Natural Gas Energy Measurement by A. Attari, D.L. Klass

By A. Attari, D.L. Klass

Papers awarded on the First and moment IGT Symposium, Chicago, IL, united states, 26-28 August 1985 and 30 April-2 may perhaps 1986.

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2% difference. As we all know, temperature changes occur all along in a pipe line for various reasons. If a gas is not allowed to drop below the dew point temperature, no fall out will occur, but if it drops below the dew point, water will condense. For this reason pipelines should have a minimum temperature that they can operate at. The main equations used at present are as follows: 1. 2130 2. 0181 cu ft. Therefore utilizing the standard manner of stating water content used by the gas industry then 3.

Table 2 lists the compositions and heating values of several mixtures which were considered for these standards. Figure 2 illustrates the SRK. dew point vs pressure curves for these mixtures. It can be seen that, while the 812 Btu/SCF gas (mixture B) has a dew point temperature of −144°F, the 1261 Btu/SCF gas (mixture 5) approaches the −5°F dew point region. Thus the mixture represented by curve “C”, a 75% methane, 25% ethane blend with a heating value of 1185 Btu/SCF was chosen to be as near 1200 Btu/SCF as possible and yet maintain a reasonably low dew point temperature of −26°F/.

Under these conditions, the volume calculation can be factored to give a monthly average pressure and temperature, thus making correction easy. So far, the methods discussed have utilized volume corrections that can be subtracted from measured volumes but IGT developed an empirical method that corrects dry Btu basis to wet basis. This formula is as follows: where— An example of this method is as follows: 1. 73 psia A. A=22,500 from Table B=NGPA ref. std. manual. 11 B. Pressure Base Correction C.

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