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Total produced or injected flowrate of all fluids of natural gas across the well-reservoir contact with the volumes measured at the sandface temperature and pressure conditions.
Usually abbreviated as
or .
For the volatile oil fluid model the total sandface flowrate is related to surface flowrates of fluid components asnatural gas as:
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q_tg = B_wg \, ( q_W + \frac{B_o G - 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)
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where
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| body | \{ q_W, \, q_O, \, q_G \} |
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| water, crude oil, and natural gas surface flowrates |
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| body | \{ B_w, \, B_o, \, B_g \} |
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| 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:
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q_t = B_w \, q_W + B_o \, q_O + (B_g - R_s B_o) \, q_G
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and simplifies further down to production from undersaturated reservoir as:
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q_t = B_w \, q_W + B_o \, q_O
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simplifies for gas reservoir with surface flow rate
and gas formation volume factor :| LaTeX Math Block |
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q_tg = q_G \cdot B_g
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See also
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Non-linear multi-phase diffusion derivation @model
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