Post on 03-Mar-2016
description
CAN PREVENT
THIS
WELL INTERVENTION CERTIFICATION COURSE
Chapter 1
COMPLETION EQUIPMENT
1
Well Completion
Last process of completing a petroleum well after the installation of casing, cementing job & perforation.
Series of tubular (tubing & completion accessories) are run & placed to enable the well to produce or inject, accordingly.
Xmas tree is positioned on top to regulate or isolate flow.
Single or multiple string determined by the reservoirs.
Vertical or horizontal completion determined by reservoir geological aspects.
Conventional or monobore completion determined by the fields economics.
2
Completion Equipment
Various type of equipment installed with production tubing string & each of them with its specific function.
The essential type of equipments install in completion string are:
1. Production Packer
2. Circulation Device
3. Sub-Surface Safety Valve (SSSV)
4. Landing Nipple
5. Other Accessories
6. Tubing Hanger
7. Wellhead & Xmas Tree
NOTE:
All illustration are not to scale3
PRODUCTION PACKER
4
A mechanical device connected with production tubing serves as downhole barrier.
Production PackerFunction
Seal between tubing & casing.
Prevent fluids movement due to pressure differential.
Seal between multiple zones
Contained reservoir fluid within tubing.
Isolates casing from reservoir fluids & corrosion fromwell effluents or injection fluids
Application
Use in high pressure & highly corrosive reservoirs.
Placement
Position above perforation & away from casing collar.
NEVER set packer across casing collar.
EOT of tailpipe shall be 10ft above perforation.
5
Perforation
Casing
Casing Collar
Tubing
Packer
Production Packer
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Slips
Slips
Packer
Seal Element
Body
Construction
Body
Hardened Slips
Packing Element
Shear Pins
Setting Mechanism
Mechanical (Manipulation of string)
Wireline Set (Electrical & Explosive)
Hydraulically Set (Using Pressure)
Production Packer
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Permanent Packer
Single Retrievable Packer
Dual Retrievable Packer
Production Packer Variant
1. Permanent Packer
Single String
2. Retrievable Packer
Single String
Dual Strings
Permanent Packer
Integral part of casing.
Removed by milling operation.
Wireline set.
Retrievable Packer
Integral part of tubing.
Can be retrieved & redressed.
Hydraulically set
Packer Installations
8
Single Zone Completion
Single String Multi Zones Completion
Dual Completion
Retrievable Packer Accessory
Travel Joint
To compensate tubing movement due to temperature and/or pressure changes during treating or production.
Install on the short string for dual completion.
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Permanent Packer Accessories
10
ATA LTSTSR
PBRLocator Tubing Seal (LTS) Seals assembly with locator
providing effective tubing/packer seal.
Anchor Tubing Assemblies (ATA) Seal assembly with anchoring
feature.
Polished Bore Receptacle (PBR) Polished ID tubular installed on
top of packer to accept male tubing seal assembly.
Tubing Seals Receptacles (TSR) PBR Inverted version attached on top
of packer to accept female tubing seal assembly.
Seal Bore Extension Same packer ID tubular connected to the bottom of packer to
accept male seal assembly & milling spear or tool.
CIRCULATION DEVICE
11
A mechanical device serves to provide communication between tubing & annulus.
Circulation DeviceFunction
Provide communication between tubing & annulus or reservoir.
Eliminate false production data.
Application
Fluids circulation.
Fluids displacement.
Gas lift.
Production access.
Well killing.
Production data acquisition
12
Variants of Circulation Devices
1. Sliding Side Door (SSD).
2. Side Pocket Mandrel (SPM).
3. Perforated Joint.
4. Ported Nipple.
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SPM
Ported Nipple
SSD
PERFORATED JOINT
Circulation Device
Function Provide communication between tubing &
annulus or reservoir.
Application
Fluids Circulation Fluids Displacement Well Killing Production Access.
Construction
Seal Bores Inner Sleeve Nipple Profile Self Equalizing Ports
Placement
As close as possible above top production packer. Above each reservoirs perforation
SSD
14
SSD
Nipple Profile
Seal Bore
Equalizing Port
Flow Port
Inner Sleeve
Seal Bore
SSD
15
Straddle Tool
Equalizing Sub
Mandrel Extension
Lower PackingAssembly
Lock MandrelAssembly
Isolation Tool
Isolation Sub
Variants
Jar To Open
Jar To Open
Larger Flow Ports
Smaller Flow Ports
Disadvantage
Inner sleeve may stuck due to sand or other substance sticking.
Advantage
More than one SSD can be installed in one tubing string.
Can set Straddle Tool. Can set Isolation Tool.
Straddle Tool
Blank off top zone & bottom zone to flow.
Tool Construction:
Lock Mandrel Equalizing Sub Mandrel Extension Lower Packing Assembly
Separation Tool
Blank off bottom zone & top zone to flow.
Tool Construction:
Lock Mandrel Separation Sub Mandrel Extension Lower Packing Assembly
SSD Accessories
Side Pocket MandrelOriginally designed for gas lift system but it also
used for communication device.
Feature:
Full tubing bore
Orientating sleeve
Discriminator
1 or 1 valve pocket
Valve Type:
Dummy Valve (DV)
Gas Lift Valve (GLV)
Chemical Injection Valve (CIV)
Circulation Valve (CV)
Differential Dump Kill Valve (DDKV)
Equalizing Valve (EV)
All valve utilize Latch to lock in pocket. 17
SPM
Full Tubing Bore & Pocket
Orientating Sleeve
Discriminator
Receptacle
DVGLVLATCH
Perforated JointFunction
Eliminate flow restrictions. Provide true downhole readings. Prevent instrument vibration.
Application
True production data acquisition
Construction
Tubing pup joint perforated with greater flow areas than tubing.
Placement
Installed above gauge hanger landing nipple.
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Perforated Holes
Collar
PERFORATED JOINT
Perforated Joint Application
19
With Perforated JointWith Out Perforated Joint
Gauge Gauge
Nipple Nipple
Flow Flow
Flow turbulence created in nipple. Gauge vibrate (gauge damage). False data acquisition.
Flow thru nipple & perforated joint. No vibration (gauge safe). True data acquisition.
FlowFlow
Ported NippleFunction
Provide communication between tubing & reservoir.
Application
Production access in sand accumulation zones. .
Construction
Short Tubular
Nipple Profile
Seal Bores
Flow Ports
Placement
Installed above sand accumulation zones reservoirs perforation
20
PORTED NIPPLE
Port
Seal Bore
Seal Bore
Profile
DHSV
21
A mechanical downhole barrier serves toprevent uncontrollable hydrocarbon flow
possible cause by surface impact or explosion
Downhole Safety ValveFunction
Permit flow during normal conditions but would isolate formation pressure from wellhead to prevent damage during emergency.
Application
Medium or high pressure well.
DHSV Type
DCSSV
SCSSV
Valve Closure
Ball Flapper Poppet
22
Remote controlled by hydraulic pressure, set only in designated nipple & can be integrated with pilots, ESD & surface safety manifolds.
Direct activated by surrounding pressure & can be set anywhere in tubing string.
Closed Open
BALL TYPE
Closed
Open
FLAPPER TYPE POPPET TYPE
Closed Open
DCSSVThese valves are installed in appropriate landing nipples with
wireline lock mandrel.
Types of DCSSV (Closure Mechanism - Poppet or Ball Valve )
1. Pressure Differential Safety Valve
2. Ambient Safety Valve
3. Injection Valve
4. Bottom Hole Regulator
23
A Normally Open valve utilizes pressure-differential to close valve. Pressure differential exceeded pre-set spring & forces it to close. Adjustable bean size can be set for pressure differential. Surface pressure will equalize & open valve.
A Fail Safe valve utilizes pre-charged dome pressure. Well pressure reaches the pre-set dome pressure & open the valve. When well pressure drops below pre-set dome pressure the valve will close.
A Normally Close valve. It serves like a check valve allowing passage of injected fluid but close when injection ceased.
A throttling valve installed downhole to enhance overall well safety where high surface pressure & hydrates formation present problems. In gas well it increase downhole temperature & prevent hydrates formation. In oil well it liberate gas & lighten oil column to increase flow velocity.
STORM CHOKE
Pre-Charge Connection
Spring
Ball Valve
Lock Mandrel
Connection
SCSSV
24
SCSSV Variants
WRSV
TRSV
SCSSV Construction
Body Piston Spring Flow Tube Valve (Ball or Flapper)
SCSSV Placement
Set below crater depth Above control line hydraulic fluid
hydrostatic head.
WRSV
Lock Mandrel
Piston
Spring
Flow Tube
Flapper
Packing
Fluid Inlet Port
WRSV
25
WRSV SV Nipple
TRSV
26
TRSV With Insert ValveTRSV Close TRSV Open TRSV Lock Open
Flapper
Spring
Flow Tube
Lock Open Sleeve
Lock Open Profile
Ratchet Profile
Nipple Profile
Safety Valve Integrity Test
Integrity Test
Leak test are performed immediately after DHSV are installed & periodically to accomplish 3 functions;
1. Integrity of safety valve seals
2. Integrity of WRSV lock assembly
3. To cycle valve prevent freezing after setting for extended periods of time.
NOTE:
Only authorized personnel should conduct all the above test on all SSSV.
27
Annulus Safety Valve
A Fail Safe Close device that isolate flow of gas between above & below the tubing/casing annulus.
Function
Provide control in annulus if tubing hanger is breached.
Application
Artificial lift or secondary recovery production wells.
Closure Mechanism
Sliding sleeve Poppet Flapper
28
29
Annular Safety Valve
Surface Control Manifold
Function
Provide & control the hydraulic pressure required to hold SCSSV & SSV open.
Construction & Operation
One or more pneumatic hydraulic pumps to maintain hydraulic operating pressure for the safety valve.
3 way valve controlled by remote pressure pilots & fire sensors which is controlling the safety valve hydraulic pressure
Pilots, sensors or manual activation removes the hydraulic pressure thus close the safety valve.
Sequential Opening & closing Logic
1. Closing
SSV 1st
SCSSV 2nd
30
2. Re-Opening SCSSV 1st
SSV 2nd
LANDING NIPPLE
31
A receptacle in tubing string for FCD.
Landing NippleFunction
Receptacle for Flow Control Device (FCD).
Application
Production wells.
Construction
Profile (to secure locking mechanism) Seal Bore No-Go shoulder (provide positive location in highly deviated well).
Type
Non-Selective Nipple Selective Nipple Ported Nipple Safety Valve Nipple
32NON SELECTIVE NIPPLE
(Bottom No-Go)
Profile
Seal Bore
No-Go Shoulder
SELECTIVE NIPPLE
(Top No-Go)
PORTED NIPPLE
Port
SV NIPPLE
Control Line Port
Landing NippleNon-Selective Type
Smallest ID in tubing string.
Only one installed in tubing
Bottom No-Go
Selective Type
Several nipples of same size installed
Top No-Go
Placement
Non-Selective
Bottom most nipple
Selective
Strategic point for FCD
Immediately below production packer
33
OTHER ACCESSORY
34
Wireline Entry Guide
35
HALF MULE SHOE WEG
45 Angle
BELL GUIDE WEG
45 Taper
Function Provides safe re-entry of WL tools.
Construction
Its chamfered internal end prevent tool hung-up.
Placement
Attached at the end of tubing or tail pipe.
Type
1. Half Mule Shoe
Incorporate large 45 angle cut on one side to facilitate entry of permanent packer top.
2. Bell Guide
Incorporate 45 lead in taper to allow re-entry of WL tools into tubing.
Blast Joint
Function
Withstand external abrasive action from formation fluids.
Construction
Medium length (20) with SS heavy-wall.
Placement
Installed opposite perforations (for non-gravel pack completion).
36
BLAST JOINT
Flow Coupling
Function
Withstand internal corrosion caused by flow turbulence.
Construction
Short tubular with SS heavy wall.
Placement
Installed DS FCD which caused turbulence e.g. Nipple, SSD, SCSSV.
High velocity & high pressures wells installed both US & DS.
37
FLOW COUPLING
DS Flow Coupling
US Flow Coupling
Landing Nipple
with FCD
Control Line
Function 1 conduit connected to SVLN or TRSV that supplies
hydraulic fluid to SCSSV & terminated at tubing hanger.
Application
Clamp to tubing external by protector
Materials
316 SS for sweet service INCONEL or ELGILOY alloys for sour service
Note
NOT recommended to splice control line.
38
Tubing
Function
Medium to convey well fluids from wellbore to surface or vise versa & prevent well effluents expose to casing.
Thread Connections
API: Tapered thread & rely on thread compound to effect seal
Premium: Metal-to-Metal seal
Tubing Selection Governed By:
Well peak production rate
Well depth
Use of WL tools
Pressure & temperature
Annulus differential pressure etc
39HYDRIL CS Connection
Metal to Metal Seal
API EUE Connection
Tapered Thread
TUBING HANGER
40
Function Suspend tubing string with threaded
connection Isolate casing tubing annular Provide access to annular space (A
annulus) & control line. Receptacle for BPV
Hanger Type
1. Bowl & Mandrel Tubing Hanger Combination of Tubing Head &
Hanger
2. Multiple Mandrel Tubing Hanger
Use in multiple completion. Similar to No 1
3. Ram Tubing Hanger
Tubing manipulation is necessary to locate/latch & maintain tension
41
TUBING SPOOL
TUBING HANGER
RAM TUBING HANGER
Tubing Hanger
Tubing Hanger
Feature
1. Landing Threads
Uppermost threads on the hanger & support the entire tubing string weight during landing operations.
2. Bottom Thread
Support entire tubing string weight & seal producing conduit from the tubing/casing annulus.
3. Sealing Area
Provide compression type sealing between hanger seal OD & tubing spool ID. Sealing is accomplished by energizing elastomer seals or metal-to-metal seals by tubing weight action on various load bearing surfaces,
42
Seal Neck
Seal
Tubing Connection
Profile
Control Line Connection
Landing Thread
Tubing Spool Features1. Connections
Size & pressure rating must be compatible of joining connections.
2. Upper Bowl Provides seal area for tubing hanger
3. Lower Bowl Provide isolation seal
4. Tie Down Bolt Secure & prevent upward movement due to
pressure surges. Energizes body seal on tubing hanger.
5. Outlets Access to A annulus (pressure monitoring or
gas lift).6. Test Port
Permit pressure testing to hanger seal, lock-down screw packing connection between flanges & secondary (isolation) seal.
TUBING SPOOLUpper Bowl
Lower Bowl
Outlet
Test Port
Tie Down Bolts
Tubing Spool
43
WELLHEAD & XMAS TREE
44
WellheadWellhead is the assembly of casing spools & tubing spool on top of a well.
Functions
Anchor & connections for each individual casing
Pressure isolation of individual casing
Connection for Xmas tree
Connections for completion string
Isolation of production annulus
Access to annulus for pressure monitoring and/or pumping.
Wellhead Types
Conventional Wellhead (modular)
Compact Wellhead (sub-sea)
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CasingAt drilling stage, various casing strings are run & cemented in a well.
1. Conductor
2. Surface Casing
3. Intermediate Casing
4. Production Casing
5. Liner
Function of Casing
Protect against borehole collapse
Prevent unwanted leakage into or from formations
Provide concentric bore for future operations
Provide wellhead foundation
Each type of casing string is suspended in CHH & assembled on module stack that forms wellhead.
46
Casing Type
1 Conductor Pipe
Prevents unconsolidated formations being eroded.
Provides flow path for drilling fluids.
Cemented in pre-drilled hole or pile driven.
Sizes ranging from 16 30 OD.
Depth varies from surface to 40 400.
CONDUCTOR PIPE
Surface Casing
2 Surface Casing
Protection in case of blowout & Acts as wellhead foundation.
Isolates shallow consolidated & fresh water formations.
Cemented along its whole length.
Sizes ranging from 13 20 OD.
Setting depth up to 1 500 below surface.
48
SURFACE CASING
Intermediate Casing
3 Intermediate Casing
Seals off problem zones, loss circulation zones, high pressure gas pockets & soft formations encountered.
Protects production casing from corrosive fluids.
Cemented up to surface casing shoe.
Sizes ranging from 7 13 OD.
Depth depends on total well depth & conditions encountered, shallow wells not necessary to set this.
49
INTERMEDIATE CASING
Production Casing
4 Production Casing
Isolates reservoir from other fluid bearing formations.
Set above or through producing formations.
Cemented from intermediate casing shoe to its bottom.
Sizes ranging from 5 9 OD.
50
PRODUCTION CASING
Liner
5 Liner
Used when geological & pressure conditions make it hazardous to penetrate the producing formation without the hole being protected by casing.
Shortened casing hangs from bottom of previous casing through producing formations.
Cemented along its length.
Cost effective
51
Liner
Production casing
Intermediate Casing
Conductor PipeSurface Casing
Conventional (Modular) WellheadIts a built up of casing spools. During drilling, drilling BOP is installed above this
casing spool. The drilling BOP must be removed each time a new casing
spool to be installed for next stage of drilling & position the drilling BOP on
top of this new casing spool before drilling commence.
Features:
1 Starter Spool (Conductor Pipe)
2 Surface Casing Spool
3 Surface Casing Hanger
4 Production Casing Spool
5 Production Casing Hanger
6 Tubing Spool
7 Tubing Hanger A Annulus
B Annulus
C Annulus
(Zero Reference point)
VETCOGRAY Subsea Wellhead MS-800
Advantages:
Utilized in shallow water and deep wells
Full-Bore enables to run one extra casing string under BOP control
Option to run 18 and 16 casing strings below the mud line.
Larger completion options, by reaching total depth with a larger production string.
53
Energizing RingRetainer Nut
Wicker Profile
Support Ring
Casing Hanger
Debris Trap Area
Compact Wellhead (subsea)
Surface valves manifold to control flow of well fluids & access for well
intervention activities.
Features
1 Lower Master Valve (LMV)
Manual, NOT working valve optimum conditions.
2 Upper Master Valve (UMV or SSV)
Emergency valve
3 Flow Wing Valve (FWV)
Permits passage of well fluids to CV.
4 Choke Valve (CV)
Restrict, control or regulate flow of well fluids.
5 Kill Wing Valve (KWV)
Permits entry of kill fluids into tubing or equalize.
6 Swab Valve (SV)
Permits entry of well interventions.
Xmas Tree
54
The valves used in Xmas tree are invariably of the gate type providing full bore access to the well. These valves must be operated in the fully open or fully closed position.
Xmas Tree Type
1 Solid Block
2 Composite Block
3 Horizontal Xmas Tree
Solid Block Xmas Tree
Contains fewer components (for high pressure gas wells).
SV
KWV WV
CV
LMV
UMV
Tree Cap
Xmas Tree Type
Composite Block Xmas Tree
Valves are located on separate block & jointed by API flange (for medium pressure oil well).
56
SV
LMV
UMV
KWV WVCV
Tree Cap
Horizontal Xmas Tree
New concept used for subsea completion.
57
2nd MV
KV
CV
Tree Cap
Wellhead
Tubing Hanger with double
plugs
1st MV
AV
Xmas Tree
Wellhead spools, valves, chokes etc are installed by means of the
following connection types:
1 Screwed Type
Low pressure application (5000 psi)
API Flanged type are mostly used by Oil Companies even in low pressure
application because its less susceptible to leakage & easier oriented.
What does API Flange specification of 9 5000 psi means?
9 is the ID of the flange & 5000 psi is the WP58
Xmas Tree Valve Operating Sequence
Sequence during RIH & POOH
1 RIH
Close WV & KWV Open UMV Open LMV Open SV
2 POOH
Close SV Close LMV Close UMV
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End of Chapter 1
Any Question?
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