Electrical Submersible Pumps (ESP) Quiz

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Questions and Answers

Match the artificial lift methods with their typical operating depth (TVD):

Rod Pump = 100 to 2000 ft PCP = 10000 ft ESP = 5000 ft Hydraulic Piston = 10000 ft

Match the artificial lift methods with their maximum operating depth (TVD):

Gas Lift = 20000 ft Plunger Lift = 15000 ft Hydraulic Jet = 15000 ft PCP = 6000 ft

Match the artificial lift methods with their typical operating volume (BFPD):

Rod Pump = 5 to 1500 BFPD ESP = 50 to 500 BFPD Hydraulic Piston = 100 - 10000 BFPD Hydraulic Jet = 300 - 4000 BFPD

Match the artificial lift methods with their primary characteristics:

Rod Pump = Positive Displacement ESP = Dynamic Displacement PCP = Positive Displacement Hydraulic Jet = Dynamic Displacement Signup and view all the answers

Match the artificial lift methods with the type of lift mechanism used:

Gas Lift = Gas Injection Plunger Lift = Mechanical Plunger Hydraulic Piston = Fluid-driven Piston ESP = Electrical Submersible Signup and view all the answers

Match the following design considerations with their associated terms:

Capital cost = Downhole equipment Operating costs = Efficiency Reliability = Flexibility Salvage value = Miscellaneous problems Signup and view all the answers

Match the following normal operating considerations with their relevant aspects:

Casing size limits = Depth limits Noise level = Obtrusiveness Surveillance = Testing Time cycle = Pump-off controllers Signup and view all the answers

Match the artificial lift considerations with their corresponding capabilities:

Corrosive handling = Slim-hole completions Gas-handling ability = High-viscosity fluid handling Multiple completions = Offshore application Paraffin-handling capability = Low-volume lift capabilities Signup and view all the answers

Match the efficiency factors with their applications:

High-volume lift capabilities = Gas-handling ability Temperature limitations = Crooked/deviated holes Solids/sand-handling ability = High-viscosity fluids Prime mover flexibility = Intake capabilities Signup and view all the answers

Match the terms related to system evaluation with their significance:

Operational usage = Applications need evaluation Overall system = Total operating costs Flexibility = Reliability Salvage value = Cost considerations Signup and view all the answers

Match the following advantages of Electrical Submersible Pumps (ESP) with their descriptions:

Cost efficiency = High volume applications High-temperature capability = Can operate in wells above 350°F Corrosive fluid handling = Pumps can be modified for corrosive fluids Adaptability = Can be used in high-angle and horizontal wells Signup and view all the answers

Match the following disadvantages of Electrical Submersible Pumps (ESP) with their implications:

Gas lock or sand damage = Potential damage to the pump High GOR fluid production = Downhole gas separator required Limited production ranges = Changes in production rates require pump adjustments Repair requirements = Tubing must be pulled for repairs or replacements Signup and view all the answers

Match the components of the Electric Submersible Pump (ESP) system with their functions:

Downhole centrifugal pump = Pumps fluid to the surface Submersible electric motor = Drives the pump from below Armored cable = Provides power and control Power source = Supplies electricity to the motor Signup and view all the answers

Match the following characteristics of Plunger Lift with their descriptions:

Relies on natural energy = Uses the well’s natural energy to lift fluids Plunger mechanism = Drops from the surface into production tubing Pressure dynamics = Moves upward when gas pressure exceeds liquid pressure Fluid accumulation = Occurs when pressure or production rate decreases Signup and view all the answers

Match the following types of fluids associated with ESP systems to their characteristics:

Corrosive fluids = Pumps can be modified to handle High water-cut production = Can be managed by ESP systems Gas-oil ratio (GOR) = Impacts the need for downhole separators Sand production = May damage ESP pumps if not controlled Signup and view all the answers

Match the following production ranges handled by ESP systems with their values:

Minimum fluid volume = 100 B/D Maximum fluid volume = 60,000 B/D High-temperature operations = Above 350°F Corrosive fluid capacity = Modifications required on pumps Signup and view all the answers

Match the following aspects of ESP pump installation with their challenges:

High-angle wells = Requires placement in straight sections Well length = Assembly can be several hundred feet long Repair complexities = Tubing must be pulled for maintenance Production rate adjustments = Involves pump changes or variable-speed drives Signup and view all the answers

Match the following ESP systems components with their specific purposes:

Submersible motor = Drives the pump assembly Cables = Connects pump to power source at the surface Pump stages = Determine the production capabilities Gas separators = Required for high GOR fluid wells Signup and view all the answers

Match the artificial lift method with its primary characteristics:

Gas Lift = Economical in remote fields with no gas market Rod Pumping = Overwhelming choice for typical onshore wells ESP = Proper lift approach for high volume wells PCP = Favorable results for solids production such as sand Signup and view all the answers

Match the comparison basis with its description:

Initial Capital Cost = Upfront investment required for installation Monthly Operating Expense = Regular costs incurred during operation Equipment Reliability = Likelihood of the system functioning without failure Expected Producing Life = Duration a well is projected to produce effectively Signup and view all the answers

Match the artificial lift conditions with their ideal lift system:

Multiple Wells = Gas lift's economical choice Short Producing Life = Capital costs play an important role Little Gas Production = Best practice is plunger lift Deviated Wells = Hydraulic pumping as the application of choice Signup and view all the answers

Match the lift system characteristics with their challenges:

Gas Lift = High gas prices reduce profitability Submersible Pumps = Less attractive where electricity is not available Hydraulic Pumping = Capital and operating costs affect choice PCP = Shows favorable results in waterflood supply wells Signup and view all the answers

Match the operational factors with their impact on lift system choice:

High Gas Prices = Increases operating expenses for gas lift Prevalence of Equipment = Affects attractiveness of lift systems Surface Compression Facilities = Not ideal for one or two-well systems Remote Field Locations = Favor gas lift due to gas market absence Signup and view all the answers

Match the lift methods with their preferred scenarios:

Gas Lift = Widely used offshore due to space constraints Rod Pumping = Preferred for typical onshore well applications ESP = Effective for wells with little gas or solids Plunger Lift = Common for gas wells with minimal water production Signup and view all the answers

Match the lift system types with their key advantages:

Hydraulic Pumping = Effective for deviated wells PCP = Suitable for handling solids in production Gas Lift = Cost-efficient in specific production scenarios Rod Pumping = Proven success in onshore applications Signup and view all the answers

Match the factors that influence the choice of artificial lift systems:

Equipment Reliability = Can influence maintenance strategies Capital Cost Considerations = Critical in uncertain well performances Operating Costs = Directly related to gas pricing fluctuations Expected Life of Wells = Determines long-term investment viability Signup and view all the answers

Match the artificial lift systems with their main challenges in horizontal wells:

Rod Pumping Systems = Gas locking and rod wear Gas Lift Systems = Installation difficulties Beam Pumping = Sensitivity to gas locking Coiled Tubing Systems = Restricted to vertical applications Signup and view all the answers

Match the components with the appropriate artificial lift system challenges:

Fluid head = Increases back pressure in rod pumps Wireline tools = Limited deviation angle for gas lift Solid-liquid slugs = Problems in undulating sections for gas lift Rod guides = Prevent tubing erosion in rod systems Signup and view all the answers

Match the terms with their relevant descriptions:

Gas segregation = Gas gathers at high points in horizontal wells Fluid head = Pressure difference due to pump setting depth Undulating lateral leg = Area where liquids and solids can collect Back pressure = Lowers production rate in rod pumping Signup and view all the answers

Match the artificial lift methods with their area of efficiency:

Beam Pumping = Widely applied but prone to gas locking Gas Lift = Effective in laterally undulating sections Rod Pumping = Requires rod guides to minimize wear Coiled Tubing = Facilitates gas lift equipment deployment Signup and view all the answers

Match the keywords with their significant effects in horizontal wells:

Gas locking = Causes a drop in production rates Erosion = Results from rod tubes sliding against tubing Fluid head = Affects back pressure on the reservoir Slug flow = Can complicate production in horizontal segments Signup and view all the answers

Match the artificial lift systems with their typical orientations:

Rod Pumping Systems = Most efficient in vertical and horizontal wells Gas Lift Systems = Used widely in vertical but limited in horizontal Beam Pumping = Common in both orientations but sensitive to gas Coiled Tubing = Used for deploying gas lift in horizontal wells Signup and view all the answers

Match the challenges with their impact on production efficiency:

Gas segregation = Reduces production during horizontal operation Rod wear = Increases maintenance needs for rod pumps Installation difficulties = Impacts gas lift setup in horizontal directions Fluid head = Creates additional pressure and lowers output rates Signup and view all the answers

Match the methods with their specific installation requirements:

Gas Lift Systems = Require coiled tubing for horizontal legs Rod Pumping Systems = Need rod guides to prevent erosion Wireline tools = Limited to vertical applications only Coiled Tubing Systems = Allows efficient equipment deployment in deviated wells Signup and view all the answers

Match each artificial lift mechanism with its primary characteristic:

Rod Pump = Limited to ~1000 BFPD in deviated wells Gas Lift = High gas rates required to lift Electric Submersible Pump (ESP) = Excellent if > 20,000 BFPD Plunger = Good liquid removal with up to 20° deviation Signup and view all the answers

Match the artificial lift options with their gas tolerance:

Rod Pump = Poor gas tolerance Gas Lift = Excellent gas tolerance Electric Submersible Pump (ESP) = Poor gas tolerance Plunger = Moderate gas tolerance Signup and view all the answers

Match the artificial lift mechanisms with their efficiency levels:

Rod Pump = Poor efficiency in horizontal wells Gas Lift = Excellent efficiency Electric Submersible Pump (ESP) = Full efficiency if conditions met Plunger = Moderate efficiency Signup and view all the answers

Match each artificial lift system with its required flow conditions:

Rod Pump = Requires separation and limited angle Gas Lift = Requires high gas rates Electric Submersible Pump (ESP) = Requires constant flow Plunger = Requires constant flow and straight section Signup and view all the answers

Match the artificial lift mechanisms with their applicable well deviation:

Rod Pump = Not usually used in deviated wells Gas Lift = Can be run to any position Electric Submersible Pump (ESP) = Full horizontal applicability Plunger = Not used above 20° deviation Signup and view all the answers

Match each artificial lift mechanism with its volume lifted per day:

Rod Pump = Limited to ~1000 BFPD Gas Lift = Varies with gas usage Electric Submersible Pump (ESP) = Typically > 20,000 BFPD Plunger = 10 to 50 BFPD Signup and view all the answers

Match each pump with its comments on usage:

Rod Pump = Requires separation and limited angle Gas Lift = Excellent for high gas environments Electric Submersible Pump (ESP) = Requires straight section to set pump Plunger = Good liquid removal Signup and view all the answers

Match the mechanisms to their solids tolerance:

Rod Pump = Poor solids tolerance Gas Lift = Excellent solids tolerance Electric Submersible Pump (ESP) = Limited solids tolerance Plunger = Good solids tolerance Signup and view all the answers

Match the mechanism with its limitations:

Rod Pump = Limited by rod wear Gas Lift = Requires high gas rates Electric Submersible Pump (ESP) = Requires straight section for installation Plunger = Usually low rate limits Signup and view all the answers

Study Notes

Artificial Lift Overview

Artificial lift is a method used when reservoir pressure is insufficient to produce fluids naturally.
Two major categories of artificial lift are gas lift and pump-assisted lift.
A third hybrid approach, plunger lift, combines elements of both gas lift and pump-assisted lift.

Gas Lift

Injects high-pressure gas into the well annulus to reduce the hydrostatic pressure in the fluid column.
Used in high-productivity index wells.
Two types: continuous and intermittent.
- Continuous gas lift: injects gas constantly, lowering overall density for higher production rates; used in high productivity index wells with high bottomhole pressures.
- Intermittent gas lift: injects slugs of gas; displaces liquid to surface; suitable for lower-productivity wells.

Reciprocating Rod Pump Systems

A common artificial lift method.
Uses a pumping unit to reciprocate a plunger inside the tubing, forcing fluids to the surface.
Subsurface pump is connected via a rod string.
Includes surface and subsurface equipment; subsurface pump selection and rod string design are key considerations.

Progressive Cavity Pump Systems

Uses a spiral rotor that turns inside an elastomer-lined stator to move fluid.
Suitable for waterflood projects, and for producing heavy/high-viscosity fluids.

Hydraulic Pump Systems

Injects a power fluid (usually oil or water) into the well to push fluids to surface.
Two types: reciprocating hydraulic pumps and hydraulic jet pumps.
- Reciprocating hydraulic pumps use a downhole fluid engine to drive a piston.
- Hydraulic jet pumps have no moving parts.
Suitable for lifting heavy viscous fluids.

Electrical Submersible Pump Systems

Uses an electric motor and a centrifugal pump to lift fluids to the surface.
Commonly used for high-volume applications or high-water-cut production in deviated wells.

Plunger Lift Systems

Relies solely on the well's natural energy.
Plunger is automatically dropped and moves up as the pressure of gas below is greater than the liquid above.
Cost-effective method for producing gas and high GOR oil wells.

Selecting an Artificial Lift Method

Reservoir and hole considerations are key for selecting the appropriate artificial lift method.
Inflow Performance Relationship (IPR) defines the well's production potential.
Liquid production rate, water cut, and gas-liquid ratio impact efficiency of each method.
Viscosity, formations volume factor, and reservoir drive mechanism should be considered.

Initial Screening Criteria (summarization of important factors)

Inflow Performance Relationship (IPR)
Liquid Production Rate
Water Cut
Gas-Liquid Ratio
Viscosity
Formation Volume Factor (volume of reservoir fluid vs surface volume)
Reservoir Drive Mechanism (depletion drive, water drive, gas cap drive, combination drive.)

Artificial Lift-Specific Method Details (summarized)

Gas lift, continuous and intermittent
Reciprocating rod pumps
Progressive cavity pumps (PCP)
Hydraulic pumps
Electrical submersible pumps (ESP)
Plunger Lift
Important factors in selecting the best artificial lift method.

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Test your knowledge on Electrical Submersible Pumps (ESP) through a series of matching questions related to their operating depths, volumes, characteristics, and design considerations. This quiz covers the key capabilities and efficiency factors associated with ESP systems, providing a comprehensive evaluation of your understanding.