API MPMS 20.2-2016 Manual of Petroleum Measurement Standards Chapter 20.2 Production Allocation Measurement Using Single-phase Devices (FIRST EDITION) .pdf

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1、Manual of Petroleum Measurement Standards Chapter 20.2Production Allocation Measurement Using Single-phase DevicesFIRST EDITION, NOVEMBER 2016Special Notes API publications necessarily address problems of a general nature. With respect to particular circumstances, local, state, and federal laws and

2、regulations should be reviewed. Neither API nor any of APIs 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

3、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 APIs employees, subcontractors, consultants, or other assignees represent that use of this publication would not infringe upon privately owned

4、rights. API publications may be used by anyone desiring to do so. Every effort has been made by the Institute to ensure 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 ex

5、pressly 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 opera

6、ting 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 practi

7、ces. 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 a

8、pplicable API standard. All rights reserved. No part of this work may be reproduced, translated, stored in a retrieval system, or transmitted by any means, electronic, mechanical, photocopying, recording, or otherwise, without prior written permission from the publisher. Contact the publisher, API P

9、ublishing Services, 1220 L Street, NW, Washington, DC 20005. Copyright 2016 American Petroleum Institute Foreword This edition of API Manual of Petroleum Measurement Standards (MPMS) Chapter 20.2 supersedes the below-listed sections of API MPMS Chapter 20.1, Allocation Measurement, First Edition, 19

10、93: Section 1.5 Liquid Quantity Measurement (subsections not superseded by MPMS Chapter 20.2include 1.5.2.4 Tanks and 1.5.2.5.2 Indirect Mass Measurement); Section 1.7.2.2.3 Flow Meters; Section 1.8 Liquid Proving and Calibration Techniques; Section 1.10 Gas Quantity Measurement; Section 1.11.4 Mete

11、r Calibration; Section 1.14 Gas Calibration and Proving Techniques.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

12、 contained in the publication be construed as insuring anyone against liability for infringement of letters patent. Shall: As used in a standard, “shall” denotes a minimum requirement in order to conform to the standard. Should: As used in a standard, “should” denotes a recommendation or that which

13、is advised but not required in order to conform to the standard. May: As used in a standard, “may” denotes a course of action permissible within the limits of a standard. Can: As used in a standard, “can” denotes a statement of possibility or capability. This document was produced under API standard

14、ization 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

15、 developed should be directed in writing to the Director of Standards, American Petroleum Institute, 1220 L Street, NW, Washington, DC 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 st

16、andards 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

17、 materials is published annually by API, 1220 L Street, NW, Washington, DC 20005. Suggested revisions are invited and should be submitted to the Standards Department, API, 1220 L Street, NW, Washington, DC 20005, standardsapi.org. iiiContents1 Scope . . . . . . . . . . . . . . . . . . . . . . . . .

18、. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12 Normative References . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13 Terms, Definitions, Acr

19、onyms, and Abbreviations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 23.1 Terms and Definitions. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 23.2 Acronyms and Abb

20、reviations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 44 Overview. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

21、. . . 44.1 Production Processes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 44.2 Single-phase Meters Used for Production Allocation Measurement . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 54.3

22、 Capability and Uncertainty . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 75 General Metering . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

23、. . . . . . . . . . . . 86 Liquid Metering . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 106.1 Common Liquid Meters . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

24、. . . . . . . . . . . . . . . . . . . . . . . . 106.2 Factors Affecting Liquid Allocation Meter Performance. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 106.3 Liquid Flow Meter Installation Considerations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

25、 . . . . . . . . . . . . . . . . 136.4 Liquid Flow Meter Assembly Considerations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 156.5 Proving of Hydrocarbon Liquid Allocation Meters . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

26、 . . . . . . . . . 167 Gas Metering . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 187.1 Common Gas Meters . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

27、. . . . . . . . . . . . . . . . . . . . . . . 187.2 Factors Affecting Gas Allocation Meter Performance. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 197.3 Gas Flow Meter Installation Considerations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

28、 . . . . . . . . . . . . . . . . 217.4 Gas Flow Meter Assembly Considerations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 217.5 Gas Meter Calibration and Verification Techniques . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

29、. . . . . . . . . . 23Annex A (informative) Measurement Process Flow Diagram . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 25Annex B (normative) Proving Procedures for Separator-based Liquid Metering . . . . . . . . . . . . . . . . . . . . . . . . 26Annex C (norma

30、tive) Calibration Procedures for Chart Recorders. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 30Annex D (informative) Uncertainty of Meter Proving Results. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 31Bibliography . . . . . . . . . . . .

31、 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 33FigureA.1 Example MPFD. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

32、 . . . . 25TablesB.1 Mean Average K-factor Example . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 26D.1 Equivalent Repeatability. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

33、 . . . . . . . . . . . . . . . 32vIntroductionThis standard covers the application of production allocation (determination of flow quantities and rates of oil, gas, water, and other constituents) using single-phase measurement devices in combination with a two- or three-phase production separator. W

34、hen fluid flow from different wells production streams are commingled into a single processing facility or flow line, it is preferred to measure the flow from each production stream separately, either continuously or on a specified interval, before it enters the common processing facility or flow li

35、ne. Periodic measurement at a specified interval is the common practice since continuous measurement of an individual well production stream is normally not an available option.On a production facility, it is common to have multiple production separators continuously measuring multiple combined prod

36、uction streams. Normally, these production separators (bulk separators) are dedicated to the same production streams.The measurement of these well production streams (both combined and individual) is used in the process of allocating the facility production quantities (gas, oil, and water) back to t

37、he producing wells.The traditional method of measuring multiphase flow has been to separate the flow into multiple single-phase streams (two- or three-phase separation). Single-phase flow meters are then applied to measure the flow of these separated streams. Factors that can impact measurement incl

38、ude, but are not limited to, the following: varying fluid properties, varying operating conditions, varying flow rates, well flow dynamics, varying flow line lengths, separator and process design, piping configuration.Measurement error, due to these characteristics, can result in inaccurate measurem

39、ent of production streams and can cause inequitable allocation of the commingled streams.This document provides guidance with respect to the major factors that could contribute to measurement uncertainty for single-phase devices used in production allocation. It is not intended to prescribe a partic

40、ular meter type or allocation method. Allocation methodologies are addressed in API MPMS Chapter 20.1.1 Production Allocation Measurement Using Single-phase Devices 1 Scope This standard is applicable to single-phase measurement techniques upstream of the custody transfer points where custody transf

41、er conditions are not possible. The standard presents single-phase flow measurement used in the allocation process and located downstream of the first stage of separation on a production facility. This standard addresses common allocation single-phase flow measurement devices for liquid hydrocarbons

42、, water, and gas including ancillary flow measurement systems such as fuel, flare, and recirculation. This standard discusses configuration and operation of flow measurement equipment, fluid properties, production processing, associated flow conditions, and their effects on the quality of the flow m

43、easurement results. This standard discusses the possible impacts on these devices during inefficient and/or ineffective separation. 2 Normative References The following documents are indispensable for the application of this document. For dated references, only the edition cited applies. For undated

44、 references, the latest edition of the referenced document (including any amendments) applies. API Manual of Petroleum Measurement Standards (MPMS) Chapter 4 (all sections), Proving Systems API MPMS Chapter 4.5, Master Meter Provers API MPMS Chapter 5.2-2005, Measurement of Liquid Hydrocarbons by Di

45、splacement Meters API MPMS Chapter 5.3-2005 (including Addendum 1-2009), Measurement of Liquid Hydrocarbons by Turbine Meters API MPMS Chapter 5.6-2002, Measurement of Liquid Hydrocarbons by Coriolis Meters API MPMS Chapter 7-2001 (including Addendum 1-2011), Temperature Determination API MPMS Chapt

46、er 11 (all parts), Physical Properties Data API MPMS Chapter 12.2 (all parts), Calculation of Petroleum Quantities Using Dynamic Measurement Methods and Volumetric Correction Factors API MPMS Chapter 12.2.3-1998, Calculation of Petroleum Quantities Using Dynamic Measurement Methods and Volumetric Co

47、rrections Factors, Part 3 Proving Reports API MPMS Chapter 13.2-1994, Methods of Evaluating Meter Proving Data API MPMS Chapter 14.2/AGA Report No. 8 1, Compressibility Factors of Natural Gas and Other RelatedHydrocarbon Gases API MPMS Chapter 14.3 (all parts), Concentric Square-edged Orifice Meters

48、 API MPMS Chapter 14.9, Measurement of Natural Gas by Coriolis Meter API MPMS Chapter 20.1, Allocation Measurement 1 American Gas Association, 400 N. Capitol St., NW, Suite 450, Washington, DC 20001, www.aga.org. 2 API MPMS CHAPTER 20.2 API MPMS Chapter 21.1/AGA Report No. 3, Flow Measurement Using

49、Electronic Metering SystemsElectronic Gas Measurement API MPMS Chapter 21.2, Electronic Liquid Volume Measurement Using Positive Displacement and Turbine Meters AGA Report No. 9, Measurement of Gas by Multipath Ultrasonic Meters ASME Performance Test Code 19.3-2010 2, Temperature Measurement3 Terms, Definitions, Acronyms, and Abbreviations 3.1 Terms and Definitions For the purposes of this document, the following definitions apply. 3.1.1 allocation measurement Measurement systems and procedures required to perform a fair and equitable allocation. Such systems and procedur

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