ESP_PRESENTATION_pptx.pptx

1. PAPER
ON
ELECTRICAL SUBMERSIBLE
PUMP (ESP)
BY
SAMPSON, IBINYE ETEYEN

2. CONTENTS
 INTRODUCTION
 ESP SYSTEMS
 ADVANTAGES AND DISADVANTAGES OF ESP
 ESP PERFORMANCE CURVE
 CONCLUSION
 RECOMMENDATIONS

3. INTRODUCTION
ESP, is an efficient and reliable artificial-lift method for lifting
moderate to high volumes of fluids from wellbores.
ESP is used in Old well producing a large volume of water
compared with volume of oil
Pump powered by an electric motor, supplied with current
through an insulated armoured cable
The whole assembly is submerged in the fluid to be pumped
and pushes fluid to the surface.

4. ARTIFICIAL LIFT TECHNOLOGIES
 Plunger lift,
 Beam/Sucker rod pumps,
 Gas lift,
 Electric submersible pumps.

5. The ESP’s main components
 A multistage centrifugal pump
 A seal-chamber section
 A three-phase induction motor
 Power cable
 Downhole controls

6. ESP SYSTEMS

8. ADVANTAGES
 Adaptable to highly deviated wells; up to
horizontal, but must be set in straight section.
 Quiet, safe, and sanitary in an offshore and
environmentally conscious area.
 High-volume pump.
 Increased volumes and water cuts
 Permits placing wells on production even while
drilling
 Good in harsh environment.

9. DISADVANTAGES
 Tolerate minimal % of solids
 Need relatively large (> 4½-in. OD) casing size
for moderate- to high-production-rate equipment.
 Not suitable for viscous fluids.

10. MOTOR
Estimate volume of production.

11. USES OF ESP
 Produced water injection
 Liquid petroleum products
 Disposal or injection fluids
 Fluids containing free gas
 Some solids or contaminates
 CO2 and H2S gases or treatment chemicals
 Produced water disposal
 Waterflood injection
 CO2 flood injection/booster
 Crude oil transfer
 Condensate transfer

12. ESP SELECTION AND PERFORMANCE
CALCULATIONS
1. Basic data: Well data, Production data, Well fluids
conditions, Power sources, Possible production problems.
2 . Production capacity: PI and IPR
3 . Gas calculations: Bg, Bo, Total volume of fluids
4. Total dynamic head, TDH
5. Pump type: pump selection
6. Optimum size of components: Pump, Separator,
Motor, Seal selection
7. Electric cable: Cable size, Cable type, Cable length,
Cable venting
8. Accessory and optional equipment: Downhole
accessory equipment, Motor controllers, Single-phase and
three-phase transformers, Surface cable, Wellheads and
accessories, Servicing equipment, Optional equipment
9. Variable speed submersible pumping system

13. ESP PERFORMANCE CURVE

14. Conclusion
As system design engineers and production
engineers evaluate costs, maintenance
requirements, environmental impact, efficiency
and flexibility, long life of ESP equipment is
required to keep production economical.
Recommendation
ESP should be used for high water cut wells of
up to 75%, to improve productivity.