Recommended Practice for Subsea Pump Module...

Recommended Practice for Subsea Pump Module Systems API RECOMMENDED PRACTICE 17X FIRST EDITION, XXXX2018

BALLOT DRAFT MAY 2018

API RECOMMENDED PRACTICE 17X ii

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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.

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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Generally, API standards are reviewed and revised, reaffirmed, or withdrawn at least every five years.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].

mailto:[email protected]

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Contents

1 Scope ............................................................................................................................................... 1

2 Normative References ..................................................................................................................... 2

3 Terms, Definitions, and Abbreviations ............................................................................................. 3 3.1 Terms and Definitions ...................................................................................................................... 3 3.2 Acronyms and Abbreviations ........................................................................................................... 7

4 Systems and Interface Descriptions .............................................................................................. 10 4.1 System Configuration ..................................................................................................................... 10 4.2 Classification and Designation ....................................................................................................... 11

5 Design ............................................................................................................................................ 13 5.1 General Design Requirements ....................................................................................................... 13 5.2 Pump Types ................................................................................................................................... 14 5.3 Pressure Casings ........................................................................................................................... 15 5.4 Mechanical Shaft Seals.................................................................................................................. 16 5.5 Rotor Dynamics .............................................................................................................................. 17 5.6 Motor .............................................................................................................................................. 18 5.7 Bearing and Bearing Design .......................................................................................................... 22 5.8 Motor Cooling Systems .................................................................................................................. 22

6 Pump Control, Protection, and Monitoring Systems ...................................................................... 23 6.1 General........................................................................................................................................... 23 6.2 Functional Requirements for Control Systems .............................................................................. 23 6.3 Functional Requirements for Monitoring Systems ......................................................................... 23

7 Pump Module Packaging ............................................................................................................... 25 7.1 Pump Module ................................................................................................................................. 25 7.2 Module and Infrastructure Rated Pressure .................................................................................... 25 7.3 Pressure-limiting and Recycle Valves ............................................................................................ 26 7.4 Umbilical Interfaces ........................................................................................................................ 26

8 Installation and Intervention ........................................................................................................... 28 8.1 Flushing Facilities for Retrieval ...................................................................................................... 28 8.2 Transportation and Testing Equipment .......................................................................................... 29 8.3 Special Tools .................................................................................................................................. 30

9 Performance Testing ...................................................................................................................... 31 9.1 Qualification and Requalification .................................................................................................... 31 9.2 Test Scope ..................................................................................................................................... 33 9.3 Individual Tests Requirements ....................................................................................................... 35 9.4 Test Acceptance Criteria ................................................................................................................ 36 9.5 Factory Acceptance Testing .......................................................................................................... 39 9.6 System integration testing .............................................................................................................. 41

10 Materials and Materials Inspection ................................................................................................ 42 10.1 Pump Module Structure and Piping ............................................................................................... 42 10.2 Pump and Motor Casing Specifications ......................................................................................... 42 10.3 Manufacturing Quality Control: Pump and Motor Casing .............................................................. 43 10.4 Nondestructive Examination .......................................................................................................... 43

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10.5 Pump Internals―Materials ............................................................................................................. 44

11 Manufacturing, Inspection, and Preparation for Shipment............................................................. 45 11.1 General........................................................................................................................................... 45 11.2 Inspection ....................................................................................................................................... 46 11.3 Preservation and Storage Procedures ........................................................................................... 46

12 Manufacturer’s Data and Marking .................................................................................................. 48 12.1 General........................................................................................................................................... 48 12.2 Marking........................................................................................................................................... 50

Annex A ....................................................................................................................................................... 53

Pump Design Data Sheets .......................................................................................................................... 53

Annex B ....................................................................................................................................................... 74

Qualification Testing .................................................................................................................................... 74

Annex C....................................................................................................................................................... 80

Application Specific Testing ........................................................................................................................ 80

Annex D....................................................................................................................................................... 86

Pump Manufacturing Data Check List and Schedule ................................................................................. 86

Bibliography ................................................................................................................................................ 99

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List of Figures: Figure 1―Subsea Pump System ................................................................................................................ 11 Figure 2―Decision Aid for identifying need to qualify/requalify .................................................................. 32 Figure 3―Decision Tree for Testing ........................................................................................................... 33 Figure 4: Vibration limits for GVF < 40% in a rotodynamic pump with hydrodynamic bearings ................ 36 Figure 5: Vibration limits for GVF > 40% in a rotodynamic pump with hydrodynamic bearings ................ 37 Figure 6: Illustration of recommended placement for proximity probes during testing .............................. 38

List of Tables: Table 1―Pump Classification Type Identification....................................................................................... 11 Table 2―Insulation Thermal Classes used for Subsea Motors.................................................................. 20 Table 3―Typical SUTA Components ......................................................................................................... 27 Table 4―Pre-accepted Configuration Changes ......................................................................................... 31 Table 5―Scope of Test Object ................................................................................................................... 34 Table 6: Bollting Requirement .................................................................................................................... 42 Table 7―Inspection Classes as Applicable to API 17X ............................................................................. 44 Table 8―Classification by Installation Depth.............................................................................................. 50 Table 9―Classification by Sea Water Temperature ................................................................................... 51 Table 10―Classification by Process Fluid Temperature (Expanded from API 6A).................................... 51 Table 11―Casing Rated Pressure Class ................................................................................................... 51 Table 12 - Manufacturer Drawing and Data Requirement List ................................................................... 86 Table 13―Details and Comments to Table 12 ........................................................................................... 89

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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 manufacturer 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 manufacturer identify any variations from this Standard and provide details.

A bullet (•) at the beginning of a section or sub-section 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.

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 1

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1 Scope

This recommended practice provides recommendations for the design, manufacture and installation of subsea pumps, including rotary displacement and rotodynamic types for single phase, and multi‑phase services. The recommended practice applies to all subsea pump systems placed at or above the mud line.



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2 Normative 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.

API Specification 6A, Specification for Wellhead and Christmas Tree Equipment, Twentieth Edition, October 2010, Addendum 4, March 2016.

API Specification 17D, Design and Operation of Subsea Production Systems—Subsea Wellhead and Tree Equipment, Second Edition, May 2011, Addendum 1, September 2015.

API Standard 17F, Standard for Subsea Production Control Systems

API Recommended Practice 17H, Recommended Practice for Remotely Operated Tools and Interfaces on Subsea Production Systems

API Recommended Practice 17P, Design and Operation of Subsea Production Systems—Subsea Structures and Manifolds

API Standard 541, Form-wound Squirrel Cage Induction Motors—375 kW (500 Horsepower) and Larger,

API Standard 547, General-purpose Form-wound Squirrel Cage Induction Motors-185 kW (250 hp) through 2240 kW (3000hp)

API Standard 610, Centrifugal Pumps for Petroleum, Petrochemical and Natural Gas Industries, Eleventh Edition, September 2010, Errata July 2011

ASTM D1418 - 10a(2016)1, Standard Practice for Rubber and Rubber Latices—Nomenclature

HI2 9.6.7 Rotodynamic Pumps - Guideline for Effects of Liquid Viscosity on Performance

IEC 600853, Electrical insulation - Thermal evaluation and designation

IEC/IEEE 61886-1: Subsea equipment - Power connectors, penetrators and jumper assemblies with rated voltage from 3 kV (Umax = 3,6 kV) to 30 kV (Umax = 36 kV) (Under Development)

ISO 14224:2016, Petroleum, petrochemical and natural gas industries. Collection and exchange of reliability and maintenance data for equipment

ISO/TR 17766, Centrifugal pumps handling viscous liquids — Performance corrections

NEMA MG 1-20144, Motors and Generators

1 American Society for Testing and Materials, 100 Barr Harbor Dr., P.O. Box C700, West Conshocken, PA, 19428-2959 USA, www.astm.org 2 Hydraulic Institute, 6 Campus Drive, First Floor North, Parsippany, NJ 07054, USA, pumps.org 3 International Electrotechnical Commission, 3, rue de Varembé, Case postale 131, CH-1211, Geneva, Switzerland, www.iec.org. 4 National Electrical Manufacturers Association, 1300 North 17th St. Ste 900, Arlington VA 22209, USA, www.nema.org



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3 Terms, Definitions, and Abbreviations

3.1 Terms and Definitions

For the purposes of this document, the following terms and definitions apply.

allowable operating envelope Portion of a pump's hydraulic coverage over which the pump can operate, based on vibration within the upper limit of this recommended practice or temperature rise or other limitation, specified by the manufacturer

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.

forging specification level FSL Term used to describe a method for determining testing and documentation levels required to reduce risk associated with manufacturing quality

average gas volume fraction GVF Time average ratio of volume of gas to that of the total volume of the fluid (oil, water, and gas) at pump suction temperature and pressure, the fraction being expressed as a percentage

NOTE: GVF represents the long-term (hours or longer) average value of GVFi and corresponds to the expected steady-state value.

average water-cut WC Time average (over longer periods of time: hours or longer) ratio of the water volume to total liquid volume at pump suction

NOTE The ratio being expressed as a percentage.

closure bolting Bolting used to assemble or join pressure-containing parts, including end and outlet connections



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NOTE Examples of closure bolting include flange bolting, bonnet bolting, end connection bolting, and hub clamp bolting.

instantaneous gas volume fraction GVFi Instantaneous ratio of volume of gas to total volume of the fluid (oil, water, and gas) at pump suction temperature and pressure, the fraction being expressed as a percentage with a value over shorter periods of time (less than one minute)

NOTE 1 GVFi represents the variability in GVF where the long-term average value of GVFi corresponds to the expected steady-state value, GVF.

NOTE 2 GVFi may, because of multiphase flow behavior, hold-up, transient operations, and start-up and shut-down effects, vary between 0 and 100%.

instantaneous water-cut WCi Instantaneous ratio of the volume of water to total liquid volume of the fluid (oil and water) at pump suction temperature and pressure, the fraction being expressed as a percentage with the value over shorter periods of time (less than one minute)

NOTE The ratio being expressed as a percentage.

low-voltage (LV) Rated voltages up to 1.8/3 (3.6) kV (AC) for use in subsea applications.

manufacturer Organization supplying a device meeting the requirements of this document

maximum allowable dynamic pressure MADP Maximum transient pressure for which the manufacturer has designed the pump (or any part to which the term is referred) when pumping the specified liquid at the specified maximum operating temperature

maximum allowable working pressure MAWP Maximum continuous pressure for which the manufacturer has designed the pump (or any part to which the term is referred) when pumping the specified liquid at the specified maximum operating temperature



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medium-voltage (MV) Rated voltages above 1.8/3 (3.6) kV (AC) and up to 18/30 (36) kV (AC) for use in subsea applications.

multi-phase pump Pump designed for continuous operation at GVFi > 5% and < 95%

net positive suction head required NPSH3 Net positive suction head that results in a 3 % loss of head (first-stage head in a multistage pump) determined by the vendor by testing with water

normal wear part Part normally restored or replaced at each pump overhaul

preferred operating envelope Optimum range of parameters in which operations will result in ideal, continuous equipment performance

pressure casings Pressure and liquid containing vessels which encapsulate the pump and motor

pressure-controlling bolting Bolting used to assemble or join pressure-controlling part(s)

pressure-retaining bolting Bolting used to assemble or join pressure-retaining parts whose failure would result in a release of wellbore fluid to the environment

purchaser Identified end-user or target end-users for which the device is intended.

NOTE In the case of qualification testing, this may be a specific project customer or it may be a consortium aimed at generic testing.



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rated speed Highest speed (revolutions per minute) that the pump requires of any of the operating conditions and at which rated power is developed

rotodynamic pump Kinetic machine in which energy is continuously imparted to the pumped fluid by means of a rotating impeller, propeller or rotor

NOTE 1 This includes centrifugal and helicoaxial pumps

NOTE 2 This excludes positive displacement pumps.

single-phase pump Pump designed for continuous operation at GVFi ≤ 10%

special tool Tool required for installation, maintenance and removal equipment not considered part of the finished product

NOTE Some special tools may be rental tools.

surge Compressor term for a condition defining minimum stable flowrate at given tip speed and head which is characterized by vibration, performance and/or efficiency losses

technology readiness level TRL See API 17N

utility bolting All bolting that is required to mount equipment and accessories to the pump and ancillary equipment that is not closure bolting, pressure retaining, or pressure controlling NOTE Examples include bolting on lifting eyes, pad eyes (non-welded), nameplate, clamps for tubing, and guards.



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3.2 Acronyms and Abbreviations

For the purposes of this document, the following acronyms and abbreviations apply. ANSI American National Standards Institute API American Petroleum Institute ASME American Society of Mechanical Engineers ASTM American Society for Testing and Materials Au amplitude of displacement AWS American Welding Society bbl barrel BEP best efficiency point BF barrier fluid BSL bolting specification level BTU British Thermal Unit CFD computational fluid dynamics CRA corrosion resistant alloy DNV Det Norske Veritas EFAT extended factory acceptance test EMF electromagnetic field ESP electrical submersible pump ESD emergency shutdown ESS emergency safety system FAT factory acceptance test FEA finite element analysis FFT fast Fourier transform FSL forging specification level GA general assembly drawing GVF [average] gas volume fraction



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GVFi instantaneous gas volume fraction HI Hydraulics Institute HPU hydraulic power unit Hz hertz ID inner diameter IEC International Electrotechnical Commission IEEE Institute of Electrical and Electronics Engineers ISO International Organization for Standardization kV kilo Volt LV low voltage MADP maximum allowable dynamic pressure MAWP maximum allowable working pressure mmscfd million standard cubic feet per day MPP multiphase pump MRB manufacturing record book MSDS material safety data sheet MT magnetic particle test MV middle [medium] voltage MVA million Volt-Amps MW mega Watt NDE nondestructive examination NEMA National Electrical Manufacturers Association NORSOK Norsk Sokkel Konkuranseposisjon NPSH net positive suction head NPSH3 net positive suction head at 3 % head loss NPSHA net positive suction head available P&ID process and instrumentation diagram



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PSD process shutdown PSL product specification level PT [liquid] penetrant testing RAM reliability and maintenance ROV remotely operated vehicle RP recommended practice RT radiographic testing SCM subsea control module SEM subsea electronics module SEPS Subsea Electrical Power Standardization SI Systeme International (d’unites) SP SIT system integration test STB stock tank barrel STI subsea termination interface SURF subsea umbilicals, risers and flowlines SUTA subsea umbilical termination assembly TIR total indicator runout TRL technology readiness level TUTA topsides umbilical termination assembly UNS unified numbering system USC United States customary units UT ultrasonic testing UTA umbilical termination assembly VFD variable frequency drive VSD variable speed drive VT visual inspection



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WC [average] water-cut WCi instantaneous water-cut WLR water liquid ratio XLPE crosslinked polyethylene

4 Systems and Interface Descriptions

4.1 System Configuration

Figure 1 provides an overview of the subsea pump configuration covered by this document. The labelled items are directly covered in this document. Other portions of Figure 1 are included for reference. Reference is also made to API 610, API 674, API 675, API 676, API 682, and API 685 for the various components that may be incorporated into subsea pump systems.

− Subsea pumps (including ESP applications at or above the mud line)

− Motors for subsea pumps

− Minimum requirements for relevant auxiliaries (power, control, barrier fluids and lubricants)

− The packaging of the pumps in a module (interfaces, lifting requirements, barrier philosophy, etc.)

The standard does not describe items not labeled in Figure 1, temporary equipment, or ESP applications. Equipment selection, pump station layout and design are project specific and are subject to separate design criteria.



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Figure 1―Subsea Pump System (Note this is a placeholder figure and subject to change)

4.2 Classification and Designation

Description of Codes The pumps described in this recommended practice are classified and designated by type codes, as shown in Table 1.

Table 1―Pump Classification Type Identification

Subsea Pump Type Working Principle

Rotary Displacement

Vane

Lobe

Gear

Multi-Screw

Rotodynamic

Centrifugal

Helicoaxial

Combined Centrifugal and Helicoaxial



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Pump Designations and Descriptions Pumps listed in Table 1 of this recommended practice can be correlated to the corresponding sections of API 610 and API 676. Despite 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 refer to such standards for further descriptions.



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5 Design

5.1 General Design Requirements The design of the equipment shall ensure the following:

− Equipment, including all auxiliaries, shall be designed for subsea installation and the specified site environmental conditions as specified in the Pump Design Data Sheets (Annex C).

− Materials for the pump module internal components shall be compatible with production fluids and chemicals in accordance with the Pump Design Data Sheets (Annex C).

− External materials shall be compatible with seawater and a cathodic protection system.

− External components which are enclosed (e.g., with insulation) shall be compatible with internal production fluids, chemicals, seawater and the cathodic protection systems in accordance with the Pump Design Data Sheets (Annex A).

− Equipment, including all auxiliaries, shall be designed for the operating conditions, production profiles, the fluid properties, site conditions and utility requirements shall be specified, including all data shown on the Pump Design Data Sheets (Annex A).

− The motor power rating, excluding the service factor (if any) shall not be less than the maximum power of all specified conditions. The motor rating should include a margin of 10% of the maximum pump power.

− The pump and motor unit shall be capable of operating at 105% of rated speed.

− The pump and the pump system including motor and the associated barrier fluid system (if any) shall be designed to tolerate any transient condition including emergency shut down and power failure.

− The pump system shall be capable of starting from cold restart conditions if filled with process fluid, as defined by the Pump Design Data Sheets (Annex A).

− The pump system shall be capable of starting after a long-term standstill if preserved, as defined by the Pump Design Data Sheets (Annex A).

− The equipment shall be capable of operating within the entire performance map, at all specified operating conditions, as well as accommodating other conditions such as momentary surge, settle-out, trip, and start-up.

− For single phase flow, the calculated preferred operating envelope shall be identified in accordance with API 610. For multi-phase flow, the calculated preferred operating envelope shall be upon agreement as defined by the Pump Design Data Sheets (Annex A).

NOTE 1 The key parameters of the operating envelope are minimum speed, maximum speed, surge, choke, and maximum power for a give GVF and suction pressure. NOTE 2 Multiple envelopes are required to cover the identified inlet GVF and suction pressures.

− The pump module system shall be compatible with the hydrate and other flow assurance related strategies employed within the application.



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− Unless otherwise specified by the end-user, the equipment (including auxiliaries) covered by this recommended practice shall be designed and constructed for a minimum service life of 20 years (excluding normal wear parts).

Additionally, the design should ensure that the equipment be able of sustaining a minimum of 40,000 hours of cumulative run time within a 5-year period, including 250 starts and stops.

NOTE 3 The 40,000 hours is based on a 90% target availability in five years.

− The erosion velocity methods described in API 14E do not provide sufficient detail for the evaluation of erosion potential within a pump and shall not be used for that purpose.

NOTE 4: In the known presence of sand, API 14E recommends that the pipe velocity limits should be “significantly reduced” below the calculated values. Within the pump, this reduction may not be feasible.

5.2 Pump Types

Design Classes The pumps described in this recommended practice are classified as shown in Table 1 and are divided into two dissimilar design classes, rotodynamic and rotary positive displacement. For both types, the fundamental sizing and rating criteria shall be derived from inputs as listed in Annex A.

The pump thrust bearing and thrust balancing system shall accommodate uneven flow and phase distributions which are typically not an issue with rotary positive displacement pump.

Pumps and auxiliaries shall minimally be designed to tolerate or mitigate occasional upset operation at 100 % GVF at the pump inlet over a time period described by a controlled shutdown from rated speed.

NOTE 1 Unstable flow regimes, gas-filled well start-up conditions or gas-filled pump conditions are to be expected.

NOTE 2 Mechanical seals can experience significant temperature and pressure deviations when operating near 100 % GVF.

The pump control system shall include automated logic to ensure operation within the stated safe operation limits.

A recycle control system should be implemented as protection against unstable flow regimes.

NOTE 3 Rotary positive displacement pumps are not subject to surge caused by pump performance.

NOTE 4 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 should be avoided.

Viscosity Correction CFD analyses or test data shall be used for viscosity corrections.

NOTE Centrifugal pumps that handle single-phase fluids, more viscous than water, may have their water performance corrected per ISO 17766 (HI 9.6.7).



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Correction factors used for viscous single-phase liquids should be submitted with the pump curves (pump curves should be corrected to specified fluids).

In all cases, appropriate data on fluid viscosity changes resulting from temperature change, phase transitions, wax gelation and emulsions, and non-Newtonian behavior shall be provided.

If correction methods are unavailable, physical testing shall be performed using a fluid with similar rheological properties.

For multistage pumps, performance predictions shall take into account interstage heating (including slippage) which can significantly impact performance for high viscosity fluids.

Rotodynamic Pumps The GVF at the pump suction demonstrated for the pump design shall include the specified GVFi ranges.

Stable head/flowrate curves (continuous head rise to shutoff) should be used.

For parallel operation, stable head/flowrate curves (continuous head rise to shutoff) shall be used and the head rise from rated point to shutoff should be at least 10 %.

The NPSH margin shall not be less than 1.5 meters (4.6 ft.) of liquid for all operating points within the preferred operating region.

The proposal shall include pump curves with

− the preferred operating range on the pump curves; and

− the NPSH3 curve as evaluated.

NOTE 1: API 610, Section 6 requires pumps to have a preferred operating region of 70 % to 120 % of best efficiency flow rate. For subsea pumps, this requirement may prove difficult to meet as a result of changing flow and pressure requirements.

NOTE 2: NPSHA, NPSH3 and NPSH margin and associated API 610 requirements are not relevant when GVF is greater than zero.

The minimum flow (both thermal and steady state) and any limitations of operation shall be shown on the proposal and shall indicate

− The surge and choke limits with regards to speeds, GVFi, suction pressures and actual flowrates.

− Safe operation limits including the necessary separation margins.

5.3 Pressure Casings

General



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The casing and other pressure-retaining parts and supports shall be designed to prevent detrimental distortion caused by the worst combination of temperature, pressure (including test pressure), torque, and allowable external forces and moments based on the specified operating conditions.

NOTE 1: The motor and pump pressure casing can be bolted together as one single pressure container.

NOTE 2 The purchaser and manufacturer may agree to allow for small threaded holes for test ports, drainage and venting to be used during the assembly and test period.

Casing Seals Due to the size of the interfaces, elastomeric seals may be preferred.

Clearances and Wear Radial running clearances shall be used to limit internal leakage and, where necessary, balance axial thrust. Impeller pumping vanes or close axial clearances shall not be used to balance axial thrust. Renewable wear rings shall be provided in the pump casing. Impellers shall have either integral wear surfaces or renewable wear rings.

Mating wear surfaces of hardenable materials shall have a difference in Brinell hardness number of at least 50 unless both the stationary and the rotating wear surfaces have Brinell hardness numbers of at least 400.

Renewable wear rings, if used, shall be held in place by a press fit with locking pins, screws (axial or radial) or by tack welding. The diameter of a hole in a wear ring for a radial pin or threaded dowel shall not be more than one-third the width of the wear ring.

When establishing internal running clearances between wear rings and other moving parts, consideration shall be given to pumping temperatures, suction conditions, the liquid properties, the thermal expansion and galling characteristics of the materials, and pump efficiency. Clearances shall be sufficient to assure dependability of operation and freedom from seizure under all specified operating conditions.

NOTE: Multi‑phase pumps that operate with less fluid support to the rotor from the wear rings and throttle bushings or dry running may require additional clearances.

5.4 Mechanical Shaft Seals

Seals in subsea applications shall be used exclusively to isolate the process fluid 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.

Thermal expansion differences between the casing and pump internals should be included when designing internal sealing clearances between the casing and internal pump parts.

NOTE 1 Because of high heat transfer rates to the surrounding seawater, subsea pump casings will be exposed to large, transient 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.



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The pressure rating of the mechanical seal gland between the barrier and process fluids shall be agreed between the manufacturer and purchaser.

The mechanical seal rotating sleeve shall be mechanically locked in both torsion and axial directions.

The mechanical seal shall be designed for both rotation directions.

NOTE 2 Subsea seals are engineered for a specific function and therefore other industry standards (e.g., API 682) do not apply.

An analysis of transient cases, including resulting barrier fluid system responses, shall be completed as inputs to the choice of mechanical seal (See Annex A).

The maximum mechanical seal leakage at the specified operating conditions should be stated in the proposal and final documentation.

NOTE 3 This information determines the rate of barrier or buffer fluid usage and thus the sizing of HPU.

In dual seal applications, the maximum seal leakage shall be stated both towards the process and away from it.

Mechanical seals shall be tested at the following conditions:

− at minimum and maximum differential pressures,

− maximum temperature

− for transient conditions such as emergency shut-down or reverse pressure, and

− using liquid and gas at the process side.

5.5 Rotor Dynamics

Rotor Dynamic Analyses The following shall apply:

− For pump/motor units with a rigid coupling connecting the motor and pump shaft, rotor dynamic analyses shall be performed for the combined motor and pump rotor.

− For liquid-filled motors, the effect of liquids in the rotor-stator gap shall be included in the analyses.

− For liquid-filled magnetic couplings, the effect of liquids in the rotor-stator gap between the coupling halves shall be included in the analyses.

− Evaluation and acceptance criteria shall be agreed between the manufacturer and end-user.



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NOTE 1 Because the rotors of twin screw and small slow speed pumps are designed to have a first dry-bending critical speed at least 20 % above the pump's maximum continuous operating speed, then the rotor dynamic analysis is not required.

NOTE 2 When selecting bearings, for multi‑phase pumps, damping properties may have priority over stiffness properties. This may be achieved by larger bearings, reduced preload etc.

NOTE 3 The liquid present in the rotor–stator gap may cause a significant negative stiffness, a positive damping and a large added mass which makes the rotor dynamic behavior very different from that of an air-filled motor.

5.6 Motor

Electro-Magnetic Design The rotor in induction motors shall be designed per either API 541 or API 547 and the following apply.

− For variable frequency driven motors, the performance requirements shall be met throughout the frequency range and match the characteristics of the specified drive-system.

− The minimum breakdown torque shall be no less than 160% of the rated torque.

− At the defined operating frequency and maximum 80% of the rated voltage, the minimum locked rotor torque (cold start conditions) and maximum 80% of the rated voltage should be minimum 1.1 times the pump unit breakaway torque (stiction torque) for all pump conditions.

− At maximum 80% of the defined starting voltage and the line frequency, the minimum pull-up torque (cold start conditions) shall exceed the maximum load torque with a safety factor of 1.1, including starting with the maximum specified pump fluid viscosity.

− Harmonic torques shall be included if the safety factor against the load torque is less than 10% of the load torque.

− Due to the variations in temperature between the cold condition and maximum operating temperatures, the effect of variations in rotor resistance shall be included in system evaluations.

− For variable-frequency electric motor starting (VSD start), the start-up procedure (e.g. maximum acceleration rate and idling speed, waiting time between start attempts, etc. shall be provided

− For variable frequency driven or started induction motors with rolling bearings, current through the bearings shall be interrupted or diverted in accordance with NEMA MG 1-2014. a means shall be provided to interrupt current thru the bearings or otherwise divert current around the bearings in accordance with NEMA MG 1-2014. This bearing bypass shall be verified during the motor FAT.



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NOTE 1 Motors can be designed for either fixed frequency or variable frequency drives depending on pump application.

NOTE 2 Motors operated with a VFD have a risk of bearing damage due to common mode (zero sequence) harmonic voltage present in the driving voltage waveform. This common mode voltage oscillates at high frequency and is capacitively coupled to the rotor. This results in voltage pulses from shaft to ground, which can take a path through either or both bearings, thus causing damage. This is not expected to be an issue for permanent magnet motors.

Motor Mechanical Design For liquid-filled motors:

− the rotor/stator gap shall be optimized to achieve good balance between overall efficiency and motor performance.

− The rotor - stator eccentricity shall be limited to maximum 0.25 mm (0.01 in.).

− The rotor-stator gap shall be effectively cooled.

NOTE 1 Rotors for liquid filled motors are usually designed with a small rotor diameter and increased rotor length to reduce gap friction. This complicates the design because highly destabilizing forces (negative stiffness) increase with reduced gaps as result of dynamic flows in the gap liquid combined with magnetic pull.

Motor rotors shall be dynamically balanced in a minimum of two planes. The stator lamination pack shall be compressed to avoid vibration between the individual laminations.

All metal parts that may come into contact with windings shall have smooth surfaces and be deburred with defined radii on corners.

All significant natural frequencies of the stator housing and laminations shall (throughout the motor operation range with a margin of 15%) be outside the range of the following:

− rotor bar passing frequency,

− rotor magnet excitation frequency

− slot harmonics

− VSD harmonics

NOTE 2 Modes which are in resonance with any motor excitation frequency, may be allowed if they can be proven to be well damped.

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 2. The maximum continuous operation temperature of the winding should be limited to one class below the thermal class of the insulation system to ensure durability of the insulation.



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Table 2―Insulation Thermal Classes used for Subsea Motors

Thermal class (IEC60085)

Previous letter designation

Maximum hotspot winding temperature

90 Y 90 oC (194 oF) 105 A 105 oC (221 oF) 120 E 120 oC (248 oF) 130 B 130 oC (266 oF) 155 F 155 oC (311 oF) 180 H 180 oC (356 oF)

NOTE 3: 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 higher than 40 °C (104 oF), limitin the motor performance if the API 541 requirement is applied for a class H insulation.

The ambient temperature for subsea motors is defined by the sea-water temperature class per 12.2 noting that correction to 40 °C (104 oF) ambient temperature is not required. The coolant medium temperature is determined by Manufacturer and is based on media properties, motor thermal losses, circulation rates, ambient temperatures, ambient currents, cooler design data and other thermal contributors.

Thermal analysis shall be performed, using validated models, to define the thermal class and to determine optimum locations for temperature sensors within the windings.

Excursions to higher temperatures during transient conditions should be limited in duration to ensure adequate insulation life (service factor>1.0). Maximum hotspot winding temperatures shall not exceed thermal class 180 oC. IEC thermal class 120 o C should not be utilized.

NOTE 4 XLPE may be added as an acceptable cable insulation material.

Power and Instrumentation For cable wound motors, in lieu of winding temperature detectors, confirmation of analytic temperature calculated in the windings shall be obtained during type-testing.

NOTE: Embedded temperature detector readings are affected by conduction along the sensor path. The sensor cables themselves affect the flowpath and the cooling of the motor. This interaction creates uncertainty in the measurement results.

During project execution, Manufacturer should 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

The motor power penetrators, subsea jumper assemblies, and wet-mate connectors shall be designed in accordance with IEC/IEEE 61886-1 (formerly SEPS SP-1001).

Shaft Couplings



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Couplings between motors and driven equipment shall be supplied and mounted by Manufacturer.

Rigid (non-flexible) couplings may be used for subsea pump – motor units.

NOTE 1 Unlike topside pumps, alignment is typically maintained in subsea pumps using rabbet fits.

NOTE 2 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.

NOTE 3 Torque couplings may be used to provide a mechanical speed control of the pump. The use of torque or magnetic couplings may influence the pressure test strategy for the pump and motor combination.

When spline couplings are used, precautions should be taken with regards to pump – motor alignment to avoid spline fretting.

Magnetic Couplings Magnetic couplings can be used to transfer the motor shaft torque to the pump shaft without physical contact between the two shafts. When magnetic couplings are used, the membrane or gap cup between the motor and pump sides of the coupling should be designed for the same rating as the pump pressure casing.

− The magnetic coupling operating limits (speed, torque, power) shall correspond to motor and pump capacities.

− The magnetic coupling pressure barrier shall be rated to MADP

NOTE The inclusion of a magnetic coupling as a replacement for a mechanical seal separating pumped fluid from the motor environment allows for a pressure rating specification break between the motor and pump casings.

− Use of special materials is allowed to minimize eddy current losses and increase the magnetic coupling efficiency. The choice of materials shall be agreed.

− Magnetic couplings shall be tested as an integral part of motor pump unit

Magnetic coupling shall be designed and tested per API 685. The magnetic coupler external design pressure shall at least be equal to the pump casing internal design pressure. The magnetic coupling external design pressure shall be at least equal to the motor casing internal design pressure.

The magnetic coupling shall be pressure integrity tested on a component level. The assembly of motor casing with magnetic coupling shall be considered an individual pressure casing, and shall be tested accordingly. The assembly of pump casing with magnetic coupling shall be considered an individual pressure casing, and shall be tested accordingly.

Torque Coupling Torque couplings may be used to provide mechanical speed control of the pump.



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5.7 Bearing and Bearing Design

Subsea motor and pump bearings should be designed for subsea use in varying flow conditions with varying loads resulting from these changes. The designs should be qualified with the pump and motor to demonstrate:

− Tolerance to start-up and shut-down (both planned an unplanned)

− Tolerance to load variations resulting from dynamic loads such as changes GVFi, WLR, densities, viscosities, pressures and temperatures, as well as solid particles

− Long term reliability

− Cooling needs and sufficiency of the cooling solution

5.8 Motor Cooling Systems

The motor cooling system is often designed to include the bearing cooling loads. In both cases, the system shall be designed and qualified to include those loads and to include expected variations in seabed current and environmental conditions, including biofouling potential. The relevant site environmental data for the application are specified in the Pump Design Data Sheets (Annex A). NOTE 1 The pit test facility may be designed to include circulation beyond that of expected seabed currents. These circulation rates should be included in the evaluations and can be used to mitigate the effect of elevated pit temperatures.

NOTE 2 With product standardization in mind, the cooling solution may be required to cover the full range of sea (and fresh) water conditions (from -4 oC [25 oF] to 25 oC [77 oF]), the global variability in sea (and fresh) water and the variation with these water properties with depth.



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6 Pump Control, Protection, and Monitoring Systems

6.1 General

The control, protection and monitoring systems for subsea pumps shall be designed in accordance with applicable sections of API 17F.

6.2 Functional Requirements for Control Systems

Pump Control System The pump control system shall:

− Respond to Emergency Safety System (ESS) signals and take appropriate actions to secure the system

− Protect the pump and take appropriate actions to secure the system. Examples are: ― Flowline transients by taking appropriate action ― Closed downstream valves

− Avoid prolonged/continuous operation in any harmful resonant frequencies, if any (e.g. structural, torsional, lateral within the pump module itself.)

− Continuously monitor the motor drive electric frequency with fail-safe feedback loop. The barrier fluid system should be qualified to ensure reliable response throughout the operating period of the pump module.

Chemical Injection NOTE 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.

Control System Communications Because of the rapid response requirements for pump protection systems, signal quality, reliability, response time are important to the reliability and safety of the installed system.

6.3 Functional Requirements for Monitoring Systems

General For each individual installation, a review of the cost versus benefit of the implementation of each of the various monitoring technologies can be conducted.

− Power Consumption of the pump motor should be measured and logged.



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− Number of hours the pump has run should be measured and logged.

− Suction and discharge pressure should be measured and logged.

− If a barrier fluid system is used, the consumption of barrier fluid should be measured and logged.

− A means of monitoring motor winding, seal and bearing temperatures should be implemented.

From analysis of these measurements, the remaining useful lifetime of the pump can be estimated. This in turn can be used to schedule maintenance and pump replacement.

Vibration Sensors When specified, accelerometers and/or proximity probes should be supplied, installed, and tested.

− When specified, qualified and commercially available, the pump and motor should be equipped with proximity probes for measuring the rotor movement during operation. This should 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 per revolution marker.

− Proximity probes (if implemented in the design) should be designed and qualified to operate within an environment including all the production fluids and chemicals within the fluid stream. Purchaser to provide a complete list of these chemicals (including barrier fluids) to Manufacturer (Annex A).

− If temporary proximity probes are required for testing, the pump should be designed to simplify their removal and to limit post-removal testing to simple hydrostatic leak testing.

− Pump-motor units where the two rotors are separated by a variable coupling like a hydrodynamic coupling, should have two separate probe sets (one on each rotor).

Flowmeters Flowmeters may be implemented as a portion of the pump control / protection system. API 17S provides an appropriate guideline for design criteria for this use.



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7 Pump Module Packaging

7.1 Pump Module

Typically, subsea pump modules, ROV panels, barrier fluid connections, power and control connections and instrumentation connections, etc., are supported in a structural frame which allows deployment and retrieval using retrieval tools, ROV's etc. Connectors, piping, structural elements, valves and auxiliaries in the module and supporting structures should be designed and manufactured in accordance with the requirements described by API 17P and 17R.

Natural Vibration Frequency and Response Analyses A report describing the natural frequency responses of the system should be documented in a report containing:

− 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 continuous 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 should be run continuously from 0 Hz up to minimum 150 % of maximum continuous speed with a reasonable delta frequency (for instance 1 Hz)

NOTE 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 to make the unit “mass dependent.” Subsea pump units typically contain sufficient mass in the motor and pump casing to avoid inappropriate vibration responses.

7.2 Module and Infrastructure Rated Pressure

Purchaser should develop the design case for a subsea pump and the connected systems which should include

− maximum shut-in/settle out pressure in the system including

− response times and required pressures from the barrier fluid system

− potential exposure of the system to pressures resulting from dynamic kills or high pressure chemical supplies.

− overheating of enclosed volumes

− requirements for dead-head operation



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NOTE: Pressure excursions can be expected to influence the barrier-fluid and other chemical injection systems. Because these events may occur with some frequency, the use of steady-state design criteria occurs at the risk of pressure-containment.

Unless otherwise specified, the barrier fluid system (HPU through to the pump) shall be pressure tested to the design code.

7.3 Pressure-limiting and Recycle Valves

Pressure-limiting valves Unlike surface mounted solutions, pressure limiting valves are not required. Pressure-limit control should be achieved using motor torque control.

NOTE Rotary-positive displacement pumps may be capable of generating pressures in excess of system design values.

Recycle or Surge Control Valves Recycle or surge control valves are part of the pump control system and are also used to ensure operability; they should be designed and sized to meet the minimum flow requirements of the pump.

7.4 Umbilical Interfaces

General Because of the system dependence between the power and barrier fluid system and the pump interfaces, Purchaser should ensure an early interface between the umbilical manufacturer, the SURF contractor, and the pump module manufacturer. A key factor effected by this interface is the potential to optimize the termination assemblies and mitigate installation issues during deployment.

SUTA and STI For a subsea pump station, the Subsea Umbilical Termination Assembly (SUTA) should connect the power cables, control lines and hydraulic lines to the subsea pump station. There will be 4 main types of SUTA, which are dependent on the number of pumps in the station and if a subsea transformer is needed.

A Subsea Termination Interface (STI) is a structural unit which forms an interface between the umbilical and the SUTA, and it features a bolted flange for physical connection to the SUTA. The STI is typically supplied by the umbilical manufacturer while the SUTA is typically supplied by the subsea pump station integrator.

SUTA–Subsea Umbilical Termination Assembly For a subsea pump station, this unit should connect the power cables, control lines and hydraulic lines to the subsea pump station.



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The content assumed to be included in the module is listed Table 3

Table 3―Typical SUTA Components

Content Description

Mechanical Structural including guidance Controls Connectors and jumpers Power Termination Assembly,

LV connectors and jumpers MV Connectors and jumpers

NOTE The subsea structure layout may affect the size of the SUTA.

SUTA and power modules should be dedicated to one side of the station (opposite of flowline tie-in) and be located close to the consumers (e.g. pump and compressor).

In cases with a large subsea power scope (e.g. subsea VSDs and switch gear) it could be beneficial to have parts of the station (e.g. subsea step-down transformer) located on a separate structure.

In early conceptual and front-end engineering phases of field layout, the number of consumers (pumps and compressors) and need for subsea transformers should be reviewed. A two-pump system can be served by a single umbilical. This directly influences the required number of functional elements in the umbilical, and, therefore, governs the size of the SUTA. Limiting the number of functional elements to a practical amount is a preferred method of limiting the size of a SUTA, as opposed to limiting or eliminating the ability to utilize spare lines or compromising on design reliability with respect to materials of construction, minimum bend radii, and the number of welded fittings.

In API 17TR9 SUT “Selection and sizing” a workflow has been developed to guide the user on how to find an optimized UTA design. The umbilical should be as per API 17E.

As the impact of the SUTA size can be significant an optimization of the UTA size, to reduce cost and duration of the installation of the umbilical and the SUTA, should be performed. The installation contractor should be engaged and consulted early during the design phase to provide inputs on the install-ability and optimize the design.



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8 Installation and Intervention

8.1 General

Pump modules shall meet the installation and intervention requirements of API 17P and API 17H.

8.2 Flushing Facilities for Retrieval

In addition to the requirements described in API 17P and API 17R, the following requirements are added.

− Flushing infrastructure should be designed to provide effective flushing of the module to be retrieved. The flushing facilities shall be used to minimize the release of hydrocarbon or other harmful fluids to the environment.

− A recommended flushing procedure should also be part of Manufacturer’s documentation and shall be developed prior to retrieval of a module.

− The non-retrievable infrastructure should be designed with appropriate barriers to isolate the piping and its contents from the environment. The volume between these barriers and the retrievable items should also be included in the flushing strategy.

− A barrier philosophy document should be issued describing these interfaces.

− 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 part of the design. Procedures for pressure relief should also be supplied as part of the manufacturer documentation.

− 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.

− Manufacturer to supply installation tools, lifting points to adhere to these requirements

− Manufacturer to supply flushing and depressurization procedures to ensure safe transport after FAT, during transport and deployment, and after retrieval.

− To minimize leakages during transport etc., temporary caps or plugs, if required, should also be supplied.



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8.3 Transportation and Testing Equipment

General The design of transportation or shipping skids should include limitations in the total height and handling loads of equipment for ease of transportation on land and for loadout to vessels.

The retrievable module of the boosting system should be transported in a dedicated transport frame which may also function as an offshore test frame (for use in pre-deployment testing). 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.

Lifting Arrangements Lifting lugs on transportation and testing equipment to allow handling may be supplied and should conform with certification agreed between Purchaser and Manufacturer. Testing of reusable lifting equipment is more stringent as this equipment is subject to lifting cycles throughout its lifetime.

− Lift points should, in the least, be designed per Annex K of API 17D.

− Additional regional, rig operator or SURF contractor requirements may be invoked. These should be clarified during the tendering process as erroneous choices may restrict applications.

− The design of test stands and fixtures should include assembly, transport, and handling loads as well as test loads.

Test Equipment 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.

Test Stands Test stands simulate the profiles of the subsea manifold, flow base, 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 stands should have ability to isolate and communicate with everyone bore of the test stump to facilitate pressure testing. This may be achieved via individually plumbed test ports or manifold test ports with isolation valves.

Equipment used for Shipping Skids used for storage or shipping should be designed to simplify inspection of seal (and other) surfaces.



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8.4 Special Tools

Although field maintenance is likely infeasible, a small number of special tools may be required for tests prior to deployment. These should be minimized and designed to be shareable across applications.



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9 Performance Testing

9.1 Qualification and Requalification

General 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 or DNV-RP-A203. Qualification tests will require more resources and post-test inspection than application specific tests.

Qualification The key outputs of the qualification process are the generation of data for the pump.

NOTE Requalification may be required if significant changes to the following occur:

− Power Flow-rate Head or differential pressure

− Rotational Speed

− Maximum pressure

− Maximum operating temperature

− Orientation

− Water Depth

− GVF tolerance (range and variation)

− Change in barrier fluid composition

Table 4, Figure 2 and Figure 3 provide additional guidance on the need for qualification by providing a list of pre-accepted configuration changes and their associated qualification strategies.

Table 4―Pre-accepted Configuration Changes

Nr Change Rationale 1 Motor-Penetrator Pairing Covered by IEC/IEEE 61886-1 (formerly SEPS SP-1001) 2 Power Umbilical Step-out Qualification by analysis, Qualified simulation models exist 3 BF Umbilical Step-out Qualification by analysis subject to model validation

4 Change in BF Composition Qualification solely by compatibility testing and analyses using a model validated by testing.

5 Changes in hydraulic stack Hydraulic and rotor dynamic analysis verified by testing



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Figure 2―Decision Aid for identifying need to qualify/requalify



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Figure 3―Decision Tree for Testing

9.2 Test Scope

Individual Test Types The following tests (if individually applicable) are completed during the qualification process and some or all are typically required for FAT and EFAT. The individual test requirements should be specified in the datasheets, see Annex A. The tests are described in further detail in annexes (B-C) Start-up and Shutdown

― Normal Performance Operation

― Liquid Slugging

― Extended Performance and Operation

― Break-away Torque



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NOTE: 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 manufacturer 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 manufacturer and operator.

The FAT and project/application specific test requirements should be held to a subset of the qualification requirements.

Test System The system tests apply to a typical subsea boosting system and should include a minimum level of system components as described in Table 5. When use of full scale components is not feasible, components may be simulated. Components from the larger system may be required for some tests on the pump and motor. For example, an umbilical can be simulated using an umbilical simulator.

As an aid to the decision, and as described in API 17Q, an assessment of the Technology Readiness Level of the proposed solution both at the module level and at the system level should be performed and further utilized to evaluate needs for qualification (Annex B Illustrates a possible approach to making that decision).

Table 5―Scope of Test Object

Test Object Qualification Application Specific Test

Power Distribution and Communications: Subsea power interface/connectors Required Required

Subsea power umbilical a Optional Emulated

Subsea or topsides transformers b Emulated Contract Transformer Variable speed drive Emulated Contract VSD SCM or equivalent c If Applicable If Applicable Pump Module:

Pump and motor Required Required Barrier fluid system If Applicable If Applicable

Pump sump If Integrated If Integrated Pressurization system d Emulated Required

Motor/lubricant cooler (s) Required Required Pump Station:

Buffer tank (for MPP) For Slug Tests Required Liquid extraction unit If Applicable If Applicable

Recycle valve If Applicable If Applicable Recycle coolers If Applicable If Applicable

FOOTNOTES aThe power umbilical is an application specific item with the details of the manufacturing solution affecting the design of the emulator.

bThe emulation of the subsea transformer should be based on the use of the topsides equivalent model. cAn SCM may not always be implemented. Alternative solutions should be included as a portion of the qualification/application specific program.

dThe dynamics of the solution used for pressurization are application specific. Application specific tests should be performed with an appropriate HPU and relevant umbilical emulation.



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9.3 Individual Tests Requirements

Operating Data The following parameters should be monitored and included in the test report:

− Balance line pressure (if applicable)

− Barrier fluid cleanliness measurement (e.g. by sample and analysis)

− Barrier fluid dielectric properties (conductivity and relative permittivity at a given frequency), if applicable

− Barrier fluid flow rate within the cooling loop

− Barrier fluid leakage rate (bulk leakage rate and for steady state operation only)

− Barrier fluid pressures

− Barrier fluid temperature upstream

− Barrier fluid temperature within motor

− Flowrate

− GVF, GVFi

− Inlet barrier fluid temperature (if applicable)

− Motor current

− Motor voltage

− Motor winding temperature (measured via barrier fluid temperature)

− Process fluid density (calculated at pump inlet)

− Pump and motor casing vibration data (accelerometer data)

NOTE 1 The casing vibration data should be obtained and used for long term surveillance.

− Pump and motor rotor vibration data if feasible (rotor radial and axial displacements relative to the casing)

NOTE 2 After the prototype phase, rotor and motor vibration data acquisition may not be feasible.

− Pump inlet and discharge pressure

− Pump inlet and discharge temperature

− Pump and/or Motor speed



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Additional Test Instrumentation Additional test instrumentation requirements shall be defined in the data sheets (See Annex A).

9.4 Test Acceptance Criteria

General Acceptance criteria shall be specified in the datasheets (See Annex A) and cover

− Pump and motor power

− Head and flow rate

− Barrier fluid (if applicable) consumption, control response and process fluid contamination

− Bearing and motor temperatures (measured as specified

− Vibration

Vibration The vibration measured during the pump performance test shall not exceed the values shown in Figure 4. and Figure 5 and shall only be valid for rotodynamic multiphase pumps with hydrodynamic support bearings operating within their preferred operating envelope.

Figure 4—Vibration Limits for GVF < 40% in a Rotodynamic Pump with Yydrodynamic Bearings



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Figure 5—Vibration Limits for GVF > 40% in a Rotodynamic Pump with Hydrodynamic Bearings

For flexible coupled vertical liquid filled electric motors the criteria shall be load independent thus overall shaft vibrations peak-peak at bearing locations shall not exceed 50% of the hydrodynamic support bearing diametral clearance.

− For discrete frequencies (FFT) below running frequency (f<n) the vibration amplitude A shall not exceed 33% of the overall vibration amplitude Au (A≤0.33 Au).

− When operating outside the preferred operating envelope overall (peak to peak) vibration is accepted to increase by 30%.

− Casing measurements shall be included during the test, and velocity sensors shall be located near the bearing housings. The vibration limit for casing vibration shall be 3 mm/s (RMS) for all operating points.

Au amplitude of measured overall displacement f frequency n rotational speed in rpm FFT Fast Fourier Transform. Z Highest Number of impeller vanes in any stage,

For this purpose, FFT spectra shall be measured using Hann windowing and a minimum frequency resolution of 400 lines.

During the performance test, overall vibration measurements over a range of 5 Hz to 1 000 Hz and a Fast Fourier Transform (FFT) spectrum shall be made at each test point except shutoff. The vibration measurements should be made at the following locations:



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− on the bearing housing(s) or equivalent location(s) of all pumps, at the positions shown in Figure 6

− on the shaft of pumps with hydrodynamic bearings and proximity probes. The FFT spectra shall include the range of frequencies from 5 Hz to 2Z times running speed (where Z is the number of impeller vanes; in multistage pumps with different impellers, Z is the highest number of impeller vanes in any stage). If requested, the plotted spectra shall be included with the pump test results. NOTE: The discrete frequencies 1,0, 2,0, and Z times running speed are associated with various pump phenomena, and are, therefore, of particular interest in the spectra.

Figure 6—Illustration of Recommended Placement for Proximity Probes During Testing

Post Qualification Test Internal Inspection Data and Criteria After qualification testing is complete, the pump shall be disassembled and inspected for wear or damage to the following components.

− Visual inspection of the disassembled pump and motor components, including the mechanical seal, radial and thrust bearings

− Bearing pad wear should be such that the bearing is within original manufacturing tolerances after the test



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− Bearing edge wear should be recorded using photographs and reviewed: polishing and deburring are acceptable.

− If feasible, bearing clearances should be reported.

NOTE: Dimensional and clearance changes to bearings may be difficult to assess without special instrumentation (if at all feasible).

− Any deterioration of seal or bearing components should be reported

− Mechanical seal components should be measured before and after testing

− Microscopic inspection of seal faces and elastomers may be performed; which and how many to be agreed between Manufacturer and Purchaser

− No evidence of debris generation from the pump/motor should be present in the barrier fluid system.

NOTE: Flushing does not necessarily remove all particles from a complex assembly. Care should therefore be taken on inspection to determine if any debris remains within that indicate machine wear.

− Any contamination of the barrier fluid should be reported

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.

Pump disassembly is not required after factory acceptance testing. Analysis of operating data is sufficient to confirm that the pump is not damaged during this form of testing.

9.5 Factory Acceptance Testing

General A comprehensive acceptance test program should be undertaken at the fabrication site to ensure that components have been manufactured in accordance with specified requirements. The test should be performed to a predefined and approved procedure. Any non-conformance should be documented and analysed to find the its cause. The non-conformance should be corrected. If the non-conformance cannot be corrected, a review of the calculated reliability of the system should be conducted to determine if the deviation can be accepted.

Factory acceptance testing is generally a multi-tiered approach, involving individual component checks, subsystem checks (e.g. control system), interface checks and unitized system checks. Modifications and changes to the equipment during testing and manufacture should be formally documented.

A typical format for a subsea equipment factory acceptance testing procedure can include the following:

− purpose/objective;



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− scope;

− requirements for fixtures/set-ups, facilities, equipment, environment and personnel;

− performance data;

− acceptance criteria;

− reference information.

Factory acceptance testing typically covers the following items:

− individual component testing;

− assembly fit and function testing using actual subsea equipment and tools where possible;

− interface checks using actual subsea equipment and tools where possible;

− interchangeability testing;

− hydrostatic testing:

― includes valve seal checks at operating pressure,

― verifies piping code requirements,

― duration according to design code or 1 hour (recommended) if not specified,

− seal testing of end closures.

Unless otherwise specified and per API 6A, pumps should not be disassembled after passing the final performance test(s).

Performance Testing Unless otherwise agreed, performance tests should be performed using single-phase water at a temperature not exceeding 55 °C (130 °F).

All warning, protective and control devices used during the test should be checked and adjusted as required

The duration of the test should be indicated on the test report.

Pump and motor bearings should operate within bearing temperature limits specified by the bearing manufacturer.



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Bearing metal temperatures or relevant lubricant/barrier fluid temperatures should be recorded at the beginning and the end of the test.

All barrier fluid or lubricant, properties and temperatures should be within the range of operating values recommended in the manufacturer’s operating instructions for the specified unit being tested

Fluids from the barrier fluid circuit (if any) should be sampled and analysed contaminants (either process fluid or particulates) to confirm function and maintenance of overpressure.

If agreed, excessive seal leakage during the test should require the assembled pump and seal to be rerun to demonstrate satisfactory seal performance.

After the test has been completed and after barrier fluid circuit samples have been taken:

− the pump internals exposed to the pumped fluid should be drained to the extent practical displaced with a fluid which is both suitable for preservation and compatible with test and production fluids

− the barrier fluid circuit should be flushed and closed,

− Manufacturer should record base-line vibration data values for these data during FAT and supply them with the MRB and user manual. Similarly, installed base-line values should be recorded after deployment and stored for reference.

− Values should be recorded at each test point except shutoff during the per 9.4.

− Pump performance curves should be post-processed and reported in accordance with API 610. Disassembly of multistage pumps for any head adjustment (including less than 5 % diameter change) after test, should be cause for retest.

− If it is necessary to dismantle a pump for any other correction, such as hydraulic performance, NPSH or mechanical operation, the initial test should not be accepted, and the final performance test should be run after the correction is made.

9.6 System integration testing

While the total system integration test is outside the scope of this document, the pump module and pump station should be part of the system integration test. The tests performed during integration testing should be used to check reliability and should demonstrate tolerance requirements and correct functioning of the complete system. The purpose of the test is to simulate all operations that can be done offshore, to the extent practical, and to verify all equipment/systems related to the permanent seabed installations.

A typical scope and guidance for a SIT can be found in API 17P.



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10 Materials and Materials Inspection

10.1 Pump Module Structure and Piping

General The material requirements for the structure, cathodic protection, piping, tubing and valves and including coatings and welding found on a pump module shall conform to API 17P.

Fasteners Threaded fasteners should conform to the requirements of Table 6.The manufacturer may select either the API option or the NORSOK option.

Table 6: Bollting Requirement

Material Specification Options

Pressure-controlling Bolting Alloy steel and carbon steel API 20E BSL-2 NORSOK M-001 Stainless steel and CRA API 20F BSL-2 NORSOK M-001

Closure Bolting Alloy steel and carbon steel API 20E BSL-3 NORSOK M-001 Stainless steel and CRA API 20F BSL-3 NORSOK M-001

Pressure-retaining Bolting Alloy steel and carbon steel API 20E BSL-3 NORSOK M-001 Stainless steel and CRA API 20F BSL-3 NORSOK M-001

Structural Load Bearing Bolting Alloy steel and carbon steel API 20E BSL-2 NORSOK M-001 Stainless steel and CRA API 20F BSL-2 NORSOK M-001

Utility Bolting Alloy steel and carbon steel Mfg. Spec.(1) Mfg. Spec.(1)

Stainless steel and CRA Mfg. Spec.(1) Mfg. Spec.(1)

NOTE: (1) Based on manufacturer’s written specification

10.2 Pump and Motor Casing Specifications

Specifications Per API 6A, all metallic and non-metallic pressure-containing or pressure-controlling parts shall require a written material specification.

Metallic Material Requirements For this application, the items in question are typically required to follow API 6A PSL 3.

The pressure casing shall be treated as a body and API 6A sections 5.4.1 and 5.4.2 apply. The reader is referred to the API 20-series (API 20B and API 20C) for manufacturer and forging qualification details applying the rules for FSL levels 2 and higher.



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DNVGL-RP-0034 may be used as a purchasing guideline for pressure casing forgings noting further that the items are fatigue sensitive and fall into SFC 3.

The manufacturer's written specified requirements shall define the following, along with acceptance 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

Non-metallic Seal Requirements

Non-metallic pressure-containing or pressure-controlling seals shall have written material specifications including

− generic base polymer(s); see ASTM D1418 physical property requirements

− material qualification, which shall meet the equipment class requirement

− storage and age-control requirements

Special Materials Special materials and processing methods such as Hot Isostatic Pressing are covered by ISO 17782 and NORSOK M-650 and are subject to the qualification procedures covered by the referenced standards.

10.3 Manufacturing Quality Control: Pump and Motor Casing

Unless otherwise specified, pressure-casing materials should be inspected in accordance with the requirements of Table 7 below.

10.4 Nondestructive Examination

Personnel Qualifications



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Personnel performing NDE and Welding Inspection shall be qualified in accordance with API 17P.

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.

Material Testing Table 7 describes the NDE inspection details and acceptable alternatives.

Manufacturer shall submit details of the critical areas proposed to receive MT/PT/RT/UT inspection for Purchaser's approval.

Table 7―Inspection Classes as Applicable to API 17X

Type of Component Inspection Class

I II III

Minimum >80 % MADP and > 200 °C (392 °F)

<0.5 SG or

> 200 °C (392 °F) and < 0.7 SG, or

> 260 °C (500 °F) Extremely hazardous

servicese

Casingb: wroughtc VI, plus MT or PT of critical areas

VI, plus MT or PT of critical areas

VI, plus MT or PT (critical areas), plus UT (critical areas)

Nozzle weld: casing VI, plus 100 % MT or PT VI, plus 100 % MT or PT VI, plus 100 % MT or

PT plus RT (100 %) Auxiliary connection weldsd VI, plus MT or PT VI, plus MT or PT VI, plus MT or PT (100 %)

Internals VI VI VI Screw tips’ hardened surfaces UT UT UT

a Definition of abbreviations: VI: Visual inspection MT: Magnetic particle inspection PT: Liquid penetrant inspection

RT: Radiographic inspection UT: Ultrasonic examination

b “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.

c “Wrought” materials include forgings, plate, and tubular products. d Due to complex geometry and thickness variations, it is not practical to RT butt-welded auxiliary casing connections. e Extremely hazardous services, as specified by Purchaser.

10.5 Pump Internals― Fluid Exposure, Corrosion and Erosion

Based on the following, manufacturer should provide a materials philosophy document with the technical proposal. The details of the required information are listed in Annex A.



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− A complete equation of state characterization should be provided including details of the chosen Equation of State and any tuning parameters (including values for transport properties).

− A set of reference data in the form of a phase envelope and matching data from petroleum fluid studies should be provided

− 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).

− Expected production rates of and properties for sand and other solids.

− Expected extremes in temperatures resulting during start-up and blowdown.

− A complete list of production and intervention chemicals to which the pump module may be exposed.

11 Manufacturing, Inspection, and Preparation for Shipment

11.1 General

Purchaser should specify the extent of their participation in the inspection and testing. Further, purchaser and manufacturer should agree the procedures (including fluids), extent and content of the inspection and testing activities. The participation includes the following requirements and information exchanges:

− If shop inspection and testing have been specified, the purchaser and the manufacturer should coordinate manufacturing hold points and inspector visits

− The expected dates of testing should be communicated at least 30 days in advance and the actual dates confirmed as agreed. Unless otherwise agreed, the manufacturer should give at least five working days advanced notification of a witnessed or observed inspection or test

− 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

− The manufacturer should notify sub-manufacturers of the purchaser’s inspection and testing requirements.

− After advance notification to Manufacturer by Purchaser, Purchaser’s representative should have reasonable access to all manufacturer and sub-manufacturer plants where manufacturing, testing or inspection of the equipment is in progress. The level of facility access should be agreed during purchasing.

− Equipment, materials and utilities for the specified inspections and tests should be provided by the manufacturer.



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− If specified, Purchaser’s representative, Manufacturer’s representative, or both, should indicate conformance with an inspector’s checklist by initialing, dating, and submitting the completed checklist to the purchaser before shipment.

− Purchaser’s representative should have access to the manufacturer’s quality program for review.

11.2 Inspection

General

All preliminary running tests and mechanical checks shall be completed by Manufacturer before Purchaser’s final inspection.

Data Storage

The manufacturer should keep the following data available for at least 20 years:

− 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

Optional Requirements The purchaser may specify the following:

− parts that should be subjected to surface and subsurface examinations

− type of examination required, such as magnetic-particle, liquid-penetrant, radiographic, and ultrasonic examinations

11.3 Preservation and Storage Procedures

General



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Preservation and Storage Procedures shall meet the requirements of API 17P. In addition, the procedures shall include instructions describing the needs for:

− Intermittent operation of the pump, motor, barrier fluids, and associated valving

− Internal and external inspection, including in-situ methods for post-installation preservation.

− EMF exposure prevention.

Manufacturer should include the following 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

− The individual requirements of all materials and storage conditions should be included in the evaluation and choice of preservation fluids. These requirements include compatibility, thermal exposure, sun tolerance, chemical stability, etc.

− Shock logging devices shall be installed.

− Suitable rust preventatives shall be soluble in oil (or water if the pump intended for water injection) and compatible with all pumped liquids

− Rotors should be locked if necessary. Locked rotors should be identified by means of corrosion-resistant tags attached with stainless steel wire.

− Exterior machined surfaces, which are agreed to not be subject to coating requirements, should be coated with a rust preventive.

− Flanged openings should 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 should be used to secure closures.

− Threaded openings should be provided with temporary steel caps or steel plugs.

NOTE Water accumulations resulting from submergence, condensation or spray in threaded bolt-holes and other threaded openings can be a corrosion source.

− If appropriate Metal filter elements and screens should be cleaned and reinstalled prior to shipment.

− If appropriate Non-metallic filter elements should be shipped and installed in an unused condition

Loose seals, stab subs, and ring gaskets should be individually boxed or wrapped for shipping and storage.

Manufacturer should document instructions concerning the proper storage environment, age control procedures, and protection of elastomer materials.



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Hydraulic systems should be in a suitable state of cleanliness prior to shipment, to meet that need:

− Prior to shipment, the total shipment including hydraulic lines should be flushed and filled in accordance with Manufacturer’s written specification.

− Exposed hydraulic end fittings should be capped or covered.

− All pressure should be bled from equipment, unless otherwise agreed between Manufacturer and Purchaser.

− A cleanliness certificate shall be submitted prior to shipment.

Manufacturer should document instructions concerning proper storage and shipping of all electrical cables, connectors, and electronic packages

Extended Storage and Export Shipment Procedures for export shipment, post-delivery and extended storage and preservation should be agreed between Purchaser and Manufacturer. Manufacturer should provide recommendations for storage to the user upon request.

NOTE A requirement for mechanical operation during long term storage extends the scope of supply.

12 Manufacturer’s Data and Marking

12.1 General

The information to be supplied should conform with API 610 and API 676 modified as follows for application to subsea project requirements and practices.

NOTE: DNVGL-RP_O101 provides an alternative approach to meeting these documentation requirements.

Information described in Annex D, should be supplied in accordance with the agreed documentation schedule as described during the tendering process.

The documents should be marked to identify

− Purchaser’s/owner’s corporate name;

− the job/project number;

− the equipment item number and service name;

− the inquiry or Purchaser’s order number;

− any other identification specified in the inquiry or purchase order;



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− Manufacturer’s identifying proposal number, shop

Table 12 is, in general, structured by order of appearance and alphabetically.

Items with an “P” in the first column “Proposal” are required at as a part of the proposal package.

Items with an “I” in the column “Engineering Documentation” are not subject to Purchaser review (unless required by other entries) and are to be stored by Manufacturer as a part of their engineering documentation requirement and should be stored in accordance with industry practice.

Items with an “D” in the column “Systems Engineering Design Review” are subject to Purchaser review and are also required at Draft state as an input to the named review.

Items with an “C” in the column “MRB” should be supplied to Purchaser with the final delivery are subject to Purchaser review. These should be stored by both Purchaser and Manufacturer for time periods relevant to the role.

Items with an “C” in the column “User Manual” should be supplied to Purchaser with the final delivery are subject to Purchaser review. These should be stored by both Purchaser and Manufacturer for time periods relevant to the role.

The letter “O” denotes optional documentation requirements which Purchaser may request.

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.

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 Purchaser and describe installation, use, storage and operation of the pump and ancillary equipment. These are subject to Purchaser approval and may be subject to updates during the life of the installed item.

Example:

The first item “Barrier fluid/cooling system GA and component drawings” should be described based on:

− Manufacturer’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



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− Finalized by the end of the project and documented in both the MRB and user manual.

12.2 Marking

General A nameplate shall be securely attached at a readily visible location on the equipment and on any other major piece of auxiliary equipment. In general, marking shall contain the designation “17X”.

Rotating Equipment Rotation arrows shall be cast/forged/machined/stamped in or attached to each major item of rotating equipment in a readily visible location.

Nameplates and rotation arrows (if attached) shall be of ANSI Standard Type 300 stainless steel or of nickel-copper alloy such as UNS N04400. Attachment pins shall be of the same material. Welding shall not be permitted.

The nameplate information shall include:

− the purchaser’s item number,

− the vendor’s name,

− the machine’s serial number,

− the machine’s type,

− the machine’s rating data (including pressures, temperatures, speeds, power, and critical speeds)-

− Units combined with motors shall also include motor power, insulation class, line voltage and frequency ranges as well as torque capacities

− By its choice of datasheet units, the purchaser will specify on the datasheet whether USC or SI units are to be shown.

Pump units shall be marked in accordance with Table 8, Table 9, Table 10 and Table 11.

Marking using low-stress (dot, vibration or rounded V) stamps shall be acceptable. Conventional sharp V-stamping shall only be permitted in low-stress areas.

Table 8―Classification by Installation Depth

Depth class Depth A 0 to < 500 meter 0 to < 1640 ft B 500 to < 1500 meter 1640 to < 4920 ft C 1500 to < 3000 meter 4920 to < 9840 ft D 3000 to 5000 meter 9840 ft to 16400 ft



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Table 9―Classification by Sea Water Temperature

Temperature class Temperature Range A -2 ºC to < +10 ºC +28 oF to < +50 oF B +10 ºC to < +20 ºC +50 oF to < +68 oF C +20 ºC to +30 ºC +68 oF to +86 oF

Table 10―Classification by Process Fluid Temperature (Expanded from API 6A)

Temperature Classification

Minimum Temperature

Maximum

Temperature

S -18 °C 0 °F 60 ºC 150 °F

T -18 °C 0 °F 82 ºC 180 °F

U -18 °C 0 °F 121 ºC 250 °F

V 2 °C 35 °F 121 ºC 250 °F

W -18 °C 0 °F 149 ºC 300 °F

X 2 °C 35 °F 149 ºC 300 °F

Y -18 °C 0 °F 177 ºC 350 °F

Z 2 °C 35 °F 177 ºC 350 °F

Table 11―Casing Rated Pressure Class

Pressure Class Rated Pressure A 138 bar 2,000 psi B 207 bar 3,000 psi C 345 bar 5,000 psi D 690 bar 10,000 psi E 1035 bar 15,000 psi F 1380 bar 20,000 psi

Motors delivered separately from pumps Motors connected separately to pumps via torque converters or magnetic couplers shall have the following nameplate data.

− the purchaser’s item number,

− the vendor’s name,



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− the machine’s serial number,

− the machine’s type,

− the machine’s rating data (including pressures & temperatures, speeds, power, torque capacities and critical speeds)-

− the machine’s insulation class, line voltage and frequency ranges

− By its choice of datasheet units, the purchaser will specify on the datasheet whether USC or SI units are to be shown.

Minimum Flow Valves and Actuators Minimum flow valves and actuators shall be treated as chokes and marked as per API 17D. In lieu of hydraulic pressure rating data, electric actuators should be marked with:

− input voltage

− input frequency

− power rating

− communication protocol

− motor torque rating

− motor rotational direction / manual override direction

− maximum input torque (if equipped with manual override)

− electrical storage capacity

External heat exchangers If mounted separately from the pump and motor, in addition to the requirements from API 17D and API 17P, external heat exchangers should be marked with:

− design duty rating

− design seawater depth

− design seawater temperature

− design seawater current (in velocity units)

− design internal fluid temperature

− primary internal flow direction



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Annex A (Informative)

Pump Design Data Sheets

This annex contains typical data sheets for use by Purchaser in communication with Manufacturer.



54

Date: Project: Page: ___ of ___

General Design Requirements (SI Units) Description Input Value Reference Number Application Description Application Site Geographic Location Application Service Application Type Pump Count Design Life Design Conditions MAWP, bar MADP, bar Rated Pressure, bar 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 tons Envelope Dimensions, WxLxH (m) Testing Requirements Application/Contract Specific Performance Testing Factory Acceptance Testing



55

Site Integration Testing Date: Project: Page: ___ of ___

Operating Data (SI Units) Description Minimum

Flow Expected Maximum

Flow Attachment

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), Sm3/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, µm Sand Rate at Upset Conditions, kg/d Sand Size at Upset Conditions, µm 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



56


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 Gas Oil Recombined Component Mol Percent Mol Percent Mol Percent H2S N2 CO2 CH4 C2H6 C3H8 i-C4H10 n-C4H10 i-C5H10 n-C5H10 Molecular wt. Specific Gravity Hexanes Heptanes Octanes Nonanes Decanes Decanes + Undecanes Dodecanes Tridecanes Tetradecanes Pentadecanes Hexadecanes Heptadecanes Octadecanes Nonadecanes Eicosanes +



57


Fluid Description (SI Units) Description Input Value Reference Number


Formation Water Composition (SI Units) Total Dissolved Solids pH Ion Ion mol wt. Charge Range mg/l 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 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 SO4

2- 96.0618 -2 CO3

2- 76.0972 -2 sum



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Motor Design Requirements (SI Units) Description Input Appendix Number 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 Seawater Current, m/s Seawater Salinity, kg/kg Design Case Fouling Factor, m2∙K/kW Interface Requirements Power Connection Instrumentation Requirements Motor Torque Key Phasor 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



59


Pump Instrumentation Requirements (SI Units) Description Input Value Reference Number 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



60


Pump and Motor Mechanical Design Outputs (SI Units) Description Output Value Reference Number 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 tons Envelope Dimensions, WxLxH (m) Handling Tool Part Number or Padeye Rating Transport Skid Part Number



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Pump Design Outputs (SI Units) Description Output Value Reference Number 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



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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 Reference Number 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



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Motor Design Outputs (SI Units) Description Output Value Reference Number 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



64


General Design Requirements (USC Units) Description Input Value Reference Number Application Description Application Site Geographic Location Application Service Application Type Pump Count Design Life Design Conditions MAWP, psia MADP, psia Rated Pressure, psia Rated 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



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Site Integration Testing


Operating Data (USC Units) Description Minimum

Flow Expected Maximum

Flow Attachment

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, µm Sand Rate at Upset Conditions, lbm/d Sand Size at Upset Conditions, µm 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



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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 Gas Oil Recombined Component Mol Percent Mol Percent Mol Percent H2S N2 CO2 CH4 C2H6 C3H8 i-C4H10 n-C4H10 i-C5H10 n-C5H10 Molecular wt. Specific Gravity Hexanes Heptanes Octanes Nonanes Decanes Decanes + Undecanes Dodecanes Tridecanes Tetradecanes Pentadecanes Hexadecanes Heptadecanes Octadecanes Nonadecanes Eicosanes +



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Formation Water Composition (USC Units) Total Dissolved Solids pH Ion Ion mol wt. Charge Range mg/l 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 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 SO4

2- 96.0618 -2 CO3

2- 76.0972 -2 sum



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Motor Design Requirements (USC Units) Description Input Appendix Number Power System Distance to Host Facility, km Line Frequency at Source, Hz Short-Circuit Capacity at Source, MVA Phase Current at Source, A Line Voltage at Source, kV Cooler Design Design Case Seawater Current, ft./s Seawater Salinity, lbm/lbm Design Case Fouling Factor, hr. ft.2∙R/BTU Interface Requirements Power Connection Instrumentation Requirements Motor Torque Key Phasor 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



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Pump Instrumentation Requirements (USC Units) Description Input Value Reference Number 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



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Pump and Motor Mechanical Design Outputs (USC Units) Description Output Value Reference Number 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



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Pump Design Outputs (USC Units) Description Output Value Reference Number Pump Casing Rated Pressure, psia Rated Temperature, oF 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



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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 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 Reference Number 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



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Motor Design Outputs (USC Units) Description Output Value Reference Number Motor Type Rated Power, HP 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, BTU/hr. Area, ft.2 Materials U-Value Used in Design, BTU/(hr.∙ft.2 R) Coating Requirements Coating Details Interface Power Connection Instrumentation Motor Torque Key Phasor Proximity Probes Cooler Inlet Pressure Cooler Inlet Temperature Coolant Flowmeter



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Annex B (Informative)

Qualification Testing

B.1 General Procedure for Qualification Testing

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.

B.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 can meet 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 should be conducted to discover and verify resonant or high vibration conditions.

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.

For this test, the barrier fluid should be uncontrolled at the ambient and pit temperatures as they vary during the test.

The tests are detailed below but are set up to give combinations based on the following example in Table B.1:

Table B. 1―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

20 total 5 Cycles 5 Cycles 5 Cycles 5 Cycles

Allowable start up ramp rate 10 at minimum ramp-up rate 10 at maximum ramp-up rate

Shutdown rate 4 ESD simulations 8 at maximum ramp-down rate 8 minimum ramp-down rate

Minimum suction pressure 10 each



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Maximum suction pressure 10 each Table B.2 lists each parameter for each test.

Table B. 2 ―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 min

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 max

8 min max max max min 15 max min min max max 13 max min min max min 14 max min max min min 19 max max min min min

Monitor all variables specified in 9.3.1. This test will create variations in torque, speed, barrier fluid pressure, process fluid pressure, and vibration levels that should be analyzed for signs of system damage. Produce Bode plots for each cycle.

B.3 Normal Performance Qualification

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

Qualification tests are performed at multiple combinations of the key variables for pump performance:

― set speed



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― 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 Manufacturer and Purchaser.


Set temperature and GVF at design point(s) within the range agreed for qualification of system.

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%

― GVFi within 5 % of desired value for GVF (if not in intermittent flow regime)

― GVFi within 5 % of desired value for GVF (if in intermittent flow regime)

Qualification Test Duration: No less than 15 minutes of additional operation after thermal and pressure equilibria are established by the criteria above in 9.4.

Monitor all variables specified in 9.3.1.

B.4 Liquid Slugging Tolerance

The qualification test is aimed at the minimum scope pump system and is aimed at evaluating its tolerance to GVFi 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

― 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 in a controlled manner to liquid slugs and gas pockets. Because extensive field modelling and dynamic simulation results are required to



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predict a worst-case scenario for the size of GVFi fluctuations and the duration of time in which these changes can occur this qualification test may be 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.

This dynamic test does not have a fixed test point. The pump system should begin operating near the BEP ∆p and flowrate for a given GVF and remain within the operational envelope while responding to changing process conditions.


Process fluid conditions vary, as specified by the agreed test conditions. The GVF is chosen near the design point and varies to simulate liquid slugs and gas pockets per worst-case scenario predictions or agreed criteria.

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.

B.5 Extended Performance Qualification

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.

This set of test points should be repeated for the entire range of process variables claimed by the pump manufacturer. For example, if a pump can run with GVF from 40 % to 60 %, the test points should 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 should 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



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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 B.-1 indicates where each test point lands on the operational envelope. The seven test points should be repeated over the entire range of GVF values for multi‑phase pumps.

Figure B. 1― Location of Test Points on the Operational Envelope



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For this test, the process fluids should be at maximum temperature and GVF.

Table B-3 provides durations for each of the tests.

Table B. 3―Suggested Extended Performance Test Process for Qualification Testing

Scenario Procedure Duration/Cumulative Run time 1. Hot/Cold Start: Start up the pump at ambient temperature

and the process fluid at maximum temperature.

2. 10 Cycles Set I Start up and shutdown the pump ten times including a minimum of five emergency stops.

Run each test point for equal amounts of time for 10 hours qualification giving 100 hours cumulative test time

3. Test Point Extended Performance Set I

Run each of the 7 chosen test points for equal amounts of time

~15 hours per point 100 hours cumulative

4. Hot/Cold Start Repetition

Start up the pump at ambient temperature and the process fluid at maximum temperature.

5. 10 Cycles Set II Start up and shutdown the pump ten times including a minimum of five emergency stops.

6. Test Point Extended Performance Set II



7. 30 Cycles: Start up and shutdown the pump 30 times including a minimum of five emergency stops.

8. Test Point Extended Performance Set III



For items 3, 6, and 8, operate the system at the specified set points until the steady-state conditions are met as described in 9.4 above: No less than fifteen minutes of additional operation are required once the temperatures and pressures are constant.



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Annex C (Informative)

Application Specific Testing

C.1 Start-Up and Shutdown Test

The primary objectives of the test steps listed in Table C.1 are to:

― Identify any damaging oscillatory torque that occurs during start-up ― Confirm that motor can provide the 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 should be conducted to discover and verify resonant or high vibration conditions.

Table C.1―Suggested Start-up and Shut-down Test Process for Application Specific Testing

Scenario Data Points Start cycles at Minimum Settle-out Pressure

Minimum Flowrate @ maximum GVF Maximum Flowrate @ minimum GVF

Start cycles at Maximum Settle-out Pressure Minimum Flowrate @ maximum GVF Maximum Flowrate @ minimum GVF

One Stop cycle at Maximum Suction Pressure Maximum Flowrate @ minimum

10 total 2 each

Allowable start up ramp rate 4 at standard speed ramp-up rate Shutdown rate 2 ESD simulations3 at PSD ramp-down rate Minimum settle-out pressure 4 each Maximum settle-out pressure 4 each

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.

Ambient temperature for test environment as varies during the test.

Table C.2 lists each parameter for each test.

Table C.2―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 max min std PSD min 2 min max std PSD min 3 max min std PSD max 4 min max std PSD max 5 min max std ESD max 6 max min std PSD min



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7 min max std PSD min 8 max min std PSD max 9 min max std PSD max 10 min max std ESD max

Monitor all variables specified in 9.3.1. This test creates variations in torque, speed, barrier fluid pressure, process fluid pressure, and vibration levels that should be analyzed for signs of system damage. Produce Bode plots for each cycle.

C.2 Test of Normal Performance

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 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 Manufacturer and Purchaser.

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 %;

― GVFi within 5 % of desired GVF value (if not in intermittent flow regime) ― GVF within 5 % of desired GVF value (if in intermittent flow regime)

Test Duration: No less than 15 minutes of additional operation after thermal and pressure equilibria are established by the criteria above.

Monitor all variables specified in 9.3.1.



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C.3 Liquid Slugging Mitigation

Confirm that the system responds in a controlled manner 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 GVFi 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 GVFi 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 should 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 Manufacturer and Purchaser. This test does not include the qualification or application specific testing of process or flow conditioning equipment.

This dynamic test does not have a fixed test point. The pump system should begin operating near the BEP ∆p and flowrate for a given GVF and remain within the operational envelope while responding to changing process conditions.


Process fluid conditions vary, as specified by the operator, for specific field conditions. The chosen GVF begins near the design point and varies to simulate liquid slugs and gas pockets per worst-case scenario predictions or agreed criteria.

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 operating 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.

C.4 Extended Performance (Optional)

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.

This set of test points should be repeated for the entire range of GVF values claimed by the pump manufacturer. For example, if a pump can run with GVF from 40 % to 60 %, the test points should be run at the upper and lower GVF values. The number of GVF values to be run between the upper and lower limits should be agreed on by all parties prior to testing.

Test point 1

Speed: midpoint (at the minimum flowrate)/Flowrate: minimum/∆p: midpoint.



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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 C.1 indicates where each test point lands on the operational envelope. The seven test points should be repeated over the entire range of GVF values for multi‑phase pumps.



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Figure C.1―Location of Test Points on the Operational Envelope


For this test, the process fluids should be at maximum temperature and GVF.

Table C.3 provides a sequential suggestion for steps and times for execution of the extended performance test procedures when conducted for application specific testing.



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Table C.3―Suggested Extended Performance Test Process for Application Specific Testing

Scenario Procedure Duration/Cumulative Run time 1. Hot/Cold Start: Start up the pump at ambient

temperature and the process fluid at maximum temperature.

2. 10 Cycles Set I Start up and shutdown the pump ten times including a minimum of five emergency stops.

Run each test point for equal amounts of time for ~7 hours testing giving 50 hours cumulative test time

3. Test Point Extended Performance Set I



4. Hot/Cold Start Repetition Start up the pump at ambient temperature and the process fluid at maximum temperature.

5. 10 Cycles Set II Start up and shutdown the pump ten times including a minimum of five emergency stops.

6. Test Point Extended Performance Set II



7. 30 Cycles: Start up and shutdown the pump 30 times including a minimum of five emergency stops.

8. Test Point Extended Performance Set III



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 9.4 above: No less than fifteen minutes of additional operation are required once the temperatures and pressures are constant.



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Annex D (Informative)

Pump Manufacturing Data Check List and Schedule

Table D.1 - Manufacturer Drawing and Data Requirement List SUBSEA PUMPS JOB ITEM DRAWING & PURCHASE

ORDER DATE

DATA REQUIREMENTS REQUISITION DATE INQUIRY DATE PAGE OF BY API 17X REVISION UNIT FOR SITE SERVICE NUMBER

REQUIRED

Pro

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Des

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FAT/

EFA

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General

P D C C GEN.1 Barrier fluid/cooling system GA & component drawings

P D C C GEN.2 Barrier philosophy document P I C GEN.3 Cause and effect report P D C C GEN.4 Control system and GUI description P D C C GEN.5 Data sheets

P D C C GEN.6 Electrical and instrumentation arrangement drawing and list of connections

P C GEN.7 Export Control Tagging (If required) P D C GEN.8 Flushing system design P D C GEN.9 Inspection Plan P D C GEN.10 List of handling and maintenance tools P D C C GEN.11 List of special tools furnished P I D C GEN.12 Materials specifications and welding procedures

P C C GEN.13 MSDS information on all lubricants, preservatives, and chemicals

P GEN.14 MDR: List of documents, drawings, and other submittals

P I D C GEN.15 Nondestructive testing procedures P C O GEN.16 Performance and current/speed/torque curves P I D C GEN.17 Performance and optional test procedures P I D C GEN.18 Plan, schedule, and progress reports P C C C C GEN.19 Scope of supply drawing P D C C GEN.20 Shipping List P C GEN.21 Spare parts recommendations P D C GEN.21 Tabulation of utility requirements



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SUBSEA PUMPS JOB ITEM DRAWING & PURCHASE

ORDER DATE


REQUIRED

Pro

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Des

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Rev

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Pro

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Des

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FAT/

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T

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O GEN.23 Technology readiness level self-assessment P D C O GEN.24 Vibration Analyses and Data P C C GEN.25 Weight report Verification I C VER.1 Barrier fluid and cooling system dynamic studies I C VER.2 Control system dynamic studies I C VER.3 Damped unbalanced response analyses VER.4 Electrical system response analyses I C VER.5 Lateral critical speed analysis I C VER.6 Thermal expansion C C VER.7 Torsional critical speed analysis MRB C C MRB.1 As-built clearances C MRB.2 Barrier Fluid / Sealing Fluid drawings,

manufacturing data, and bills of materials

C MRB.3 Bearing Assembly drawings, manufacturing data, and bills of materials

C C MRB.4 Certified dimensional outline drawing C MRB.5 Certified hydrostatic test data C MRB.6 Certified rotor balance data C MRB.7 Cooler assembly drawing, manufacturing data,

and bills of materials

C MRB.8 Coupling assembly drawing, manufacturing data, and bills of materials

C MRB.9 Electrical and instrumentation schematics, wiring diagrams, and bills of materials

C MRB.10 Lubricating oil schematic, manufacturing data, and bills of materials

C MRB.11 Material certificates C MRB.12 Mechanical / Shaft seal drawing and bills of

materials

C MRB.13 Primary and auxiliary flushing system schematics and bills of materials

C MRB.14 Rotor assembly drawing, manufacturing data, and bills of materials



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SUBSEA PUMPS JOB ITEM DRAWING & PURCHASE

ORDER DATE


REQUIRED

Pro

posa

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Eng

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ring

Doc

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Sys

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Eng

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ring

Des

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Rev

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/Fre

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Man

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Use

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ual

VD

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N

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Pro

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Des

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FAT/

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C MRB.15 Shaft coupling assembly drawing, manufacturing data, and bills of materials

C C MRB.16 Sub assembly dimensional verification FAT Specific C C FAT.1 Noise and vibration data C C FAT.2 Residual unbalance check C C FAT.3 Rotor mechanical & electrical runout for pumps

with non-contacting vibration probes

C C FAT.4 Noise and vibration data User Manual C USE.1 Allowable flange loadings (can be part of

certified outline drawing)

C USE.2 Cross-sectional drawings and bills of materials C USE.3 Installation, inspection, and retrieval manual C USE.4 Lifting / running procedures, and relevant data C USE.5 List of handling and maintenance tools C USE.6 Operation and maintenance manual C USE.7 Preservation, packaging, and shipping

procedures

C USE.8 ROV Panel images and drawings



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D.1 Details

The entries above are described in more detail in Table D,2, which provides guidelines as to the intended content of each entry.

Table D.2―Details and Comments to Table 12

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Description

General

GEN.1 Barrier fluid/cooling system GA and component drawings

Document should describe − pumps − reservoirs and accumulators − valves − tubing − coolers

GEN.2 Barrier philosophy report

Document should describe physical safety barriers as implemented in design − isolation valves − caps − check valves (and test procedures if accepted by Purchaser)

Document and illustrations should describe barriers for items as installed as well as barriers on the retrieved and unretrieved portions of the pump module and subsea facility

GEN.3 Cause and effect report



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Description

Document should describe: − alarms − shutdown limits − operational setpoints − operational sequencing.

GEN.4 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. − system interlocks

GEN.5 Data sheets

Data sheets applicable to proposals, purchase and as-built Including auxiliary systems, single line, and wiring diagrams

GEN.6 Electrical and instrumentation arrangement drawing and list of connections

GEN.7 Export control tagging document

GEN.8 Flushing system design

GEN.9 Inspection Plan

GEN.10 List of handling and maintenance tools



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Description

GEN.11 List of special tools furnished

GEN.12 Materials specifications and welding procedures

GEN.13 MSDS information on all lubricants, preservatives, and chemicals

GEN.14 MDR: List of documents drawings and submittals

GEN.15 Nondestructive testing procedures

GEN.16 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 (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



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Description

− 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.17 Performance and optional test procedures

GEN.18 Plan, schedule, and progress reports

Progress reports and delivery schedules, including manufacturer buy-outs and milestones, progress reports detailing the cause of any delays: the reports should include engineering, purchasing, manufacturing and testing schedules for all major components. Planned and actual dates, and the percentage completed, should be indicated for each milestone in the schedule.

GEN.19 Scope of supply drawing

The drawings should indicate the extent of the system to be supplied by Manufacturer and the extent to be supplied by others.

GEN.20 Shipping List

Shipping list, including all major components that will ship separately.

GEN.21 Spare parts recommendations



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Description

GEN.22 Tabulation of utility requirements

Tabulation of utility requirements including power, coolant, lubricant, chemicals, and heat loads

GEN.23 Technology readiness level self-assessment

GEN.24 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.25 Weight report

The document should 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

The document to cover agreed application specific scenarios: − steady-state − transient

Each to include system-wide flow and pressure responses at each use point and agreed operational transients. These analyses should also include steady-state and thermal transient details of the cooler design.

VER.2 Control system dynamic studies



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Description


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 should be supplied prior to systems engineering review, no later than 3 months after the date of order.

VER.4 Electrical system response analyses


Each to include system-wide responses at each use point and agreed operational transients

VER.5 Lateral critical speed analysis


VER.6 Pressure casing, piping and thermal expansion evaluations

The document to cover agreed application specific scenarios: − steady-state pressure containment − transient pressure responses − erosion evaluations − surge, slug, and water-hammer − piping vibration including hydraulic and chemical tubing



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Description

VER.7 Torsional critical speed analysis


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

MRB.4 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 bolt holes and thicknesses of sections through which bolts should 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 centerline height; − shaft end dimensions, plus tolerances for the coupling; − direction of rotation. − size and locations of external alignment devices (guideposts, pins, etc.)



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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

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



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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

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, centers of gravity and details of lifting lugs

USE.5 List of handling and maintenance tools



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USE.6 Operation and maintenance manual

Operation and maintenance manual should 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



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Bibliography

[1] API Specification 17E, Specification for Subsea Umbilicals.

[2] API Recommended Practice 17N, Recommended Practice for Subsea Production System Reliability and Technical Risk Management

[3] API RP 17Q, Subsea Equipment Qualification—Standardized Process for Documentation

[4] API Recommended Practice 17R, Recommended Practice for Flowline Connectors and Jumpers

[5] API Recommended Practice 17S, Recommended Practice for the Design, Testing, and Operation of Subsea Multiphase Flow Meters

[6] API Specification 20B, Open Die Shaped Forgings for Use in the Petroleum and Natural Gas Industry

[7] API Specification 20C, Closed Die Shaped Forgings for Use in the Petroleum and Natural Gas Industry

[8] API Standard 676, Positive Displacement Pumps—Rotary, Third Edition, November 2009.

[9] API Standard 674, Positive Displacement Pumps—Reciprocating

[10] API Standard 675, Positive Displacement Pumps - Controlled Volume for Petroleum, Chemical, and Gas Industry Services

[11] API Standard 682, Pumps―Shaft Sealing Systems for Centrifugal and Rotary Pumps

[12] API Standard 685, Sealless Centrifugal Pumps for Petroleum, Heavy Duty Chemical, and Gas Industry Process Services

[13] API Technical Report 17TR8 High-pressure, High-Temperature Design Guidelines

[14] API Technical Report 17TR9 Subsea Umbilical Termination (SUT) Selection and Sizing Recommendations

[15] API Technical Report 17TR10 Subsea Umbilical Termination (SUT) Design Recommendations

[16] ASME, Boiler and Pressure Vessel Code, Section VIII Div.2: Rules for Construction of Pressure Vessels, Alternative Rules

[17] ASME Boiler and Pressure Vessel Code, Section VIII Div.3: Rules for Construction of Pressure Vessels, Alternative Rules for Construction of High Pressure Vessels

[18] ISO 9712, Non-destructive testing -- Qualification and certification of personnel

[19] ISO 17782, Petroleum, petrochemical and natural gas industries -- Qualification of manufacturers of special materials



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[20] NORSOK M-0015: Materials selection

[21] NORSOK M-650: Qualification of manufacturers of special materials [22] SEPS SP-10016, Power connectors, penetrators and jumper assemblies with rated voltage from 3

kV (Umax = 3.6 kV) to 30 kV (Umax = 36 kV)

5 Norsk Sokkels Konkuranseposisjon, Standards Norway, Strandveien 18, Postboks 252, 1326 Lysaker, Norway,

www.standard.no 6 Subsea Electrical Power Standardization, OTM Consulting, Ltd, Great Burgh, Yew Tree Bottom Rd., Epson KT18 5XT, UK



101

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Washington, DC 20005-4070

USA

202.682.8000

Additional copies are available through IHS

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Fax Order: 303-397-2740

Online Orders: Global.ihs.com

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Is available on the web at www.api.org

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