DOE - Fossil Energy Techline - Issued on:  August 15, 2001

DOE Selects 2 Projects to Help Boost Gas Flow from Low-Permeability Rock


New Technologies Targeted at Future Gas Production From "Tight" Formations in Western United States

Morgantown, WV - America has vast resources of natural gas, but President Bush's National Energy Policy cautions that domestic production of the easier "conventional" gas could peak as early as 2015.

To help prepare for the day when the Nation's increasing demand for clean-burning natural gas will have to be met by gas trapped in denser, more difficult-to-produce "unconventional" formations, the U.S. Department of Energy has selected two firms to develop advanced methods for locating and producing these low permeability gas reservoirs.

The National Energy Technology Laboratory, through its Strategic Center for Natural Gas, has selected: [click on project for details]

The two projects are valued at just over $5 million. Once negotiations are completed, they will join the Energy Department's fossil energy research portfolio. Currently, the department has nearly a dozen projects underway to develop better ways to find natural gas locked within low-permeability formations, produce more of it per well, and reduce the number of dry holes.

Comparison Photos of Conventional and Tight Gas Sandstone
MICROSCOPIC SECTIONS OF SANDSTONE. Conventional sandstone (top) has well- connected pores (dark blue). The pores of tight gas sandstone (bottom) are irregularly distributed and poorly connected by very narrow capillaries. Gas flows through these rocks at generally low rates.
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The effort to unlock the huge gas resources believed to exist in these difficult formations has become increasingly important with recent projections for dramatic increases in the Nation's consumption of natural gas, the cleanest burning fossil fuel.

The Energy Department currently forecasts that U.S. gas demand could rise by more than 50 percent over the next two decades. President Bush's National Energy Policy, released on May 17, 2001, warns that "While the resource base that supplies today's natural gas is vast, U.S. conventional production is project to peak as early as 2015. Increasingly, the nation will have to rely on natural gas from unconventional resources...."

The Administration's forecast is consistent with the findings of the National Petroleum Council, a non-government advisory group to the Energy Department, which estimated that production from low-permeability wells will need to double by 2015 to meet growing demand for natural gas.

Several studies by the U.S. Geological Survey estimate that low-permeability reservoirs contain several thousand trillion cubic feet of gas, enough to meet total U.S. demand for at least 30 years even if only one third of it can be recovered.

Much of the low-permeability natural gas resource is found in reservoirs deeper than 15,000 feet. Most of these wells are marginally productive because they do not have an extensive, interconnected network of natural fractures, which can serve as conduits through which natural gas can flow to producing wells.

Also, drillers have encountered large amounts of water in some low-permeability resources where water production would not be expected to be an issue. High-water production forces natural gas companies to think twice about developing certain areas and may cause the industry to abandon significant gas reserves.

The two new projects will focus on resolving these issues.

Project Details

  • Innovative Discovery Technologies, Inc., Laramie, WY, proposes to remove some of the risks and uncertainty of drilling low-permeability wells by developing a basin-wide, 3-dimensional model that gives detailed information about the reservoir before drilling begins. The model maps a well's water and gas content, porosity and its likelihood of producing gas by identifying its "sweet spots," high-production areas. It also locates pressure boundaries and characterizes them. As a result, gas companies can avoid excessive water production by designing optimum drilling and completion programs. IDT proposes to demonstrate this technology in the Wind River Basin, Central Wyoming.

    Project cost: $1.94 million; proposed DOE share: $970,000; participant share: $970,000;
    Project duration: 2 years
    Principal investigator: Ronald C. Surdam, (307) 745-4476

  • The University of Texas at Austin, Austin, TX, plans to improve the performance and reduce the cost of creating hydraulic (man-made) fractures in tight areas of sandstone where gas is frequently trapped and difficult to recover. The university will create a model using laboratory tests, improved fracture simulations, and implementation and analysis for the Bossier play (field) southeast of Dallas. To confirm the predictions of such a model in the field, a fracture-monitoring program is proposed with a detailed analysis of current and future fracture treatments. Developing an inexpensive fluid to prevent water blockage in some of the very tight sand formations could recover additional gas from zones that currently do not produce after they are fractured. Productive sands are found at depths ranging from 12,000 feet to 15,000 feet. Costs are just as staggering: The gas industry spends $1.75 million to drill a single well and get it ready to produce. The University of Texas at Austin will partner with Anadarko Petroleum Corp. in Houston.

    Project cost: $3.09 million; proposed DOE share: $883,931; participant share: $2.21 million
    Project duration: 2 years
    Principal investigator: Mukul M. Sharma, (512) 471-3257

- End of Techline -

For more information, contact:
Otis Mills, Jr., DOE National Energy Technology Laboratory, 412/386-5890, e-mail mills@netl.doe.gov

Technical contact:
James R. Ammer, DOE National Energy Technology Laboratory, 304/285-4383, e-mail jammer@netl.doe.gov