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Manual of Petroleum Measurement Standards Chapter 4—Proving Systems Section 1—Introduction SECOND EDITION, MAY 1998

COPYRIGHT 2000 American Petroleum Institute


Manual of Petroleum Measurement Standards Standards Chapter 4—Proving Systems Section 1—Introduction Measurement Coordination SECOND EDITION, MAY 1998


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. API is not undertaking to meet the duties of employers, manufacturers, or suppliers to warn and properly train and equip their employees, and others exposed, concerning health and safety risks and precautions, nor undertaking their obligations under local, state, or federal laws. Information concerning safety and health risks and proper precautions with respect to particular materials and conditions should be obtained from the employer, the manufacturer or supplier of that material, or the material safety data sheet. 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. Generally, API standards are reviewed and revised, reaffirmed, or withdrawn at least every five years. Sometimes a one-time extension of up to two years will be added to this review cycle. This publication will no longer be in effect five years after its publication date as an operative API standard or, where an extension has been granted, upon republication. Status of the publication can be ascertained from the API Measurement Coordination Department [telephone (202) 682-8000]. A catalog of API publications and materials is published annually and updated quarterly by API, 1220 L Street, N.W., Washington, D.C. 20005. 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 standard or comments and questions concerning the procedures under which this standard was developed should be directed in writing to the director of the Measurement Coordination Department (shown on the title page of this document), 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. API standards are published to facilitate the broad availability of proven, sound engineering and operating practices. These standards are not intended to obviate the need for applying sound engineering judgment regarding when and where these standards should be utilized. The formulation and publication of API standards 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.

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FOREWORD Petroleum Measurement Measurement Standards Standards was prepared as a guide Chapter 4 of the Manual of Petroleum for the design, installation, calibration, and operation of meter proving systems commonly used by the majority of petroleum operators. The devices and practices covered in this chapter may not be applicable to all liquid hydrocarbons under all operating conditions. Other types of proving devices that are not covered in this chapter may be appropriate for use if agreed on by the parties involved. The information contained in this edition of Chapter 4 supersedes the information contained in the previous edition (First Edition, May 1978), which is no longer in print. It also Measuresupersedes the information on proving systems contained in API Standard 1101, Measurement of Petroleum Liquid Hydrocarbons by Positive Displacement Meter (First Edition, Mechanical Displacement Meter Provers Provers; API Standard 2533, 1960); API Standard 2531, Mechanical Metering Viscous Hydrocarbon Hydrocarbonss; and API Standard 2534, Measurement Measurement of of Liquid HydrocarHydrocarbons by Turbine-Meter Systems, which are no longer in print. This publication is primarily intended for use in the United States and is related to the standards, specifications, and procedures of the National Institute of Standards and Technology (NIST). When the information provided herein is used in other countries, the specifications and procedures of the appropriate national standards organizations may apply. Where appropriate, other test codes and procedures for checking pressure and electrical equipment may be used. For the purposes of business transactions, limits on error or measurement tolerance are usually set by law, regulation, or mutual agreement between contracting parties. This publication is not intended to set tolerances for such purposes; it is intended only to describe methods by which acceptable approaches to any desired accuracy can be achieved.

Chapter 4 now contains the following sections: Section 1—“Introduction” Section 2—“Conventional Pipe Provers” Section 3—“Small Volume Provers” Section 4—“Tank Provers” Section 5—“Master-Meter Provers” Section 6—“Pulse Interpolation” Section 7—“Field-Standard Test Measures” Section 8—“Operation of Proving Systems” 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 federal, state, or municipal regulation with which this publication may conflict. Suggested revisions are invited and should be submitted to the director of the Measurement Coordination Department, American Petroleum Institute, 1220 L Street, N.W., Washington, D.C. 20005.

iii



CONTENTS Page

SECTION 1—INTRODUCTION 1

SCOPE SCOPE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1

2

REFERENC REFERENCED ED PUBLI PUBLICATI CATIONS. ONS. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1

3

DEFINIT DEFINITION ION OF OF TERMS TERMS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1

4

LIQUID LIQUID METER METERING ING HIERARCH HIERARCHIES IES . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1 4.1 Overvi Overview ew of Hier Hierarc archy hy . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1 4.2 Uncert Uncertain ainty ty Limit Limitss With Within in the the Hierar Hierarchy chy . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2

5

PROVING PROVING AND AND METER METER FACTO FACTOR R . . . . . .. . . .. . . .. . . .. . . .. . . .. . . .. . . .. . . .. 3 5.1 Genera Generall Consid Considera eratio tions ns . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3 5.2 Object Objectiv ives. es. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3 5.3 Proced Procedure uress . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3 5.4 Provin Proving g Tech Techniq nique ue . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3 5.5 Accura Accuracy cy . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4 5.6 Multip Multiple le Mete Meters rs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4

6

TYPES TYPES OF PROVERS PROVERS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4 6.1 Conven Conventio tional nal Pipe Pipe Prover Provers. s. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4 6.2 Small Small Volume olume Prov Provers ers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4 6.3 Tank Prov Provers. ers. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4 6.4 Master Master-Me -Meter ter Prover Proverss . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4

7

FIELD-S FIELD-STAND TANDARD ARD TEST TEST MEASU MEASURE RE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4

Tables 1 Genera Generall Liqui Liquid d Meter Metering ing Hierar Hierarchy chy Level Levelss . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1 2 Uncert Uncertain ainty ty Indi Indices ces for Genera Generall Liqui Liquid d Meter Metering ing Hierarc Hierarchy. hy. . . . . . . . . . . . . . . . . . 2 3 Hypo Hypoth thet etic ical al Annua Annuall Unce Uncert rtai aint nty y Limi Limits ts in in Gener General al Liquid Metering Metering Hierarchy Hierarchy . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2

v



Chapter 4—Proving Systems Section 1—Introduction 1 Scope

3.7 3.7

Chapter 1 is a general introduction to the subject of proving. The requirements in Chapter 4 are based on customary practices that evolved for the crude oils covered by Table 6A and the products covered by Table 6B in Chapter 11.1. The prover and meter uncertainties should be appropriate for the measured fluids and should be agreeable to the parties involved.

3.8

3.9 3.9

4 Liqu Liquid id Met Meter erin ing g Hier Hierar arch chie ies s 4.1 4.1

Table 1—General 1—General Liquid Metering Hierarchy Hierarchy Levels Levels Levels 1 2 3 4 5 6 7

Terms used in this chapter are defined in 3.1 through 3.9.

3.1 calib libration ion: The procedure used to determine the volume of a prover.

Description of Hierarchy Level Primary Standards Secondary Working Standards Field Standard Test Me Measures Meter Prover Meter Assembly (indicated volume) Corrections fo for Qu Quality an and/or Qu Quantity Custody Tr Transfer Ti Ticket (n (net st standard volume)

Level Level 1. Primary Standards involve mass, volume, and/or density standards developed and/or maintained by National Institute of Standards and Technology (NIST) and/or other national laboratories to calibrate secondary working standards. Level 2. Secondary Working Standards include mass, volume, density, and/or weighing systems maintained by NIST and/or other national laboratories to calibrate field transfer standards conforming to Chapter 4.7. Secondary Working Standards may also be maintained by state and other certified metrology laboratories to calibrate field transfer standards. These additional secondary working standards, however, increase uncertainty in the final custody transfer quantities. Level 3. Field Transfer Standards conforming to Chapter 4.7 are devices used to calibrate meter provers conforming to Chapters 4.2, 4.3, and 4.4. Level 4. Meter provers conforming to Chapter 4 are used to determine meter factors that correct the indicated volumes of meters Levels 5,6, & 7. Compositional analyses, where appropriate, together with the meter factor, is used to make corrections in the quality and/or quantity of the indicated volume of the

meter pr proof oof: The multiple passes or round trips of the

displacer in a prover for purposes of determining a meter factor.

3.3 3.3

mete meterr pro prover: ver: An open or closed vessel of known volume that is used as a volumetric reference standard for the calibration of meters in liquid petroleum service. Such provers are designed, fabricated, and operated within the recommendations of Chapter 4. mete meterr puls pulse: e: A single electrical pulse generated by

flow induced effects in the meter. The flow induced effects are normally caused by movement of physical elements within the meter’s primary flow element but may be caused by other flow induced effects that are proportional to flow rate. The pulses produced by the meter shall not be multiplied to increase the number of pulses to conform to the requirements of Chapter 4.

proving: The procedure used to determine a meter

factor.

3.6 prover ver pa pass: One movement of the displacer between the detectors in a prover. 1


OVER OVERVI VIEW EW OF HIE HIERA RARC RCHY HY

Liquid metering systems for custody transfer and other mea Manual surement activities performed in conformance of API’s Manual of Petroleum Measurement Standards typically have at least the following levels in its hierarchy as shown in Table 1.

3 De Defi finitio ition n of Terms erms

3.5

stan standa dard rd cond condit itio ions ns:: 60°F(15°C) and atmospheric

pressure.

Several documents served as references and as a resource of information in the revision of this standard. Manual of Petroleum etroleum Measur Measurement ement Standar Standards ds Chapter 1—“Vocabulary” 1—“Vocabulary” Chapter 4—“Proving Systems” Chapter 5—“Metering” Chapter 7—“Temperature Determination” Chapter 11.1—“Physical Properties Data” Chapter 12—“Calculation of Petroleum Quantities” Chapter 13—“Statistical Aspects Aspects of Measuring and Sampling”

3.4 3.4

shall: Used throughout Chapter 4 for situations in

which a deviation from the recommended practice is likely to adversely affect measurement.

2 Re Refe fere renc nced ed Publ Public icat atio ions ns

3.2 3.2

prov prover er rou round nd tri trip: p: The forward and reverse passes in

a bi-directional prover. prover.

2

CHAPTER 4—PROVING SYSTEMS

meter, to determine the net standard volume being metered for custody transfer purposes. When practical, the number of levels in a hierarchy should be kept to a minimum to keep uncertainty low. Each level in the hierarchy will increase the uncertainty of subsequent levels and eventually the final custody transfer quantity.

4.2 UNCERT UNCERTAIN AINTY TY LIMI LIMITS TS WITHI WITHIN N THE THE HIERARCHY Each level within a hierarchy will include all the errors and uncertainties from the previous or higher levels of the hierarchy. Therefore, uncertainties will always increase throughout each level of the hierarchy. Exact, defined, and rigorous procedures must be developed and followed exactly through each level of a hierarchy so that the uncertainty in the final level of the hierarchy is not higher than specified and still tolerable for commercial purposes. For levels in the hierarchy that exhibit randomness because of the intrinsic random nature of the activity or equipment, error or uncertainty limits may be limited to twice or slightly less of the uncertainty in previous level in the hierarchy. archy. For levels that are performed infrequently in the hierarchy, such as primary standards, the next level in the hierarchy, such as secondary working standards, may have uncertainty limits that are up to four times the previous level level in the hierarchy. In the general hierarchy shown in Table 2, uncertainty indices are used to indicate the ratio of uncertainty of one level compared to the primary standard.

The effects of time should also be included in establishing limits within a hierarchy. Most custody transfer contracts or arrangements are in effect for years between two or more parties; therefore, the effects of random uncertainties to propagate to lower average values with time should be considered. Frequently, Frequently, repeated activities may have uncertainty limits that are closer to the adjacent level in the hierarchy if rigorous procedures are developed and implemented that minimize additional uncertainties. In the hierarchy of Table 2, the uncertainty index for meter indicated volume and corrections for quantity, quantity, such as the meter factors, can be lower than indicated in Table 2. An uncertainty index of 16 to 24 or lower can be obtainable over the period of a year or longer. A lower uncertainty index over time for the custody transfer ticket of 32 to 48 is also obtainable from rigorous and frequently performed activities. If the uncertainty limit for the average of a custody transfer over one year is prescribed as ± 0.10%, the corresponding uncertainty limits for each of the levels in the hierarchy would be found in Table 3. Within each of the hierarchy there are other activities that are sources of error that must be identified and limited so that they do not disrupt the integrity of the hierarchy. These activities include procedures for calibrating the secondary working standards, field transfer standards, and meter provers. Rigorous procedures must be developed and followed so that these additional sources of uncertainties do not disrupt the uncertainty control within the hierarchy.

Table 2—Uncertainty 2—Uncertainty Indices for General General Liquid Metering Hierarchy Hierarchy Uncertainty Indices Level 1 2 3 4 5 6 7

Description of Hierarchy Level Primary Standards Secondary Working Standards Field Transfer Standards Meter Prover Base Volume Meter Indicated Volume Correction for Quality and/or Quantity Custody Transfer Ticket

Per Event

Average with Time

1 2 to 4 4 to 16 8 to 32 16 to 64 32 to 128 64 to 256

1 2 to 4 4 to 8 8 to 16 16 to 64 24 to 32 32 to 48

Table 3—Hypothetical 3—Hypothetical Annual Uncertainty Uncertainty Limits in General Liquid Metering Hierarchy Hierarchy Uncertainty Limit, + or – % Level 1 2 3 4 5 6 7

Description of Hierarchy Level Primary Standards Secondary Working Standards Field Transfer Standards Meter Prover Base Volume Meter Indicated Volume Correction for Quality and/or Quantity Custody Transfer Ticket


Per Event

Per Year

0.002 0.005 0.015 0.03 0.10 0.15 0.20

0.002 0.005 0.015 0.03 0.05 0.07 0.10

SECTION 1—INTRODUCTION

5 Prov Provin ing g and and Me Mete terr Fac Facto torr The purpose of proving a meter is to determine its meter factor, which is the number obtained by dividing the actual volume of liquid passed through a meter during proving by the volume registered by the meter The purpose of a meter factor is to correct a meter’s indicated volume. Obtaining a meter factor is an essential step in calculating the net standard volume of a receipt or delivery of petroleum liquids. Because all calculations involve one or more corrections, and because the computation of numerous correction factors can lead to small differences if the computations are not carried out in a standard way, the calculations of petroleum quantities in dynamic measurement is covered in API MPMS Chapter 12.2. Refer to Chapter 12.2 whenever one or more of the following items must be calculated: a. Volumes in the provers. provers. b. Meter Meter factor factors. s. c. Measur Measureme ement nt ticket tickets. s.

5.1 GENERA GENERAL L CONSID CONSIDERA ERATIO TIONS NS A meter that requires flow conditioning should be proved with its normal flow-conditioning sections. All meters should be proved with the liquid to be measured and at the operating flowrate, pressure, and temperature. If the meter cannot be proved with the liquid to be measured, it should be proved with a liquid that has a density (API gravity) and viscosity as close as possible to that of the liquid to be measured and is known to give comparable results. A meter that is used to measure several different liquids should be proved with each liquid. Meter proving must be performed with a high degree of accuracy. The many details of the meter, its auxiliary equipment, and the proving system can contribute to measurement uncertainty. Likewise, there are difficulties in determining the physical properties of the measured liquid, pressure, temperature, and the presence of trapped air. Thorough inspections of provers and their appurtenances should be made frequently to ensure the reproducibility of proving results. Meter-proving data must be observed, recorded, and studied, and calculations must be correct. See API MPMS Chapters 12 and 13 for applicable methods.

5.2

OBJECTIVES

Meter proving has two general objectives depending on the type of service. A meter may be proved to adjust its registration, if necessary, to give a meter factor as close to 1.0000 (unity) as practical. The meter’s indicated volume will be the volume of liquid actually delivered (gross volume) within allowable tolerances. This is the normal practice for meters that operate on intermittent deliveries, such as tank-truck meters or loading-rack meters at terminals or bulk plants.


3

Alternatively, Alternatively, a meter may be proved to determine its meter factor (an expression of meter performance). The meter factor is applied to the indicated volume to compute the volume that is delivered through the meter. This is normal practice for pipeline and oil production operations.

5.3 PR PRO OCE CEDU DURE RES S Meter proving can be classified according to the following procedures: a. The standing standing start-and-s start-and-stop top procedure procedure uses the meter meter register, or counter, from which the opening and closing readings are obtained at no-flow conditions. If the flow is started too rapidly, pressure in the piping may momentarily fall below the vapor pressure of the liquid, causing some vapor to pass through the meter. The result may be damage to the meter and over-registration of indicated flow. Too rapid a change of liquid velocity may cause hydraulic shock. b. The running running start-and-sto start-and-stop p procedure procedure requires that that the opening and closing meter readings of the proof be obtained while the meter is in operation. This is accomplished by using an auxiliary or a secondary register or counter of high discrimination that may be started and stopped while the meter and primary register continue to operate. If the line meter proving registration is derived from something other than the meter register, steps shall be taken to ensure that all volumes indicated by the proving counter are also reflected in the meter register.

5.4 5.4

PRO PR OVING VING TECH TECHNI NIQU QUE E

Meter proofs should be made with the same read-out equipment that is used in regular operation or with additional auxiliary readouts, or counters, that meet the requirements in API MPMS Chapter 4.8. If it is used, auxiliary equipment such as gravity selectors, temperature compensators, pressure and temperature instrumentation, and quantity-predetermining registers or computers should be set and operative while meter proofs are being made. Time intervals between prover passes should be kept to a practical minimum.

5.4.1 5.4 .1 Prelim Prelimina inary ry Proof Proof Runs Runs Before a meter is proved, a preliminary unrecorded pass or passes should be made to stabilize temperatures, pressures, and flowrate; displace vapors or gases; and wet the interior of the prover. Temperature and pressure measuring instruments should be checked periodically against appropriate standards and calibrated, or replaced, as applicable.

5.4.2 5.4 .2 Prov Proving ing for for Meter Meter Adju Adjust stme ment nts s The meter registration may be adjusted after each proving to correct the indicated volume. Proving and required adjustments should be continued until consecutive results demon-

4

CHAPTER 4—PROVING SYSTEMS

strate that the meter register is indicating a delivered volume that is within the desired accuracy tolerance.

5.4.3 5.4. 3

Proving Proving to Determi Determine ne Meter Meter Factor Factor

When a meter is proved to determine the meter factor, no adjustments are made to the meter’s registration. Meter proofs are made and recorded until the required number repeats within a pre-established allowable variation. The average factor from these meter proofs is accepted as the meter factor. If mutually agreed on by the interested parties, the allowable repeatability deviation may be relaxed in special situations (e.g., when small throughput meters are used).

5.5

ACCURACY

The accuracy of any calculated meter factor or the average of two or more meter factors is limited by at least the following considerations: a. Prover Prover calibrat calibration ion uncertai uncertainty nty.. b. Meter proving proving procedur procedural al uncertaintie uncertainties. s. c. Equipm Equipment ent perfor performan mance. ce. d. Errors Errors that arise arise from from observati observation. on. e. Errors Errors that are implicit implicit in the computati computation on used to correct correct a measurement to standard conditions. Abbreviated tables, nonstandardized rounding of conversion factors, or intermediate calculations (see API MPMS Chapter 12.2 for standardized calculations) can adversely affect the consistency of calculations. The observed and computed data for all meter proofs that are made to obtain a meter factor or another expression of meter performance shall be reported on a suitable meter-proving report form; examples are provided in API MPMS Chapter 12.2.

5.6 5.6

MUL MU LTIPL TIPLE E METE METERS RS

Most of the procedures described apply to the proving of a single meter. If the meter to be proved is part of a battery of meters that handles a common stream, the stream must be diverted from the selected meter to be proved through the prover. The flow through the meter being proved must be maintained at its normal operating rate.

pass of the displacer. This results in a proving resolution of at least one part in ten thousand (0.0001). For more detailed information on conventional pipe provers see API MPMS Chapter 4, Section 2.

6.2 6.2

SMAL SMALL L VOL VOLUM UME E PRO PROVERS VERS

Small volume provers have a volume between detectors that does not permit a minimum accumulation of 10,000 direct (unaltered) pulses from the meter. Small volume provers require pulse interpolation to increase the resolution to a minimum of one part in ten thousand parts (0.0001). For more detailed information on small volume provers see API MPMS Chapter 4, Section 3, and Chapter 4, Section 6.

6.3 6.3

TAN ANK K PR PROVERS VERS

A tank prover is a volumetric vessel that has a reduced cross section or neck located at both the top and bottom or, in some cases, at the top only. These necks are equipped with gauge glasses and graduated scales. Tank provers may be open to the atmosphere, or they may be closed pressurized vessels. Proving by a tank prover employs the standing start-and-stop method (that is, the flow through the meter must come to a complete stop at the beginning and end of each proving run). For more detailed information on tank provers see API MPMS Chapter 4, Section 4.

6.4 6.4

MAST MA STER ER-M -MET ETER ER PRO PROVERS VERS

The master-meter is an indirect prover that uses the concept of transfer proving. A flow meter, with exceptional linearity and repeatability is selected to serve as a master-meter (Intermediate Standard) between a meter or prover operating in the field and a master-meter prover prover.. Two separate stages are required in master-meter proving: first, the master-meter must be proved using a meter prover (master prover) that has been calibrated by the water-draw method, with test measures traceable to NIST; and second, this proved master-meter is then used to determine the meter factor of the field operating meter or to calibrate other field provers. For more detailed information on master-meter provers see API MPMS Chapter 4, Section 5.

6 Types of Pr Prove verrs 6.1 CONVEN CONVENTIO TIONAL NAL PIPE PIPE PRO PROVER VERS S

7 Fiel Fieldd-St Stan anda darrd Tes Testt Me Meas asur ure e

A pipe prover includes a calibrated section in which the displacer travels with the flow, activating detection devices and finally stopping as the stream is diverted or bypassed. A conventional pipe prover is defined as a prover with a sufficient volume to accumulate a minimum of 10,000 whole unaltered meter pulses between detector switches for each

A field-standard test measure is a volumetric container that is calibrated by NIST or by any other NIST-certified laboratory that can provide traceability to NIST and is acceptable to all parties involved. The field standard test measure is the standard used to calibrate most proving systems and is described in detail in API MPMS Chapter 4.


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H30082

MPMS Ch. 4.2, Conventional Pipe Provers

$40.00

H30083

MPMS Ch. 4.3, Small Volume Provers

$40.00

H30084

MPMS Ch. 4.4, Tank Provers

$40.00

H30085

MPMS Ch. 4.5, Master-Meter Provers

$30.00

H30086

Interpolat ion MPMS Ch. 4.6, Pulse Interpolat

$30.00

H30087

MPMS Ch. 4.7, Field-Standard Test Measures

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H04081

MPMS Ch. 4.8, Operation of Proving Systems

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API MPMS 4.1.pdf

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