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The AAPG/Datapages Combined Publications Database

AAPG Special Volumes


Pub. Id: A066 (1986)

First Page: 1

Last Page: 8

Book Title: SG 24: Geology of Tight Gas Reservoirs

Article/Chapter: Devonian Gas-Bearing Shales in the Appalachian Basin

Subject Group: Reservoirs--Sandstones and Carbonates

Spec. Pub. Type: Studies in Geology

Pub. Year: 1986

Author(s): Wallace de Witt Jr.


The Devonian gas shales of the Appalachian basin constitute a sequence of dark brownish-gray to black laminated rocks that contain 0.5 to 20 weight percent (wt%) organic matter, the source of the gas in the shale. The gas shales underlie about 170,000 mi2 (440,300 km2) of the basin, mainly under the Appalachian plateaus. Their total volume exceeds 12,600 mi3 (52,517 km3), and they contain more than 3.3 trillion tons (3.6 ^times 1012 Mg) of organic matter. The gas shales are low-permeability, low-porosity rocks having permeabilities of 0.1 to 10 microdarcys (┬Ád) and porosities in the 1 to 3% range. They have produced slightly more than 3 trillion cubic fe t (8.5 ^times 1010 m3), mainly from the Big Sandy area of eastern Kentucky and adjacent West Virginia, but their adsorbed gas in place is large; estimates range from less than 200, (5.66 ^times 1012 m3) to more than 1,860, (5.27 ^times 103 m3). Near outcrops on the west side of the basin, the gas shales yield gases of low thermal maturity that have a large component of biogenic gas; deep in the basin at depths of 8,000 to 11,000 ft (2.438 to 3.352 km) below sea level, the shales yield high-maturity dry gas at approximately the upper limit of gas gen ration.

Because the gas shales have low permeability and most of the generated gas is adsorbed on organic matter, the Devonian gas shales must be broken by extensive natural fracture systems before the shales will yield gas in commercial volumes. Shallow gas wells near Lake Erie yield 5,000 to 100,000 cubic feet (5 to 100 mcf) (142 to 2,832 m3) per day at nearly atmospheric pressure, whereas the deeper wells of the Big Sandy field may yield as much as 5 million cubic feet (mmcf) (1.416 ^times 105 m3) per day at normal rock pressure. Production rates even in the larger wells usually drop to about 20% of the initial rate before stabilizing to a nearly flat rate. The ensuing slow decline over several deca es is attributed to a nearly steady-state flow of gas from the shale matrix through the fracture system to the well bore. The size and geometry of the fracture system may be the most important factor in determining a well's productivity.

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