| CPC E21B 49/08 (2013.01) [G01V 99/005 (2013.01); G06F 30/20 (2020.01); E21B 43/00 (2013.01); E21B 2200/20 (2020.05)] | 13 Claims |
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1. A method, comprising:
obtaining, by a reservoir simulator, a coarse grid model comprising a plurality of wellbore radial grid portions and model data for a reservoir region of interest;
obtaining, by the reservoir simulator, reservoir pressure data from a plurality of pressure sensors and a plurality of flowrate sensors coupled to one or more wells penetrating the reservoir region of interest;
obtaining, by the reservoir simulator, multi-fluid phase data from the plurality of flow rate sensors for gas production from one or more wellheads among the one or more wells;
determining, by the reservoir simulator, a plurality of time steps for a reservoir simulation of the reservoir region of interest, wherein the plurality of time steps comprise a first time step and a second time step;
determining, by the reservoir simulator and for the first time step within an iterative simulation process, a plurality of first pseudo-pressure values based on the model data and the reservoir pressure data;
determining, by the reservoir simulator and for the first time step, a plurality of first dynamic skin factor values for the plurality of wellbore radial grid portions using the plurality of first pseudo-pressure values and the multi-fluid phase data, wherein the plurality of first dynamic skin factor values corresponds to gas mobility within the reservoir region of interest, and wherein first dynamic skin factor values among the plurality of first dynamic skin factor values differ based on a radial distance from a production well within the reservoir region of interest;
predicting, by the reservoir simulator and for the first time step, a first well production rate for the production well using the plurality of first dynamic skin factor values and a first pressure distribution for the reservoir region of interest;
determining, by the reservoir simulator and for the second time step within the iterative simulation process, a plurality of second pseudo-pressure values based on the first well production rate;
determining, by the reservoir simulator and for the second time step, a plurality of second dynamic skin factor values for the plurality of wellbore radial grid portions using the plurality of second pseudo-pressure values, wherein the plurality of second dynamic skin factor values is different from the plurality of first dynamic skin factor values; and
predicting for the second time step within the iterative simulation process, a second well production rate using the plurality of second dynamic skin factor values and a second pressure distribution for the reservoir region of interest.
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