US20140116688A1 - Downhole water detection system and method - Google Patents
Downhole water detection system and method Download PDFInfo
- Publication number
- US20140116688A1 US20140116688A1 US14/148,045 US201414148045A US2014116688A1 US 20140116688 A1 US20140116688 A1 US 20140116688A1 US 201414148045 A US201414148045 A US 201414148045A US 2014116688 A1 US2014116688 A1 US 2014116688A1
- Authority
- US
- United States
- Prior art keywords
- water
- chemical element
- detectable
- formation
- detectable chemical
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Abandoned
Links
Images
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B44/00—Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/12—Packers; Plugs
- E21B33/1208—Packers; Plugs characterised by the construction of the sealing or packing means
Definitions
- a tubular conduit such as a string of tubing extending from the well surface to a subterranean location
- plugs are designed to be permanently installed, and they must be drilled or milled to be removed, which can be labor intensive.
- Other types of plugs are designed to be retrieved when the purpose for which the plug has been installed has been accomplished.
- Retrievable plugs generally employ some form of releasable anchoring device by which the plug may be secured to the internal bore of the well pipe and which may then be released to enable the plug to be withdrawn.
- One disadvantage of this prior art arrangement is that a restriction in the internal diameter of the tubing string often accompanies the design.
- the prior art plugs were often retrieved on a wireline and the retrieval operation was complicated in the case of deviated well bores. Debris that sometimes accumulates on the top of the retrievable plug can also cause issues in the wellbore.
- Another prior art plug design involves the incorporation of a plug of expendable material and an actuating device used to dislocate or fracture the plug upon receipt of a triggering signal.
- the potential for remaining and problematic debris from the plug in the tubing string or wellbore must be carefully monitored in such devices.
- Sand plugs, for instance, have been provided for zonal isolation within wellbores, however the integrity of such sand plugs can be inconsistent and remaining particulates must be dealt with.
- a downhole water detection system configured to detect presence of water in an underground location, the system includes: a chemical sensor disposable within a tubular in a borehole; and a first water detection body including a first detectable chemical element surrounded by water soluble glass, wherein the first water detection body is locatable within a fractured formation; wherein the chemical sensor is arranged to sense the first detectable chemical element when formation water dissolves the water soluble glass.
- a method of detecting water in a formation includes directing a first water detection body including a first detectable chemical element embedded within water soluble glass to an underground location of a formation.
- FIG. 1 depicts a schematic view of a well bore completion showing an exemplary embodiment of a dissolvable plug
- FIG. 2 depicts a cross sectional view of an exemplary embodiment of the dissolvable plug of FIG. 1 ;
- FIG. 3 depicts a cross sectional view of another exemplary embodiment of the dissolvable plug of FIG. 1 ;
- FIG. 4 depicts a cross-sectional view of an exemplary embodiment of a dissolution advancement system
- FIGS. 5A-5C depict various embodiments of a protective oil-based layer on the dissolvable plug of FIG. 1 ;
- FIG. 6 depicts a schematic view of an exemplary embodiment of a chemical employing system for removing the protective oil-based layer of FIGS. 5A-5C ;
- FIG. 7 depicts a schematic view of an exemplary embodiment of a mechanical device for removing the protective oil-based layer of FIGS. 5A-5C ;
- FIG. 8 depicts a schematic view of an exemplary embodiment of a system for detecting formation water
- FIG. 9 depicts a circuit diagram for use with a chemical sensor within the exemplary system of FIG. 8 ;
- FIG. 10 depicts a circuit diagram of an exemplary embodiment of a closure device.
- a wellbore 10 is shown lined with a casing 12 , also known as a tubular, tubular housing, string, etc.
- a tubing mounted valve 14 may be located within the string of casing 12 .
- a packer 16 isolates an annular region 18 between the casing 12 and the wellbore 10 .
- a dissolvable plug 20 initially closes off flow from a perforated zone 100 up the internal bore 22 of the casing 12 to the well surface 24 .
- the dissolvable plug 20 forms a portion of the well tool 26 , and may, in one exemplary embodiment, have an outer diameter which is approximately equal to an internal diameter of the casing 12 forming the flow path to the well surface 24 where the plug 20 is seated.
- the plug 20 advantageously need not require any significant constructions or devices that restricts an internal diameter of the internal bore 22 of the casing 12 , however, as shown in FIG. 2 , a small seat 30 such as seating device or shoulder or other protrusion may be provided to ensure that the plug 20 does not slide out of place.
- the seating device 30 may be made from the same dissolvable material as the plug 20 .
- the casing 12 may include a section 36 have an internal diameter in an area for receiving the plug 20 that is larger than an internal diameter of a remainder of the internal bore 22 of the casing 12 .
- the plug 20 may be formed with the casing 12 prior to positioning the tubing in the wellbore 10 .
- the plug 20 may be formed and pre stressed within a section of the tubing string or casing 12 to provide sufficient strength against pressure within the tubing.
- the plug 20 may first be formed as a separate element and then secured within the casing 12 using an adhesive component such as, but not limited to, the same dissolvable material as the plug 20 .
- the plug 20 is made of water soluble glass, which is made from silica and soda. Soda reduces the melting point of silica, which makes it easier to create glass, and soda also renders the glass water soluble.
- soda-lime glass also called soda-lime-silica glass, where the lime is added to restore insolubility.
- the plug 20 made from soda and silica and without lime, the water soluble glass plug 20 will dissolve when in contact with water or steam.
- the solubility rate is temperature sensitive to the water that it is dissolved in, and salt water has been shown to dissolve the water soluble glass at a slower rate.
- the material remains intact at high temperatures, such as about 1500° F. to about 2000° F.
- the plug 20 is insoluble to oil and petroleum based liquids and this feature may be advantageously employed in the present invention.
- the plug 20 is formed using water soluble glass with dimensions and content suitable for its intended applications.
- the solubility can be modulated.
- the thickness and soda content of a plug 20 can be adjusted such that a wellbore tool 26 , such as a packer, remains plugged until the required operation is carried out.
- the removal of the plug 20 may be determined based on intended use.
- the plug 20 is installed in the wellbore tool 26 in a conventional manner and may be allowed to begin dissolving while the operation is being carried out, so long as the plug 20 is not completely dissolved until after the operation is completed.
- the thickness of the plug 20 may be sufficiently thick and the soda content sufficiently low such that the plug 20 barely dissolves even in the presence of water to guarantee that a required operation is completed before dissolution.
- At least one fluid port 40 may be provided in an area circumferentially surrounding the plug 20 .
- Water or heated water may be provided to the plug 20 at a time when the plug 20 is to be dissolved.
- the temperature of the water and the time the plug 20 is exposed to the water may both be selected to dissolve the plug 20 in a desired amount of time.
- the fluid ports 40 may be arranged such that the water or heated water is directed towards a portion of the plug 20 that is desired to be dissolved first.
- the plug 20 includes a protective oil-based layer 50 deployed on at least one surface of the plug 20 to prevent the plug 20 from coming into contact with water, thereby retaining its initial structure until the layer 50 is removed and water is introduced to the plug 20 .
- the layer 50 is deployed on an upper surface 52 of the plug 20 , such as a surface facing an uphole direction of the wellbore 10 .
- the lower surface 54 of the plug 20 includes a protective oil-based layer 50 , such as a surface facing a downhole direction of the wellbore 10
- at least both the upper and lower surfaces 52 , 54 of the plug 20 include a protective oil-based layer 50 , such as all surfaces of the plug 20 .
- Removal of the oil-based layer 50 may be accomplished using a mechanical device and/or chemical means.
- surfactants such as emulsifiers, detergents, etc.
- the chemical introduction may occur using fluid ports 40 that direct the oil removing chemical substance towards the oil-based layer 50 .
- These may be the same ports 40 that direct water or heated water to the plug 20 for dissolution of the plug 20 .
- the fluid ports 40 may also be used to vacuum the oil removing chemical substance and oil-based layer 50 away from the plug 20 . While certain chemical removal embodiments are described, other devices to chemically remove the layer from the plug would be within the scope of these embodiments.
- a mechanical device 56 may extend from the casing 12 , such as a scraper or brush which may be used to at least partially remove the protective layer.
- the scraper or brush may be a single blade used to wipe off the oil, matter used to absorb the oil, a series of bristles, etc.
- the mechanical device 56 may be actuated using known downhole tool actuators and may rotate along an interior of the casing 12 to wipe off the layer 56 .
- the mechanical device may also includes elements made of water soluble material, such as water soluble glass, such that it can also be dissolved in the presence of water. While certain mechanical removal embodiments are described, other devices to mechanically remove the layer from the plug would be within the scope of these embodiments.
- the plug 20 may be removed by first breaking the glass structure of the plug 20 . Breaking the glass structure of the plug 20 may be accomplished by using any known fracturing technique. By fracturing the plug 20 and introducing water to interior surfaces of the plug 20 , the plug 20 will quickly dissolve and be absorbed by the wellbore fluid.
- the water soluble glass is used as a carrier for long term curing chemicals, which are embedded in the glass matrix, for fracturing/stimulating operations.
- the glass body 104 when sent down the well bore 10 or into perforations 100 would be able to store chemicals underground and release them only when exposed to formation water.
- the chemicals When the glass body 104 is dissolved by formation water, the chemicals are released and enter the casing 12 through openings 108 in tool 110 and they may then be sensed by a chemical sensor 106 , which in turn may send a communication signal that indicates the presence of formation water, may actuate a downhole tool such as opening or closing a sleeve, or may increase a count on a counter.
- a glass body or bodies 104 containing a first detectable chemical element may be pumped or otherwise directed into a first layer or perforation 100 of the well, while a glass body or bodies 112 containing a second detectable chemical element, different than the first detectable chemical element, is pumped into a second layer or perforation 102 of the well which is distanced from the first layer or perforation 100 .
- First and second chemical sensors 106 , 114 may be positioned within the casing 12 for detecting the existence of the corresponding chemicals, and may trigger the appropriate response as described above. While only two different detectable chemical elements and layers are described, it would be within the scope of these embodiments to include multiple different chemical elements for detecting formation water from any number of layers. Thus, it is possible to detect from what specific layer formation water is coming from depending on which chemical sensor is activated. While two chemical sensors have been described, it would also be within the scope of these embodiments to employ a single chemical sensor, which reacts differently, depending on which chemical is detected.
- FIG. 9 An exemplary embodiment of chemical sensor 106 is shown in FIG. 9 .
- Sensor 106 is communicatively connected to and triggers switch 116 closing a circuit to battery 118 and powering actuation mechanism 120 .
- the water soluble glass is used as an inexpensive override system to actuate a downhole tool.
- the water soluble glass may be used to shut down a non-deepset safety valve.
- a passive dissolvable part made with the water soluble glass may then initiate a process that leads to the final closure of a flapper.
- the process may be completely mechanical, such as by the passive dissolvable part releasing a latch.
- the dissolvable part 122 may include an electrode and when a water soluble glass covering of the part 122 is dissolved by water, the electrode is ground to the casing 12 or to the wellbore fluids and completes the circuit. Dissolving the encapsulated electrode completes the circuit and allows power to flow across the actuator mechanism 126 to actuate the downhole tool.
Abstract
A downhole water detection system configured to detect presence of water in an underground location. The system includes a chemical sensor disposable within a tubular in a borehole; and a first water detection body including a first detectable chemical element surrounded by water soluble glass. Wherein the first water detection body is locatable within a fractured formation wherein the chemical sensor is arranged to sense the first detectable chemical element when formation water dissolves the water soluble glass. Also included is a method of detecting water in a formation.
Description
- This application is a divisional application of U.S. Non Provisional Application Ser. No. 12/981,083 filed Dec. 29, 2010, the entire disclosure of which is incorporated herein by reference.
- While drilling and producing wells for the recovery of petroleum and other subsurface deposits, it is often necessary to close off or plug a tubular conduit, such as a string of tubing extending from the well surface to a subterranean location, at a chosen point along the length of the conduit. Subsequently, it is necessary to be able to re-open the conduit for flow therethrough. A plug used to close off the tubing during setting of a well tool, such as a packer, may then be released so that fluid may be circulated through the tubing.
- Certain types of plugs are designed to be permanently installed, and they must be drilled or milled to be removed, which can be labor intensive. Other types of plugs are designed to be retrieved when the purpose for which the plug has been installed has been accomplished. Retrievable plugs generally employ some form of releasable anchoring device by which the plug may be secured to the internal bore of the well pipe and which may then be released to enable the plug to be withdrawn. One disadvantage of this prior art arrangement is that a restriction in the internal diameter of the tubing string often accompanies the design. Also, the prior art plugs were often retrieved on a wireline and the retrieval operation was complicated in the case of deviated well bores. Debris that sometimes accumulates on the top of the retrievable plug can also cause issues in the wellbore.
- Another prior art plug design involves the incorporation of a plug of expendable material and an actuating device used to dislocate or fracture the plug upon receipt of a triggering signal. The potential for remaining and problematic debris from the plug in the tubing string or wellbore must be carefully monitored in such devices. Sand plugs, for instance, have been provided for zonal isolation within wellbores, however the integrity of such sand plugs can be inconsistent and remaining particulates must be dealt with.
- Also while producing wells for the recovery of petroleum and other subsurface deposits, unexpected formation water leads to increased, and often undesirable, water handling requirements and costs.
- A downhole water detection system configured to detect presence of water in an underground location, the system includes: a chemical sensor disposable within a tubular in a borehole; and a first water detection body including a first detectable chemical element surrounded by water soluble glass, wherein the first water detection body is locatable within a fractured formation; wherein the chemical sensor is arranged to sense the first detectable chemical element when formation water dissolves the water soluble glass.
- A method of detecting water in a formation, the method includes directing a first water detection body including a first detectable chemical element embedded within water soluble glass to an underground location of a formation.
- The following descriptions should not be considered limiting in any way. With reference to the accompanying drawings, like elements are numbered alike:
-
FIG. 1 depicts a schematic view of a well bore completion showing an exemplary embodiment of a dissolvable plug; -
FIG. 2 depicts a cross sectional view of an exemplary embodiment of the dissolvable plug ofFIG. 1 ; -
FIG. 3 depicts a cross sectional view of another exemplary embodiment of the dissolvable plug ofFIG. 1 ; -
FIG. 4 depicts a cross-sectional view of an exemplary embodiment of a dissolution advancement system; -
FIGS. 5A-5C depict various embodiments of a protective oil-based layer on the dissolvable plug ofFIG. 1 ; -
FIG. 6 depicts a schematic view of an exemplary embodiment of a chemical employing system for removing the protective oil-based layer ofFIGS. 5A-5C ; -
FIG. 7 depicts a schematic view of an exemplary embodiment of a mechanical device for removing the protective oil-based layer ofFIGS. 5A-5C ; -
FIG. 8 depicts a schematic view of an exemplary embodiment of a system for detecting formation water; -
FIG. 9 depicts a circuit diagram for use with a chemical sensor within the exemplary system ofFIG. 8 ; and, -
FIG. 10 depicts a circuit diagram of an exemplary embodiment of a closure device. - A detailed description of one or more embodiments of the disclosed apparatus and method are presented herein by way of exemplification and not limitation with reference to the Figures.
- Referring to
FIG. 1 , awellbore 10 is shown lined with acasing 12, also known as a tubular, tubular housing, string, etc. A tubing mountedvalve 14 may be located within the string ofcasing 12. Apacker 16 isolates anannular region 18 between thecasing 12 and thewellbore 10. According to exemplary embodiments of the present invention, adissolvable plug 20 initially closes off flow from aperforated zone 100 up theinternal bore 22 of thecasing 12 to thewell surface 24. Thedissolvable plug 20 forms a portion of thewell tool 26, and may, in one exemplary embodiment, have an outer diameter which is approximately equal to an internal diameter of thecasing 12 forming the flow path to thewell surface 24 where theplug 20 is seated. Thus, theplug 20 advantageously need not require any significant constructions or devices that restricts an internal diameter of theinternal bore 22 of thecasing 12, however, as shown inFIG. 2 , asmall seat 30 such as seating device or shoulder or other protrusion may be provided to ensure that theplug 20 does not slide out of place. In an exemplary embodiment, theseating device 30 may be made from the same dissolvable material as theplug 20. - In an alternative exemplary embodiment shown in
FIG. 3 , in lieu ofseating device 30, thecasing 12 may include asection 36 have an internal diameter in an area for receiving theplug 20 that is larger than an internal diameter of a remainder of theinternal bore 22 of thecasing 12. In this case, theplug 20 may be formed with thecasing 12 prior to positioning the tubing in thewellbore 10. - The
plug 20 may be formed and pre stressed within a section of the tubing string orcasing 12 to provide sufficient strength against pressure within the tubing. In an alternative exemplary embodiment, theplug 20 may first be formed as a separate element and then secured within thecasing 12 using an adhesive component such as, but not limited to, the same dissolvable material as theplug 20. - In these exemplary embodiments, the
plug 20 is made of water soluble glass, which is made from silica and soda. Soda reduces the melting point of silica, which makes it easier to create glass, and soda also renders the glass water soluble. The most prevalent type of glass is soda-lime glass, also called soda-lime-silica glass, where the lime is added to restore insolubility. In one exemplary embodiment of theplug 20, made from soda and silica and without lime, the watersoluble glass plug 20 will dissolve when in contact with water or steam. Some samples have been shown to dissolve at a rate of about 0.0001″ per minute at about 180° F., however the solubility rate is temperature sensitive to the water that it is dissolved in, and salt water has been shown to dissolve the water soluble glass at a slower rate. In a non aqueous environment, the material remains intact at high temperatures, such as about 1500° F. to about 2000° F. As another important feature, theplug 20 is insoluble to oil and petroleum based liquids and this feature may be advantageously employed in the present invention. - In one exemplary embodiment, the
plug 20 is formed using water soluble glass with dimensions and content suitable for its intended applications. By varying and balancing both the thickness of the plug and the content of soda in the glass matrix, the solubility can be modulated. For example, the thickness and soda content of aplug 20 can be adjusted such that awellbore tool 26, such as a packer, remains plugged until the required operation is carried out. - While the
plug 20 may be installed in thecasing 12 using conventional methods, the removal of theplug 20 may be determined based on intended use. In one exemplary embodiment, theplug 20 is installed in thewellbore tool 26 in a conventional manner and may be allowed to begin dissolving while the operation is being carried out, so long as theplug 20 is not completely dissolved until after the operation is completed. In another exemplary embodiment, the thickness of theplug 20 may be sufficiently thick and the soda content sufficiently low such that theplug 20 barely dissolves even in the presence of water to guarantee that a required operation is completed before dissolution. - In an exemplary embodiment shown in
FIG. 4 , to advance the dissolution of theplug 20, at least onefluid port 40, or a plurality offluid ports 40 may be provided in an area circumferentially surrounding theplug 20. Water or heated water may be provided to theplug 20 at a time when theplug 20 is to be dissolved. The temperature of the water and the time theplug 20 is exposed to the water may both be selected to dissolve theplug 20 in a desired amount of time. Thefluid ports 40 may be arranged such that the water or heated water is directed towards a portion of theplug 20 that is desired to be dissolved first. - In yet another exemplary embodiment, as shown in
FIGS. 5A-5C , theplug 20 includes a protective oil-basedlayer 50 deployed on at least one surface of theplug 20 to prevent theplug 20 from coming into contact with water, thereby retaining its initial structure until thelayer 50 is removed and water is introduced to theplug 20. In an exemplary embodiment shown inFIG. 5A , thelayer 50 is deployed on anupper surface 52 of theplug 20, such as a surface facing an uphole direction of thewellbore 10. In another exemplary embodiment shown inFIG. 5B , thelower surface 54 of theplug 20 includes a protective oil-basedlayer 50, such as a surface facing a downhole direction of thewellbore 10, and in yet another exemplary embodiment shown inFIG. 5C , at least both the upper andlower surfaces plug 20 include a protective oil-basedlayer 50, such as all surfaces of theplug 20. - Removal of the oil-based
layer 50 may be accomplished using a mechanical device and/or chemical means. To chemically remove the oil-basedlayer 50, surfactants, such as emulsifiers, detergents, etc., may be used to break the bonds holding the molecules of the oil together so that the oil molecules can be separated and rinsed away. As shown inFIG. 6 , the chemical introduction may occur usingfluid ports 40 that direct the oil removing chemical substance towards the oil-basedlayer 50. These may be thesame ports 40 that direct water or heated water to theplug 20 for dissolution of theplug 20. Thefluid ports 40 may also be used to vacuum the oil removing chemical substance and oil-basedlayer 50 away from theplug 20. While certain chemical removal embodiments are described, other devices to chemically remove the layer from the plug would be within the scope of these embodiments. - As shown in
FIG. 7 , to mechanically remove the oil basedlayer 50 from theplug 20, amechanical device 56 may extend from thecasing 12, such as a scraper or brush which may be used to at least partially remove the protective layer. The scraper or brush may be a single blade used to wipe off the oil, matter used to absorb the oil, a series of bristles, etc. Themechanical device 56 may be actuated using known downhole tool actuators and may rotate along an interior of thecasing 12 to wipe off thelayer 56. The mechanical device may also includes elements made of water soluble material, such as water soluble glass, such that it can also be dissolved in the presence of water. While certain mechanical removal embodiments are described, other devices to mechanically remove the layer from the plug would be within the scope of these embodiments. - Although the
plug 20 has been described as being removed by dissolving with water, in yet another exemplary embodiment, the plug may be removed by first breaking the glass structure of theplug 20. Breaking the glass structure of theplug 20 may be accomplished by using any known fracturing technique. By fracturing theplug 20 and introducing water to interior surfaces of theplug 20, theplug 20 will quickly dissolve and be absorbed by the wellbore fluid. - The exemplary embodiments disclosed thus far have provided a glass water
soluble plug 20 for use in plugging atool 26 until removal of theplug 20 is warranted. Alternative exemplary embodiments of designs and methods for employing the water soluble glass material within thewellbore 10 will now be described. - In one exemplary embodiment for employing water soluble glass in a
wellbore 10, as shown inFIG. 8 , the water soluble glass is used as a carrier for long term curing chemicals, which are embedded in the glass matrix, for fracturing/stimulating operations. Theglass body 104, when sent down the well bore 10 or intoperforations 100 would be able to store chemicals underground and release them only when exposed to formation water. When theglass body 104 is dissolved by formation water, the chemicals are released and enter thecasing 12 throughopenings 108 intool 110 and they may then be sensed by achemical sensor 106, which in turn may send a communication signal that indicates the presence of formation water, may actuate a downhole tool such as opening or closing a sleeve, or may increase a count on a counter. - Similar to the above-described exemplary embodiment, in another exemplary embodiment for employing water soluble glass in a
wellbore 10, different detectable chemical elements are embedded in the glass matrix andglass bodies 112 including the different detectable chemical elements are pumped in multi-layered fractured formations. That is, a glass body orbodies 104 containing a first detectable chemical element may be pumped or otherwise directed into a first layer orperforation 100 of the well, while a glass body orbodies 112 containing a second detectable chemical element, different than the first detectable chemical element, is pumped into a second layer orperforation 102 of the well which is distanced from the first layer orperforation 100. First and secondchemical sensors 106, 114 may be positioned within thecasing 12 for detecting the existence of the corresponding chemicals, and may trigger the appropriate response as described above. While only two different detectable chemical elements and layers are described, it would be within the scope of these embodiments to include multiple different chemical elements for detecting formation water from any number of layers. Thus, it is possible to detect from what specific layer formation water is coming from depending on which chemical sensor is activated. While two chemical sensors have been described, it would also be within the scope of these embodiments to employ a single chemical sensor, which reacts differently, depending on which chemical is detected. - An exemplary embodiment of
chemical sensor 106 is shown inFIG. 9 .Sensor 106 is communicatively connected to and triggers switch 116 closing a circuit tobattery 118 and poweringactuation mechanism 120. - In yet another exemplary embodiment, the water soluble glass is used as an inexpensive override system to actuate a downhole tool. In one such exemplary embodiment, the water soluble glass may be used to shut down a non-deepset safety valve. In a condition where the chamber becomes flooded by water, replacing oil initially present, a passive dissolvable part made with the water soluble glass may then initiate a process that leads to the final closure of a flapper. The process may be completely mechanical, such as by the passive dissolvable part releasing a latch. Alternatively, as represented by
FIG. 10 , thedissolvable part 122 may include an electrode and when a water soluble glass covering of thepart 122 is dissolved by water, the electrode is ground to thecasing 12 or to the wellbore fluids and completes the circuit. Dissolving the encapsulated electrode completes the circuit and allows power to flow across theactuator mechanism 126 to actuate the downhole tool. - While the invention has been described with reference to an exemplary embodiment or embodiments, it will be understood by those skilled in the art that various changes may be made and equivalents may be substituted for elements thereof without departing from the scope of the invention. In addition, many modifications may be made to adapt a particular situation or material to the teachings of the invention without departing from the essential scope thereof. Therefore, it is intended that the invention not be limited to the particular embodiment disclosed as the best mode contemplated for carrying out this invention, but that the invention will include all embodiments falling within the scope of the claims. Also, in the drawings and the description, there have been disclosed exemplary embodiments of the invention and, although specific terms may have been employed, they are unless otherwise stated used in a generic and descriptive sense only and not for purposes of limitation, the scope of the invention therefore not being so limited. Moreover, the use of the terms first, second, etc. do not denote any order or importance, but rather the terms first, second, etc. are used to distinguish one element from another. Furthermore, the use of the terms a, an, etc. do not denote a limitation of quantity, but rather denote the presence of at least one of the referenced item.
Claims (20)
1. A downhole water detection system configured to detect presence of water in an underground location, the system comprising:
a chemical sensor disposable within a tubular in a borehole; and
a first water detection body including a first detectable chemical element surrounded by water soluble glass, wherein the first water detection body is locatable within a fractured formation;
wherein the chemical sensor is arranged to sense the first detectable chemical element when formation water dissolves the water soluble glass.
2. The system of claim 1 , further comprising a second water detection body including a second detectable chemical element surrounded by water soluble glass, the second detectable chemical element different than the first detectable chemical element.
3. The system of claim 2 wherein the chemical sensor is a first chemical sensor, and further comprising a second chemical sensor disposable within the tubular and configured to sense the second detectable chemical element when formation water dissolves the water soluble glass of the second water detection body.
4. The system of claim 3 wherein the first chemical sensor is longitudinally distanced from the second chemical sensor.
5. The system of claim 2 , wherein the chemical sensor determines a location of formation water based on which detectable chemical element is sensed.
6. The system of claim 1 , further comprising the tubular, wherein the tubular includes at least one opening configured to receive the first detectable chemical element there through if the water soluble glass of the first water detection body is dissolved by water.
7. The system of claim 1 , wherein the first water detection body is seated within a fractured formation until the water soluble glass dissolves and the first detectable chemical element enters the tubular.
8. The system of claim 1 , further comprising a communication signal sent by the chemical sensor upon sensing of the first detectable chemical element, the communication signal indicating presence of formation water.
9. The system of claim 1 , wherein the first detectable chemical element is a curing chemical.
10. The system of claim 1 wherein the chemical sensor includes a circuit which closes upon detection of the first detectable chemical element to power an actuation mechanism.
11. A method of detecting water in a formation, the method comprising:
directing a first water detection body including a first detectable chemical element embedded within water soluble glass to an underground location of a formation.
12. The method of claim 11 , further comprising conducting one of a fracturing and stimulating operation prior to directing the first water detection body to the location.
13. The method of claim 11 further comprising reacting to presence of water, subsequent dissolution of the water soluble glass and release of the first detectable chemical element, by sensing the first detectable chemical element.
14. The method of claim 13 , further comprising disposing a sensor within a casing, the sensor reactive to the first detectable chemical element.
15. The method of claim 13 , wherein reacting to the presence of water further includes, subsequent sensing the first detectable chemical element, triggering an actuating device to close a wellbore.
16. The method of claim 13 , wherein reacting to the presence of water further includes, subsequent sensing the first detectable chemical element, triggering an actuating device to close a sleeve.
17. The method of claim 11 , further comprising directing a second water detection body including a second detectable chemical element different than the first detectable chemical element within a second body of water soluble glass, to a different underground location or different fractured formation than the first water detection body.
18. The method of claim 17 , further comprising determining a location of formation water by sensing one of the first and second detectable chemical elements released from dissolved water soluble glass.
19. The method of claim 18 , further comprising, subsequent determining a location of formation water, closing a sleeve at the location of formation water.
20. The method of claim 16 , further comprising disposing first and second chemical sensors at longitudinally displaced locations within a tubular, the first and second chemical sensors reactive to the first and second detectable chemical elements, respectively.
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US14/148,045 US20140116688A1 (en) | 2010-12-29 | 2014-01-06 | Downhole water detection system and method |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US12/981,083 US8668019B2 (en) | 2010-12-29 | 2010-12-29 | Dissolvable barrier for downhole use and method thereof |
US14/148,045 US20140116688A1 (en) | 2010-12-29 | 2014-01-06 | Downhole water detection system and method |
Related Parent Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US12/981,083 Division US8668019B2 (en) | 2010-12-29 | 2010-12-29 | Dissolvable barrier for downhole use and method thereof |
Publications (1)
Publication Number | Publication Date |
---|---|
US20140116688A1 true US20140116688A1 (en) | 2014-05-01 |
Family
ID=46379727
Family Applications (2)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US12/981,083 Active US8668019B2 (en) | 2010-12-29 | 2010-12-29 | Dissolvable barrier for downhole use and method thereof |
US14/148,045 Abandoned US20140116688A1 (en) | 2010-12-29 | 2014-01-06 | Downhole water detection system and method |
Family Applications Before (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US12/981,083 Active US8668019B2 (en) | 2010-12-29 | 2010-12-29 | Dissolvable barrier for downhole use and method thereof |
Country Status (2)
Country | Link |
---|---|
US (2) | US8668019B2 (en) |
WO (1) | WO2012091984A2 (en) |
Cited By (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO2018031008A1 (en) * | 2016-08-10 | 2018-02-15 | Halliburton Energy Services, Inc. | Soluble plug usable downhole |
Families Citing this family (79)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US9682425B2 (en) | 2009-12-08 | 2017-06-20 | Baker Hughes Incorporated | Coated metallic powder and method of making the same |
US8403037B2 (en) | 2009-12-08 | 2013-03-26 | Baker Hughes Incorporated | Dissolvable tool and method |
US8327931B2 (en) | 2009-12-08 | 2012-12-11 | Baker Hughes Incorporated | Multi-component disappearing tripping ball and method for making the same |
US9109429B2 (en) | 2002-12-08 | 2015-08-18 | Baker Hughes Incorporated | Engineered powder compact composite material |
US9101978B2 (en) | 2002-12-08 | 2015-08-11 | Baker Hughes Incorporated | Nanomatrix powder metal compact |
US9079246B2 (en) | 2009-12-08 | 2015-07-14 | Baker Hughes Incorporated | Method of making a nanomatrix powder metal compact |
US9127515B2 (en) | 2010-10-27 | 2015-09-08 | Baker Hughes Incorporated | Nanomatrix carbon composite |
US8573295B2 (en) * | 2010-11-16 | 2013-11-05 | Baker Hughes Incorporated | Plug and method of unplugging a seat |
US9227243B2 (en) | 2009-12-08 | 2016-01-05 | Baker Hughes Incorporated | Method of making a powder metal compact |
US8528633B2 (en) | 2009-12-08 | 2013-09-10 | Baker Hughes Incorporated | Dissolvable tool and method |
US10240419B2 (en) * | 2009-12-08 | 2019-03-26 | Baker Hughes, A Ge Company, Llc | Downhole flow inhibition tool and method of unplugging a seat |
US9243475B2 (en) | 2009-12-08 | 2016-01-26 | Baker Hughes Incorporated | Extruded powder metal compact |
US8776884B2 (en) | 2010-08-09 | 2014-07-15 | Baker Hughes Incorporated | Formation treatment system and method |
US9090955B2 (en) | 2010-10-27 | 2015-07-28 | Baker Hughes Incorporated | Nanomatrix powder metal composite |
US8668019B2 (en) * | 2010-12-29 | 2014-03-11 | Baker Hughes Incorporated | Dissolvable barrier for downhole use and method thereof |
US9080098B2 (en) | 2011-04-28 | 2015-07-14 | Baker Hughes Incorporated | Functionally gradient composite article |
US8631876B2 (en) | 2011-04-28 | 2014-01-21 | Baker Hughes Incorporated | Method of making and using a functionally gradient composite tool |
US9139928B2 (en) | 2011-06-17 | 2015-09-22 | Baker Hughes Incorporated | Corrodible downhole article and method of removing the article from downhole environment |
US9707739B2 (en) | 2011-07-22 | 2017-07-18 | Baker Hughes Incorporated | Intermetallic metallic composite, method of manufacture thereof and articles comprising the same |
US8783365B2 (en) | 2011-07-28 | 2014-07-22 | Baker Hughes Incorporated | Selective hydraulic fracturing tool and method thereof |
US9833838B2 (en) | 2011-07-29 | 2017-12-05 | Baker Hughes, A Ge Company, Llc | Method of controlling the corrosion rate of alloy particles, alloy particle with controlled corrosion rate, and articles comprising the particle |
US9643250B2 (en) | 2011-07-29 | 2017-05-09 | Baker Hughes Incorporated | Method of controlling the corrosion rate of alloy particles, alloy particle with controlled corrosion rate, and articles comprising the particle |
US9057242B2 (en) | 2011-08-05 | 2015-06-16 | Baker Hughes Incorporated | Method of controlling corrosion rate in downhole article, and downhole article having controlled corrosion rate |
US9033055B2 (en) | 2011-08-17 | 2015-05-19 | Baker Hughes Incorporated | Selectively degradable passage restriction and method |
US9856547B2 (en) | 2011-08-30 | 2018-01-02 | Bakers Hughes, A Ge Company, Llc | Nanostructured powder metal compact |
US9109269B2 (en) | 2011-08-30 | 2015-08-18 | Baker Hughes Incorporated | Magnesium alloy powder metal compact |
US9090956B2 (en) | 2011-08-30 | 2015-07-28 | Baker Hughes Incorporated | Aluminum alloy powder metal compact |
US9643144B2 (en) | 2011-09-02 | 2017-05-09 | Baker Hughes Incorporated | Method to generate and disperse nanostructures in a composite material |
US9187990B2 (en) | 2011-09-03 | 2015-11-17 | Baker Hughes Incorporated | Method of using a degradable shaped charge and perforating gun system |
US9133695B2 (en) | 2011-09-03 | 2015-09-15 | Baker Hughes Incorporated | Degradable shaped charge and perforating gun system |
US9347119B2 (en) | 2011-09-03 | 2016-05-24 | Baker Hughes Incorporated | Degradable high shock impedance material |
US9238953B2 (en) | 2011-11-08 | 2016-01-19 | Schlumberger Technology Corporation | Completion method for stimulation of multiple intervals |
US9010416B2 (en) | 2012-01-25 | 2015-04-21 | Baker Hughes Incorporated | Tubular anchoring system and a seat for use in the same |
US9068428B2 (en) | 2012-02-13 | 2015-06-30 | Baker Hughes Incorporated | Selectively corrodible downhole article and method of use |
US9605508B2 (en) | 2012-05-08 | 2017-03-28 | Baker Hughes Incorporated | Disintegrable and conformable metallic seal, and method of making the same |
US9458692B2 (en) | 2012-06-08 | 2016-10-04 | Halliburton Energy Services, Inc. | Isolation devices having a nanolaminate of anode and cathode |
US9689227B2 (en) | 2012-06-08 | 2017-06-27 | Halliburton Energy Services, Inc. | Methods of adjusting the rate of galvanic corrosion of a wellbore isolation device |
US9777549B2 (en) | 2012-06-08 | 2017-10-03 | Halliburton Energy Services, Inc. | Isolation device containing a dissolvable anode and electrolytic compound |
US9689231B2 (en) | 2012-06-08 | 2017-06-27 | Halliburton Energy Services, Inc. | Isolation devices having an anode matrix and a fiber cathode |
US9759035B2 (en) | 2012-06-08 | 2017-09-12 | Halliburton Energy Services, Inc. | Methods of removing a wellbore isolation device using galvanic corrosion of a metal alloy in solid solution |
US9650851B2 (en) | 2012-06-18 | 2017-05-16 | Schlumberger Technology Corporation | Autonomous untethered well object |
NO20130184A1 (en) * | 2013-02-05 | 2013-11-18 | Tco As | Device and method for protecting crushable production well plugs against falling objects with one layer of viscous liquid |
NO341182B1 (en) * | 2013-02-05 | 2017-09-04 | Tco As | Well equipment Saver. |
US20190078414A1 (en) * | 2013-05-13 | 2019-03-14 | Magnum Oil Tools International, Ltd. | Dissolvable aluminum downhole plug |
MX2015014138A (en) | 2013-05-17 | 2016-04-20 | Halliburton Energy Services Inc | Method and apparatus for generating seismic pulses to map subterranean fractures. |
US9500069B2 (en) | 2013-05-17 | 2016-11-22 | Halliburton Energy Services, Inc. | Method and apparatus for generating seismic pulses to map subterranean fractures |
CA2911013A1 (en) * | 2013-05-31 | 2014-12-04 | Halliburton Energy Services, Inc. | Method and apparatus for generating seismic pulses to map subterranean fractures |
US9631468B2 (en) | 2013-09-03 | 2017-04-25 | Schlumberger Technology Corporation | Well treatment |
US9816339B2 (en) | 2013-09-03 | 2017-11-14 | Baker Hughes, A Ge Company, Llc | Plug reception assembly and method of reducing restriction in a borehole |
US9353596B2 (en) | 2013-09-18 | 2016-05-31 | Rayotek Scientific, Inc. | Oil well plug and method of use |
US9657547B2 (en) | 2013-09-18 | 2017-05-23 | Rayotek Scientific, Inc. | Frac plug with anchors and method of use |
CA2936851A1 (en) | 2014-02-21 | 2015-08-27 | Terves, Inc. | Fluid activated disintegrating metal system |
US11167343B2 (en) | 2014-02-21 | 2021-11-09 | Terves, Llc | Galvanically-active in situ formed particles for controlled rate dissolving tools |
US20170268088A1 (en) | 2014-02-21 | 2017-09-21 | Terves Inc. | High Conductivity Magnesium Alloy |
US10689740B2 (en) | 2014-04-18 | 2020-06-23 | Terves, LLCq | Galvanically-active in situ formed particles for controlled rate dissolving tools |
CA2936816A1 (en) | 2014-02-21 | 2015-08-27 | Terves, Inc. | Manufacture of controlled rate dissolving materials |
US10400535B1 (en) | 2014-03-24 | 2019-09-03 | Nine Downhole Technologies, Llc | Retrievable downhole tool |
US9915114B2 (en) | 2015-03-24 | 2018-03-13 | Donald R. Greenlee | Retrievable downhole tool |
CN106460133B (en) | 2014-04-18 | 2019-06-18 | 特维斯股份有限公司 | The particle of electro-chemical activity for controllable rate dissolution tool being formed in situ |
WO2015167640A1 (en) * | 2014-05-02 | 2015-11-05 | Halliburton Energy Services. Inc. | Isolation devices having a nanolaminate of anode and cathode |
US10167534B2 (en) | 2014-08-28 | 2019-01-01 | Halliburton Energy Services, Inc. | Fresh water degradable downhole tools comprising magnesium and aluminum alloys |
US9910026B2 (en) | 2015-01-21 | 2018-03-06 | Baker Hughes, A Ge Company, Llc | High temperature tracers for downhole detection of produced water |
US10378303B2 (en) | 2015-03-05 | 2019-08-13 | Baker Hughes, A Ge Company, Llc | Downhole tool and method of forming the same |
US9885229B2 (en) | 2015-04-22 | 2018-02-06 | Baker Hughes, A Ge Company, Llc | Disappearing expandable cladding |
US9879492B2 (en) | 2015-04-22 | 2018-01-30 | Baker Hughes, A Ge Company, Llc | Disintegrating expand in place barrier assembly |
US10458197B2 (en) | 2015-06-16 | 2019-10-29 | Baker Huges, A Ge Company, Llc | Disintegratable polymer composites for downhole tools |
CA2989561A1 (en) * | 2015-06-17 | 2016-12-22 | Baker Hughes, A Ge Company, Llc | Downhole structures including soluble glass |
US10221637B2 (en) | 2015-08-11 | 2019-03-05 | Baker Hughes, A Ge Company, Llc | Methods of manufacturing dissolvable tools via liquid-solid state molding |
US10066453B2 (en) | 2015-11-25 | 2018-09-04 | Baker Hughes, A Ge Company, Llc | Self locking plug seat, system and method |
US10016810B2 (en) | 2015-12-14 | 2018-07-10 | Baker Hughes, A Ge Company, Llc | Methods of manufacturing degradable tools using a galvanic carrier and tools manufactured thereof |
NO342249B1 (en) * | 2016-02-24 | 2018-04-30 | Scale Prot As | Inflow Indicator Device |
US20180306027A1 (en) * | 2016-09-23 | 2018-10-25 | Terves Inc. | Method of Assuring Dissolution of Degradable Tools |
US10677008B2 (en) * | 2017-03-01 | 2020-06-09 | Baker Hughes, A Ge Company, Llc | Downhole tools and methods of controllably disintegrating the tools |
CA3012511A1 (en) | 2017-07-27 | 2019-01-27 | Terves Inc. | Degradable metal matrix composite |
WO2019091043A1 (en) * | 2017-11-08 | 2019-05-16 | 中国石油天然气股份有限公司 | Method for loading oil pipe in gas well without well killing, decomposable bridge plug, and method for preparing material therefor |
GB201807489D0 (en) * | 2018-05-08 | 2018-06-20 | Sentinel Subsea Ltd | Apparatus and method |
US11459846B2 (en) * | 2019-08-14 | 2022-10-04 | Terves, Llc | Temporary well isolation device |
AT523013B1 (en) * | 2019-09-23 | 2021-10-15 | Georg Bistekos Ing Michael | Pipe separator or collecting container for liquids with a hermetically sealed overflow |
CN110952949A (en) * | 2019-11-22 | 2020-04-03 | 中国石油天然气股份有限公司 | Soluble plugging tool for tail end of velocity string and using method thereof |
Citations (19)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4923806A (en) * | 1985-06-14 | 1990-05-08 | Carrier Corporation | Method and apparatus for refrigerant testing in a closed system |
US6349766B1 (en) * | 1998-05-05 | 2002-02-26 | Baker Hughes Incorporated | Chemical actuation of downhole tools |
US20080149351A1 (en) * | 2006-12-20 | 2008-06-26 | Schlumberger Technology Corporation | Temporary containments for swellable and inflatable packer elements |
US20080262735A1 (en) * | 2007-04-19 | 2008-10-23 | Baker Hughes Incorporated | System and Method for Water Breakthrough Detection and Intervention in a Production Well |
US20090034368A1 (en) * | 2007-08-02 | 2009-02-05 | Baker Hughes Incorporated | Apparatus and method for communicating data between a well and the surface using pressure pulses |
US20100288495A1 (en) * | 2007-12-14 | 2010-11-18 | 3M Innovative Properties Company | Methods of treating subterranean wells using changeable additives |
US20100294500A1 (en) * | 2007-05-22 | 2010-11-25 | Timothy Michael Lesko | Method of improving the conductivity of a fracture in the space between proppant pillars |
US20100307745A1 (en) * | 2009-06-03 | 2010-12-09 | Schlumberger Technology Corporation | Use of encapsulated tracers |
EP2372331A1 (en) * | 2010-03-31 | 2011-10-05 | PRAD Research and Development Limited | System and method for determining incursion of water in a well |
US20110240287A1 (en) * | 2010-04-02 | 2011-10-06 | Schlumberger Technology Corporation | Detection of tracers used in hydrocarbon wells |
US20110257887A1 (en) * | 2010-04-20 | 2011-10-20 | Schlumberger Technology Corporation | Utilization of tracers in hydrocarbon wells |
US20110277996A1 (en) * | 2010-05-11 | 2011-11-17 | Halliburton Energy Services, Inc. | Subterranean flow barriers containing tracers |
US20110290480A1 (en) * | 2010-05-25 | 2011-12-01 | Saudi Arabian Oil Company | Surface detection of failed open-hole packers using tubing with external tracer coatings |
US20120168153A1 (en) * | 2010-12-30 | 2012-07-05 | Baker Hughes Incorporated | Watercut sensor using reactive media |
US20120247777A1 (en) * | 2011-03-30 | 2012-10-04 | Hutchins Richard D | Methods for supplying a chemical within a subterranean formation |
US20130017610A1 (en) * | 2011-07-12 | 2013-01-17 | Jeffery Roberts | Encapsulated tracers and chemicals for reservoir interrogation and manipulation |
US20130075090A1 (en) * | 2010-06-11 | 2013-03-28 | Absolute Completion Technologies Ltd. | Wellbore fluid treatment and method |
US8833154B2 (en) * | 2010-10-19 | 2014-09-16 | Schlumberger Technology Corporation | Tracer identification of downhole tool actuation |
US20150134253A1 (en) * | 2012-04-16 | 2015-05-14 | Weatherford/Lamb, Inc. | Method and apparatus for monitoring a downhole tool |
Family Cites Families (58)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US2638167A (en) * | 1948-06-28 | 1953-05-12 | Edward N Jones | Seal for well tubing |
US3361203A (en) * | 1965-10-22 | 1968-01-02 | Halliburton Co | Self-cleaning sand screen |
US4050517A (en) * | 1976-10-14 | 1977-09-27 | Sperry Rand Corporation | Geothermal energy well casing seal and method of installation |
US4332297A (en) * | 1980-08-18 | 1982-06-01 | Union Oil Company Of California | Selectively controlling fluid flow through the higher permeability zones of subterranean reservoirs |
US4374543A (en) * | 1980-08-19 | 1983-02-22 | Tri-State Oil Tool Industries, Inc. | Apparatus for well treating |
US4464994A (en) * | 1982-06-30 | 1984-08-14 | Standard Oil Company (Indiana) | Apparatus for plugging a blast hole in an in situ oil shale retort or the like |
US4579175A (en) * | 1984-08-10 | 1986-04-01 | Deutsche Texaco Aktiengesellschaft | Method of reducing water production |
DE3886392T2 (en) * | 1988-06-06 | 1994-04-07 | Sanipor International Ag Chur | Method for improving the strength and waterproofness of floors and structures. |
US5623993A (en) * | 1992-08-07 | 1997-04-29 | Baker Hughes Incorporated | Method and apparatus for sealing and transfering force in a wellbore |
US5417285A (en) * | 1992-08-07 | 1995-05-23 | Baker Hughes Incorporated | Method and apparatus for sealing and transferring force in a wellbore |
US6026903A (en) * | 1994-05-02 | 2000-02-22 | Halliburton Energy Services, Inc. | Bidirectional disappearing plug |
US5765641A (en) * | 1994-05-02 | 1998-06-16 | Halliburton Energy Services, Inc. | Bidirectional disappearing plug |
US5826661A (en) * | 1994-05-02 | 1998-10-27 | Halliburton Energy Services, Inc. | Linear indexing apparatus and methods of using same |
US5479986A (en) * | 1994-05-02 | 1996-01-02 | Halliburton Company | Temporary plug system |
US5607017A (en) * | 1995-07-03 | 1997-03-04 | Pes, Inc. | Dissolvable well plug |
US6076600A (en) * | 1998-02-27 | 2000-06-20 | Halliburton Energy Services, Inc. | Plug apparatus having a dispersible plug member and a fluid barrier |
US6161622A (en) * | 1998-11-02 | 2000-12-19 | Halliburton Energy Services, Inc. | Remote actuated plug method |
US6220350B1 (en) * | 1998-12-01 | 2001-04-24 | Halliburton Energy Services, Inc. | High strength water soluble plug |
US6472068B1 (en) * | 2000-10-26 | 2002-10-29 | Sandia Corporation | Glass rupture disk |
US6367549B1 (en) * | 2001-09-21 | 2002-04-09 | Halliburton Energy Services, Inc. | Methods and ultra-low density sealing compositions for sealing pipe in well bores |
US6554068B1 (en) * | 2002-01-29 | 2003-04-29 | Halliburton Energy Service,S Inc. | Method of downhole fluid separation and displacement and a plug utilized therein |
US7021389B2 (en) * | 2003-02-24 | 2006-04-04 | Bj Services Company | Bi-directional ball seat system and method |
US20040231845A1 (en) * | 2003-05-15 | 2004-11-25 | Cooke Claude E. | Applications of degradable polymers in wells |
US8342240B2 (en) * | 2003-10-22 | 2013-01-01 | Baker Hughes Incorporated | Method for providing a temporary barrier in a flow pathway |
NO321976B1 (en) * | 2003-11-21 | 2006-07-31 | Tco As | Device for a borehole pressure test plug |
US7168494B2 (en) * | 2004-03-18 | 2007-01-30 | Halliburton Energy Services, Inc. | Dissolvable downhole tools |
US7246665B2 (en) * | 2004-05-03 | 2007-07-24 | Halliburton Energy Services, Inc. | Methods of using settable compositions in a subterranean formation |
US8061388B1 (en) * | 2004-11-08 | 2011-11-22 | O'brien Daniel Edward | Chemical barrier plug assembly and manufacturing and dislodgement methods for hydrostatic and pneumatic testing |
US7322417B2 (en) * | 2004-12-14 | 2008-01-29 | Schlumberger Technology Corporation | Technique and apparatus for completing multiple zones |
US7350582B2 (en) * | 2004-12-21 | 2008-04-01 | Weatherford/Lamb, Inc. | Wellbore tool with disintegratable components and method of controlling flow |
US7422060B2 (en) * | 2005-07-19 | 2008-09-09 | Schlumberger Technology Corporation | Methods and apparatus for completing a well |
US8567494B2 (en) * | 2005-08-31 | 2013-10-29 | Schlumberger Technology Corporation | Well operating elements comprising a soluble component and methods of use |
US20070051521A1 (en) * | 2005-09-08 | 2007-03-08 | Eagle Downhole Solutions, Llc | Retrievable frac packer |
US8231947B2 (en) * | 2005-11-16 | 2012-07-31 | Schlumberger Technology Corporation | Oilfield elements having controlled solubility and methods of use |
US7493956B2 (en) * | 2006-03-16 | 2009-02-24 | Baker Hughes Incorporated | Subsurface safety valve with closure provided by the flowing medium |
US7325617B2 (en) * | 2006-03-24 | 2008-02-05 | Baker Hughes Incorporated | Frac system without intervention |
US8056628B2 (en) * | 2006-12-04 | 2011-11-15 | Schlumberger Technology Corporation | System and method for facilitating downhole operations |
RU2006146962A (en) * | 2006-12-28 | 2008-07-10 | Шлюмбергер Текнолоджи Б.В. (Nl) | METHOD FOR PREVENTING THE DISPOSAL OF PROPANTA FROM CRACK AND GRAVEL FILTER |
US20080199351A1 (en) | 2007-02-15 | 2008-08-21 | Airocare, Inc. | Zero yield reactor and method of sanitizing air using zero yield reactor |
US20080251253A1 (en) * | 2007-04-13 | 2008-10-16 | Peter Lumbye | Method of cementing an off bottom liner |
US7690436B2 (en) * | 2007-05-01 | 2010-04-06 | Weatherford/Lamb Inc. | Pressure isolation plug for horizontal wellbore and associated methods |
US20090084539A1 (en) * | 2007-09-28 | 2009-04-02 | Ping Duan | Downhole sealing devices having a shape-memory material and methods of manufacturing and using same |
US8714250B2 (en) * | 2007-10-18 | 2014-05-06 | Schlumberger Technology Corporation | Multilayered ball sealer and method of use thereof |
US7806189B2 (en) * | 2007-12-03 | 2010-10-05 | W. Lynn Frazier | Downhole valve assembly |
EP2083059A1 (en) * | 2007-12-28 | 2009-07-29 | Services Pétroliers Schlumberger | Cement compositions containing inorganic and organic fibres |
US8056643B2 (en) * | 2008-03-26 | 2011-11-15 | Schlumberger Technology Corporation | Systems and techniques to actuate isolation valves |
US8936085B2 (en) * | 2008-04-15 | 2015-01-20 | Schlumberger Technology Corporation | Sealing by ball sealers |
US7775286B2 (en) * | 2008-08-06 | 2010-08-17 | Baker Hughes Incorporated | Convertible downhole devices and method of performing downhole operations using convertible downhole devices |
US8006755B2 (en) | 2008-08-15 | 2011-08-30 | Sun Drilling Products Corporation | Proppants coated by piezoelectric or magnetostrictive materials, or by mixtures or combinations thereof, to enable their tracking in a downhole environment |
US7775285B2 (en) * | 2008-11-19 | 2010-08-17 | Halliburton Energy Services, Inc. | Apparatus and method for servicing a wellbore |
US9091133B2 (en) | 2009-02-20 | 2015-07-28 | Halliburton Energy Services, Inc. | Swellable material activation and monitoring in a subterranean well |
US8413727B2 (en) * | 2009-05-20 | 2013-04-09 | Bakers Hughes Incorporated | Dissolvable downhole tool, method of making and using |
US20110284232A1 (en) * | 2010-05-24 | 2011-11-24 | Baker Hughes Incorporated | Disposable Downhole Tool |
US20110308802A1 (en) * | 2010-06-17 | 2011-12-22 | Ladva Hemant K J | Degradable material for different oilfield applications |
US20110315381A1 (en) * | 2010-06-25 | 2011-12-29 | Foy Streetman | Compositions and method for use in plugging a well |
CA2746034C (en) * | 2010-07-15 | 2018-09-04 | Lafarge | Low density cementitious compositions using limestone |
AU2011343765A1 (en) * | 2010-12-14 | 2013-07-18 | Altarock Energy, Inc. | High temperature temporary diverter and lost circulation material |
US8668019B2 (en) * | 2010-12-29 | 2014-03-11 | Baker Hughes Incorporated | Dissolvable barrier for downhole use and method thereof |
-
2010
- 2010-12-29 US US12/981,083 patent/US8668019B2/en active Active
-
2011
- 2011-12-19 WO PCT/US2011/065839 patent/WO2012091984A2/en active Application Filing
-
2014
- 2014-01-06 US US14/148,045 patent/US20140116688A1/en not_active Abandoned
Patent Citations (24)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4923806A (en) * | 1985-06-14 | 1990-05-08 | Carrier Corporation | Method and apparatus for refrigerant testing in a closed system |
US6349766B1 (en) * | 1998-05-05 | 2002-02-26 | Baker Hughes Incorporated | Chemical actuation of downhole tools |
US20080149351A1 (en) * | 2006-12-20 | 2008-06-26 | Schlumberger Technology Corporation | Temporary containments for swellable and inflatable packer elements |
US20080262735A1 (en) * | 2007-04-19 | 2008-10-23 | Baker Hughes Incorporated | System and Method for Water Breakthrough Detection and Intervention in a Production Well |
US20100294500A1 (en) * | 2007-05-22 | 2010-11-25 | Timothy Michael Lesko | Method of improving the conductivity of a fracture in the space between proppant pillars |
US20090034368A1 (en) * | 2007-08-02 | 2009-02-05 | Baker Hughes Incorporated | Apparatus and method for communicating data between a well and the surface using pressure pulses |
US20100288495A1 (en) * | 2007-12-14 | 2010-11-18 | 3M Innovative Properties Company | Methods of treating subterranean wells using changeable additives |
US20100307745A1 (en) * | 2009-06-03 | 2010-12-09 | Schlumberger Technology Corporation | Use of encapsulated tracers |
EP2372331A1 (en) * | 2010-03-31 | 2011-10-05 | PRAD Research and Development Limited | System and method for determining incursion of water in a well |
US20110239754A1 (en) * | 2010-03-31 | 2011-10-06 | Schlumberger Technology Corporation | System and method for determining incursion of water in a well |
US8596354B2 (en) * | 2010-04-02 | 2013-12-03 | Schlumberger Technology Corporation | Detection of tracers used in hydrocarbon wells |
US20110240287A1 (en) * | 2010-04-02 | 2011-10-06 | Schlumberger Technology Corporation | Detection of tracers used in hydrocarbon wells |
US20110257887A1 (en) * | 2010-04-20 | 2011-10-20 | Schlumberger Technology Corporation | Utilization of tracers in hydrocarbon wells |
US20110277996A1 (en) * | 2010-05-11 | 2011-11-17 | Halliburton Energy Services, Inc. | Subterranean flow barriers containing tracers |
US8322414B2 (en) * | 2010-05-25 | 2012-12-04 | Saudi Arabian Oil Company | Surface detection of failed open-hole packers using tubing with external tracer coatings |
US20110290480A1 (en) * | 2010-05-25 | 2011-12-01 | Saudi Arabian Oil Company | Surface detection of failed open-hole packers using tubing with external tracer coatings |
US20130075090A1 (en) * | 2010-06-11 | 2013-03-28 | Absolute Completion Technologies Ltd. | Wellbore fluid treatment and method |
US8833154B2 (en) * | 2010-10-19 | 2014-09-16 | Schlumberger Technology Corporation | Tracer identification of downhole tool actuation |
US20120168153A1 (en) * | 2010-12-30 | 2012-07-05 | Baker Hughes Incorporated | Watercut sensor using reactive media |
US8684077B2 (en) * | 2010-12-30 | 2014-04-01 | Baker Hughes Incorporated | Watercut sensor using reactive media to estimate a parameter of a fluid flowing in a conduit |
US9091142B2 (en) * | 2010-12-30 | 2015-07-28 | Baker Hughes Incorporated | Watercut sensor using reactive media |
US20120247777A1 (en) * | 2011-03-30 | 2012-10-04 | Hutchins Richard D | Methods for supplying a chemical within a subterranean formation |
US20130017610A1 (en) * | 2011-07-12 | 2013-01-17 | Jeffery Roberts | Encapsulated tracers and chemicals for reservoir interrogation and manipulation |
US20150134253A1 (en) * | 2012-04-16 | 2015-05-14 | Weatherford/Lamb, Inc. | Method and apparatus for monitoring a downhole tool |
Cited By (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO2018031008A1 (en) * | 2016-08-10 | 2018-02-15 | Halliburton Energy Services, Inc. | Soluble plug usable downhole |
GB2566408A (en) * | 2016-08-10 | 2019-03-13 | Halliburton Energy Services Inc | Soluble plug usable downhole |
GB2566408B (en) * | 2016-08-10 | 2021-07-28 | Halliburton Energy Services Inc | Soluble plug usable downhole |
AU2016418517B2 (en) * | 2016-08-10 | 2022-03-24 | Halliburton Energy Services, Inc. | Soluble plug usable downhole |
Also Published As
Publication number | Publication date |
---|---|
US20120168152A1 (en) | 2012-07-05 |
WO2012091984A2 (en) | 2012-07-05 |
WO2012091984A3 (en) | 2012-11-08 |
US8668019B2 (en) | 2014-03-11 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
US8668019B2 (en) | Dissolvable barrier for downhole use and method thereof | |
CA2819364C (en) | Autonomous downhole conveyance system | |
US10053968B2 (en) | Methods for multi-zone fracture stimulation of a well | |
US20170314372A1 (en) | System and Method for Autonomous Tools | |
US8960295B2 (en) | Fracture valve tools and related methods | |
US11421526B2 (en) | Completion and production apparatus and methods employing pressure and/or temperature tracers | |
US20120227962A1 (en) | Non-intrusive flow indicator | |
US20150107825A1 (en) | Downhole device for data acquisition during hydraulic fracturing operation and method thereof | |
BR112015004235B1 (en) | METHODS FOR REMOVING A BUFFER AND FOR REMOVING A DEGRADABLE BARRIER BUFFER, AND, APPLIANCE FOR USE IN AN UNDERGROUND WELL AND FOR REMOVING A DEGRADABLE BUFFER | |
CA2912295C (en) | Multiple-interval wellbore stimulation system and method | |
WO2012161854A2 (en) | Safety system for autonomous downhole tool | |
WO2015039248A1 (en) | Hydraulically actuated tool with pressure isolator | |
WO2015002822A1 (en) | Selective plugging element and method of selectively plugging a channel therewith | |
US11578539B2 (en) | Dissolvable connector for downhole application | |
NO20200477A1 (en) | Plug formed from a disintegrate on demand (dod) material | |
US11649694B2 (en) | Open hole multi-zone single trip completion system |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
STCB | Information on status: application discontinuation |
Free format text: ABANDONED -- FAILURE TO RESPOND TO AN OFFICE ACTION |