A New Approach in Pressure Transient Analysis: Using Numerical Density Derivatives to Improve Diagnosis of Flow Regimes and Estimation of Reservoir Properties for Multiple Phase Flow

Table 8

Comparison of estimates between conventional and numerical density parameters.

Scenario	Numerical density method		Calculated; (mD)	Conventional; (mD)	Simulation; model (mD)	Relative	% phase; contribution to flow
	Phases	(mD)
(a)	Gas	142.2				0.04	3.0
	Oil	3574.7	404.6	370.7	400	0.89	87.0
	Water	370.7				0.09	9.0
(b)	Gas	149				0.04	4.0
	Oil	3514.1	403.8	340.9	400	0.89	88.0
	Water	340.9				0.08	9.0