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