340 Sediments, Carbonates (Posters)

Wednesday, 28 September 2016
9:00 AM - 6:30 PM
Exhibit Hall E/F

POROSITY SIZE DISTRIBUTION IN MINERALIZED FRACTURES WITHIN A SHALE FORMATION

Paper number: 340-18
Program: Technical Sessions
Time: 9:00 AM – 6:30 PM

Authors

Abstract

Shale formations are both source rocks for unconventional oil and gas production and cap rocks for conventional oil and gas plays, carbon dioxide sequestration, and industrial waste water disposal. Mineralized fractures in these formations may act as both a barrier and a conduit for fluids, depending on flow direction, fracture orientation, and fracture porosity. In oil and gas production, variations in fracture characteristics can manifest as well production that is inconsistent with expectations. Likewise, mineralized fractures in cap rock formations can alter physical and chemical properties of the formation, resulting in changes to the sealing capacity. Additionally, porosity in fractures can provide pathways for fluids to migrate into overlying formations. A mechanistic understanding of fracture mineralization and porosity is vital to predicting behavior of shale formations.

Standard petrographic analysis practices may not be sufficient for characterizing shale formations containing mineralized fractures for industrial and economic activities. Fractures that appear to be completely occluded by calcite and dolomite precipitation under standard petrographic analysis may provide connected flow pathways at nanometer to micron scales. The current research examines the following hypotheses: (A) Pores in the fracture material span orders of magnitude in length scale from nm to mm. (B) Small-scale pores (< micron) provide connected porosity for fluid flow. Core samples from a well bore were analyzed using small-angle neutron scattering (SANS) and scanning electron microscopy (SEM) to identify the size distribution of fracture porosity. Cathode luminescence (CL) microscopy was performed to identify different mineralization events during fracture diagenesis. SANS analysis of the connected porosity was performed on two of the samples by adding a deuterated water mixture, a technique called contrast matching. The poly-disperse hard sphere model PRINSAS was used to interpret the intensity data of scattered neutrons as a function of length-scale to produce the both the total porosity and connected porosity for each fracture analyzed. Continuing research will include further analysis of connected porosity using SANS.

Geological Society of America Abstracts with Programs. Vol. 48, No. 7

doi: 10.1130/abs/2016AM-287203

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