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Coal beds contain fractures and pores that can transmit large volumes of water. In some areas, coal beds may function as local or regional aquifers and are important sources for ground water (Rice and Nuccio 2000). The volume of water varies significantly from basin to basin. These variations can occur for many different reasons depending on the part the CBM development cycle plays, the rank of the coal, the depth of the coal, and the hydrologic connectivity to other water bearing aquifers. Generally, deeper coal seams will contain less water, but the salinity of the water will be higher. Water to gas ratios are used to describe the volume of water produced per million cubic feet of natural gas. Water to gas ratios are used, along with the estimated recoverable reserves of natural gas, to predict the volume of water that will be generated in each producing basin. 2.3 Current Produced Water Management Practices Water is considered a byproduct of oil and gas production and generally is treated by the oil and gas industry as a waste for disposal. Produced water management practices are driven by the cost of the hydrocarbon resource. Produced water is the largest volume waste stream associated with oil and gas production. Because produced water is viewed as a waste byproduct to the oil and gas industry, historically, the most commonly practiced management strategies are aimed at disposal rather than beneficial use. The most common practices for produced water disposal include land application or discharge, subsurface injection, and offsite trucking. • Land application or discharge is a relatively inexpensive method of disposal for produced water. However, this is only an option for relatively high quality produced waters. If the water is of poor quality, contamination of the surrounding soil, water, and vegetation can occur. Regulatory guidelines also must permit land applications. • Subsurface injection is the industry preferred alternative to produced water disposal. In some cases, re-injection of produce waters is not feasible because the subsurface formation does not have the capacity to receive the water. • In the event that land application or re-injection is not feasible, the water may be trucked to offsite, re-injection facilities. Re-injection facilities commonly are located around a feasible accepting geologic formation for injection. These facilities sometimes include minor treatment applications aimed at lowering the scaling potential of the reinjection water or modify the chemistry of the water to aid in disposal. Typically, producers have limited water treatment experience and are hesitant to employ produced water treatment technologies given their negative past experiences. From an oil and gas producer’s perspective, the primary concern of beneficial use of produced water as a management strategy is liability; therefore, 7PDF Image | Oil and Gas Produced Water Management
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