reservoir fluid

reservoir fluid

[′rez·əv‚wär ‚flü·əd]
(geology)
The subterranean fluid trapped by a reservoir formation; can include natural gas, liquid and vapor petroleum hydrocarbons, and interstitial water.
References in periodicals archive ?
Reservoir analysis is a process that aids in determining the flow-related properties like pressure, volume, porosity, temperature, and permeability of the reservoir fluid. It also helps in optimizing the recovery techniques and production.
Specialists at Hunter Well Science, a subsidiary of Probe since December 2017, developed the tool to measure reservoir fluid saturation of oil, water and gas.
from projects where wells have been drilled and core and reservoir fluid samples have been taken for analyses.
[48] determined the relationship between viscosity and NMR relaxation properties through theoretical derivation and clarified the feasibility of using nuclear magnetic resonance to distinguish reservoir fluid properties.
After the fracture is closed, the capacity of the support filling belt to the reservoir fluid is higher than the gum fracturing fluid.
It covers topics like the properties of ideal and real gases and dry and wet gases; the properties of black oils, including definitions, reservoir fluid studies and their application, field data, and correlations; and clathrate hydrates of petroleum.
The size of the throat radius determines the ability of the reservoir fluid to flow [17, 18].
Component Mole fraction [N.sub.2] 0.0096 C[O.sub.2] 0.0058 [H.sub.2]S 0.0030 [C.sub.1] 0.0449 [C.sub.2] 0.0299 [C.sub.3] 0.0475 I[C.sub.4] 0.0081 N[C.sub.4] 0.0192 I[C.sub.5] 0.0127 N[C.sub.5] 0.0219 [C.sub.6] to [C.sub.9] 0.2573 [C.sub.10] to [C.sub.17] 0.2698 [C.sub.18] to [C.sub.27] 0.1328 [C.sub.28+] 0.1375 Sum 1 Table 2: PVT properties of the reservoir fluid and C[O.sub.2] mixtures at 59[degrees]C [18].
where [k.sub.nf ]is natural fracture permeability, mD; [[phi].sub.nf] is natural fracture porosity, dimensionless; [mu] is reservoir fluid viscosity, mPa s; [C.sub.t] is natural fracture comprehensive compression factor, 1/MPa; [p.sub.0] is the reservoir initial fluid pressure, MPa; [p.sub.i] is the fluid pressure at intersection point of hydraulic fracture and natural fracture, MPa; [L.sub.nf] is natural fracture length, m.
where [phi] is porosity, c is reservoir compressibility, [mu] is the viscosity of reservoir fluid, and k is the reservoir permeability.