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Author's personal copy Energy 57 (2013) 505e512 Utilization of carbon dioxide from coal-based power plants as a heat transfer fluid for electricity generation in enhanced geothermal systems (EGS) Arun Ram Mohan a, Uday Turaga b, Vishakha Shembekar c, Derek Elsworth a, Sarma V. Pisupatia,* a John and Willie Leone Family Department of Energy and Mineral Engineering and EMS Energy Institute, The Pennsylvania State University, 110 Hosler Building, University Park, PA 16802, USA b ADI Analytics LLC, 14511 Old Katy Road, Suite 374, Houston, TX, USA c Omkar Scientific Solutions LLC, 3133 Buffalo Speedway Apt 1309, Houston, TX, USA Contents lists available at SciVerse ScienceDirect Energy journal homepage: www.elsevier.com/locate/energy articleinfo Article history: Received 12 November 2012 Received in revised form 19 March 2013 Accepted 16 May 2013 Available online 9 July 2013 Keywords: Carbon dioxide sequestration IGCC Enhanced geothermal systems Electricity Organic Rankine cycle 1. Introduction Recoverable geothermal energy is available in low permeability sedimentary rocks and basement formations with low porosity. At a depth of 6.5 km from the surface, the thermal reserve is of the order of 1.1 106 EJ [1]. Assessment of enhanced geothermal sys- tems (EGS) for commercial utilization of geothermal heat shows tremendous potential for electricity generation [2]. The conven- tional engineering and technology used to access oil and gas can be adapted for the extraction of geothermal energy provided it is abstract The feasibility of using carbon dioxide (CO2) as a heat transfer fluid by organic Rankine cycle (ORC) in enhanced geothermal systems (EGS) in arid regions is explored in this paper. As CO2 is available for sequestration at high pressures from an Integrated Gasification Combined Cycle (IGCC) plant, this idea is examined by pairing an IGCC plant with an EGS plant to facilitate both the simultaneous extraction of geothermal heat and sequestration of CO2 as well as power generation from EGS. The ORC portion of EGS was modeled by ASPEN Plus version 7.3. Four different working fluids were chosen for the ORC portion of the EGS to absorb the geothermal energy from the CO2 in a binary heat exchanger. The power generated from the EGS and the lowest possible temperature at which CO2 can be discharged from the binary heat exchanger was evaluated for each working fluid. The addition of a preheater provides an opportunity to add a second cycle so that both CO2 and the working fluid can be discharged at the lowest possible temperature. In all cases, the thermal energy recovered from the EGS reservoir is substantially higher than that required to compress the CO2 stream from the IGCC for sequestration. capable of accommodating temperatures greater than 250 Stimulation of the low permeability rocks comprising geothermal reservoir is necessary as native permeabilities typically in the micro-Darcy range. This is accomplished by draulic fracturing or hydraulic shearing to create and expand reservoir, elevate fluid flow-through rates and increase the heat * Corresponding author. Fax: รพ1 814 865 3248. E-mail addresses: sxp17@psu.edu, spisupati@psu.edu (S.V. Pisupati). 0360-5442/$ e see front matter ! 2013 Elsevier Ltd. All rights reserved. http://dx.doi.org/10.1016/j.energy.2013.05.047 C. the are hy- the ! 2013 Elsevier Ltd. All rights reserved. transfer area of the reservoir. This facilitates the extraction of geothermal heat by creating a network of fractures that connects the injection wells with the production wells. In case of geothermal reservoirs with sufficient native permeability, techniques like water-flooding used for oil recovery are utilized for the extraction of geothermal heat [3]. Rock temperature in excess of 200 C is preferable for the production of electricity from the resulting high enthalpy geothermal fluid [3]. The thermal energy is recovered from the reservoir by pumping the heat transfer fluid through the injection well deep into the subsurface and by recovering the hot fluid at the production well [4]. Modeling results show that approximately 40% of the thermal energy can be recovered from a stimulated reservoir of volume approximately 0.1 km3. The magnitude of the stimulated volume (0.1 km3) considered for these subsequent calculations, for a range of fracture spacing, perme- ability and well arrangements, is well below that achieved in the field. This improves the chances of recovering more thermal energy from the geothermal reservoirs [5]. The deepest geothermal well so far drilled in the United States is approximately 2.8 km and less than 100 geothermal wells arePDF Image | Energy Technology ORC
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