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, crude oil and 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 |
See also
Non-linear multi-phase diffusion derivation @model