Electrical submersible pumps could be installed in four different production environments where the criteria for the design changes as fluid properties and well conditions change. In this article, four basic design types of ESP’s will be presented.
The basic designs will change accordingly and will mainly
Downhole flow rate can be calculated from surface flow rate (stock tank barrels) using the following equation. It is assumed that no gas is dissolved in the water phase and the water formation volume factor is equal to one.
In this article “ Total Dynamic Head Calculation ”, the concept of the dynamic head is further detailed. As discussed in the previous article titled: “Total Dynamic Head (TDH)”, TDH is the sum of three basic components:
Net Vertical Lift (NL) = is the net distance where the fluid must be lifted,
Tubing Friction Loss (TFL) = Flow disturbance in the tubing string during pumping process,
Tubing Head Pressure (THP) = Pressure which the unit must pump against (back pressure caused by choking on well head).
To properly select the pump, well performance must be estimated. Fundamentally, well performance estimates deﬁne what additional energy (i.e., volumetric ﬂow rate and differential pressure or head) must be supplied by the pump to deliver a desired stock tank ﬂow rate (API RP11 S4).
It is common to simplify the procedure by combining or summarizing the additional energy that the pump must supply into a single term, Total Dynamic Head (TDH). TDH is a summation of the net vertical distance ﬂuid must be lifted from an operating ﬂuid level in the well, the frictional pressure drop in the tubing and the desired wellhead pressure.