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API COPM CPMA Chapter 20.X

David Courtney Pamela Chacon

Matt Zimmerman Dan Cutting

American Petroleum Institute (API)

Committee on Petroleum Measurement (COPM)

Sub-Committee on Production Measurement and Allocation

(CPMA)

Manual of Petroleum Measurement Standards (MPMS)

Chapter 20.X

• The CPMA committee was organized and started up during the 2007 API COPM Spring and Fall committee meetings.

• The committee was created to revise the 1993 version of MPMS Chapter 20.1 Allocation Measurement into 6 separate standards to better reflect the current onshore and offshore production allocation measurement needs.

• It was decided by the committee during the 2012 meeting that the content of the 6th standard (20.6) was now going to be included as part of the 1st standard (20.1).

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CPMA Introduction

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• Ch. 20.1 First edition September 1993. Allocation Measurement.

• Ch. 20.2 First edition November 2016. Production Allocation Measurement Using Single Phase Devices

• Ch. 20.3 First edition January 2013. Measurement of Multiphase Flow.

• Draft Standard First edition August 2016. Application of Hydrocarbon Phase Behavior Modeling in Upstream Measurement and Allocation Systems.

• Ch. 20.5 First edition recommended practice is expected in 2017. Recommended Practice for Application of Production Well Testing in Measurement and Allocation.

CPMA Introduction

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CPMA Ad-hoc Groups started at the 2016 fall meetings are:

1. Wet gas sampling. 2. Proving and meter verification for allocation

liquid meters. 3. Vented sources of gas.

MPMS Chapter 20.1Allocation Measurement

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• The responsibility of the MPMS Chapter 20.1 standard was formerly transferred from the Committee on Liquid Measurement (COLM) to the CPMA committee during the fall 2007 COPM meetings. The thought at the time was to develop the other “new” standards first and then revise the current 20.1 to fit in with the new standards.

• The first Standards Resource & Research Request (SR3) for 20.1 was formerly approved during the April 2010 net meeting.

• Another SR3 was approved with a scope and title change during the June 2012 net meeting.

• A third SR3 is planned to be presented for vote at the spring 2017 CPMA meeting to approve another scope change and a new title.


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The current scope of the 1993 20.1 standard is; This document provides design and operating guidelines for liquid and gas allocation measurement systems. Included are recommendations for metering, static measurement, sampling, proving, calibrating, and calculating procedures.

The scope approved in 2012 is; This document provides an overview of liquid and gas allocation including measurement system design and operating guidelines. Common production measurement configurations are described to provide a background of how production well fluids are produced, gathered and processed. The processes of reconciling or allocating the production system's outflow measurement (normally custody transfer quality measurement) to the production sources (wells) are addressed. It will not specifically address other related operations such as upstream area gathering systems, and certain pipeline operations where phase change is inherent to the operation.Guidance is provided concerning the application of the other Chapter 20 documents. Included are descriptions of metering, static measurement, sampling, proving, calibrating, and calculating procedures as they apply to allocation systems. Elements common to multiple Chapter 20 subjects are contained within this document including the definition of related terms and allocation concepts and the calculation of theoretical production quantities. Quality determination of produced fluids as it relates to the allocation process is described. The measurement of single-phase, stabilized products is covered in other API standards and is not reproduced herein.

The proposed scope for the new draft will be more concise with some of the above information moving to the introduction section.


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The proposed new table of contents is shown below.

1. Scope2. Normative references3. Terms and definitions4. Relevance and Applicability of Allocation5. Identify Allocation System Requirements6. Select Basis of Allocation7. Define Allocation Methodology8. Implement Allocation System9. Operate and Manage Allocation System


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A proposed flow chart will be a part of chapter 4 to help the readers understand how all the CPMA standards fit together.


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Value this standard will have for the industry;

• To give guidance on how to design, implement, and maintain an allocation system for wellhead gas, oil, and water production.

• To give guidance on how to incorporate the other API Chapter 20 standards, recommended practices, and draft standards into an allocation system.

MPMS Chapter 20.2 Production Allocation Measurement Using Single Phase Devices

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• Chapter 20.2 is a new standard. • The first SR3 was approved during the fall 2008 CPMA

meeting. • An updated SR3 was approved during the fall 2011 meetings. • The draft was balloted during the last half of 2015 and all

comments were resolved during the first half of 2016. • The first published edition is dated November 2016.• The new MPMS 20.2 standard supersedes certain sections of

the current MPMS 20.1 standard. (see 20.1 Addendum 2 issued November 2016)


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The scope for the Chapter 20.2 standard is;

This standard is applicable to single-phase measurement techniques upstream of the custody transfer points where custody transfer 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, 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 measurement results. This standard discusses the possible impacts on these devices during inefficient and/or ineffectiveseparation.


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The table of contents are listed below.

1. Scope2. Normative References3. Terms, Definitions, Acronyms, and

Abbreviations 4. Overview5. General Metering 6. Liquid Metering 7. Gas Metering


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Part of the introduction to the standard is as follows

This 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.

When 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 line. 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.


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The standard provides guidance with respect to the major factors that could contribute to measurement uncertainty for single-phase devices used in production allocation.

The standard discusses design considerations for production allocation measurement.

MPMS Chapter 20.3 Measurement of Multiphase Flow

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• The Chapter 20.3 is a new standard. • The first SR3 was approved during the spring 2008 CPMA committee

meeting. • The first and current edition was published in January 2013. It

supersedes certain sections of the current MPMS 20.1 standard, API Recommended Practice (RP) 86-2005 (which has been withdrawn), and certain sections of API RP 85-2003.

• A new SR3 was approved during the fall 2016 committee meeting to reopen the standard for a revision to include lessons learned and additional requirements the industry has identified as gaps in the first edition.


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The current scope of MPMS Chapter 20.3 is;

This standard addresses multiphase flow measurement in the production environment, upstream of the custody transfer (single-phase) measurement point, where allocation measurement for onshore, offshore, or subsea is applied. For other multiphase flow measurement applications, such as reservoir management, well tests, and flow assurance, the standard can be used as a reference or guide. However, the focus of this standard is on those applications where the accuracy of multiphase flow measurement for allocation systems is required.This document refers to existing standards and recommended practices to supplement the guidance it provides in this subject area. The document addresses principles used in multiphase flow measurement, multiphase metering types and classifications, assessment of expected performance, and selecting and operating multiphase measurement systems. Operational requirements or constraints are addressed, including expectations for flow meter acceptance, calibration criteria, flow loop and in situ verifications, and other guidance specific to different multiphase flow metering applications. The document does not address specific meter configurations.


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The table of contents for Chapter 20.3 is;

1. Scope2. Terms, Definitions, Abbreviations, and Symbols 3. Multiphase and Wet Gas Flow 4. Techniques of Multiphase Flow Metering Systems5. Multiphase Flow Metering Systems—Calibration, Correction, Performance

Testing, and Verification.6. Multiphase Measurement Uncertainty 7. Operation and Application of Multiphase Flow Metering Systems 8. Selection of Multiphase Flow Metering Systems9. Integration Testing, Installation, Commissioning, and Decommissioning10. Multiphase Flow Metering System Calibration, Performance Testing, and

Verification 11. Operation


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• This standard provides guidance on multiphase flow measurement taken upstream of the custody transfer point. The standard is intended for the application of production allocation measurement where required by commercial contracts. While this document is not aimed specifically for use in reservoir management or other operational needs, it can be used for this purpose.

• This standard addresses in depth the question of how the user measures (multiphase) flow rates of oil, gas, water, and any other fluids that are present in the production stream.

• In this standard, the measurement of multiphase flow addresses all possible flow conditions that can be encountered in the production of oil and gas—i.e. there are no conditions specifically excluded here that are found in typical hydrocarbon production.


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• The value for 20.3 is that it documents, for the first time, guidance and requirements for selection and operation of multiphase meters.

• A work group is currently being formed to revise the current standard so it will bring even more value to the industry.


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Work group directives for the 20.3 revision.

• Direction on device selection:-a) limitations and differences between technologies

b) technical methods of measurement (discuss variables

and how to determine them in more detail i.e. WLR, GVF, velocity, slip effects)

• Direction on verification including both In-

situ/diagnostic based and External methods (test

separator, production separator, virtual metering,

system balance)

• Common every day operational considerations


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Work group directives for the 20.3 revision

continued.

• Performance expectation:-a) Pros and cons of calibration loops using live fluids and higher

pressure (clearly define lab deliverables, what adjustments are

made to the meter and how do the adjustments correlate to the

field conditions) – direction for vendors to disclose, come up with generic form with list of factors.

b) revisit performance at low process pressure

c) water properties impact on performance

d) uncertainty of phase behavior/PVT should be considered

independent of instrument uncertainty (PVT can be done

internal or external to the meter flow computer.

• Address new technologies or alternatives to traditional multiphase meters since publication

MPMS Draft Standard Application of Hydrocarbon Phase Behavior Modeling in Upstream

Measurement and Allocation Systems

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• The API MPMS is a draft standard (a prospective standard for provisional application) and is why there is not a “chapter” (20.X) number assigned to the document. It will remain a draft standard for a 2-year review period. During that time the industry can submit comments on the standard that will be reviewed for incorporation into the standard when revised. Then the CPMA committee will vote to move it to a first edition standard and give it a chapter number.

• The first SR3 was approved during the spring 2008 CPMA committee meeting. • There were two more SR3 ‘s approved, one during the fall 2013 committee

meeting and the other during the spring of 2015. Both SR3 were for a scope changes and the second one was for a title change as well.

• The first edition draft standard was balloted and approved during the last half of 2015 and first half of 2016. It currently has a published date of August 2016.



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The current Scope is:

This document provides requirements and guidelines for the application of hydrocarbon phase behavior modelling in upstream measurement and allocation systems. The requirements and guidelines apply to the development, implementation and performance management of a process simulation model (PSM) incorporating an equation of state (EOS) description of phase behavior. This includes functional specifications, validation and maintenance of the PSM, EOS specification and implementation, and fluid compositional specification and validation.



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1. Scope2. Normative References 3. Terms, Definitions, Abbreviations, and Symbols 4. Relevance and Applicability of Hydrocarbon Phase Behavior

Modeling5. Development of a PSM Using an EOS Description of Phase

Behavior6. Implementation of a PSM Using an EOS Description of Phase

Behavior 7. Performance Management



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• This draft standard establishes a framework to develop, implement, and manage the application of hydrocarbon phase behavior modeling in upstream measurement and allocation systems.

• The applied phase behavior modeling addressed in this document refers to a process simulation model (PSM) incorporating an equation of state (EOS) description of the phase behavior, or pressure, volume, temperature (PVT) properties, of the fluids within the modeled process.

• The intent of this document is to provide operators with a consistent and transparent approach for applying and managing an EOS-based PSM within an upstream measurement and allocation system.

• It is not intended to prescribe a particular mathematical phase estimation (i.e. EOS), process simulation (i.e. PSM), or allocation method. Allocation methodologies are addressed in API MPMS Chapter 20.1.



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• Provides the industry with requirements and guidelines for an emerging technology;

• Provides the industry with the opportunity to use the document, and generate feedback prior to evaluating as a full standard;

MPMS Chapter 20.5 Application of Production Well Testing

in Measurement and Allocation

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• The first SR3 for Ch. 20.5 was approved during the fall 2009CPMA committee meeting.

• Another SR3 was approved for added funding during the spring 2015 meeting.

• A third SR3 was approved at the fall 2016 meeting to approve a title and scope change.

• The draft is currently being balloted within the CPMA committee with a March 2, 2017 closing date.

• The first published Ch. 20.5 should be during 2017.



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The approved new title is;Recommended Practice for Application of Production Well Testing in Measurement and Allocation.

The approved new scope is;This document provides recommendations and guidelines for the application of production well testing in production measurement and allocation. The recommendations and guidelines apply to conducting a production well test, calculating production well test volumes and rates, and the application of production well test data for use in measurement and allocation. This includes production well testing preparation, initiation, measurement, validation, and volume and rate calculations for separator, multiphase flow meter, and tank production well test systems. Additionally, this document addresses the proration of production well test results for use in allocation, the application of production well tests for validation and update of well flow models and virtual flow metering, and the adjustment of gas well continuous measurement results with production well test data. This document also provides recommendations and guidelines for the application of well flow modeling and virtual flow metering in production measurement and allocation.



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1. Scope2. Normative References 3. Terms, Definitions, Abbreviations and Symbols 4. Production Well Testing in Upstream Measurement

and Allocation 5. Conducting a Production Well Test6. Calculating Production Well Test Volumes and Rates 7. Applying Production Well Test Data for Use in

Allocation



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• The RP establishes a framework to conduct and apply production well testing for well rate determination in measurement and allocation.

• Production well testing addressed in the document refers to measurement of gas, oil, and water quantities from a single well during a specified length of time under controlled operational conditions.

• The intent of the document is to provide operators with a consistent and transparent approach for conducting, applying, and managing production well testing within an upstream measurement and allocation system.

• It is not intended to prescribe a particular production well test method, or particular application of production well test data use in allocation.

• Allocation methodologies are addressed in API MPMS Ch. 20.1.



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Value this recommended practice will have for the industry;

• The RP establishes a framework to conduct and apply production well testing for well rate determination in measurement and allocation.

• The intent of the document is to provide operators with a consistent and transparent approach for conducting, applying, and managing production well testing within an upstream measurement and allocation system.

Summary

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The API CPMA committee has developed standards and is getting close to developing and revising more standards related to the production/allocation measurement areas for the oil and gas industry. This area of the industry has

unique issues and problems that are being addressed with these new standards that should assist industry

companies and regulatory groups to better understand how to set up systems to perform production allocation

measurement.

api copm cpma chapter 20 - upm forum · pdf file02.03.2017 · mpms chapter 20.1...

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