This paper describes a hydraulic fracturing study undertaken on the Clinton Sandstone in southern Ohio. The purpose of this study was to improve the effectiveness of the fracturing treatments being pumped to increase well production. The methodology employed in this study used a hydraulic fracturing simulator and production data analysis to evaluate the effectiveness of the treatments.

Historical fracture treatments were analyzed with a 2dimensional fracture design model1  to estimate propped fracture half-lengths. These treatments, typical of Clinton fracture treatments in Ohio, consisted of a gel pad followed by gel and slick water carrying 20/40 Ottawa sand at low concentrations. Results showed that most of the fracturing sand was falling out of the pay zone due to the low fluid viscosity. Over a period of one year, the treatments were modified using the fracture simulator as a design tool. Some of these changes included increasing sand concentration and pumping the sand with a higher viscosity fluid.

This simple methodology presented in this paper is applicable to Clinton wells in Ohio and other tight gas formations throughout the Appalachian Basin to improve production by modifying fracturing practices without increasing fracturing costs substantially. The methodology does not require large data collection and thus is cost effective to apply.

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