Research Article

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 5

Comparison of estimates between conventional and numerical density parameters.

ScenarioNumerical density method Calculated
(mD)
Conventional
(mD)
Simulation
model (mD)
Relative % phase
contribution to flow
Phases (mD)

(a)Gas15.80.033.0
Oil403.747.350.850.00.8686.0
Water50.80.1111.0

(b)Gas120.032.0
Oil484.443.250.050.01.1389.0
Water500.129.0

(c)Gas20.90.044.0
Oil484.257.050.050.00.8687
Water500.099.0

(d)Gas17.50.033.0
Oil49052.350.050.00.9588.0
Water500.109.0