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 or
.
The concept applies both to producing and injecting wells.
For volatile oil fluid model the total sandface flowrate is related to surface flowrates of fluid components as:
q_t = q_w + q_o + q_g = B_w \, q_W + (B_o - R_v \, B_g) \, q_O + (B_g - R_s \, B_o) \, q_G |
where
| water, oil and gas sandface flowrates | |
| water, crude oil and natural gas surface flowrates | |
| formation volume factors between separator and sandface pressure/temperature conditions | |
| Solution GOR and Vaporized oil ratio at sandface pressure/temperature conditions |
It simplifies for the Black Oil model to:
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:
q_t = B_w \, q_W + B_o \, q_O |
and even simpler for single-phase fluid (water, dead oil or dry gas) with surface flow rate and formation volume factor B:
q_t = q \cdot B |
Non-linear multi-phase diffusion derivation @model