Water-sensitivity damage is inevitable during hydraulic
fracturing
for tight reservoir stimulation. A polymer clay stabilizer is the
most effective and commonly used agent for reducing this kind of permeability
damage. However, due to the small pore throat radii of tight reservoirs,
polymers may be captured and detained, resulting in secondary permeability
damage caused by polymer plugging. Therefore, it is necessary to clarify
the matching relationship between the relative molecular mass of the
clay stabilizer and the permeability of tight cores, which has not
been reported yet. In response to this problem, the residual resistance
factor and the permeability damage rate of PDMDAAC (poly dimethyl
diallyl ammonium chloride, a kind of commonly used polymer clay stabilizer)
to tight cores from Xinjiang Oilfield were investigated in cores with
permeabilities of 0.10 × 10
–3
μm
2
(0.08–0.17 × 10
–3
μm
2
), 0.05 × 10
–3
μm
2
(0.035–0.065 × 10
–3
μm
2
), and 0.01 × 10
–3
μm
2
(0.007–0.020
× 10
–3
μm
2
) through flow experiments.
It was found that the relative molecular masses of PDMDAAC, which
did not cause obvious core permeability damage, should be less than
10 000, 5000, and 2000, respectively. In addition, the bridging
flocculation principle between the hydrodynamics radius of the clay
stabilizer and the radius of the tight core pore throat can be used
to explain the matching relationship between the relative molecular
mass of the polymer clay stabilizer and the permeability of the tight
reservoir. This study points out the direction for the optimization
of the polymer clay stabilizer used in tight reservoir hydraulic fracturing
and provides some references for the construction of hydraulic fracturing
fluid systems for the efficient development of unconventional oil
and gas resources.