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Subsurface flow controls external
 

Subsurface flow controls external

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    Subsurface flow controls external Subsurface flow controls external Presentation Transcript

    • Subsurface Flow Controls
    • 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 2
    • Locks and Landing Nipples
    • Nipple Profiles/Lock Mandrels Selective No-Go Monobore Completions Completions CompletionsX® RPT, RQ Monolock®STD Weight FC - SSSV, Plug, FC - Plug, Choke, Choke, Gauge GaugeFC - SSSV, Plug,Choke, Gauge FBN® SafetySet® SSSV Full Bore,R® Special Applications MonoboreHeavy Weight High Pressure and CompletionsFC - SSSV, Plug, Flow Rate FC - Plug, ChokeChoke, Gauge SRP Wellhead Plugs 4
    • X® & R® Selective Landing Nipple/Locking Mandrel System Design Benefits  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 mandrelOTIS® X®  Maximum versatility reducing completion and productionLocking OTIS X® maintenance costsMandrel Landing Nipple  Allows for repositioning of flow controls as well conditions change  Keys of locking mandrel retracted into assembly while running and retrieving 5
    • 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 misrunsApplications  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 requiredFeatures  Large bore  Lock mandrel no-go locates on top of the nipples’ polished boreBenefits RPT® Lock with Equalizing Valve and  No secondary restrictions normally associated with bottom no- Cap installed in RPT go profiles Nipple  Lock mandrels in a particular size range use the same running and pulling tools 6
    • Nippleless Plugs
    • Mirage® Disappearing PlugApplications 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 8
    • Mirage® Disappearing Plug and Autofill Device How it Hydraulic-Set Packer Autofill Device Multi-cycle Mirage® Plug works: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. 9
    • Monolock® PlugApplications • Retrievable bridge plug • Can be adapted to install BHP gauges and other flow control devices • Plug tubing below hanger for wellhead repairsAvailable in  3-1/2” thru 7”  Pressure rating base or 70% of pipe yield or maximum of 10,000 psi 10
    • 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 11
    • Benefits of Design 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 12
    • Sliding Side-Door® Circulating Devices
    • DuraSleeve® Non-ElastomerCirculation / Production Sleeve Applications in - TOP SUB WITH LANDING NIPPLE  Producing alternate zone in single- PROFILE selective completions  Circulating kill fluid eliminates expense of perforating tubing  Secondary recovery CLOSING SLEEVE  Washing above packer NON-ELASTOMER NON- SEALS Design Capability- LARGE FLOW PORTS  Sizes for 1 1/2” to 7” production tubing EQUALIZING PORTS  Pressure ratings equal to tubing ratings  Open-up and open-down options BOTTOM SUB WITH POLISHED BORE  A variety of materials and thread END SUB options 14
    • Shifting Force of DURATEF™ ECM Seals Designing sleeves to shift after years of production 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. 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 15
    • Slimline 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 OD 2 7/8” – 3.22 v. 3.92 OD 3 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 16
    • 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 17
    • Wellhead Plugs
    • 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 19
    • SRP Wellhead PlugDesign 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 20
    • SRP wellhead with added back pressurevalve Equalizing plug w/ M-T-M Redundant seal stacks seal plus redundant seal Back pressure valve uses M-T-M seal with redundant seal stack Hold-down pins engage expander mandrel after set 21
    • SRP Wellhead Back Pressure ValveDesign 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 22
    • SRP Wellhead Back PressureValveOptional test prong isolates the backpressure valve to allow pressure testingof SRP plug from above 23
    • SSP Wellhead Plug• MTM seal plus a single packing stack, compatible with FMC wellhead First Fishneck• Compact length Third Fishneck• Test pressures up to 15,000 psi Expander Sleeve• PR-2 and vibration tested Second Fishneck• Static after set – Hydrostatic running tool applies Debris Barriers predetermined force into expander sleeve taper 3° Taper – 3 degree taper statically sets key into profile for no plug movement• Secondary interference locking sleeve• Large throw keys MTM Seal• Three fishnecks – Two fishnecks on expander sleeve Interference Sleeve for – Additional fishneck on plug body Secondary Hold Down 24
    • Wellhead Isolation Sleeve Applications • Used to isolate flow wing valves during tree testing and handling Features • Interference “hold down” mechanism • Run and pulled using conventional wireline methods • Debris barrier • Run and retrieved ssing the same tool 25
    • Accessory Items
    • Flow CouplingsFlow 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, tubing retrievable safety valves, or any other restriction that may cause turbulent flowBenefits  Helps extend the life of the well completion 27
    • Blast JointsBlast 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 thezone 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 action near perforations  Installed opposite perforations in one or more zonesBenefits  Helps extend the life of the well completion 28
    • Subsurface Flow Controls