total sandface flowrate as function of time
drain-area formation pressure as function of time
bottomhole pressure as function of time
One of the Productivity Diagnostics methods based on correlation between cumulative pressure drawdown:
G (t) = \int_0^t \left( p_{wf}(\tau) - p_e(\tau) \right) d\tau |
and total sandface cumulative offtake/intake:
Q_t(t) = \int_0^t q_t(\tau) d\tau |
where
| production/injection time | |
total sandface flowrate as function of time | |
drain-area formation pressure as function of time | |
bottomhole pressure as function of time |
|
| Fig. 1.1. Hall Plot |
It shows unit slope on log-log plot for stabilized reservoir flow:
G(t) = J^{-1} Q_t(t) |
where
| constant productivity index |
It is highly recommended to plot sandface flowrates rather than surface flowrates to achieve better linearity in correlation for stabilized reservoir flow.
Although it is equally applicable to producers and injectors, due to lack of BHP and formation pressure data availability for producers in most practical cases in the past the Hall plot analysis was mostly applied for water injectors.
The pressure drawdown integral is usually calculated over interpolated values of formation pressure and bottomhole pressure :
G(t) = \int_0^t \left( p_{wf}(\tau) - p_e(\tau) \right) d\tau = \sum_k \left( p_{wf}(\tau_k) - p_e(\tau_k) \right) \delta \tau_k |
Petroleum Industry / Upstream / Production / Subsurface Production / Field Study & Modelling / Production Analysis / Productivity Diagnostics
