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<oai_dc:dc xmlns:dc="http://purl.org/dc/elements/1.1/" xmlns:oai_dc="http://www.openarchives.org/OAI/2.0/oai_dc/" xmlns:xsi="http://www.w3.org/2001/XMLSchema-instance" xsi:schemaLocation="http://www.openarchives.org/OAI/2.0/oai_dc/ http://www.openarchives.org/OAI/2.0/oai_dc.xsd">
  <dc:contributor>Peter D. Warwick</dc:contributor>
  <dc:contributor>Steven T. Anderson</dc:contributor>
  <dc:creator>Hossein Jahediesfanjani</dc:creator>
  <dc:date>2018</dc:date>
  <dc:description>&lt;p id="spar0085"&gt;&lt;span&gt;The U.S.&amp;nbsp;Geological Survey&amp;nbsp;(USGS) national assessment of&amp;nbsp;carbon dioxide&amp;nbsp;(CO&lt;/span&gt;&lt;sub&gt;2&lt;/sub&gt;&lt;span&gt;) storage capacity evaluated 192 saline Storage Assessment Units (SAUs) in 33 U.S. onshore&amp;nbsp;sedimentary basins&amp;nbsp;that may be utilized for CO&lt;/span&gt;&lt;sub&gt;2&lt;/sub&gt;&lt;span&gt;&amp;nbsp;&lt;/span&gt;storage (see USGS Circular 1386). Similar to many other available models, volumetric analysis was utilized to estimate the initial CO&lt;sub&gt;2&lt;/sub&gt;&lt;span&gt;injection and storage capacity of these SAUs based on&amp;nbsp;aquifer characteristics&amp;nbsp;and buoyant and residual trapping. The factor being almost always overlooked in most CO&lt;/span&gt;&lt;sub&gt;2&lt;/sub&gt;&lt;span&gt;&amp;nbsp;storage capacity models is that many of the evaluated SAUs contain large numbers of both conventional and unconventional discovered and undiscovered oil and&amp;nbsp;gas reservoirs. The&amp;nbsp;hydrocarbon&amp;nbsp;production and&amp;nbsp;pressure distribution&amp;nbsp;of the resident oil and gas reservoirs may be negatively influenced by the propagated CO&lt;/span&gt;&lt;sub&gt;2&lt;/sub&gt;&lt;span&gt;&amp;nbsp;&lt;/span&gt;plume and pressure front resulting from a CO&lt;sub&gt;2&lt;/sub&gt;&lt;span&gt;&amp;nbsp;&lt;/span&gt;injection and storage operation in the surrounding SAU.&lt;/p&gt;&lt;p id="spar0090"&gt;To have a more realistic and accurate estimation of CO&lt;sub&gt;2&lt;/sub&gt;&lt;span&gt;&amp;nbsp;&lt;/span&gt;injection and storage capacity in saline formations, a model was previously developed that considers the CO&lt;sub&gt;2&lt;/sub&gt;&lt;span&gt;&amp;nbsp;injectivity of a given formation, underground pressure build-up limitations imposed by the rock fracturing pressure and the presence of&amp;nbsp;hydrocarbon reservoirs&amp;nbsp;within these&amp;nbsp;aquifers. The developed method estimates the pre–brine extraction, pressure-limited CO&lt;/span&gt;&lt;sub&gt;2&lt;/sub&gt;&lt;span&gt;&amp;nbsp;&lt;/span&gt;injection and storage capacity of a saline formation by applying 3D numerical simulation only on the effective injection area (A&lt;sub&gt;eff&lt;/sub&gt;) surrounding each CO&lt;sub&gt;2&lt;/sub&gt;&lt;span&gt;&amp;nbsp;&lt;/span&gt;injection well utilizing TOUGH2-ECO2N simulation software.&lt;/p&gt;</dc:description>
  <dc:format>application/pdf</dc:format>
  <dc:identifier>10.1016/j.ijggc.2018.09.011</dc:identifier>
  <dc:language>en</dc:language>
  <dc:publisher>Elsevier</dc:publisher>
  <dc:title>Estimating the pressure-limited CO2 injection and storage capacity of the United States saline formations: Effect of the presence of hydrocarbon reservoirs</dc:title>
  <dc:type>article</dc:type>
</oai_dc:dc>