Selection of the best artificial lift systems for the well depend on location, depth, estimated production, reservoir properties, and many other factors. Here is an overview on selection criteria for the best results

1. Artificial Lift Selection Criteria for Optimum Efficiency
Reservoir Types & Limitations
Aditya Kumar
Director – Petroleum Engineering
aditya@telestoenergy.com

2. Outline
• Nodal Analysis / Well Performance
• Reservoir Inflow Capability
• Reservoir Drive Mechanisms
• Reservoir Trends and Recovery
• Reservoir Relevant Consideration in Selecting an Artificial
Lift Method

3. Nodal Analysis / Well Performance
0
500
1000
1500
2000
2500
3000
3500
0 500 1000 1500 2000 2500 3000 3500 4000 4500
Production rate, STB/D
Flowingbottomholepressure,psi
Inflow (Reservoir) Curve
Outflow (Tubing) Curve
2111 STB/D
1957 psi

4. Reservoir Inflow Capability
 

















s
r
r
B
pphk
q
w
e
oo
wf
4
3
ln
1008.7 3

wfpp
q
J




















s
r
r
B
kh
J
w
e
oo
4
3
ln
1008.7 3

5. Solution Gas Drive Reservoir

6. Gas Cap Drive Reservoir

7. Water Drive Reservoir

8. Gravity Drainage Drive Reservoir
Oil
Oil
Oil
Point A
Point B
Point C
Gas
Gas
Gas

9. Recovery Factors for Oil Reservoirs
Drive Mechanism
Average Recovery
Range
(% of OOIP)
Average Recovery
Factor
(% of OOIP)
Solution Gas Drive 5-30 15
Gas Cap Drive 15-50 30
Water Drive 30-60 40
Gravity Drainage Drive 16-85 50

10. Reservoir Changes and AL selection
• Reservoir behavior changes over the period of time for different drive
mechanisms
• Rate of decrease of reservoir pressure
• Rate of increase in water cut
• Behavior of GOR with time
• Selection of an appropriate artificial lift method should take account of
• Inflow performance of the well based upon type of reservoir
• Variation of reservoir and fluid properties over time
• Capacity and operation of the lift systems

11. Liquid production rate The anticipated production rate is a controlling factor in selecting a lift method
Water cut High water cuts require a lift method that can move large volumes of fluid
Gas-liquid ratio A high GOR generally lowers the efficiency of pump-assisted lift
Viscosity High-viscosity fluids can cause difficulty, particularly in sucker rod pumping
Formation volume factor Ratio of reservoir volume to surface volume determines how much total fluid must be lifted to achieve
the desired surface production rate
Reservoir drive mechanism Depletion drive reservoirs: Late-stage production may require pumping to produce low fluid volumes
or injected water.
Water drive reservoirs : High water cuts may cause problems for lifting systems
Gas cap drive reservoirs : Increasing gas-liquid ratios may affect lift efficiency.
Other reservoir problems Sand, paraffin, or scale can cause plugging and/or abrasion. Presence of H2S, CO2 or salt water can
cause corrosion. Downhole emulsions can increase backpressure and reduce lifting efficiency. High
bottomhole temperatures can affect downhole equipment.
Reservoir Relevant Consideration in Selecting an Artificial Lift Method

12. Reservoir Relevant Properties: AL Selection
Characteristic Specific Gas Lift ESP PCP Rod Pump Jet Pump
Recovery
Primary Recommended Recommended Recommended Recommended Recommended
Secondary waterflood Recommended, however high
WC reduces the ability to
move large fluid volumes.
Recommended Recommended Recommended Recommended
Tertiary Can be used Can be used Steam flood will cause
a problem; elastomers
may degrade.
Can be used
Production rate
Less than 1000 B/D The full range of production
rates can be handled. Cannot
achieve as much drawdown as
ESP
The full range of
production rates can
be handled.
Rate dependent on
setting depth.
Generally PCP is
suitable for low rate
wells.
Rate is dependent on setting
depth. Feasible for low rates
(<100 B/D) and low GOR
(<250).
The full range of
production rates can
be handled.
1000 to 10,000 B/D Suitable Suitable Usually up to 4000 b/d
at 3000 feet
Restricted to shallow depths
using large plungers. In
general, not recommended.
Suitable
Greater than 10,000 B/D Suitable Suitable Not available. Not available. Suitable
Pressure support
Yes Well suited, however
increasing water cut reduces
the ability to move large fluid
volumes.
Recommended as an
ESP is able to move
the same fluid
volume no matter
what water cut.
Recommended Recommended Recommended, as jet
pump system is
independent of water
cut percentage
producing from a well.
No Recommended as the
flexibility of gas lift allows one
installation to deal with falling
pressure and production rates.
Not recommended
when there is
significant pressure
drop
Not recommended
when there is
significant pressure
drop
If there is no pressure support
from the reservoir,
production rate will decline
and the well will be
“pumped-off”.
Not recommended
when there is
significant pressure
drop in the reservoir

13. Characteristic Specific Gas Lift ESP PCP Rod Pump Jet Pump
Gas/oil ratio
Less than 500 scf/STB Recommended Recommended. Recommended. Feasible for low
rate and low GOR
Recommended.
500 to 2000 scf/STB Recommended The achievable pump rate
will be limited by the
amount of gas breaking out
of solution.
The achievable pump
rate will be limited by
the amount of gas
breaking out of solution.
Gassy wells usually
have lower
volumetric
efficiency.
Target design is less than 1000
GLR.
Greater than 2000 scf/STBRecommended. Gas lift
would be only
expected to be of
benefit at higher GOR.
FBHP will need to stay
above the bubble point
pressure to avoid gas
cavitation.
Not recommended. Not recommended Not recommended. Gas above
2000 SCF/STB substantially
reduces efficiency but helps
lift.
Bubble point
High Recommended for all
bubble points.
Not recommended. Not recommended. Not highly
recommended.
Not recommended.
Low Recommended for all
bubble points.
Recommended. Recommended. Recommended. Recommended.
Fluid viscosity
(at reservoir
temperature)
Less than 100 cp Recommended Recommended Recommended Recommended Recommended
100 to 500 cp Recommended Efficiency of ESP will be
reduced.
Recommended. Pump
efficiency will increase
as viscosity increases.
Good for < 200 cp
fluids and low rate.
Recommended
Greater than 500 cp Has been used with
success up to 1000 cp
but problems with
very high viscosity.
Not recommended. Recommended for all
high viscosity crude. Up
to 80,000 cp.
Not recommended,
as pump efficiency
will reduce.
The system is capable of
handling high-viscosity fluid.
Production with up to 800 cp
possible.
Reservoir Relevant Properties: AL Selection

14. Reservoir Relevant Properties: AL Selection
Characteristic Specific Gas Lift ESP PCP Rod Pump Jet Pump
Oil Gravity
No limitations. Preferable > 15
API.
No limitations.
Preferable > 12 API.
Not used for oil with gravity
greater than 40 degrees API
due to high aromatic
content that will deteriorate
elastomers.
> 8 API. > 8 to 45 API.
Water Cut
Low Recommended. Recommended for the
full range of water cut.
The ESP is largely
insensitive to increasing
water cut.
Recommended Recommended Recommended
Moderate Reduced efficiency due to
heavier column of fluid to
lighten.
Recommended Recommended Recommended Recommended
High Reduced efficiency due to
heavier column of fluid to
lighten.
Recommended Recommended Recommended Recommended
Water coning
Gas lift effective ESP effective PCP can be effective Rod pump effectiveJet pump effective
Gas coning
Gas lift can be effective in
producing a well that cones
gas.
Not recommended. Usually can be used if free
gas is < 40% by volume.
For gassy reservoir.
Rod pump handling
is fair to good.
Not recommended.
Cavitation in jet pump
likely.

15. THANK YOU
Telesto Energy Pte Ltd
30 Cecil Street, #19-08, Prudential Towers, Singapore 049712
Email: contact@telestoenergy.com | Website:
www.telestoenergy.com
Global Presence: India | Perth | Algiers
Telestoenergy #telestoenergy
Telestoenergy