ESTABLISHING A DEVELOPMENT PROGRAM FOR HYDROCARBON MEASUREMENT STAFF
Author(s): Richard L. Britton
Abstract/Introduction:
With the downsizing of many energy companies in the 1990s, the impending retirement of many of the energy industrys expertise, the rapid advancement of technologies, and increased world demand for energy, the development of technical talent within the energy industry has become paramount. Nowhere is the need to develop talent more apparent than in the area of hydrocarbon custody measurement. Given the quantities involved, inaccurate measurements of hydrocarbon transfers between suppliers and customers, and owners and transporters pose a relatively high financial risk to all affected parties. Addressing this need is substantially more complex than in many disciplines, as many of the skills required for success must be acquired in the work place rather than in a university or technical school. This paper discusses a process for creating a development program for hydrocarbon measurement staff, a possible program structure and its application. It provides examples of skills that may be required by measurement staff, competencies for a number of these skills and information on the types of activities which may be undertaken to acquire the required competencies.
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Document ID:
B1AE6BBD
Equipment and Techniques Used in Real Time Component Volume Calculations For Natural Gas Liquid Measurement
Author(s): David Beitel
Abstract/Introduction:
Correct measurement practices are established to minimize uncertainty in the determination of the custody transfer volume (or mass) of products. Understanding and evaluation of the fundamental cause and effect relationships with the liquid to be measured will lead to a volume determination that most closely matches the true volume at the referenced standard pressure and temperature. When designing a new measurement station it is up to us as measurement people, to understand the product to be measured, apply the correct equipment, and implement the appropriate correction equations. Crucial to the proper selection of measurement equipment and the proper calculation technique is an understanding of the product that is being measured.
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Document ID:
EDF1B752
INTRODUCTION TO UNCERTAINTY IN MEASUREMENT
Author(s): Casey Hodges
Abstract/Introduction:
This paper describes the concepts of both uncertainty and bias in measurement, discusses the need to eliminate
bias prior to performing an uncertainty calculation, outlines the difference between component uncertainty and
system uncertainty, and provides several sample calculations. This paper also introduces simple statistical methods
such as standard deviation and mean.
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Document ID:
B437A6EB
Crude Oil Gathering - Gauging Testing and Truck Measurement Alternatives
Author(s): John W Brackett
Abstract/Introduction:
Since ISHM was last held the world has seen tremendous change: we saw an entire planet stand still halting commerce and advancement in order to save lives. The great shuttering of the planet in 2020 and the pandemic that followed proved to us all that, like death and taxes, change is inevitable. While the pandemic is not the catalyst for change in methods for gathering crude by truck, it is the fuel for an already smoldering fire. The world of lease tank measurement must learn to adapt to the rapid changes brought on by the pandemic. The American Petroleum Institute has set forth the standards for the gauging of lease tanks in Chapter 18.1 and section 1A of Chapter 3 in the Manual of Petroleum Measurement Standards or MPMS. Additionally, many more standards may apply to lease sites depending on a sites specific variables and requirements. These Standards provide the complete methodology to the operation of lease tanks and the custody transfer process. Lists of applicable standards are found in the addendum of this document.
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Document ID:
15F57F7E
SMART TRANSMITTER SELECTION, CALIBRATION AND INSTALLATION
Author(s): Emily Saopraseuth
Abstract/Introduction:
Smart pressure and temperature transmitters emerged in the 1980s and have continued to evolve over the past 30 years. They evolved from simple analog process variable generators to increasingly sophisticated microprocessor-based Smart transmitters. Modern devices are full of new technology including: Improved performance and stability New transmitter capabilities Process, power and transmitter diagnostics This paper will provide a guideline for selecting, installing and maintaining modern pressure and temperature transmitters.
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Document ID:
3B2E0C3F
CONDITION-BASED MONITORING OF NATURAL GAS ULTRASONIC MEASUREMENT FACILITIES
Author(s): Ed Hanks
Abstract/Introduction:
During the past several years the use of ultrasonic meters (USMs) has gained worldwide acceptance for fiscal applications. The many benefits of USMs have been documented in papers at virtually every major conference. The significance of knowing the ultrasonic meter is operating accurately has never been more important. The use of diagnostics to help identify metering issues has been discussed in several papers at many conferences Ref 1, 2 & 3. USM technology has played a key role in reducing Lost and Un-accounted For (LAUF) numbers. However, like any technology, the client must understand the meters diagnostics in order to validate it is working correctly. Due to mergers, acquisitions, changes in technology, and purchasing preferences within an organization, it can be difficult for technicians to be skilled on all products. Also, changing technology adds to the difficulty as they often encounter multiple manufacturers equipment.
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Document ID:
E6ADF0EF
Crude Oil Quality-What Is It and Why Its Important
Author(s): Paul Furman, Rick Gebbia
Abstract/Introduction:
Crude oil quality is critical to the custody transfer process of delivering Crude oil to market. The actual process of determining the quality of crude oil is pretty well documented, but can have different meanings depending on the oils location in its life cycle of delivery. In this part of the delivery process, an entire market of 3rd party independent laboratories, Production Companies, Pipeline Companies and Refineries are responsible for the Quality determination at these points of Custody transfer in the delivery life cycle of crude oil. American Society for Testing and Materials (ASTM) and American Petroleum Institute (API) have multiple standards that guide each effected group on how to perform the requested tests in a uniform manner. The standards assure individuals in industry are consistently producing repeatable results within an accepted and documented set of rules that all parties must follow. Now, lets talk for a minute about what these test mean to you and each group that handles the crude oil in its delivery life cycle.
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Document ID:
E7D67B1D
THE ROLE OF THE BUREAU OF LAND MANAGEMENT IN OIL AND GAS MEASUREMENT
Author(s): Amanda Eagle
Abstract/Introduction:
The Bureau of Land Management (BLM)manages about 700 million acres of Federal and Indian mineral estate, which contribute a significant portion of domestic oil and gas production. BLMs role in oil and gas measurement is to ensure that volumes and qualities are accurately measured and properly reported, as Federal and Indian royalty is derived from these measurements. BLMs measurement requirements are dictated by Federal laws, from which BLM develops regulations, Onshore Orders, and Notices to Lessees. Most oil and gas measurement functions are carried out at the Field Office level through the approval of permits and variance requests. BLM inspects Federal and Indian measurement facilities to ensure compliance with regulations, Onshore Orders, and Notices to Lessees, as well as permit Conditions of Approval. BLM inspectors have various enforcement tools to ensure compliance. The public can comment on all proposed rulemaking, and parties adversely affected by specific decisions have several avenues of appeal.
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Document ID:
447DBAE8
ALLOCATION MEASUREMENT 101-FUNDAMENTALS OF ALLOCATIONS
Author(s): Jerry Haney
Abstract/Introduction:
Every upstream oil and gas company faces the same challenges of accurately reporting production from its wells. These challenges occur whether the company operates a single well or multiple wellsand whether the production from a well is kept isolated from the production from other wells or whether it is commingled, or mixed, with the production from other wells. Additionally, each producer is tasked with ensuring they accurately track and report what happens to the production from each well. These dispositions indicate what happened to the product after it was produced. They include, but are not limited to: gas that is sold, oil that is sold via truck or pipeline, gas used for fuel, gas that is flared, and water that is moved via truck or pipeline. (Additional dispositions can be found on regulatory agencies websites e.g. https://www.onrr.gov/ReportPay/pdfdocs/dispAdj.pdf.)
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Document ID:
B34D4DA3
CHROMATOGRAPH APPLICATIONS AND PROBLEMS FROM THE USERS STANDPOINT
Author(s): Steve Savell
Abstract/Introduction:
Process chromatograph applications consist of two systems that work collectively to provide critical analytical data to process operations, measurement analysts, and management to ensure accurate process control, accounting, and management direction. The sample conditioning system (SCS) and the gas chromatograph (GC) work together to extract a representative sample from the process, condition the sample to ensure it is clean and dry, and then inject it into the GC to determine the composition of the sample. It is imperative the samples integrity is maintained from the extraction point to injection in the GC to ensure accurate and reliable data. Problems can occur, mainly in the sample conditioning system, that will affect the GCs performance and will result in an inaccurate analysis.
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Document ID:
C418C9FD
UNCERTAINTIES WITHIN THE CENTRIFUGE METHODS AND MITIGATIONS
Author(s): Allen Wong
Abstract/Introduction:
The centrifuge method is widely used to determine the amount of water and/or sediment in crude oil as part of the
custody transfer process. The parties involved in a transaction would benefit to minimize the uncertainties
involved. Pipeline companies publish the quantity of water and sediment it will contractually accept. Maintaining a
balanced system is crucial to the business of a pipeline company.
This paper discusses what could be the contributing factors to uncertainties related to the centrifuge methods with
the assumption that a homogenous sample was obtained from the process line. Proper mixing, temperature
control, visual aids to enhance reading ability, training, equipment with consistent performance and capable to
provide the required relative centrifugal force are some of the contributing factors.
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Document ID:
3567869A
CAUSES AND CURES OF REGULATOR INSTABILITY
Author(s): Jeff Hoffman
Abstract/Introduction:
This paper will address the gas pressure reducing regulator installation and the issue of erratic control of the downstream pressure. A gas pressure reducing regulators job is to manipulate flow in order to control pressure. When the downstream pressure is not properly controlled, the term unstable control is applied. Figure 1 is a list of other terms used for various forms of downstream pressure instability. This paper will not address the mathematical methods of describing the automatic control system of the pressure reducing station, but will deal with more of the components and their effect on the system stability.
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Document ID:
CB1DEB3C
ON LINE WATER MEASUREMENT DEVICES IN LIQUID SERVICE
Author(s): Craig McWhorter
Abstract/Introduction:
In todays fast changing energy market there is a tremendous emphasis on cost saving and productivity at all levels of the industry. Online water detection - continuous measurement of free and entrained water quantities in petroleum and petroleum products - provides vital real-time information regarding water concentrations in hydrocarbons in a wide variety of applications, empowering the user with the knowledge necessary to maximize efficiencies and cost savings while increasing many safety factors at the same time. There are several important considerations regarding the usage of on-line water detectors or OWDs (also called water cut meters or BS&W monitors). There are multiple technologies and form factors offered for these units, each with differing pros and cons dependent upon user requirements, applications, process conditions, suitable installation, and budget.
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Document ID:
8F506D58
HELICAL TURBINE METERS FOR LIQUID MEASUREMENT
Author(s): Daniel Householder
Abstract/Introduction:
Turbine meters have been used for the custody transfer of refined petroleum products and light crude oils for over
50 years. When correctly applied, they offer high accuracy and long service life over a wide range of products
and operating conditions. Traditionally, turbine meters were used for the measurement of low viscosity liquids
and positive displacement meters for higher viscosity fluids. However, developments in turbine meter technology
are pushing these application limits while increasing reliability and accuracy. This paper will examine the
fundamental differences between conventional and helical turbine meter measurement. It will also discuss flow
conditioning, helical meter proving and viscosity compensation to extend turbine meter application limits.
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Document ID:
50B36BFE
COMMUNICATION SYSTEMS FOR GAS MEASUREMENT DATA
Author(s): Ryan Padilla
Abstract/Introduction:
In regard to Communication Systems for Gas Measurement, SCADA (Supervisory Control And Data Acquisition) is an effective tool that can be deployed in just about any environment that requires real-time monitoring, automated controls, and data collection. SCADA Systems have existed since the 1960s and are constantly evolving to meet a wide range of industries. While there are many different SCADA software packages, in its entirety, a SCADA system can be deduced to a few key components.
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Document ID:
19433031
MEASUREMENT POLICIES AND PROCEDURES - DEVELOPMENT AND IMPLEMENTATION CONSIDERATIONS
Author(s): Tom Cleveland
Abstract/Introduction:
The role of a typical energy organizations Measurement department is to create, collect and validate raw measurement data from a variety of sources and to turn it into useable, valuable measurement information. This measurement information is then provided to other internal and external organizations for various financial, operational, and strategic uses. In addition to the Measurement department, many individuals from other departments are key stakeholders in the process, including technicians that install, maintain, and verify the equipment in the field, as well as collect samples. Commercial representatives involved in negotiations of various agreements include measurement language that requires consideration. SCADA resources configure polling engines to collect the data and deliver it to the measurement system. The stakeholders involved in various stages of the cradle to grave path of raw measurement data to final useable measurement information may report up through different managers in the organization or may be an outside service provider. This is overlaid on the fact that the final measurement information must be auditable, meet contractual requirements, and be delivered timely. Also, the process must be repeatable, as the final invoicing is based on a monthly accounting cycle. Different departments within the organizations may be operating with differing priorities of time and use of limited resources.
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Document ID:
7457E59C
NEAR INFRARED ANALYSIS OF HYDROCARBON COMPOSITION AND PROPERTIES IN
NATURAL GAS APPLICATIONS
Author(s): Phil Harris
Abstract/Introduction:
The determination of hydrocarbon composition and physical properties is a critical step in allocation of assets,
process control, transportation and facility optimization. However, the instrumentation to perform such analysis is
often complex to install, maintain, and operate. Recent advances in Near Infrared (NIR) Spectroscopy has enabled
equipment which is ruggedized for field use, can operate at line conditions, and perform similar analysis as
conventional equipment with better reliability and speed.
An NIR analyzer has been developed to perform at-line measurements in applications ranging from upstream
production, to midstream processing, to downstream refining. The analyzer has been used to measure crude
properties in real time, optimize fractionation facilities and monitor composition and product quality in pipelines
and for resource allocation. The operating characteristics of the analyzer are discussed and application results are
presented.
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Document ID:
60833BB9
FUNDAMENTALS OF GAS MEASUREMENT I
Author(s): Dean Graves
Abstract/Introduction:
After 40+ years in the gas measurement industry, I look back and recognize that I missed and/or did not correct
measurement problems because I did not understand some fundamentals about gas and gas measurement in my
early years. This lack of understanding cost my company many dollars. This paper is written to possibly help new
people in the industry become familiar with some of these fundamentals early in their career and not repeat the
mistakes I made.
Though this paper will explore some subjects some find boring, hopefully, it is written in a way that any newer
person in the industry can relate to and use in their business.
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Document ID:
9F83AA48
INSTALLATION AND OPERATION ERRORS IN GAS MEASUREMENT
Author(s): Edgar B. Bowles, Jr., Dr. Thomas B. Morrow
Abstract/Introduction:
Installation errors may occur when an instrument is used in a manner different from how it was calibrated. For
example, suppose that a temperature sensor is calibrated in a stirred, constant temperature bath. During
calibration, the sensor is in thermal equilibrium with the circulating fluid, and the fluid and sensor temperatures are
the same. Next, let the same sensor be used to measure the temperature of natural gas flowing through a pipe at
low velocity. If the pipe wall temperature is different from the flowing gas temperature, convection heat transfer
will occur between the gas and the pipe wall, radiation heat transfer will occur between the pipe wall and the
sensor, and convection heat transfer will occur between the sensor and the flowing gas. In this example, the
sensor would not be in thermal equilibrium with the flowing gas and the sensor temperature would be different
from the flowing gas temperature.
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Document ID:
EE6DB634
INTRODUCTION TO GAS QUALITY USING SPECTROSCOPY
Author(s): Allan Rilling,
Abstract/Introduction:
Controlling or maintaining natural gas qualities to respect regulatory or operational limits requires a means to have
information. In turn, to have information on any gas quality or property requires measurement. The measurement
may come in various forms while focused on the key properties or qualities of interest. Spectroscopy is used as
an analytical tool for measurement of a wide variety of properties important to natural gas quality. Optical
spectroscopic analyzers allow for relatively simple based analyzers to be applied that provide reliable and
repeatable measurement as the measurement itself is dependent to the molecular interaction with light and the
measured signal or influence is highly specific based on the molecular makeup of natural gas sample.
This paper outlines some of the spectroscopic tools applied for measurement of natural gas quality. Some
specific optical spectroscopic analyzers are presented as practical examples for measurement of natural gas
quality.
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Document ID:
6E210DB5
MASS METERS FOR LIQUID MEASUREMENT
Author(s): Michael Keilty
Abstract/Introduction:
A mass flowmeter is a system that provides a measurement of fluid flow in units of mass pounds, tons. Mass flowmeters could either measure the mass flow directly or derive the mass flow from a volumetric flow measure using the known density of the liquid. The Coriolis flowmeter is a type of flowmeter which measures the mass of the liquid flow directly. Coriolis mass flowmeters were first introduced more than 30 years ago. Global acceptance has spread across all industries where precision flow measurement is needed. Today, installations number in the hundreds of thousands of measurement points including those in liquid hydrocarbon and natural gas applications. This paper will review the Coriolis mass flowmeter technology describing the differences and similarities between Coriolis flowmeters and electronic and mechanical meters and looking at some latest developments in Coriolis mass meter design and operation.
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Document ID:
BB51FB5E
Orifice Meter Diagnostic Systems Use of Differential Pressure Diagnostics to Identify Various Issues
Author(s): Richard Steven
Abstract/Introduction:
Orifice plate meters are popular for being relatively simple, reliable and inexpensive. Their principles of operation are relatively easy to understand. Although seen as a traditional mature metering technology, as with all flow metering technologies, the orifice meter is continually being developed. Significant developments in the last decade include significant improvements of DP transmitter capabilities, wet gas flow algorithm published by ISO, and a comprehensive validation system. This orifice meter validation system operates through a comprehensive diagnostic tool. This paper discusses this orifice meter validation system (Prognosis) developed by DP Diagnostics and now available on multiple platforms by different suppliers.
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Document ID:
DDB44F63
ORIFICE METERS FOR LIQUID MEASUREMENT
Author(s): Hunter Ward
Abstract/Introduction:
Orifice meters have been in use for decades, and in the energy industry, it is one of the most widely used meter
technologies. Orifice has primarily been used for gas measurement. Some of the reasons for this could be that most
of the past research was conducted by the American Gas Association (AGA), liquid measurement has had a wider
variety of devices that could be used, etc. It is important to know that much of the research conducted to develop
orifice meter factors, such as discharge coefficients, was performed using oil, water, steam, air, and natural gas.
The theory and technical basis of orifice measurement applies to any fluid, be it gas or liquid. Orifice meters used
in liquid measurement systems provide adequate accuracy. This accuracy can be achieved without the requirement
of meter proving, so long as the system is properly designed, installed, and maintained. Although it is not required,
orifice meters can be field proven using traditional proving methods.
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Document ID:
E28BBFC4
REAL TIME ELECTRONIC GAS MEASUREMENT
Author(s): Martin Johnson
Abstract/Introduction:
Electronic flow measurement as applied to the natural gas industry has advanced considerably over the last 30 years.
Applications to address Upstream, Midstream and Downstream gas measurement technologies have become more complex.
Over time it has become necessary to understand the fundaments that make up this ever-changing environment.
This paper will discuss the important fundamental parameters to consider when designing a real time Electronic Flow
Measurement (EFM) system. Please be aware of the many variances to each specific design and understand this is only a
fundamental paper to give new gas industry members an initial look at the technologies that are required when considering
Electronic Gas Measurement.
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Document ID:
C1BB680B
STATISTICAL CONTROL OF METER FACTORS - A SIMPLIFIED APPROACH
Author(s): Dan Comstock, Pete Jakubenas
Abstract/Introduction:
Statistical control is a tool for discernment and communication. This paper will describe a simplified method for monitoring the performance of each flow meter in a system comprised of multiple meters and a prover. The idea is to provide graphical assistance using meter factor control charts to: (a) develop preventive maintenance programs (b) heighten awareness of alarm situations and, (c) reduce risk to the financial bottom line. Meter factor control charts and logs make it easier to prepare reports provided to maintenance, operations, financial, and executive managers from time to time and furthermore, they make it easier for the target audience to digest the points being made.
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Document ID:
C0D3A10F
METER FACTOR TRACEABILITY FOR CORIOLIS MASS FLOW METERS
Author(s): Michael Keilty
Abstract/Introduction:
Coriolis mass flowmeters that are gravimetrically calibrated on water have been proven to be capable to satisfy
the specifications and requirements of national and international standards for the measurement of natural gas in
custody transfer applications.
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Document ID:
7879CFFF
NEW TECHNOLOGIES IN S&W MEASUREMENT
Author(s): WILLIAM SCOTT
Abstract/Introduction:
This course will discuss the technologies and methods of measuring sediment and water (S&W) in a liquid line. As with any topic, the history of how things came to be is critical in understanding what exists today. For this reason, both new and old technologies will be discussed in detail. Measuring S&W in the oilfield has many challenges. There have been various methods incorporated over the last 50 years ranging from Mason Jars, automated sampling systems, manual sampling to online real time measurement. Todays new technologies, combined with standards that are in work with regards to custody transfer, point to an automated process in the future.
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Document ID:
2684C32B
AUDITING ELECTRONIC GAS MEASUREMENT PER API CHAPTER 21.1
Author(s): Duane Harris
Abstract/Introduction:
API 21.1 is recognized as an international industry standard documentingAPI 21.1 is recognized as an international industry standard documenting the electronic gas measurement (EGM)
system audit and record requirements for differential and linear meter measurement.
This standard is used throughout the measurement community to reduce overall EGM system uncertainty and
improve measurement data integrity.
Measurement data integrity plays a critical part in measurement accuracy for all organizations and generally has a
direct impact to the financial bottom line of your organization. Measurement integrity is also vital for ensuring
compliance with regulatory and industry standard requirements.
On August 1, 1993, the first edition of the American Petroleum Institute (API) Manual of Petroleum Measurement
Standards (MPMS) Chapter 21.1 Flow Measurement Using Electronic Metering Systems-Electronic Gas
Measurement was released following a four-year collaborative effort. This document provided the industry with a
much-needed standard for several key areas related to custody transfer gas measurement using flow computers. the electronic gas measurement (EGM)
system audit and record requirements for differential and linear meter measurement.
This standard is used throughout the measurement community to reduce overall EGM system uncertainty and
improve measurement data integrity.
Measurement data integrity plays a critical part in measurement accuracy for all organizations and generally has a
direct impact to the financial bottom line of your organization. Measurement integrity is also vital for ensuring
compliance with regulatory and industry standard requirements.
On August 1, 1993, the first edition of the American Petroleum Institute (API) Manual of Petroleum Measurement
Standards (MPMS) Chapter 21.1 Flow Measurement Using Electronic Metering Systems-Electronic Gas
Measurement was released following a four-year collaborative effort. This document provided the industry with a
much-needed standard for several key areas related to custody transfer gas measurement using flow computers.
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Document ID:
5FE935C9
OPERATIONAL EXPERIENCE WITH LIQUID CORIOLIS METERS
Author(s): Joseph Crews
Abstract/Introduction:
Widely utilized in the petroleum industry, coriolis meters are have become prolific in applications involving liquid
hydrocarbon custody transfer. Coriolis meters ability to measure a vast array of process fluids, multiple process
variables, process insights, and wide turndown have driven the increase in use. While their use is wide spread,
coriolis meters are still considered a relatively new and in some cases unknown technology. Unfamiliarity with
operational principles coupled with everchanging software packages and diagnostics can make these mass and
density meters seem truly inaccessible.
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Document ID:
AC9D2B30
CALCULATIONS OF LIQUID PETROLEUM QUANTITIES
Author(s): Keith Fry
Abstract/Introduction:
There are a variety of ways to calculate liquid petroleum quantities. Some methods will be better than the others,
depending on the measurement application. Unfortunately, the outcomes of different methods, even though they
may be valid, may come up with different results. This could be a cause of controversy and dispute between different
parties trading or accounting for quantities of liquid petroleum. This is the reason for standards.
Petroleum measurement standards in the United States are industry-established means of determining what is
universally or widely accepted by the industry. They are usually agreed upon in a contract between different entities
or between parties within the same organization. Outside of the United States, standards may be dictated by the
government. Every common liquid petroleum quantity calculation can be found in a standard.
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Document ID:
256B492C
Fundamentals of Gas Chromatography
Author(s): Daniel Tiller
Abstract/Introduction:
Chromatography is the separation of a mixture by passing it in solution or suspension or as a vapor (as in gas
chromatography) through a medium in which the components move at different rates. Russian botanist Mikhail
Tswett is credited with discovering the technique of chromatography. He used chalk and alcohol to determine plant
extract properties.
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Document ID:
904AA87B
FUNDAMENTALS OF GAS MEASUREMENT III
Author(s): Don Sextro
Abstract/Introduction:
The ideal gas laws and their underlying reasoning are helpful to those engaged in measuring natural gas for
commercial purposes. Ideal gas behavior is a useful technique for approximating the effects of pressure,
temperature and other attributes on a gas volume. The gas laws provide a useful background as well to a discussion
of the behavior of molecules in a gas mixture which then leads to a discussion of real gas behavior and a correction
for compressibility.
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Document ID:
9433A314
API 11.3.4 Miscellaneous Hydrocarbon Properties - Ethanol Density and VCF
Author(s): James M. Pettinato, Jr.
Abstract/Introduction:
The use of ethanol as an oxygenate component of retail motor fuels has been a standard practice since the 1980s. Billions of dollars worth of fuel composed of blend of gasoline and ethanol is delivered each year. There has always seemed to be a general acknowledgement in the industry that there was higher than expected uncertainty in the measurement of product volumes when gasoline and ethanol are blended. Measurement experts were witness to the uncertainty when using different blend stocks or between varying blending methods. Prior to the work starting to develop this new standard, the potential impact of the uncertainty related to ethanol-gasoline blend volumes was estimated to be around 90,000,000 per year in the U.S. alone. It became evident that there was a need to address these discrepancies in blended product volume.
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Document ID:
EC27B546
BENEFITS AROUND TIMELY ANALYSIS OF MEASUREMENT DATA
Author(s): Duane Harris
Abstract/Introduction:
The timely analysis of measurement data is a critical process throughout the energy sector value chain. Most organizations are closing the prior months measurement data on the 3 to 10 working day of the next month, e.g. February 2020 was closed on March 4 th - 13th . Initially some companies use that reference point as the driver to analyze and resolve all measurement data issues. However, there are many organizations that strive to resolve all measurement anomalies daily. The driver for a daily measurement processes are generally driven by the measurement group with feedback form a combination of the upstream and downstream groups within the organization. These groups include marketing-based systems including the nominations and allocations groups, field operations teams including gas control plus the accounting group(s), Today the measurement system provides the critical layer of measurement data integrity required to meet the timely overall measurement accuracy for an organization due to its direct impact on the bottom line. The integrity of measurement data begins at the primary device in the field and continues through to the validation of all data received and processed by the measurement group.
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Document ID:
0C3B647D
ESTIMATING MEASUREMENT UNCERTAINTY FOR GAS METERS
Author(s): Adam Hawley
Abstract/Introduction:
Measurement accuracy is an important concept for anyone who deals with measurement on a regular basis. In
fact, a measurement is not truly complete until the accuracy has been assessed and is understood. This paper will
introduce multiple concepts regarding measurement accuracy and how they apply to flow measurement. The
examples in this paper will focus on natural gas measurement, but the concepts discussed could also be applied to
other measurement systems.
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Document ID:
9D204059
MASTER METER PROVER CALIBRATIONS PER API MPMS 4.9.3
Author(s): Kevin Fields,Steve Wilson
Abstract/Introduction:
When discussions about prover calibrations occur, they normally end with a disagreement about the accuracies of the different approved methods. This method was developed over 25 years ago to minimize difficulties in calibrating very large volume provers. In todays fast-paced world, where downtime is money, more companies are starting to utilize the master meter prover (MMP) method to save time and money on prover calibrations. Accurate and acceptable calibrations require proper technique from a knowledgeable technician performing the test. Without the proper knowledge, experience and equipment there is little chance a calibration will be accurate, repeatable or meet the requirements of API MPMS Chapter 4.9.3. This paper will discuss the master meter method of prover (MMP) calibration as described in API MPMS Chapter 4.9.3.
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Document ID:
A369EC04
REFINED PRODUCT SAMPLING SYSTEMS
Author(s): Jim Klentzman
Abstract/Introduction:
This paper discusses design considerations for refined product sampling systems. Refined product sampling is
usually divided into two different areas: the sampling that occurs inside the refinery, which deals with blending of
the gasoline and diesel fuels, and the sampling that occurs outside the refinery in pipeline areas, which typically
involves a custody transfer situation in the field. The blending compositor sampling and equipment involved is
connected to the control room and is closely monitored to ensure that the sample can be shown to be very
accurate by using level indicators and bite checkers to verify volume in the container. Custody sampling is a less
complicated unit typically outside of a refinery and at custody transfer points. The system is operated by a PLC
and is usually multiple containers with a single pump without level indicators or bite checkers integrated into the
system and the purpose is to verify what has been sent down the pipeline to the end users. Refined products are
typically, jet fuel, diesel, gasolines, and aviation gasolines/fuel.
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Document ID:
3D600712
SAMPLE CONDITIONING AND CONTAMINANT REMOVAL FOR
WATER VAPOR CONTENT DETERMINATION IN NATURAL GAS
Author(s): Brad Massey
Abstract/Introduction:
The Natural Gas Industry experiences numerous operational problems associated with high water vapor content in
the natural gas stream. As a result several problems are experienced such as, equipment freezes, dilution of
physical properties reducing heating value, volume measurement interference, and pipeline corrosion. Contracts
and Tariffs usually limit the amount of water vapor content allowed at the custody transfer point. For these and
other reasons, accurate Water Vapor Dewpoint measurements are critical measurements for all companies
involved in natural gas production, gathering, transmission and delivery.
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Document ID:
38BDC4CD
MEASUREMENT SCENE INVESTIGATIONS
Author(s): Casey Hodges
Abstract/Introduction:
There are many ways to measure hydrocarbons. Measurements may be performed on liquids, gases, or multiphase fluids. Measurement may be made utilizing orifice plates, ultrasonic meters, Coriolis meters, or a host of other meter types. After the actual meter, there is secondary instrumentation involved from transmitters to flow computers and SCADA systems. With so many components to a flow measurement system, determining the root cause of measurement discrepancies becomes a forensic exercise. In any forensic exercise, the more information the Detective has the more likely they are to find the culprit. This paper describes methodologies to determine the causes of measurement discrepancies. While this paper does draw a parallel between criminal forensics and measurement forensics, it should not be interpreted that measurement discrepancies are criminal. The world of measurement is becoming more automated, and monitor systems can detect and analyze discrepancies faster than before. However, a vast majority of measurement systems are not being monitored at the highest level, and by the time discrepancies are noted, it is all hands on deck to solve the crime.
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Document ID:
B6BFA7FA
D.O.T. REQUIREMENTS FOR THE TRANSPORTATION
OF SAMPLE CYLINDERS
Author(s): David J. Fish
Abstract/Introduction:
The United States Department of Transportation (D.O.T.) is a department of the U.S. Federal Government which
oversees all issues regarding transportation within the United States of America and U.S. Territories. Its influence
around the world is great and widely respected, but its jurisdiction and power of enforcement is limited to the USA
and its territories. As regards this paper, we will discuss the D.O.T. and its involvement surrounding sample
cylinders for the hydrocarbon industry and the rules regarding the movement of these cylinders from point to point
in the United States.
The most important statement to be made is that the D.O.T. and Code of Federal Regulations, Title 49 (CFR-49)
is the definitive and final authority on all issues regarding the handling and transportation of sample cylinders.
Much has been written and quoted over the years and many regulations have changed over the years. It is the
sole responsibility of each company involved with sample cylinders, to have a copy of CFR-49 and to be
responsible for clarification of any issues they have, by researching CFR-49 and consulting with D.O.T.
representatives. They have the final word on any questions. D.O.T. is the enforcement agency regarding sample
cylinder transportation. Transport Canada in Canada is in close parallel to the United States Department of
Transportation, but they should not be confused with each other and should be studied and reviewed separately.
The author of this paper and the company he represents do not present themselves as authorities on this matter
for you or your company. This paper is presented for the sole purpose of providing limited information and to
encourage you and your company to become better informed for your specific needs and operations.
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Document ID:
259C17B4
OVERVIEW OF CHANGES TO API2350 TANK OVERFILL PROTECTION
Author(s): Rich Ireland
Abstract/Introduction:
The USAs dominance in hydrocarbon extraction, refining and transportation (and Export!) is supported by the existence of ample, efficient and safe hydrocarbon-storage facilities. The American Petroleum Institute is the recognized standards development organization for every aspect of the hydrocarbon supply chain. Keeping the precious liquid inside the pipeline or inside the tank is of utmost importance for safety and low environmental impact. API-2350 is the standard (OF MINIMUM REQUIREMENTS) for overfill prevention in atmospheric storage tanks. The standard (formerly referred to as a Recommended Practice) is now in its 5th edition. In 2011, Edition 4 was released as the comprehensive move to elevate 2350 as a Standard. We can now explore the re-visitation of the standard in the newly released Edition 5.
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Document ID:
E1E4DEB8
DOT QUALIFICATION TRAINING FOR MEASUREMENT AND CONTROL TECHNICIANS
Author(s): Joey Rockett
Abstract/Introduction:
The Operator Qualification (OQ) Program was mandated by Congress in 1992, and again in 1996.
Congress became concerned by the occurrences of pipeline accidents and directed the Office of
Pipeline Safety to developed regulations addressing OQ. The intent of this qualification rule was to
ensure a qualified work force and to reduce the probability and consequence of incidents caused by
human error. It established qualification requirements for individuals performing covered tasks, and
amended certain training requirements in the hazardous liquid regulation. Also, it was emphasized that
the ability to recognize and react to abnormal operating conditions is crucial.
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Document ID:
A6F04F5A
CHALLENGES IN ALLOCATION MEASUREMENT
Author(s): Bill Theriot
Abstract/Introduction:
The primary goal of the allocator is to provide a fair and equitable allocation to all parties. In order to provide an equitable allocation, produced volumes will need to be corrected for any biases, uses and known losses. All of these happening between the allocation point and the sales point. The second critical goal of the allocator is to minimize any differences between the allocation volumes and the sales volumes to be allocated. By dividing one by the other the result is commonly referred to as the system factor. In a perfect world the allocation factor will be 1.00000. However we do not live in a perfect world. Due to the potential uncertainties and bias (uniformly distributed) related to allocation measurement, allocated quantities may be higher or lower than the custody sales quantity, but still provide fair and equitable measurement. The uncertainties and bias in allocation measurement may come from the metering, sampling, production equipment, and/or the phase quality of the fluid.
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Document ID:
00F316BB
Advanced Application of Liquid Flow Computers
Author(s): Brent H. Palmer
Abstract/Introduction:
A flow computer is an electronic computational device which implements the required algorithms to turn the raw
data received from flow meters to which it is connected into volumes at base conditions.
A flow computer also audits changes that have been made to any of the parameters required to turn the raw flow
meter data into volumes. It records events and alarms related to the flow meter (for example, loss of flow, loss of
required electrical signals from measurement transducers, or transition of these electrical signals near their upper
or lower range). It will keep a running tally of the volume for each flow meter it monitors and perform a total of this
volume on an hourly, daily or monthly basis. The flow data is made available externally through an electronic
interface so that other computers can download the information for the purposes of supervision, accounting or
auditing.
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Document ID:
AD907228
Cone Meters for Liquid and Gas Measurement
Author(s): Philip A Lawrence
Abstract/Introduction:
This paper describes the Differential Pressure Cone Flow Meter, its design as a primary measurement device, its operating principle, and how the meter is used for the measurement of liquids and gases. Differential pressure cone flow meters have become synonymous with specialist metering applications due to the special traits that are inherent with this type of meter. Measurement principles and concepts pioneered by Venturi and Bernoulli will also be mentioned in the paper to assist the student. Natural gas flow measurement including both dry and wet gas applications have been performed using various types and designs of cone flow meters. Specialty unprocessed liquid measurements with asphaltenes and wax deposition within the fluid stream have also been metered in certain applications. Other applications for off/on-shore, steam measurement for enhanced oil recovery and custody transfer/fiscal measurement have been a quite successful use for this technology. Brand names will not be mentioned in the main body of this paper per ISHM guidelines.
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Document ID:
753381AC
Engineering Ethics
Author(s): Casey Hodges
Abstract/Introduction:
An engineer represents many different ENTITIES. Obviously, an engineer represents themselves, but they also represent their families, their employers, their universities, their hometowns, and their entire profession. This is a great responsibility, and is one that engineers should take very seriously. To understand that your actions reflect not only on your personal reputation, but the reputation of all the other engineers before you is paramount when making engineering judgements and decisions. This paper discusses the guidelines for Professional Engineers when it comes to making ethical decisions. Just like Medical Doctors take the Hippocratic oath of Do No Harm, Professional Engineers take a similar pledge.
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Document ID:
35F6A0AA
COMPRESSIBILITY OF NATURAL GAS
Author(s): Jeffrey L. Savidge
Abstract/Introduction:
The compressibility factor is a ubiquitous concept that is used in many engineering applications and measurement
practices. At a basic level the compressibility factor is a correction factor. It corrects a value estimated from an ideal
mathematical model to a value that is more consistent with a measured value, presumably a more accurate one
than the ideal value. At a deeper level compressibility is a measure of intermolecular forces exerted between
molecules at various temperature and pressure conditions. Embedded in this very basic description are multiple
layers of data, complexity and uncertainty. Unfortunately the background, mathematical methods, tools,
descriptions and data associated with the compressibility factor obscure its basic simplicity.
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Document ID:
8294FE3C
THE MEASUREMENT DATA HANDLING PROCESS-NOW AND IN THE FUTURE
Author(s): Duane Harris
Abstract/Introduction:
Oil and gas measurement automation software applications are continuing to strive to meet the
required and growing functionality expected within the industry. In response to the current business
climate that is characterized by commodity prices running below the projected levels, operating
companies are investing into the optimization of existing assets to increase efficiency and looking for
ways to streamline the overall measurement process.
Our goal has always been centered around measurement integrity. This goal must remain at the
forefront as we move into the future for every type of measurement facility and processing design. For
instance, in unconventional resource plays with multiple-well pads, rapidly declining production rates in
properties such as shale fields, etc. all present a considerable challenge to the Rate of Investment (ROI).
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Document ID:
F373B76E
OVERVIEW OF GPA 2172/API 14.5 REVISION
Author(s): Matt Holmes
Abstract/Introduction:
GPA Standard 2172 / API Manual of Petroleum Measurement Standards Chapter 14, Section 5, Calculation of
Gross Heating Value, Relative Density, Compressibility and Theoretical Hydrocarbon Liquid Content for Natural
Gas Mixtures for Custody Transfer, Third Edition, January 2014 provides methods to calculate a variety of
necessary properties from a gas analysis. Several important changes occurred in the 2009 revision of the standard,
which was most recently reaffirmed in 2019. The main changes are for incorporating water vapor into the analysis
calculations and calculating theoretical hydrocarbon liquid content on a real gas basis. Additional cautionary notes
are provided regarding the characterization of heavier components and accounting for water in the gas analysis,
and a number of detailed example calculations are provided. Refer to the standard itself for requirements,
procedures, details and further explanation.
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Document ID:
501B2321
IDENTIFYING AND ELIMINATING EFFECTS OF INDUCED SIGNALS ON MEASUREMENT SYSTEM
ELECTRONICS
Author(s): Peter P. Jakubenas
Abstract/Introduction:
Measurement errors and other effects of induced signals on measurement system electronic equipment can be
quite profound. This paper will explore the sources and effects of induced signals and other phenomena including
effects of cathodic protection systems, high voltage power lines, faulty grounds, lightning, RFI, and intermittent
events. Information to prevent and eliminate undesirable signals is provided as well as technical references.
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Document ID:
8F88CF10
FLUID VOLUME CALCULATIONS
Author(s): Matt Holmes
Abstract/Introduction:
Fluid volume is the basis for most of the sale and purchase of hydrocarbons in the oil and natural gas industry, in
the United States and around the world. As such, it is important that fluid volumes are measured, calculated, and
corrected as accurately as possible. This paper outlines the fundamental derivation of fluid volumetric calculations
at base conditions as made from measurements directly related to or used to infer volume, for both single-phase
hydrocarbon gases and single-phase hydrocarbon liquids.
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Document ID:
E852890F
TESTING, MAINTENANCE AND OPERATION OF ELECTRONIC FLOW COMPUTERS FOR THE GAS INDUSTRY
Author(s): Tushar Shah
Abstract/Introduction:
The intention for this paper is to provide an overview of testing, maintenance, and operation of electronic flow computers for the Gas Industry and how they integrate into the world of electronic gas measurement while utilizing the American Petroleum Institute (API) API MPMS 21.1 standard (AGA Report No. 13) Flow Measurement Using Electronic Metering Systems - Electronic Gas Measurement. This overview is for those who are new to the industry or for those who are looking for a refresher on the basic application of flow computers.
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Document ID:
BD57E545
Wireless Economics 101
Author(s): Brian Lux
Abstract/Introduction:
Over the last several years, operators across North America tight oil and shale gas basins have achieved a step change in productivity improvements by applying advanced manufacturing processes in drilling and completion operations. This shift in operational philosophy demonstrates the benefits of changing traditional operating strategies. This continuous improvement mindset can also be applied to how production facilities are designed and constructed to ensure safe, reliable operations for the duration of a field development. Operators cannot control the prevailing commodity prices, but they can create value by changing the efficiency in which wells are drilled, brought to production and operated. Based on a study of 34 different operators across North America, producers that use standardized well pad designs and the latest wireless automation technologies have achieved more than 75k of capital savings per 4- pad well, while also improving production, reliability and safety.
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Document ID:
CD5BDF32
Improvement of Historic Proving Practice Through API MPMS Chapter 13 Statistical Methods
Author(s): Karl Stappert
Abstract/Introduction:
The American Petroleum Institutes (API) Manual of Petroleum Measurement Standards (MPMS) Chapter 4,8, Operation of Proving Systems, Second Edition, Section 12, Assessment of Proving Results outlines methods for the evaluation of proving data. Section 12.1 of the document states, The estimated random uncertainty of a proving (meter factors or meter pulses) is the primary criteria for an acceptable proving. A minimum of three consecutive proving runs is required. Any number of consecutive proving runs from 3 to 30 can be used. The preferred proving run uncertainty for custody transfer application is 0.027% or less.
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Document ID:
8D782AC0
Simplifying Real-time and Historical (EFM) Data Collection for the Oil & Gas Industry
Author(s): Stephen Sponseller
Abstract/Introduction:
An Industrial Control System (ICS) is comprised of many disparate components, including hardware and software
technologies, system infrastructure- from the communications network to the physical plant infrastructure-, the
human element for tasks that require manual intervention, and the environment.
To realize operational excellence, organizations must monitor and manage all aspects of the control system,
turning data into usable business intelligence. To accomplish this, all the components that make up the control
system must seamlessly interoperate with one another as if provided by a single vendor. The system must be
both reliable and able to withstand the elements that can impact operation. And it must be extensible over time
with the ability to scale and meet the needs of tomorrow. Lastly, the proper amount of security and safety must be
built into the system to prevent costly downtime and damage, while safeguarding the environment and the
surrounding community.
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Document ID:
2558BDF6
ORIFICE FITTINGS AND METER TUBES
Author(s): Hunter Ward
Abstract/Introduction:
An orifice meter is a differential pressure device. Bernoullis Principle states that an increase in the speed of a fluid occurs simultaneously with a decrease in static pressure or a decrease in the fluids potential energy. Orifice meters have been in use for decades, and in the energy industry, it is one of the most widely used meter technologies. Orifice has primarily been used for gas measurement. Some of the reasons for this could be that most of the past research was conducted by the American Gas Association (AGA), liquid measurement has had a wider variety of devices that could be used, etc. It is important to know that much of the research conducted to develop orifice meter factors, such as discharge coefficients, was performed using oil, water, steam, air, and natural gas. The theory and technical basis of orifice measurement applies to any fluid, be it gas or liquid.
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Document ID:
A1004B49
Measurement Methods for Liquid Storage Tanks
Author(s): Daniel Baldwin
Abstract/Introduction:
The purpose of this paper is to provide, in general terms, an overview of the different technologies available to
measure volumes in atmospheric storage tanks. There are typically four (4) volumes that are of interest to be
calculated for atmospheric storage tanks: Total Observed, Gross Observed, Gross Standard, and Net Standard
(see Fig 20 page 9). The basic measurements required for these volumes are: product level, observed
temperature, water level, and the observed density of the product.
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Document ID:
1A892378
ULTRASONIC METERS AND MEASUREMENT ACCURACY IN LEAK DETECTION
Author(s): Daniel Householder
Abstract/Introduction:
Pipeline operators are committed to safely transporting petroleum and refined products in an error-free and spill-
free manner. To achieve this safety goal, pipeline integrity management programs are developed and maintained.
These programs are primarily designed to prevent the unintended releases of liquid hydrocarbons, but when such
releases happen, quickly detecting them and activating response plans to mitigate their effects is very important.
Leak Detection Systems (LDS) are deployed to promptly alert pipeline operators that a release has potentially
occurred, and to determine the size and location of the leak. Different methods, often used in combination, are used
by LDS to accomplish this. Some of these methods use algorithms to detect hydraulic anomalies in pipelines and
are described by API RP 1130 as Computational Pipeline Monitoring (CPM) systems. The majority of CPMs use
pipeline operational variables to perform their calculations, and flow rate is one of the most important of them. Liquid
ultrasonic meters, because of their non-intrusive design, negligible pressure drop, high accuracy, and diagnostics
capabilities, have demonstrated to be one of the best choices when it comes to providing flow to CPM algorithms.
This paper describes the important relationship between the accuracy of the ultrasonic meters and the sensitivity,
reliability, robustness, and accuracy of the Leak Detection Systems. A discussion is included on how dynamic lab
testing is used to improve the accuracy of ultrasonic meters over a wide range of operating conditions. Also, the
paper discusses how diagnostics play a key role in verifying whether meter accuracy shifts over time, even when
no field proving is available, and how diagnostics also aid to uncover various and unusual operational events.
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Document ID:
39E646D3
CHALLENGES IN ALLOCATION MEASUREMENT
Author(s): Bill Theriot
Abstract/Introduction:
The primary goal of the allocator is to provide a fair and equitable allocation to all parties. In order to provide an equitable allocation, produced volumes will need to be corrected for any biases, uses and known losses. All of these happening between the allocation point and the sales point. The second critical goal of the allocator is to minimize any differences between the allocation volumes and the sales volumes to be allocated. By dividing one by the other the result is commonly referred to as the system factor. In a perfect world the allocation factor will be 1.00000. However we do not live in a perfect world. Due to the potential uncertainties and bias (uniformly distributed) related to allocation measurement, allocated quantities may be higher or lower than the custody sales quantity, but still provide fair and equitable measurement. The uncertainties and bias in allocation measurement may come from the metering, sampling, production equipment, and/or the phase quality of the fluid.
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Document ID:
1A821382
CONTAMINANT ACCUMULATION EFFECT ON GAS ULTRASONIC FLOW METERS
Author(s): Ed Hanks
Abstract/Introduction:
The following paper discusses the effects of accumulation on natural gas ultrasonic meters. The paper uses four meters, two Daniel meters and two Instromet meters, that were recalibrated at the CEESI Iowa facility. From CEESIs experience with recalibrations of contaminated meters, the results of these four meters are typical. Due to the relative newness of the other brands of meters in the US market, CEESI does not have recalibration data available for this paper and thus other brands are not included.
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Document ID:
D1F7E043
MEASUREMENT STATION INSPECTION DOCUMENTATION PROGRAM AND GUIDE
Author(s): Debra Ball, Joe Sena
Abstract/Introduction:
Having a formalized maintenance and inspection program is important to ensure measurement metering accuracy and that custody related activities are documented to show compliance with regulatory and contractual requirements. Oil and gas companies must operate within many constraints such as Regulations, (Federal, State, BIA (Bureau of Indian Affairs), FERC (Federal Energy Regulatory Commission), PHMSA-DOT (Pipeline and Hazardous Materials Safety Administration - Department of Transportation) & BSEE (Bureau of Safety and Environmental Enforcement), Contractual obligations (tariff, gather, buy/sell, & measurement agreements) and Industry standards (API ((American Petroleum Institute), AGA (American Gas Association), & GPA (Gas Processors Association)).
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Document ID:
059F125C
DATA VALIDATION - REQUIREMENTS OF AN EGM EDITOR
Author(s): Lindsey Agers
Abstract/Introduction:
The current environment of the hydrocarbon industry is extremely dependent on the timeliness and accuracy of measurement data. From production through plant processing, all operational departments make time-sensitive, financially driven decisions based on the flow data received through field measurement systems. Industry regulations and corporate contracts dictate measurement-specific requirements for accurate and efficient operational continuity. The industrys focus on real-time troubleshooting and response have forced the requirement for a quality Electronic Gas Measurement (EGM) editing system within a companys portfolio.
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Document ID:
3953D92C
D
Author(s): Matt Holmes
Abstract/Introduction:
The natural gas industry has only one standard that has maintained requirements for averaging input data for volumetric calculations over a calculation period. That standard is the American Petroleum Institutes (API) Manual of Petroleum Measurement Standards (MPMS) Chapter 21.1 - Flow Measurement Using Electronic Metering Systems - Electronic Gas Measurement. Data averaging is used to represent operational and flowing conditions over a period of time, to limit the number of records required to maintain a full audit trail, to help verify the validity of the reported volume, and to allow recalculation of volume and editing if needed. Data points are averaged over a defined calculation period, typically 15 minutes or an hour, with measurements and calculations taking place typically around once per second.
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Document ID:
0D1D21C4
Flow Conditioning for Fluid Flow Measurement
Author(s): Blaine Sawchuk
Abstract/Introduction:
The flow conditioner, examples as illustrated in Figure 1 - Flow Conditioners, is an essential component of any fluid (gas or liquid) AGA, API, GPA or ISO, etc. meter run. Orifice meter, turbine meter, coriolis meter, ultrasonic meter etc. or any type of meter run as well as pump inlet pipe require flow conditioning. The flow conditioner isolates the meter from any piping installation effects which adversely affect the meters performance. This paper provides a background to flow conditioners, and why they are required. It then provides an overview of the popular flow metering standards in use and then flow conditioner placement requirements.
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Document ID:
0AA0A60E
ORIFICE METER MAINTENANCE AND OPERATION
Author(s): Clay Mol
Abstract/Introduction:
The natural gas industry has seen many changes lately. The world population is increasing and with this the energy demands in the world are also increasing. Producers and pipeline companies have seen tremendous growth and reorganization through these increased demands for energy. The advances in technology in the last decade have literally put a computer and cellular phone at everyones fingertips and increased the need for electricity, thus the need for natural gas to generate this electricity. With this increased demand for natural gas, the logistics involved in acquiring it, and the profit differential between demand and logistics, the need for proper maintenance is more important than ever.
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Document ID:
40026BC4
THEORY AND APPLICATION OF PULSE INTERPOLATION TO PROVER SYSTEMS
Author(s): David J. Seiler
Abstract/Introduction:
Pulse interpolation, by definition, is the ability to estimate values of (a function) between two known values. Therefore, pulse interpolation enables pulse counts to be made to a fraction of a pulse, thus greatly reducing the rounding - off errors that occur when pulse counts are made to the nearest whole number which always happens in the absence of Pulse Interpolation.
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Document ID:
D9FE8736
PRODUCTION EQUIPMENT EFFECTS ON ORIFICE GAS MEASUREMENT
Author(s): Stormy Phillips
Abstract/Introduction:
The condition of gas as it presents itself in the pipeline is often not ideal for accurate measurement, by an orifice flow meter. It is the requirement of the American Gas Association (AGA) that the natural gas be in a single phase and with a swirl-free fully developed profile as it passes across the orifice plate to meet the standard of measurement to provide acceptable uncertainty for the flow calculation. Thus, it is often necessary to condition the gas prior to measurement. Using the basic laws of gases, we can control these conditions by altering the temperature, pressure, or component makeup of the gas. Neglecting these conditions will create a poor measurement environment and inaccurate measurement. It is therefore necessary for measurement personnel to be familiar with common production equipment, how that equipment is utilized and what effect it can have on the overall ability for a system to provide accurate measurement.
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Document ID:
456298C4
IMPROVING FLOW MEASUREMENTS WITH IMPROVED
CALIBRATION AND DATA HANDLING PROCEDURES
Author(s): Duane Harris
Abstract/Introduction:
The continual flow of information from field measurement staff to the office measurement staff is extremely
demanding and creates tremendous and constant challenges for every organization.
Every day, field technicians test their knowledge bases and skill sets regarding:
? Electronic and pneumatic controls
? Communication system support
? Multiple technical disciplines
? Measurement and verification equipment
? Keeping current with applicable measurement standards
? Standard operating procedures
? Facility regulatory requirements
? Current measurement guidelines
? Ongoing training
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Document ID:
70BE644B
SAMPLING AND CONDITIONING OF NATURAL GAS CONTAINING ENTRAINED LIQUIDS
Author(s): Donald P. Mayeaux
Abstract/Introduction:
The monetary value of natural gas is based on its energy content and volume. The energy content and physical
constants utilized in determining its volume are computed from analysis. Therefore correct assessment of the
value of natural gas is dependent to a large extent on overall analytical accuracy.
The largest source of analytical error in natural gas is distortion of the composition during sampling. Sampling
clean, dry natural gas, which is well above its Hydrocarbon Dew Point (HCDP) temperature, is a relatively simple
task. However, sampling natural gas that is at, near, or below its HCDP temperature is challenging. For these
reasons, much attention is being focused on proper methods for sampling natural gas which have a high HCDP
temperature.
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Document ID:
7C4145B8
CALIBRATION OF LIQUID PROVERS
Author(s): Nathan Wilson
Abstract/Introduction:
A meter prover is installed in series with a meter and used to establish a meter factor. The volume that passes through the meter is compared to the prover volume during the time a sphere or piston passes between two detector switches. The prover volume is accurately determined by a calibration procedure known as the Water Draw method.
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Document ID:
26C515E4
BASICS OF HIGH-PRESSURE MEASURING AND REGULATING STATION DESIGN
Author(s): James N. Witte
Abstract/Introduction:
This paper presents a review of the criteria necessary for designing high-pressure natural gas measuring and
regulating stations. For the purpose of this discussion, high pressure is assumed to be gauge pressure values
above typical distribution mainline pressures (greater than 60 psig). Therefore, it is most applicable to station
designs with gathering, midstream, and transmission operations.
The design engineer has many factors to consider when designing a metering facility. These factors must include
considerations for their impact on measurement accuracy, facility capital cost, environmental stewardship, public
stewardship, and long-term maintenance cost. The successful designer will seek to achieve high accuracy at an
appropriate capital cost, while minimizing the risks of environmental hazards, public nuisance, such as noise, and
maintenance requirements.
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Document ID:
D9CDBDA7
DETERMINATION OF H 2S AND TOTAL SULFUR IN NATURAL GAS
Author(s): David Haydt
Abstract/Introduction:
Hydrogen sulfide and other sulfur bearing compounds exist naturally in many natural gas fields throughout the
world. It is generally necessary to remove these sulfur bearing compounds from the gas in order to preserve
public safety, reduce corrosion in pipelines, meet contractual agreements and to control odor in the gas. Thus the
determination of hydrogen sulfide and total sulfur in natural gas is critical to the natural gas industry.
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Document ID:
4AEBADF0
Effects and Control of Pulsation in Gas Measurement
Author(s): Michael Royce Miller
Abstract/Introduction:
Pulsation created by compressors, flow control valves, regulators and some piping c o n f ig u r a t i o n s a r e k n o w n t o c a u s e significant errors in gas measurement. In recent years the Pipeline-and Compressor Research Council (PCRC) now know as (GMRC) Gas Machinery Research Council, a subsidiary of the Southern Gas Association, commissioned and funded various pulsation research projects at Southwest Research Institute (SWRI) in San Antonio, Texas. This research culminated in the publication of several technical papers, including the April 1987 PCRC report 10.87-3 titled Pulsation and Transient-induced Errors at Orifice Meter Installations and a report, An Assessment of Technology for Correcting Pulsation Induced Orifice Flow Measurement dated November 1991. The PCRC sponsored research programs concluded that pulsation induced measurement errors fall into two broad categories: 1) Primary Element Error: which includes square root averaging error (SRE), inertial errors, and shifts in the orifice coefficient. 2) Secondary Element Errors: which consist of gauge line distortion and gauge line shift, together commonly referred to as gauge line error (GLE)
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Document ID:
1959D768
Fundamentals of Sampling Natural Gas for BTU Determination
Author(s): Brad Massey
Abstract/Introduction:
BTU determination of a natural gas stream is typically accomplished by chromatographic compositional analysis
but in some instances the BTU is measured from the heat produced by burning the delivered sample. In either
case the sample delivered to the analyzer must be representative of the flowing gas stream. For this reason, careful
consideration is required in the design of the sample extraction, conditioning, and delivery systems. These systems
are typically referred to as Sample Conditioning Systems.
Because natural gas has wide variables in composition, diluents, and potential contaminants, the methods used for
sampling conditioning systems must account for the probability of factors that may influence the analytical results.
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Document ID:
D99261C4
ENERGY MEASUREMENT USING ULTRASONIC FLOW MEASUREMENT AND GAS CHROMATOGRAPHY
Author(s): Vertis Grummert
Abstract/Introduction:
With the ever-increasing world population and industry converting fuel oil, coal and other fossil fuels to the more efficient and economical natural gas, the need for quality and accurate energy measurement is crucial to the natural gas industries bottom line. In todays transactional environment, an onsite total energy measurement system is necessary to provide a more timely settlement of the fluid quantities between parties. Custody transfer volume and energy quantities are calculated and archived by the Electronic Flow Measurement device. The EFM receives the volume and gas quality data from the ultrasonic meter and gas chromatograph. A remote communication system is utilized to transfer the data to the measurement data repository and gas accounting, without the need for any adjustments or editing, hence reducing another source of possible error.
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Document ID:
189E36DC
LIQUID MEASUREMENT FIELD SURVEYS
Author(s): Chris Levy
Abstract/Introduction:
A successful hydrocarbon measurement program is composed of many dynamic components. At the core, accurate
measurement system performance is dependent upon measurement tasks being performed consistently in
accordance with established operational processes and procedures. Routine assessments help assure equipment
is operated and maintained as intended. As shown in Figure 1, assessments provide a feedback loop that measures
the performance so that adjustments can be made to address deficiencies and achieve desired results.
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Document ID:
F7476047
Pycnometer Installation, Operation and Calibration
Author(s): Billy Burton
Abstract/Introduction:
This white paper will cover the various steps necessary to accomplish a successful density meter proving using
the pycnometer test method. This document will include the requirements for certification and the information that
must be recorded and present on the associated report. Also included will be a brief overview of critical equipment
and recommendations for proper configuration, installation, and maintenance. The information provided is in
accordance with API MPMS 9.4 and all standards referenced within that document.
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Document ID:
ED81330C
BASIC ELECTRONICS FOR THE FIELD TECHNICIAN
Author(s): Hampton Stapleton
Abstract/Introduction:
Electronic measurement and controls have become an increasingly important staple in the oil and gas
industry. There are many complex operations and equations involved with electronics and controls, but they
still require basic electronic fundamentals for setup and maintenance. The purpose of this paper is to teach
and reinforce those essential fundamentals.
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Document ID:
CDF870B1
Operations and Problems Associated with Prover Detector Switches
Author(s): Nathan Wilson
Abstract/Introduction:
A meter prover is used to calibrate meters to establish a meter factor. The volume that passes through the meter
is compared to the known prover volume. This known volume is the displacement of the liquid between the
detector switches on the prover. The displacement is measured either by a sphere or piston from the activation of
the first detector switch to the activation of the second detector switch. The known volume is typically determined
by a calibration known as the waterdraw method. Detector switches are critical in the design of a prover and the
ability to establish the known volume to determine a meter factor .
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Document ID:
D43558DE
TROUBLESHOOTING LIQUID PIPELINE LOSSES AND GAIN
Author(s): Joseph T. Rasmussen, Michael R. Plasczyk
Abstract/Introduction:
Liquid pipelines are integrated transportation networks providing multiple services for many shippers and customers. These systems may connect to multiple origins and destinations, and carry various products across long distances with changing elevation profiles, pipe dimensions and directions. Expectations are that the volumes received in the system are equivalent to the volumes delivered, with the exception of inventory changes. But in reality, every pipeline system will experience a loss or gain over time. Monitoring pipeline losses and gains employs tools and analysis methods developed specifically to troubleshoot pipeline variances. Evaluation of pipeline losses and gains uses basic statistical tools as well as intuitive and creative insight into what controls losses and gains. The basic tool for evaluating system performance is Loss/Gain, a measure of how well receipts, deliveries and inventory match up over a period of time. The concept is similar to that used for leak detection, but usually covers a longer time period. Loss/gain is a measure of the quality of the overall measurements in a system, and excessive loss/gain can signal the need for an investigation to identify causes and develop corrective actions.
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Document ID:
D93A45F1
FIELD PROVING GAS METERS
Author(s): Joel Clancy, Rich Schoonover
Abstract/Introduction:
This paper will discuss the field proving of gas meters. There have been many designs throughout the history of
field gas proving. A few designs will be discussed in this paper. For perspective, liquid proving will be briefly
discussed. Liquid field proving is a more widely used and accepted practice when compared to gas field proving.
Also discussed will be American Gas Association (AGA) Report No. 6. The title of this report is AGA Report No. 6,
Field Proving of Gas Meters Using Transfer Methods1
. This AGA report provides field personnel a guide for the
field proving of gas meters.
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Document ID:
54F8C9D1
MULTIPHASE FLOW MEASUREMENT
Author(s): Richard Steven
Abstract/Introduction:
The measurement of unprocessed hydrocarbon flows is becoming more prevalent in the hydrocarbon production industry. Multiphase meters are now often integral in the design plans for new developments. However, the phrase multi-phase flow covers a huge range of flow conditions and metering these varied flows has proven a major challenge to engineers. Furthermore, the relatively complex and proprietary nature of these meter designs leads to the finer details of their operation not being divulged, so there is often a lack of technical understanding amongst the end users. In this paper, definitions of the phrases multiphase flow and wet gas flow will be discussed. There will be a discussion on the requirement for multiphase metering before multiphase flow patterns and the methods of predicting them are discussed. Finally, an overview of the common multiphase meter generic principles will be given.
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Document ID:
9162FA68
DETERMINATION OF LEAKAGE AND UNACCOUNTED FOR GAS
Author(s): Allison Bentley
Abstract/Introduction:
Natural gas producers, gathers, treaters, processors, transporters, and distributors are all exposed to the potential safety hazards and costs associated with lost and unaccounted for gas. Safety hazards include leaks and theft, and costs may be incurred due to incorrectly measured gas or line pack. Costs can also be associated with imbalances or contractual caps. Common acronyms representing lost and unaccounted for gas are as follows: LAUF Lost And Unaccounted For LAU Lost And Unaccounted for L&U Lost & Unaccounted for L&U will be the acronym used for reference throughout this paper.
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Document ID:
255E2774
CERTIFICATION and PERFORMANCE TESTING of AUTOMATIC SAMPLERS
Author(s): James M. Strawn
Abstract/Introduction:
Automatic sampling systems should be tested and certified according to the American Petroleum Institute (AP)
Manual of Petroleum Measurement Standards (MPMS), Chapter 8, Section 2, and the sample container/mixing
system according to API 8.3. The complete system should be tested once it is installed in the field, under field
operating conditions. Once certified, the system performance should be continually monitored and recorded to
ensure the system is producing representative samples.
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Document ID:
3156CADC
UNDERSTANDING LIQUID METER PROVINGS AND PROVING REPORTS
Author(s): Billy Burton
Abstract/Introduction:
This document will discuss liquid proving reports for mass and volume measurement applications. New capabilities in the software and flow computer interfaces has dramatically improved the proving process. The reporting and audit trail capabilities of todays measurement systems far surpass yesterdays basic proving report. This paper will outline certain requirements and highlight some differences in common proving reports.
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Document ID:
CF066FC4
AUTOMATED TRUCK LOADING SYSTEMS
Author(s): James M. Pettinato, Jr.
Abstract/Introduction:
Bulk storage facilities and the associated infrastructure to perform loading/unloading of transports, often referred to
collectively as distribution terminals or load racks, must support the loading and unloading of liquid product between
storage tanks, railcars, tank trucks, and barges. These transfers of petroleum products impact multiple facets of
terminal operations including safety, security, measurement accuracy, and regulatory requirements. Due to the
continuous advancement of electronic systems, improvements are continually being made in the development of
specialized systems to address the needs of these applications. This report will focus on the types of automated
systems utilized to meet these needs and the features they provide.
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Document ID:
C65408BD
FLARE MEASUREMENT PRACTICES
Author(s): Eric Estrada
Abstract/Introduction:
With the recent release of the Green House Gas Regulations, the increased visibility of flaring natural gas and
increased awareness of royalty owners, the ability to accurately measure and account for the amount of product
flared from a facility has become increasingly important to regulators, royalty owners and operators. In the past,
flare gas was not considered a necessary measurement, so the measurement of flared product has often been
overlooked or not given the same attention as custody transfer measurement. As such API published API MPMS
Chapter 14.10, Measurement of Flow to Flares, in June of 2007 and subsequently published the second edition in
December of 2021. This paper will provide a quick overview of the contents of API MPMS 14.10 but is encouraged
to obtain 14.10 if more detailed information is desired. In addition, a brief discussion on the importance of calibrating
flare flow meters is also discussed.
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Document ID:
4DD17BAB
OVERPRESSURE PROTECTION METHODS
Author(s): Jeff Hoffman
Abstract/Introduction:
Overpressure protective devices are of vital concern to the gas industry. Safety codes and current laws require their
installation each time a pressure reducing station is installed that supplies gas from any system to another system
with a lower maximum allowable operating pressure.
The purpose of this article is to provide a systematic review of the various methods of providing the overpressure
protection. Advantages and disadvantages of each method are evaluated, and engineering guidelines are provided.
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Document ID:
F54D79B5
Displacement Meters for Liquid Measurement
Author(s): Darren Heath
Abstract/Introduction:
This paper explores the strengths, weaknesses and inherent design principles that are relevant to positive
displacement meters. It will also highlight the parameters to be considered in order to provide accurate meter &
meter system selection.
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Document ID:
4619EC73
ODORIZATION IN NATURAL GAS
Author(s): Kris Kimmel
Abstract/Introduction:
It is generally accepted that natural gas has become a critically important energy source for the future. The abundance of natural gas, its favorable impact on the environment and its use across all sectors of the economy means natural gas will play an increasingly important role in meeting the global demand for energy. It is important to note a key driver for demand of natural gas has been and will continue to be public safety. Since natural gas has no color and rarely has a detectable odor, a mission critical process in delivering natural gas safely is a robust odorant injection program. In order to give this complex and challenging task some perspective, the United States has approximately 1200 Distribution companies with 1.2M miles of pipeline networks. The purpose of this paper will be to provide basic information regarding characteristics of chemical odorant, accepted methods of injecting odorant into natural gas pipelines, and detecting odorant in natural gas.
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Document ID:
B349AF60
MEASUREMENT OF PETROLEUM ON BOARD MARINE VESSELS
Author(s): Sandie Hughes
Abstract/Introduction:
The process that calculates the volume of liquid petroleum loaded onto, or received from, a ship or barge is
known as Custody Transfer Measurement. It is important to note that the custody transfer measurement is not
determined by a single measurement. A series of measurements are taken, tests are performed and calculations
are made before, during and after the transfer takes place in order to reach a Custody Transfer Measurement.
The transferred volume is usually determined by calculating the difference between the volume measured before
and after the transfer.
After gauging, sampling and temperature readings are taken ashore, on the vessel(s) or by a combination of the
two, volume quantities may be calculated. Shore volumes are the quantities measured on shore. The quantities
measured on the vessel are ship, barge or vessel volumes.
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Document ID:
6DD69E8E
INTERFACE DETECTION IN LIQUID PIPELINES
Author(s): Marc Buttler
Abstract/Introduction:
Ever since the first pipelines for crude oil were constructed in Pennsylvania in 1862, pipeline technology has continued to evolve to meet the ever increasing demand for more capacity to transport valuable crude oil and refined fuel products. The first trunk lines came soon after, in 1879, but it wasnt until 1943 when the first big-inch cross-country pipelines started to appear.
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Document ID:
AF4B4D43
Installation and Operation of Densitometers
Author(s): Paul A. Mullen
Abstract/Introduction:
This paper will cover the recommended installation and operation of densitometers in the petroleum
industry. The use of densitometers is widespread over many different industries. Densitometers are used
to monitor flowing density of non-custody transfers, fluid mixed interfaces, custody transfers and other
applications. We will be reviewing some of the standards for density measurement found in API
Standards Chapter 9.4 Continuous Density Measurement Under Dynamic (Flowing) Conditions.
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Document ID:
FD22F373
MEASUREMENT ACCURACY AND SOURCES OF ERROR IN TANK GAUGING
Author(s): Dan Comstock
Abstract/Introduction:
Upright cylindrical storage tanks are used not only to store liquid petroleum between custody transfers for inventory purposes, but to measure the quantities of those transfers. As in all measurements for custody transfer, it is essential to identify the sources of error in the measurement processes and to keep the impact of those sources to a minimum. The following items will be considered in this discussion: Tank Calibration Frequency Tank Capacity Table Tank Calibration Frequency Tank Conditions Tank Gauging Tank Temperature Tank Sampling and Testing Abridged Examples of Uncertainty
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Document ID:
82FBC4AF
FUNDAMENTALS OF GAS MEASUREMENT II
Author(s): Jerry Paul Smith
Abstract/Introduction:
A knowledge of the Fundamentals of Gas Measurement is essential for all technicians and engineers that are called
upon to perform gas volume calculations. These same people should have at least a working knowledge of the
fundamentals to perform their everyday jobs including equipment calibrations, specific gravity tests, collecting gas
samples, etc.
To understand the fundamentals, one must be familiar with the definitions of the terms that are used in day-to-day
gas measurement operations. They also must know how to convert some values from one quantity as measured
to another quantity that is called for in the various custody transfer agreements.
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Document ID:
9B32EE2D
TECHNIQUES OF COMPOSITE SAMPLING
Author(s): Marielle Verot
Abstract/Introduction:
In the always competitive natural gas market, producers are continually striving to maximize their market value, to achieve the highest return of invested income. The month to month and sometimes week to week fluctuations in pricing make this an increasingly important goal. One way to accomplish this goal is to ensure that you are receiving maximum value for the products produced. In addition to the producer, it is extremely important for all other stakeholders whether they be, gathering system operators, processors, or transporters to do their due diligence to ensure they are also receiving and/or properly accounting for the true and full value of the natural gas products that pass through their systems. Royalty rates, transportation levies and processing fees are based on the value of the natural gas being commercially bought and sold, processed, or transported. Sampling and analysis when properly implemented can ensure that everyones needs and product expectations are met. This paper will discuss issues that must be considered to obtain a good representative gas sample through continuous composite sampling.
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Document ID:
D6FC66BB
Crude Oil Gathering - Gauging Testing and Truck Measurement Alternatives
Author(s): John W Brackett
Abstract/Introduction:
Since ISHM was last held the world has seen tremendous change: we saw an entire planet stand still halting commerce and advancement in order to save lives. The great shuttering of the planet in 2020 and the pandemic that followed proved to us all that, like death and taxes, change is inevitable. While the pandemic is not the catalyst for change in methods for gathering crude by truck, it is the fuel for an already smoldering fire. The world of lease tank measurement must learn to adapt to the rapid changes brought on by the pandemic.
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Document ID:
C7C5DE86
CERTIFICATION and PERFORMANCE TESTING of AUTOMATIC SAMPLERS
Author(s): James M. Strawn
Abstract/Introduction:
Automatic sampling systems should be tested and certified according to the American Petroleum Institute (AP)
Manual of Petroleum Measurement Standards (MPMS), Chapter 8, Section 2, and the sample container/mixing
system according to API 8.3. The complete system should be tested once it is installed in the field, under field
operating conditions. Once certified, the system performance should be continually monitored and recorded to
ensure the system is producing representative samples.
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Document ID:
09AC8066
Wet Gas Measurement
Author(s): Philip A. Lawrence
Abstract/Introduction:
Wet gas measurement is becoming widely used in the modern oil and gas market place. The effect of entrained liquid
in gas and its impact on measurement systems has been researched world-wide by various laboratories and JIP
working groups. The impact can be very significant financially and importance in the subject has grown over the years.
The subject matter is quite large and encompasses many different concepts, meter types and opinions, with many
new ideas being brought to the forefront each year as more research and flow meter development occurs. From
upstream applications to midstream measurement issues caused by liquid drop out in the pipelines were gas
gathering systems are used. The issue of entrained gas is becoming a big issue. Small quantities of hydrocarbon
liquid in a gas sample stream can have a large impact on the BTU value analysis and cause large losses or gains
depending on which side of the fence you are together seen with the errors seen using single phase meters in
combination to measure gas with liquid entrainment, flow measurement results can be difficult to manage.
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Document ID:
CC6170B7
Selection, Sizing and Operation of Control Valves for Gases and Liquids
Author(s): Mike Stinn
Abstract/Introduction:
The Instrumentation, Systems, and Automation (ISA) Society defines a control valve as a power operated device that modulates the fluid flow rate in a process control system. Process plants contain control loops to help a certain variable or set of variables reach a desired set point. These loops consist of sensors, transmitters, and process controllers that receive the information and calculate necessary action to achieve a set point upon system disturbance. The control valve is one of the most common final control elements that the process controller manages to maintain the set point. A properly sized and selected control valve will be able to keep the process variable as close as possible to the set point, making the control valve a crucial part of the process.
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Document ID:
23E78FE8
BASICS OF GAS ULTRASONIC METER DIAGNOSTICS
Author(s): John Lansing
Abstract/Introduction:
This paper discusses basic diagnostic features of gas ultrasonic meters (USM), and how capabilities built into todays electronics can identify problems that may have gone undetected in the past. It primarily discusses fiscal- quality, multi-path USMs and does not cover issues that may be different with non-fiscal meters as they are often single path designs. Although USMs basically work the same, the diagnostics for each manufacturer does vary. All brands provide basic features as discussed in AGA 9 Ref 1. However, some provide more advanced features that can be used to help identify issues such as blocked flow conditioners and gas compositional errors. This paper focuses on the Westinghouse and British Gas configurations (both being chordal designs) and the information presented here may or may not be applicable to other path designs.
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Document ID:
8ABB4A2E
VERIFICATION/CERTIFICATION OF DEVICES USED IN LIQUID MEASUREMENT
Author(s): Anne Walker Brackett, Ph.D.
Abstract/Introduction:
In the past the standards from the American Petroleum Institute (API) and the American Society for Testing and Measurement (ASTM) provided specifications for instruments and equipment. Simple compliance with these standards was not enough. Therefore, a system of verification and/or certification of equipment used in measurement of liquids was instituted. These requirements were written into the standards as they came up for review. An excellent example of such a standard is Chapter 3.1.A. Standard Practice for the Manual Gauging of Petroleum and Petroleum Products of the APIs Manual of Petroleum Measurement. 3.1.A. calls for field verification of working tapes against against a National Institute of Standards and Technology traceable master tape when it is new and every year thereafter. This is an example of the requirements to ensure the instrument and the equipment meets the specifications of each standard. It is important to understand the definitions of traceability, verification, and certification before discussing the specifications for equipment used in liquid measurement.
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Document ID:
2C2D2B89
Effective Use of Deadweight Testers
Author(s): John A. Kappes
Abstract/Introduction:
With the now common use of higher accuracy digital sensors, one of the most critical problems facing
measurement managers is the accurate calibration of pressure or differential pressure (DP) measuring
instruments. The deadweight gauge or tester is an economical answer to many of these problems, as a
deadweight is a primary standard with accuracy expressed in percent of reading.
The instrument engineer will typically specify the type of deadweight tester required for the application and
the technician will use the standard. For both parties, it is essential to understand certain aspects of
deadweight operations, concepts related to the design and functionality, and the best use practices for
these instruments.
This paper describes the scientific and engineering concepts related to, and methods used to select
deadweight testers and gauges. Also included are procedures for using hydraulic and pneumatic
deadweight testers.
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Document ID:
1CAAC578
LPG TERMINAL OPERATIONS AND MEASUREMENT
Author(s): Zaki Husain
Abstract/Introduction:
In the oil and gas industry, the commercial viability of a product depends on economic considerations of marketability of the product. The marketable products can be naturally occurring or is often a byproduct of refining and/or chemical process. Marketability of a product is impacted by cost of processing, handing, transportation, dispensing, safety precautions, storage, quality control, etc. If a product is deemed commercially unmarketable, it is often disposed, internally used for heat generation, or flared. Liquefied Petroleum Gas (LPG) is one of those hydrocarbon liquids that pose very complex difficulties in storage, handling, and measurement accuracy. Hence, historically LPG byproduct was treated as a nuisance by many companies in the petroleum industry and was disposed, burned as plants internal heating fuel, or flared. With increasing production of natural gas and demand and cost of energy resources, the marketability of LPG has become an economically viable commodity. With increasing cost versus profitability of the petroleum industry and expanding demand for energy, there are consorted efforts to market LPG and overcome the known difficulties of storage, transportation, safety issues, handling, and accurately measure the LPG products.
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Document ID:
4BA0C41E
LEAK DETECTION ON PETROLEUM PIPELINES
Author(s): Peter Han
Abstract/Introduction:
Pipelines have transported water, oil and gas for hundreds of years, serving residential communities, industrial sites
and commercial centers reliably and silently. Leak detection systems (LDS) are needed because pipeline spills
occur more frequently as infrastructure ages and more hazardous products are transported. Leak detection systems
cannot prevent leaks, but they can certainly help minimize the consequence of leak. Regrettably, too many leak
detection systems fail to detect leaks, and other leak detection systems are ignored by the operators because they
are unreliable. Thus, leaks that should have been small spills become disasters that cost pipeline owners millions
of dollars.
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Document ID:
1068467A
FUNDAMENTALS OF LIQUID MEASUREMENT III - DYNAMIC
Author(s): Peter W Kosewicz
Abstract/Introduction:
Weve learned when measuring crude oil or any hydrocarbon that liquids expand and contract with increases and decreases in temperature. The liquid volume also decreases when pressure is applied. All these effects are part of the physical properties of liquid petroleum fluids. In addition to the effects of temperature and pressure on the liquid and their indicated volume, the container in which the liquid is measured also changes the volume it contains at different temperature and pressures. These changes must also be accounted for in determining the true volume being transferred. We learned in Fundamentals of Liquid Measurement I how these physical properties effect the measurement of liquid hydrocarbons. The objective of either static measurement or dynamic measurements is to determine the quantity and quality of hydrocarbons transferred. However these measurements are rarely performed at the standard conditions discussed in Fundamentals I, therefore not only must temperature be measured, but also density, sediment and water, vapor pressure, flowing pressure and viscosity must be measured. With these measurements correction factors such as Volume Correction Factors (VCF) can be determined to allow volumes determined at operating conditions to be expressed at standard reference conditions.
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Document ID:
2A9B5DCC
RESOLVING LIQUID MEASUREMENT DIFFERENCES
Author(s): Rex Mitchener
Abstract/Introduction:
All liquid measurement has uncertainty in the resulting measured value, having differences between the results of
two meters measuring the same quantity. Be concerned if two measurements match exactly.
Assessing and resolving measurement differences is why we need to understand the reasons that measurement
differences exist and create a process to determine if there is a reasonable concern they are not within established
limits.
This class discusses the physical transfer of a liquid quantity moved through a meter or moved into or out of a tank
and reviews methods for correcting discrepancies of custody transfer liquid measurement between contract parties
that are relevant to meter-to-meter, tank-to-tank and meter-to-tank measurements.
Each quantity represents a monetary value and often one party to a transaction receives a payment from the other
party for that measured quantity. That measurement is typically referred to as the custody transfer quantity.
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Document ID:
E87B33E1
BTU DETERMINATION OF NATURAL GAS USING A PORTABLE CHROMATOGRAPH
Author(s): Caleb Northington
Abstract/Introduction:
Determining the analysis and its BTU of natural gas via a portable gas chromatograph is widely used and an industry
accepted standard. A sample of natural gas and its BTU content can vary greatly depending on where and how a
natural gas sample is acquired. When sampling and determining the analysis and BTU of natural gas with a portable
gas chromatograph, there are inherent risks that could impact the correct determination of the analysis and the
BTU. If an analysis and its BTU are not correct, the financial impact could be tremendous. The following discussion
is mainly focused towards field level personnel and helping to mitigate common mistakes when determining BTU in
the field.
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Document ID:
8095AFDC
Hydrocarbon Dew Point Effect on Gas Flow Measurement
Author(s): Sohrab Zarrabian
Abstract/Introduction:
The presence of liquids in pipelines creates many operational and financial issues. Liquids are created in
pipelines when the gas crosses the phase boundary. This crossing can be caused by lowering of temperature,
increase of pressure, or decrease of pressure. Hydrocarbon Dew Point (HCDP) is the temperature at which
hydrocarbons begin to condense in a natural gas stream, at a given pressure. It is not to be confused with Water
Dew Point (WDP) which is the temperature at which water condenses out, at a given pressure. Both HCDP and
WDP are important gas properties that need to be measured and monitored throughout gas processing and
transport operations. In this paper, we concentrate on HCDP.
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Document ID:
697BDCE3
VOLUMETRIC MEASUREMENT OF LIQUEFIED PETROLEUM GASES
Author(s): Chris Bollich
Abstract/Introduction:
Liquefied Petroleum Gas (LPG) is defined as butane, propane or other light ends separated from natural gas or crude oil by fractionation or other processes. At atmospheric pressure, LPGs revert to the gaseous state. Included in this paper will be information for turbine, coriolis and positive displacement meters used in volumetric measurement systems. The basic calculations and industry standards covering volumetric measurement will also be covered.
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Document ID:
20534A83
MEASUREMENT AND REGULATION OPERATION OF AN LDC
Author(s): John ONeal
Abstract/Introduction:
At approximately 3 AM on a cold icy night, your phone rings. It is Paul from pressure control. John, we are losing pressure at Paradise City Gate and I cannot get the regulators to respond. The low point is showing five pounds. How fast can you get there? As you bail out of bed grabbing your clothes, you respond, I am on my way! Or you get a call from Sue in your gas billing department, John, the ACME Manufacturing Company has a problem with their bill. It is 3 MMCF more than what they used this time last year. Can you go check on this? Yes maam. I am on my way! Or you get an email from George in your Lost and Unaccounted for Gas department stating that Walsh City Gate shows 10% less gas than what we showed on our meters in the town. Can you please check out this meter? You reply that you are on your way!
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Document ID:
55E08441
MEASUREMENT ECONOMICS
Author(s): David Wofford
Abstract/Introduction:
Before we get waist deep into science and technology and economics and variability in return rates based upon the intransient effects of Federal Reserve interest rate and debt management policy on petroleum commodity markets and related no-fault based derivative securities: A neutron walks into a bar and orders a drink. What do I owe you? the neutron asks the bartender. For you? No charge! An electron sitting at the other end of the bar jumps up with outrage and yells at the bartender . Why does he drink for free and I have to pay? Because youre always so negative! barks the bartender. The electron turns to the attractive proton sitting next to him and asks . Am I really negative? Yes said the proton. Are you sure? Im absolutely positive!
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Document ID:
5EBD2741
Fundamentals of Liquid Measurement
Author(s): David Beitel
Abstract/Introduction:
Correct measurement practices are established to minimize uncertainty in the determination of the custody transfer volume (or mass) of products. Understanding and evaluation of the fundamental cause and effect relationships with the liquid to be measured will lead to a volume determination that most closely matches the true volume at the referenced standard pressure and temperature. When designing a new measurement station it is up to us as measurement people, to understand the product to be measured, apply the correct equipment, and implement the appropriate correction equations. Proper procedures could implement this process:
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Document ID:
F2548442
ENERGY MEASUREMENT USING FLOW COMPUTERS AND CHROMATOGRAPHY
Author(s): Cody Winberg
Abstract/Introduction:
The energy business environment is ever-changing to include faster and more reliable information to determine and attain measured fluid quantities between various parties. System balances, contractual agreements, and settlements are vital factors to the success of companies. The use of flow computers is becoming industry and API standards across the business. To accomplish these standards Primary Flow Meters, Secondary Devices, Electronic Flow Meters (EFM), and Gas Chromatographs are utilized. Combining these elements allow for critical information to be obtained, historized, and processed with minimal manual input from analysts or operators.
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Document ID:
A80D2664
TRANSIENT LIGHTNING PROTECTION FOR ELECTRONIC MEASUREMENT DEVICES
Author(s): Laura Gonzalez, Tony Hollimam
Abstract/Introduction:
Transients are momentary changes in voltage that occur over a short period of time in a system. Transients
negatively affect electrical equipment and are introduced into a system in a variety of ways. Transient occurrences
cannot be completely avoided but there are ways to minimize their effects. Common threats include electrostatic
discharge (ESD), cable discharge (CDE), electrical fast transients (EFT) and lightning surges in the environment.
It is important to protect equipment from transients because prolonged exposure can lead to damaged equipment,
loss of or incorrect data, operating failures and other safety concerns. Lightning surges are the easiest type of
transient exposure to trace but lower energy transients are more frequent and harder to spot.
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Document ID:
65F98965
SCADA AND FIELD DATA CAPTURE IN THE CLOUD
Author(s): Shawn Cutter
Abstract/Introduction:
In our currently volatile commodity market, data is the new economy. It is used to drive the creation of
information and value across every industry. In the world of hydrocarbons, the necessity of tangible
things like drill bits and tubulars have long been understood but possessing the right information at the
right time is the latest intangible invaluable asset needed. Information technology has enabled oil and
gas companies to eliminate countless man hours and improve efficiencies throughout the hydrocarbon
value chain. Data now flows in real time from the field to backend reporting systems where it is
transformed into actionable information, delivering value to internal and external users alike.
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Document ID:
5B97F623
MARINE CRUDE OIL TERMINAL MEASUREMENT SYSTEMS
Author(s): James Bares
Abstract/Introduction:
Crude oil terminals are an integral part in our industry for many years now. In prior years, we were in need of several millions of barrels of crude oil per day to feed the refineries the raw material from which diesel, gasoline, and many other products in high demand. With our ever changing world and the areas that crude oils are being found, we now are seeing many of these oils exported instead of imported. The most economical means of getting these crudes to the different continental markets is by way of shipping transportation. This needs to be done quickly, and more important- ACCURATELY! There are several parties that take great interest when dealing with crude oil. They include the owner, terminal, U.S. customs, vessel owners, independent section companies, and the buyers. Along with these interests, there are legal and contractual requirements, and measurements that must meet custody transfer requirements. The measurement requirements are generally covered by the American Petroleum Institutes (API) Manual of Petroleum Measurement Standards (MPMS).
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Document ID:
F7FC4B14
EFFECTS OF ABNORMAL CONDITIONS ON ACCURACY OF ORIFICE MEASUREMENT
Author(s): Dean Graves
Abstract/Introduction:
Whenever one focuses on gas or fluid measurement, he or she will eventually discover an abnormal condition at a measurement station. Invariably someone will ask, What effect will it have on measurement? A student of measurement may spend years answering this question. This and similar questions have generated many research studies. This research has enabled us to better understand measurement abnormalities and to improve measurement procedures and standards. Even though we have made great strides in measurement, we will continue to ask this question.
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Document ID:
399E01CD
Proving Liquid Meters with Microprocessor Based Pulse Outputs
Author(s): Galen Cotton
Abstract/Introduction:
The advent of microprocessor driven flow meters in the late 1960s and early 1970s was heralded as a new frontier in flow measurement. Little did we anticipate the unintended consequence of adopting these new technologies, or how our conventional verification techniques would be challenged? We are still playing catch-up in the realm of flow meter verification where manufactured or, computationally derived flow meter pulse outputs, are concerned.
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Document ID:
359A7A95
MEASUREMENT MANAGEMENT SYSTEMS
Author(s): Duane Harris
Abstract/Introduction:
Today the measurement system provides the critical layer of measurement data integrity required
to meet the overall measurement accuracy for an organization due to its direct impact on the
bottom line. In addition, measurement management systems ensure compliance with both
regulatory and industry requirements. The integrity of measurement data begins at the primary
device in the field and continues through to the validation of all data received and processed by
the measurement group.
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Document ID:
0D6F5823
CHROMATOGRAPHIC ANALYSIS OF NATURAL GAS LIQUIDS
Author(s): Darville Dee Orr Jr.
Abstract/Introduction:
The analysis of natural gas liquids has become an integral part of the oil and gas industry. The analytical results from these analysis are used by measurement departments, operational department to meet product specifications, and engineering departments for the design of processing equipment. Two methods that are commonly used in the gas industry to provide this analytical data are the GPA Standard 2177, Analysis of Natural Gas Liquid Mixtures Containing Nitrogen and Carbon Dioxide by Gas Chromatography and the GPA Standard 2186, Method for the Extended Analysis of Hydrocarbon Liquid Mixtures Containing Nitrogen and Carbon Dioxide by Temperature Programmed Gas Chromatography. The purpose of this paper is to provide an overview of the standards and the steps needed to obtain accurate results.
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Document ID:
0A0C6562
MASS METERS FOR GAS MEASUREMENT
Author(s): Marc Buttler
Abstract/Introduction:
Since the early 1977, Coriolis meters have gained worldwide acceptance in gas, liquid, and slurry applications
with an installed base of well over a million units. Since the early 1990s Coriolis meters have rapidly gained
acceptance in gas applications with over 100,000 meters installed worldwide.
Principal gas applications for Coriolis meters include fiscal transfer of valuable process gases such as ethylene,
oxygen, and hydrogen, utility gases such as natural gas, and reactor feed gases such as hydrogen, ethylene,
ammonia, and chlorine. Coriolis meters offer improved measurement accuracy over wide turndowns and with
less installed uncertainty due to swirl and flow profile effects.
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Document ID:
4B837017
AUDITING LIQUID MEASUREMENT
Author(s): Jennifer Merkins
Abstract/Introduction:
In the current environment of lack of resources and lack of training for personnel, now more than ever is the
importance of auditing to protect your companies interest most important. How do you approach the objective and
what are the necessary tools and training needed to perform a liquid measurement audit? Prioritizing what type of
audit, you will conduct for what product is a good starting place. Where is the biggest financial risk and make a
plan.
This paper will encompass the reviewing of the processes, procedures and the documentation that make a
defensible audit trail of all the components required.
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Document ID:
D224BBF7
THERMOMETRY IN GAS MEASUREMENT
Author(s): Stephen T. (Steve) Stark
Abstract/Introduction:
Measured several times between the wellhead and its final point of consumption, natural gas temperature is
dynamic, meaning that temperature changes constantly. Gas molecules heat up when packed tightly together,
such as when they undergo compression, and they cool off as they expand, such as after flowing through a
regulator or other restriction. Natural gas temperature is also affected by the temperature of the pipe through
which it flows.
The measurement of gas temperature contributes directly to measurement precision. The greater the
temperature measurement error, the higher the overall measurement uncertainty becomes. Even relatively small
temperature measurement errors can have a large impact on the bottom line.
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Document ID:
B89363C8
LIQUID TANK LEVEL - INTERFACE MEASUREMENT
Author(s): Lydia Miller
Abstract/Introduction:
In the hydrocarbon processing industry, often there are situations where there is more than one type of liquid in the same vessel or process stream. In the upstream part of the process, generally you are working to separate the different liquids and in the downstream part of the process you are mixing them together. When you are working to separate the different liquid types, one method is to us a separator. Separators can be used when there is a density difference between the liquids and they are immiscible, meaning they would naturally form distinct layer if left alone. A key part of this process is getting the liquids to efficiently form into layers so you can draw off one of the liquids. But equally important is being able to measure the interface - or the place where two different liquids meet - in order to draw off only one liquid.
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Document ID:
01616845
PREPARING A PROVER FOR A WATER DRAW CALIBRATION
Author(s): Patrick J. Rowell
Abstract/Introduction:
The key to a successful calibration of a prover by the water draw method is thorough planning and organization followed by
good execution of the plan. The primary goal is to get the prover as clean as possible and perform any replacements and
maintenance needed prior to the arrival of the Calibration Company. This paper is intended to assist you attain an accurate
calibration by presenting some things to consider for the planning, organization and execution phases.
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Document ID:
E6E8388B
Natural Gas Analysis by Gas Chromatograph
Author(s): Seth Nease
Abstract/Introduction:
The most equitable means of exchange of Natural Gas and Natural Gas Liquid products is by the
measure of their energy. In order to determine the energy of the product, the individual
components within the product must be measured. The most common and accepted means of
measuring the amounts of each component within a Natural Gas or Natural Gas Liquid sample is
by the use of a gas chromatograph (GC). The following is a description of basic GC operation
for energy determination.
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Document ID:
3F6998BD
FUNDAMENTALS OF LIQUID MEASUREMENT II - STATIC MEASUREMENT
Author(s): MARTIN R. DUDLEY
Abstract/Introduction:
Hydrocarbon fluid measurement is primarily achieved by two methods, dynamic measurement or static measurement. Dynamic measurement is a methodology where the fluid is measured while in motion. Static measurement is its opposite and refers to a fluid measured at rest, motionless. The oil and gas industry utilizes both methods under conditions that meet the requirements for custody transfer to perform accurate, precise measurement for their companies. It is paramount that professionals in industry understand the intricacies of both dynamic and static measurement in order to protect their governing assets and the integrity of the industry. This paper will discuss the API Standards, ASTM Standards, and best work practices associated with a wide range of static measurement principles in the hope that it expands the knowledge of professionals within our field.
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Document ID:
6914CD51
FUNDAMENTALS OF LIQUID MEASUREMENT II - STATIC MEASUREMENT
Author(s): MARTIN R. DUDLEY
Abstract/Introduction:
Hydrocarbon fluid measurement is primarily achieved by two methods, dynamic measurement or static measurement. Dynamic measurement is a methodology where the fluid is measured while in motion. Static measurement is its opposite and refers to a fluid measured at rest, motionless. The oil and gas industry utilizes both methods under conditions that meet the requirements for custody transfer to perform accurate, precise measurement for their companies. It is paramount that professionals in industry understand the intricacies of both dynamic and static measurement in order to protect their governing assets and the integrity of the industry. This paper will discuss the API Standards, ASTM Standards, and best work practices associated with a wide range of static measurement principles in the hope that it expands the knowledge of professionals within our field.
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Document ID:
21747DEC
Techniques of Gas Spot Sampling
Author(s): Matthew S. Parrott
Abstract/Introduction:
While inaccuracies in measurement can be costly and common, they are also avoidable in most cases. Technicians willing to study the experiences and best practices of industry leaders can make a world of difference by applying what theyve learned and sharing the knowledge shared in this paper with others. This paper aims to describe spot sampling as defined by industry standards, and discuss important factors that may impact accuracy when taking a spot sample.
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Document ID:
DCD062AD
Design Considerations for Analyzer Enclosure Systems
Author(s): David Beitel
Abstract/Introduction:
Instrument shelters are a necessity. In the Rocky Mountain Region, the decision to provide an Instrument Shelter is not something that is usually debated. The real issue is how sophisticated (read Expensive) they need to be and what should go into them. The decision as to what goes into a Shelter for a project engineer can be a delicate balancing act. Depending on the various adders the cost of a shelter can become quite expensive. When we talk about Instrument Shelters, two general categories are relevant: Buildings that house Meters, and Buildings that house Quality Instrumentation- Chromatographs, Water Monitors, H2S Analyzers, and Oxygen Analyzers.
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Document ID:
FA49EC23
Proper Handling & Maintenance of Natural Gas Calibration Cylinders
Author(s): Richard Rayon
Abstract/Introduction:
In todays market, with accounting and other regulations being tougher and with higher restrictions dealing with safety, knowing how to properly handle calibration standards and the cylinders they come in should be and needs to be a high priority. The equipment being used in the field (plant, laboratory, and pipeline) is more advanced than even ten years ago. There are DOT regulations and company policies that need to be followed to ensure accurate use of the standard and safety in the use and transportation of all cylinders. The results of the analytical measurement and the use of the calibration cylinders go hand-in-hand with each other. Calibration standards should be made with the highest quality roducts and with the most accurate measurements. Not knowing about the calibration cylinders could affect the Calibration Standard.
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Document ID:
D52CEA4F
LIQUID METER PROVING TECHNIQUES
Author(s): Jerry Upton
Abstract/Introduction:
A meter is only an indication of flow unless it is proved. That sounds like a bold statement. But it is true. A lot of people think that a meter always gives you the right answer. They are ignorant of the facts. A meters ability to be right is a function of its traceability to a National Metrology Institute or NMI. You are probably thinking what in the world is that and what does it have to do with a meter. Well, the oil industry has agreed to make all Custody Transfer measurements directly traceable to something that everyone has faith in. And, that is an NMI. The NMI in the United States is the National Institute of Standards and Technology or NIST. That is where all the standards for the United States are kept.
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Document ID:
13BF4C72
Loading of Crude into Rail Tank Cars
Author(s): Martin Dudley
Abstract/Introduction:
Railcar Operations, at times, seems to be an enigma within the oil & gas supply chain. Often when
professionals seek out recommended practices and/or guidelines specific for rail application they find the
solution is using adjacent references or indirect applicable recommended practices and/or guidelines.
This paper will highlight an operational overview of loading crude oil into railcars, commonly referenced
standards/recommended practices, and common transfer operations within the oil & gas industry. This
course was created to help industry professionals navigate the complexity and convolution of rail loading
operations and how it relates to metrology.
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Document ID:
F2BD2B9D
Effects of Atmospheric Pressure on Gas Measurement
Author(s): Ian Borton
Abstract/Introduction:
Atmospheric pressure is the force created by
the column of atmosphere directly above an
object. Gravity pulls on the atmosphere giving
it a weight.
The atmospheric pressure at sea level is 14.696
psia, while the atmospheric pressure on the top
of Mount Everest is 4.888 psia, while in outer
space there is no atmospheric pressure.
Understanding the pressure readings, the
elevation, and ambient conditions can help
avoid gas measurement errors caused by
misunderstanding of atmospheric pressure.
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Document ID:
9101B4E6
USING CONTROL CHARTS TO PREDICT FAILURES OF MEASUREMENT DEVICES
Author(s): ZAKI HUSAIN
Abstract/Introduction:
Control Chart of a flow metering device is the historical documentation of the performance of the meter. Control
chart of a flowmeters is typically the Meter Factor (MF) of the flowmeter plotted or tabulated in a chronological
order. Figure 1 is an example of the control chart of a flowmeter that was installed to monitor flowrate for a
process control application of a flowing fluid at different operating flowrates and temperatures and the flowmeter
was calibrated once a week. The flowrate during proving of the meter varied over the range of 62 to 85 percent of
the maximum flow rate range of the meter, while the fluid temperature varied between 55 and 83 degrees
Fahrenheit. The desired measurement uncertainty for the process control was +/-0.05%. Although the baseline
calibration plotted data of the flowmeter indicated some variations in meter factor from week to week,
performance of the meter was within the acceptable limits of the process application.
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Document ID:
92FD0AD6
EVAPORATION LOSS MEASUREMENT FROM STORAGE TANKS
Author(s): Andrew Yearwood
Abstract/Introduction:
The American Petroleum Institute Committee for Evaporation Loss Estimation (API CELE) operates under the Committee on Petroleum Measurement to perform research and produce the Manual of Petroleum Measurement Standards (MPMS), Chapter 19. API CELE is composed of Petroleum Company Representatives, Equipment and Instrumentation Manufacturers, Consultants, Energy Institute (Europe) and is attended by the US EPA and State Air/Emission Regulators. The current Chair is Shankar Ananthakrishna of Chevron Energy Technology Company. The current API Staff person is Sally Goodson. API CELE is responsible for determining evaporation losses (emissions inventory) from storage tanks, vessels and transfer operations (loading racks / berths). The API MPMS Chapter 19 Standards are adopted by US EPA (Standard AP-42) to determine Emission Inventory and widely used by petroleum industry and regulators in US, Europe, and other regions of the world.
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Document ID:
A94B551A
THE UNCERTAINTY OF A WATERDRAW CALIBRATION vs. GRAVIMETRIC CALIBRATION
ON SMALL VOLUME PROVERS
Author(s): James E. Gallagher
Abstract/Introduction:
This paper presents the Base Prover Volume (BPV) uncertainty using the waterdraw volumetric method versus the
waterdraw gravimetric method for small volume provers.
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Document ID:
F193DEC4
CONVENTIONAL MEASUREMENT IN UNCONVENTIONAL PLAYS
Author(s): Stephen C. Anson
Abstract/Introduction:
Advances in hydraulic fracturing technology have allowed access to, and the development of, shale formations
previously considered to be uneconomical (API, 2014). This access and development has led to increased
production of oil and natural gas within the United States. As these discoveries and developments grow, so does
the need to rethink how this production is harvested, gathered and transported. Several factors are changing the
way we have conventionally produced, measured and sold our crude oil and natural gas in these unconventional
plays which is why we must begin to evaluate the need for changes to our conventional tactics.
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Document ID:
F29B02E5
MANUFACTURED METER PULSES - AN EXPLANATION
Author(s): Robert Fritz
Abstract/Introduction:
The electronic interface between flow meters and flow computers takes a couple of different forms (i.e. a current loop proportional to flow rate, a voltage loop proportional flow rate, or electronic pulses representing a volume). For the remainder of this paper we are going consider only the electronic pulse interface. These electronic pulses are typically generated by a change in voltage and take the form of a square wave similar to those shown in Figure 1.
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Document ID:
DB81237B
GAS METER SELECTION
Author(s): Robert Fritz
Abstract/Introduction:
This paper is intended to provide general guidelines & criteria for the evaluation & selection of a high pressure gas meter, including a discussion of the basic operating principles and installation and maintenance considerations. This paper will concentrate primarily on four high pressure/high volume custody transfer flow meters, Orifice, Ultrasonic, Coriolis and Turbine. A short discussion will be provided for other alternative types of flow meters and different gas stream conditions. When selecting a gas flow meter for particular application remember that there is no one Panacea for flow measurement. No one meter is the right choice for all applications.
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Document ID:
B3BE9B1C
PID Control Implementation in Electronic Flow Computers
Author(s): Rick Kroeker
Abstract/Introduction:
Electronic Flow Computers (EFC) often function as flow and/or pressure controllers on pipeline systems. Because the EFC calculates the flow and can accept pressure signals, it is an obvious choice to also perform the control function. The process control algorithm that is embedded in the EFC firmware is some version of a Proportional/Integral/Derivative (PID) controller. This PID controller must be tuned to the process in order to provide stable, accurate and robust control. To be effective in setting up and tuning a control loop the following must be understood.
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Document ID:
808D75DC