Changes

==Gasification==

==Gasification==

Gasification is the conversion of oil to gas resulting from thermal cracking. It primarily takes place during burial. If oil is spilled from a trap by gas displacement during gasification, the oil may occur in economic [[accumulation]]s updip along the migration pathway.<ref name=ch11r12>Gussow, W. C., 1954, [http://archives.datapages.com/data/bulletns/1953-56/data/pg/0038/0005/0800/0816.htm Differential entrapment of oil and gas: a fundamental principle]: AAPG Bulletin, vol. 38, p. 816–853.</ref>

Gasification is the conversion of oil to gas resulting from thermal [[cracking]]. It primarily takes place during burial. If oil is spilled from a trap by gas displacement during gasification, the oil may occur in economic [[accumulation]]s updip along the [[migration pathway]].<ref name=ch11r12>Gussow, W. C., 1954, [http://archives.datapages.com/data/bulletns/1953-56/data/pg/0038/0005/0800/0816.htm Differential entrapment of oil and gas: a fundamental principle]: AAPG Bulletin, vol. 38, p. 816–853.</ref>

==Predicting and recognizing gasification==

==Predicting and recognizing gasification==

The following characteristics can help us predict and recognize gasification.

The following characteristics can help us predict and recognize gasification.

* Geohistory analysis with proper gasification kinetics can usually predict at what depth [[accumulation]]s have been gasified.

* Geohistory analysis with proper gasification [[kinetics]] can usually predict at what depth [[accumulation]]s have been gasified.

* As a rule of thumb, oil should not be expected at subsurface temperatures > [[temperature::150&deg;C]] or a maturation level much above 1.3% R_o. Dry gas accumulations can occur at shallower depths, but oil is not likely at greater depths.

* As a rule of thumb, oil should not be expected at subsurface temperatures > [[temperature::150&deg;C]] or a [[maturation]] level much above 1.3% R_o. Dry gas accumulations can occur at shallower depths, but oil is not likely at greater depths.

* Gasification of oil in reservoirs is associated with the formation of pyrobitumen.<ref name=ch11r34>Tissot, B. P., D. H. Welte, 1984, Petroleum Formation and Occurrence, 2 ed.: New York, Springer-Verlag, 699 p. 460–461</ref>

* Gasification of oil in reservoirs is associated with the formation of pyrobitumen.<ref name=ch11r34>Tissot, B. P., D. H. Welte, 1984, Petroleum Formation and Occurrence, 2 ed.: New York, Springer-Verlag, 699 p. 460–461</ref>

* Displacement of oil from a trap by gas is associated with asphaltene precipitates and/or relatively unaltered oil stain.

* Displacement of oil from a trap by gas is associated with asphaltene precipitates and/or relatively unaltered oil stain.

==Predicting gas destruction==

==Predicting gas destruction==

It is not the destruction of methane as much as the lack of economic [[accumulation]]s which occurs at higher maturation levels. Methane occurs in fluid inclusions from lower crustal depths, and shows of methane are not unusual where drilling through low-grade metamorphic rocks—even those at a grade high enough to contain graphite instead of kerogen (R₀ > 8%). For example the Shell Barret #1 well in Hill County, Texas, had a 30-minute methane flare at over [[depth::13,000 ft]] depth in rock described as dolomite and calcite marble with graphitic inclusions.<ref name=ch11r30>Rozendal, R., A., Erskine, W., S., 1971, [http://archives.datapages.com/data/bulletns/1971-73/data/pg/0055/0011/2000/2008.htm Deep test in Ouachita structural belt of Central Texas]: AAPG Bulletin, vol. 56, p. 2008–2017.</ref>

It is not the destruction of methane as much as the lack of economic [[accumulation]]s which occurs at higher maturation levels. Methane occurs in fluid inclusions from lower crustal depths, and shows of methane are not unusual where drilling through low-grade metamorphic rocks—even those at a grade high enough to contain graphite instead of [[kerogen]] (R₀ > 8%). For example the Shell Barret #1 well in Hill County, Texas, had a 30-minute methane flare at over [[depth::13,000 ft]] depth in rock described as [[dolomite]] and calcite marble with graphitic inclusions.<ref name=ch11r30>Rozendal, R. A., and W. S. Erskine, 1971, [http://archives.datapages.com/data/bulletns/1971-73/data/pg/0055/0011/2000/2008.htm Deep test in Ouachita structural belt of Central Texas]: AAPG Bulletin, vol. 56, p. 2008–2017.</ref>

The following characteristics can help us predict and recognize gas destruction:

The following characteristics can help us predict and recognize gas destruction:

* Economic gas [[accumulation]]s become more unusual with maturation levels > 2.8% R_o.<ref name=ch11r3>Bartenstein, H., 1980, Coalification in NW Germany: Erdöl und Kohle-Erdgas-Petrochemie: vol. 33, p. 121–125.</ref> This is the traditional base of the gas preservation zone.

* Economic gas [[accumulation]]s become more unusual with maturation levels > 2.8% R_o.<ref name=ch11r3>Bartenstein, H., 1980, Coalification in NW Germany: Erdöl und Kohle-Erdgas-Petrochemie: vol. 33, p. 121–125.</ref> This is the traditional base of the gas preservation zone.

* The major gas accumulation with the highest well-documented maturity level where [[Calculating charge volume|charging]] occurred before or during exposure to the high temperatures occurs at a maturation level 3.5–3.8% R_o equivalent (Wilburton field, Oklahoma).<ref name=ch11r13>Hendrick, S., J., 1992, Vitrinite reflectance and deep Arbuckle maturation at Wilburton field, Latimer County, OK: Oklahoma Geological Survey Circular 93, p. 176–184.</ref>

* The major gas accumulation with the highest well-documented maturity level where [[Calculating charge volume|charging]] occurred before or during exposure to the high temperatures occurs at a maturation level 3.5–3.8% R_o equivalent (Wilburton field, Oklahoma).<ref name=ch11r13>Hendrick, S. J., 1992, Vitrinite reflectance and deep Arbuckle maturation at Wilburton field, Latimer County, OK: Oklahoma Geological Survey Circular 93, p. 176–184.</ref>

==Gas dilution==

==Gas dilution==

Carbon dioxide, hydrogen sulfide, and nitrogen can constitute a significant percentage of natural gas from some [[accumulation]]s. In some cases, natural gas is uneconomic due to the high nonhydrocarbon gas content.

Carbon dioxide, hydrogen sulfide, and nitrogen can constitute a significant percentage of natural gas from some [[accumulation]]s. In some cases, natural gas is uneconomic due to the high nonhydrocarbon gas content.

Although low concentrations of carbon dioxide can be derived from organic sources or byproducts of silicate reactions at moderate temperatures<ref name=ch11r32>Smith, J., T., Ehrenberg, S., N., 1989, Correlation of carbon dioxide abundance with temperature in clastic hydrocarbon reservoirs: relationship to inorganic chemical equilibrium: Marine and Petroleum Geology, vol. 6, p. 129–135., 10., 1016/0264-8172(89)90016-0</ref> high concentrations of carbon dioxide are usually associated with igneous intrusion or regional heating of impure limestones.<ref name=ch11r9>Farmer, R., E., 1965, [http://archives.datapages.com/data/specpubs/methodo2/data/a071/a071/0001/0350/0378.htm Genesis of subsurface carbon dioxide], in Young, A., Galley, J., eds., Fluids in Subsurface Environments: AAPG Memoir No. 4, p. 378–385.</ref>

Although low concentrations of carbon dioxide can be derived from organic sources or byproducts of silicate reactions at moderate temperatures<ref name=ch11r32>Smith, J. T., and S. N. Ehrenberg, 1989, Correlation of carbon dioxide abundance with temperature in clastic hydrocarbon reservoirs: relationship to inorganic chemical equilibrium: Marine and Petroleum Geology, vol. 6, p. 129–135., 10., 1016/0264-8172(89)90016-0</ref> high concentrations of carbon dioxide are usually associated with [[igneous]] intrusion or regional heating of impure limestones.<ref name=ch11r9>Farmer, R. E., 1965, [http://archives.datapages.com/data/specpubs/methodo2/data/a071/a071/0001/0350/0378.htm Genesis of subsurface carbon dioxide], in A. Young, and J. Galley, eds., Fluids in Subsurface Environments: AAPG Memoir No. 4, p. 378–385.</ref>

Hydrogen sulfide concentration increases with depth in gas reservoirs with anhydrite, indicating that it, too, is a product of higher maturity.<ref name=ch11r20 /> The methane is reacting with the sulfate to form hydrogen sulfide and carbon dioxide gas. The reaction is probably kinetically controlled.

Hydrogen sulfide concentration increases with depth in gas reservoirs with [[anhydrite]], indicating that it, too, is a product of higher maturity.<ref name=ch11r20 /> The methane is reacting with the sulfate to form hydrogen sulfide and carbon dioxide gas. The reaction is probably kinetically controlled.

The origin of nitrogen gas is not well characterized. In nonpetroleum basins, nitrogen may have high concentration because no other gas is present to dilute it. High-nitrogen gas in thermally mature basins is possibly from [[coal]] sources<ref name=ch11r33>Stahl, W., Boigk, H., Wollanke, G., 1978, Carbon and nitrogen isotope data of upper Carboniferous and Rotliegend natural gases from north Germany and their relationship to the maturity of the organic source material: Advances in Organic Geochemistry 1976, p. 539–559.</ref> or from the mantle or deep crust.<ref name=ch11r17>Jenden, P., D., Kaplan, I., R., 1989, [http://archives.datapages.com/data/bulletns/1988-89/data/pg/0073/0004/0400/0431.htm Origin of natural gas in Sacramento basin, California]: AAPG Bulletin, vol. 73, p. 431–453.</ref>

The origin of nitrogen gas is not well characterized. In nonpetroleum basins, nitrogen may have high concentration because no other gas is present to dilute it. High-nitrogen gas in thermally mature basins is possibly from [[coal]] sources<ref name=ch11r33>Stahl, W., H. Boigk, and G. Wollanke, 1978, Carbon and nitrogen isotope data of upper Carboniferous and Rotliegend natural gases from north Germany and their relationship to the maturity of the organic source material: Advances in Organic Geochemistry 1976, p. 539–559.</ref> or from the [[mantle]] or deep [[crust]].<ref name=ch11r17> Jenden, P. D.,and I. R. Kaplan, 1989, [http://archives.datapages.com/data/bulletns/1988-89/data/pg/0073/0004/0400/0431.htm Origin of natural gas in Sacramento basin, California]: AAPG Bulletin, vol. 73, p. 431–453.</ref>

==Predicting burial destruction==

==Predicting burial destruction==

* Analyzing geohistory or mapping maturation indicators can identify reservoir maturation levels where methane [[accumulation]]s may be uneconomic. Most sizable gas accumulations occurring at maturation levels > 2.8% R_o have thick claystone seals that help preserve the accumulation.

* Analyzing geohistory or mapping maturation indicators can identify reservoir maturation levels where methane [[accumulation]]s may be uneconomic. Most sizable gas accumulations occurring at maturation levels > 2.8% R_o have thick claystone seals that help preserve the accumulation.

* Presence of intrusives in the fetch area can indicate a potential for carbon dioxide dilution.<ref name=ch11r29>Parker, C., 1974, Geopressures and secondary porosity in the deep Jurassic of Mississippi: Transactions of the Gulf Coast Association of Geological Societies, vol. 24, p. 69–80.</ref>

* Presence of intrusives in the fetch area can indicate a potential for carbon dioxide dilution.<ref name=ch11r29>Parker, C., 1974, Geopressures and secondary porosity in the deep Jurassic of Mississippi: Transactions of the Gulf Coast Association of Geological Societies, vol. 24, p. 69–80.</ref>

* If reservoir rocks are associated with evaporite cements or beds, expect hydrogen sulfide if the reservoir is exposed to temperatures > [[temperature::150&deg;C]] and iron is not present to remove the hydrogen sulfide.

* If reservoir rocks are associated with [[evaporite]] cements or beds, expect hydrogen sulfide if the reservoir is exposed to temperatures > [[temperature::150&deg;C]] and iron is not present to remove the hydrogen sulfide.

* Nitrogen is released during the late stages of coal maturation.<ref name=ch11r18>Jüntgen, V., H., Karweil, J., 1966, Gasbildung and gasspeicherung in steinkohlenfluzen, I. gasbildung: Erdöl und Kohle-Erdgas-Petrochemie, vol. 19, p. 339–344.</ref> Therefore, if a prospect is [[Calculating charge volume|charged]] by a type III source rock only during its late maturation stage (R_o > 2.5%), nitrogen dilution is possible. High nitrogen gas content is also characteristic of evaporative settings and hydrocarbon-poor basins.

* Nitrogen is released during the late stages of coal maturation.<ref name=ch11r18>Jüntgen, V. H., and J. Karweil, 1966, Gasbildung and gasspeicherung in steinkohlenfluzen, I. gasbildung: Erdöl und Kohle-Erdgas-Petrochemie, vol. 19, p. 339–344.</ref> Therefore, if a prospect is [[Calculating charge volume|charged]] by a type III source rock only during its late maturation stage (R_o > 2.5%), nitrogen dilution is possible. High nitrogen gas content is also characteristic of evaporative settings and hydrocarbon-poor basins.

* Nonhydrocarbon gas concentrations in mature basins can be estimated from evaluating regional gas concentration trends.

* Nonhydrocarbon gas concentrations in mature basins can be estimated from evaluating regional gas concentration trends.

[[Category:Predicting the occurrence of oil and gas traps]]  

[[Category:Predicting the occurrence of oil and gas traps]]  

[[Category:Predicting preservation and destruction of accumulations]]

[[Category:Predicting preservation and destruction of accumulations]]