WO2009052114A2 - Water sensing adaptable inflow control device using a powered system - Google Patents
Water sensing adaptable inflow control device using a powered system Download PDFInfo
- Publication number
- WO2009052114A2 WO2009052114A2 PCT/US2008/079869 US2008079869W WO2009052114A2 WO 2009052114 A2 WO2009052114 A2 WO 2009052114A2 US 2008079869 W US2008079869 W US 2008079869W WO 2009052114 A2 WO2009052114 A2 WO 2009052114A2
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- flow control
- control element
- fluid
- flow
- water detector
- Prior art date
Links
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 title claims abstract description 67
- 239000012530 fluid Substances 0.000 claims abstract description 72
- 238000000034 method Methods 0.000 claims abstract description 13
- 238000005259 measurement Methods 0.000 claims abstract description 10
- 230000004044 response Effects 0.000 claims abstract description 9
- 238000004519 manufacturing process Methods 0.000 description 44
- 230000015572 biosynthetic process Effects 0.000 description 11
- 238000005755 formation reaction Methods 0.000 description 11
- 239000007789 gas Substances 0.000 description 8
- 229930195733 hydrocarbon Natural products 0.000 description 6
- 150000002430 hydrocarbons Chemical class 0.000 description 6
- 239000000463 material Substances 0.000 description 4
- 239000012267 brine Substances 0.000 description 2
- 238000010276 construction Methods 0.000 description 2
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 description 2
- 239000004215 Carbon black (E152) Substances 0.000 description 1
- 230000009471 action Effects 0.000 description 1
- 239000003990 capacitor Substances 0.000 description 1
- 239000004020 conductor Substances 0.000 description 1
- 238000001514 detection method Methods 0.000 description 1
- 238000005553 drilling Methods 0.000 description 1
- 230000003203 everyday effect Effects 0.000 description 1
- 230000004941 influx Effects 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 239000002184 metal Substances 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 150000003839 salts Chemical class 0.000 description 1
- 239000004576 sand Substances 0.000 description 1
- 239000002520 smart material Substances 0.000 description 1
- 238000011144 upstream manufacturing Methods 0.000 description 1
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
- 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
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/32—Preventing gas- or water-coning phenomena, i.e. the formation of a conical column of gas or water around wells
Definitions
- TITLE WATER SENSING ADAPTABLE INFLOW CONTROL DEVICE USING A POWERED SYSTEM
- the disclosure relates generally to systems and methods for selective control of fluid flow into a production string in a wellbore.
- Hydrocarbons such as oil and gas are recovered from a subterranean formation using a wellbore drilled into the formation.
- Such wells are typically completed by placing a casing along the wellbore length and perforating the casing adjacent each such production zone to extract the formation fluids (such as hydrocarbons) into the wellbore.
- These production zones are sometimes separated from each other by installing a packer between the production zones. Fluid from each production zone entering the wellbore is drawn into a tubing that runs to the surface. It is desirable to have substantially even drainage along the production zone. Uneven drainage may result in undesirable conditions such as an invasive gas cone or water cone.
- a gas cone may cause an inflow of gas into the wellbore that could significantly reduce oil production.
- a water cone may cause an inflow of water into the oil production flow that reduces the amount and quality of the produced oil. Accordingly, it is desired to provide even drainage across a production zone and / or the ability to selectively close off or reduce inflow within production zones experiencing an undesirable influx of water and/or gas.
- the present disclosure provides an apparatus for controlling a flow of fluid into a wellbore tubular disposed in a wellbore that intersects a subterranean formation of interest.
- the apparatus may include a flow control element configured to control the flow of fluid into the wellbore tubular; and a water detector operably coupled to the flow control element.
- the water detector may be configured to actuate the flow control element in response to a measurement of a property of the flowing fluid.
- the water detector is a capacitive proximity sensor.
- the measured property may be a dielectric constant.
- the flow control element may be configured to permit a predetermined amount of flow of fluid after being actuated to a closed position.
- the water detector may be configured to measure a property of the fluid flowing after the flow control element has been actuated to the closed position.
- the apparatus may include a power storage element connected to the flow control element.
- the flow control element may be configured to move between an open position and a closed position based on a charge state of the power storage element.
- the present disclosure provides a method for controlling a flow of fluid into a wellbore tubular in a wellbore. The method may include positioning a flow control element along the wellbore tubular to control the flow of fluid into the wellbore tubular; measuring a property of a flowing fluid using a water detector; and actuating the flow control element in response to the measurement.
- the present disclosure provides a system for controlling a flow of fluid in a well.
- the system may include a tubular positioned in the well; at least one flow control element positioned along the tubular, the at least one flow control element being configured to control the flow of fluid into the wellbore tubular; and a water detector operably coupled to the flow control element, the water detector being configured to actuate the flow control element in response to a measurement of a property of a flowing fluid.
- Fig. 1 is a schematic elevation view of an exemplary multi-zonal wellbore and production assembly which incorporates an inflow control system in accordance with one embodiment of the present disclosure
- Fig. 2 is a schematic elevation view of an exemplary open hole production assembly which incorporates an inflow control system in accordance with one embodiment of the present disclosure
- Fig. 3 is a schematic cross-sectional view of an exemplary production control device made in accordance with one embodiment of the present disclosure
- Fig. 4 is a schematic view of an powered in-flow control device made in accordance with one embodiment of the present disclosure.
- Fig. 5 is a schematic of another in-flow control device made in accordance with one embodiment of the present disclosure.
- the present disclosure relates to devices and methods for controlling production of a hydrocarbon producing weli.
- the present disclosure is susceptible to embodiments of different forms. There are shown in the drawings, and herein will be described in detail, specific embodiments of the present disclosure with the understanding that the present disclosure is to be considered an exemplification of the principles of the disclosure and is not intended to limit the disclosure to that illustrated and described herein. Further, while embodiments may be described as having one or more features or a combination of two or more features, such a feature or a combination of features should not be construed as essential unless expressly stated as essential.
- FIG. 1 there is shown an exemplary wellbore 10 that has been drilled through the earth 12 and into a pair of formations 14, 16 from which it is desired to produce hydrocarbons.
- the wellbore 10 is cased by metal casing, as is known in the art, and a number of perforations 18 penetrate and extend into the formations 14, 16 so that production fluids may flow from the formations 14, 16 into the wellbore 10.
- the wellbore 10 has a deviated, or substantially horizontal leg 19.
- the wellbore 10 has a late-stage production assembly, generally indicated at 20, disposed therein by a tubing string 22 that extends downwardly from a wellhead 24 at the surface 26 of the wellbore 10.
- the production assembly 20 defines an internal axial flowbore 28 along its length.
- An annulus 30 is defined between the production assembly 20 and the wellbore casing.
- the production assembly 20 has a deviated, generally horizontal portion 32 that extends along the deviated leg 19 of the wellbore 10.
- Production devices 34 are positioned at selected points along the production assembly 20.
- each production device 34 is isolated within the welfbore 10 by a pair of packer devices 36. Although only two production devices 34 are shown in Fig. 1, there may, in fact, be a large number of such production devices arranged in serial fashion along the horizontal portion 32.
- Each production device 34 features a production control device 38 that is used to govern one or more aspects of a flow of one or more fluids into the production assembly 20.
- the term "fluid” or “fluids” includes liquids, gases, hydrocarbons, multi-phase fluids, mixtures of two of more fluids, water, brine, engineered fluids such as drilling mud, fluids injected from the surface such as water, and naturally occurring fluids such as oil and gas. Additionally, references to water should be construed to also include water-based fluids; e.g., brine or salt water.
- the production control device 38 may have a number of alternative constructions that ensure selective operation and controlled fluid flow therethrough.
- FIG. 2 illustrates an exemplary open hole wellbore arrangement 11 wherein the production devices of the present disclosure may be used. Construction and operation of the open hole wellbore 11 is similar in most respects to the wellbore 10 described previously. However, the wellbore arrangement 11 has an uncased borehole that is directly open to the formations 14, 16. Production fluids, therefore, flow directly from the formations 14, 16, and into the annulus 30 that is defined between the production assembly 21 and the wall of the wellbore 11. There are no perforations, and open hole packers 36 may be used to isolate the production control devices 38. The nature of the production control device is such that the fluid flow is directed from the formation 16 directly to the nearest production device 34, hence resulting in a balanced flow.
- a production control device 100 for controlling the flow of fluids from a reservoir into a flow bore 102 of a wellbore tubular (e.g., tubing string 22 of Fig. 1).
- This flow control may be a function of water content.
- the control devices 100 can be distributed along a section of a production well to provide fluid control at multiple locations. This can be advantageous, for example, to equalize production flow of oil in situations wherein a greater flow rate is expected at a "heel" of a horizontal well than at the "toe" of the horizontal well.
- a well owner can increase the likelihood that an oil bearing reservoir will drain efficiently. Exemplary devices for controlling one or more aspects of production are discussed herein below.
- the production control device 100 includes a particulate control device 110 for reducing the amount and size of particulates entrained in the fluids, a flow control device 120 that controls overall drainage rate from the formation, and an in-flow control device 130 that controls the rate or amount of flow area based upon the presence of water content fluid in a flowing fluid.
- the particulate control device 110 can include known devices such as sand screens and associated gravel packs.
- the in-flow control device 130 may utilize power supplied by a power source, which may be downhole or at the surface, to selectively actuate a flow control element 132 that is configured to restrict fluid flow into the flow bore 102.
- the actuation of the flow control element 132 is based on the measurements of a water detector 134 that may be configured to measure one or more properties of the fluid.
- the property may be a material property (e.g., viscosity, density, etc.) or an electrical property (e.g., dielectric constant, conductivity, etc.). Other illustrative embodiments are discussed below.
- a material property e.g., viscosity, density, etc.
- an electrical property e.g., dielectric constant, conductivity, etc.
- FIG. 4 there is shown one embodiment of an inflow control device 140 that may be used to control flow of a fluid into a flow bore 102 of a wellbore tubular, such as a tubing 22 (Fig. 1).
- the in-flow control device 140 may include a water detector 142, a flow control element 144, and a power circuit 146.
- the water detector 142 may be positioned downstream or upstream of the flow control element 144 and either inside or outside of the in-flow control device 140. In embodiments, the water detector 142 may be responsive to the presence of water in the fluid flowing through the in-flow control device 140. For example, upon detecting water or detecting a preprogrammed threshold amount of water, the water detector 142 may transmit a signal to the flow control element 144 or actuate a switch in a circuit containing the flow control element 144. The flow control element 144 may be actuated between an open position and a closed position after receiving the signal or after actuation of the switch.
- the flow control element 144 may be a sliding sleeve valve, a choke, a poppet valve, a throttle, or any similar device configured to partially or completely restrict flow from the in- flow control device 140 to the flow bore 102.
- the power circuit 146 may be configured to supply electrical power to the water detector 142 and / or the flow control element 144.
- the power circuit may include a downhole power generator such as a turbine 148 in the flow bore 102 that is energized by the production fluid flowing therethrough.
- the power circuit may include a conductor (not shown) that supplies power from the surface, a downhole battery, a piezoelectric generator or other like devices.
- the flow control element 144 is initially set in an open position to allow fluid flow across the in-flow control device 140. As long as the water detector 142 does not detect water, the flow control element 144 remains in the open position. Upon detecting water, the water detector 142 transmits a signal or actuates a switch that causes the power circuit 146 to energize the flow control element 144. When energized, the flow control element 144 shifts from the open position to the closed position. The flow control element 144 may remain in the closed position permanently or may revert to the open position either on its own or upon the occurrence of a pre-determined condition.
- the in-flow control device 160 may include a dielectric sensor 162, an electromagnetic valve 164, and a power circuit 166.
- the dielectric constant for water is much greater than that of hydrocarbons.
- the dielectric sensor 162 may be configured as a capacitive proximity sensor or other suitable sensor that measures, directly or indirectly, the dielectric constant of the fluid in the vicinity of the in-flow control device 160 to determine whether water is present.
- the dielectric sensor 162 may include a control device such as a switch 168 that controls the supply of power to the valve 164.
- the power circuit 166 may be configured to supply electrical power to the dielectric sensor 162 and the valve 164.
- the power circuit 166 may be connected to a downhole power source 170 such as a turbine, a battery, a piezoelectric generator or other suitable power source.
- the power circuit 166 may also include power storage elements 172, which may be capacitors.
- the electromagnetic valve 164 may be configured to be in an open position to permit flow along the in-flow control device 160. The electromagnetic valve 164 may be shifted to the closed position by charging the power storage element 172. The electromagnetic valve 164 may revert to the open position after the power storage element 172 loses its charge.
- the valve 164 may be a sliding sleeve valve, a poppet valve, a throttle, or any similar device configured to partially or complete restrict flow from the inflow control device 160 to the flow bore 102 (Fig. 3). Additionally, in arrangements, the electrical power may be used to activate a "smart material" such as magnetostrictive material, an electrorheological fluid that is responsive to electrical current, a magnetorheological fluid that is responsive to a magnetic field, or piezoelectric materials that are responsive to an electrical current. These "smart" materials also may be used to actuate a flow restriction element between an open position and a closed position. [0017] In one mode of operation, the valve 164 is initially set in an open position to allow fluid flow across the in-flow control device 160.
- the downhole power source 170 by itself or in conjunction with the power storage element 172 may energize the dielectric sensor 162. As long as the dielectric sensor 162 does not detect water, the electromagnetic valve 164 remains in the open position. It should be understood that the in-flowing fluid may always have some amount of water. Thus, the dielectric sensor 162 may be configured to take an action upon measuring a dielectric constant indicative of a given quantity of water. Upon detecting water or a specified amount of water, the dielectric sensor 162 actuates the switch 168 to close the circuit 166. Thereafter, the downhole power source 170 supplies electrical energy that charges the power storage element 172, if the power storage element 172 has not been previously charged.
- the charged power storage element 172 causes the electromagnetic valve 164 to shift from the open position to the closed position.
- the electrical charge of power storage element 172 may energize a solenoid associated with the valve 164.
- the valve 164 may completely stop fluid flow.
- the valve 164 is configured to permit a controlled amount of fluid in-flow so that the dielectric sensor 162 may continuously monitor fluid flow and detect changes in the amount of water in the fluid in-fiow. For example, if water incursion has dissipated once the valve 164 has been closed, then it may be advantageous to re-open the valve 164.
- the dielectric sensor 162 may be configured to open the switch 168 to stop the flow of electrical power to the power storage element 172.
- the electromagnetic valve 164 returns to the open position.
- the electromagnetic valve 164 may be cycled between the open and closed positions in response to the measurements made by the dielectric sensor 162.
- the power storage element 172 will gradually lose its electrical charge.
- the electromagnetic valve 164 returns to the open position. This may be the case whether or not the dielectric sensor 162 is detecting water. If the dielectric sensor 162 is still detecting water, then the switch 170 remains closed and the downhole power source 170 recharges the power storage element 172. Once the power storage element 172 has a sufficient charge, the electromagnetic valve 164 returns to the closed position. Thus, the electromagnetic valve 164 may cycle between the open and closed positions until the dielectric sensor 162 detects no water in the fluid.
- the in-flow control device may utilize electronics programmed to periodically "wake up” the water detector to measure water content.
- "wake up" circuitry may be programmed to operate a water detector periodically, e.g., every day or every week. Thus, power may be conserved by not continuously operating the water detector.
- Figs. 1 and 2 are intended to be merely illustrative of the production systems in which the teachings of the present disclosure may be applied.
- the wellbores 10, 11 may utilize only a casing or liner to convey production fluids to the surface.
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- 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)
- Other Liquid Machine Or Engine Such As Wave Power Use (AREA)
- Flow Control (AREA)
- Measuring Volume Flow (AREA)
- Pipeline Systems (AREA)
- Investigating Or Analyzing Materials By The Use Of Electric Means (AREA)
Abstract
Description
Claims
Priority Applications (3)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
BRPI0817821 BRPI0817821A2 (en) | 2007-10-19 | 2008-10-14 | Flow control device adaptable to water detection using an energized system |
AU2008312601A AU2008312601A1 (en) | 2007-10-19 | 2008-10-14 | Water sensing adaptable inflow control device using a powered system |
NO20100554A NO20100554L (en) | 2007-10-19 | 2010-04-19 | Water-sensing adaptable inflow control device employing a power-driven system |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US11/875,464 US20090101329A1 (en) | 2007-10-19 | 2007-10-19 | Water Sensing Adaptable Inflow Control Device Using a Powered System |
US11/875,464 | 2007-10-19 |
Publications (2)
Publication Number | Publication Date |
---|---|
WO2009052114A2 true WO2009052114A2 (en) | 2009-04-23 |
WO2009052114A3 WO2009052114A3 (en) | 2009-07-09 |
Family
ID=40562277
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/US2008/079869 WO2009052114A2 (en) | 2007-10-19 | 2008-10-14 | Water sensing adaptable inflow control device using a powered system |
Country Status (5)
Country | Link |
---|---|
US (1) | US20090101329A1 (en) |
AU (1) | AU2008312601A1 (en) |
BR (1) | BRPI0817821A2 (en) |
NO (1) | NO20100554L (en) |
WO (1) | WO2009052114A2 (en) |
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US11753910B2 (en) | 2016-11-18 | 2023-09-12 | Halliburton Energy Services, Inc. | Variable flow resistance system for use with a subterranean well |
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Also Published As
Publication number | Publication date |
---|---|
US20090101329A1 (en) | 2009-04-23 |
WO2009052114A3 (en) | 2009-07-09 |
BRPI0817821A2 (en) | 2015-03-31 |
NO20100554L (en) | 2010-07-01 |
AU2008312601A1 (en) | 2009-04-23 |
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