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dependence of relative permeabilities on the degree of saturation of
pore medium by different phases. This dependence is widely used in
the theory and practice of oil fields exploitation.

Permeability coefficient of rock for water is determined by the
equation which follows from Darcy’s law:

Q    L
k  w w , (4.1)
рer.w.
A  P
2
where k is rock permeability coefficient for water, m ; Q is the
рer.w. w
3
volumetric flow rate of liquid (water) through the rock sample, m /s;
2
A is the filtration area (cross-sectional area of the rock sample), m
 d  2
( A  ); d is the diameter of the rock sample of cylindrical form,
4
m;  is dynamic viscosity of water, Pas; L is the length of the rock
w
sample, m; P is pressure difference at the ends of the rock sample,
Pa ( P  P 1 - P ); Р is pressure in front of the core, Pa; Р is pressure
1
2
2
behind the core, Pa.
Rock permeability coefficient of oil- and gas-bearing formations
changes from several mD to 2 – 3 D.
The magnitude of permeability coefficient is used in flow

calculations (such as determination of well productivity and formation
hydroconductivity) and calculations on formations simulation.

4.3 Equipment, devices and materials

The following equipment, devices and materials should be used
for the experiment: the apparatus (installation) WCPE-1 (ВКТВ-1),

installation IIPC-1M (УДПК-1М), the core (the rock sample),
educational posters and stopwatch.

Description of the apparatus (installation) WCPE-1 (ВКТВ-1)
for determining water permeability coefficient of rocks and
installation IIPC-1M (УДПК-1М)

The experiment is conducted by means of the apparatus
(installation) WCPE-1 (ВКТВ-1). The chart of this installation is
shown on figure 4.1. It сonsists of head capacity 2, discharge capacity

3, cylinder with air or hydraulic press 1 and manifold 5. Capacity 3 is

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