Subsurface Flow Controls

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 Completions No-Go Completions Monobore Completions X STD Weight FC - SSSV, Plug, Choke, Gauge R Heavy Weight FC - SSSV, Plug, Choke, Gauge RPT, RQ FC - SSSV, Plug, Choke, Gauge SafetySet SSSV Special Applications High Pressure and Flow Rate SRP Wellhead Plugs Monolock FC - Plug, Choke, Gauge FBN Full Bore, Monobore Completions FC - Plug, Choke 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 mandrel OTIS X Locking Mandrel OTIS X Landing Nipple 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 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 misruns Applications Features 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 Large bore Lock mandrel no-go locates on top of the nipples polished bore Benefits No secondary restrictions normally associated with bottom nogo profiles Lock mandrels in a particular size range use the same running and pulling tools 6 RPT Lock with Equalizing Valve and Cap installed in RPT Nipple

Nippleless Plugs

Mirage Disappearing Plug 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 8

Mirage Disappearing Plug and Autofill Device How it works: Hydraulic-Set Packer Autofill Device Multi-cycle Mirage Plug 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 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 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-Elastomer Circulation / Production Sleeve TOP SUB WITH LANDING NIPPLE PROFILE CLOSING SLEEVE NON-ELASTOMER SEALS LARGE FLOW PORTS EQUALIZING PORTS BOTTOM SUB WITH POLISHED BORE END SUB Applications in - Producing alternate zone in singleselective 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 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 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 nonequalizing models High-pressure rating above and below No-go design with minimum restriction 19

SRP Wellhead Plug 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 20

SRP wellhead with added back pressure valve Redundant seal stacks Equalizing plug w/ M-T-M 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 Valve 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 22

SRP Wellhead Back Pressure Valve Optional test prong isolates the back pressure valve to allow pressure testing of SRP plug from above 23

SSP Wellhead Plug 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 First Fishneck Third Fishneck Expander Sleeve Second Fishneck Debris Barriers 3 Taper MTM Seal Interference Sleeve for 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 Couplings Flow 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 27

Blast Joints Blast 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 28

Subsurface Flow Controls