Shale gas and other unconventional gas plays have become an important factor in the United States energy market and are often referred to as statistical plays due to their high heterogeneity. They present real engineering challenges for characterization and exploitation, and their productivity depends upon an inter-related set of reservoir, completion and production characteristics.The Devonian Ohio shale of eastern Kentucky is the State's most prolific gas producer. The gas shale underlies approximately two-thirds of the state, cropping out around the Bluegrass Region of central Kentucky and having a sub crop beneath the Mississippi Embayment in western Kentucky. This paper describes the reservoir modeling and history matching of a Devonian Gas Shale Play, eastern Kentucky, its potential for CO 2 enhanced gas recovery and storage.A geologic model of the shale has been compiled from mineralogical, petrographic, core, production, and wireline data. The COMET3 multi-phase, dual porosity simulator is being used to investigate CO 2 injection into the shale for enhanced gas recovery. To accomplish this, a subset of wells surrounding the potential injection site has been selected for further study. These eight wells cover approximately 5,300 acres of productive shale. The reservoir was subdivided into the Upper Ohio and Lower Huron members. To capture geological heterogeneity, gas production rates for these wells served as a proxy to characterize fracture permeability using geostatistical methods. Well production was history matched applying an automated process. Finally, several CO 2 injection scenarios spanning huff-n-puff to continuous injection were reviewed to evaluate the enhanced gas recovery potential and assess the CO 2 storage capacity of these shale reservoirs.
The Southwest Regional Partnership on Carbon Sequestration (SWP) is one of seven regional partnerships sponsored by the U.S. Department of Energy (DOE) that collectively includes more than 350 organizations spanning 40 states, three Indian nations, and four Canadian provinces. The objectives are to determine the most suitable technologies, regulations and infrastructure requirements for carbon capture, storage and sequestration in different areas of the country. In Phase I of the partnership program, significant sources of greenhouse gas emissions were inventoried, potential geological sequestration sinks identified, and small-scale sequestration demonstration opportunities developed. Many of these small-scale pilot demonstrations are currently being implemented as part of the Phase II program. One of the three geo-sequestration pilots for the SWP involves CO2injection into a deep, unmineable coalbed at the Pump Canyon site located in the San Juan Basin of northern New Mexico. At the demonstration site, a new CO2injection well was drilled into the late-Cretaceous Fruitland coals within an existing pattern of coalbed methane production wells. CO2is currently being injected into the coal at pressures not to exceed the permitted injection pressure, and a variety of monitoring, verification and accounting (MVA) methods are employed to track the movement of the CO2. Some of the MVA methods include continuous measurement of injection volumes, pressures and temperatures within the injection well, coalbed methane production rates, pressures and compositions at the offset producer wells, tracers in the injected CO2, time-lapse vertical seismic profiling, surface tiltmeter arrays, a series of shallow monitoring wells with a regular fluid sampling program, and surface measurements of soil compositions, CO2fluxes, tracers, etc. In addition, a detailed geologic characterization and reservoir modeling has been implemented in order to reproduce and understand the behavior of the reservoir. To date, the injection is still on-going and no CO2breakthrough has occurred. This paper provides a description of the Pump Canyon CO2-ECBM (enhanced coalbed methane) and sequestration demonstration field activities with particular emphasis on the lessons being learned.
Summary The Pump Canyon CO2-enhanced coalbed methane (ECBM)/ sequestration demonstration in New Mexico has the primary objective of demonstrating the feasibility of CO2 sequestration in deep, unmineable coal seams through a small-scale geologic sequestration pilot. This project is not the first of its kind; several small- or large-scale pilots were already conducted previously in the United States [Allison Unit (Reeves et al. 2003) in the San Juan, Appalachian, and Warrior basins] as well as internationally [the Recopol (Reeves and Oudinot 2002) project in Poland, and the Yubari project in Japan, Canada, and Australia]. Additional pilots are currently under way. At the project site, a new CO2-injection well was drilled within an existing pattern of coalbed-methane-production wells. Primarily operated by ConocoPhillips, these wells produce from the Late Cretaceous Fruitland coals. CO2 injection into these coal seams was initiated in late July 2008 and ceased in August 2009. A variety of monitoring, verification, and accounting (MVA) methods were employed to track the movement of the CO2 in order to determine the occurrence of leakage. Within the injection well, MVA methods included continuous measurement of injection volumes, pressures, and temperatures. The offset production wells sampled gas-production rates, pressures, and gas composition through CO2 sensors, tracers in the injected CO2, time-lapse vertical seismic profiling, and surface tiltmeter arrays. A detailed study of the overlying Kirtland shale was also conducted to investigate the integrity of this primary caprock. This information was used to develop a detailed geologic characterization and reservoir model that has been used to further understand the behavior of this reservoir. The CO2-injection pilot has ended with no significant CO2 buildup occurring in the offset production wells. However, a small but steady increase in CO2 and N2 at two of the offset wells may have been an indication of imminent breakthrough. More recent gas samples are, however, showing a decrease in CO2 and N2 content at those wells. This paper describes the project, covering the regulatory process and injection-well construction, the different techniques used to monitor for CO2 leakage, and the results of the modeling work.
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