2 A ‘/4 NPS vent connection shall be provided on
the housingor end cover for each of the spaces betweenthe
rolling element bearings and the housingshaft closures. Alternatively, where oil mist connections are between each
housing shaft closure and the bearings, one vent central to
the housing shall be supplied. Housings with only sleeve-
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
Lubrication
2.10.1 Unless otherwise specified, bearings and bearing
housings shall be arrangedfor hydrocarbon oil lubrication.
2.10.2 Flingers or oil rings used to deliver oil to the
bearings shall have anoperating submergence of 3 to 6 mm
(0.12 - 0.25 in.) above the lower edge of a flinger or above
the lower edge of the bore of an oil ring. Oil flingers shall
have mounting hubs to maintain concentricity and shall be
positively securedto the shaft.
2.1 0.3 When specified, provisions shall be made for either pure oil or purge oil mist lubrication (see 2.9.2.7 for
requirements).
2-21
~~
2.11
Materials
2.11.1 GENERAL
2.11.1.1 Materials for pump parts shall be in accordance
with AppendixH, except thatsuperior or alternative materials recommendedfor the serviceby the vendor shall be listed
on thedata sheets. Auxiliary pipingmaterials are covered in
3.5. The purchaser will specify the class of pump materials
and, for seals not conforming to API Standard 682, the mechanical seal code from Appendix H
that is applicable to the
service. TableG-1, Appendix G,is a guide showing material
classes that may be appropriate for various services. Pump
parts designatedasfull compliance materials in Table H1 of
Appendix H shall meet the requirements of the industry
specifications listed for materials in Table H-2. Pump parts
not designated asfull compliance materials in Table H-1
shall be made from materials with the applicable chemical
composition but need not meet
the other requirements of the
listed industry specification.
2.1 1.1.2 Materials shall be clearly identified in the proposal with their applicable industry standard numbers, including the material grade
(see Appendix H). When no such
designation is available, the vendor’s material specification
giving physical properties, chemical composition, and test
requirements shall be included in
the proposal.
2.11.1.3 The vendor shall specify the optionaltests and inspection procedures necessary to ensure that materials are
satisfactory for the service. Such tests and inspections shall
be listed in the proposal. The purchaser may consider specifying additionaltests and inspections,especially for materials used incritical components.
2.1 1.1.4 Classification of pump materials shall be in accordance with the following itemsa through c:
~
~
~~~
mechanical data for the heat from which the material is
supplied.
2.11.1.8 The purchaser will specify any corrosive agents
present in the motive and processfluids and in the environment, including constituentsthat may causestress corrosion
cracking.
Note: Typical agents of concern are amines, chlorides, cyanide, fluorides,
and napthenic acid.
2.11.1.9 Minor parts that are not identified (such as nuts,
springs, washers, gaskets, and keys) shall have corrosion resistance at least equal to that of specified parts in the same
environment. Gasketor seal material between the shaft and
the shaft sleeve under the packing or mechanical seal shall
be verified by the vendor
as being satisfactoryfor the service
conditions.
Note: When dissimilar materials with significantly different electrical potentials are placed in contact in the presence of an electrolytic solution,
galvanic couples that can result in serious corrosion of the less noble material
may be created. If such conditions exist, the purchaser and the vendor
should select materials in accordance with NACE Corrosion Engineer’s
Reference Book.
2.11.1.1 O Where mating parts such as studs and nuts of
austenitic stainless steelor materials with similar galling tendencies are used, they shall be lubricated with a suitable antiseizure compound of the proper temperature specification
and compatible with the contactedliquid(s).
Note: Torque loading values will differ considerably with and without an
antiseizure compound.
2.1 1.1.1 1 The purchaser will specify the presence and concentration of H2S and water in the processliquid. Materials
with a yield strength of more 620
thanN/mmz (90,000 psi) or
a hardness of more than Rockwell C22 shall not be usedfor
the following components
if they will be exposed atosour environment (wetH+) as definedby NACE MR0175:
a. Pressure casing partsof double casing pumps shall be of
a. The pressure casing.
carbon steelor alloy steel.
b.
b. Pressure casing parts of pumps that are to handle flammable Shafting (including wetted shaft nuts).
c. Balancing drums.
or hazardous liquids shallbe of carbon steelor alloy steel.
d. Impellers.
c. Cast iron construction may be offered for other services.
e. Pressure retaining mechanical seal components (excluding
2.11.1.5 If austenitic stainless steel parts exposed to conseal faces).
ditions that promote intergranular corrosion are to be fabrif. Wetted bolting.
cated, hard faced, overlaid, or repaired by welding, these
Items 1 through 4 below apply whenH2S is present:
parts shall be made of low-carbonor stabilized grades.
l . The yield strength and hardness restrictions above
Note: Overlays or hard surfaces that contain more than O. 10 percent carbon can sensitize both low-carbon and stabilized grades
of austenitic stainmay be modified in accordance withNACE MR0175.
less steel unless a buffer layer that is not sensitive to intergranular corrosion
2. The inner-casingparts of double-casing pumps, such
is applied.
as diffusers and bowls,
are not considered pressurecasing
2.11.1.6 Materials, casting factors, and the quality of any
parts.
welding shall be equalto those required by Section VIII, Di3. Renewable wear rings that must be hardened above
vision 1,of the ASME Code. The manufacturer’s data report
Rockwell C 22 for proper pump operationare acceptable.
forms, as specified in the code, are not required.
When approved bythe purchaser, in lieu of
furnishingrenewable wear rings, wear surfaces may be hardened by
2.1 1.1.7 When specified for pressure casing parts, imthe application of a suitable coating.
pellers, and shafts, the vendor shall furnish chemical and
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
2-22
API STANDARD c
l
iO
4. Wetted parts subject to welding, including fabrication
and tack welding (for example, removable wear rings),
shall be stress relieved, if required, so that both the welds
and the heat-affected zones meet the yield strength and
hardness requirements of this paragraph.
2.11.1.1 2 Low carbon steels can be notch sensitive and
susceptible to brittle fractureat ambient or low temperatures.
Therefore, only fully killed, normalized steels made to fine
grain practice are acceptable. The use of steel made to a
coarse austenitic grain size practice (such
as ASTM A5 15) is
prohibited.
2.11.2
CASTINGS
2.11 -2.1 Castings shall be sound and generally free from
porosity, hot tears, shrink holes, blow holes, cracks, scale,
blisters, and similar injurious defects. Surfaces of castings
shall be cleaned by sandblasting, shot blasting, chemical
cleaning, or any other standard methodto meet the visual requirements of MSS-SP-55. Mold parting fins and remains
of
gates and risers shall bechipped, filed, or ground flush.
2.11 -3.2 The vendor shallbe responsible for the reviewof
all repairs and repair welds to ensure they are properly heat
treated and nondestructively examined for soundness and
compliance with the applicable qualified procedures (see
2.11.1.6). Repair welds shall be nondestructively tested by
the same method usedto originally qualify the part.
2.11.3.3 Unless otherwise specified, all wdding other
than thatcovered by Section VIII, Division 1,of the ASME
Code and ANSIIASME B3 1.3, such as welding on baseplates, nonpressure ducting, lagging, and control panels,
shall be performedin accordance withANSVAWS D l. 1, or,
at the vendor’s option, in accordance withthe requirements
applied to the pressurecontaining parts of the pump.
2.1 1.3.4 Pressure containing casings made of wrought
materials or combinations of wrought and cast materials
shall conform to the conditions specified in 2.1 1.3.4.1
through 2.11.3.4.4. Theserequirements do not applyto casing nozzles andauxiliary connections (see 2.3.2 and 2.3.3).
2.11.3.4.1 Plate edges shall be inspected by magnetic particle or liquid penetrantexamination as required by Section
VIII, Division 1, UG-93(d)(3), of the ASME
Code.
2.11.2.2 The use of chaplets in pressure castings shall be
held to a minimum. The chaplets shall be clean and corrosion
free (plating permitted)
and of a composition compatible with
2.1 1.3.4.2 Accessible surfacesof welds shall be inspected
the casting. Chaplets shall
not be used in impeller castings.
by magnetic particle or liquid penetrant examination after
back chippingor gouging and again after postweld heat treat2.1 1.2.3 Ferrous pressure boundary andimpeller castings
after solution annealing.
shall not be repaired
by welding, peening, plugging, burning ment or, for austenitic stainless steels,
in, or impregnating, except as specified in 2.1 1.2.3.1 and
2.1 1.3.4.3 Pressure-containing welds, including welds of
2.11.2.3.2.
the case to horizontal and vertical
joint flanges, shall be fullfusion, full-penetration welds.
2.11.2.3.1 Weldable grades of steel castings maybe repaired by welding, using a qualified welding procedure
2.11.3.4.4 Fabricatedcasingsshall be postweld heat
based on the requirements of Section VIII, Division 1, and
treated inaccordance with the requirementsof Section VIII,
Section IX of the ASME Code. Weld repairs shall be inDivision 1 of the ASME Code. Where dimensionalstability
spected according to the same quality standard used to inof such a casing component must be assured
for the integrity
spect the casting.
of pump operation, then postweld heat treat shall be per2.11.2.3.2 Iron castings may be repaired by plugging
formed regardless of thickness.
within the limits of the applicable
IS0 (ASTM) specification.
2.1 1.3.5 Connections welded to pressure casings shall be
be carefully examined, using
The holes drilled for plugs shall
installed as specified in 2.11.3.5.1 through 2.11.3.5.6.
liquid penetrant,to ensure that all defective material has been
removed. All repairs that are not covered by I S 0 (ASTM)
2.1 1.3.5.1 Attachment of suction and discharge nozzles
specifications shallbe subject to the purchaser’s approval.
shall be by means of full-fusion, full-penetration welds.
Weld neck flanges are required for pumps handling
2.11.2.4 Fully enclosedcored voids, including voids
flammable or hazardous liquids. Dissimilar metal weldments
closed by plugging, are prohibited.
are not allowed.
o 2.11.2.5 When specified, casting repair procedures shall
2.11.3.5.2 Auxiliary piping welded to alloy steel casings
be submitted for purchaser’s approval
shall be of a material with the same nominal properties
as the
casing material or shall beof low carbonaustenitic stainless
2.11.3 WELDING
steel. Other materials compatible with the casing material
2.11.3.1 Welding of piping, pressure containing parts, and
and intended service may be used with the purchaser’s apwetted parts,as well as any weld repairsto such parts, shall
proval.
be performed and inspected by operators and procedures
2.11.3.5.3 When heat treatment is required, piping welds
qualified in accordance with Section VIII, Division 1, and
Section IX of the ASME Code.
shall be made before thecomponent is heat treated.
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
-
~
API S T D x b L O 95
CENTRIFUGAL
PUMPS
m 0732290 054bL45 759 m
PETROLEUM,
FOR
HEAWDUTY CHEMICAL,
AND
GASlNDUSTRY SERVICES
2-23
-
2.11.3.5.4 When specified, proposed connection designs
shall be submitted tothe purchaser for approval beforefabrication. The drawingshall show welddesigns, size, materials, and preweld and postweld heattreatments.
2.11.4.4 Governing thickness used to determine impact
testing requirements shall be the greater of the following:
a. The nominal thickness of the largest butt weldedjoint
b. The largest nominal section for pressure containment,ex;
cluding:
1 . Structural support sections such as feet or lugs.
2. Sections with increased thickness required for rigidity to mitigate shaft deflection.
3. Structural sections required for attachment or inclusion of mechanical features such as jackets or seal
chambers.
c. One fourthof the nominalflange thickness, including parting flange thitkness for axially split casings (in recognition
that the predominant flange stress
is not a membranestress).
2.1 1.3.5.5 All welds shall be heat treated in accordance
with the methods describedin Section VIII, Division 1,UW40, of the ASME Code.
2.11.3.5.6 Suction and discharge nozzle welds shallbe inspected in accordance with 2.11.3.4.2. The purchaser will
specify when the following additional inspection methods
are required:
a. Magnetic particle or liquid penetrant inspection of auxiliary connection welds.
b. Ultrasonicor radiographic inspection of any casing welds.
2.11.4 LOW TEMPERATURE
2.11.4.1 To avoid brittle fracture during operation, maintenance, transportation, erection, and testing, good design
practice shall be followed in the selection of fabrication
methods, welding procedures, and materials for vendor furnished steel pressureretaining parts that may besubjectedto
temperature belowthe ductile-brittle transition point.
2.11.4.2 All pressure retaining steels applied at a specified
minimum design metal temperature (2.11.4.5) below -30°C
(-20°F) require a Charpy V-notch impact test of the base
metal and the weld
joint unless theyare exempt in accordance
with the requirements of paragraph UHA-5
1 in Section VIII,
Division 1 of the ASME Code. Impact test results
shall meet
the requirements of paragraph UG-84
of the Code.
2.11.4.3 Carbon and low alloy steel pressure retaining
parts appliedat a specified minimum design metal temperature (2.11.4.5) between -30°C (-20°F) and 40°C (100°F)
shall require impact testing in accordance with 2.11.4.3.1
and 2.11.4.3.2.
2.11.4.3.1 Impact testing is not required for parts with
a governing thickness (2.1 1.4.4) of 25 mm (1 in.) or less.
2.1 1.4.3.2 Impact testing exemptionsfor parts with a governing thickness (2.11.4.4) greater than 25 mm (1 in.) shall
be established in accordance with paragraph UCS-66 in
Section VIII, Division 1 of the ASME Code. Curve B shall be
used for all carbon and low alloysteel materials (including
castings) which are not specifically listedfor curves A,C, or
D. Minimum design metal temperature without impacttesting may be reducedas shown in figure UCS-66. l . If the material is not exempt, Charpy V-notch impact test results
shall
meet the minimum impact energy requirements
of paragraph
UG-84 of the ASME Code.
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
O
2.11.4.5 The purchaser shall specify the minimum design metal temperature used to establish impact test requirements.
Note: Normally, this will be the lower of the minimum surrounding ambient temperature or minimum liquid pumping temperature. However, the
purchaser may specify a minimum design metal temperature based on
pumpage properties, such as autorefrigerationat reduced pressures.
2.12
NameplatesandRotation Arrows
2.1 2.1 A nameplate shall be securely attached at a readily
visible location on the equipment and on any other major
piece of auxiliary equipment.
2.12.2 The nameplate shall be stamped withthe following
information:
a. Purchaser's item number.
b. Vendor's size and model number.
c. Pump serial number.
d. Capacity, m3/h (GPM).
e. Pumping head, in meters (feet).
f. Casing hydrostatic test pressure, kPa (psig).
g. Speed, RPM.
h. Bearing manufacturer's identity numbers.
i. Maximum allowable workingpressure (MAWP).
j. Temperature, basis for MAWP, "C ("F).
2.1 2.3 In addition to being stampedon the nameplate, the
pumpserialnumber shall beplainly and permanently
marked on the pump casing.
2.12.4 Rotation arrows shall be cast in or attached to
each major item of rotating equipment at a readily visible
location.
2.12.5 Nameplates and rotation arrows (if attached) shall
be of austenitic stainless steel or of nickel-copper alloy
(Monel or its equivalent). Attachment pins shall be of the
same material. Weldingis not permitted.
A P I S T D t b L O 95
m
SECTION 3-ACCESSORIES
3.1
Drivers
0
o 3.1.1
The type of driver will be specified by the purchaser.
The driver shall be sizedto meet the maximum specifiedoperating conditions, including bearing, mechanical seal, exterrial gear,
and
coupling losses, as applicable, and shallinbe
accordance with the applicable specifications, as stated in the
inquiry specification,data sheets, and order.
The driver shall
be suitable for satisfactory operation under the utilitysiteand
conditions specified.
e 3.1.2 Anticipated process variations that may affect the
3.1.6 The motor’s starting torque requirements shall be
met at reduced voltages specified by the purchaser, andthe
motor shall accelerate to full speed within a period of time
agreed uponby the purchaser and the vendor.
most
Note:
For
the
is
8o percentOf
the normal voltage, and the time required
to accelerate to full speed is generally leSS than 15 seconds,
3.1.7 Rolling element bearings in the drive systems designed for radial or axial loads transmitted from the pump
shall meetthe following requirements:
a. Bearings shall be selected to give a basic rating life, LlOh,
in accordance with IS0 28 1 (ANSUABMA Standard 9), of
at least 25,000 hours with continuous operation at pump
rated conditions.
o 3.1.3 The starting conditionsfor the driven equipment will
b. Bearings shallbe selected to give a basic ratinglife, LlOh,
be specified, and the starting method shall be mutually
of at least 16,000 hours when carrying the maximum loads
agreed upon by the purchaser and the vendor. The driver’s
(radial or axial or both) imposed with internal pump clearstarting torque capabilities shall exceed the speed-torquereances at twice the design values and when operating at
quirements of the driven equipment.
any point between minimum continuous stable flow and
3.1.4 Motors shall have power ratings, including the serrated flow.
vice factor(if any), at least equal to the percentages
of power
c. For vertical motors and rightangle gears, the thrust bearat pump rated conditions given in Table 3-1. However,the
ing shall be inthe nondrive end and shall limit axialfloat to
power at rated conditions shall not exceedthe motor name125 pm (0.005 in.) .
plate rating. Whereit appears that this procedure will lead to d. Single- or double-row bearings shall be of the Conrad
unnecessary oversizing of the motor, an alternate proposal
type (no filling slots). Except for angular contact type, bearshall be submittedfor the purchaser’s approval.
ings shall have greater than Normalclearance according to
IS0 5753, Group 3 (ABMA Group 3, as defined in ABMA
o 3.1.5 The purchaser will specify the type of motor, its
Standard
20).
characteristics,and theaccessories, including the following:
e. Thrust bearings shall be designed to carry the maximum
a. Electrical characteristics.
thrust the pumpmay develop while starting, stopping,or opb. Starting conditions (including the expected voltage drop
erating at any capacity.
on starting). .
f. Hydrodynamic thrust bearings shall be selected at no
c. The type of enclosure.
more than50 percent of the bearing manufacturer’s rating at
d. The sound pressure level.
twice the pump internalclearances specified in 2.6.4.2.
e. The area classification, based on API Recommended
Note: Vertical motors 750 kW ( 1 0 0 0 hp) and larger that are equipped with
Practice 500.
less than 25,000 hour L l ~ life
h
spherical or taper roller bearings may require
to avoid skidding in normal operation.In such cases, the vendor shall state
f. The type of insulation.
the shorter design life in the proposal.
g. The required service factor.
h. The ambient temperature and elevationabove sea level.
3.1.8 Unless otherwisespecified, motors for vertical
i. Transmission losses.
pumps shall have solid shafts. When the pump thrust bearj. Temperature detectors, vibration sensors, and heaters if
ings are in, the motor, the motors shall meet the shaft and
these are required.
base tolerances shown inFigure 3- l .
k. Vibration acceptance criteria.
3.1.9 Unless otherwise specified, steam turbine drivers
1. Applicability of API Standard 541 or IEEE 841.
shall conformto IS0 10436 (API Standard 611). SteamturTable 3-1-Power Ratings for Motor Drives
bine drivers shall be sized to deliver continuously 110 percent of the maximum power required for the purchaser’s
Motor Nameplate Rating
Percentage of
specified conditions while operating at corresponding speed
Rated Pump Power
kW
with specified steamconditions.
sizing of the driver (such as changes in pressure, temperature, or properties of the liquid handled, as well as special
plant start-up conditions) will be specified.
hP
75
0732290 0 5 4 6 3 4 6 695
< 22
22-55
>55
30
30-75
125
115
3.1.1 O Unless otherwise specified, gears shall conform to
API Standard 677.
110
3-1
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
API STANOAAO
610
3-2
""
- - ".
"
"
I
A.
Shaft to driver mating face perpendicularity
and surface flatness:
B. Shaft to driver register maximum runout:
C. Maximum shaft runout with rotor rotating freely:
D. Maximum axial float:
25 pm (0.001 in.) T.I.R.
100 pm (0.004in.) T.I.R.
25 pm (0.001 in.) T.I.R.
125 pm (0.005in.) T.I.R.
Note: All measurements shall be taken withthe assembled driver in
the vertical position.
Figure 3-1-Vertically Suspended Pump Drivers: Tolerances Required
for the Driver Shaft and Base
3.1.11
For drive train components that weigh more than
450 kg (lo00 lbs), the equipmentfeet shall be provided with
vertical jackscrews.
3.1.12 The equipment feet shall be drilled with pilot holes
that are accessible for usein final doweling.
3.2
CouplingsandGuards
3.2.1 Unless otherwise specified, couplings and guards
between drivers and driven equipment shall be suppliedby
the vendor.
O
3.2.2 Unless otherwise specified, couplings shall be flexible element. Coupling hubs shall be steel. Flexible disk
types shall have disks of corrosion resistant material. The
make, model, materials, service factor, and mounting arrangement of couplings willbe specified by the purchaser.A
spacer coupling shall
be used unless otherwise specified. The
spacer shall have a nominal length of at least 125 mm
( 5 in.) and shall permit removal of the coupling, bearings,
seal, and rotor as applicable, without disturbing driver
the or
the suction and discharge piping.
Note: For flexible element couplings, consideration shouldbe given to designs that will retain the spacer if a flexible element ruptures.
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
3.2.3 Information on shafts, keyway dimensions (if any),
and shaft end movements due
to end play and thermal
effects
shall be furnished to the vendor supplying the coupling.
3.2.4 Flexible couplings shall be keyed to the shaft. Keys,
keyways, and fits shall conform toISOR773 (ANWAGMA
9002, Commercial Class). Flexible couplings with cylindrical
bores shall have the interference fit specified
in
ISOR286,
Tolerance N8, and shafting in accordance with ISOR775
(ANWAGMA 9002).Where servicing the mechanical seal
requires removal of the coupling hub, and the shaft diameter is
greater than 60 mm (2.5 in.), the hub shallbe mounted with a
taper fit. Taper for keyed couplings shall
be 1 in 1O "long series
conical" in accordance withISOR775 or alternately 1 in 16
(0.75 in./ft, diametral) for compliance with U.S. standards.
Other mounting methods shall
be agreed upon by the purchaser
and the vendor. Coupling hubs shall
be furnished with tapped
puller holes at least10 mm (3/s in.) in size to aid in removal.
Note: Appropriate assembly and maintenance procedures must be used to
assure that taperfit couplings have an interferencefit.
3.2.5 Couplings and coupling to shaft junctures shall be
rated for at least the maximum driver power, including any
service factor.
CENTRIFUGAL PUMPS FOR PETROLEUM.
HEAVYDUTY CHEMICAL,
3.2.6 Couplings shall be manufactured to meet the requirements of ANWAGMA 9000 Class 9.
3.2.7 Couplings operating at speeds of 3800 R€" or less
shall be component balanced. Each component such
as hubs,
be balsleeves, flexible elements, spacers, and adapters shall
anced individually. All machining of components, except
keyways of single keyed hubs, shall be completed before
balancing. Balancing shall be in accorgance with 2.8.4.l .
Two-plane balancingis preferred; however, single-plane balancing may be used in accordance with2.8.4.2.
3.2.8 Couplings operating at speeds in excess of 3800
RPM shall meet the requirements of API Standard 671 for
component balancing and assembled balance check.
3.2.9 Limited end float couplings with maximum coupling
end floats as specified in Table 3-2 shall be supplied with
horizontal sleeve bearing motors to prevent the motorrotor
from rubbing stationary motor parts.
Note: Couplings with axial elastic centering forces are usually satisfactory
without these precautions.
Table 3-2-Maximum Coupling
Minimum Motor Rotor
End Float
(mm)
(in.)
6
13
0.250
0.500
End Floats
Maximum Coupling
End Float
(mm)
(in.)
2
5
0.090
O. I90
3.2.1O On vertical pumps equipped with mechanical seals,
the coupling shall be a spacer type. The spacer shall be of
sufficient length to permit replacement
of the seal assembly,
including the sleeve, without removalof the driver.
3.2.11 When the vendor is not required to mount the
driver, he shall deliver the fully machined half coupling to
the driver manufacturer's plantor any other designated location, together with the necessary instructions for mounting
the half coupling on thedriver shaft.
3.2.12 Removable coupling guards shall be furnished
and shall be in accordance with requirements of applicable
national, industrial, or statutory bodies.
3.3 Baseplates
3.3.1 Single piece drain rim or drain pan baseplates shall
be furnished for horizontal pumps. The rim or pan of the
baseplate shallbe sloped at least1:120 toward the pumpend,
where a tapped drain openingat least 2 NPS shallbe located
to effect complete drainage.
3.3.2 Unless otherwise specified, the baseplate shall extend under the pump and
drive train components so that any
leakage is contained within the baseplate.
To minimize accidental bumping and damage to components, all pipe joints
and pipe flangefaces, including pump suction and discharge
flanges shall be within thedrain pan or drain rim collection
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
AND
GASINDUSTRY SERVICES
3-3
area. All other projections of the equipment supplied shall
fall within the maximum perimeter of thebaseplate. Oversized junction boxes may overhang the perimeter of the
baseplate with thepurchaser's approval.
3.3.3 Mounting pads shall be provided for the pump and
all drive train components.The pads shallbe larger thanthe
foot of the mounted equipment
to allow levelingof the baseplate without removal of the equipment. The pads shall be
fully machined flat and parallel. Corresponding surfaces
shall be in the same plane within 150 p d m (0.002 in./ft) of
distance between the pads.This requirement shallbe met by
supporting and clamping the baseplate
at the foundation bolt
holes only.
3.3.4 All pads for drive train components shall be machined to allow for the installation of shims at least 3 mm
(0.12in.) thick under each component. When the vendor
mounts the components,
a set of stainless steel shimsat least
3 mm (O. 12 in.) thick shall be furnished. When the vendor
does not mount the components, the pads shall not be drilled,
andshims shall not beprovided.
3.3.5 To minimize misalignment of the pump and driver
shafts due to piping loadeffects, the pump and its baseplate
shall be constructed with sufficient structural stiffness to limit
displacement of the pump shaft at the drive ofend
the shaftor
at the registerfit of the coupling hubto the values shownin
Table 3-3 during a test in accordance with 3.3.6. Grout or
bearing housing supports (wobble plates) shall be
notused as
a means of obtaining the required stiffness. (It is recognized
that grout can significantly increase the stiffness
of the baseplate assembly;by neglecting this effect, the adequacy
of the
baseplate can easilybe verified at the vendor's shop.)
3.3.6 When specified, the vendor shall testto demonstrate
that the pump and its baseplate assembly, when anchored
at
foundation bolt hole locations with any bearing housing
sup
port disconnected, are in compliance with 3.3.5. The pump
casing shall be subjected to moments MYc and MZc applied
to either nozzle, but not both, such that the corresponding
shaft displacements can
be measured and recorded.
MYc and
Table 3-3-Stiff ness Test Acceptance Criteria
Pump Shaft Displacement
Baseplate Intended
for Grouting
Loading
Condition
~
in.
MY,
175
0.007
0.005
MZC
75
0.003
Baseplate Not
Intended for Grouting
um
in.
125
50
0.002
Direction
+Z
-Y
Note: MY, and MZ, equal the sum of the allowable suctionand discharge
2.1A (2.1B):
nozzle moments from Table
MY, = (MY)suction+ (MY)discharge
MZ, = (MZ)suction+ (MZ)discharge
-
API STDJbLO 95
3-4
m 0732290 0546347
3T4
m
API STANDARD
610
MZc shall not be applied simultaneously.
The shaft displacement measurements shall be absolute (not relative to the
baseplate). For recordpurposes, the vendor’s testdata shall
include a schematic drawingof test setup, the calculated moment loads (MYc and M&-),and the applied moment loads
and their corresponding displacements at drive
the end of the
pump shaft.
3.3.7 Theunderside of fabricatedbaseplates,beneath
pump and driver supports shall bewelded to reinforcing
cross members, and the members shall be shaped to lock
positively into the grout. All welding shall be continuous.
Stitch welding, topor bottom, is unacceptable.
3.3.15 Vertical leveling screws spaced for stability shall be
provided on the outside perimeter of the baseplate. They
shall be locatedadjacent to anchor bolts to minimize distortion during the processof installation. These screws shall be
numerous enoughto carry the weight
of the baseplate, pump;
and drive train components without excessive deflection, but
in no case shall fewer than six screws be
provided.
3.3.8 In addition to the requirements of 3.3.7, anchor
studs, such as “J” hooks, shall be welded to the underside of
baseplate decks on maximum 300 mm (12 in.) centers to
provide additional locking into the grout.
3.3.9 All baseplates shall be provided with at least one
grout hole having a clear area of at least 125 cm* (19 in.*)
and no dimension less than 75 mm (3 in.) in each bulkhead
section. These holes shall be located to permit filling the
entire cavity under the baseplate without creating air pockets. Where practical, the holesshall be accessible for grouting with the pump and driver installedon the baseplate.
Grout holes in the drip pan area shall have 13 mm (0.5 in.)
raised lip edges. If the holes are located in an area where
liquids could impinge on the exposed
grout, metallic covers
with a minimum thickness of 1.5 mm (16 gauge) shall be
provided. Vent holes at least 13 mm (0.5 in.) in diameter
shall be provided at the highest point in each bulkhead section of the baseplate. (Appendix L provides guidelines for
grouting.)
provided for drive train components weighing more than
400 kg (900 lbs.) to facilitate longitudinal adjustments. The
lugs holding these positioning screws shall be attached to
the baseplate so that the lugs do not interfere with the installation or removal of the component. These screws shall
be at least the same size as the vertical jackscrews furnished with each component. To prevent distortion, machining of mounting pads shall be deferred until welding
on the baseplate in close proximity to the mounting pads
has been completed.
3.3.16 The height of the pump shaft centerline above the
baseplate shall be minimized. Adequate clearance shall be
provided betweenthe casing drain connection and the baseplate so that drain piping the same size
as the connection can
be installed withoutthe use of a street (male-female)elbow.
3.3.17 Unless otherwise specified, the vendor shall commercially sand blast, in accordance with
SSPC SP 6, all grout
contact surfacesof the baseplate, and coat those surfaces with
inorganic zinc silicate in preparation
for epoxy grouting.
O
3.3.1 8 Baseplates which are specified to be installed with
cementitious grout shall have grout contact
surfaces left free
of paint and primer in
order to promote maximum grout adhesion.
3.3.1 O The outside corners of the baseplate in contact
with the grout shall have at least 50 mm (2 in.) radii in the
plan view (see Figure M- 1, Appendix M).
3.3.19 The baseplate shallbe provided with lifting lugs for
at least a four-point lift. Lifting the baseplate,complete with
all equipment mounted, shall not permanently
distort or otherwise damage the baseplate or the machinery mounted
on it.
3.3.11 The bottomof the baseplate between structural members shallbe open. When the baseplate is installed on
a concrete foundation, accessibility shall be provided for grouting
under all load carrying members. The bottom
of the baseplate
shall be in one plane
to permit use ofa single level foundation.
3.3.20 Anchor bolts will be furnished by the purchaser.
The vendor shall provide for sufficient anchor bolting to
withstand nozzle reaction forces during pump start-up and
operation.
3.3.12 When driver and pump size permits, baseplates
shall have standardizeddimensions as given in AppendixM
and shall be designed
for grouting. These baseplates shall
be
referred to as “API Standard610 Standard Baseplates, Numbers 0.5-12.”
3.4
3.3.1 3 When specified,the baseplate and pedestal support
assembly shall be sufficiently rigid to be mounted without
grouting.
3.3.1 4 Transverse alignment positioning jackscrews shall
be provided for drive train components weighing more than
200 kg (450 lbs) to facilitate transverse horizontal adjustments. Axial alignment positioning jackscrews shall be
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
Instrumentation
3.4.1
TEMPERATURE
GAUGES
3.4.1.1 Dial-type temperature gauges shall meet the following requirements:
a. Heavy duty, corrosion resistant construction.
b. Bimetallic or liquid filled element.
c. 100 mm (4.5 in.) or greater diameter dial.
d. Black printing on white background.
3.4.1.2 The sensing elements of temperature gauges shall
be in theflowing liquid.
Note: This is particularly important for lines that may run partially full.
CENTRIFUGAL PUMPS FOR PETROLEUM,
HEAVY
DUTY CHEMICAL, AND GASINDUSTRY SERVICES
3.4.1.3 Temperature gauges shall be furnished with separable threaded solid bar thermowells
at least 3/4 N P S in diameter and shall be of austenitic stainless steel or another
material morecompatible with the liquid.
3.4.2PRESSUREGAUGES
3.4.2.1 Pressure gauges shall meet the following requirements:
a. Austenitic stainless steel bourdon tubes and movements.
b. 100 mm (4.5 in.) dials for pressures up to 5.5 MPa
(800 psi).
c. 160 mm (6 in.) dials for pressures of 5.5 MPa (800 psi)
or greater.
d. W S male alloy steelconnections.
e. Black printing on white background dials.
f. Normal operating pressure within 50 to 70 percent of
the rangeof the gauge.
g. The maximum reading on the dial shall be less than the
applicable relief valvesetting plus 10 percent.
h. Provided with a device, such as a disk insert or blowout
back, designedto relieve pressure.
'h
a 3.4.2.2
When specified, liquid filled gauges shall be furnished in locations subject to vibration.
3.4.3VIBRATION,POSITION,AND
TEMPERATURE DETECTORS
o 3.4.3.1 When specified for equipment with hydrodynamic
bearings, provision shall be made for mounting two radial
vibration probesin each bearing housing, two axial position
probes at the thrust end
of each machine, and
a one event per
revolution probe in each machine. The purchaser will specify whether the vendor is to supply thesedetectors. The detectors and their mounting and calibration shallsupplied,
be
installed, and testedin accordance with API Standard670.
3-5
c. Cooling water.
d. Lubricating oil.
Auxiliary systems shall comply with the requirements of
Table 3-4.
Note: Casing connections are discussed in 2.3.2.
3.5.1.2 Piping systems shall include piping, pipe fittings,
isolating valves, control valves, relief valves, pressure reducers, orifices, temperature gauges and thermowells, pressure
gauges, sight flow indicators, and related vents and
drains as
shown in the appropriate plan in Appendix D.
3.5.1.3 Unless otherwise specified, the piping systems
shall be fully assembled andinstalled.
3.5.1.4 When specified, for Plans 52 and 53 (see Appendix D), barrierhuffer fluid reservoirs shall be designed
for mounting off the pump baseplate and shall be shipped
separately. These reservoirs shall be fully assembled except
that the fluid circulation tubing shall not be supplied.
3.5.1.5 The vendor shall furnish all piping systems, including mounted appurtenances,located within theconfines
of the baseplate.
3.5.1.6 The design of piping systems shall achieve the following:
a. Proper support and protection
to prevent damage fromvibration or from shipment, operation, and maintenance.
b. Proper flexibility and normalaccessibility for operation,
maintenance, and thoroughcleaning.
c. Installation in a neat and orderly arrangement adapted to
the contour of the machinewithout obstructing access.
d. Elimination of air pockets by piping configuration or by
provision of vents at high points.
e. Complete drainage through low points without disassembly of piping.
o 3.4.3.2 When specified, hydrodynamic thrust and radial
f. Manifolding ofeach piping systemto a single purchaser's
bearings shall be fitted with bearing metal temperature detec- inlet or outlet connection at the edge of the baseplate.
tors. When pressure lubricated hydrodynamic thrust and radial g. Nipples threaded into gland ainsocket welded piping plan
bearings are supplied with temperature detectors, the detectorsshall terminate witha flange or union (see 3.5.2.10.1)at the
and their mounting and calibration shall be supplied, installed, first piping joint with no elbow between gland and flange.
and tested in accordance with
N I Standard 670.
3.5.1.7 Piping design, materials,joint fabrication, examinao 3.4.3.3 When specified, monitors with connecting cables
tion, and inspection shall
be in accordance with ANSYASMF!
to vibration, axial position, or temperature detectors shall
B3 1.3.
be supplied and/or installed in accordance with API Stan3.5.1.8 During assembly of the system before testing,
dard 670.
each component (including cast-in passagesthese
of components) and all piping and appurtenances shall be cleaned
3.5 PipingandAppurtenances
chemically or by another appropriate method to remove for3.5.1
GENERAL
eign materials, corrosion products, and mill
scale.
3.5.1.1 Auxiliary systems are defined as piping systems
3.5.1.9 Piping shall preferably be fabricated by bending
that are in the following services:
and welding to minimize the use of flanges and fittings.
Welded flanges are permitted only at equipment conneca. Auxiliary process fluids.
tions, at the edge of anybase, and for ease of maintenance.
b. Steam.
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
-
API S T D J b l O 95 m 0732290 05Ybl5l T52 m
API STANDARD
610
3-6
d
2O
8
'c)
P
3
v)
I
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
~
~~
API S T D * b L O 95
0732270 0546352 799
CENTRIFUGAL PUMPS FOR PETROLEUM, HEAVY
The use offlanges at other points is permitted only withthe
purchaser's specific approval. Except for lubricating systems, threaded or slip-on flanges are not acceptable. Other
than tees and reducers, welded fittings are permitted onlyto
facilitate pipe layoutin congested areas. Threaded connections shall be held to a minimum. Pipe bushings shall not
be used.
3.5.1.I O Pipe threads shall be taper threads in accordance
with ANSVASME B 1.20.l. Pipe threads in accordance with
IS0 228 Part 1 are an acceptable alternative when required
for
compliance with local standards. Flanges shall
be in accordance
with IS0 7005 (ANSVASME B16.5). Slip-on flanges are permitted only with the purchaser's specific approval. For socket
welded construction,a 1.5 mm (0.06 in.) gap shall be left between the pipe end and the bottom of the socket (2.3.3.3).
3.5.1 .I1 The minimum size of any connection or piping
shall be
'/2
NPS.
3.5.1.12 Connections, piping, valves, and fittings that are
1'/4, 2'/2, 3'h, 5,7, and 9 NPS shall not be used.
3.5.1.13 The bolting requirementsof 2.2.12 and 2.1l. l.10
apply to auxiliary piping.
3.5.1.14 Taper threaded plugs shall be (long shank) solid
round
head
bar
stock
plugs
in accordance
with
ANSI/ASME B 16.11 (2.3.3.7). When cylindrical threads
are specified in 2.3.3.3, plugs shall be solid hexagon head
plugs in accordance with DIN910. These plugs shall meet
the material requirements of the casing. Threads shall be
lubricated. Plastic plugs are not permitted. (See 2.7.3.15 for
plugs in seal glands.)
3.5.2 AUXILIARYPROCESSFLUIDPIPING
3.5.2.1 Auxiliary process fluid piping includes vent and
drain lines, balance lines, product flushing lines, and lines
for injection of external fluid.
3.5.2.2 The arrangement ofauxiliary process fluid piping
shall conform to Figures D-2 and D-3.
DUTYCHEMICAL. AND GASINDUSTRY SERVICES
3-7
3.5.2.6 The purchaser will specify when chloridesare present in a concentration above 10 parts per million. Caution
should then be used when applying
stainless steel.
3.5.2.7 Orifice openings shall not be less than 3 mm
(O. 12 in.) in diameter.
3.5.2.8 Unless valves are specified, threaded vent and
drain connections shall be plugged. Carbonsteel plugs shall
be used withcast iron casings.
3.5.2.9 When heating or cooling is provided, each exchanger component shallbe suitable for the process fluid and
cooling waterto which it is exposed.
3.5.2.10 In addition to the requirements of 3.5.2.1 through
3.S.2.9, the requirements specified in 3.5.2.10.1 through
3.5.2.10.3 apply to piping containing flammable orhazardous fluids.
3.5.2.1 0.1The purchaser will specify whetherflanges are
required in place of socket-welded unions. Threaded connections are permitted at mechanical seal glands.
3.5.2.10.2 For primary IS0 (ANSI) service pressure ratings above PN150 (Class 900), block valves may be of
welded-bonnet or no-bonnet construction with a bolted gland;
these valves shall be suitablefor repacking underpressure.
3.5.2.1
0.3Pressure gauges shall have block and bleed valves.
3.5.3 STEAMPIPING
Threaded joints are permitted oncast iron equipment and
instruments.
3.5.4 COOLINGWATERPIPING
3.5.4.1 The arrangement of cooling water piping shall
conform to Figures D-4 andD-5.
3.5.4.2 The cooling water piping shall be designed as
specified in 2.1.20.
3.5.4.3 Sight flow indicators shall be furnished in each
outlet line.
3.5.4.4 Unless otherwise specified, manifold inlet and out-
3.5.2.3 Piping components shall have a pressure-temper-
let valves shall befurnished.
ature ratingat least equal to the maximum discharge pressure
and temperatureof the pump casing, but in no caseless than
IS0 7005 PN50 (300 pound ANSI Class) flange at ambient
temperature (2.2.2)
3.5.5 LUBRICATINGOILPIPING
3.5.5.1 Oil drains shall be sized to run no more than half
3.5.2.5 All piping components furnished by the vendor
full and shall be arranged to ensure good drainage (recognizing the possibility of foaming conditions). Horizontal runs
shall slope continuously, at least 150, toward the reservoir.
If possible, laterals (notmore than one in any transverse
plane) should enter drain headers at 45-degreeangles in the
direction of flow.
that are shown in Figure D-2 and Figure0-3, Plans 52-54,
are considered subject to the processfluid.
turn line.
3.5.2.4 When the pump casing is of alloy material, piping
and components subjectto the process fluid shall have a corrosion/erosion resistance equal to or better than that of the
casing. Otherwise, all components shall be steel.
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
3.5.5.2 Sight flow indicators shall be furnished in each re-
API STD*bLO 95 9 0732290 05YbL53 825 9
3-8
API STANDARD
610
3.5.5.3 Piping and tubing shall be cleaned with a suitable
solvent. Cleaning shall be performed by the vendor before
assembly withthe pump.
3.5.5.4 Any portion of the pressure lubrication systems
furnished shall meet the cleanliness requirements of API
Standard 614.
3.5.5.5 Nonconsumable backup rings and sleeve type
joints shall not be used. Pressure piping downstream of oil
filters shall be free from internal obstructions
or pockets that
could accumulate dirt. Pipejoints downstream of the oil filter (filter to bearing housing) shall be butt welded. Piping
joints in return lines and upstreamof the filter (reservoir to
filter) may be socket welded. Threaded
connections shall be
used for instrument connections and where tubingis used.
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
3.6 Special Tools
3.6.1 When special tools and fixtures are required to disassemble, assemble, or maintain the unit, they shall be included in the quotation and furnished as part of the initial
supply ofthe machine. For multiple unit
installations,the requirements for quantities of special tools and fixtures shall
be mutually agreed upon by the purchaser and the vendor.
These or similar special tools shall be used during shop assembly and post-test disassembly the
of equipment.
3.6.2 When special tools are provided, they shall be packaged in separate, rugged metal boxes and marked “special
tools for (taditem number).” Each tool shallbe stamped or
tagged to indicate its intended use.
-
~~
A P I STD+b10 95
0732290 054bl154 7 6 1
SECTION GINSPECTION, TESTING, AND PREPARATIONFOR SHIPMENT
General
documented
of Results
4.1.1 After advance notification of the vendor by thepurchaser, the purchaser’s representative shall have entry to all
vendor and subvendor plants where manufacturing, testing,
or inspection of the equipment is in
progress.
0
d.
inspections.
tests and
e. Final assembly maintenance and running clearances.
4 - 1 2 The vendor shall notify subvendors of the Purchaser’s inspection andtesting requirements.
a. Parts that shall be subjected to surface and subsurface examination.
b. The type of examination required, such
as magnetic Particle, liquidFnetrm4 dographic, and ultrasOniCeX-natiOn-
4.1
4.1.3 The vendor shall provide sufficient advance notice
to the purchaser before conducting any inspection
or test that
the purchaser has specified to be witnessed or observed.
4.2.2MATERIALINSPECTION
o 4.1.4
The purchaser will specify the extent of his participation inthe inspection and testing and the amount of advance notificationreauired.
4.2.2,~ G~~~~~~
4.1.4.1 When shop inspection and testing have been specified the purchaser
and the vendor shall coordinate manufacturing hold points and inspector’s visits.
4.1.4.2 Witnessed means that a hold shallbe applied to the
production schedule and that the inspection or test shall be
carried out with the purchaser or his representative in attendance. For mechanical running
or performance tests, written
notification of a successful preliminary test
is required.
4.2.2.2
Radiography
4.2.2.2.1 Radiography shallbe in accordance with ASTM
E94 and ASTM E142.
4.1.5 Equipment for the specified inspection and tests
shall be providedby the vendor.
4.2.2.2.2 The acceptance standard used for welded fabrications shall be Section VIII, Division 1, W - 5 1 (100 percent)
and W - 5 2 (spot), of the ASME Code.The acceptance standard used for castings shall be Section VIII, Division 1,
Appendix 7, of the ASME Code.
4.1.6 When specified, the purchaser’s representative shall
indicate compliance in accordance with the inspector’s
checklist (Appendix N) by initialing, dating, and submitting
the completedchecklist to the purchaser before shipment.
4.2.2.3UltrasonicInspection
4.1.7 The purchaser’s representative shall have access to
the vendor’s quality programfor review.
4.2
4.2.2.3.1 Ultrasonic inspection shall be in accordance
with Section V, Articles 5 and 23, of the ASME Code.
Inspection
4.2.2.3.2 The acceptance standard used for welded fabrications shall be Section VIII, Division 1, Appendix 12, of the
ASME Code.The acceptance standard used
for castings shall
be Section vIII, Division Appendix 7, of the ASME code,
4.2.1
GENERAL
4.2.1.1 The vendorshallkeep the following data available
for at least 20 years for examination by the purchaser
or his
representative upon request:
4.2.2.4Magnetic
- ParticleInspection
a. Necessary certification of materials, such as mill test reports.
b. Purchasing soecifications for all items on of
bills
material.
c. Test data to verify that the requirements of the specification have been met.
4.2.2.4.1 Both wet and dry methods of magnetic particle
inspection shallbe in accordance with ASTM E709.
4.2.2.4.2 The acceptance standardused for welded fabrications shallbe Section VIII, Division 1, Appendix 6, and Sec-
”
4-1
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
When radiographic, ultrasonic, magnetic particle,
or liquid
penetrant inspection of welds or materials is required or
specified, the criteria in 4.2.2.2through 4.2.2.5 shall apply
unless othercriteria are specified by the purchaser.Cast iron
may be inspected in accordance with 4.2.2.4 and 4.2.2.5.
Welds, cast steel, and wrought material may be inspected
in
accordance with4.2.2.2through 4.2.2.5
Note: Regardless of the generalized limits in 4.2.2,it shall be the vendor’s
responsibility to review the design limitsof the equipment in theevent that
more stringent requirementsare necessary. Defects that exceed the limits
as deimposed in 4.2.2 shall be removed to meet the quality standards cited
fined by the inspection method specified.
4.1.4.3 Observed means that the purchaser shall be notified of the timing of the inspectionor test; however, the inspection or test shall be performed as scheduled, and if the
purchaser or his representative is not present, the vendor
shall proceedto the next step.(The purchaser should expect
to be in thefactory longer than for a witnessed test.)
0
4.2.1.2 Pressure containing parts shall not be painted until
the specified inspection of the parts is completed.
4.2.1.3 The purchaser
may
specify
the
following:
A P I STD*bLO 95
m
0732290
API STANDARD
61O
4-2
Table 4-2-Performance Tolerances
tion V, Article 25, of the ASME Code. The acceptability of defects in castings shallbe based on a comparison with the photographs in ASTM E125 For each typeof defect, the degree
(percent)
(percent)
of severity shall not exceed the limit specified
Tablein4- 1.
Shutoff
Point
Rated
Condition
Rated differential head
0-150 m (0-500 ft)
Liquid Penetrant Inspection
4.2.2.5
151-300 m (50l-lo00 ft)
4.2.2.5.1 Liquid penetrant inspection shall be in accordance with Section V, Article 6, of the ASME Code.
4.2.2.5.2 The acceptance standard used for welded fabripower
cations shall be Section VIII, Division l, Appendix 8,NPSH
and
Section V, Article 24, of the ASME Code. The acceptance
standard used for castings shall be Section VIII, Division 1,
Appendix 7, of theASME Code.
4.2.3MECHANICALINSPECTION
4.2.3.1 When specified, the purchaser may inspect for
cleanliness the equipment and all piping andappurtenances
furnished by or through the vendor before assembly.
4.2.3.2 When Specified, the hardness of parts, welds, and
heat-affected zones shallbe verified as being within the allowable values by testing. The method, extent, documentation, and witnessingof the testing shall be mutually agreed
upon by thepurchaser and the vendor.
4.3
Testing
4.3.1
GENERAL
in
4.3.1.1 Performance and NPSH tests shall be conducted
accordance with the Hydraulic Institute Standards except
that efficiency shall be for information only and not rating
(see Table 4-2).
4.3.1.2 When specified, at least 6 weeks before the first
scheduled running test, the vendor shall submit to the purchaser, for his review and comment,detailed procedures for
all running tests and all specified optional tests (4.3.4), including acceptance criteria for all monitored parameters.
4.3.1.3 The vendor shall notify the purchaser not
less than
5 working days before the date the equipment willbe ready
for testing. If the testing is rescheduled, the vendor shall notify the purchaser not less than 5 working days before the
new test date.
Table 4-1”Maximum Severity of Defects in Castings
Maximum
Level
W
I
II
III
IV
V
VI
Severity
Defect
Linear discontinuities
Shrinkage
Inclusions
chaplets
Chills and
Porosity
Welds
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
-2
+5
1
2
2
1
1
1
Over 300 m (lo00 ft)
Rated
Rated
-2
+3
-2
+2
+4b
+O
+10
-10a
+S
-88
+5
-5a
Note: Efficiency is not a rating value.
If a rising head capacity curve
is specified (see 2.1.ll),the negative
tolerance specified here shallbe allowed only ifthe test curve still shows
a rising characteristic.
b Under any combinationof the above. (Cumulative tolerancesare not
acceptable.)
a
4.3.1.4 Unless otherwise specified, mechanicalseals shall
not be used during the hydrostatic test but shall be
durused
ing all running or performance tests.
4.3.2 HYDROSTATIC TEST
4.3.2.1 All pressure casing components (including seal
glands and seal chambers) as defined in 1.4.40 shall be hydrostatically tested with liquid
at a minimumof 1.5 times the
maximum allowable working pressure, with special
the
provisions specified below:
a. Double-casing pumps, horizontal multistage pumps (as
described in 2.2.4), and other special design pumps as approved by the purchaser may be segmentally tested at 1.5
times the section maximumallowable working pressure.
b. Auxiliary process fluid piping (as described3.5.2.1
in and
3.5.2.5),if fabricated by welding, shall be tested
at 1.5times
the maximum allowable working pressure or section maximum allow’ableworking pressure as applicable in the preceding item a.
c. Cooling passages and components, including jackets
for bearings, seal chambers, oil coolers, and seal coolers,
shall be tested at a minimum pressure of 975 kPa gauge
(150 psig).
d. Steam, cooling water and lubricating oil piping,
when fabricated by welding, shallbe tested at 1.5 times maximum operating pressure or 975 Wa (150 psig) whicheveris greater.
e. The test liquid shall
be at a higher temperature than the nilductility transition temperature
of the material being tested.
f. Gaskets used during hydrostatic testing of an assembled
pressure casing, less seal glands, shall beof the same design
as those to be supplied with the pump.
4.3.2.2 If the part tested is to operate at a temperature at
which the strength of a materialis below the strength of that
material at room temperature, the hydrostatic test pressure
shall be multiplied by a factor obtained by dividing the al-
A P I STD*bLO
95 9 0732290 05qbL5b 5 3 4
CENTRIFUGAL PUMPS FOR PETROLEUM,
m
HEAWDUTY CHEMICAL, AND GASINDUSTRY
SERVICES
lowable workingstress for the material at room temperature
by thatat operating temperature.The stress values used shall
conform to those given ANSVASME
in
B3 1.3 for piping or
in Section II of the ASME Code.
The pressure thus obtained
shall be the minimum pressureat which the hydfostatic test
is performed.The data sheets shalllist actual hydrostatic test
pressures.
4.3.2.3 Thechloridecontent
of liquids used to test
austenitic stainless steel materials shall not exceed 50 parts
per million.To prevent deposition of chlorides as a result of
evaporative drying, all residual liquid shall
be removed from
tested partsat the conclusion of the test.
4.3.2.4 Tests shallbe maintained for a sufficient periodof
of parts under pressure.
time to permit complete examination
The hydrostatic test shall be considered satisfactory when
neither leaks nor seepage through the casingor casing joint
is observed for at least 30 minutes. Large, heavy castings may require a longer testing periodto be agreed upon by the
purchaser and the vendor.
Seepage past internal closures required for testing of segmented cases and operationof a test
pump to maintain pressureare acceptable.
4-3
4.3.3.1.1 Unless otherwise specified, the contract
seals and
bearings shall beused in the pump forthe performance test.
4.3.3.1.2 When specified or approved by the purchaser,
substitute seals may be used during the performance test if
needed to prevent damageto the contract seals or if the contract seals are not compatible with the test fluid.
4.3.3.1.3 The acceptable level of seal leakage during testthe purchaser, vendor,
ing shallbe mutually agreed upon by
and seal manufacturer prior to testing.
Note: When the pump is on the test stand and water is used as the test
fluid, seal leakage does
not necessarily indicate seal performance under the
such as test fluid, pressure, temperspecified operating conditions. Factors
ature, and system cleanliness havean appreciableeffect on seal leakage.
4.3.3.1.4 All lubricating oil pressures, viscosities, and
temperatures shall be within the range of operating values
recommended in the vendor’soperating instructions for the
specified unit being tested. For pressure lubrication systems,
oil flow rates for each bearinghousing shall be determined.
4.3.3.1.5 Bearings specified to be normally lubricated
from a pure oil mist system shall be prelubricated prior to
performance testing using suitable
a
hydrocarbon oil.
4.3.2.5 When Specified, the hydrostatic test liquid shall include a wetting agentto reduce surface tension.
This wetting
agent shouldbe considered when one or more ofthe following conditions exists:
4.3.3.1.6 All joints and connections shall be checked for
tightness, and anyleaks shall be corrected.
whichever isless.
Note: In the case of high-energy pumps (see 2.1.15), and multistage
pumps, it may not befeasible to testat shutoff.
4.3.3.1.7 All warning, protective, and control devices
used during the test shall be checked for proper operation,
a. The liquid pumped has a relative density (specific gravity) and adjustments shall be made as required.
of less than 0.7 at the pumping temperature.
4.3.3.2 Unless otherwise specified, the performance test
b. The pumping temperature is higher than260°C (500OF).
shall be conducted as specified in4.3.3.2.1though 4.3.3.2.4.
c. The casing is cast from a new or altered pattern.
d. The materials are known to have poor castability.
4.3.3.2.1 The vendor shall take test data, including head,
capacity, power, and
vibration, at a minimumof five points.
4.3.2.6 Austenitic or duplex stainless steel pressure casing
These
points
will
normally
be (a) shutoff (no vibration data
componentsrnay be hydrostatically tested with
an additional
required),
(b)
minimum
continuous
stable flow, (c) midway
amount of material on areas where machiningto critical dibetween
minimum
and
rated
flow,
(d) rated flow, and (e)
mensions and tolerances is required. The additional amount
maximum
allowable
flow
(as
a
minimum,
120 percent of
of material shall not exceed1 mm (0.040 in.) material stock
BEP).
or 5 percent of minimum allowable wall thickness,
Any areas which are machined after hydrostatic testing
shall be identified on the hydrotest report.
Note: Because of residual stresses resulting from final liquid quenching
and relatively low proportional limits inherent in these materials, small
amounts of permanent deformation may occur at critical dimensions during
hydrostatic testing. By allowing a small amount of material to remain at
these critical areas during hydrostatic testing, the need to add material by
welding torestore close toleranced dimensions after hydrotest
is avoided.
4.3.3.2.2 All running tests and mechanical checks shall
be
completed bythe vendor beforethe purchaser’s inspection.
4.3.3.2.3 Unless otherwise mutually agreed upon, the test
speed shqllbe within 3 percent of the rated speed shownon
the pump data sheet (see AppendixB). Test results shallbe
converted to anticipated results at the rated speed.
4.3.3 PERFORMANCE TEST
Unless otherwise specified, each pump shall be given a performance test on water at a temperature less than 65OC
(150°F) in accordance with 4.3.3.1through 4.3.3.4.
4.3.3.2.4 The vendor shall maintain a complete, detailed
log of all final tests and shall prepare
the required numberof
copies, certified for correctness. Data shall include test
curves and a summary
of test performance data compared to
guarantee points (see6.2.4,6.3.3.2,and Appendix T).
4.3.3.1 The requirements of 4.3.3.l . 1 through 4.3.3.1.7
shall be met before the performance test
is performed.
4.3.3.3 During the performance test, the requirements of
4.3.3.3.1 through 4.3.3.3.3shall be met.
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
-
~
0732290 0 5 4 b L 5 7 470
A P I STD+bLO 95
4-4
API STANDARD
610
4.3.3.3.1 Vibration values shall be recorded during the
test in accordance with
2.8.3.2.Vibration values shall not exceed those given in 2.8.3.7 and 2.8.3.8. When U.S. dimensions are specified, True Peak bearing housing velocities
shall also be recorded.
4.3.4.1.2 A 3 percent drop in head (first stage head on
multistage pumps) shall be interpreted as indicating performance impairment. The first stage head of pumps with two
or more stages shallbe measured using a separate connection
to the first stage discharge whenever possible.If this is not
feasible, testing of the first stage only should be considered.
4.3.3.3.2 Pumps shall operate within bearing temperature
limits as defined in paragraph 2.9.2.3 and shall not display
signs of unfavorable operation, such as noise caused by cavitation.
4.3.4.1.3 NPSHR at the rated point shall not exceed the
quoted value (see Table
4-2). Dismantling to correct NPSHR
requires a retest (see4.3.3.4.2).
4.3.3.3.3 When operated at rated speed, pumps shall perform within the tolerances given in Table4-2.
4.3.4.2
The pump and driver train, complete with all auxiliaries
that make up the unit, shall be tested together. Whenspecified, torsional vibration measurementsshall be madeto verify the vendor’s analysis. The complete unit test shall be
performed in placeof or in addition to separate tests of individual components specified by the purchaser.
4.3.3.4 Unless otherwise specified, the requirements of
4.3.3.4.1 through 4.3.3.4.3 shall be met after the performance testis completed.
4.3.3.4.1 If it is necessary to dismantle a pump after the
performance testfor the sole purpose of machining impellers
to meet the tolerancesfor differential head, no retest will be
required unless the reduction in
diameter exceeds 5 percent
of the original diameter. The diameter of the impeller at the
time of shop test, as well as the final diameter of the impeller, shall be recorded on a certified shop test curve that
shows the operating characteristics after the diameter of the
impeller has been reduced.
4.3.4.3SoundLevelTest
Sound level tests shall be performed as agreed between
the purchaser and the vendor.
Note: IS0 Standards 3740,3744, and 3746 may be consulted for guidance.
4.3.4.4AuxiliaryEquipmentTest
4.3.3.4.2 If it is necessary to dismantle a pump for some
other correction, such as improvement of power, NPSH, or
mechanical operation, the initial test will notbe acceptable,
and the final performance test shall be run after the correction is made.
Auxiliary equipment suchas oil systems, gears, and control systems shall be tested in the vendor’s shop. Details of
the auxiliary equipment test shall
be developedjointly by the
purchaser and the vendor.
4.3.3.4.3 If it is necessary to disturb the mechanical seal
assembly following the performance test, or if the test seal
faces are replaced with the job seal faces, the final seal assembly shall be air tested as follows:
4.3.4.5BearingHousingResonanceTest
With the pump unpiped, the bearing housing(s) shall be
excited by impact or other suitable means
and the naturalfrequency(ies) shall be determined from the response. A minimum separation margin
of 10 percent shallexist between the
natural frequency(ies) and the following excitation frequencies:
a. Pressurize each sealing section independently with clean
air to a test pressureof 175 kPa (25 psig).
b. Isolatethetestsetup
from the pressurizingsource
and maintainthe pressure for a minimum of5 minutes, or 5
minutes per 30 liters (1 ft3) of test volume, whichever is
greater.
c. The maximum allowable pressure drop during the test is
15 kPa (2 psi).
a. Multiples of running speed (RPM): 1.0,2.0,3.0.
b. Multiples of vane passing frequency:1.0,2.0.
4.4
O
4.3.4OPTIONALTESTS
When specified, the shoptestsdescribed in 4.3.4.1
through 4.3.4.5 shall be performed. Testdetails shall be mutually agreed upon by the purchaser and the vendor.
4.3.4.1NPSHRTest
4.3.4.1 .l NPSHR data shall be taken at each test point
(4.3.3.2.1)except shut-off.
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
CompleteUnitTest
Preparationfor Shipment
4.4.1 Equipment shall be suitably preparedfor the type of
shipment specified, including restraint of the when
rotor necessary. Restrained rotors
shall be identified by means of corrosion resistant tags attached with stainless steel wire. The
preparation shall makethe equipment suitable for 6 months
of outdoor storage from the timeof shipment, with nodisassembly required before operation, except for inspection of
bearings and seals. If storage for a longer period is contemplated, the purchaser will consult with the vendor regarding
the recommendedprocedures to be followed.
"
A P I S T D W b L O 95
m 0732290 0546358 307
CENTRIFUGAL PUMPS
FOR PETROLEUM,
HEAVY
D m CHEMICAL,
AND GASINDUSTRY
SERVICES
4-5
~
4.4.2 The vendor shall provide the purchaser withthe instructions necessary to preserve the integrity of the storage
preparation after the equipment arrives
at the job site and before start-up.
4.4.3.8 Openings that have been beveled
for welding shall
be provided with closures designed to prevent entrance of
foreign materialsand damage to the bevel.
4.4.3.3 Exterior surfaces, except for machined surfaces,
shall be given at least one coat of the manufacturer's standard paint. The paint shall not contain lead or chromates.
Stainless steel parts need notbe painted. The undersides of
baseplates shall be preparedfor grout in accordance with either 3.3.17or 3.3.18.
proof adhesivetape.
4.4.3.9 Lifting points and lifting lugs shall
be clearly iden4.4.3 The equipment shall be prepared for shipment after
tified.
all testing and inspection has been completed and the equip4.4.3.1 O The equipment shall be identified with item and
ment has been released by the purchaser. The preparation
serial
numbers. Material shipped separately shallbe identishall include that specified in 4.4.3.1 through 4.4.3.11.
fied with securelyaffixed, corrosion resistant metal tags in4.4.3.1 Any packing used in tests shall be removed from
dicating the item and serial number of the equipment for
the stuffing boxes prior to shipment.
which it is intended. In addition, crated equipment shall be
shipped with duplicate packing lists, one inside and one on
4.4.3.2 Unless otherwise specified, pumps shall not be
the
outside of the shippingcontainer.
disassembled after performance testing, provided the pump,
including the seal chamber, is completely drained and dried
4.4.3.11 Exposed shafts and shaftcouplingsshall be
and all internal parts are coated with a suitable rust prevenwrapped with waterproof, moldable waxed cloth
or volatiletative within4 hours of testing.
corrosion inhibitor paper.
The seams shallbe sealed with oil-
4.4.3.4 Exterior machined surfacesof cast iron and carbon
steel parts shall be coated with
a suitable rust preventive.
4.4.4 Auxiliary piping connections furnished on the purchased equipment shall be impression stamped or permanently taggedto agree with the vendor'sconnection table or
general arrangement drawing.
Service and connection designations shall be indicated. Symbols for all pump connections, including pluggedconnections shall be in accordance
with AppendixD.
4.4.3.5 Internal areasof cast iron and carbon steel bearing
housings and oil system components shall be coated with a
suitable oil soluble rust preventive.
4.4.5 Bearing assemblies shall be fully protected from the
entry of moisture and dirt.If vapor phase inhibitor crystals in
bags are installed in large cavities to absorb moisture, the
bags
must be attached in an accessible area for ease of re4.4.3.6 Flanged openings shall be provided with metal
moval.
Where applicable, bags shall be installed in wire
closures at least 5 mm (0.19 in.) thick, with elastomer gascages
attached
to flanged covers. Bag locations shall be inkets and at least four full diameter bolts. For studdedopendicated
by
corrosion
resistant tags attached with stainless
ings, all nuts needed for the intended service shall betoused
steel
wire.
secure closures.
4.4.3.7 Threaded openings shall be provided with steel
caps or steel plugs inaccordance with 3.5.1.12.
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
4.4.6 One copy of the manufacturer's standard installation
instructions shallbe packed and shipped with the equipment.
SECTION 5-SPECIFIC PUMP TYPES
5.1.2.9 Pumps shall be designed such that thefirst dry lateral critical speed is at least 20 percent above the continuous
operating speed.
Note: See Figures l . 1 and 1.2 for pump classifications and typical illustations.
5.1 SingleStageOverhungPumps
5.1.2.1 O Vibration readings are to be taken on the pump
bearing housing at designated locations (see2.8.3.2 and
2.9.2.10). Vibration readings shall meet therequirements of
2.8.3.
5.1.1HORIZONTAL(TYPEOH2)
5.1.1.1 Horizontalsinglestageoverhungcenterline
mounted pumps have asingle bearing housing toabsorb all
forces imposed uponthe pump shaft and maintainrotor position during operation. The pumps are mounted on a baseplate and are flexibly coupled to their drivers.
5.1.1.2 Type OH2 pumps shall be designed such that their
first dry lateral critical speed is at least 20 percent above
maximum continuous operating speed.
5.1.2.11 With the purchaser’s approval, bearing housings
may be arranged for grease lubrication. The stabilized bearing housing temperature shall not exceed 82°C (180°F)
when operatingat an ambient temperature of 43°C (1 10°F).
Recommended greases shall be suitable for operation at
these temperatures.
5.1.2.1 2 Coupling hubs may be supplied with aslip fit to
5.1.2VERTICALIN-LINE(TYPEOH3)
the shaft, secured with setscrews.
Note: This allows for final coupling hub adjustment required due tovari5.1.2.1 Vertical single stage overhung pumps have a bearations in distance between shaft ends.
ing housing integral with the pump to absorb all pump loads.
The driver is mounted
on a support integral
to the pump. The
5.1.2.1 3 Unless otherwise specified, auxiliary piping syspumps and their drivers are flexibly coupled.
tems (Appendix D, Plans 52 and 53) shall not be mountedon
the
pumps.
5.1.2.2 A flat contact surface shallbe provided on the bottom of the casing to makethe pump stable when free-standing on a pad or foundation. The ratio of the unit center of
be no greater
gravity heightto the contact surface width shall
than 3: l. This stability may be achievedthrough the design
of the casing or by a permanentexternal stand.
5.1.3INTEGRALGEARDRIVEN(TYPEOH6)
5.1.3.1 Integral gear driven pumps have a speed increasing gearbox integral with the pump. The impeller
is mounted
directly to the gearbox output shaft. Therenoiscoupling between the gearbox and pump; however, the gearbox
is flexibly coupledto its driver. Pumpsmay be oriented vertically
or horizontally.
5.1.2.3 Pumps shall be designed to float with the suction
and discharge pipe.
5.1.2.4 When specified, pumps shall be designed to be
bolted to a pad or foundation.
5.1.3.2 Impellers may be open, semiopen, or fully enclosed. Impellers shall be constructed as single piece castings or weldments. Fabricatedimpellersrequire
the
purchaser’s specific approval.
Note: Flange loading on the pump may increase when the unit is bolted
down and must be addressed in the piping design.
‘h
5.1 -2.5 A minimum NPS tapped drain connection shall
be provided so that no liquid collects on thecover or driver
support.
Note: Integral gear pumps are frequently utilized in low specific speedapplications, where efficiency is optimized with open type impellers.
O 5.1.3.3 When specified, the vendor shall perform a lateral
critical speed analysisfor each machine to assure acceptable
5.1.2.6 The pump and seal chamber shall be continuously
amplitudes of vibration throughout the anticipated
operating
vented with a high point
connection in either the seal chamber or seal flush piping. Systems needing manual venting re- speed range.The analysis shall be performedas described in
5.2.4. l .
quire purchaser approval.
Note: If venting to atmosphere is not acceptable, the vent must be connected tothe process pipingat an elevation abovethe seal chamber.
5.1.2.7 Pumps shall be designed to facilitate removal and
installation of the back pullout assembly. When specified, a
device shall be provided
which allows direct rigging
or lifting
of the back pullout assembly from outside
the motor support.
5.1.3.4
used.
Single piece hydrodynamic radial bearings
may be
5.1.3.5 Integral gear pumps may require partial disassembly to permit replacementof the seal assembly.
5.1.2.8 Pumps shall meet the requirements of paragraph
2.5.7 for shaft stiffness.
5-1
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
Note: Lateral critical speeds may beof concern with TypeOH6 pumps. Refer to 5.2.4.1 relative to the need for a lateral analysis. Normallypumps of
this type are thoroughly investigated during development, and typical rotor
dynamics are available and applicable. A lateral analysis should be specified
only for unique, new,or critical pumps.
API STANDARD 610
5-2
5.2.3.2 Interstage bushings and thrust-balancing devices
on multistage pumps may have the manufacturer’s standard
clearances, provided these clearances are stated as exceptions to this standard(see 2.6.4.2) in the proposal andare approved by the purchaser. Whenthe manufacturer’s standard
clearances are based on material combinations exhibiting superior wearcharacteristics,supporting data shall be included
in the proposal.
5.1.3.6 Unless otherwise specified, auxiliary piping systems (see Appendix D, Plans 52 and 53) shall not be
mounted on the pump.
5.2
Between Bearings Pumps
(Types BB1-885)
5.2.1
PRESSURE
CASINGS
5.2.1.1 Axially split casings may have a composition
sheet gasket or a metal-to-metaljoint; the vendor’s bidshall
state which is being offered.
5.2.1.2 Pumpsforservicetemperatures
(300°F) may be foot mounted.
’
5.2.4
DYNAMICS
5.2.4.1 Lateral Analysis
below 150°C
Note: Depending on pump design, the first or second wet lateral critical
speed of multistage and high-speed pumps may coincide with the operating
A lateral analspeed, particularly as internal clearances increase with wear.
ysis can predict whenthis coincidence is likelyand whether the resultingvibration will be acceptable.
5.2.1.3 For pumpswithaxiallysplitcasings,liftinglugs or
tapped holes for eyebolts shall be provided for lifting only
the top half of the casing and shall
be so tagged. Methodsfor
lifting the assembled machine shall be specified by the vendor (see 6.2.2.1, Item d).
5.2.4.1.1 Unless otherwise specified, the needfor a lateral
analysis of a pump’srotor shall be determined using the process set out in Figure 5-1. For this process, the following definitions apply:
5.2.2 ROTOR
5.2.2.1 Impellers of multistage pumps shallbe individually
located along the shaft and positively secured against axial
movement in the direction of normal hydraulic thrust.
An interference fit is not considered a positive locking method.
o 5.2.2.2 When specified, impellers of multistage pumps
shall also be positively lockedagainst axial movement in the
direction opposite to normal hydraulic thrust.
5.2.2.3 The runout of shafts and assembled rotors measured with theshaft or rotor supported on V blocks or bench
rollers adjacent to its bearings shall be within the limits
given in Table5- l.
5.2.3
RUNNING
CLEARANCES
5.2.4.1.2
5.2.3.1 Renewable casing bushings and interstage sleeves
or the equivalent shall be provided at all interstage points.
Table 5-1-Shaft
>1.9x109
(3.0~106)
40
Allowable shaft runout,
TIR um (in.) (0.0015)
I
Commnent
fit
on shaft
When
a
lateral analysis is required by the process in 5.2.4.1.1, it shall be carried out and its results assessed in accordance with AppendixI.
and Rotor Runout Requirements
Flexibility factor(see Note I),
L4/D2, m m 2 (in*) (seeNote 2)
radial
Allowable rotor
Runout, l m (in.)
TIR (seeNote 3)
a. Identical pump: same size, hydraulic design, number of
stages, RPM, clearances, type of shaft seal (axial face or
breakdown bushing), type of bearings, coupling weight, coupling overhang, and pumpingthe same liquid.
b. Similarpump: by agreement between purchaser and manufacturer, taking account of the factors listed in the preceding
definition (Item a).
c. Clussicullyst@ first dry critical speed (1.4.7)
is above the
pump’s maximum allowable continuous speed by the following:
1.20 percent for rotors designed for wet running only.
2.30 percent for rotors designedto be able to run dry.
I Clearance I
I
90
(0.0033
I
Interference
60 50
(0.0025)
51.9~109
(3.0~106)
25
(0.00101
I
I
Clearance
75
(0.0030)
I
I
Interference
(0.0020)
Notes:
1. The shaft flexibility factorL4/@ is directly related tothe static deflection of a simplysupported shaft, and is
therefore a good indicator of the runout attainable during manufactureand the quality of balance that can be
achieved and maintained.
2. L = bearing span; D = shaft diameter (largest) at impeller.
3. Runout of impeller hubs, balancingdrum, and sleeves.
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
I
CENTRIFUGAL PUMPS PETROLEUM,
FOR
\
HEAW DUTY CHEMICAL.
AND
GASINDUSTRY
5-3
SEFIVICES
TO EXISTING
CLASSICALLY
Y
ES
ANALYSIS
NOT
RECOMMENDED
I No
ANALYSIS
REQUIRED
Figure 5-l-Decision Tree for Rotor Lateral Analysis
5.2.4.2
Rotor Balancing
5.2.4.2.1 Rotors of the categories listed below shall be
two-plane dynamically balancedat low speedto the balance
grade in Table 5-2:
a. Multistage pumps (three or more stages).
b. One and two-stage pumps whose maximum
continuous
rotative speed is greater than 3800 RPM.
The sequence of rotor assembly and balance correction
shall follow IS0 5406. For balancing, the rotor does not include the pump half coupling hub or the rotary unitsof the
mechanical seals.
Note 1: Table 5-2 shows I S 0 balance grade G2.5 for all interference
fit rotors to speedsof 3800 M M . This is based on two factors: (a) At 3800
RPM the upper limit of balance grade G2.5 produces a force due to
unbalance of 10 percent of rotor weight, which means that unbalancewill
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
not have any material effecton the rotor’s operating shape;(b) Forrotors
whose flexibility is high (see Table 5-l), it is not practical to achieve and
maintain the rotor straightness necessary
for balance gradeG1.O.
Note 2: The mass eccentricity associated with balance grade G1.O is
very small; (for example,
O.OOO1 in. maximumfor operation at3800 MM).
Therefore, the balance quality
may not be verifiableif the rotoris disturbed
from its positionon the balancing stand or disassembled and reassembled.
It is normally possible, however,to perform a residual unbalance check to
verify the accuracy of the balancing stand.
5.2.4.2.2 For rotor balancing, any vacant single keyways
shall be filled with crowned half keys.
5.2.4.2.3 Whenever an assembledrotor is balanced, a rotor residual unbalancecheck shall be performed. The check
shall be carried out after final balancing of the rotor, following the procedure given
in Appendix J. The weight of all half
keys used duringfinal balancing of the assembled rotor shall
be recorded onthe residual unbalance worksheet.
A P I STDxbltO 95 W 0732290 054bltb2 8 3 8 W
API STANDARD
610
5-4
Table 5-2"Rotor Balance Requirements
Component
Shaft
on
Fit
I
Clearance
I
Interference
Maximum continuous
speed (RF")
To 38Wa
To 3800
Above 3800
Flexibility factor,
L4/D*, mm2 (in.2)
No Limit
No Limit
5 1.9 X 109
(3.0 x 106)"
Note: See Table 5-1 for shaft androtor runout requirements.
a1.05 (3600) for Nrbine overspeed.
balance correction during assembly is not feasible because clearancefit
will not maintain corrected balance.
'When rotors of higher flexibility are used at speeds above 3800 RPM,
achieving and maintaining this balancelevel willrequire special attention to
design, manufacture, and maintenance.
dApproximately equal to the midpointof the corresponding I S 0 balance
quality grade.
5.2.5 BEARINGSANDBEARINGHOUSINGS
5.2.5.1 When required by 2.9.1.1, hydrodynamic radial
bearings shall be in accordance with 5.2.5.1.1 through
5.2.5.1.3.
5.2.5.1.1 Bearings shallbe split for ease of assembly, precision bored, and of the sleeve or pad type, with steelbacked, babbitted replaceable liners, pads, or shells. The
bearings shallbe equipped with antirotation
pins and shallbe
positively securedin the axial direction.
continuous applied load produces a minimumoil film thickness of 13 pm (0.0005 in.) or a maximum babbit temperature
of 88°C (190"F), whichever occurs first. When specified,
thrust bearingsizing shall be reviewed and approved by the
purchaser.
Note: The limits given above correspond to a design factorof 2 or more
based onthe bearing's maximum continuousthrust capacity.
5.2.5.2.5 Thrust bearings shall be arrangedto allow axial
positioning of each rotor relative
to the casing and the setting
of the bearing's clearance or preload.
5.2.5.3 Beating housings for pressure lubricated hydrodynamic bearingsshall be arranged tominimize foaming. The
drain system shall be adequate to maintain the oil and foam
level below shaft end seals. The rise in oil temperature
through the bearing and housings shall not exceed 28°C
(50°F) under the most adverse specified operating conditions. The bearing outlet oil temperature shall not exceed
70°C (160°F) (see 2.9.2.3). When the inlet oil temperature
exceeds 50°C (120"F), special consideration shall be given
to bearing design, oil flow, and allowable temperature rise.
Oil outlets from thrust bearingsshall be as recommended by
the bearing manufacturer
for the collar speed and lubrication
method involved.Oil connections on bearing housingsshall
be in accordance with 3.5.
5.2.5.4 Axially split bearing housings shall have a metalto-metal split joint whose halves are located by means of
cylindrical dowels.
5.2.6
LUBRICATION
5.2.5.1.2 The liners, pads,or shells shall be in axially split
housings and shall be replaceable without havingto disman5.2.6.1 When specified or if recornended by the
tle any portion of the casing or remove the coupling hub. and approved
by the purchaser, a pressure lubrication system
shall be furnished to supply oil at a suitable pressure to the
5.2.5.1.3 Bearings shall be designed to prevent installapump bearings,the driver, and any other driven equipment,
tion
backwards
or upside
down
or both.
including gears and continuously lubricated couplings.
5.2.5.2 Hydrodynamic thrust bearings shall be in accordance with 5.2.5.2.1 through 5.2.5.2.5.
5.2.6.2 As a minimum, an external pressure lubrication
system shall include the following items (see Appendix D,
Figure D-6, for a typical schematic):
5.2.5.2.1 Thrust bearings shall be of the steel-backed,
babbitted multiple-segment-type, designed for equal thmst
a. A shaft-driven main oil pump with asuction strainer.
capacity in both directions and arrangedfor continuous pres- a b. An oil cooler, preferably separate and of the shell-andsurized lubrication to each side. Both sides shall be of the
tube type, with tubes of inhibited admiralty brass. Internal
tilting-pad type, incorporating a self-leveling
feature that asoil coolers are not acceptable. When specified, to prevent
sures that each pad carries an equal share of the thrust load
the oil from being contaminated if the cooler fails, the oilwith minorvariation in pad thickness.
side operating bressure shall be higher than the water-side
operating
pressure.
5.2.5.2.2 Thrust collars shall be positively locked to the
c.
Unless
otherwise specified,
an austenitic stainless steeloil
shaft to prevent fretting.
reservoir with the following characteristics:
5.2.5.2.3 Both faces of thrust collars shall have a surface
1. The capacity to avoid frequent refilling, to provide adfinish of not more than 0.4 pm (16 pin.) Ra, and, after
equate allowance for system rundown, and to provide a
mounting, the axial
total indicated runout of
either face shall
retention time of at least 3 minutes to settle moisture and
not exceed 13 pn (0.0005 in.).
foreign matter adequately.
a 5.2.5.2.4 Thrust bearing loading shall be determinedas in
2. Provisions to eliminate air and minimize flotation of
2.9.1.2. Bearings shall be selected such that the maximum
foreign matter to the pump suction.
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
~~
~~
API S T D * b L O 95 W 0732290 0546363 774 W
CENTRIFUGAL
PUMPS
FOR PETROLEUM,
HEAVYDUTYCHEMICAL,
AND GAS INDUSTRY
3. Fill connections, reflex-type level indicators, and
breathers suitable for outdoor use.
4. Sloped bottoms and connectionsforcomplete
drainage.
5. Cleanout openings as large as is practicable.
6. A bypass line that returns below the oil level to eliminate aeration and static electricity.
0
5-5
Note: Typically this is necessary only for critical, high speed services.
5.2.8
TESTING
5.2.8.1 For pressure lubricated bearings, test stand oil filtration shall be 25 pm nominal or finer. Oil system components downstream of the filters shall meet the following
cleanliness requirements:
d. A supply and returnsystem.
a. After 1 hour of oil circulation at 65-70°C (15O-16O0F),
e. A duplex full-flow filter with replaceable elements and fil-examination of a 100 mesh screen (0.1 mm (0.004 in.)) ditration of 25 pm nominal or finer. Filtercartridge materials
ameter wire with0.15 mm (0.006 in.) openings, installed at
shall be corrosion resistant. Metal mesh
or sintered metalfilthe bearing housing oil supply connection, shall show the
ter elements are not acceptable. The filter shall not be
following:
equipped witha relief valveor an automatic bypass.
l. Random distributionof particles on the screen.
f. A motor driven auxiliary oil pump with suction strainer and 2. No particle larger than 250 pm (0.010 in.).
an automatic/manual control system arranged
to start automat3. Total particle count less than that listed in Table 5-3.
ically on low oil pressure and with manual shutdown only. b. Freedom from foreignmatter (rust, scale, metal shavings,
g. Sight flowindicators in each bearing drain line.
sand) upon visual inspection and no
grittiness to the touch.
h. Temperaturegauges (with thennowells) in the reservoir,
5.2.8.2 During the shop test of pumps with pressure lubriafter the oil cooler, and in each bearing drain line.
cated bearings, theoil flow rate to each bearing housingshall
i. Low-oil-pressure alarm and shutdown switches.
be measured andrecorded.
j. A pressure gauge (valvedfor removal) for each pressure
5.2.8.3 All purchased vibration probes, transducers, and
level, and a pressure differential indicator to measurefilter
oscillator-demodulators
shall be in use duringthe test. If vipressure drop.
bration probes are not furnishedby the vendoror if the pur5.2.6.3 When specified, a removable steam heating elechasedprobesare
not compatible with shopreadout
ment external to the oil reservoir or a thermostatically confacilities, shop probes and readouts that meet the accuracy
trolled electric immersion heater with a sheath of austenitic
requirements of AF’I Standard 670 shall be used.The vibrastainless steel shall be provided for heating the charge cation measured withthis instrumentation shallbe the basis for
pacity of oil before start-up in cold weather.The heating deacceptance or rejection of the pump (see
2.8.3.7 and 2.8.3.8).
vice shall have sufficient capacity to heat the oil in the
5.2.8.4 With the purchaser’s approval, to accommodate
reservoir from thespecified minimum site ambient tempertest stand piping constraints, single-stage double-suction
ature to the manufacturer’s required start-up temperature
pumps
may be assembled for testing
by driving from theopwithin 12 hours. If an electric immersion heater is used, the
posite
end
of
the
pump
when
compared
to the general arwatt density shallnot exceed 2.33 watts persq. cm (15 watts
rangement
for
the
contract
pump
and
driver.
No retest is
per sq. in.).
required after final assembly.
5.2.6.4 The main and standby oil pumps shall have steel
casings unless they are enclosed in a reservoir. All other oil o 5.2.8.5 When specified, hydrodynamic bearings shall be
removed, inspected by the purchaser or his representative,
containing pressure components shall
be steel. (See3.5.5 for
and reassembledafter the performance test iscompleted.
requirements for lubricating oil piping.)
o 5.2.6.5
Where oil is supplied from a common system to
two or more machines (such
as a pump, a gear, anda motor),
by
the oil’s characteristics
will be specified on the data sheets
the purchaseron the basis of mutual agreement with all vendors supplying equipment served
by the commonoil system.
Note: The typical lubricants employed in a commonoil system are hydrocarbon oils that correspond to IS0 Grades 32 through 68,as specified in
IS0 3448.
o 5.2.6.6
When specified, the pressure lubrication system
shall conformto the requirementsof I S 0 10438 ( M I Standard 614).
0
SERVICES
5.2.7
ACCESSORIES
When specified, couplings and coupling mountings shall
conform to AF’I Standard 67 1.
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
5.2.9PREPARATION
FOR SHIPMENT
5.2.9.1 When a spare rotor or element is purchased, it
shall be prepared for unheated indoor storage of 3 years.
Storage preparation shall include treatment with a rust preventive and enclosure in a vapor barrier envelope with slow
release vapor phase inhibitor. The rotor or element shall be
Table 5-&Maximum Number of Particles
Nominal
Pipe
Size
Particle
Count
1 and less
5
1X
10
20
40
2
3
5-6
API STANDARD
610
5.3.3.2 The running clearances specified in 2.6.4.2 do not
apply to the clearances of steady bearingsor interstage bushings. The clearances used shall be stated in the proposal and
approved by the purchaser.
boxed for the type of shipment specified. A rotor shall have
a resilient material (but not lead, TFE or PTFE), at least 3
mm (0.12 in.) thick, between the rotor and its support cradle; support shall not be at the rotor’s journals. An element
shall have its rotor secured to prevent movement within the
stator.
5.2.9.2 When specified, a sparerotor shall be preparedfor
vertical storage. The rotor shall be supported from its coupling end with fixture
a
designed to support 1.5 times the rotor’s weight without damaging the
shaft. Instructions on the
use of the fixture shall be included in the installation, operation, and maintenance manual.
5.3.3.3 Pumps with semiopenimpellers in an erosive service shall have a replaceable casing liner.
O
5.3 Vertically SuspendedPumps
5.3.1
PRESSURE
CASINGS
5.3.1.1 Jackscrews and casing alignment dowels are not
required for rabbeted bowl assemblies.
5.3.1.2 The design of bowl and columnbolting shall take
into account possible pressure surges during pump start-up.
5.3.1.3 Unless otherwise specified, pumps shall be provided with vent connections for suction barrels and seal
chambers.
5.3.2 ROTORS
5.3.2.1 Unless otherwise specified, impellers shallbe fully
enclosed and constructed
as single-piece castings. Fabricated
impellers require the purchaser’sapproval.
Note: Enclosed (closed) impellers are less sensitive to axial setting and,
therefore, preferable forlong settings when shaft elongation due to axial
thrust is substantial. Similarly, closed impellers should
usedbe
for coldor hot
liquids dueto thermal shaft expansiodcontraction. Semiopen impellers offer
higher efficiency, due to the elimination of disc friction
onefrom
shroud. The
running clearances forsemiopen impellers are able to be adjusted from the
coupling or top of the motor, thus restoring efficiency and pump output without disassembly of pump parts. The openimpeller is typically of an axial
flow propellertype designed for large capacitiesat low heads; the open impeller is also used for volute sump pumps with
a separate discharge.
5.3.2.2 Pump shafts less than 100 mm (4 in.) diameter
shall be machined or ground and finished throughout their
entire length. The total indicated run-out shall not exceed 4
pm per 100 mm (0.0005 in. per ft) of length. Total run-out
shall not exceed 80 km (0.003 in.) over total shaft length.
5.3.2.3 The pump shaft shall be in one piece unless otherof total shaft length
wise approved by the purchaser (because
or shipping restrictions).
5.3.4
DYNAMICS
5.3.4.1 Vertically suspended pumps are generally flexible
structures with running speeds located between natural frequencies. As such, they aresusceptibleto resonant vibration
if their separation margins are not verified during design.
When specified, the vendor shall furnish an analysis of the
structure to confirm preconstruction design. The purchaser
and the vendor shall mutually agree on the extent, method,
and acceptance criteria for this analysis.
Note: The basic structural elements typically include the foundation,
pump structures and motor frames. Typically
the deflection of the foundation will represent less than
5 percent of the total deflection of the structural
elements. If foundation data is
not available when the analysis
is being conducted, a mutually agreed upon value shall
be used.
Generally a 20 percent separationmargin shall be maintained between the
natural frequency of the motor support structure and the operating
(in speed
other words, below the minimumor above the maximum continuous
operating speed).
5.3.4.2 Pump rotors shall be designed such thattheir first
dry critical speed is the following percentage above their
maximum allowable continuous speed:
a. For rotors designed for wet running only,20 percent.
b. For rotorsdesigned to be able to run d r y , 30 percent.
5.3.5GUIDEBUSHINGSANDBEARINGS
5.3.5.1 Guide bushings shall be suitably corrosion resistant and abrasion resistant
for the specified product and temperature. The maximum spacing between shaftguide
bushings shall be in accordance with Figure 5-2.
5.3.5.2 Th.mst bearings that are integral with the driver
shall meet the requirements of 3.1. Thrust bearings and
housings integral with the pump shall meet the applicable
requirements of 2.9.1 and 2.9.2. To allow axial rotor adjustment andoil lubrication, the thrust bearing shall
be mounted
with an interference fit on a slide-fit, key-driven sleeve.
5.3.5.3 Unless otherwise specified, except for volute
sump
pumps (Type VS4), the first stage impeller shall be located
between bearings.
Note: Although between bearingfirst stage impellers may result in superior rotor support, certain applications which require superior suction performance may benefit from an overhung
first stage impeller arrangement.
5.3.3WEARPARTSANDRUNNING
CLEARANCES
5.3.6
LUBRICATION
5.3.3.1 Renewable casing bushings shallbe provided at all
interstage and steady bearing points; however, the interstage Internal bearings in vertical pumps
are normally lubricated
pressure differential and the character of the liquid handled
by the liquid pumped. Alternate methods of lubrication shall
(for example, dirty or nonlubricating) shoulddetermine the
be proposed whenthe pumped liquidis not suitable.
need for corresponding shaft sleeves.
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
-
API STD*b10 95 W 0732290 OS4bLb5547
W
CENTRIFUGAL PUMPS FOR PETROLEUM, HEAW
DUTY CHEMICAL, AND GASINDUSTRY SERVICES
4500 (1
5-7
80)
4000 (1 60)
3500 (140)
3000 (1
2500
-L
Y
"
E
E
I
m
20)
1
(1
00)
2250 (90)
2000
(80)
1750(70)
.-C
8
5:
1500(60)
.-G
1250 (50)
2
H
1 O00 (40)
875 (35)
750 (30)
625 (25)
500 (20)
Figure 5-2-Maximum Spacing Between
Shaft Guide Bushings
5.3.7
ACCESSORIES
ficiently below it to permitthrough
the
ofuse
body flange.
5.3.7.1
Drivers
5.3.7.3.2 Single casing vertical pumps shall have the manufacturer's standardmountingarrangement.
5.3.7.1.1 Theframe of fabricated vertical motors shall be
post-weld stress relieved.
bolting on the
5.3.7.3.3 The pump-to-motor mounting surface shall contain arabbeted fit.
5.3.7.1.2 Pumpsandmotorassembliesthatcouldbedamaged by reverse rotation shall be provided with a nonreverse
ratchet or another purchaser-approved deviceto prevent reverse rotation.
5.3.7.3.4 A minimum of fouralignmentpositioning
screws shall be providedfor each drive train component that
weighs more than400 kg (900 lbs) to facilitate horizontaladjustment withinthe rabbeted fit.
5.3.7.2CouplingsandGuards
~~
Coupling faces shall be perpendicular to the axis of the
coupling within 1 pm per 10 mm (0.0001 in. per in.) of face
diameter or 13 pm (0.0005 in.) total indicated run-out,
whichever is greater.
O
5.3.7.3.5 When specified,pumps shall be provided with a
separate sole plate for bolting and grouting to
the foundation.
This plate shall be machined onits top surface for mounting
of the discharge head,can, or motor support.
dances
Piping
5.3.7.4
Plates
Mounting
5.3.7.3
5.3.7.3.1 The mounting plate for double casing pumps
shall beseparate from the main bodyflange and located suf-
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
are not installed prior to
When mechanical seals and drivers
be fully assembled.
shipment, theseal piping system shall not
A P I S T D * h L O 95
5-8
m
0 7 3 2 2 9 0 O546366 483
m
API STANDARD
610
5.3.8INSPECTION,TESTING,AND
PREPARATION FOR SHIPMENT
5.3.8.1 Pumps shall be tested as complete assemblies.
Tests using only bowls and
impellers are not recommended.
In cases where assembled unit testing
is impractical, the vendor shall submit alternative testing procedures withthe proposal. Suctioncans, if supplied,are not required for
performance testing.
o 5.3.8.2
When specified, a resonance test with the pump
unpiped shall be conducted on the pump structure/driver
frame assembly. This assembly shall be excited by an impact
on the driver frame, and the natural frequency(ies) shall be
determined by the response. This test shall be performed
with an impact on the driver in the direction of the discharge
flange and repeatedat 90 degrees from the discharge flange.
The separation margin duringthese tests shallbe 10 percent
below the minimum or above the maximum continuous operating speed.
5.3.9 SINGLE CASE DIFFUSER (VS1) AND
VOLUTE (VS2) PUMPS
5.3.9.1 Vertically suspended, single casing diffuser pumps
with discharge through the column are designatedVSType
l.
5.3.9.2 Vertically suspended, single casing volute pumps
with discharge through the column are designatedVS2.
Type
5.3.9.3 The componentswhich constitute the pressure casing are the casing (bowls), column, and discharge head.
5.3.9.4 Line shaft may be open or enclosed. Open line
shafting is lubricated by the pumped liquid. When pumped
liquid is not suitable as a lubricant, enclosed line shafting
may be provided toensure a clean lubrication supply
for line
shaft bearings. The type of lubrication will be specified by
the purchaser.
5.3.9.5 The discharge head mounting surface shall be suitable for grouting or mounting on a machined sole plate.
5.3.9.6 Thrust restraints are required at the pump
if an expansion joint is installed onthe discharge nozzle. Design review of the proposed installation and piping
by the vendor is
recommended.
m 5.3.9.7 When specified, line shafting shall be furnished
with hardened sleeves underthe bearing.
5.3.1 0.2 The components which constitute the pressure
casing are the casing (bowl), column and discharge head.
5.3.1 0.3 Column sections shall incorporate integral bearing spiders and rabbeted fits for column sizes of 300 mm
(12 in.) inside diameter pipe or larger.
5.3.10.4 Bowls shall have metal-to-metal-rabbeted fits.
5.3.11SINGLECASINGVOLUTELINESHAFT
(VS4) AND VOLUTE CANTILEVER (VS5)
PUMPS
5.3.11.1 Vertically suspended, single casing volute lineshaft driven sump pumps are designated TypeVS4.
5.3.11.1 .I Steady bearings shall be provided to support
the shaft and impeller.
5.3.1 1.1.2 Thrust bearings shall be designed for either
grease or oil mist lubrication. Steady bearings (or bushings) may be lubricated with water, grease, product, or be
self-lubricating.
5.3.1 1.2 Vertically suspended cantilever sump pumps are
designated as Type VS5.
5.3.1 1.2.1 The rotor shall be cantilevered fromits bearing
assembly. Submerged bottom bearingsand/or bushings are
not used to guide the shaft.
5.3.11.2.2 The shaft stiffness shall limit total deflection,
without the use of a casing bushing, such that the impeller
does not contact the pump casing under the most
severe dynamic conditions over the complete head capacity curve
with
a maximum diameter impeller and at the maximum speed
and fluid density.
5.3.11.2.3 Unless otherwisespecified,pumpbearings
shall be grease lubricated. The stabilized bearing housing
temperature shall not exceed 82°C (180°F) when operated
at an ambient temperature of 43°C(1 10°F). Recommended
greases shall be suitable for operation at these temperatures.
5.3.11.3 For open system sump pump service, the pressure containing components Types VS4 andVS5 pumps are
the volute casing, suction cover, and discharge line. For
closed system pressurizedor vacuum tankservice, the outer
stuffing box or seal housing, pump cover plate, and tank
cover also become pressurecontaining components.
5.3.11.4 For services above 12OOC (250"F), the pump
5.3.9.8 Product lubricated column sections shall incorporate integral bearing spiders and rabbeted fits for column sizesmust be designed to accommodate differences in thermal exof 300 mm (12 in.) inside diameter pipe
pansion between the pipe column and discharge pipe and beor larger.
tween the casing and support plate.
5.3.9.9 Unless otherwise specified, bowls shall be flanged
and shall havemetal-to-metal rabbeted fits.
5.3.11.5 Lifting lugs shall be provided in the cover plate
for lifting the pump assembly, includingthe driver.
5.3.1 O SINGLE CASING AXIAL FLOW (V=)
PUMPS
5.3.1 0.1 Vertically suspended, single casing axial flow pumps
with discharge through the column
are designated Type VS3.
5.3.11.6 The discharge nozzle shall be flanged. The discharge nozzle andcover plate shall be designed
to withstand
twice theforces and momentsin Table 2.l.
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
-
~~
A P I STD*bLO
95
m 0732290 054b1b7
CENTRIFUGAL PUMPS FOR PETROLEUM.
~
~~~
HEAVYDUTY CHEMICAL.
AND
3LT
m
GAS INDUSTRY SERVICES
5-9
-
screws. This facilitates final coupling adjustment for variations in spacing betweenshaft ends.
Note: If the pump is mounted in a vessel,the nozzle of the vessel shall also
be designed to withstand these loads. See2.4 for allowable nozzle loads.
5.3.11.7 For flammable or hazardous fluids, cover plate
joints shall be vapor tight. The cover plate design and mount-5.3.12DOUBLECASINGDIFFUSER(VS6)AND
VOLUTE (VS7) PUMPS
ing shallbe mutually agreed toby the purchaser and vendor.
5.3.12.1
Verticallysuspendeddoublecasingpumps
are
5.3.1 1.8 The shaft total indicated runout shall not exceed
50 pm (0.002 in.) as measured on the shaft directly above the designated Type VS6 for diffuser construction and VS7 for
volute construction.
mechanical seal or stuffing box.
O
5.3.1 2.2 The components which constitute the pressure
casing of Type VS6 pumps are the discharge head and the
suction can.
5.3.11.9 When a mechanical seal is specified, it shall be
located at the cover plate to seal the vapor in the supply tank
or vessel. Mechanical seals normally seal vapor; however,
they shall be designed to operate in liquid in the event of
tank or vessel overfilling. With purchaserapproval, the vendor may supply a seal pressurized by flush from the pump
discharge or from an external source. External seal flush
must be compatible withthe liquid being pumped. Theseal
chamber shall have provisions for a high point vent.
5.3.12.3 The components which constitute the pressure
casing of Type VS7 pumps are the outer casing (complete
with the discharge nozzle), the head plate, and the suction
pipe.
5.3.1 2.4 Complete outer case venting shall be ensured by
means of a highpoint vent connection.
5.3.1 1.1O . Unless otherwise specified, pump out vanes
shall be used to reduce leakage backinto the sump. The reduction in axial thrust caused by the pump out vanes, however, shall not be consideredin sizing axial thrust bearings.
5.3.11 .ll Spacer couplings are not typically required for
VS4 and VS5 type pumps. Unless otherwisespecified, coupling hubs shall be supplied withslip
a fit to the shafts. Coupling hubs and keys shall be secured to the shaft with set
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
5.3.1 2.5 Provision shall be madeto ensure complete venting of the inner assembly withinthe seal chamber or associated auxiliary process piping.
O
5.3.12.6 When specified,the suction can shall be supplied
with a drain piped to the surface.
5.3.12.7 Column sections shall incorporate integral bearing spiders and rabbetted fits for all column sizes.
SECTION &VENDOR’S DATA
6.1
specific statement that the system and all its components
are
in strict accordance with this standard. If the system and
components are not instrict accordance, the vendor shall include a list that detailsand explains each deviation.
The vendor shall provide details to enable the purchaserto evaluate
any proposed alternative designs. All correspondence shall
be clearly identified in accordance with
6.1.2
General
6.1.1 The information to be furnished by the vendor is
specified in 6.2 and 6.3. The vendor shall complete and forward the Vendor Drawing and Data Requirements form
(see
Appendix O) to the addressor addresses notedon the inquiry
or order. This form shall detail the schedule
for transmission
of drawings, curves, and data as agreed to at thetime of the
order, as well as the number and typeof copies required by
the purchaser.
6.1.2 The data shall be identified on transmittal (cover)
letters and intitle blocks or title pages with the following information:
a. The purchaseduser’s corporate name.
b. The job/project number.
c. The equipment item number and service name.
d. The inquiry or purchaser order number.
e. Any other identification specified in the inquiry or purchaser order.
f. The vendor’s identifying proposal number, shop order
number, serial number,
or other reference required
to identify
return correspondencecompletely.
6.2.1.2 Clearances less than those required by 2.6.4.2(refer to 5.2.3.2)must be stated as exceptions to this standardin
the proposal.
6.2.2
DRAWINGS
6.2.2.1 The drawings indicated on the Vendor Drawing
and Data Requirementsform (see Appendix O) shall be included in the proposal. As a minimum, the following data
shall be furnished:
a. A general arrangementor outline drawing for each major
skid or system, showing direction
of rotation, size, and location of major purchaser connections; overall dimensions;
maintenance clearance dimensions; overall weights; erection
weights; maximum maintenance weights (indicated
for each
piece); andif applicable the Standard Baseplate number
(see
e 6.1.3 When specified, a coordination meeting shall be
Appendix M).
held, preferably at the vendor’s plant, within 4 weeks after
b. Cross-sectional drawings showing the details of the prothe purchase commitment.An agenda shall be prepared for
posed equipment.
this meeting and mayinclude the followingitems:
c. Schematics of all auxiliary systems, including the lube
oil,
control, and electrical systems. Bills of material shall be
a. The purchase order, scope of supply, unit responsibility,
included.
and subvendoritems.
d. Sketches that show methodsof lifting the assembled mab. The data sheets.
(This information
c. Applicable specifications and previously agreed-upon ex- chine or machines and major components.
may be includedon the drawings specified in the preceding
ceptions.
Item a.)
d. Schedules for transmittal of data, production, andtesting.
e. The quality assurance program and procedures.
6.2.2.2 If typical drawings, schematics, and billsof matef. Inspection, expediting, and testing.
rial are used, they shall be marked up to show the correct
g. Schematics and bills of material for auxiliary systems.
weight and dimension data and to reflect the actual equiph. The physical orientation of the equipment, piping, and
ment and scope proposed.
auxiliary systems.
i. Coupling selections.
6.2.3TECHNICALDATA
j. Thrust-bearing sizing and estimated loadings.
The following data shall be included inthe proposal:
k. The rotor dynamics analysis.
a. The purchaser’s data sheets, with complete vendor’s infor1. Vendor supplied maintenance data.
mation entered thereon
and literature to fully describe details
m. Other technical items.
of the offering.
b. The purchaser’s noisedata sheet.
6.2 Proposals
c. The Vendor Drawing and Data Requirements form (see
6.2.1
GENERAL
Appendix O),indicating the schedule according
to which the
vendor agrees to transmit all thedata specified as part of the
6.2.1.1 The vendor shall forward the original proposal and
contract.
the specified numberof copies to the addressee specified in
the inquiry documents. As
a minimum, the proposal shall in- d. A schedule for shipment ofthe equipment, in weeks after
receipt of the order.
clude the data specified in 6.2.2 through 6.2.4, as well as a
6-1
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
A P I STDabLO 95
6-2
0
m
0 7 3 2 2 9 0 0 5 4 b L b 9 L92 W
API SI
rANDARD 610
e. A list of major wearing components, showing inter6.3 Contract Data
changeability with the purchaser’s other units.
f. A listof spare parts recommendedfor start-up and normal
6.3.1
GENERAL
maintenance purposes (see Table 6-1). (The purchaser will
6.3.1.1 Vendor contract data shall be furnished and mainspecify any special requirements for long-term storage.)
tained as specified in Appendix
O. Each drawing, billof mag. A list of the special tools furnished for maintenance.
terial, and data sheet shall have a title block in its lower
h. An outline of all necessary special weather and winterizright-hand comer that shows the date of certification, a refing protection required by the pump,its auxiliaries, and the
erence to all identification data specified in 6.1.2, the revidriver (if furnished by the vendor) for start-up, operation,
sion number anddate, and the title.
and idleness. The vendor shall list separately the protective
items he proposes
to furnish. (The purchaser will specify any 6.3.1.2 The purchaser will promptly review the vendor’s
requirements for long-term storage.)
data when he receives them; however, this review shall not
i. A complete tabulation of utility requirements, such as
constitute permission to deviate from any requirements in
those for steam, water, electricity, air, gas, and lube oil, inthe order unless specifically agreed upon in writing. After
cluding the quantity
of lube oil required and the supply pres- the data have been reviewed, the vendorshall furnish certisure, the heat load to be removed by the oil, and the
fied copies in the quantity specified.
nameplate power rating and operating power requirements of
6.3.1.3 A complete list of vendor data shall be included
auxiliary drivers. (Approximate data shall be defined and
with
the fmt issue of the major drawings.This list shallconclearly identified as such.)
tain
titles, drawing numbers, and a schedule
for transmission
j. A description of the tests and inspection procedures for
of
all
the
data
the
vendor
will
furnish
(see
Appendix
O).
materials, as required by 2.11.1.3.
k. A description of any special requirements specified the
in
purchaser’s inquiry andas outlined in 1.2,2.7.3.5,2.1 l. 1.2,
6.3.2
DRAWINGS
2.11.1.3,3.6.1,5.2.1.1, 5.2.3.2,5.3.3.2,and5.3.8.1.
The drawings furnished shall contain sufficient information
1. When specified, alist of similar machines installed and
op
so that with the drawings and the manuals specified in 6.3.6,
erating under analogous conditions.
the purchaser can properly install, operate, and maintain the
m.Any start-up, shutdown,or operating restrictions required
ordered equipment. Drawings shall
be legible, identified in
acto protect theintegrity of the equipment.
cordance with6.3.1.1, and in accordance withIS0 3 1 (symn. The calculation of suction specific speed, which shall be
bols), I S 0 128 (principles of presentation), IS0 129
made for the maximum impeller diameter, at the best effi(dimensioning principles),IS0 3098 (lettering) (ANSVASME
ciency point.
Y 14.2M) or other corresponding standards as agreed upon
o. Any test facility limitations that
may require the vendorto
with the purchaser. Each drawing shall include the details
for
assemble anddrive single-stage, double-suction pumps from
that drawing listedin AppendixO.
the opposite end for testing (see 5.2.8.4).
6.2.4
CURVES
The vendor shall provide complete performance curves,
including differential head, typical efficiency, water
NPSHR,
and power expressed as functions of capacity. The curves
shall be extended to at least 120 percent of capacity at peak
efficiency, and the rated operating point shall be indicated.
The head curve for maximum and minimumimpeller diameters shall be included. The eye area of the first-stage impeller and the impeller
identificationnumber shall be shown
on the curves. If applicable, the curves shall indicate viscosity corrections. Minimum flow (both thermal and stable),
preferred and allowable operating regions, and any limitations of operation shall be indicated.
6.3.3TECHNICALDATA
6.3.3.1 The data shall be submitted in accordance withA p
pendix O and identifiedin accordance with6.3.l. l.Any comments on the drawings or revisions of specifications that
necessitate a change in the data shall
be noted by the vendor.
These notations will result in the purchaser’s issue of completed, correcteddata sheets as pat? of the order specifications.
6.3.3.2 Certified test curves and data (Appendix T) shall
be submitted within 15 days after testing and shall include
head, power recalculatedto the proper specific gravity, and
efficiency, plotted against capacity. If applicable, viscosity
corrections shallbe indicated. The water NPSHR curve shall
be included, drawn from actual test data,
for an impeller cast
from the same pattern. The curve sheet shall include the
o 6.2.5
OPTIONS
maximum and minimum diameters of the impeller design
When specified, the vendor shall furnish a list of the prosupplied, the eye area of the fiist-stage impeller, the identicedures for any specialor optional tests that have been spec- fication number of the impeller or impellers, i d the pump
ified by the purchaser or proposed by the vendor.
serial number.
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
~~~~
API S T D x b b O 95
0732290 054bl170 904
CENTRIFUGAL
PUMPS FOR PETROLEUM, HEAVY
DUTY CHEMICAL,
AND
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
m
GASINDUSTRY
SERVICES
6-3
A P I STD*bLO 95
m 0732290 054bL7L 840
API STANDARD
610
6-4
6.3.4PROGRESSREPORTS
Unless otherwise specified, the vendor shall submit
progress reportsto the purchaser at the
intervals specified on
the Vendor Drawingand Data Requirements form (see Appendix O).
6.3.5PARTSLISTSANDRECOMMENDED
SPARES
6.3.5.1 The vendor shall submitcomplete parts lists for all
equipment and accessories supplied. The lists shall include
manufacturer’s uniquepart numbers, materials ofconstruction, and delivery times. Materials shall be identified as
specified in 2.11.1.2. Each part shall be completely identified
and shown on cross-sectional
or assembly-type drawings so
that the purchaser may determine the interchangeability of
these parts withother equipment. Parts that have been modified from standard dimensions andor finish to satisfy specific performance requirements shall be uniquely identified
by part numberfor interchangeability and future duplication
purposes. Standard purchased items shall
be identified by the
original manufacturer’s name and part number.
chaser to correctly install, operate, and maintain all of the
equipment ordered. This information shall be compiled in a
manual or manuals with acover sheet that contains all reference identifying data specified in 6.1.2, an index sheet that
contains section titles, and acomplete list of referenced and
enclosed drawings by title and drawing number.The manual
manshall be prepared
for the specified installation; a typical
ual is notacceptable.
6.3.6.2InstallationManual
Any special information required
for proper installation design that is not on the drawingsbeshall
compiled in a manual
that is separate from the operating and maintenance instructions. This manual shall be forwarded at a time that is mutually agreed upon
in the order, but not later than
the final issue
of prints.The manual shall contain information such
as special
alignment and grouting procedures, utility specifications
(including quantities), and all other installation design data,
including the drawings and
data specified in6.2.2and 6.2.3.The
manual shall also include sketches that showthe location of
the centerof gravity and rigging provisions to permit rethe
moval of the top half of the casings, rotors, and any subassemblies that weigh more than
135 kg (300 lbs).
6.3.5.2 The vendor shall indicate on the preceding parts
lists which parts are recommended spares for start-up and
normal maintenance as referenced in 6.2.3, Item f (Table 61). The vendor shall forward the lists to the purchaser
6.3.6.3Operating,Maintenance,and
promptly after receipt of the reviewed drawings and intime
Technical Data Manual
to permit order and delivery
of the parts before field start-up.
The transmittal letter shall be identified with the data speciThe manual containingoperating maintenance and technified in 6.1.2.
cal data shall be sent at the time of shipment. This manual
shall include a section thatprovides special instructions for
6.3.6INSTALLATION,OPERATION,
operation at specified extreme environmental conditions,
MAINTENANCE, AND TECHNICAL
such as temperatures. As a minimum,the manual shall also
DATA MANUALS
include all of the data listed in Appendix O.
6.3.6.1
General
The vendor shall provide sufficient written instructions
and a cross-referencedlist of alldrawings to enable the pur-
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
A P I STD*:61O 95
APPENDIX A-
A.l
0732290 0546172 787
REFERENCED PUBLICATIONS AND INTERNATIONAL STANDARDS
B 16.5 Pipe Flanges and Flanged Fittings (steel)
B16.11 Forged Steel Fittings, Socket- Welding
and Threaded
B3 l. 1 Power Piping
B31.3 Chemical Plant and Petroleum Refinery
Piping
B46.1 Surface
Texture
(Surface
Roughness,
Waviness andLay)
Boiler and Pressure VesselCode, SectionII, “Materials”;
Section
“Nondestructive
Examination ”;Section Vlll, “Pressure Vessels”;
and Section IX, “Welding and Brazing
Qualijications
Referenced
Publications
The following publications are citedin this standard:
ABMAI
Standard 7
Standard 9
Standard 20
m
Shaft and HousingFits for Metric Radial
Ball andRoller Bearings
Load Ratings and Fatigue Life for Ball
Bearings
Metric Balland Roller Bearings (Except
Tapered Roller Bearings)Conforming to
Basic Boundary Plans: Boundary Dimensions, Tolerances, and IdentiJication
”
AGMA2
9000
9001
9002
9003
ASTM4
Flexible Couplings-Potential Unbalance Classifcation
Lubrication of Flexible Couplings
Bores and Keyways for Flexible Couplings {Inch Series)
Flexible Couplings-Keyless Fits
Test Method for Linear Shrinkage and
Coefficient of Thermal Expansion of
Chemical-ResistantMortars,Grouts,
and Monolithic Sugacings
Test
Methodsfor Compressive Strength of
c 579
Chemical-Resistant Mortarsand Monolithic Sugacings
C 882 Test Methodfor Bond Strength of EpoxyResin Systems Used With Concrete
C 884 Test Method for Thermal Compatability
Between Concrete and an Epoxy-Resin
Overlay
c 1181 Test Method for Compressive Creep of
Chemical-Resistant Polymer Machinery
Groups
D 638 Test Method f o r Tensile Properties of
Plastics
D 247 1 Test Method f o r GelTimeandPeal
Exothermic Temperature of Reacting
Thermosetting Resins
E 94 Guidefor Radiographic Testing
E 125 Reference Photographs for Magnetic
Particle Indications on Ferrous Castings
E 142 Method for Controlling Quality of Radiographic Testing
E 709 Practicefor Magnetic Particle Examination
C 531
API
spec. 5L
Specijicationfor Line Pipe
Classifcation of Locationsfor Electrical
Installations at Petroleum Facilities
Standard 54 1 Form-Wound Squirrel-Cage Induction
Motors-250 Horsepower and Larger
Turbines for ReStandard 6 1 1 General Purpose Steam
jïnery Service
Standard 6 14 Lubrication, Shaft-Sealing, and ControlOil Systemsfor Special-Purpose Applications
Standard 670 Vibration, Axial-Position, and BearingTemperature MonitoringSystems
Standard 671 Special-Purpose Couplingsfor Refinery
Service
Standard 677 General-Purpose GearUnitsfor Rejinery
Service
Standard 682 Shaft Sealing Systems for Centrifugal
and Rotary Pumps
RP 500
ASME3
B1.20.1
B16.1
Pipe Threads, General Purpose(Inch)
Cast IronPipe Flanges and FlangedFittings
AWS5
D1.l
4American Society for Testing and Materials, 1916 Race Street, Philadelphia, Pennsylvania 19103-1187.
SAmerican Welding Society,550 N.W. LeJeune Road, P.O. Box 351040,
Miami, Florida 33135.
‘American Bearing Manufacturers Association, 1200 19th Street, N.W.,
Suite 300, Washington, D.C.20036.
*American Gear ManufacturersAssociation, 1500 King Street, Suite 201,
Alexandria, Virginia223 14.
3American Society of Mechanical Engineers, 345 East 47th Street, New
York, New York 10017.
A- 1
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
Structural Welding Code-Steel
~
A P I STD*bLO 75
A-2
~~~
~~~
~
m 0732270
0 5 4 6 3 7 3 bL3 W
API STANDARD
610
DIN6
910
HI’
Heavy-Duty Hexagon Head Screw Plugs
3098
3448
The codes, standards, and specificationsof
the Hydraulic Institute (CentrifugalPump
Section) also form part of this standard.
3740
IEEES
84 1
Standardfor Petroleum and Chemical
Industry Severe Duty TEFC Squirrel Cage
Induction Motors-Up To and Including
500 HP
3744
1s09
3746
31-0
General Principles Concerning Quantities, Units, and Symbols
128 Technical Drawings-General Principles
of Presentation
129 Technical Drawings-DimensioningGeneral Principles, Dejinitions, Methods
of Execution, and Special Indications
228- 1 PipeThreadsWherePressure-Tight
Joints
Not
Made
are
the
on
Threads-Part I : “Designation, Dimensions and Tolerances
262 I S 0 GeneralPurposeMetricScrew
Threads-SelectedSizes
f o r Screws,
Bolts, and Nuts
281-1 Rolling Bearings-Dynamic Load Ratings and Rating Life-Part I : “Calculation Methods”
286 I S 0 System of Limits and Fits-Part I :
“Bases of Tolerances, Deviations and
Fits ”;and Part 2-“Tables of Standard
Tolerance Grades and Limit Deviations
for Holes and Shafts”
R 773 Rectangular or Square ParallelKeys and
Their Corresponding Keyways
R 775 Cylindrical and I / I O Conical Shaft Ends
1503 Geometrical Orientation and Direc-
tions of Movements
1940
Mechanical Vibration-Balance Quality
Requirements of Rigid Rotors-Part I :
5406
5753
7005- 1
7005-2
1O436
1 O438
MSSlo
MSS-SP-55
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
Quality Standardfor Steel Castings for
Valves, Flanges and Fittings and Other
Piping Components-Visual Method
NACE11
MR 0175
Standard Material Requirements: SulJde
Stress CrackingResistant Metallic Materials for Oiljïeld Equipment Corrosion
Engineers ReferenceHandbook
NFFA 12
NFFA 70
National Electrical Code
ssPc13
SP 6
6DIN Deutsches Institut fur Normung, Burggrafenstrasse
6, Postfach 1107,
D-1000 Berlin 30, Germany.
Ohio 44107.
7Hydraulic Institute,712 Lakewood Center North, Cleveland,
*Institute of Electrical and Electronics Engineers, Inc., 345 East 47th Street,
New York, New York 10017.
%ternational Organization for Standardization publications are available
from the American National Standards Institute,11 West 42nd Street, New
York, New York 10036.
“Determinationof Permissible Residual
Unbalance”
Technical Drawings
Industrial Liquid Lubricants-IS0 Viscosity Classification
Acoustics-Determination of Sound
Power Levels of Noise Sources-Precision Methodsfor Broad-Band Sourcesin
Reverberation Rooms
Acoustics-Determination
of Sound
Power Levels of Noise Sources-Engìneering Methodsfor Free-Field Conditions Over a Rejecting Plane
Acoustics-Determination
of Sound
Power Levelsof Noise Sources-Survey
Method
The Mechanical Balancingof Flexible
Rotors
Rolling
Bearings-Radial
Internal
Clearance
Metallic
Flanges-Part
I:
“Steel
Flanges”
Metallic Flanges-Part 2: “Cast Iron
Flanges”
PetroleumandNaturalGasIndustriesGeneral-Purpose Steam Turbines
for Rejinery Service
Lubricatiort,shaft-sealg and Coml- oil
Systems For Special-Purpose Applications
Surface PreparationSpecification
Wanufacturers Standardization Society, 127 Park Street, N.E., Vienna,
Virginia 22 180.
IlNational Associationof Corrosion Engineers, P.O. Box 218340, Houston,
Texas 77218.
12National Fire ProtectionAssociation, 1 Batterymarch Park, Quincy,Massachusetts 02269.
%teel Structures Painting Council,4400 Fifth Avenue, Pittsburgh, Pennsylvania 15213-2683.
CENTRIFUGAL PUMPS FOR PETROLEUM, HEAWDUTV CHEMICAL, AND
U.S. Army Corps of Engineers14
CRD C611
Test
Methods
f o r Flow
Grout
Mixtures
(Flowcone
Method)
c621 corps Of EngineersSpecifcations for
Non-Shrink
Grout
I4U.S. Army Corps of Engineers, 20 Massachusetts Avenue, N.W., Washington, D.C. 20314
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
A.2
GASINDUSTRY
SERVICES
A-3
Corresponding
International
Standards
Table A- 1 contains
international
standards
corresponding
to thoselistedin A-1. Table A-2 shows U.S. andcorresponding
international
components.
piping
standards
for
A P I STDxbLO 95 W 0732290 0546375 496 W
A4
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
API STANDARD
610
~~
A P I STD*bLO 95
0732290 0546376 322
m
A-5
CENTRIFUGAL
PUMPSFOR PETROLEUM,
HEAWDUTYCHEMICAL,
AND GASINDUSTRYSERVICES
a
L
O
r-
W
B
v]
i;
4
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
>
A P I STD+bLO 95
A-6
0732270 05qbL77 267
API STANDARD
610
C
8
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I
gig
SS
8
2
v)
P
e
I
l i
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
A P I STDvbLO 95
m 0732290 0546L78 L T 5 m
CENTRIFUGAL PUMPS
FOR PETROLEUM,
HEAWDUTYCHEMICAL,
AND GASINDUSTRY
SERVICES
-
a
xo
8õ
I
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@
3
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COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
3
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A-7
A P I STD*bLO 95
A-8
m
0732290 O546379 033
API STANDARD
610
3
I
.
3
c
3
5
2
Y
2
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P
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
m
~~
API STDrbLO 95
0732290 O546380 853
CENTRIFUGAL
PUMPSFOR PETROLEUM, HEAVY
DUTY CHEMICAL,
AND
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
m
GASINDUSTRY
SERVICES
A-9
A-1 O
API STANDARD
610
.
3
-
m
I
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m S
4
E
N
O
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m
;SI
ö
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w m
m
Pm
Pm
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9
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9
3
3
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B
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
A P I STDxblO 95
0732290 054bL82 b2b
APPENDIX B-PUMP
B-1
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
DATA SHEETS
A P I S T D z b l O 95
m
0732290 054bl183 5 6 2
m
PAGE
API 610, 8TH EDITION
CENTRIFUGAL PUMP DATA SHEET
SI UNITS / IS0 STANDARDS (1.2.2)
i
2
8
10
il
12
13
14
-
VARIATIONS
I
SERVICE
NPE
0
STAGES
BYMANUFACTURER
NO.
BYMANUFACTURERORPURCHASER
0 GENERAL (3.1.1)
OPERATE
MRS
P'UTO
cSERIES) WITH
IN (PARALLEL)
MOTOR
NO.
DRIVEN
TURBINE
NO.
DRIVEN
PUMP ITEMNO.
PUMP ITEM NO.
GE
;A
R ITEM NO.
MOTOR ITEMNO.
TURBINE ITEM NO.
cE
;A
R PROWDED BYc;EAR MOUNTED BY
MOTOR PROVIDED BY
TURBINE PROVIDED BY
MOTOR MOUNTED BY
TURBINE MOUNTED BY
TURBINE DATA SHEET NO.
-
MOTOR DATA SHEET NO.
;A
R DATA SHEET NO.
CE
SITE AND UTILITY DATA (CONT.)
OPERATING CONDITIONS
15 O' CAPACITY,
NORMAL
16
OTHER
17 O1 SUCTION
PRESSURE
MAXIRATED
(kPa)
DATE
UNIT
FOR
-
9
DATE
BY
AS BUILT
~
7
5
/
PURCH ORDER NO.
INQUIRY NO.
REVISION
3
SITE
4 PUMP
NIO. REQ
SIZE
5
NWUFACTURER SERIAL
MOOEL
6
1rlOTE: 0 INDICATESINFORMATIONCOMPLETEDBYPURCHASER
NO.
OF
ITEM
REQ / SPEC NO.
0 PURCHASE
0 PROPOSAL
APPLICABLETO
NO.
JOB NO.
1
(rn3/h) RATED
WATER SOURCE
(,,,3h)
I
@pa)
(m)
18 C1 DISCHARGE
PRESSURE
19 C1 DIFFERENTIAL
PRESSURE
20 C HEAD
DIFFERENTIAL
(3.5.2.6)
CHLORIDE CONCENTRATION( P M
INSTRUMENT A I R : W I N PRESS
@Pa)
I
LIQUID
I
0 TYPUNAME OF LIQUID
(m) O PUMPING TEMPERATURE:
(m) NPSHA
21 C PROCESS
NORMAL
ec)w
(" C) MIN
(3.1.2)
22
C) STARTING
CONDITIONS
(3.1.3) 0 VAPOR PRESSURE
ah) @
23 SERVC
0 RELATIVE DENSITY (SPECIFIC GRAMPI):
I E:
O CONTINUOUS OINTERMI~ENT(STARTDAW
NORMAL
MAX
MIN
24 C) PARALLEL OPERATION REQ'D (2.1.11)
25
0 SPECIFIC HEAT, Cp
SITE AND UTILITY DATA
26ì L,OCATION: (2.1.29)
0 WSCOSIN
(CP)
27' C) INDOOR
0 HEATED
0 UNDERROOF
0 MAX VISCOSIN
e C)
e C)
osa
-
e ;
28I C) OUTDOOR
28' C1 GRADE
0 UNHEATED
0 MEZZANINE
0 PARTIALSIDES
0
DIV CL
31I
31I
HEATING
0 TROPICALIZATION
REQ'D
M I W
37
(2.1.23)
(m) BAROMETER
(Iss ah)
MINM
I
I
0 DUST
42I
MIN
(m)
MAX
(kW
MAX
THERMAL
(kW
(mm)
(W
e c)
e c)
(m3W
(m3h) STABLE
0 PREFERRED OPERATING REGION
eC)
e C)-(kPa)
MIN
0 RATED
EFFICIENCY
POWER
(BHP)
0MINIMUM CONTINUOUS FLOW:
0 FUMES
0ALLOWABLE OPERATING REGION
0 hhX HEAD @IMPELLER
RATED
0MAX POWER @IMPELLER
RATED
0 NPSH REQUIRED AT RATED CAP
ELECTRICITY:
DRIVERS
HEATING
CONTROL
SHUTDOWN
44I
O RPM
PROPOSAL CURVE NO.
e C) 0IMPELLER DIA RATED(%)
38' C) OTHER
39' C) UTILITY CONDITIONS:
DRIVERS 40I SìTEAM:
41
42
(m
PERFORMANCE
C ALTITUDE
35 C) AMBIENT
RANGE
OF
TEMPS:
36 CHUMIDITY.
) RELATIVE
CONDITIONS
UINUSUAL
C)
C)
(3.5.2.6)
0 CHLORIDE CONCENTRATION( P m
(2.11.1.11)
0 H2S CONCENTRATION(l'PM)
LIQUID (2.1.3)
0 !-WARDOUS
0 FLAkMWLE
0 OTHER
GR
C1 WINTERIZATION
REQ'D
8) B LITE DATA(2.129)
O
(2.11.1.8)
OCORROSNUEROSIVE AGENT
x I C1 ELECTRICAL AREA CLASSIFICATION(2.1.22 I 3.1.5)
32!
Wh
3
W
TO@
TO___@
3
4
(m)
m
(m) (2.1.8)
VOLTAGE
$il SUCTION SPECIFIC SPEED
45i
HERTZ
0 MAX SOUND PRESS. LEVEL REQ'D
(dBA)(2.1.14)
4ci
PHASE
0 EST MAX SOUND PRESS. LEVEL
(dBA)(2.1.14)
4;r
COOLING WATER: (2.1.17)
4l3
TEMP INLET
4!3
PRESS NORMAL
5l3
MIN RETURN
5'1
i
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
REMARKS
C) MAX RETURN
DESIGN
DP
@Pa) MAX ALLOW
e C)
osa)
(fi)
(2.1.9)
A P I STD*bLO 95
m
0732290 05qbl8Y 4 T 9
m
2
PAGE
API 610, 8TH EDITION
CENTRIFUGAL PUMP DATASHEET
SI UNITS / IS0 STANDARDS (1.2.2)
1
(SEE
PPUCABCESTANDARD:
3
) API 610
4
)
5
PUMP TYPE: (1.1.2)
6
B
7
8
11
1 OH3
1 OH6
fl
fl
SHAFT DlAMETER
BETWEEN
BEARINGS
B91
VS1
BB2
ka
VS2
88.3
fl
VS3
ka
a
ga 885
fl
7 NOZZLECONNECTIONS 2.3.2
NSCHARGE
15
IALANCE DRUM
16
PRESSURE CASING CONNE
O
0 LUBRICATION
POSmON
3 VENT
1 PRESSURE GAUGE
1TEMP GAUGE
DRNER HALF COUPLING MOUNTED BY:
0 PURCHASER
BASEPLATES:
BASEPLATE
(APPENDIX
NUMBER
M)
0
NON-GROUT(CONSTRUCTION:(3.3.13l5.3.8.3.5)
REMARKS:
MATERIAL
CASING MOUNTING: (SEE SEPARATE SHEET FOR VERTICALS)
0
[7 FOOT
28
0 IN-LINE
0
CENTERLINE
(2.11.1.1) CLASS
NEARCENTERLINE
H 0 APPENDIX
BARREUCASE
o
OAXlAL
31
m I N G TYPE:
32
0 SINGLEVOLUTE 0 MULTIPLEVOLUTE
RADIAL
DIFFUSER
fl BETWEEN
BEARINGS
BARREL
REMARKS
CASE PRESSURERATIW.
0 MAX ALLOWABLE
WORKING
PRESSURE
L
36
WELLER
0 C A S W E U E R WEAR RINGS
O SHAFT
0 DIFFUSERS
0 COUPLINGSPACERMUBS
0 COUPLING DIAPHRAGMS (DISKS)
:MING SPLIT
a OVERHUNG
e C)
0 M N DESIGN
METAL
(2.11.4.5)
TEMP
SEPARATE MWNTING PLATE
ao
35
(mm)
SERWCEFACTOR
CYLINDRICAL THREADS REQUIRED(2.3.3)
27
34
SPACER
0 API
1WARM-UP
3 BALANCEI LEAK-OFF
26
33
LIMITED END FLOAT REQUIRED
0 PUMPMFR. 0 DRNER
MFR.
0 COUPLING PER A P I 671 (5.2.7)
1 DRAIN
20
29
CPLG RATING (kW1100 RPM)
LENGTH
19
2s
W
MODEL
vs5
17
24
(mm)
-PUMP
DRNER
COUPLINGS: (3.2.2)
OTHER
EEEB
14
23
& IMPELLER
vs7
FACING
13
22
(mm)
VS6
VS4
UCTION
21
(mm)
REMARKS
BB4
12
ta
DATE
BY
DATE
0BETWEEN
SPAN
BEARING
CENTERS
0 BETWEEN
SPAN
BEARING
OTHER
9
10
/
CONSTRUCTION (CONT)
8TH EDITION
om
5
ITEM NO.
JOB NO.
REQ / SPEC NO.
PURCH ORDERNO.
INQUIRY NO.
REVISION
CONSTRUCTlON
2
OF
(lea)
e
C)
37
PRESSURE
0 HYDROTEST
BEARINGSAND LUBRICATION
98 1 SUCTION PRESS. REGIONS MUST BE DESIGNED FOR MAWP (2.2.4) B W N G (TYPEfNUMBER):
(e)
39
ROTATW. (VIEWED FROM COUPLING END)
OCW
40
occw
D RADIAL
I
0 THRUST
I
41
1 %WELLERS INDIVIDUALLY SECURED (5.2.2.2)
0 RMEW AND APPROVE THRUST BEARINGSEE (5.2.5.2.4)
42
REMARKS:
LUBRICATION: (2.10)
43
GREASE
fl
44
46
SHAFT:
47
7S
MDW
COUPLING
T E R AT
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
FLOOD
0 PURGE
OIL
RlNGOK
MIST
0 PURE
OILMIST
0 CONSTANT L M L OILER PREFERENCE (SEE REMARKS) (2.92.2)
0 PRESSURELUBESYS(5.2.6)OAPl-610
0 APl-614
BOLT OH3 PUMP TO PADFOUNDATION (5.1.2.4)
46
FLINGER
(mm)
OIL VISC. IS0 GRADE (5.2.6.5)
A P I S T D r b L O 95
0732290 054bL85 335
PAGE
API 610, 8TH EDITION
CENTRIFUGAL PUMP DATASHEET
SI UNITS / IS0 STANDARDS (1.2.2)
1
JOB NO.
REQ / SPEC NO.
PURCH ORDER NO.
INQUIRY NO.
REVISION
ITEM NO.
2
fl OILHEATER REQD'
3
0 OIL PRESSTO BE GREATER THAN COOLANT PRESS(5.2.6.2.b)
4
REMARKS
0 ELECTRICOSTEAM (2.9.2.915.2.6.3)
DATE
BY
DATE
RATE
0 FLOW
N"
SEAL DATA (2.7.2)
0 SEE ATTACHED API-682 DATA SHEET
0 FLOW RATE
g]a
I
B
(Wa)
0 PIPING ASSEMBLY (3.5.2.10.1)
FLOW
(m3/h)
O
THREADED
KI
UNIONS
FMNGED
g]a
TUBE
TYPE
FITTINGS
l9
0SEAL CHAMBER SIZE (TABLE2.3)
g]a
Cl TOTAL LENGTH
O PRESSURE SWITCH
(mm)
LENGTH
(mm)
24
0 AUX SEAL DEVlCE (2.7.3.20)
25
fl JACKET REQUIRED(2.7.3.17)
0 LEVEL GAUGE (PLAN52/53)
0 TEMP INDICATOR (PLANS 21.22,23,32,41)
0 HEAT EXCHANGER (PLAN52/53)
REMARKS
GLAND TAPS: (2.7.3.14)
g]a
29
HEATING (H)
30
fl BARRIERBUFFER@)
DRAN (D)
QUENCH (Q)
BALANCE FLUID (E)
fl COOLING
(C)
LUBRICATION
(G)
fl GE
PUMPED FLUID (P)
fl EXTERNAL FLUID INJECTION(X)
SEAL FLUIDS REQUIREMENT AND AVAILABLE FLUSH
LIQUID
32
NOTE: IF FLUSH LIQUIDIS PUMPAGE LIQUID(ASIN FLUSH PIPING
PLANS 11 TO 41). FOLLOWING FLUSH LIQUID DATA1
s NOT REQD.
34
1
0TEMPERATURE
SUPPLY
"IN
I
NO. OF RINGS
0 RELATIVE DENSITY (SPECIFIC GRAVITY)
OHAZARDOUS
40
41
42
0 PACWNGINJECTION
1
0FLOW
C
'()
I
36 0 NAMEOFFLUID
37 0
Cp
HEAT,
SPECIFIC
38 0PRESSURE
VAPOR
PACKING DATA: (APpamx c)
MANUFACTURER
TYPE
31
33
e C)
(kPa a h ) BI
m
0TEMPERATURE
REQUIRED
WATER COOLING
cc)
I
"IN
"IN
0 RELATIVE
DENSITY
(SPECIFIC
GRAVITY)
46 0 NAME OF FLUID
47
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
cc)
I
C-@
( m ' ~L
(Wa:
( m ' ~
8
C)
REMARKS-
(kpa
e)
( m ' ~BI
TOTAL
0 STEAM PIPING:
BARRlERlElUFFER FLUID(2.7.3.21):
&
(3.5.4.
SEAL
EXCHANGER
HEAT
e) QUENCH
I
e(
e
COOLING WATER PIPINGPLAN
SEAL JACKETIW.0
HSG
(,,/'h)
I
(m%
0 COOLING WATER REQUIREMENTS
0 FLAMMABLE 0 OTHER
0
RATE
FLOW
W I N
0 PRESSURE REWIRED F " l N
REQUIRED
LANTERNRING
STEAM M D COOLING WATER PIPING
C)
@Jkg o C)
44 0 SUPPLY
TEMPERATURE
(PLAN 52/53) TYPE
LEVEL SWITCH (PLAN52/53) TYPE
23
FLUSH (F)
fl SOCKET WELDED
0 PRESSURE GAUGE(PLAN 52/53)
0SLEEVE M4TERlAL
0GLAND MATERIAL
28
O CLW
SEAL CONSTRUCTION:
27
STAINLESS STEEL
PRESSURE
g]a
26
STEEL
CARBON
PIPE
l8
22
STEEL
STAINLESS
TUBING
SEALCHAMBER DATA (2.1.6l2.1.7)
TEMPERATURE
21
CARBONSTEEL
PIPE
0 AUXILIARY FLUSH PLAN
MANUFACTURER CODE
l7
(m'~
fl TUBING
g]a SEAL MANUFACTURER
(QC)
e C)
SEAL FLUSH PIPING:(2.7.3.19AND APPENDIX D)
l3 g]aTYPE
SEE AND
l5
I
(2.1 1.I
.I)0 SEAL FLUSH PIPING PLAN
0 APPENDIX
H
SEAL CODE
l4
Va)
I
"IN
QUENCH FLUID:
ONAMEOFFLUD
lo0 NON-API882 SW(2.7.2)
20
W I N
TEMPERATURE
REQUIRED
MECHANICAL SEAL OR PACKING
(m%
I
0 PRESSURE
REQUIRED
6
l2
/
0 VAPOR
PRESSURE
(kpa a b ) h('
C)
0 HAZARDOUS 0 FLAMMABLE 0 OTHER
S
7
5
MECHANICAL SEAL OR PACKING (CONT)
BEARINGS AND LUBRICATION
(COW)
8
OF
3
(m'/h)
0 TUBING
0 PIPE
API 610, 8TH EDITION
CENTRIFUGAL PUMP DATA SHEET
SI UNITS / IS0 STANDARDS (1.2.2)
1
2
/
DATE
BY
DATE
MOTOR DRIVE(cont) (9.1.5)
REMARKS
VIBRATION:
0 NONCONTACTING (M 670)
4
0 PROVISION FOR MOUNTING ONLY
(2.9.2.11)
0 FLAT SURFACE REQD(2.9.2.12)
6
0 TRANSDUCER
SURFACE PREPARATIONAND PAINT
7
3 SEE ATTACHEDAPl870 DATA SHEET
3 MONITORS AND CABLES(3.4.3.3)
0 MANUFACTURER'S STANDARD
0 OTHER (SEE BELOW)
8
REMARKS
PUMP:
9
0 PUMP SURFACE PREPARATION
10
li
0 PRIMER
0 FINISH COAT
TEMPERATURE AND PRESSURE
b A D W BR0 METAL TEMP O THRUST BRG METAL TEMP
13 0 PROWSION FOR INSTRUMENTS ONLY
14 0 SEE ATTACHEDAPL670 DATA SHEET
BASEPLATE(3.3.18)
15
0 FINISH COAT
SHIPMENT (4.4.1)
12
0 BASEPLATE SURFACE PREPARATION
0 PRIMER
OTEMP GAUGES (WITH THERMOWELLS
) (3.4.1.3)
16
OTHER
17 0 PRESSURE GAUGElYPE(3.4.2.2)
LOCATION
18
3 DOMESTIC
0 EXPORT
0 EXPORT
BOXING
REQUIREC
0 OUTDOOR STORAGE MORE THAN6 MONTHS
19 REMARKS
SPARE ROTORASSEMBLY PACKAGED FOR
20
3 HORIZONTALSTORAGE
0 VERTICALSTORAGE
3 TYPE OF SHIPPING PREPARATION
21
22
23
24
SPARE PARTS(TAME 6.1)
REMARKS
0 NORMALWNTENANCE
0 START-UP
3 SPECIFY
25
0 WEIGHTS
26
27
MOTOR DRIVEN:
WEIGHT OF PUMP (kg)
MOTOR DRIVE (3.1.6)
28
WEIGHT OF BASEPLATE (kg)
MANUFACTURER
29
7
30
fl HORIZONTAL
31
7 FRAME
32
fl S E M E FACTOR
33
0 0
@PM)
lnVERTICAL
WEIGHT OF MOTOR (kg)
WEIGHT OF G
M (kg)
TOTAL WEIGHT(kg)
TURBINE DRIVEN:
I
VOLTSPHASUHERTZ
I
WEIGHT OF BASEPLATE (kg)
34
3 TYPE
WEIGHT OF TURBINE (kg)
35
fl ENCLOSURE
WEIGHT OF GEAR(kg)
36
3 MINIMUM STARTING VOLTAGE
(3.1.S)
37 3 TEMPERATURE RISE
38
2% FULL LOADAMPS
39
fl LOCKED ROTORAMPS
40
2% INSULATION
41
fl LUBE
43
7 VERTICAL THRUST CAPACIN
44
UP
3EARINGS (TYPE I NUMBER):
46
47
TOTAL WEIGHT(kg)
REMARKS
STARTING METHOD
42
45
5
ITEMNO.
JOB NO.
REQ / SPEC NO.
PURCH ORDER NO.
INQUIRY NO.
REVISION
INSTRUMENTATION
3
5
OF
4
PAGE
0 DOWN
J
R
A
D
A
IL
7 THRUST
48
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
I
I
3 RMEW FOUNDATION DRAWINGS(2.1.27)
3 RMEW PIPING DRAWINGS
0 3 OBSERVE PIPING CHECKS
3 OBSERVE INlTlMALIGNMENT CHECK
3 CHECK ALIGNMENT AT OPERATING TEMPERATURE
3 CONNECTION MStGN APPROVAL (2.11.3.5.4)
I
A P I STD*bLO
0732290 05YbL87 L08
95
5
PAGE
API 610, 8TH EDITION
CENTRIFUGAL PUMP DATA SHEET
SI UNITS / IS0 STANDARDS (1.2.2)
1
RIGGING D M C E REQD FOR TYPEOH3 PUMP (5.1.2.7)
3
7
8
' SPARE ROTOR VERTICAL STORAGE(5.2.9.2)
9
' TORSIONAL ANALYSISlREPORT(2.8.2.6)
10
' PROGRESS REPORTS REQUIRED(6.3.4)
EMARKS:
6
Il
3 ALTERNATIVE ACCEPTANCE CRITERIA (SEE REMARKS)
(4.2.2.1)
3 HARDNESS TEST REQUIREDFOR
(4.2.3.;
3 WETTING AGENT HYDROTEST(4.3.2.5)
3 VENDOR SUBMIT TEST PROCEDURES(4.3.1Z6.2.5)
3 RECORD FINAL ASSEMBLY RUNNING CLEARANCES
N)
REMARKS
1
16
1 PERFORMANCE
17
1 SHOP
18
1 TEST WITH SUBSTITUTESEAL (4.3.3.1.2)
R M E W VENDORS QA PROGRAM(4.1.7)
GENERAL REMARKS
CURVE APPROVAL
REMARK 1:
INSPECTION(4.1.4)
19
TEST
20
YDROSTATIC (4.3.2)
21
ERFORMANCE(4.3.3)
NON-WIT
OBSERVE
22
IPSH (4.3.4.1)
O
O
O
23
:OMPLETE UNIT TEST(4.3.4.2)
O
O
O
24
OUND LEVELTEST(4.3.4.3)
25
)
O
O
O
O
O
O
O
O
O
O
O
O
26
CLEANLINESS PRIOR TO
FINAL ASSEMBLY(4.2.3.1)
27
NOZZLE LOAD TEST
(3.3.6)
O
O
O
BR0 HSG RESONANCE
O
O
O
O
O
O
)
29
REMARK 2:
REMARK 3
TEST (4.3.4.5.)
REMOWNSPECT
HYDRODYNAMlC BEARINGS
I
31
32
AFTER TEST(5.2.8.5)
REMARK 4:
) AUXILIARY EQUIPMENT
34
O
O
O
O
O
O
O
O
O
TEST (4.3.4.4)
)
36
I
37
'MATERIAL CERTIFICATION REQUIRED(2.11.1.7)
38
0 CASING
0 OTHER
39
REMARK5
o SHAFT
0 IMPELLER
40
1
41
1 INSPECTION REQUIRED FOR CONNECTION WELDS
(2.11.3.6)
42
CASTING REPAIR PROCEDURE APPROVAL REQD(2.11.2.5)
0 MAG PARTICLE
0 RADIOGRAPHIC
43
44
0 LIQUID
PENETRANT
0 ULTRASONIC
QA INSPECTIONAND TEST
15
35
(4.2.1.3
2 INSPECTION
CHECK-LIST
(APPENDIX
14
33
DATE
BY
DATE
0 MAG
PARTICLE
0 RADIOGRAPHIC
13
30
1
1 ADDITIONAL INSPECTION REQUIRED FOR
12
28
ITEM NO.
HYDRODYNAMIC THRUST BRGSEE RMEW REQD(5.2.5.2.4)
i LATERAL ANALYSIS REQUIRED(5.1.435.2.4.1)
1 ROTOR D Y W C BALANCE(5.2.4.2)
1 MOUNT SEAL RESERVOIR OFF BASEPLATE (3.5.1.4)
1 INSTALLATION LIST IN PROPOSAL(6.23)
5
5
QA INSPECTIONAND TEST ( C O W )
OTHER PURCHASER REQUIREMENTS
(cont)
2
4
JOB NO.
REQ 1 SPEC NO.
PURCH ORDER NO.
INQUIRY NO.
REVISION
OF
)
0 LIQUID PENETRANT
0 ULTRASONIC
INSPECTION REQUIRED FOR CASTINGS(4.2.1.3)
45
0 MAG PARTICLE
46
0 RADIOGRAPHIC
47
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
0 LIQUID PENETRANT
0 ULTRASONIC
REMARK 6:
(4.1.€
VERTICAL
TYPE
(Fio 1.1)
VS1
VS2
1
PAGE
API 610, 8TH EDITION
SUPPLEMENTAL
NO. SHEET
ORDER
VERTICAL PUMP DATA
SI UNITS / IS0 STANDARDS
JOB NO.
REQ f SPEC NO.
PURCH
INQUIRY NO.
VS3
VS4
1
OF
ITEM NO.
f
DATE
BY
VS5
VS6
VS7
g% OTHER
REMARKS
3
4
VERTICAL PUMPS (CONTD)
LINESHAFT:
OLINE S
g% ENCLOSED
OPEN
M D I A M E T E R : ( m m o TUBE DIAMETER:-(mm:
LINE SHAFT COUPLING:
0 SLEEVELKEY
THICKNESS
CAN
0 SUCTION
0
0
0 THREADED
(mm
LENGTH
(m
DIAMETER
(m
0 SUCTION STRAINER TYPE
0 FLOAT 6 ROD
0 FLOAT
SWITCH
0 MPEUER COLLETS ACCEPTABLE(2.5.2)
0 HARDENEDSLEEVES UNDER BEARINGS(5.3.10.7)
0 RESONANCE TEST (5.3.9.2)
0 STRUCTURAL ANALYSIS (5.3.5.1)
0 M W N PIPEDTO SURFACE (5.3.13.6)
CENTERLINE OF DISCHARGE
+
1
SUMP ARRANGEMENT
GRADE
SUMP
DEPTH
PUMP
LENGTH
DATUU
ELEVATION
( I S T STG
IMPELLER)
LOU
LIQUID
- I SUBMERGENCE REQ'D
L -
SUMP DlMENSlOH
REFER TO HYDRAULICINSTITUTE
FOR D E F I N I T I O N S
0
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
STANDARDS
PUMP LENGTH
Lm)
SUBMERGENCE REQ'D
(m)
c]
CENTERLINE
0
DATUM ELEVATION1 -
DISCHARGE
HEIGHT
(m)
~~
~
~~
A P I STD*bLO 95 W 07322900546189
T80 W
1
PAGE
API 610, 8TH EDITION
CENTRIFUGAL
PUMP
DATA
SHEET
US UNITS/ US STANDARDS (1.2.2)
JOB NO.
REP SPEC NO.
WRCH ORDER NO.
OF
5
I T E M NO.
/
DATE
BY
IYPUIRY NO.
REVISION
0 PURCHASE
0 PROPOSAL
APPLlCABLETO
BUILT AS
FOR
UNIT
SERVICE
SITE
PUMP
NO.REQ
MODEL
PlPE
STAGES
NO.
MANUFACTURER
NO.
NOTE: 0 INDICATES INFORMATION COMPLETED BY PURCHASER
7
BYMANUFACTURER
BYMANUFACTURERORPURCHASER
NO. TURBINE DRIVEN
NO. MOTOR DRIVEN
PUMPS TO OPERATEIN (PARALLEL)
TEMMOTOR NO.
0
0 GENERAL (3.1.1)
PUMP ITEMNO.
(SERIES) WITH
lo GEAR
ITEM
PUMP rTEMNO.
NO.
li
PROVIDED
TURBINE
PROVIDED
BYMOTOR
PROVIDED
BY GEAR
BY
l2
MOUNTED
GEAR
MOUNTED
BY
TURBINE
MOUNTED
BYMOTOR
BY
l3
TURBINE
MOTOR
SHEET
SHEET
DATA
NO.
DATA
GEAR
NO.
NO.
14
SITE ANDUTILITY DATA (CONT.)
OPERATING CONDITIONS
(GPM) WATER SOURCE
CONCENTRATION
CHLORIDE
0 CAPACITY,
NORMAL
(GPM)
RATED
l6
OTHER
l7 0 SUCTION
PRESSURE
MAWRATED
I
(PSIG)
0 DIFFERENTIAL
HEAD
(3.5.2.6)
(PFM)
"IN
PRESS
(psw
l8 0 DISCHARGE
PRESSURE
l9 0 DIFFERENTIAL
PRESSURE
2o
INSTRUMENT
AIR:
WIG)
I
LWID
(PSIG) 0 TYPUNAME OF LIQUID
0 0 PUMPING TEMPERATURE
0 NPSHA
21 0 PROCESS
VARIATIONS
N
O
-
(3.1.2)
eF)w
(OF)MN
en
L
e F)
22 0 STARTING
PRESSURE
(Psw
CONDITIONS
(3.1.3) 0 VAPOR
23 SERVICE: O CONTINUOUS OINTERMITENT(STARTIDAYL
0 REIATNE DENSITY (SPECIFIC GRAVITY):
MAX
MIN
NORMAL
24 0 PARALLEL OPERATION REQD
(2.1.11)
25
LOCATION: (2.1.29)
27
0
0
0
0
28
29
31
32
(BTULBCp
0 HEAT,
SPECIFIC
SITE ANDUllIJTY DATA
26
INDOOR
OUTDOOR
GRADE
0 HEATED
0 UNHEATED
0 MEZZANINE
0
UNDERROOF
0 PARTIALSIES
0 WINTERIZATION REQD
33
0 TROPlCALIZATlON
REQD
46
e F)
W)
(2.11.1.8)
PERFORMANCE SITE DATA
I
I
CURVE
NO.
(PSIA) PROPOSAL
CF) 0 IMPELLERMARATED
(%)
0 N M S
STABLE
e
e
44
L
0 CHLORIDE
CONCENTRATION
0
(3.5.2.6)
0 YS CONCENTRATION PPM)
(2.11.1.11)
uclulD(2.1.3)
0 HAu\RDOUS
0 FLAMMABLE
0 OTHER
.a
(2.129)
34 0 ALTITUDE
0BAR-R
0 RANGE OF AMBIENT
TEMPS:
M
W
0
HUMIDFN:
RELATIVE
M l W
37 UNUSUAL
CONDITIONS (2.1.23)
0 DUST
OOTHER
39 0 UTILITY CONDITIONS:
HEATING
DRIVERS
40 STEAM:
41
MIN
(PSW
F)-(PSIG)
42
MAX
(PSW
F)-(Psw
43
(cm
AGENT
OCORROSIM/EROSIVE
0
ELECTRW AREA CLASSIFICATION(2.1.22 I 3.1
DN
CL
GR
o F)
o vlscosm
o MAX VISCosllY
o RPM
MAX
(GFM)
ELECTRICIM:
DRIVERS
HEATING
CONTROL
SHUTDOWN
(S)
THERMAL
0 PREFERRED OPERATING REGION
0 ALLOWABLE OPERATING REGION
eF) 0 MAX HEAD Qp RATED lMpELLER
CF)
MIN-flN)
0POWER
RATED
(BHP) EFFICIENCY
0 MINIMUM CONTINUOUS FLOW:
0 MAX POWER Qp RATEDW E U E R
0 NPSHR AT RATED CAPACITY
SUCTION SPECIFIC SPEED
VOLTAGE
(GM
TO-WW
TO____(OPM)
o
@HP)
(FT) (2.1 .S)
(2.1.9)
HERTZ
0 MAX SOUND PRESS. LEVEL REQ'D
(daA)(2.1.14)
PHASE
1
0 EST MAX SOUND PRESS. LEVEL
(dBA)(2.1.14)
47
COOLING WATER (21.17)
48
TEMPINLET
49
PRESS NORMAL
MINRETURN
(O F) MAX RETURN
(PSIG) DESIGN
(PSIG) MAX ALLOW DP
COPYRIGHT American Petroleum Institute
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CF)
m)
PS0
~
A P I STD*bLO
95
m
m
0732290 0546390 7T2
2
PAGE
API 610, 8TH EDITION
CENTRIFUGAL PUMP DATA SHEET
US UNITS/ US STANDARDS (1.2.2)
1
(SEE
/
DATE
BY
DATE
CONSTRUCTION (CONT)
4
1 OTHER
0 SHAFT DIAMETER
BETWEEN
BEARINGS
0
BETWEEN
BEARING
CENTERS
SPAN
0 BETWEEN
SPAN
BEARING
5
PUMP TYPE: (1.12)
REMARKS
6
9
9
9
WPLICABLE STANDARD:
3
A P I 610 8TH EDITION
7
8
OH2
fl
OH3
OH6
fl
9
10
11
fl
BBl
VS1
B82
VS2
B83
VS3
B84
VS4
12
vs7
-
OTHER
COUPLINGS: (3.2.2)
14
XSCHARGE
1s
)/UANCEDRUM
16
PRESSURE CASING CONNE
FACING
-
DRIVER PUMP
RATING (HP/lOo RFW)
0 LUBRICATION
POSITION
LENGTH
E D END FLOAT REQUIRED
BN)
SPACER
SERVICEFACTOR
DRIVER HALF COUPLING MOUNTED BY:
17
0 PUMPMFR.
20
3 DRAIN
3 VENT
3 PRESSURE GAUGE
21
7 TEMP GAUGE
0
22
J WARMUP
23
7 BALANCE / LEAK-OFF
19
24
2s
0 PURCHASER
0 DRIVER
MFR.
0 COUPLING PER API 671 (5.2.7)
18
BASEPLATES:
0 API BASEPIATENUMBER
(APPENDIX
M
NONOROUT(CONSTRUCTION:(3.3.135.3.8.3.5)
REMARKS:
CYLINDRICAL THREADS REQUIRED (2.3.3)
MATERIAL
CASING MOUNTING: (SEE SEPARATE SHEET FOR VERTICALS)
~
26
27
28
0 CENTERLINE
0 FOOT
0 IN-UNE
0
0
SEPARATE
MOUNTING
PLATE
OAXlAL
31
:MING TYPE:
32
0 SINGLEVOLUTE 0 MULTIPLEVOLUTE
3s
36
37
38
39
40
41
42
o
CF)
o SHAFT
RADW
0
BRWEEN BEARINGS
0 MAX ALLOWABLE
WORKING
PRESSURE
o
CF)
0 HWROTEST PRESSURE
DIFFUSERS
o COUPLINGSPACEWHUBS
0 DIFFUSER
~
o COWLING "S(DISKS)
BARREL
REMARKS
CASE PRESSURE RATING:
(Psw
(psw
SUCTION PRESS. REGIONS MUST BE DESIGNED FOR
MAWP (2.2.4)
BEARINGS AND LUBRICATION
BEARING (TYPUNUMBER):
ORADIAL
0 THRUST
ROTATION (VIEWED FROM COUPLING END)
OCW
(2.11.1.l]
0 CASMMPELLERWEAR RINGS
30
OVERHUNG
~
IMPELLER
0 BARREUCASE
:ASING SPLIT:
34
~~~~
0 APPENDIX H CLASS
DESIGN
0
METAL
MIN
TEMP (2.11.4.5)
NEARCENTERLINE
29
33
ON:
& IMPELLER
MODEL
0
(2.3.2)
fl W
iUCTlON
ON
OMAKE
SIZE(IW
13
ON
VS6
ia
VS5
B85
7 NOZZLECONNECTIONS
5
ITEM NO.
JOB NO.
REP / SPEC NO.
PURCH ORDERNO.
INQUIRY NO.
REVISION
CONSTRUCTION
2
OF
occw
I
I
0 RMEW AND APPROVE THRUST BEARING SIZE (5.2.5.2.4)
IMPELLERS INDMDUALLY SECURED
(52.22)
rEM4Rus:
LUBRICATION(210)
43
GREASE
mFLFLaoD
44
FLINGER
0 PURGE
OILMIST
4s
3 BOLT OH3 PUMP TO PADFOUNDATION(5.1.2.4)
46
SHAFT:
47
7 SHAFTAT
DIAMETER
COUPLING
48
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
RING OIL
0 PURE
OIL
MIST
0 CONSTANT LEML OILER PREFERENCE (SEE REMARKS)(292.2)
0 PRESSURELUBESYS (52.6) OAp1610 0 -14
v9
d
3
PAGE
API 610, 8TH EDITION
CENTRIFUGAL PUMP DATA SHEET
US UNITS / US STANDARDS (1.2.2)
JOB NO.
REP / SPEC NO.
PURCH ORDER NO.
INQUIRY NO.
REVISION
3 OILHEATERREQD
3
1 OIL PRESS TO BE GREATER THAN COOLANT PRESS
(5.2.6.2.b)
3EMARKS
0 ELECTRICOSTEAM
DATE
BY
DATE
" A N
3 SEAL MANUFACTURER
13
TYPE AND3 SIZE
14 3 MANUFACTURER CODE
(Gm
SEAL FLUSH PIPING: (2.7.3.19 AND APPENDIX D)
1 SEAL FLUSH PIPINGPLAN
(2.11.1.1)
3
3
12
I
TUBING
STEEL
CARBON
PIPE
STEEL
STAINLESS
3 AUXILIARY FLUSH PLAN
15
SEAL CHAMBER DATA (2.1.W.1.7)
16
3 TEMPERATURE
3 PRESSURE
3 TUBING
3 PIPE
CF)
FLOW
STEEL
CARBON
g% STEEL
STAINLESS
(PW
3 PIPING ASSEMBLY (3.5.2.10.1)
(Gm
3 THREADED
UNIONS
3 FLANGED
g% TUBE
TYPE
3 PRESSURESWITCH(PLAN 52/53)
19
1SEAL CHAMBER SIZE (TABLE2.3)
20
7 TOTAL
LENGTH
21
SEAL CONSTRUCTION:
3 PRESSURE GAUGE(PLAN 52l53)
22
7 S L E M MATERUIL
7 GLAND MATERIAL
3 LEVEL SWITCH (PLAN 5263)
23
24
3 AUX SEAL D M C E (2.7.320)
25
B JACKET REQUIRED(2.7.3.17)
26
GLANDTAPS: (2.7.3.14)
29
30
a QUENCH (Q)
a HEATINGO
BALANCE FLUID (E)
(IN)
CLEAR
LENGTH
(IN)
fl DRAIN (D)
COOLING
(C)
LUBRICATION
(G)
LEAKAGE
PUMPEDFLUID (P)
PACKING DATA: (APPENDIX C)
MANUFACTURER
EXTERNAL FLUID INJECTION(X)
32
SIZE
33
NOTE: IF FLUSH LIQUIDIS PUMPAGE WUID (AS IN FLUSH PIPING
PLANS 11 TO 41), FOLLOWING FLUSH LIQUID DATA
IS NOT REQD.
34
TEMPERATURE
0 SUPPLY
"IN
35
0 RELATIVE
DENSITY
(SPECIFIC
I
I
GRAW
P
F
)
O
(Psw L
0 VAPOR
PRESSURE
0 HAZARDOUS 0 L-E
F
J LANTERNRING
COOLING
PIPING
WATER
F)
C F)
SEAL JACKETBRG HSG
WIG)
COOUNG
I
"N
en
WATER
I
BARRlERlBUFFER FLUID(27.3.21):
45
0
TEMPERATURE
SUPPLY
"lN
0 RELATNE DENSITY (SPECIFICGRAm.-81-.e
46
0 NAME OF FLUID
CO
I
F)
47
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
~~
~
~
(GW L
(PSK
(GmL
W
(
SEAL HEAT EXCHANGER
(Gm
I
(3.5.4.,
PIAN
0 CoouNo WATER REQUIREMENTS
0 OTHER
MAXlMlN40
RATE
0 FLOW
41 0 PRESSURE
REQUIRED
MAXlMN
44
NO.OF
STEAM AND COOLING WATER PIPING
0 NAME OF FLUID
37
@TULB Cp 0HEAT,
SPECIFIC
43
RINGS
7 PACKING INJECTION REQUIRED
@PM)
C CF) 7 FLOW
36
0 TEMPERATURE
REQUIRED
TYPE
g% BARRIERIBUFFER(B)
TYPE
42
TYPE
REMARKS
SEAL FLUIDS REQUIREMENT AND AVAILABLE FLUSH LIQUID
39
SOCKET
WELDED
FIITINGS
3 LEVEL GAUGE(PLAN 52/53)
3 TEMP INDICATOR(PLANS 21.22.23.32.41)
3 HEAT EXCHANGER(PLAN 52/53)
31
38
eF
I
1 NAME W FLUID
2 SEE ATTACHEDAPI-682 DATA SHEET
3 NON-API 682 SEAL (2.7.2)
11 H2 APPENDIX SEAL CODE
B FLUSH (F)
(PSG
I
7 FLOW
RATE
10
28
@PM:
I
"IN
QUENCH FLUID:
SEALDATA: (2.7.2)
9
27
e F)
0 F W L E 0 OTHER
3 FLOWRATE"IN
3 PRESSURE
REQUIRED
3 TEMPERATURE
REQUIRED
MECHANICAL S W OR PACKING
7
1
(Psw L
)
H
A
Z
A
R
D
O
U
S
6
18
/
) VAPOR
PRESSURE
(2.9.2.96.2.6.3)
5
17
ITEM NO.
MECHANICALSEAL OR PACKING (CONT)
BEARINGS AND LUBFUCATION(cont)
2
8
5
I
1
4
OF
QUENCH
( G W8
(PSU
TOTAL
0 STENAPIPING:
REMARKS
(Gm
0 TUBING
0 PIPE
A P I STDtbLO 95
0732290
0546392
API 610, 8TH EDITION
CENTRIFUGAL PUMP DATASHEET
US UNITS / US STANDARDS (1.2.2)
1
PAGE
JOB NO.
REP / SPEC NO.
PURCHORDER NO.
INQUIRY NO.
REVISION
OF
5
/
DATE
BY
DATE
MOTOR DRNE (cont)(3.1.5)
REMARKS
VIBRATION:
8
9
4
ITEM NO.
INSTRUMENTATION
0 NONCONTACTING (API 670)
0 TRANSDUCER
0 PROVlSlON FOR MOUNTING ONLY(232.11)
0 FLAT SURFACE REQD
'
(2.9.2.12)
0 SEE ATTACHEDAPM70 DATA SHEET
0 MANUFACTURERS STANDARD
0 MONITORS AND CABLES(3.4.3.3)
0 OTHER (SEE BELOW)
REMARKS
PUMP
SURFACE PREPARAllON AND PAINT
0 PUMP SURFACE PREPARATION
0 PRIMER
0 flNlSH COAT
11 TEMPERATURE AND PRESSURE:
BASEPLATE: (3.3,18)
l2 0 RADW BR0 METAL TEMP 0 THRUST BRG METALTEMP
l3 0 PROVISION FOR INSTRUMENTS ONLY
0 BASEPLATE SURFACE PREPARATION
0 PRIMER
0 flNlSH COAT
l4 0 SEE AlTACHED " 6 7 0 DATA SHEET
l5 OTEMP GAUGES (WITH THERMOWEUS
) (3.4.1.3)
l6
OTHER
l7
SHIPMENT (4.4.1)
0 PRESSURE GAUGE TYPE (3.4.2.2)
0 DOMESTIC 0 EXPORT
0 EXPORT
BOXING
REQUIREC
0 OUTDOOR STORAGE MORETHAN 6 MONTHS
l
LOCATION
18
19
575
. I
SPARE ROTOR ASSEMBLY PACKAGEDFOR:
REMARKS
0 HORIZONTALSTORAGE
0 MRTlcAL STORAGE
0 TYPE OF SHIPPING PREPARATION
I
I
-
SPARE PARTS (TABLE 6.1)
24
0 NORMALMAINTENANCE
lo SPECIFY
0 WEIGHTS
26
M T O R DRIVEN:
WEIGHT OF PUMP (LBS)
3
27
MOTOR DRNE (3.1.6)
28
fl MANUFACTURER
29
o
30
31
WEIGHT OF BASEPLATE(LBS)
(HP)
HORIZONTAL
0
SERVlCE FACTOR
33
VOLTSlPHASUnERTZ
WEIGHT OF MOTOR(LBS)
@PM)
WEtGHTOFGEAR(LBS)
VERTICAL
OFRAME
32
TOTAL WEIGHT(LBS)
TURBINE M
N
:
I
WEIGHT OF BASEPLATE (LBS)
I
WEIGHT OF TURBINE (LBS)
OTYPE
WEl<;HT OF GEAR (LBS)
ENCLOSURE
37
0 MINI" STARTING VOLTAGE
0 TEMPERATURE RISE
38
R3 FUULOADAMPS
39
LOCKED ROTORAMPS
40
INSULATION
TOTAL WEIGHT (LBS)
(3.1.6)
lREMARKS
OTHER PURCHASER REQUIREMENTS
41
STARTING METHOD
(
42
LUBE
I9 ROllRN FOUNDATION
44
BEARINGS CrVpE I NUMBER):
46
ORADIAL
0 THRUST
47
3 COORDNATlONlKEllNG REWIRED (6.1.3)
0 MRTlCAL THRUST CAPACITY
UP
W)
45
DRAWINGS(2.127)
3 R M O N PIPING DRAWINGS
I
(Lw I
I
I
I
I
3 CONNECTION DESIGN APPRWAL(2.11.3.5.4)
I
-
48
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
~~
I
~
I
I
~
A P I S T D a b l O 95 W 0732290 0546173 401 W
5
PAGE
API 610, 8TH EDITION
CENTRIFUGAL PUMPDATA SHEET
US UNITS / US STANDARDS (1.2.2)
1
JOB NO.
RER I SPEC NO.
WRCH ORDER NO.
I N W I R Y NO.
REVISION
/
DATE
BY
DATE
c1A INSPECTIONAND T
E
!
3
1(cont)
' RIGGING DEVICE REQD FOR TYPE
OH3 PUMP (5.1.2.7)
3
' HYDRODYNAMIC THRUST BRG SEE REVIEW REQO(5.2.5.2.4)
4
7
1 LATERAL ANALYSIS REQUIRED(5.1.4.j15.2.4.1)
1 ROTOR DYNAMIC BALANCE(5.2.4.2)
1 MOUNT SEAL RESERVOIR OFF BASEPLATE (3.5.1.4)
1 INSTALLATION LISTIN PROPOSAL (6.2.3L)
8
' SPARE ROTOR VERTICAL STORAGE(5.2.9.2)
6
9
' TORSIONAL ANALYSISREPORT (2.8.2.6)
10
' PROGRESS REPORTS REWIRED (6.3.4)
11
EMARKS:
5
ITEM NO.
OTHER PURCHASER REQUIREMENTS(cont)
2
5
OF
1 ADomoNAL INSPEClWN
REQUIRED FOR:
(42.1.:
0 MAG
PARTICLE
0 RADIOGRAPHIC
0 L W I D PENETRANT
0 ULTRASONIC
I'
1 ALTERNATIVE ACCEPTANCE CRITEFUA (SEE REMARKS)(422.1)
1 HARDNESS TEST REQUIRED FOR:
(4.2.3.
12
1 WETTING AGENT HYDROTEST(4.325)
1 VENDOR S U M TEST PROCEDURES (4.3.126.2.5)
3 RECORD FINAL ASSEMBLY RUNNING CLEARANCES
3 INSPECllON
CHECK-LIST
(APPENDIX
N)
13
REMARKS
14
QA INSPECTION AND TEST
15
1
REVIEW MNDORS QA PROGRAM(4.1.7)
16
I
PERFORMANCE CURVE APPROVAL
K
S
GENERAL M
17
' SHOP INSPECTION(4.1.4)
18
P TEST WITH SUBSTITUTESEAL (4.3.3.1.2)
TEST
W 1
OBSERF
YDROSTATIC (4.3.2)
O
O
O
19
20
21
REMARK I:
NON-WIT
ERFORMANCE (4.3.3)
O
O
O
22
PSH (4.3.4.1)
CAWLET€ UNIT TEST(4.3.4.2)
24
OUND LEVELTEST(4.3.4.3)
O
O
O
O
23
O
O
O
O
25
1
O
O
O
26
CLEANLINESS PRIORTO
FINAL ASSEMBLY (42.3.1)
27
' NOZZLE LOAD TEST(3.3.6)
O
28
1 BRG M G RESONANCE
O
O
O
O
O
O
O
O
29
REMOVUlNSPECT
HYDRODYNAMIC BEARINGS
31
32
AFTER TEST(5.2.8.5)
33
b AUXILIARY EQUIPMENT
34
REMARK 4:
O
O
O
O
O
O
O
O
O
TEST (4.3.4.4)
35
b
36
)
37
)MATERIAL CERTIFICATION REQUIRED
(2.1I.I.7)
o CASING
38
39
REMARK 5:
o SHAFT
0 WELLER
0 OTHER
40
)
CASTING REPAIR PROCEDURE APPROVAL REQD
(2.1 1.2.5)
41
)
INSPECTION REQUIRED FOR CONNECTION WELDS
(2.113.5.6)
43
44
REMARK 3
TEST (4.3.4.5.)
30
42
REMARK 2:
O
0 MAG PARTICLE
0 RADIOGRAPHIC
) INSPECTION
0 LIQUID PENETRANT
0 ULTRASONIC
REQUIRED FOR CAsnNGs (4.2.1.3)
45
0 MAG PARTICLE
0 LIQUID PENETRANT
46
0 RADIOGRAPHIC
o ULTRASONIC
47
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
(4.1.1
VERTICALTYPE
(FIG
fl
1.1)
VS1
fl
VS2
1
PAGE
API 610, 8TH EDITION
SUPPLEMENTAL
VERTICAL PUMP DATA SHEET
US UNITS / US STANDARDS
ITEM NO.
JOB 'NO.
REP / SPEC NO.
PURCH ORDER NO.
INQUIRY NO.
VS4
VS3
1
OF
/
DATE
BY
VS5
VS6
VS7
OTHER
REMARKS
3
4 1
5
6
VERTICAL PUMPS
0THRUST
PUMP
W
MIN
FLOW
VERTICAL PUMPS(CONT'D)
(+) up
(-) DOWN
AT
RATED
10
II
'*
(IN)
l3
(Lw
AT
ATMAXFLOW
16
"
l8
(LW
MAXTHRUST
(LW
(LW
SOLEPLATE
(LBS)
(IN)
0
FLANGED
(IN)
0
THREADED
LENGTH
0NUMBER
0LINE SHAFT BEARING
SPACING
(FT)
(IN)
19 GUIDE BUSHING LUBE:
o OIL
0 WATER
0 GREASE
20
21
ENCLOSED
OLINE
SHAFT DIAMETER:-(IN~
0
SLEMLKEY
TUBE DIAMETER:-(IN)
0
DIAMETER
0THREADED
(Lw 0SUCTIONCAN
(IN1 THICKNESS
0 LENGTH
(IN)
X
DIAMETER
GUIDE BUSHINGS:
OPEN
LINE SHAFT COUPLING:
(Lw
0 THICKNESS
SOLEPLATE
l4 COLUMNPIPE:
15
LINESHAFT:
(FT:
(m
0 SUCTION STRAINER TYPE
0 FLOAT L ROD
0 FLOAT
SWITCH
0 IMPELLER COLLETS ACCEPTABLE (2.5.2)
0 HARDENEDS L E M S UNDER BEARINGS(5.3.10.7)
0 RESONANCE TEST(5.3.9.2)
0 STRUCTURAL ANALYSIS(5.3.5.1)
0 DRAIN PIPED TO SURFACE
(5.3.13.6)
0 PUMPAGE
22
CENTERLINE OF DISCHARGE
SUMP ARRANGEMENT
A
T+
DATUM
ELEVATION
(1ST STG
IMPELLER)
PUMP
LENGTH
GRADE
A
LOU
LIQUID
v
A
SUBMERGENCE
REQ'D
W
v
REFER TO HYDRAULIC INSTITUTE STANDARDS
FOR DEFINITIONS
SUMP D IMENSI ON
0
0
0
DES
PU
TH
M
F
[-T
.P
)
LENGTH
SUMP D I M E N S I O N C F T )
LOU LIQUID
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
CFT)
0
0
0
0
PUMP
CFT)
SUBMERGENCE REQ'D
(FT)
CENTERLINE
DISCHARGE
HEIGHT
CFT)
DATUM ELEVATION A
F
T
)
APPENDIX C-STUFFING BOXES FOR PACKING
C.l
Pumps
C S Glands
Glands shall be retained by studs in the pump casing.
Where split glands are used, the halves shall be bolted-or
positively locked-together.
Pumps designedfor packing shouldbe arranged to minimize the pressure in the stuffing box when
the rated suction
pressure is above atmospheric pressure or the pump developed pressure is greater than350 kP (50 psi), unless thrust
balance requirements dictate otherwise. This can be accomplished with rings on the back
of the impeller or with a close
fitting throat bushing with bleed backsuction.
to
C.2
C.6
High-TemperatureService
For services in which the liquid’s vapor pressure is greater
than 100 kPa (14.7 psi) absolute at pumping temperature,
glands shallbe of the water-smotheringtype. For high-temperature service, steam may be substituted for water. When
cooling water piping is providedby the vendor,the flexible
hose or tubingto the quench gland shall have
a minimum inside diameter of 6 mm (%in.).
StuffingBoxes
Stuffing boxes on packed pumps shall have provision
for
seal cages (lantern rings) for the introduction of a cooling
medium directly into the packing. Inlet and outlet connections shall be provided for the seal cage.
C.3 Packing
C.7
Packing for stuffing boxes shallbe a minimum of 10 mm
(%in.) square; however, a packing size of at least 12.5 mm
(!4 in.) is preferred.
C.4
Packing Furnished by the Vendor
If pump packing is furnished by the vendor, it shall be
packaged separatelyfor installation in the field.
Space
Ample space shall be provided for replacing the packing
without removing or dismantling any part other than the
gland and, if split, the seal cage.
c-1
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
C.8
Drain
A drain shallbe provided on vertical pumpsso that noliquid can collect in the driver-supportpiece.
A P I S T D a b l O 95 W 0732290 0546196 I110
APPENDIX D-MECHANICAL SEAL AND PIPING SCHEMATICS
D-1
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
API STD*bLO 75
057
0732290 0546177
m
APPENDIX D-MECHANICAL SEAL AND PIPING SCHEMATICS
This appendix contains schematics for mechanical seals and piping. The notes and key
to symbols for Figures 9-1through D-5 are shown below.
Key to symbols:
Heat exchanger
0
PS
Pressure switch
with block valve
@ gauge
Pressure
with
”
valve
Block valve
Valve A-Inlet shutoff valve
Check valve
Valve B-Branch flow valve
Ofifice
Valve C-Outlet shutoff valve
Cyclone
separator
block valve
@ Dial thermometer @ Flow indicator
Notes:
l . These plans represent commonly used systems. Other variations andsystems are available and should be specified in detail by the purchaser and mutually agreed upon by the
purchaser and the vendor.
2. These plans are for
use with the connection“F’on the single and unpressurized dual seal
arrangements shown in Figure D-1 .
3. For plan 32, the purchaser will specify the fluid characteristics, and the vendor shall
specify the volume, pressure, andtemperature required.
4. When supplemental seal fluid is provided, the purchaser will specify fluid characteristics. The vendor shall specify the volume, pressure, and temperature required, where
these
are factors.
5 . An asterisk (*) indicates an optional item, furnished only when specified.
Symbols for Pump and Seal Gland Connections
Connections
F
L
B
X
Q
C
H
G
E
P
suffix
I
O
Flush
Leakage
BamedBuffer Fluid Injection
Extemal Fluid Injection
Quench
Cooling
Heating
Lubrication
Balance Fluid
Pumped Fluid
Inlet
Outlet
S
Fill
D
Drain
Vent
V
D-3
COPYRIGHT American Petroleum Institute
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A P I STD*bLO 95
m
0 7 3 2 2 9 0 0546398T93
API STANDARD
610
D4
Note 2
ealing
(auxiliary
Note 2
Seal chamber
SINGLE SEAL
Note 2
Note 2
UNPRESSURIZED DUAL SEAL
Nota 2
Note 2
Nota 2
PRESSURIZED DUAL SEAL
Notes:
1, These illustrations are typical and do not represent any specific design or brand of seal.
2. Refer to appropriate pipingplan (Figures D-2 and D-3)for required connections.
Figure D-1"Typical Mechanical Seal Arrangements
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
m
~~
A P I STD*h10 95
0732290 0546399 92T
CENTRIFUGAL PUMPS FOR PETROLEUM, HEAVY
DUTY CHEMICAL, AND
m
GASINDUSTRY SERVICES
D-5
~~
W
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n
v)
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z
4
a
3a
iz.
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c
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
4
A P I STD*bLO 95 M 0732290 O546200 471
D-6
m
API STANDARD
610
c
O
W
C
lu
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
A P I S T D * h L O 95
m 0732290 0546201 308 m
CENTRIFUGAL
PUMPS
FOR PETROLEUM,
HEAVY
D
m CHEMICAL,
AND GAS
INDUSTRY
SERVICES
E
I
L-l
J
œ
W
>
U
t
s
a
9
I
I
A"
*
c
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
I
A P I STD*bLO 95
D-8
m 0732Z90
O546202244
API STANDARD
610
I
s-!
3
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
A P I STD*bLO 95
m 0732270
054b203 L B O
D-9
CENTRIFUGAL PUMPS
FOR PETROLEUM,
HEAVY DUTY
CHEMICAL,
AND GASINDUSTRY SERVICES
~
ò
c
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
A P I STD*bLO 95
m
07322900546204
017
m
API STANDARD
610
D-10
i
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O
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5
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tL]
dl I
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4
9
-7-
COPYRIGHT American Petroleum Institute
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A P I STD*bLO 95
m 0732270
054b205 T 5 3
m
D-1 1
CENTRIFUGAL PUMPS
FOR PETROLEUM, HEAVY
DUN CHEMICAL,
AND GASINDUSTRYSERVICES
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A P I S T D * b L O 95 W 0732290 0546206 99T W
D-12
API STANDARD
61O
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A P I S T D * b L O 95 M 07322900546208762
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COPYRIGHT American Petroleum Institute
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~~
A P I STD*bLO 95
0732290 0546207 bT7
CENTRIFUGAL
PUMPSFOR PETROLEUM, HEAW
DUTYCHEMICAL,
AND GAS INDUSTRY SERVICES
m
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I
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D-15
API STDtbLO 95 m 0732290 0596230 3 L O m
API STANDARD
61O
D-16
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COPYRIGHT American Petroleum Institute
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A P I STDxbLO 95 W 0732270 054b2LL 257 W
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A9
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A P I STD*bLO
95
m
0732290 O546232 L93
m
-"1
Oil reservoir
LEGEND
FI
Flow indicator
TI
Temperature
indicator
PI
Pressure
indicator
0
-iM
Instrument(lettersindicatefunctlon)
Gate valve
Relief valve
PD1
Pressure
differential
indicatoc
-Id-
PSU
Low-pressure
switch
(auxiliary pump start)
&
PSLB
Low-pressure
switch
(alarm)
PSLL
Low-pressure
switch
(trip)
Line
strainer
Pressure control valve
Check vale
bd Block and bleed valve
[sil
Reflex-typelevelindicator
Note: This illustration is a typical schematic and does not constitute any specific design, nor does it
include all details (for example, vents and drains).
Figure D-+Typical
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Pressurized LubeOil System
API S T D M b l O 95 m 0732290 0546213 02T m
APPENDIX E-HYDRAULIC POWER RECOVERY TURBINES
E.l Scope
E.3.3.3 Rotor systems that have low inertia and are subThis appendix applies to reverse-running hydraulic power ject to accidental unloading should be equipped with a
quick-acting brake to prevent damage from overspeed.
recovery turbines (HPRTs) used in the petroleum industry.
E.3.4DUALDRIVERS
When an HPRT is usedto assist another driver, the considerations in E.3.4.1 through E.3.4.4apply.
E.2 Terminology
This standard uses terms that need to be changed or
deleted when the standard is applied to HPRTs. In such a
context, the word pump should be interpreted as meaning
HPRT, the word suction should be interpreted as meaning
ourler, and the word discharge should be interpreted as
meaning inlet. The term netpositive suction head (NPSH) is
not applicable to HPRTs.
E.3.4.1 The main driver should be rated to drive the train
without assistance from the HPRT.
E.3.4.2 An overrunning clutch (that is, a clutch thattransmits torque in one direction and freewheels in the other)
should generally be used between the
HPRT and the trainto
allow the driven equipment
to operate duringHPRT maintenance and to permit start-up of the train before the HPRT
process stream is lined up.
E.3 Design
E.3.1FLUIDCHARACTERISTICS
E.3.4.3 Flow to the HPRT may vary widely and freThe purchaser will advise the HPRT manufacturer
quently.
When the flow drops to about 40 percent of the
whether any portion of the process stream entering the HPRT
rated
flow,
a drag may be imposed on the main driver. An
will flash to vapor and whether absorbedgas in the stream
overrunning
clutch will prevent this drag.
will evolveat any pressure less than the inlet pressure.
In either case, the purchaser must specify the volume
percentage
E.3.4.4 The HPRT should never be placed between the
of vapor or gas or both at the turbine outlet and the pressure main driver and the driven equipment.
and temperature at which the vapor will flash off. When
E.3.5
GENERATORS
known, the fluid composition, and the liquid and vapor (or
gas) density versus pressure shouldalso be specified.
When a generator is driven
by an HPRT on a gas-rich process stream, the generator should be generously sized. The
E.3.2SEALFLUSHINGSYSTEM
output power of HPRTs can be as much as 20 to 30 percent
To avoid shortening seallife, consideration mustbe given
or more over that predictedby water tests, as a result of the
to evolution of gas and vaporizationin seal flushing streams.
effects of evolved gas or flashed liquid.
Where this potentialexists, a seal flush from other than the
E.3.6THROTTLEVALVES
HPRT inlet is generally recommended.
For most applications, valves used to control flow tothe
E.3.3
OVERSPEED
TRIP
HPRT should be placed upstream and near the inlet of the
E.3.3.1 An overspeed trip should be considered when the
HPRT (see Figure E-1).Placement upstreamallows the meHPRT and other equipment in the train cannot tolerate the
chanical seals to operate at the outlet pressure of the HPRT
and, for gas-rich streams, permits the gas to evolve, which
calculated overspeed (runaway speed).It is important to realize that overspeed with
inlet liquids rich in absorbed
gas or
increases thepower output.
with liquids that partiallyflashas
they flow through
E.3.7BYPASSVALVES
the HPRT can be several times higher than overspeed with
water. Withsuch liquids, the overspeedcahot be accurately
Regardless of the arrangement of the HPRT train, a fulldetermined.
flow bypass valve with modulation capability must be installed. Common control
of the modulating bypass valve and
E.3.3.2 The risk of overspeed is reduced whenthe driven
the HPRT inlet control valve is normally achieved by means
equipment, such as a pump or fan, cannot realistically be expected to lose function.
The risk is increased when the driven of a split-level arrangement (see Figure E- 1).
equipment isa generator, since a sudden disconnection from
E.4
Testing
electric power circuits will unload the HPRT. In the latter
case, automatic sensing and dummy-load switching should
E.4.1 The HPRT should receive a performance test at the
manufacturer’s test facility.
be provided.
E-I
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API STD*bLO 95 m 0732290 054b2L4 T b b m
E-2
API STANDARD
610
E.4.2 Figure E-2 shows recommended test performance
tolerances for HPRTs. The pump criteria given in the text of
this standard areapplicable.
not
E.4.3 Vibration levels for HPRTs shouldmeetthe criteria
for pumps
given
in this standard.
COPYRIGHT American Petroleum Institute
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E.4.4 Itmay be useful to verifytheoverspeed trip setting
for the HPRT at the manufacturer’s test facility. Determining
the runaway speed during a water test may be considered,
but this speed canbe accurately calculated once performance
with water is known. Runaway speed for gas rich-steams
cannot be determined by water
tests.
API STD*b10 95 m 0732290 0546215 9T2
CENTRIFUGAL PUMPS FOR PETROLEUM,
E-3
HEAVY
DUTY CHEMICAL, AND GASINDUSTRY SERVICES
High-pressure
,.
PUMP DRIVE
#
;
To low-pressure 4
A
vessel
I
Motor
HPRT
PumD
clutch
Generator
HPRT
GENERATOR DRIVE
Figure E-1-Typical HPRT Arrangements
COPYRIGHT American Petroleum Institute
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If
E4
API STANDARD
610
1
Flow
COPYRIGHT American Petroleum Institute
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9k%
105%
A P I STD*bLO 95
0732290 054b2L7 775
APPENDIX F-CRITERIA FOR PIPING DESIGN
F.l
Horizontal
Pumps
F.l.l Acceptable piping configurations should not cause
excessive misalignment between the pump and driver. Piping configurations that produce component nozzle
loads lying within the ranges specified in Table 2.1A (2.1B) will
limit casing distortion to one half the pump vendor’sdesign
criterion (see 2.2.8) and
will ensure pump shaft displacement
of less than 250 pm (0.010 in.).
F.1.2 Piping configurationsthat produce loads outside the
ranges specified in Table 2.1A (2.1B) are also acceptable
without consultation with the pump vendorif the conditions
specified in F.1.2.1 through F.1.2.3 are satisfied. Satisfying
these conditions will ensure that anypump casing distortion
will be within the vendors design
criteria (see 2.2.8) and that
the displacement of the pump shaft will be less than 380 pm
(0.015 in.). Note: This is a criterion for piping design only.
(F-2)
(F-4)
MRCA < 1.5(MRs~z+ MRDn)
(F-5)
Verticalln-LinePumps
P=(012)+(0214+Z2)0~~<41
F.1.2.3 The applied component forces and moments acting
on each pump nozzle flange must be translated to the center
of the pump. The magnitude of the resultant applied force
(FRCA),the resultant applied moment (MRCA), and the applied momentshall be limited by Equations F-3, F-4, and F5. (The sign convention shown in Figures 2.2-2.6 and the
right hand rule should
be used in evaluating these equations.)
MYCA< 2.O(MYSn + MYDT~)’”
Note: When U.S. units are used, the constant loo0 must be changed to
12. This constant is the conversion factorto change millimetersto meters or
inches to feet.
Vertical in-line pumps that are supported only by the attached piping may be subjected to component piping loads
that are more than double the values shown in Table 2.1A
(2.1B) if these loads do not cause a principal stress greater
than 41 MPa (5950 psi) ineither nozzle. For calculation purposes, the section properties of the pump nozzles shall be
based on Schedule 40 pipe whose nominal size is equal to
that of the appropriate pump nozzle. Equations F-6A (F-6B),
F-7A (F-7B), and F-8A
(F-8B) can be used to evaluate prinshear stress, respectively,
cipal stress, longitudinal stress, and
in the nozzles.
(FRSA 11.5FRS~z)+ (MRSA I 1.5MRSn) I 2(F-1)
(F-3)
MZCA = MZSA + MZDA - [(FXSA) (YS)+ (FXD&D)
- (FYSA)(xS) - (FYDA) (a)]
I loo0
F.2
F.1.2.2 The resultant applied force (FRSA, FRDA) and the
resultant applied moment (MRSA, MRD,) acting on each
pump nozzle flange shall satisfy the appropriate interaction
equation (Equations F- 1 and F-2).
FRCA < 1.5(FRSn + F R h z )
MYCA = MYSA + MYDA + [(FXSA) (zS)+(FXDA)(ZD)
- (FSA)(XS) - (FmA) (fl111 1000
F.1.3 Piping configurations that produce loads greater than
those allowedin F. 1.2 shall be mutually approved by the purchaser and the vendor.
F.1.2.1 The individual component forcesand moments acting on each pump nozzle flange shall not exceed the range
specified in Table 2.1A (2.1B)
by a factorof more than2.
(FRDA I ISFRDT~)
+ (MRDA I ISMRDT~)I2
MXCA= MXSA + MXDA- [(FYSA)(zS) + (FYDA)(zD)
- (FZSA)6s)- ( m ~
(@)I) 1 loo0
B=
[ 1.27 FYI (Do2 - D?)]
+ [1.O2 X l$Do(M@ + M$)”’]
= [ 1.27(F$
+
I (D$ - 4 4 )
(F-7A)
I (Do2 - D?)
+ [0.51 x 104Do(MY)] I (Do4-D?)
(F-SA)
For U.S. units, the following equations apply:
P = ( 0 / 2 ) + ( 4 2 / 4 + 72)0.5<5950
(3
z
FRCA = [(FXCA )2+ (FYCA)2 + (FZCA)2]0.5
I (D$ - D?)
(F-7B)
= [ 1 . 2 7 ( ~+
~ 2~22)0.511 (o02
-4 2 )
+ [61Do(MY)]/ (Do4- D?)
FXCA= FXSA + FXDA
(F-6B)
= [1.27 FYI (Do2- D?)]
+ [ 122D0(MX2+ MZ 2)”]
Where:
(F-8B)
Note: FX,FY,F Z , MX,MY,and M2 represent the applied loads acting
on the suction or discharge nozzles; thus, suffixes SAand DA have been
omitted to simplifythe equations. The signof FY is positive if the load puts
is negative if the load puts thenozzle in comthe nozzle in tension; the sign
pression. One must referto Figure 2.2 and the applied nozzleloads to determine whether thenozzle is in tensionor compression. The absolute value
of
M Y should be used in Equation F-8A
(F-SB).
FYCA = FYSA+ FYDA
FZCA = F D A + F Z D A
MRCA = [(MXCA)2 + (MYCA )2 + (MZCA)2
F-1
COPYRIGHT American Petroleum Institute
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(F-6A)
~
F-2
F.3
Nomenclature
The following definitions applyto the sample problems in
F-4:
c =center of the pump.
D
DI
D,
F
FR
M
MR
P
S
x, y, z
X,Y, Z
0
T
SubscriptA
Subscript 72
For pumptypes OH2
and BB2 with two support pedestals, the
center is definedby the intersectionof the
pump shaft centerline and
a vertical plane
passing through the center of the two
pedestals (see Figures2.5 and 2.6). For
pump types BBl, BB3, BB4 and BB5
with four support pedestals, the center is
defined by the intersectionof the pump
shaft centerline anda vertical plane passing midway between the four pedestals
(see Figure 2-4).
= discharge nozzle.
= inside diameter of Schedule 40 pipe
is equal to that of the
whose nominal size
pump nozzle in question, inmm (in.).
= outside diameter of Schedule 40 pipe
whose nominal size is equal to that of
the pump nozzle in question, in
mm
(in.).
= force, in N (lbs).
= resultant force.(FRS, and
are calculated by the square root of the sum of
the squares method using the applied
component forces acting on the nozzle
flange. FRSn and FRD, are extracted
from Table 2.1A (2.
lB), using the appropriate nozzle size.)
= moment, in Nm (ft-lb).
= resultant moment.(MRSA and MRDA are
calculated by thesquareroot of the
squares method using the applied
componentmomentsactingonthenozzle
flange. MRS, and M D T 2are extracted
from Table 2.1A (2.1B) using the appropriate nozzle size.)
= principle stress, in MPa (psi).
= suction nozzle.
= location coordinatesof the nozzle flanges
with respect to thecenter of the pump,in
mm (in.).
= direction of theloads(seeFigures
2.2-2.6).
= longitudinal stress, in MPa (psi).
= shear stress, in MPa (psi).
= applied loads.
= loads extracted from Table 2-1A (2-1B).
COPYRIGHT American Petroleum Institute
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SampleProblems
F.4
F
R
D
,
EXAMPLE1A ( S.I. UNITS)
FA1
F.4.1.1
Problem
For an overhung end suction processpump, the nozzle
sizes and location coordinates are as given in Table F-1A.
The applied nozzleloadings are as given in Table F-2A.The
problem is to determine whether theconditions specified in
F.1.2.1, F.1.2.2, and F.1.2.3 are satisfied.
F.4.1.2
F.4.1.2.1
Solution
A check of condition F.1.2.1 is as follows:
For the lONPS endsuction nozzle,
I FXS, / FXS, I = I +12,900 / 6670 I = 1.93 < 2.00
IFYS,/FYS,I=
I0/53401 =0<2.00
I F Z S , / F Z S , I = 1-8852/44501 =1.99<2.00
IMXS,/MXS,I=
1-1356/50201 =0.27<2.00
I MYSA/ M Y S , I = 1-5017 / 2440 I = 2.06 > 2.00
I M Z S A / M Z S , I = 1-7458 / 3800 1 = 1.96 < 2.00
2.1A by more
Since MYS, exceeds the specified in Table
than a factorof 2, it is not satisfactory. Assume thatMYS,
can be reduced to -4879. Then,
I MYS, / M Y S , I =
1 4 8 7 9 / 2440 I = 1.9996 < 2.00
For the 8NPS topdischarge nozzle,
= 1+7117/37801 =1.88<2.00
IFYD,IFYD,I = 1-445/31101 =0.14<2.00
I F D A / F Z D , I = I +8674 / 4890 I = 1.77 < 2.00
IFXD,/FXD,I
l M X D , I M x D , I = 1+678/35301 =0.19<2.00
I MYDA/ MYD, I = 1-3390 / 1760 I = 1.93 2.00
I MZDA / MZD, I = I 4 8 8 2 / 2580 I = 1.89 < 2.00
Provided that MYS, can be reduced to-4879, the applied
piping loads actingon each nozzle satisfythe condition specified inF. 1.2. l.
F.4.1.2.2 , A check of condition F.1.2.2 is as follows:
For the suction nozzle, FRSA and MRSA are determined
using the square root of the sumof the squares method:
Table F-1A-Nozzle Sizes and Location
Coordinates for Example 1A
Suction
Discharge
lONPS
SNPS
+267
O
O
O
-311
+38 1
A P I STD*bLO
95
m
CENTRIFUGAL
PUMPSPETROLEUM,
FOR
0732290 0546239 548
HEAWDUTY CHEMICAL, AND GASINDUSTRY SERVICES
FZCA = (-8852)+ (+8674)
FRC, = [(+20017)2
Value
(newtons) meters)
(newton
Moment
Fzs,
O
-8852
FXDA
+7117
-1356
-5017’
-7458
”=A
Discharge
MXDA
MYDA
MZDA
-445
FYDA
+8674
+ (-445)2
=-178
+ (-178)2]O.’= 20023
Referring to Equation F-3,
Suction
MXSA
MYSA
+12900
FXSA
FYSA
F-3
FYCA = ( O ) + (-445) = -445
Table F-2A-Applied Nozzle Loadings
for Example 1A
Force
m
+678
-3390
-4882
FRCA C l.S(FRS,
+ FRD,)
20023 c 1.5(9780 + 6920)
20023c 25050
MYC, is determined as follows (see F.1.2.3):
MYCA = MYS,
+ MYDA + [(FXSA)(zS) +(FXDA)
(zD)
- (FZS,)(xS)- (FZD,)
‘See F.4.1.2.l.
1 lo00
= (4879)+ (-3390)+ [(+12900) (0.00) +
FRSA = [ ( F X S A ) ~( F Y S A ) ~( F Z S A ) ~ ] ~ ’ ~
= [(+12,900)’ + (O)’+
(-8852)’IO.’ = 15645
MRSA = [ ( M x s ~ )MYS
~ SA)^
(MDA)~]”~
+ (-4879)’+ (-7458)’IO.’= 9015
= [(-1356)2
Referring to Equation F-1,
(FRSA I 1.5FRSn) + (MRSAI 1.5MRSn) I2
15645 I [1.5(9780)] + 9015I [1.5(6750)1 I 2
1.96c 2
For the discharge nozzle,FRDA and MRDA are determined
by the same method usedto find FRSA and MRSA:
FRDA = [(FXDA)2+ (FYDA)2+ (FZDA)~]~.’
= [(+7117)2
+ (-445)2 + (+8674)2]0.5= 11229
MRDA = [(MxDA)2+ (MYDA)’
= [(+678)2
+ (iwu)A)2]o.5
+ (-3390)’+ (-4882)’l”’= 5982
Referring to Equation F-2,
+ (MRDAI 1SMRD,) I2
11229I [1.5(6920)] + 5982I [1.5(4710)] I 2
(FRDA I 1SFRD,)
1.93C 2
The loads acting on each nozzle satisfy
the appropriate interaction equation,so the condition specified Fin
.1.2.2is satisfied.
F.4.1.2.3
A check of condition F. 1.2.3is as follows:
To check this condition,
the applied component forces
and
moments are translated and resolved to the center of the
pump. FRC, is determined as follows (see F.1.2.3):
FXCA = FXSA + FXDA
(+7117) (+381)
- (-8852)(+267) (+8674)(0.00)] I lo00 = -3194
Referring to Equation F-4,
MYCA < 2.0(MYS, + MYD,)
-3194< 2.0(2440 + 1760)
-3 194< 8400
MRCA is determined as follows (see F. 1.2.3):
MXCA = MXSA + MXDA - [(FYSA)(zS) +(FYDA)
($1 - ( F D A )(YS)- (FZD,) OD)]1 lo00
MYCA = MYS, + MYDA + [(FXSA)(zS) +(FXDA)
(a)
- (FZS,)(xS) - (FZD,)(xD)]
1 lo00
MZCA = M Z S , + MZDA - [(FXSA)(YS)+(FXDA)
( y o ) -(FYS,) (xS) (xD)lI lo00
MRC, = [F(MXCA12 + (MYC, )2 + (MZCA)2]O.’
MXCA = (-1356)+ (+678)- [(O) (0.00)
+ (445)(+381)(-8852) (0.00) - (+8674)(-3 1])l I loo0
= -3206
MYC, = -3194 (see previous calculation)
MZCA = (-7458)+ (-4882)- [(+129OO)(O.00) +(+7117)
(-311) - (0)(+267) - (-445)(0.00)] I lo00
= -10127
MRCA = [(-3206)2 + (-3194)’ + (-10127)’]0.5 = 11092
Referring to Equation F-5,
MRCA C 1.5(MRSn + MRD,)
11092C 1.5(6750 + 4710)
11092< 17190
Thus, all of the requirements of F.1.2.3have been satisfied.
FYCA = FYSA + FYDA
F.4.2
FZCA = FZS, + F W A
F.4.2.1
FRCA = [(FXCA)2 + (FYCA )2 + (FZCA )2]0.5
FXC, = (+12900)+ (+7117)= +20017
COPYRIGHT American Petroleum Institute
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EXAMPLE 2A (S.I.UNITS)
Problem
For an 80 x 100 x 178vertical in-line pump,the proposed
applied nozzle loadings are as given in TableF-3A.By in-
A P I STD*bLO 95
m
F4
0 7 3 2 2 9 0 054b220 2bT W
API STANDARD
610
Table F-SA-Proposed Applied Nozzle
Loadings for Example 2A
Force
Force
Value
(N)
FXSA
FYSA
-2224
-5338
+I334
m
A
FXDA
FYDA
+1334
-2224
Moment
4NPS Suction
MXSA
MYSA
“=A
3NPS Discharge
MXDA
MYDA
+445
Value
(Nm)
+I36
-2034
+1356
+2712
+27 1
+I36
P,=(6,/2)+(6,2/4+2,2)0,s<41
= (+23.52 / 2) + [(+23.52)2/4 + (+20.77)21°.’
= +35.63 < 41
Thus, the suction nozzle loadsare satisfactory.
F.4.2.2.2 Discharge nozzle calculations are as follows:
For Schedule 40 pipe with a nominalsize of 80 mm,D, =
89 mm and D, = 78 mm. Therefore,
Do2 - DIZ=(89)2 - (78)2 = 1837
D04 - D? = (89)4 - (78)4 = 2.573 x 10 7
[(FXDA)~
+ (FZDA)~]~”=
[(+1334)2(+445)21°.’
spection, FZT,, M B A ,and MXDA are greater thantwo times
the values shownin Table 2.1A. As stated inF.2, these component loads are acceptable provided that the calculated
principal stress is less than 41 MPa.The problem isto determine the principal stress for the suction nozzle and the discharge nozzle.
F.4.2.2
Solution
= 1406
[(MXDA)~
+ (MZDA)~]O.~
= [(+2712)2+ (+136)21°.’
= 2715
Equation F-7A is used
to determine the longitudinal stress
for the discharge nozzle, 6,.
Note: the applied FYDA load acting on the discharge nozzle is in the
negative l‘direction and will produce a tensilestress; therefore, a positive
sign on FYDA is used.
6,=[1.27FYDA/(DO2-D3)]
F.4.2.2.1 Suction nozzle calculations are as follows:
For Schedule 40 pipe with a nominal size
of 100 mm,
D, = 114 mm and D, = 102 mm. Therefore,
[ 1.o2 X ~@DO(MXDA~
~ ~ Z D A ~/ ) ” ]
(Do4- Dl4>
= [1.27(+2224) / 18371 + [1.02 x 1@(89) (2715)l
/ 2.573 X lO7= 97.33
Do2 - D? = (114)2- ( 102)2= 2592
DO4-DI4=(114)4-(lO2)4=6.065x 107
( F ~ L ~ A =) ~[(-2224)2
]~”
+ (+1334)2]05
[ ( F x s ~+) ~
= 2593
[(MXSA)~
+ (MZSA)~]~.’
= [(-136)2 + (+1356)2]05
= 1363
stress
Equation F-7Ais used to determine the longitudinal
for the suction nozzle, 6 ,.
Note: the applied FYSA load actingon the suction nozzle is in the negative
Y direction and will produce a compressive stress; therefore, the negative
sign on FYSA is used.
Equation F-8Ais used to determine theshear stress for the
discharge nozzle, z D.
Z D = [ I.~~(FXDA’
+ FZDA~)’’1 / (Do2 - Dr’)]
+ [OS1 X ~@D,(MYDA)]/ (D$
= [1.27(1406)/ 18371 + [OS1 X 1@(89)(I +271 I )] /
2.573 X lO7]= 5.75
The principal stress for the dischargenozzle, P,, is calculated using Equation F-6A:
PD=(~D/2)+(6D2/4+TD2)0.5<41
(3,=[1.27FYsA/(Do2-D?)]+
= (+97.33/2) + [(+97.33)2/ 4 + (+5.75)21°.’
= +97.67 > 41
+
[ 1-02x 1@D&fxsA2 M=A2)o‘5] /
(Do4 - 04)
= [1.27(-5338)/2592]+ [1.02 X 1@(114) (1363)]/
6.065 X lo7= 23.52
Equation F-8Ais used to determine the shear stress for the
suction nozzle, Z ,.
Thus, the discharge nozzle loads
are too large. By inspection, if MXDA is reduced by 50 percent to 1356 Nm, the resulting principal stress will still exceed 41 MPa.Therefore,
the maximum value
for MXDA will be twice MXD,, or 1900
Nm.
T ,= [ 1.27(FXSA2+ F ~ A ~ /) (Do2
~ ” -] D?)]
+ [ O S 1 X ~@D,(MYSA)]/ (Do4- DI4)
= [1.27(2593) / 25921 + [0.51 X 1@( 114)
( 1-20341 )] / 6.065 x lo7] = 20.77
The principal stress for
the suction nozzle,P,, is calculated
using Equation F-6A:
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
-4 4 )
F.5.1
F.5.1.1
EXAMPLE 1B (U.S. UNITS)
Problem
For an overhung end-suction process pump, the nozzle
sizes and location coordinates are as given in Table F-1B.
The applied nozzle loadingsare as given in Table F-2B.
The
CENTRIFUGAL P U M P S FOR PETROLEUM,
HEAVY
DUTY CHEMICAL, AND
F.5.1.2.2
Table F-1B-Nozzle Sizes and Location
Coordinates for Example 1B
(in.)
(in.)
Nozzle
Suction
Discharge
Size
(in.)
X
10
+10.50
8
O
Y
L
(in.)
+I5
problem isto determine whether theconditions specified in
F.1.2.1,F.1.2.2, andF.1.2.3 aresatisfied.
F.5.1.2
F.5.1.2.1
A check of condition F.1.2.2 is as follows:
FRSA = [(FxsA)2+ (FYsA)2+ ( F z s ~ ) ~ ] ~ ’
= [(+2900)2+ (0)2+ (-1990)2]05= 3517
MRSA = [(MxsA)2+
+ (h!fBA)2]05
= [(-1000)2+ (-3599)2 + (-5500)2]05 = 6649
Referring to Equation F- 1,
(FRSA / 1.5FRS,)
Solution
A check of condition of F, 1.2.1 is as follows:
+ (MRSA / 1.5MRST,) I 2
35 17 / [ 1.5(2200)]+ 6649 / [ 1.5(5OOOj] S 2
1.95
For the IO-in. end suction nozzle,
I FXSA / FXSTZ I = I +2900 / 1500 I = 1.93 < 2.00
IFYS,/FYS,I
= 10/12001 =0<2.00
I FZSA / FZS, I = I -1990 / 1000 I = 1.99 < 2.00
IMXSp,IMXS,I
F-5
SERVICES
For the suction nozzle, FRSA and MRSA are determined
using the square root
of the sumof the squares method:
O
O
-12.25
GASINDUSTRY
= I-l000/37001 =0.27<2.00
IMYS, / MYST, I = I -3700 / 1800 I = 2.06 > 2.00
I MZSA / MZST, I = I -5500 / 2800 I = 1.96 < 2.00
Since MYS, exceeds the specified in Table 2.1B by
more than a factor of 2, it is not satisfactory. Assume that
MYS, can be reducedto -3599. Then,
For the discharge nozzle,
FRDA and MRDA are determined
by the same method usedto find FRSA and MRSA:
FRDA = [(FXDA)2+ (FYDA)2+ ( F Z D A ) ~ ] ~ ’ ’
= [(+1600)2+ (-100)2 + (+1950)2]O” = 2524
MRDA = [MxDA)2+ MY DA)^ + (MZDA)~]”’
= [(+500)2+ (-25OOj2 + (-3600)2]0.s= 441 1
Referring to Equation F-2,
(FRDA / 1SFRDnj
+ (MRDA / 1.5MRDT,) I 2
2524 / [1.5(1560)]+ 4411 / [1.5(3500)] I 2
I MYSA / MYS,, I = I -3599 / 1800 I = 1.9996 < 2.00
For the 8-in. top discharge nozzle,
I FXD, / FXD, I = I +1600 / 850 I = 1.88 < 2.00
IFYDA/FYDT,I = I-l00/7001 =0.14<2.00
2
1.92 < 2
The loads actingon each nozzle satisfy the appropriate interaction equation, so the condition specified in F.1.2.2 is
satisfied.
I FZDA / FZDT, I = I +1950 / 1100 I = 1.77 < 2.00
IMXDAIMXDnI = 1+500/26001 =0.19<2.00
F.5.1.2.3
I MYDA / MYDn I = I -2500 / 1300 I = 1.93 < 2.00
I MZDA / MZD, I = I -3600 / 1900 I = 1.89 < 2.00
and
To check this condition, the applied component forces
moments are translated and resolved to the center of the
pump. FRC, is determined as follows (see F.1.2.3):
Provided thatMYSA can be reducedto -3599, the applied
piping loads actingon each nozzle satisfy the condition specified in F.1.2.1.
Force
FXSA
FYSA
FDA
+ 2900
O
-1990
F W A
a
FYCA = FYSA + FYDA
FRCA = [(FXCA )2 + (FYCA )2 + (FZCA )2]0.s
FXCA = (+2900) + (+1600) = +4500
Moment
Suction
MXS,
MYSA
M B A
(ft-lbs)
+I600
MXDA
-100
MYDA
+I950
MZDA
See F.4.1.2.1
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
FYCA = ( O ) + (-100) = -100
+ (+1950) = -40
FRC, = [(+4500)2 + (-1oo)2 + (-40)2]0.5 = 4501
FZCA = (-1990)
-lo00
-37Ooa
-5500
Discharge
FXDA
FYDA
FXCA = FXSA + FXDA
FZCA = FZS, + FZDA
Table F-2B-Applied Nozzle
Loadings for Example 1B
Value
(lbs)
A check of condition F. 1.2.3 is as follows:
+SOO
-2500
-3600
Referring to Equation F-3,
FRCA < l.S(FRS,
+ FR&)
4501 < 1.5(2200 + 1560)
4501
5640
A P I STDxLLO 95
m
0732290 O546222 032 m
API STANOARO
610
F-6
Table F9B”Proposed Applied Nozzle
Loadings for Example 28
MYC, is determined as follows (see F.1.2.3):
MYCA = MYSA + MYDA + [(FXSA) (zS) +
(FXDA)(tD) - (FZS&S)
Value - (FZD,) (xD)] I 12
= (-3599) + (-2500) + [(+2900) (0.00)+ ( + l m )
(+15) - (-1990)(+10.5)- (+1950)(0.00)]I 12
= -2358
Referring to Equation F-4,
Moment
(Nm)
4NPS
-500
-1200
+300
FXSA
FYSA
FDA
I MYCAI c 2.0(MY&MY&)
I -2358 I
Value
(N)
Force
+lo0
MXSA
MYSA
-1 500
+IO00
“=A
3NPs
C 2.0 (1800 + 1300)
+300
FXDA
FYDA
FZD,
2358 c 6200
+2000
MXD,
MYDA
-500
+200
+lo0
+lo0
MRCA is determined as follows (see F. 1.2.3):
MXCA = MXSA + MXDA - [(FYSA)(zT)+
.
(FYDA)(zD)- (FzDA) (yD)]
I 12
MYCA = MYSA + MYDA + [(FXS,)(zS) +(FXDA)(zD)
- (FZS,J(xS) - (Fu),) (xD)] I 12
MZCA = MZS, + MZDA - [(FXSA)glS) +
(FxDA)(YD) - (FYSA)(XS)- (FYDA) bD)l
I 12
F.5.2.2
SOLUTION
F.5.2.2.1
Suction nozzle calculations are as follows:
For Schedule-40 pipe with a nominal size of 4 in., Do =
4.500 in. andDI = 4.026 in. Therefore,
Do2 - DF = (4.500)’ - (4.026)’ = 4.04
D04 - D? = (4.500)4 - (4.026)4 = 147.34
MRCA = [(MXCA )2 + (MYCA 12 + (MZCA)’
[(FxSA)2+ (FBA)2]o’5
= [(-500)2 + (+300)’]0.5 = 583
MxcA = (-1OOo) + (+500) - [( 0 ) (0.00)+ (-100)
(+15.00) - (-1990) (0.00)- (+1950) (-12.25)]
I 12 = -2366
[(MXSJ2
= 1005
+
(MZSA)’]~” =
+
(+1000)2]0’5
MYCA= -2358 (see previous calculation)
Equation F-7B isused to determine the longitudinal stress
for the suction nozzle, 6,.
MZCA = (-5500) + (-3600) -[(+2900)(0.00) + (+1600)
(-12.25) - (0)(+10.50) - (-lOO)(O.Wj
/ 12 = -7467
Note: The appliedFYSAload acting on the suction nozzleis in the negative Y direction and will produce a compressive stress; therefore,the negative signon FYSA is used.
MRCA = [(-2366)2 + (-2358)’
+ (-7467)2]05 = 8180
6 ,= [ 1.27 FYSA /
+ [212Do(hfXS~’+ MzA2)o‘5]1 (Do4 - o?)
Referring to Equation F-5,
= [ 1.27(-1200)/4.04]
MRCA C 1S(MRST2 + MRDn)
8180 c 1.5(5000 + 3500)
8180 c 12750
Thus, all of the requirements of F. 1.2.3 have been satisfied.
F 5 2 EXAMPLE 2 8 (U. S. CUSTOMARY UNITS)
F.5.2.1
Problem
(Do’ - DF)]
+ [122(4.500)(lOO5)l I 147.34
= 3367
Equation F-8Bis used to determine the shear stress for the
suction nozzle, 7 ,.
7
= [1.27(FXSA2 + Fz+$A2)o.5]
/ (Do2 - DF)]
+ [61Do(MyS~)]1 (Do4- Dl4)
= [1.27(583) / 4.041
+ [61(4.500)(I -1500
I )] /
147.341 = 2978
For a 3 x 4 x 7 vertical in-line pump, the proposed applied
The principal stressfor the suction nozzle,P,, is calculated
nozzle loadings are as given in Table F-3B. By inspection,
using Equation F-6B:
ITSA,M a A ,and MXD,are greater than two times the values
P,=(~,/2)+(6,2/4+7,2)~.~<5950
shown in Table 2.1B.As stated in F.2, these component loads
= (+3367 12) + [(+3367)2/4 + (+2978)2]0.5
are acceptable provided that the calculated principal stress
is
= +%O5 < 5950
less than 5950 psi. The problem
is to determine the principal
stress for the suction nozzle and the discharge nozzle.
Thus, the suction nozzle loads are satisfactory.
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
A P I STD*bltO 95
m
0732290 05Vb223 T79
m
CENTRIFUGAL
PUMPS
FOR PETROLEUM,
HEAWDUTY
CHEMICAL, AND GASINDUSTRY
SERVICES
F.5.2.2.2
Discharge nozzle calculations are as follows:
For Schedule-40 pipe with a nominal size
of 3 in., Do =
3.500, and DI = 3.068. Therefore,
Do2 - D,* = (3.500)2 - (3.068)2= 2.84
D$ - D$ = (3.500)4 - (3.068)4 = 61.47
[(FxDA)2+ (FzDA)2]05= [(+300)2 + (+i00)2]05= 316
[(MxDA)2 + (MzDA)2]05= [(+2000)2 + (+ioo)2]0'5
= 2002
Equation F-7Bis used to determine the longitudinal stress
for the discharge nozzle, 6,.
Note: The applied FYDA load acting on the discharge nozzle is in the
negative Y direction and will produce a tensile stress; therefore, a positive
sign on FYDAis used.
CD
= [ 1.27 FYDA / (Do2- DF)]
+ [122D0(MxDA2+ !!bfzDA2)05]/ (DO4 -074)
= [ 1.27(+500) / 2.841 + [122(3.5) (2002)] / 61.47
= 14131
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
F-7
Equation F-8B is used to determine the shear stress for the
discharge nozzle, 7 D.
2D
= [ 1.27(~X~,2
+ F Z D , ~ ) O/~(002
]
- DF)]
+ [61&(MyD~)]/ (Do4 - 04)
= [1.27(316) / 2.841 + [61(3.500)( I +200 I )] /
6 1.471 = 836
The principal stress for the discharge nozzle,PD,is calculated using Equation F-6B:
PD=(60/2)+( 6D2/4+TD2)o'5<5950
= (+14131 / 2) + [(+14131)2/4+ (+836)2]05=
+14181>5950
Thus, the discharge nozzle loads
are too large. By inspection, if MXD, is reduced by 50 percent tolo00 ft-lbs the resulting principal stress will still exceed 5950 psi. Therefore,
the maximum value for
MXD, will be twiceMXD,, or 1400
ft-lbs.
A P I STD*LLO 95 0732290
0 5 q b 2 2 q 905
m
APPENDIX G-MATERIAL CLASS SELECTION GUIDE
G-1
COPYRIGHT American Petroleum Institute
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A P I S T D r b L O 95 W 0732290 054b225 491 W
API STANDARD
610
G-2
Table G-1-Material Class Selection Guide
CAUTION This table is intended asa general guidefor on-plot process plants and off-plot transfer and loading services. It should
not be
used withouta knowledgeable reviewof the specificservices involved.
service
Fresh water, condensate, cooling
tower water
Boiling water and process water
Boiler feed water
Axially split
Doublk &ing (barrel)
Boiler circulator
Foul water, refluxdrum water, water draw,
and hydrocarbons containing these
waters, including refluxstreams
Propane, butane, liquefied
(Mi3) c450
petroleum gas, and ammonia
Diesel oil; gasoline; naphtha,
kerosene; gas oils; light, medium,
heavy and fuellube oils;
oil; residuum;
crude oil; asphalt; synthetic
Allcrude bottoms
>700
Noncorrosive hydrocarbons,
e.g., catalytic reformate.
oils
isomate, desulfurized
Xylene, toluene, acetone, benzene,
furfural. MEK. cumene
c450
carbonate.Sodium
doctor solution
Caustic (sodium hydroxide)
concentration ofQO%
~
Seawater
Sour water
Sulfur (liouid state)
Potassium
EA,
c350
c700
TEA-stock solutions
MEA,
DEA.
MEA-lean solution(CO, only)
MEA-lean solution (CO2 and
H#)
8
MEA, DEA, TEA, rich solutions
Sulfuric acid concentration9 5 %
430
85% - ~ 1 %
ntrationacid Hydrofluoric
>%%
~~
Temperature
Reference Range Material
"C
OF
C100
c120
120-175
>175
>95
>95
>95
475
c212
c250
250-350
C-6 >350
>200
>200
>200
c350
S-6
>175
>350
Q30
Q30
230-370
c450
All 450-700
1-2
S-3
Class
All or
All
All
All
1-1
1-1 or 1-2
S-5
All
All
All
All
C4
or S-6
All
C-6
All
S- 1
All
S- 1
S-6
450-700
All
S4
Q30
475
c350
All
All
S- 1
I- 1
c175
c370
420
c120
80-150
80-150
c80
4 8
4 8
5
5
5
6
6 7
6
230-370
C100
>lo0
4 5
R60
All
Note
C-6
>370
S-1
All
All
All
All
AU
All
c210
>200
4250
450
175-300
175-300
S-1 c175
<l00
A-8 c450
C100
All
All
All
All
All
All
All
All
All
All
c200
c470
A-8
General Notes:
in
1. The materials for pump parts for each material class are given
Appendix H.
2. Specific materials recommendations should be obtained for services
not clearly identifiedby the servicedescriptions listed in this table.
3. Cast iron casings, where recommended
for chemical services,are for nonhazardous locations only. Steel casings (2.11.1.4) should
be used for pumpsin
services
located
near
process
plants
or in
any
location
where
released vapor froma failure could createa hazardous situationor where
pumps could be subjected to hydraulic shock, for example, in loading
services.
4. Mechanicalseal materials:For streams containing chlorides,all springs and
other metal parts should be Alloy 20
or better. Buna N and Neoprene should
not be used in anyservice containimgaromatics. Viton should be used in services containing aromatics above 95°C
(200'F).
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
S%%
Pressure
Range
D- 1
7
8
9
10
S-1
C-6
S-1
S-1
S-9
-
8
8
8, 11
S-1
6
6
S-9
6
Reference Notes:
5. Oxygen contentand buffering of water should
be considered in material selection.
6. The corrosiveness of foul waters, hydrocarbons
over 230°C (450°F). acids,
and acid sludgesmay vary widely. Material recommendations shouldbe obtained for each service.The material class indicated above will
be satisfactory
for many ofthese services, but must be verified.
7. If product corrosivityis low, Class S 4 materials may be used for services
at 231"-370"C (451"-700"F). Specific material recommendations should be
obtained ineach instance.
8. All weldsshall be stress relieved.
9. Alloy 20 or Monel pump materialand dual mechanical seals shouldbe
used with a pressurid seal oil system.
10. For seawater service, the purchaser and the vendor should agree on the
construction materialsthat best suit the intended use.
11. Class A-7 materials shouldbe used except for carbon steel casings.
~
A P I STD*bLO
95
m 0732290 0546226 788 m
APPENDIX H-MATERIALS AND MATERIAL SPECIFICATIONS
FOR PUMP PARTS
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
A P I STDxbLO 95
H-2
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
m 0732290 O546227 b L 4 m
API STANDARD
610
A P I STD*b10 75
m O732270
CENTRIFUGAL PUMPS FOR PETROLEUM,
054b228 5 5 0
m
HEAW DUW CHEMICAL, AND GASlNDUsTRY SERVICES
H-3
Reference and General Notesfor Table H- I:
1. Austenitic stainless steels include IS0 Types 683-13-10/19 (AISI Standard Types
302,303, 304,316, 321, and 347).If a
particular type is desired, the purchaser will so state.
to liquid and running in bushings,the shaft shall be 12 percent
2. For vertically suspended pumps with shafts exposed
chrome, except for Classes S-9, A7, A-8, andD- 1. Cantilever (Type VS5) pumps may utilize AISI4140 where the service liquid will allow.
3. Unless otherwise specified, the need for hard-facing and thespecific hard-facing materialfor each application shallbe
determined by the vendor and described inthe proposal. Alternatives to hard-facing may include opening runningclearances (2.6.4) or the use of non-galling materials, such
as Nitronic 60 and Waukesha88, depending on thecorrosiveness
of the pumped liquid.
4. For Class S-6, the shaft shall be 12 percent chrome if the temperature exceeds 175°C (350°F) or if used for boiler feed
service (see Appendix G. TableG-1).
5. The gland shall be furnished with a non-sparkingfloating throttle bushing of a material suchas carbon graphite or
glass-filled PTFE, in accordance with 2.7.3.20. Unlessotherwise specified, the throttle bushing shall be premiumcarbon
graphite.
6. If pumps with axiallysplit casings are furnished, a sheet gasket suitable for the service is acceptable. Spiral wound
gaskets should contain afiller matrial suitable for the service.
7. Alternate materialsmay be substituted for liquid temperatures greater than
45°C (1 10OF) or for other special services.
8. Unless otherwise specified, AISI 4140 steel maybe used for non-wetted case and gland studs.
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
H4
STANDARD
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
API
61O
-
API STD*bLO 95 W 0732290 05Yb230 L O 9 W
COPYRIGHT American Petroleum Institute
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A P I STD*bLO
95
m
0732290 0546231 045
m
API STANDARD
610
H-6
Table H-3-Miscellaneous Materials
Material
Alloy 20
ASTM B73, UNS 8020 (wrought), ASTM A744,Grade CN7M (cast)
Babbitt
ASTM B23, Grades 1-9, as required by vendor for service conditions
Bronze
UNS C87200 (silicon bronze), C90700
or C92200 (tin bronze), C95200 (aluminum bronze) or C95800 (nickel aluminum
bronze)
Carbon
Suitable mechanical carbon as recommendedby vendor for the service conditions
Filled carbon
Carbon withan appropriate filler material (usually metal)to enhance its mechanical properties
Fluorcelastomer (FKM)
ASTM D1418 FKM elastomer. suchas DuPont Viton
Flexible graphite
Union Carbide Grafoil(or the equivalent)
Hardfacing
Stellite (Cabot Corp.) (or the equivalent), Colmonoy (Wall-Colmonoy
Corp.) (orthe equivalent), Type 3 tungsten
carbide,
if available, a solidcast part of equal
etc.; overlay-weld deposit of 0.8mm (0.030 in.) minimum finished thickness, or,
material may be substituted.
required for service conditions, with cobalt binder (solid
part, not overlay);
Type 2 tungstencarbide-as required for serviceconditions, with nickel binder (solid part, not overlay);
Qpe 3 tungsten carbide-sprayed overlay as required for service conditions, minimum thickness
of 0.8 mm (0.030 in.)
Type 1 tungsten carbide-as
Low carbon nickel
molybdenum chrome
alloy
Hastelloy (Cabot Corp.) Alloy C-276 (or equivalent):
the
ASTM B564, UNS N10276 (forgings)
ASTM B574. UNS N10276 (bar and rod)
ASTM 8575, UNS N10276 (plate,sheet, and strip)
ASTM A494,Grade CW-2M (weldable cast)
Nickel copper alloy
400 (or the equivalent):
Monel (Huntington Alloys) Alloy
ASTM B564,UNS NO4400 (forgings)
ASTM B 164,Class A, UNS NO4400(bar and rod)
ASTM B127, UNS NO4400 (plate, sheet, and
strip)
ASTM A494. GradeM30C (weldable cast)
Ni resist
ASTM A436, Type1,2, or 3, UNS F41000/F41002 I F41004 respectively (austeniticcast iron);
ASTM A439,Qpe D2, UNS F43000 (austeniticductile iron)
Nitrile
B. F. Goodrich Hycar,BUMN (or theequivalent)
Perfluomelastomer
ASTM D1418 FFKM elastomer, suchas DuPont Kalrez
(m)
Polytetrafluoroethylene
(m)
DuPont Teflonor similar material
Glass filledPTFE
25 percent glass filled polytetrafluoroethylene
Precipitation hardening
nickel alloy
Inconel (Huntington Alloys) Alloy
718 (or the equivalent):
ASTM B637, UNS N07718 (forgings and bars)
ASTM B670,UNS N07718 (plate, sheet, and
strip)
Precipitation hardening
stainlesssteel
ASTM A564, Grade 630,UNS S 17400 or Grade63 1, UNS 17700 (wrought)
ASTM A747, Grade CB7Cu1, UNS J92180 (cast)
Sheet gasket
suitable for service
conditions, or spiral wound stainless steel and equal
Long fiber material with synthetic rubber binder
gasket material
Silicon carbide(Sic)
Reaction bonded silicon carbide (RBSiC)
or self sintered silicon carbide(SSSiCbsee API Standard 682for Sic
application guidelines in mechanicalseals
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
~~
"
API STD*bLO 95
CENTRIFUGAL PUMPS FOR
m
0732290 O546232 T B 1
H-7
PETROLEUM,
HEAW DUTY CHEMICAL, AND GASlNDUSTRV
SERVICES
Table H-&Fourth Letter of Mechanical Seal
Classification Code
API Standard 610 Mechanical Seal Materials and
Classification Codes
Mechanical seal materials and
construction features shall
Fourth
be coded according to the following classification system: GasketRine Letter
First letter:
Balanced (B) or unbalanced (U)
Second letter:
Single ( S ) , unpressurized dual (T),
or pressurized dual(D)
Stationary Seal
Third letter:Sealglandtype
(P = plain,nothrottle bushing; T = throttle bushing
with quench, leakage and/or drain
connections; A = auxiliary sealing
device, type to be specified)
Seal Ring to
Sleeve Gasket
FKM
FKM
m
PTFE
PTFE
Nitrile
FFKM
Graphite foil
As specified
Spiral wound
Nitrile
FFKM elastomer
Graphite foil
As specified
Graphite foil
FKM
Note: See 2.7.3.21.
Fourth letter:
Gasket materials (see TableH-4)
Fifth letter:
Face materials(see Table H-5)
Table H-&Fifth Letter of Mechanical Seal
Classification Code
For example, a seal coded BSTFM would be a balanced
single seal with throttle bushing seal gland and would have
a fluoroelastomer (FKM) stationary gasket, an FKM sealring-to-sleeve gasket, and carbon against tungsten carbide 2
faces. Seal materials other than those listedabove should be
coded X and defined on thedata sheets (see Appendix B).
Sealing Ring Face Materials
Mechanical Seal Notes
l . Unless otherwise specified, the spring materialfor multiple springseals shall be HastelloyC. The spring material for
single spring seals shall be austenitic stainless steel (AISI
Standard Type 316 or equal). Other metal parts shall be
austenitic stainless steel (AISI Standard Type 3 16or equal)
or another corrosion resistant material suitable for the service, except that metal bellows, where used, shall be of
the
material recommended bythe seal manufacturerfor the service. Metal bellows shall have a corrosion rate of less than
50 pm ( 2 mils) peryear.
2. Unless otherwise specified, the gland plate
to seal chamber
seal shall be a fluoroelastomer O-ring for services below
150°C (300°F). For temperatures 150°C (300°F) and above
or
when specified, graphite-filled austenitic stainless steel spiral
wound gaskets shallbe used. The gasket shall be capable of
withstanding the full (uncooled) temperature
of the pumped
fluid.
3. A metal seal ring shall not have sprayed overlay in place
of a solidface.
4. When the pumping temperature exceeds 175°C (350"F),
the vendor and seal manufacturer should
be jointly consulted
about using a cooled flush to the seal faces or running the
seal chamber dead-ended withjacket cooling.
5. The temperature limits on mechanical seal gaskets shall
be as specifiedin Table H-6.
H-7
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
Fifth
Letter
Ring 1
L
M
N
O
P
X
Carbon
Carbon
Carbon
Tungsten carbide2
Silicon carbide
As specified
Ring 2
Tungsten carbide 1
Tungsten carbide2
Silicon carbide
Silicon carbide
Silicon carbide
As specified
Table H-&Temperature Limits on Mechanical
Seal Gaskets and Bellows
Gasket Material
PTFE
-100
Nitrile
Neoprene
FKM
Metal bellowsa
FFKM
Graphite foil
Glass filledTFE
Micdgraphite
Ethylene propylene
Ambient or Pumping Temperature
Minimum
Maximum
("C)
("F)
("C)
("F)
-75
40
-20
-20
-12
-240
-212
-240
-5 I
4
O
O
200
120
90
200
400
250
200
400
10
260
500
4
0
0
-350
4oob
750b
450
1300
350
400
-70
230
700
180
Consult manufacturer for minimum and maximum ambient pumping
temperature.
bMaximum temperature is 870°C (1600°F) for nonoxidizing atmospheres;
consult manufacturer.
~
A P I STDJbLO 95
m
07322900546233
918
m
APPENDIX I-LATERAL ANALYSIS
1.1
veloped by an approximate calculation based on the damping. Second, employing damping allows a minimum valueto be specified for natural frequency to running speed ratios from 0.8 to 0.4, thereby assuring the rotor
of
freedom from significant subsynchronous vibration.
Lateral
Analysis
1.1.1
GENERAL
When a lateral analysis is required (see 5.2.4.1), the
method and assessment of results shall be as specified in
I. 1.2 through1.1.5. Figure 1.1 illustrates the analysis process.
The method and assessment specified are peculiar to liquid
handling turbomachines.
Note 2 Damping factor, 6, is related to logarithmic decrement,6, by the
equation:
6 = 2n 6 / (1 - 5 2 y . 5
For 6 up to 0.4, the following approximate relationships between
6.6, and
amplification factor,A F , are sufficiently accuratefor practical purposes:
5=6/2n=11(2AF)
Critically damped corresponds to the following:
1.1.2NATURALFREQUENCIES
Within the frequency range zero to 2.2 times maximum
continuous speed, all the rotor’s natural frequencies shall be
calculated for the speed range25-125 percent ofrated, taking account of the following:
6 2 0.2,6 2 1.2, AF I 2.5
1.1.4
DAMPED
UNBALANCE
RESPONSE ANALYSIS
When the damping factor versus separation margin for a
mode or modes is not acceptable by the
criteria in Figure1.2,
the rotor’s damped response to unbalance shall be determined for the mode(s)in question on the following basis:
a. Stiffness and damping at internal running clearances, for
both new and two times (2x) new clearances with pumped
liquid, and for both new clearances with water at the expected test temperature.
a. The pumped liquid.
b. Stiffness and damping
at the shaft seals
(if labyrynth type).
b.
Clearances at new and 2x new values.
c. Stiffness and damping within the bearings for the average
c.
clearance and oil temperature; see the note following the lists.Total unbalance of four times (4x) the allowable value
(see 5.2.4.2.1) lumped at one or more points to excite the
d. Mass andstiffness of the bearingsupport structure.
mode(s)
being investigated.
e. Inertia of the pump half coupling hub and half the coupling spacer.
Only one mode shall be investigated in each computer run.
The report shall state the following:
1.1.5ALLOWABLEDISPLACEMENT
a. Those natural frequencies with a damping ratio less than
The peak to peak displacement of the unbalanced rotor at
0.4.
the
point(s) of maximum displacement shall not exceed 35
b. The values or the basis of the stiffness anddamping coefpercent
of the diametral running clearance at that point.
ficients used in thecalculation.
Note: In centrifugal pumps, the typical damped responseto unbalance
does not show a peak in displacement
at resonance large enough toassess
the amplification factor.
With this limitation, assessmentof the damped response to unbalance is restricted to comparing rotor displacement to the
available clearance.
Note: The effect of bearing stiffness and damping in pumps is generally
minor in comparison to that of the intemal running clearances; therefore,
it
is sufficient to analyze the bearings
at theiraverage clearance andoil temperature.
1.1-3 SEPARATION MARGINS AND DAMPING
For both new and2x new clearances, the damping factor
versus separation margin between any bending natural frequency andthe synchronous run line shall be within the “acceptable” region shown on Figure 1.2. If this condition
cannot be satisfied, the dampedresponse to unbalance shall
be determined(see 1.1.4).
1.2 ShopVerificationof Rotor’s
Dynamic Characteristics
”
Note 1: In liquid handling turbomachines, the
f i t assessment of a rotor’s
dynamic characteristicsis based on damping versus separation margin,
rather than amplification factor venus separation margin.Two factors account for this basis. First, the rotor’s
natural frequencies increase with rotative speed, a consequence of the differential pressure across internal
clearances also increasing with rotative
speed. On a campbelldiagram,Figure1.3, this means the closer separations
are between the running
speed and
natural frequencies rather than between the running
speed and the critical
speeds. Because the amplification
factor atthe closer separationsis not related to synchronous (unbalance) excitationof the rotor, it can only be de-
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
0
1.2.1 When specified, the rotor’s dynamic characteristics
shall be verified during the shop test. The rotor’s actual response to unbdance shall be the basis for confirming thevalidity of the damped lateral analysis. This response is
measured during either variable speed operationfrom rated
speed downto 75 percent of the first critical speed or during
coast down.If the damped response to unbalance was notdetermined in the original rotor analysis (see 1.1.4), this response will need to be determined for a pump with new
clearances handling water before proceeding with
shop verification. The test unbalances shall be vectorially added in
phase with the residual unbalance
at locationsdetermined by
the manufacturer (usuallythe coupling and/or thrust collar).
API S T D r b L O 75
0732270 054b234 854 W
API STANDARD
610
1-2
LI
ANALYSIS
REQUIRED
PUMP DESIGN
ANALYSIS NOT
RECOMMENDED
4
ANALYSIS NOT
RECOMMENDED
4
I
IDENTICAL OR
ROTOR DESIGN
+
CALCULATE Ist,
2nd, AND 3rd
DAMPED NATURAL
FREQUENCY W,,)
CLASSICALLY
AMPLIFICATION
CALCULATE
DAMPED
RESPONSE TO
UNBALANCE
DESIGN
ACCEPTABLE
ARE ROTOR
DESIGN
REVISE
DISPLACEMENTS
WITHIN LIMIT?
4
-
NO
1
Figure I-î-Rotor Lateral Analysis Logic Diagram
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
7
CENTRIFUGAL PUMPS FOR PETROLEUM, HEAW DUTY CHEMICAL,
AND
Note:Theprincipalobjective of shopverification by response to unbalance isverify
to the
existence
critical
aof speed
(vibration
peak)within tolerance of the calculated value,or if the analysis predicteda highly damped
,--tical
a b S m o f a vibration peak wjthin tolerance ofcalculated
value. Shop verification by this method is feasible only for pumps that have
sleeve bearingsand are furnished with proximity probepain at each journal
bearing.
the
With
1.2.2 The magnitude and location of the test unbalance(s)
GASINDUSTRY SERVICES
shall be determined from a calibration of the rotor's sensitivity to
nec-.ibration shall &
by obtainingthevibration Orbits at each bearing, filtered to rotor
speed (lx),during two trial runs as follows:
a.
rotor as built.
b. With trial unbalance weights added 90 degrees from the
maximum displacement in run a.
0.40
0.35
0.30
0.25
8
L
o
Q
u-
.P
o.
0.20
s
O
0.15
Acceptable
0.10.
0.05.
0.00 '
I
0.2
I
0.4
I
0.6
I
0.8
I
1.0
I
1.2
I
1.4
Note: fn,
f,,
I
1.6
I
1.8
- i th natural frequency
- running frequency
minimum to maximum
continuous
Figure I-2-Damping Factor Versus Frequency Ratio
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
1-3
1-4
API STANDARD
610
The magnitude of the test unbalances should be such that
the calculated maximum shaft displacement caused by the
resultant total unbalance (residual plus test)
is 150-200 percent of the allowable displacement from Tables2.5 or 2.6 at
the bearing probes, but shall not exceed eight times the maximum allowable rotor unbalance.
1.2.3 During the test,the rotor’s speed, vibration displacement, andcorresponding phase angle, filteredto rotor speed
(lx),shall be measured and recorded.
1.2.4 The rotor’s characteristics shall be considered verified if the following requirements are met:
a. Observed criticalspeed(s) (distinct vibrationpeak and appropriate phase shift) within *IO percent of the calculated
value(s).
b. Measured vibrationamplitudes within G35 percent of the
calculated values.
Note: Highly damped critical speeds will not be observable; therefore, the
absence of rotor responsein the region of a calculated highlydamped critical speed will be verification of the analysis.
1.2.5 If the acceptance criteria given in 1.2.4 are not met,
the stiffness or damping coefficients,
or both, used in the natural frequency calculation shall be adjusted to produce
agreement betweenthe calculated and measured results. The
coefficients ofone type of element, annular clearances with
UD O. 15. annular clearancesW D > O. 15, impeller interaction, andbearings shall be adjusted with the same correction
factor. Once agreement is reached, the same correction factors shall be applied to thecalculation of the rotor’s natural
frequencies and dampingfor the pumped liquid, and the
ro-
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
tor’s separation margins versus damping factors rechecked
for acceptability.
Note: Of the coefficients used in rotor lateral analysis, those fordamping
are therefore usually
in annular clearances have the highest uncertainty and
the first to be adjusted. The stiffness coefficientsof annular clearances typically have low uncertainty and,therefore, shouldbe adjusted only on the basis of supporting data. Adjustments of bearing coefficients require specific
justification;because the typical valuesare based on reliable empiricaldata.
1.2.6 Alternative methodsof verifying the rotor’s dynamic
characteristics, forexample, variable frequency excitation
with the pump at running speed
to determine the rotor’s natural frequencies, are available.The use of alternative methods and the interpretationof the results shallbe mutually
agreed between thepurchaser and manufacturer.
1.3
Documentation
1.3.1 The report on a lateral analysis shall include the following:
a. Results of initial assessment (see 5.2.4.1.1).
b. Fundamental rotordata used for the analysis.
c. Campbell diagram (seeFigure 1-3).
d. Plot of damping ratio versus separation margin.
e. Mode shape at the criticalspeed(s) for which the damped
response to unbalance was determined (see I. 1.4).
f. Bode plot(s) from shop verificationby unbalance (see
1.2.3).
g. Summary of analysis correctionsto reach agreement with
shop verification (see 1.2.5).
Note: Receding items e through g are furnished only if the activity documented was required by the analysis or specified by the purchaser.
A P I STDxbLO 95
0732290 0 5 4 b 2 3 7 563
CENTRIFUGAL PUMPS FOR PETROLEUM, HEAVY DUTY CHEMICAL, AND
GAS INDUSTRY SERVICES
A
0
o
Ø
d
#
/
New cl.
c
1st Bending
/
I
Newel.
2x cl.
e e @
c
0 4
Min. separation margins
1st & 2nd f respectively
Critical speeds
cl. = Clearances
f, = Naturalfrequency
CPM = Cycles per minute
Min
Max
Pump Speed (RPM)
Figure I-3-Typical Campbell Diagram
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
1-5
~~
~
API STD*b10 95 m 0732290 054b238 4 T T m
APPENDIX J-PROCEDURE FOR DETERMINATIONOF RESIDUAL UNBALANCE
J.l
Scope
This appendix describes the procedure
to be used to determine residual unbalance in machine rotors. Although some
balancing machines may be set up to read out the exact
amount of unbalance, the calibration can be in error. The
only sure method
of determining residual unbalance toistest
the rotor with a known amount of unbalance.
sitions (six or twelve) in equal (60 or 30 degree) increments
around the rotor. Add the trial weight to the last known
heavy spot in one plane. If the rotor has been balanced very
precisely and the final heavy spot
cannot be determined, add
the trial weightto any one of the marked radialpositions.
5.4.2.3 To verify thatan appropriate trial weighthas beem
selected, operate the balancing machine and note theof units
unbalance indicated on the meter.
If the meter pegs, a smaller
J.2 Definition
trial weight shouldbe used. If little or no meter readingreResidual unbalance refers to the amountof unbalance results, a larger trial weight should
be used. Little or no meter
maining in a rotor after balancing. Unless otherwise specified, reading generally indicates that the rotor was not balanced
residual unbalance shallbe expressed ing*mm or oz-in.
correctly, the balancing machine
is not sensitive enough,or a
balancing machine fault exists (i.e., a faulty pickup). What5.3MaximumAllowableResidual
ever the error,
it must be corrected before proceeding with the
Unbalance
residual check.
J.3.1 The maximum allowable residual unbalance per
5.4.2.4 Locate the weight at each of the equally spaced
plane shall be determined from Table5.2.2 of this standard.
positions in turn, and record the amountof unbalance indiJ.3.2 If the actual static weight load on eachjournal is not
cated on themeter for each position. Repeatthe initial posiknown, assume that the total rotor weight is equally suption as a check. All verification shall be performed using
ported by the bearings. For example, a two bearing rotor
only one sensitivity rangeon the balance machine.
weighing 2700 kg (6000 lbs) would be assumed to impose a
static weight loadof 1350kg (3000lbs) on each journal.
J.4.2.5 Plot the readings on the residual unbalance work
sheet and calculate the amount of residual unbalance (see
J.4 ResidualUnbalanceCheck
Figure J-1). The maximum meter reading occurs when the
trial weight is addedat the rotor’s heavy spot; the minimum
5.4.1 GENERAL
reading occurs when the trial weight is opposite the heavy
J.4.1.1 When the balancing machine readings indicate
spot. Thus, the plotted readings should form an approximate
that the rotor has been balancedto within the specified tolercircle (see Figure J-2). An average of the maximum and
ance, a residual unbalance check shall be performedbefore
minimum
meter readings represents the effect of the trial
the rotor is removedfrom the balancing machine.
weight. The distance of the circle’s center from the origin of
5.4.1.2 To check the residual unbalance, a known trial
the polar plot represents the residual unbalance
in that plane.
weight is attached to the rotorsequentially in six (or twelve,
if specified by the purchaser) equally spaced radial positions, J.4.2.6 Repeat the stepsdescribed in 5.4.2.1 through
5.4.2.5 for each balance plane. If the specified maximum aleach at the same radius.The check is run in eachcorrection
lowable residual unbalance has been exceeded in any balplane, andthe readings ineach plane are plotted on agraph
using the procedure specified in 5.4.2.
ance plane, the rotor shall be balanced more precisely and
checked again.If a correction is made in any balance plane,
5.4.2 PROCEDURE
the residual unbalancecheck shall be repeated in
all planes.
J.4.2.1 Select a trial weightand radius that willbe equivalent to between one and two times the maximumallowable
residual unbalance [that is, if U,,,,, is 1440 gomm (2 oz-in.),
the trial weight should cause 1440-2880 g*mm
( 2 4 oz-in.) of
unbalance].
J.4.2.7 For stack component balanced rotors, a residual
unbalance check shall be performed after the addition and
balancing of the first rotor component, and
at the completion
of balancing of the entire rotor, as a minimum.
5.4.2.2 Starting at the last known heavy spot in each
correction plane, mark
off the specified number
of radial po-
Note: This ensures that time is not wasted and rotor components are not
a mulsubjected to unnecessary material removal in attempting to balance
tiple component rotor with a faulty balancing machine.
J-1
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
API STD*bLO 95 W 0732290 054b239 33b m
API STANDARD610
J-2
~~~~
Equipment (Rotor) No.:
Purchase OrderNo.:
Correction Plane (inlet, drive end,
etc.-use sketch):
Balancing Speed:
H a x i m u m Allowable RotorSpeed:
&Weight of Journal (closest to this correction plane):
U"+laximum Allowable Residual Unbalance
=
6350 WN(4 W m
6350x
kg/
rpm; 4 x
lbs/
Trial unbalance(2 x
rpm
U-)
gmm (oz-in.)
(at which weightwill be placed):
/+Radius
gomm foz-in.)
mm (in.)
Trial Unbalance Weight= Trial UnbalancelR
gmml
mml in. oz-in./
Conversion Information:1 ounce = 28.350 grams
Rotor Sketch
Test Data
POSh
Trial Wei@
Anaular Lacation
Balancing Machine
A
m
d
W Readout
6
7
Test Date-Graphic Anaiysis
Step 1: Plot data on the polar chart (Figure
J-1). Scale the chartso the largest and smallest
amplitude will fit conveniently.
Step 2: With a compass, drawthe best fit circle throughthe six points and mark the center of this circle.
Step 3: Measure the diameter of the circlein units of
chosenscale units in
record.
Step 1 and
Step 4: Record the
(oz-in.)
gomm
trial
above.
unbalance
from
Step 5: Double the trial unbalancein Step 4 (may use
unbalance).
residual actualtwice the
gmm (oz-in.)
Scale
Factor
Step 6: Divide the answer in Step 5 by the answer in Step 3.
on the polar chart andthe pin af actual balance.
You now havea correlation between the units
Notes:
1. The triai weigh anguhr location shouldbe referenced to a keyway or some other permanent marking on
the rotor.
2. The balancing machine amplitude readout for
position "7" should be the same as position"1," indicating
trialthe
weight.
repeatability. Slight variations may result from imprecise positioning of
Figure J-I-Residual Unbalance WorkSheet
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
A P I STDabLO 95
m
0732290 0546240 058
m
J-3
CENTRIFUGAL
PUMPSFOR PETROLEUM,
HEAVY DUTY
CHEMICAL,AND GASINDUSTRY
SERVICES
1
O"
90"
270"
180"
The circle you have drawn must contain the origin of the polar
If it doesn't,
chart.
the residual unbalanceof the rotor exceeds the applied test unbalance.
NOTE: Several possibilities for the drawn circle not including the origin of the polar chart are: operator error during balancing, a faulty balancing machine or
pickup
cable, or the balancing machine is not sensitive enough.
If the circle does contain the origin of the polar chart, the distance between origin
of the chart and the center of your circle
is the actual residual unbalance present
in
on the rotor correction plane. Measure the distance
in units of scale you choose
Step 1 and multiply this number by the scale factor determined
in Step 6. Distance
in units of scale between origimand center of the circle times scale factor equals
actual residual unbalance.
Record actual residual unbalance
(pmm)(oz-in.)
Record allowable residual unbalance (from Figure J-1)
(g.mm)(oz-in.)
No.
Rotor
Correction
for
plane
BY
(hashas not) passed.
Date
Fqure J-1-Residual Unbalance Work Sheet (Continued)
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
API STD*blO 95 W 0732290 O546243 T 9 4
API STANDARD
61O
J-4
Equipment (Rotor)No.:
c-101
Purchase Order No.:
Correction Plane (inlet, drive end,
etc.-use sketch):
A
Balancing Speed:
&Maximum Allowable Rotor Speed:
of Journal (closet to this correction plane):
W-Weight
800
rpm
10,000
rpm
908
U-,Maxm
i um
Allowable Residual Unbalance=
6350 W/N(4 W/N)
C ' 3 E n \ r q m m m ;
4 x 908 lbs/ 10.000 rpm
O.36
g
Trial unbalance(2 x U,,,&
O.72
g e m (oz-in.)
"Radius (at which weight willbe placed):
6.875
m (oz-in.)
~
fiw~
(in.)
Trial Unbalance Weight= Trial Unbalance/R
70.72
o. 10
oz-in./ 6.875 in.
3 (04
Conversion Information: 1 ounce = 28.350 grams
Test Data
I
Position
~
1
2
3
4
5
6
7
ctual
~~~
I
Rotor Sketch
I
Trial Weight
Balancing
Machine
Angular Location
Amplitude
Readout
~~
___
O
60
120
180
240
300
O
~~
~
I
14.0
12.0
14.O
23.5
23.O
15.5
13.5
Test D a t e r a p h i c Analysis
Step 1: Plot data on the polar chart (Figure J-2 continued). Scale the so
chart
the largest and smallest
amplitude will fit conveniently.
Step 2: With a compass, draw the best fit circle through the six points and the
mark
centerof this circle.
circle in units of
Step 3:Measure the diameter of the
35
units
scale chosen in Step 1 and record.
Step 4: Record thetrial unbalance from above.
O.72
(oz-in.)
in Step 4 (may use
Step 5: Double the trial unbalance
the
twice
1.44
(oz-in.)
Step 6: Divide
the
answer
in Step 5 by the
answer in Step 3.
0.041
Scale
Factor
You now havea correlation between the units on the polar chart and the gain. of actual balance.
Notes:
1. The trial weight angular location should
be referenced to a keyway or some other permanent marking
on
the rotor.
2. The balancing machine amplitude readout for position
"7"should be the same as position"1," indicating
repeatability. Slight variations may result from imprecise positioning of trial
the weight.
Figure J-2-Sample Calculationsfor Residual Unbalance
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
~~
API STDxbZO 95
m
0732290 O546242 920 H
CENTRIFUGAL
PUMPSFOR PETROLEUM,
HEAWDUTYCHEMICAL,
AND GASINDUSTRY
SERVICES
J-5
O"
90"
270"
180"
The circle you have drawn must contain the origin of the polar
Ifit doesn't,
chart.
the residual unbalanceof the rotor exceeds the applied test unbalance.
NOTE: Several possibilities for the drawn circle not including theoforigin
the polar chart are: operator error during balancing, a faulty balancing machine pickup or
cable, or the balancing machineis not sensitive enough.
If the circle does contain the origin
of the polar chart, the distance between origin
of the chart and the centerof your circle is the actual residual unbalance present
on the rotor correction plane. Measure the distance
in units of scale you choosein
Distance
Step 1 and multiply this number by the scale factor determined in6.Step
in unitsof scale between origin and center of the circle times scale factor equals
actual residual unbalance.
i
Recordactualresidualunbalance
6-5 (o.o41)=
J-2)
Record allowable residual unbalance (from Figure
Correction
plane
A
John Inspector
Rotor
for
No. c-1oz
Date
(gmm)(oz-in.)
(-)(oz-in.)
(had-)
passed.
I I -31-94
Figure J-2-Sample Calculations for Residual Unbalànce (Continued)
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
A P I STDxbLO 95
m
0 7 3 2 2 9 0 0546243 Bb7 9
APPENDIX K-SEAL CHAMBER RUNOUT ILLUSTRATIONS
The schematics in this appendix illustrate the measurements desired,
thenot
method or orientation.
Note:Measure concentricity to register fit to be used, not both.
Figure K-1-Seal Chamber Concentricity (2.7.3.11)
Figure K-2-Seal Chamber Face Runout (2.7.3.13)
K- 1
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
A P I STD*bLO
95
0732290 0546244 ?T3
APPENDIX L-BASEPLATE AND SOLEPLATE GROUTING
L.l
General
Unless otherwise specified, epoxy grout with precision
grouting techniques are required whena fully grouted baseplate is specified. Full grouting is defined as the complete
filling with grout of the void area under the baseplate
or soleplate while supported by a concrete foundation. The epoxy
grout shall be applied
in accordance with the grout manufacturer’s procedure.
L.2
Minimum
requirements
The creep Of the epoxy grout
be leSSthan
5 pm/mm (0.005 inlin.) when tested by ASTM C 1181
method. The test shall be at 2 0 0 ~ ( 7 0 0and
~ ) 60°C ( 1 4 0 0 ~ )
place
epoxy
grout
under
baseplates.
with a load of 2.8 MPa (400 psi).
L.3.2 Placing of the grout is accomplished in a manner
which avoidsair entrapment, anda head box is usedto aid in
pouring the grout into the grout holes. The head box provides a hydraulic head to force the grout to the vent holes.
When the head boxis moved to the next grout hole, a 15 cm
(6 in.) high stand pipe shall be placed over the grout hole and
filled with grout. These stand pipes provide
a continuous hydraulic head to sweep air from under the baseplate to the
vent holes. Never allow
the grout to fall below the baseplate
level once the grout has made contact with the baseplate.
The use of a head box providesa surge volume for the
grout
as well as providing the critical hydraulic head.
L.3.3 NO push rods, chains, Or vibrators shall be used t0
~ - 4GeneralApplication
L.2.2 Linear shrinkage of epoxy grout shall be less than
0.080 percent and thermal expansion less than 54 x
mdmm/oC (30 x 10-6 in./in./oF) when tested by ASTM c
53 1 test method.
L.4.1 Groutshould be applied only when surrounding
temperatures are between 15°Cand 32°C (60°F and 90°F).
L.2.3 The compressive strength of epoxy grout shall be a
minimum of 83 MPa (12,000 psi) in 7 days when tested by
ASTM C 579 method 8, modified.
L.4.2 Before an epoxy grout isapplied, the baseplate temperature shouldbe estimated to ensure that the grout can resist the expected temperature.
L.2.4 Bond strength of epoxy groutto concrete grout shall
be greater than14 MPa (2,000 psi) when using ASTMC 882
test method.
L.4.3 Approximately 10 to 25 mm (0.5 to 1 in.) of the top
of the cementitious foundation material should be scarified
with a chipping hammer before the grout is applied. This
procedure is recommended to remove low-strength, highporosity concrete in this area. The concrete foundation
should be allowed tocure for at at least 7 days prior to this
surface preparation.
L.2.5 Epoxy grout shall pass the thermal compatibility test
when overlayed on cement grout using test method
ASTM C
884.
L.2.6 Tensile strength and modulus of elasticity shall be
determined by ASTM D 638. The tensile strength shall not
be less than12 MPa (1,700 psi) and the modulus
of elasticity
shall not be less than 1.2 x 104 MPa (1.8 x 1 0 6 psi).
L.2.7 Gel time and peak exothermic temperature of epoxy
grouts shallbe determined by ASTM D 247 l. Peak exothermic temperature shallnot exceed 45°C (1 10°F)when a specimen 15 cm (6 in.) diameterx 30 cm (12 in.) high is used. Gel
time shallbe at least 150 minutes.
Placement
L.3
L.3.1 Epoxy grout is very viscous; however, it will flow
readily given time and positive hydraulic head.
If the epoxy
grout is installed below 2OoC (70°F) ambient temperature,
consult the grout manufacturer
to determine if aggregate adjustment is necessary. Generally, itis best to start placing the
grout at the center of one end of the baseplate or soleplate
and work towardthe ends in such manneras to force the air
from beneath the baseplate or soleplate and out the vent
holes, to eliminate voids.
L.4.5 The baseplate should belocated in the desired position by supporting it on shims or leveling screws and securing it with anchor bolts. Approximately
25-50 mm (1-2 in.)
of grouting clearance should be allowed between
the bottom
of the baseplate rim and the top
of the scarified foundation.
L.4.6 All water and foreign materials shall be removed
from theanchor bolt sleeves before grouting.
L.4.7 After the baseplate is installed, the anchor bolt
sleeve holes should befilled with a nonbonding material or
the chosen grout, depending on the user’s preference.This
should bedone before the main grouting ofthe baseplate.
L-1
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
L.4.4 All grease, oil, paint, laitance and other undesired
materials shall be removed from the surfaces to be grouted.
The roughened concrete surface shall be blown with
oil-free
compressed air to remove all dust and loose particles. When
cementitious grout is used, the concrete surface be
shall
thoroughly soaked with water until absorption stops, and any excess water shall be removed. When epoxy grout is used, all
surfaces shall be kept dry before application.
A P I S T D x b l O 95 M 0732290 054b245 b 3 T
L-2
API STANDARD
610
L.4.8
If voids are present after the grouting sequence,
epoxy grout may be used to fill them. If cementitious grout
is used, a full 28-daycure is recommended beforethis epoxy
is applied. Epoxy grout is usually hand pumped through
high-pressure threaded fittings installedin the baseplate
where voids havebem found. Extreme care should be taken
to ensure that excessivepressures do not buckle the baseplate. At least one vent hole should be drilled into each void
to help prevent excessive pressures.
L.5
m
References
AST"
for Creep of
C 1181 StandardTestMethod
Concrete in Compression
C 53 1 Standard Test Method for Linear Shrinkage and Co&cient ofTkermal ExparZrion
of Chemical Resistant Mortars, Grouts,
and Monolithic Surfaces
'American Society for Testing and Materials, I916 Race Street, Philadelphia, Pennsylvania 19103-1187.
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
C 579 Standard Test Method for Compressive
Strength of (Method B) Chemical Resistant Mortars and Monolithic Surfacings
C 882-87 Standard Testfor Bond Strengthof E p x y Resin Systems Used with Concrete
C 884-87 Standard Test Method for Thermal CompatibilitybetweenConcreteandan
Epoxy-Resin Overlay
D 638-89 Standard Test Methods for Tensile Properties of Plastics
D 2471-88 Standard Test Method for Gel í7me and
Peak ExothermicTemperature of Reacting Thermosetting Resins
Corps of Engineers2
CRD C611 Test Methods for Flow Grout Mixtures
(Flowcone Method)
CRD C62 1 Corps of Engineers Spectjìcationfor Nonshrink Grout
* U.S. A m y Corps of Engineers, 20 Massachusetts Avenue,N.W.,Washington, D.C.20314.
A P I S T D x b l O 75
0732270 054b24b 5 7 6
APPENDIX M-STANDARD BASEPLATES
M-1
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
CENTRIFUGAL
PUMPSFOR PETROLEUM,
HEAWDUTYCHEMICAL,
AND GASINDUSTRYSERVICES
M-3
Table M-1 -Dimensions of API 61O Standard Baseplates
Baseplate
Number
No. of
Holes per
Side
A
d310.5
B
k2511.O
0.5
1
1.5
2
3
3.5
4
5
5.5
6
6.5
7
7.5
8
9
9.5
10
11
11.5
12
3
3
3
4
3
4
4
3
4
4
5
4
4
5
4
4
5
4
4
5
760130.0
760130.0
760130.0
760130.0
915136.0
915136.0
915136.0
1065142.0
1065142.0
1065142.0
1065142.0
1245149.0
1245149.0
1245149.0
1395155.0
1395155.0
1395155.0
1550161.0
1550161.O
1550161.O
1230148.5
1535160.5
1840172.5
2145184.5
1840l72.5
2145184.5
2450196.5
1840172.5
2 145184.5
2450196.5
27501108.5
2145184.5
2450196.5
27551108.5
2145184.5
2450196.5
27551108.5
2145184.5
2450196.5
27551108.5
Dimensions (rndin.)
C
D
k3l0.12
k310.12
465118.25
615124.25
770130.25
920136.25
770130.25
920136.25
1075142.25
770130.25
920136.25
1075142.25
1225148.25
920136.25
1075142.25
1225148.25
920136.25
1075142.25
1225148.25
920136.25
1075142.25
1225148.25
465118.25
615124.25
770130.25
615124.16
770130.25
61 5124.16
715128.16
770130.25
615124.16
715128.16
615124.12
615124.16
715128.16
61 5124.12
61 5124.16
715128.16
61 5124.12
61 5124.16
715128.16
61 5124.12
Note: See Figures M-1 and M-2 for explanation of dimensions.
25mm (1 in.)
diameter holesfor
20mm (0.75 in.)
anchor bolts
I
L D ” D & D A
I
I
-.
Figure M-1-Schematic for API 610 Standard Baseplates
Grouting c l e a r a n c A b
25mm (1 in.) min.
50mm
max.(2 in.)
.. t
Figure M-2-Anchor Bolt Projection
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
E
k310. 12
F
+1310.5
685127.0
685127.0
685127.0
685127.0
840133.0
8401330
840133.0
990139.0
990139.0
990139.0
990139.0
1 170146.0
1170146.0
1170146.0
1320152.0
1320152.0
1320152.0
1475158.0
1475158.0
1475158.0
14015.5
14015.5
14015.5
14015.5
14015.5
14015.5
14015.5
16516.5
16516.5
16516.5
16516.5
16516.5
16516.5
16516.5
16516.5
16516.5
16516.5
16516.5
16516.5
16516.5
A P I STD*bLO 95
0732290 0546248 349 W
APPENDIX N-INSPECTOR’S CHECKLIST
The levels indicated in thefollowing checklistmay be characterized as follows: Level 1 is typically used for pumps in general
is more stringent than Level
l . Level 3 items shouldbe
services. Level2 comprises performance and material requirements and
considered for pumps in criticalservices.
Piping fabrication and installation
3.5.1
Equipment nameplate data
2.12.2
Rust prevention
4.4.3.4
4.4.3.5
4.4.3.11
4.4.5
Painting
4.4.3.3
Preparation for shipment
4.4.1
tags
4.4.3.10 Shipping documents and
aCheck against certified dimensional outline drawing.
N-1
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
API STANDARD
61O
N-2
APPENDIX N-INSPECTOR’S CHECKLIST (Continued)
API Standard
Witness
61Inspected
O
Date
Inspected
Reference
,item
BY
-
1)
Level 2 Intermediate (Add to Level
Casing marking (serial no.)
2.1 9.3
Copies of subvendor purchase orde
Material certification
2.11.1.2
Nondestructive examination
2.11.1.3
4.2.2.1
(components)
Hydrotest witnessed
4.3.2.1
Building record (runouts, clearances 2.5.6
2.5.10
2.6.4.2
5.2.2.3
5.3.2.2
5.3.3.2
5.3.7.2
5.3.1 1.8
Performance and NPSH tests
witnessed
-
I
Level 3 Special ( Add
Levels
to
Material identification
Welding procedures approved
Welding repairs approved
Welding repair maps
Impellerhotor balancing
Complete unit test
Sound level test
Auxiliary equipment test
Resonance test (bearing housing)
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
1 and 2)
status
Yes/No
A P I STD+b10 95
m 0732290 0546250
TT7 W
APPENDIX O-VENDOR
DRAWING AND DATA REQUIREMENTS
Appendix O consists ofa sample distribution record (schedule), followed by a representative descriptionof the items thatare presented numerically in the schedule.
0-1
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
API STD*bLO 95
0732290 05Llb251 933
TYPICAL
VENDOR DRAWING AND
DATA REQUIREMENTS
JOB NO.
ITEM NO.
DATE
PURCHASEORDERNO.
REQUISITIONNO.
DATE
INQUIRY NO.
DATE
’
PAGE
FOR
OF
2
BY
REVISION
SITE
UNIT
SERVICE
Proposala
Bidder
shall
fumish
-copies
of
data
for
Revied
all
items
indicated
by
an
X.
-transparencies
of
drawings
and
data
indicated.
Vendor
shall
fumish
-copies
and
FinalC
Vendor
shall
fumish
-copies
and
-transparencies
of
drawings
and
data
indicated.
Vendor shall fumish -operating and maintenance manuals.
I
rT T
I
DISTRIBUTION
RECORD
Final-Received from vendor
vendorC
Final-Due
from
Review-Due from vendorC
DESCRIPTION
r
Pump
-
1. Certified dimensional outline drawina.
2. Cross sectional drawings andbill of materials,
3. Shaft seal drawing and billsof materials.
4. Shaft coupling assembly drawing and
bill of materials induding allowable misalignment
tolerances and the style of the coupling guard.
5. Primary and auxiliary sealing schematics and bills of materials including seal fluid, fluid
flows, pressure, pipe and valve sizes, instrumentation, and orifice sizes.
vibration probes.
do not haveto be certified or as built. Typical data shall be clearly identified as such.
aProposal drawings and data
bPurchaser will indicate in this column the time frame for submission of materials using the nomendature end
given
of at
thistheform.
two columns to reflect his actual distribution schedule and include this form with his proposal.
CBidder shall complete these
0-3
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
A P I STD*bLO 95
m
0732290 0546252 8 7 T
TYPICAL
VENDOR DRAWING AND
DATA REQUIREMENTS
ITEM NO.
PAGE
OF
BY
DATE
REVISION
X.
-copies
and -transparencies
of
drawings
and
data
indicated.
Reviewb
Vendor
shall
furnish
FinalC
Vendor
shall
furnish
JOB NO.
-copiesofdataforallitemsindicatedbyan
Proposala
Bidder
shall
furnish
m
-copies
and -transparencies of drawings
and
data
indicated.
Vendor shall furnish-operating and maintenance manuals.
I
Final-Received from vendor
Final-Due from vendorC
Review-Returned to vendor
Review-Received from vendor
Revier-Due
from
vendorC
DISTRIBUTION
RECORD
I I
I
I
I
l
DESCRIPTION
26. Data sheet applicableto proposals, purchase, and as-built.
t
I
I
I
I
I
27. Noise data sheet.
28. As-built clearances.
29. Instruction manuals describing installation, operation, and maintenance procedures.
30. Spare park recommendations and price list.
31. Preservation, packaging, and shipping procedures.
32. Material safety data sheets.
Motor
35. Data sheets applicableto proposals. purchase, and as-built.
38. Certified drawings of auxiliary systems including wiring diagrams for each auxiliary
40. Spare parts reeornmendations and
price list.
41. Material safety data sheets.
I
aProposal drawings and data
do not haveto be certified or as-built. Typical
data shall be clearly identified as
such.
bPurchaser will indicate
in this durnn the time frame for submission of materials using the nomenclature given at the end of this form.
two columns to reflect
his actual distributionschedule and include this form with his proposal.
OBidder shall complete these
Notes:
l . Send all drawings and datato
2.All drawings and data must show project, appropriation, purchase order, and
item numbersin addition to the plant location and unit.
In addition to the copies
specified above, one set of the drawingshnstructions necessary for field
installation must be forwarded with the shipment.
Nomenclature:
S-number of weeks prior to shipment.
F-number of weeks after firm order.
D-number of weeks after receipt of approved drawings.
ence
Vendor
Vendor
Date
Signature
(Signature acknowledges receiptof all instructions)
0-4
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
API STD*bLO 95
0732290 054b253 706
m
CENTRIFUGAL
PUMPS FOR PETROLEUM, HEAVY
DUTY CHEMICAL, AND GASINDUSTRY SERVICES
DESCRIPTION
Pump
1. Certified dimensional outline drawing including:
all customer connections.
a. The size, rating, and location of
b. Approximate overall and handling weights.
C. Overall dimensions, and maintenance and dismantling clearances.
d. Shaft centerline height.
e. Dimensions of bhseplates (if furnished) complete with diameters, number, and locations ofbolt holes and the thicknesses of sections through
which the bolts must pass.
f. Grouting details.
g. Forces and moments for suction and discharge nozzles.
h. Center of gravity and lifting points.
Shaft end separation and alignment data.
I.
j. Direction of rotation.
k. Winterization, tropicalization, and/or noise attenuation details, when required.
2. Cross sectional drawings and bill of materials.
of materials.
3. Shaft seal drawing and bill
4. Shaft coupling assembly drawing and of
billmaterials including allowable
misalignment tolerances and the style of the coupling guard.
5. Primary and auxiliary sealing schematic and bill
of materials including seal
fluid, fluid flows, pressure, pipe and valve sizes, instrumentation, and orifice sizes.
6. Cooling or heating schematic and bill of materials including cooling or heating media, fluid flows, pressure, pipe and valve sizes, instrumentation, and
orifice sizes.
7. Lube oil schematic and bill of materials including the following:
a. Oil flows, temperatures, and pressures at each use point.
b. Control, alarm, and trip settings (pressure and recommended temperatures).
c. Totalheatloads.
d. Utility requirements, including electrical, water, and air.
e. Pipe, valve, and orifice sizes.
f. Instrumentation, safety devices, control schemes, and wiring diagrams.
8 . Lube oil system arrangement drawing including size, rating, and location of
all customer connections.
9. Lube oil component drawings and data including the following:
a.Pumpsanddrivers.
b. Coolers, filters, and reservoir.
c. Instrumentation.
d. Spare parts lists and recommendations.
1o.
Electrical and instrumentation schematics, wiring diagrams, and bill of materials including the following:
a. Vibration alarm and shutdown limits.
b. Bearing temperature alarm and shutdown limits.
c. Lube oil temperature alarm and shutdown limits.
d.
Driver.
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
0-5
0-6
API STANDARD
610
11. Electrical and instrumentation arrangement drawing and list of connections.
12. Performancecurves.
13.Vibrationanalysisdata.
14. Dampedunbalancedresponseanalysis.
15. Lateral critical speed analysis.
3
The required number of lateral critical analysis reports, no later than
months after the date of the order. The reports shall
be as required by Appendix I. Paragraph 1.3.1.
16. Torsional critical speed analysis.
The required number of torsional critical analysis reports, no later than
3
months after the date of the order. The reports shall be as required by
Paragraph 2.8.2.6.
17. Certified hydrostatic test data.
18.Materialcertifications.
The vendor’s physical and chemical data from
mill reports (or certification)
of pressure parts, impellers, and shafts.
19. Progress reports detailing the cause of any delays.
The reports shall include engineering, purchasing, manufacturing, and testing schedules for all major components. Planned and actual dates and the
percentage completed shall be indicated for each milestone in the schedule.
20. Weldprocedures.
21. Performancetestdata.
Certified shop logsof the performance test.A record of shop test data
20 years after the date of
(which the vendor shall maintain for at least
shipment). The vendor shall submit certified copies of the test to
data
the
purchaser before shipment.
22. Optional tests data and reports.
Optional tests data and reports include NPSHR test, complete unit test,
sound level test, auxiliary equipment test, bearing housing resonance test,
and any other tests mutually agreed upon by the purchaser and vendor.
23. Certified rotor balance data for multistage pumps.
24. Residualunbalancecheck.
25. Rotor mechanical and electrical runout for pumps designed to use noncontacting vibration probes.
26. Data sheets applicable to proposals, purchase, and as-built.
27.Noisedatasheets.
28. As-builtclearances.
29. Instruction manuals describing installation, operation, and maintenance
procedures. Each manual shall include the following sections:
Section 1-Installation:
a.
Storage.
b. Foundation.
c.
Grouting.
d. Setting equipment, rigging procedures, component weights, and lifting
diagram.
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
A P I STD*bLO 95 W 0732290 0546255 589 W
CENTRIFUGAL PUMPS FOR PETROLEUM,
HEAVYDUTY CHEMICAL, AND GASINDUSTRY SERVICES
e.
Alignment.
f. Pipingrecommendations.
g. Composite outline drawing for pump/driver train, including anchor bolt
locations.
h.Dismantlingclearances.
Section 2-Operation:
a. Start-up including tests and checks before start-up.
b.Routineoperationalprocedures.
c.Lubeoilrecommendations.
Section 3-Disassembly and assembly:
a. Rotor in pump casing.
b.Journalbearings.
c. Thrust bearings (including clearance and preload on antifriction bearings).
d.
Seals.
e. Thrust collars, if applicable.
f. Allowable wear of running clearances.
g. Fits and clearances for rebuilding.
h. Routine maintenance procedures and intervals.
Section 4- Performance curves including differential head, efficiency, water
NPSHR, and brake horsepower versus capacity for
all operating conditions
specified on the data sheets.
Section 5-Vibration data:
a. Vibration analysis data.
b. Lateral critical speed analysis.
c. Torsional critical speed analysis.
Section 6-As-built data:
a. As-built data sheets.
b.As-builtclearances.
c. Rotor balance data for multistage pumps.
d. Noise data sheets.
e.Performancedata.
Section 7-Drawing and data requirements:
listconnections.
a. Certified dimensional outline drawing and of
of materials.
b. Cross sectional drawing and bill
C. Shaft seal drawing and bill of materials.
d. Lube oil arrangement drawing and list of connections.
e. Lube oil component drawings and data, and
bill of materials.
f. Electrical and instrumentation schematics, wiring diagrams, and bills of
materials.
listcon9. Electrical and instrumentation arrangement drawing and of
nections.
h. Coupling assembly drawing and bill of materials.
Primary and auxiliary seal schematic and bill of materials.
I.
i. Primary and auxiliary seal piping, instrumentation, arrangement, and
list of connections.
k. Cooling or heating schematic and bill of materials.
I. Cooling or heating piping, instrumentation arrangement, and list of connections.
30.
Spare parts recommendations and price list.
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
0-7
API STANDARD
61O
0-8
31. Preservation, packaging, and shipping procedures.
32. Material safety data sheets.
Motor
all auxiliary equipment
33. Certified dimensional outline drawing for motor and
including the following:
a. Size, location, and purpose ofall customer connections, including conduit, instrumentation, and any piping or ducting.
b. ANSI rating and facing for any flanged connections.
C. Size and location of anchor bolt holes and thicknesses of sections
through which bolts must pass.
d. Total weight of each item of equipment (motor and auxiliary equipment)
plus loading diagrams, heaviest weight, and name of the part.
e. Overall dimensions andall horizontal and vertical clearances necessary for dismantling and the approximate location of lifting lugs.
f. Shaft centerline height.
9. Shaft end dimensions, plus tolerances for the coupling.
h. Direction of rotation.
34. Cross sectional drawing andbill of materials including the axial rotor float.
35. Data sheets applicable to proposals, purchase, and as-built.
36. Noise data sheets.
37. Performance data including the following:
a. For induction motors 150 kW (200 hp) and smaller:
l . Efficiency and power factor at one-half, three-quarter, and full load.
2. Speed-torquecurves.
b. For induction motors larger than 150 kW (200 hp) and larger, certified
test reports forall tests run and performance curves as follows:
l. Time-currentheatingcurve.
2. Speed-torque curves at 70, 80,90, and 1O0 percent of rated voltage.
3. Efficiency and power factor curves from O to rated service factor.
4. Current versus load curves from O to rated service factor.
5. Current versus speed curves fromO to 1O0 percent of rated speed.
38. Certified drawings of auxiliary systems including wiring diagrams for each
auxiliary system supplied. The drawings shall clearly indicate the extent of
to be supplied
the system to be supplied by the manufacturer and the extent
by others.
39. Motor instruction manuals describing installation, operation, and maintenance procedures. Each manual shall include the following sections:
Section 1-Installation:
a.
Storage.
b. Setting motor, rigging procedures, component weights, and lifting diagram.
c. Piping and conduit recommendations.
d. Composite outline drawing for motor including locations of anchor bolt
holes.
e.Dismantlingclearances.
Section 2-Operation:
a. Start-up including check before start-up.
b.Normalshutdown.
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
A P I STDsblO 9 5
CENTRIFUGAL PUMPS FOR PETROLEUM,
0732270 0546257 351
m
HEAVYDUTY CHEMICAL, AND GASINDUSTRY SERVICES
c. Operating limits including number of successive starts.
d.Lube oilrecommendations.
Section 3-Disassembly and assembly instructions:
a. Rotor in motor.
b.Journalbearings.
c.
Seals.
d. Routine maintenance procedures and intervals.
Section 4-Performance data required by Item 37.
Section 5-Data Sheets:
a. As-built data sheets.
b. Noise data sheets.
Section 6-Drawing and data requirements:
a. Certified dimensional outline drawing for motor and all auxiliary equipment with listof connections.
b. Cross sectional drawing and bill of materials.
40. Spare parts recommendations and price list.
41.
Materialsafetydatasheets.
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
0-9
A P I STD*bLO 75
m 0732290
054b258 2 9 8
m
APPENDIX P-PURCHASER’S CHECKLIST
This checklist is to be used to indicate the purchaser’s specific requirements whenthis standard indicates that a decision is
required by the purchaser. In this standard,
items requiring adecision are indicated by a bullet preceding the paragraph
number.
The checklist should be used in conjunction with the
data sheets (see Appendix B). In the following list, the purchaser should
circle yes or no, or mark the appropriate space with anX.
Note: The use of this checklist is optional where these items are covered by a narrative specification.
Paragraph
1.2.2
Item
General:
Are SI dimensions or U.S. dimensions applicable? (See data sheets.)
Are IS0 standards or U.S. standards applicable? (See data sheets.)
Basic Design:
Are there any other anticipated operating
conditions?
2.1.3
Limitation on suction specific speed (see data sheets).
2.1.9
Is parallel operationanticipated?
2.1.11
2.1.14
Maximum allowable sound pressurelevel (see data sheets).
Is cooling required (see data sheets)?
2.1.17
Are local codes applicable?
2.1.22
Have copies been furnished to vendor?
2.1.21
What additional review of installation factors by vendor isrequired?
Review and comment on purchaser’s piping and foundation
drawings?
Observe acheck of the piping, performedby parting the flanges
after installation?
Be present duringthe initial alignment check of the pump anddrive train?
Recheck thealignment of the pumpand drive train at the operating temperature?
Location andenvironmental conditions (see data sheets).
2.1.29
Is pump suction on multistage pumpsto be suitable for maximum
2.2.4
allowable working pressure(single pressure casing)?
Are cylindrical threads required?
2.3.3.3
2.3.3.11
Are pressure gaugeconnections required?
Is API Standard682 compliance required?
2.7.3
2.7.3.17 Are jackets required on seal chambers?
2.7.3.19 Mechanical seal piping plan (see data sheets).
2.7.3.20 Are throttle bushings required with dualseals?
2.7.3.21 Dual seals and auxiliaryshaft sealing devices (see data sheets).
Is a torsionalanalysis report required if driver is in accordance to2.8.2.1?
2.8.2.6
2.9.2.2
Are specific constant level oilers required?
Are oilheaters required?
2.9.2.9
Are threaded connections requiredin bearing housingsfor mounting
2.9.2.11
vibration transducers?
2.9.2.12 Is a flat surface required on bearing housingf6r magnetic pick up?
Are provisionsto be made for pure or purge oil mist lubrication?
2.10.3
Have materialsof construction beenspecified?
2.11.1.1
Shall vendor furnishchemical and mechanicaldata for materials?
2.11.1.7
2.11.1.8 Have allcorrosive agents present beenspecified on the data sheets?
2.11.1.11 Is H,S present in pumpedfluid?
Shall casting repair procedures be submitted to the purchaser forapproval?
2.11.2.5
2.11.3.5.4 Shall connection designs be submitted to the purchaser forapproval?
P- 1
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
Yes
No
Yes
No
Yes
Yes
Yes
No
No
No
Yes
No
Yes
Yes
Yes
No
No
No
Yes
Yes
Yes
Yes
Yes
No
No
No
No
No
Yes
No
Yes
Yes
Yes
No
No
No
Yes
Yes
Yes
Yes
Yes
Yes
Yes
Yes
Yes
No
No
No
No
No
No
No
No
No
API STD+bLO 95
P-2
O732290 0546259 L24 W
API STANDARD
610
Purchaser’s Checklist (Continued)
Paragraph
Item
Basic Design (Continued):
2.1 1.3.5.6 Is special inspection of weldsrequired?
2.11.4.5
Minimum design metaltemperature for establishing impact tests
(See data sheets)
3.1.1
3.1.2
3.1.3
3.1.5
3.1.6
3.2.2
3.3.6
3.3.13
3.3.18
3.4.2.2
3.4.3.1
3.4.3.2
3.4.3.3
Accessories
Has the type ofdriver been specified on thedata sheets?
Are there process variationor startup conditions that
affect driver selection?
Driver starting conditions and methods (seedata sheets).
Motor type and characteristics (see data sheets).
Is it a reduced voltagestart?
Type of coupling (see data sheets).
Is a pump andbaseplate stiffness (pipe load) test required?
Shall pump, baseplate, and pedestalsupport assembly be
sufficiently rigid to be mounted without
grouting?
Are grout contact surfaces to be leftfree of paint andprimer?
Are liquid filled pressure gauges to be furnished?
Shall provision be made for mounting vibrationdetectors?
Shall detectors be furnished?
Shall detectors be installed?
Shall provision be madefor mounting a bearingtemperature detector?
Shall a bearing temperaturedetector be furnished?
Shall a bearing temperaturedetector be installed?
Shall monitors befurnished?
Shall monitors be installed?
Piping and Appurtenances
3.5.1.4
Are seal reservoirs to be mounted off the baseplate and shipped
separately?
3.5.2.6
Is chloride content above 10 parts permillion?
3.5.2.10.1 Are flanges required in place of socket weldedunions?
4.1.4
4.1.6
4.2.1.3
4.2.2.1
4.2.3.1
4.2.3.2
4.3.1.2
4.3.2.5
4.3.3.1.2
4.3.4
4.4.1
Inspection and Testing
Witnessed or observed tests (see data sheets).
Is purchaser’s inspector to submit completed inspection
checklist before shipment?
Is examination of pressure containing parts required?
Are specific additional material inspectioncriteria needed?
Will equipment be inspected for cleanliness?
Has hardness test been specified?
Is purchaser review of test procedures
required?
Is special hydrostatic test liquid required?
Are substitute seals to be used during the performancetest?
What optional tests are required by purchaser (see data sheets)?
Is long-term storage required?
Is type ofshipment specified?
Yes
No
Yes
No
Yes
No
Yes
No
Yes
No
Yes
Yes
Yes
Yes
Yes
Yes
Yes
Yes
Yes
Yes
Yes
No
No
No
No
No
Yes
Yes
Yes
No
No
No
Yes
Yes
Yes
Yes
Yes
Yes
Yes
Yes
No
No
No
No
No
No
No
No
Yes
Yes
No
Yes
No
No
No
No
No
No
No
No
Specific Pump Types
5.1.2.4
Shall vertical in-line pumps be designed for bolting to a pad or foundation?
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
~~~
A P I S T D x b L O 95
m 0732290
CENTRIFUGAL PUMPS FOR PETROLEUM,
054b260 9 4 b
HEAW DUTY CHEMICAL,
AND
H
GASINDUSTRY
P-3
SERVICES
Purchaser’s Checklist (Continued)
Paragraph
Item
Specific Pump Types (Continued):
5.1.2.7
5.1.3.3
5.2.2.2
5.2.5.2.4
5.2.6.1
5.2.6.2
5.2.6.3
5.2.6.5
5.2.6.6
5.2.7
5.2.8.5
5.2.9.2
5.3.4.1
5.3.7.3.5
5.3.8.2
5.3.9.7
5.3.12.6
Is a rigging device required to facilitate removal and installation of
the back pullout assembly?
Is a lateral critical speed analysisrequired?
Are impellers for multistage pumpsto be positively locked against
axial movement in the direction opposite to normal hydraulicthrust?
Is purchaser review of thrust bearingsizing required?
Is pressure lubrication system required?
Must oil side pressure be higher than waterside pressure?
Is heating of the oil reservoir required?
Is specific oil required?
Does API Standard614 apply for the pressure lubrication system?
Shall couplings and coupling mountings comply with
API Standard 671?
Must inspectionof hydrodynamic bearings after test be witnessed?
Is vertical storage of spare rotor required?
Is natural frequencyanalysis required for vertically suspended pumps?
Is grouting required for vertically suspended pumps (a
sole plate shall
be provided)?
Is a resonance test requiredfor vertically suspended pumps?
Is line shafting to be furnished with hardenedsleeves under thebearings?
Is a piped drain required in the suction canof vertical double case pumps?
Yes
Yes
No
No
Yes
Yes
Yes
Yes
Yes
Yes
Yes
Yes
Yes
Yes
Yes
Yes
No
No
No
No
No
No
No
No
No
No
No
No
Yes
Yes
Yes
No
No
No
Yes
Yes
No
No
Yes
No
Vendor’s Data:
6.1.3
6.2.3
6.2.5
Is coordination meetingrequired?
Is user list required withproposal?
Is a list of the procedures for any specialor optional tests required
with the proposal?
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
A P I STD*bLO 95
m
0732290 0 5 4 6 2 6 1 882
m
Appendix Q-Standardized Electronic Data Exchange File
Specification
Q.l
Scope
The purpose of this appendix is to establish a standard format for the storage and transmittal
of centrifugal pump data. This standard format is also known as the ”neutral data exchange file
format.”
Q.l.l The role of this specification is somewhat different from the “Standardized Electronic
Database” in the 7th Editionof A P I Standard 610.The data exchange file outlined in this specification extends beyond thescope of the API Standard 610 data sheets (Appendix B), such that data
fields for virtually all pertinent centrifugal pump infomation are defined within thisspecification.
This includes data fields thatare part of the following:
a. The A P I Standard 610 Centrifugal pump data sheets in the 8th Edition.
b. The A P I Standard 610 centrifugal pump data sheetsin the 7th Edition.
c. Additional data that isan important partof the informationexchange between the purchaser and
the manufacturer includingperformance curve data and other detailed technical information.
d. Dimensional infomation used in equipment general arrangement drawings.
e. Nozzle load data.
f. Multiple operating conditions.
Q.1.2 Purchasers and manufacturers are encouraged to use this specification to transfer data via
electronic methods rather than Vaditio~lpaper data sheets. proprietary systems designedto manage centrifugal pump databases may be used, provided import/export capabilities are used that
adhere to the data
exchange format of this specification The legal ramifications
of exchanging data
electronically is subject to policy established between purchaser and manufacturer. Data sheets
and/or specifications in paper format may be required as approved legal documents.
Q.1.3 APC-compatibleMI Centrifugal Pump Databare Program
that imports from or exports to
the data exchange file format will be availablein late 1995. This program will allow any purchaser or manufacturer to electronically communicate centrifugal pump datawith (a) any other user of
the Program or (b) any proprietary system with import/export capability. Standard API 610 data
sheets may be printed via thisProgram. To register to receive thediskette when it is available, call
A P I Publications and Distribution at 202-682-8375 or fax (202-962-4776)or mail the order form
at the endof this book.
Q.1.4 The data exchange file specification may be revised during the effective period of the 8th
Edition. Revisions to the program anddata exchange specification will beavailable to all registered
users of the program and throughAPI. Proprietary systems may be affected by these revisions but
will be generally protected through the revision control strategy outlined in the
specification.
Q-i
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
~
A P I STD*bLO 95
m
Q-2
~~
0732290 0 5 4 b 2 b 2 719
m
API STANDARD
610
Q.2 File Format
Q.2.1 FILESTRUCTURE
data.
The Neutral File format is comprised of a cornputer file, records, groups, and fields of
A sample file format is shown below.
8
#CENTRIFUGAL PUMP NEUTRAL FILE EXCHANGE
{header)
#VERSION 0.0
{version number}
#BEGIN: HEADER DATA
{start of header group}
----- File Header Data here: {see specification}
#END: HEADER DATA
{end of header group}
#RECORD STARTS
{start of record}
#BEGIN: PUMP DATA
{start of pump group)
Pump Data here: [see specification]
#END: PUMP DATA
{end of pump group}
#BEGIN: ADDITIONAL DATA
{start of additional group}
---- Additional Data here: [see specification]
#END: ADDITIONAL DATA
{end of additional group}
#BEGIN: DIMENSIONAL DATA
{start of dimensional group}
---- Dimensional Data here: [see specification]
#END: DIMENSIONAL DATA
{end of dimensional group}
#BEGIN: NOZZLE LOAD DATA
{start of nozzle load group}
---- Nozzle Load Data here: [see specification]
#END: NOZZLE LOAD DATA
{end of nozzle load group}
#BEGIN: ADDITIONAL OPERATING CONDITIONS
{start of additional perating
DATA
conditions group}
- ._
---- Additional Operating Conditions Data here
: [see specification]
#END: ADDITIONAL OPERATING CONDITIONS DATA {end of additional operating
c
----
ENDS #RECORD
#FILE ENDS
conditions group}
{end of record}
{end of file}
(2.2.2 DATA FILES
Data is exchangedasconventionalASCIItext
files supportedbyallcommon
computer operating systems such as DOS, UNIX, and VAXNMS. These files may be
createdandmodifiedusingstandardtexteditorssuch
asDOS(edit),UNIX(vi),and
VAWVMS (edit) or via a separate computer program.
The naming convention for the computer file is established directly between the
trading partners. However, the preferred file format is as follows:
where
and
-.pxf
xxxxxxxx is an 8 alphanumericfile prefix
pxf is a 3 digitfileextension(pumpexchangefile)
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
A P I STD*bLO
CENTRIFUGAL
PUMPS
FOR
95
m 0732290
PETROLEUM,
0546263 655 H
HEAVY
Dur/ CHEMICAL,
AND
GAShDUSTRY SERVICES
Each file must contain the file header shown below:
#CENTRIFUGALPUMPNEUTRALFILEEXCHANGE
#VERSION 1.O
number}
HEADER
DATA
#BEGIN:
----- File Header Data here: {see specification)
DATA
HEADER
#END:
and the end of file identifier
ENDS
#FILE
file}
(header)
(version
(start group}
of header
(endgroup}
of header
(end of
(2.2.3 DATA RECORDS
A record represents a collection of data about a single pump item(in aconventional
inquiry or proposal). The record starts with
(start of record}
#RECORD STARTS
and ends with
(end of record}
ENDS
#RECORD
Each file contains one
or more records.
Q.2.4 DATA GROUPS
Each record contains any of the followinggroups of field data.
a. Pump Data group. This group is mandatory for each record.
b. Additional Data group. This group is optional for each record.
C. Dimensional Data group. This group is optional for each record.
d. Nozzle Load Data group. This group is optional for each record.
e. Additional Operating Condtions Data group: This group is optional for each record. This
group may be repeated one or more times withm a record to represent multiple operating
conditions.
f. Header Data group: This group is mandatory for each file.
Q.2.5 DATA FIELDS
The body of the Neutral Exchange file are the data fields. Data fields are comprised of
the following:
a. Number: Field numbers are preceded by a group letter and a sequentially assigned 3 digit
number of the form:
Xnnn
where X is an alpha characterand nnn is a sequential number from O01 to 999
b. Delimiter: The delimiter is acomma (,) to separate the Field Number from theField Value.
c. Value: The value orcontents of the field corresponding to the fieldnumber.
Thevaluesare restricted according tothedefinitions outlined in 4 . 3 , Data Field
Definitions.
The one character fieldvalue, #, denotes a Required Reply Field. This indicatesto the
recipient of the exchange file that the specified field value is currently unknown as is
required upon reply by the recipient. This is used to clanfy the minimum set of data
fields which are required by the sender.
d. End of Field Delimiter: Each field is followed by an endof line and carriage return.
Q.2.6 EXAMPLES
The following examples show properNeutral Data Exchange File formats.
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
0-3
A P I STD*bLO 95
0732290 0546264 5 9 1
API STANDARD
610
0-4
(2.2.6.1 Example 1: Single record with only one group (Pump Data). The field values are
sample values only and arenot intended to represent a truepumping application.
#CENTRIFUGAL PUMP NEUTRAL FILE EXCHANGE
#VERSION 1.O
#BEGIN: HEADER DATA
F001,TO: Company A
F002,FROM: Company B
F003,DATE: October 5,1994
F005 1
#END: HEADER DATA
#RECORD STARTS
#BEGIN: PUMP DATA
AOOl,JOB21-3454
A002,ITEMOl
A003,Requisition number
A005,Purchase order number
A006,199501O1
A017,3X8
A018,DA
A019,6
A020,A pump company
A021,12-DA-90874-4523132
A022,109-132-76123-321984
A023,A
A025,l
A l 38,#
#END: PUMP DATA
#RECORD ENDS
#FILE ENDS
4.2.6.2 Example 2: Two records with all four groups in the first record and one group in the
second record. The field values are sample values only and are not intended to represent a true
pumping application.
#CENTRIFUGAL PUMP NEUTRAL FILE EXCHANGE
#VERSION 1.O
#BEGIN: HEADER DATA
F001 ,TO: Company A
F002,FROM: Company B
F003,DATE: October 5,1994
F005,2
#END: HEADER DATA
#RECORD STARTS
#BEGIN: PUMP DATA
AOOl,JOB21-3454
A002,ITEMOl
A003,Requisition number
AOO5,Purchase order number
AOO6,199501O1
A017,3X8
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
CENTRIFUGAL PUMPS FOR PETROLEUM, HEAW
DUTY CHEMICAL, AND GASlNDUSTRY SERVICES
A018,DA
A019,6
A020,A pump company
A021,12-DA-908744523132
A022,109-132-76123-321984
A023,A
A025,l
A138,#
#END: PUMP DATA
#BEGIN: ADDITIONAL DATA
8005,6000
8006,1.3209E+03
8007,200.0
8008,C
B009,l
E N D : ADDITIONAL DATA
#BEGIN: DIMENSIONAL DATA
cool,1200
c002,1200
C059,1200
#END: DIMENSIONAL DATA
#BEGIN: NOZZLE LOAD DATA
DOO1,1O00
D002,l O00
D003,l O00
D004,1234
D005 1234
D006,123
D007,lO00
D008,lO00
D009,1234
D010,3452
D01 1,7654
D012,1243
#END: NOZZLE LOAD DATA
#BEGIN: ADDITIONAL OPERATING CONDITIONS DATA
E002,200.1
E008,134.
#END: ADDITIONAL OPERATING CONDITIONS DATA
#BEGIN: ADDITIONAL OPERATING CONDITIONS DATA
E002,252.4
E008,103.
#END: ADDITIONAL OPERATING CONDITIONS DATA
#RECORD ENDS
#RECORD STARTS
#BEGIN: PUMP DATA
AOOI,JOB21-3455
A002,ITEM02
#END: PUMP DATA
#RECORD ENDS
#FILE ENDS
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
Q-5
API STANDARD
61O
Q-6
Q.3 Data Field Definitions
Q.3.1 DATAFIELDS
The body of the Neutral Exchange file described in 4.3.2 arethe datafields. Data field
definitinons arecomprised of the following:
a. Number: Field numbers are preceded by a group letter and a sequentially assigned 3 digit
number of the form:
Xnnn
where
X is an alpha character such that:
A = Pump group
B = Additional Data group
C = Dimensional Data group
D = Nozzle LoadData group
E = Additional Operating Conditions group
F = Header Data group
and nun is a sequentialnumber from O01 to 999
b. Name: A description of the field. This generally corresponds to a field name in a data
sheet.
C. Field: A field name is assigned for use in the definition of a computerized database. The
field name is not used as part of the neutral exchange file. This is 10 characters or less in
length.
d. Type: Describes the data field type where:
C is a character field. The contents are any ASCII characters. Note that a comma (J
is an acceptable character and should not be confused with the comma used as a data
field delimiter. Special restrictions
for
the field values are described inthe
ContentdUnits column in 4.3.2.
D isdate
a
field. Dates are represented as 8 character fields of the form
JTYYMMDD. For example, October 5,1994 is represented as 19941005.
I is an integer field. The contents are only whole number values. Examples include
1234 or 2.
L is a logical field. The contents are either:
Yes (true):
1
No (false):
O
N is a numeric field. The contents are numeric values that have a field length of 13.
Numeric values are represented by a maximum of 7 significant figureswhen the field is
shown in exponential notation. Any of the following notations are alsoacceptable:
Integer: 1234
Floating:
1234.00
Exponential:
+1.234OOO+EO3
e. Length: The maximum number of characters allowed.
f. ContentdUnit: Fields have the following additional attributes:
Contents are restricted to enumerated lists for certain fields. (Example: A:proposal;
B:purchase; C:as built; 2:other)
Units are assigned to certain numeric fields. Units are always stored according to the
preferred SI unitstandardfor
centrifugalpumps.
Theapplicationprogramis
responsible for converting the units into the
preferred units of the trading partner.
Q.3.2 DATA FIELD COMMENTS
The following N
I 610,8th Edition Neutral Data Exchange File Specification shows the
data fields within each
of the 6 data groups.
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
A P SI T D * b L O
95
m
0732290 054b2b7 2 T O
CENTRIFUGAL PUMPS FOR PETROLEUM,
HEAVY
DUTY
CHEMICAL,
AND
m
GASINDUSTRY
SERVICES
Q.3.3 COMMENTS TO THE NEUTRAL DATA EXCHANGE FILE SPECIFICATION
(2.3.3.1 POLYNOMIALEQUATIONS
Polynomial equations are used to describe continuous curves of pump flowrate versus
head, power, and N P S H R . A 6th order polynomial equation is written in the form:
l'=Al + A z Q + A 3 Q 2 + A 4 Q 3 + A s e+4 A s e 5 + A Q 6
The coefficients of these polynomial equations are used in either Group B, Additional
Data or Group E, Additional Operating Conditions such that the A , term corresponds to the
"term l",theA,term corresponds to the "term 2" designations ,etc.
The coefficient terms in Group B reference the impeller diameter, pump speed, and
liquid condtions described in the Group A, Pump Data. Alternatively, the coefficient terms in
Group E reference the impeller diameter in Group A and the pump speed and liquid conditions
referenced in Group E.
(2.3.3.2 REFERENCE TO HYDRAULIC INSTITUTE DIMENSIONAL STANDARDS
The nomenclature selected for the Dimensional Data Group (Group C ) was adopted from
the HydraulicInstituteStandardsforCentrifugal,Rotary,andReciprocatingPumps.
For
example, the fieldnumber COO1, "Width of basesupport", has thefield name definition of
"HIS-A". This corresponds to dimension "A" in the HydrauIic Institute Standards.
Q.3.4 REVISIONS TO THE NEUTRAL DATA EXCHANGE FILE SPECIFICATION
(2.3.4.1 Revisions to this specification are identified by Version Number. As of this writing, the
Version Number is 1.0, Those organizations which develop proprietary systems which conform
tothis data exchange specification are responsible for maintaining compatibility with new
Version Numbers.
Q.3.4.2
Future program revisions are expectedto adhere tothefilestructureoutlinedin
paragraph 4.2.1. New fields will be introduced within each Data Group by issuing new 3 digit
sequence numbers. New revisions to the Data Exchange Specification will be made available
throughthe A P I Publications Oftice or through an upcoming API electronicbulletin board
service.
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
Q-7
API STANDARD
610
Q-8
API 610,8th Edition
Neutral Data ExchangeFile Specification
15Jun-95
No
Name
Field
ContentsRJnit
Type Length
Pump Data
Headings
JOB-NO
C
10
A002
Item
number
ITEM
C
25
A003
Requisition
Number
REQ-N
25
AO01
Job
number
A004
Specification
Number
SPEQ-N
C
C
AO05
Purchase
Order
Number
PO-NO
C
25
AO06
Purchase
Order
Date
DATE
D
8
A007
Inquiry
Number
INQ-NO
C
25
25
AO08
Inquiry By
INQ-BY
C
15
A009
Revision
Number
REV
C
2
AO10
Revision
Date
For
AO11
REV-DATE
D
8
FOR
C
59
A012
Applicable
To
APPLIC
C
1
Unit
A013
UNIT
C
20
A014
Site
SITE
C
59
AO15
Number
Required
NO-REQD
I
5
Service
A016
SERVICE
C
30
PUMP-SIZE
C
30
A01 7
Pump Sue
YYYY"DD
YYYYMMDD
A:proposal; B:purchase; C:as built; Zother
A01 8
Pump
Type
PUMP-TYPE
C
20
A019
Number of Stages
STAGES
I
5
A020
Manufacturer
MFGR
C
25
MODEL
C
SERIAL
C
20
20
1
A:parallel; B:series;C:both series and
parallel; 2:other
1:yes (true); O: no (false)
Model
A021
AO22
Serial
Number
General
AO23
Operation
OPERATE
C
A024
IS0 Standard
US Standard
lS0-STD
C
1
A025
US-STD
C
1
I:yes (true); O: no (false)
AO26
Other
Standard
OTH-STD
C
1
1 :yes (true);O: no (false)
A027
Number
Motor
Driven
NO-PMPS-M
NO-PMPS-T
I
I
5
A028
Number
Turbine
Driven
Wifh
Pump ItemNumberMotorDrive
Pump ItemNumberTurbineDrive
PUMP-WITH
C
20
ITEM-NO"
C
24
ITEM-NO-T
C
24
A032
Gear Item Number
G-ITEM-NO
C
24
A033
Motor
Item
Number
M-ITEM-NO
C
24
Turbine
Item
Number
T-ITEM-NO
C
24
20
AO29
AO30
A031
A034
5
A035
Gear
Provided
By
G-BY
C
AO36
Motor Provided By
"BY
C
20
A037
Turbine
Provided
By
T-BY
C
20
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
Q-9
Field No
Gear
AO38
Type Length Contentdunit
Name
By
Mounted
By
A039
Motor
Mounted
Turbine Mounted By
G-MTD-BY
C
M-MTD-BY
C
20
20
20
20
T-MTD-BY
C
A041GearDataSheetNumber
G-DATA-SHT
C
AO42
Motor
Datasheet
Number
M-DATA-SHT
C
AO43
Turbine DataSheetNumber
T-DATA-SHT
C
20
20
A040
Operating Conditions
AO44
Normal
Capacity
A045
Rated
Capaclty
NORM-CAP
N
13
m3/h
RATED-CAP
N
13
m3/h
AO46
Other
Capacity
OTHER-CAP
N
13
rnVh
A047
Suction Pressure
Maximum
SUCT-PRESM
N
13
kPa
A048
Suction Pressure Rated
SUCT-PRES
N
13
kPa
DISCH-PRES
N
13
kPa
kPa
A049
Discharge
Pressure
A050
Differential Pressure
DIFF-PRES
N
13
A051
Differential Head
HEAD
N
13
m
A052
NPSH
Available
NPSHA
N
13
m
A053
Hydraulic
Power
HYD-POWER
N
13
kW
A054
Process Variations
PROC-VAR
C
25
AO55
Driver Starting Conditions
DR-START-C
C
25
OPER-SERV
C
1
STRTS-PER
I
5
PAR-OPER
C
1
I:yes (true);O: no (false)
1 :yes (true);O: no (false)
Service
A056
A057
Starts per Day
A058
Parallel
operation
required
A:continuous; Bhtermittent; Z:other
Site and Utility Data
A059
Indoor
INDOOR
C
1
A060
Outdoor
OUTDOOR
C
1
1 :yes (true);O: no (false)
A061
Grade
GRADE
C
I
1 :yes (true);O: no (false)
1
1 :yes (true);O: no (false)
1
1 :yes (true);O: no (false)
A062
Heated
HEATED
A063
Mezzanine
MEU
Ç
C
1
1:yes (true); O: no (false)
1
1:yes (true); O: no (false)
A064
Under Roof
ROOF
C
A065
Partial Sides
PART-SIDES
C
A066
Other Location
OTHER-SITE
C
19
A067
Electric Area Classification CL
ELECT-CL
C
6
AO68
Electric Area Classification GR
ELECT-GR
C
6
A069
Electric Area Classification DIV
ELECT-DIV
C
1
A070
Winterization
WINTER
C
1
AO7 1
Tropicaliation
TROPIC
C
1
1:yes (true); O: no (false)
13
m
1:yes (true); O: no (false)
A072
Altitude
ELEV
N
A073
Barometer
BAR
N
13
kPa abs
A074
Ambient Temperature: Min
SITE-TM-MN
N
13
"C
A075
Ambient Temperature: Max
SITE-TM-MX
N
13
"C
N
13
% (O to loo)
A076
Relative Humidity:Max
SITE-RH-MX
A077
Relative Humidity: Min
SITE-RH-MN
N
13
% (O to loo)
A078
Dust Atmosphere
DUST-ATM
C
1
1 :yes (true);O: no (false)
A079
Fumes Atmosphere
FUME-ATM
C
1
1 :yes (true);O: no (false)
A080
Other Atmosphere
OTHER-ATM
C
25
A081
Steam Drivers Minimum Pressure
DSTM-MNPR
N
A082
Steam Drivers Minimum Temperature
D-STM-MNTM
N
13
13
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
kPa
"C
A P I S T D x b l O 95
0732Z90 0596270 895
m
API STANDARD
610
Q-1O
No
Name
A083
A084
FieldLength
Type
Steam
Drivers
Maximum
Pressure
D-STM-MXPR
N
13
SteamDriversMaximumTemperature
D-STM-MXTM
N
13
"C
H-STM-MNPR
N
13
kPa
H-STM-MNTM
N
13
"C
A087HeatingMaximumSteamPressure
H-STM-MXPR
N
13
kPa
A088HeatingMaximumSteamTemperature
H-STM-MXTM
N
13
"C
A089
Driver
DVR-V-MIN
N
13
V
A090
Driver
Volts
Maximum
DVR-V-MAX
N
13
V
A091
Driver
Hertz
DVR-HERTZ
N
13
Hz
A092
Driver
Phase
DVR-PHASE
I
1
Volts Minimum
HTG-V-MIN
N
13
V
Heating Volts Maximum
HTG-V-MAX
N
13
V
Hz
A085HeatingMinimumSteam
A086
HeatingMinimumSteamTemperature
Volts Minimum
A093
Heating
AO94
Pressure
Contentsiunit
A095
Heating
Hertz
HTG-HERTZ
N
13
A096
Heating
Phase
HTG-PHASE
I
1
kPa
A097
Control
Volts
CNTL-VOLTS
N
13
V
A098
Control
Hertz
CNTL-HERTZ
N
13
Hz
AO99
Control Phase
CNTL-PHASE
I
1
A l O0
ShutdownVolts
SHDN-VOLTS
N
13
V
A l O1
Shutdown
Hertz
SHDN-HERTZ
N
13
Hz
SHDN-PHASE
I
1
A102
Shutdown
Phase
"C
A103Cooling
Water TemperatureInlet
C-WTR-TMIN
N
13
A104Cooling
Water MaximumReturn
C-WTR-TMOU
N
13
"C
A l 05
Cooling Water PressureNormal
C-WTR-PRNO
N
13
kPa
A l 06
Cooling Water PressureDesign
C-WTR-PRDE
N
13
kPa
A l 07
Cooling Water MinimumReturnPressure
C-WTR-PROU
N
13
kPa
Al08
Cooling Water MaximumDelta P
C-WTR-PRDI
N
13
kPa
A l O9
Cooling Water Source
C-WTR-SOUR
C
20
A l 10
Coolingwaterchlorideconcentration
C-WTR-CHL
N
13
AI 11
InstrumentAir:MaximumPressure
AIR-PR-MX
N
13
kPa
A l 12
Instrument Air:Minimum Pressure
AIR-PR-MIN
N
13
kPa
40
parts per million
Liquid
Ai13
Name of Liquid
LlQ-NAME
C
A l 14
Pumping Temperature Normal
TEMP-NORM
N
13
"C
A l 15
Pumping Temperature Maximum
TEMP-MAX
N
13
'C
"C
A l 16
Pumping Temperature Minimum
TEMP-MIN
N
13
A l 17
Specific Gravity Q Normal Temperature
SG-NORM
C
13
A l 18
Specific Gravity Q Maximum Temperature SG-MAX
C
13
A l 19
Specific Gravity Q Minimum Temperature
SG-MIN
C
13
A I 20
Specific Heat
SP-HEAT
N
13
kJ/kg"C
A l 21
Vapor Pressure
VAPOR-PRES
N
13
kPa abs
A l 22
Vapor pressure temperature
VAPOR-TEMP
N
13
"C
AI23
Viscoslty
VISC
N
13
CP
A l 24
Viscosity Temperature
VISC-TEMP
N
13
"C
A l 25
Maximum Viscosity
"VISC
N
13
CP
A l 26
CorrosiveiErrosive Agent
CORROSIVE
C
15
A l 27
Chloride concentration
CH-CON-LIQ
N
13
parts per million
A l 28
H2S Concentration
HZS-CONC
N
13
parts per million
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
API STD*bLO 95 m 0732290 0 5 4 b 2 7 1 721 m
CENTRIFUGAL
PUMPSFOR PETROLEUM,
HEAVYDUTY
CHEMICAL,
No
Name
Type
Field
AND
GASINDUSTRY SERVICES
Q-11
Length Contentdunit
~
A l 29
A l 30
Hazardous(Toxic)
Flammable
A131
Other
Liquid
Hazard
1 :yes (true);O: no (false)
TOXIC
C
1
FLAMMABLE
C
1
1 :yes (true);O: no (false)
OTHER-HZRD
C
1
1 :yes (true);O: no (false)
RPM
Performance
A l 32
Rated pump speed
PMP-RPM
N
13
A l 33
Proposal Curve Number
PROP-CRV-N
C
15
IMP-DIA-RA
N
13
mm
A l 35
Impeller Diameter Maximum
IMP-DI-MAX
N
13
mm
A l 36
Impeller Diameter Minimum
IMP-DI-MIN
N
13
mm
A l 37
Rated Power
BHP
N
13
kW
AI 38
Efficiency
EFF
N
13
% (O to 100)
A l 39
Minimum flow: thermal
MN-FL-THER
N
13
m’/h
MN-FL-STAB
N
13
m3/h
m
AI 34 Impeller Diameter Rated
A l 40
Minimum flow stable
A l 41
Maximum head rated impeller
MAX-HEAD
N
13
A I 42
Preferred operating region (mimimum)
OPER-PREF1
N
13
mVh
A l 43
Preferred operating region (maximum)
PREF-OPER2
N
13
m3/h
A l 44
Allowable operating region (minimum)
ALWB-OPER1
N
13
mVh
A l 45
Allowable operating region (maximum)
ALWB-OPER2
N
13
m’lh
A l 46
Maximum power rated impeller
MAX-PWR
N
13
kW
A l 47
NPSH required
NPSHR
N
13
m
N
13
metric units (see paragraphI.4.42)
A l 48
Suction specific speed
SP-SPEED
DBA
N
13
dBA
N
13
d BA
PERF-REMK
C
140
ID
PUMP-CLASS
C
3
8th editioncompliance
APl6lO-CMP
C
1
A l 49
Maximum sound pressure level required
A I 50
Estimated maximum sound pressure level EST-DBA
A l 51
Performance remark
Construction
A l 52Pumpclassification
A153API610,
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
OVERHUNG TYPE:
OH1:foot mounted/horizontal/flexibly coupled
OH2:center line mounted/horizontal/flexibly
coupled
OH3:in-line bearing frame/vertical/flexibly
coupled
OH4:in-line/vertical/rigidlycoupled
OH5:high speed integral gearhidgidly
coupled
BETWEEN BEARINGS TYPE:
BB1 :axially spliV1 or 2 stages
BB2:radially spliUl or 2 stage
BB3:axially spliVmultistage
BB4:single casehadially splitlmultistage
BB5:double case/radially spliVmultistage
VERTICAL SUSPENDED TYPE:
VS1 :single caseldischarge through
colurnnldiffuser
VS2:single casddischarge through
column/volute
VS3:single caseldischarge through
column/axial flow
VS4:single caselseperate discharge/line
shaft
VS5:single case/seperate
dischargelcantilever
VS6:double case (canned)/diffuser
VS7:double case (canned)/volute
Z:Other
1 :yes (true);O: no (false)
~~
A P I STD*bLO
Q-12
m
95 M 0732290 0546272 668
API STANDARD
610
No
Name
FieldLength
Type
A l 54
Other compliance
OTH-COMP
C
1
A l 55
Other compliance remark
OTH-COMP-R
C
20
A l 56
Suction Size
SUCT-SIZE
C
10
A l 57
Suction Rating
SUCT-RATE
C
10
A l 58
Suction Facing
SUCT-FACE
C
1
A:flat face; B:raised flange; C:ring type joint;
D: threaded; ï!:other
A l 59
Suction position
SUCT-POSIT
C
1
A l 60
Discharge size
DISCH-SIZE
C
10
A:end; B:top; C:side; D:bottom; E:inline;
F:sump; G:can; 2:other
The decimal numericvalue is followed by
"mm" or "in". Example: 1.5 in or 38 mm
A161
Discharge rating
DISCH-RATE
C
10
AI62
Discharge facing
DISCH-FACE
C
1
A:flat face; B:raised flange; C:ring type joint;
D:threaded; 2:other
A l 63
Discharge position
DISCH-POSI
C
1
A:top; B:side; C:inline; Z:other
A l 64
Balance drum size
BAL-DR-SI2
C
10
The decimal numeric value
is followed by
"mm" or "in". Example: 1.5 in or 38 mm
A l 65
Balance drum rating
BAL-DR-RAT
C
10
A l 66
Balance drum facing
BAL-DR-FAC
C
5
ContentsATnit
A l 67
Balance drum position
BAL-DR-POS
C
6
A l 68
Other mnn size
OTHER-SIZE
C
10
A l 69
Other connrating
OTHER-RATE
C
10
A l 70
Other conn facing
OTHER-FACE
C
1
A171
Other conn position
OTHER-POSI
C
6
A l 72
Number of drains
DRN-NO
I
5
A l 73
Drain size
DRN-SIZE
C
10
A l 74
Drain type
DRN-TYPE
C
15
A l 75
Number of vents
VENT-NO
I
5
A l 76
Vent size
*VENT-SIZE
C
10
A l 77
Vent type
VENT-TYPE
C
15
A l 78
Number pressuregauge
P-GAGE-NO
C
5
A l 79
Pressure gauge size
P-GAGE-SIZ
C
10
A l 80
Pressure gauge type
P-GAGE-TYP
C
15
A l 81
Number temperature gauge
T-GAGE-NO
I
5
A l 82
Temperature gauge sue
T-GAGE-SIZ
C
10
1:yes (true); O: no (false)
The decimal numeric valueis followed by
"mm" or "in". Example: 1.5 in or 38 mm
The decimal numeric value is followed by
"mm" or "in". Example: 1.5 in or 38 mm
A: flat face; B:raised flange; C:ring type
joint; D:threaded; 2:other
The decimal numeric valueis followed by
"mm" or "in". Example: 1.5 in or 38 mm
The decimal numeric value
is followed by
"mm" or "in". Example: 1.5 in or 38 mm
The decimal numericvalue is followed by
"mm" or "in". Example: 1.5 in or 38 mm
The decimal numeric value is followed by
or "in".Example: 1.5 in or 38 mm
,Smm"
A l 83
Temperature gauge type
T-GAGE-TYP
C
15
A l 84
Number warm up
WRMUP-NO
I
5
A I 85
Warm upsize
WRMUP-SIZE
C
10
A l 86
Warm up type
WRMUP-TYPE
C
15
A l 87
Balance I leak-off number
B-LEAK-NO
I
5
A l 88
Balance I leak-off size
B-LEAK-SI
C
10
A l 89
Balance I leak-off type
B-LEAK-TY
C
15
A l 90
Cylindrical threads required
CYLTHR-REQ
C
1
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
The decimal numeric valueis followed by
"mm" or "in". Example: 1.5 in or 38 mm
The decimal numericvalue is followed by
"mm" or "in". Example: 1.5 in or 38 mm
1 :yes (true);O: no (false)
CENTRIFUGAL PUMPS FOR PETROLEUM, HEAWDUTY CHEMICAL,
AND GAS INDUSTRY
SERVICES
Q-13
~
A l 91
Casing mounting
CSG-MTG
C
1
A l 92
Casing split
CSG-SPLT
C
1
A l 93
Casing type
CSG-TYPE
C
1
A I 94
Impeller mounted
IMP-MOUNT
C
1
I
~~
Axenter-fine; B:near center-line; C:foot;
D:seperate mounting plate; E:vertical;
F:sump; G:inline; Z:other
A:axial; B:radial; 2:other
A: single volute;B:muliple volute;
C:diffuser; D:staggered volute; E:barrel;
F:vertical double casing;
Z:other
A:between bearings; B:over hung;
C:vertically suspended; Z:other
I:yes (true); O: no (false)
A l 95
Impellers secured against reverse thrust
IMP-IND-SE
C
A l 96
Case pressure
CASE-PRESS
C
1
1 :yes (true);O: no (false)
A l 97
Maximum allowable working pressure
MAWP
N
13
kPa
A l 98
Reference temperature forMAWP
T-MAWP
N
13
"C
A l 99
Casing hydrotest pressure
CASE-HYD
N
13
kPa
A200
Rotation
ROTATION
C
1
A: CW; B:CCW per Hydraulic Institute;
Z:other
A201
Construction remark
CONST-RMK
C
140
A202
Bott OH-3 pump to pad/foundation
BOLT-FNDN
C
1
1:yes (true); O: no (false)
A203
Shaft diametera! sleeve
SH-DI-SLVE
N
13
mm
A204
Shaft diameterat coupling
SH-DI-CPLG
N
13
mm
A205
Shaft diameter between bearings
SH-DI-BRGS
N
13
mm
A206
Span between bearings
SPAN-BRGS
N
13
mm
A207
Impeller overhang
SPAN-BR-IM
N
13
mm
A208
Shaft remark
SHAF-REMK
C
140
A209
Coupling make
CPLG-MFG
C
A21O
Coupling model
CPLG-MODEL
C
15
10
A21 1
Coupling rating
CPLG-RATE
N
13
A21 2
Coupling lubrication
CPLG-LUBE
C
15
A213
Limited endfloat required
CPLG-ENDF
C
1
1:yes (true); O: no (false)
A21 4
Coupling spacer length
CPLG-SPCR
N
13
mm
A21 5
Service factor
CPLG-SERV
C
13
kW / IO00 RPM
1 :yes (true);O: no (false)
A216
Dynamic balance
CPLG-BAL
C
1
A21 7
Balance class
CPLG-CLASS
C
2
A21 8
Driver half coupling mountedby
MTD-CPLG
C
1
A219
Coupling perAPI 671
CPLG-671
C
1
A220
API Baseplate number
BASE-NO
C
5
A221
Non grout construction
NON-GROUT
C
1
1:yes(true); O: no (false)
A222
Vertical level screws
VERT-SCREW
C
1
1:yes (true); O: no (false)
A223
Horizontal positioning screws
HORZ-SCRE
C
1
1:yes(true); O: no (false)
A224
Coupling remark
CPLG-REMK
C
140
5
A:pump mfg; 6:driver mfg; C:purchaser;
Zother
1 :yes (true); O: no (false)
Materials
A225
Table Hl material class
MATL-CLASS
C
A226
Minimum metal temperature
MATL-MN-T
N
13
A227
Barrekase material
MATL-CASE
C
20
Aî28
Impeller material
MATL-IMP
C
20
A229
A230
A231
Case wearing material
ML-WR-RI-C
c
X)
Impeller wear ring material
ML-WR-RI-I
C
20
Shaft material
MATL-SHAFT
C
20
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
"C
A P I STDlrbLO 95 M 0732290 0546274 430 M
Q-14
STANDARD
610
No
Name
Field
Type Length ContentdUnit
A232
Sleeve
material
MATL-SLEEV
C
A233
Diffusor
material
MATL-DIFFU
C
20
MATL-C P-H U
C
20
A234
Coupling
hubs material
20
A235
Coupling
spacer
material
MATL-CP-SP
C
20
A236
Coupling
diaphragm
material
MATL-CP-DI
C
20
A237
Baseplate
material
MATL-BSEPL
C
20
A238
Material
remark
MATL-RMK
C
140
Bearings and Lubrication
type
A239
Radial
bearing
RAD-BRG-T(
C
10
A240
Radial
bearing
number
RAD-ERG-NU
C
10
A241
Thrust
bearing
type
THR-BRG-TY
C
10
A242
Thrust
bearing
number
THR-BRG-NO
C
10
A243Review
Iapprovethrustbearingsize
APP-THR-BR
C
1
1 :yes (true);O: no (false)
A244
Lubrication
LUBRlCATlO
C
1
A245
Oil mist
lubrication
OIL-MIST-L
C
1
A:grease; 6:flood; C:ring oil; D:flinger;
2:other
A:none; B:purge oil mist; C:pure oil mist;
Z:other
A246
Constant
lever
oiler
CONST-LVL
C
1
Pressure
A247
PRESS-LU6
C
1
1 :yes (true);O: no (false)
AP1-61O-LU
C
1
1 :yes (true); O: no (false)
1 :yes (true);O: no (false)
A248
API
A249
610
API
614
1 :yes (true);O: no (false)
AP1-614-LU
C
1
ISO-VIS
C
15
A251
Oil
heater
required
O IL-H EAT
C
1
A:none; B:electric; C:steam; Z:other
A252Oilpressuregreaterthancoolant
OIL-P-GT-C
C
1
1 :yes (true);O: no (false)
A253
Lubrication
remark
LUBE-RMK
C
140
SEAL-SPEC
C
1
A: API 682; B: API 610; C:none; Zother
SHT-682-AT
C
1
1 :yes (true);O: no (false)
API682 seal
NON-682-SL
C
1
1 :yes (true);O: no (false)
A257
Seal
chamber
temperature
SEAL-TEMP
N
13
"C
A258
Seal
chamber
pressure
SEAL-PRESS
N
13
kPa
A259
Sealchamberflowrate
SEAL-FLOW
N
13
mVh
A260
API Sealchambersize
SEAL-CHAM6
C
5
A250Oilviscosity
I S 0 grade
Mechanical Seal or Packing
A254
Seal
specification
A255
A256Non
API 682 Datasheetattached
A261
Seal
chamber
bore
SEAL-BORE
N
13
mm
A262
Seal
total
length
SEAL-TOT-L
13
mm
A263
Seal
clear
length
SEAL-CLR-L
N
N
13
mm
A264AppendixHAPIclasscode
SEAL-CODE
C
5
A265
Seal
manufacturer
SEAL-MFR
C
15
A266
Seal
size
SEAL-SIZE
C
10
A267
Seal
type
SEAL-TYPE
C
10
A268
Manufacturer
code
SEAL-MFR-C
C
15
A269
Cartridge
mount
SEAL-CART
C
1
1 :yes (true); O: no (false)
1:yes (true); O: no (false)
A270Hookedsleeve
I noncartridge
SEAL-NON-C
C
1
A271
No
sleeve
SEAL-NO-SL
C
1
1 :yes (true); O: no (false)
A272
Circulating
device
CIRC-DEV
C
1
1 :yes (true);O: no (false)
A273
Sleeve
material
SLEEVE-MAT
C
10
A274
Gland
material
GLAND-MATL
C
10
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
CENTRIFUGAL
PUMPSFOR PETROLEUM,
HEAVY
DUTY
CHEMICAL,
AND
GASINDUSTRY
SERVICES
No
Name
Field
Type Length Contentdunit
A275
Aux seal device
AUX-SEAL-D
C
15
A276
Jacket required
JACKET-REQ
C
1
1 :yes (true);O: no (false)
A277
Flush gland taps
F-GLAND-TA
C
1
1 :yes (true);O: no (false)
A278
Drain gland taps
D-GLAND-TA
C
1
1:yes (true);O: no (false)
A279
Barrier gland taps
B-GLAND-TA
C
1
1:yes (true); O: no (false)
A280
Vent gland taps
V-GLAND-TA
C
1
1:yes (true); O: no (false)
A281
Cooling gland taps
C-GLAND-TA
C
I
1 :yes (true);O: no (false)
1 :yes (true);O: no (false)
A282
Quench gland taps
Q-GLAND-TA
C
1
A283
Heating gland taps
H-GLAND-TA
C
1
1 :yes (true);O: no (false)
A284
Lubricant gland taps
L-GLAND-TA
C
1
1 :yes (true);O: no (false)
A285
Leakage gland taps
LK-GLND-TA
C
1
1 :yes (true);O: no (false)
A286
Pumped fluid gland taps
PF-GLND-TA
C
1
1:yes (true);O: no (false)
A287
Balance fluid gland taps
BF-GLND-TA
C
1
1 :yes (true);O: no (false)
A288
Fluid injection gland taps
EF-GLND-TA
C
1
1:yes (true);O: no (false)
A289
Flush supply temperature
FLUSH-TEMP
N
13
"C
A290
Flush minimum temperature
FLUSH-T-MI
N
13
"C
A291
Flush maximum temperature
FLUSH-T-MA
N
13
"C
A292
Specific gravity
FLUSH-SG
C
13
A293
Specific gravity temperature
FLUSH-SG-T
N
13
A294
Flush fluid name
FLUSH-FLUI
C
20
A295
Flush specific heat
FLUSH-SP-H
N
13
kJ/kg"C
A296
Flush vapor pressure
FLUSH-VP
N
13
kPa abs
A297
Flush vapor pressure temperature
FLUSH-VP-T
N
13
"C
A298
Flush hazardous
FLUSH-TOXI
C
1
1 :yes (true);O: no (false)
A299
Flush flammable
FLUSH-FLAM
C
1
1 :yes (true);O: no (false)
A300
Flush other
FLUSH-OTHE
C
15
A301
Flush maximum flowrate
FLUSH-MAX
N
13
m3/h
A302
Flush minimum flowrate
FLUSH-MIN
N
13
m3/h
A303
Flush maximum pressure
FLUSH-P-MX
N
13
kPa
A304
Flush minimum pressure
FLUSH-P-MN
N
13
kPa
A305
Flush maximurn temperature
FLSH-T-MX
N
13
"C
13
"C
"C
A306
Flush minimum temperature
FLUSH-T-MN
N
A307
Barrier minimum temperature
BARR-TM-MN
N
13
"C
A308
Barrier maximum temperature
BARR-TM-MX
N
13
"C
A309
Barrier SG
BARR-SG
C
13
A31O
Barrier SG Temperature
BARR-SG-TM
N
13
A31 1
Barrier liquid name
BARR-FLUID
C
20
A312
Barrier vapor pressure
BARR-VP
N
13
kPa abs
A31 3
Barrier vapor pressure temperature
BARR-VP-TM
N
13
"C
1
1 :yes (true);O: no (false)
1 :yes (true);O: no (false)
A31 4
Barrier toxic
BARR-TOXIC
C
"C
A315
Barrier flammable
BARR-FLAME
C
1
A31 6
Barrier other
BARR-OTHER
C
15
A317
Barrier now maximum
BARR-FL-MX
N
13
mYh
Barrier flow minimum
BARR-FL-MN
N
13
mYh
kPa
A318
A31 9
Barrier maximum pressure
BARR-PR-MX
N
13
A320
Barrier minimum pressure
BARR-PR-MN
N
13
kPa
A321
Barrier temperature maximum
BARR-T-MAX
N
13
"C
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
Q-15
API STANDARD
610
016
No
Name
A322
Barrier
temperature
minimum
A323
Quench
fluid
Field
Type Length Contentsmnit
BARR-T-MIN
N
13
QUENCH-FLU
C
20
N
13
A325Sealflushpipeplan
QUENCH-FLO
SEAL-PI-PL 1
C
A326
Seal
piping
construction
SEAL-PIPE
C
A327
Piping
material
PIPE-MAT 1
C
A328
Other
material
description
0-MTL-DESC
C
A329
Aux
piping
plan
AUX-PI-PL 1
C
A330Auxpipingplanconstruction
AUX-PLAN-T1
C
A331Auxpipingplanmaterial
AUX-PIAN"
C
1
A332Otherauxmaterialdescription
O-AUX-"D
C
20
A333
Piping
connections
ASSEMBLY 1
C
A334
ASSEMBLY2
1
C
A324Quench
flow rate
Pipingconnectionspart2
"C
m3/h
A:none; B:API Plan 1; C: API Plan 2;
D: API Plan 11; E: API Plan 12;
F:API Plan 13; G:API Plan 14;
H:API Plan 21; LAPI Plan22;
J:API Plan 23; K:API Plan 31;
L:API Plan 32; M:API Plan 41
;
N:API Plan 51; 0:API Plan 52;
P:API Plan 53; Q:API Plan 54;
R:API Plan 61; S:API Plan 62;2: other
1
A:tubing; B:pipe; Z:other
A:carbon steel; B:stainless steel; 2:other
20
A:none; RAPI Plan 52; C:API Plan 53;
D:API Plan 54;E:API Plan 61; F:API Plan
62; 2:other
A:tubing; B:pipe; 2:other
A:carbon steel; B:stainless steel; 2:other
A:threaded; B:socket welded; C:seal
welded; 2:other
A:unions; B:flanged; 2:other
A335Sealpipingtubefitting
SEAL-T-ASY1
C
A336Sealtubefmingtype
SEAL-T-FIT
C
A337
Seal
flow
indicator
SEAL-FI
1
C
1 :yes (true);O: no (false)
A338
Seal
pressure
switch
SEAL-PS
1
C
1 :yes (true);O: no (false)
A339Sealpressureswitchtype
SEAL-PS-TY15
C
A340
Seal
pressure
gauge
SEAL-PI
C
A341
Seal
level
switch
SEAL-LS
C
1
A342Seallevelswitchtype
SEAL-LS-TY
C
15
A343
Seal
level
gauge
SEAL-LG
A344
Seal
temperature
indicator
SEAL-TI
A345
Seal
heat
exchanger
SEAL-HX
A346
Mechanical
seal
remarks
SEAL-RMK
C
140
A347
Packing
manfacturer
PKG-MFR
C
m
PKG-TYPE
C
20
PKG-SIZE
C
13
PKG-RINGS
I
5
A351
Packing
injection
required
PKG-INJ
C
1 :yes (true);O: no (false)
A352
Packing
injection
flow
PKG-FLOW 13
N
m3/h
A353
Packing
PKG-PRESS
N
13
PKG-LANTER
C
20
A348
Packing
type
A349
Packing
size
A350
Packing
no rings
injection pressure
A354
Packing
lantern
ring
1
1
1
1 :yes (true);O: no (false)
1 :yes (true);O: no (false)
1 :yes (true);O: no (false)
C
C
1
1 :yes (true);O: no (false)
15
1
C
1 :yes (true);O: no (false)
1 :yes (true);O: no (false)
kPa
Cooling Water Piping
A355Coolingwaterpipeplan
CW-PIPE-PN
A356Coolingwatersightflowindicator
A357Coolingwatermanifoldoutlet
valve
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
A:Plan
1CB:Plan
A;
SIGHT-FLOW
C
MANIFOLD-V
1
C
B; C:Plan
D:Plan
C; D;
E:Plan E; F:Plan F; G:Plan G; H:Plan H;
J:Plan J; K:Plan K; L:Plan L; M:Plan M;
N:none;Z:other '
1
1 :yes (true); O: no (false)
1 :yes (true);O: no (false)
A P I S T D * b l O 95
CENTRIFUGAL
PUMPS
Field No
FOR
m 0732290
054b277 L 4 T
PETROLEUM, HEAVY
DUTY
CHEMICAL,
AND
m
GASINDUSTRY SERVICES
Type Length ContentdUnit
Name
Cooling
A358
water material
piping
CW-PIP-MAT
C
1
A:galvanized pipe; B:copper tube;
C:stainless tubing; 2:other
m%
N
13
A360
Cooling
waterlseal
jacket
pressure
SEAL-JKT-P
N
13
kPa
A361
Cooling
water/bearing
housing
BRG-H-FL
flow
N
13
m%
N
13
kPa
Cooling
A359
waterlseal
SEAL-JKT-Q
flow
jacket
A362
Cooling
waterlbearing
housing
press
BRG-H-PR
A363
Cooling
water/seal
heat
exchanger
flow
SEAL-HX-FL
N
13
mVh
A364
Cooling waterheal heatexchangerpressureSEAL-HX-PR
N
13
kPa
QUENCH-FL
water/quench
Cooling
flow
A365
Cooling
waterlquench
A366pressure
QUENCH-PR
cooling
Total
A367
TOTAL-FLOW
flowwater
N
13
mYh
N
13
kPa
N
13
mYh
A368
C
1
A:tubing; B:pipe; Z:other
RMK
remarkwaterCoolingA369
C
140
Steam
Instrumentation
A370
Vibration non-contact
VB-NONCONT
C
1
1:yes (true); O: no (false)
A371
Vibration transducer
VB-ACCEL
C
1
1:yes (true); O: no (false)
A372
Provision for mounting only (Vib)
VB-MTG-ONL
C
1
1:yes (true); O: no (false)
A373
Flat surface required
VB-FL-SRF
C
1
I:yes (true); O: no (false)
A374
See attachedAPL670 data sheet (Vib)
VB-DATA-SH
C
1
1:yes (true); O: no (false)
A375
Monitors and cables
VB-MON-CB
C
1
1:yes (true); O: no (false)
A376
Vibration remark
VB-RMK
C
140
A377
Radial bearing metal temperature
TM-RAD-BRG
C
1
A378
Thrust bearing metal temperature
TM-THR-BRG
C
1
1 :yes (true);O: no (false)
A379
Provision for instruments only
TM-INS-ONL
C
1
1:yes (true); O: no (false)
A380
See attached API-670 data sheet (Temp) TM-DATA-SH
C
1
1:yes (true);O: no (false)
1:yes (true); O: no (false)
A381
Temperature gauges
TEMP-GAGES
C
1
1:yes (true); O: no (false)
A382
Temperature thermowells
TEMP-WELLS
C
1
1:yes (true); O: no (false)
A383
Temperature other
TEMP-OTHER
C
A384
Pressure gauge type
PR-GAGE-TY
C
A385
Pressure gauge location
PR-GAGE-LO
C
A386
Pressure switch type
PR-SW-TYPE
C
A387
Pressure switch location
PR-SW-LOC
C
A388
Instrument remark
INST-RMK
C
20
20
20
20
20
140
Spare Parts
SPARE-STAR
C
1
A390
Normal
maintance
spares
SPARE-NORM
C
1
1:yes (true); O: no (false)
A391
Spares
recondiioning
SPARE-RECO
C
1
1:yes (true); O: no (false)
A392Spares
critical services
SPARE-CRIT
C
1
1:yes (true); O: no (false)
SPARE-RMK
C
140
A389
Spares
start
up
A393
Spares
specify
remark
1:yes (true); O: no (false)
Motor Drive
MTR-MFGR
C
20
A395
Motor
power
MTR-POWER
N
13
A396
Motor
speed
MTR-SPEED
C
13
RPM
A397
Motor
orientation
MTR-ORNT
C
1
A:horizontal; B:vertical; Z:other
A398
Motor
frame
MTR-FRAME
C
10
A399
Motor
service
factor
MTR-SERV-F
C
13
A394
Motor
manufacturer
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
kW
Q-17
A P I STD*bLO 95
Q-18
m
0732290 0546278 08b
m
API STANDARD
61O
~~~~
No
Name
A400
Motor
volts
ContentslUnit
FieldLength
Type
MTR-VLT
C
10
A401
Motor
phase
MTR-PHASE
I
1
A402
Motor
hertz
MTR-HERTZ
N
13
A403
Motor
type
MTR-TYPE
C
15
A404
Motor
enclosure
MTR-ENCL
C
10
A405Motorexplosionproofrating
MTR-EXPL-P
C
10
A406Motorminimumstartvolts
Hz
MTR-STARTV
N
13
rise
MTR-TEMP-R
N
13
"C
full loadamperes
MTR-FL-AMP
C
13
A
C
13
A
A407
Motor
temperature
A408Motor
V. Dual voltage values are separated
with a "P. Example: 230/460
A409Motorlockedrotoramperes
MTR-LR-AMP
A410
Motor
insulation
MTR-INSUL
C
5
A41 1
MTR-STRT-M
C
20
Motorstartingmethod
A412
Motor
bearings
MTR-BRGS
C
20
A413
Motor
lubrication
MTR-LUBE
C
20
V
A41 4
Motor 2x thrustrating
MTR-THRUST
C
1
1:yes (true); O: no (false)
A41 5
Motorverticalshaft
MTR-VS
C
1
A:solid; B:hollow; ï!:other
A41 6
Motorverticalthrustcapacity
MTR-VERT-T
C
1
1:yes (true); O: no (false)
MTR-THR-UP
N
13
N
MTR-THR-DN
N
13
N
MTR-RB-TY
C
10
MTR-RB-NU
C
10
MTR-TB-TY
C
10
A417Motor
A418
thrust up
Motor thrust down
A419Motorradialbearingtype
A420
Motorradialbearingnumber
A421Motorthrustbearing
type
A422
Motor thrust bearingnumber
MTR-TB-NO
C
10
A423
Motor
remark
MTR-RMK
C
140
Vertical Pumps
A424
Up thrust at minimum flow
TH-MN-UP
N
13
N
A425
Down thrust at minimum flow
TH-MN-DN
N
13
N
A426
Up thrust at rated flow
TH-RTD-UP
N
13
N
A427
Down thrust at rated flow
TH-RTD-DN
N
13
N
A428
Up thrust at runout flow
TH-RUN-UP
N
13
N
A429
Down thrust at runout flow
TH-RUN-DN
N
13
N
A430
Maximum Up thru&
TH-MAX-UP
N
13
N
A431
Maximum downthrust
TH-MAX-DN
N
13
N
A432
Seperate mounting plate
SEP-MTG-PL
C
1
1:yes (true): O: no (false)
A433
Alignment screws
ALGN-SCREW
C
1
1:yes (true); O: no (false)
A434
Pit I sump depth
PIT-DEPTH
N
13
mm
A435
Pump length
PUMP-LENGT
N
13
mm
A436
Datum elevationto 1st stage impeller
PUMP-CL
N
13
mm
A437
Minimum submergence required
PUMP-SUBME
N
13
mm
A438
Column pipe
CLMN-PIP
C
1
A:flanged; 6:threaded; ï!:other
A439
Soleplate length
SOLE-LEN
N
13
mm
A440
Soleplate width
SOLE-WID
N
13
mm
A441
Soleplate thickness
SOLE-THK
N
13
mm
A442
Column pipe diameter
COL-PIP-D
N
13
mm
A443
Column pipe length
COL-PIP-L
N
13
mm
A444
Number guide bushes
Q-GU-BSH
I
5
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
A P I STD+61O 95
CENTRIFUGAL
PUMPS
m
0732290 0546279 T12
AND
GASINDUSTRY SERVICES
Field
Type
Length
Contentsmnit
A445Lineshaftbearingspacing
LS-BRG-S
N
13
mm
A446
Shaft
diameter
SHT-DIA
13
mm
13
mm
FOR
Name
No
PETROLEUM, HEAWDUTY
CHEMICAL,
Q-19
A447Lineshafttubediameter
LSHT-TD
N
N
A448
S-K-SHF-C 1
C
1 :yes (true);O: no (false)
1
C
1 :yes (true);O: no (false)
Sleeve and key shaftcoupling
A449Threadedshaftcoupling
TH-SHT-C
A450
Suction
can
thickness
SUCT-C-T
N
13
mm
A451
Suction
can
length
SUCT-C-L
N
13
mm
A452
Suction
can
diameter
SUCT-C-D
N
13
mm
A453
Suction
strainer
SUCT-ST
A454Suctionstrainertype
SUCT-ST-TY20
A455
Float
and
rod
FLO-ROD
:yes
(true);
1 1C
A456
Float
switch
FLO-SWT
:yes
(true);
1 1C
A457
Impeller
collets
acceptable
IMP-COLLET
C
A458Hardenedsleeveunderbearings
HARD-BRGS
:yes
(true);
1 1C
O:(false)
no
A459Verticalpumpresonancetest
:yes
(true);
1 1C
O:(false)
no
C
O:(false)
no
O:(false)
no
1
:yes
(true);
1
O: no (false)
V-RES-TEST
:yes
(true);
1 1C
O:(false)
no
A460
Vertical pump structural analysis
V-STR-ANLY
:yes
(true);
1 1C
O: no (false)
A461
Drain pipeto surface
D-P-SURF
:yes
(true);
1 1C
O:(false)
no
A462
mm
Maximum pump external diameter below V-DIA-SP
soleplate
Low liquid level from underside
of soleplate V-HT-SP
for vertical pumps
V-HT-SS
Sump size minimum dimension
A463
A464
13
N
N
13
A466
A467
Guide bushings bowl material
GD-BSHG-BO
15
C
A468
Guide bushings line shaft material
GD-BSHG-SH
15
C
mm
mm
N
N
Centerline of discharge from underside ofV-DIS-USP
soleplate
8:enclosed;
1
C
LINE-SHFT A:open;
Line shaft
A465
13
13
mm
Zother
A469
Guide
bushings
lube
BSHG-LUB
A470
Vertical
pump
remark
VERT-RMK 254
C
A471Vendorhavingunitresponsibilty
VNDR-RESP
C
50
A472
Governing
specification
GOVN-SPEC
C
50
A473
Specification
remark
140
SPEC-REMKS
C
A:water;
C:grease;
B:oil;
1
D:pumpage;
C
2:other
Applicable Specifications
Surface Preparation and Painting
1:yes
(true);
1C
A474
Manufacturer
preparation
standard
PREP-MFR-S
A475
Prep
other
PREP-OTHER
C
20
A476
Pump
surface
prep
PMP-PREP
C
20
A477
Pump
primer
20
PMP-PRIMER
C
PMP-FINISH20
C
A479
Baseplate
surface
prep
BSPL-PREP 20
C
A480
Baseplate
prime
BSPL-PRIME20
C
A481
Baseplate
finish
coat
BSPL-FINIS
C
A482
Baseplate
grout
BSPL-GRT
A483Baseplategroutsurfaceprep
BSPL-GRT-P
C
10
A478
Pump
A484
Baseplate
finish
epoxy
primer
A485
Grout
remark
A486
Shipment
type
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
O:(false)
no
20
:yes
(true);
1 1C
O: no (false)
BSPL-EPOXY
C
20
GROUT-RMKS
C
20
SHP-DEST
C A:domestic;
B:export;
Z:other
1
Q-20
API STANDARD
610
No
Name
A487
Export
boxing
required
Field
Type Length Contentdunit
SHP-EXP-BO
C
1
1:yes (true); O: no (fa-
SHIP-OUTDO
C
1
1:yes (true); O: no (false)
A489
Spare
rotor
storage
SHP-RT-ST
C
1
A:horizontal; B:vertical; 2:other
A490
Type
shipping
prep
SHP-TYPE
C
20
A491Surfaceprepandpaintingremark
PREP-RMK
C
140
6 months
A488Outdoorover
Weights
A492
Weight of pump
WT-PUMP
N
13
A493
Weight of baseplate(motordriven)
WT-BAS
N
13
A494
Weight ofmotor(motordriven)
WT-MOTOR
N
13
A495
Weight ofgear(motordriven)
WT-GEAR
N
13
A496
Total weight(motordriven)
WT-TOTAL
N
13
A497
Weightbaseplate(turbinedriven)
WT-BAS-TUR
N
13
A498
Weight of turbine(turbinedriven)
WT-TURBINE
N
13
WT-GEA-TUR
N
13
A500Totalweight(turbinedriven)
WT-TOT-TUR
N
13
A501
WT-RMK
C
140
A499Weightof
gear (turbinedriven)
Weight
remark
Other Purchaser Requirements
A502
Coordination meeting required
COORD-MTG
C
1
1:yes (true);O: no (false)
A503
Meeting date
MTG-DATE
D
8
YYYYMMDD
A504
Review foundation drawings
R-FOUND-DR
C
1
1:yes (true); O: no (false)
A505
Review pipe drawings
R-PIPE-DRG
C
1
1:yes (true); O: no (false)
A506
Observe piping checks
ORS-PIPE-C
C
1
1:yes (true);O: no (false)
A507
Observe initial alignment check
OBS-ALI-CH
C
1
1:yes (true); O: no (false)
A508
Check alignmentat operating temperature CHK-ALI-TE
C
1
1:yes (true); O: no (false)
A509
Connection design approval
CON-APPROV
C
1
1:yes (true);O: no (false)
A51O
Rotor dynamic balance
RTR-BAL-AA
C
1
1:yes (true);O: no (false)
A51 1
Rigging device for type
OH3 pump
RIG-OHB
C
1
1:yes (true); O: no (false)
A51 2
Vendor demo maximum allowable vibration DEMO-MAXVB
C
1
1:yes (true); O: no (false)
A51 3
Hydrodynamic thrust bearing size review
TH-BRG-R
C
1
1:yes (true); O: no (false)
A514
Lateral critical speed analysis
LAT-RESP
C
1
A:pump only; B:all equipment; N:none;
Z:other
A515
Spare rotor vertical storage
SP-R-V-S
C
1
1:yes (true);O: no (false)
A516
Critical speed analysis
CRIT-SP-AL
C
1
1:yes (true); O: no (false)
A517
Mount seal reservoiroff baseplate
MNT-RES-OF
C
1
1:yes (true);O: no (false)
A51 8
Installation list in proposal
INST-LST
C
1
1:yes (true);O: no (false)
A519
Stiffness map rotor
STIFF-MAP
C
1
1:yes (true); O: no (false)
A520
Torsional analysis
TOR-ANAL
C
1
1:yes (true); O: no (false)
A521
Progress report required
PROG-RPTS
C
1
1:yes (true);O: no (false)
A522
Purchase requirements remark
PURCH-RMK
C
140
C
1
1:yes (true);O: no (false)
C
1
1:yes (true}; O: no (false)
C
1
1:yes (true); O: no (false)
C
1
1:yes (true); O: no (false)
C
1
A:non witnessed; B:witnessed;
C:observed; D: none; Z:other
QA Inspection and Test
Review
vendors
A523
A524
Shop
QA program
REV-QA
Performance
approval
curve
APP-PER-CR
A525
T-SUB-SEAL
substitute
sealwithTest
A526
Hydrostatic
A527
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
HYD
A P I STDmbltO 9 5
CENTRIFUGAL
PUMPS
Field No
F
OMPLETE test
test
m
PETROLEUM, HEAVYDUTY CHEMICAL, AND GASINDUSTRY SERVICES
Type Length ContentsRJnit
Performance
C
1
A529
NPSH test
C
1
unit
A530
Complete
C
1
Sound
C
1
C
1
C
1
HYD-BEAR
C
1
A:non witnessed; 8:witnessed;
C:observed; D: none; Z:other
PIPE-LOAD
C
1
BRG-HOUS
C
1
C
1
A:non witnessed; B:witnessed;
C:observed; D: none; Z:other
A:non witnessed; 8:witnessed;
C:observed; D: none; Z:other
A:non witnessed; B:witnessed;
C:observed; D: none; Z:other
DESC-OTH-1
C
20
level
A531
test
0 5 4 6 2 8 1 670
Name
testA526
NPSH
FOR
m 0732290
A532after Dismantle
DlSM
A533
Cleanliness
inspection
to
CLEAN
prior
A534
Hydrodynamic
bearing
inspection
A535
Nozzle
load
A536
Bearing
housing
resonance
test
I shaft
deflection
test
AUX-TEST
test
equipment
Auxiliary
A537
description
A536 test Other
1
A539
Other test 1
TEST-OTH-1
C
1
A540
Other test description2
DESC-OTH-2
C
20
A541
Other test2
TEST-OTH-2
C
1
A542
Other test description 3
DESC-OTH-3
C
20
A543
Other test 3
TEST-OTH-3
C
1
A544
Other test description 4
DESC-OTH-4
C
20
1
A:non witnessed; B:witnessed;
C:observed; D: none; Z:other
A:non witnessed; B:wAnessed;
C:observed; D: none; Z:other
A:non witnessed; B:witnessed;
C:observed; D: none; Z:other
A:non witnessed; B:witnessed;
C:observed; D: none; Z:other
A:non witnessed; B:witnessed;
C:observed; D: none; Zother
A:non witnessed; B:witnessed;
C:observed; D: none; Z:other
A:non witnessed; B:witnessed;
C:observed; D: none; ï!:other
A:non witnessed; B:witnessed;
C:observed; D: none; Z:other
A:non witnessed; B:witnessed;
C:observed; D: none; Z:other
A545
Other test4
TEST-OTH-4
C
A546
Material
casing
certificate
for
MAT-CER-CA
C
1
A:non witnessed; B:witnessed;
C:observed; D: none; Z:other
1:yes (true);O: no (false)
A547
Material
certificate
impeller
for
MAT-CER-IM
C
1
1:yes (true); O: no (false)
A548
shaft
Material
certificate
for
MAT-CER-SH
C
1
1:yes (true); O: no (false)
A549
other
Material
certificate
for
MAT-CER-OT
C
20
CAS-REP-PR
C
A550
Casting
repair
procedure
approval
1
1 :yes (true);O: no (false)
A551
Mag particle inspection of connection welds NOZ-MT
C
1
1:yes (true); O: no (false)
A552
C
1
1 :yes (true);O: no (false)
A553
Liquidpenetrantinspectionofconnection
NOZ-LP
welds
Radiographic inspection of connection weldsNOZ-RT
C
1
1 :yes (true);O: no (false)
A554
Ultrasonicinspectionofconnectionwelds
NOZZ-UT
C
1
1 :yes (true);O: no (false)
A555
Mag
particle
inspection
castings
of
CAS-MT
C
A556
CAS-LP
C
1
1
1 :yes (true);O: no (false)
Liquid
penetrant
inspection
of
castings
A557
Radiographic
inspection
castings
of
CAS-RT
C
1
1 :yes (true); O: no (false)
A556
Ultrasonic
inspection
castings
of
CAS-UT
C
1
1 :yes (true); O: no (false)
CHARPY-FOR
C
20
INSP-FOR
C
20
INSP-MT
C
1
1:yes (true); O: no (false)
for
required
test
Charpy
A559
A560
Additional
inspection
required
1 :yes (true);O: no (false)
A561
Additional
magnetic
particle
inspection
A562
Additional
liquid
penetrant
inspection
INSP-LP
C
1
1 :yes (true);O: no (false)
A563
Additional
radiographic
inspection
INSP-RT
C
I
1 :yes (true);O: no (false)
A564
Additional
ultrasonic
inspection
INSP-UT
C
1
1 :yes (true); O: no (false)
A565
Alternative
acceptance
ALT-AC-CRI
criteria
C
1
1 :yes (true);O: no (false)
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
Q-21
API STD*bLO 95
Q-22
m
0732290 0546282 507
m
API STANDARD
61O
~~~~~~~
No
Name
A566Hardnesstestrequiredfor
A567
Surfactant
hydrotest
A568Vendorsubmit
A569Record
test procedure
final assemblyrunningclearances
5 years
A570Vendormaintainrecord
A571
Inspection
check
list
A572Q/Ainspectionandtestremark
Field
Type Length
ContentsRJnit
HARD-FOR
C
20
C
1
1:yes
(true);
C
1
1:yes (true); O:(false)
no
RUN-CLEAR
C
1
1:yes (true); O:(false)
no
REC-5-YRS
C
1
1:yes (true); O: no (false)
INSP-CHKL
C
1
1:yes (true); O:(false)
no
QA-RMK
C
140
General Remarks
A573
General
remark 1
GEN-RMK1
C
254
A574
General
remark 2
GEN-RMK2
C
254
3
GEN-RMK3
C
254
254
A575
General
remark
A576
Generalremark 4
GEN-RMK4
C
A577
General
remark
5
GEN-RMK5
C
254
A578
General
remark
6
GEN-RMK6
C
254
ALT-PRO-ID
C
2
VENDOR-REF
C
10
30
Additional Data
Headings
** No longersupported **
B001
B002
Vendor
reference
number
General
P-I D-N O
C
B028Number
of pumpsoperated in parallel
NO-PARALL
I
5
B029Number
of pumps operated in series
NO-SERIES
I
5
MAWP-18C
N
13
kPa
MX-PW-MD
N
13
kW
MX-HD-MD
N
13
m
B030
Static
head
STATIC-HD
N
13
m
B053
CV-HEAD
N
13
m
B025
Solid
description
SOLID-DESC
C
25
B026
Solid
dia
SOLID-DIA
N
13
SOLID-PER
C
13
B003
P & ID Number
Operating Conditions
@ 18'C
BOO5
Maximumworkingpressure
BOO6
Maximumpoweratmaximumdiameter
B007Maximumhead
atmaximumdiameter
Closed valve
head
Liquid
B027
Solid
% concentration
mm
Performance
B049
First critical speed(dry)
CR-SP-DRY
C
13
rPm
BO50
First critical speed(wet)
CR-SP-WET
C
13
8054
Ratedheadterm
1
R-HTERMI
N
13
rPm
m
B055Ratedheadterm
2
R-HTERM2
N
13
m/(mf/h)
B056
3
R-HTERMJ
N
13
m/(ma/h)"2
B057Ratedheadterm
4
R-HTERM4
N
13
m/(mf/h)A3
BO58
5
R-HTERM5
N
13
m/(mf/h)"4
13
m/(m3/h)A5
m/(ma/h)"6
Ratedheadterm
Ratedheadterm
B059Ratedheadterm
6
R-HTERM6
N
B060Ratedheadterm
7
R-HTERM7
N
13
R-STP-CAP
N
13
mYh
R-PTERMl
N
13
kW
BO61
Rated
stop
capacity
B062Ratedpowerterm
1
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
O: no (false)
SURF-HYDRO
TEST-PROC
~~~~~~
API STDabLO 95 m 0732290 0 5 4 b 2 8 3 443 W
CENTRIFUGAL
PUMPSFOR PETROLEUM,
HEAVY
DUTY CHEMICAL,
AND GASINDUSTRY
SERVICES
No
Name
Contents/Unit
FieldLength
Type
B063
Rated power term2
R-PTERM2
N
13
kW/(m3/h)
B064
Rated power term3
R-PTERM3
N
13
k~/(m3/h)~2
B065
Rated power term4
R-PTERM4
N
13
kW/(m3/h)A3
B066
Rated power term5
R-PTERM5
N
13
kW/(m3/h)"4
B067
Rated power term6
R-PTERM6
N
13
kW/(mYh)A5
B068
Rated power term7
R-PTERM7
N
13
kW/(mYh)%
BO69
Rated NPSH term 1
R-NTERM1
N
13
m
B070
Rated NPSH term 2
R-NTERM2
N
13
m/(m3/h)
B071
Rated NPSH term 3
R-NTERM3
N
13
m/(m3/h)A2
B072
Rated NPSH term 4
R-NTERM4
N
13
m/(m3/h)A3
B073
Rated NPSH term5
R-NTERM5
N
13
m/(m3/h)A4
B074
Rated NPSH term6
R-NTERM6
N
13
rn/(m3/h)5
B075
Rated NPSH term7
R-NTERM7
N
13
rn/(m'A1)~6
B076
Rated NPSH start capacity
R-NSTART
N
13
mYh
B077
Maximum diameter head term1
T-HTERMl
N
13
m
B078
Maximum diameter head term
2
T-HTERM2
N
13
m/(m3/h)
B079
Maximum diameter head term
3
T-HTERM3
N
13
m/(m3/h)~2
B080
Maximum diameter head term
4
T-HTERM4
N
13
m/(m3/h)Q
B081
Maximum diameter head term
5
T-HTERM5
N
13
m/(m3/h)A4
B082
Maximum diameter head term
6
T-HTERM6
N
13
m/(m3/h)5
B083
Maximum diameter head term
7
T-HTERM7
N
13
m/(mV1)~6
B084
Maximum diameter power term1
T-PTERM1
N
13
kW
B085
Maximurn diameter power term
2
T-PTERM2
N
13
kW/(mYh)
B086
Maximum diameter power term3
T-PTERM3
N
13
kW/(mYh)A2
B087
Maximum diameter power term4
T-PTERM4
N
13
kW/(mYh)A3
B088
Maximum diameter power term5
T-PTERMS
N
13
kW/(mYh)A4
B089
Maximum diameter power term6
T-PTERM6
N
13
kW/(mYh)%
B090
Maximum diameter power term7
T-PTERM7
N
13
kW/(m3/h)A6
B091
Maximum diameter start flow
T-START
N
13
tWh
B092
Maximum diameter stop flow
T-STOP
N
13
m3/h
B093
Minimum diameter head term1
B-HTERM1
N
13
m
B094
Minimum diameter head term
2
B-HTERM2
N
13
m/(m3/h)
B095
Minimum diameter head term
3
B-HTERM3
N
13
m/(m'/h)"2
B096
Minimum diameter head term
4
B-HTERM4
N
13
m/(m3/h)A3
B097
Minimum diameter head term
5
B-HTERM5
N
13
m/(m3/h)A4
B098
Minimum diameter head term
6
B-HTERMG
N
13
m/(mYh)%
BO99
Minimum diameter head term
7
B-HTERM7
N
13
rn/(m3/h)"6
B1O0
Minimum diameter power term1
B-PTERMI
N
13
kW
B1O1
Minimum diameter power term2
B-PTERM2
N
13
kW/(mYh)
B102
Minimum diameter power term3
B-PTERM3
N
13
k~l(m~t9~2
B103
Minimum diameter power term4
B-PTERM4
N
13
kW@1Yh)~3
B104
Minimum diameter power term5
B-PTERM5
N
13
kW/(mYh)."4
B105
Minimum diameter power term6
B-PTERM6
N
13
kW/(mYh)5
B106
Minimum diameter power term7
B-PTERM7
N
13
kW/(mYh)%
B107
Minimum diameter start flow
B-START
N
13
ma/h
B108
Minimum diameter stop flow
B-STOP
N
13
m3/h
B1 12
Viscous Cq factor
CQ-FACTOR
N
13
dimensionless
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
Q-23
A P I STD*bbO 95
m 0732290 054b284
38T
m
API STANDARD
610
(2-24
No
Name
Field
B I 13
Viscous Ch factor
CH-FACTOR
N
13
dimensionless
B1 14
Viscous Ce factor
CE-FACTOR
N
13
dimensionless
Type Length Contentdunit
Construction
B009
Coupling guard nonspark
CP-G-N-SP
C
1
1 :yes (true);O: no (false)
BO20
Baseplate drain
BPLATE-DR
C
11
A:Rain gutter; B:Drip pan; Z:other
B021
Baseplate drain connection
BPLATE-OC
C
1
1:yes (true); O: na (false)
BO22
Four pointlifting lugs
F-LIFT-LG
C
1
1:yes (true); O: no (false)
B040
Design pressure
DSGN-PRES
N
13
kPa
BO41
Design temperature
DSGN-TEMP
N
13
“C
B042
Test pressure
TEST-PRESS
N
kPa
BO43
Impeller type
IMP-TYPE
C
BO44
Baseplate type
BASE-TYPE
C
20
20
20
B052
Thrust bearing location(pump)
TH-BRG-PUM
C
20
B1O9
Sealless drivesue
MAG-SIZE
C
10
B110
Magnetic drive eddy
loss
EDDY-LOSS
N
13
kW
B111
Magnetic drive viscousloss
VlSC-LOSS
N
13
kW
INDUC-MAT
C
20
Materials
B031
Inducer
material
B032
Guard
material
GUARD-MAT
C
20
BO33
Motor
frame
material
MTR-MATL
C
20
20
20
20
BO35
Column
material
COLMN-MAT
C
BO36
Inner
Case/Bowl
material
BOWL-MAT
C
B037
Discharge
Head
material
DIS-HD-MAT
C
BO38
Nozzle
material
NOZ-MAT
C
BO39
Flange
material
FLANGE-MAT
C
20
20
Bearings and Lubrication
BO1O
Materialoutermagnet
MT-OUT-MG
C
20
BO11
Material inner magnet
MT-INN-MG
C
20
MT-CON-SH
C
MT-BEARS
C
20
20
Sealing
system
SEAL-SYST
C
1
A:Mag drive; B:Canned rotor; C:Mechanical
seal; D:Packing; 2:other
BO14Secondarypipingsealwelded
1 :yes(true); O: no (fake)
B o l 2Materialcontainment
shell
B013Materialbearings
Mechanical Seal or Packing
BOO8
SEC-PI-SEW
C
1
BOI5
Secondary piping socket welded
SEC-PP-SKW
C
1
1:yes (true); O: no (false)
BO16
Secondarypipingthreaded
SEC-PP-TH
C
1
1 :yes (true);O: no (false)
1:yes (true); O: no (false)
B017
Secondary
piping
flanged
SEC-PP-FL
C
1
BOI8
Secondarypipingunions
SEC-PP-UN
C
1
1:yes(true); O: no (fake)
BO19
Secondarytube fntings
SEC-TU-FT
C
1
A:Swagelock; B:Parker; 2:other
M-DRV-MON
C
1
CON-SHELL
C
1
A:Low amp relay; B:Power monitor system;
Zother
A:Type J thermocouple; &Type K
thermocouple; C:RTD; 2:other
MTR-MNTING
C
1
Instrumentation
BO23
Magneticdrive power monitor
B024
Containment
shell
Motor Drive
BO34
Motor
mounting
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
A:foot; B:fiange; C:foot and flange; D:skirt;
Zother
CENTRIFUGAL
PUMPS
FOR
PETROLEUM, HEAVYDUTY
CHEMICAL,
AND
GASlNDUSTRY SERVICES
No
Name
Field
Type Length ContentdUnit
BO51
Thrust bearinglocation(motor)
TH-BRG-MOT
C
B I 15
Motor shaftdiameter at coupling end
MTR-SFTDIA
N
13
B I 16
Motor IEC safety standardrating
MTR-IECSSR
C
6
B I 17
Motorsoundpressurelevel
MTR-SNDLEV
N
13
dBA
SHP-SPEC-W
N
13
kg
SHP-SPEC-C
C
13
CU.
WT-GT
N
13
ks
N
13
kg
C
13
dBA
20
mm
Weights
BO45
BO46
of
Gross
Shipping
spec:
weight
’
Shipping spec: cubage
WeightB047
WT-DIESEL
Engine
Diesel
BO48 of Weight
m
QA Inspection and Test
BOO4
Sound
SND-PW-LV
Power Level
Dimensional Data
coo1
Width of base support
HIS-A
mm
Length of base support
HIS-B
N
N
13
cm2
13
mm
cm3
Length of driver
HI S-C
N
13
mm
COO4
Length of pump
HIS-CP
N
13
mm
COO5
HIS-D
N
13
mm
COO6
Vertical height: bottom base suppMt
to CL
Pump
Distance pump CLto bottom drain plug
HIS-DD
N
13
mm
c007
Distance CL pump toCL holt down bolts
HIS-E
N
13
mm
13
mm
COO8
Distance from CLto CL hold down bolts
HIS-F
N
Coo9
Thickness of pads on support,or height of
base plate
bolt holes
Diameter of hold down
HIS-G
N
13
mm
HIS-H
N
13
mm
Width of base support
HIS-H A
N
13
mm
c012
Length of base support
HIS-HB
N
13
mm
CO13
Overall lengthof combined pump and driver HIS-HC
when on base
Vertical height bottom of base support CL
to HIS-HD
of pump
HIS-HEI
Distance from CL pump to CL hold down
N
13
mm
N
13
mm
N
13
mm
HIS-HE2
N
13
mm
HIS-HE3
N
13
mm
c01o
c01 1
CO14
COI 5
bolts
COI 6
Distance from CLpump to CL hold down
bolts
CO17
Distance fromCL pump to CL hold down
bons
CO18
Distance fromCL to CL of hold down bolts HIS-HF1
N
13
mm
c019
Distance fromCL to CL of hold down bolts HIS-HF2
N
13
mm
c020
Distance fromCL to CL of hold down bolts
HIS-HF3
N
13
mm
HIS-HG
13
mm
CM2
Thickness of padson support, or height of
baseplate
bold holes
Diameter of hold down
N
HIS-HH
N
13
mm
CO23
Width of pads for hold down bolts
HIS-H J
N
13
mm
c024
Length of support pads
for down hold bolts
HIS-HK1
N
13
mm
Length of support padsfor down hold bolts HIS-HK2
N
13
mm
c021
CM5
c026
Length of support pads for down hold
bolts
HIS-HK3
N
13
mm
CM7
Length of support pads for down hold
bolts
HIS-HK4
N
13
mm
C028
Length of support padsfor down hdd bolts
HIS-HK5
N
13
mm
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
025
API STANDARD
610
Q-26
No
Name
Co29
Length of support
down
hold
pads
for
CO30
HorizontaldistancefromsuctionnozzleHIS-HL
face toCL nearest hold downbolt holes
C031
c032
c033
C034
C035
c036
C037
c038
Field
Type Length ContentsRJnit
HIS-HK6
N
N
13
13
mm
Height of unit-bottomof base to top of driver HIS-HM
N
13
mm
Vert.
di&.-bottom
of
support
to disch.
HIS-HO
nozzle faceor top of case on hor. split
Pumps
Length from edge of support, or base plate, HIS-HP
to CL of bolt holes
Horiuontal distance-CL discharge flange to HIS-HR
CL hold down bolt hole
Horizontal
distance
between
pump
and
HIS-HT
driving shaft
Distancefrom CL ofdischarge to endofHIS-HW
motor
N
13
mm
N
13
mm
N
13
mm
N
13
mm
N
13
mm
Width pads
of for
hold
down
N
N
N
13
mm
13
mm
13
mm
rd
13
mm
N
13
mm
bolts
bolts
HIS-J
Length of support pads for hold down bolts HIS-K
Horizontaldistancefromsuctionnozzle
face to CL nearest hold down bolt holes
HIS-LP
piece
adaptor
Length of
c040
C039
HIS-L
c041
HorizontaldistancefromCLofdischarge
flange to CL of suction flange
C042
to
HIS-MP
Distanceformfaceofsuctionflange
mounting flange of adapter
Distance end of bearing housing to end of HIS-N
shaft
Vertical
distance
bottom
of
support
to
HIS-O
discharge nozzle faceor top of case on hor.
split pumps
to
HIS-OP
Vertical
distance
bottom
of
support
discharge nozzle faceor top of caseon hor.
split case
Horizontal distance-CL discharge flange to HIS-R
CL hold down bolt holes
N
13
mm
N
13
mm
N
13
mm
N
13
mm
N
13
mm
c047
Distance from CL of pump to CL of suction HIS-S
nozzle
N
13
mm
c048
Diameter of straight shaftcoupling end
HIS-U
mm
Length of shaftavailableforcoupling of
HIS-V
pulley
HIS-VD
Verticalheight-bottomofbasesupport to
CL of discharge nozzle of vertical pumps
Distance from CL of vertical pump to CL of HIS-VF
hold downbolt holes
Vertical distance41 of discharge nozzle of HIS-VS
CL of suction nozzleon vertical pumps
HIS-W
Horizontal distance-CL of pump to face of
suction elbow of vertical
pumps
Distancefrom CL of dischargeflange to
HIS-W
end of pump shaft
Distance from discharge face CL
to of pump HIS-X
N
N
13
CO49
13
mm
N
13
mm
N
13
mm
N
13
mm
N
13
mm
N
13
mm
N
13
mm
N
13
mm
N
13
mm
N
13
mm
CO43
c044
CO45
c046
C050
c051
c052
C053
c054
c055
c056
C057
c058
HIS"
mm
Distance fromCL of motor hold down bolt to HIS-XR
CL of conduit box
Horizontal distance-CL discharge nozzleto HIS-Y
suction face
Horizontal distance41 case to suction
HIS-YY
nonle face on horizontally split pumps
COPYRIGHT American Petroleum Institute
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ty
A P I STD*bLO 95 W 0732290 0546287 O77
CENTRIFUGAL
PUMPS
FOR
PETROLEUM, HEAVY
DUTY
CHEMICAL,
Name
CO59
CL discharge nonle to CL of pump
GASINDUSTRY SERVICES
Length ContentsAJnit
TypeField
No
AND
m
HIS-213
N
mm
Nozzle Load Data
Nozzle Loads
nozzle Suction D001
LOAD-SFX Fx
N
13
N
nozzle Suction D002
LOAD-SFY Fy
N
13
N
nozzle Suction D003
LOAD-SF2 Fz
D004
nozzle Suction
Mx
N
LOAD-SMX
D005
nozzle Suction
LOAD-SMY My
DOO6
Suction
LOAD-SM2
n w l e Mz
nozzle
Discharge
D007
LOAD-DFX Fx
D008nozzle
Discharge
LOAD-DFY Fy
NmN
13
NmN
13
13
N
13
N
N
13
N
N
13
N
13
N
Nm
nozzle
Discharge
D009
LOAD-DFZ Fz
D01O
nozzle
Discharge
LOAD-DMX
Mx
Nm
N
13
DOI 1 nozzle
Discharge
LOAD-DMY
My
Nm
N
13
Nm
N
13
C
254
N
13
m31h
DOI
Mz
2 nozzle
Discharge
LOAD-DMZ
N
Additional Operating Conditions
Operating Conditions
E001
Additional
operating
condition
remark
AOC-RMK
Normal
E002
ENORM-CAP
Rated
E003
N
13
Other
E004
N
13
mVh
m3/h
E005 Maximum
Pressure
ESUC-PRESM
Suction
N
13
kPa
N
13
kPa
ESUC-PRES
Rated
Pressure
Suction
E006
N
13
kPa
N
13
kPa
E009 EHEAD
Differential Head
N
13
m
EO10ENPSHA
NPSH Available
N
13
m
E01I
N
13
kW
20
13
"C
RES
Pressure
Discharge E007
E008
Differential
EDIFF-PRES
Pressure
Hydraulic
EHYD-POWER
Power
Liquid
E012
Name of Liquid
ELlQ-NAME
E013
Pumping Temperature Normal
ETEMP-NORM
C
N
EO14
Pumping Temperature Maximum
ETEMP-MAX
N
13
"C
E015
Pumping Temperature Minimum
ETEMP-MIN
N
13
"C
E016
Specific Gravity Q Normal Temperature
ESG-NORM
C
13
EO17
Specific Gravty Q Maximum Temperature ESG-MAX
C
13
E018
Specific Gravity Q Minimum Temperature
ESG-MIN
C
13
E019
Specific Heat
ESP-HEAT
N
13
kJIkg'C
E020
Vapor Pressure
EVAP-PRES
N
13
kPa abs
E021
Vapor pressure temperature
EVAP-TEMP
N
13
"C
EO22
viscosity
EVISC
N
13
CP
E023
Viscosity Temperature
EVISC-TEMP
N
13
"C
E024
Maximum Viscosity
EMAX-VISC
N
13
CP
E025
CorrosivelErrosive Agent
ECORROSIVE
C
M
ECH-CONC
N
13
E026
Chloride concentration
COPYRIGHT American Petroleum Institute
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Parts per million
Q-27
A P I STDxblO
95
0732290 054b288 T25
API STANDARD
610
G28
No
Name
E027
H2S Concentration
ContentsAJnit
FieldLength
E028
EO29
E030
Type
EMS-CONC
N
13
Hazardous
ETOXIC
C
1
1 :yes (true);O: no (false)
Flammable
EFLAM
C
1
1:yes (true); O: no (false)
Other Liquid Hazard
EOTH-HZRD
C
1
1 :yes (true);O: no (false)
E031
Rated
Pump
Speed
EPMP-RPM
N
13
RPM
E032
Closed
valve
head
ECV-HEAD
N
13
m
EO33
Ratedhead term 1
ER-HTERMI
N
13
m
E034
Ratedhead term 2
ER-HTERM2
N
13
m/(ma/h)
E035
Ratedhead term 3
ER-HTERM3
N
13
m/(m3/hy2
EO36
Ratedhead term 4
ER-HTERM4
N
13
n‘1/(mYh)~3
term 5
ER-HTERM5
N
13
m/(m3/h)Y
Parts per million
Performance
E037Ratedhead
EO38
Ratedhead term 6
ER-HTERM6
N
13
m/(~n~/h)~S
EO39
Ratedhead term 7
ER-HTERM7
N
13
m/(m‘/h)^6
E040
Rated stop capacity
ER-STP-CAP
N
13
mYh
term 1
ER-PTERMl
N
13
kW
E042
Rated power term 2
ER-PTERM2
N
13
kW/(ma/h)
E043
Ratedpower term 3
ER-PTERM3
N
13
k~/(mm)~
EO44
Ratedpower term 4
ER-PTERM4
N
13
kW/(mYh)”3
term 5
ER-PTERM5
N
13
kW/(mYh)A4
power term 6
E041Ratedpower
E045Ratedpower
ER-PTERM6
N
13
W/(ma/h)A5
term 7
ER-PTERM7
N
13
kW/(ma/h)%
NPSH term 1
ER-NTERM1
N
13
m
Rated NPSH term 2
ER-NTERM2
N
13
ml(m’/h)
13
m/(mv1)~2
ml(m3/h)”3
E046Rated
E047Ratedpower
E048Rated
E049
E050Rated
NPSH term 3
ER-NTERMJ
N
E051Rated
NPSH term 4
ER-NTERM4
N
13
E052
Rated NPSH term 5
ER-NTERMS
N
13
ml(ma/h)Y
E053
Rated NPSH term 6
ER-NTERM6
N
13
ml(1n~/h)~5
E054
Rated NPSH term 7
ER-NTERM7
N
13
m/(rn3/h)”6
ER-NSTART
N
13
m3/h
E055Rated
NPSH stad capactty
Header Data
F001
To
HDR-TO
C
40
F002
From
HDR-FROM
C
40
F003
Date
HDR-DATE
D
8
YYYYMMDD
F004
Time
HDR-TIME
C
6
HHMMSS
I
5
F005
Number of Records
HDR-RCDS
F006
F007
Header CommentsI
HDR-COM1
C
254
Header Comments 2
HDR-COM2
C
254
F008
Header Comments 3
HDR-COM3
C
254
COPYRIGHT American Petroleum Institute
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A:non
witnessed;
B:witnessed;
C:observed; D:none; Z:other
A P I STD*bLO 95
m 0732290
0546289 9 6 1
m
APPENDIX R-SI TO U.S. UNITS CONVERSION FACTORS,
SYMBOLS, DEFINITIONS, AND ABBREVIATIONS
R-1
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~~
~~
A P I STD*bLO
R-2
95
m
0732290 0546290 683
API STANDARD
610
x+
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
m
A P I STD*b10 95
m
0732290 0546291 51T
CENTRIFUGAL
PUMPS
FOR PETROLEUM,
HEAW DUTYCHEMICAL,
AND GAS INDUSTRY
Abbreviations, and Symbols:
SERVICES
m3/h
cubic meter(s)/hour
micron
micrometer (one thousandthof a
millimeter - 0.001 mm)
mil
One thousandth of an inch (one mil
equals 0.001 in.)
mm
millimeter(s)
Pm
micrometer (one thousandth ofa
millimeter - 0.001 mm)
BTU
British thermal unit
cm
centimeter(s)
cm*
square centimeter(s)
ft
foot (feet)
ft2
square foot (feet)
ft3
cubic foot (feet)
mm/s
millimeter(s)/second
g
g *mm
gram(s)
gram millimeter(s)
MPa
megapascal (one thousand kPa)
(1 N/mm2 = 1 MPa)
GPM
gallons per minute
N
Newton
H
head in meters (feet)
Nm
Newton meter
hP
Hz
horsepower
N/mm2
Newton(s)/square millimeter
hertz
NPS
Nominal pipe size
in.
inch(es)
oz
ounce (16 oz = 1 pound)
in./ft
inches per foot
oz-in.
ounce-inch(es)
in./in.
inches per inch
Pa
pascal
in./sec
inches per second
Pk
in.2
square inch(es)
kg
kN
kilogram(s) (one thousand grams)
PWPk
psi
Peak
peak to peak
kilonewton (one thousand newtons)
psia
pounds per square inchabsolute
kPa
kilopascal (one thousandPa) (100 kPa = 1 bar)
PSk
pounds per square inch gauge
kW
kilowatts (one thousand watts)
Q
total pump flow in m%ec (GPM)
1
liter(s)
RMS
root mean square
lb
pound
RPM
revolutions per minute
lb/ft
pounds per foot
W
watts
Ibf
pound(s) force
lbs
pound(s)
Symbols:
m
meter(s)
6
logarithmic decrement
m/S
meter(s)/second
P
prefix for micro
(pm=micrometer)
m*
square meter@)
5
damping factor
m3
cubic meter(s)
COPYRIGHT American Petroleum Institute
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pounds per square inch
R-3
APPENDIX S-CALIBRATION AND PERFORMANCE VERIFICATION OF
TRUE PEAK AND RMS MEASUREMENT INSTRUMENTS
USED FOR TEST STAND ACCEPTANCE
Required Instruments
Set up the unit under testfor the desired fullscale amplitude and the sensitivity of the transducer being used. The
following example uses a full scale of IOmmlsec. (0.4
in./sec) peak and a transducer scale
factor of 20 mV/mm/sec
(500 mV/in./sec).
The True Peak andRMS verification tests require a
pulse/function generator and anoscilloscope.
l. Typical pulse/functiongenerators:
a. Hewlett Packard8 1 1 1A pulse/function generator.
2. Adjust the pulse/function generator with
the aid ofthe oscilloscope to create a sine wave as shown in Figure S-2 with
an amplitude accuracy of+5 percent or better.
b. Tektronix PFG 5105.
c. Stanford Research Systems DS345.
3. Verify that the unit under test reads 10 mm/sec (0.4
in./sec) peak+7 percent.
d. Other equivalent.
2. Typical oscilloscopes:
4. Switch the pulse/function generator from the sine wave
to
the pulse signalas shown in FigureS-3.
a. Tektronix model 2430A.
b. Other equivalent.
5. Verify that the unit under test still reads 10 mm/sec (0.4
in./sec) peak +7 percent.
True Peak Measurements
RMS Measurements
Verify a True Peak measurement instrument
by first establishing an initial calibration using asine wave. Then verify
the pulse responseof the instrument using a nonsymmetrical
duty cycle pulse and compare the results to the sine wave
calibration. Follow these steps:
l . Set up the instruments as shown in FigureS- l.
The RMS (as defined in 2.8.3.4.2) measurement calibration shallbe verified by using both sine and square waves of
the same RMS value.
1. Set up the instruments as shown in Figure S-l.
Set up the unit under
test for the desired
full scale amplitude
Instrument
under
'
I"-o?
generator
equivalent
Phase
oscilloscope
figure S-1-Instrument Test Setup
S-1
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A P I STD*bLO 75 M 0732290 O546273 392
API STANDARD
610
S-2
andthesensitivity of thetransducerbeingused. The following example uses a full scale of 10 d s e c (0.4 in./sec) RMS
and a transducerscalefactor
of 20mV/mm/sec (500
mV/in./sec).
2. Adjust the pulse/function generator with the aid of the
oscilloscope to create a sine wave as shown in Tigure S-4
with an amplitude accuracy of +S percent or better.in./sec)
3. Verify that the unit under test reads lOmm/sec (0.4
in./sec) RMS +7 percent.
4. Switch the pulse/function generator from the sine wave
to a square wave signalas shown inFigure S-5.
5.
Verify that the unit under test reads lOmm/sec (0.4
RMS +7 percent.
H
Period = 50 milliseconds (20 Hz)
Figure S-2-Sine Wave Signal Showing True Peak
Period = 50 milliseconds (20 Hz)
50 microseconds f10%
Figure S-3-Pulse Signal Showing True Peak
COPYRIGHT American Petroleum Institute
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CENTRIFUGAL PUMPS FOR PETROLEUM,
HEAVYDUTY CHEMICAL, AND GASINDUSTRY SERVICES
S-3
I
Period = 50 milliseconds (20 Hz)f10%
Figure S-4-Sine Wave Signal Showing RMS
J1
--
"
"
Duty
cycle = 50%
PP
Period = 50 milliseconds+I 0%
Figure S-5-Pulse
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
Signal Showing RMS
API STD*bLO 95
0732290 OSLI6295 Lb5
APPENDIX T-TEST DATA SUMMARY
T- 1
COPYRIGHT American Petroleum Institute
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A P I STD*bLO
95 E 0732290 054629b O T 1 E
APPENDIX T - API 610 TEST DATA SUMMARY
Curve No.
Test Date
Customer
Purchaser
Purchase Order No.
Item No.
, Pump Serial No.
Size and Type
No. of Stages
I
Certified By
(Vendor Representative)
Witnessed by
(Purchaser Representative)
\
Hydraulic Performance (Table 4.21
I
I
Rated
1
Tested
VolutelDiffuser
Pattern No.
Blade Tip Clearance
%
(2.1.1 5)
Actual
Deviation
+/- %
I
Acceptance TOI.
VolutalDiffuser
Pattern No.
Blade Tip Clearance
%
(2.1 .15)
Mechanical Performance
Maximum Vibration Levels recorded within specified flow region (2.8.3)
/c’’’’’
Rated Flow
Tested
Housina Velocitv:
Drive End:
Overall / Filtered
Non-Drive End:
Overall / Filtered
Shaft Displacement:
Drive end:
Overall I Filtered
Non-Drive End:
Overall / Filtered
/
Specified
/
Allowable Operating
Region
Tested
Specified
Preferred Operating
Region
Tested
Specified
/
/
/
Ø
/
/
/
y/////
Bearing Temperatures O
Pressurized Lubrication Systems
Ambient Temp.
Oil Temp. Rise
Oil Outlet Temp.
Max. Bearing MetalTemp.
Drive End Journal
Non Drive End Journal
Thrust Bearing
C (OF)
(2.9.2.3)
Ring Oil or Splash Systems
Ambient Temp.
rise Oil Temp
Oil Sump Temp.
I
I
.
(1) This mechanical performance summaryis for recording maximum test levels
for each operating
region relative to specified values.It is not intended to replace
shop test data logs.
(2) Units of measurementshall be mm/sec (in./sec.) RMS for velocity, pm (mils) peaklpeakfor
displacement andOC CF) for temperature
T-2
COPYRIGHT American Petroleum Institute
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~~
A P I STD+bLO 95
m
0732270 0546297 T38
CENTRIFUGAL
PUMPSFOR PETROLEUM, HEAW DUTY CHEMICAL,
AND GASINDUSTRYSERVICES
Pump Serial No.
Pumped Liquid
Curve No.
Size and Type
Density
Flow
Head
NPSHR
Power
No. of Stages
Temperature
Speed, RPM
(CP)
Impeller No.
(“c)
T-3
Rated Point
=
210.0
m=
m=
89.0
6.3
59.5
kW =
Viscosity
Kinematic
Calculated Efficiency %: 85.5 Ref.
Impeller
mm2
Eye Area
-
Impeller Diameter
-
-
-
-
-
-
-
-
O
100
200
Flow (m3/h)
Note: Values for scales,flow, head, NPSHR, power, efficiency for illustration only.
Figure T-1-Test
COPYRIGHT American Petroleum Institute
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Curve Format-IS0 Style
20
A P I STDvbLO 95
0732290 0546298 974
m
API STANDARD
610
T-A
Note: Values for scales, flow, head, NPSHR, power,efficiency for illustration only.
Figure T-2-Test
COPYRIGHT American Petroleum Institute
Licensed by Information Handling Services
Curve Format-US. Style
API STD*bLO 95 m 0732290 0546299 B O O m
APPENDIX U-SEAL CHAMBER DIMENSIONS: BASIC PHILOSOPHY
FOR STANDARDIZATION
The objective of standardization of seal chamber dimensionsslightly different from the7th Edition of API Standard 610
is to allow standard seals to be developed for682
APIand for
due to conversion to metric and graduation with increasing
API Standard 610 pumps. These dimensions will allow comshaft sizes.
plete standard cartridges to be developed for single stage overg. Chamber depth, C minus E, is free. For existing designs
hung pumps interchangeable between pump manufacturers.
with “traditional seal chambers” this isa finite length. The
be
For other typesof pumps, custom sleeves and glands may
intent is to place complete responsibility
for the designof the
required, but the basic seal components will
be interchangeseal chamberin the hands of the seal vendor. The
C and E diable.
mensions, which are minimum, effectively establish a diThe standard dimensions(see Table 2.3) have been set to
mension, C minus E, which for the seal manufacturer isthe
facilitate designs capable of meeting the reliability requiremaximum that seal components can extend into the pump.
ments of API Standards 682 and 610. They recognize the
For pumps with dimensionsless than the difference between
conflict between the desirability of large seal chambers for
C and E, either a spacer is required tofit the standard sealor
the seal designer and the desirabilityof short overhangsfor
a bolt-on seal chamber is required.
A specific chamber depth
the pump manufacturer. Alldimensions are chosen to meet
dimension has, therefore, been deleted from the table
in this
these ends while minimizing the impacton pump manufacrevision. However, it is necessary
for the pump manufacturer
turers’ existing designs:
to supply the resulting (C minus E) dimension to the seal
manufacturer when supplying sealchamber drawings.
a. Seal chamber standard sizesare tabulated from 1 to 10.
While the additional joint incurred by this spacer is not
b. Shaft dimensions are chosen
on 10 mm increments to minparticularly desirable, the reality is that dual seals already
reimize numbersof seals. Shaft diameter
is a maximum dimension. Ultimate standardization on these shaft sizes is desirable.quire two joints associated with the seal gland. The ability to
install a standard seal withouta spacer might then becomea
c. Seal chamber bores are chosen to allow adequate radial
point of evaluation by users, and the industry might move
space to fit a seal and meet the radialclearance requirements
of 610 and 682. These dimensions are slightly larger than the voluntarily toward fixing a “ D ’ dimension (for single stage
overhung pumps) at the difference between C and E in the
7th Editionof API Standard 610.
table. As an alternative, the user canelect to specify custom
d. Gland stud circles are chosen to allow installation of
seal glands which have axial length sufficient to eliminate
a 6 mm ( ‘ / 4 in.) spiral wound gasketin an 8 mm ( 5 / ~ 6in.) gasthe need for a spacer.
ket pocket and to be compatible with most or all API 610,
7th Edition pump bearing bracket webs. These criteria allow h. Clear length, E, is a new minimum dimension. APIStandard 610 requires that pumps have a separable gland. The
conservative gasket selection anddo not force pump manugland must have axial space fora seal flush connection ( ‘ 1 2
facturers to redesign their pump bearingbrackets.
NPS minimum), quench and
drain (3/8 NPS minimum) anda
e. Radial dimension from shaft
to seal chamberis chosen for
floating throttle bushing. This dimension was chosen from
the same reasonas seal chamber boresin the preceding item
known axial dimensions of existing standard seals.
c. These dimensions are slightly larger than in the 7th Edi610. However, the radial dimension has i. Stud sizes have been chosen basis ASME calculations to
tion of API Standard
become redundant and has been eliminated from the in
table meet pressure requirements. Larger studsizes shall be conthis revision.
sidered only if required to meet the stress requirements of
f. Total length, C, is established to allow installation of the
Section VI11 or Section II of the ASME Code, or to suffilongest seal arrangement whichmight be specified, in
ciently compress spiral wound gaskets in accordance with
otherwords, a dual seal witha throttle bushing.Total length is
the manufacturer’sspecifications.
u-1
COPYRIGHT American Petroleum Institute
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1220 L Street. Northwest
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