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THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
Recommended Practice for Subsea
Pumps
RECOMMENDED PRACTICE 17X
FIRST EDITION, XXXX 2016
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
II
Special Notes
API publications necessarily address problems of a general nature. With respect to particular
circumstances, local, state, and federal laws and regulations should be reviewed.
Neither API nor any of API's employees, subcontractors, consultants, committees, or other assignees
make any warranty or representation, either express or implied, with respect to the accuracy, completeness,
or usefulness of the information contained herein, or assume any liability or responsibility for any use, or
the results of such use, of any information or process disclosed in this publication. Neither API nor any of
API's employees, subcontractors, consultants, or other assignees represent that use of this publication
would not infringe upon privately owned rights.
API publications may be used by anyone desiring to do so. Every effort has been made by the Institute to
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 liability or responsibility for loss or damage resulting from its use or for the violation of any authorities
having jurisdiction with which this publication may conflict.
API publications are published to facilitate the broad availability of proven, sound engineering and
operating practices. These publications are not intended to obviate the need for applying sound
engineering judgment regarding when and where these publications should be utilized. The formulation and
publication of API publications is not intended in any way to inhibit anyone from using any other practices.
Any manufacturer marking equipment or materials in conformance with the marking requirements of an API
standard is solely responsible for complying with all the applicable requirements of that standard. API does
not represent, warrant, or guarantee that such products do in fact conform to the applicable API standard.
ii
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
III
Foreword
Nothing contained in any API publication is to be construed as granting any right, by implication or
otherwise, for the manufacture, sale, or use of any method, apparatus, or product covered by letters
patent. Neither should anything contained in the publication be construed as insuring anyone against liability
for infringement of letters patent.
This document was produced under API standardization procedures that ensure appropriate notification
and participation in the developmental process and is designated as an API standard. Questions
concerning the interpretation of the content of this publication or comments and questions concerning the
procedures under which this publication was developed should be directed in writing to the Director of
Standards, American Petroleum Institute, 1220 L Street, N.W., Washington, D.C. 20005. Requests for
permission to reproduce or translate all or any part of the material published herein should also be
addressed to the director.
Generally, API standards are reviewed and revised, reaffirmed, or withdrawn at least every five years. A
one-time extension of up to two years may be added to this review cycle. Status of the publication can be
ascertained from the API Standards Department, telephone (202) 682-8000. A catalog of API
publications and materials is published annually by API, 1220 L Street, N.W., Washington, D.C. 20005.
Suggested revisions are invited and should be submitted to the Standards Department, API, 1220 L Street,
NW, Washington, D.C. 20005, [email protected]
iii
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
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QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
IV
Contents
1
Scope ............................................................................................................................................... 1
2
References ....................................................................................................................................... 2
3
3.1
3.2
Terms, Definitions, and Abbreviations ............................................................................................. 5
General............................................................................................................................................. 5
Acronyms and Abbreviations ......................................................................................................... 17
4
4.1
4.2
Systems and Interface Descriptions .............................................................................................. 22
General........................................................................................................................................... 22
Classification and Designation ....................................................................................................... 23
5
5.1
5.2
5.3
Requirements ................................................................................................................................. 24
Units ............................................................................................................................................... 24
Statutory Requirements ................................................................................................................. 24
Requirements ................................................................................................................................. 24
6
6.1
6.2
6.3
6.4
6.5
6.6
6.7
6.8
6.9
6.10
6.11
Motorpump Unit Design ................................................................................................................. 25
General............................................................................................. Error! Bookmark not defined.
Pump Types ................................................................................................................................... 27
Pressure Casings ........................................................................................................................... 32
Internal Pump Components ........................................................................................................... 34
Mechanical Shaft Seals.................................................................................................................. 35
Rotordynamics ............................................................................................................................... 37
Bearings and Bearing Housings .................................................................................................... 38
Motor .............................................................................................................................................. 39
Couplings and Guards ................................................................................................................... 44
Motor Cooling Systems .................................................................................................................. 48
Barrier and Lubrication System ...................................................................................................... 49
7
7.1
7.2
7.3
Pump Control, Protection and Monitoring Systems ....................................................................... 50
General........................................................................................................................................... 50
Functional Requirements for Control Systems .............................................................................. 50
Functional Requirements for Monitoring Systems ......................................................................... 51
8
8.1
8.2
8.3
8.4
8.5
8.6
8.7
Installation and Intervention ........................................................................................................... 53
Installation/Retrieval Considerations .............................................................................................. 53
Transportation and Testing Equipment .......................................................................................... 54
Preservation and Storage .............................................................................................................. 55
Pump Module Structure ................................................................................................................. 56
Pressure-Limiting Valves ............................................................................................................... 57
Piping and Appurtenances ............................................................................................................. 58
Special Tools .................................................................................................................................. 59
9
9.1
9.2
9.3
Qualification and Application Specific Testing ............................................................................... 60
Scope ............................................................................................................................................. 60
Individual Tests .............................................................................................................................. 64
Pump Acceptance Criteria ............................................................................................................. 66
iv
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
V
10
10.1
10.2
10.3
10.4
10.5
10.6
10.7
10.8
10.9
Materials and Materials Inspection ................................................................................................ 68
Scope ............................................................................................................................................. 68
Connectors, Piping, Valves, and Structure .................................................................................... 68
Fasteners ....................................................................................................................................... 68
Written Specifications: Pump and Motor Casing ........................................................................... 69
Property Requirements: Pump and Motor Casing ......................................................................... 70
Processing: Pump and Motor Casing ............................................................................................ 70
Manufacturing Quality Control: Pump and Motor Casing .............................................................. 70
Non-destructive Examination Personnel ........................................................................................ 70
Pump Internals: Materials Considerations ..................................................................................... 72
11
11.1
11.2
11.3
Manufacturing, Inspection, and Preparation for Shipment............................................................. 74
General........................................................................................................................................... 74
Inspection and FAT Testing ........................................................................................................... 74
Preparation for Shipment ............................................................................................................... 80
12
12.1
12.2
Vendor’s Data ................................................................................................................................ 83
General........................................................................................................................................... 83
Details ............................................................................................................................................ 87
Annex A
Qualification Testing .................................................................. Error! Bookmark not defined.
Annex B
Application Specific Testing ...................................................... Error! Bookmark not defined.
Annex C
Pump Design Data Sheets ........................................................ Error! Bookmark not defined.
Bibliography .............................................................................................................................................. 132
v
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
VI
List of Figures:
Figure 1 - Subsea Pump System ................................................................................................................ 22
Figure 2 - Example Acceptable Suction GVF Limit as it Applies to a Single Stage Pump with a
Conventional Flow Path. ............................................................................................................................. 29
Figure 3: Example Acceptable Suction GVF Limit as it applies to both Single-Stage and Multi-Stage
Pumps ......................................................................................................................................................... 29
Figure 4 - Decision Tree for Testing ........................................................................................................... 63
Figure 5 - Vibration Limits for Subsea Rotodynamic Pumps and Motors, GVF < 40% .............................. 77
Figure 6 - Vibration Limits for Subsea Rotodynamic Pumps and Motors, GVF > 40% .............................. 78
Figure 7 - Rotor Overall Vibration Limits and Maximum Probe Target Run-out for Subsea Pumps and
Motors Operating with Single‑phase or Multi‑phase GVF < 40% .............................................................. 79
Figure 8 - Rotor Overall Vibration Limits and Maximum Probe Target Run-out for Subsea Pumps and
Motors Operating with Multi‑phase GVF > 40% ......................................................................................... 80
Figure 9 - Location of Test Points on the Operational Envelope .............................................................. 103
List of Tables:
Table 1 - Pump Classification Type Identification ....................................................................................... 23
Table 2 - Classification by Installation Depth .............................................................................................. 27
Table 3 - Classification by Sea Water Temperature ................................................................................... 27
Table 4 - Classification by Process Fluid Temperature (Table is expanded from API 6A Table 2) ............ 27
Table 5 - Recommended Service Factors for Single-Phase Pumps .......................................................... 27
Table 6 - Recommended Service Factors for Multi‑phase Pumps............................................................. 31
Table 7 - Casing Pressure Design Class .................................................................................................... 32
Table 8 - Insulation Thermal Classes used for Subsea Motors .................................................................. 43
Table 9 - Motor Shaft and Housing Run-out Limits ..................................................................................... 46
Table 10 - Scope of Test Object ................................................................................................................. 62
Table 11 - Inspection Classes as they apply to API 17X ............................................................................ 71
Table 12 - Vendor Drawing and Data Requirement List ............................................................................. 85
Table 13 - Details and Comments to Table 13 ........................................................................................... 88
Table 14 - Suggested Start-up and Shut-down Test Process for Qualification Testing ............................. 98
Table 15 - Suggested Start-up and Shut-down Test Order for Qualification Testing ................................. 99
Table 16 - Suggested Extended Performance Test Process for Qualification Testing............................. 104
Table 17 - Suggested Start-up and Shut-down Test Process for Application Specific Testing ................ 106
Table 18 - Suggested Start-up and Shut-down Test Order for Application Specific Testing .................... 106
Table 19 - Suggested Extended Performance Test Process for Application Specific Testing ................. 110
vi
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
VII
Introduction
It is necessary that users of this Standard be aware that further or differing requirements can be needed
for individual applications. This Standard is not intended to inhibit a vendor from offering, or the purchaser
from accepting, alternative equipment or engineering solutions for the individual application. This can be
particularly appropriate where there is innovative or developing technology. Where an alternative is
offered, it is necessary that the vendor identify any variations from this Standard and provide details.
A bullet (•) at the beginning of a clause or sub-clause indicates that either a decision is required or the
purchaser is required to provide further information. It is necessary that this information should be
indicated on data sheets or stated in the enquiry or purchase order.
In this Standard, where practical, US Customary, or other units are included in parentheses for
information.
vii
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DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
1
1 Scope
This Standard recommends requirements for subsea pumps, including single phase, hybrid, and multi‑
phase. Reference is made to API 610, 674, 675, 676, and 685 for the various components that may be
incorporated into subsea pump systems. The Standard applies to all subsea placed at or above the
muddling and includes hydraulic expanders (pumps running in reverse as hydraulic power recovery
turbines, for use in petroleum, petrochemical and gas industry process services).
The standard describes typical subsea requirements with a scope including:
–
–
–
Subsea pump units
Motors for subsea pumps
Minimum requirements for relevant auxiliaries (power, control, barrier fluids and lubricants)
Equipment selection, pump station layout and design are not within the scope of this document.
Exceptions to this standard must be defined and agreed between vendor and purchaser.
1
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
2
2 References
The following referenced documents are indispensable for the application of this document. For dated
references, only the edition cited applies. For undated references, the latest edition of the referenced
document (including any amendments) applies.
1
AGMA 9002 : Bores and Keyways for Flexible Couplings (Inch Series)
2
ANSI /API STD 682/ISO 21049, Shaft Sealing Systems for Centrifugal and Rotary Pumps
3
ANSI/HI 9.6.7 Rotodynamic Pumps - Guideline for Effects of Liquid Viscosity on Performance
API RP 14E, Recommended Practice for Design and Installation of Offshore Production Platform Piping
Systems
API RP 17N, Recommended Practice for Subsea Production System Reliability and Technical Risk
Management
API RP 17P, Design and Operation of Subsea Production Systems—Subsea Structures and Manifolds
API RP 17Q, Subsea Equipment Qualification—Standardized Process for Documentation
API RP 17R, Recommended Practice for Flowline Connectors and Jumpers
API Spec 6A, Specification for Wellhead and Christmas Tree Equipment
API Spec 17D, Design and Operation of Subsea Production Systems—Subsea Wellhead and Tree
Equipment
API Spec 20B, Open Die Shaped Forgings for Use in the Petroleum and Natural Gas Industry
API Spec 20C, Closed Die Shaped Forgings for Use in the Petroleum and Natural Gas Industry
API Spec 20D, Nondestructive Examination Services for Equipment Used in the Petroleum and Natural
Gas Industry
API Spec 20E, Alloy and Carbon Steel Bolting for Use in the Petroleum and Natural Gas Industries
API Spec 20F, Corrosion Resistant Bolting for Use in the Petroleum and Natural Gas Industries
API Spec 685, Sealless Centrifugal Pumps for Petroleum, Petrochemical, and Gas Industry Process
Service
API STD 17F, Specification for Subsea Production Control Systems
1
2
3
American Gear Manufacturers Association, 1001 N. Fairfax St. Suite 500, Alexandria, VA 22314-1587, USA, www.agma.org
American National Standards Institute, 1889 L St, NW, Washington DC, 20036, USA, www.ansi.org.
Hydraulic Institute, 6 Campus Drive, First Floor North, Parsippany, NJ 07054, USA, pumps.org
2
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
3
API STD 547, General-purpose Form-wound Squirrel Cage Induction Motors-250 Horsepower and
Larger, First Edition
API STD 610, Centrifugal Pumps for Petroleum, Petrochemical and Natural Gas Industries
API STD 614, Lubrication, Shaft-sealing and Oil-control Systems and Auxiliaries
API STD 671, Special-Purpose Couplings for Petroleum, Chemical, and Gas Industry Services
API STD 675, Positive Displacement Pumps - Controlled Volume for Petroleum, Chemical, and Gas
Industry Services
API STD 676, Positive Displacement Pumps—Rotary
API RP 686, Machinery Installation and Installation Design
4
ASME VIII Div.2 : Rules for Construction of Pressure Vessels, Alternative Rules
ASME VIII Div.3: Rules for Construction of Pressure Vessels, Alternative Rules for Construction of High
Pressure Vessels
5
ASNT SNT-TC-1A-2016 , Topical Outlines for Qualification of Nondestructive Testing Personnel
6
ASTM D1418 - 10a(2016) , Standard Practice for Rubber and Rubber Latices—Nomenclature
7
IEC 60038 , IEC Standard Voltages
IEC 60085, Electrical insulation - Thermal evaluation and designation
8
ISO 7-1 , Pipe threads where pressure-tight joints are made on the threads — Part 1: Dimensions,
tolerances and designation
ISO 228-1, Pipe threads where pressure-tight joints are not made on the threads — Part 1: Dimensions,
tolerances and designation
ISO 1940-1:2003, Mechanical vibration -- Balance quality requirements for rotors in a constant (rigid)
state -- Part 1: Specification and verification of balance tolerances
ISO 9712, Non-destructive testing -- Qualification and certification of personnel
4
5
6
7
8
The American Society of Mechanical Engineers: Two Park Ave. New York, NY 10016 USA, www.asme.org.
The American Society for Nondestructive Testing, P.O. Box 28518, 1711 Arlingate Late, Columbus, OH 43228-0518, USA,
www.asnt.org
American Society for Testing and Materials, 100 Barr Harbor Dr., P.O. Box C700, West Conshocken, PA, 19428-2959 USA,
www.astm.org
International Electrotechnical Commission, 3, rue de Varembé, Case postale 131, CH-1211, Geneva, Switzerland,
www.iec.org.
International Organization for Standardization, 1, ch. De la Voie-Creuse, Case postale 56, CH-1211, Geneva, Switzerland,
www.iso.org.
3
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
4
ISO 10441: 2007, Petroleum, petrochemical and natural gas industries -- Flexible couplings for
mechanical power transmission -- Special-purpose applications
ISO 14691:2008, Petroleum, petrochemical and natural gas industries -- Flexible couplings for
mechanical power transmission -- General-purpose applications
ISO/TR 17766, Centrifugal pumps handling viscous liquids — Performance corrections
ISO 17782, Petroleum, petrochemical and natural gas industries -- Qualification of manufacturers of
special materials
9
NACE MR 0103 , Materials Resistant to Sulfide Stress Cracking in Corrosive Petroleum Refining
Environments
10
NEMA MG 1-2014 , Motors and Generators
11
NORSOK M-650 : Qualification of manufacturers of special materials (Rev. 4, September 2011)
12
SEPS SP-1001 , Power connectors, penetrators and jumper assemblies with rated voltage from 3 kV
(Umax = 3.6 kV) to 30 kV (Umax = 36 kV)
9
10
11
12
National Association of Corrosion Engineers, Houston, Texas, USA.
National Electrical Manufacturers Association, 1300 North 17th St. Ste 900, Arlington VA 22209, USA, www.nema.org
The Norwegian shelf’s competitive position, Standard Norge, Postboks 252, 1326 Lysaker, Norway. www.standard.no
Subsea Electrical Power Standardization, OTM Consulting, Ltd, Great Burgh, Yew Tree Bottom Rd., Epson KT18 5XT, UK
4
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
5
3 Terms, Definitions, and Abbreviations
3.1 General
For the purposes of this document, the following terms and definitions apply.
3.1.1
acceptance criteria
Defined limits placed on characteristics of materials, products or services.
3.1.2
allowable operating region
Portion of a pump's hydraulic coverage over which the pump is allowed to operate, based on vibration
within the upper limit of this Recommended Practice or temperature rise or other limitation, specified by
the vendor.
3.1.3
ambient
Environmental temperature at test facility at test installation (water temperature if submerged).
3.1.4
ampacity
The current carrying capacity of an electrical conductor at a given temperature.
3.1.5
application specific testing
Process by which a repeat manufacture system (or sub-system) is tested against the original qualification
criteria and application specific objectives
NOTE
Application specific performance maps may be generated. See API 17N.
3.1.6
axially split
Split with the principal joint parallel to the shaft centerline
3.1.7
barrier fluid
Fluid used to maintain a positive pressure within pump-motor cavities isolated by sealing mechanisms
from ambient seawater and production fluids, and to lubricate mechanical pump components
3.1.8
best efficiency point
BEP
Flowrate at which a pump achieves its highest efficiency at rated impeller diameter
NOTE
The best efficiency point flowrate at maximum impeller diameter is used to determine pump specific speed
and suction specific speed. The best efficiency point flowrate at reduced impeller diameters is similarly
reduced from the value at maximum impeller diameter.
5
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RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
6
3.1.9
body
Any portion of wellhead and Christmas tree equipment between end connections, with or without internal
parts, which contains well-bore pressure
NOTE See API 6A.
3.1.10
bolting specification level
BSL
Term used to describe a method for determining testing and documentation levels required to reduce risk
associated with manufacturing quality
3.1.11
bonding
Connecting or joining of metal parts to form an electrically conductive and continuous path to conduct
safely any current likely to be imposed
3.1.12
carbon steel
Alloy of carbon and iron containing a maximum of 2 % mass fraction carbon, 1.65 % mass fraction
manganese, and residual quantities of other elements, except those intentionally added in specific
quantities for deoxidation (usually silicon and/or aluminum)
3.1.13
casting (noun)
Object at or near finished shape obtained by solidification of a fluid substance in a mold
3.1.14
chemical analysis
Determination of the chemical composition of material
3.1.15
closed-loop control system
Control system in which the output has an effect on the input, in such a way as to maintain the desired
output value
NOTE A closed-loop system includes some way to measure its output to sense changes so that corrective action
can be taken. In the case of subsea booster pump controls, the closed-loop control system is in charge of
maintaining a desired pump output using a reference input such as pump suction pressure.
3.1.16
closure bolting
Threaded fastener used to assemble pressure-containing parts or join end or outlet connections
3.1.17
corrosion resistant alloy
CRA
Nonferrous-based alloy in which any one or the sum of the specified amount of the elements titanium,
nickel, cobalt, chromium, and molybdenum exceeds 50 % mass fraction
6
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
7
3.1.18
date of manufacture
Date of vendor's final acceptance of finished equipment
3.1.19
direct drive power system
Subsea power system in which a single booster pump or other single load is powered directly from the
power source (generally a VFD) on the platform without transformers in the power train
3.1.20
earthed (EU Usage)
Connected (bonded) to earth by means of earth electrodes (rods)
NOTE See definition for “Grounded US”
3.1.21
earthing
Intentional means to minimize the resistance of a ground grid or earth electrode to “infinite earth” (i.e., a
voltage reference point = 0)
3.1.22
“Effectively-Grounded” system
Grounding mode or characteristic of a three-phase system which is grounded through a grounding device
of sufficiently low impedance to limit transient line-to-ground over-voltages due to ground faults to limits
established for the power system components
NOTE
In terms of symmetrical components, an “effectively grounded –system” is where grounding is through a
sufficiently low impedance such that for all system conditions the ratio of zero sequence reactance to
positive sequence reactance (Xo/Xl) is positive and less than 3, and the ratio of zero sequence resistance to
positive-sequence reactance (R0/Xl) is positive and less than 1.
3.1.23
electrode
Especially designed conductor in intimate contact with earth for the purpose of providing a connection
with the earth
NOTE Also referred to as “ground rod” or “ground electrode”.
3.1.24
fault
Any abnormal flow of electric current in an electric power system
NOTE 1
For example, a fault could be a condition where current is flowing in a different path and/or at a level
exceeding that used during normal operation.
NOTE 2
Three Fault conditions are defined where some measure of design enhancement must take place to
ensure survival of the umbilical, as well as all other current carrying components, in an unexpected
electrical situation.
7
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
8
3.1.25
forging specification level
FSL
Term used to describe a method for determining testing and documentation levels required to reduce risk
associated with manufacturing quality
3.1.26
gas liquid ratio
GLR
Ratio of the volume of gas to the volume of total liquid (oil and water only) at pump suction pressure and
temperature
3.1.27
gas oil ratio
GOR
Ratio of gas in a well stream expressed in standard cubic meters of gas per stock tank cubic meter of oil,
3
3
3
Sm /Sm in SI units or standard cubic feet of gas per stock tank barrel of oil, ft /bbl in USC units
NOTE
The value is derived by performing a single-stage phase calculation or experiment of the whole stream fluid
at standard conditions.
3.1.28
gas volume fraction
GVF
Ratio of the volume of gas to the total fluid volume (gas, oil and water) at pump suction temperature and
pressure
3.1.29
ground
Conducting connection whether intentional or unintentional between an electrical circuit or equipment
item and the earth or to some other body that serves in place of the earth (NEC Definition)
3.1.30
ground fault
Unintended current flow, usually thru insulation, between an energized conductor and ground
3.1.31
grounded (US)
Intentional or unintentional connection to earth or to an extended conducting body that serves in place of
the earth
NOTE See definition for “earthed”
3.1.32
grounding
Act of connecting (bonding) equipment or hardware to a ground grid or electrode
8
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
9
3.1.33
grounding–island
That portion of a neutral-grounded system within which a ground-fault current (I0) flows as an outgoing
unbalanced phase current and returns in a ground-return path to its source neutral (i.e., transformer or
generator) and can be detected by ground-current-responsive devices
NOTE
External to a grounding-island, its ground-fault current is converted (by specific transformer connections)
into equal outgoing and return phase currents, and thus not detectable by ground-fault protective devices.
3.1.34
grounding-system
System that consists of all interconnected grounding connections and defined by its isolation from
adjacent grounding systems
3.1.35
ground-return conductor
Normally non-current carrying metal components of the system, used to conduct ground fault current
back to its source
3.1.36
ground-return path
Path in earth or other conductive channels that ground fault currents will naturally return from the point of
fault to the grounded neutral of the power source such a transformer or generator.
EXAMPLE
NOTE
Motor starting current;
Typically, the power conductors should be rated for 125% of the expected current. In some subsea power
systems, it may be desirable to increase this rating even further.
3.1.37
hot isostatic pressing
HIP
Manufacturing process used to reduce the porosity and increase the density of metal castings,
consolidated powders, or sintered parts
3.1.38
hydrostatic pressure
Maximum external pressure of ambient ocean environment (maximum water depth) that equipment is
designed to contain and/or control
3.1.39
hydrostatic body test pressure
Pressure to which a body shall be tested to very pressure containment. Applied to all production items
having a product specification level of 2 or higher
NOTE
For all pressure ratings, the hydrostatic body test pressure shall be a minimum of 1.5 times the rated
working pressure. The acceptance criterion for hydrostatic pressure tests shall be no visible leakage during
the hold period. If a pressure-monitoring gauge and/or a chart recorder is used for documentation purposes,
the chart record should show an acceptable pressure settling rate not exceeding 3 % of the test pressure
per hour. The final settling pressure shall not fall below the test pressure before the end of the test hold
period. Initial test pressure shall not be greater than 5 % above the specified test pressure.
9
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
10
3.1.40
identical pump
Pump of the same size, hydraulic design, number of stages, rotational speed, clearances, type of shaft
seal (axial face or breakdown bushing), type of bearings, coupling mass, coupling overhang, and
pumping the same liquid
3.1.41
life-of-field
Full range of operation of hydrocarbon asset, from first production to abandonment
3.1.42
maximum allowable speed
Highest speed at which the vendor's design permits continuous operation
3.1.43
maximum allowable temperature
Maximum continuous temperature for which the vendor has designed the pump (or any part to which the
term is referred) when pumping the specified liquid at the specified maximum operating pressure (does
not include mechanical seal)
3.1.44
maximum allowable working pressure
MAWP
Maximum continuous pressure for which the vendor has designed the pump (or any part to which the
term is referred) when pumping the specified liquid at the specified maximum operating temperature
(does not include mechanical seal)
3.1.45
maximum discharge pressure
Maximum specified suction pressure plus the maximum differential pressure the pump with the furnished
impeller is able to develop when operating at rated speed with liquid of the specified normal relative
density (specific gravity)
3.1.46
maximum operating temperature
Highest temperature of the pumped liquid, including upset conditions, to which the pump is exposed
3.1.47
maximum suction pressure
Highest suction pressure to which the pump is subjected during operation (non-transient; does not include
water-hammer)
3.1.48
minimum allowable speed
Lowest speed (in rpm) at which the vendor's design permits continuous operation
3.1.49
minimum continuous flow
Lowest flow at which the pump can operate without exceeding the vibration limits imposed by this
document
10
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
11
3.1.50
minimum continuous thermal flow
Lowest flow at which the pump can operate without its operation being impaired by the temperature rise
of the pumped liquid
3.1.51
minimum design metal temperature
Lowest mean metal temperature (through the thickness) expected in service, including operation upsets,
auto-refrigeration and temperature of the surrounding environment, for which the equipment is designed
3.1.52
multistage pump
Pump with three or more stages
3.1.53
neutral
Common return point of an AC power supply (such as a transformer or generator) which can be grounded
3.1.54
net positive suction head
NPSH
Total absolute suction head determined at the suction nozzle and referred to the datum elevation minus
the head of the vapor pressure of the fluid
NOTE
It is expressed as head of water, in meters (feet).
3.1.55
Net positive suction head available
NPSHA
Minimum value of NPSH determined to be available under any specified operation condition, accounting
for line losses, under steady state flow conditions
NOTE
NPSHA is a value provided by the purchaser.
3.1.56
net positive suction head required
Minimum value of NPSH determined to be required under any specified operation condition, based on
steady state flow
NOTE
NPSHR is a value provided by the vendor by taking the equipment requirements, which are based on the
centerline of inlet reference point, and adjusting it to the underside of the baseplate.
3.1.57
open-loop control system
Control system in which the output has no effect on the input. In the case of subsea booster pump
controls, the open-loop control system is typically at the main pump HMI and is in charge of relaying
manual inputs and platform-generated shutdowns
3.1.58
operating region
Portion of a pump's hydraulic coverage over which the pump operates
11
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
12
3.1.59
Overload
Fault condition where more than nominal steady state rated current is flowing, to and from the load
through its assigned path
3.1.60
overload
A condition where more than steady state rated current is flowing, but all current is flowing to the electrical
load through its assigned path
EXAMPLE
Motor starting current
3.1.61
performance est
Running test conducted to measure flow rate, differential pressure, and power consumed at specified
conditions
3.1.62
per–phase charging Current (IC0)
Current (Vl-n /XC0) that passes through one phase of the system to charge the distributed capacitance per
phase-to-ground of the system.
NOTE
Vl-n is the line-to-neutral voltage and XC0 is the per-phase distributed capacitive reactance of the system.
3.1.63
phase-to-ground fault
Condition where some or all of the current from one phase is moving back to the source through a
ground/ neutral path ground
NOTE 1
A phase-to-ground fault causes the phase-to-ground voltage of the unaffected phase conductors to be
higher than normal. The Recommended Practice way to combat this situation requires increasing the
insulation rating of all power system components, including power cable terminations/ connectors/
penetrators and booster pump windings.
NOTE 2
A phase-to-ground fault may or may not necessitate stopping operation of the booster pump. Some
systems are built to operate with one phase continuously faulted to ground.
EXAMPLE
Failure of a wet mate connector such that phase A is in direct contact with the connector case, and thus
the seawater. Once a phase-to-ground fault has occurred, the booster pump system (if so designed)
can continue operation. However, the umbilical must be sufficiently rated to survive the phase to ground
fault indefinitely.
3.1.64
phase-to-phase fault or short circuit
Condition where two or more of the 3-phases are connected directly together or to earth ground and
maximum current is flowing
EXAMPLE
Failure of the motor windings such that phase A and phase B come in direct contact with each other.
Once a phase-to-phase fault has occurred, the booster pump system is no longer operational. The
umbilical must be sufficiently rated to survive the duration of the fault until the circuit protection system
de-energizes the power system.
12
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
13
3.1.65
planned intervention
Repair or replacement of subsea equipment where the impending failure of the equipment was
anticipated and replacement equipment, installation vessels, and personnel were ready to perform the
repair prior to shut in of production
3.1.66
platform
Generic term for any floating vessel or fixed structure where topside equipment can be housed above
water
3.1.67
preferred operating region
Portion of a pump's hydraulic coverage over which the pump's vibration is within the base limit of this
document
3.1.68
pressure casing
Composite of all stationary pressure-containing parts of the pump, including all nozzles, seal glands, seal
chambers and auxiliary connections but excluding the stationary and rotating members of mechanical
seals
3.1.69
pressure containing part
Part whose failure to function as intended results in a release of wellbore fluid to the environment
3.1.70
pressure controlling part
Part intended to control or regulate the movement of pressurized fluids
3.1.71
product specification level
PSL
Term used to describe a method for determining testing and documentation levels required to reduce risk
associated with manufacturing quality
3.1.72
pump manifold
Permanent structure installed subsea which provides piping/flow base for hosting a subsea Pump Module
and interfaces with the subsea field architecture.
NOTE
Pump Manifold structure includes any flow conditioning hardware-recycle system or pump bypass piping
and all associated process connectors, valves and interface for outboard manifold power, control and
communication.
3.1.73
pump module
Retrievable structure, hosted in the Pump Manifold, which includes the pump and motor assemblies.
13
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
NOTE
14
The Pump Module also includes key subsystems (where applicable) such as the Barrier Fluid System, Pump
Controls, any machinery condition monitoring equipment, high voltage connectors, interface panel, a soft
landing system etc.
3.1.74
pump installation
That which contains all systems and subsystems that are necessary to deploy and operate a subsea
pumping module
NOTE 1
Some of this systems and subsystems, like the VSDs, HPUs, Control Systems, etc. may be located
topsides while others may be deployed subsea
NOTE 2
See Figure1
3.1.75
rated operating point
Point at which the vendor certifies that pump performance is within the tolerances stated in this document
NOTE:
Normally, the rated operating point is the specified operating point with the highest flow.
3.1.76
qualification
Process by which a new or significantly modified system (or sub-system) is verified as applicable for use
including the generation of standard-case performance maps
NOTE
See API 17N.
3.1.77
rated operating point
Point at which the vendor certifies that pump performance is within the tolerances stated in this
Recommended Practice
3.1.78
rated power
Power delivered to the pump input shaft at rated operating point. It is also called brake power (brake
horsepower, brake kilowatts, etc.)
3.1.79
rated pump efficiency
Pump efficiency at rated operating point
NOTE
See pump efficiency.
3.1.80
rated speed
Highest rotational speed (rpm) required to meet any of the specified operating conditions
3.1.81
rated volumetric efficiency
Volumetric efficiency at rated operating point
14
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
15
3.1.82
rated working pressure
Maximum internal pressure that equipment is designed to contain and/or control.
3.1.83
rotary displacement pump
Pump built upon the principle of transporting volumes of fluids via closed or semi-closed chambers at a
near constant volume for each rotation.
NOTE
The chambers in rotary displacement pumps may consist of screws, lobes, gears or cams.
3.1.84
rotodynamic pump
Pump built upon the principle of converting kinetic energy to head by use of a rotating impeller
3.1.85
service factor
Service factor of an AC motor is a multiplier that when applied to the rated horsepower indicates a
permissible horsepower loading that may be carried under the conditions specified for the service factor
NOTE 1
See NEMA MG 1.
NOTE 2
IEC standards do not recognize service factor.
3.1.86
similar pump
Pump that is accepted, by agreement between purchaser and vendor as sufficiently similar to not require
a lateral analysis, taking into account the factors listed for an identical pump
3.1.87
single load power system
Subsea power system where a single booster pump or other single load is powered by a single circuit
from the platform
3.1.88
solid grounding
Refers to the connection of a system conductor, usually the neutral of a generator, power transformer, or
grounding transformer directly to ground, without any intentional intervening impedance
3.1.89
specific speed
Index relating flow, total head and rotational speed for pumps of similar geometry
3.1.90
stage
One impeller and associated diffuser or volute and return channel, if required
3.1.91
stall
Pump term for a condition defining minimum stable flowrate at given tip speed and head characterizeable
by vibration or performance
15
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
16
3.1.92
standard conditions
Reference pressure and temperatures used to describe production volumes of hydrocarbons.
o
o
NOTE 1
These vary worldwide, but are typically 15 C and 1bar (60 F and 1 atm).
NOTE 2
Not to be confused with normal conditions.
3.1.93
step-out distance
Distance between the platform power generation system and the subsea power load
3.1.94
stonewall
Compressor term defining maximum stable flowrate at given tip speed and head
NOTE
This is viewed as an indicator of sonic flow conditions.
3.1.95
subsea power system
Combination of components (electrical, mechanical, thermal) that act together to supply power to a
subsea load.
3.1.96
surge
Compressor term for a condition defining minimum stable flowrate at given tip speed and head
characterized by vibration, performance and/or efficiency losses
3.1.97
system charging current
Total distributed capacitive charging current (3∙Vl-n/XC0) of a three-phase system
3.1.98
three-phase, four-wire system
System of alternating current supply comprised of four conductors, three of which are connected as in a
three-phase, 3-wire system with the forth being connected to the neutral point of the supply (e.g., a deltawye connected transformer)
3.1.99
transformer based power system
Subsea power system where a single booster pump or other single load is powered through a one or
more transformers used between the power source (generally a VFD) on the platform and the load
NOTE
Transformers can be used to increase or decrease voltage to reduce current losses, or for isolation, or for
both.
3.1.100
transient overvoltage
Temporary overvoltage associated with the operation of a switching device, a fault, an arcing ground, or
other instigating event on a power system that does not have an effective grounding system in place
16
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
17
3.1.101
trip speed
Electric motor driver -synchronous speed at maximum supply frequency
3.1.102
trip speed
Variable-speed driver variable- -speed at which the independent emergency over-speed device operates
to shut down the driver
3.1.103
umbilical
Hydraulic hose, tubing, piping, and/or electrical conductor that directs fluids and/or electrical current or
signals to or from subsea trees
3.1.104
unplanned intervention
Repair or replacement of subsea equipment where the impending failure of the equipment was not
anticipated and replacement equipment, installation vessels, and personnel were not ready prior to shut
in of production
3.1.105
volumetric efficiency
Ratio of the pump rated point flow to the total theoretical displacement per unit time
3.2 Acronyms and Abbreviations
3Ø
A
ABS
AC
AFC
AFCI
AHJ
ANSI
API
ASHRAE
ASME
ASTM
AWG
AWS
bbl
BEP
BFHPU
BPCS
bpd
C
CFD
Shorthand for 3-phase AC Power
Amp
American Bureau of Shipping
Alternating Current
Adjustable Frequency Control
Arc Fault Circuit Interrupter
Authority Having Jurisdiction
American National Standards Institute
American Petroleum Institute
American Society of Heating, Refrigerating, and Air Conditioning Engineers
American Society of Mechanical Engineers
American Society for Testing and Materials
American Wire Gauge
American Welding Society
Barrel
Best Efficiency Point
Barrier Fluid Hydraulic Power Unit
Booster Pump Control System
Barrels per day
Celsius
Computational Fluid Dynamics
17
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
CRA
CSA
DR
DNV
DOL
EFAT
EFL
EMI
EP
EPR
EPU
ERC
ESD
ESP
ESS
F
FA
FAT
FEA
FM
FMECA
FP
FPS
FPSO
FPU
FSD
ft
FTP
g
GFI
GLR
GOR
GVF
HFL
HIP
HISC
HMI
HMWPE
hp
HP
HPU
HSSE
HV
HVAC
Hz
I0
IADC
Corrosion Resistant Allow
Canadian Standards Association
Density Ratio
Det Norske Veritas
Direct-On-Line
Extended Factory Acceptance Test
Electrical Flying Leads
Electromagnetic Interference
Explosion-Proof
Ethylene Propylene Rubber
Electrical Power Unit
Erosion Risk Classification
Emergency Shut Down
Electric Submersible Pumps
Emergency Safety System
Fahrenheit
Forced Air
Factory Acceptance Test
Finite Element Analysis
Factory Mutual Research Corporation
Failure Mode, Effects, and Criticality Analysis
Flame Proof
Floating Production System
Floating Production Storage Offloading
Floating Production Unit
Flowline Shutdown
feet
File Transfer Protocol
Gravity
Ground Fault Interrupter
Gas Liquid Ratio
Gas Oil Ratio
Gas Volume Fraction
Hydraulic Flying Leads
Hot Isostatic Pressing
Hydrogen Induced Stress Cracking
Human Machine Interface
High Molecular Weight Polyethylene
Horsepower
High Pressure
Hydraulic Power Unit
Health, Safety, Security and Environment
High Voltage (35kV and above)
Heating, Ventilation, and Air Conditioning
Hertz, unit of frequency equal to 1 cycle per second
Ground-fault Current
International Association of Drilling Contractors
18
18
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
ICEA
IEC
IEEE
IES
IMO
IPC
ISA
ISO
k
K
kpsi
ksi
kVA
kW
LEL
LFL
LP
LV
LVTC
m
mm
M
3
m /hr
MCC
MMS
MODU
MPC
MPP
MTTF
MV
MW
NACE
NDE
NEC
NEMA
NFPA
NPSH
NPSHR
NPSHA
NPSH3
NRTL
NTP
OA
VENDOR
OFL
Pa
Insulated Cable Engineers Association
International Electrotechnical Commission
Institute of Electrical and Electronics Engineers
Illuminating Engineering Society of North America
International Maritime Organization
Institute for Interconnecting and Packaging Electronic Circuits
The International Society for Measurement and Control
(formerly Instrument Society of America)
International Organization for Standardization
Kilo
Kelvin
Kilo-pounds force per square inch
Kilo-pounds per square inch
Kilovolt-Ampere
Kilowatt
Lower Explosive Limit (LFL Preferred)
Lower Flammable Limit
Low Pressure
Low Voltage (0V to 1kV)
Load Varying Tap Changer
Meter
millimeter if alone or prefix for millions in USC
Mega
Cubic meters per hour
Motor Control Center
Minerals Management Service, U.S. Department of the Interior
Mobile Offshore Drilling Unit
Main Pump Controller
Multi-Phase Pump
Mean Time to Failure
Medium Voltage (1kV to 35kV)
Megawatt
National Association of Corrosion Engineers International
Non-Destructive Examination
National Electric Code
National Electrical Vendors Association
National Fire Protection Association
Net Positive Suction Head
Net Positive Suction Head required
Net Positive Suction Head available
Net Positive Suction Head required measured at 3% head drop
Nationally Recognized Testing Laboratory
Network Time Protocol
Open Air
Original Equipment Vendor
Optical Flying Lead
Pascal
19
19
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
P.A.
PAS
PE
pf
PLC
PMSM
PSI
PSS
PVC
QA
QC
R
RAM
RBD
RDC
RGD
MAX
MIN
ROT
ROV
RPM
SAE
SALM
S
scf
SCM
SCMMB
SCMRT
SEM
SEPS
SIT
SF
3
Sm
STB
SUTA
TEFC
TENV
TLP
TRL
TUTA
UL
USCG
UTA
V
VA
VFD
VSD
Public Address
Process Automation System
Polyethylene
Power Factor
Programmable Logic Controller
Permanent Magnet Synchronous Motor
Pound per Square Inch
Process Safety System
Polyvinyl Chloride
Quality Assurance
Quality Control
Rankine
Reliability, Availability, and Maintainability
Reliability Block Diagram
Rapid Density Change
Rapid Gas Decompression
Maximum Fluid Density
Minimum Fluid Density
Remote Operator Terminal
Remotely Operated Vehicle
Revolutions per Minute
Society of Automotive Engineers
Single Anchor Leg Mooring (Buoy)
Standard or Prefix to Denote Subsea
Standard cubic foot
Subsea Control Module
Subsea Control Module Mounting Base
Subsea Control Module Running Tool
Subsea Electronic Module
Subsea Electrical Power Standardization
Site Integration Test
Stress Factor
Standard cubic meter
Stock Tank Barrel
Subsea Umbilical Termination Assembly
Totally Enclosed Fan Cooled
Totally Enclosed Non-Ventilated
Tension Leg Platform
Technology Readiness Level
Topsides Umbilical Termination Assembly
Underwriters Laboratories Inc.
United States Coast Guard
Umbilical Termination Assembly
Volt
Volt-Amp
Variable Frequency Drive
Variable Speed Drive
20
20
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
W
XLPE
p
Watt
Crosslinked Polyethylene
Differential Pressure Generated by Pump
21
21
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DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
22
4 Systems and Interface Descriptions
4.1 General
4.1.1 System Configuration
Figure 1 provides an overview of the subsea pump configuration covered by this document. The items
shown in orange are directly covered in this document. Other sections of Figure 1 are included for
reference.
Figure 1 - Subsea Pump System
4.1.2 Unit Responsibility
Unless otherwise specified, the pump vendor shall have unit responsibility. The pump vendor shall ensure
that all sub-vendors comply with the requirements of this Standard and all reference documents.
22
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
23
4.2 Classification and Designation
4.2.1 Description of Codes
The pumps described in this Standard are classified and designated by type codes, as shown in Table 1.
Table 1 - Pump Classification Type Identification
Pump Type
Working Principle
Vane
Rotary displacement
Subsea Pumps
Lobe
Single
Phase
Gear
Screw
Rotodynamic
Multi‑phase
Screw
Single
Phase
Single or multistage
Hybrid
Multi-phase
Multistage
True
Multi-phase
Single or multistage
Type Code
Vane in Rotor
Vane in Stator
Single
Multiple
Timed External
Untimed External
Internal
w/Crescent
Progressive
Cavity
Timed Twin
Screw
Multiple Screw
Progressive
Cavity
Timed Twin
Screw
Axial
Radial
Helico‑axial/
Radial
Semi-axial/Radial
Helico‑axial
Semi-axial
SVR
SVS
SLS
SLM
SGET
SGEU
SGI
SPC
STS
SMS
SMPPC
SMPTS
SSPA
SSPR
SMPHAR
SMPSAR
SMPHA
SMPSA
NOTE: This document does not cover ESP’s installed in the well. Mudline ESPs are covered by this
document, in accordance with their type and working principle.
4.2.2 Pump Designations and Descriptions
Pumps listed in Table 1 of this standard can be correlated to the corresponding sections of API 610 and
API 676. A prefix “S” has been added to the beginning of the code of each pump type to denote its
subsea application. In spite of the subsea nature of the application the basic principle of operation or
layout of each type of pump does not differ from the ones described in API 610 and 676, therefore please
refer to such standards for further descriptions.
23
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
24
5 Requirements
5.1 Units
The purchaser shall specify whether data, drawings, and maintenance dimensions of pumps shall be in
the SI or US Customary (USC) system of measurements. Use of an SI data sheet (see Annex C)
indicates the Standard System of measurements shall be used. Use of a USC data sheet (see Annex C)
indicates the USC system of measurements shall be used.
5.2 Statutory Requirements
The purchaser and the vendor shall mutually determine the measures necessary to comply with any
governmental codes, regulations, ordinances, or rules that are applicable to the equipment, its packaging
and preservation.
5.3 Requirements
In case of conflict between this Standard and purchaser requirements, the purchaser requirements shall
govern.
Section 6 of this document contains general design guidelines for all pumps described in Table 1. Specific
detailed design guidelines for each type of Rotodynamic pump as described in Section 9 of API 610 are
applicable.
24
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
25
6 Motorpump Unit Design
6.1 Design
6.1.1 General
The subsea motor and pump unit is a highly integrated machine which combines both the pump and the
motor to one single unit. This necessitates a pump and motor design which are dependent upon each
other. As a result of this integration, is the motor and pump cannot practically be treated as individual
components. In this chapter there are several chapters that are common for both the pump and motor for
example bearings and dynamics.
In general, any subsea rotodynamic pump shall conform to the requirements of API 610, eleventh edition,
September 2010. This document then describes key deviations from API Standard 610. Similarly, rotary
positive displacement pumps shall comply to API 676 with the key deviations from that standard
described herein.
The same applies for subsea motor that in general shall follow API 541 fifth edition 2014.
6.1.2 General Design Requirements
The general design requirements are described in API STD 610 section 6.1 noting the following key
additions:
a) Equipment, including all auxiliaries, shall be designed for subsea installation and the specified site
environmental conditions. The vendor shall advise of any equipment protection required for the
storage before deployment (i.e. winterization for low ambient temperatures, or protection against
unusual corrosive conditions, etc.). Purchaser shall specify any environmental conditions applicable
to the design of the pump such as but not limited to maximum and minimum pressure, water depth,
external pressure, corrosive or erosive conditions, water currents and/or local regulations or codes
pertaining to the fishing industry, wildlife conservation or any such specific considerations.
b) The pump and motor are to be designed to be retrievable as one single unit. All equipment shall be
designed to permit rapid and economical maintenance. Major parts, such as casing components and
bearing housings, shall be designed and manufactured to ensure accurate alignment on reassembly.
c) Installation and retrieval of units will expose the units to vertical and lateral acceleration loads several
times as well as impact tolerance requirements. See Section 8.
d) Spare and all replacement parts for the pump and all furnished auxiliaries shall, as a minimum, meet
all the criteria of this Recommended Practice.
The purchaser shall specify the operating conditions, the fluid properties, site conditions and utility
conditions, including all data shown on the Pump Design Data Sheets (Annex C), over the life of the field.
The purchaser is responsible for including details describing changes over time in: reservoir PVT data,
25
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
26
water cut, and flow rates, etc. The purchaser is therefore encouraged to estimate those changes and
provide the field evolution flows, GVF and water‑cut so the pump may be sized to meet both current and
future conditions. This forward planning may change the number of operating pumps, and / or pump
components necessary to achieve such forecasted performance.
The equipment shall be capable of operation at the normal and rated operating points and any other
anticipated operating conditions specified by the purchaser.
In some cases, as a result of expected or unexpected changes in pump operating conditions, pump
components may have to be exchanged to reach future conditions. The vendor shall clearly indicate in
the proposal the conditions of service which shall require the replacement of the pump or any of its
components. Where relevant, the motor barrier fluid, cooling, sealing, pressure boundary and other
systems shall be sized to cover such future conditions.
A subsea pump is normally operated with an electric motor coupled to a variable speed drive (VSD or
VFD). The choice of motor rating shall include a fixed margin of 10% to the maximum pump power and
speed and also include applicable service factors for the intended use.
Pumps shall be capable of operating at least up to the specified maximum continuous speed. The
maximum continuous speed shall be synchronous speed for fixed speed pumps and at least 105% for
variable speed pumps. Variable-speed pumps shall be designed for excursions to the specified trip speed
(automatic shutdown speed) without damage.
The pump and the pump system including motor and the associated barrier fluid system shall be
designed to tolerate any transient condition including emergency shut down and power failure.
The vendor shall state the minimum safe operation speed considering any relevant issues including
bearing and mechanical seal face lubrication. Vendor shall also state the maximum safe speed
acceleration and deceleration for the unit.
Start-up of subsea pumps may prove difficult due to potential complexities of the electric power system,
including long distance cabling and transformers. Complete power system analysis must be made to
ensure safe start-up for the worst combination of pump pressure, temperature and viscosity. Start-up
friction in pump and motor thrust bearings must include margins for long-term standstill of the unit. These
analyses shall be documented and supplied in accordance with Section 12.
During FAT, the pump with its motor shall perform within the specified performance test tolerances.
Performance acceptance criteria post installation shall be based on FAT results. Vendor and Purchaser
shall work together to determine long term effects, consequences and mitigations if FAT performance is
largely different to post installation performance.
6.1.3 Operational and Environmental Conditions
The installation of subsea units will face some extra environmental challenges regarding water depth and
sea water temperature. In order to promote standardization of units, water depth and sea water
temperatures are organized into classes, defined in Tables 2 through 5.
26
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
27
Table 2 - Classification by Installation Depth
Depth class
Name
Depth
A
B
C
D
Shallow
Deep
Ultra-deep
Extreme deep
0 – 500 meter
500 – 1500 meter
1500 – 3000 meter
3000 – 5000 meter
Table 3 - Classification by Sea Water Temperature
Temperature class
Name
A
B
C
Cold
Intermediate
Hot
Temperature Range
o
-2 ºC to +10 ºC
+10 ºC to +20 ºC
+20 ºC to +30 ºC
o
+28 F to +50 F
o
o
+50 F to +68 F
o
o
+68 F to +86 F
Table 4 - Classification by Process Fluid Temperature (Table is expanded from API 6A Table 2)
Temperature
classification:
S
T
U
V
W
X
Y
Z
Minimum
temperature:
-18 °C
-18 °C
-18 °C
2 °C
-18 °C
2 °C
-18 °C
2 °C
Maximum
temperature:
66 ºC
82 ºC
121 ºC
121 ºC
149 ºC
149 ºC
177 ºC
177 ºC
Minimum
temperature:
0 °F
0 °F
0 °F
35 °F
0 °F
35 °F
0 °F
35 °F
Maximum
temperature:
150 °F
180 °F
250 °F
250 °F
300 °F
300 °F
350 °F
350 °F
Table 5 - Recommended Service Factors for Single-Phase Pumps
Case:
Service Factor (SF):
Single-phase pumps with steady-state operation and smooth start/stop
Single-phase pumps with frequent and rapid speed changes
Single-phase pumps with direct-on-line operation and frequent start/stop
a
Single-phase pumps experiencing frequent rapid density change
a
1.00
1.10
1.25
ρMAX/ ρMIN
– rapid here means a faster change than the VSD is able to adjust
6.2 Pump Types
6.2.1 General
The pumps described in this Standard are classified and designated by type codes, as shown in Table 1.
Pumps listed in Table 1 of this standard can be correlated to the corresponding sections of API 610 and
API 676. A prefix “S” has been added to the beginning of the code of each pump type to denote its
subsea application. In spite of the subsea nature of the application the basic principle of operation or
27
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
28
layout of each type of pump does not differ from the ones described in API 610 and 676, therefore please
refer to such standards for further descriptions.
6.2.2 Rotodynamic Pumps
6.2.2.1
General
Rotodynamic pumps are pumps that generate differential head (pressure) only by dynamic action as they
utilize either the centrifugal forces in a rotating fluid (centrifugal impeller) or by pressure difference over a
moving blade (axial impellers). All rotodynamic pumps are operating with one or several rotating
impellers. Rotodynamic pumps are not self-priming and needs to be filled with fluid prior to start-up.
These pumps cannot hold back fluid once they are stopped and will need a check valve in the system to
prevent reverse or back flow.
6.2.2.2
Single-phase selection
For subsea pumps, the difference between between single-phase and multi‑phase pumps is very
important and a decision between the two must be made. The Gas Volume Fraction (GVF) limit of single
phase technologies is one key parameter as it describes the maximum gas fraction which a classic singlephase pump can tolerate. The limit is very dependent on the Density Ratio (DR) between the liquid and
[1]
the gas at pump stage inlet conditions. Gulich provides some guidelines for use of conventional rotors
based on air water testing and utilize a relationship of the form:
𝐴𝑙𝑙𝑜𝑤𝑎𝑏𝑙𝑒 𝐺𝑉𝐹 <
𝑎
√𝐷𝑅
Where a is derived from Figure 1.3.21 in Gulich’s book and is approximately
0.75 for single stage
1 for multistage
Because hydrocarbon fluids are mutually soluble, the gas and liquid densities will approach each other
meaning that further manipulation of these models may not be consistently conservative (Figures 2 and 3
show such a difference). Further manipulation of these relationships is therefore not without risk. Figure 2
illustrates the variability to be expected in simple approach for a model fluid system (pure methane and
pure octane) estimated using analytic models. The figure shows the effect of temperature and pressure
on the GVF limit estimate. Figure 3 illustrates the same concepts but applied to a different fluid system
and illustrates the equivalent curves for multistage pumps.
28
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DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
Figure 2 - Example Acceptable Suction GVF Limit as it Applies to a Single Stage Pump with a
Conventional Flow Path.
Figure 3: Example Acceptable Suction GVF Limit as it applies to both Single-Stage and MultiStage Pumps
29
29
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
30
Pumps, which handle fluids with dissolved gases (like well-stream pumps and pumps downstream a
separator), shall be evaluated for possible gas flashing as a result of dynamic or steady-state pressure
changes at the pump inlet. These reviews shall be performed for all operating conditions. The actual GVF
at the impeller suction shall always be less than the gas tolerance demonstrated for the pump design.
6.2.2.3
Single-Phase Pumps
The purchaser shall specify a service factor reflecting the operating conditions of the pump.
Table 5 shows recommended service factors for single-phase pumps (including liquid-liquid multi‑phase
pumps). The service factor shall be the minimum ratio between the rated design load and the actual
operational load.
Single phase pumps that have stable head/flowrate curves (continuous head rise to shutoff) are preferred
for all applications and are required if parallel operation is specified. If parallel operation is specified, the
head rise from rated point to shutoff shall be at least 10 %.
Section 6 of API Standard 610 provides instructions on preferred operating region and single‑phase
pump sizing. Pumps shall have a preferred operating region of 70 % to 120 % of best efficiency flowrate
of the pump as furnished. For subsea pumps, it is recognized that during life-of-field it may prove very
difficult to operate inside the preferred operating region at all time due to changing flow and pressure
requirements. Single phase small pumps that are known to operate satisfactorily at flows outside the
specified limits should be offered, where appropriate, and their preferred operating region clearly shown
on the proposal curve.
Centrifugal Pumps that handle liquids more viscous than water shall have their water performance
corrected in accordance with ISO/TR 17766 (ANSI/HI 9.6.7). Correction factors used for viscous liquids
shall be submitted with both sales proposal curves and final test curves. To perform this evaluation, the
purchaser shall provide the appropriate data on fluid viscosity changes as a result of:
― Wax gelation
― Emulsions
― Newtonian/non-Newtonian behavior
― Other fluid rheology related phenomena
Subsea single-phase pumps, whether for wellstream boosting or water injection, are usually operated
with suction pressures in excess of 10 bar but the purchaser should evaluate the effect of dissolved
gases on NPSH. The NPSH margin (NPSHA – NPSHR) shall be evaluated for all rated operating points
as described in API 610. The minimum NPSH margin shall be stated by the purchaser. For subsea
pumps, the NPSH margin shall in any case be minimum 1.5 meters (4.6 ft) for all operating points.
30
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DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
31
Systems including single-phase pumps downstream subsea separation facilities shall be designed to
ensure shall a positive head between separation device and the single-phase pump.
6.2.2.4
Multi-Phase and Hybrid Pumps
Two types of multi‑phase pumps are defined, the hybrid pump and the true multi‑phase pump.
The hybrid pump is a combination of multi‑phase impellers in the first stages and single-phase (radial or
axial) impellers in the last stages. The first multi‑phase impellers are used to compress/reduce the gas
content to a GVF level within the capabilities of a single-phase impeller. Hybrid pumps are normally used
downstream a scrubber or separator where significant amounts of gas carry-under can be expected. The
hybrid is usually used for a GVF range of 0 – 40%.
A true multi‑phase pump can operate in the entire GVF range from 0 – 100%.
The purchaser shall specify a service factor reflecting the operating conditions of the pump. Table 6
shows recommended service factors for multi‑phase pumps. The service factor shall be the minimum
ratio between the rated design load and the actual operational load.
Table 6 - Recommended Service Factors for Multi‑phase Pumps
Case:
Service Factor (SF):
Multi‑phase pumps with steady-state operation and adequate slug damper
1.00
Multi‑phase pumps with frequent and rapid speed changes
1.10
Multi‑phase pumps with direct-on-line operation and frequent start/stop
1.25
Multi‑phase pumps operating without proper slug damping capability
Multi‑phase pumps experiencing frequent rapid density change
a
a
2.00
ρMAX/ ρMIN
– rapid here means a faster change than the VSD is able to adjust
Multi‑phase pump operation is usually limited by surge at some reduced flow and a choke limit
(stonewall) at high flow. Surge is a harmful condition to multi‑phase pumps and must be avoided. The
vendor must state the surge and choke limits with regards to speed, GVF, suction pressure and actual
flow and must also state the safe operation limits including the necessary separation margins. The pump
control system must include a strategy to avoid operating outside the stated limits.
Since NPSH is defined for single phase fluids and describes the pressure difference before vaporization,
NPSHA and NPSHR are not relevant when gas is present.
There is currently no proven method of calculating the influence of fluid viscosity on multi‑phase pumps.
The friction loss and power loss may be substantially larger than for a single phase centrifugal pump due
to longer flow paths in the impellers and high peripheral speed. Multi‑phase pumps shall have their
performance corrected in accordance with vendor's documented and tested methods.
True multi‑phase pumps must be designed to tolerate occasional short-time dry running. The vendor
shall state any limitations regarding speed-time and temperature limitations for dry running and also
incorporate a control strategy to avoid damages to the pump unit caused by dry running.
31
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RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
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API RECOMMENDED PRACTICE 17X
32
6.2.3 Rotary Positive Displacement Pumps – Selection and Rating Criteria
Equipment shall be selected to run simultaneously at the pressure-limiting accumulation pressure, trip
speed and water depth without suffering damage. Vendor shall advise purchaser of increased power
operating requirements necessary to achieve this.
Unless otherwise specified, the vendor shall recommend the pump speed for the specified service,
considering such factors as NPSHA and NPSHR when applicable, maximum and minimum fluid viscosity
and temperature, GVF, solids and abrasive content and wear allowance if required.
NOTE: It must be recognized that different rotary pump designs operate on different principles so that no
single speed criterion can be applied.
6.3 Pressure Casings
6.3.1 General
Pressure casings are the pressure and liquid containing vessels where the pump and motor is
encapsulated in subsea pumps. Unlike topside units, the motor and pump pressure casing are bolted
together as one single pressure container. This chapter is then covering both the pump casing and the
motor casing.
In order to promote standardization of subsea units, it is recommended to limit the casings pressure
classes to the six design classes shown in the Table 7 below, corresponding to API 6A Chapter 4.2.
Table 7 - Casing Pressure Design Class
Pressure class:
Name:
Design pressure:
A
B
C
D
E
F
2 000 Psi
3 000 Psi
5 000 Psi
10 000 Psi
15 000 Psi
20 000 Psi
138 Bar
207 Bar
345 Bar
690 Bar
1035 Bar
1380 Bar
For well-stream pumps, the potential well shut-in pressure shall be included in the maximum operation
pressure unless the system is provided with means to avoid this pressure in a safe way.
The pressure casing shall be a separate shell outside the motor and pump units. Pump flow passages
other than the suction and discharge nozzle, shall not be integrated in the pressure casing.
Pressure casings for subsea pumps are generally designed for a combination of wellhead design
pressure and/or outside environment pressure. ASME Section VIII Div. 2, Part 5 “Design by analysis
requirements” is suggested.
For class E and F the use of ASME VIII Div. 3 (Alternative Rules for Construction of High Pressure
Vessels) may be agreed.
32
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DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
33
Due to the high pressures and relatively large diameters, the design by rule methods in API 610, 676, 685
and other specifications are not adequate. The vendor, in his proposal, shall state the source of the
material properties from those listed in Table H.2 (i.e. ISO, ASTM, UNS, EN, JIS), as well as design
method and any casting factors applied. National material standards other than those listed in Table H.2,
may be used with specific purchaser approval.
Subsea pressure casings shall be verified by analysis to resist the external collapse pressure by the sea
water depth on the outside and vacuum on the inside of the casing.
As a result of high heat transfer rates to the surrounding seawater, subsea pump casings will exposed to
large thermal gradients between internal and external conditions. Thermal expansion between the pump
casing, internal parts, and other interfaces may result in sealing issues, stresses, etc. These must be
considered when designing internal sealing clearances between the casing and internal pump parts.
The purchaser and vendor may agree to allow for possible casing thickness reduction due to external sea
water pressure according to API 17TR12.
If 6B flanges as per API 6A are specified by the purchaser, metal –to-metal fits with ring gaskets as
defined in section 10.4 of API 6A shall be used.
Threaded holes in pressure parts are generally not allowed. The purchaser and the vendor may agree to
use small threaded holes for test ports, drainage and venting to be used during the assembly and test
period. Provided these threaded holes are plugged with a double-sealing barrier between the pump fluid
and the surrounding sea water and use metal to metal sealing.
Subsea structures are usually protected by Cathodic Protection (CP) and the risk of HISC must be
addressed in the design of pressure casings if using materials which may be sensitive to this.
6.3.2 Pressure Casings – Rotodynamic Pumps
In general, the design rules listed in API 610 chapter 6.3 (Pressure casings) also apply to subsea
rotodynamic pump and motor casings. Special requirements of subsea pumps requiring exceptions and
additions to these design rules are described in Section 6.1.1 of this document.
6.3.3 Pressure Casings – Rotary Displacement Pumps
Casing and other pressure-retaining parts and supports shall be designed to prevent detrimental
distortion caused by the worst combination of temperature, pressure, torque, and allowable external
forces and moments based on the specified operating conditions.
Unless specified, suction regions shall be designed for the same MACP as the discharge section.
6.3.4 Bolting and Threads
Fasteners, bolting and threads are covered in section 10.4.
33
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
34
6.3.5 External Pressure Casing Connections
External connections that require ROV interface will be designed following the guidelines as established
in API 17H.
Suction, discharge or auxiliary connections that do not require ROV interfacing shall follow the API 6A
guidelines established for subsea high pressure connections as agreed by vendor and purchaser. Note
that Cast Iron connections or nozzles are not allowed in subsea applications.
Other special flanges, as the “Compact Flange” type, may be agreed between vendor and purchaser, and
is especially relevant for the highest pressure classes and large diameters. For non-standardized
connections, fit for purpose for the flange, seal and bolt connection shall be proven by Finite Element
Analysis including non-linear material properties, pressure, tensioning loads and external forces and
moments, as well as a ratcheting analysis.
6.3.6 External Nozzle Forces and Moments
External allowable forces and loads at the pump flanges shall be limited to the maximum levels as
established by API 610 Chapter 6.5, and 676 respectively for each pump type.
When Flowline connection systems are used through valves or manifolds from the pump module to the
pump manifold, API 17H shall apply.
Pumps and pump module shall be designed for satisfactory performance if subjected to such forces and
moments applied simultaneously to both suction and discharge nozzles and connections at the interface
between the pump module and manifold at the most demanding combination of conditions of service as
specified in the process datasheet.
6.3.7 Casing Seals
Casing seals including the main seal shall be metal-to-metal seals where the casing contains
hydrocarbons, toxic or other hazardous fluids. Other seals may be agreed where the casing only contains
barrier fluid with a low environmental impact in case of leakage.
Elastomeric seals, which are exposed to the production fluids are subject to review and materials should
be qualified for rapid gas decompression.
6.4 Internal Pump Components
6.4.1 Rotodynamic Pumps
In general, the design rules listed in API 610 chapter 6 (Basic design) also apply to subsea rotodynamic
pumps. Also the specific pump types in chapter 9 shall be considered. Most subsea pumps are of the
between-bearing type and thus chapter 9.2 (Between-bearing pumps) shall be considered. Subsea
pumps do have some special requirements and a few exceptions and additions are listed here.
The minimum clearance between impeller and diffusor or volute shall be as stated in API 610 Chapter
6.1.15 and 6.1.16. This also applies to axial clearances in helico‑axial and semiaxial multi‑phase pumps.
34
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DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
35
Minimum clearances between rotating and static parts shall be as API 610 Chapter 6.7. Hybrid and multi‑
phase pumps that operate with less fluid support to the rotor from the wear rings and throttle bushes or
even experience dry running may require even higher clearances.
6.4.2 Rotary Displacement Pumps
Refer to API 676 (section 6.8), for internal rotating and hydraulic component requirements.
Inspection ports as required by section 6.8.2.4 of API 676 are not allowed in subsea applications.
If specified, replaceable liners shall be provided for screw pumps.
Unless otherwise specified for multi‑phase twin-screw pumps, hard coatings and/or surface hardening
shall be applied to the liner bores.
6.5 Mechanical Shaft Seals
6.5.1 General
Mechanical seals in subsea applications are to be used exclusively to isolate the process containing
sections of the pump module where the rotating shafts protrude towards the barrier fluid containing
section or other fully enclosed section of the pump module. Rotating shafts shall in no event in subsea
applications extend beyond the casing boundaries towards the environment (seawater).
Pumps shall be equipped with cartridge type mechanical seals in accordance with API 682 when feasible.
When full API 682 compliance is not possible (i.e. seal chamber dimensions cannot be met due to pump
design) vendor’s standard seal meeting the intent of API 682 shall be supplied. The following items shall
be provided in the proposal:
–
Category
–
Type
–
Arrangement and geometry
–
Materials of construction
–
Reference list
NOTE Space or design parameters for some pump types, sizes, or applications make the use of API 682 seals
impractical.
This standard does not cover the design of the component parts of mechanical seals. However, the
design of the component parts shall be suitable for the specified service conditions and consistent with
API 682. The purchaser shall specify the seal requirements using the selection process and the data
sheets in API 682 for this purpose including any required seal flush plans as defined by API 682.
35
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
36
Mechanical seals and glands for all subsea pumps shall be installed in the pump before shipment and
shall be clean and ready for initial service.
Seal selection shall be suitable for specified variations in suction and/or discharge conditions during startup, operation, or shutdown, including possible upset conditions. The vendor and purchaser shall agree on
the maximum static and dynamic sealing pressures that can be anticipated to occur in the seal chamber
and the vendor shall state these values on the data sheet [see 3.23 and 3.25]. If the seal is exposed to
suction pressure, special consideration may also be necessary for low suction pressure conditions or
when a single phase pump is subjected to a NPSH test requirement.
During transient conditions, the differential pressure across the mechanical seal is depending on the
response and functionality of the barrier fluid system. The vendor must analyze all possible transient
cases the pump may be subject to and from the barrier fluid system response, specify the highest and
lowest differential pressure and temperature the mechanical seal may be exposed to.
The maximum mechanical seal leakage at the specified operating conditions shall be provided with the
purpose of determining the rate of barrier or buffer seal oil usage and thus the sizing of the seal oil
reservoir or the barrier fluid system. In dual seal applications, the maximum seal leakage shall be
provided both towards the process and away from it.
The vendor shall also specify the minimum safe mechanical seal leakage at the specified operation
conditions in order to provide sufficient lubrication and cooling of the seal faces.
If a seal gland is used, its component parts shall be satisfactory for the maximum seal-chamber design
pressure and pumping temperature. It shall have sufficient rigidity to avoid any distortion that would impair
seal operation, including distortion that may occur during tightening of the bolts or nuts.
Mechanical seals shall be tested at worst case operating condition as minimum and maximum differential
pressures, maximum temperature and for transient conditions as emergency shut-down.
6.5.2 Rotodynamic Pumps
Rotodynamic pumps using mechanical seals shall in general conform to API 610 Chapter 6.8.
For subsea pumps which are highly integrated units and with no possibility to do maintenance on
mechanical seals without a complete disassembly of the unit, the requirement for seal cartridge removal
without disturbing the driver in Chapter 6.8.2 is not required. The seal chamber dimensions in Chapter
6.8.3 is recommended, but not required.
For pumps handling multi‑phase fluid (hybrid and multi‑phase pumps), the mechanical seal(s) must be
able to operate safely without any liquid on the pump side of the mechanical seal. The potential for rapid
temperature and pressure changes due to alternation between liquid exposure and gas exposure to the
seal faces shall be evaluated by the vendor and specified for the mechanical seal.
The mechanical seal rotating sleeve must be mechanically locked in both torsion and in both axial
directions by keys, shaft shoulders and lock nuts or similar.
36
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
37
6.6 Rotordynamics
6.6.1 Pumps
For rotodynamic pumps, the requirements in API 610 Chapter 6.9 generally apply.
6.6.2 General
For true multi‑phase rotodynamic pumps which may operate with high GVF or even run dry, the
requirements regarding maximum shaft deflection in API 610 Chapter 6.9.1.3 shall include no liquid
stiffening effect in the wear rings and throttle bushes also for multistage pumps.
Twin screw pump rotors shall have sufficient stiffness to ensure that its deflection is such that there is no
contact between the tips of the screw and the bores of the casing throughout the complete agreed
spectrum of differential pressure and speed at any given fluid viscosity or GVF.
Test requirements for vibration are found in Section 9.3.2.
6.6.3 Balancing
Balancing requirement is as described in API 610 Chapter 6.9.4 and API 676 section 6.8.1.9 for both
motor and pump.
6.6.4 Rotordynamic Lateral Analysis
The rotors of twin screw and small slow speed pumps are generally designed so its first dry-bending
critical speed is at least 20 % above the pump's maximum continuous operating speed.
In general, the requirements in API 610 Chapter 6.9 apply to rotodynamic pumps.
For rotodynamic high-speed multistage pumps and motors, a rotordynamic analyses shall be performed
according to API 610 Annex I with some extra considerations listed below.
a) For pump/motor units with a rigid coupling connecting the motor and pump shaft, the rotordynamic
analysis shall be made for the combined motor and pump rotor.
b) For multi‑phase pumps, the rotordynamic analysis must consider the actual operating conditions. In
particular the stiffness and damping effect from the multi‑phase fluid on internal seals, balance
piston, throttle bushes and impeller/stator interaction from caused by GVF, flow, pressure,
temperature and the Density Ratio (DR)
When selecting bearings, bushes and seals for multi‑phase pumps, damping properties should have
priority over stiffness properties when selecting bearings, bushes and seals. This may be achieved by
larger bearings, reduced preload etc.
37
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DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
38
6.6.5 Rotordynamics of Liquid Filled Motors
API 610 Annex I should be applied for the evaluation of damping ratios and separation margins of liquidfilled motors.
For the motor rotor analysis, the effect of liquid filling to stiffness, damping and added mass properties,
especially in the rotor – stator gap shall be considered.
The liquid present in the rotor – stator gap will cause a significant negative stiffness, a positive damping
and a large added mass which will make the rotordynamic behavior very different from that of an air-filled
motor.
The negative forces in the rotor – stator gap caused partly by the liquid filling and partly by the magnetic
pull, shall be evaluated for determining the motor bearing forces. This analysis must consider the
maximum rotor stator eccentricity and the actual bearing clearances.
6.6.6 Rotordynamic Torsional Analysis
When required, torsional analysis shall be performed following the guidelines as defined in Section 6.9.2
of API 610.
In the event that torsional analysis is required for rotary positive displacement pumps, the same guideline
is to be used but impeller vane and cutwater pass frequencies shall be replaced by screw mesh
frequency.
6.6.7 Pump-motor Unit Support Structure
The design of the structure for vibration is described in section 8.5.2
6.7 Bearings and Bearing Housings
6.7.1 General
Bearings shall be designed following the guidelines established in API 610, 676, 685 or similar above
referenced specifications to the pumps in the scope of this recommended practice.
Unlike pumps designed for topside applications and unless otherwise specified, bearings and bearing
housings for subsea applications are designed for lubrication and cooling by the barrier fluid. The bearing
technology and materials must be chosen in order to fit with the actual barrier fluid.
Special designed bearings may be proposed by the vendor to ensure a minimum bearing life that meets
the design criteria as specified in Section 6.1.1 of this document. Such deviations shall be clearly
indicated in the proposal. Such bearing and lubrication systems (which may also include the barrier fluid
and mechanical seal systems) shall be qualified prior to being deployed in the subsea pump.
38
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
39
6.7.2 Hydrodynamic Radial Support Bearings
Vertical pumps and motors with hydrodynamic bearings shall be equipped with radial tilt pad bearings for
all radial bearings in order to minimize destabilizing cross-coupling forces which may lead to “oil whirl”
instability.
Pump process lubricated support bearings may be accepted for single phase pumps and hybrid pumps
where it is impossible for the pump to run dry. The bearing material and design shall be a proven design
which can withstand the actual pumped fluid including possible sand content.
Radial bearing clearances shall be chosen to ensure an adequate bearing clearance during the most
extreme transient and steady-state operation conditions in order to avoid heat build-up and a reduced
clearance which in turns could cause a bearing seizure to the shaft. The nominal bearing diametrical
clearance shall be minimum 0.15% of the bearing diameter.
6.7.3 Hydrodynamic Thrust Bearings
The thrust bearing shall be able to take thrust force in both directions.
Hydrodynamic thrust bearings should be of the tilt-pad type.
The maximum start-up stiction torque for hydrodynamic thrust bearing (after long time of standstill) shall
be tested and used as input for the choice of motor and power equipment.
The thrust bearing maximum operational load shall always be less than 50% of the bearing ultimate load.
The thrust disc bore shall be perpendicular to the shaft centerline and have an interference fit to the shaft.
It shall be mechanically locked and secured in tangential and both axial directions.
6.8 Motor
6.8.1 General
Unlike topside pumps, the subsea pump motor is typically inside the pressure boundary with the subsea
pumping element. The barrier fluid system is circulated to cool the motor, and lubricate and cool the
mechanical seals and pump/motor bearing systems. Subsea motors for pumps are so far made with liquid
filling. This standard is only focusing on liquid filled motors and do not include any kind of gas-filled motor.
In general, the requirements in API 610 Chapter 7.1 and API 541 shall be followed where applicable. In
addition, some special requirements for subsea motors are defined.
Induction motors shall comply with API 541 (5th Edition) performance and test criteria. If a synchronous
motor alternative is proposed by Vendor, this alternative shall require a separate design review before
purchase and shall require written acceptance from Purchaser. Synchronous motors shall comply with the
performance and test requirements of API 546.
For induction motors, vendor shall submit all comments and exceptions to API 541 with bid documents for
Purchaser review and acceptance. Vendor shall submit an API 541 data sheet for Purchaser review and
39
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
40
acceptance. For synchronous motors, vendor shall submit all comments and exceptions to API 546 with
bid documents for Purchaser review and acceptance.
6.8.2 Motor Rating and Service Factor
Unless otherwise specified, the motor shall be sized according to API 610. The motor rating shall be
110% of the rated pump power (ref. API 610
40
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
41
Table 12). In addition, the service factors described in Chapter 6.2 shall also be applied for the motor.
The vendor and purchaser shall agree on design-case and future conditions and size the motor
accordingly.
For subsea motors, the motor input voltage may vary considerably due to losses in the umbilical and an
eventual subsea transformer. Unless the voltage is measured and controlled subsea in front of the motor
penetrators, the motor and rating shall allow for a voltage variation of ±10%.
The purchaser shall specify the type of motor in keeping with section 7.1.5 of API 610.
Electric motors for rotary positive displacement pumps shall be specified as suitable for constant torque
loads.
The motor nameplate rating, including service factor, shall be suitable for operation at 100 percent of the
pressure-limiting valve accumulation pressure in rotary pumps. Consideration shall be given to the
starting conditions of both the motor and driven equipment and the possibility that these conditions may
be different from the normal operating conditions. Equipment driven by induction motors shall be rated at
the actual motor speed for the rated load conditions.
6.8.3 Motor Electro-magnetic Design
6.8.3.1
General
Two types of electric motors are recognized as suitable for subsea pumps - Induction motors and
Permanent Magnet Synchronous Motors (PMSM). These motors have different characteristics and
different requirement applies to the two types of motors.
6.8.3.2
Induction Motors
The induction rotor shall be designed according to API 541. Motors can be designed for either fixed
frequency or variable frequency drives depending on pump application. For variable frequency driven
motors the performance requirements must be met throughout the frequency range. The purchaser
should specify the characteristics of the drive-system that is intended for the application.
The motor rated speed references to the actual speed of the motor for the rated frequency and rated load.
The minimum breakdown torque should be > 1.6 X the rated torque.
For a Motor starting with a fixed frequency (DOL start):
The minimum locked rotor torque (cold start conditions) at the defined operating frequency and maximum
80% of the rated voltage should be minimum 1.1 times the pump unit breakaway torque (stiction torque)
for all possible pump conditions.
The minimum pull-up torque (cold start conditions) for maximum 80% of the defined starting voltage and
the line frequency should exceed the maximum load torque with a safety factor of 1.1, including starting
with the maximum specified pump fluid viscosity. Harmonic torques must be taken into account if the
safety factor against the load torque is less than 10% of the load torque.
41
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
42
A system analysis may be required to show that the inrush current does not produce an excessive
voltage drop through the system to verify that the motor terminal voltage > 80% of the rated voltage for
the worst case conditions. Otherwise, the above requirement applies to the actual voltage level at the
motor terminals for the worst case conditions.
For a Motor starting with a variable frequency drive (VSD start) the minimum locked rotor torque (cold
start conditions) at the defined starting frequency and maximum 80% of the defined starting voltage
should be minimum 1.1 times the pump unit breakaway torque (stiction torque) for all possible pump
conditions.
The minimum pull-up torque (cold start conditions) for maximum 80% of the defined starting voltage and
the starting frequency should exceed the maximum load torque with a safety factor of 10% including
starting with the maximum specified pump fluid viscosity. Harmonic torque must be taken into account if
the safety factor against the load torque is less than 10% of the load torque.
The vendor should specify the start-up procedure (e.g. maximum acceleration rate and idling speed,
waiting time between start attempts, etc.).
6.8.3.3
Permanent Magnet Synchronous Motors (PMSM)
Permanent magnet motors should be designed according to API 547.
Control strategies should be sensor-less to avoid the need for resolvers/encoders.
6.8.4 Motor Mechanical Design
6.8.4.1
General
Unless otherwise specified, the motor shall be aligned to the pumping element by the use of rabbet fits or
other methods to assure alignment with varying ambient temperature and pressure associated with
deployment of the subsea pump module.
6.8.4.2
Motor Rotor – Stator Gap
The rotor – stator gap is very important in a liquid filled motor. The liquid friction will increase significantly
with reduced clearance and also destabilizing fluid forces may cause rotordynamic problems. In general,
it is recommended to use a radial gap of minimum 1.5% of the rotor diameter.
It is of vital importance to control and minimize the maximum rotor – stator gap eccentricity in an liquid
filled motor due to high destabilizing forces (negative stiffness) caused by both the gap liquid and the
magnetic pull. The motor design and the assembly procedure must take this into due consideration. The
rotor - stator eccentricity should be limited to maximum 0.25 mm (0.01 in.).
The design must consider the generation of high friction loss in the rotor – stator gap and provide
adequate means of effectively cooling this area.
42
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RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
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API RECOMMENDED PRACTICE 17X
6.8.4.3
43
Motor Rotor
Motors designed for speeds > 3800 RPM shall have interference fits for all major rotating parts in order to
maintain proper balance quality. The interference fit shall be adequate to compensate for component
radial deflection during operation at maximum speed.
Rotors for liquid filled motors are usually designed with a small rotor diameter and increased rotor length
in order to reduce gap friction. This long and slender rotor is more sensitive to destabilizing forces
generated by the gap liquid and the magnetic pull. The rotor design must in general incorporate
generously dimensioned shaft diameter, radial bearings and bearing housing in order to handle these
destabilizing forces.
For long and slender rotors in subsea motors, it is recommended to have a center balancing plane on the
rotor in order to properly balance a flexible rotor. This is mandatory for all rotors to operate >3800 RPM.
6.8.4.4
Motor Stator
The stator lamination pack must be adequately compressed in order to avoid harmful vibration between
the individual laminations.
All metal parts that may possibly come into contact with windings shall have smooth surfaces and be
deburred with defined radii on corners. It is recommended to use slot liners of PTFE or similar in the
lamination slots.
All significant natural frequencies of the stator housing and laminations shall be outside the range of rotor
bar passing frequency or rotor magnet excitation frequency throughout the motor operation range with a
margin of 15%.
6.8.4.5
Motor Stator Winding
The motor insulation class shall be selected from the standard voltage classes as given in IEC 60038. For
converter driven and/or motors for which continuous operation with an earth fault requirement the
insulation class shall be selected to be one class higher than the rated voltage class of the motor.
The motor winding may be either form wound or fully insulated cables.
The maximum copper temperature (continuous peak temperature including hot spots for the rated output
torque at the rated frequency and voltage) of the winding depending on the thermal rating of the insulation
material is summarized in Table 8. The maximum continuous operation temperature of the winding should
be limited to one class below the actual thermal class of the cable to ensure durability of the insulation.
Note that API 541 allows a maximum temperature rise corresponding to class B insulation for both class F
and class H insulation. For high speed subsea motors the coolant temperature is typically significantly
o
higher than 40 °C (104 F), thereby significantly limiting the motor performance if the API 541 requirement
is applied for a class H insulation.
The ambient temperature for subsea motors is determined by the sea-water temperature class according
o
to Table 3. Correction to 40 °C (104 F) ambient temperature is not required. The coolant medium
43
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RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
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API RECOMMENDED PRACTICE 17X
44
temperature is determined by the vendor given the ambient temperature and cooler properties and
losses.
For practical reasons it may be difficult to measure the winding temperature in a liquid filled motor with
fully insulated windings (cable wound) since it is difficult to ensure that the temperature measurement is
not affected by the coolant fluid which will result in a low temperature reading. Embedded temperature
detector readings should be interpreted with caution for verification of the temperature targets. Preferably
the copper temperature should be measured directly either by a temperature detector during a heat-run
test or a resistance measurement of the winding immediately after a heat run test. A resistance
measurement requires correction for stopping time and gives only the average winding temperature which
needs to be taken into account for interpreting the results. As an alternative method, calibrated CFD can
be used to verify that the temperature limits are not exceeded. This requires detailed knowledge about
the thermal properties of the insulation.
For temperature measurement limits (depending on the method of measurement) the limits corresponding
to one thermal class below the thermal rating of the insulation should be used. The appropriate margin on
the measured temperature is summarized in Table 8.
Excursions to higher temperatures during transient conditions should be limited in duration to ensure
adequate insulation life (service factor>1.0). Temperatures in excess of the thermal class are not allowed.
Table 8 - Insulation Thermal Classes used for Subsea Motors
Thermal class
(IEC60085)
90
105
130
155
180
NOTE
Previous letter
designation
Y
A
B
F
H
Maximum hotspot
winding temperature
o
o
90 C (194 F)
o
o
105 C (221 F)
o
o
130 C (266 F)
o
o
155 C (311 F)
o
o
180 C (356 F)
IEC thermal class 120 °C (E) is not recommended
Cable pigtails to the power penetrators shall have sufficient surplus length to allow minimum 10
connections/disconnections between the windings and the power penetrators.
The end-windings shall be supported or strapped in a way sufficient to avoid harmful vibration.
The design shall assure proper cooling of windings in areas where cables are bundled together.
6.8.5 Power and Instrumentation
6.8.5.1
Instrumentation
Pump motors shall include the winding and bearing temperature detectors and vibration detectors
required by API 541 for permanent mounting and operation in the motor. For cable wound motors, in lieu
of winding temperature detectors, confirmation of analytic temperature calculated in the windings shall be
confirmed during type test by method proposed by Vendor and agreed to by Purchaser.
44
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
6.8.5.2
45
Power System Engineering
During the course of project execution, the Vendor shall have the responsibility to confirm, by analytical
simulation, that all components included in the electrical circuit, including power umbilicals and
transformers, from the topside or onshore power supply to the variable speed drive (VSD) to the subsea
pump motor are rated to start the motor and supply continuous motor shaft power at the operating
conditions detailed in the project basis of design
–
–
Vendor shall supply an electrical component design confirmation report for Purchaser review and
acceptance
The definition of "all electrical circuit components included in the electrical circuit to the subsea motor"
shall include all components supplied by Vendor and all components supplied by others
Vendor shall issue torsional and lateral critical speed analysis reports for the pump and motor string and a
motor lateral critical speed analysis for Purchaser review and acceptance.
6.8.5.3
HV Penetrator
Vendor shall design and test the motor power penetrators, subsea jumper assemblies, and wet mate
connectors in accordance with SEPS SP-1001.
6.9 Couplings and Guards
6.9.1 General
Subsea motors are typically supplied by the pump module vendor and mounted by the pump module
vendor.
6.9.2 Coupling Rating and Service Factor
Couplings and coupling to shaft junctures shall be rated for at least the maximum motor power, including
the motor service factor listed in Section 6.2 of this document. Couplings shall in general have a minimum
safety factor of 2 with regards to maximum operational torque.
6.9.3 Coupling Design
Unlike topside pumps, spacer couplings are not used in subsea pumps for mechanical seal replacement
due to space restrictions and inaccessibility to do maintenance work. The coupling spacer may be
needed for other functions as noted by the vendor.
Rigid (non-flexible) couplings may be used for subsea pump – motor units.
If specified, couplings shall meet the requirements of ISO 14691, ISO 10441 or ANSI/API 671.
If specified, coupling hubs shall be fitted hydraulically. (This may need to be a requirement on
rotodynamic pumps operating above 3800 rpm).
45
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
46
Coupling guards are not necessary in subsea pumps since the coupling is most often contained inside the
pressure boundary housing. If the coupling is not contained within the pump/motor housing, then
corrosion resistant coupling guards as required in API 610 and 676. shall be supplied.
6.9.4 Alignment
Unlike topside pumps, alignment is typically maintained in subsea pumps through the use of rabbet fits.
On subsea pumps it is often necessary for the coupling design to allow for variations in motor shaft
projection. Splines or other methods are allowed based on the specific design requirements. In case
splines are used, special precautions must be taken with regards to pump – motor alignment in order to
avoid spline fretting.
Proper shaft alignment between pump and motor is of utmost importance in subsea units with non-spacer
type couplings. The design and assembly procedure must include a recognized method for measurement
and validation of both angular and parallel alignment.
If not otherwise agreed, the maximum shaft and housing run-out limits illustrated in Figure 4 and specified
in Table 10 shall be used.
Figure 4: Alignment of Motor and Pump
46
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
47
Table 9 - Motor Shaft and Housing Run-out Limits
Dial gage
Description
Requirement
A
B
C
Shaft run-out
Shaft-to-housing mating face radial direction
Shaft-to-housing mating face axial direction
30 µm TIR
50 µm TIR
50 µm TIR
Unless otherwise specified, couplings between motors and driven equipment shall be supplied and
mounted by the vendor with unit responsibility.
If specified, all-metal flexible element, spacer-type couplings shall be manufactured in accordance with
AGMA 9000 Class 9. Additionally, couplings shall comply with the following:
― Flexible elements shall be of corrosion-resistant material
― Couplings shall be designed to positively retain the spacer if a flexible element ruptures
NOTE The use of bolt heads or flexible element fasteners alone to retain the spacer (if a flexible membrane ruptures)
might not provide reliable support because they are subject to wear after the failure.
― Coupling hubs shall be steel or alloy steel
― Unlike topside pumps, spacer couplings are not used in subsea pumps for mechanical seal
replacement. The coupling spacer may be needed for other functions as noted by the vendor
― Unlike topside pumps, alignment is typically maintained in subsea pumps through the use of rabbet
fits
― Couplings operating at speeds in excess of 3 800 rpm shall meet the requirements of ANSI/API 671
for component balancing and assembly balance check
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.
Flexible couplings shall be keyed to the shaft. Keys, keyways and fits shall conform to AGMA 9002,
Commercial Class. Shaft coupling keyways shall be cut to accommodate a rectangular cross section key.
Sled-runner type keys and keyways shall not be provided. Keys shall be fabricated and fitted to minimize
unbalance. High speed rotodynamic pumps may require hydraulic fit coupling hubs or other methods.
Couplings and coupling to shaft junctures shall be rated for at least the maximum motor power, including
the motor service factor.
Coupling hubs designed for interference fits to the shaft shall be furnished with tapped puller holes at
least 10 mm (0.38 in) in diameter to aid in removal. On subsea pumps it is often necessary for the
coupling design to allow for variations in motor shaft projection. Splines or other methods are allowed
based on the specific design requirements.
If specified, couplings shall be fitted hydraulically. (This may need to be a requirement on pumps
operating above 3800 rpm).
47
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
48
If specified, couplings shall be fitted with a proprietary clamping device. Acceptable clamping devices may
include tapered bushes, frictional locking assemblies and shrink discs. The vendor responsible for the
final machining of the hub bores shall select a suitable rating/size device to suit the coupling and the
application.
Care should be exercised in the selection of these devices, as some are not inherently self-centering and
may introduce eccentricity and unbalance into the coupling assembly. This effect shall be evaluated and
allowed for when determining coupling potential unbalance.
Subsea motors are always supplied by the pump module vendor and mounted by the pump module
vendor.
Coupling guards are not necessary in subsea pumps since the coupling is most often contained inside the
pressure boundary housing. If the coupling is not contained within the pump/motor housing, then
corrosion resistant coupling guards as required in API 610, 676, etc. shall be supplied.
Unless otherwise specified, cooling systems shall be designed for external subsea conditions in Table 2.
6.10 Motor Cooling Systems
The need for cooling shall be determined by the vendor, and the method shall be agreed upon with the
purchaser. Vendors may propose external cooling coils to exchange the heat to the sea water.
If specified, the cooling coils shall be accessible on the outside for flushing/cleaning with ROV. Details on
method and the required space shall be agreed.
Provision shall also be made to allow the cleaning of jackets or cooling coils, after retrieval.
Jacket systems, if provided, shall be designed to prevent the process stream from leaking into the jacket.
Jacket passages shall not open into casing joints.
Provisions shall be made for complete venting and vacuuming of the cooling system prior to delivery.
The same design rules regarding pressure, temperatures and water depth apply for cooling coils or
jackets as for pressure casings in chapter 6.3.
The rheological and heat transfer properties for coolants shall be carefully evaluated for pressure and
temperature effects and their suitability for subsea use. Oil-based fluids should also be evaluated for
gelation and other thermal effects.
48
THIS
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RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
49
In order to meet the requirements of the various test and operation environments, the motor cooling
system design shall include an evaluation of:
― Test environment conditions including circulation and temperature. The cooling system shall be
dimensioned to allow full load testing in the test pit during FAT at the actual pit temperature.
― Operational environment conditions including the effect of pressure, temperature and salinity on the
heat transfer properties of seawater
― Variability of environmental conditions between intended operating depth and locations
― Fouling and scaling shall be considered in the design. The cooling coils or cooling jacket shall be
2 o
designed for a minimum (internal+external) fouling factor of 0.35 m2∙K/kW (0.002 hr∙ft ∙ R/BTU) with
additional requirements for bio-fouling and other application specific conditions.
― Access should be included if mechanical cleaning using ROVs is assumed in the design.
6.11 Barrier and Lubrication System
Where relevant, the motor should be protected by a barrier fluid and shall ensure that the design of both
the motor and barrier fluid system maintains over pressure above the pump process pressure and
provides sufficient lubrication and heat transfer cooling of motor components.
49
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
50
7 Pump Control, Protection and Monitoring Systems
7.1 General
The control, protection and monitoring systems for subsea pumps shall be designed in accordance with
applicable sections of API 17F. Specific functional requirements for the control and monitoring systems
are given in the sections below.
7.2 Functional Requirements for Control Systems
7.2.1 General
The functional requirements of the pump control system are listed below for the pump system and
associated subsystems.
7.2.2 Pump System
–
–
–
–
–
–
Respond to Emergency Safety System (ESS) signals and take appropriate actions to secure the
system
Ensure pump suction and discharge pressures/temperatures remain within their predetermined limits,
and to take appropriate actions to prevent damage to equipment or the environment
Continuously maintain subsea pump operation within its designated operating envelope
Protect the subsea pump from flowline transients by taking appropriate action
Avoid prolonged/continuous operation in structure resonant frequencies, if any
Continuously monitor VSD frequency with fail-safe feedback loop.
The subsea pump suction and discharge pressures shall be monitored with two separate subsystems
within the subsea control system. The intent of this is to mitigate common mode failures between those
two pressure monitoring systems. Each of the two pressure monitoring subsystems shall be capable of
independently halting pump operation in the event of adverse pressure conditions.
7.2.3 Pipeline Isolation
The subsea pump shall be isolated from production pipe line with isolation valves. The control system
shall ensure the closing duration of the subsea pump isolation valves is short enough to protect subsea
pump from flowline pressure transients such as ESD boarding valve closure in any production flow
conditions.
7.2.4 Barrier Fluid System
The barrier fluid system for the subsea pump shall be designed to continuously provide barrier fluid to the
subsea pump during facility evacuation, to continuously protect the subsea pump during subsea pump
and/or pump manifold leak test, and also to lubricate and regulate temperature of mechanical pump
components.
50
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
51
The control system for the barrier fluid system shall be required to continuously monitor subsea barrier
fluid consumption, pressure and temperature, replenish barrier fluid as needed and also regulate subsea
barrier fluid supply pressure according to production pressure to ensure positive pressure over
mechanical seals. The barrier fluid system shall also be required to maintain a positive pressure during
facility evacuations. Maximum design pressure for the barrier fluid system and the associated control
system shall be specified in coordination with system leak test pressure.
7.2.5 Chemical Injection System
Pressure transducers shall be included for monitoring of chemical injection pressures both at topside
upstream of the umbilical and subsea upstream of the subsea chemical isolation valve(s). The monitored
chemical injection pressures may be used by the control system to interlock subsea chemical injection
valve opening and may be used to automatically close the subsea chemical injection valve to protect the
subsea pump from chemical injection pressure transients.
7.2.6 Control System Communications
Induced electrical noise from the medium/high voltage power lines shall be considered while choosing
subsea communication method. The optical communication is the preferred method of communication.
Induced voltage and induced electrical noise from the medium/high voltage power lines to lower voltage
controls power lines shall be considered while designing subsea control system.
All pump control system external and internal critical communications shall be fail-safe. In particular, in
the event of loss communication with subsea, the Pump Control System shall stop the pump. Likewise, in
the event of Variable Frequency Drive frequency feedback loop failure or operational discrepancy, the
pump control system shall cause disconnection of supply power to the VFDs.
7.3 Functional Requirements for Monitoring Systems
7.3.1 Gauges
If furnished, temperature indicators and pressure gauges shall be in accordance with API 614, as
applicable to subsea environment and pressure.
7.3.2 Vibration Sensors
When specified, accelerometers and/or proiximity probes shall be supplied, installed and tested in
accordance with API 670.
7.3.3 Flowmeters
Flowmeters may be implemented as a portion of the pump control / protection system. API RP 17S
provides an appropriate guideline for design criteria appropriate for this use. Since the primary goal of the
device is to identify operations outside the intended operating range of the pump, the following
considerations are important.
51
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DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
52
The flowmeter system meter needs to provide results sufficiently quickly that the pump control system can
react and respond. Bulk fluid rates and Gas Volume Fraction should be primary measurement capabilities
of the flowmeter system.
The meter accuracy and operating range needs to be sufficient for the pumping application. Specific
examples of flowmeter requirements are listed below.
–
–
High Gas Volume Fraction: The meter cannot operate with fixed fluid properties and needs to
measure the gas rate or GVF directly over the intended operating range.
High Flowrate: The pump vendor must identify the accuracy required to prevent stonewall.
Continuous response capability may also be required and meter saturation needs to be considered.
Low Flowrate: The pump vendor must identify the accuracy required to prevent stall/surge of the
subsea pump. Continuous response capability may also be required.
7.3.4 Torque Sensors
Because flowmeter responses show a sufficiently long lag between measurement and output, torque
measurements provide immediate indications of high speed transients in fluid contents at the pump inlet.
52
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DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
53
8 Installation and Intervention
8.1 General
The general requirements for the permanent and retrievable portions of a subsea boosting facility are
described in:
API 17D, Design and Operation of Subsea Production Systems—Subsea Wellhead and Tree Equipment
API 17P, Design and Operation of Subsea Production Systems—Subsea Structures and Manifolds
API 17R, Recommended Practice for Flowline Connectors and Jumpers
The following portions of other relevant standards DO NOT apply to subsea boosting devices
With the exception of the storage and preservation clauses, API 686 does not apply to subsea pump
modules
Baseplate portions of API 610, 676, 685, etc. do not apply to subsea pumps
8.2 Installation/Retrieval Considerations
API 17P and API 17R provide descriptions for the frame and connections solutions of the considerations
related to installation and retrieval of the pump module.
During installation, the subsea boosting module solution should:
–
–
–
–
–
–
–
–
–
–
–
–
not rely on hydraulic pressure to retain the necessary locking force in (module-to-module) connectors;
allow cessation of operations without compromising safety
allow testing/verification of interface connections subsequent to connection
allow for quick, easy and reliable make-up of modules
have facilities for testing prior to deployment by the use of test/transport skids, if applicable
minimize entry of water or contamination into hydraulic and barrier fluid circuits during connections
(which can jeopardize system functionality)
facilitate orientation and guidance during installation
may include shock absorbers or any soft landing devices, as required, in order to allow for specified
maximum landing velocity
be tolerant of small amounts of seabed debris between the interface connections or allow flushing
prior to make-up operation
avoid loss of harmful fluids during installation, operation and retrieval
minimize impact of equipment malfunction leading to discharge of hydrocarbons
facilitate periodic testing to verify that the system is fully functional
An important consideration with respect to these equipment and the application of API 17TR12 is related
to the temperature difference between subsea and surface conditions. A system flushed then closed-in
prior to retrieval may see significant pressure increases as a result of thermal expansion of the trapped
53
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DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
54
fluids. Similarly, trapped fluids captured at surface conditions then heated by the production fluids and
o
boosting system may be subjected to the same issue. Trapped seawater subjected to a 75 F (42 C) will
generate a pressure rise in excess of 4350 psi (300 bar). In addition to thermal expansion, trapped
hydrocarbons may undergo a phase change as a result of the temperature rise during retrieval.
In addition to the requirements described in API 17P and API 17R, the following requirements should be
evaluated:
–
–
–
–
–
–
–
Flushing facilities to minimize hydrocarbon or other harmful fluid volumes trapped within the item to
be retrieved. Flushing infrastructure should be designed to provide effective flushing of the module to
be retrieved
A recommended flushing procedure may also be part of the manufacturer documentation.
If the system is to be retrieved or transported as a sealed assembly, a solution allowing for pressure
relief during retrieval or transport should be considered as part of the design.
Retrievable modules should be designed to enhance flexibility in the choice of installation/
maintenance vessels
The pump module should be designed for entry through the splash-zone – large closed surface-areas
should be avoided
Provisions should be made for draining, flushing, and filling of structural steel during installation
and/or retrieval
Vendor to supply installation tools, lifting points to adhere to section 1.2.1 requirement
8.3 Transportation and Testing Equipment
8.3.1 General
This scope of this section is limited to the initial delivery process to the purchaser. Consideration should
be given to transportation and handling onshore as well as offshore. The retrievable module of the
boosting system should be transported in a dedicated transport frame. Test stands and fixtures (including
jigs) are used at the point of assembly or installation to verify the interface and functional operation, load
and pressure capacity, and interchangeability of the equipment being installed. They may also serve as
the shipping skids for transporting equipment offshore.
8.3.2 Lifting Arrangements
Lifting lugs on transportation and testing equipment to allow handling may be supplied and should comply
with certification agreed between the purchaser and the vendor. Testing of reusable lifting equipment is
more stringent as this equipment is subject to lifting cycles throughout its lifetime. Annex K of API 17D
provides design, testing, and maintenance guidelines for both reusable lifting equipment and permanently
installed equipment.
The design of test stands and fixtures shall consider assembly and handling loads as well as test loads.
8.3.3 Test Equipment
Test stands and fixtures used only at the manufacturer’s facilities are outside the scope of this document.
54
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RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
55
Where test equipment is used to simulate mating components for testing the assembly of interest, they
shall be made to the same dimensions and tolerances at all interfaces as the simulated component.
8.3.4 Test Stands
Test stands simulate the profiles of the subsea manifold, flowbase, etc. to facilitate pressure testing of the
pump module, and to position orienting joints relative to the subsea infrastructure. They may also contain
hydraulic couplers and electrical connectors to facilitate testing of the controls and power related
functions.
Test ports shall communicate with the individual bores of the test stumps to facilitate pressure testing.
The benefits of piping all test ports back to a common manifold with isolation test valves shall be
examined.
Guidance provided by the test stands shall simulate the requirements of the actual equipment being
tested.
8.3.5 Equipment used for Shipping
Test stands, etc. used for shipping equipment offshore shall provide protection to the equipment during
handling and transportation. Sea fastenings shall be designed to take all the static and accelerated
loading conditions due to roll, pitch and heave of the vessel in the locality where it will be transported and
should be suitable for securing the assembly to the rig and rig skids.
8.4 Preservation and Storage
8.4.1.1
General
The manufacturer should include the following considerations in the development of preservation and
storage procedures.
–
–
–
Maximum and Minimum temperatures during transport from manufacturing site to installation site and
including transshipment and storage sites
Loads occurring during shipping or land transport
Considerations of all exposed materials and storage conditions should be included in the evaluation
of preservation fluids
8.4.1.2
Draining after Testing
All equipment shall be drained and lubricated in accordance with the manufacturer’s written specification
after testing and prior to storage or shipment.
8.4.1.3
Corrosion Prevention
Prior to shipment, parts and equipment shall have exposed metallic surfaces (except those otherwise
designated, such as anodes or nameplates) either protected with a rust preventive coating that does not
55
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DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
56
become fluid at temperatures less than 50 °C (122 °F) or filled with a compatible fluid containing suitable
corrosion inhibitors in accordance with the manufacturer’s written specification. Equipment already
coated, but showing damage after testing, should undergo coating repair prior to storage or shipment.
8.4.1.4
Sealing Surface Protection
Exposed seals and seal surfaces, threads, and operating parts shall be protected from mechanical
damage during shipping. Equipment or containers shall be designed such that equipment does not rest
on any seal or seal surface during shipment or storage. Storage skids should be designed to simplify
inspection of seal (and other) surfaces.
8.4.1.5
Loose Seals and Ring Gaskets
Loose seals, stab subs, and ring gaskets shall be individually boxed or wrapped for shipping and storage.
8.4.1.6
Elastomer Age Control
The manufacturer shall document instructions concerning the proper storage environment, age control
procedures, and protection of elastomer materials.
8.4.1.7
Hydraulic Systems including Barrier Fluids
Prior to shipment, the total shipment including hydraulic lines shall be flushed and filled in accordance
with the manufacturer’s written specification. Exposed hydraulic end fittings shall be capped or covered.
All pressure shall be bled from equipment, unless otherwise agreed between the manufacturer and
purchaser.
8.4.1.8
Electrical/Electronic Systems
The manufacturer shall document instructions concerning proper storage and shipping of all electrical
cables, connectors, and electronic packages
8.4.1.9
Extended Storage
Storage and preservation requirements for equipment after delivery to the user are beyond the scope of
this document. The manufacturer shall provide recommendations for storage to the user upon request.
Note that a requirement for mechanical operation during long term storage extends the scope of supply.
8.5 Pump Module Structure
8.5.1 General
Subsea pump module, ROV panel, barrier fluid connections, power and control connections and
instrumentation connections, etc., are supported in a structural frame which allows deployment and
56
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RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
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API RECOMMENDED PRACTICE 17X
57
retrieval using retrieval tools, ROV's etc. The structure is to be designed to be consistent with API 17P,
17R, 17D including lifting, side impact, and acceleration requirements associated with transport to from
and within the intended market.
The structure shall extend such that nothing protrudes beyond the structure frame to the side and top
other than safety ladders and attachment points.
If specified, the support structure shall be constructed to deflect or guide fishing nets or other drawn
objects around the structure to less chance of damage to the structure and its contained components.
8.5.2 Vibration
For vertical units, the Pump Module Support Structure together with the pump module shall have their first
(fundamental) natural frequencies 25 % below the lowest operational speed of the unit. The natural
frequencies analysis together with a response analysis shall be documented in a report. This shall as a
minimum include:
–
–
–
A description of the analyzed model, the methods used and the assumptions made during the
analysis
The calculated natural frequencies from 0 Hz up to minimum 150 % of maximum speed and plots
showing their corresponding mode shapes, and
The response analysis in both displacement (mm) and vibration (mm/s) caused by a unit load (for
instance 1000 N) on each pump and motor bearing locations. The analysis shall be run continuously
from 0 Hz up to minimum 150 % of maximum speed with a reasonable delta frequency (for instance
1 Hz)
Note:
In order to avoid resonances between the natural frequencies of the Pump Module, Support
Structure and the operational frequency of the unit, it is very advantageous to have the first
natural frequencies of the structure well below the operational frequencies in order to make the
unit “mass dependent”. Subsea pump units typically contain sufficient mass in the motor and
pump casing to avoid inappropriate vibration responses.
8.6 Pressure-Limiting Valves
Pressure-limiting valves or other protective devices shall be used with all positive displacement pumps.
Rupture disks shall not be used. The sizing, selection and installation of pressure limiting valves shall
meet the requirements of API Recommended Practice 520, Parts I and II.
Unless otherwise specified, the purchaser shall provide pressure-limiting valves in accordance with
API 526. The vendor shall provide the purchaser with information on recommended flow rate and
relieving pressure. The vendor and purchaser should review the purchaser’s valve selection. Pressurelimiting valve sizes and settings, including accumulation, shall take into account all possible modes of
equipment failure and shall meet the requirements of 6.3.2.
If specified, the valve shall be provided by the vendor.
Unless agreed to by the purchaser, pressure limiting valves that are integral with or internal to the pump
are not acceptable.
57
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DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
58
8.7 Piping and Appurtenances
8.7.1 General
Piping shall be in accordance with the requirements described by API 17P and 17R.
Auxiliary systems are defined as piping systems that are in the following services:
–
–
–
auxiliary process liquids
barrier fluid/lubricating fluid or oil, and
cooling water circulation if utilized
Auxiliary system materials shall be agreed upon by vendor and purchaser. Table H.4 in API 610 may be
of some assistance but was not written for subsea environment.
Barrier/buffer fluid valves/makeup reservoirs and any piping system as a whole shall be mounted in the
pump module structure and fully assembled.
The vendor shall furnish and locate all piping systems, including mounted appurtenances, within the
confines of the pump module structure.
Each piping system requiring umbilical or ROV interface shall be manifolded to a single purchaser's inlet
or outlet connection near the edge and within the confines of the pump module structure in a section that
will be accessible once the pump module is mounted in the pump manifold.
Plugs shall be avoided.
8.7.2 Auxiliary Process Liquid Piping
Auxiliary process-liquid piping includes vent lines, drain lines, balance lines, product flushing lines and
lines for injection of external fluid.
Piping components shall have a pressure-temperature rating at least equal to MAWP of the pump casing.
Piping and components subject to the process liquid shall have a corrosion/erosion resistance equal to or
better than that of the casing. Otherwise, all components shall be steel.
Orifice openings shall not be less than 3 mm (0.12 in) in diameter. Orifice hole size shall be stamped on
the orifice plate. The purchaser shall specify orifice tagging or labelling requirements.
Drain valves and a drain manifold shall be supplied for pumps that require more than one drain
connection. The drain manifold shall be inside the pump module structure limits. The purchaser and
vendor shall agree upon whether the valves are to ROV operated, or, only hand operated once the pump
module has been retrieved for maintenance.
If heating or cooling is provided, each exchanger component shall be suitable for the process liquid and
ambient water to which it is exposed.
Threaded piping joints shall not be used.
58
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QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
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API RECOMMENDED PRACTICE 17X
59
8.7.3 Cooling-Water Piping
Cooling loop piping on subsea pumps is very special and the schematics in API 610 and other specs are
probably not adequate to describe the needs of subsea pump cooling, barrier fluid piping, etc. The
purchaser and vendor shall agree on any cooling loop piping systems.
The cooling-water piping shall be designed for all of applications including qualification, and factory
acceptance test conditions.
8.8 Special Tools
If 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 of the machine. For multiple-unit
installations, the requirements for quantities of special tools and fixtures shall be agreed upon by the
purchaser and the vendor. These or similar special tools shall be used during shop assembly and posttest disassembly of the equipment.
If special tools are provided, they shall be packaged in separate, rugged metal boxes and marked
“special tools for (tag/item number)”. Each tool shall be stamped or tagged to indicate its intended use.
59
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RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
60
9 Qualification and Application Specific Testing
9.1 Scope
9.1.1 General
The API RP 17X testing section recommends system and sub-system level qualification and application
specific tests. The section describes procedures for qualification testing of new or significantly modified
solutions. The section further describes application specific testing of pumps and motors in series that
have already successfully undergone and passed qualification testing.
Application Specific Testing
Application specific testing is intended to confirm that systems made after the first production run have
been manufactured correctly.
Qualification Testing
Qualification testing is driven by new or changed, pump and motor designs, applications or operating
conditions and combinations thereof that have not been previously demonstrated via qualification tests.
The tests will bring the subsea pump and motor to a minimum TRL 4, as defined in API 17N. Qualification
tests will require more resources and post-test inspection than application specific tests.
Endurance Testing (or Extended Testing)
Endurance tests are tests aimed at establishing the reliability model for a system (as per TRL 4 of API
17N). As a result of that relationship, it is only required for first in series testing of products with
fundamental changes in one or more of:
a)
Absorbed power
b)
Flow capacity
c)
Orientation
d)
Bearing philosophy
e)
Lubrication/cooling system
Component and reliability testing are required to reach TRL 2 and 3. These system level tests
supplement the qualification process developed according to API 17N (TRL/TRC assessment, FMECA,
RBD, RAM, Qualification Plan).
All testing prior to system level tests fall outside the scope of this section. The system tests defined herein
reduce the risk of deploying equipment that either lacks successful field experience or lacks relevant
experience in the required operating conditions.
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QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
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9.1.2 Test Validity
Qualification tests on pump systems shall remain valid on subsequent pump systems when the following
conditions are met:
a) The qualified system shall have equal or higher ratings than the subsequent system for each of the
following parameters.
― Power (MW or hp)
3
― Flow-rate (m /hr or bpd)
― Head (m or ft) ) or differential pressure (psi/bar
― Rotational Frequency (RPM)
― Shut-in pressure (bar or kpsi)
― Maximum operating temperature (ºC or ºF)
― Orientation (horizontal or vertical)
b) The qualified system shall have a GVF range that is equal to or includes the allowable GVF range for
the subsequent system. For example, if the qualified system GVF range is 20 to 60 %, a subsequent
system can have a range of 20 to 60 % GVF or 30 to 50 % GVF without requalification.
c) The subsequent system shall use a barrier fluid (if required) that has been tested and qualified with
the qualified system.
d) The subsequent system shall use a barrier fluid (if required) that has been tested and qualified with
the qualified system.
e)
f) he qualified system should be tested under slug flow regime conditions.
All qualification tests must be repeated if any of the conditions above are not satisfied. A subsequent
pump system only requires application specific testing if the conditions above are satisfied.
9.1.3 Pump System Layout
The boundaries of the boosting system (pump and motor) referenced within this document extend from
inlet flange to outlet flange of the pump module and includes the power system from the drive down to the
motor. The pump control (pump instrumentation to topsides control system) and barrier fluid systems to
mechanical seals are also included. When use of full scale components is not feasible, components may
be simulated. For example, an umbilical can be simulated by the use of an umbilical simulator.
Components from the larger system may be required for some tests on the pump and motor. The system
tests apply to a typical subsea boosting system, which are generally composed of the following
qualification and application specific testing objects (See Table 10). Figure 5 is a flowchart describing the
decision process for choosing between paths (qualification or application specific testing).
61
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QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
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API RECOMMENDED PRACTICE 17X
62
Table 10 - Scope of Test Object
Test Object
Qualification
Application Specific Test
Required
Required
Optional
Emulated
Emulated
Contract Transformer
Emulated
Contract VSD
If relevant
If relevant
Pump and motor
Required
Required
Barrier fluid system
If relevant
If relevant
If Integrated
If Integrated
Emulated
Required
Required
Required
Buffer tank (for MPP)
For Slug Tests
Required
Liquid extraction unit
If Relevant
If Relevant
Recycle valve
If Relevant
If Relevant
Recycle coolers
If Relevant
If Relevant
Power Distribution and Communications:
Subsea power interface/connectors
Subsea power umbilical
a
Subsea or topsides transformers
b
Variable speed drive
SCM or equivalent
c
Pump Module:
Pump sump
Pressurization system
d
Motor/lubricant cooler (s)
Pump Station:
Notes:
a
The power umbilical is an application specific item with the details of the manufacturing solution affecting the
design of the emulator.
b
The emulation of the subsea transformer should be based on the use of the topsides equivalent model.
c
An SCM may not always be implemented. Alternative solutions must be included as a portion of the
qualification/application specific program.
d
The dynamics of the hydraulic solution are application specific. Application specific tests should be performed
with an appropriate HPU and relevant umbilical emulation.
62
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RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
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API RECOMMENDED PRACTICE 17X
63
Figure 5 - Decision Tree for Testing
The above list is for reference only and is not intended to be comprehensive. It is a high level collection of
components meant to show the reader the scope and size of the boosting system referenced within this
document.
Component level tests shall be performed prior to conducting the system testing. Component tests are
not defined in this document; however, relevant component level tests defined in other industry standards
are referenced where possible.
The tests apply to the pumps described in Table 1.
63
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QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
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API RECOMMENDED PRACTICE 17X
64
9.2 Individual Tests
9.2.1 General
This document defines test procedures for the following types of boosting system tests:
― Start-up and Shutdown
― Locked Rotor Start-up
― Normal Performance Operation
― Liquid Slugging
― Extended Performance and Operation
In addition to defining the system tests, this document defines how to report system performance test
results. The standard set of boosting system performance results enables straightforward comparisons of
different boosting systems.
The tests are divided into two categories, one aimed at new product qualification which is characterized
by generic specifications and undefined contractual relationship between pump vendor and operator. The
second category is aimed at product application acceptance which is characterized by testing a
separately qualified design against application specifications and a clear contractual relationship between
pump vendor and operator.
The project/application specific test requirements are a subset of the qualification process.
NOTE
Unless otherwise specified, ‘maximum’ refers to the maximum operating condition for any given
parameter, according to the design of the system and the range of operating conditions for which it shall
be qualified.
NOTE
Unless otherwise specified, ‘minimum’ refers to the minimum operating condition for any given parameter,
according to the design of the system and the range of operating conditions for which it shall be qualified
9.2.2 Reporting Requirements
Test reports that follow these tests shall be comprised of operating and inspection data.
9.2.3 Operating Data
The following parameters shall be monitored and included in the test report:
― Pump inlet and discharge pressure
― Pump inlet and discharge temperature
― Pump speed
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RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
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65
― Flowrate
― GVF
― Inlet barrier fluid temperature (if relevant)
― Barrier fluid leakage rate (for steady state operation only)
― Barrier fluid temperature within motor
― Balance line pressure (if applicable)
― Motor current
― Motor voltage
― Pump and motor rotor vibration data (rotor radial and axial displacements relative to the casing)
― Pump and motor casing vibration data (accelerometer data)
― Barrier fluid cleanliness measurement (e.g. by sample and analysis)
― Barrier fluid dielectric properties (conductivity and relative permittivity at a given frequency), if
applicable
― Process fluid density (measured at pump inlet)
― Motor winding temperature (if available)
― Barrier fluid temperature upstream and downstream of cooler
― Barrier fluid flow rate within the cooling loop
NOTE A minimum of 2 pairs of radial proximity probes shall be installed during qualification testing for each rotor, one
for each journal bearing.
9.2.4 Inspection Data and Inspection Criteria
9.2.4.1
After Qualification Testing
After qualification testing is complete, the pump shall be disassembled and inspected for wear or damage
to the following components listed in 9.2.3.1.1 and 9.2.3.1.2.
No visible or measured signs of damage or wear shall be present, beyond what is deemed acceptable
between the pump supplier and operator. No evidence of debris generation from the pump/motor shall be
present in the barrier fluid system.
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RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
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66
― Operator shall be permitted time to make a visual inspection of the disassembled pump and motor
components, including the mechanical seal, radial and thrust bearings
― Microscopic inspection of seal faces and elastomers shall be performed; which and how many to be
agreed between vendor and purchaser
― Bearing pad wear shall such that the bearing is within original manufacturing tolerances after the test
― Bearing edge wear shall not be visible to the naked eye
― Bearing clearances shall be reported
― Any deterioration of seal or bearing components shall be reported
― Any contamination of barrier fluid shall be reported
― Mechanical seal components shall be measured before and after testing
9.2.4.2
After Application Specific Testing
Pump disassembly is not required for application specific testing. Analysis of operating data is sufficient to
confirm that the pump is not damaged during this form of testing.
9.2.4.3
Factory Acceptance Testing
Pump disassembly is not required for application specific testing. Analysis of operating data is sufficient to
confirm that the pump is not damaged during this form of testing.
9.3 Pump Acceptance Criteria
9.3.1 General
The following parameters shall be subject to acceptance criteria:
9.3.2 Vibration Data
Vibration acceptance criteria are listed in Section 11.2.5 with the following additions:
–
–
Pump peak-to-peak vibration measured at radial bearings shall meet pre-determined supplier criteria
for overall, synchronous, and non-synchronous components
Motor peak-to-peak vibration measured at radial bearings shall meet pre-determined supplier criteria
for overall, synchronous, and non-synchronous components
66
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RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
–
–
–
–
67
For each test point, the pump and motor vibration data shall remain consistent from the beginning to
the end of testing within the noise range of the measurement. (For example, if the pump driven end
peak-to-peak vibration is 60 microns +/- 10 % for test point 7 within the first 100 hours of testing, the
same vibration levels shall be measured for test point 7 in the last 100 hours of testing.) The supplier
shall demonstrate that vibration levels do not increase throughout the endurance tests
Maximum allowable bearing and seal clearances taken up by shaft vibration shall meet predetermined supplier criteria
Observed critical speed(s) indicated by a distinct vibration peak and appropriate phase shift shall
occur within +/-10& of the calculated value(s) per API 610 1.2.4a
Measured vibration amplitudes shall be within 35% of calculated values per API 610 1.2.4b
9.3.3 Pump Performance
–
–
–
–
Pump shall produce head and flow rate at a given power, as stated in the contract
Barrier fluid leakage rate shall conform to the rate agreed by operator, supplier, and VENDOR
The maximum speed of barrier fluid pressure change (bar/second) must be reported and held within
the values agreed on by the operator, supplier, and VENDOR
Pressure differential between barrier and process fluid must also be measured, reported, and held
within the agreed upper and lower limits
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QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
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API RECOMMENDED PRACTICE 17X
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10 Materials and Materials Inspection
10.1 Scope
This clause covers both covered by and items not covered by API 17A, 17P, 17R. The relevant material
class should be chosen using the methodology described in API 6A Clause 4.2. Further API 6A Clause
6.15 describes the material performance, processing and compositional requirements for the pump
casing and other pressure containing parts in the pump assembly. Other pressure-containing and
pressure-controlling parts shall be made of materials that satisfy 6.15.2 and the design requirements of
API 6A Clause 4.
All material requirements in API 6A Clause 6.15 apply to carbon steels, low-alloy steels and martensitic
stainless steels (other than precipitation-hardening types). Other alloy systems (including precipitationhardening stainless steels) may be used, provided they satisfy the requirements of Clause 6.15 and the
design requirements of API 6A Clause 4.
10.2 Special Materials
Special materials and processing methods such as Hot Isostatic Pressing are covered by ISO 17782 and
NORSOK M-650 ed.4 and are subject to the qualification procedures covered by the referenced
standards.
10.3 Connectors, Piping, Valves, and Structure
The design and materials requirements for connectors, valves, piping, and structural items are described
in API 17D, API 17P, and API 17R.
10.4 Fasteners
Fasteners for load bearing or pressure containing items shall be compliant with subsea requirements as
described in API 6A, API 20E, and API 20F.
Bolting and threads for pressure containing applications, end and outlet connections shall follow the
guidelines as established in:
― API Spec 6A section 10.1.
― API Spec 20E
― API Spec 20F
― The API Task Group Report on Bolting Failures
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QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
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API SPEC 6A section 4.3.4 and 4.4.3 shall apply to any other types of bolted connections exposed to the
environment and/or connecting pressure boundary parts or parts that are designed as or could become
pressure boundaries in the event of a failure of other components.
10.5 Written Specifications: Pump and Motor Casing
10.5.1 General
In keeping with API 6A, all metallic and non-metallic pressure-containing or pressure-controlling parts
shall require a written material specification.
10.5.2 Metallic Requirements
For this application, the items in question are typically required to follow API 6A PSL 3. The
manufacturer's written specified requirements for metallic materials for bodies, bonnets, end and outlet
connections, stems, valve bore sealing mechanisms and mandrel hangers shall define the following,
along with accept/reject criteria noting:
― mechanical property requirements
― material qualification
― heat-treatment procedure, including cycle time, quenching practice and temperatures with tolerances
and cooling media
― material composition with tolerances
― non-destructive examination (NDE) requirements
― allowable melting practice(s)
― forming practice(s), including hot-working and cold-working practices, and
― heat-treating equipment calibration
10.5.3 Non-metallic Requirements
Non-metallic pressure-containing or pressure-controlling seals shall have written material specifications.
The manufacturer's written specified requirement for non-metallic materials shall define the following:
― generic base polymer(s); see ASTM D1418
― physical property requirements
― material qualification, which shall meet the equipment class requirement
― storage and age-control requirements
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QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
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10.6 Property Requirements: Pump and Motor Casing
10.6.1 General
The reader is referred to the API Specification 20 series (20B and 20C) for vendor and forging
qualification details with the further requirement for FSL levels 2 and higher. The general guidelines for
other portions of the supply are in keeping with PSL3 as defined in API 6A.
10.6.2 Mechanical Properties
The following apply noting that the pressure casing is treated as a body. Specifically, API 6A clauses
5.4.1 and 5.4.2 apply.
10.6.3 Material Qualification Testing
The reader is referred to the API Specification 20 series (20B and 20C) for vendor and forging
qualification details applying the rules for FSL levels 2 and higher.
10.7 Processing: Pump and Motor Casing
10.7.1 Quenching
The procedures in API 6A clause 5.4.4.3 apply.
10.7.2 Chemical Composition
Material shall conform to the manufacturer's written specification as described in API 6A clause 5.4.5.
10.7.3 Welding
The reader is referred to API 6A Clause 6 and API 17D Clause 5.3 with the provision that the items shall
meet the requirements of PSL 3.
10.8 Manufacturing Quality Control: Pump and Motor Casing
Unless otherwise specified, pressure-casing materials shall be inspected in accordance with the
requirements of Table 11 below (which mimics Table 14 of API 610).
10.9 Non-destructive Examination Personnel
10.9.1 General
Personnel performing NDE shall be qualified in accordance with the manufacturer's documented training
program that is based on the requirements specified in ISO 9712 or ASNT SNT-TC-1A. 7.3.2.
70
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QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
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Table 11 - Inspection Classes as Applied to API 17X
Inspection Class
Type of
Component
I
—
b
Casing : wrought
c
Nozzle weld: casing
Auxiliary connection
d
welds
Internals
Screw tips’
hardened surfaces
a
b
c
d
e
II
III
<0.5 SG
or
> 200 °C (392 °F) and < 0.7 SG,
or
> 260 °C (500 °F)
e
Extremely hazardous services
VI, plus MT or PT (critical areas),
plus UT (critical areas)
VI, plus 100 % MT or
PT plus RT (100 %)
Minimum
>80 % MAWP and > 200 °C
(392 °F)
VI, plus MT or PT of
critical areas
VI, plus MT or PT of critical
areas
VI, plus 100 % MT or PT
VI, plus 100 % MT or PT
VI, plus MT or PT
VI, plus MT or PT
VI, plus MT or PT (100 %)
VI
VI
VI
UT
UT
UT
Definition of abbreviations:
VI: Visual inspection
MT: Magnetic particle inspection
PT: Liquid penetrant inspection
RT: Radiographic inspection
UT: Ultrasonic examination
“Casing” includes all items of the pressure boundary of the finished pump casing (e.g. the casing itself and other parts, such as
nozzles, flanges, etc. attached to the casing). “Critical areas” are inlet nozzle locations, outlet nozzle locations and casing wall
thickness changes. The vendor shall submit details of the critical areas proposed to receive MT/PT/RT/UT inspection for
purchaser's approval.
“Wrought” materials include forgings, plate and tubular products.
Due to complex geometry and thickness variations, it is not practical to RT butt-welded auxiliary casing connections.
Extremely hazardous services, as specified by the purchaser.
10.9.2 Visual Examination Personnel
Personnel performing visual inspection for acceptance shall take and pass an annual vision examination
in accordance with the manufacturer's documented procedures that meet the applicable requirements of
ISO 9712 or ASNT SNT-TC-1A.
10.9.3 Welding Inspectors
Personnel performing visual inspections of welding operations and completed welds shall be qualified and
certified as
― AWS-certified welding inspector
― AWS-senior certified welding inspector
― AWS-certified associate welding inspector, or
― welding inspector certified by the manufacturer's documented training program
71
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DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
72
10.9.4 Other Personnel
All other personnel performing measurements, inspections or tests for acceptance shall be qualified in
accordance with the manufacturer's documented procedures and requirements.
10.9.5 Material Testing
The reader is referred to API 6A clause 7.4.2.3 with the following NDE inspection details as acceptable
alternatives.
10.10 Pump Internals: Materials Considerations
10.10.1
General
This sub-clause is limited to the internals of the pump and motor and treats them as identical similar items
manufactured for surface application. As a result, the general recommendation is to refer to the
appropriated design standard API 610 or API 676. These references are relevant both for:
― Materials specifications
― Materials inspection requirements
To assist with the choice of materials, the purchaser needs to include a complete list of fluids to which the
pump shall be exposed. That list should at least contain:
a) A detailed fluid composition including trace components such as mercury, CO 2, H2S, etc.
― A complete Equation of State characterization should be provided
― A set of reference data in the form of a phase envelope and matching data from petroleum fluid
studies should be provided
b) Expected variation in fluid composition over time as well as appropriately matched turndown
requirements (flows and temperatures at : minimum condition, expected condition, and maximum
conditions).
c) Expected sand and other solids production.
d) Expected extremes in temperatures as a result of start-up procedures.
e) A complete list of production chemicals to which the pump may be exposed.
10.10.2
Rotodynamic Pumps
This group includes centrifugal and helico‑axial pump designs. API 610 provides guidance on materials
related considerations. The manufacturer should provide a materials philosophy document with the
technical proposal.
72
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RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
10.10.3
73
Rotary Pumps
This group includes the subsea application of designs described by API 676 which provides some
guidance on materials related considerations. The manufacturer should provide a materials philosophy
document with the technical proposal.
73
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DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
74
11 Manufacturing, Inspection, and Preparation for Shipment
11.1 General
The purchaser shall specify the extent of his participation in the inspection and testing. Witnessed
Performance tests are required for Subsea pumps.
Examples:
― If shop inspection and testing have been specified, the purchaser and the vendor shall coordinate
manufacturing hold points and inspector’s visits
― The expected dates of testing shall be communicated at least 30 days in advance and the actual
dates confirmed as agreed. Unless otherwise agreed, the vendor shall give at least five working days
advanced notification of a witnessed or observed inspection or test
― For smaller pumps where set-up and test time is short, five to ten business days’ notice may require
the removal of the pump from the test stand between preliminary and witness tests
― All witnessed inspections and tests are hold points. For observed tests, the purchaser should expect
to be in the factory longer than for a witnessed test
― If specified, witnessed mechanical and performance tests shall require a written notification of a
successful preliminary test. The vendor and purchaser shall agree whether or not to maintain the
machine test set-up or whether the machine can be removed from the test stand between the
preliminary and witnessed tests
The vendor shall notify sub-vendors of the purchaser’s inspection and testing requirements.
After advance notification to the vendor by the purchaser, the purchaser’s representative shall have
reasonable access to all vendor and sub-vendor plants where manufacturing, testing or inspection of the
equipment is in progress. The level of access shall be agreed upon.
Equipment, materials and utilities for the specified inspections and tests shall be provided by the vendor.
If specified, the purchaser’s representative, the vendor’s representative, or both, shall indicate compliance
in accordance with an inspector’s checklist such as that provided in Annex E by initialing, dating and
submitting the completed checklist to the purchaser before shipment.
The purchaser’s representative shall have access to the vendor’s quality program for review.
11.2 Inspection and FAT Testing
11.2.1 General
The vendor shall keep the following data available for at least 20 years:
74
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RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
75
― necessary or specified certification of materials, such as mill test reports
― test data and results to verify that the requirements of the specification have been met
― if specified, details of all repairs and records of all heat-treatment performed as part of a repair
procedure
― results of quality control tests and inspections
― as-built running clearances
― other data specified by the purchaser or required by applicable codes and regulations (see 10.3.1 and
10.3.2)
In addition to the requirements of 6.12.1.5, the purchaser may specify the following:
–
–
parts that shall be subjected to surface and subsurface examinations
type of examination required, such as magnetic-particle, liquid-penetrant, radiographic and ultrasonic
examinations
All preliminary running tests and mechanical checks shall be completed by the vendor before the
purchaser’s final inspection.
11.2.2 Additional Test Instrumentation
Subsea pump – motor units shall be equipped with a minimum 5 accelerometers or velocity meters
attached to the outside of the pump and motor casing during FAT or EFAT.
― Two radial in orthogonal directions on the top of the motor casing
― Two radial in orthogonal directions on the bottom of the pump casing
― One axial close to the thrust bearing
11.2.3 Performance Test
Unless otherwise specified, each pump shall be given a submerged performance test.
The following requirements of a) through i) shall be met while the pump is operating on the test stand and
before the performance test is performed.
― The contract seals and bearings shall be used in the pump for the performance test
― The seal (or seals) shall not have a leakage rate during any phase of the pump performance test that
is in excess of that specified in API 682 A.1.3 or as otherwise agreed by the vendor and purchaser.
Any unacceptable leakage during the pump performance test requires a disassembly and repair to
the seal. If the seal is disassembled or removed, the seal shall be retested with an air test of the
pump using the criteria defined in 8.3.3.7 d)
75
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RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
NOTE
76
Subsea pumps typically have a barrier fluid pressure well above the pump pressure in the seal
chambers so any leakage will be barrier fluid into the pumpage, not pumpage into the barrier fluid –
which could cause damage to motor and other components
― If specified, seal leakage during test shall require the assembled pump and seal to be rerun to
demonstrate satisfactory seal performance
― All lubricating-oil pressures, viscosities and temperatures shall be within the range of operating values
recommended in the vendor’s operating instructions for the specified unit being tested
― Bearings specified as normally lubricated from a pure oil-mist system shall be pre-lubricated prior to
performance testing using a suitable hydrocarbon oil
― All joints and connections shall be checked for tightness and any leaks shall be corrected
― All warning, protective and control devices used during the test shall be checked and adjusted as
required
― Unless otherwise agreed, performance tests shall be performed using water at a temperature not
exceeding 55 °C (130 °F). Multi‑phase tests shall be performed with fluids/gases as agreed between
purchaser and vendor
Unless otherwise specified, the performance test including test tolerances and pass criteria for single
phase fluids, shall be conducted as specified in API 610, 676, 685, etc. For multi‑phase fluids, the
performance test shall be conducted as agreed upon by the purchaser and vendor.
While vibration and other data that is not attainable for subsea pumps due to component inavailability or
limitations can often be applied in an FAT environment. Where these measurements are possible,
API 610, 676, and 685 vibration levels and other acceptance criteria shall be used. Vibration limits and
methods of measuring shall be agreed upon between purchaser and vendor. Due to multi‑phase
excitations, compliance with API 610 for helico‑axial pumps is not possible. In any case the acceptance
criteria for conditional monitoring instruments shall be agreed between the purchaser and vendor prior to
the FAT.
During the performance test, the requirements of a) through d) as follows shall be met.
Vibration values shall be recorded at each test point (except shutoff for centrifugal pumps) during the test
in accordance with 6.9.3.2. Vibration values shall not exceed those given in 6.9.3.6.
The requirements of a) through d) as follows shall be met after the performance test is completed.
a) If specified, disassembly of multistage pumps for any head adjustment (including less than 5 %
diameter change) after test, shall be cause for retest.
b) If it is necessary to dismantle a pump for any other correction, such as hydraulic performance, NPSH
or mechanical operation, the initial test shall not be acceptable, and the final performance test shall
be run after the correction is made.
76
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RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
77
c) The use of Test Seal Faces is not allowed.
Unless otherwise specified and in keeping with API 6A, pumps shall not be disassembled after final
performance testing. The pump internals exposed to the pumped fluid shall be drained to the extent
practical, filled with a water-displacing inhibitor within 4 h of testing and redrained. The barrier fluid shall
remain in place.
11.2.4 Optional Tests
Optional tests fall into the category of Application or Project Specific Tests as described in Section 9.
11.2.5 Vibration Requirements
11.2.5.1 General
In general for rotodynamic pumps and motors, the requirements in API 610 Chapter 6.9.3 apply. Some
special requirements for subsea pumps are listed below.
11.2.5.2 Casing Vibration
The overall vibration velocity requirements for subsea rotodynamic pumps and motors operating with
single-phase and multi-phase up to 40 % GVF are shown in Figure 6 below.
Figure 6 - Vibration Limits for Subsea Rotodynamic Pumps and Motors, GVF < 40%
77
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DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
78
The overall vibration velocity requirements for subsea rotodynamic pumps and motors operating with
multi‑phase above 40 % GVF are shown in Figure 7 below.
Figure 7 - Vibration Limits for Subsea Rotodynamic Pumps and Motors, GVF > 40%
NOTE Subsea pump motor units usually incorporate a heavy casing surrounding the pump and motor unit. For
practical and reliability reasons, accelerometers or velocity meters are attached on the outside of the casing. This will
reduce the actual vibration compared to most topside units. The vibration limits listed in API 610 or other standards
intended for topside machinery is not useful as the limits are too high. For this standard, it is suggested to use half the
acceptance levels listed in API 610 for accelerometers or velocity probes attached to the outside of the casing.
The overall vibration requirement is increased by 30% for operation outside the preferred operation
region.
Requirements for discrete frequencies are maximum 0.67 times the overall requirement.
11.2.5.3 Rotor Vibration
When specified, the pump and motor shall be equipped with proximity probes for measuring the rotor
movement during operation. This shall include two radial probes close to each radial bearing in both the
pump and the motor, one axial probe close to the thrust bearing(s) and one probe for rotor speed/once pr.
revolution marker. Pump-motor units were the two rotors are separated by a variable coupling like a
hydrodynamic coupling, shall have separate probes for rotor speed/once pr. revolution marker on each
rotor.
The total mechanical and electrical run-out of the probe target area on the rotor shall be limited to
maximum 20% of the allowable rotor vibration with a maximum of 16 µm Peak – Peak. See Figures 5 and
6.
For subsea pumps and motors operating with single‑phase or multi‑phase up to 40% GVF, the
requirement for maximum rotor vibration is 25% of the actual bearing clearance with a maximum of 65 µm
78
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DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
79
Peak – Peak both for the pump and the motor. In case run-out compensation is used, the overall vibration
requirement is reduced to 19% of the actual bearing clearance with a maximum of 50 µm Peak – Peak.
See Figure 8.
Figure 8 - Rotor Overall Vibration Limits and Maximum Probe Target Run-out for Subsea Pumps
and Motors Operating with Single‑phase or Multi‑phase GVF < 40%
For subsea pumps and motors operating with multi‑phase above 40% GVF, the requirement for
maximum rotor vibration is 35% of the actual bearing clearance with a maximum of 80 µm Peak – Peak
both for the pump and the motor. In case run-out compensation is used, the overall vibration requirement
is reduced to 28% of the actual bearing clearance with a maximum of 65 µm Peak – Peak. See Figure 9.
79
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DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
80
Figure 9 - Rotor Overall Vibration Limits and Maximum Probe Target Run-out for Subsea Pumps
and Motors Operating with Multi‑phase GVF > 40%
NOTE The vibration and run-out requirement based on the actual bearing clearance is chosen in order to avoid
less robust bearing designs with reduced clearances which is aimed to reduce rotor vibration.
The overall vibration requirement is increased by 30% for operation outside the preferred operation
region.
Requirements for discrete frequencies are maximum 0.67 times the overall requirement.
11.3 Preparation for Shipment
Unless otherwise specified, equipment shall be prepared for domestic shipment. Domestic shipment
preparation shall make the equipment suitable for outdoor storage for a period of at least six months with
no disassembly required before operation except possibly inspection of bearings and seals. Preparation
for longer storage or export shipment is more rigorous and, if specified, shall be provided by the vendor
following agreed procedures.
The equipment shall be prepared for shipment after all testing and inspection has been completed and
the equipment has been released by the purchaser. The preparation shall include that specified below 1)
through 9).
a)
Rotors shall be blocked if necessary. Blocked rotors shall be identified by means of corrosionresistant tags attached with stainless steel wire.
b)
Internal surfaces of bearing housings and carbon-steel oil-systems components shall be coated
with an oil-soluble rust preventive that is compatible with the lubricating oil.
80
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DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
81
c)
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, the bags shall be attached in an accessible
area for ease of removal. If applicable, bags shall be installed in wire cages attached to flanged
covers and bag locations shall be indicated by corrosion-resistant tags attached with stainless steel
wire.
d)
Exterior surfaces, except for machined surfaces, shall be given at least one coat of the vendor's
standard paint. The paint shall not contain lead or chromates. It is not necessary to paint stainless
steel parts. If appropriate, the undersides of baseplates shall be prepared for grout in accordance
with API 610 section 7.3.12.
e)
Exterior machined surfaces, except for corrosion-resistant material, shall be coated with a rust
preventive.
f)
Flanged openings shall be provided with metal closures at least 5 mm (0.19 in) thick, with
elastomeric gaskets and at least four full-diameter bolts. For studded openings, all nuts required for
the intended service shall be used to secure closures.
g)
Threaded openings shall be provided with steel caps or steel plugs in accordance with API 610
section 6.4.3.11.
h)
Openings that have been beveled for welding shall be provided with closures designed to prevent
entrance of foreign materials and damage to the bevel.
i)
Exposed shafts and shaft couplings shall be wrapped with waterproof, moldable waxed cloth or
volatile-corrosion inhibitor paper. The seams shall be sealed with oil-proof adhesive tape.
Auxiliary piping connections furnished on the purchased equipment shall be impression-stamped or
permanently tagged to agree with the vendor's connection table or general arrangement drawing. Service
and connection designations shall be indicated.
Lifting points and lifting lugs shall be clearly identified.
The equipment shall be identified with item and serial numbers. Material shipped separately shall be
identified with securely affixed, corrosion-resistant metal tags indicating the item and serial number of the
equipment for which it is intended. Crated equipment shall be shipped with duplicate packing lists, one
inside and one on the outside of the shipping container.
One copy of the vendor's standard installation manual shall be packed and shipped with the equipment.
The vendor shall provide the purchaser with API 686-compliant instructions for the preservation of the
integrity of the storage preparation at the job site and before start-up.
Pump module shall be shipped fully assembled in its support structure.
If it is necessary to ship any major components separately, prior purchaser approval is required.
If appropriate:
81
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RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
― Metal filter elements and screens shall be cleaned and reinstalled prior to shipment.
― Non-metallic filter elements shall be shipped and installed in an unused condition
Suitable rust preventatives shall be oil-soluble and compatible with all pumped liquids.
82
82
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RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
83
12 Vendor’s Data
12.1 General
The information to be supplied shall be in agreement with the intentions of API 610 and API 676 modified
for application to subsea project requirements and practices. Information described in Table XX, shall be
supplied in accordance with the agreed documentation schedule as described during the tendering
process. The documents shall be clearly marked to identify
a) the purchaser’s/owner’s corporate name;
b) the job/project number;
c) the equipment item number and service name;
d) the inquiry or purchaser’s order number;
e) any other identification specified in the inquiry or purchaser order;
f)
the vendor’s identifying proposal number, shop
The table is, in general structured by order of appearance and alphabetically.
Items with an “X” in the first column “Proposal” are required at as a part of the proposal package.
Items with an “X” in the column “Engineering Documentation” are not subject to purchaser review (unless
required by other entries) and are to be stored by the vendor as a part of their engineering documentation
requirement and shall be stored in accordance with industry practice.
Items with an “X” in the column “MRB” shall supplied to the purchaser with the final delivery are subject to
customer review. These shall be stored by both the purchaser and vendor for time periods relevant to the
role.
Items with an “X” in the column “User Manual” shall supplied to the purchaser with the final delivery are
subject to customer review. These shall be stored by both the purchaser and vendor for time periods
relevant to the role.
The final four columns illustrate the need for agreed delivery milestones for the documents.
Items under the row heading of “General” are initially supplied during the proposal phase and are updated
as the project matures. These may be duplicated in other documents.
Items under the row heading of “Verification” are initially supplied during the execution phase and are
updated as the project matures. Portions or summaries of these may be duplicated in the MRB or User
Manuals.
83
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RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
84
Items under the row heading of “Manufacturing Record Book” are initially supplied with the delivered
product and are updated only if the item is modified prior to installation. Portions of these may be
duplicated in other documents.
Items under the row heading of “FAT Specific” are outputs of the testing of the manufactured product and
may be included in both the MRB and User Manual.
Items under the row heading of “User Manual” are to be delivered to the purchaser and describe
installation, use, storage and operation of the pump and ancillary equipment. These are subject to
purchaser approval and mar be subject to updates during the life of the installed item.
Example:
The first item “Barrier fluid/cooling system GA and component drawings” shall be described based on:
–
The vendor’s understanding of the system requirements as based on the tender request
–
Updated to match the final agreement by the time of the system engineering design review
–
Finalized by the end of the project and documented in both the MRB and user manual.
84
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DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
85
Table 12 - Vendor Drawing and Data Requirement List
API 17X
X
X
X
X
GEN.1
X
X
X
X
X
X
X
GEN.2
GEN.3
GEN.4
X
X
X
X
GEN.5
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
GEN.6
GEN.7
GEN.8
GEN.9
GEN.10
GEN.11
GEN.12
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
O
X
X
X
X
O
X
GEN.13
GEN.14
GEN.15
GEN.16
GEN.17
GEN.18
GEN.19
GEN.20
GEN.21
GEN.22
VER.1
VER.2
VER.3
VER.4
VER.5
VER.6
Proposal Acceptance
VDDR Note Reference
Number
User Manual
Manufacturing Record
Book
System Engineering
Design Review/Freeze
Engineering
Documentation
Proposal
FOR SITE SERVICE
OF
DATE
DATE
BY
General
Barrier fluid/cooling system GA & component
drawings
Cause and effect report
Control system and GUI description
Data sheets
Electrical and instrumentation arrangement
drawing and list of connections
Flushing system design
Inspection Plan
List of handling and maintenance tools
List of special tools furnished
Materials specifications and welding procedures
MSDS information on all lubricants,
preservatives, and chemicals
MDR: List of documents, drawings and other
submittals
Nondestructive testing procedures
Performance and current/speed/torque curves
Performance and optional test procedures
Plan, schedule, and progress reports
Scope of supply drawing
Shipping List
Spare parts recommendations
Tabulation of utility requirements
Vibration Analyses and Data
Weight report
Verification
Barrier fluid and cooling system dynamic studies
Control system dynamic studies
Damped unbalanced response analyses
Electrical system response analyses
Lateral critical speed analysis
Thermal expansion
85
Final Supply
DATA REQUIREMENTS
ITEM
DATE
FAT/EFAT
JOB
PURCHASE
ORDER
REQUISITION
INQUIRY
PAGE
REVISION
UNIT
NUMBER
REQUIRED
System Engineering
Design Review/Freeze
SUBSEA PUMPS
VENDOR DRAWING &
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
API 17X
VER.7
MRB.1
MRB.2
MRB.3
MRB.4
MRB.5
MRB.6
MRB.7
MRB.8
MRB.9
MRB.10
MRB.11
MRB.12
MRB.13
MRB.14
MRB.15
MRB.16
FAT.1
FAT.2
FAT.3
FAT.4
Proposal Acceptance
VDDR Note Reference
Number
X
User Manual
System Engineering
Design Review/Freeze
X
Manufacturing Record
Book
Engineering
Documentation
Proposal
FOR SITE SERVICE
OF
DATE
DATE
BY
Torsional critical speed analysis
MRB
As-built clearances
Barrier Fluid / Sealing Fluid drawings,
manufacturing data, and bills of materials
Bearing Assembly drawings, manufacturing data,
and bills of materials
Certified dimensional outline drawing
Certified hydrostatic test data
Certified rotor balance data
Cooler assembly drawing, manufacturing data,
and bills of materials
Coupling assembly drawing, manufacturing data,
and bills of materials
Electrical and instrumentation schematics, wiring
diagrams, and bills of materials
Lubricating oil schematic, manufacturing data,
and bills of materials
Material certificates
Mechanical / Shaft seal drawing and bills of
materials
Primary and auxiliary flushing system
schematics and bills of materials
Rotor assembly drawing, manufacturing data,
and bills of materials
Shaft coupling assembly drawing, manufacturing
data, and bills of materials
Sub assembly dimensional verification
FAT Specific
Noise and vibration data
Residual unbalance check
Rotor mechanical & electrical runout for pumps
with non-contacting vibration probes
Noise and vibration data
86
Final Supply
DATA REQUIREMENTS
ITEM
DATE
FAT/EFAT
JOB
PURCHASE
ORDER
REQUISITION
INQUIRY
PAGE
REVISION
UNIT
NUMBER
REQUIRED
System Engineering
Design Review/Freeze
SUBSEA PUMPS
VENDOR DRAWING &
86
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
API 17X
USE.1
USE.2
USE.3
USE.4
USE.5
USE.6
USE.7
USE.8
Proposal Acceptance
VDDR Note Reference
Number
User Manual
Manufacturing Record
Book
System Engineering
Design Review/Freeze
Engineering
Documentation
Proposal
FOR SITE SERVICE
OF
DATE
DATE
BY
Final Supply
DATA REQUIREMENTS
ITEM
DATE
FAT/EFAT
JOB
PURCHASE
ORDER
REQUISITION
INQUIRY
PAGE
REVISION
UNIT
NUMBER
REQUIRED
System Engineering
Design Review/Freeze
SUBSEA PUMPS
VENDOR DRAWING &
87
User Manual
Allowable flange loadings (can be part of
certified outline drawing)
Cross-sectional drawings and bills of materials
Installation, inspection and retrieval manual
Lifting / running procedures, and relevant data
List of handling and maintenance tools
Operation and maintenance manual
Preservation, packaging, and shipping
procedures
ROV Panel images and drawings
12.2 Details
The entries above are described in more detail in Table 13, which provides guidelines as to the intended
content of each entry.
87
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
Reference
Data Requirement
Vendor Drawing and
Table 13 - Details and Comments to Table 12
Description
General
GEN.1
Barrier fluid/cooling system GA and component drawings
Document shall describe
- pumps
- reservoirs and accumulators
- valves
- tubing
- coolers
GEN.2
Cause and effect report
Document shall describe:
- alarms
- shutdown limits
- operational setpoints
- operational sequencing.
GEN.3
Control system and GUI description
Control system and GUI description
- instrumentation, safety devices, control schemes
- control, alarm and trip settings (pressure and recommended temperatures),
- vibration alarm and shutdown limits,
- bearing temperature alarm and shutdown limits,
- lubricating oil temperature alarm and shutdown limits.
GEN.4
Data sheets
88
88
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
Reference
Data Requirement
Vendor Drawing and
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
Description
Data sheets applicable to proposals, purchase and as-built
Including auxiliary systems, single line, and wiring diagrams
GEN.5
Electrical and instrumentation arrangement drawing and list of connections
GEN.6
Flushing system design
GEN.7
Inspection Plan
GEN.8
List of handling and maintenance tools
GEN.9
List of special tools furnished
GEN.10
Materials specifications and welding procedures
GEN.11
MSDS information on all lubricants, preservatives, and chemicals
GEN.12
MDR: List of documents drawings and submittals
GEN.13
Nondestructive testing procedures
GEN.14
Performance and current/speed/torque curves
For proposal: preliminary or simulated data,
- Average torque versus speed during starting at rated voltage and minimum starting
conditions (voltage and short circuit MVA).
- Current versus speed during starting at rated voltage and minimum starting conditions
(voltage and short circuit MVA).
- The expected moment of inertia of the rotor.
- Estimated times for acceleration at rated voltage and minimum starting conditions (voltage
and short circuit MVA) s.
- The locked-rotor (stalled) withstand time with the motor at ambient temperature and at its
maximum rated operating temperature for rated voltage and minimum starting conditions
89
89
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
Reference
Data Requirement
Vendor Drawing and
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
90
Description
(voltage and short circuit MVA).
- Expected and guaranteed efficiencies.
For final supply,
- Performance test data for both motor alone and pump/motor assembly including:
- certified shop logs of the performance test,
- record of shop test data
For induction motors less than 150 kW (200 hp) , certified test reports for all test run and
performance curves as follows:
- speed-torque curves
- efficiency and power factor curves at one-half, three-quarter, and full load.
For induction motors larger than 150 kW (200 hp) and larger, certified test reports for all test
run and performance curves as follows:
- Time current heating curve
- speed-torque curves at 70%, 80%, 90%, and 100% of rated voltage
- efficiency and power factor curves from 0 to rated service factor
- current vs load curves from 0 to rated service
- current vs speed curves from 0 to 100% of rated speed
For Pump/motor assembly,
- total rotor moment of inertia,
see also separate sections for application specific testing, qualification, or FAT/EFAT
GEN.15
Performance and optional test procedures
GEN.16
Plan, schedule, and progress reports
Progress reports and delivery schedules, including vendor buy-outs and milestones. 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.
GEN.17
Scope of supply drawing
The drawings shall clearly indicate the extent of the system to be supplied by the
manufacturer and the extent to be supplied by others.
90
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
Reference
Data Requirement
Vendor Drawing and
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
GEN.18
Description
Shipping List
Shipping list, including all major components that will ship separately.
GEN.19
Spare parts recommendations
GEN.20
Tabulation of utility requirements
Tabulation of utility requirements including power, coolant, lubricant, chemicals, and heat
loads
GEN.21
Vibration Analyses and Data
For proposal stage: relevant vibration results from previous supply/qualification
For final supply: data from FAT/EFAT/Application Specific Testing
GEN.22
Weight report
The document shall describe the total mass of each item of equipment (motor and auxiliary
equipment) plus loading diagrams, heaviest mass, and name of part
Verification
VER.1
Barrier fluid and cooling system dynamic studies
91
91
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
Reference
Data Requirement
Vendor Drawing and
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
92
Description
The document to cover agreed application specific scenarii:
- steady-state
- transient
Each to include system-wide flow and pressure responses at each use point and agreed
operational transients.
These analyses shall also include steady-state and thermal transient details of the cooler
design.
VER.2
Control system dynamic studies
The document to cover agreed application specific scenarii:
- steady-state
- transient
Each to include system-wide flow and pressure responses at each use point and agreed
operational transients
VER.3
Damped unbalanced response analysis
The analysis reports shall be supplied prior to systems engineering review, no later than 3
months after the date of order.
VER.4
Electrical system response analyses
The document to cover agreed application specific scenarii:
- steady-state
- transient
Each to include system-wide responses at each use point and agreed operational transients
VER.5
Lateral critical speed analysis
92
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
Reference
Data Requirement
Vendor Drawing and
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
Description
The analysis reports shall be supplied prior to systems engineering review, no later than 3
months after the date of order.
VER.6
Pressure casing, piping and thermal expansion evaluations
The document to cover agreed application specific scenarii:
- steady-state pressure containment
- transient pressure responses
- erosion evaluations
- surge, slug, and water-hammer
- piping vibration including hydraulic and chemical tubing
VER.7
Torsional critical speed analysis
The analysis reports shall be supplied prior to systems engineering review, no later than 3
months after the date of order.
Manufacturing Record Book
MRB.1
As-built clearances
MRB.2
Barrier Fluid / Sealing Fluid drawings, manufacturing data, and bills of materials
The document to include:
- primary and auxiliary seal drawings and bills of materials
- seal/barrier fluid, fluid flows, pressure, pipe and valve sizes, instrumentation, and orifice
sizes.
MRB.3
Bearing Assembly drawings, manufacturing data, and bills of materials
93
93
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
Reference
Data Requirement
Vendor Drawing and
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
MRB.4
94
Description
Certified dimensional outline drawing
Certified dimensional outline drawing
- size, location, and purpose of all purchaser connections, including conduit, instrumentation,
and any piping or
ducting;
- ASME rating and facing for any flanged connections;
- size and location of anchor bolt holes and thicknesses of sections through which bolts must
pass;
- total mass of each item of equipment (motor and auxiliary equipment) plus loading
diagrams, heaviest mass,
and name of the part;
- overall dimensions and all horizontal and vertical clearances necessary for dismantling, and
the approximate
location of lifting lugs;
- shaft centreline height;
- shaft end dimensions, plus tolerances for the coupling;
- direction of rotation.
MRB.5
Certified hydrostatic test data
Including pressure plots from body tests
MRB.6
Certified rotor balance data
MRB.7
Cooler assembly drawing, manufacturing data, and bills of materials
MRB.8
Coupling assembly drawing, manufacturing data, and bills of materials
MRB.9
Electrical and instrumentation schematics, wiring diagrams, and bills of materials
94
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
Reference
Data Requirement
Vendor Drawing and
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
Description
MRB.10
Lubricating oil schematic, manufacturing data, and bills of materials
MRB.11
Material certificates
MRB.12
Mechanical / Shaft seal drawing and bills of materials
MRB.13
Primary and auxiliary flushing system schematics and bills of materials
MRB.14
Rotor assembly drawing, manufacturing data, and bills of materials
MRB.15
Shaft coupling assembly drawing, manufacturing data, and bills of materials
MRB.16
General and sub -assembly dimensional verification
General and Sub assembly dimensional verification of
- Rotors/impellers, etc
- Shafts
- Gears
- Seals and seal surfaces
- Bearings and mating surfaces
- Overall dimensions including interfaces
FAT Specific
FAT.1
Noise and vibration data
FAT.2
Residual unbalance check
FAT.3
Rotor mechanical & electrical runout for pumps with noncontacting vibration probes
User Manual
95
95
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
Reference
Data Requirement
Vendor Drawing and
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
96
Description
USE.1
Allowable flange loadings (can be part of certified outline drawing)
USE.2
Cross-sectional drawings and bills of materials
USE.3
Installation, inspection and retrieval manual
USE.4
Lifting / running procedures, and relevant data
Lifting and handling drawings and data including baskets and slings and
including weights, dimensioned general assembly drawings, centres of gravity and details of
lifting lugs
USE.5
List of handling and maintenance tools
USE.6
Operation and maintenance manual
Operation and maintenance manual shall include
- start-up, including tests and checks before start-up,
- operating limits including number of successive attempts to start
- planned and emergency shutdown
- routine operations
- barrier fluid / lubricant recommendations
USE.7
Preservation, packaging, and shipping procedures
USE.8
ROV Panel images and drawings
96
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
97
Annex A
(Normative)
Qualification Testing
A.1
General Procedure for Qualification Testing
The general process is as described by the flowchart below. The testing procedure starts with the
development of a test objective from the pump specification; then continues with the development of an
experimental design within the capabilities of the test facility and test object. Four different sets of tests
are then executed within the chosen experimental design. Each of these tests generates data which are
used to develop the outputs in the test report.
A.2
General Procedure for the Start-up and Shut-down Tests
The primary objectives of this test are to:
–
–
–
Identify any damaging oscillatory torque that occurs during start-up
Confirm that motor is able to make necessary start-up torque for the pump, and
Confirm the dynamic response of the barrier fluid system and mechanical seals to process fluid GVF
fluctuations and temperature changes
Additional start-up and shutdown tests shall be conducted to discover and verify resonant or high
vibration conditions.
(1)
Test Points
This is a dynamic test without a defined steady-state test point. In this transient test, the pump begins at
rest, ramps up to the maximum operating speed, and ramps down to rest.
(2)
Barrier Fluid Temperature
Ambient temperature for test environment as varies during the test.
(3)
Process Fluid Conditions
Run the test under the following process fluid conditions:
–
–
–
–
Minimum flow rate/minimum GVF
Minimum flow rate/maximum GVF
Maximum flow rate/minimum GVF, and
Maximum flow rate/maximum GVF
97
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
(4)
98
Start-up and Shutdown Test Procedure
The tests are detailed below but are generally set up to give combinations based on the following
example:
–
Minimum flowrate at minimum GVF and minimum suction pressure
-
Start-up using minimum ramp-up speed at minimum GVF
ESD Trip from minimum flowrate at minimum GVF
Start-up using maximum ramp-up speed at minimum GVF
Shut-down at minimum ramp-down speed at minimum GVF
Start-up using minimum ramp-up speed at minimum GVF
Shut-down at maximum ramp-down speed at minimum GVF
–
Minimum flowrate at minimum GVF and maximum suction pressure
-
Start-up using maximum ramp-up speed at minimum GVF
Shut-down at minimum ramp-down speed at minimum GVF
Start-up using minimum ramp-up speed at minimum GVF
Shut-down at maximum ramp-down speed at minimum GVF
Table 14 - Suggested Start-up and Shut-down Test Process for Qualification Testing
Scenario
Data Points
Start-stop cycles
Minimum Flowrate @ minimum GVF
Minimum Flowrate @ maximum GVF
Maximum Flowrate @ minimum GVF
Maximum Flowrate @ maximum GVF
Allowable start up ramp rate
20 total
5 Cycles
5 Cycles
5 Cycles
5 Cycles
10 at minimum ramp-up rate
10 at maximum ramp-up rate
4 ESD simulations
8 at maximum ramp-down rate
8 minimum ramp-down rate
10 each
10 each
Shutdown rate
Minimum suction pressure
Maximum suction pressure
98
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
99
The table below lists each parameter for each test.
Table 15 - Suggested Start-up and Shut-down Test Order for Qualification Testing
Cycle #
GVF
Flow Rate
Starting Ramp Rate
Shut Down Rate
Suction Pressure
6
min
max
max
ESD
max
11
max
min
min
ESD
max
16
max
max
max
ESD
max
5
min
min
min
max
max
4
min
min
max
min
max
10
min
max
max
max
max
12
max
min
max
min
max
17
max
max
min
min
max
18
max
max
max
max
max
20
max
max
max
max
max
1
min
min
min
ESD
min
3
min
min
min
max
min
2
min
min
max
min
min
9
min
max
min
min
min
7
min
max
min
min
min
8
min
max
max
max
min
15
max
min
min
max
min
13
max
min
min
max
min
14
max
min
max
min
min
19
max
max
min
min
min
Monitor all variables specified in section 3.1. This test will create variations in torque, speed, barrier fluid
pressure, process fluid pressure, and vibration levels that must be analyzed for signs of system damage.
Produce Bode plots for each cycle.
A.3
Normal Performance Qualification
(1)
Qualification Objective
The primary goals of this test are to determine the performance map and vibration behavior of a new
design:
–
–
–
Determine the system performance at steady-state
Confirm the predicted performance map at steady-state, and
Confirm the operating region with respect to pre-defined vibration limits (Section 9.3)
99
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
(2)
100
Normal Performance Test Points
Qualification tests are performed at multiple combinations of the key variables for pump performance:
–
–
–
–
–
Set speed
Flowrate
Suction pressure
Differential pressure, and
GVF
In the case of application specific tests, the choice of data points near the Best Efficiency Point(s) (BEP)
or design point(s), may be specified in the contract between vendor and purchaser.
(3)
Barrier Fluid Temperature
Ambient temperature for test environment as varies during the test.
(4)
Process Fluid Conditions
Set temperature and GVF at design point(s) according to range for qualification of system.
(5)
Normal Performance Qualification Test Procedure
Operate the system at the specified set point(s) until the following conditions are met:
–
–
–
Inlet and discharge pressure variations achieve steady state and are less than +/- 5 bar or 5 %
(whichever is smaller)
Process and barrier fluid temperatures reach their steady state values and vary by no more than
+/- 5%
GVF within 5 % of desired value (if not in intermittent flow regime)
Qualification Test Duration:
No less than one hour of additional operation after thermal and pressure
equilibria are established according to the criteria above.
Monitor all variables specified in section 9.2.2.
A.4
Liquid Slugging Tolerance
(1)
Objective
The qualification test is aimed at the minimum scope pump system and is aimed at evaluating its
tolerance to GVF variations. This test is aimed at verifying the slug tolerance of the pump sub-system.
The dynamics of the responses will also qualify the dynamic response of the barrier fluid system to
process pressure changes. The test qualifies the combination of the following:
–
The pump control system
100
THIS
DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED
API RECOMMENDED PRACTICE 17X
–
–
–
101
The barrier fluid system
The capacity of (any) pump sumps
Any other directly associated equipment
The test is therefore aimed at confirming that the test system responds adequately to liquid slugs and gas
pockets. Because extensive field modelling and dynamic simulation results are required to predict a
worst-case scenario for the size of GVF fluctuations and the duration of time in which these changes can
occur this qualification test may be relatively generic. Because of the test infrastructure needs,
distinctions between application specific and qualification testing will be defined by each application
project and the chosen “system-of-systems” level slug mitigation technologies.
(2)
Slugging Tolerance Test Point
This dynamic test does not have a fixed test point. The pump system shall begin operating near the BEP
p and flowrate for a given GVF and remain within the operational envelope while responding to changing
process conditions.
(3)
Barrier Fluid Temperature
Ambient temperature for test environment as varies during the test.
(4)
Process Fluid Conditions
Process fluid conditions vary, as specified by the agreed test conditions. GVF begins near the design
point and vary to simulate liquid slugs and gas pockets according to worst-case scenario predictions or
agreed criteria.
(5)
General Slugging Tolerance Test Procedure
Operate the system near BEP at a GVF near the design point. Vary the process conditions and allow the
pump system to respond to keep operation within the allowable envelope. Again, the parameters of this
test are highly reservoir and field dependent and a choice of test procedure will require detailed
evaluation of the target market for the pump.
A.5
Extended Performance Qualification
(1)
Objective
This test demonstrates design robustness and simulates an extended duration of operation by going
through several cycles and operating near the edge of the envelope with barrier fluid at maximum
temperature.
101
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QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
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(2)
102
Extended Performance Test Points
This set of test points must be repeated for the entire range of process variables claimed by the pump
vendor. For example, if a pump can run with GVF from 40 % to 60 %, the test points shall be run at the
upper and lower GVF values. Continuing with that example, the number of GVF values to be run between
the upper and lower limits shall be agreed on by all parties prior to testing.
Test point 1
Speed: midpoint (at the minimum flowrate)/Flowrate: minimum/p: midpoint.
Test point 2
Speed: midpoint (at the maximum flowrate)/Flowrate: maximum/p: midpoint.
Test point 3
Speed: maximum/Flowrate: maximum/p: maximum (at the given flowrate).
Test point 4
Speed: minimum/Flowrate: minimum/p: minimum.
Test point 5
Speed: minimum/Flowrate: maximum (at the minimum speed)/p: minimum.
Test point 6
Speed: maximum/Flowrate: minimum/p: maximum (at the given flowrate).
Test point 7
Speed: maximum (at the maximum power)/Flowrate: midpoint (furthest point from surge and stonewall)/
p: maximum (at the max power).
Figure 10 indicates where each test point lands on the operational envelope. The seven test points shall
be repeated over the entire range of GVF values for multi‑phase pumps.
102
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API RECOMMENDED PRACTICE 17X
Figure 10 - Location of Test Points on the Operational Envelope
(3)
Barrier Fluid Temperature
For this test, the barrier fluid shall be at pit temperature as it varies during the test.
(4)
Process Fluid Conditions
For this test, the process fluids shall be at maximum temperature and GVF.
103
103
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QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
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(5)
104
Extended Performance Qualification Test Procedure
Table 16 - Suggested Extended Performance Test Process for Qualification Testing
Scenario
1.
Hot/Cold Start:
2.
10 Cycles Set I
3.
Test Point Extended
Performance Set I
4.
Hot/Cold Start
Repetition
5.
10 Cycles Set II
6.
Test Point Extended
Performance Set II
7.
30 Cycles:
8.
Test Point Extended
Performance Set III
Procedure
Duration/Cumulative Run time
Start up the pump at ambient temperature
and the process fluid at maximum
temperature.
Start up and shutdown the pump ten times
including a minimum of five emergency
stops.
Run each of the 7 chosen test points for
equal amounts of time
Run each test point for equal amounts
of time for 10 hours qualification giving
100 hours cumulative test time
~15 hours per point
100 hours cumulative
Start up the pump at ambient temperature
and the process fluid at maximum
temperature.
Start up and shutdown the pump ten times
including a minimum of five emergency
stops.
Run each of the 7 chosen test points for
equal amounts of time
~15 hours per point
100 hours cumulative
Start up and shutdown the pump 30 times
including a minimum of five emergency
stops.
Run each of the 7 chosen test points for
equal amounts of time
~30 hours per point
200 hours cumulative
For items 3, 6, and 8, operate the system at the specified set points until the steady-state conditions are met as
described in section A.1.3.5 above:
No less than fifteen minutes of additional operation are required once the temperatures and pressures are constant.
104
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QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
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API RECOMMENDED PRACTICE 17X
105
Annex B
(Normative)
Application Specific Testing
B.1
Start-Up and Shutdown Test
(1)
Start-up and Shutdown Test Objective
The primary objectives of this test are to:
–
–
–
Identify any damaging oscillatory torque that occurs during start-up
Confirm that motor is able to make necessary start-up torque for the pump, and
Confirm the dynamic response of the barrier fluid system and mechanical seals to process fluid GVF
fluctuations and temperature changes
Additional start-up and shutdown tests shall be conducted to discover and verify resonant or high
vibration conditions.
(2)
Start-up Shutdown Test Points
This is a dynamic test without a defined steady-state test point. In this transient test, the pump begins at
rest, ramps up to the maximum operating speed, and ramps down to rest.
(3)
Barrier Fluid Temperature
Ambient temperature for test environment as varies during the test.
(4)
Process Fluid Conditions
Run the test under the following process fluid conditions:
–
–
–
–
Minimum flow rate/minimum GVF
Minimum flow rate/maximum GVF
Maximum flow rate/minimum GVF, and
Maximum flow rate/maximum GVF
105
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QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
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API RECOMMENDED PRACTICE 17X
(5)
106
Start-up and Shutdown Test Procedure
Table 17 - Suggested Start-up and Shut-down Test Process for Application Specific Testing
Scenario
Data Points
Start-stop cycles
Minimum Flowrate @ minimum GVF
Minimum Flowrate @ maximum GVF
Maximum Flowrate @ minimum GVF
Maximum Flowrate @ maximum GVF
Allowable start up ramp rate
Shutdown rate
Minimum suction pressure
Maximum suction pressure
8 total
2 Cycles
2 Cycles
2 Cycles
2 Cycles
4 at minimum ramp-up rate
4 at maximum ramp-up rate
2 ESD simulations
3 at maximum ramp-down rate
3 minimum ramp-down rate
4 each
4 each
The table below lists each parameter for each test.
Table 18 - Suggested Start-up and Shut-down Test Order for Application Specific Testing
Cycle #
GVF
Flow Rate
Starting Ramp Rate
Shut Down Rate
Suction Pressure
1
2
3
4
5
6
7
8
min
min
min
min
max
max
max
max
min
min
max
max
min
min
max
max
min
max
min
max
min
max
min
max
ESD
min
max
min
ESD
max
min
max
min
min
min
max
max
max
min
min
Monitor all variables specified in section 9.2.2. This test will create variations in torque, speed, barrier fluid
pressure, process fluid pressure, and vibration levels that must be analyzed for signs of system damage.
Produce Bode plots for each cycle.
B.2
Test of Normal Performance
(1)
Test Objective
The primary goals of the application specific tests at normal operating conditions test are the confirmation
that the desired performance is met by the design:
–
–
–
Confirm that the system meets the required performance objective
Confirm the predicted performance map at steady-state, and
Confirm that the desired performance is within pre-defined vibration limits (Section 9.3)
106
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QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
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(2)
107
Normal Performance Test Points
Application specific tests are performed at multiple combinations of the key variables for pump
performance:
–
–
–
–
–
Set speed
Flowrate
Suction pressure
Differential pressure, and
GVF
In the case of application specific tests, the choice of data points near the BEP or design point(s), may be
specified in the contract between pump supplier and operator.
(3)
Normal Performance Test Procedure
Operate the system at the specified set point(s) until the following conditions are met:
–
–
–
Inlet and discharge pressure variations achieve steady state and are less than +/- 5 bar or 5 %
(whichever is smaller)
Process and barrier fluid temperatures reach their steady state values and vary by no more than
+/-5 %, and
GVF within 5 % of desired value (if not in intermittent flow regime)
Test Duration: No less than one hour of additional operation after thermal and pressure equilibria are
established according to the criteria above.
Monitor all variables specified in section 9.2.2.
B.3
Liquid Slugging Mitigation
(1)
Test Objective
Confirm that the system responds adequately to liquid slugs and gas pockets. Extensive field modelling
and dynamic simulation results are required to predict a worst-case scenario for the size of GVF
fluctuations and the duration of time in which these changes can occur. The qualification test is aimed at
the minimum scope pump system and is aimed at evaluating its tolerance to GVF variations. The
dynamics of the responses are also required to qualify the dynamic response of the barrier fluid system to
process pressure changes. Because of the infrastructure needs, distinctions between application specific
and qualification testing shall be determined by each project and the chosen “system-of-systems” level
slug mitigation technologies.
The test may include equipment that is designed to mitigate any effects of slugs or other flow variations.
This can be simulated, if agreed between vendor and purchaser. This test does not include the
qualification or application specific testing of process or flow conditioning equipment.
107
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QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
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(2)
108
Slug Mitigation Test Point
This dynamic test does not have a fixed test point. The pump system shall begin operating near the BEP
p and flowrate for a given GVF and remain within the operational envelope while responding to changing
process conditions.
(3)
Barrier Fluid Temperature
Ambient temperature for test environment as varies during the test.
(4)
Process Fluid Conditions
Process fluid conditions vary, as specified by the operator, for specific field conditions. GVF begins near
the design point and vary to simulate liquid slugs and gas pockets according to worst-case scenario
predictions or agreed criteria.
(5)
General Slug Mitigation Test Procedure
Operate the system near BEP at a GVF near the design point. Vary the process conditions and allow the
pump system to respond to keep operation within the allowable envelope.
As with the qualification test, the parameters of this test are highly reservoir and field dependent.
Distinctions between application specific testing and the acceptance of this qualification test will be
determined by each project and the chosen system level slug mitigation technologies.
B.4
Extended Performance (Optional)
(1)
Application Specific Test Objective
This test demonstrates design robustness and simulates an extended duration of operation by going
through several cycles and operating near the edge of the envelope with barrier fluid at test environment
temperature.
(2)
Extended Performance Test Points
This set of test points must be repeated for the entire range of GVF values claimed by the pump vendor.
For example, if a pump can run with GVF from 40 % to 60 %, the test points must be run at the upper and
lower GVF values. The number of GVF values to be run between the upper and lower limits must be
agreed on by all parties prior to testing.
Test point 1
Speed: midpoint (at the minimum flowrate)/Flowrate: minimum/p: midpoint.
Test point 2
108
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109
Speed: midpoint (at the maximum flowrate)/Flowrate: maximum/p: midpoint.
Test point 3
Speed: maximum/Flowrate: maximum/p: maximum (at the given flowrate).
Test point 4
Speed: minimum/Flowrate: minimum/p: minimum.
Test point 5
Speed: minimum/Flowrate: maximum (at the minimum speed)/p: minimum.
Test point 6
Speed: maximum/Flowrate: minimum/p: maximum (at the given flowrate).
Test point 7
Speed: maximum (at the maximum power)/Flowrate: midpoint (furthest point from surge and stonewall)/
p: maximum (at the max power).
Figure 9 indicates where each test point lands on the operational envelope. The seven test points shall be
repeated over the entire range of GVF values for multi‑phase pumps.
(3)
Barrier Fluid Temperature
For this test, the barrier fluid shall be at pit temperature as it varies during the test.
(4)
Process Fluid Conditions
For this test, the process fluids shall be at maximum temperature and GVF.
109
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QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
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(5)
110
Performance Application Specific Test Procedure
Table 19 - Suggested Extended Performance Test Process for Application Specific Testing
Scenario
1.
Hot/Cold Start:
2.
10 Cycles Set I
3.
Test Point Extended
Performance Set I
4.
Hot/Cold Start Repetition
5.
10 Cycles Set II
6.
Test Point Extended
Performance Set II
30 Cycles:
7.
8.
Test Point Extended
Performance Set III
Procedure
Start up the pump at ambient
temperature and the process fluid at
maximum temperature.
Start up and shutdown the pump ten
times including a minimum of five
emergency stops.
Run each of the 7 chosen test points
for equal amounts of time
Start up the pump at ambient
temperature and the process fluid at
maximum temperature.
Start up and shutdown the pump ten
times including a minimum of five
emergency stops.
Run each of the 7 chosen test points
for equal amounts of time
Start up and shutdown the pump 30
times including a minimum of five
emergency stops.
Run each of the 7 chosen test points
for equal amounts of time
Duration/Cumulative Run time
Run each test point for equal amounts
of time for ~7 hours testing giving 50
hours cumulative test time
~7 hours per point
50 hours cumulative
~7 hours per point 50 hours cumulative
~15 hours per point
100 hours cumulative
For items 3, 6, and 8, operate the system at the specified set points until the steady-state conditions are met as
described in section A.1.3.5 above:
No less than fifteen minutes of additional operation are required once the temperatures and pressures are constant.
110
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QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
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Annex C
(Informative)
Pump Design Data Sheets
This annex contains typical datasheets for use by the purchaser in communication with the vendor.
111
111
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QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE
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Project:
Date:
Page: ___ of ___
General Design Requirements (SI Units)
Description
Input Value
Application Description
Application Site
Geographic Location
Application Service
Application Type
Pump Count
Design Life
Design Conditions
Design Pressure, bar
Design Temperature, oC
Ambient Conditions
Water Depth, m (Mean Sea Level reference)
Water Temperature, oC
Seawater Salinity, kg/kg
Minimum Current, m/s
System Documents
P&ID
Layout
Cause and Effect
HMI Requirements
Material Standard
Material Class (AA-HH)
Forging Specification Level (FSL-2, -3 or -4)
Product Specification Level (PSL -3, -3G or -4)
Bolt Specification Level (BSL-2 or -3)
Piping Geometry
Inlet Diameter, mm
Inlet Elevation, m
Inlet Orientation
Inlet Connector
Discharge Diameter, mm
Discharge Elevation, m
Discharge Orientation
Discharge Connector
Coating Requirements
Relevant Standard
Weight/Size Limitations
Weight, metric tonnes
Envelope Dimensions, WxLxH (m)
Testing Requirements
Application/Contract Specific Performance Testing
Factory Acceptance Testing
Site Integration Testing
112
Reference Number
112
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Date:
Project:
113
Page: ___ of ___
Operating Data (SI Units)
Description
Minimum
Flow
Capacity Requirement
Oil Rate (Standard Conditions), Sm3/d
Oil Rate (Pump Inlet Conditions), m3/d
Gas Rate (Standard Conditions), MSm3/d
Gas Rate (Pump Inlet Conditions), m3/d
Water Rate (Standard Conditions), Sm 3/d
Water Rate (Pump Inlet Conditions), m3/d
Production Profile (attach data)
Operating Inlet Pressure, bara
Operating Discharge Pressure, bara
Operating Inlet Temperature, oC
Phase Data at Pump Inlet
Oil Density, kg/m3
Oil Viscosity, cP
Oil Heat Capacity, kJ/(kg K)
Gas Density, kg/m3
Gas Viscosity, cP
Gas Heat Capacity, kJ/(kg K)
Produced Water Density, kg/m3
Produced Water Viscosity, cP
Produced Water Heat Capacity, kJ/(kg K)
Produced Water Salinity
Emulsion Viscosity
Sand Data
Sand Rate at Steady-State, kg/d
Sand Size at Steady-State, m
Sand Rate at Upset Conditions, kg/d
Sand Size at Upset Conditions, m
Period for Upset Condition, hours
Hydrate Potential
Attach Curve
Wax Behavior
Wax Appearance Temperature, oC
Pour Point, oC
Production Chemicals
Hydrate Inhibitor(s), l/d
Scale Inhibitor(s), l/d
Scale Squeeze Philosophy (attach)
Asphaltene Inhibitor(s), l/d
Wax Inhibitor(s), l/d
Others
113
Expected
Maximum
Flow
Attachment
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Date:
Project:
114
Page: ___ of ___
Fluid Description (SI Units)
Description
Input Value
Reference Number
Stock Tank Oil Properties, (Single Stage Flash)
Density, kg/m3
Viscosity, cP
Gas Properties (Single Stage Flash)
Molecular weight or specific gravity
Viscosity, cP
Saturation Point
Pressure, bara
Temperature, oC
Phase Envelope (attach)
Single Stage Flash Results
Gas-Oil-Ratio/Condensate Gas Ratio, Sm3/Sm3
Trace Components
Mercury
Other
Recombined Fluid, Gas, Oil Compositions
Separator Reference Temperature, oC
Separator Reference Pressure, bara
Separator Gas-Oil Ratio, Sm3/Sm3
Component
Gas
Mol Percent
Oil
Mol Percent
Recombined
Mol Percent
H2S
N2
CO2
CH4
C2H6
C3H8
i-C4H10
n-C4H10
i-C5H10
n-C5H10
Hexanes
Heptanes
Octanes
Nonanes
Decanes
Decanes +
Undecanes
Dodecanes
Tridecanes
Tetradecanes
Pentadecanes
Hexadecanes
Heptadecanes
Octadecanes
Nonadecanes
Eicosanes +
Molecular wt
114
Specific Gravity
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Date:
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Formation Water Composition (SI Units)
Total Dissolved Solids
pH
Ion
Ion mol wt
Charge Range
H+
1.00798
+1
Na+
22.9898
+1
K+
39.0983
+1
Mg
24.305
+1 to +2
Ca++
39.0983
+1 to +2
Ba++
137.327
+1 to +2
Mnn+
54.9381
+1 to +7
++
Si
n+
28.085
+4 to +4
Srn+
87.62
+1 to +2
Crn+
51.9961
+4 to +6
Fen+
55.845
+4 to +6
Znn+
65.38
+2 to +2
OH
17.007
-1
Cl-
35.453
-1
HCO3-
61.106
-1
SO42-
96.0618
-2
CO32-
76.0972
-2
-
sum
115
mg/l
115
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Motor Design Requirements (SI Units)
Description
Input
Power System
Distance to Host Facility
Line Frequency at Source
Short-Circuit Capacity at Source (MVA)
Phase Current at Source (A)
Line Voltage at Source (kV)
Cooler Design
Design Case Current
Seawater Salinity
Design Case Fouling Factor, m2∙K/kW
Interface Requirements
Power Connection
Instrumentation Requirements
Motor Temperature
Motor Torque
Motor Bearing Temperature
Key Phasor
Cooler Inlet Pressure
Cooler Inlet Temperature
Cooler Inlet Pressure
Cooler Inlet Temperature
Coolant Flowmeter
Testing Requirements
Full Speed/Full Load
Full Speed/No Load
Locked Rotor
Hydro-Test with Internals
Gas Test if Relevant
116
Appendix Number
116
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Pump Instrumentation Requirements (SI Units)
Description
Input Value
Communication System
Distance to Host Facility
Communication and Control Interface
Communication Bandwidth
Communication Standard
SEM Interface
Instrumentation Requirements
Accelerometer
Acoustic Sensors
Leakage Detection
Bearing Temperature
Radial Proximity Probes
Axial Proximity Probes
Pump Inlet Pressure
Pump Inlet Temperature
Pump Discharge Pressure
Pump Discharge Temperature
Pump Inlet Bulk Rate
Pump Inlet GVF
117
Reference Number
117
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Pump and Motor Mechanical Design Outputs (SI Units)
Description
Output Value
Pump Ratings
Pump Type
Rated Pressure, bara
Maximum Differential Pressure, barg
Rated Temperature, oC
Rated Capacity at BEP, m3/d
Rated Volumetric Efficiency at BEP, %
Required Power at Rated Condition, MW
Required Power at Pressure Limiting Rate, MW
Maximum Allowable Speed, rpm
Performance Curves
Coupling
Type
Piping Geometry
Materials
Inlet Diameter, mm
Inlet Interface/Connector
(SI Units)
Discharge Diameter, mm
Discharge Interface/Connector
System Dimensions
Weight, metric tonnes
Envelope Dimensions, WxLxH (m)
Handling
Tool Part Number or Padeye Rating
Transport Skid Part Number
118
Reference Number
118
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RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
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Pump Design Outputs (SI Units)
Description
Output Value
Pump Casing
Rated Pressure, bara
Rated Temperature, oC
Hydrostatic Test Pressure, barg
Casing Materials
Bolting Materials
Coating Materials
Motor Casing
Rated Pressure, bara
Rated Temperature, oC
Hydrostatic Test Pressure, barg
Casing Materials
Bolting Materials
Coating Materials
Piping
Coating Materials
Inner Barrel/Liner
Material
Coating Description
Hydrostatic Test Pressure, barg
Casing Materials
Bolting Materials
Rotor/Impeller/Bearing/Gears/Shaft
Rotor/Impeller Description
Rotor/Impeller Material
Rotor/Impeller Coating
Rotor/Impeller Mounting
Rotor/Impeller Diameter, mm
Rotor/Impeller Length, mm
Rotor/Impeller Clearance, mm
Shaft Diameter at Rotor/Impeller, mm
Shaft Diameter at Coupling/Drive-End, mm
Shaft Diameter at non-Drive-End, mm
Shaft Material
Timing Gear Standard
Timing Gear Pitch/Line Diameter, mm
Timing Gear Material
Radial Bearing Count
Radial Bearing Type
Thrust Bearing Type
Thrust Bearing Material
Mechanical Seals
119
Reference Number
119
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Pump Instrumentation Outputs (SI Units)
Description
Output Value
Reference Number
Interface
Communication Standard
Electrical Connector
Pump Instrumentation
Accelerometer
Acoustic Sensors
Leakage Detection
Bearing Temperature
Radial Proximity Probes
Axial Proximity Probes
Pump Inlet Pressure
Pump Inlet Temperature
Pump Discharge Pressure
Pump Discharge Temperature
Pump Inlet Bulk Rate
Pump Inlet GVF
Barrier Fluid/Lubrication System Design Outputs (SI Units)
Description
Output Value
Lubricant/Barrier Fluid
Expected Normal Rate, l/d
Maximum Allowed Rate, l/d
Fluid Type
Fluid Density, kg/m3
Fluid Viscosity, cP
Fluid Classification/MSDS
Barrier Fluid/Lubricant System
Rated Pressure, bara
Instrumentation
Controls Interface
Piping/Tubing Materials
Piping/Tubing Interface Details
Piping/Tubing Coating Requirements
Piping/Tubing Coating Details
120
Reference Number
120
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Motor Design Outputs (SI Units)
Description
Output Value
Motor
Type
Rated Power, MW
Rated Speed, rpm
Rated Voltage, kV
Voltage Range, kV
Insulation Class
Frequency Range, Hz
Number of Poles
Number of Phases
Minimum Starting Voltage, V
Full Load Current, A
Locked Rotor Current, A
Motor Efficiency, %
Motor Cooler
Coolant Circulation Rate, l/h
Duty, MW
Area, m2
Materials
U-Value Used in Design, W/(m2∙K)
Coating Requirements
Coating Details
Interface
Power Connection
Instrumentation
Motor Temperature
Motor Torque
Motor Bearing Temperature
Key Phasor
Proximity Probes
Cooler Inlet Pressure
Cooler Inlet Temperature
Cooler Inlet Pressure
Cooler Inlet Temperature
Coolant Flowmeter
121
Reference Number
121
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DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
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General Design Requirements (USC Units)
Description
Input Value
Application Description
Application Site
Geographic Location
Application Service
Application Type
Pump Count
Design Life
Design Conditions
Design Pressure, psia
Design Temperature, oF
Ambient Conditions
Water Depth, m (Mean Sea Level reference)
Water Temperature, oF
Seawater Salinity, lbm/lbm
Minimum Current, ft/s
System Documents
P&ID
Layout
Cause and Effect
HMI Requirements
Material Standard
Material Class (AA-HH)
Forging Specification Level (FSL-2, -3 or -4)
Product Specification Level (PSL -3, -3G or -4)
Bolt Specification Level (BSL-2 or -3)
Piping Geometry
Inlet Diameter, in
Inlet Elevation, ft
Inlet Orientation
Inlet Connector
Discharge Diameter, in
Discharge Elevation, ft
Discharge Orientation
Discharge Connector
Coating Requirements
Relevant Standard
Weight/Size Limitations
Weight, tons
Envelope Dimensions, WxLxH (ft)
Testing Requirements
Application/Contract Specific Performance Testing
Factory Acceptance Testing
Site Integration Testing
122
Reference Number
122
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DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
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Operating Data (USC Units)
Description
Minimum
Flow
Capacity Requirement
Oil Rate (Standard Conditions), stb/d
Oil Rate (Pump Inlet Conditions), bbl/d
Gas Rate (Standard Conditions), mmscfd
Gas Rate (Pump Inlet Conditions), ft3/d
Water Rate (Standard Conditions), stb/d
Water Rate (Pump Inlet Conditions), bbl/d
Production Profile (attach data)
Operating Inlet Pressure, psia
Operating Discharge Pressure, psia
Operating Inlet Temperature, oF
Phase Data at Pump Inlet
Oil Density, lbm/ft3
Oil Viscosity, cP
Oil Heat Capacity, BTU/(lbm∙R)
Gas Density, lbm/ft3
Gas Viscosity, cP
Gas Heat Capacity, BTU/(lbm∙R)
Produced Water Density, lbm/ft3
Produced Water Viscosity, cP
Produced Water Heat Capacity, BTU/(lbm∙R)
Produced Water Salinity
Emulsion Viscosity
Sand Data
Sand Rate at Steady-State, lbm/d
Sand Size at Steady-State, m
Sand Rate at Upset Conditions, lbm/d
Sand Size at Upset Conditions, m
Period for Upset Condition, hours
Hydrate Potential
Attach Curve
Wax Behavior
Wax Appearance Temperature, oF
Pour Point, oF
Production Chemicals
Hydrate Inhibitor(s), gpm
Scale Inhibitor(s), gpm
Scale Squeeze Philosophy (attach)
Asphaltene Inhibitor(s), gpm
Wax Inhibitor(s), gpm
Others
123
Expected
Maximum
Flow
Attachment
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Fluid Description (USC Units)
Description
Input Value
Reference Number
Stock Tank Oil Properties, (Single Stage Flash)
Density, lbm/ft3
Viscosity, cP
Gas Properties (Single Stage Flash)
Molecular weight or specific gravity
Viscosity, cP
Saturation Point
Pressure, psia
Temperature, oF
Phase Envelope (attach)
Single Stage Flash Results
Gas-Oil-Ratio/Condensate Gas Ratio, scf/STB or STB/mmscf
Trace Components
Mercury
Other
Recombined Fluid, Gas, Oil Compositions
Separator Reference Temperature, oF
Separator Reference Pressure, psia
Separator Gas-Oil Ratio, scf/STB
Component
Gas
Mol Percent
Oil
Mol Percent
Recombined
Mol Percent
H2S
N2
CO2
CH4
C2H6
C3H8
i-C4H10
n-C4H10
i-C5H10
n-C5H10
Hexanes
Heptanes
Octanes
Nonanes
Decanes
Decanes +
Undecanes
Dodecanes
Tridecanes
Tetradecanes
Pentadecanes
Hexadecanes
Heptadecanes
Octadecanes
Nonadecanes
Eicosanes +
Molecular wt
124
Specific Gravity
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Formation Water Composition (USC Units)
Total Dissolved Solids
pH
Ion
Ion mol wt
Charge Range
+
H
1.00798
+1
Na+
22.9898
+1
K+
39.0983
+1
Mg++
24.305
+1 to +2
++
Ca
39.0983
+1 to +2
Ba++
137.327
+1 to +2
Mnn+
54.9381
+1 to +7
Sin+
28.085
+4 to +4
Sr
87.62
+1 to +2
Crn+
51.9961
+4 to +6
Fen+
55.845
+4 to +6
Znn+
65.38
+2 to +2
OH-
17.007
-1
n+
Cl
-
35.453
-1
HCO3-
61.106
-1
SO42-
96.0618
-2
CO32-
76.0972
-2
sum
125
mg/l
125
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Motor Design Requirements (USC Units)
Description
Input
Power System
Distance to Host Facility
Line Frequency at Source
Short-Circuit Capacity at Source (MVA)
Phase Current at Source (A)
Line Voltage at Source (kV)
Cooler Design
Design Case Current
Seawater Salinity
Design Case Fouling Factor, hr∙ft2∙R/BTU
Interface Requirements
Power Connection
Instrumentation Requirements
Motor Temperature
Motor Torque
Motor Bearing Temperature
Key Phasor
Cooler Inlet Pressure
Cooler Inlet Temperature
Cooler Inlet Pressure
Cooler Inlet Temperature
Coolant Flowmeter
Testing Requirements
Full Speed/Full Load
Full Speed/No Load
Locked Rotor
Hydro-Test with Internals
Gas Test if Relevant
126
Appendix Number
126
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Pump Instrumentation Requirements (USC Units)
Description
Input Value
Communication System
Distance to Host Facility
Communication and Control Interface
Communication Bandwidth
Communication Standard
SEM Interface
Instrumentation Requirements
Accelerometer
Acoustic Sensors
Leakage Detection
Bearing Temperature
Radial Proximity Probes
Axial Proximity Probes
Pump Inlet Pressure
Pump Inlet Temperature
Pump Discharge Pressure
Pump Discharge Temperature
Pump Inlet Bulk Rate
Pump Inlet GVF
127
Reference Number
127
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DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
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Pump and Motor Mechanical Design Outputs (USC Units)
Description
Output Value
Pump Ratings
Pump Type
Rated Pressure, psia
Maximum Differential Pressure, psig
Rated Temperature, oF
Rated Capacity at BEP, bbl/d
Rated Volumetric Efficiency at BEP, %
Required Power at Rated Condition, MW
Required Power at Pressure Limiting Rate, MW
Maximum Allowable Speed, rpm
Performance Curves
Coupling
Type
Piping Geometry
Materials
Inlet Diameter, in
Inlet Interface/Connector
Discharge Diameter, in
Discharge Interface/Connector
System Dimensions
Weight, tons
Envelope Dimensions, WxLxH (ft)
Handling
Tool Part Number or Padeye Rating
Transport Skid Part Number
128
Reference Number
128
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RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR
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Pump Design Outputs (USC Units)
Description
Output Value
Pump Casing
Rated Pressure, psia
Rated Temperature, oC
Hydrostatic Test Pressure, psig
Casing Materials
Bolting Materials
Coating Materials
Motor Casing
Rated Pressure, psia
Rated Temperature, oF
Hydrostatic Test Pressure, psig
Casing Materials
Bolting Materials
Coating Materials
Piping
Coating Materials
Inner Barrel/Liner
Material
Coating Description
Hydrostatic Test Pressure, psig
Casing Materials
Bolting Materials
Rotor/Impeller/Bearing/Gears/Shaft
Rotor/Impeller Description
Rotor/Impeller Material
Rotor/Impeller Coating
Rotor/Impeller Mounting
Rotor/Impeller Diameter, in
Rotor/Impeller Length, in
Rotor/Impeller Clearance, in
Shaft Diameter at Rotor/Impeller, in
Shaft Diameter at Coupling/Drive-End, in
Shaft Diameter at non-Drive-End, in
Shaft Material
Timing Gear Standard
Timing Gear Pitch/Line Diameter, in
Timing Gear Material
Radial Bearing Count
Radial Bearing Type
Thrust Bearing Type
Thrust Bearing Material
Mechanical Seals
129
Reference Number
129
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DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT
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Pump Instrumentation Outputs (USC Units)
Description
Output Value
Reference Number
Interface
Communication Standard
Electrical Connector
Pump Instrumentation
Accelerometer
Acoustic Sensors
Leakage Detection
Bearing Temperature
Radial Proximity Probes
Axial Proximity Probes
Pump Inlet Pressure
Pump Inlet Temperature
Pump Discharge Pressure
Pump Discharge Temperature
Pump Inlet Bulk Rate
Pump Inlet GVF
Barrier Fluid/Lubrication System Design Outputs (USC Units)
Description
Output Value
Lubricant/Barrier Fluid
Expected Normal Rate, gpm
Maximum Allowed Rate, gpm
Fluid Type
Fluid Density, lbm/ft3
Fluid Viscosity, cP
Fluid Classification/MSDS
Barrier Fluid/Lubricant System
Rated Pressure, psia
Instrumentation
Controls Interface
Piping/Tubing Materials
Piping/Tubing Interface Details
Piping/Tubing Coating Requirements
Piping/Tubing Coating Details
130
Reference Number
130
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Motor Design Outputs (USC Units)
Description
Output Value
Motor
Type
Rated Power, MW
Rated Speed, rpm
Rated Voltage, kV
Voltage Range, kV
Insulation Class
Frequency Range, Hz
Number of Poles
Number of Phases
Minimum Starting Voltage, V
Full Load Current, A
Locked Rotor Current, A
Motor Efficiency, %
Motor Cooler
Coolant Circulation Rate, gpm
Duty, MW
Area, ft2
Materials
U-Value Used in Design, BTU/(hr∙ ft2 ∙R)
Coating Requirements
Coating Details
Interface
Power Connection
Instrumentation
Motor Temperature
Motor Torque
Motor Bearing Temperature
Key Phasor
Proximity Probes
Cooler Inlet Pressure
Cooler Inlet Temperature
Cooler Inlet Pressure
Cooler Inlet Temperature
Coolant Flowmeter
131
Reference Number
131
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Bibliography
[1]
Gűlich, Johann Friedrich, Centrifugal Pumps, Second Edition, Springer-Verlag,2010
132
132
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