Journal
ENERGIES
Volume 15, Issue 22, Pages -Publisher
MDPI
DOI: 10.3390/en15228557
Keywords
geochemical modeling; shale reservoirs; hydraulic fracture
Categories
Funding
- US Department of Energy through the Los Alamos National Laboratory (LANL)
- National Nuclear Security Administration of U.S. Department of Energy [89233218CNA000001]
- Laboratory Directed Research and Development program at LANL
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This study modeled a hydraulic fracture stage and found that geochemical interactions have a positive impact on the fate of reservoir fluids and well performance. Sea water shows promise as an alternative fracturing fluid, and lower-saline connate water improves well performance.
Field operations report that at least half of the fracturing fluid used in shale reservoirs is trapped. These trapped fluids can trigger various geochemical interactions. However, the impact of these interactions on well performance is still elusive. We modeled a hydraulic fracture stage where we simulated the initial conditions by injecting the fracturing fluid and shutting the well to allow the fluids to soak into the formation. Our results suggest a positive correlation between the dissolution and precipitation rates and the carbonate content of the rock. In addition, we observed that gas and load recovery are overestimated when geochemical interactions are overlooked. We also observed promising results for sea water as a good alternative fracturing fluid. Moreover, we observed better performance for cases with lower-saline connate water. The reactions of carbonates outweigh the reactions of clays in most cases. Sensitivity analysis suggests that the concentration of SO4, K and Na ions in the fracturing fluid, and the illite and calcite mineral content, along with the reservoir temperature, are the key factors affecting well performance. In conclusion, geochemical interactions should be considered for properly modeling the fate of the fracturing fluids and their impact on well performance.
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