1、Manual of PetroleumMeasurement StandardsChapter 4Proving SystemsSection 1IntroductionTHIRD EDITION, FEBRUARY 2005REAFFIRMED, JUNE 2014Manual of PetroleumMeasurement StandardsChapter 4Proving SystemsSection 1IntroductionMeasurement CoordinationTHIRD EDITION, FEBRUARY 2005REAFFIRMED, JUNE 2014SPECIAL
2、NOTESAPI publications necessarily address problems of a general nature. With respect to partic-ular circumstances, 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
3、 their employees, and others exposed, concerning healthand safety risks and precautions, nor undertaking 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 obtaine
4、d from the employer, the manufacturer orsupplier of that material, or the material safety data sheet.Nothing 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 lette
5、rs patent. Neither should anything contained in the publication be con-strued as insuring anyone against liability for infringement of letters patent.Generally, API standards are reviewed and revised, reaffirmed, or withdrawn at least everyfive years. Sometimes a one-time extension of up to two year
6、s will be added to this reviewcycle. This publication will no longer be in effect five years after its publication date as anoperative API standard or, where an extension has been granted, upon republication. Statusof the publication can be ascertained from the API Measurement Coordination Departmen
7、ttelephone (202) 682-8000. A catalog of API publications and materials is published annu-ally and updated quarterly by API, 1220 L Street, N.W., Washington, D.C. 20005.This document was produced under API standardization procedures that ensure appropri-ate notification and participation in the devel
8、opmental process and is designated as an APIstandard. Questions concerning the interpretation of the content of this standard or com-ments and questions concerning the procedures under which this standard was developedshould be directed in writing to the standardization manager, American Petroleum I
9、nstitute,1220 L Street, N.W., Washington, D.C. 20005. Requests for permission to reproduce ortranslate all or any part of the material published herein should also be addressed to the gen-eral manager.API standards are published to facilitate the broad availability of proven, sound engineer-ing and
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13、1220 L Street, N.W., Washington, D.C. 20005.Copyright 2005 American Petroleum InstituteFOREWORDChapter 4 of the Manual of Petroleum Measurement Standards was prepared as a guidefor the design, installation, calibration, and operation of meter-proving systems commonlyused by the majority of petroleum
14、 operators. The devices and practices covered in this chap-ter may not be applicable to all liquid hydrocarbons under all operating conditions. Othertypes of proving devices that are not covered in this chapter may be appropriate for use ifagreed on by the parties involved.The information contained
15、in this edition of Chapter 4 supersedes the information containedin the previous edition (First Edition, May 1978), which is no longer in print. It also supersedesthe information on proving systems contained in API Std 1101 Measurement of Petroleum Liq-uid Hydrocarbons by Positive Displacement Meter
16、 (First Edition, 1960); API Std 2531Mechanical Displacement Meter Provers; API Std 2533 Metering Viscous Hydrocarbons; andAPI Std 2534 Measurement of Liquid Hydrocarbons by Turbine-Meter Systems, which are nolonger in print.This publication is primarily intended for use in the United States and is r
17、elated to thestandards, specifications, and procedures of the National Institute of Standards and Technol-ogy (NIST). When the information provided herein is used in other countries, the specifica-tions and procedures of the appropriate national standards organizations may apply. Whereappropriate, o
18、ther test codes and procedures for checking pressure and electrical equipmentmay be used.For the purposes of business transactions, limits on error or measurement tolerance areusually set by law, regulation, or mutual agreement between contracting parties. This publi-cation is not intended to set to
19、lerances for such purposes; it is intended only to describemethods by which acceptable approaches to any desired accuracy can be achieved.Chapter 4 now contains the following sections:Section 1“Introduction”Section 2“Displacement Provers”Section 4“Tank Provers”Section 5“Master-Meter Provers”Section
20、6“Pulse Interpolation”Section 7“Field-Standard Test Measures”Section 8“Operation of Proving Systems”Section 9“Calibration of Provers”API publications may 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 th
21、em; however, theInstitute makes no representation, warranty, or guarantee in connection with this publicationand hereby expressly disclaims any liability or responsibility for loss or damage resultingfrom its use or for the violation of any federal, state, or municipal regulation with which thispubl
22、ication may conflict.Suggested revisions are invited and should be submitted to the standardization manager,American Petroleum Institute, 1220 L Street, N.W., Washington, D.C. 20005.iiiCONTENTSPage1 SCOPE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
23、 . . . . . . . . . . . . . . . 12 REFERENCED PUBLICATIONS. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13 DEFINITION OF TERMS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 14 LIQUID METERING HIERARCHIES . . . . . . .
24、 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 14.1 Overview of Hierarchy . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 14.2 Uncertainty Limits within the Hierarchy. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 25 PROVING AND
25、 METER FACTOR . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 35.1 General Considerations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 35.2 Objectives. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
26、 . . . . . . . . . . . . . . . . . . 35.3 Procedures . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 35.4 Accuracy . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 36 TYPES OF
27、 PROVERS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 36.1 Displacement Provers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 36.2 Tank Provers. . . . . . . . . . . . . . . . . . . . . . . . . . . .
28、. . . . . . . . . . . . . . . . . . . . . . . . . . 46.3 Master Meter Provers. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 47 CALIBRATION OF PROVERS. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4Tables1 General L
29、iquid Metering Hierarchy Levels . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 22 Uncertainty Indices for General Liquid Metering Hierarchy . . . . . . . . . . . . . . . . 23 Hypothetical Uncertainty Limits in General Liquid Metering Hierarchy . . . . . . 2v1Manual of Petroleum Measuremen
30、t StandardsChapter 4Proving SystemsSECTION 1INTRODUCTION1 ScopeSection 1 is a general introduction to the subject of prov-ing. The requirements in Chapter 4 are based on customarypractices that evolved for crude oils and products covered byAPI MPMSCh. 11.1. The prover and meter uncertaintiesshould b
31、e appropriate for the measured fluids and should beagreeable to the parties involved.2 Referenced PublicationsSeveral documents served as references and as a resourceof information in the revision of this standard.Manual of Petroleum Measurement StandardsChapter 1“Vocabulary”Chapter 4“Proving System
32、s”Chapter 5“Metering”Chapter 7“Temperature Determination”Chapter 11.1“Physical Properties Data”Chapter 12“Calculation of Petroleum Quantities”Chapter 13“Statistical Aspects of Measuring and Sampling”3 Definition of TermsTerms used in this chapter are defined in 3.1 through 3.9.3.1 calibration:The pr
33、ocedure used to determine the vol-ume of a prover.3.2 meter proof:The multiple passes or round trips ofthe displacer in a prover for purposes of determining a meterfactor.3.3 meter prover:An open or closed vessel of knownvolume that is used as a volumetric reference standard for thecalibration of me
34、ters in liquid petroleum service. Such prov-ers are designed, fabricated, and operated within the recom-mendations of Chapter 4.3.4 meter pulse:A single electrical pulse generated byflow induced effects in the meter. The flow induced effects arenormally caused by movement of physical elements within
35、the meters primary flow element but may be caused by otherflow induced effects that are proportional to flow rate. Thepulses produced by the meter shall not be multiplied toincrease the number of pulses to conform to the requirementsof Chapter 4.3.5 prover pass:One movement of the displacer betweent
36、he detectors in a prover.3.6 prover round trip:The forward and reverse passes ina bi-directional prover.3.7 proving:The procedure used to determine a meterfactor.3.8 standard conditions:60F and atmospheric pres-sure.4 Liquid Metering Hierarchies4.1 OVERVIEW OF HIERARCHYLiquid metering systems design
37、ed and operated in con-formance with APIs Manual of Petroleum MeasurementStandards typically have one or more of the following levelsof hierarchy as shown in Table 1.Level 1.Primary standards involve mass, volume, and/or density stan-dards developed and/or maintained by National Institute ofStandard
38、s and Technology (NIST) and/or other national labo-ratories to calibrate secondary working standards.Level 2.Secondary working standards include mass, volume, den-sity, and/or weighing systems maintained by NIST and/orother national laboratories to calibrate field transfer standardsconforming to Cha
39、pter 4.7. Secondary working standardsmay also be maintained by state and other certified metrologylaboratories to calibrate field transfer standards. These additional secondary working standards, however,increase uncertainty in the final custody transfer quantities.Level 3.Field transfer standards c
40、onforming to Chapter 4.7 aredevices used to calibrate meter provers conforming to Chap-ters 4.2, 4.3, and 4.4.Level 4.Meter provers conforming to Chapter 4 are used to deter-mine meter factors that correct the indicated volumes ofmeters.2CHAPTER4PROVINGSYSTEMSLevels 5, 6, therefore, the effects of r
41、andom uncertainties to propa-gate to lower average values with time should be considered.Frequently, repeated activities may have uncertainty limitsthat are closer to the adjacent level in the hierarchy if rigorousprocedures are developed and implemented that minimizeadditional uncertainties. In the
42、 hierarchy of Table 2, theuncertainty index for meter indicated volume and correctionsfor quantity, such as the meter factors, can be lower than indi-cated in Table 2. An uncertainty index of 16 24 or lower formeter indicated volume is obtainable over the period of a yearor longer. A lower uncertain
43、ty index over time for the custodytransfer ticket of 32 48 is also obtainable from rigorous andfrequently performed activities.If the uncertainty limit for the average of custody transferover one year is prescribed as 0.10%, the possible hypothet-ical corresponding uncertainty limits for each of the
44、 levels inthe hierarchy are presented in Table 3. Within each of the hierarchy levels there are other activitiesthat are sources of error that must be identified and limited sothat they do not disrupt the integrity of the hierarchy. Theseactivities include procedures for calibrating the secondarywor
45、king standards, field transfer standards, and meter prov-ers. Rigorous procedures must be developed and followed sothat these additional sources of uncertainties do not disruptthe uncertainty control within the hierarchy.Table1General Liquid Metering Hierarchy LevelsLevels Description of Hierarchy L
46、evel1 Primary Standards2 Secondary Working Standards3 Field Standard Test Measures4 Meter Prover5 Meter Assembly (Indicated Volume)6 Corrections for Quality and/or Quantity7 Custody Transfer Ticket (Net Standard Volume)Table2Uncertainty Indices for General Liquid Metering HierarchyLevel Description
47、of Hierarchy LevelUncertainty IndicesPer EventAverage with Time1 Primary Standards 1 12 Secondary Working Standards 2 4 2 43 Field Transfer Standards 4 16 4 84 Meter Prover Base Volume 8 32 8 165 Meter Indicated Volume 16 64 16 246 Correction for Quality and/or Quantity32 128 24 327 Custody Transfer
48、 Ticket 64 256 32 48Table3Hypothetical Uncertainty Limits in General Liquid Metering HierarchyLevelDescription of Hierarchy LevelUncertainty Limit, + or %Per Event Per Year1 Primary Standards 0.002 0.0022 Secondary Working Standards 0.005 0.0053 Field Transfer Standards 0.015 0.0154 Meter Prover Bas
49、e Volume 0.03 0.035 Meter Indicated Volume 0.10 0.056 Correction for Quality and/or Quantity0.15 0.077 Custody Transfer Ticket 0.20 0.10SECTION1INTRODUCTION35Proving and Meter FactorThe purpose of proving a meter is to determine its meterfactor. The meter factoris obtained by dividing the provervolume by the indicated volume of the meter, both correctedto the standard conditions.The purpose of a meter factor is to correct a meters indi-cated volume. Obtaining a meter factor is an essential step incalculating the net standard volu
