Design and Simulation Studies on An ESP System

Design and Simulation Studies on An ESP System

Dasari Venkata Manoj

Department of Petroleum Engg & Petrochemical Engineering

JNTUK, Kakinada, Andhra Pradesh, India

Pampana Anil Kumar

Department of Petroleum Engg & Petrochemical Engineering

JNTUK, Kakinada, Andhra Pradesh, India

Sreenivas Matla

Department of Petroleum Engg & Petrochemical Engineering

JNTUK, Kakinada, Andhra Pradesh, India

Koppisetti Srinivasa Rao

Department of Petroleum Engg & Petrochemical Engineering

JNTUK, Kakinada, Andhra Pradesh, India

Abstract – Artificial lift methods are used for the enhancement of productivity from oil wells. These methods are implemented in oil wells whose energy from the reservoir is insufficient to lift the fluids to the surface. In this study about Electrical submersible pump and its design & simulation in PROSPER software. It is one of the important type of artificial lift methods, which is used to lower the producing bottom hole pressure on the formation to obtain a higher production rate from the well. It is an efficient and reliable method for lifting moderate to high volumes of fluids from wellbores. PROSPER is a well performance, design and optimization computer software for modelling most types of well configurations. This study major focuses on the design and simulation of an ESP system for wells having different productivity index using the PROSPER software.

Keywords: Artificial lift methods, Electrical submersible pump, PROSPER software, Well performance.

1. INTRODUCTION

   The artificial lift system of a well resembles the human heart which pumps the high volumes of reservoir fluids to the surface in low producing wells. These methods are employed in oil wells whose energy from the reservoir is insufficient to lift the fluids to the surface. Most of the producing wells in the world nearly 90 % are presently working on the artificial lift system from early stages. Among the available artificial lift methods, the electrical submersible pump (ESP) system is very effective in wells with low bottom hole pressure, low gas to oil ratio, low bubble point pressure, high water cut, and deviated wells [1].

   Electrical Submersible Pump System

   History and origin:

   A Russian engineer named Armais Arutunoff in 1911 invented an electric motor that can be worked on the water. By the addition of a drill and centrifugal pump to the motor, he invented an electrical submersible pump. Later he improves the system and invented the Russian Electrical Dynamo of Arutunoff for which Schlumberger is currently acting as a service provider [1].

   Some of the ESP System Service Providers are listed: Schlumberger- REDA, Weatherford, Baker Hughes- Centrilift, Wood Group ESP, ALNAS.

   Components:

   The components of an ESP System can be categorized into surface and downhole components are listed [2]: a). Surface Components: Transformers, Motor controllers, Junction box, Well Head. b). Downhole Components: Electrical Cable, Cable Protectors, Pumps, Gas Separator, Seal section, Motor, Pump intake, Drain valve, Check valve. The ESP System along with its components labelled is shown in Fig.1.0.

   Working Principle of ESP System:

   Electrical Submersible Pumps are the vertical alignment of centrifugal pumps in the borehole which accelerates the velocity of fluids by impellers. The kinetic energy produced by the impellers is converted into pressure energy by the diffuser and pumps the fluid. An Electrical Submersible Pump is a multi-stage stacked centrifugal pump whose stages are determined by bottom hole pressure and desired flow rate. The arrangement of each stage of an ESP System consists of an impeller and diffuser. When the fluid enters the impeller of the first stage, it centrifuges the liquid radially outward and increases the velocity of the fluid. Now the fluid enters the diffuser from the sharp edges of the impeller where the kinetic energy of the fluid is converted into pressure energy. The pressure gained by the fluid in the first stage and enters the next stage where the pressure is increased slightly than the first stage. As the stages are increase, the pressures are gaining incrementally in each stage to desired discharge pressure and designed head of the pump [1].

   Figure 1.0: ESP System and its components

   Advantages, Disadvantages, and Industrial applications of ESP system:

   The major advantages of an ESP system [3,4,5]:

   • Capable of pumping high viscous crude oils to the surface.

   • It can be applied to well having low bottom hole pressure.

   • ESP System has a low tendency of scale forming operating conditions.

   • It has a capacity to produce high volumes of fluids up to 18,000 barrels/day to surface.

   • High efficiency and low operating costs. The major disadvantages of an ESP system [3,4]:

   • It can take high repair and maintenance costs.

   • It is not applicable to high GOR producing wells.

   • The efficiency of the motor is reduced in sand producing wells and sand producing wells will cause mechanical repairs to wells.

   • ESP System installation is very critical in highly deviated and dogleg severity wells.

   • Special equipment is needed for the repair of the ESP system in deviated wells.

   • It is not applicable to the high temperature and deep wells.

     The Industrial applications of an ESP system [3, 4, 5]:

   • High productive index wells.

   • Offshore wells.

   • Mostly deviated and horizontal wells.

   • ESP is also used for the dewatering purpose of the wells.

   Economic analysis of an ESP system:

   The better economic evaluation of an ESP System is carried out through the PROSPER software and production can be forecasted in different scenarios for 5-6 years. ESP generates higher gross profits because it produces high potentials of reservoir fluids. On other hand it can also have high operating expenses due to high water cuts and the replacement of failed pumps.

2. DESIGN AND SIMULATION STUDIES ON ESP SYSTEM USING THE PROSPER SOFTWARE

   PROSPER is a production optimization software used to models the well completions configuration and design artificial lift methods. It predicts the reservoir fluid properties as a function of temperature and pressure. It simulates the optimized results for the particular artificial lift method based on input data. PROSPER distinctive matching options that tune PVT, multi-phase flow correlations and IPR to match measured field information. It is accustomed style and optimize well completions as well as multi-lateral, multi-layer and horizontal wells, conduit and pipeline sizes [6,7,8].

   Stepwise Procedure for Design of ESP System Using PROSPER Software

   • First click on file option and select the new file.

   • Now in the system summary, water and oil with Black Oil model options are chosen for fluid description and

     choose Electrical Submersible Pump for artificial lift method.

   • Enter the PVT parameters in the PVT input data window and match data with correlations to get the least deviation.

   • After matching PVT data, input reservoir operating parameters in the IPR window to develop the inflow performance relation (IPR) curve and determine the absolute open flow.

   • Enter deviation survey data, downhole equipment data, surface equipment data, (if available) and geothermal gradient data in their respective windows.

   • Enter desirable design parameters and calculate the output design parameters and generate a plot based on output design parameters.

   • From the plot generated, choose the optimum operating design of ESP System.

   We consider two wells having different productivity index wells (i.e. High and Low) for the design of the ESP System.

   Design of ESP System for low productivity index of a well:

   The following table 1 delineates the reservoir and fluid input data for the PROSPER software to design the ESP System for the low productivity index of a well.

   Table 1: Reservoir and Fluid Input Data

   Reservoir and Fluid Input Data
   Reservoir pressure	3200 psi
   Bubble point pressure	1500 psi
   Reservoir Temperature	1800F
   GOR	300 scf/stb
   Water cut	75 %
   Oil API	320API
   Gas specific gravity	0.7
   Water salinity	80000 ppm
   Oil FVF	1.2 bbl/stb
   Oil viscosity	0.31 cp
   Productivity index	2 stb/day. psi

   After giving the reservoir and fluid input data to the software, inflow performance relation (IPR) curve is generated and the absolute open flow (AOF) of the well is determined. The Fig. 2.0. Illustrates the IPR curve for low productivity index well with AOF.

   Figure 2.0: IPR curve of a low productivity index well

   According to the absolute open flow rate, give the desirable design parameters to software as shown in table 2 and generate calculated output design of ESP System as shown in table 3.

   Table 2: Input Design Data

   Input data
   Pump depth(measured)	5500 ft
   Operating frequency	60 Hz
   Maximum pump outside diameter	6 in
   Length of cable	7000 ft
   Design rate	5300 stb/day
   Water cut	75%
   Top node pressure	300 psig

   Table 3: Calculated Design Data

   Calculated Design Data
   Pump Intake Pressure	11.33 psig
   Pump Intake Rate	53911.2 Rb/Day
   Free GOR Entering Pump	298.6 scf/STB
   Pump Discharge Pressure	2498.9 psig
   Pump Discharge Rate	5626.7 Rb/Day
   Total GOR Above Pump	300 scf/STB
   Average Downhole Rate	6946 Rb/Day
   Head Required	7417.6 ft
   Pump Inlet Temperature	174.460F

   On the basis calculated design data, select the better downhole equipment like pump, motor and electrical cable for well having low productivity index (PI = 2) available in the software. For the selected equipment generate optimum output results are presented in table 4 and the design plot of a ESP system as shown in Fig. 3. 0. From the plot generated the best efficiency and better operating conditions of system.

   Table 4: Results for selected Equipment

   Results
   Number of Stages	341
   Power Required	459.79 HP
   Pump Efficiency	63.812 %
   Pump Outlet Temperature	186.59 0 F
   Current Used	116.48 amps
   Motor Efficiency	82.83 %
   Power Generated	459.79 HP
   Motor Speed	3438.53 rpm
   Voltage Drop along Cable	303.75 volts
   Voltage Required at Surface	2778.75 volts

   Design of ESP System for high productivity index of a well:

   The following table 5 below represents the reservoir and fluid input data for the PROSPER software to design ESP System for low productivity index of a well.

   Table 5: Reservoir and Fluid Input Data

   Reservoir and Fluid Input Data
   Reservoir pressure	5500 psig
   Bubble point pressure	3500 psi
   Reservoir Temperature	2500F
   GOR	500 scf/stb
   Water cut	50 %
   Oil API	32o API
   Gas specific gravity	0.72
   Water salinity	75000 ppm
   Oil FVF	1.42 bbl/stb
   Oil viscosity	0.5 cp
   Productivity index	6.5 stb/day. psi

   After giving the reservoir and fluid input data to the software, an inflow performance relation (IPR) curve is generated and the absolute open flow (AOF) of the well is determined. The figure 4 delineates the IPR curve for the high productivity index well with AOF.

   Figure 4: IPR Curve for high productivity index well

   Based on the absolute open flow rate, give the desirable design parameters to software as shown in table 6 and generate calculated output design of ESP System as show in table 7.

   Figure 4: ESP Design plot for low productivity index well

   Table 6: Input Design Data

   Input data
   Pump depth(measured)	12200 ft
   Operating frequency	60 Hz
   Maximum pump outside diameter	6 in
   Length of cable	13400 ft
   Design rate	13000 stb/day
   Water cut	50 %
   Top node pressure	350 psig

   Table 7: Calculated Design Data

   Calculated Design Data
   Pump Intake Pressure	3209.97 psig
   Pump Intake Rate	15319.9 Rb/Day
   Free GOR Entering Pump	52.73 scf/STB
   Pump Discharge Pressure	4575.05 psig
   Pump Discharge Rate	15036.3 Rb/Day

   Total GOR Above Pump	500 scf/STB
   Average Downhole Rate	15122.5 Rb/Day
   Head Required	3676.2 ft
   Pump Inlet Temperature	174.460F

   Total GOR Above Pump	500 scf/STB
   Average Downhole Rate	15122.5 Rb/Day
   Head Required	3676.2 ft
   Pump Inlet Temperature	174.460F

   Parameters	Low Productivity Index Well	High Productivity Index Well
   Pump setting depth	Low	High
   Design Rate	Low (5300 STB/Day)	High (13000 STB/Day)
   Water cut	High (75 %)	Low (50%)
   Pump Intake Pressure	Low	High
   Pump Intake Rate	High	Low
   Pump discharge Rate	Low	High
   Head Required	High	Low
   Number of Stages	High	Low
   Pump efficiency	Low	High
   Voltage Drop along Cable	Low	High

   Parameters	Low Productivity Index Well	High Productivity Index Well
   Pump setting depth	Low	High
   Design Rate	Low (5300 STB/Day)	High (13000 STB/Day)
   Water cut	High (75 %)	Low (50%)
   Pump Intake Pressure	Low	High
   Pump Intake Rate	High	Low
   Pump discharge Rate	Low	High
   Head Required	High	Low
   Number of Stages	High	Low
   Pump efficiency	Low	High
   Voltage Drop along Cable	Low	High

   Table 9: Comparison of results of two wells

   Based on calculated design data, select the better downhole equipment like the pump, motor, and electrical cable for well having high productivity index (PI = 6.5) available in the software. For the selected equipment generate optimum output results are shown in table 8 and the ESP Design plot as depicts in figure 5. From the plot generated the efficiency and better operating conditions are determined.

   Table 8: Results for selected Equipment

   Results
   Number of Stages	66
   Power Required	508.28 HP
   Pump Efficiency	69.235 %
   Pump Outlet Temperature	253.41 0 F
   Current Used	112.42 amps
   Motor Efficiency	82.83 %
   Power Generated	508.79 HP
   Motor Speed	3441.53 rpm
   Voltage Drop along Cable	509.07 volts
   Voltage Required at Surface	3344.07 volts

   Figure 5: ESP Design plot for high productivity index well

   Comparison between the High Productivity and Low Productivity Index of Wells:

   The following table 9 represents comparison of results of low productivity index well and high productivity index well which are taken as case studies.

3. CONCULSION

   From the Design of ESP Systems of two wells, we studied that a greater number of stages of pumping and high head is required for low productive well, due to these factors the pump efficiency is decreased. More over Pump intake pressure and Pump discharge pressure are decreased because of its low producing rates. The same conditions are vice versa for high productive wells.

4. ACKNOWLEDGMENT

   I would prefer to specific my profound sense of feeling to guide Mr, P. Anil Kumar, Asst. Professor, Department of Petroleum Engineering and Petrochemical Engineering, JNTUK, Kakinada, for his or her skillful steerage, timely suggestions and encouragement in finishing this paper.

5. REFERENCES

1. Rick Van Flatern, Electrical Submersible Pumps the Defining Series, Senior Edition, 2014.

2. Matthew Amao, Lecture notes on Electrical Submersible Pumping (ESP) Systems, 2014.

3. Quartz School for Well Site Supervisors, Module 12: Well Completions / Section 2: The Completion String & Accessories, 2004.

4. Abdelhady A, Gomaa S, Ramzi H, Hisham H, Galal A and Abdelfattah A, Electrical Submersible Pump Design in Vertical Oil Wells, Petroleum & Petrochemical Engineering Journal ISSN: 2578- 4846, 2020.

5. Boyun Guo, William C. Lyons, Ali Ghalambor, Petroleum Production Engineering A Computer Assisted Approach Elsevier Science & Technology Books, 2007.

6. Petroleum Experts IPM PROSPER Version 11.5, User Manual, 2015.

7. Knut Undheim Stanghelle, Evaluation of artificial lift methods on the Gyda field, Master thesis, 2009.

8. Imran A. Hullio*, Sarfraz A. Jokhio, Khalil Rehman Memon, Sohail Nawab and Khair Jan Baloch, Design and Economic Evaluation of the ESP and Gas Lift on the Dead Oil Well International Journal of Current Engineering and Technology,2018.