Gas factor

The activity, coke, and gas factors are the tests that reflect the relative catalytic behavior of the catalyst. 

The CF and GF represent the coke- and gas-forming tendencies of an E-cat compared to a standard steam-aged catalyst sample at the same conversion. The CF and GF are influenced by the type of fresh catalyst and the level of metals deposited on the E-cat. Both the coke and gas factors can be indicative of the dehydrogenation activity of the metals on the catalyst. The addition of amorphous alumina to the catalyst will tend to increase the nonselective cracking, which forms coke and gas. 

Gas Factor is the hydrogen and lighter gas-producing (C1-C4) characteristics of the equilibrium catalyst relative to the hydrogen and lighter gas-producing characteristics of some standard catalyst at the same conversion. 

A good methanation catalyst is one which is physically strong, is reducible at 300°C (570°F) and has high activity. In order to provide a long life, it must retain these properties in use. Lives of 3-5 years are commonly obtained from charges of Imperial Chemical Industries, Ltd. (ICI) catalyst 11-3, depending on the temperature of operation and the presence of poisons in the synthesis gas, factors which are discussed below. These properties can be obtained by careful attention to the formulation and manufacture of the catalyst. 

The fluidizing gas is usually methane, helium, or another non-reactive gas. Factors to consider to obtain proper fluidization are the density and size of the particles to be coated, and the velocity, density, and viscosity of the gases.If the velocity is too low, the particles will fall into the gas inlet if it is too high, they... 

The majority of the process vessels you see in your plant are gravity, vapor-liquid separators. Their main purpose is to settle out droplets of entrained liquid from the upflowing gas. Factors that affect the settling rate of these droplets are... 

Here iin = ehjlmp = 2.723 x 10 in atomic units) is analogous to ur, but with tlie proton mass instead of the elet the nuclear magneton, tron mass. The gA factor There is one exception, however, namely tlie mteractiou of the nuclear quadmpole moment with the electric field gradient, which is of order 1/c. Although nuclei often ... 

Fiq. 84. Water-formation volume factor for pure water and mixtures of water and natural gas. Factors are plotted as a function of pressure at 100°, 150°, 200°, and... 

As metallation proceeds the product selectivity changes. The coke factor (defined in Table 2) in sample CD increases from 1.5 at 8 hours to 2.1 at 24 hours operation. The gas factor changes from 0.6 to 1.1 for the same period of time. By comparison, factors for ECAT and HTD (1.4 and 1.5) and gas factors (1.3 and 0.6) are almost constant. The gasoline selectivity varies from 67 to 75% for sample CD, 62 to 64% for sample HTD and remains almost constant 69-70% for sample ECAT2. 

Sample Activity H2/CH4 Gas factor Coke factor GLP olefmicitv Selectivity (%) GLP easoline bottoms ... 

Przepiorski, J. and Oya, A. (1998). K2C03-loaded deodorizing activated carbon fibre against H2S gas factors influencing the deodorizing efficiency and the regeneration method. J. Mater. Sci. Lett., 17, 679-82. 

The gas factor required in subsequent calculations may be determined from the safety valve discharge data and standard references. Table 6-2 summarizes the calculations for gas factors. 

Gas ratio equaled 6m /ton, which corresponded to the initial value. Precisely at these gas factor values, all the wells of the above mentioned deposits showed free flow during the early production stage. Upon completion of well 55, the formation pressure in that part of the reservoir was 28.7 kg/cm. Had this pressure been sufficient, well 55 would have been completed to produce by free flow. The analysis of core data and the high gas saturation of the crude indicated that except for the pressure at the time of completion of well 55, the condition of the reservoir at that particular place corresponded to early stages of production. Lower pressure readings were due to the fact that by the time well 55 was drilled, that section of the reservoir was already exploited by wells with strong encroachment of formation waters. 

Most of the remaining oil reserves present in the Miocene strata of the Krasnodar Petroliferous Region are concentrated in reservoirs with poor permeability. Special experimental studies were therefore carried out to find an efficient method of increasing the oil recovery factor of these low permeability reservoirs. Models of two different kinds of porous media and of different gas factors were used in these experiments. 

In a series of experiments, both the fracture- and the porosity-models were used the permeabilities of the models used were 0.26 Darcies and 5.2 Darcies. Two kinds of samples of liquids were used (a) samples of crude oil with different gas content, (b) samples of degassed oil recombined with gas with gas factors of 1.5, 4.6, 9.1, 14.4, and 20.8 m. The results of these experiments are given in Table 7 and Fig. 7. 

The first of these intervals corresponds to the scale values of 0.3-0.7. This regime exists when the pressure in the formation is brought down to a point below the gas saturation pressure of the oil sample. With further pressure reduction, in the intervals of 0.7 to 0.9, the rates of oil extraction decrease somewhat Sharp increases in gas factors is observed within this range, and the infinite gas factor reaches the value of 1. With pressure reduction within the interval 0.9-1.0, the gas factor decreases sharply from 1.0 to the initial values of 0.02-0.03. This drop in gas factor is accompanied by a significant increase in the rate of total oil yield. The above rate increases from 0.06 to 0.1 per unit of pressure drop. 

For real gases, especially at high pressure, the design equations must be corrected with the real gas factor (Figure 3.1.2-1, Chapter 3). 

Real gas factor r = pVfRT of dry air at different temperatures an pressures. 

The presence of free gas in oil (oil gas) also causes complications in production, gathering, preparation, and transportation of oil. A gas breakthrough in productive wells from the gas cap of the geological horizon or from gas-bearing horizons is sometimes observed. It leads to an increase of the gas factor of produced oU. 

Oil gases at various fields differ by their fractional composition, but, as a rule, the predominant component is methane (from 30 up to 95%). At normal conditions, quantitative ratios between phases of hydrocarbon systems are represented by the quantity called the gas factor and having dimensionality m /m or m /ton. The gas factor of hydrocarbon systems can vary over a wide range - from low values, measured in ones and tens, to high values, measured in hundreds and thousands m of gas per 1 ton or 1 m of oh. It is obvious that for low gas factors, the mixture is a liquid-gas one, and for high gas factors, we have a gas-liquid mixture. Therefore, in the former case we talk about oil-gas systems, and in the latter case - about gas-oil or gas-condensate systems. 

Each oil field is characterized by its own gas factor. Fields with predominantly light oil are characterized by high gas factors. The gas factor can also be high in the case when in the process of field exploitation, gas breaks from the gas cap of the stratum or from gas - bearing horizons into productive wells. There are also fields with very low gas factor. 

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