Internship Report

Eastern Testing Services
Internship Report 1
What is ETS all about?
Eastern testing services (ETS) is a service company which provides
products services to the petroleum exploration and production industry
but do not typically produce petroleum itself.
What makes this diverse group a unique actor in the petroleum sector is
its relationship to oil company operators. A manager from a leading
French oilfield services company explained that oilfield services
companies are in the first row of a project’s pyramid of services
and their function is to select and integrate technologies into the
project delivery.
What Services do they provide?
Eastern testing services provides following services to its clients;
• Surface well testing
• Drill stem testing
• Tubing-conveyed perforation
• Wire line
• Slick line

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Surface Well Testing:
It is provided to many E&P Company for upstream and downstream
solution. Down hole well testing service delivers accurate results that
helps in characterizing reservoir economically, giving confidence in
well's ability to produce.
Tests on oil and gas wells are performed at various stages of well
construction, completion and production. The test objectives at each
stage range from simple identification of produced fluids and
determination of reservoir deliverability to the characterization of
complex reservoir features.
Objective:
Most well tests can be grouped as productivity testing or descriptive
testing. Productivity well tests are conducted to
 Identify produced fluids and determine their respective volume
ratios
 Measure reservoir pressure and temperature
 Obtain samples suitable for pressure-volume-temperature (PVT)
analysis
 Determine well deliverability
 Evaluate completion efficiency
 Characterize well damage
 Evaluate work over or stimulation treatment.
Test tools:
Here are some tools that are used for surface well testing;
Flow head
Introduction:
When testing a well, surface shut off
is usually provided by a flow control
head or flow head that functions as a
temporary Christmas tree. The flow
head is located on top of the well and
is the first piece of equipment at the
surface that fluid flows through.
Features:
The FLOWHEAD consists of 4

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valves;
• 1 master valve
• 1 swab valve
• 2 wing valves
Benefits:
• It supports the weight of the test string.
• It allows up-and-down and rotation movement of the test string.
• It flows out of the well through a flow valve.
• It allows to pump fluid into the well through a kill valve.
• It allows tools to be introduced into the well through the swab
valve.
Applications:
The flow head is used to provide temporary shut off at the surface for
the following:
• Pre-completion testing
• Drill stem testing
• Post-completion testing
The Choke Manifold
Introduction:
The choke manifold is used to control the
fluid from the well by reducing the flowing
pressure and by achieving a constant flow
rate before the fluid enters the processing
equipment on the surface.
When testing a well, the aim is to impose
critical flow across the choke. When critical
flow is achieved, changes pressure and flow
rate made downstream from the choke do
not affect down hole pressure and flow
rate.
Features:
The choke manifold consists of:

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• Four gate valves used to isolate the choke boxes on either
side of the choke manifold.
• An adjustable choke to gain quick control of the well and to
change fixed choke beans without interrupting the flow.
• A fixed choke box to insert calibrated choke beans of
different diameters, depending on the pressure and flow rate
required.
• Tapping points for measurement of the upstream and
downstream pressures.
• Thermometer well inserted in the flow path allowing the
fluid temperature to be monitored.
Benefits:
The choke manifold, with a design featuring a fixed and adjustable
choke, is a versatile piece of equipment. At both chokes, the size of the
orifice that fluid flows through can be varied, allowing maximum control
over fluid flow rate and pressure. In addition, the adjustable choke
makes it possible to control flow pressure without stopping the well,
further enhancing the flexibility of the system.
The combination of a fixed and adjustable choke allows the choke
manifold to achieve various flow rates (low and high) as needed to
support well testing requirements and client 3pecifications.
Applications:
The choke manifold is part of the minimum set of surface testing
equipment needed when a well is being tested. It is used whenever the
fluid flow rate and pressure need to be controlled altered for the
purpose of testing the well.
Separator:
Introduction:
Test separators are versatile pieces of
equipment that allow separation,
metering and sampling of all phases
of the effluent.
Because test separators are used on
exploration wells where the effluent
is unknown, they must be able to

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treat widely varying effluents such as gas, gas condensate, light oil, heavy
oil and foaming oil, as well as oil containing water and impurities such as
mud or solid particles.
Features:
Benefits:
Test separator has following benefits;
• Onshore and offshore operations
• Three-phase capability
• Enables measurement of single phases of processed
well production
• Multiple sampling points through-out system
Applications:
Test separator has following applications;
• Onshore offshore operations
• Well testing operations
• Drill stem testing operations
• Well cleanup operations
• Production testing operations
• Early production facilities and extended appraisal tests

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Oil and gas manifold
Oil manifold Gas manifold
Introduction:
These manifolds divert oil and gas without flow interruption , from the
separator to the burner for disposal , to the tank for measure or storage ,
or to a production line.
Two burners are normally available for offshore operation to allow
continuous testing under any prevailing wind direction.
From the gauge tank and through a transfer pump that boosts the
pressure , flow is also piped to the oil manifold so that the oil can be
supplied to a burner or reinserted to flow line. The oil manifold allows
for the flow to one tank compartment while a pump empties the other
tank.
Features:
• The oil manifold consists of five ball valves arranged as a manifold
and is skid mounted.
• The gas manifold consists of five ball valves arranged as a
manifold and is skid mounted.
Benefits:
• Able to divert oil and gas to the safest burner with respect to
wind direction .
• Fitted with two ball valves for gas manifold and with five ball
valves for oil manifold.

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• Skid mounted.
Applications:
• On shore and offshore operation
• Production wells
• Diverting flow to the tanker
Sand filter:
Introduction:
The DUAL PORT SAND FILTER is a field
proven, versatile and rugged surface equipment
that finds its application in oil or gas wells during
a well test and subsequent production life of a
well. It detects and traps sand/solids coming with
the well stream before passing through the coils
of an indirect heater or entering the separator
vessel. It acts as a safeguard against erosion of the
heater coils and pipe work downstream of it and
also prevents over flooding the separator with these solids since they
tend to settle at the base of the separator vessel on entry. Over flooding
the separator vessel with sands and solid particles can lead to a
dangerous increase in separator pressure, damage to valves and inside
components of the separator, malfunctioning of separator controls and
metering devices, and affecting the overall efficiency of the separation
process.
Applications:
• barefoot completion,
• cleanups
• maximum sand-free rate tests

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Drill stem test
A drill stem test (DST) is a procedure for isolating and testing the
pressure, permeability and productive capacity of a geological formation
during the drilling of a well. The test is an important measurement of
pressure behavior at the drill stem and is a valuable way of obtaining
information on the formation fluid and establishing whether a well has
found a commercial hydrocarbon reservoir.
Objectives:
• Isolate target zone
• Monitor dynamic
reservoir response
• Acquire down hole data
• Control flow
• Control the well

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Test tools:
Here are some tools that are used for dill stem
testing;
Full Bore Circulating Valve:
The Full Bore Circulating Valve (FBCV) is opened
and closed by increasing and bleeding off tubing
pressure. This allows the FBCV to be used in both
open hole and cased-hole testing and is completely
independent of tools actuated by differential
pressure. The FBCV Indexing Mandrel shifts up
when internal tubing pressure is increased to
hydrostatic pressure plus 500 psi. Once tubing
pressure is released annulus pressure will force the
indexing mandrel back to its original position. A
guide sleeve will restrict movement of the indexing
mandrel forcing the valve to stay closed. At a
predetermined number of these up/down cycles,
the guide sleeve will allow the indexing mandrel to
shift all the way down exposing ports for reverse
circulation. The next increase in tubing pressure
will shift the indexing mandrel all the way up
exposing ports for tubing to annulus circulation.
Once the increased tubing pressure is released, the
indexing mandrel will shift back down to its
original closed position. The FBCV is again ready
to repeat its cycling sequence.

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Full Bore Tester Valve:
The Full Bore Tester Valve is an annulus pressure
controlled ball valve and is designed to allow multiple
cycles during cased hole testing and perforating
operations. It is fully balanced to annulus pressure
and will remain in the closed position while tripping
in hole. Operation of the FBTV insensitive to tubing
pressure changes. The FBTV is a spring loaded
normally closed ball valve. Spring force holds the
valve in the closed position. It is opened and
maintained open by applying additional pressure to
the annulus. When applied annulus pressure is
released, the ball valve will close. Fluid at hydrostatic
pressure is trapped behind the nitrogen chamber
acting against a piston, compressing the nitrogen to
hydrostatic pressure. The nitrogen then acts against
the lower piston, the same hydrostatic pressure that
is acting against the lower piston is also passing
through pressure ports, located in the upper outer
housing acting against the upper piston. Both the
upper and lower piston have the same cross-sectional
area, thus keeping the ball valve balanced. Therefore,
the only load holding the ball valve closed is the
compression spring. One of two different unique
ratchet sleeves are available. Depending on which ratchet is used, the
ball valve will open with applied annulus pressure and will close, or lock
open, once pressure is released. The FBTV has a splined lower end and
will allow torque to be applied through the tool.

Full Bore Gauge Carriers:
The Full Bore Gauge Carrier (FBGC) has been
designed as a single body type carrier capable of
housing up to four QUARTZ DIGITAL or Piezo-
Resistive Electronic Memory Pressure /
Temperature Gauges. The gauges are attached to
the housing with metal seal connectors and are
retained below the O.D. of the carrier to protect
the gauges from damage while running the string.
The carrier can be configured to provide outside
and inside position electronic recorders. The gauge
carrier can be custom designed to client’s
requirements.

Full Bore Test Packers:
The Full Bore Test Packer (FBTP) is specially
designed for Full Bore Drill Stem Testing (DST) and
Tubing Conveyed Perforating (TCP) operations.
During TCP operations where the detonation of the
TCP charges can cause rapid pressure surges, the
hydraulic hold downs react to prevent packer
movement.
The full opening design allows unrestricted fluid flow
and tool movement through the tubing bore. A
pressure balanced bypass valve which is held open
when running and retrieving, prevents swabbing
effect. The valve also allows debris to be washed from
the top of the packer when releasing. The bypass
valve is held closed by pressure from below and in
turn helps prevent upward movement of tubing.

Full Bore Hydraulic Jar:
Full Bore Hydraulic Jar (FBHJ) is a straight-pull operated
jar with a closed hydraulic system and a unique balance
piston used to equalize oil pressure with tubing pressure.
The FBHJ is also able to transmit torque to the right at
any position along full stroke.
The FBHJ is designed for easy control of the jarring
action by the operator. The time delay impact control is
allowed for by use of Flow Restrictors between the upper
and lower oil chambers. Fluid flow is restricted only in
the upward pull direction so the jar is easily reset for
subsequent jars.
Due to the balance piston, the hydraulic section is sealed
to well bore fluids however is balanced to tubing
pressure. This helps reduce tool wear and the potential of seal failure.

Full Bore Tension Safety Joint:
The Full Bore Tension Safety Joint (TJ-1001) is a two stage
disconnect tool which is run above the packer that allows
the tubing to be disconnected from the tool string below it
should the need arise. The TJ first requires a predetermined
tensile load to be applied from surface in order to sever the
shear ring assembly which initiates the disconnection. The
tensile load required to shear is dependent of specific
requirements and ranges from 4,000 to 66,000 pounds (this
figure includes the weight of the test string below the TJ).
The second stage of disconnection requires right hand
torqueto be applied to the tubing while simultaneously
stroking it vertically approximately nine inches.
Disconnection requires two strokes per revolution and
approximately six revolutions are required. The inner
mandrel of the tool is indexed to both the splined housing
and the release nut. In rotating the tubing to the right the
mandrel indexes the release nut which has a left hand
thread, unscrewing it from the body and separating the
tool. In the unlikely event that the shear pin assembly is severed
unintentionally during operations the tool will not separate unless right-
hand torque and vertical stroking are applied.

Wire Line
In the oil and gas industry, the
term wire line usually refers to a
cabling technology used by operators
of oil and gas wells to lower
equipment or measurement devices
into the well for the purposes of well
intervention, reservoir evaluation,
and pipe recovery.
Objectives:
When it comes to critical subsurface information about well, wire line
services can provide unequalled flexibility to help meet operational and
budgetary objectives across all types of reservoirs.
Wire line services include measurement, well intervention, and
remediation operations that use a multi-strand cable to convey
equipment and measurement devices into open- and cased-hole wells.

Slick line
Slickline refers to a single strand wire which is used to run tools into
wellbore for several purposes. It is used in the oil and gas industry, but
also describes that niche of the industry that involves using a slickline
truck or doing a slickline job.
Uses:
Slickline is more commonly used in production tubing. The wireline
operator monitors at surface the slickline tension via a weight indicator
gauge and the depth via a depth counter 'zeroed' from surface, lowers
the downhole tool to the proper depth, completes the job by
manipulating the downhole tool mechanically, checks to make sure it
worked if possible, and pulls the tool back out by winding the slickline
back onto the drum it was spooled from. The slickline drum is
controlled by a hydraulic pump, which in turn is controlled by the
'slickline operator'.
Advantages:
It is advantageous to keep the diameter of the wire as small as possible
for the following reasons:
 It reduces the load of its own weight.
 It can be run over smaller diameter sheaves, and wound on smaller
diameter spools or reels without overstressing by bending (where
the wire bends makes it weaker. Where it makes a complete circle,
such as a counter wheel, makes it weaker yet).
 It keeps the reel drum size to a minimum (which reduces the area
needed in the back of the slickline unit to house the drum and
hydraulic pump, reducing weight and leaving more room for the
other specialized equipment needed for slickline operations).
 It provides a small cross-section area for operation under pressure.
Disadvantages:
The disadvantage of a smaller diameter slickline is the lower strength.
Depth and the nature of the job (a tool that must be pulled hard or
might be stuck) will affect what slickline truck (different trucks specialize
in different sizes of line) used.

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