Total produced or injected flowrate of all fluids across the well-reservoir contact with the volumes measured at the sandface temperature and pressure conditions.
Usually abbreviated as q_t or qB.
For the volatile oil fluid model the total sandface flowrate is related to surface flowrates of fluid components as:
| (1) | q_t = B_w \, q_W + \frac{B_o - R_v B_g}{1 - R_v R_s} \, q_O + \frac{B_g - R_s B_o}{1 - R_v R_s} \, q_G |
where
\{ q_W, \, q_O, \, q_G \} | water, oil, gas surface flowrates |
\{ B_W, \, B_O, \, B_G \} | formation volume factors between separator and sandface pressure/temperature conditions |
\{ R_s, \, R_v \} | Solution GOR and Vaporized oil ratio at sandface pressure/temperature conditions |
It simplifies for the Black Oil model to:
| (2) | q_t = B_w \, q_W + B_o \, q_O + (B_g - R_s B_o) \, q_G |
and simplifies further down to production from undersaturated reservoir as:
| (3) | q_t = B_w \, q_W + B_o \, q_O |
and even simpler for single-phase fluid with surface flow rate q and formation volume factor B:
| (4) | q_t = q \cdot B |