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Gas Processing

Natural gas reserves are generally contaminated with undesirable (nonbuming) components which contribute to the reduction of the heating value of the gas. [Pg.321]

improved gas burning characteristics and improved transport properties (low-Btu gases have higher density and viscosity resulting in higher pumping costs) [Pg.323]

high methane recovery with minimal power consumption at high inlet nitrogen content [Pg.323]

allowance for extraction of heavier hydrocarbons and natural gas liquids [Pg.323]

higher hydrocarbon partial pressures when the gas is used for chemical reactions [Pg.323]

The term gas processing is used to refer to the removing of ethane, propane, butane, and heavier components from a gas stream. They may be fractionated and sold as pure components, or they may be combined and sold as a natural gas liquids mix, or NGL. [Pg.241]

The first step in a gas processing plant is to separate the components that are to be recovered from the gas into an NGL stream. It may then be desirable to fractionate the NGL stream into various liquefied petroleum gas (LPG) components of ethane, propane, iso-butane, or normal-butane. The LPG products are defined by their vapor pressure and must meet certain criteria as shown in Table 9-1. The unfractionated natural gas liquids product (NGL) is defined by the properties in Table 9-2. NGL is made up principally of pentanes and heavier hydrocarbons although it may contain some butanes and very small amounts of propane. It cannot contain heavy components that boil at more than 375°F. [Pg.241]

In most instances gas processing plants are installed because it is more economical to extract and sell the liquid products even though this lowers the heating value of gas. The value of the increased volume of liquids sales may be significantly higher than the loss in gas sales revenue because of a decrease in heating value of the gas. [Pg.241]

Product Characteristics Propane Butane Mixtures HD-5 Methods Cr  [Pg.242]

Composition Predominantly Predominantly Predominantly Not less than 90 ASTM D-2163-82  [Pg.242]


Bi-Gas process A high-pressure operation for the conversion of solid fuel into substitute natural gas (SNG) using two stages of gasification. [Pg.59]

Before oil and gas processing are described in detail in the following sections it is useful to consider how oil and gas volumes and compositions are reported. [Pg.241]

In this section gas processing will be described in the context of site needs and evacuation, i.e. how gas may be processed for disposal or prior to transportation by pipeline to a downstream gas plant. Gas fractionation and liquefaction will be described in Section 10.1.4 Downstream Gas Processing . [Pg.249]

Gas processing facilities generally work best at between 10 and 100 bar. At low pressure, vessels have to be large to operate effectively, whereas at higher pressures facilities can be smaller but vessel walls and piping systems must be thicker. Optimum recovery of heavy hydrocarbons is achieved between 20 bar and 40 bar. Long distance pipeline pressures may reach 150 bar and reinjection pressure can be as high as 700 bar. The gas process line will reflect gas quality and pressure as well as delivery specifications. [Pg.249]

Gas turbine driven centrifugal compressors are very efficient under the right operating conditions but require careful selection and demand higher levels of maintenance than reciprocating compressors. Compression facilities are generally the most expensive item in an upstream gas process facility. [Pg.253]

The gas processing options described in the previous section were designed primarily to meet on-site usage or evacuation specifications. Before delivery to the customer further processing would normally be carried out at dedicated gas processing plants, which may receive gas from many different gas and oil fields. Gas piped to such plants is normally treated to prevent liquid drop out under pipeline conditions (dew point control) but may still contain considerable volumes of natural gas liquids (NGL) and also contaminants. [Pg.253]

The reaction of adipic acid with ammonia in either Hquid or vapor phase produces adipamide as an intermediate which is subsequentiy dehydrated to adiponitrile. The most widely used catalysts are based on phosphoms-containing compounds, but boron compounds and siHca gel also have been patented for this use (52—56). Vapor-phase processes involve the use of fixed catalyst beds whereas, in Hquid—gas processes, the catalyst is added to the feed. The reaction temperature of the Hquid-phase processes is ca 300°C and most vapor-phase processes mn at 350—400°C. Both operate at atmospheric pressure. Yields of adipic acid to adiponitrile are as high as 95% (57). [Pg.220]

Olefins are produced primarily by thermal cracking of a hydrocarbon feedstock which takes place at low residence time in the presence of steam in the tubes of a furnace. In the United States, natural gas Hquids derived from natural gas processing, primarily ethane [74-84-0] and propane [74-98-6] have been the dominant feedstock for olefins plants, accounting for about 50 to 70% of ethylene production. Most of the remainder has been based on cracking naphtha or gas oil hydrocarbon streams which are derived from cmde oil. Naphtha is a hydrocarbon fraction boiling between 40 and 170°C, whereas the gas oil fraction bods between about 310 and 490°C. These feedstocks, which have been used primarily by producers with refinery affiliations, account for most of the remainder of olefins production. In addition a substantial amount of propylene and a small amount of ethylene ate recovered from waste gases produced in petroleum refineries. [Pg.171]

Blue gas, or blue-water gas, so-called because of the color of the flame upon burning (10), was discovered in 1780 when steam was passed over incandescent carbon (qv), and the blue-water gas process was developed over the period 1859—1875. Successfiil commercial appHcation of the process came about in 1875 with the introduction of the carburetted gas jet. The heating value of the gas was low, ca 10.2 MJ /m (275 Btu/fT), and on occasion oil was added to the gas to enhance the heating value. The new product was given the name carburetted water gas and the technique satisfied part of the original aim by adding luminosity to gas lights (10). [Pg.62]


See other pages where Gas Processing is mentioned: [Pg.115]    [Pg.385]    [Pg.371]    [Pg.371]    [Pg.235]    [Pg.235]    [Pg.236]    [Pg.249]    [Pg.253]    [Pg.2]    [Pg.8]    [Pg.18]    [Pg.19]    [Pg.32]    [Pg.151]    [Pg.189]    [Pg.225]    [Pg.244]    [Pg.288]    [Pg.309]    [Pg.314]    [Pg.396]    [Pg.527]    [Pg.620]    [Pg.642]    [Pg.646]    [Pg.783]    [Pg.818]    [Pg.886]    [Pg.905]    [Pg.944]    [Pg.973]    [Pg.1015]    [Pg.1016]    [Pg.1035]    [Pg.1072]    [Pg.518]   


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