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Fluid invades fracks.
The results show that the gas pressure increases because drilling fluid invades the fracture.
The bump in capillary pressure is shown to correspond to the instant when the fluid invades the narrow pore throats, which require a higher capillary pressure threshold.
The interfacial tension of the fracturing fluid is shown to control whether fluid invades pore space at the borehole wall and this in turn changes the local stress regime, hence breakdown pressure.
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This paper investigates equilibrium of a pressurized plastic fluid invading a tensile wellbore crack in a linear elastic, permeable rock.
The crack is initially filled by pore fluid at ambient pressure, that is immiscibly displaced by the plastic fluid invading from the wellbore.
External fluid invading into reservoir could induce formation damage in form of phase trapping in tight sandstone reservoirs (in-situ permeability<0.1 mD).
Well blowout – caused by the formation fluids invading a wellbore because of the imbalance of the bottom-hole pressure and formation pressure – is the most hazardous accident in deepwater drilling and well completion engineering.
A simple desktop test method, such as immersion testing, can help production engineers choose the appropriate shale inhibitors such as salt, tetramethylammonium chloride (TMAC) and polymers that can effectively reduce the impact of oilfield fluids invading shale and causing it to swell or disperse.
Dry shale samples were evacuated for nearly 24 h at 99.99 % vacuum, and saturated by allowing non-traced fluid to invade the evacuated sample.
Theories on the 99mTc-PYP uptake mechanism concern calcium salt deposition and formation of complexes with denatured macromolecules, since the tracer has been found in edema fluid and invading inflammatory cells as well as in injured muscle fibers [33 35].
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