THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED Recommended Practice for Subsea Pumps RECOMMENDED PRACTICE 17X FIRST EDITION, XXXX 2016 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X II Special Notes API publications necessarily address problems of a general nature. With respect to particular circumstances, local, state, and federal laws and regulations should be reviewed. Neither API nor any of API's employees, subcontractors, consultants, committees, or other assignees make any warranty or representation, either express or implied, with respect to the accuracy, completeness, or usefulness of the information contained herein, or assume any liability or responsibility for any use, or the results of such use, of any information or process disclosed in this publication. Neither API nor any of API's employees, subcontractors, consultants, or other assignees represent that use of this publication would not infringe upon privately owned rights. API publications may be used by anyone desiring to do so. Every effort has been made by the Institute to assure the accuracy and reliability of the data contained in them; however, the Institute makes no representation, warranty, or guarantee in connection with this publication and hereby expressly disclaims any liability or responsibility for loss or damage resulting from its use or for the violation of any authorities having jurisdiction with which this publication may conflict. API publications are published to facilitate the broad availability of proven, sound engineering and operating practices. These publications are not intended to obviate the need for applying sound engineering judgment regarding when and where these publications should be utilized. The formulation and publication of API publications is not intended in any way to inhibit anyone from using any other practices. Any manufacturer marking equipment or materials in conformance with the marking requirements of an API standard is solely responsible for complying with all the applicable requirements of that standard. API does not represent, warrant, or guarantee that such products do in fact conform to the applicable API standard. ii THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X III Foreword Nothing contained in any API publication is to be construed as granting any right, by implication or otherwise, for the manufacture, sale, or use of any method, apparatus, or product covered by letters patent. Neither should anything contained in the publication be construed as insuring anyone against liability for infringement of letters patent. This document was produced under API standardization procedures that ensure appropriate notification and participation in the developmental process and is designated as an API standard. Questions concerning the interpretation of the content of this publication or comments and questions concerning the procedures under which this publication was developed should be directed in writing to the Director of Standards, American Petroleum Institute, 1220 L Street, N.W., Washington, D.C. 20005. Requests for permission to reproduce or translate all or any part of the material published herein should also be addressed to the director. Generally, API standards are reviewed and revised, reaffirmed, or withdrawn at least every five years. A one-time extension of up to two years may be added to this review cycle. Status of the publication can be ascertained from the API Standards Department, telephone (202) 682-8000. A catalog of API publications and materials is published annually by API, 1220 L Street, N.W., Washington, D.C. 20005. Suggested revisions are invited and should be submitted to the Standards Department, API, 1220 L Street, NW, Washington, D.C. 20005, standards@api.org. iii 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 IV Contents 1 Scope ............................................................................................................................................... 1 2 References ....................................................................................................................................... 2 3 3.1 3.2 Terms, Definitions, and Abbreviations ............................................................................................. 5 General............................................................................................................................................. 5 Acronyms and Abbreviations ......................................................................................................... 17 4 4.1 4.2 Systems and Interface Descriptions .............................................................................................. 22 General........................................................................................................................................... 22 Classification and Designation ....................................................................................................... 23 5 5.1 5.2 5.3 Requirements ................................................................................................................................. 24 Units ............................................................................................................................................... 24 Statutory Requirements ................................................................................................................. 24 Requirements ................................................................................................................................. 24 6 6.1 6.2 6.3 6.4 6.5 6.6 6.7 6.8 6.9 6.10 6.11 Motorpump Unit Design ................................................................................................................. 25 General............................................................................................. Error! Bookmark not defined. Pump Types ................................................................................................................................... 27 Pressure Casings ........................................................................................................................... 32 Internal Pump Components ........................................................................................................... 34 Mechanical Shaft Seals.................................................................................................................. 35 Rotordynamics ............................................................................................................................... 37 Bearings and Bearing Housings .................................................................................................... 38 Motor .............................................................................................................................................. 39 Couplings and Guards ................................................................................................................... 44 Motor Cooling Systems .................................................................................................................. 48 Barrier and Lubrication System ...................................................................................................... 49 7 7.1 7.2 7.3 Pump Control, Protection and Monitoring Systems ....................................................................... 50 General........................................................................................................................................... 50 Functional Requirements for Control Systems .............................................................................. 50 Functional Requirements for Monitoring Systems ......................................................................... 51 8 8.1 8.2 8.3 8.4 8.5 8.6 8.7 Installation and Intervention ........................................................................................................... 53 Installation/Retrieval Considerations .............................................................................................. 53 Transportation and Testing Equipment .......................................................................................... 54 Preservation and Storage .............................................................................................................. 55 Pump Module Structure ................................................................................................................. 56 Pressure-Limiting Valves ............................................................................................................... 57 Piping and Appurtenances ............................................................................................................. 58 Special Tools .................................................................................................................................. 59 9 9.1 9.2 9.3 Qualification and Application Specific Testing ............................................................................... 60 Scope ............................................................................................................................................. 60 Individual Tests .............................................................................................................................. 64 Pump Acceptance Criteria ............................................................................................................. 66 iv THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X V 10 10.1 10.2 10.3 10.4 10.5 10.6 10.7 10.8 10.9 Materials and Materials Inspection ................................................................................................ 68 Scope ............................................................................................................................................. 68 Connectors, Piping, Valves, and Structure .................................................................................... 68 Fasteners ....................................................................................................................................... 68 Written Specifications: Pump and Motor Casing ........................................................................... 69 Property Requirements: Pump and Motor Casing ......................................................................... 70 Processing: Pump and Motor Casing ............................................................................................ 70 Manufacturing Quality Control: Pump and Motor Casing .............................................................. 70 Non-destructive Examination Personnel ........................................................................................ 70 Pump Internals: Materials Considerations ..................................................................................... 72 11 11.1 11.2 11.3 Manufacturing, Inspection, and Preparation for Shipment............................................................. 74 General........................................................................................................................................... 74 Inspection and FAT Testing ........................................................................................................... 74 Preparation for Shipment ............................................................................................................... 80 12 12.1 12.2 Vendor’s Data ................................................................................................................................ 83 General........................................................................................................................................... 83 Details ............................................................................................................................................ 87 Annex A Qualification Testing .................................................................. Error! Bookmark not defined. Annex B Application Specific Testing ...................................................... Error! Bookmark not defined. Annex C Pump Design Data Sheets ........................................................ Error! Bookmark not defined. Bibliography .............................................................................................................................................. 132 v THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X VI List of Figures: Figure 1 - Subsea Pump System ................................................................................................................ 22 Figure 2 - Example Acceptable Suction GVF Limit as it Applies to a Single Stage Pump with a Conventional Flow Path. ............................................................................................................................. 29 Figure 3: Example Acceptable Suction GVF Limit as it applies to both Single-Stage and Multi-Stage Pumps ......................................................................................................................................................... 29 Figure 4 - Decision Tree for Testing ........................................................................................................... 63 Figure 5 - Vibration Limits for Subsea Rotodynamic Pumps and Motors, GVF < 40% .............................. 77 Figure 6 - Vibration Limits for Subsea Rotodynamic Pumps and Motors, GVF > 40% .............................. 78 Figure 7 - Rotor Overall Vibration Limits and Maximum Probe Target Run-out for Subsea Pumps and Motors Operating with Single‑phase or Multi‑phase GVF < 40% .............................................................. 79 Figure 8 - Rotor Overall Vibration Limits and Maximum Probe Target Run-out for Subsea Pumps and Motors Operating with Multi‑phase GVF > 40% ......................................................................................... 80 Figure 9 - Location of Test Points on the Operational Envelope .............................................................. 103 List of Tables: Table 1 - Pump Classification Type Identification ....................................................................................... 23 Table 2 - Classification by Installation Depth .............................................................................................. 27 Table 3 - Classification by Sea Water Temperature ................................................................................... 27 Table 4 - Classification by Process Fluid Temperature (Table is expanded from API 6A Table 2) ............ 27 Table 5 - Recommended Service Factors for Single-Phase Pumps .......................................................... 27 Table 6 - Recommended Service Factors for Multi‑phase Pumps............................................................. 31 Table 7 - Casing Pressure Design Class .................................................................................................... 32 Table 8 - Insulation Thermal Classes used for Subsea Motors .................................................................. 43 Table 9 - Motor Shaft and Housing Run-out Limits ..................................................................................... 46 Table 10 - Scope of Test Object ................................................................................................................. 62 Table 11 - Inspection Classes as they apply to API 17X ............................................................................ 71 Table 12 - Vendor Drawing and Data Requirement List ............................................................................. 85 Table 13 - Details and Comments to Table 13 ........................................................................................... 88 Table 14 - Suggested Start-up and Shut-down Test Process for Qualification Testing ............................. 98 Table 15 - Suggested Start-up and Shut-down Test Order for Qualification Testing ................................. 99 Table 16 - Suggested Extended Performance Test Process for Qualification Testing............................. 104 Table 17 - Suggested Start-up and Shut-down Test Process for Application Specific Testing ................ 106 Table 18 - Suggested Start-up and Shut-down Test Order for Application Specific Testing .................... 106 Table 19 - Suggested Extended Performance Test Process for Application Specific Testing ................. 110 vi THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X VII Introduction It is necessary that users of this Standard be aware that further or differing requirements can be needed for individual applications. This Standard is not intended to inhibit a vendor from offering, or the purchaser from accepting, alternative equipment or engineering solutions for the individual application. This can be particularly appropriate where there is innovative or developing technology. Where an alternative is offered, it is necessary that the vendor identify any variations from this Standard and provide details. A bullet (•) at the beginning of a clause or sub-clause indicates that either a decision is required or the purchaser is required to provide further information. It is necessary that this information should be indicated on data sheets or stated in the enquiry or purchase order. In this Standard, where practical, US Customary, or other units are included in parentheses for information. vii 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 1 Scope This Standard recommends requirements for subsea pumps, including single phase, hybrid, and multi‑ phase. Reference is made to API 610, 674, 675, 676, and 685 for the various components that may be incorporated into subsea pump systems. The Standard applies to all subsea placed at or above the muddling and includes hydraulic expanders (pumps running in reverse as hydraulic power recovery turbines, for use in petroleum, petrochemical and gas industry process services). The standard describes typical subsea requirements with a scope including: – – – Subsea pump units Motors for subsea pumps Minimum requirements for relevant auxiliaries (power, control, barrier fluids and lubricants) Equipment selection, pump station layout and design are not within the scope of this document. Exceptions to this standard must be defined and agreed between vendor and purchaser. 1 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 2 2 References The following referenced documents are indispensable for the application of this document. For dated references, only the edition cited applies. For undated references, the latest edition of the referenced document (including any amendments) applies. 1 AGMA 9002 : Bores and Keyways for Flexible Couplings (Inch Series) 2 ANSI /API STD 682/ISO 21049, Shaft Sealing Systems for Centrifugal and Rotary Pumps 3 ANSI/HI 9.6.7 Rotodynamic Pumps - Guideline for Effects of Liquid Viscosity on Performance API RP 14E, Recommended Practice for Design and Installation of Offshore Production Platform Piping Systems API RP 17N, Recommended Practice for Subsea Production System Reliability and Technical Risk Management API RP 17P, Design and Operation of Subsea Production Systems—Subsea Structures and Manifolds API RP 17Q, Subsea Equipment Qualification—Standardized Process for Documentation API RP 17R, Recommended Practice for Flowline Connectors and Jumpers API Spec 6A, Specification for Wellhead and Christmas Tree Equipment API Spec 17D, Design and Operation of Subsea Production Systems—Subsea Wellhead and Tree Equipment API Spec 20B, Open Die Shaped Forgings for Use in the Petroleum and Natural Gas Industry API Spec 20C, Closed Die Shaped Forgings for Use in the Petroleum and Natural Gas Industry API Spec 20D, Nondestructive Examination Services for Equipment Used in the Petroleum and Natural Gas Industry API Spec 20E, Alloy and Carbon Steel Bolting for Use in the Petroleum and Natural Gas Industries API Spec 20F, Corrosion Resistant Bolting for Use in the Petroleum and Natural Gas Industries API Spec 685, Sealless Centrifugal Pumps for Petroleum, Petrochemical, and Gas Industry Process Service API STD 17F, Specification for Subsea Production Control Systems 1 2 3 American Gear Manufacturers Association, 1001 N. Fairfax St. Suite 500, Alexandria, VA 22314-1587, USA, www.agma.org American National Standards Institute, 1889 L St, NW, Washington DC, 20036, USA, www.ansi.org. Hydraulic Institute, 6 Campus Drive, First Floor North, Parsippany, NJ 07054, USA, pumps.org 2 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 3 API STD 547, General-purpose Form-wound Squirrel Cage Induction Motors-250 Horsepower and Larger, First Edition API STD 610, Centrifugal Pumps for Petroleum, Petrochemical and Natural Gas Industries API STD 614, Lubrication, Shaft-sealing and Oil-control Systems and Auxiliaries API STD 671, Special-Purpose Couplings for Petroleum, Chemical, and Gas Industry Services API STD 675, Positive Displacement Pumps - Controlled Volume for Petroleum, Chemical, and Gas Industry Services API STD 676, Positive Displacement Pumps—Rotary API RP 686, Machinery Installation and Installation Design 4 ASME VIII Div.2 : Rules for Construction of Pressure Vessels, Alternative Rules ASME VIII Div.3: Rules for Construction of Pressure Vessels, Alternative Rules for Construction of High Pressure Vessels 5 ASNT SNT-TC-1A-2016 , Topical Outlines for Qualification of Nondestructive Testing Personnel 6 ASTM D1418 - 10a(2016) , Standard Practice for Rubber and Rubber Latices—Nomenclature 7 IEC 60038 , IEC Standard Voltages IEC 60085, Electrical insulation - Thermal evaluation and designation 8 ISO 7-1 , Pipe threads where pressure-tight joints are made on the threads — Part 1: Dimensions, tolerances and designation ISO 228-1, Pipe threads where pressure-tight joints are not made on the threads — Part 1: Dimensions, tolerances and designation ISO 1940-1:2003, Mechanical vibration -- Balance quality requirements for rotors in a constant (rigid) state -- Part 1: Specification and verification of balance tolerances ISO 9712, Non-destructive testing -- Qualification and certification of personnel 4 5 6 7 8 The American Society of Mechanical Engineers: Two Park Ave. New York, NY 10016 USA, www.asme.org. The American Society for Nondestructive Testing, P.O. Box 28518, 1711 Arlingate Late, Columbus, OH 43228-0518, USA, www.asnt.org American Society for Testing and Materials, 100 Barr Harbor Dr., P.O. Box C700, West Conshocken, PA, 19428-2959 USA, www.astm.org International Electrotechnical Commission, 3, rue de Varembé, Case postale 131, CH-1211, Geneva, Switzerland, www.iec.org. International Organization for Standardization, 1, ch. De la Voie-Creuse, Case postale 56, CH-1211, Geneva, Switzerland, www.iso.org. 3 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 4 ISO 10441: 2007, Petroleum, petrochemical and natural gas industries -- Flexible couplings for mechanical power transmission -- Special-purpose applications ISO 14691:2008, Petroleum, petrochemical and natural gas industries -- Flexible couplings for mechanical power transmission -- General-purpose applications ISO/TR 17766, Centrifugal pumps handling viscous liquids — Performance corrections ISO 17782, Petroleum, petrochemical and natural gas industries -- Qualification of manufacturers of special materials 9 NACE MR 0103 , Materials Resistant to Sulfide Stress Cracking in Corrosive Petroleum Refining Environments 10 NEMA MG 1-2014 , Motors and Generators 11 NORSOK M-650 : Qualification of manufacturers of special materials (Rev. 4, September 2011) 12 SEPS SP-1001 , Power connectors, penetrators and jumper assemblies with rated voltage from 3 kV (Umax = 3.6 kV) to 30 kV (Umax = 36 kV) 9 10 11 12 National Association of Corrosion Engineers, Houston, Texas, USA. National Electrical Manufacturers Association, 1300 North 17th St. Ste 900, Arlington VA 22209, USA, www.nema.org The Norwegian shelf’s competitive position, Standard Norge, Postboks 252, 1326 Lysaker, Norway. www.standard.no Subsea Electrical Power Standardization, OTM Consulting, Ltd, Great Burgh, Yew Tree Bottom Rd., Epson KT18 5XT, UK 4 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 5 3 Terms, Definitions, and Abbreviations 3.1 General For the purposes of this document, the following terms and definitions apply. 3.1.1 acceptance criteria Defined limits placed on characteristics of materials, products or services. 3.1.2 allowable operating region Portion of a pump's hydraulic coverage over which the pump is allowed to operate, based on vibration within the upper limit of this Recommended Practice or temperature rise or other limitation, specified by the vendor. 3.1.3 ambient Environmental temperature at test facility at test installation (water temperature if submerged). 3.1.4 ampacity The current carrying capacity of an electrical conductor at a given temperature. 3.1.5 application specific testing Process by which a repeat manufacture system (or sub-system) is tested against the original qualification criteria and application specific objectives NOTE Application specific performance maps may be generated. See API 17N. 3.1.6 axially split Split with the principal joint parallel to the shaft centerline 3.1.7 barrier fluid Fluid used to maintain a positive pressure within pump-motor cavities isolated by sealing mechanisms from ambient seawater and production fluids, and to lubricate mechanical pump components 3.1.8 best efficiency point BEP Flowrate at which a pump achieves its highest efficiency at rated impeller diameter NOTE The best efficiency point flowrate at maximum impeller diameter is used to determine pump specific speed and suction specific speed. The best efficiency point flowrate at reduced impeller diameters is similarly reduced from the value at maximum impeller diameter. 5 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 6 3.1.9 body Any portion of wellhead and Christmas tree equipment between end connections, with or without internal parts, which contains well-bore pressure NOTE See API 6A. 3.1.10 bolting specification level BSL Term used to describe a method for determining testing and documentation levels required to reduce risk associated with manufacturing quality 3.1.11 bonding Connecting or joining of metal parts to form an electrically conductive and continuous path to conduct safely any current likely to be imposed 3.1.12 carbon steel Alloy of carbon and iron containing a maximum of 2 % mass fraction carbon, 1.65 % mass fraction manganese, and residual quantities of other elements, except those intentionally added in specific quantities for deoxidation (usually silicon and/or aluminum) 3.1.13 casting (noun) Object at or near finished shape obtained by solidification of a fluid substance in a mold 3.1.14 chemical analysis Determination of the chemical composition of material 3.1.15 closed-loop control system Control system in which the output has an effect on the input, in such a way as to maintain the desired output value NOTE A closed-loop system includes some way to measure its output to sense changes so that corrective action can be taken. In the case of subsea booster pump controls, the closed-loop control system is in charge of maintaining a desired pump output using a reference input such as pump suction pressure. 3.1.16 closure bolting Threaded fastener used to assemble pressure-containing parts or join end or outlet connections 3.1.17 corrosion resistant alloy CRA Nonferrous-based alloy in which any one or the sum of the specified amount of the elements titanium, nickel, cobalt, chromium, and molybdenum exceeds 50 % mass fraction 6 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 7 3.1.18 date of manufacture Date of vendor's final acceptance of finished equipment 3.1.19 direct drive power system Subsea power system in which a single booster pump or other single load is powered directly from the power source (generally a VFD) on the platform without transformers in the power train 3.1.20 earthed (EU Usage) Connected (bonded) to earth by means of earth electrodes (rods) NOTE See definition for “Grounded US” 3.1.21 earthing Intentional means to minimize the resistance of a ground grid or earth electrode to “infinite earth” (i.e., a voltage reference point = 0) 3.1.22 “Effectively-Grounded” system Grounding mode or characteristic of a three-phase system which is grounded through a grounding device of sufficiently low impedance to limit transient line-to-ground over-voltages due to ground faults to limits established for the power system components NOTE In terms of symmetrical components, an “effectively grounded –system” is where grounding is through a sufficiently low impedance such that for all system conditions the ratio of zero sequence reactance to positive sequence reactance (Xo/Xl) is positive and less than 3, and the ratio of zero sequence resistance to positive-sequence reactance (R0/Xl) is positive and less than 1. 3.1.23 electrode Especially designed conductor in intimate contact with earth for the purpose of providing a connection with the earth NOTE Also referred to as “ground rod” or “ground electrode”. 3.1.24 fault Any abnormal flow of electric current in an electric power system NOTE 1 For example, a fault could be a condition where current is flowing in a different path and/or at a level exceeding that used during normal operation. NOTE 2 Three Fault conditions are defined where some measure of design enhancement must take place to ensure survival of the umbilical, as well as all other current carrying components, in an unexpected electrical situation. 7 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 8 3.1.25 forging specification level FSL Term used to describe a method for determining testing and documentation levels required to reduce risk associated with manufacturing quality 3.1.26 gas liquid ratio GLR Ratio of the volume of gas to the volume of total liquid (oil and water only) at pump suction pressure and temperature 3.1.27 gas oil ratio GOR Ratio of gas in a well stream expressed in standard cubic meters of gas per stock tank cubic meter of oil, 3 3 3 Sm /Sm in SI units or standard cubic feet of gas per stock tank barrel of oil, ft /bbl in USC units NOTE The value is derived by performing a single-stage phase calculation or experiment of the whole stream fluid at standard conditions. 3.1.28 gas volume fraction GVF Ratio of the volume of gas to the total fluid volume (gas, oil and water) at pump suction temperature and pressure 3.1.29 ground Conducting connection whether intentional or unintentional between an electrical circuit or equipment item and the earth or to some other body that serves in place of the earth (NEC Definition) 3.1.30 ground fault Unintended current flow, usually thru insulation, between an energized conductor and ground 3.1.31 grounded (US) Intentional or unintentional connection to earth or to an extended conducting body that serves in place of the earth NOTE See definition for “earthed” 3.1.32 grounding Act of connecting (bonding) equipment or hardware to a ground grid or electrode 8 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 9 3.1.33 grounding–island That portion of a neutral-grounded system within which a ground-fault current (I0) flows as an outgoing unbalanced phase current and returns in a ground-return path to its source neutral (i.e., transformer or generator) and can be detected by ground-current-responsive devices NOTE External to a grounding-island, its ground-fault current is converted (by specific transformer connections) into equal outgoing and return phase currents, and thus not detectable by ground-fault protective devices. 3.1.34 grounding-system System that consists of all interconnected grounding connections and defined by its isolation from adjacent grounding systems 3.1.35 ground-return conductor Normally non-current carrying metal components of the system, used to conduct ground fault current back to its source 3.1.36 ground-return path Path in earth or other conductive channels that ground fault currents will naturally return from the point of fault to the grounded neutral of the power source such a transformer or generator. EXAMPLE NOTE Motor starting current; Typically, the power conductors should be rated for 125% of the expected current. In some subsea power systems, it may be desirable to increase this rating even further. 3.1.37 hot isostatic pressing HIP Manufacturing process used to reduce the porosity and increase the density of metal castings, consolidated powders, or sintered parts 3.1.38 hydrostatic pressure Maximum external pressure of ambient ocean environment (maximum water depth) that equipment is designed to contain and/or control 3.1.39 hydrostatic body test pressure Pressure to which a body shall be tested to very pressure containment. Applied to all production items having a product specification level of 2 or higher NOTE For all pressure ratings, the hydrostatic body test pressure shall be a minimum of 1.5 times the rated working pressure. The acceptance criterion for hydrostatic pressure tests shall be no visible leakage during the hold period. If a pressure-monitoring gauge and/or a chart recorder is used for documentation purposes, the chart record should show an acceptable pressure settling rate not exceeding 3 % of the test pressure per hour. The final settling pressure shall not fall below the test pressure before the end of the test hold period. Initial test pressure shall not be greater than 5 % above the specified test pressure. 9 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 10 3.1.40 identical pump Pump of the same size, hydraulic design, number of stages, rotational speed, clearances, type of shaft seal (axial face or breakdown bushing), type of bearings, coupling mass, coupling overhang, and pumping the same liquid 3.1.41 life-of-field Full range of operation of hydrocarbon asset, from first production to abandonment 3.1.42 maximum allowable speed Highest speed at which the vendor's design permits continuous operation 3.1.43 maximum allowable temperature Maximum continuous temperature for which the vendor has designed the pump (or any part to which the term is referred) when pumping the specified liquid at the specified maximum operating pressure (does not include mechanical seal) 3.1.44 maximum allowable working pressure MAWP Maximum continuous pressure for which the vendor has designed the pump (or any part to which the term is referred) when pumping the specified liquid at the specified maximum operating temperature (does not include mechanical seal) 3.1.45 maximum discharge pressure Maximum specified suction pressure plus the maximum differential pressure the pump with the furnished impeller is able to develop when operating at rated speed with liquid of the specified normal relative density (specific gravity) 3.1.46 maximum operating temperature Highest temperature of the pumped liquid, including upset conditions, to which the pump is exposed 3.1.47 maximum suction pressure Highest suction pressure to which the pump is subjected during operation (non-transient; does not include water-hammer) 3.1.48 minimum allowable speed Lowest speed (in rpm) at which the vendor's design permits continuous operation 3.1.49 minimum continuous flow Lowest flow at which the pump can operate without exceeding the vibration limits imposed by this document 10 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 11 3.1.50 minimum continuous thermal flow Lowest flow at which the pump can operate without its operation being impaired by the temperature rise of the pumped liquid 3.1.51 minimum design metal temperature Lowest mean metal temperature (through the thickness) expected in service, including operation upsets, auto-refrigeration and temperature of the surrounding environment, for which the equipment is designed 3.1.52 multistage pump Pump with three or more stages 3.1.53 neutral Common return point of an AC power supply (such as a transformer or generator) which can be grounded 3.1.54 net positive suction head NPSH Total absolute suction head determined at the suction nozzle and referred to the datum elevation minus the head of the vapor pressure of the fluid NOTE It is expressed as head of water, in meters (feet). 3.1.55 Net positive suction head available NPSHA Minimum value of NPSH determined to be available under any specified operation condition, accounting for line losses, under steady state flow conditions NOTE NPSHA is a value provided by the purchaser. 3.1.56 net positive suction head required Minimum value of NPSH determined to be required under any specified operation condition, based on steady state flow NOTE NPSHR is a value provided by the vendor by taking the equipment requirements, which are based on the centerline of inlet reference point, and adjusting it to the underside of the baseplate. 3.1.57 open-loop control system Control system in which the output has no effect on the input. In the case of subsea booster pump controls, the open-loop control system is typically at the main pump HMI and is in charge of relaying manual inputs and platform-generated shutdowns 3.1.58 operating region Portion of a pump's hydraulic coverage over which the pump operates 11 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 12 3.1.59 Overload Fault condition where more than nominal steady state rated current is flowing, to and from the load through its assigned path 3.1.60 overload A condition where more than steady state rated current is flowing, but all current is flowing to the electrical load through its assigned path EXAMPLE Motor starting current 3.1.61 performance est Running test conducted to measure flow rate, differential pressure, and power consumed at specified conditions 3.1.62 per–phase charging Current (IC0) Current (Vl-n /XC0) that passes through one phase of the system to charge the distributed capacitance per phase-to-ground of the system. NOTE Vl-n is the line-to-neutral voltage and XC0 is the per-phase distributed capacitive reactance of the system. 3.1.63 phase-to-ground fault Condition where some or all of the current from one phase is moving back to the source through a ground/ neutral path ground NOTE 1 A phase-to-ground fault causes the phase-to-ground voltage of the unaffected phase conductors to be higher than normal. The Recommended Practice way to combat this situation requires increasing the insulation rating of all power system components, including power cable terminations/ connectors/ penetrators and booster pump windings. NOTE 2 A phase-to-ground fault may or may not necessitate stopping operation of the booster pump. Some systems are built to operate with one phase continuously faulted to ground. EXAMPLE Failure of a wet mate connector such that phase A is in direct contact with the connector case, and thus the seawater. Once a phase-to-ground fault has occurred, the booster pump system (if so designed) can continue operation. However, the umbilical must be sufficiently rated to survive the phase to ground fault indefinitely. 3.1.64 phase-to-phase fault or short circuit Condition where two or more of the 3-phases are connected directly together or to earth ground and maximum current is flowing EXAMPLE Failure of the motor windings such that phase A and phase B come in direct contact with each other. Once a phase-to-phase fault has occurred, the booster pump system is no longer operational. The umbilical must be sufficiently rated to survive the duration of the fault until the circuit protection system de-energizes the power system. 12 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 13 3.1.65 planned intervention Repair or replacement of subsea equipment where the impending failure of the equipment was anticipated and replacement equipment, installation vessels, and personnel were ready to perform the repair prior to shut in of production 3.1.66 platform Generic term for any floating vessel or fixed structure where topside equipment can be housed above water 3.1.67 preferred operating region Portion of a pump's hydraulic coverage over which the pump's vibration is within the base limit of this document 3.1.68 pressure casing Composite of all stationary pressure-containing parts of the pump, including all nozzles, seal glands, seal chambers and auxiliary connections but excluding the stationary and rotating members of mechanical seals 3.1.69 pressure containing part Part whose failure to function as intended results in a release of wellbore fluid to the environment 3.1.70 pressure controlling part Part intended to control or regulate the movement of pressurized fluids 3.1.71 product specification level PSL Term used to describe a method for determining testing and documentation levels required to reduce risk associated with manufacturing quality 3.1.72 pump manifold Permanent structure installed subsea which provides piping/flow base for hosting a subsea Pump Module and interfaces with the subsea field architecture. NOTE Pump Manifold structure includes any flow conditioning hardware-recycle system or pump bypass piping and all associated process connectors, valves and interface for outboard manifold power, control and communication. 3.1.73 pump module Retrievable structure, hosted in the Pump Manifold, which includes the pump and motor assemblies. 13 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X NOTE 14 The Pump Module also includes key subsystems (where applicable) such as the Barrier Fluid System, Pump Controls, any machinery condition monitoring equipment, high voltage connectors, interface panel, a soft landing system etc. 3.1.74 pump installation That which contains all systems and subsystems that are necessary to deploy and operate a subsea pumping module NOTE 1 Some of this systems and subsystems, like the VSDs, HPUs, Control Systems, etc. may be located topsides while others may be deployed subsea NOTE 2 See Figure1 3.1.75 rated operating point Point at which the vendor certifies that pump performance is within the tolerances stated in this document NOTE: Normally, the rated operating point is the specified operating point with the highest flow. 3.1.76 qualification Process by which a new or significantly modified system (or sub-system) is verified as applicable for use including the generation of standard-case performance maps NOTE See API 17N. 3.1.77 rated operating point Point at which the vendor certifies that pump performance is within the tolerances stated in this Recommended Practice 3.1.78 rated power Power delivered to the pump input shaft at rated operating point. It is also called brake power (brake horsepower, brake kilowatts, etc.) 3.1.79 rated pump efficiency Pump efficiency at rated operating point NOTE See pump efficiency. 3.1.80 rated speed Highest rotational speed (rpm) required to meet any of the specified operating conditions 3.1.81 rated volumetric efficiency Volumetric efficiency at rated operating point 14 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 15 3.1.82 rated working pressure Maximum internal pressure that equipment is designed to contain and/or control. 3.1.83 rotary displacement pump Pump built upon the principle of transporting volumes of fluids via closed or semi-closed chambers at a near constant volume for each rotation. NOTE The chambers in rotary displacement pumps may consist of screws, lobes, gears or cams. 3.1.84 rotodynamic pump Pump built upon the principle of converting kinetic energy to head by use of a rotating impeller 3.1.85 service factor Service factor of an AC motor is a multiplier that when applied to the rated horsepower indicates a permissible horsepower loading that may be carried under the conditions specified for the service factor NOTE 1 See NEMA MG 1. NOTE 2 IEC standards do not recognize service factor. 3.1.86 similar pump Pump that is accepted, by agreement between purchaser and vendor as sufficiently similar to not require a lateral analysis, taking into account the factors listed for an identical pump 3.1.87 single load power system Subsea power system where a single booster pump or other single load is powered by a single circuit from the platform 3.1.88 solid grounding Refers to the connection of a system conductor, usually the neutral of a generator, power transformer, or grounding transformer directly to ground, without any intentional intervening impedance 3.1.89 specific speed Index relating flow, total head and rotational speed for pumps of similar geometry 3.1.90 stage One impeller and associated diffuser or volute and return channel, if required 3.1.91 stall Pump term for a condition defining minimum stable flowrate at given tip speed and head characterizeable by vibration or performance 15 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 16 3.1.92 standard conditions Reference pressure and temperatures used to describe production volumes of hydrocarbons. o o NOTE 1 These vary worldwide, but are typically 15 C and 1bar (60 F and 1 atm). NOTE 2 Not to be confused with normal conditions. 3.1.93 step-out distance Distance between the platform power generation system and the subsea power load 3.1.94 stonewall Compressor term defining maximum stable flowrate at given tip speed and head NOTE This is viewed as an indicator of sonic flow conditions. 3.1.95 subsea power system Combination of components (electrical, mechanical, thermal) that act together to supply power to a subsea load. 3.1.96 surge Compressor term for a condition defining minimum stable flowrate at given tip speed and head characterized by vibration, performance and/or efficiency losses 3.1.97 system charging current Total distributed capacitive charging current (3∙Vl-n/XC0) of a three-phase system 3.1.98 three-phase, four-wire system System of alternating current supply comprised of four conductors, three of which are connected as in a three-phase, 3-wire system with the forth being connected to the neutral point of the supply (e.g., a deltawye connected transformer) 3.1.99 transformer based power system Subsea power system where a single booster pump or other single load is powered through a one or more transformers used between the power source (generally a VFD) on the platform and the load NOTE Transformers can be used to increase or decrease voltage to reduce current losses, or for isolation, or for both. 3.1.100 transient overvoltage Temporary overvoltage associated with the operation of a switching device, a fault, an arcing ground, or other instigating event on a power system that does not have an effective grounding system in place 16 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 17 3.1.101 trip speed Electric motor driver -synchronous speed at maximum supply frequency 3.1.102 trip speed Variable-speed driver variable- -speed at which the independent emergency over-speed device operates to shut down the driver 3.1.103 umbilical Hydraulic hose, tubing, piping, and/or electrical conductor that directs fluids and/or electrical current or signals to or from subsea trees 3.1.104 unplanned intervention Repair or replacement of subsea equipment where the impending failure of the equipment was not anticipated and replacement equipment, installation vessels, and personnel were not ready prior to shut in of production 3.1.105 volumetric efficiency Ratio of the pump rated point flow to the total theoretical displacement per unit time 3.2 Acronyms and Abbreviations 3Ø A ABS AC AFC AFCI AHJ ANSI API ASHRAE ASME ASTM AWG AWS bbl BEP BFHPU BPCS bpd C CFD Shorthand for 3-phase AC Power Amp American Bureau of Shipping Alternating Current Adjustable Frequency Control Arc Fault Circuit Interrupter Authority Having Jurisdiction American National Standards Institute American Petroleum Institute American Society of Heating, Refrigerating, and Air Conditioning Engineers American Society of Mechanical Engineers American Society for Testing and Materials American Wire Gauge American Welding Society Barrel Best Efficiency Point Barrier Fluid Hydraulic Power Unit Booster Pump Control System Barrels per day Celsius Computational Fluid Dynamics 17 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X CRA CSA DR DNV DOL EFAT EFL EMI EP EPR EPU ERC ESD ESP ESS F FA FAT FEA FM FMECA FP FPS FPSO FPU FSD ft FTP g GFI GLR GOR GVF HFL HIP HISC HMI HMWPE hp HP HPU HSSE HV HVAC Hz I0 IADC Corrosion Resistant Allow Canadian Standards Association Density Ratio Det Norske Veritas Direct-On-Line Extended Factory Acceptance Test Electrical Flying Leads Electromagnetic Interference Explosion-Proof Ethylene Propylene Rubber Electrical Power Unit Erosion Risk Classification Emergency Shut Down Electric Submersible Pumps Emergency Safety System Fahrenheit Forced Air Factory Acceptance Test Finite Element Analysis Factory Mutual Research Corporation Failure Mode, Effects, and Criticality Analysis Flame Proof Floating Production System Floating Production Storage Offloading Floating Production Unit Flowline Shutdown feet File Transfer Protocol Gravity Ground Fault Interrupter Gas Liquid Ratio Gas Oil Ratio Gas Volume Fraction Hydraulic Flying Leads Hot Isostatic Pressing Hydrogen Induced Stress Cracking Human Machine Interface High Molecular Weight Polyethylene Horsepower High Pressure Hydraulic Power Unit Health, Safety, Security and Environment High Voltage (35kV and above) Heating, Ventilation, and Air Conditioning Hertz, unit of frequency equal to 1 cycle per second Ground-fault Current International Association of Drilling Contractors 18 18 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X ICEA IEC IEEE IES IMO IPC ISA ISO k K kpsi ksi kVA kW LEL LFL LP LV LVTC m mm M 3 m /hr MCC MMS MODU MPC MPP MTTF MV MW NACE NDE NEC NEMA NFPA NPSH NPSHR NPSHA NPSH3 NRTL NTP OA VENDOR OFL Pa Insulated Cable Engineers Association International Electrotechnical Commission Institute of Electrical and Electronics Engineers Illuminating Engineering Society of North America International Maritime Organization Institute for Interconnecting and Packaging Electronic Circuits The International Society for Measurement and Control (formerly Instrument Society of America) International Organization for Standardization Kilo Kelvin Kilo-pounds force per square inch Kilo-pounds per square inch Kilovolt-Ampere Kilowatt Lower Explosive Limit (LFL Preferred) Lower Flammable Limit Low Pressure Low Voltage (0V to 1kV) Load Varying Tap Changer Meter millimeter if alone or prefix for millions in USC Mega Cubic meters per hour Motor Control Center Minerals Management Service, U.S. Department of the Interior Mobile Offshore Drilling Unit Main Pump Controller Multi-Phase Pump Mean Time to Failure Medium Voltage (1kV to 35kV) Megawatt National Association of Corrosion Engineers International Non-Destructive Examination National Electric Code National Electrical Vendors Association National Fire Protection Association Net Positive Suction Head Net Positive Suction Head required Net Positive Suction Head available Net Positive Suction Head required measured at 3% head drop Nationally Recognized Testing Laboratory Network Time Protocol Open Air Original Equipment Vendor Optical Flying Lead Pascal 19 19 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X P.A. PAS PE pf PLC PMSM PSI PSS PVC QA QC R RAM RBD RDC RGD MAX MIN ROT ROV RPM SAE SALM S scf SCM SCMMB SCMRT SEM SEPS SIT SF 3 Sm STB SUTA TEFC TENV TLP TRL TUTA UL USCG UTA V VA VFD VSD Public Address Process Automation System Polyethylene Power Factor Programmable Logic Controller Permanent Magnet Synchronous Motor Pound per Square Inch Process Safety System Polyvinyl Chloride Quality Assurance Quality Control Rankine Reliability, Availability, and Maintainability Reliability Block Diagram Rapid Density Change Rapid Gas Decompression Maximum Fluid Density Minimum Fluid Density Remote Operator Terminal Remotely Operated Vehicle Revolutions per Minute Society of Automotive Engineers Single Anchor Leg Mooring (Buoy) Standard or Prefix to Denote Subsea Standard cubic foot Subsea Control Module Subsea Control Module Mounting Base Subsea Control Module Running Tool Subsea Electronic Module Subsea Electrical Power Standardization Site Integration Test Stress Factor Standard cubic meter Stock Tank Barrel Subsea Umbilical Termination Assembly Totally Enclosed Fan Cooled Totally Enclosed Non-Ventilated Tension Leg Platform Technology Readiness Level Topsides Umbilical Termination Assembly Underwriters Laboratories Inc. United States Coast Guard Umbilical Termination Assembly Volt Volt-Amp Variable Frequency Drive Variable Speed Drive 20 20 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X W XLPE p Watt Crosslinked Polyethylene Differential Pressure Generated by Pump 21 21 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 22 4 Systems and Interface Descriptions 4.1 General 4.1.1 System Configuration Figure 1 provides an overview of the subsea pump configuration covered by this document. The items shown in orange are directly covered in this document. Other sections of Figure 1 are included for reference. Figure 1 - Subsea Pump System 4.1.2 Unit Responsibility Unless otherwise specified, the pump vendor shall have unit responsibility. The pump vendor shall ensure that all sub-vendors comply with the requirements of this Standard and all reference documents. 22 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 23 4.2 Classification and Designation 4.2.1 Description of Codes The pumps described in this Standard are classified and designated by type codes, as shown in Table 1. Table 1 - Pump Classification Type Identification Pump Type Working Principle Vane Rotary displacement Subsea Pumps Lobe Single Phase Gear Screw Rotodynamic Multi‑phase Screw Single Phase Single or multistage Hybrid Multi-phase Multistage True Multi-phase Single or multistage Type Code Vane in Rotor Vane in Stator Single Multiple Timed External Untimed External Internal w/Crescent Progressive Cavity Timed Twin Screw Multiple Screw Progressive Cavity Timed Twin Screw Axial Radial Helico‑axial/ Radial Semi-axial/Radial Helico‑axial Semi-axial SVR SVS SLS SLM SGET SGEU SGI SPC STS SMS SMPPC SMPTS SSPA SSPR SMPHAR SMPSAR SMPHA SMPSA NOTE: This document does not cover ESP’s installed in the well. Mudline ESPs are covered by this document, in accordance with their type and working principle. 4.2.2 Pump Designations and Descriptions Pumps listed in Table 1 of this standard can be correlated to the corresponding sections of API 610 and API 676. A prefix “S” has been added to the beginning of the code of each pump type to denote its subsea application. In spite of the subsea nature of the application the basic principle of operation or layout of each type of pump does not differ from the ones described in API 610 and 676, therefore please refer to such standards for further descriptions. 23 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 24 5 Requirements 5.1 Units The purchaser shall specify whether data, drawings, and maintenance dimensions of pumps shall be in the SI or US Customary (USC) system of measurements. Use of an SI data sheet (see Annex C) indicates the Standard System of measurements shall be used. Use of a USC data sheet (see Annex C) indicates the USC system of measurements shall be used. 5.2 Statutory Requirements The purchaser and the vendor shall mutually determine the measures necessary to comply with any governmental codes, regulations, ordinances, or rules that are applicable to the equipment, its packaging and preservation. 5.3 Requirements In case of conflict between this Standard and purchaser requirements, the purchaser requirements shall govern. Section 6 of this document contains general design guidelines for all pumps described in Table 1. Specific detailed design guidelines for each type of Rotodynamic pump as described in Section 9 of API 610 are applicable. 24 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 25 6 Motorpump Unit Design 6.1 Design 6.1.1 General The subsea motor and pump unit is a highly integrated machine which combines both the pump and the motor to one single unit. This necessitates a pump and motor design which are dependent upon each other. As a result of this integration, is the motor and pump cannot practically be treated as individual components. In this chapter there are several chapters that are common for both the pump and motor for example bearings and dynamics. In general, any subsea rotodynamic pump shall conform to the requirements of API 610, eleventh edition, September 2010. This document then describes key deviations from API Standard 610. Similarly, rotary positive displacement pumps shall comply to API 676 with the key deviations from that standard described herein. The same applies for subsea motor that in general shall follow API 541 fifth edition 2014. 6.1.2 General Design Requirements The general design requirements are described in API STD 610 section 6.1 noting the following key additions: a) Equipment, including all auxiliaries, shall be designed for subsea installation and the specified site environmental conditions. The vendor shall advise of any equipment protection required for the storage before deployment (i.e. winterization for low ambient temperatures, or protection against unusual corrosive conditions, etc.). Purchaser shall specify any environmental conditions applicable to the design of the pump such as but not limited to maximum and minimum pressure, water depth, external pressure, corrosive or erosive conditions, water currents and/or local regulations or codes pertaining to the fishing industry, wildlife conservation or any such specific considerations. b) The pump and motor are to be designed to be retrievable as one single unit. All equipment shall be designed to permit rapid and economical maintenance. Major parts, such as casing components and bearing housings, shall be designed and manufactured to ensure accurate alignment on reassembly. c) Installation and retrieval of units will expose the units to vertical and lateral acceleration loads several times as well as impact tolerance requirements. See Section 8. d) Spare and all replacement parts for the pump and all furnished auxiliaries shall, as a minimum, meet all the criteria of this Recommended Practice. The purchaser shall specify the operating conditions, the fluid properties, site conditions and utility conditions, including all data shown on the Pump Design Data Sheets (Annex C), over the life of the field. The purchaser is responsible for including details describing changes over time in: reservoir PVT data, 25 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 26 water cut, and flow rates, etc. The purchaser is therefore encouraged to estimate those changes and provide the field evolution flows, GVF and water‑cut so the pump may be sized to meet both current and future conditions. This forward planning may change the number of operating pumps, and / or pump components necessary to achieve such forecasted performance. The equipment shall be capable of operation at the normal and rated operating points and any other anticipated operating conditions specified by the purchaser. In some cases, as a result of expected or unexpected changes in pump operating conditions, pump components may have to be exchanged to reach future conditions. The vendor shall clearly indicate in the proposal the conditions of service which shall require the replacement of the pump or any of its components. Where relevant, the motor barrier fluid, cooling, sealing, pressure boundary and other systems shall be sized to cover such future conditions. A subsea pump is normally operated with an electric motor coupled to a variable speed drive (VSD or VFD). The choice of motor rating shall include a fixed margin of 10% to the maximum pump power and speed and also include applicable service factors for the intended use. Pumps shall be capable of operating at least up to the specified maximum continuous speed. The maximum continuous speed shall be synchronous speed for fixed speed pumps and at least 105% for variable speed pumps. Variable-speed pumps shall be designed for excursions to the specified trip speed (automatic shutdown speed) without damage. The pump and the pump system including motor and the associated barrier fluid system shall be designed to tolerate any transient condition including emergency shut down and power failure. The vendor shall state the minimum safe operation speed considering any relevant issues including bearing and mechanical seal face lubrication. Vendor shall also state the maximum safe speed acceleration and deceleration for the unit. Start-up of subsea pumps may prove difficult due to potential complexities of the electric power system, including long distance cabling and transformers. Complete power system analysis must be made to ensure safe start-up for the worst combination of pump pressure, temperature and viscosity. Start-up friction in pump and motor thrust bearings must include margins for long-term standstill of the unit. These analyses shall be documented and supplied in accordance with Section 12. During FAT, the pump with its motor shall perform within the specified performance test tolerances. Performance acceptance criteria post installation shall be based on FAT results. Vendor and Purchaser shall work together to determine long term effects, consequences and mitigations if FAT performance is largely different to post installation performance. 6.1.3 Operational and Environmental Conditions The installation of subsea units will face some extra environmental challenges regarding water depth and sea water temperature. In order to promote standardization of units, water depth and sea water temperatures are organized into classes, defined in Tables 2 through 5. 26 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 27 Table 2 - Classification by Installation Depth Depth class Name Depth A B C D Shallow Deep Ultra-deep Extreme deep 0 – 500 meter 500 – 1500 meter 1500 – 3000 meter 3000 – 5000 meter Table 3 - Classification by Sea Water Temperature Temperature class Name A B C Cold Intermediate Hot Temperature Range o -2 ºC to +10 ºC +10 ºC to +20 ºC +20 ºC to +30 ºC o +28 F to +50 F o o +50 F to +68 F o o +68 F to +86 F Table 4 - Classification by Process Fluid Temperature (Table is expanded from API 6A Table 2) Temperature classification: S T U V W X Y Z Minimum temperature: -18 °C -18 °C -18 °C 2 °C -18 °C 2 °C -18 °C 2 °C Maximum temperature: 66 ºC 82 ºC 121 ºC 121 ºC 149 ºC 149 ºC 177 ºC 177 ºC Minimum temperature: 0 °F 0 °F 0 °F 35 °F 0 °F 35 °F 0 °F 35 °F Maximum temperature: 150 °F 180 °F 250 °F 250 °F 300 °F 300 °F 350 °F 350 °F Table 5 - Recommended Service Factors for Single-Phase Pumps Case: Service Factor (SF): Single-phase pumps with steady-state operation and smooth start/stop Single-phase pumps with frequent and rapid speed changes Single-phase pumps with direct-on-line operation and frequent start/stop a Single-phase pumps experiencing frequent rapid density change a 1.00 1.10 1.25 ρMAX/ ρMIN – rapid here means a faster change than the VSD is able to adjust 6.2 Pump Types 6.2.1 General The pumps described in this Standard are classified and designated by type codes, as shown in Table 1. Pumps listed in Table 1 of this standard can be correlated to the corresponding sections of API 610 and API 676. A prefix “S” has been added to the beginning of the code of each pump type to denote its subsea application. In spite of the subsea nature of the application the basic principle of operation or 27 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 28 layout of each type of pump does not differ from the ones described in API 610 and 676, therefore please refer to such standards for further descriptions. 6.2.2 Rotodynamic Pumps 6.2.2.1 General Rotodynamic pumps are pumps that generate differential head (pressure) only by dynamic action as they utilize either the centrifugal forces in a rotating fluid (centrifugal impeller) or by pressure difference over a moving blade (axial impellers). All rotodynamic pumps are operating with one or several rotating impellers. Rotodynamic pumps are not self-priming and needs to be filled with fluid prior to start-up. These pumps cannot hold back fluid once they are stopped and will need a check valve in the system to prevent reverse or back flow. 6.2.2.2 Single-phase selection For subsea pumps, the difference between between single-phase and multi‑phase pumps is very important and a decision between the two must be made. The Gas Volume Fraction (GVF) limit of single phase technologies is one key parameter as it describes the maximum gas fraction which a classic singlephase pump can tolerate. The limit is very dependent on the Density Ratio (DR) between the liquid and [1] the gas at pump stage inlet conditions. Gulich provides some guidelines for use of conventional rotors based on air water testing and utilize a relationship of the form: 𝐴𝑙𝑙𝑜𝑤𝑎𝑏𝑙𝑒 𝐺𝑉𝐹 < 𝑎 √𝐷𝑅 Where a is derived from Figure 1.3.21 in Gulich’s book and is approximately 0.75 for single stage 1 for multistage Because hydrocarbon fluids are mutually soluble, the gas and liquid densities will approach each other meaning that further manipulation of these models may not be consistently conservative (Figures 2 and 3 show such a difference). Further manipulation of these relationships is therefore not without risk. Figure 2 illustrates the variability to be expected in simple approach for a model fluid system (pure methane and pure octane) estimated using analytic models. The figure shows the effect of temperature and pressure on the GVF limit estimate. Figure 3 illustrates the same concepts but applied to a different fluid system and illustrates the equivalent curves for multistage pumps. 28 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 Figure 2 - Example Acceptable Suction GVF Limit as it Applies to a Single Stage Pump with a Conventional Flow Path. Figure 3: Example Acceptable Suction GVF Limit as it applies to both Single-Stage and MultiStage Pumps 29 29 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 30 Pumps, which handle fluids with dissolved gases (like well-stream pumps and pumps downstream a separator), shall be evaluated for possible gas flashing as a result of dynamic or steady-state pressure changes at the pump inlet. These reviews shall be performed for all operating conditions. The actual GVF at the impeller suction shall always be less than the gas tolerance demonstrated for the pump design. 6.2.2.3 Single-Phase Pumps The purchaser shall specify a service factor reflecting the operating conditions of the pump. Table 5 shows recommended service factors for single-phase pumps (including liquid-liquid multi‑phase pumps). The service factor shall be the minimum ratio between the rated design load and the actual operational load. Single phase pumps that have stable head/flowrate curves (continuous head rise to shutoff) are preferred for all applications and are required if parallel operation is specified. If parallel operation is specified, the head rise from rated point to shutoff shall be at least 10 %. Section 6 of API Standard 610 provides instructions on preferred operating region and single‑phase pump sizing. Pumps shall have a preferred operating region of 70 % to 120 % of best efficiency flowrate of the pump as furnished. For subsea pumps, it is recognized that during life-of-field it may prove very difficult to operate inside the preferred operating region at all time due to changing flow and pressure requirements. Single phase small pumps that are known to operate satisfactorily at flows outside the specified limits should be offered, where appropriate, and their preferred operating region clearly shown on the proposal curve. Centrifugal Pumps that handle liquids more viscous than water shall have their water performance corrected in accordance with ISO/TR 17766 (ANSI/HI 9.6.7). Correction factors used for viscous liquids shall be submitted with both sales proposal curves and final test curves. To perform this evaluation, the purchaser shall provide the appropriate data on fluid viscosity changes as a result of: ― Wax gelation ― Emulsions ― Newtonian/non-Newtonian behavior ― Other fluid rheology related phenomena Subsea single-phase pumps, whether for wellstream boosting or water injection, are usually operated with suction pressures in excess of 10 bar but the purchaser should evaluate the effect of dissolved gases on NPSH. The NPSH margin (NPSHA – NPSHR) shall be evaluated for all rated operating points as described in API 610. The minimum NPSH margin shall be stated by the purchaser. For subsea pumps, the NPSH margin shall in any case be minimum 1.5 meters (4.6 ft) for all operating points. 30 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 31 Systems including single-phase pumps downstream subsea separation facilities shall be designed to ensure shall a positive head between separation device and the single-phase pump. 6.2.2.4 Multi-Phase and Hybrid Pumps Two types of multi‑phase pumps are defined, the hybrid pump and the true multi‑phase pump. The hybrid pump is a combination of multi‑phase impellers in the first stages and single-phase (radial or axial) impellers in the last stages. The first multi‑phase impellers are used to compress/reduce the gas content to a GVF level within the capabilities of a single-phase impeller. Hybrid pumps are normally used downstream a scrubber or separator where significant amounts of gas carry-under can be expected. The hybrid is usually used for a GVF range of 0 – 40%. A true multi‑phase pump can operate in the entire GVF range from 0 – 100%. The purchaser shall specify a service factor reflecting the operating conditions of the pump. Table 6 shows recommended service factors for multi‑phase pumps. The service factor shall be the minimum ratio between the rated design load and the actual operational load. Table 6 - Recommended Service Factors for Multi‑phase Pumps Case: Service Factor (SF): Multi‑phase pumps with steady-state operation and adequate slug damper 1.00 Multi‑phase pumps with frequent and rapid speed changes 1.10 Multi‑phase pumps with direct-on-line operation and frequent start/stop 1.25 Multi‑phase pumps operating without proper slug damping capability Multi‑phase pumps experiencing frequent rapid density change a a 2.00 ρMAX/ ρMIN – rapid here means a faster change than the VSD is able to adjust Multi‑phase pump operation is usually limited by surge at some reduced flow and a choke limit (stonewall) at high flow. Surge is a harmful condition to multi‑phase pumps and must be avoided. The vendor must state the surge and choke limits with regards to speed, GVF, suction pressure and actual flow and must also state the safe operation limits including the necessary separation margins. The pump control system must include a strategy to avoid operating outside the stated limits. Since NPSH is defined for single phase fluids and describes the pressure difference before vaporization, NPSHA and NPSHR are not relevant when gas is present. There is currently no proven method of calculating the influence of fluid viscosity on multi‑phase pumps. The friction loss and power loss may be substantially larger than for a single phase centrifugal pump due to longer flow paths in the impellers and high peripheral speed. Multi‑phase pumps shall have their performance corrected in accordance with vendor's documented and tested methods. True multi‑phase pumps must be designed to tolerate occasional short-time dry running. The vendor shall state any limitations regarding speed-time and temperature limitations for dry running and also incorporate a control strategy to avoid damages to the pump unit caused by dry running. 31 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 32 6.2.3 Rotary Positive Displacement Pumps – Selection and Rating Criteria Equipment shall be selected to run simultaneously at the pressure-limiting accumulation pressure, trip speed and water depth without suffering damage. Vendor shall advise purchaser of increased power operating requirements necessary to achieve this. Unless otherwise specified, the vendor shall recommend the pump speed for the specified service, considering such factors as NPSHA and NPSHR when applicable, maximum and minimum fluid viscosity and temperature, GVF, solids and abrasive content and wear allowance if required. NOTE: It must be recognized that different rotary pump designs operate on different principles so that no single speed criterion can be applied. 6.3 Pressure Casings 6.3.1 General Pressure casings are the pressure and liquid containing vessels where the pump and motor is encapsulated in subsea pumps. Unlike topside units, the motor and pump pressure casing are bolted together as one single pressure container. This chapter is then covering both the pump casing and the motor casing. In order to promote standardization of subsea units, it is recommended to limit the casings pressure classes to the six design classes shown in the Table 7 below, corresponding to API 6A Chapter 4.2. Table 7 - Casing Pressure Design Class Pressure class: Name: Design pressure: A B C D E F 2 000 Psi 3 000 Psi 5 000 Psi 10 000 Psi 15 000 Psi 20 000 Psi 138 Bar 207 Bar 345 Bar 690 Bar 1035 Bar 1380 Bar For well-stream pumps, the potential well shut-in pressure shall be included in the maximum operation pressure unless the system is provided with means to avoid this pressure in a safe way. The pressure casing shall be a separate shell outside the motor and pump units. Pump flow passages other than the suction and discharge nozzle, shall not be integrated in the pressure casing. Pressure casings for subsea pumps are generally designed for a combination of wellhead design pressure and/or outside environment pressure. ASME Section VIII Div. 2, Part 5 “Design by analysis requirements” is suggested. For class E and F the use of ASME VIII Div. 3 (Alternative Rules for Construction of High Pressure Vessels) may be agreed. 32 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 33 Due to the high pressures and relatively large diameters, the design by rule methods in API 610, 676, 685 and other specifications are not adequate. The vendor, in his proposal, shall state the source of the material properties from those listed in Table H.2 (i.e. ISO, ASTM, UNS, EN, JIS), as well as design method and any casting factors applied. National material standards other than those listed in Table H.2, may be used with specific purchaser approval. Subsea pressure casings shall be verified by analysis to resist the external collapse pressure by the sea water depth on the outside and vacuum on the inside of the casing. As a result of high heat transfer rates to the surrounding seawater, subsea pump casings will exposed to large thermal gradients between internal and external conditions. Thermal expansion between the pump casing, internal parts, and other interfaces may result in sealing issues, stresses, etc. These must be considered when designing internal sealing clearances between the casing and internal pump parts. The purchaser and vendor may agree to allow for possible casing thickness reduction due to external sea water pressure according to API 17TR12. If 6B flanges as per API 6A are specified by the purchaser, metal –to-metal fits with ring gaskets as defined in section 10.4 of API 6A shall be used. Threaded holes in pressure parts are generally not allowed. The purchaser and the vendor may agree to use small threaded holes for test ports, drainage and venting to be used during the assembly and test period. Provided these threaded holes are plugged with a double-sealing barrier between the pump fluid and the surrounding sea water and use metal to metal sealing. Subsea structures are usually protected by Cathodic Protection (CP) and the risk of HISC must be addressed in the design of pressure casings if using materials which may be sensitive to this. 6.3.2 Pressure Casings – Rotodynamic Pumps In general, the design rules listed in API 610 chapter 6.3 (Pressure casings) also apply to subsea rotodynamic pump and motor casings. Special requirements of subsea pumps requiring exceptions and additions to these design rules are described in Section 6.1.1 of this document. 6.3.3 Pressure Casings – Rotary Displacement Pumps Casing and other pressure-retaining parts and supports shall be designed to prevent detrimental distortion caused by the worst combination of temperature, pressure, torque, and allowable external forces and moments based on the specified operating conditions. Unless specified, suction regions shall be designed for the same MACP as the discharge section. 6.3.4 Bolting and Threads Fasteners, bolting and threads are covered in section 10.4. 33 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 34 6.3.5 External Pressure Casing Connections External connections that require ROV interface will be designed following the guidelines as established in API 17H. Suction, discharge or auxiliary connections that do not require ROV interfacing shall follow the API 6A guidelines established for subsea high pressure connections as agreed by vendor and purchaser. Note that Cast Iron connections or nozzles are not allowed in subsea applications. Other special flanges, as the “Compact Flange” type, may be agreed between vendor and purchaser, and is especially relevant for the highest pressure classes and large diameters. For non-standardized connections, fit for purpose for the flange, seal and bolt connection shall be proven by Finite Element Analysis including non-linear material properties, pressure, tensioning loads and external forces and moments, as well as a ratcheting analysis. 6.3.6 External Nozzle Forces and Moments External allowable forces and loads at the pump flanges shall be limited to the maximum levels as established by API 610 Chapter 6.5, and 676 respectively for each pump type. When Flowline connection systems are used through valves or manifolds from the pump module to the pump manifold, API 17H shall apply. Pumps and pump module shall be designed for satisfactory performance if subjected to such forces and moments applied simultaneously to both suction and discharge nozzles and connections at the interface between the pump module and manifold at the most demanding combination of conditions of service as specified in the process datasheet. 6.3.7 Casing Seals Casing seals including the main seal shall be metal-to-metal seals where the casing contains hydrocarbons, toxic or other hazardous fluids. Other seals may be agreed where the casing only contains barrier fluid with a low environmental impact in case of leakage. Elastomeric seals, which are exposed to the production fluids are subject to review and materials should be qualified for rapid gas decompression. 6.4 Internal Pump Components 6.4.1 Rotodynamic Pumps In general, the design rules listed in API 610 chapter 6 (Basic design) also apply to subsea rotodynamic pumps. Also the specific pump types in chapter 9 shall be considered. Most subsea pumps are of the between-bearing type and thus chapter 9.2 (Between-bearing pumps) shall be considered. Subsea pumps do have some special requirements and a few exceptions and additions are listed here. The minimum clearance between impeller and diffusor or volute shall be as stated in API 610 Chapter 6.1.15 and 6.1.16. This also applies to axial clearances in helico‑axial and semiaxial multi‑phase pumps. 34 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 35 Minimum clearances between rotating and static parts shall be as API 610 Chapter 6.7. Hybrid and multi‑ phase pumps that operate with less fluid support to the rotor from the wear rings and throttle bushes or even experience dry running may require even higher clearances. 6.4.2 Rotary Displacement Pumps Refer to API 676 (section 6.8), for internal rotating and hydraulic component requirements. Inspection ports as required by section 6.8.2.4 of API 676 are not allowed in subsea applications. If specified, replaceable liners shall be provided for screw pumps. Unless otherwise specified for multi‑phase twin-screw pumps, hard coatings and/or surface hardening shall be applied to the liner bores. 6.5 Mechanical Shaft Seals 6.5.1 General Mechanical seals in subsea applications are to be used exclusively to isolate the process containing sections of the pump module where the rotating shafts protrude towards the barrier fluid containing section or other fully enclosed section of the pump module. Rotating shafts shall in no event in subsea applications extend beyond the casing boundaries towards the environment (seawater). Pumps shall be equipped with cartridge type mechanical seals in accordance with API 682 when feasible. When full API 682 compliance is not possible (i.e. seal chamber dimensions cannot be met due to pump design) vendor’s standard seal meeting the intent of API 682 shall be supplied. The following items shall be provided in the proposal: – Category – Type – Arrangement and geometry – Materials of construction – Reference list NOTE Space or design parameters for some pump types, sizes, or applications make the use of API 682 seals impractical. This standard does not cover the design of the component parts of mechanical seals. However, the design of the component parts shall be suitable for the specified service conditions and consistent with API 682. The purchaser shall specify the seal requirements using the selection process and the data sheets in API 682 for this purpose including any required seal flush plans as defined by API 682. 35 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 36 Mechanical seals and glands for all subsea pumps shall be installed in the pump before shipment and shall be clean and ready for initial service. Seal selection shall be suitable for specified variations in suction and/or discharge conditions during startup, operation, or shutdown, including possible upset conditions. The vendor and purchaser shall agree on the maximum static and dynamic sealing pressures that can be anticipated to occur in the seal chamber and the vendor shall state these values on the data sheet [see 3.23 and 3.25]. If the seal is exposed to suction pressure, special consideration may also be necessary for low suction pressure conditions or when a single phase pump is subjected to a NPSH test requirement. During transient conditions, the differential pressure across the mechanical seal is depending on the response and functionality of the barrier fluid system. The vendor must analyze all possible transient cases the pump may be subject to and from the barrier fluid system response, specify the highest and lowest differential pressure and temperature the mechanical seal may be exposed to. The maximum mechanical seal leakage at the specified operating conditions shall be provided with the purpose of determining the rate of barrier or buffer seal oil usage and thus the sizing of the seal oil reservoir or the barrier fluid system. In dual seal applications, the maximum seal leakage shall be provided both towards the process and away from it. The vendor shall also specify the minimum safe mechanical seal leakage at the specified operation conditions in order to provide sufficient lubrication and cooling of the seal faces. If a seal gland is used, its component parts shall be satisfactory for the maximum seal-chamber design pressure and pumping temperature. It shall have sufficient rigidity to avoid any distortion that would impair seal operation, including distortion that may occur during tightening of the bolts or nuts. Mechanical seals shall be tested at worst case operating condition as minimum and maximum differential pressures, maximum temperature and for transient conditions as emergency shut-down. 6.5.2 Rotodynamic Pumps Rotodynamic pumps using mechanical seals shall in general conform to API 610 Chapter 6.8. For subsea pumps which are highly integrated units and with no possibility to do maintenance on mechanical seals without a complete disassembly of the unit, the requirement for seal cartridge removal without disturbing the driver in Chapter 6.8.2 is not required. The seal chamber dimensions in Chapter 6.8.3 is recommended, but not required. For pumps handling multi‑phase fluid (hybrid and multi‑phase pumps), the mechanical seal(s) must be able to operate safely without any liquid on the pump side of the mechanical seal. The potential for rapid temperature and pressure changes due to alternation between liquid exposure and gas exposure to the seal faces shall be evaluated by the vendor and specified for the mechanical seal. The mechanical seal rotating sleeve must be mechanically locked in both torsion and in both axial directions by keys, shaft shoulders and lock nuts or similar. 36 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 37 6.6 Rotordynamics 6.6.1 Pumps For rotodynamic pumps, the requirements in API 610 Chapter 6.9 generally apply. 6.6.2 General For true multi‑phase rotodynamic pumps which may operate with high GVF or even run dry, the requirements regarding maximum shaft deflection in API 610 Chapter 6.9.1.3 shall include no liquid stiffening effect in the wear rings and throttle bushes also for multistage pumps. Twin screw pump rotors shall have sufficient stiffness to ensure that its deflection is such that there is no contact between the tips of the screw and the bores of the casing throughout the complete agreed spectrum of differential pressure and speed at any given fluid viscosity or GVF. Test requirements for vibration are found in Section 9.3.2. 6.6.3 Balancing Balancing requirement is as described in API 610 Chapter 6.9.4 and API 676 section 6.8.1.9 for both motor and pump. 6.6.4 Rotordynamic Lateral Analysis The rotors of twin screw and small slow speed pumps are generally designed so its first dry-bending critical speed is at least 20 % above the pump's maximum continuous operating speed. In general, the requirements in API 610 Chapter 6.9 apply to rotodynamic pumps. For rotodynamic high-speed multistage pumps and motors, a rotordynamic analyses shall be performed according to API 610 Annex I with some extra considerations listed below. a) For pump/motor units with a rigid coupling connecting the motor and pump shaft, the rotordynamic analysis shall be made for the combined motor and pump rotor. b) For multi‑phase pumps, the rotordynamic analysis must consider the actual operating conditions. In particular the stiffness and damping effect from the multi‑phase fluid on internal seals, balance piston, throttle bushes and impeller/stator interaction from caused by GVF, flow, pressure, temperature and the Density Ratio (DR) When selecting bearings, bushes and seals for multi‑phase pumps, damping properties should have priority over stiffness properties when selecting bearings, bushes and seals. This may be achieved by larger bearings, reduced preload etc. 37 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 38 6.6.5 Rotordynamics of Liquid Filled Motors API 610 Annex I should be applied for the evaluation of damping ratios and separation margins of liquidfilled motors. For the motor rotor analysis, the effect of liquid filling to stiffness, damping and added mass properties, especially in the rotor – stator gap shall be considered. The liquid present in the rotor – stator gap will cause a significant negative stiffness, a positive damping and a large added mass which will make the rotordynamic behavior very different from that of an air-filled motor. The negative forces in the rotor – stator gap caused partly by the liquid filling and partly by the magnetic pull, shall be evaluated for determining the motor bearing forces. This analysis must consider the maximum rotor stator eccentricity and the actual bearing clearances. 6.6.6 Rotordynamic Torsional Analysis When required, torsional analysis shall be performed following the guidelines as defined in Section 6.9.2 of API 610. In the event that torsional analysis is required for rotary positive displacement pumps, the same guideline is to be used but impeller vane and cutwater pass frequencies shall be replaced by screw mesh frequency. 6.6.7 Pump-motor Unit Support Structure The design of the structure for vibration is described in section 8.5.2 6.7 Bearings and Bearing Housings 6.7.1 General Bearings shall be designed following the guidelines established in API 610, 676, 685 or similar above referenced specifications to the pumps in the scope of this recommended practice. Unlike pumps designed for topside applications and unless otherwise specified, bearings and bearing housings for subsea applications are designed for lubrication and cooling by the barrier fluid. The bearing technology and materials must be chosen in order to fit with the actual barrier fluid. Special designed bearings may be proposed by the vendor to ensure a minimum bearing life that meets the design criteria as specified in Section 6.1.1 of this document. Such deviations shall be clearly indicated in the proposal. Such bearing and lubrication systems (which may also include the barrier fluid and mechanical seal systems) shall be qualified prior to being deployed in the subsea pump. 38 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 39 6.7.2 Hydrodynamic Radial Support Bearings Vertical pumps and motors with hydrodynamic bearings shall be equipped with radial tilt pad bearings for all radial bearings in order to minimize destabilizing cross-coupling forces which may lead to “oil whirl” instability. Pump process lubricated support bearings may be accepted for single phase pumps and hybrid pumps where it is impossible for the pump to run dry. The bearing material and design shall be a proven design which can withstand the actual pumped fluid including possible sand content. Radial bearing clearances shall be chosen to ensure an adequate bearing clearance during the most extreme transient and steady-state operation conditions in order to avoid heat build-up and a reduced clearance which in turns could cause a bearing seizure to the shaft. The nominal bearing diametrical clearance shall be minimum 0.15% of the bearing diameter. 6.7.3 Hydrodynamic Thrust Bearings The thrust bearing shall be able to take thrust force in both directions. Hydrodynamic thrust bearings should be of the tilt-pad type. The maximum start-up stiction torque for hydrodynamic thrust bearing (after long time of standstill) shall be tested and used as input for the choice of motor and power equipment. The thrust bearing maximum operational load shall always be less than 50% of the bearing ultimate load. The thrust disc bore shall be perpendicular to the shaft centerline and have an interference fit to the shaft. It shall be mechanically locked and secured in tangential and both axial directions. 6.8 Motor 6.8.1 General Unlike topside pumps, the subsea pump motor is typically inside the pressure boundary with the subsea pumping element. The barrier fluid system is circulated to cool the motor, and lubricate and cool the mechanical seals and pump/motor bearing systems. Subsea motors for pumps are so far made with liquid filling. This standard is only focusing on liquid filled motors and do not include any kind of gas-filled motor. In general, the requirements in API 610 Chapter 7.1 and API 541 shall be followed where applicable. In addition, some special requirements for subsea motors are defined. Induction motors shall comply with API 541 (5th Edition) performance and test criteria. If a synchronous motor alternative is proposed by Vendor, this alternative shall require a separate design review before purchase and shall require written acceptance from Purchaser. Synchronous motors shall comply with the performance and test requirements of API 546. For induction motors, vendor shall submit all comments and exceptions to API 541 with bid documents for Purchaser review and acceptance. Vendor shall submit an API 541 data sheet for Purchaser review and 39 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 40 acceptance. For synchronous motors, vendor shall submit all comments and exceptions to API 546 with bid documents for Purchaser review and acceptance. 6.8.2 Motor Rating and Service Factor Unless otherwise specified, the motor shall be sized according to API 610. The motor rating shall be 110% of the rated pump power (ref. API 610 40 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 41 Table 12). In addition, the service factors described in Chapter 6.2 shall also be applied for the motor. The vendor and purchaser shall agree on design-case and future conditions and size the motor accordingly. For subsea motors, the motor input voltage may vary considerably due to losses in the umbilical and an eventual subsea transformer. Unless the voltage is measured and controlled subsea in front of the motor penetrators, the motor and rating shall allow for a voltage variation of ±10%. The purchaser shall specify the type of motor in keeping with section 7.1.5 of API 610. Electric motors for rotary positive displacement pumps shall be specified as suitable for constant torque loads. The motor nameplate rating, including service factor, shall be suitable for operation at 100 percent of the pressure-limiting valve accumulation pressure in rotary pumps. Consideration shall be given to the starting conditions of both the motor and driven equipment and the possibility that these conditions may be different from the normal operating conditions. Equipment driven by induction motors shall be rated at the actual motor speed for the rated load conditions. 6.8.3 Motor Electro-magnetic Design 6.8.3.1 General Two types of electric motors are recognized as suitable for subsea pumps - Induction motors and Permanent Magnet Synchronous Motors (PMSM). These motors have different characteristics and different requirement applies to the two types of motors. 6.8.3.2 Induction Motors The induction rotor shall be designed according to API 541. Motors can be designed for either fixed frequency or variable frequency drives depending on pump application. For variable frequency driven motors the performance requirements must be met throughout the frequency range. The purchaser should specify the characteristics of the drive-system that is intended for the application. The motor rated speed references to the actual speed of the motor for the rated frequency and rated load. The minimum breakdown torque should be > 1.6 X the rated torque. For a Motor starting with a fixed frequency (DOL start): The minimum locked rotor torque (cold start conditions) at the defined operating frequency and maximum 80% of the rated voltage should be minimum 1.1 times the pump unit breakaway torque (stiction torque) for all possible pump conditions. The minimum pull-up torque (cold start conditions) for maximum 80% of the defined starting voltage and the line frequency should exceed the maximum load torque with a safety factor of 1.1, including starting with the maximum specified pump fluid viscosity. Harmonic torques must be taken into account if the safety factor against the load torque is less than 10% of the load torque. 41 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 42 A system analysis may be required to show that the inrush current does not produce an excessive voltage drop through the system to verify that the motor terminal voltage > 80% of the rated voltage for the worst case conditions. Otherwise, the above requirement applies to the actual voltage level at the motor terminals for the worst case conditions. For a Motor starting with a variable frequency drive (VSD start) the minimum locked rotor torque (cold start conditions) at the defined starting frequency and maximum 80% of the defined starting voltage should be minimum 1.1 times the pump unit breakaway torque (stiction torque) for all possible pump conditions. The minimum pull-up torque (cold start conditions) for maximum 80% of the defined starting voltage and the starting frequency should exceed the maximum load torque with a safety factor of 10% including starting with the maximum specified pump fluid viscosity. Harmonic torque must be taken into account if the safety factor against the load torque is less than 10% of the load torque. The vendor should specify the start-up procedure (e.g. maximum acceleration rate and idling speed, waiting time between start attempts, etc.). 6.8.3.3 Permanent Magnet Synchronous Motors (PMSM) Permanent magnet motors should be designed according to API 547. Control strategies should be sensor-less to avoid the need for resolvers/encoders. 6.8.4 Motor Mechanical Design 6.8.4.1 General Unless otherwise specified, the motor shall be aligned to the pumping element by the use of rabbet fits or other methods to assure alignment with varying ambient temperature and pressure associated with deployment of the subsea pump module. 6.8.4.2 Motor Rotor – Stator Gap The rotor – stator gap is very important in a liquid filled motor. The liquid friction will increase significantly with reduced clearance and also destabilizing fluid forces may cause rotordynamic problems. In general, it is recommended to use a radial gap of minimum 1.5% of the rotor diameter. It is of vital importance to control and minimize the maximum rotor – stator gap eccentricity in an liquid filled motor due to high destabilizing forces (negative stiffness) caused by both the gap liquid and the magnetic pull. The motor design and the assembly procedure must take this into due consideration. The rotor - stator eccentricity should be limited to maximum 0.25 mm (0.01 in.). The design must consider the generation of high friction loss in the rotor – stator gap and provide adequate means of effectively cooling this area. 42 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 6.8.4.3 43 Motor Rotor Motors designed for speeds > 3800 RPM shall have interference fits for all major rotating parts in order to maintain proper balance quality. The interference fit shall be adequate to compensate for component radial deflection during operation at maximum speed. Rotors for liquid filled motors are usually designed with a small rotor diameter and increased rotor length in order to reduce gap friction. This long and slender rotor is more sensitive to destabilizing forces generated by the gap liquid and the magnetic pull. The rotor design must in general incorporate generously dimensioned shaft diameter, radial bearings and bearing housing in order to handle these destabilizing forces. For long and slender rotors in subsea motors, it is recommended to have a center balancing plane on the rotor in order to properly balance a flexible rotor. This is mandatory for all rotors to operate >3800 RPM. 6.8.4.4 Motor Stator The stator lamination pack must be adequately compressed in order to avoid harmful vibration between the individual laminations. All metal parts that may possibly come into contact with windings shall have smooth surfaces and be deburred with defined radii on corners. It is recommended to use slot liners of PTFE or similar in the lamination slots. All significant natural frequencies of the stator housing and laminations shall be outside the range of rotor bar passing frequency or rotor magnet excitation frequency throughout the motor operation range with a margin of 15%. 6.8.4.5 Motor Stator Winding The motor insulation class shall be selected from the standard voltage classes as given in IEC 60038. For converter driven and/or motors for which continuous operation with an earth fault requirement the insulation class shall be selected to be one class higher than the rated voltage class of the motor. The motor winding may be either form wound or fully insulated cables. The maximum copper temperature (continuous peak temperature including hot spots for the rated output torque at the rated frequency and voltage) of the winding depending on the thermal rating of the insulation material is summarized in Table 8. The maximum continuous operation temperature of the winding should be limited to one class below the actual thermal class of the cable to ensure durability of the insulation. Note that API 541 allows a maximum temperature rise corresponding to class B insulation for both class F and class H insulation. For high speed subsea motors the coolant temperature is typically significantly o higher than 40 °C (104 F), thereby significantly limiting the motor performance if the API 541 requirement is applied for a class H insulation. The ambient temperature for subsea motors is determined by the sea-water temperature class according o to Table 3. Correction to 40 °C (104 F) ambient temperature is not required. The coolant medium 43 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 44 temperature is determined by the vendor given the ambient temperature and cooler properties and losses. For practical reasons it may be difficult to measure the winding temperature in a liquid filled motor with fully insulated windings (cable wound) since it is difficult to ensure that the temperature measurement is not affected by the coolant fluid which will result in a low temperature reading. Embedded temperature detector readings should be interpreted with caution for verification of the temperature targets. Preferably the copper temperature should be measured directly either by a temperature detector during a heat-run test or a resistance measurement of the winding immediately after a heat run test. A resistance measurement requires correction for stopping time and gives only the average winding temperature which needs to be taken into account for interpreting the results. As an alternative method, calibrated CFD can be used to verify that the temperature limits are not exceeded. This requires detailed knowledge about the thermal properties of the insulation. For temperature measurement limits (depending on the method of measurement) the limits corresponding to one thermal class below the thermal rating of the insulation should be used. The appropriate margin on the measured temperature is summarized in Table 8. Excursions to higher temperatures during transient conditions should be limited in duration to ensure adequate insulation life (service factor>1.0). Temperatures in excess of the thermal class are not allowed. Table 8 - Insulation Thermal Classes used for Subsea Motors Thermal class (IEC60085) 90 105 130 155 180 NOTE Previous letter designation Y A B F H Maximum hotspot winding temperature o o 90 C (194 F) o o 105 C (221 F) o o 130 C (266 F) o o 155 C (311 F) o o 180 C (356 F) IEC thermal class 120 °C (E) is not recommended Cable pigtails to the power penetrators shall have sufficient surplus length to allow minimum 10 connections/disconnections between the windings and the power penetrators. The end-windings shall be supported or strapped in a way sufficient to avoid harmful vibration. The design shall assure proper cooling of windings in areas where cables are bundled together. 6.8.5 Power and Instrumentation 6.8.5.1 Instrumentation Pump motors shall include the winding and bearing temperature detectors and vibration detectors required by API 541 for permanent mounting and operation in the motor. For cable wound motors, in lieu of winding temperature detectors, confirmation of analytic temperature calculated in the windings shall be confirmed during type test by method proposed by Vendor and agreed to by Purchaser. 44 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 6.8.5.2 45 Power System Engineering During the course of project execution, the Vendor shall have the responsibility to confirm, by analytical simulation, that all components included in the electrical circuit, including power umbilicals and transformers, from the topside or onshore power supply to the variable speed drive (VSD) to the subsea pump motor are rated to start the motor and supply continuous motor shaft power at the operating conditions detailed in the project basis of design – – Vendor shall supply an electrical component design confirmation report for Purchaser review and acceptance The definition of "all electrical circuit components included in the electrical circuit to the subsea motor" shall include all components supplied by Vendor and all components supplied by others Vendor shall issue torsional and lateral critical speed analysis reports for the pump and motor string and a motor lateral critical speed analysis for Purchaser review and acceptance. 6.8.5.3 HV Penetrator Vendor shall design and test the motor power penetrators, subsea jumper assemblies, and wet mate connectors in accordance with SEPS SP-1001. 6.9 Couplings and Guards 6.9.1 General Subsea motors are typically supplied by the pump module vendor and mounted by the pump module vendor. 6.9.2 Coupling Rating and Service Factor Couplings and coupling to shaft junctures shall be rated for at least the maximum motor power, including the motor service factor listed in Section 6.2 of this document. Couplings shall in general have a minimum safety factor of 2 with regards to maximum operational torque. 6.9.3 Coupling Design Unlike topside pumps, spacer couplings are not used in subsea pumps for mechanical seal replacement due to space restrictions and inaccessibility to do maintenance work. The coupling spacer may be needed for other functions as noted by the vendor. Rigid (non-flexible) couplings may be used for subsea pump – motor units. If specified, couplings shall meet the requirements of ISO 14691, ISO 10441 or ANSI/API 671. If specified, coupling hubs shall be fitted hydraulically. (This may need to be a requirement on rotodynamic pumps operating above 3800 rpm). 45 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 46 Coupling guards are not necessary in subsea pumps since the coupling is most often contained inside the pressure boundary housing. If the coupling is not contained within the pump/motor housing, then corrosion resistant coupling guards as required in API 610 and 676. shall be supplied. 6.9.4 Alignment Unlike topside pumps, alignment is typically maintained in subsea pumps through the use of rabbet fits. On subsea pumps it is often necessary for the coupling design to allow for variations in motor shaft projection. Splines or other methods are allowed based on the specific design requirements. In case splines are used, special precautions must be taken with regards to pump – motor alignment in order to avoid spline fretting. Proper shaft alignment between pump and motor is of utmost importance in subsea units with non-spacer type couplings. The design and assembly procedure must include a recognized method for measurement and validation of both angular and parallel alignment. If not otherwise agreed, the maximum shaft and housing run-out limits illustrated in Figure 4 and specified in Table 10 shall be used. Figure 4: Alignment of Motor and Pump 46 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 47 Table 9 - Motor Shaft and Housing Run-out Limits Dial gage Description Requirement A B C Shaft run-out Shaft-to-housing mating face radial direction Shaft-to-housing mating face axial direction 30 µm TIR 50 µm TIR 50 µm TIR Unless otherwise specified, couplings between motors and driven equipment shall be supplied and mounted by the vendor with unit responsibility. If specified, all-metal flexible element, spacer-type couplings shall be manufactured in accordance with AGMA 9000 Class 9. Additionally, couplings shall comply with the following: ― Flexible elements shall be of corrosion-resistant material ― Couplings shall be designed to positively retain the spacer if a flexible element ruptures NOTE The use of bolt heads or flexible element fasteners alone to retain the spacer (if a flexible membrane ruptures) might not provide reliable support because they are subject to wear after the failure. ― Coupling hubs shall be steel or alloy steel ― Unlike topside pumps, spacer couplings are not used in subsea pumps for mechanical seal replacement. The coupling spacer may be needed for other functions as noted by the vendor ― Unlike topside pumps, alignment is typically maintained in subsea pumps through the use of rabbet fits ― Couplings operating at speeds in excess of 3 800 rpm shall meet the requirements of ANSI/API 671 for component balancing and assembly balance check Information on shafts, keyway dimensions (if any), and shaft end movements due to end play and thermal effects shall be furnished to the vendor supplying the coupling. Flexible couplings shall be keyed to the shaft. Keys, keyways and fits shall conform to AGMA 9002, Commercial Class. Shaft coupling keyways shall be cut to accommodate a rectangular cross section key. Sled-runner type keys and keyways shall not be provided. Keys shall be fabricated and fitted to minimize unbalance. High speed rotodynamic pumps may require hydraulic fit coupling hubs or other methods. Couplings and coupling to shaft junctures shall be rated for at least the maximum motor power, including the motor service factor. Coupling hubs designed for interference fits to the shaft shall be furnished with tapped puller holes at least 10 mm (0.38 in) in diameter to aid in removal. On subsea pumps it is often necessary for the coupling design to allow for variations in motor shaft projection. Splines or other methods are allowed based on the specific design requirements. If specified, couplings shall be fitted hydraulically. (This may need to be a requirement on pumps operating above 3800 rpm). 47 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 48 If specified, couplings shall be fitted with a proprietary clamping device. Acceptable clamping devices may include tapered bushes, frictional locking assemblies and shrink discs. The vendor responsible for the final machining of the hub bores shall select a suitable rating/size device to suit the coupling and the application. Care should be exercised in the selection of these devices, as some are not inherently self-centering and may introduce eccentricity and unbalance into the coupling assembly. This effect shall be evaluated and allowed for when determining coupling potential unbalance. Subsea motors are always supplied by the pump module vendor and mounted by the pump module vendor. Coupling guards are not necessary in subsea pumps since the coupling is most often contained inside the pressure boundary housing. If the coupling is not contained within the pump/motor housing, then corrosion resistant coupling guards as required in API 610, 676, etc. shall be supplied. Unless otherwise specified, cooling systems shall be designed for external subsea conditions in Table 2. 6.10 Motor Cooling Systems The need for cooling shall be determined by the vendor, and the method shall be agreed upon with the purchaser. Vendors may propose external cooling coils to exchange the heat to the sea water. If specified, the cooling coils shall be accessible on the outside for flushing/cleaning with ROV. Details on method and the required space shall be agreed. Provision shall also be made to allow the cleaning of jackets or cooling coils, after retrieval. Jacket systems, if provided, shall be designed to prevent the process stream from leaking into the jacket. Jacket passages shall not open into casing joints. Provisions shall be made for complete venting and vacuuming of the cooling system prior to delivery. The same design rules regarding pressure, temperatures and water depth apply for cooling coils or jackets as for pressure casings in chapter 6.3. The rheological and heat transfer properties for coolants shall be carefully evaluated for pressure and temperature effects and their suitability for subsea use. Oil-based fluids should also be evaluated for gelation and other thermal effects. 48 THIS 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 49 In order to meet the requirements of the various test and operation environments, the motor cooling system design shall include an evaluation of: ― Test environment conditions including circulation and temperature. The cooling system shall be dimensioned to allow full load testing in the test pit during FAT at the actual pit temperature. ― Operational environment conditions including the effect of pressure, temperature and salinity on the heat transfer properties of seawater ― Variability of environmental conditions between intended operating depth and locations ― Fouling and scaling shall be considered in the design. The cooling coils or cooling jacket shall be 2 o designed for a minimum (internal+external) fouling factor of 0.35 m2∙K/kW (0.002 hr∙ft ∙ R/BTU) with additional requirements for bio-fouling and other application specific conditions. ― Access should be included if mechanical cleaning using ROVs is assumed in the design. 6.11 Barrier and Lubrication System Where relevant, the motor should be protected by a barrier fluid and shall ensure that the design of both the motor and barrier fluid system maintains over pressure above the pump process pressure and provides sufficient lubrication and heat transfer cooling of motor components. 49 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 50 7 Pump Control, Protection and Monitoring Systems 7.1 General The control, protection and monitoring systems for subsea pumps shall be designed in accordance with applicable sections of API 17F. Specific functional requirements for the control and monitoring systems are given in the sections below. 7.2 Functional Requirements for Control Systems 7.2.1 General The functional requirements of the pump control system are listed below for the pump system and associated subsystems. 7.2.2 Pump System – – – – – – Respond to Emergency Safety System (ESS) signals and take appropriate actions to secure the system Ensure pump suction and discharge pressures/temperatures remain within their predetermined limits, and to take appropriate actions to prevent damage to equipment or the environment Continuously maintain subsea pump operation within its designated operating envelope Protect the subsea pump from flowline transients by taking appropriate action Avoid prolonged/continuous operation in structure resonant frequencies, if any Continuously monitor VSD frequency with fail-safe feedback loop. The subsea pump suction and discharge pressures shall be monitored with two separate subsystems within the subsea control system. The intent of this is to mitigate common mode failures between those two pressure monitoring systems. Each of the two pressure monitoring subsystems shall be capable of independently halting pump operation in the event of adverse pressure conditions. 7.2.3 Pipeline Isolation The subsea pump shall be isolated from production pipe line with isolation valves. The control system shall ensure the closing duration of the subsea pump isolation valves is short enough to protect subsea pump from flowline pressure transients such as ESD boarding valve closure in any production flow conditions. 7.2.4 Barrier Fluid System The barrier fluid system for the subsea pump shall be designed to continuously provide barrier fluid to the subsea pump during facility evacuation, to continuously protect the subsea pump during subsea pump and/or pump manifold leak test, and also to lubricate and regulate temperature of mechanical pump components. 50 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 51 The control system for the barrier fluid system shall be required to continuously monitor subsea barrier fluid consumption, pressure and temperature, replenish barrier fluid as needed and also regulate subsea barrier fluid supply pressure according to production pressure to ensure positive pressure over mechanical seals. The barrier fluid system shall also be required to maintain a positive pressure during facility evacuations. Maximum design pressure for the barrier fluid system and the associated control system shall be specified in coordination with system leak test pressure. 7.2.5 Chemical Injection System Pressure transducers shall be included for monitoring of chemical injection pressures both at topside upstream of the umbilical and subsea upstream of the subsea chemical isolation valve(s). The monitored chemical injection pressures may be used by the control system to interlock subsea chemical injection valve opening and may be used to automatically close the subsea chemical injection valve to protect the subsea pump from chemical injection pressure transients. 7.2.6 Control System Communications Induced electrical noise from the medium/high voltage power lines shall be considered while choosing subsea communication method. The optical communication is the preferred method of communication. Induced voltage and induced electrical noise from the medium/high voltage power lines to lower voltage controls power lines shall be considered while designing subsea control system. All pump control system external and internal critical communications shall be fail-safe. In particular, in the event of loss communication with subsea, the Pump Control System shall stop the pump. Likewise, in the event of Variable Frequency Drive frequency feedback loop failure or operational discrepancy, the pump control system shall cause disconnection of supply power to the VFDs. 7.3 Functional Requirements for Monitoring Systems 7.3.1 Gauges If furnished, temperature indicators and pressure gauges shall be in accordance with API 614, as applicable to subsea environment and pressure. 7.3.2 Vibration Sensors When specified, accelerometers and/or proiximity probes shall be supplied, installed and tested in accordance with API 670. 7.3.3 Flowmeters Flowmeters may be implemented as a portion of the pump control / protection system. API RP 17S provides an appropriate guideline for design criteria appropriate for this use. Since the primary goal of the device is to identify operations outside the intended operating range of the pump, the following considerations are important. 51 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 52 The flowmeter system meter needs to provide results sufficiently quickly that the pump control system can react and respond. Bulk fluid rates and Gas Volume Fraction should be primary measurement capabilities of the flowmeter system. The meter accuracy and operating range needs to be sufficient for the pumping application. Specific examples of flowmeter requirements are listed below. – – High Gas Volume Fraction: The meter cannot operate with fixed fluid properties and needs to measure the gas rate or GVF directly over the intended operating range. High Flowrate: The pump vendor must identify the accuracy required to prevent stonewall. Continuous response capability may also be required and meter saturation needs to be considered. Low Flowrate: The pump vendor must identify the accuracy required to prevent stall/surge of the subsea pump. Continuous response capability may also be required. 7.3.4 Torque Sensors Because flowmeter responses show a sufficiently long lag between measurement and output, torque measurements provide immediate indications of high speed transients in fluid contents at the pump inlet. 52 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 53 8 Installation and Intervention 8.1 General The general requirements for the permanent and retrievable portions of a subsea boosting facility are described in: API 17D, Design and Operation of Subsea Production Systems—Subsea Wellhead and Tree Equipment API 17P, Design and Operation of Subsea Production Systems—Subsea Structures and Manifolds API 17R, Recommended Practice for Flowline Connectors and Jumpers The following portions of other relevant standards DO NOT apply to subsea boosting devices With the exception of the storage and preservation clauses, API 686 does not apply to subsea pump modules Baseplate portions of API 610, 676, 685, etc. do not apply to subsea pumps 8.2 Installation/Retrieval Considerations API 17P and API 17R provide descriptions for the frame and connections solutions of the considerations related to installation and retrieval of the pump module. During installation, the subsea boosting module solution should: – – – – – – – – – – – – not rely on hydraulic pressure to retain the necessary locking force in (module-to-module) connectors; allow cessation of operations without compromising safety allow testing/verification of interface connections subsequent to connection allow for quick, easy and reliable make-up of modules have facilities for testing prior to deployment by the use of test/transport skids, if applicable minimize entry of water or contamination into hydraulic and barrier fluid circuits during connections (which can jeopardize system functionality) facilitate orientation and guidance during installation may include shock absorbers or any soft landing devices, as required, in order to allow for specified maximum landing velocity be tolerant of small amounts of seabed debris between the interface connections or allow flushing prior to make-up operation avoid loss of harmful fluids during installation, operation and retrieval minimize impact of equipment malfunction leading to discharge of hydrocarbons facilitate periodic testing to verify that the system is fully functional An important consideration with respect to these equipment and the application of API 17TR12 is related to the temperature difference between subsea and surface conditions. A system flushed then closed-in prior to retrieval may see significant pressure increases as a result of thermal expansion of the trapped 53 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 54 fluids. Similarly, trapped fluids captured at surface conditions then heated by the production fluids and o boosting system may be subjected to the same issue. Trapped seawater subjected to a 75 F (42 C) will generate a pressure rise in excess of 4350 psi (300 bar). In addition to thermal expansion, trapped hydrocarbons may undergo a phase change as a result of the temperature rise during retrieval. In addition to the requirements described in API 17P and API 17R, the following requirements should be evaluated: – – – – – – – Flushing facilities to minimize hydrocarbon or other harmful fluid volumes trapped within the item to be retrieved. Flushing infrastructure should be designed to provide effective flushing of the module to be retrieved A recommended flushing procedure may also be part of the manufacturer documentation. If the system is to be retrieved or transported as a sealed assembly, a solution allowing for pressure relief during retrieval or transport should be considered as part of the design. Retrievable modules should be designed to enhance flexibility in the choice of installation/ maintenance vessels The pump module should be designed for entry through the splash-zone – large closed surface-areas should be avoided Provisions should be made for draining, flushing, and filling of structural steel during installation and/or retrieval Vendor to supply installation tools, lifting points to adhere to section 1.2.1 requirement 8.3 Transportation and Testing Equipment 8.3.1 General This scope of this section is limited to the initial delivery process to the purchaser. Consideration should be given to transportation and handling onshore as well as offshore. The retrievable module of the boosting system should be transported in a dedicated transport frame. Test stands and fixtures (including jigs) are used at the point of assembly or installation to verify the interface and functional operation, load and pressure capacity, and interchangeability of the equipment being installed. They may also serve as the shipping skids for transporting equipment offshore. 8.3.2 Lifting Arrangements Lifting lugs on transportation and testing equipment to allow handling may be supplied and should comply with certification agreed between the purchaser and the vendor. Testing of reusable lifting equipment is more stringent as this equipment is subject to lifting cycles throughout its lifetime. Annex K of API 17D provides design, testing, and maintenance guidelines for both reusable lifting equipment and permanently installed equipment. The design of test stands and fixtures shall consider assembly and handling loads as well as test loads. 8.3.3 Test Equipment Test stands and fixtures used only at the manufacturer’s facilities are outside the scope of this document. 54 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 55 Where test equipment is used to simulate mating components for testing the assembly of interest, they shall be made to the same dimensions and tolerances at all interfaces as the simulated component. 8.3.4 Test Stands Test stands simulate the profiles of the subsea manifold, flowbase, etc. to facilitate pressure testing of the pump module, and to position orienting joints relative to the subsea infrastructure. They may also contain hydraulic couplers and electrical connectors to facilitate testing of the controls and power related functions. Test ports shall communicate with the individual bores of the test stumps to facilitate pressure testing. The benefits of piping all test ports back to a common manifold with isolation test valves shall be examined. Guidance provided by the test stands shall simulate the requirements of the actual equipment being tested. 8.3.5 Equipment used for Shipping Test stands, etc. used for shipping equipment offshore shall provide protection to the equipment during handling and transportation. Sea fastenings shall be designed to take all the static and accelerated loading conditions due to roll, pitch and heave of the vessel in the locality where it will be transported and should be suitable for securing the assembly to the rig and rig skids. 8.4 Preservation and Storage 8.4.1.1 General The manufacturer should include the following considerations in the development of preservation and storage procedures. – – – Maximum and Minimum temperatures during transport from manufacturing site to installation site and including transshipment and storage sites Loads occurring during shipping or land transport Considerations of all exposed materials and storage conditions should be included in the evaluation of preservation fluids 8.4.1.2 Draining after Testing All equipment shall be drained and lubricated in accordance with the manufacturer’s written specification after testing and prior to storage or shipment. 8.4.1.3 Corrosion Prevention Prior to shipment, parts and equipment shall have exposed metallic surfaces (except those otherwise designated, such as anodes or nameplates) either protected with a rust preventive coating that does not 55 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 56 become fluid at temperatures less than 50 °C (122 °F) or filled with a compatible fluid containing suitable corrosion inhibitors in accordance with the manufacturer’s written specification. Equipment already coated, but showing damage after testing, should undergo coating repair prior to storage or shipment. 8.4.1.4 Sealing Surface Protection Exposed seals and seal surfaces, threads, and operating parts shall be protected from mechanical damage during shipping. Equipment or containers shall be designed such that equipment does not rest on any seal or seal surface during shipment or storage. Storage skids should be designed to simplify inspection of seal (and other) surfaces. 8.4.1.5 Loose Seals and Ring Gaskets Loose seals, stab subs, and ring gaskets shall be individually boxed or wrapped for shipping and storage. 8.4.1.6 Elastomer Age Control The manufacturer shall document instructions concerning the proper storage environment, age control procedures, and protection of elastomer materials. 8.4.1.7 Hydraulic Systems including Barrier Fluids Prior to shipment, the total shipment including hydraulic lines shall be flushed and filled in accordance with the manufacturer’s written specification. Exposed hydraulic end fittings shall be capped or covered. All pressure shall be bled from equipment, unless otherwise agreed between the manufacturer and purchaser. 8.4.1.8 Electrical/Electronic Systems The manufacturer shall document instructions concerning proper storage and shipping of all electrical cables, connectors, and electronic packages 8.4.1.9 Extended Storage Storage and preservation requirements for equipment after delivery to the user are beyond the scope of this document. The manufacturer shall provide recommendations for storage to the user upon request. Note that a requirement for mechanical operation during long term storage extends the scope of supply. 8.5 Pump Module Structure 8.5.1 General Subsea pump module, ROV panel, barrier fluid connections, power and control connections and instrumentation connections, etc., are supported in a structural frame which allows deployment and 56 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 57 retrieval using retrieval tools, ROV's etc. The structure is to be designed to be consistent with API 17P, 17R, 17D including lifting, side impact, and acceleration requirements associated with transport to from and within the intended market. The structure shall extend such that nothing protrudes beyond the structure frame to the side and top other than safety ladders and attachment points. If specified, the support structure shall be constructed to deflect or guide fishing nets or other drawn objects around the structure to less chance of damage to the structure and its contained components. 8.5.2 Vibration For vertical units, the Pump Module Support Structure together with the pump module shall have their first (fundamental) natural frequencies 25 % below the lowest operational speed of the unit. The natural frequencies analysis together with a response analysis shall be documented in a report. This shall as a minimum include: – – – A description of the analyzed model, the methods used and the assumptions made during the analysis The calculated natural frequencies from 0 Hz up to minimum 150 % of maximum speed and plots showing their corresponding mode shapes, and The response analysis in both displacement (mm) and vibration (mm/s) caused by a unit load (for instance 1000 N) on each pump and motor bearing locations. The analysis shall be run continuously from 0 Hz up to minimum 150 % of maximum speed with a reasonable delta frequency (for instance 1 Hz) Note: In order to avoid resonances between the natural frequencies of the Pump Module, Support Structure and the operational frequency of the unit, it is very advantageous to have the first natural frequencies of the structure well below the operational frequencies in order to make the unit “mass dependent”. Subsea pump units typically contain sufficient mass in the motor and pump casing to avoid inappropriate vibration responses. 8.6 Pressure-Limiting Valves Pressure-limiting valves or other protective devices shall be used with all positive displacement pumps. Rupture disks shall not be used. The sizing, selection and installation of pressure limiting valves shall meet the requirements of API Recommended Practice 520, Parts I and II. Unless otherwise specified, the purchaser shall provide pressure-limiting valves in accordance with API 526. The vendor shall provide the purchaser with information on recommended flow rate and relieving pressure. The vendor and purchaser should review the purchaser’s valve selection. Pressurelimiting valve sizes and settings, including accumulation, shall take into account all possible modes of equipment failure and shall meet the requirements of 6.3.2. If specified, the valve shall be provided by the vendor. Unless agreed to by the purchaser, pressure limiting valves that are integral with or internal to the pump are not acceptable. 57 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 58 8.7 Piping and Appurtenances 8.7.1 General Piping shall be in accordance with the requirements described by API 17P and 17R. Auxiliary systems are defined as piping systems that are in the following services: – – – auxiliary process liquids barrier fluid/lubricating fluid or oil, and cooling water circulation if utilized Auxiliary system materials shall be agreed upon by vendor and purchaser. Table H.4 in API 610 may be of some assistance but was not written for subsea environment. Barrier/buffer fluid valves/makeup reservoirs and any piping system as a whole shall be mounted in the pump module structure and fully assembled. The vendor shall furnish and locate all piping systems, including mounted appurtenances, within the confines of the pump module structure. Each piping system requiring umbilical or ROV interface shall be manifolded to a single purchaser's inlet or outlet connection near the edge and within the confines of the pump module structure in a section that will be accessible once the pump module is mounted in the pump manifold. Plugs shall be avoided. 8.7.2 Auxiliary Process Liquid Piping Auxiliary process-liquid piping includes vent lines, drain lines, balance lines, product flushing lines and lines for injection of external fluid. Piping components shall have a pressure-temperature rating at least equal to MAWP of the pump casing. Piping and components subject to the process liquid shall have a corrosion/erosion resistance equal to or better than that of the casing. Otherwise, all components shall be steel. Orifice openings shall not be less than 3 mm (0.12 in) in diameter. Orifice hole size shall be stamped on the orifice plate. The purchaser shall specify orifice tagging or labelling requirements. Drain valves and a drain manifold shall be supplied for pumps that require more than one drain connection. The drain manifold shall be inside the pump module structure limits. The purchaser and vendor shall agree upon whether the valves are to ROV operated, or, only hand operated once the pump module has been retrieved for maintenance. If heating or cooling is provided, each exchanger component shall be suitable for the process liquid and ambient water to which it is exposed. Threaded piping joints shall not be used. 58 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 59 8.7.3 Cooling-Water Piping Cooling loop piping on subsea pumps is very special and the schematics in API 610 and other specs are probably not adequate to describe the needs of subsea pump cooling, barrier fluid piping, etc. The purchaser and vendor shall agree on any cooling loop piping systems. The cooling-water piping shall be designed for all of applications including qualification, and factory acceptance test conditions. 8.8 Special Tools If special tools and fixtures are required to disassemble, assemble, or maintain the unit, they shall be included in the quotation and furnished as part of the initial supply of the machine. For multiple-unit installations, the requirements for quantities of special tools and fixtures shall be agreed upon by the purchaser and the vendor. These or similar special tools shall be used during shop assembly and posttest disassembly of the equipment. If special tools are provided, they shall be packaged in separate, rugged metal boxes and marked “special tools for (tag/item number)”. Each tool shall be stamped or tagged to indicate its intended use. 59 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 60 9 Qualification and Application Specific Testing 9.1 Scope 9.1.1 General The API RP 17X testing section recommends system and sub-system level qualification and application specific tests. The section describes procedures for qualification testing of new or significantly modified solutions. The section further describes application specific testing of pumps and motors in series that have already successfully undergone and passed qualification testing. Application Specific Testing Application specific testing is intended to confirm that systems made after the first production run have been manufactured correctly. Qualification Testing Qualification testing is driven by new or changed, pump and motor designs, applications or operating conditions and combinations thereof that have not been previously demonstrated via qualification tests. The tests will bring the subsea pump and motor to a minimum TRL 4, as defined in API 17N. Qualification tests will require more resources and post-test inspection than application specific tests. Endurance Testing (or Extended Testing) Endurance tests are tests aimed at establishing the reliability model for a system (as per TRL 4 of API 17N). As a result of that relationship, it is only required for first in series testing of products with fundamental changes in one or more of: a) Absorbed power b) Flow capacity c) Orientation d) Bearing philosophy e) Lubrication/cooling system Component and reliability testing are required to reach TRL 2 and 3. These system level tests supplement the qualification process developed according to API 17N (TRL/TRC assessment, FMECA, RBD, RAM, Qualification Plan). All testing prior to system level tests fall outside the scope of this section. The system tests defined herein reduce the risk of deploying equipment that either lacks successful field experience or lacks relevant experience in the required operating conditions. 60 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 61 9.1.2 Test Validity Qualification tests on pump systems shall remain valid on subsequent pump systems when the following conditions are met: a) The qualified system shall have equal or higher ratings than the subsequent system for each of the following parameters. ― Power (MW or hp) 3 ― Flow-rate (m /hr or bpd) ― Head (m or ft) ) or differential pressure (psi/bar ― Rotational Frequency (RPM) ― Shut-in pressure (bar or kpsi) ― Maximum operating temperature (ºC or ºF) ― Orientation (horizontal or vertical) b) The qualified system shall have a GVF range that is equal to or includes the allowable GVF range for the subsequent system. For example, if the qualified system GVF range is 20 to 60 %, a subsequent system can have a range of 20 to 60 % GVF or 30 to 50 % GVF without requalification. c) The subsequent system shall use a barrier fluid (if required) that has been tested and qualified with the qualified system. d) The subsequent system shall use a barrier fluid (if required) that has been tested and qualified with the qualified system. e) f) he qualified system should be tested under slug flow regime conditions. All qualification tests must be repeated if any of the conditions above are not satisfied. A subsequent pump system only requires application specific testing if the conditions above are satisfied. 9.1.3 Pump System Layout The boundaries of the boosting system (pump and motor) referenced within this document extend from inlet flange to outlet flange of the pump module and includes the power system from the drive down to the motor. The pump control (pump instrumentation to topsides control system) and barrier fluid systems to mechanical seals are also included. When use of full scale components is not feasible, components may be simulated. For example, an umbilical can be simulated by the use of an umbilical simulator. Components from the larger system may be required for some tests on the pump and motor. The system tests apply to a typical subsea boosting system, which are generally composed of the following qualification and application specific testing objects (See Table 10). Figure 5 is a flowchart describing the decision process for choosing between paths (qualification or application specific testing). 61 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 62 Table 10 - Scope of Test Object Test Object Qualification Application Specific Test Required Required Optional Emulated Emulated Contract Transformer Emulated Contract VSD If relevant If relevant Pump and motor Required Required Barrier fluid system If relevant If relevant If Integrated If Integrated Emulated Required Required Required Buffer tank (for MPP) For Slug Tests Required Liquid extraction unit If Relevant If Relevant Recycle valve If Relevant If Relevant Recycle coolers If Relevant If Relevant Power Distribution and Communications: Subsea power interface/connectors Subsea power umbilical a Subsea or topsides transformers b Variable speed drive SCM or equivalent c Pump Module: Pump sump Pressurization system d Motor/lubricant cooler (s) Pump Station: Notes: a The power umbilical is an application specific item with the details of the manufacturing solution affecting the design of the emulator. b The emulation of the subsea transformer should be based on the use of the topsides equivalent model. c An SCM may not always be implemented. Alternative solutions must be included as a portion of the qualification/application specific program. d The dynamics of the hydraulic solution are application specific. Application specific tests should be performed with an appropriate HPU and relevant umbilical emulation. 62 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 63 Figure 5 - Decision Tree for Testing The above list is for reference only and is not intended to be comprehensive. It is a high level collection of components meant to show the reader the scope and size of the boosting system referenced within this document. Component level tests shall be performed prior to conducting the system testing. Component tests are not defined in this document; however, relevant component level tests defined in other industry standards are referenced where possible. The tests apply to the pumps described in Table 1. 63 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 64 9.2 Individual Tests 9.2.1 General This document defines test procedures for the following types of boosting system tests: ― Start-up and Shutdown ― Locked Rotor Start-up ― Normal Performance Operation ― Liquid Slugging ― Extended Performance and Operation In addition to defining the system tests, this document defines how to report system performance test results. The standard set of boosting system performance results enables straightforward comparisons of different boosting systems. The tests are divided into two categories, one aimed at new product qualification which is characterized by generic specifications and undefined contractual relationship between pump vendor and operator. The second category is aimed at product application acceptance which is characterized by testing a separately qualified design against application specifications and a clear contractual relationship between pump vendor and operator. The project/application specific test requirements are a subset of the qualification process. NOTE Unless otherwise specified, ‘maximum’ refers to the maximum operating condition for any given parameter, according to the design of the system and the range of operating conditions for which it shall be qualified. NOTE Unless otherwise specified, ‘minimum’ refers to the minimum operating condition for any given parameter, according to the design of the system and the range of operating conditions for which it shall be qualified 9.2.2 Reporting Requirements Test reports that follow these tests shall be comprised of operating and inspection data. 9.2.3 Operating Data The following parameters shall be monitored and included in the test report: ― Pump inlet and discharge pressure ― Pump inlet and discharge temperature ― Pump speed 64 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 65 ― Flowrate ― GVF ― Inlet barrier fluid temperature (if relevant) ― Barrier fluid leakage rate (for steady state operation only) ― Barrier fluid temperature within motor ― Balance line pressure (if applicable) ― Motor current ― Motor voltage ― Pump and motor rotor vibration data (rotor radial and axial displacements relative to the casing) ― Pump and motor casing vibration data (accelerometer data) ― Barrier fluid cleanliness measurement (e.g. by sample and analysis) ― Barrier fluid dielectric properties (conductivity and relative permittivity at a given frequency), if applicable ― Process fluid density (measured at pump inlet) ― Motor winding temperature (if available) ― Barrier fluid temperature upstream and downstream of cooler ― Barrier fluid flow rate within the cooling loop NOTE A minimum of 2 pairs of radial proximity probes shall be installed during qualification testing for each rotor, one for each journal bearing. 9.2.4 Inspection Data and Inspection Criteria 9.2.4.1 After Qualification Testing After qualification testing is complete, the pump shall be disassembled and inspected for wear or damage to the following components listed in 9.2.3.1.1 and 9.2.3.1.2. No visible or measured signs of damage or wear shall be present, beyond what is deemed acceptable between the pump supplier and operator. No evidence of debris generation from the pump/motor shall be present in the barrier fluid system. 65 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 66 ― Operator shall be permitted time to make a visual inspection of the disassembled pump and motor components, including the mechanical seal, radial and thrust bearings ― Microscopic inspection of seal faces and elastomers shall be performed; which and how many to be agreed between vendor and purchaser ― Bearing pad wear shall such that the bearing is within original manufacturing tolerances after the test ― Bearing edge wear shall not be visible to the naked eye ― Bearing clearances shall be reported ― Any deterioration of seal or bearing components shall be reported ― Any contamination of barrier fluid shall be reported ― Mechanical seal components shall be measured before and after testing 9.2.4.2 After Application Specific Testing Pump disassembly is not required for application specific testing. Analysis of operating data is sufficient to confirm that the pump is not damaged during this form of testing. 9.2.4.3 Factory Acceptance Testing Pump disassembly is not required for application specific testing. Analysis of operating data is sufficient to confirm that the pump is not damaged during this form of testing. 9.3 Pump Acceptance Criteria 9.3.1 General The following parameters shall be subject to acceptance criteria: 9.3.2 Vibration Data Vibration acceptance criteria are listed in Section 11.2.5 with the following additions: – – Pump peak-to-peak vibration measured at radial bearings shall meet pre-determined supplier criteria for overall, synchronous, and non-synchronous components Motor peak-to-peak vibration measured at radial bearings shall meet pre-determined supplier criteria for overall, synchronous, and non-synchronous components 66 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 – – – – 67 For each test point, the pump and motor vibration data shall remain consistent from the beginning to the end of testing within the noise range of the measurement. (For example, if the pump driven end peak-to-peak vibration is 60 microns +/- 10 % for test point 7 within the first 100 hours of testing, the same vibration levels shall be measured for test point 7 in the last 100 hours of testing.) The supplier shall demonstrate that vibration levels do not increase throughout the endurance tests Maximum allowable bearing and seal clearances taken up by shaft vibration shall meet predetermined supplier criteria Observed critical speed(s) indicated by a distinct vibration peak and appropriate phase shift shall occur within +/-10& of the calculated value(s) per API 610 1.2.4a Measured vibration amplitudes shall be within 35% of calculated values per API 610 1.2.4b 9.3.3 Pump Performance – – – – Pump shall produce head and flow rate at a given power, as stated in the contract Barrier fluid leakage rate shall conform to the rate agreed by operator, supplier, and VENDOR The maximum speed of barrier fluid pressure change (bar/second) must be reported and held within the values agreed on by the operator, supplier, and VENDOR Pressure differential between barrier and process fluid must also be measured, reported, and held within the agreed upper and lower limits 67 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 68 10 Materials and Materials Inspection 10.1 Scope This clause covers both covered by and items not covered by API 17A, 17P, 17R. The relevant material class should be chosen using the methodology described in API 6A Clause 4.2. Further API 6A Clause 6.15 describes the material performance, processing and compositional requirements for the pump casing and other pressure containing parts in the pump assembly. Other pressure-containing and pressure-controlling parts shall be made of materials that satisfy 6.15.2 and the design requirements of API 6A Clause 4. All material requirements in API 6A Clause 6.15 apply to carbon steels, low-alloy steels and martensitic stainless steels (other than precipitation-hardening types). Other alloy systems (including precipitationhardening stainless steels) may be used, provided they satisfy the requirements of Clause 6.15 and the design requirements of API 6A Clause 4. 10.2 Special Materials Special materials and processing methods such as Hot Isostatic Pressing are covered by ISO 17782 and NORSOK M-650 ed.4 and are subject to the qualification procedures covered by the referenced standards. 10.3 Connectors, Piping, Valves, and Structure The design and materials requirements for connectors, valves, piping, and structural items are described in API 17D, API 17P, and API 17R. 10.4 Fasteners Fasteners for load bearing or pressure containing items shall be compliant with subsea requirements as described in API 6A, API 20E, and API 20F. Bolting and threads for pressure containing applications, end and outlet connections shall follow the guidelines as established in: ― API Spec 6A section 10.1. ― API Spec 20E ― API Spec 20F ― The API Task Group Report on Bolting Failures 68 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 69 API SPEC 6A section 4.3.4 and 4.4.3 shall apply to any other types of bolted connections exposed to the environment and/or connecting pressure boundary parts or parts that are designed as or could become pressure boundaries in the event of a failure of other components. 10.5 Written Specifications: Pump and Motor Casing 10.5.1 General In keeping with API 6A, all metallic and non-metallic pressure-containing or pressure-controlling parts shall require a written material specification. 10.5.2 Metallic Requirements For this application, the items in question are typically required to follow API 6A PSL 3. The manufacturer's written specified requirements for metallic materials for bodies, bonnets, end and outlet connections, stems, valve bore sealing mechanisms and mandrel hangers shall define the following, along with accept/reject criteria noting: ― mechanical property requirements ― material qualification ― heat-treatment procedure, including cycle time, quenching practice and temperatures with tolerances and cooling media ― material composition with tolerances ― non-destructive examination (NDE) requirements ― allowable melting practice(s) ― forming practice(s), including hot-working and cold-working practices, and ― heat-treating equipment calibration 10.5.3 Non-metallic Requirements Non-metallic pressure-containing or pressure-controlling seals shall have written material specifications. The manufacturer's written specified requirement for non-metallic materials shall define the following: ― generic base polymer(s); see ASTM D1418 ― physical property requirements ― material qualification, which shall meet the equipment class requirement ― storage and age-control requirements 69 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 70 10.6 Property Requirements: Pump and Motor Casing 10.6.1 General The reader is referred to the API Specification 20 series (20B and 20C) for vendor and forging qualification details with the further requirement for FSL levels 2 and higher. The general guidelines for other portions of the supply are in keeping with PSL3 as defined in API 6A. 10.6.2 Mechanical Properties The following apply noting that the pressure casing is treated as a body. Specifically, API 6A clauses 5.4.1 and 5.4.2 apply. 10.6.3 Material Qualification Testing The reader is referred to the API Specification 20 series (20B and 20C) for vendor and forging qualification details applying the rules for FSL levels 2 and higher. 10.7 Processing: Pump and Motor Casing 10.7.1 Quenching The procedures in API 6A clause 5.4.4.3 apply. 10.7.2 Chemical Composition Material shall conform to the manufacturer's written specification as described in API 6A clause 5.4.5. 10.7.3 Welding The reader is referred to API 6A Clause 6 and API 17D Clause 5.3 with the provision that the items shall meet the requirements of PSL 3. 10.8 Manufacturing Quality Control: Pump and Motor Casing Unless otherwise specified, pressure-casing materials shall be inspected in accordance with the requirements of Table 11 below (which mimics Table 14 of API 610). 10.9 Non-destructive Examination Personnel 10.9.1 General Personnel performing NDE shall be qualified in accordance with the manufacturer's documented training program that is based on the requirements specified in ISO 9712 or ASNT SNT-TC-1A. 7.3.2. 70 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 71 Table 11 - Inspection Classes as Applied to API 17X Inspection Class Type of Component I — b Casing : wrought c Nozzle weld: casing Auxiliary connection d welds Internals Screw tips’ hardened surfaces a b c d e II III <0.5 SG or > 200 °C (392 °F) and < 0.7 SG, or > 260 °C (500 °F) e Extremely hazardous services VI, plus MT or PT (critical areas), plus UT (critical areas) VI, plus 100 % MT or PT plus RT (100 %) Minimum >80 % MAWP and > 200 °C (392 °F) VI, plus MT or PT of critical areas VI, plus MT or PT of critical areas VI, plus 100 % MT or PT VI, plus 100 % MT or PT VI, plus MT or PT VI, plus MT or PT VI, plus MT or PT (100 %) VI VI VI UT UT UT Definition of abbreviations: VI: Visual inspection MT: Magnetic particle inspection PT: Liquid penetrant inspection RT: Radiographic inspection UT: Ultrasonic examination “Casing” includes all items of the pressure boundary of the finished pump casing (e.g. the casing itself and other parts, such as nozzles, flanges, etc. attached to the casing). “Critical areas” are inlet nozzle locations, outlet nozzle locations and casing wall thickness changes. The vendor shall submit details of the critical areas proposed to receive MT/PT/RT/UT inspection for purchaser's approval. “Wrought” materials include forgings, plate and tubular products. Due to complex geometry and thickness variations, it is not practical to RT butt-welded auxiliary casing connections. Extremely hazardous services, as specified by the purchaser. 10.9.2 Visual Examination Personnel Personnel performing visual inspection for acceptance shall take and pass an annual vision examination in accordance with the manufacturer's documented procedures that meet the applicable requirements of ISO 9712 or ASNT SNT-TC-1A. 10.9.3 Welding Inspectors Personnel performing visual inspections of welding operations and completed welds shall be qualified and certified as ― AWS-certified welding inspector ― AWS-senior certified welding inspector ― AWS-certified associate welding inspector, or ― welding inspector certified by the manufacturer's documented training program 71 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 72 10.9.4 Other Personnel All other personnel performing measurements, inspections or tests for acceptance shall be qualified in accordance with the manufacturer's documented procedures and requirements. 10.9.5 Material Testing The reader is referred to API 6A clause 7.4.2.3 with the following NDE inspection details as acceptable alternatives. 10.10 Pump Internals: Materials Considerations 10.10.1 General This sub-clause is limited to the internals of the pump and motor and treats them as identical similar items manufactured for surface application. As a result, the general recommendation is to refer to the appropriated design standard API 610 or API 676. These references are relevant both for: ― Materials specifications ― Materials inspection requirements To assist with the choice of materials, the purchaser needs to include a complete list of fluids to which the pump shall be exposed. That list should at least contain: a) A detailed fluid composition including trace components such as mercury, CO 2, H2S, etc. ― A complete Equation of State characterization should be provided ― A set of reference data in the form of a phase envelope and matching data from petroleum fluid studies should be provided b) Expected variation in fluid composition over time as well as appropriately matched turndown requirements (flows and temperatures at : minimum condition, expected condition, and maximum conditions). c) Expected sand and other solids production. d) Expected extremes in temperatures as a result of start-up procedures. e) A complete list of production chemicals to which the pump may be exposed. 10.10.2 Rotodynamic Pumps This group includes centrifugal and helico‑axial pump designs. API 610 provides guidance on materials related considerations. The manufacturer should provide a materials philosophy document with the technical proposal. 72 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 10.10.3 73 Rotary Pumps This group includes the subsea application of designs described by API 676 which provides some guidance on materials related considerations. The manufacturer should provide a materials philosophy document with the technical proposal. 73 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 74 11 Manufacturing, Inspection, and Preparation for Shipment 11.1 General The purchaser shall specify the extent of his participation in the inspection and testing. Witnessed Performance tests are required for Subsea pumps. Examples: ― If shop inspection and testing have been specified, the purchaser and the vendor shall coordinate manufacturing hold points and inspector’s visits ― The expected dates of testing shall be communicated at least 30 days in advance and the actual dates confirmed as agreed. Unless otherwise agreed, the vendor shall give at least five working days advanced notification of a witnessed or observed inspection or test ― For smaller pumps where set-up and test time is short, five to ten business days’ notice may require the removal of the pump from the test stand between preliminary and witness tests ― All witnessed inspections and tests are hold points. For observed tests, the purchaser should expect to be in the factory longer than for a witnessed test ― If specified, witnessed mechanical and performance tests shall require a written notification of a successful preliminary test. The vendor and purchaser shall agree whether or not to maintain the machine test set-up or whether the machine can be removed from the test stand between the preliminary and witnessed tests The vendor shall notify sub-vendors of the purchaser’s inspection and testing requirements. After advance notification to the vendor by the purchaser, the purchaser’s representative shall have reasonable access to all vendor and sub-vendor plants where manufacturing, testing or inspection of the equipment is in progress. The level of access shall be agreed upon. Equipment, materials and utilities for the specified inspections and tests shall be provided by the vendor. If specified, the purchaser’s representative, the vendor’s representative, or both, shall indicate compliance in accordance with an inspector’s checklist such as that provided in Annex E by initialing, dating and submitting the completed checklist to the purchaser before shipment. The purchaser’s representative shall have access to the vendor’s quality program for review. 11.2 Inspection and FAT Testing 11.2.1 General The vendor shall keep the following data available for at least 20 years: 74 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 75 ― necessary or specified certification of materials, such as mill test reports ― test data and results to verify that the requirements of the specification have been met ― if specified, details of all repairs and records of all heat-treatment performed as part of a repair procedure ― results of quality control tests and inspections ― as-built running clearances ― other data specified by the purchaser or required by applicable codes and regulations (see 10.3.1 and 10.3.2) In addition to the requirements of 6.12.1.5, the purchaser may specify the following: – – parts that shall be subjected to surface and subsurface examinations type of examination required, such as magnetic-particle, liquid-penetrant, radiographic and ultrasonic examinations All preliminary running tests and mechanical checks shall be completed by the vendor before the purchaser’s final inspection. 11.2.2 Additional Test Instrumentation Subsea pump – motor units shall be equipped with a minimum 5 accelerometers or velocity meters attached to the outside of the pump and motor casing during FAT or EFAT. ― Two radial in orthogonal directions on the top of the motor casing ― Two radial in orthogonal directions on the bottom of the pump casing ― One axial close to the thrust bearing 11.2.3 Performance Test Unless otherwise specified, each pump shall be given a submerged performance test. The following requirements of a) through i) shall be met while the pump is operating on the test stand and before the performance test is performed. ― The contract seals and bearings shall be used in the pump for the performance test ― The seal (or seals) shall not have a leakage rate during any phase of the pump performance test that is in excess of that specified in API 682 A.1.3 or as otherwise agreed by the vendor and purchaser. Any unacceptable leakage during the pump performance test requires a disassembly and repair to the seal. If the seal is disassembled or removed, the seal shall be retested with an air test of the pump using the criteria defined in 8.3.3.7 d) 75 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X NOTE 76 Subsea pumps typically have a barrier fluid pressure well above the pump pressure in the seal chambers so any leakage will be barrier fluid into the pumpage, not pumpage into the barrier fluid – which could cause damage to motor and other components ― If specified, seal leakage during test shall require the assembled pump and seal to be rerun to demonstrate satisfactory seal performance ― All lubricating-oil pressures, viscosities and temperatures shall be within the range of operating values recommended in the vendor’s operating instructions for the specified unit being tested ― Bearings specified as normally lubricated from a pure oil-mist system shall be pre-lubricated prior to performance testing using a suitable hydrocarbon oil ― All joints and connections shall be checked for tightness and any leaks shall be corrected ― All warning, protective and control devices used during the test shall be checked and adjusted as required ― Unless otherwise agreed, performance tests shall be performed using water at a temperature not exceeding 55 °C (130 °F). Multi‑phase tests shall be performed with fluids/gases as agreed between purchaser and vendor Unless otherwise specified, the performance test including test tolerances and pass criteria for single phase fluids, shall be conducted as specified in API 610, 676, 685, etc. For multi‑phase fluids, the performance test shall be conducted as agreed upon by the purchaser and vendor. While vibration and other data that is not attainable for subsea pumps due to component inavailability or limitations can often be applied in an FAT environment. Where these measurements are possible, API 610, 676, and 685 vibration levels and other acceptance criteria shall be used. Vibration limits and methods of measuring shall be agreed upon between purchaser and vendor. Due to multi‑phase excitations, compliance with API 610 for helico‑axial pumps is not possible. In any case the acceptance criteria for conditional monitoring instruments shall be agreed between the purchaser and vendor prior to the FAT. During the performance test, the requirements of a) through d) as follows shall be met. Vibration values shall be recorded at each test point (except shutoff for centrifugal pumps) during the test in accordance with 6.9.3.2. Vibration values shall not exceed those given in 6.9.3.6. The requirements of a) through d) as follows shall be met after the performance test is completed. a) If specified, disassembly of multistage pumps for any head adjustment (including less than 5 % diameter change) after test, shall be cause for retest. b) If it is necessary to dismantle a pump for any other correction, such as hydraulic performance, NPSH or mechanical operation, the initial test shall not be acceptable, and the final performance test shall be run after the correction is made. 76 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 77 c) The use of Test Seal Faces is not allowed. Unless otherwise specified and in keeping with API 6A, pumps shall not be disassembled after final performance testing. The pump internals exposed to the pumped fluid shall be drained to the extent practical, filled with a water-displacing inhibitor within 4 h of testing and redrained. The barrier fluid shall remain in place. 11.2.4 Optional Tests Optional tests fall into the category of Application or Project Specific Tests as described in Section 9. 11.2.5 Vibration Requirements 11.2.5.1 General In general for rotodynamic pumps and motors, the requirements in API 610 Chapter 6.9.3 apply. Some special requirements for subsea pumps are listed below. 11.2.5.2 Casing Vibration The overall vibration velocity requirements for subsea rotodynamic pumps and motors operating with single-phase and multi-phase up to 40 % GVF are shown in Figure 6 below. Figure 6 - Vibration Limits for Subsea Rotodynamic Pumps and Motors, GVF < 40% 77 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 78 The overall vibration velocity requirements for subsea rotodynamic pumps and motors operating with multi‑phase above 40 % GVF are shown in Figure 7 below. Figure 7 - Vibration Limits for Subsea Rotodynamic Pumps and Motors, GVF > 40% NOTE Subsea pump motor units usually incorporate a heavy casing surrounding the pump and motor unit. For practical and reliability reasons, accelerometers or velocity meters are attached on the outside of the casing. This will reduce the actual vibration compared to most topside units. The vibration limits listed in API 610 or other standards intended for topside machinery is not useful as the limits are too high. For this standard, it is suggested to use half the acceptance levels listed in API 610 for accelerometers or velocity probes attached to the outside of the casing. The overall vibration requirement is increased by 30% for operation outside the preferred operation region. Requirements for discrete frequencies are maximum 0.67 times the overall requirement. 11.2.5.3 Rotor Vibration When specified, the pump and motor shall be equipped with proximity probes for measuring the rotor movement during operation. This shall include two radial probes close to each radial bearing in both the pump and the motor, one axial probe close to the thrust bearing(s) and one probe for rotor speed/once pr. revolution marker. Pump-motor units were the two rotors are separated by a variable coupling like a hydrodynamic coupling, shall have separate probes for rotor speed/once pr. revolution marker on each rotor. The total mechanical and electrical run-out of the probe target area on the rotor shall be limited to maximum 20% of the allowable rotor vibration with a maximum of 16 µm Peak – Peak. See Figures 5 and 6. For subsea pumps and motors operating with single‑phase or multi‑phase up to 40% GVF, the requirement for maximum rotor vibration is 25% of the actual bearing clearance with a maximum of 65 µm 78 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 79 Peak – Peak both for the pump and the motor. In case run-out compensation is used, the overall vibration requirement is reduced to 19% of the actual bearing clearance with a maximum of 50 µm Peak – Peak. See Figure 8. Figure 8 - Rotor Overall Vibration Limits and Maximum Probe Target Run-out for Subsea Pumps and Motors Operating with Single‑phase or Multi‑phase GVF < 40% For subsea pumps and motors operating with multi‑phase above 40% GVF, the requirement for maximum rotor vibration is 35% of the actual bearing clearance with a maximum of 80 µm Peak – Peak both for the pump and the motor. In case run-out compensation is used, the overall vibration requirement is reduced to 28% of the actual bearing clearance with a maximum of 65 µm Peak – Peak. See Figure 9. 79 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 80 Figure 9 - Rotor Overall Vibration Limits and Maximum Probe Target Run-out for Subsea Pumps and Motors Operating with Multi‑phase GVF > 40% NOTE The vibration and run-out requirement based on the actual bearing clearance is chosen in order to avoid less robust bearing designs with reduced clearances which is aimed to reduce rotor vibration. The overall vibration requirement is increased by 30% for operation outside the preferred operation region. Requirements for discrete frequencies are maximum 0.67 times the overall requirement. 11.3 Preparation for Shipment Unless otherwise specified, equipment shall be prepared for domestic shipment. Domestic shipment preparation shall make the equipment suitable for outdoor storage for a period of at least six months with no disassembly required before operation except possibly inspection of bearings and seals. Preparation for longer storage or export shipment is more rigorous and, if specified, shall be provided by the vendor following agreed procedures. The equipment shall be prepared for shipment after all testing and inspection has been completed and the equipment has been released by the purchaser. The preparation shall include that specified below 1) through 9). a) Rotors shall be blocked if necessary. Blocked rotors shall be identified by means of corrosionresistant tags attached with stainless steel wire. b) Internal surfaces of bearing housings and carbon-steel oil-systems components shall be coated with an oil-soluble rust preventive that is compatible with the lubricating oil. 80 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 81 c) Bearing assemblies shall be fully protected from the entry of moisture and dirt. If vapor-phase inhibitor crystals in bags are installed in large cavities, the bags shall be attached in an accessible area for ease of removal. If applicable, bags shall be installed in wire cages attached to flanged covers and bag locations shall be indicated by corrosion-resistant tags attached with stainless steel wire. d) Exterior surfaces, except for machined surfaces, shall be given at least one coat of the vendor's standard paint. The paint shall not contain lead or chromates. It is not necessary to paint stainless steel parts. If appropriate, the undersides of baseplates shall be prepared for grout in accordance with API 610 section 7.3.12. e) Exterior machined surfaces, except for corrosion-resistant material, shall be coated with a rust preventive. f) Flanged openings shall be provided with metal closures at least 5 mm (0.19 in) thick, with elastomeric gaskets and at least four full-diameter bolts. For studded openings, all nuts required for the intended service shall be used to secure closures. g) Threaded openings shall be provided with steel caps or steel plugs in accordance with API 610 section 6.4.3.11. h) Openings that have been beveled for welding shall be provided with closures designed to prevent entrance of foreign materials and damage to the bevel. i) Exposed shafts and shaft couplings shall be wrapped with waterproof, moldable waxed cloth or volatile-corrosion inhibitor paper. The seams shall be sealed with oil-proof adhesive tape. Auxiliary piping connections furnished on the purchased equipment shall be impression-stamped or permanently tagged to agree with the vendor's connection table or general arrangement drawing. Service and connection designations shall be indicated. Lifting points and lifting lugs shall be clearly identified. The equipment shall be identified with item and serial numbers. Material shipped separately shall be identified with securely affixed, corrosion-resistant metal tags indicating the item and serial number of the equipment for which it is intended. Crated equipment shall be shipped with duplicate packing lists, one inside and one on the outside of the shipping container. One copy of the vendor's standard installation manual shall be packed and shipped with the equipment. The vendor shall provide the purchaser with API 686-compliant instructions for the preservation of the integrity of the storage preparation at the job site and before start-up. Pump module shall be shipped fully assembled in its support structure. If it is necessary to ship any major components separately, prior purchaser approval is required. If appropriate: 81 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 ― Metal filter elements and screens shall be cleaned and reinstalled prior to shipment. ― Non-metallic filter elements shall be shipped and installed in an unused condition Suitable rust preventatives shall be oil-soluble and compatible with all pumped liquids. 82 82 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 83 12 Vendor’s Data 12.1 General The information to be supplied shall be in agreement with the intentions of API 610 and API 676 modified for application to subsea project requirements and practices. Information described in Table XX, shall be supplied in accordance with the agreed documentation schedule as described during the tendering process. The documents shall be clearly marked to identify a) the purchaser’s/owner’s corporate name; b) the job/project number; c) the equipment item number and service name; d) the inquiry or purchaser’s order number; e) any other identification specified in the inquiry or purchaser order; f) the vendor’s identifying proposal number, shop The table is, in general structured by order of appearance and alphabetically. Items with an “X” in the first column “Proposal” are required at as a part of the proposal package. Items with an “X” in the column “Engineering Documentation” are not subject to purchaser review (unless required by other entries) and are to be stored by the vendor as a part of their engineering documentation requirement and shall be stored in accordance with industry practice. Items with an “X” in the column “MRB” shall supplied to the purchaser with the final delivery are subject to customer review. These shall be stored by both the purchaser and vendor for time periods relevant to the role. Items with an “X” in the column “User Manual” shall supplied to the purchaser with the final delivery are subject to customer review. These shall be stored by both the purchaser and vendor for time periods relevant to the role. The final four columns illustrate the need for agreed delivery milestones for the documents. Items under the row heading of “General” are initially supplied during the proposal phase and are updated as the project matures. These may be duplicated in other documents. Items under the row heading of “Verification” are initially supplied during the execution phase and are updated as the project matures. Portions or summaries of these may be duplicated in the MRB or User Manuals. 83 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 84 Items under the row heading of “Manufacturing Record Book” are initially supplied with the delivered product and are updated only if the item is modified prior to installation. Portions of these may be duplicated in other documents. Items under the row heading of “FAT Specific” are outputs of the testing of the manufactured product and may be included in both the MRB and User Manual. Items under the row heading of “User Manual” are to be delivered to the purchaser and describe installation, use, storage and operation of the pump and ancillary equipment. These are subject to purchaser approval and mar be subject to updates during the life of the installed item. Example: The first item “Barrier fluid/cooling system GA and component drawings” shall be described based on: – The vendor’s understanding of the system requirements as based on the tender request – Updated to match the final agreement by the time of the system engineering design review – Finalized by the end of the project and documented in both the MRB and user manual. 84 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 85 Table 12 - Vendor Drawing and Data Requirement List API 17X X X X X GEN.1 X X X X X X X GEN.2 GEN.3 GEN.4 X X X X GEN.5 X X X X X X X X X X X X X X X X X X X X X X X X X X X X X X X X X X X GEN.6 GEN.7 GEN.8 GEN.9 GEN.10 GEN.11 GEN.12 X X X X X X X X X X X X X X X X X X X X X X X X X X X X X O X X X X O X GEN.13 GEN.14 GEN.15 GEN.16 GEN.17 GEN.18 GEN.19 GEN.20 GEN.21 GEN.22 VER.1 VER.2 VER.3 VER.4 VER.5 VER.6 Proposal Acceptance VDDR Note Reference Number User Manual Manufacturing Record Book System Engineering Design Review/Freeze Engineering Documentation Proposal FOR SITE SERVICE OF DATE DATE BY General Barrier fluid/cooling system GA & component drawings Cause and effect report Control system and GUI description Data sheets Electrical and instrumentation arrangement drawing and list of connections Flushing system design Inspection Plan List of handling and maintenance tools List of special tools furnished Materials specifications and welding procedures MSDS information on all lubricants, preservatives, and chemicals MDR: List of documents, drawings and other submittals Nondestructive testing procedures Performance and current/speed/torque curves Performance and optional test procedures Plan, schedule, and progress reports Scope of supply drawing Shipping List Spare parts recommendations Tabulation of utility requirements Vibration Analyses and Data Weight report Verification Barrier fluid and cooling system dynamic studies Control system dynamic studies Damped unbalanced response analyses Electrical system response analyses Lateral critical speed analysis Thermal expansion 85 Final Supply DATA REQUIREMENTS ITEM DATE FAT/EFAT JOB PURCHASE ORDER REQUISITION INQUIRY PAGE REVISION UNIT NUMBER REQUIRED System Engineering Design Review/Freeze SUBSEA PUMPS VENDOR DRAWING & THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X API 17X VER.7 MRB.1 MRB.2 MRB.3 MRB.4 MRB.5 MRB.6 MRB.7 MRB.8 MRB.9 MRB.10 MRB.11 MRB.12 MRB.13 MRB.14 MRB.15 MRB.16 FAT.1 FAT.2 FAT.3 FAT.4 Proposal Acceptance VDDR Note Reference Number X User Manual System Engineering Design Review/Freeze X Manufacturing Record Book Engineering Documentation Proposal FOR SITE SERVICE OF DATE DATE BY Torsional critical speed analysis MRB As-built clearances Barrier Fluid / Sealing Fluid drawings, manufacturing data, and bills of materials Bearing Assembly drawings, manufacturing data, and bills of materials Certified dimensional outline drawing Certified hydrostatic test data Certified rotor balance data Cooler assembly drawing, manufacturing data, and bills of materials Coupling assembly drawing, manufacturing data, and bills of materials Electrical and instrumentation schematics, wiring diagrams, and bills of materials Lubricating oil schematic, manufacturing data, and bills of materials Material certificates Mechanical / Shaft seal drawing and bills of materials Primary and auxiliary flushing system schematics and bills of materials Rotor assembly drawing, manufacturing data, and bills of materials Shaft coupling assembly drawing, manufacturing data, and bills of materials Sub assembly dimensional verification FAT Specific Noise and vibration data Residual unbalance check Rotor mechanical & electrical runout for pumps with non-contacting vibration probes Noise and vibration data 86 Final Supply DATA REQUIREMENTS ITEM DATE FAT/EFAT JOB PURCHASE ORDER REQUISITION INQUIRY PAGE REVISION UNIT NUMBER REQUIRED System Engineering Design Review/Freeze SUBSEA PUMPS VENDOR DRAWING & 86 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X API 17X USE.1 USE.2 USE.3 USE.4 USE.5 USE.6 USE.7 USE.8 Proposal Acceptance VDDR Note Reference Number User Manual Manufacturing Record Book System Engineering Design Review/Freeze Engineering Documentation Proposal FOR SITE SERVICE OF DATE DATE BY Final Supply DATA REQUIREMENTS ITEM DATE FAT/EFAT JOB PURCHASE ORDER REQUISITION INQUIRY PAGE REVISION UNIT NUMBER REQUIRED System Engineering Design Review/Freeze SUBSEA PUMPS VENDOR DRAWING & 87 User Manual Allowable flange loadings (can be part of certified outline drawing) Cross-sectional drawings and bills of materials Installation, inspection and retrieval manual Lifting / running procedures, and relevant data List of handling and maintenance tools Operation and maintenance manual Preservation, packaging, and shipping procedures ROV Panel images and drawings 12.2 Details The entries above are described in more detail in Table 13, which provides guidelines as to the intended content of each entry. 87 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X Reference Data Requirement Vendor Drawing and Table 13 - Details and Comments to Table 12 Description General GEN.1 Barrier fluid/cooling system GA and component drawings Document shall describe - pumps - reservoirs and accumulators - valves - tubing - coolers GEN.2 Cause and effect report Document shall describe: - alarms - shutdown limits - operational setpoints - operational sequencing. GEN.3 Control system and GUI description Control system and GUI description - instrumentation, safety devices, control schemes - control, alarm and trip settings (pressure and recommended temperatures), - vibration alarm and shutdown limits, - bearing temperature alarm and shutdown limits, - lubricating oil temperature alarm and shutdown limits. GEN.4 Data sheets 88 88 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE Reference Data Requirement Vendor Drawing and COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X Description Data sheets applicable to proposals, purchase and as-built Including auxiliary systems, single line, and wiring diagrams GEN.5 Electrical and instrumentation arrangement drawing and list of connections GEN.6 Flushing system design GEN.7 Inspection Plan GEN.8 List of handling and maintenance tools GEN.9 List of special tools furnished GEN.10 Materials specifications and welding procedures GEN.11 MSDS information on all lubricants, preservatives, and chemicals GEN.12 MDR: List of documents drawings and submittals GEN.13 Nondestructive testing procedures GEN.14 Performance and current/speed/torque curves For proposal: preliminary or simulated data, - Average torque versus speed during starting at rated voltage and minimum starting conditions (voltage and short circuit MVA). - Current versus speed during starting at rated voltage and minimum starting conditions (voltage and short circuit MVA). - The expected moment of inertia of the rotor. - Estimated times for acceleration at rated voltage and minimum starting conditions (voltage and short circuit MVA) s. - The locked-rotor (stalled) withstand time with the motor at ambient temperature and at its maximum rated operating temperature for rated voltage and minimum starting conditions 89 89 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE Reference Data Requirement Vendor Drawing and COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 90 Description (voltage and short circuit MVA). - Expected and guaranteed efficiencies. For final supply, - Performance test data for both motor alone and pump/motor assembly including: - certified shop logs of the performance test, - record of shop test data For induction motors less than 150 kW (200 hp) , certified test reports for all test run and performance curves as follows: - speed-torque curves - efficiency and power factor curves at one-half, three-quarter, and full load. For induction motors larger than 150 kW (200 hp) and larger, certified test reports for all test run and performance curves as follows: - Time current heating curve - speed-torque curves at 70%, 80%, 90%, and 100% of rated voltage - efficiency and power factor curves from 0 to rated service factor - current vs load curves from 0 to rated service - current vs speed curves from 0 to 100% of rated speed For Pump/motor assembly, - total rotor moment of inertia, see also separate sections for application specific testing, qualification, or FAT/EFAT GEN.15 Performance and optional test procedures GEN.16 Plan, schedule, and progress reports Progress reports and delivery schedules, including vendor buy-outs and milestones. progress reports detailing the cause of any delays: the reports shall include engineering, purchasing, manufacturing and testing schedules for all major components. Planned and actual dates, and the percentage completed, shall be indicated for each milestone in the schedule. GEN.17 Scope of supply drawing The drawings shall clearly indicate the extent of the system to be supplied by the manufacturer and the extent to be supplied by others. 90 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE Reference Data Requirement Vendor Drawing and COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X GEN.18 Description Shipping List Shipping list, including all major components that will ship separately. GEN.19 Spare parts recommendations GEN.20 Tabulation of utility requirements Tabulation of utility requirements including power, coolant, lubricant, chemicals, and heat loads GEN.21 Vibration Analyses and Data For proposal stage: relevant vibration results from previous supply/qualification For final supply: data from FAT/EFAT/Application Specific Testing GEN.22 Weight report The document shall describe the total mass of each item of equipment (motor and auxiliary equipment) plus loading diagrams, heaviest mass, and name of part Verification VER.1 Barrier fluid and cooling system dynamic studies 91 91 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE Reference Data Requirement Vendor Drawing and COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 92 Description The document to cover agreed application specific scenarii: - steady-state - transient Each to include system-wide flow and pressure responses at each use point and agreed operational transients. These analyses shall also include steady-state and thermal transient details of the cooler design. VER.2 Control system dynamic studies The document to cover agreed application specific scenarii: - steady-state - transient Each to include system-wide flow and pressure responses at each use point and agreed operational transients VER.3 Damped unbalanced response analysis The analysis reports shall be supplied prior to systems engineering review, no later than 3 months after the date of order. VER.4 Electrical system response analyses The document to cover agreed application specific scenarii: - steady-state - transient Each to include system-wide responses at each use point and agreed operational transients VER.5 Lateral critical speed analysis 92 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE Reference Data Requirement Vendor Drawing and COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X Description The analysis reports shall be supplied prior to systems engineering review, no later than 3 months after the date of order. VER.6 Pressure casing, piping and thermal expansion evaluations The document to cover agreed application specific scenarii: - steady-state pressure containment - transient pressure responses - erosion evaluations - surge, slug, and water-hammer - piping vibration including hydraulic and chemical tubing VER.7 Torsional critical speed analysis The analysis reports shall be supplied prior to systems engineering review, no later than 3 months after the date of order. Manufacturing Record Book MRB.1 As-built clearances MRB.2 Barrier Fluid / Sealing Fluid drawings, manufacturing data, and bills of materials The document to include: - primary and auxiliary seal drawings and bills of materials - seal/barrier fluid, fluid flows, pressure, pipe and valve sizes, instrumentation, and orifice sizes. MRB.3 Bearing Assembly drawings, manufacturing data, and bills of materials 93 93 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE Reference Data Requirement Vendor Drawing and COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X MRB.4 94 Description Certified dimensional outline drawing Certified dimensional outline drawing - size, location, and purpose of all purchaser connections, including conduit, instrumentation, and any piping or ducting; - ASME rating and facing for any flanged connections; - size and location of anchor bolt holes and thicknesses of sections through which bolts must pass; - total mass of each item of equipment (motor and auxiliary equipment) plus loading diagrams, heaviest mass, and name of the part; - overall dimensions and all horizontal and vertical clearances necessary for dismantling, and the approximate location of lifting lugs; - shaft centreline height; - shaft end dimensions, plus tolerances for the coupling; - direction of rotation. MRB.5 Certified hydrostatic test data Including pressure plots from body tests MRB.6 Certified rotor balance data MRB.7 Cooler assembly drawing, manufacturing data, and bills of materials MRB.8 Coupling assembly drawing, manufacturing data, and bills of materials MRB.9 Electrical and instrumentation schematics, wiring diagrams, and bills of materials 94 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE Reference Data Requirement Vendor Drawing and COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X Description MRB.10 Lubricating oil schematic, manufacturing data, and bills of materials MRB.11 Material certificates MRB.12 Mechanical / Shaft seal drawing and bills of materials MRB.13 Primary and auxiliary flushing system schematics and bills of materials MRB.14 Rotor assembly drawing, manufacturing data, and bills of materials MRB.15 Shaft coupling assembly drawing, manufacturing data, and bills of materials MRB.16 General and sub -assembly dimensional verification General and Sub assembly dimensional verification of - Rotors/impellers, etc - Shafts - Gears - Seals and seal surfaces - Bearings and mating surfaces - Overall dimensions including interfaces FAT Specific FAT.1 Noise and vibration data FAT.2 Residual unbalance check FAT.3 Rotor mechanical & electrical runout for pumps with noncontacting vibration probes User Manual 95 95 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE Reference Data Requirement Vendor Drawing and COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 96 Description USE.1 Allowable flange loadings (can be part of certified outline drawing) USE.2 Cross-sectional drawings and bills of materials USE.3 Installation, inspection and retrieval manual USE.4 Lifting / running procedures, and relevant data Lifting and handling drawings and data including baskets and slings and including weights, dimensioned general assembly drawings, centres of gravity and details of lifting lugs USE.5 List of handling and maintenance tools USE.6 Operation and maintenance manual Operation and maintenance manual shall include - start-up, including tests and checks before start-up, - operating limits including number of successive attempts to start - planned and emergency shutdown - routine operations - barrier fluid / lubricant recommendations USE.7 Preservation, packaging, and shipping procedures USE.8 ROV Panel images and drawings 96 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 97 Annex A (Normative) Qualification Testing A.1 General Procedure for Qualification Testing The general process is as described by the flowchart below. The testing procedure starts with the development of a test objective from the pump specification; then continues with the development of an experimental design within the capabilities of the test facility and test object. Four different sets of tests are then executed within the chosen experimental design. Each of these tests generates data which are used to develop the outputs in the test report. A.2 General Procedure for the Start-up and Shut-down Tests The primary objectives of this test are to: – – – Identify any damaging oscillatory torque that occurs during start-up Confirm that motor is able to make necessary start-up torque for the pump, and Confirm the dynamic response of the barrier fluid system and mechanical seals to process fluid GVF fluctuations and temperature changes Additional start-up and shutdown tests shall be conducted to discover and verify resonant or high vibration conditions. (1) Test Points This is a dynamic test without a defined steady-state test point. In this transient test, the pump begins at rest, ramps up to the maximum operating speed, and ramps down to rest. (2) Barrier Fluid Temperature Ambient temperature for test environment as varies during the test. (3) Process Fluid Conditions Run the test under the following process fluid conditions: – – – – Minimum flow rate/minimum GVF Minimum flow rate/maximum GVF Maximum flow rate/minimum GVF, and Maximum flow rate/maximum GVF 97 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X (4) 98 Start-up and Shutdown Test Procedure The tests are detailed below but are generally set up to give combinations based on the following example: – Minimum flowrate at minimum GVF and minimum suction pressure - Start-up using minimum ramp-up speed at minimum GVF ESD Trip from minimum flowrate at minimum GVF Start-up using maximum ramp-up speed at minimum GVF Shut-down at minimum ramp-down speed at minimum GVF Start-up using minimum ramp-up speed at minimum GVF Shut-down at maximum ramp-down speed at minimum GVF – Minimum flowrate at minimum GVF and maximum suction pressure - Start-up using maximum ramp-up speed at minimum GVF Shut-down at minimum ramp-down speed at minimum GVF Start-up using minimum ramp-up speed at minimum GVF Shut-down at maximum ramp-down speed at minimum GVF Table 14 - Suggested Start-up and Shut-down Test Process for Qualification Testing Scenario Data Points Start-stop cycles Minimum Flowrate @ minimum GVF Minimum Flowrate @ maximum GVF Maximum Flowrate @ minimum GVF Maximum Flowrate @ maximum GVF Allowable start up ramp rate 20 total 5 Cycles 5 Cycles 5 Cycles 5 Cycles 10 at minimum ramp-up rate 10 at maximum ramp-up rate 4 ESD simulations 8 at maximum ramp-down rate 8 minimum ramp-down rate 10 each 10 each Shutdown rate Minimum suction pressure Maximum suction pressure 98 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X 99 The table below lists each parameter for each test. Table 15 - Suggested Start-up and Shut-down Test Order for Qualification Testing Cycle # GVF Flow Rate Starting Ramp Rate Shut Down Rate Suction Pressure 6 min max max ESD max 11 max min min ESD max 16 max max max ESD max 5 min min min max max 4 min min max min max 10 min max max max max 12 max min max min max 17 max max min min max 18 max max max max max 20 max max max max max 1 min min min ESD min 3 min min min max min 2 min min max min min 9 min max min min min 7 min max min min min 8 min max max max min 15 max min min max min 13 max min min max min 14 max min max min min 19 max max min min min Monitor all variables specified in section 3.1. This test will create variations in torque, speed, barrier fluid pressure, process fluid pressure, and vibration levels that must be analyzed for signs of system damage. Produce Bode plots for each cycle. A.3 Normal Performance Qualification (1) Qualification Objective The primary goals of this test are to determine the performance map and vibration behavior of a new design: – – – Determine the system performance at steady-state Confirm the predicted performance map at steady-state, and Confirm the operating region with respect to pre-defined vibration limits (Section 9.3) 99 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X (2) 100 Normal Performance Test Points Qualification tests are performed at multiple combinations of the key variables for pump performance: – – – – – Set speed Flowrate Suction pressure Differential pressure, and GVF In the case of application specific tests, the choice of data points near the Best Efficiency Point(s) (BEP) or design point(s), may be specified in the contract between vendor and purchaser. (3) Barrier Fluid Temperature Ambient temperature for test environment as varies during the test. (4) Process Fluid Conditions Set temperature and GVF at design point(s) according to range for qualification of system. (5) Normal Performance Qualification Test Procedure Operate the system at the specified set point(s) until the following conditions are met: – – – Inlet and discharge pressure variations achieve steady state and are less than +/- 5 bar or 5 % (whichever is smaller) Process and barrier fluid temperatures reach their steady state values and vary by no more than +/- 5% GVF within 5 % of desired value (if not in intermittent flow regime) Qualification Test Duration: No less than one hour of additional operation after thermal and pressure equilibria are established according to the criteria above. Monitor all variables specified in section 9.2.2. A.4 Liquid Slugging Tolerance (1) Objective The qualification test is aimed at the minimum scope pump system and is aimed at evaluating its tolerance to GVF variations. This test is aimed at verifying the slug tolerance of the pump sub-system. The dynamics of the responses will also qualify the dynamic response of the barrier fluid system to process pressure changes. The test qualifies the combination of the following: – The pump control system 100 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X – – – 101 The barrier fluid system The capacity of (any) pump sumps Any other directly associated equipment The test is therefore aimed at confirming that the test system responds adequately to liquid slugs and gas pockets. Because extensive field modelling and dynamic simulation results are required to predict a worst-case scenario for the size of GVF fluctuations and the duration of time in which these changes can occur this qualification test may be relatively generic. Because of the test infrastructure needs, distinctions between application specific and qualification testing will be defined by each application project and the chosen “system-of-systems” level slug mitigation technologies. (2) Slugging Tolerance Test Point This dynamic test does not have a fixed test point. The pump system shall begin operating near the BEP p and flowrate for a given GVF and remain within the operational envelope while responding to changing process conditions. (3) Barrier Fluid Temperature Ambient temperature for test environment as varies during the test. (4) Process Fluid Conditions Process fluid conditions vary, as specified by the agreed test conditions. GVF begins near the design point and vary to simulate liquid slugs and gas pockets according to worst-case scenario predictions or agreed criteria. (5) General Slugging Tolerance Test Procedure Operate the system near BEP at a GVF near the design point. Vary the process conditions and allow the pump system to respond to keep operation within the allowable envelope. Again, the parameters of this test are highly reservoir and field dependent and a choice of test procedure will require detailed evaluation of the target market for the pump. A.5 Extended Performance Qualification (1) Objective This test demonstrates design robustness and simulates an extended duration of operation by going through several cycles and operating near the edge of the envelope with barrier fluid at maximum temperature. 101 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X (2) 102 Extended Performance Test Points This set of test points must be repeated for the entire range of process variables claimed by the pump vendor. For example, if a pump can run with GVF from 40 % to 60 %, the test points shall be run at the upper and lower GVF values. Continuing with that example, the number of GVF values to be run between the upper and lower limits shall be agreed on by all parties prior to testing. Test point 1 Speed: midpoint (at the minimum flowrate)/Flowrate: minimum/p: midpoint. Test point 2 Speed: midpoint (at the maximum flowrate)/Flowrate: maximum/p: midpoint. Test point 3 Speed: maximum/Flowrate: maximum/p: maximum (at the given flowrate). Test point 4 Speed: minimum/Flowrate: minimum/p: minimum. Test point 5 Speed: minimum/Flowrate: maximum (at the minimum speed)/p: minimum. Test point 6 Speed: maximum/Flowrate: minimum/p: maximum (at the given flowrate). Test point 7 Speed: maximum (at the maximum power)/Flowrate: midpoint (furthest point from surge and stonewall)/ p: maximum (at the max power). Figure 10 indicates where each test point lands on the operational envelope. The seven test points shall be repeated over the entire range of GVF values for multi‑phase pumps. 102 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 Figure 10 - Location of Test Points on the Operational Envelope (3) Barrier Fluid Temperature For this test, the barrier fluid shall be at pit temperature as it varies during the test. (4) Process Fluid Conditions For this test, the process fluids shall be at maximum temperature and GVF. 103 103 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X (5) 104 Extended Performance Qualification Test Procedure Table 16 - Suggested Extended Performance Test Process for Qualification Testing Scenario 1. Hot/Cold Start: 2. 10 Cycles Set I 3. Test Point Extended Performance Set I 4. Hot/Cold Start Repetition 5. 10 Cycles Set II 6. Test Point Extended Performance Set II 7. 30 Cycles: 8. Test Point Extended Performance Set III Procedure Duration/Cumulative Run time Start up the pump at ambient temperature and the process fluid at maximum temperature. Start up and shutdown the pump ten times including a minimum of five emergency stops. Run each of the 7 chosen test points for equal amounts of time Run each test point for equal amounts of time for 10 hours qualification giving 100 hours cumulative test time ~15 hours per point 100 hours cumulative Start up the pump at ambient temperature and the process fluid at maximum temperature. Start up and shutdown the pump ten times including a minimum of five emergency stops. Run each of the 7 chosen test points for equal amounts of time ~15 hours per point 100 hours cumulative Start up and shutdown the pump 30 times including a minimum of five emergency stops. Run each of the 7 chosen test points for equal amounts of time ~30 hours per point 200 hours cumulative For items 3, 6, and 8, operate the system at the specified set points until the steady-state conditions are met as described in section A.1.3.5 above: No less than fifteen minutes of additional operation are required once the temperatures and pressures are constant. 104 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 105 Annex B (Normative) Application Specific Testing B.1 Start-Up and Shutdown Test (1) Start-up and Shutdown Test Objective The primary objectives of this test are to: – – – Identify any damaging oscillatory torque that occurs during start-up Confirm that motor is able to make necessary start-up torque for the pump, and Confirm the dynamic response of the barrier fluid system and mechanical seals to process fluid GVF fluctuations and temperature changes Additional start-up and shutdown tests shall be conducted to discover and verify resonant or high vibration conditions. (2) Start-up Shutdown Test Points This is a dynamic test without a defined steady-state test point. In this transient test, the pump begins at rest, ramps up to the maximum operating speed, and ramps down to rest. (3) Barrier Fluid Temperature Ambient temperature for test environment as varies during the test. (4) Process Fluid Conditions Run the test under the following process fluid conditions: – – – – Minimum flow rate/minimum GVF Minimum flow rate/maximum GVF Maximum flow rate/minimum GVF, and Maximum flow rate/maximum GVF 105 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X (5) 106 Start-up and Shutdown Test Procedure Table 17 - Suggested Start-up and Shut-down Test Process for Application Specific Testing Scenario Data Points Start-stop cycles Minimum Flowrate @ minimum GVF Minimum Flowrate @ maximum GVF Maximum Flowrate @ minimum GVF Maximum Flowrate @ maximum GVF Allowable start up ramp rate Shutdown rate Minimum suction pressure Maximum suction pressure 8 total 2 Cycles 2 Cycles 2 Cycles 2 Cycles 4 at minimum ramp-up rate 4 at maximum ramp-up rate 2 ESD simulations 3 at maximum ramp-down rate 3 minimum ramp-down rate 4 each 4 each The table below lists each parameter for each test. Table 18 - Suggested Start-up and Shut-down Test Order for Application Specific Testing Cycle # GVF Flow Rate Starting Ramp Rate Shut Down Rate Suction Pressure 1 2 3 4 5 6 7 8 min min min min max max max max min min max max min min max max min max min max min max min max ESD min max min ESD max min max min min min max max max min min Monitor all variables specified in section 9.2.2. This test will create variations in torque, speed, barrier fluid pressure, process fluid pressure, and vibration levels that must be analyzed for signs of system damage. Produce Bode plots for each cycle. B.2 Test of Normal Performance (1) Test Objective The primary goals of the application specific tests at normal operating conditions test are the confirmation that the desired performance is met by the design: – – – Confirm that the system meets the required performance objective Confirm the predicted performance map at steady-state, and Confirm that the desired performance is within pre-defined vibration limits (Section 9.3) 106 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X (2) 107 Normal Performance Test Points Application specific tests are performed at multiple combinations of the key variables for pump performance: – – – – – Set speed Flowrate Suction pressure Differential pressure, and GVF In the case of application specific tests, the choice of data points near the BEP or design point(s), may be specified in the contract between pump supplier and operator. (3) Normal Performance Test Procedure Operate the system at the specified set point(s) until the following conditions are met: – – – Inlet and discharge pressure variations achieve steady state and are less than +/- 5 bar or 5 % (whichever is smaller) Process and barrier fluid temperatures reach their steady state values and vary by no more than +/-5 %, and GVF within 5 % of desired value (if not in intermittent flow regime) Test Duration: No less than one hour of additional operation after thermal and pressure equilibria are established according to the criteria above. Monitor all variables specified in section 9.2.2. B.3 Liquid Slugging Mitigation (1) Test Objective Confirm that the system responds adequately to liquid slugs and gas pockets. Extensive field modelling and dynamic simulation results are required to predict a worst-case scenario for the size of GVF fluctuations and the duration of time in which these changes can occur. The qualification test is aimed at the minimum scope pump system and is aimed at evaluating its tolerance to GVF variations. The dynamics of the responses are also required to qualify the dynamic response of the barrier fluid system to process pressure changes. Because of the infrastructure needs, distinctions between application specific and qualification testing shall be determined by each project and the chosen “system-of-systems” level slug mitigation technologies. The test may include equipment that is designed to mitigate any effects of slugs or other flow variations. This can be simulated, if agreed between vendor and purchaser. This test does not include the qualification or application specific testing of process or flow conditioning equipment. 107 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X (2) 108 Slug Mitigation Test Point This dynamic test does not have a fixed test point. The pump system shall begin operating near the BEP p and flowrate for a given GVF and remain within the operational envelope while responding to changing process conditions. (3) Barrier Fluid Temperature Ambient temperature for test environment as varies during the test. (4) Process Fluid Conditions Process fluid conditions vary, as specified by the operator, for specific field conditions. GVF begins near the design point and vary to simulate liquid slugs and gas pockets according to worst-case scenario predictions or agreed criteria. (5) General Slug Mitigation Test Procedure Operate the system near BEP at a GVF near the design point. Vary the process conditions and allow the pump system to respond to keep operation within the allowable envelope. As with the qualification test, the parameters of this test are highly reservoir and field dependent. Distinctions between application specific testing and the acceptance of this qualification test will be determined by each project and the chosen system level slug mitigation technologies. B.4 Extended Performance (Optional) (1) Application Specific Test Objective This test demonstrates design robustness and simulates an extended duration of operation by going through several cycles and operating near the edge of the envelope with barrier fluid at test environment temperature. (2) Extended Performance Test Points This set of test points must be repeated for the entire range of GVF values claimed by the pump vendor. For example, if a pump can run with GVF from 40 % to 60 %, the test points must be run at the upper and lower GVF values. The number of GVF values to be run between the upper and lower limits must be agreed on by all parties prior to testing. Test point 1 Speed: midpoint (at the minimum flowrate)/Flowrate: minimum/p: midpoint. Test point 2 108 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 109 Speed: midpoint (at the maximum flowrate)/Flowrate: maximum/p: midpoint. Test point 3 Speed: maximum/Flowrate: maximum/p: maximum (at the given flowrate). Test point 4 Speed: minimum/Flowrate: minimum/p: minimum. Test point 5 Speed: minimum/Flowrate: maximum (at the minimum speed)/p: minimum. Test point 6 Speed: maximum/Flowrate: minimum/p: maximum (at the given flowrate). Test point 7 Speed: maximum (at the maximum power)/Flowrate: midpoint (furthest point from surge and stonewall)/ p: maximum (at the max power). Figure 9 indicates where each test point lands on the operational envelope. The seven test points shall be repeated over the entire range of GVF values for multi‑phase pumps. (3) Barrier Fluid Temperature For this test, the barrier fluid shall be at pit temperature as it varies during the test. (4) Process Fluid Conditions For this test, the process fluids shall be at maximum temperature and GVF. 109 THIS DOCUMENT IS NOT AN API STANDARD; IT IS UNDER CONSIDERATION WITHIN AN API TECHNICAL COMMITTEE BUT HAS NOT RECEIVED ALL APPROVALS REQUIRED TO BECOME AN API STANDARD. IT SHALL NOT BE REPRODUCED OR CIRCULATED OR QUOTED, IN WHOLE OR IN PART, OUTSIDE OF API COMMITTEE ACTIVITIES EXCEPT WITH THE APPROVAL OF THE CHAIRMAN OF THE COMMITTEE HAVING JURISDICTION AND STAFF OF THE API STANDARDS DEPT. COPYRIGHT API. ALL RIGHTS RESERVED API RECOMMENDED PRACTICE 17X (5) 110 Performance Application Specific Test Procedure Table 19 - Suggested Extended Performance Test Process for Application Specific Testing Scenario 1. Hot/Cold Start: 2. 10 Cycles Set I 3. Test Point Extended Performance Set I 4. Hot/Cold Start Repetition 5. 10 Cycles Set II 6. Test Point Extended Performance Set II 30 Cycles: 7. 8. Test Point Extended Performance Set III Procedure Start up the pump at ambient temperature and the process fluid at maximum temperature. Start up and shutdown the pump ten times including a minimum of five emergency stops. Run each of the 7 chosen test points for equal amounts of time Start up the pump at ambient temperature and the process fluid at maximum temperature. Start up and shutdown the pump ten times including a minimum of five emergency stops. Run each of the 7 chosen test points for equal amounts of time Start up and shutdown the pump 30 times including a minimum of five emergency stops. Run each of the 7 chosen test points for equal amounts of time Duration/Cumulative Run time Run each test point for equal amounts of time for ~7 hours testing giving 50 hours cumulative test time ~7 hours per point 50 hours cumulative ~7 hours per point 50 hours cumulative ~15 hours per point 100 hours cumulative For items 3, 6, and 8, operate the system at the specified set points until the steady-state conditions are met as described in section A.1.3.5 above: No less than fifteen minutes of additional operation are required once the temperatures and pressures are constant. 110 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 Annex C (Informative) Pump Design Data Sheets This annex contains typical datasheets for use by the purchaser in communication with the vendor. 111 111 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 Project: Date: Page: ___ of ___ General Design Requirements (SI Units) Description Input Value Application Description Application Site Geographic Location Application Service Application Type Pump Count Design Life Design Conditions Design Pressure, bar Design Temperature, oC Ambient Conditions Water Depth, m (Mean Sea Level reference) Water Temperature, oC Seawater Salinity, kg/kg Minimum Current, m/s System Documents P&ID Layout Cause and Effect HMI Requirements Material Standard Material Class (AA-HH) Forging Specification Level (FSL-2, -3 or -4) Product Specification Level (PSL -3, -3G or -4) Bolt Specification Level (BSL-2 or -3) Piping Geometry Inlet Diameter, mm Inlet Elevation, m Inlet Orientation Inlet Connector Discharge Diameter, mm Discharge Elevation, m Discharge Orientation Discharge Connector Coating Requirements Relevant Standard Weight/Size Limitations Weight, metric tonnes Envelope Dimensions, WxLxH (m) Testing Requirements Application/Contract Specific Performance Testing Factory Acceptance Testing Site Integration Testing 112 Reference Number 112 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 Date: Project: 113 Page: ___ of ___ Operating Data (SI Units) Description Minimum Flow Capacity Requirement Oil Rate (Standard Conditions), Sm3/d Oil Rate (Pump Inlet Conditions), m3/d Gas Rate (Standard Conditions), MSm3/d Gas Rate (Pump Inlet Conditions), m3/d Water Rate (Standard Conditions), Sm 3/d Water Rate (Pump Inlet Conditions), m3/d Production Profile (attach data) Operating Inlet Pressure, bara Operating Discharge Pressure, bara Operating Inlet Temperature, oC Phase Data at Pump Inlet Oil Density, kg/m3 Oil Viscosity, cP Oil Heat Capacity, kJ/(kg K) Gas Density, kg/m3 Gas Viscosity, cP Gas Heat Capacity, kJ/(kg K) Produced Water Density, kg/m3 Produced Water Viscosity, cP Produced Water Heat Capacity, kJ/(kg K) Produced Water Salinity Emulsion Viscosity Sand Data Sand Rate at Steady-State, kg/d Sand Size at Steady-State, m Sand Rate at Upset Conditions, kg/d Sand Size at Upset Conditions, m Period for Upset Condition, hours Hydrate Potential Attach Curve Wax Behavior Wax Appearance Temperature, oC Pour Point, oC Production Chemicals Hydrate Inhibitor(s), l/d Scale Inhibitor(s), l/d Scale Squeeze Philosophy (attach) Asphaltene Inhibitor(s), l/d Wax Inhibitor(s), l/d Others 113 Expected Maximum Flow Attachment 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 Date: Project: 114 Page: ___ of ___ Fluid Description (SI Units) Description Input Value Reference Number Stock Tank Oil Properties, (Single Stage Flash) Density, kg/m3 Viscosity, cP Gas Properties (Single Stage Flash) Molecular weight or specific gravity Viscosity, cP Saturation Point Pressure, bara Temperature, oC Phase Envelope (attach) Single Stage Flash Results Gas-Oil-Ratio/Condensate Gas Ratio, Sm3/Sm3 Trace Components Mercury Other Recombined Fluid, Gas, Oil Compositions Separator Reference Temperature, oC Separator Reference Pressure, bara Separator Gas-Oil Ratio, Sm3/Sm3 Component Gas Mol Percent Oil Mol Percent Recombined Mol Percent H2S N2 CO2 CH4 C2H6 C3H8 i-C4H10 n-C4H10 i-C5H10 n-C5H10 Hexanes Heptanes Octanes Nonanes Decanes Decanes + Undecanes Dodecanes Tridecanes Tetradecanes Pentadecanes Hexadecanes Heptadecanes Octadecanes Nonadecanes Eicosanes + Molecular wt 114 Specific Gravity 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 Date: Project: Page: ___ of ___ Formation Water Composition (SI Units) Total Dissolved Solids pH Ion Ion mol wt Charge Range H+ 1.00798 +1 Na+ 22.9898 +1 K+ 39.0983 +1 Mg 24.305 +1 to +2 Ca++ 39.0983 +1 to +2 Ba++ 137.327 +1 to +2 Mnn+ 54.9381 +1 to +7 ++ Si n+ 28.085 +4 to +4 Srn+ 87.62 +1 to +2 Crn+ 51.9961 +4 to +6 Fen+ 55.845 +4 to +6 Znn+ 65.38 +2 to +2 OH 17.007 -1 Cl- 35.453 -1 HCO3- 61.106 -1 SO42- 96.0618 -2 CO32- 76.0972 -2 - sum 115 mg/l 115 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 Date: Project: Page: ___ of ___ Motor Design Requirements (SI Units) Description Input Power System Distance to Host Facility Line Frequency at Source Short-Circuit Capacity at Source (MVA) Phase Current at Source (A) Line Voltage at Source (kV) Cooler Design Design Case Current Seawater Salinity Design Case Fouling Factor, m2∙K/kW Interface Requirements Power Connection Instrumentation Requirements Motor Temperature Motor Torque Motor Bearing Temperature Key Phasor Cooler Inlet Pressure Cooler Inlet Temperature Cooler Inlet Pressure Cooler Inlet Temperature Coolant Flowmeter Testing Requirements Full Speed/Full Load Full Speed/No Load Locked Rotor Hydro-Test with Internals Gas Test if Relevant 116 Appendix Number 116 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 Date: Project: Page: ___ of ___ Pump Instrumentation Requirements (SI Units) Description Input Value Communication System Distance to Host Facility Communication and Control Interface Communication Bandwidth Communication Standard SEM Interface Instrumentation Requirements Accelerometer Acoustic Sensors Leakage Detection Bearing Temperature Radial Proximity Probes Axial Proximity Probes Pump Inlet Pressure Pump Inlet Temperature Pump Discharge Pressure Pump Discharge Temperature Pump Inlet Bulk Rate Pump Inlet GVF 117 Reference Number 117 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 Date: Project: Page: ___ of ___ Pump and Motor Mechanical Design Outputs (SI Units) Description Output Value Pump Ratings Pump Type Rated Pressure, bara Maximum Differential Pressure, barg Rated Temperature, oC Rated Capacity at BEP, m3/d Rated Volumetric Efficiency at BEP, % Required Power at Rated Condition, MW Required Power at Pressure Limiting Rate, MW Maximum Allowable Speed, rpm Performance Curves Coupling Type Piping Geometry Materials Inlet Diameter, mm Inlet Interface/Connector (SI Units) Discharge Diameter, mm Discharge Interface/Connector System Dimensions Weight, metric tonnes Envelope Dimensions, WxLxH (m) Handling Tool Part Number or Padeye Rating Transport Skid Part Number 118 Reference Number 118 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 Date: Project: Page: ___ of ___ Pump Design Outputs (SI Units) Description Output Value Pump Casing Rated Pressure, bara Rated Temperature, oC Hydrostatic Test Pressure, barg Casing Materials Bolting Materials Coating Materials Motor Casing Rated Pressure, bara Rated Temperature, oC Hydrostatic Test Pressure, barg Casing Materials Bolting Materials Coating Materials Piping Coating Materials Inner Barrel/Liner Material Coating Description Hydrostatic Test Pressure, barg Casing Materials Bolting Materials Rotor/Impeller/Bearing/Gears/Shaft Rotor/Impeller Description Rotor/Impeller Material Rotor/Impeller Coating Rotor/Impeller Mounting Rotor/Impeller Diameter, mm Rotor/Impeller Length, mm Rotor/Impeller Clearance, mm Shaft Diameter at Rotor/Impeller, mm Shaft Diameter at Coupling/Drive-End, mm Shaft Diameter at non-Drive-End, mm Shaft Material Timing Gear Standard Timing Gear Pitch/Line Diameter, mm Timing Gear Material Radial Bearing Count Radial Bearing Type Thrust Bearing Type Thrust Bearing Material Mechanical Seals 119 Reference Number 119 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 Date: Project: Page: ___ of ___ Pump Instrumentation Outputs (SI Units) Description Output Value Reference Number Interface Communication Standard Electrical Connector Pump Instrumentation Accelerometer Acoustic Sensors Leakage Detection Bearing Temperature Radial Proximity Probes Axial Proximity Probes Pump Inlet Pressure Pump Inlet Temperature Pump Discharge Pressure Pump Discharge Temperature Pump Inlet Bulk Rate Pump Inlet GVF Barrier Fluid/Lubrication System Design Outputs (SI Units) Description Output Value Lubricant/Barrier Fluid Expected Normal Rate, l/d Maximum Allowed Rate, l/d Fluid Type Fluid Density, kg/m3 Fluid Viscosity, cP Fluid Classification/MSDS Barrier Fluid/Lubricant System Rated Pressure, bara Instrumentation Controls Interface Piping/Tubing Materials Piping/Tubing Interface Details Piping/Tubing Coating Requirements Piping/Tubing Coating Details 120 Reference Number 120 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 Date: Project: Page: ___ of ___ Motor Design Outputs (SI Units) Description Output Value Motor Type Rated Power, MW Rated Speed, rpm Rated Voltage, kV Voltage Range, kV Insulation Class Frequency Range, Hz Number of Poles Number of Phases Minimum Starting Voltage, V Full Load Current, A Locked Rotor Current, A Motor Efficiency, % Motor Cooler Coolant Circulation Rate, l/h Duty, MW Area, m2 Materials U-Value Used in Design, W/(m2∙K) Coating Requirements Coating Details Interface Power Connection Instrumentation Motor Temperature Motor Torque Motor Bearing Temperature Key Phasor Proximity Probes Cooler Inlet Pressure Cooler Inlet Temperature Cooler Inlet Pressure Cooler Inlet Temperature Coolant Flowmeter 121 Reference Number 121 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 Date: Project: Page: ___ of ___ General Design Requirements (USC Units) Description Input Value Application Description Application Site Geographic Location Application Service Application Type Pump Count Design Life Design Conditions Design Pressure, psia Design Temperature, oF Ambient Conditions Water Depth, m (Mean Sea Level reference) Water Temperature, oF Seawater Salinity, lbm/lbm Minimum Current, ft/s System Documents P&ID Layout Cause and Effect HMI Requirements Material Standard Material Class (AA-HH) Forging Specification Level (FSL-2, -3 or -4) Product Specification Level (PSL -3, -3G or -4) Bolt Specification Level (BSL-2 or -3) Piping Geometry Inlet Diameter, in Inlet Elevation, ft Inlet Orientation Inlet Connector Discharge Diameter, in Discharge Elevation, ft Discharge Orientation Discharge Connector Coating Requirements Relevant Standard Weight/Size Limitations Weight, tons Envelope Dimensions, WxLxH (ft) Testing Requirements Application/Contract Specific Performance Testing Factory Acceptance Testing Site Integration Testing 122 Reference Number 122 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 Date: Project: 123 Page: ___ of ___ Operating Data (USC Units) Description Minimum Flow Capacity Requirement Oil Rate (Standard Conditions), stb/d Oil Rate (Pump Inlet Conditions), bbl/d Gas Rate (Standard Conditions), mmscfd Gas Rate (Pump Inlet Conditions), ft3/d Water Rate (Standard Conditions), stb/d Water Rate (Pump Inlet Conditions), bbl/d Production Profile (attach data) Operating Inlet Pressure, psia Operating Discharge Pressure, psia Operating Inlet Temperature, oF Phase Data at Pump Inlet Oil Density, lbm/ft3 Oil Viscosity, cP Oil Heat Capacity, BTU/(lbm∙R) Gas Density, lbm/ft3 Gas Viscosity, cP Gas Heat Capacity, BTU/(lbm∙R) Produced Water Density, lbm/ft3 Produced Water Viscosity, cP Produced Water Heat Capacity, BTU/(lbm∙R) Produced Water Salinity Emulsion Viscosity Sand Data Sand Rate at Steady-State, lbm/d Sand Size at Steady-State, m Sand Rate at Upset Conditions, lbm/d Sand Size at Upset Conditions, m Period for Upset Condition, hours Hydrate Potential Attach Curve Wax Behavior Wax Appearance Temperature, oF Pour Point, oF Production Chemicals Hydrate Inhibitor(s), gpm Scale Inhibitor(s), gpm Scale Squeeze Philosophy (attach) Asphaltene Inhibitor(s), gpm Wax Inhibitor(s), gpm Others 123 Expected Maximum Flow Attachment 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 Date: Project: 124 Page: ___ of ___ Fluid Description (USC Units) Description Input Value Reference Number Stock Tank Oil Properties, (Single Stage Flash) Density, lbm/ft3 Viscosity, cP Gas Properties (Single Stage Flash) Molecular weight or specific gravity Viscosity, cP Saturation Point Pressure, psia Temperature, oF Phase Envelope (attach) Single Stage Flash Results Gas-Oil-Ratio/Condensate Gas Ratio, scf/STB or STB/mmscf Trace Components Mercury Other Recombined Fluid, Gas, Oil Compositions Separator Reference Temperature, oF Separator Reference Pressure, psia Separator Gas-Oil Ratio, scf/STB Component Gas Mol Percent Oil Mol Percent Recombined Mol Percent H2S N2 CO2 CH4 C2H6 C3H8 i-C4H10 n-C4H10 i-C5H10 n-C5H10 Hexanes Heptanes Octanes Nonanes Decanes Decanes + Undecanes Dodecanes Tridecanes Tetradecanes Pentadecanes Hexadecanes Heptadecanes Octadecanes Nonadecanes Eicosanes + Molecular wt 124 Specific Gravity 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 Date: Project: Page: ___ of ___ Formation Water Composition (USC Units) Total Dissolved Solids pH Ion Ion mol wt Charge Range + H 1.00798 +1 Na+ 22.9898 +1 K+ 39.0983 +1 Mg++ 24.305 +1 to +2 ++ Ca 39.0983 +1 to +2 Ba++ 137.327 +1 to +2 Mnn+ 54.9381 +1 to +7 Sin+ 28.085 +4 to +4 Sr 87.62 +1 to +2 Crn+ 51.9961 +4 to +6 Fen+ 55.845 +4 to +6 Znn+ 65.38 +2 to +2 OH- 17.007 -1 n+ Cl - 35.453 -1 HCO3- 61.106 -1 SO42- 96.0618 -2 CO32- 76.0972 -2 sum 125 mg/l 125 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 Date: Project: Page: ___ of ___ Motor Design Requirements (USC Units) Description Input Power System Distance to Host Facility Line Frequency at Source Short-Circuit Capacity at Source (MVA) Phase Current at Source (A) Line Voltage at Source (kV) Cooler Design Design Case Current Seawater Salinity Design Case Fouling Factor, hr∙ft2∙R/BTU Interface Requirements Power Connection Instrumentation Requirements Motor Temperature Motor Torque Motor Bearing Temperature Key Phasor Cooler Inlet Pressure Cooler Inlet Temperature Cooler Inlet Pressure Cooler Inlet Temperature Coolant Flowmeter Testing Requirements Full Speed/Full Load Full Speed/No Load Locked Rotor Hydro-Test with Internals Gas Test if Relevant 126 Appendix Number 126 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 Date: Project: Page: ___ of ___ Pump Instrumentation Requirements (USC Units) Description Input Value Communication System Distance to Host Facility Communication and Control Interface Communication Bandwidth Communication Standard SEM Interface Instrumentation Requirements Accelerometer Acoustic Sensors Leakage Detection Bearing Temperature Radial Proximity Probes Axial Proximity Probes Pump Inlet Pressure Pump Inlet Temperature Pump Discharge Pressure Pump Discharge Temperature Pump Inlet Bulk Rate Pump Inlet GVF 127 Reference Number 127 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 Date: Project: Page: ___ of ___ Pump and Motor Mechanical Design Outputs (USC Units) Description Output Value Pump Ratings Pump Type Rated Pressure, psia Maximum Differential Pressure, psig Rated Temperature, oF Rated Capacity at BEP, bbl/d Rated Volumetric Efficiency at BEP, % Required Power at Rated Condition, MW Required Power at Pressure Limiting Rate, MW Maximum Allowable Speed, rpm Performance Curves Coupling Type Piping Geometry Materials Inlet Diameter, in Inlet Interface/Connector Discharge Diameter, in Discharge Interface/Connector System Dimensions Weight, tons Envelope Dimensions, WxLxH (ft) Handling Tool Part Number or Padeye Rating Transport Skid Part Number 128 Reference Number 128 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 Date: Project: Page: ___ of ___ Pump Design Outputs (USC Units) Description Output Value Pump Casing Rated Pressure, psia Rated Temperature, oC Hydrostatic Test Pressure, psig Casing Materials Bolting Materials Coating Materials Motor Casing Rated Pressure, psia Rated Temperature, oF Hydrostatic Test Pressure, psig Casing Materials Bolting Materials Coating Materials Piping Coating Materials Inner Barrel/Liner Material Coating Description Hydrostatic Test Pressure, psig Casing Materials Bolting Materials Rotor/Impeller/Bearing/Gears/Shaft Rotor/Impeller Description Rotor/Impeller Material Rotor/Impeller Coating Rotor/Impeller Mounting Rotor/Impeller Diameter, in Rotor/Impeller Length, in Rotor/Impeller Clearance, in Shaft Diameter at Rotor/Impeller, in Shaft Diameter at Coupling/Drive-End, in Shaft Diameter at non-Drive-End, in Shaft Material Timing Gear Standard Timing Gear Pitch/Line Diameter, in Timing Gear Material Radial Bearing Count Radial Bearing Type Thrust Bearing Type Thrust Bearing Material Mechanical Seals 129 Reference Number 129 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 Date: Project: Page: ___ of ___ Pump Instrumentation Outputs (USC Units) Description Output Value Reference Number Interface Communication Standard Electrical Connector Pump Instrumentation Accelerometer Acoustic Sensors Leakage Detection Bearing Temperature Radial Proximity Probes Axial Proximity Probes Pump Inlet Pressure Pump Inlet Temperature Pump Discharge Pressure Pump Discharge Temperature Pump Inlet Bulk Rate Pump Inlet GVF Barrier Fluid/Lubrication System Design Outputs (USC Units) Description Output Value Lubricant/Barrier Fluid Expected Normal Rate, gpm Maximum Allowed Rate, gpm Fluid Type Fluid Density, lbm/ft3 Fluid Viscosity, cP Fluid Classification/MSDS Barrier Fluid/Lubricant System Rated Pressure, psia Instrumentation Controls Interface Piping/Tubing Materials Piping/Tubing Interface Details Piping/Tubing Coating Requirements Piping/Tubing Coating Details 130 Reference Number 130 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 Date: Project: Page: ___ of ___ Motor Design Outputs (USC Units) Description Output Value Motor Type Rated Power, MW Rated Speed, rpm Rated Voltage, kV Voltage Range, kV Insulation Class Frequency Range, Hz Number of Poles Number of Phases Minimum Starting Voltage, V Full Load Current, A Locked Rotor Current, A Motor Efficiency, % Motor Cooler Coolant Circulation Rate, gpm Duty, MW Area, ft2 Materials U-Value Used in Design, BTU/(hr∙ ft2 ∙R) Coating Requirements Coating Details Interface Power Connection Instrumentation Motor Temperature Motor Torque Motor Bearing Temperature Key Phasor Proximity Probes Cooler Inlet Pressure Cooler Inlet Temperature Cooler Inlet Pressure Cooler Inlet Temperature Coolant Flowmeter 131 Reference Number 131 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 Bibliography [1] Gűlich, Johann Friedrich, Centrifugal Pumps, Second Edition, Springer-Verlag,2010 132 132 1220 L Street, NW Washington, DC 20005-4070 USA 202.682.8000 Additional copies are available through HIS Phone Orders: Phone Orders: 1-800-854-7179 (Toll-free in the U.S. and Canada) 303-397-7956 (Local and International) Fax Order: 303-397-2740 Online Orders: Global.ihs.com Information about API Publications, Programs, and Services Is available on the web at www.api.org 1