Test & measurement


Improved measurement of water content in natural gas


Contaminants in natural gas can cause a variety of problems for pipeline operators and petrochemical plants, especially when combined with water. This makes accurate and reliable measurement of water content in natural gas streams critical, but traditional techniques often fall short. Fortunately, new analysers offer much improved performance, as Sam Miller, head of Technical Marketing, TDLAS/QF, Endress+Hauser Optical Analysis, explains...


N


atural gas composition is controlled to some extent. Wherever natural gas is traded commercially, there are regulations as to its chemical


content and attributes such as calorific value. Local specifications and ranges vary, but typically there are limits for total sulfur, hydrogen sulfide (H2S), carbon dioxide (CO2), oxygen (O2), and


water (H2O). All of them are considered contaminants. Sulfur and its many compounds


represent the most widely encountered contaminants in all fossil fuels and are known for their toxicity and pollutants. Oxygen degrades amine and some mercaptans which are used in


natural gas treatment and CO2 dilutes the overall heat value. The greater problem results when these contaminants combine with another: water. All of them work together with water to produce acids capable of attacking carbon steel piping, valves, and other equipment to cause internal corrosion and metal loss over time. Natural gas pipelines can corrode from the outside and inside, but internal metal loss is more difficult to recognise and measure. If the water condenses, it


Continued on page 66...


Since natural gas can stem from a variety of sources (fossil- based, renewable), the composition and attributes vary.


Instrumentation Monthly April 2022 65


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