subsurface flow controls - · pdf filelanding nipples – x®, r®, rpt, fbn lock...
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Subsurface Flow Controls
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Subsurface Flow Controls
Landing Nipples – X®, R®, RPT, FBN
Lock Mandrels and accessories
Nippleless Tubing Plugs - Mirage® plug, Monolock®
DuraSleeve® Sliding Side-Door® circulating device
Wellhead Plugs - SRP, SSP
Back Pressure Valve- SRP
Accessory Items – flow couplings, blast joints
Locks and Landing Nipples
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Nipple Profiles/Lock Mandrels
Monolock®
FC - Plug, Choke,Gauge
FBN®
Full Bore,Monobore CompletionsFC - Plug, Choke
X®
STD WeightFC - SSSV, Plug,Choke, Gauge
RPT, RQFC - SSSV, Plug,Choke, Gauge
SafetySet®
SSSVSpecial ApplicationsHigh Pressure andFlow Rate
SRPWellhead Plugs
MonoboreCompletions
R®
Heavy WeightFC - SSSV, Plug,Choke, Gauge
SelectiveCompletions
No-GoCompletions
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X® & R® Selective Landing Nipple/Locking Mandrel System
OTIS X®
Landing Nipple
OTIS® X®
Locking Mandrel
Nipples installed in tubing string in any order- reducing workover risk
Provides unlimited number of positions to set
Running tool allows selection of nipple to land and set the lock
Same ID in all nipples reducing flowing pressure loss and minimizing turbulence
Maximum flow capacity from large, straight-through bore of locking mandrel
Maximum versatility reducing completion and production maintenance costs
Allows for repositioning of flow controls as well conditions change
Keys of locking mandrel retracted into assembly while running and retrieving
Design BenefitsDesign Benefits
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Otis® RPT® No-Go Type Nipple and Lock Mandrel• Provides a means of running a series of positive location landing
nipples in a tubing string with minimum restriction• Locates on top of the polished bore of the nipple• No secondary restrictions normally associated with bottom no-go
profiles• Provides positive location of the lock and minimizes the possibility
of misruns
Applications
High-pressure, high temperature, large bore completions
For running a series of nipples in a tubing string when positive location and minimal ID reduction are required
Features
Large bore
Lock mandrel no-go locates on top of the nipples’ polished bore
Benefits
No secondary restrictions normally associated with bottom no- go profiles
Lock mandrels in a particular size range use the same running and pulling tools
RPT® Lock with Equalizing Valve and Cap installed in RPT
Nipple
Nippleless Plugs
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Applications in -• Horizontal wells where plug installation
after completion is undesirable• Setting production and isolation
packers• Testing tubing• Wells where slickline or CTU
intervention after completion is undesirable
Mirage® Disappearing Plug
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Autofill DeviceHydraulic-Set Packer Multi-cycle Mirage® PlugHow it works:
Mirage® Disappearing Plug and Autofill Device
1. Autofill and Mirage plug are run to depth below a hydraulic set packer. The tubing is filled through the Autofill when running downhole.
2. Multiple pressure cycles against the Mirage plug allows closure of Autofill, tubing test and setting of packer.
3. Final pressure cycle dissolves Mirage plug matrix for full bore access.
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Monolock® Plug
Applications• Retrievable bridge plug• Can be adapted to install BHP gauges and other
flow control devices• Plug tubing below hanger for wellhead repairs
Available in
3-1/2” thru 7”
Pressure rating base or 70% of pipe yield or maximum of 10,000 psi
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Benefits of Design
• Requires no landing nipple for broader applications
• Seals against pipe ID which can eliminate restrictive sealing bores in tubing string
• Retained in set position by internal slips providing same reliability as production packers
• Can use slickline rather than conductor line lowering installation and retrieval costs
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Can be installed and retrieved through restrictions
Plug is run in closed position increasing reliability
Can be run with DPU®, Baker setting tool, or hydraulic setting tool
Run on slickline, braided line, coiled tubing, or electric line
Soft set for sensitive equipment
Benefits of Design
Sliding Side-Door® Circulating Devices
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Applications in -
Producing alternate zone in single- selective completions
Circulating kill fluid eliminates expense of perforating tubing
Secondary recovery
Washing above packer
Design Capability-
Sizes for 1 1/2” to 7” production tubing
Pressure ratings equal to tubing ratings
Open-up and open-down options
A variety of materials and thread options
TOP SUB WITH TOP SUB WITH LANDING NIPPLELANDING NIPPLE PROFILEPROFILE
CLOSING SLEEVECLOSING SLEEVE
NONNON--ELASTOMERELASTOMER SEALSSEALSLARGE FLOWLARGE FLOW PORTSPORTSEQUALIZING PORTSEQUALIZING PORTS
BOTTOM SUB BOTTOM SUB WITH POLISHED BORE WITH POLISHED BORE END SUBEND SUB
DuraSleeve® Non-Elastomer Circulation / Production Sleeve
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Shifting Force of DURATEF™ ECM Seals
Designing sleeves to shift after years of production
Shifting forces for Nitrile Seal, PEEK seal, and the DURATEF™ ECM seal
Shifting forces for DuraSleeve® sliding sleeve are less than 1/5 the force required for sleeves with competitive
materials such as PEEK
Nitrile Seal* PEEK Seal ECM
3000 lbs
2500 lbs
2000 lbs
1500 lbs
1000 lbs
500 lbs
0 lbs* The Engineering T est Lab used the nitrile seal as a benchmark to compare the PEEK seal and the engineered composite seal.
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Slimline Sliding Side-Door® DeviceSlimline Sliding Side-Door® Device
• Small OD SSD designed for concentric string gravel pack completions
• Allows for running larger size tubing inside small ID casing
2 3/8” – 2.72 v. 3.25 OD2 7/8” – 3.22 v. 3.92 OD3 1/2” - 3.92 v. 4.50 OD
• OD’s comparable to CS Hydril upset• 5000 psi rating (more with material upgrade)• Tensile rating 60-70% of N-80 tubing• Standard B shifting tool
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SSD Variations
Surface controlled by control line
Pressure close/auto open device
Setting depth sensitive
Pressure activated (HASSD)
Run closed
Pressure tubing over annulus to activate
Opens on bleed down
Wellhead Plugs
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SRP Wellhead Plugs• Deepwater development has created
demand for wellhead plugs
• Used primarily in subsea trees
• Ultra-compact design allows for use in horizontal trees
• Available in equalizing and non- equalizing models
• High-pressure rating above and below
• No-go design with minimum restriction
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Design Features-
Compact length reduces space requirements of wellhead
Single leak path is through two full packing stacks
High pressure rating from above and below
Multiple shear pin hold down mechanisms for redundancy
Simple design for high reliability. Only two moving parts: keys and expander sleeve
SRP Wellhead Plug
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SRP wellhead with added back pressure valve
Redundant seal stacksBack pressure valve uses M-T-M seal with redundant seal stack
Equalizing plug w/ M-T-M seal plus redundant seal
Hold-down pins engage expander mandrel after set
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Design Features-
Redundant seals along all leak paths
OD leak path is through two full packing stacks
Equalizing plug leak path is through a static MTM seal and an O-ring
Valve leak path is through a MTM seal and a packing stack
Multiple shear pin hold down mechanisms for redundancy
Only three moving parts: keys, expander sleeve, and valve
Can hold pressure from above with the addition of a test prong
Cannot be pulled until equalized
Two options for equalizing prongs. One engages the knock-out plug and one pushes the dart off seat
SRP Wellhead Back Pressure Valve
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SRP Wellhead Back Pressure Valve
Optional test prong isolates the back pressure valve to allow pressure testing of SRP plug from above
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SSP Wellhead Plug
Interference Sleeve for Secondary Hold Down
MTM Seal
3° Taper
Second Fishneck
Third Fishneck
First Fishneck
• MTM seal plus a single packing stack, compatible with FMC wellhead
• Compact length• Test pressures up to 15,000 psi• PR-2 and vibration tested• Static after set
– Hydrostatic running tool applies predetermined force into expander sleeve taper
– 3 degree taper statically sets key into profile for no plug movement
• Secondary interference locking sleeve• Large throw keys• Three fishnecks
– Two fishnecks on expander sleeve– Additional fishneck on plug body
Expander Sleeve
Debris Barriers
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Wellhead Isolation Sleeve
ApplicationsApplications
•• Used to isolate flow wing valves during Used to isolate flow wing valves during tree testing and handling tree testing and handling
FeaturesFeatures
•• Interference Interference ““hold downhold down”” mechanismmechanism
•• Run and pulled using conventional Run and pulled using conventional wireline methodswireline methods
•• Debris barrierDebris barrier
•• Run and retrieved Run and retrieved ssingssing the same toolthe same tool
Accessory Items
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Flow CouplingsFlow couplings in the tubing are an important part of life-of-the-well completion planning. Flow couplings have a wall thickness greater than the corresponding tubing to inhibit erosion caused by flow turbulence. Flow couplings should be installed above and below landing nipples or other restrictions that may cause turbulent flow.
Applications
To help inhibit erosion caused by flow turbulence
Installed above and below landing nipples, tubing retrievable safety valves, or any other restriction that may cause turbulent flow
Benefits
Helps extend the life of the well completion
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Blast JointsBlast joints are installed in the tubing opposite perforations in wells with two or more zones. The blast joints are heavy walled and are sized to help prevent tubing damage from the jetting action of the zone perforations. Blast joints should be installed above and below landing nipples or other restrictions that may cause turbulent flow.
Applications
To help inhibit erosion caused by jetting action near perforations
Installed opposite perforations in one or more zones
Benefits
Helps extend the life of the well completion
Subsurface Flow Controls