Entity

Time filter

Source Type

United States

Herring J.,Michell Instruments Inc.
GPA Annual Convention Proceedings | Year: 2011

A discussion covers the major factors that contribute to best practices for measuring the hydrocarbon dew point in natural gas; most popular methods for measuring this parameter, i.e., manual visual method with a chilled mirror dew point instrument, EOS calculations from analysis by chromatography, and automatic optical dew point instrument; pros and cons for each technique; "Best Practices" for making this critical measurement using any of the techniques; and quantifiable financial impact of this measurement. This is an abstract of a paper presented at the 90th Annual Convention of the GPA (San Antonio, TX 4/3-6/2011). Source


Herring J.,Michell Instruments Inc.
Proceedings of the American Gas Association, Operating Section | Year: 2012

Hydrocarbon dew point is dependent on pressure, temperature, and the composition of the gas. Installed cost is an important consideration in the choice of methods used to measure hydrocarbon dew point. An inaccurate instrument choice can also add to the already high parasitic load by over-reporting the dew point temperature which would drive the control system to heat the incoming gas more than necessary. Reliable instrumentation producing an accurate measurement assists in controlling the costs of operating a gas processing plant, a pipeline or turbine compressors/generators and protecting these assets. The costs, risks, and major factors that contribute to best practices for measuring the hydrocarbon dew point of the natural gas fuel are discussed. This is an abstract of a paper presented at the 2012 AGA Operations Conference (San Francisco, CA 5/1-4/2012). Source


Herring J.,Michell Instruments Inc.
86th Annual International School of Hydrocarbon Measurement 2011 | Year: 2011

The focus of this paper is to identify the major factors that contribute to best practices for measuring the hydrocarbon dew point (HCDP) in natural gas. The three most popular methods for measuring this parameter will be discussed. These three techniques are: • Manual visual method with a chilled mirror dew point instrument • Equation of state calculations from analysis by chromatography. • Automatic optical dew point instrument. Pros and cons for each technique will be listed that will provide a basis for comparing these three methods of measurement for this important parameter. The "Best Practices" for making this critical measurement using any of the techniques above will be discussed. The quantifiable financial impact of this measurement will be shown. Source


Scelzo M.,Michell Instruments Inc. | Herring J.,Michell Instruments Inc.
ACS National Meeting Book of Abstracts | Year: 2011

In many petrochemical processes unwanted moisture has serious detrimental effects on plant operation and production efficiency. Catalytic processes often rely on trace moisture levels being continuously controlled below a strict threshold to avoid costly poisoning of the catalyst. Excessive moisture in hydrocarbon feedstocks produces unwanted reactions such as acid formation. Moisture in solvents used in polymer production results in adverse changes in fluid viscosity and drying times. In liquid fuels such as diesel, kerosene and LPG, the presence of moisture is an undesirable contaminant that can separate to form liquid water or ice if not restricted to low concentrations. In this paper, two case studies illustrate 'Best Practices' for successful moisture measurement in liquid hydrocarbons. These techniques significantly enhance catalyst life and reduce downtime while maximizing production efficiencies by avoiding undesired reactions and catalyst deactivation. The theory of continuous, on-line moisture measurement in hydrocarbon liquids is also discussed in detail. Source


Stokes A.M.V.,Michell Instruments Inc. | Price A.J.,Michell Instruments Inc. | Summers M.D.,Michell Instruments Inc.
Proceedings of the American Gas Association, Operating Section | Year: 2014

This paper will present recent developments in the field of TDLAS based moisture measurement techniques that are advantageous for field instrumentation and allow such analyzers to meet both the present natural gas processing markets needs, and the future challenges in this sector that result from the increasing proportion of shale gas entering the transmission system. Test data are presented illustrating the performance of such an analyzer covering natural gas compositions illustrative of the variations that are known to occur dynamically in natural gas derived from conventional and unconventional sources. Source

Discover hidden collaborations