BEGIN:VCALENDAR VERSION:2.0 METHOD:PUBLISH PRODID:-//Tendenci - The Open Source AMS for Associations//Tendenci Codeba se MIMEDIR//EN BEGIN:VEVENT DESCRIPTION:--- This iCal file does *NOT* confirm registration.\r\nEvent d etails subject to change. ---\r\nhttps://www.spegcs.org/events/3294/\r\n\r \nEvent Title: Reservoir: Petrophysical and Fluid Flow Properties of a Tig ht Carbonate Source Rock Using Digital Rock Analysis\r\nStart Date / Time: Sep 20, 2016 11:30 AM US/Central\r\nLocation: Sullivan's Steakhouse\r\nSp eaker: Dr. Avrami Grader\r\nGoogle\r\nhttp://maps.google.com/maps?q=4608+W estheimer+Rd,Houston,Texas,77027\r\n\r\nForecast\nhttp://www.weather.com/w eather/monthly/77027\r\n\r\n The evaluation of shale is complicated by the structurally heterogeneous nature of fine-grained strata and their intric ate pore networks, which are interdependent on many geologic factors inclu ding total organic carbon (TOC) content, mineralogy, maturity and grain-si ze. The ultra-low permeability of the shale rock requires massive hydrauli c fracturing to enhance connectivity and increase permeability for the flo w. To design an effective fracturing technique, it is necessary to have a good understanding of the reservoir characteristics and fluid flow propert ies at multiple scales.\r\n In this work, representative core plug samples from a tight carbonate source rock in the Middle East were characterized at the core and pore scale levels using a Digital Rock Characterization wo rkflow. The tight nature of the carbonate rocks prevented the use of conve ntional methods in measuring special core analysis (SCAL) data. 2D Scannin g Electron Microscopy (SEM) and 3D Focused Ion Beam (FIB)-SEM analysis wer e studied to characterize the organic matter content in the samples togeth er with (organic and inorganic) porosity and matrix permeability. The FIB- SEM images in 3D were also used to determine petrophysical and fluid flow (SCAL) properties in primary drainage and imbibition modes.\r\n A clear tr end was observed between porosity and permeability related to identified r ock fabrics and organic matter in the core. The organic matter was found t o have an effect on the imbibition two-phase flow relative permeability an d capillary pressure behavior and hysteresis trends among the analyzed sam ples. The data obtained from DRP provided information that can enhance the understanding of the pore systems and fluid flow properties in tight form ations, which cannot be derived accurately using conventional methods.--- This iCal file does *NOT* confirm registration.Event details subject to ch ange. ---\r\n\r\n--- By Tendenci - The Open Source AMS for Associations -- -\r\n UID:uid3294@spegcs.org SUMMARY:Reservoir: Petrophysical and Fluid Flow Properties of a Tight Carbonate Source Rock Using Digital Rock Analysis DTSTART:20160920T163000Z DTEND:20160920T180000Z CLASS:PUBLIC PRIORITY:5 DTSTAMP:20240329T154844Z TRANSP:OPAQUE SEQUENCE:0 LOCATION:Sullivan's Steakhouse X-ALT-DESC;FMTTYPE=text/html:
 \;The eval uation of shale is complicated by the structurally heterogeneous nature of fine-grained strata and their intricate pore networks, which are interdep endent on many geologic factors including total organic carbon (TOC) conte nt, mineralogy, maturity and grain-size. The ultra-low permeability of the shale rock requires massive hydraulic fracturing to enhance connectivity and increase permeability for the flow. To design an effective fracturing technique, it is necessary to have a good understanding of the reservoir c haracteristics and fluid flow properties at multiple scales.
 \;In this work, representative core plug samp les from a tight carbonate source rock in the Middle East were characteriz ed at the core and pore scale levels using a Digital Rock Characterization workflow. The tight nature of the carbonate rocks prevented the use of co nventional methods in measuring special core analysis (SCAL) data. 2D Scan ning Electron Microscopy (SEM) and 3D Focused Ion Beam (FIB)-SEM analysis were studied to characterize the organic matter content in the samples tog ether with (organic and inorganic) porosity and matrix permeability. The F IB-SEM images in 3D were also used to determine petrophysical and fluid fl ow (SCAL) properties in primary drainage and imbibition modes.
 \;A clear trend was observed between porosi ty and permeability related to identified rock fabrics and organic matter in the core. The organic matter was found to have an effect on the imbibit ion two-phase flow relative permeability and capillary pressure behavior a nd hysteresis trends among the analyzed samples. The data obtained from DR P provided information that can enhance the understanding of the pore syst ems and fluid flow properties in tight formations, which cannot be derived accurately using conventional methods.