Other completion items
•
Travel Joints
•
SBE (Seal Bore Extension)
(
)
•
PBR (Polished Bore Recepticle)
•
TSR (Tubing Seal Recepticle)
ALL DESIGNED TO ALLOW TUBING MOVEMENT
DURING CHANGING WELL CONDITIONS
SSD - Position
Sliding Side Door
Upper Completion
Equipment
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Sliding Side Door (SSD)
To provide Communication
between the casing annulus
and the tubing.
aka: Sliding Sleeve
aka: Sliding Sleeve
Key Words:
Key Words:
Sliding Sleeve, Communication
Device Internal Sleeve Shifting
Device, Internal Sleeve, Shifting
Tool, Reverse Circulating Device,
Tailpipe, Kick Off Device.
Tailpipe, Kick Off Device.
SLIDING SIDE DOOR
A Sliding Side Door (SSD) or Sliding Sleeve, Figure 4, allows communication between the tubing and the annulus. Sliding Side Doors consist of two concentric sleeves, each with slots or holes.
The inner sleeve can be moved with well intervention tools, usually wireline, to align the openings to provide a communication path for the circulation of fluids.
Sliding Side Doors are used for the following purposes: Sliding Side Doors are used for the following purposes:
• To circulate a less dense fluid into the tubing prior to production • To circulate appropriate kill fluid into the well prior to workover To circulate appropriate kill fluid into the well prior to workover • As a production devices in a multi-zone completion
• As a contingency should tubing/tailpipe plugging occur
• As a contingency to equalise pressure across a deep set plug after pressure integrity testing
• To assist in the removal of hydrocarbons below packers.
NOTE: As with all communication devices the differential pressure across SSDs
NOTE: As with all communication devices, the differential pressure across SSDs
should be known prior to opening.
NOTE: In some areas, the sealing systems between the concentric sleeves
are incompatible with the produced fluids and hence alternative methods of
are incompatible with the produced fluids and hence alternative methods of
producing tubing-to-annulus communication is used (e.g. Side Pocket
SSD Applications
Uses:
•
Selective Zone
Isolation
•
Dual well production
•
Kill/circulation path
above packer
above packer
SSD Operation
Closed Position – chevrons isolate the ports in the body of the sleeve from the slots in the insert
Closed Position – chevrons isolate the ports in the body of the sleeve from the slots in the insert.
Equalizing Position – slot equalizes the pressure between the annulus and tubing
Equalizing Position slot equalizes the pressure between the annulus and tubing
Sub Surface Systems
Critical Safety item to shut in well below ground (seabed) in an
EMERGENCY
EMERGENCY
ESD’ l
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t
SUB-SURFACE SAFETY VALVES (SSSVS)
•
The purpose of an SSSV is to shut off flow from a well in the event of
a potentially catastrophic situation occurring These situations include
a potentially catastrophic situation occurring. These situations include
serious damage to the wellhead, failure of surface equipment, and
fire at surface. Different operating companies have differing
hil
hi
th i
l
i
SSSV F
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i
ff h
philosophies on the inclusion an SSSV. For example, in an offshore
well, at least one SSSV is placed in every well at a depth which
varies from 200 ft to 2,000 ft below the sea bed. The depth at which
an SSSV is installed in a completion is dependent on well
environment (onshore, offshore), production characteristics (wax or
hydrate deposition depth), and the characteristics of the safety valve
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p
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y
(maximum failsafe setting depth).
•
NOTE: It is generally recommended that an SSSV be installed in
a well that is capable of sustaining natural flow.
•
NOTE: In the North Sea, the installation of an SSSV is governed
by law
Types of Safety Valves
Local laws define usage
•
Direct Controlled (DCSSV)
–
High flow activated
–
Low Pressure activated
•
Surface Controlled (SCSSV)
(
)
–
Tubing Retrievable
Insert (Wireline Retrievable)
–
Insert (Wireline Retrievable)
•
Types of closure
–
Flapper
–
Ball
SSSVs can be divide into type groups according to their method of operation:
Di t C t ll d S f t V l Th d i d t h t i th ll h
• Direct Controlled Safety Valves: These are designed to shut in the well when
changes occur in the flowing conditions at the depth of the valve, that is, when the flowing condition exceed a pre-determined rate or when the pressure in the tubing at the depth of the valve falls below a pre-determined value. Such valves are often called p p .storm chokes..
• Remote Controlled Safety Valves: These are independent of changes in well
conditions and are actuated open usually by hydraulic pressure from surface via a conditions and are actuated open usually by hydraulic pressure from surface via a control line to the depth of the safety valve. Loss of hydraulic pressure will result in closure of the valve. A number of monitoring pilots or sensing devices can be linked to the safety system, each pilot capable of causing the valve to close if it senses a
t ti ll d it ti Th l t d S f C t ll d S b potentially dangerous situation. These valves are termed Surface Controlled Sub-Surface Safety Valves (SCSSVs). An SCSSVs run on wireline is called a wireline
retrievable safety valve (WRSV) and is installed in a special safety valve landing nipple (SVLN) which is made up as part of the completion string; A control line external to the (SVLN) which is made up as part of the completion string; A control line external to the tubing provides hydraulic pressure to actuate the valve open. The main advantage of utilising a WRSV is that it can be economically retrieved for inspection. A primary disadvantage of a WRSV is related to its restricted bore which does present a
t i ti t fl d h d t ffi l i if th i t restriction to flow, and can cause hydrate or paraffin plugging if the appropriate
TRSCSSV
Tubing Retrievable Surface
Controlled Subsurface Safety
Valve
TRSCSSV
SCSS
Key Words:
Blowout Containment, Hydraulic
Control Line Control Line Protector
Control Line, Control Line Protector,
Ball Valve, Flapper Valve, WRSCSSV
Wireline (Insert) Safety Valve
•
Inserted into nipple profile or inside a TRSV
•
Held open by hydraulic pressure from surface
Flow Coupling
•
Installed above/below
any area of flow
turbulence to prevent
p
internal tubing erosion.
•
Not required if no flow
•
Not required if no flow
restriction
TUBING HANGER
Sits inside the Tubing Head Spool and provides the following functions:
•
Suspends the tubing
•
Provides a seal between the tubing and the tubing head spool
•
Installation point for barrier protection. (accept a BPV Back Pressure
valve)
The Tubing Head Spool provides the following functions:
•
Provides a facility to lock the tubing hanger in place
y
g
g
p
•
Provides a facility for fluid access to the .A. annulus
•
Provides an appropriate base for the completion Xmas Tree
•
Provides an appropriate base for the completion Xmas Tree.
Both the Tubing Hanger and Tubing Head Spool are prepared to allow
the actuation of an SCSSV.
Christmas Tree
• An Xmas Tree is an assembly of valves, all with specific functions, used to control flow from the well and to provide well intervention access for well maintenance or reservoir monitoring.
• NOTE: The Xmas Tree is normally connected directly to the tubing hanger spool that sits on the uppermost casing head spool. The whole assemblage of Xmas Tree, Tubing Hanger, and uppermost Casing Head Spool is sometimes referred to as the Wellhead.
• A Xmas Tree may be a composite collection of valves or, more commonly nowadays, constructed from a single block; Refer to Figure 11. The solid block enables the unit to be smaller and
eliminates the danger of leakage from flanges. Typically, from bottom to top, an Xmas Tree will contain the following valves:
• NOTE: Nowadays, all Xmas Tree valves are of the gate-valve type that allows full bore access.
