This document provides information about gas lift optimization. It discusses the need for gas lift when wells are not producing through natural flow. Gas lift involves injecting natural gas into the well to lift fluids to the surface. The document outlines the basic principles of gas lift and gas lift systems. It describes how gas lift valves work and the process of unloading a well using multiple unloading valves. The goal of optimization is to find the optimal injection point and amount of gas injected to maximize oil production rates. Charts are provided showing well performance curves with injection rate versus oil rate.

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Gas Lift
One day course

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One day Gas Lift Course
At the end of this section, you will
know……
1. Why we need Gas Lift
2. Why we need the of Gas Lift Valves
3. How to unload a well
4. How to optimize a Gas Lift well

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Why we need the of Gas Lift
OPERATING
POINT
QACTUALPACTUAL
FLOWING WELLDEAD WELL
Flow rate Q
PressureP
Outflow
(TPR)
Inflow
(IPR)

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 Gas lifting is used to produce
fluids from wells not producing
in natural flow (dead) or to
increase the production rate of
naturally flowing wells.
 Gas lifting uses natural
compressed at the surface and
injected in the wellstream at
some downhole point.
 In continuous flow gas lift, a
steady rate of gas is injected in
well tubing, aerating the liquid and
thus reducing the hydrostatic
backpressure.
Basic Principles of Gas Lift

5. Gas Lift Systems
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Why we need the of GL Valves
 Gas lifting is a process of lifting fluids from an
oil well by injecting gas into formation
fluids at predetermined depth.
 To achieve an efficient operation and to ensure
that the proper amount of gas is injected at
all times, gas entry must be controlled by
utilizing some kind of downhole control device:
Gas Lift Valves.

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Overview of Gas Lift Valves
 Continuous Gas Lift usually consists of a
number of unloading valves and an
orifice valve at the operating point.
 The role of the unloading gas lift valve
should be to allow smooth, positive
and reliable unloading of the well
 The role of the orifice valve (Operating
valve) should be to allow production
over many years with continuously
changing conditions.
 Several different types of gas lift valves
used in order to achieve this and each
uses a particular design technique
Operating valve
Unloading valve
Unloading valve
Unloading valve
Unloading valve

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 A gas lift valve is designed to stay
closed until certain conditions of
pressure in the annulus and
tubing are met.
 When the valve opens, it permits gas
or fluid to pass from the casing
annulus into the tubing
 An operating gas lift valve is
installed to control the point of gas
injection.
 Valves are installed above the
desired point of injection to unload
the well.
 After unloading, they close to
eliminate gas injection above the
operating valve.
Operating valve
Unloading valve
Unloading valve
Unloading valve
Unloading valve
Overview of Gas Lift Valves

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How the GL Valves work

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Unloading
Sequence

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Unloading sequence
1. After a well is completed or worked over, the fluid level in the
casing and tubing is usually at or near the surface.
2. Casing and Tubing are in hydraulic communication because
the gas lift valve are in open position
3. The gas lift pressure available to unload the well is generally not
sufficient to unload fluid to the desired depth for gas injection.
This is because the pressure caused by the static column of fluid
in the well at the desired depth of injection is greater than the
available gas pressure at the depth of injection.
4. In this case a series of unloading gas lift valves are installed in
the well for the purpose.
5. These valves are designed to use the available gas injection
pressure (depending on gas compression system characteristics)
to unload the well until the desired depth of injection is achieved.

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Unloading sequence
 In this specific case, the fluid level in the casing and the tubing is at surface.
 No gas is being injected into the casing and no fluid is being produced.
 All the gas lift valves are open. The pressure to open the valves is provided by the
weight of the fluid in the casing and tubing.
 The fluid level in the tubing and casing will be determined by the shut in bottom hole
pressure (SIBHP) and the hydrostatic head or weight of the column of fluid which is in
turn determined by the density.
Schlumberger courtesy

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Unloading sequence
 Gas injection into the casing has begun. Fluid is U-tubed through all the open gas lift
valves.
 No formation fluids are being produced because the pressure in the wellbore at
perforation depth is greater than the reservoir pressure i.e. no drawdown.
 All fluid produced is from the casing and the tubing.
 All fluid unloaded from the casing passes through the open gas lift valves. Because
of this, it is important that the well be unloaded at a reasonable rate to prevent damage
to the gas lift valves.

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Unloading sequence
 The fluid level has been unloaded to the top gas lift valve.
 This aerates the fluid above the top gas lift valve, decreasing the fluid density. This
reduces the pressure in the tubing at the top gas lift valve, and also reduces pressure in
the tubing at all valves below the top valve. This is reflected on TBG pressure curve.
 This pressure reduction allows casing fluid below the top gas lift valve to be U-tubed
further down the well and unloaded through valves 2, 3 and 4.
 If this reduction in pressure is sufficient to give some drawdown at the perforations then
the well will start to produce formation fluid.

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Unloading sequence
 The fluid level in the annulus has now been unloaded to just above valve
number two. This has been possible due to the increasing volume of gas
passing through top valve reducing the pressure in the tubing at valve two
thus enabling the U-tubing process to continue.
 The weight reduction of the fluid column in the TBG (as consequence of
the higher GLR above the top gas lift valve) gives some drawdown at the
perforations then the well starts to produce formation fluid.

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Unloading sequence
 The fluid level in the casing has been lowered to a point below the second gas lift
valve. The top two gas lift valves are open and gas being injected through
both valves. All valves below also remain open and continue to pass casing fluid.
 The tubing has now been unloaded sufficiently to sensibly reduce the flowing
bottom hole pressure (FBHP). This increases the differential pressure from the
reservoir to the wellbore and in turn increases the formation fluid flow rate.

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Unloading sequence
 The top gas lift valve is now closed, and all the gas is being injected
through the second valve. When casing pressure operated valves are used
a slight reduction in the casing pressure causes the top valve to close.
With fluid operated and proportional response valves, a reduction in the
tubing pressure at valve depth causes the top valve to close.
 Unloading the well continues with valves 2, 3 and 4 open and casing fluid
being removed through valves 3 and 4.

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Unloading sequence
 The No 3 valve has now been uncovered. Valves 2 and 3 are both open
and passing gas. The bottom valve below the fluid level is also open.
 Note that the deeper the point of injection the lower the FBHP and thus
the greater the drawdown on the well. As well productivity is directly
related to the drawdown then the deeper the injection the greater the
production rate.

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Unloading sequence
 The No. 2 valve is now closed. All gas is being injected through valve No 3. Valve
No 2 is closed by a reduction in casing pressure for casing operated valves or a
reduction in tubing pressure for fluid operated and proportional response valves.
 Valve No 3 is the operating valve in this example. This is because the ability of
the reservoir to produce fluid matches the ability of the tubing to remove fluids
(Inflow/Outflow Performance). The operating valve can either be an orifice valve or
can be a gas lift valve. The valve in mandrel No 4 will remain submerged
unless operating conditions or reservoir conditions change.

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Unloading sequence

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Gas Lift
Optimization

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Gas Lift Optimization Concept
Find the:
1. Optimum injection point for stable flow
conditions (at system design stage)
2. Optimum quantity of gas to be injected to
maximise the oil rate at specific well flow
condition (during the production phase)

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Well Performance Curve
Lift Gas Injection rate vs Oil Rate
0
200
400
600
800
1000
1200
1400
1600
1800
0 0.5 1 1.5 2 2.5 3
Lift Gas Injection Rate mmscf/d
OilRatestb/d

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Gas Lift Optimization

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Question?