Classifications

• • E—FIXED CONSTRUCTIONS
  • E21—EARTH OR ROCK DRILLING; MINING
  • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
  • E21B34/00—Valve arrangements for boreholes or wells
  • E21B34/06—Valve arrangements for boreholes or wells in wells
  • E21B34/08—Valve arrangements for boreholes or wells in wells responsive to flow or pressure of the fluid obtained
• • E—FIXED CONSTRUCTIONS
  • E21—EARTH OR ROCK DRILLING; MINING
  • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
  • E21B23/00—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
  • E21B23/004—Indexing systems for guiding relative movement between telescoping parts of downhole tools
  • E21B23/006—"J-slot" systems, i.e. lug and slot indexing mechanisms
• • E—FIXED CONSTRUCTIONS
  • E21—EARTH OR ROCK DRILLING; MINING
  • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
  • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
  • E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
• • E—FIXED CONSTRUCTIONS
  • E21—EARTH OR ROCK DRILLING; MINING
  • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
  • E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
  • E21B2200/02—Down-hole chokes or valves for variably regulating fluid flow
• • E—FIXED CONSTRUCTIONS
  • E21—EARTH OR ROCK DRILLING; MINING
  • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
  • E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
  • E21B2200/06—Sleeve valves
• • E—FIXED CONSTRUCTIONS
  • E21—EARTH OR ROCK DRILLING; MINING
  • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
  • E21B34/00—Valve arrangements for boreholes or wells
  • E21B34/06—Valve arrangements for boreholes or wells in wells
  • E21B34/063—Valve or closure with destructible element, e.g. frangible disc

Definitions

• FIG. 1 therein is depicted an exemplary well system 10 comprising a wellbore 12 with both a substantially vertical section 14 and a substantially horizontal section 16, casing 18, tubular string 20, plurality of spaced apart packers 22 and flow control devices 24, and a formation 26.
• Frictional effects of the fluid flow through the tubular string 20 may result in increased fluid pressure loss in the uphole section of the tubular string 20 disposed in the horizontal section 16. This pressure loss results in an increased pressure differential between the uphole sections of the tubular string 20 disposed in the horizontal section 16 and the formation 26, which in turn results in a higher flow rate into the uphole section of the tubular string 20.
• isolating each fluid control device 24 allows for the tailoring of the metering capability of each fluid control device 24 to result in a more even flow rate into each section of the tubular string 20.
• the uphole flow control devices 24 could include larger flow restrictions to act against the larger differential pressure forcing fluid into the flow control devices.
• the biasing member 126 may comprise a compression spring disposed about the tubular member 102 in the chamber 108c and is initially restrained from movement in a compressed state by shear member 124. Furthermore, the biasing member 126 produces a biasing force against the shear member 124.
• the shearing member 124 and the biasing member 126 are designed such that the shearing member can withstand the biasing force without shearing.
• FIG. 2B depicts the biasing member 126 to be a spring, any suitable biasing mechanism may be used to provide a force to the piston 114 as described herein, such as disc springs, torsion springs, gas springs, elastomeric members and the like.
• fluid enters the flow control device 100 through first port 106 and then passes through fluid passage 112 of flow restrictor 110, which creates a pressure drop between fluid entering the flow restrictor and fluid exiting the flow restrictor.
• the fluid passing along flow path 130 is prevented from flowing around or bypassing the flow restrictor 110 due to the seal 120a located on the flow restrictor which seals the engaging surfaces of the flow restrictor 110 and the piston 114. Having exited the flow restrictor 110, the fluid then follows flow path 130 through second port 122 and into the tubular member 102.
• the shear member 124 may be configured to shear at a known applied force, such the amount of pressure needed to be applied to the fluid in the tubular member 102 may be calculated so an operator of the well system will know approximately what pressure must be applied to the tubular member 102 for the shearing member 124 to be sheared.
• an operator will reduce the pressure within the tubular member 102 until a pressure differential is created in which there is a higher pressure in the fluid of a formation 26 surrounding the flow control device 100 and a lower pressure in the tubular member 102.
• the reduced pressure in the tubular member 102 results in a reduction of pressure and thus a reduced force acting on the first side 116 of the piston 114.
• the reduced force acting on the first side 116 is offset by the biasing force produced by the biasing member 126.
• a second flow path 134 results. Fluid passing along second flow path 134 first enters the filter 104 and flows into the flow control device 100 through the first port 106. Following this, the fluid in the flow path 134 flows around the flow restrictor 110, through gap 138 that is formed between the piston 114 and the flow restrictor 110. Then, the fluid in flow path 134 is directed through the second port 122 and into the internal fluid passageway 102a of tubular member 102.
• lug 706 occupies first position 708 (FIG. 8), and is in contact with the outer wall of slot 702. Because lug 706 is fixed in the axial direction due to the disposition of ring 704 within a slot of housing wall 108a, the engagement of lug 706 in first position 708 with the outer wall of slot 702 prevents piston 114 from axial movement in the direction of first port 106.
• another method for producing hydrocarbons from a well system may comprise flowing a fluid from a formation into an internal passageway of a production string. As the fluid enters the production string, it flows through a filter and an ICD to create a pressure drop in the fluid flow as it enters the internal passageway. After a period of producing fluid from the formation, fluid may be pumped into the production string from the surface, such as to create an internal pressure differential where the pressure within the internal passageway is higher than the pressure in the surrounding wellbore and formation. This internal pressure differential actuates a bypass of the flow restrictor disposed within each ICD in the production string. However, in another embodiment, this internal pressure differential may only actuate a portion of the ICDs in the production string.

Landscapes

• Geology (AREA)
• Life Sciences & Earth Sciences (AREA)
• Engineering & Computer Science (AREA)
• Mining & Mineral Resources (AREA)
• Environmental & Geological Engineering (AREA)
• Fluid Mechanics (AREA)
• Physics & Mathematics (AREA)
• General Life Sciences & Earth Sciences (AREA)
• Geochemistry & Mineralogy (AREA)
• Flow Control (AREA)
• Fluid-Pressure Circuits (AREA)
• Pipe Accessories (AREA)
• Percussive Tools And Related Accessories (AREA)

Priority Applications (8)

Applications Claiming Priority (1)

Publications (1)

Family

ID=49379044

Family Applications (1)

Country Status (8)

Cited By (1)

Families Citing this family (24)

Citations (4)

Family Cites Families (14)

• 2012
  • 2012-04-18 EP EP12874466.1A patent/EP2839109A4/en not_active Withdrawn
  • 2012-04-18 AU AU2012377410A patent/AU2012377410B2/en not_active Ceased
  • 2012-04-18 CN CN201280072521.7A patent/CN104246119A/zh active Pending
  • 2012-04-18 SG SG11201405957TA patent/SG11201405957TA/en unknown
  • 2012-04-18 IN IN7789DEN2014 patent/IN2014DN07789A/en unknown
  • 2012-04-18 WO PCT/US2012/034010 patent/WO2013158085A1/en not_active Ceased
  • 2012-04-18 US US13/814,930 patent/US9260938B2/en active Active
  • 2012-04-18 CA CA2870840A patent/CA2870840A1/en not_active Abandoned

Patent Citations (4)

Non-Patent Citations (1)

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