A model has been developed to optimize sizing the staging and brake horsepower requirements for an electrical sub-mersible pump (ESP) in a solution-gas-drive horizontal well. Three components are examined by the model, reservoir in-flow performance, casing and tubing outflow performance, and pump performance. Since severe gas slugging has been a characteristic of many horizontal wells, the gas slugging potential is monitored during the pressure traverse from where the fluid flows into the wellbore to the pump set depth. Flexibility for handling the gas at the pump intake has been included. The model can take into account the gas removed by a gas separator and the gas produced up the annulus. Actual data provided from norizontal wells producing with electrical submersible pumps has been used to verify the model's relative accuracy in sizing.

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