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Under some basic conditions

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 – 
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 the basic equations of 
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pageVolatile/Modified Black Oil Reservoir Flow @model
 – 
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pageVolatile/Modified Black Oil Reservoir Flow @model
 simplify to one equation on average phase pressure for some effective single-phase fluid (see derivation here): 

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\phi \, c_t \, \partial_t P - \nabla \big( M \cdot ( \nabla p - \rho \cdot \mathbf{g} ) \big)  - c \cdot M \cdot (\nabla p)^2  = \sum_k \, q_t(\mathbf{r}k(t) \cdot \delta(\mathbf{r} -\mathbf{r}_k)

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time

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body--uriencoded--%7B\bf r%7D = (x,y,z)

reservoir location

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well–reservoir contact for 

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-th  well


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p = \frac{1}{3} \cdot \left( p_w + p_o + p_g \right)



3-phase average reservoir pressure


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q_t(\mathbf{r}k(t) = q_w + q_o + q_g = B_w \, q_{W,k}(t) + (B_o - R_v \, B_g) \, q_{O,k}(t) + (B_g - R_s \, B_o) \, q_{G,k}(t)



total sandface flowrate
at reservoir location  from/to the 

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-th well


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B_w = B_w(p), \ B_o = B_o(p), \ B_g = B_g(p)



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\phi(\mathbf{r}, \ p) = \phi_0(\mathbf{r}) \exp \left[ - \int_{p_i}^p c_r(p) \, dp \right]



effective porosity
as a function of reservoir location

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and reservoir pressure at this location
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s(\mathbf{r}) = \{ s_w(\mathbf{r}), \ s_o(\mathbf{r}), \ s_g(\mathbf{r})  \}



reservoir saturation
as a function of location

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c_t(s,p, T) = c_r + c_w s_w +  c_o s_o +  c_g s_g  + s_o [ R_{sp} + (c_r  + c_o)  R_{sn} ] + s_g [ R_{vp} + R_{vn}(c_r + c_g) ]



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с_r(p) 



reservoir pore compressibility
as function ofreservoir pressure

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с_w(p, T), \ с_o(p, T), \ с_g(p, T) 



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M(s, p, T) = M_w + M_o \big( 1 + R_{sn} \big) + M_g \big( 1 + R_{vn} \big)



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M_w(s,p, T) = k_a \cdot M_{rw}(s,p, T)



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M_o(s,p, T) = k_a \cdot M_{ro}(s,p, T)



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M_g(s,p, T) = k_a \cdot M_{rg}(s,p, T)



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M_{rw}(s, p, T) = \frac{k_{rw}(s)}{\mu_w(p, T)}



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M_{ro}(s,p, T) = \frac{k_{ro}(s)}{\mu_o(p, T)}



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M_{rg}(s,p, T) = \frac{k_{rg}(s)}{\mu_g(p, T)}



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k_a(\mathbf{r}, \ p, \ \nabla p)  = k_a^{\circ} (\mathbf{r}) \cdot k_p (p, \ \nabla p)



absolute permeability
as a function of location

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, reservoir pressure and reservoir pressure gradient



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k_a^{\circ} (\mathbf{r})



absolute permeability
as a function of location

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at Initial formation pressure, pi and absence of spatial reservoir pressure gradient


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k_p(p, \ \nabla p)



absolute permeability
correction factor for reservoir pressure and reservoir pressure gradient


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\mu_w(p, T), \ \mu_o(p, T), \ \mu_g(p, T)



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R_{sn}(p, T) = \frac{R_s B_g}{B_o} \ , \quad R_{vn}(p, T) = \frac{R_v B_o}{B_g}



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R_{sp}(p, T) = \frac{\dot R_s B_g}{B_o} \ , \quad R_{vp}(p, T) = \frac{\dot R_v B_o}{B_g}



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\rho(p, T) = \frac{ M_{rw} \rho_w + M_{ro}  (1 + R_{sn}) \rho_o  + M_{rg}  (1+R_{vn}) \rho_g }{ M_{rw}  + M_{ro}  (1 + R_{sn})  + M_{rg}  (1+R_{vn}) }





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g = 9.81 \ \textrm{m} / \textrm{s}^2



standard gravity


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 \big (   \big)^{\LARGE \cdot} = \frac{d}{dp}



differentiation
with respect to the pressure

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