Completion-Course-26-12.pdf

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

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SSD - Position Sliding Side Door

Upper Completion q p Equipment

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Sliding Side Door (SSD) To provide Communication between the casing annulus and the tubing. aka: Sliding Sleeve Key Words: Sliding Sleeve, Communication Device Internal Sleeve Device, Sleeve, Shifting Tool, Reverse Circulating Device, Tailpipe, Kick Off Device. © 2006 Weatherford. All rights reserved.

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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: • To circulate a less dense fluid into the tubing prior to production • 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 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 producing tubing-to-annulus communication is used (e.g. Side Pocket Mandrel, Tubing Perforating). © 2006 Weatherford. All rights reserved.

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SSD Applications Uses: • Selective Zone Isolation • Dual well production • Kill/circulation path above packer

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SSD Operation

Closed Position – chevrons isolate the ports in the body of the sleeve from the slots in the insert insert.

Equalizing Position – slot equalizes the pressure between the annulus and tubing

Open Position – ports and slot are open, insert is shifted all the way

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Safety Systems

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Sub Surface Systems Critical Safety item to shut in well below ground (seabed) in an

EMERGENCY

• ESD’s ESD’ located l t d att multiple lti l locations: l ti eg h helideck, lid k b boatt llanding di etc t © 2006 Weatherford. All rights reserved.

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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 occurring. These situations include serious damage to the wellhead, failure of surface equipment, and fire at surface. Different operating companies have differing philosophies hil hi on th the iinclusion l i an SSSV SSSV. F For example, l iin an offshore ff h 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 y deposition p depth), p ) and the characteristics of the safety y valve (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. law © 2006 Weatherford. All rights reserved.

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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) • Types of closure – Flapper – Ball – Poppet © 2006 Weatherford. All rights reserved.

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SSSVs can be divide into type groups according to their method of operation: • Di Directt C Controlled t ll d Safety S f t Valves: V l Th These are d designed i d tto shut h t iin th the wellll when h 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 p of the valve falls below a p pre-determined value. Such valves are often called .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 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 potentially t ti ll dangerous d situation. it ti Th These valves l are ttermed dS Surface f C Controlled t ll d S Subb 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 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 restriction t i ti tto flow, fl and d can cause h hydrate d t or paraffin ffi plugging l i if th the appropriate i t conditions exist An SCSSVs run as part of the tubing string is called a tubing retrievable safety valve (TRSCSSV); © 2006 Weatherford. All rights reserved.

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TRSCSSV Tubing Retrievable Surface Controlled Subsurface Safety Valve TRSCSSV SCSS

Key Words: Blowout Containment, Hydraulic Control Line, Line Control Line Protector, Protector Ball Valve, Flapper Valve, WRSCSSV System.

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Wireline (Insert) Safety Valve • Inserted into nipple profile or inside a TRSV • Held open by hydraulic pressure from surface • Equalizing/non options

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Flow Coupling • Installed above/below any area of flow turbulence to prevent p internal tubing erosion.

• Not required if no flow restriction

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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 y to lock the tubing g hanger g in p place • Provides a facility for fluid access to the .A. annulus • Provides an appropriate base for the completion Xmas Tree Tree. Both the Tubing Hanger and Tubing Head Spool are prepared to allow the actuation of an SCSSV. © 2006 Weatherford. All rights reserved.

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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.

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