Uncertainty and Sensitivity Analysis for a Model of an Electric Submersible Pump Lifted Oil Field

Sharma, Roshan; Glemmestad, Bjørn

doi:10.7763/ijmo.2014.v4.386

Cited by 7 publications

(27 citation statements)

References 9 publications

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“…Detailed modeling and simulation of the oil field can be found at [9]. In this paper, only the final equations of the model of the oil field have been rewritten similar to the paper by [10], [11] however with few improvements and details.…”

Section: Model Of the Oil Fieldmentioning

confidence: 99%

“…Viscosity is a function of Water Cut (WC) of the fluid. In [9]- [13], the water cut of each oil well of the field is assumed to be the same. In this paper, we consider that the oil wells of the field have different water cut values as listed in Table I.…”

Section: B Esp Modelmentioning

confidence: 99%

“…Hydraulic Institute Model (HIM) for viscosity correction [15] is used to correct the pump characteristics for pumping a viscous fluid as detailed in [9]. The kinematic viscosity of the fluid in centiStoke used in HIM is,…”

Section: B Esp Modelmentioning

confidence: 99%

“…The production choke valves cannot be opened/closed by more than 1% per second and the speed of the ESPs cannot be changed by more than 1 Hz per second if the pumps are working inside the operating window. However, for shutting down a well, specific actions are applied as follows [9]:…”

Section: Simulation Examplementioning

confidence: 99%

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Mixed Integer Nonlinear Optimization for ESP Lifted Oil Field and Improved Operation through Production Valve Choking

Sharma¹,

Glemmestad²

2014

IJMO

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Abstract-The demand for the total production of oil from an Electric Submersible Pump (ESP) lifted oil field may vary with time. It may not always be economically profitable to use all of the available oil wells for varying production rates. Depending on the amount of oil to be produced from the oil field, some of the oil wells may have to be shut down. The number of oil wells to be used should be properly selected. Not only the number of oil wells should be known, but which wells to use should also be exactly identified. The operating speed of the ESP and the production choke valve opening of each selected oil well should be optimally chosen so that the profit from the oil field is maximized by keeping the operational expenses at the minimum. The oil well scheduling problem is formulated as a Mixed Integer Nonlinear Programming (MINLP) problem. The cost of the electrical power consumed by the pumps, the operational cost of separation process and the income from the oil production are considered for the MINLP formulation. In the first part of the paper, the production choke valves are always fully opened and the number of wells and their respective pump speeds are calculated for varying total production flow rates. However, in the second half of the paper, it is shown that the operation of the oil field can be improved in terms of power consumption through production valve choking.Index Terms-Mixed integer nonlinear programming, ESP lifted oil field, well scheduling, optimal operation, production valve choking. I. INTRODUCTIONIn an ESP lifted oil field, multiple oil wells are connected in parallel to a common gathering manifold. The oil produced from each of the wells is collected by the gathering manifold and then transported to the separator through the transportation lines (see Fig. 4). Each oil well is fitted with a multistage centrifugal pump. The main operational expense in the oil field is the total cost of power consumed by the pumps and the cost of operating the separator. The income is the production of crude oil from the field. The energy costs associated with the operation of the pumps in an ESP lifted oil field is of great significance when multiple oils wells are considered. The cost of operating the separator is less significant compared to the energy costs of the pumps.The total amount of oil to be produced from the field may vary. For higher production rates from the oil field, all of the available oil wells may be used to meet the demand. On the contrary for lower production rates, some of the oil wells of the oil field can be shut down to meet the lower production demand. The lower the pump speed, the lower is the fluid flow rate through the well. However, running all of the available oil wells at lower pump speeds for fulfilling lower production demands might not be beneficial. The wells might be consuming more power than what is actually needed. Shutting down an oil well reduces the consumption of electric power as the ESP for the well is turned off. So, the balance between fulfilling the to...

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Section: Model Of the Oil Fieldmentioning

confidence: 99%

Section: B Esp Modelmentioning

confidence: 99%

Section: B Esp Modelmentioning

confidence: 99%

Section: Simulation Examplementioning

confidence: 99%

See 2 more Smart Citations

Mixed Integer Nonlinear Optimization for ESP Lifted Oil Field and Improved Operation through Production Valve Choking

Sharma¹,

Glemmestad²

2014

IJMO

Self Cite

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“…A detailed model of the oil field including the model of the pump and the oil wells can be found at Sharma and Glemmestad (2013). In this paper, only the final equations of the oil field model have been rewritten.…”

Section: Model Of the Oil Fieldmentioning

confidence: 99%

Optimal control strategies with nonlinear optimization for an Electric Submersible Pump lifted oil field

Sharma¹,

Glemmestad²

2013

MIC

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In an Electric Submersible Pump (ESP) lifted oil field, the ESP of each oil well should be operated inside its operating window. The total power consumed by the ESPs in the oil field should be minimized. The speed of the ESPs and the production choke valve opening should be optimally chosen for maximizing the total oil produced from the oil field. At the same time, the capacity of the separator should not be exceeded. In this paper, nonlinear steady state optimization based on Sequential Quadratic Programming (SQP) is developed. Two optimal control structures are proposed in this paper. In the first case, the optimal pump speed is controlled by a PI controller by varying the electrical excitation signal to the motors. The optimal fluid flow rate through each oil well is controlled by another PI controller by varying the production choke valve opening. The paper shows that the production choke valve for each oil well has to be always 100% open to maintain the optimal fluid flow rate. In the second case, the production choke valves are considered to be always 100% open as hard constraints. The optimal fluid flow rate through each oil well is controlled by a PI controller by varying the pump speed. It is shown that when the optimal fluid flow rate is tracked by the controller, the speed of each of the pumps is equal to the optimal pump speed calculated by the optimizer. This basically means that we can achieve the optimization objective with the same optimal results as in the first case by using only a single PI controller. The limitations of these two optimal control structures for very low values and for very high values of the separator capacity are discussed. For the feasible range of separator capacities, the optimal locus of the fluid flow rate and the pump speed are shown in this paper.

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A Bayesian approach to the dynamic modeling of ESP-lifted oil well systems: An experimental validation on an ESP prototype

Costa

Abreu

Silva

et al. 2021

Journal of Petroleum Science and Engineering

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Uncertainty and Sensitivity Analysis for a Model of an Electric Submersible Pump Lifted Oil Field

Cited by 7 publications

References 9 publications

Mixed Integer Nonlinear Optimization for ESP Lifted Oil Field and Improved Operation through Production Valve Choking

Mixed Integer Nonlinear Optimization for ESP Lifted Oil Field and Improved Operation through Production Valve Choking

Optimal control strategies with nonlinear optimization for an Electric Submersible Pump lifted oil field

A Bayesian approach to the dynamic modeling of ESP-lifted oil well systems: An experimental validation on an ESP prototype

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