Comp Overview 2

DOWNHOLE TECHNOLOGY LIMITEDCOMPLETION SYSTEMS
Completions Overview
COMPLETION SYSTEMS
COMPLETION SYSTEMS
From above information you can determine:
Burst/Collapse (psi)
Tensile strength
Number x 1000 = Yield Stress (N-80 = 80,000 lb per in2)
Tech Resource
COMPLETION SYSTEMS
COMPLETION SYSTEMS
Yield Strengths
© Weatherford International, Inc. All rights reserved.
COMPLETION SYSTEMS
Not suitable for gas wells.
PREMIUM CONNECTIONS
Some have multiple seal surfaces
Some have elastomer inserts
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Packer Types
Temporary
Permanent
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Retrievable Packer
Lower Completion
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Tubing
Casing
Elastomer
Slips
Mandrel
A packer is a sealing device , barrier. It can be one of the most important piece of equipment run.
When set properly create a pressure tight seal tubing and casing,
All packers had a set ctiteria ,slips, mandrel etc.
COMPLETION SYSTEMS
Protection of Casing
Operating Requirements of Wellbore
Casing protect from corrosive chemicals
Safety it provides a barrier and can isolate the casing fom pressure and chemicals which could cause a problem
It also you to have control of the well.
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Separate formation from gas lift pressure
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Packer Components
Slips grip the casing and keep the tool from moving after it is set
Packing elements
Drag pads
Mandrel
Packing
Elements
Slips
Drag
Pads
Mandrel
Slips
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Activation Energy
The energy to set the packer pack off the elements comes from either a mechanical or hydraulic forse
Neutral set- opposite slips lock in the force and the packer can be left in any of the 3 conditions
Wirline –lock ring as with hydraulic.
If the energy fails , serious concequences
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Set-Ability
Retrieve-Ability
Seal-Ability
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Packer Categories
Retrievable
Designed in a way that they can be run, pulled and rebuilt to run again.
Permanent
Designed in a way that it can be removed only by complete destruction.
.Retrievable packers and plugs are intended to be retrieved from a well without milling, and are repairable. When redressed they are ready to run again. They are generally built from low carbon-alloy steels.
Drillable or “permanent” packers and plugs are intended to be used only once and are designed to be milled or drilled to remove them from the wellbore. They are generally built with cast iron and malleable metals.
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Retrievable Packer
Set hydraulically or mechanically and can be recovered when necessary
Key Words: Tubing Pressure Set, Straight Pull to Release, One Trip Completion Installation.
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Production Packers
Saleable items
Modular components
Cost-effective Manufacturing processes
Production packers are typically salable items which stay in a well for an extended period of time
They are suited for long term exposure to both chemical and temperature factors. This includes attention to detail for metallurgy, coatings and elastomer selection
They are also designed to address a particular market niche’ such as CO2 injection, hot and deep production, etc.
Many systems are modular and offer an operator a variety of completion techniques to suit future needs
Unloader and packing element systems are often designed to work just once for retrieval purposes
Equipment engineering and materials are more sensitive to cost-effective processes
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Hydraulic Set
Wireline Set
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Service Packers
Rental items
Redressable
Service packers and plugs are typically rental items which stay in wells for a relatively short time.
They are designed for strength and to be used in rigorous acidizing, fracing, cementing and testing operations.
Usually materials are high yield steels and are not suitable for long term exposure to corrosive environments.
Much design work is focused on ease of setting, ease of release, resetability, and durable of packing element systems.
Reliable unloader systems to balance differentials before moving toolsfor repeated use.
Hold down systems designed to withstand extreme forces.
Compatibility with other service tools is necessary as the tools are often run together and / or moved together.
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Setting Mechanisms
1. This slide needs to be replaced with drawings of a permanent packer with the baker setting tool attached and in the run position.
2. Same drawing with the setting tool activated and the top slips in the set position. The packer element started to expand
3. Same drawing with the bottom slips set the element fully set and the element fully expanded. The setting tool should be sheared off.
The drawings done for this slide should also be used for page 2-5 in the packer book
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Holding devices
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Expand and grip casing
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“J” Slot
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Pressure Rating
Mandrel
Test Pressures : + 50% over working
Mandrel
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Packer Types
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Inflatable Packers
Inflates Overview
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Packer Forces
D T : Incr / Decr. tubing length
Production vs Injection
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Packer Applications
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Flanged up completion for Safety
Hydraulic Set packers are set in sequence by shear screw values
Fully retrievable completion for remedial access
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Notes:
Workover string retrieved with packer left downhole.
Production string engages On/Off Slick Joint.
Sliding Sleeve used to circulate annulus fluids to inhibited brine.
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Tubing Hanger
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Mule Shoe
Starting with first item into the well and working up
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Re-Entry Guide
Key Words:
To assist with guiding wireline tools back into tubing
Bell Guide
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Landing Nipples
Polished bore to seal
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Landing Nipples
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Common Sizes
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Lock Configuration
Equalizing device
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Equalizing Devices
Open small ports
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Calculate Force
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Calculate Force
= 3.14 x (2.281) 2
Given Plug OD = 4.562”
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Calculate Force
Area = 16.33 in 2
F = P x A
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Calculate Force
Winner ?
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Perforated Joint
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Perforated Joint
Installed above No-go to provide flow bypass when gauges are installed.
aka : Perforated pup
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Blast Joint
Ceramic
Tungsten
Rubber
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Lower Completion
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To provide Communication between the casing annulus and the tubing.
aka: Sliding Sleeve
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XO- SSD
3 positions:
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SSD Applications
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Key shape engages sleeve profile and releases when fully moved
Main types of shifting tools, run on slickline, are:
Standard Shifting tool
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Shifting SSD
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Gaslift
When the hydrostatic pressure exerted by the well fluid at the bottom of the well is greater than the formation pressure artificial lift is required
Gaslift is one such option
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Gaslift Theory
Unloading valves
Working (oriface)
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Gaslift Principles
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GLV Injection
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Gaslift Operations
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Click to bypass kickover tool
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Jar up to retrieve
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Key Words:
Continuous Gas Lift, SPMs, Unloading Valves, Gas Lift Valves, Completion Spaceout.
Tubing Hanger
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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 located at multiple locations: eg helideck, boat landing etc
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TRSCSSV
Blowout Containment, Hydraulic Control Line, Control Line Protector, Ball Valve, Flapper Valve, WRSCSSV System.
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Insert Valve
Equalizing/non options
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Flow Coupling
Installed above/below any area of flow turbulence to prevent internal tubing erosion.
Not required if no flow restriction
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Hydraulic Remote Control for Interventionless Completions
ROSS : Remote Operated Sliding Sleeve
ROSS-V : variable downhole choke
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Support for each casing string
Support for the BOP assembly
Sealing & monitoring access of annuli
Support for the completion (tubing) string
Support for the Xmas Tree
Provide :
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Wellhead Assembly
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Wellhead Configuration
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Tubing Hangers
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Wellhead System
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Xmas Tree
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Composite Tree
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Tree types
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Travel Joint
Locking/rotating version
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Technically challenging
Or piped to shore/installation
Image courtesy ABB Vetco
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Subsea Manifold
Output to pipeline or surface FPO
Image courtesy ABB Vetco
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Subsea Tree
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Subsea sequence
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Cut/recover tree
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Fishing neck (1)
Main body (2)
Inner mandrel (3)
Locking keys (4)
Optimum
Flow
Partial
Flow
Increasing
Flow
This SPM diagram is based on the Camco KBMG series and
shows a typical SPM internal configuration. The internal
components in this diagram are shown to be welded in place.
However methods of construction vary between
manufacturers.
9 5/8" Casing Hanger
13 3/8" Casing Hanger
Non Collar Recess on
applications.
Seal
Seal
Seal
Seal
applications.
Seating Nipple
Sliding Sleeve

Comp Overview 2

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Transcript of Comp Overview 2