Characterization of the Silurian “Clinton” Sandstone for CO2-EOR Potential in the East Canton Oil Field, Ohio
Ronald A. Riley¹, John L. Wicks², and Christopher J. Perry¹
¹Ohio Department of Natural Resources, Division of Geological Survey, Columbus, OH, [email protected], [email protected]
²JL Wicks Exploration, Wooster, OH, [email protected]
The purpose of this study was to conduct a detailed reservoir characterization study and evaluate the efficacy of using CO2-EOR (enhanced oil recovery) in the East Canton oil field in northeastern Ohio. Discovered in 1947, this field has produced approximately 95 MMbbl (million barrels) of oil from the Silurian “Clinton” sandstone. Encompassing 175,000 reservoir acres, the original oil-in-place for this field is estimated to be approximately 1.5 billion bbl of oil. Using an average primary recovery factor of 7 percent, the estimated original oil reserves are 105 MMbbl. Thus an estimated 10 MMbbl of remaining oil reserves could be produced through primary recovery alone. By modeling known reservoir parameters, we estimate between 76 and 279 MMbbl of additional oil could be produced through secondary recovery in this field.
The “Clinton” interval was subdivided into five sandstone units with the objective of developing a geologic model to better understand and delineate the porosity and permeability distribution and compartmentalization. Regionally, the “Clinton” interval has an average gross thickness of 110 feet. Net sandstone maps and core examination suggest a fluvial-deltaic and offshore-marine depositional environment. The clastic source is from the east and is dominantly controlled by three deltaic lobes oriented east–west and southeast–northwest.
A CO2 cyclic test (“Huff-n-Puff”) was conducted on a well in Stark County as part of the study. All data collected during this test were analyzed, interpreted, and incorporated into the reservoir characterization study and used to develop the geologic model. Eighty-one tons of CO2 (1.39 MMCF (million cubic feet)) were injected over a 20-hour period, after which the well was shut-in for a 32-day “soak” period before production was resumed. Results demonstrated injection rates of 1.67 MMCF of gas per day, which was much higher than anticipated. Encouraging results and lessons learned from this test have resulted in a proposed larger-scale CO2 flood (approximately 10,000 tons) to be conducted in this economically promising oil field.
AAPG Search and Discovery Article #90154©2012 AAPG Eastern Section Meeting, Cleveland, Ohio, 22-26 September 2012