API MPMS 21 2 ADD-2000 Manual of Petroleum Measurement Standards Chapter 21-Flow Measurement Using Electronic Metering Systems - Section 2-Electronic Liquid Vol.pdf

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1、Manual of PetroleumMeasurement StandardsChapter 21Flow MeasurementUsing ElectronicMetering SystemsAddendum to Section 2Flow Measurement Using Electronic Metering Systems, Inferred MassFIRST EDITION, AUGUST 2000REAFFIRMED, AUGUST 2011Manual of PetroleumMeasurement StandardsChapter 21Flow MeasurementU

2、sing ElectronicMetering SystemsAddendum to Section 2Flow Measurement Using Electronic Metering Systems, Inferred MassMeasurement CoordinationFIRST EDITION, AUGUST 2000REAFFIRMED, AUGUST 2011SPECIAL NOTESAPI publications necessarily address problems of a general nature. With respect to partic-ular ci

3、rcumstances, local, state, and federal laws and regulations should be reviewed.API is not undertaking to meet the duties of employers, manufacturers, or suppliers towarn and properly train and equip their employees, and others exposed, concerning healthand safety risks and precautions, nor undertaki

4、ng their obligations under local, state, or fed-eral laws.Information concerning safety and health risks and proper precautions with respect to par-ticular materials and conditions should be obtained from the employer, the manufacturer orsupplier of that material, or the material safety data sheet.N

5、othing contained in any API publication is to be construed as granting any right, byimplication or otherwise, for the manufacture, sale, or use of any method, apparatus, or prod-uct covered by letters patent. Neither should anything contained in the publication be con-strued as insuring anyone again

6、st liability for infringement of letters patent.Generally, API standards are reviewed and revised, reaffirmed,or withdrawn at least everyfi e years. Sometimes a one-time extension of up to two years will be added to this reviewcycle. This publication will no longer be in effect fi e years after its

7、publication date as anoperative API standard or, where an extension has been granted, upon republication. Statusof the publication can be ascertained from API Measurement Coordination telephone (202)682-8000. A catalog of API publications and materials is published annually and updatedquarterly by A

8、PI, 1220 L Street, N.W., Washington, D.C. 20005.This document was produced under API standardization procedures that ensure appropri-ate notificationand participation in the developmental process and is designated as an APIstandard. Questions concerning the interpretation of the content of this stan

9、dard or com-ments and questions concerning the procedures under which this standard was developedshould be directed in writing to the Standardization Manager, American Petroleum Institute,1220 L Street, N.W., Washington, D.C. 20005. Requests for permission to reproduce ortranslate all or any part of

10、 the material published herein should also be addressed to the stan-dardization manager.API standards are published to facilitate the broad availability of proven, sound engineer-ing and operating practices. These standards are not intended to obviate the need for apply-ing sound engineering judgmen

11、t regarding when and where these standards should beutilized. The formulation and publication of API standards is not intended in any way toinhibit anyone from using any other practices.Any manufacturer marking equipment or materials in conformance with the markingrequirements of an API standard is

12、solely responsible for complying with all the applicablerequirements of that standard. API does not represent, warrant, or guarantee that such prod-ucts do in fact conform to the applicable API standard.All rights reserved. No part of this work may be reproduced, stored in a retrieval system, or tra

13、nsmitted by any means, electronic, mechanical, photocopying, recording, or otherwise, without prior written permission from the publisher. Contact the Publisher, API Publishing Services, 1220 L Street, N.W., Washington, D.C. 20005.Copyright 2000 American Petroleum InstituteFOREWORDAPI publications m

14、ay be used by anyone desiring to do so. Every effort has been made bythe Institute to assure the accuracy and reliability of the data contained in them; however, theInstitute makes no representation, warranty, or guarantee in connection with this publicationand hereby expressly disclaims any liabili

15、ty or responsibility for loss or damage resultingfrom its use or for the violation of any federal, state, or municipal regulation with which thispublication may conflictThis standard is under the jurisdiction of the API Committee on Petroleum Measurement,Subcommittee on Liquid Measurement. This stan

16、dard shall become effective January 1,2000, but may be used voluntarily from the date of distribution. Suggested revisions areinvited and should be submitted to Measurement Coordination, American Petroleum Insti-tute, 1220 L Street, N.W., Washington. D.C. 20005.iiiCONTENTSPage1 SCOPE. . . . . . . .

17、. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11.1 Application. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11.2 Electronic Liquid Measurement (ELM) . . . . . . . . . . . .

18、 . . . . . . . . . . . . . . . . . . . . 12 REFERENCED PUBLICATIONS. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13 DEFINITIONS AND SYMBOLS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.1 Introduction . . . . . . . . . . . .

19、. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.2 Words and TermsIn Addition to Those in Chapter 21.2. . . . . . . . . . . . . . . . . . 24 FIELD OF APPLICATION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 25 DESCR

20、IPTION OF AN ELECTRONIC LIQUID MEASUREMENT SYSTEM. . . . 25.1 Primary Devices. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 25.2 Secondary Devices. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2

21、6 SYSTEM UNCERTAINTY . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 27 GUIDELINES FOR DESIGN, SELECTION AND USE OF ELM SYSTEM COMPONENTS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 27.1 Pri

22、mary DevicesSelection and Installation. . . . . . . . . . . . . . . . . . . . . . . . . . . . 27.2 Secondary DevicesSelection and Installation. . . . . . . . . . . . . . . . . . . . . . . . . . 27.3 Electronic Liquid Measurement Algorithms for Inferred Mass. . . . . . . . . . . . . . 28 AUDITING AND

23、 REPORT REQUIREMENTS. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 78.1 General. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 78.2 Configuration Lo . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

24、. . . . . . . . . . . . . . 78.3 Quantity Transaction Record. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 78.4 Viewing Elm Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 78.5 Data Retention. . . . . . . . . .

25、 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 79 EQUIPMENT CALIBRATION AND VERIFICATION . . . . . . . . . . . . . . . . . . . . . . . 710 SECURITY . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

26、. . 7Figures1Typical ELM Inferred Mass System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 42Example of System Uncertainty Calculation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5v1Chapter 21Flow Measurement Using Electronic Metering SystemsADDENDUM

27、TO SECTION 2, FLOW MEASUREMENT USING ELECTRONIC METERING SYSTEMS, INFERRED MASS1 ScopeThis Addendum specifically covers inferred massmeasurement systems utilizing fl w computers as the tertiaryfl w calculation device and either turbine or displacement typemeters, working with on-line density meters,

28、 as the primarymeasurement devices. The Scope does not include systemsusing calculated fl wing densities, i.e., Equations of State. Thehardware is essentially identical to that referenced in APIMPMSChapter 21.2 and the methods and procedures are asdescribed in API MPMSChapters 14.4, 14.6, 14.7 and 1

29、4.8.Audit, record keeping, collection and calculation interval,security and most other requirements for systems covered inAPI MPMSChapter 21.2 will apply to this Addendum. As inChapter 21.2, the hydrocarbon liquid streams covered in thescope must be single phase liquids at measurement conditions. 1.

30、1 APPLICATIONThe procedures and techniques discussed in this documentare recommended for use with new measurement applica-tions. Liquid measurement using existing equipment andtechniques not in compliance with this standard may have ahigher uncertainty than liquid measurement based on the rec-ommend

31、ations contained in this document.1.2 ELECTRONIC LIQUID MEASUREMENT (ELM)The term “electronic liquid measurement,” or ELM, will befreely used throughout this document to denote liquid mea-surement using electronic metering systems. (Also see 3.20 inChapter 21.2.)2 Referenced PublicationsIf the wordi

32、ng of this document conflictswith a referencedstandard, the referenced standard will govern.API Manual of Petroleum Measurement StandardsChapter 1 “Vocabulary”Chapter 4 Section 2, “Conventional Pipe Provers”Chapter 4 Section 3, “Small Volume Provers”Chapter 4 Section 6, “Pulse Interpolation”Chapter

33、5 Section 2, “Measurement of Liquid Hydro-carbons by Displacement Meters”Chapter 5 Section 3, “Measurement of Liquid Hydro-carbons by Turbine Meters”Chapter 5 Section 4, “Accessory Equipment for Liq-uid Meters”Chapter 5 Section 5, “Fidelity and Security of FlowMeasurement Pulsed-Data TransmissionSys

34、tems”Chapter 7 Section 2, “Dynamic TemperatureDetermination”Chapter 9 “Density Determination”Chapter 11 “Physical Properties Data”Chapter 12 Section 2, “Calculation of PetroleumQuantities Using Dynamic MeasurementMethods and Volume Correction Factors”Chapter 13 “Statistical Aspects of Measuring andS

35、ampling” Chapter 14 Section 4, “Converting Mass of NaturalGas Liquids and Vapors to Equivalent Liq-uid Volumes”Chapter 14 Section 6, “Continuous DensityMeasurement”Chapter 14 Section 7, “Mass Measurement of NaturalGas “Liquids”Chapter 14 Section 8, “Liquefied Petroleum GasMeasurement”Chapter 21 Sect

36、ion 1, “Electronic Gas Measurement”Chapter 21 Section 2, “Electronic Liquid VolumeMeasurement Using Positive Displacementand Turbine Meters”RP 500Classification of Locations for ElectricalInstallations at Petroleum Facilities Clas-sifiedas Class 1, Division 1 and Division 2ASTM1D5002Test Methods for

37、 Density and RelativeDensity of Crude Oil by Digital DensityAnalyzer3 Definitions and Symbols3.1 INTRODUCTIONThe purpose of these definitionsis to clarify the terminol-ogy used in the discussion of this standard only. The definitions are not intended to be an all-inclusive directory of termsused wit

38、hin the measurement industry, nor are they intendedto conflict with a y standards currently in use.1American Society for Testing and Materials, 100 Barr HarborDrive, West Conshohocken, PA 19428-2959.2MANUALOFPETROLEUMMEASUREMENTSTANDARDS, CHAPTER21FLOWMEASUREMENTUSINGELECTRONICMETERINGSYSTEMS3.2 WOR

39、DS AND TERMSIN ADDITION TO THOSE IN CHAPTER 21.23.2.1 base conditions:Defined pressure and tempera-ture conditions used in the custody transfer measurement offluidvolume and other calculations. Base conditions may bedefinedby regulation or contract. In some cases, base condi-tions are equal to stand

40、ard conditions, which within the U.S.are 14.696 psia and 60 degrees Fahrenheit.3.2.2 base density: The density of the fluidat base con-ditions. Base density is derived by correcting fl wing densityfor the effect of temperature and compressibility, expressedby the symbol RHOb.3.2.3 fl wing density:Th

41、e density of the fluidat actualfl wing temperature and pressure. In inferred mass applica-tion, fl wing density is the indicated or observed density froman online density device, expressed by the symbol RHOobs.3.2.4 inferred mass measurement:Electronic mea-surement system using a turbine or displace

42、ment type meterand an online density meter to determine the fl wing mass ofa hydrocarbon fluid stream in accordance with the require-ments of API MPMSChapters 14.4, 14.6, 14.7 and 14.8.4 Field of ApplicationInferred mass measurement was excluded from the scopeof API Manual of Petroleum Measurement S

43、tandards,Chap-ter 21.2. This addendum to the basic API MPMS Chapter21.2 standard will specifically address inferred mass mea-surement using turbine and displacement type meters, asdescribed and allowed in API MPMS Chapters 14.4, 14.6,14.7 and 14.8. API 14.4 was derived from GPA 8173 andAPI 14.7 was

44、derived from GPA 8182. Direct mass measurement using gravimetric methods orCoriolis mass meters, inferred mass measurement using ori-fice meters, and other forms of mass measurement are notcovered in this addendum.Only exceptions to Chapter 21.2 are detailed in this adden-dum. If a section of Chapte

45、r 21.2 is not referenced in the fol-lowing section, that means it is to be used in the Addendumwithout modification5 Description of an Electronic Liquid Measurement System5.1 PRIMARY DEVICESAs inferred mass is the mathematical product of fl wand density, errors in either device, fl w meter or densit

46、ymeter, will produce a proportional error in the resultantmass. The devices are therefore considered primarydevices. In determining ELM system uncertainty, thisaddendum does not address the uncertainty of the primarydevices themselves. See Figure 1 for an example of a typ-ical ELM inferred mass syst

47、em and Figure 2 for an ELMSystem Uncertainty.5.2 SECONDARY DEVICESChapter 21.2, paragraph 5.1.2 listed density as a secondarymeasurement because it was used as an input to CTL andCPL calculations. In inferred mass, density measurementbecomes a primary measurement.6 System UncertaintyChapter 21.2, Se

48、ction 6 shall govern with the exceptionthat “inferred mass” is to replace “gross standard volume” inparagraph 6.1.1.7 Guidelines for Design, Selection and use of ELM System Components7.1 PRIMARY DEVICESSELECTION AND INSTALLATIONThe following applies to inferred mass in addition to thosefound in Chap

49、ter 21.2, Section 7.1.7.1.1The density meter in an ELM system produces anelectrical signal representing the fl wing density of the fluipassing through it. Methods for producing this electrical sig-nal depend on the density meter type. The signals may beanalog or digital pulse. 7.2 SECONDARY DEVICESSELECTION AND INSTALLATION7.2.1Chapter 21.2, paragraph 7.3.1 shall govern with theexception that “inferred mass” is to replace “volume.”7.3 ELECTRONIC LIQUID MEASUREMENT ALGORITHMS FOR INFERRED MASS This section defines algorithms for inferred mass liquidmeasurement and replaces Cha