sub surface flow control slide

8/10/2019 Sub Surface Flow Control Slide

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Subsurface Flow Controls


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Landing Nipples X , R , RPT, FBN

Lock Mandrels and accessories

Nippleless Tubing Plugs - Mirage plug,Monolock

DuraSleeve

Sliding Side-Door

circulatingdevice

Wellhead Plugs - SRP, SSP

Back Pressure Valve- SRP

Accessory Items flow couplings, blast joints


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Locks and Landing Nipples


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Nipple Profiles/Lock Mandrels

Monolock FC - Plug, Choke,Gauge

FBN Full Bore,MonoboreCompletionsFC - Plug, Choke

XSTD WeightFC - SSSV, Plug,Choke, Gauge

RPT, RQFC - SSSV, Plug,Choke, Gauge

SafetySet SSSVSpecial ApplicationsHigh Pressure andFlow Rate

SRPWellhead Plugs

MonoboreCompletions

RHeavy WeightFC - SSSV, Plug,Choke, Gauge

SelectiveCompletions

No-GoCompletions


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X & R Selective Landing Nipple/Locking Mandrel System

OTIS X LandingNipple

OTIS XLockingMandrel

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 lockingmandrel

Maximum versatility reducing completion and productionmaintenance costs

Allows for repositioning of flow controls as well conditions change

Keys of locking mandrel retracted into assembly while running andretrieving

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 landingnipples 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 positivelocation 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 runningand pulling tools

RPT Lock withEqualizing Valve andCap installed in RPT

Nipple


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Nippleless Plugs


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Applications in -

Horizontal wells where plug installationafter completion is undesirable Setting production and isolation

packers Testing tubing Wells where slickline or CTU

intervention after completion isundesirable

Mirage Disappearing Plug


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Autofi ll DeviceHydraulic-Set Packer Multi-cycle Mirage PlugHow itworks:

Mirage Disappearing Plug and Autofill Device

1. Autofill and Mirage plug are run to depth below ahydraulic set packer. The tubing is filled through the

Autofill when running downhole.

2. Multiple pressure cycles against the Mirage plugallows 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 ormaximum of 10,000 psi


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Benefits of Design

Requires no landing nipple for broaderapplications

Seals against pipe ID which can eliminaterestrictive sealing bores in tubing string

Retained in set position by internal slips

providing same reliability as production packers

Can use slickline rather than conductor linelowering 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, orhydraulic setting tool

Run on slickline, braided line, coiled tubing, orelectric line

Soft set for sensitive equipment

Benefits of Design


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Sliding Side-Door Circulating Devices


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Applications in -

Producing alternate zone in single-selective completions

Circulating kill fluid eliminates expenseof perforating tubing

Secondary recovery

Washing above packer

Design Capability-

Sizes for 1 1/2 to 7 production tubing

Pressure ratings equal to tubingratings

Open-up and open-down options

A variety of materials and thread

options

TOP SUB WITHTOP SUB WITHLANDING NIPPLELANDING NIPPLEPROFILEPROFILE

CLOSING SLEEVECLOSING SLEEVE

NONNON --ELASTOMERELASTOMERSEALSSEALSLARGE FLOWLARGE FLOWPORTSPORTSEQUALIZING PORTSEQUALIZING PORTS

BOTTOM SUBBOTTOM SUBWITH POLISHED BOREWITH POLISHED BOREEND SUBEND SUB

DuraSleeve Non-ElastomerCirculation / 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 lessthan 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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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


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Wellhead Plugs


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SRP Wellhead Plugs

Deepwater development has createddemand for wellhead plugs

Used primarily in subsea trees

Ultra-compact design allows for use inhorizontal 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: keysand expander sleeve

SRP Wellhead Plug


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SRP wellhead with added back pressurevalve

Redundant seal stacksBack pressure valveuses M-T-M seal withredundant seal stack

Equalizing plug w/ M-T-Mseal p lus redundant seal

Hold-down pins engageexpander 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 backpressure valve to allow pressure testingof SRP plug from above


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SSP Wellhead Plug

Interference Sleeve forSecondary 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 appliespredetermined 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

Applications Applications

Used to isolate flow wing valves duringUsed to isolate flow wing valves during

tree testing and handlingtree testing and handling

FeaturesFeatures

InterferenceInterference hold downhold down mechanismmechanism

Run and pulled using conventionalRun and pulled using conventional

wireline methodswireline methods

Debris barrier Debris barrier

Run and retrievedRun and retrieved ssingssing the same toolthe same tool


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Accessory Items


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Flow Couplings

Flow couplings in the tubing are an important part of life-of-the-wellcompletion planning. Flow couplings have a wall thickness greaterthan the corresponding tubing to inhibit erosion caused by flowturbulence. Flow couplings should be installed above and belowlanding nipples or other restrictions that may cause turbulent flow.

Applications

To help inhibit erosion caused by flow turbulence

Installed above and below landing nipples, tubingretrievable safety valves, or any other restriction that maycause turbulent flow

Benefits

Helps extend the life of the well completion


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Blast Joints

Blast joints are installed in the tubing oppositeperforations in wells with two or more zones. Theblast joints are heavy walled and are sized to helpprevent tubing damage from the jetting action of the

zone perforations. Blast joints should be installedabove and below landing nipples or other restrictionsthat may cause turbulent flow.

Applications

To help inhibit erosion caused by jetting actionnear perforations

Installed opposite perforations in one or more

zones

Benefits

Helps extend the life of the well completion


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