Methods of activating compositions in subterranean zones.
Abstract
The present disclosure is directed to a system and method for managing cement in a subterranean zone. In some implementations, a method of cementing in a subterranean formation includes positioning a cement slurry including a plurality of activation devices in a wellbore. The activation devices configured to release an activator that increases a setting rate of the cement slurry. A signal is transmitted to at least a portion of the cement slurry to activate the activation devices. The activation device releases the activator in response to at least the signal.

Term
3.9 yearsleft in the term
Expires 23 August 2030.
- Priority
- Filed
- Granted
- Today
- Expires
3 claims: 3 independent, 0 dependent
- 1REIVINDICACIONES Un método para tratar una formación subterránea, que comprende:colocar una composición fraguadle que incluye un dispositivo de activación en un pozo, en donde el dispositivo de activación se utiliza para incrementar una velocidad de fraguado de la composición fraguable en respuesta a una señal de activación;y transmitir la señal de activación a la composición fraguable para liberar un activador del dispositivo de activación. / Un método de acuerdo con la reivindicación 1, caracterizado porque la composición fraguable es una composición de cemento y en donde la señal se transmite a por lo menos una porción de la composición de cemento para activar el dispositivo de activación, en donde el dispositivo de activación libera el activador en respuesta a por lo menos la señal.
- 23. Un método de acuerdo con la reivindicación 1 ó 2, cana-út erizado porque la composición fraguable fragua en un rango desde una hora a un día después de reaccionar con el activador. Un método de acuerdo con la reivindicación 1, 2 ó 3, caracterizado porque el dispositivo de activación incluye al menos una dimensión en un rango de aproximadamente 1 micrómetro (pm) a unos 10,000 pm. Un método de acuerdo con cualquiera de las reivindicaciones anteriores, caracterizado porque la señal comprende al menos una de una señal electromagnética, una señal de presión, una señal magnética, una señal eléctrica, una señal acústica, una señal ultrasónica, o una señal de radiación, y en donde la señal de radiación comprende al menos uno de neutrones, partículas alfa, o partículas beta.
- 36./ Un método de acuerdo con cualquiera de las reivindicaciones anteriores, caracterizado porque el dispositivo de activación es un dispositivo de Sistema MicroElectro-Mecánico (MEMS). Un método de acuerdo con cualquiera de las reivindicaciones anteriores, caracterizado porque el dispositivo de activación se mezcla con la composición fraguable en una densidad en un rango de aproximadamente 0.48 a unos 2.88 kg/1 (4 a 24 libras por galón (ppg). Un método de acuerdo con cualquiera de las reivindicaciones anteriores, caracterizado porque la composición fraguable incluye un cemento hidráulico, un fluido base y un retardador. ^3/. Un método de acuerdo con cualquiera de las reivindicaciones anteriores, además comprende transmitir una señal a través de una tubería de revestimiento para activar el dispositivo de activación. Un dispositivo de activación, que comprende:un módulo de activación que contiene un activador que incrementa una velocidad de fraguado de una composición de cemento;un transductor que recibe una señal inalámbrica de activación;y un módulo de lógica que transmite una señal de liberación al módulo de activación para liberar el activador en respuesta al transductor que recibe la señal de activación. .1. El dispositivo de activación de acuerdo con la reivindicación 10, caracterizado porque el módulo de activación incluye un elemento que contiene el activador en un depósito. . El dispositivo de activación de acuerdo con la reivindicación 10 u 11, caracterizado porque la señal de 97 IMPI “ ' INSTITUTO MEXICAN' ' PE LA PROPIEDAD INDUSTRIAL activación provoca una abertura en el elemento para liberar el activador. El dispositivo de activación de acuerdo con la reivindicación 12, caracterizado porque la abertura se basa, al menos en parte, en calentamiento resistivo, reacción química, o mecánicamente. '14. El dispositivo de activación de acuerdo con la reivindicación 10, 11, 12, ó 13, caracterizado porque el módulo activador comprende un Sistema Micro-Electro-Mecánico (MEMS) que mueve una porción del módulo de activación para liberar el activador en respuesta a una señal de activación. í 5 '· El dispositivo de activación de acuerdo con la reivindicación 14, caracterizado porque el MEMS cambia la porción del módulo de activación entre una posición abierta y una cerrada en una frecuencia especificada para dispersar el activador en la composición de cemento. lo. El dispositivo de activación de acuerdo con cualquiera un módulo X?. cualquiera porque el z· cualquiera además comprende de lógica. de acuerdo con 16, caracterizado a con el cemento. de acuerdo con 17, caracterizado de las reivindicaciones 10 a 15, de energía que energiza el módulo El dispositivo de activación de las reivindicaciones 10 a dispositivo de activación se mezcl El dispositivo de activación de las reivindicaciones 10 a IMPI porque el módulo de activación incluye al menos una dimensión en un rango de aproximadamente 1 pm a unos 10,000 pm. 19. El dispositivo de activación de acuerdo con cualquiera de las reivindicaciones 10 a 18, además comprende 5 un módulo de energía que genera una diferencia de voltaje entre dos terminales utilizando un entorno alcalino de la composición de cemento. IMPI
Independent claims3
523 paragraphs in 68 sections, as filed
(54) Title: METHODS OF ACTIVATION COMPOSITIONS IN UNDERGROUND AREAS. (54) Title: METHODS OF ACTIVATING COMPOSITIONS IN SUBTERRANEAN ZONES.
(57) Summary
This disclosure is directed to a system and method for administering cement in an underground zone. In some implementations, a cementing method in an underground formation includes positioning a cement grout that includes a plurality of triggering devices in a well. Activation devices configured to release an activator that increases a setting speed of the cement grout. A signal is transmitted to at least a portion of the cement grout to activate the trigger devices. The trigger device releases the trigger in response to at least the signal.
(57) Abstract
The present disclosure is directed to a system and method for managing cement in a subterranean zone. In some implementations, a method of cementing in a subterranean formation ineludes positioning a cement slurry including a plurality of activation devices in a wellbore. The activation devices configured to release an activator that increases a setting rate of the cement slurry. A signal is transmitted to at least a portion of the cement slurry to activate the activation devices. The activation device releases the activator in response to at least the signal.
PATENT TITLE NO. 339042
SE i
sicjum of rcmoMiÁ%. · Holder (s):
Home:
Denomination:
Classification:
In
Institute
Mexican Property
Industrial
HALLIBURTON ENERGY SERVICES, INC.
10200 Bellaire Boulevard, Houston, Texas, 1 ^ 72, USA
T; i, i
ACTIVATION COMPOSITION METHODS IN UNDERGROUND AREAS.
lnt.CI.8: C04B40 / 02; E21B33 / 14
.. JgdVI LE 'RDBER I
MX / a / 201
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<img file="MX339042B_D0002.tif" />
ICITUD
YfcS, CRAIG RODOY, ENTI
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AÍ-; x¿SX, ¿fy; ¿K
International filing date: August 23, 2010
PRIORITY
Date:
August 2009
H ζ igency: Twenty ι | tos de Vencí ent <^ 23 dtóó ^ to 2030 patent reference is
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Number:
12 / 547,233 ndamento V. 37 fraction V, 6 'fráó ^ ióh'llI, · y-he of the Property Law lij' <31 ΥΐΜΐΐΓΧ.<sup>1</sup> > -. „« You lustria !.
It is not patented for a period of improper years and will be subject to payment of the 1st »Sa gara keep vij
-w * - · - - · í with XMMf6 basis established by articles V neAma useful and 7 ° bis 2 of the
Federation (DOF) jTWUil f ,, qi ^ »» mada to 02I ^ Í ^ Wbá (7l 0/1996, 12/26/1997, 1 ¡/ 05 / 2009.06 / 01/2010, 18/06/3 ( ^ 6 ^^ 1 ^ -1 ^, ^^ 1 ^ (1 ^ 09/04/2012); articles 1, 3, month I and III of the Regulation of the Mexican Institute of Industrial Property (DOF 1
08/04/2004 and 09/13/2007); 1, 3 and 5 subsection a) and antepenultimate paragraph of the Agreement that delegates powers to the Deputy Directors General, Coordinator, Divisional Directors, Heads of Regional Offices, Divisional Deputy Directors, Departmental Coordinators and other subordinates of the Mexican Property Institute Industrial. (DOF 12/15/1999, amended on 02/04/2000, 07/29/2004, 08/04/2004 and 09/13/2007).
Pursuant to Article 23 of I ntada from the date of pres4 rights.
lien subscribes to the present Industrial Opportunity (Dlarii / 01/2004, 06/16/2005, 2!
; iso a), subsection ili) 4 ° samado, Q1 / Q7
Law of the Popí suitable for • lia%
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iables, including those of '5/1999, iction V 2/1999, I and III and ¡7/2004,
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Issue Date: May 5, 2016
DIVISIONAL JOR OF EXAMINATION OF PATENT FUND, ELECTRICAL AREAS AND OF REGISTRIES OF INDUSTRIAL DESIGNS AND
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pediww
Sand! Nc. 550. Floor i.
Co!. Pueblo Santa Maris Tepepan, xochimiicc, C P. 16020,
Mexico City
Tea!. (55) 53 34 07 00 www.irripi oob.mx
III lili IIIIIIIII
MX / 2016/36550
33W
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FIELD OF THE INVENTION
This invention relates to cementing operations and, more particularly, to cement activation methods in underground areas.
BACKGROUND OF THE INVENTION
Natural resources such as gas, oil, and water that reside in an underground formation or zone are usually recovered by drilling a well in the underground formation while circulating a drilling fluid in the well. After the circulation of the drilling fluid is complete, a column of pipe (eg casing pipe) is run in the well. In general, the drilling fluid is then circulated down through the inside of the tube and up through the ring, which is located between the outside of the tube and the walls of the well. Some wells, for example, those with a little oil and gas, are lined with casing. The casing pipe stabilizes the sides of the well. Thereafter, primary cementation is typically carried out whereby a cement grout is placed in the ring and allowed to set in
<img file="MX339042B_D0009.tif" />
a hard mass (i.e., liner) to thereby join the pipe column to the borehole walls to seal the ring. In a cementing operation, the cement is introduced down the well and into the annular space between the casing and the surrounding soil. Cement secures the casing in the well, and prevents fluids from flowing vertically in the ring between the casing and the surrounding soil. Different cement formulations are designed for a variety of well conditions, which can be above ambient temperature and pressure. When designing a cement formulation, a number of potential mixes can be evaluated to determine its mechanical properties under various conditions. Subsequent secondary cementing operations can also be carried out. An example of a secondary cementing operation is to pressurize the cementing by which the cement slurry is used to plug and seal the undesirable flow passages in the cement liner and / or liner pipe. They are also used
<td>sealants</td><td>than</td><td>are not</td><td>cement (not cementitious) for</td><td>the</td>
<td>preparation</td><td>of</td><td>a well</td><td>For example, polymer, resin,</td><td>or</td>
<td>sealants</td><td>with</td><td>base of</td><td>latex may be desirable for</td><td>its</td>
laying behind the casing.
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To improve the life of the well and minimize costs, the sealing slurries are chosen based on the calculated efforts and the characteristics of the formation to be served. Suitable sealants are selected based on the conditions expected to be encountered during the service life of the sealant. Once the sealant is chosen, it is desirable to monitor and / or evaluate the health of the sealant so that timely maintenance can be carried out and service life can be maximized. The integrity of the sealant can be negatively affected by conditions in the well. For example, cracks in cement can allow the influx of water while acidic conditions can degrade cement. The initial strength and service life of cement can be significantly affected by its moisture content from the time it is laid. Moisture and temperature are the primary means of hydration for many cements and are the critical factors in the most prevalent deterioration processes, including damage due to freezing and thawing, alkali-aggregate reaction, sulfate attack, and formation delayed Etringite (hexacalcium aluminate trisulfate). Therefore, it is desirable to measure one or more sealing parameters (eg, moisture content, temperature, pH, and ion concentration) in order
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UNWORN to monitor the integrity of the sealant. ____________________
Active, integrable sensors can involve drawbacks that make them undesirable for use in a well environment. For example, low-energy electronic moisture sensors (eg, nanowatt) are available, but have inherent limitations when embedded within cement. The highly alkaline environment can damage your electronics, and they are sensitive to electromagnetic noise.
Additionally, power must be provided from an internal battery to activate the sensor and transmit the data, which increases the size of the sensor and decreases the life of the sensor.
BRIEF DESCRIPTION OF
THE INVENTION
In accordance with one aspect of the present invention, a method of treating an underground formation is provided, comprising: placing a settable composition including an activating device in a well, where the activating device is used to increase a setting speed of the settable composition in response to an activation signal; and transmitting the activation signal to the settable composition to release an activator from the activation device.
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IMPI
MEXICAN INSTITUTE
R GIVE THE PROPERTY <sup>or</sup> INDUSTRIAL
In another aspect, the invention provides nn mÁ-h ^ rlo cementation in an underground formation, comprising:
placing a cement composition including an activating device in a well, where the activating device is configured to release an activator that increases a setting speed of the cement composition; and transmitting a signal to at least a portion of the cement composition to activate the activating device, wherein the activating device releases the activator in response to at least the signal.
In a further aspect, the invention provides an activating device, comprising: an activating module containing an activator that increases a setting speed of a cement composition; a transducer that receives a wireless trigger signal; and a logic module that transmits a release signal to the trigger module to release the trigger in response to the transducer that receives the trigger signal.
This disclosure is directed to a system and method for administering cement in an underground zone. In some implementations, a cementing method in an underground formation includes positioning a cement grout that includes a plurality of triggering devices in a well. Activation devices
IMPI
<img file="MX339042B_D0013.tif" />
configured to release an activator that increases the setting speed of the cement grout. A signal is transmitted to at least a portion of the cement grout to activate the trigger devices. The trigger device releases the trigger in response to at least the signal.
In addition, a method is disclosed herein that comprises placing a sealant composition comprising one or more MEMS sensors in a well and allowing the sealing composition to set.
Also disclosed herein is a method of servicing a well that involves placing a MEMS interrogator tool in the well, beginning with the placement within the well of a sealant composition comprising one or more MEMS sensors, and ending with placing the sealant composition in the well on top of the interrogator tool so that it is in close proximity to said one or more MEMS sensors.
Also disclosed in this document is a method comprising placing a plurality of MEMS sensors in a well service fluid.
Also disclosed in this document is a well composition comprising one or more MEMS sensors, wherein the well composition is a drilling fluid, a fluid
<img file="MX339042B_D0014.tif" />
IMPI spacer, a sealant, or combinations thereof.
The foregoing has amply indicated the features and technical advantages of the present disclosure in order to better understand the detailed description that follows.
Additional features and advantages of the apparatus and method will be described hereinafter which form the subject of the claims of this disclosure. It should be appreciated by those skilled in the art that the disclosed design and specific implementations can easily be used as a basis for modifying or designing other structures to carry out the same purposes of the present disclosure. It should also be borne in mind by those skilled in the art that such equivalent constructions do not depart from the scope of the apparatus and method as set forth in the appended claims.
Details of one or more implementations of the invention are set forth in the accompanying drawings and description below. Other features, objects, and advantages of the invention will be apparent from the description and drawings, and from the claims.
IMPI
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BRIEF DESCRIPTION OF THE DRAWINGS
Figure 1 is an exemplary well system for producing fluids from a production area.
Figures 2A and 2B are exemplary cementing processes in the well system of Figure 1.
Figure 3 illustrates an exemplary activation device for activating cement grout in a well.
Figures 4A-C illustrate exemplary processes for releasing activators in cement slurries.
Figure 5 is a flow chart illustrating an exemplary method of activating deposited cement grout.
Figure 6 is a flowchart illustrating an exemplary method of making trigger devices.
Figure 7 is an exemplary well system for transmitting trigger signals to the cement grout.
Figures 8A and 8B illustrate an exemplary power module for activation devices in a cement grout.
Figure 9 is a flow diagram illustrating or an implementation of a method in accordance with the present disclosure.
Figure 10 is a flow chart detailing a method of determining when a reverse cementing operation is complete and for subsequent optional activation.
IMPI
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of a tool inside the well.
FIG. 11 is a flow chart of a method for selecting from a group of sealant compositions in accordance with an implementation of the present disclosure.
Similar reference symbols in the different drawings indicate similar elements.
DETAILED DESCRIPTION OF THE INVENTION
FIG. 1 is a cross sectional view of an exemplary well system 100 for delivering cement in an underground zone. For example, system 100 may include a cement grout with devices that perform one or more operations associated with the delivery and setting of the cement grout. Operations may include determining one or more parameters of the cement and / or cement slurry (eg, moisture content, temperature, pH, ion concentration), releasing an activator that initiates or accelerates the setting process, and / or others. Regarding implementations that include sensors, system 100 may periodically interrogate sensors in the cement to detect operating conditions over a period of time. For example, system 100 can detect the properties of cement<sup>1</sup> to assess the status of, for example, a well in operation. Regarding activation
IMPI
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of the cement grout, system 100 may have a command cement delivery system that selectively controls the setting of a cement grout. In these examples, system 100 may include a cement grout with devices that release an activator into the cement grout in response to at least one activation signal. An activator typically includes any chemical that activates and / or accelerates the setting process of a cement grout in system 100. An activator can also retard or otherwise affect the setting or properties of the cement grout. For example, the system
100 It can include one or more of the following triggers:
sodium hydroxide, sodium carbonate, calcium chloride, calcium nitrite, calcium nitrate, and / or others. Furthermore, system 100 may include devices with sensors and activators such that the devices release activators in response to at least detecting predefined criteria in the cement slurry such as pH reaching a specified threshold. In some implementations, trigger devices may include items that contain substantially one or more triggers and that release the trigger in response to at least one event. For example, triggering devices can receive a signal (eg, infrared signal), and in
WICKED »
MEXICAN INSTITUTE · DELA PHÜHEDAI 'INDUSTRIAL response to the signal, the contained element can ΙϊΗρταγ.
said one or more activators. Regarding activation of the contained element, system 100 can mechanically move the contained element, chemically remove at least a portion of the contained element, resistively heat the contained element to form an opening, and / or other processes to release said one or more activators. For example, system 100 may include System devices
Micro-Electro-Mechanical (MEMS, Micro-Electro-Mechanical
System) in the cement grout mechanically released by the activators. In general, system 100 includes a cement grout in a ring that forms between a casing and a well, and when the cement sets, the cement secures the casing in place. By selectively monitoring and / or controlling the setting of a cement grout, system 100 can allow the properties of the cement to be tailored once the cement grout has been pumped into the wellbore.
Furthermore, system 100 can monitor cement during normal operating conditions.
In some implementations, well system 100 includes a production zone 102, a non-production zone 104, a well 106, a cement slurry 108, and devices
110. Production area 102 may be a formation
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Underground IMPI that includes resources (eg, oil, gas, water). Non-production zone 104 may be one or more formations that are isolated from well 106 using cement grout 108. For example, zone 104 may include contaminants that, when mixed with resources, may result in additional processing of resources and / or make production economically unfeasible. Cement grout 108 can be selectively pumped or positioned within well 106. In some implementations, the properties of the cement grout
108 they can be monitored using 110 devices.
Alternatively or in combination, the setting of the cement slurry 108 can be activated or accelerated using devices 110. For example, devices 110 can release an activator in response to a signal initiated by, for example, a user of system 100 and / or devices
110 that detect the specified operating conditions. By monitoring and / or controlling the setting, a user can configure the system 100 without substantial interference from the setting of the cement grout 108.
As for a more detailed description of the elements of the system 100, the well 106 extends from a surface 112 towards the production area 102. The well 106 may include equipment 114 that is placed close to the
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ΙΜΡΙ
INSTITUTO MEXICANO D £ LA PROPIEDAD INDUSTRIAL surface 112. The equipment 114 may be coupled to a column of pipe 116 that extends a substantial portion of the length of the well 106 approximately from the surface 112 towards the production areas 102 (eg. , deposit with hydrocarbon content). In some implementations, pipe column 116 may extend beyond production zone 102. Pipe column
116 may extend near end 118 of well 106. In some implementations, well 106 may be completed with pipe column 116 extending to a predetermined depth near production area 102. Ultimately, well 106 initially extends into a substantially vertical direction towards production area 102. In some implementations, well 106 may include other positions that are horizontal, inclined, or otherwise deviated from vertical.
Team 114 can be centered on an underground oil or gas formation 102 located below the earth's surface 112. Team 114 includes a work deck 124 that supports a derrick
126. Drill tower 126 supports lifting apparatus 128 for raising and lowering pipe columns such as pipe column 116. Pump 130 is capable of pumping a variety of well compositions (eg, fluid
<img file="MX339042B_D0020.tif" />
Drilling IMPI, cement) inside the well and includes a pressure measuring device that provides a pressure reading at the pump discharge. Well 106 has been drilled through the different layers of land, which includes formation 102. With the completion of the well drilling, pipe column 116 is often placed in well 106 to facilitate oil production and formation gas 102. Pipe column 116 is a pipe column and extend down the well
106, through which oil and gas can be extracted. A casing or cement shoe 132 is typically attached to the end of the pipe column when the pipe column runs into the wellbore. Casing shoe 132 guides pipe column 116 to the center of the hole and can minimize or otherwise decrease problems associated with rock overhang or landslide within well 106 while the pipe column is lowered into the well . Casing shoe 132 may be a fitted float shoe with an open bottom and valve serving to prevent the reverse flow, or U-pipe, of cement slurry 108 from ring 122 into pipe column 116 while pipe column 116 runs into well 106. The region between pipe column 116 and the
IMPI
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well wall 106 is known as the casing ring
122. To fill liner ring 122 and secure pipe column 116 in place, pipe column 116 is usually cemented into well 106, which is referred to as primary cementation. In some implementations, the cement slurry 108 can be injected into the well 106 through one or more perforations 134. The cement slurry 108 can flow through a hose
136 within pipe column 116. In some cases, pipe column 116 may rest or otherwise rest on an edge 138 of surface casing pipe 120. In some implementations, the system
100 you can activate the setting of the cement slurry 108 using the activating devices 110 during, for example, the conventional primary cementing operation.
In conventional primary cementing implementations, devices 110 can be mixed into cement grout 108 before entering pipe column 116, and cement grout 108 can then be pumped down into the column of pipeline
116. For example, devices 110 can be mixed into cement slurry 108 at a density in the range of 0.48-2.88 kg / I (4-24 pounds per gallon (ppg)). As grout 108 reaches the bottom of pipe column 116,
IMPI
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it flows out of pipe column 116 and into casing ring 122 between pipe column 116 and the well wall 106. As the grout flows upward from ring 122, it displaces any fluid in the well . To ensure that no cement remains within the pipe column 116, devices called pipe cleaners (wipers) can be pumped using a well service fluid (eg, drilling mud) through the pipe column 116 behind the grout of
<td>cement</td><td> 108.</td><td>The</td><td>pipe cleaner</td>
<td>inside</td><td>of</td><td>the</td><td>column of</td>
<td>grout</td><td> 108</td><td colspan="2">remaining out</td>
makes contact with the pipe 116 surface and pushes any of the pipe column 116.
When the cement grout reaches the surface of the earth 112, and the ring 122 is filled with grout 108, the pumping is complete. Regarding the pumping of the cement slurry 108 into the ring, a signal can be transmitted to the devices 110 before, during, and / or after the pumping is complete. The signal may request the detected operating conditions, initiate the release of the triggers, and / or other operations. For example, devices 110 can release activators that initiate and / or accelerate the setting of cement grout 108 in ring 122 in response to at least the signal. Part of or all of the pipe column 116 may be fixed to the material
IMPI ρδ ΐΝίτσυτοmfaicani>
OF THE PROPERTY VV “Te, -R®<sup>1 </sup>INPUSTWAl of adjacent soil with a cement liner as illustrated ..
in Figures 2A and 2B. In some implementations, pipe column 116 comprises a metal. After setting, pipeline column 116 may be configured to carry a fluid, such as air, water, natural gas, or to carry a power line, tubular column, or other elements.
After positioning pipeline column 116, a cement slurry 108 including devices 110 can be pumped into ring 122 by means of a pump truck (not shown). Cement grouts 110 copies are discussed in more detail below. With respect to depositing or otherwise positioning cement slurry 108 in ring 122, devices 110 can release activators to activate or otherwise increase the setting speed of cement slurry 108 in response to at least one signal . In other words, devices 110 can activate cement grout 108 to set the cement in ring 122. Alternatively, or in combination, devices 110 can detect one or more attributes of cement slurry 108 such as moisture content, temperature, pH, ion concentration, and / or other parameters. In some implementations, substantially all of the cement sets in ring 122, and
<img file="MX339042B_D0023.tif" />
only a limited portion of cement, if any, enters pipe column 116. In some implementations, all of the cement sets in ring 122, and no portion of cement grout 108 enters pipe column 116.
Relative to devices 110 including activators, activating devices 110 can release an activator that initiates or accelerates the setting of cement grout 108. For example, cement grout
108 it can remain in a substantially grout state for a specified period of time, and activating devices can activate the cement grout in response to at least one signal. Trigger devices 110 can receive a signal and, in response to the signal, release triggers. In some cases, activating devices 110 contain activators with, for example, a membrane. In some implementations, the membrane can be metal, a polymer, and / or another element. Suitable polymers to create such a membrane include polystyrene, ethylene vinyl acetate copolymer, polymethylmethacrylate polyurethanes, polylactic acid, polyglycolic acid, polyvinyl alcohol, polyvinylacetate, ethylene vinyl acetate hydrolyzate, silicones, and copolymer combinations of each. In response to the signal, activating device 110 can form an opening in the membrane. The
<img file="MX339042B_D0024.tif" />
Activation device 110 can form an opening by mechanically moving a portion of the membrane and / or by releasing a chemical that removes a portion of the membrane. In some implementations, the activation signal can directly activate the membrane. For example, the activation signal may be an ultrasonic signal that vibrates the membrane to form an opening. Activation device 110 may include a polymer membrane that is ultrasonically degraded to release contained activators.
In some examples, an ultrasonic signal can structurally change the membrane to release activators such as, for example, opening the membrane as a folding sheet.
In some implementations, the signal includes at least one of an electromagnetic signal, a pressure signal, a magnetic signal, an electrical signal, an acoustic signal, an ultrasonic signal, or a radiation signal, and wherein the radiation signal comprises at least one of neutrons, alpha particles, or beta particles. In some implementations, the cement composition can set in the range of one hour to one day after reacting with the activator. The triggering device can include at least one dimension in a range from about 1 pm to about 10,000 pm.
<img file="MX339042B_D0025.tif" />
IMPI
The release activator can include sodium hydroxide, sodium carbonate, amine compounds, salts comprising calcium, sodium, magnesium, aluminum, and / or a mixture thereof. Activation device 110 can release a calcium salt such as calcium chloride. In some implementations, activating device 110 can release a sodium salt such as sodium chloride, sodium aluminate, and / or sodium syndicate. Activation device 110 can release a magnesium salt such as magnesium chloride . In some examples, activating device 110 can release amine compounds such as triethanol amine, tripropanol amine, tri-isopropanol amine, and / or diethanol amine. In some implementations, activating device 110 can release the activator in an amount sufficient to set the cement grout
108 within about 1 minute to about 2 hours.
Alternatively, the activator may be present in an amount sufficient to set the grout within one hour to approximately one day. In implementations that include sodium chloride as the released activator, the concentration may be in the range of about 3% to 15% by weight of the cement in the cement slurry 108. In implementations that include calcium chloride as the released activator, concentration may be in the range
<img file="MX339042B_D0026.tif" />
about 0.5% to 5% by weight of the cement in the cement grout 108.
In some implementations, the triggering device 110 can quickly set (flash-set) the cement grout 108. As it is referred to herein, the term flash-set will be understood as the onset of the setting of the cement grout 108 within about 1 minute to about five minutes after making contact with the released activator. In some implementations, previously identified activators can quickly set the cement grout 108. Flash set activators can include sodium hydroxide, sodium carbonate, potassium carbonate, sodium or potassium bicarbonate salts, sodium silicate salts, sodium aluminate salts, ferrous and ferric salts (p (eg, ferric chloride and ferric sulfate), polyacrylic acid salts, and / or others. In some implementations, the following activators can quickly set the cement slurry 108 based on these activators exceeding a specified concentration:
calcium nitrate, calcium acetate, calcium chloride, and / or calcium nitrite. In some implementations, triggering device 110 can release a solid trigger.
<img file="MX339042B_D0027.tif" />
In some implementations, devices 110 comprise MEMS devices containing an ultra-sensitive polymer membrane lined micro deposit formation (eg, polyanhydrides, polyglycolides, polylactides, ethylene vinyl acetate copolymers, silicones). Micro tanks can be loaded with one or multiple cement additives (eg, accelerators, retarders). Upon exposure to acoustic waves (eg, ultrasonic waves), the polymer membrane can begin to degrade / decompose and cause the release of desired additives. The release rate of the additives can be controlled by the intensity of the ultrasound and its duration. A MEMS device can not only be made to have micro tanks but can also include micro pumps. The desired additive can be dispersed by means of the pumps. After exposure, the
MEMS 110 can have an acoustic / ultrasonic sensor / transducer / detector, the additive can be pumped through the cavitation. Furthermore, the MEMS activator can cause a cascade of events (eg, increase in temperature and / or pressure) resulting in the release of additives.
With respect to devices 110 that include one or more sensors, the sensors may be positioned within well 106. For example, sensors 110 may be
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extend along all or a portion of the length of the well 106 adjacent to the pipe column 116. The sealing grout 108 may be placed within the well as part of a primary cementing, secondary cementing, or other sealing operation such as it is described in greater detail in this document. In some implementations, a data interrogator tool may be positioned in an operable location to collect data from sensors 110, for example lowered into well 106 near sensors
110. The data interrogator tool can interrogate data sensors 110 (eg, by sending an RF signal) while the data interrogator tool traverses all or a portion of well 106 containing the sensors.
110. Data sensors 110 can be activated to record and / or transmit data on the data interrogation tool signal. The data interrogation tool can communicate the data to one or more computer components (eg, memory and / or microprocessor) that may be located inside the tool, on the surface
112, or both. Data can be used locally or remotely from the tool to calculate the location of each data sensor and correlate the measured parameter (s) with such locations to assess the performance of the sealant.
<img file="MX339042B_D0029.tif" />
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In some implementations, sensors 110 include MEMS sensors that, for example, detect conditions during drilling (eg, drilling fluid comprising MEMS sensors) or during cementing (eg, grout 108). comprising MEMS sensors) as described in greater detail below. Additionally or alternatively, data collection may be performed one or more times after initial placement in composition 108 comprising MEMS sensors 110. For example, data collection may be performed at the time of placement. initial in the composition well
108 comprising MEMS 110 sensors or shortly thereafter to provide a set of reference data. While the well is operated to recover natural resources over a period of time, data collection may be carried out additional times, for example at regular maintenance intervals such as every 1 year, 5 years, or 10 years. Data collected during subsequent monitoring intervals can be compared to baseline data as well as any other data obtained from previous monitoring intervals, and such comparisons may indicate the general condition of well 106. For example, changes in one or more of the detected parameters may indicate one or more problems in the well. Alternatively, the consistency o
<img file="MX339042B_D0030.tif" />
ΙΜΡΙ uniformity in the detected parameters may indicate that there are no bottom problems in well 106. In some implementations, data (eg, sealant parameters) from a plurality of monitoring intervals are plotted over a period of time, and a resulting graph can be provided showing a trend or operation line for the detected parameters. Atypical changes in the graph as indicated for example by a sharp change in slope or a step change in the graph may provide an indication of one or more present problems or the potential of a future problem. Accordingly, corrective and / or preventive treatments or services may be applied to well 106 to treat present or potential problems.
In some implementations, MEMS 110 sensors may be contained within a sealing composition
108 placed substantially within annular space 122 between a pipe column and the well wall. That is, substantially all of the MEMS 110 sensors may be located within or very close to annular space 122. In some implementations, the well service fluid comprising the MEMS 110 sensors (and therefore likewise the MEMS 110) may not penetrate, migrate, or travel substantially within the formation from the well
<img file="MX339042B_D0031.tif" />
,, IMPI
Ό MEXICAN INSTITUTE
OF THE PROPERTY
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106. In an alternative embodiment, substantially all of the MEMS 110 sensors are located within, adjacent to, or in close proximity to well 106, for example less than or equal to approximately 30.48 cm, 91.44 cm, 152.4 cm, or 304.8 cm (1,
3, 5, or 10 feet) from well 106. Such positioning adjacent or very close to MEMS sensors 110 in a fluid that is pumped into formation 102 in large volumes and penetrates, migrates, or travels substantially within or through formation 102, for example as occurs with a fracturing fluid or a flood fluid. Therefore, in the modalities, the MEMS sensors 110 can be placed near or adjacent to well 106 (in contrast to formation in general), and provide information relevant to the well itself and the compositions (eg, the wells). sealants 108) used in this document (again in contrast to formation or a general production area).
In some implementations, the data sensors 110 added to the sealant slurry 108 may be passive sensors that do not require continuous power from a battery or external source in order to transmit data in real time. In some implementations, data sensors 110 are micro-electromechanical systems (MEMS) that comprise one or more (and typically a plurality of) MEMS devices,
<img file="MX339042B_D0032.tif" />
IMPIs referred to herein as "EMS" sensors, W Typhs — MEMS 110 devices are well known, eg, a semiconductor device with mechanical characteristics on the micrometer scale. The MEMS contains the integration of mechanical elements, sensors, actuators, and electronics in a common substrate. In some implementations, the substrate comprises silicon. MEMS elements include mechanical elements that are movable by input energy (electrical energy or other energy). By using MEMS, a sensor 110 may be designed to emit a detectable signal based on a number of physical phenomena, including thermal, biological, optical, chemical, and magnetic effects or stimulation. MEMS 110 devices are tiny in size, have low power requirements, and are relatively inexpensive and rugged, and therefore suitable for use in well service operations. In some implementations, the data sensors 110 comprise an active material connected to (eg, mounted inside or surface mounted on) a container, the active material being capable of responding to a well parameter, and the active material been operatively connected to (eg, in physical contact with, surrounding, coating) a capacitive MEMS element. In various implementations, MEMS 110 sensors detect one or more
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parameters within well 106. In some implementations, the parameter may include temperature, pH, moisture content, ion concentration (eg, chloride, sodium, and / or potassium ions), and / or others. MEMS 110 sensors can also detect data on cement characteristics of the well such as stress, deformation, or combinations thereof. In some implementations, MEMS sensors
110 of the present disclosure may comprise active materials that respond to two or more measurements. In this way, two or more parameters can be monitored.
Suitable active materials, such as dielectric materials, that respond in a predictable and stable way to changes in parameters over a long period can be identified according to methods well known in the art, for example see, Ong ,
Zeng and Grimes. A Wireless, Passive Carbon Nanotube-based Gas
Sensor, (A Wireless Gas Sensor, based on Nanotube of
Active Carbon), IEEE Sensors Journal, 2, 2, (2002) 82-88;
Ong, Grimes, Robbins and Singl, Design and application of a wireless, passive, resonant-circuit environmental monitoring sensor, (design and application of a wireless, passive, resonant-circuit environmental monitoring sensor),
Sensors and Actuators A, 93 (2001) 33-43, each of which is incorporated by reference into this document in its
I Μ Ρ I
MEXICAN INSTITUTE ί
OF PROPERTY (* «.—> *
INDUSTRIAL - totality. MEMS sensors 110 suitable for the methods of the present disclosure that respond to various well parameters are disclosed in US Patent No. 7,038,470 B1 which is incorporated by reference herein in its entirety.
In some implementations, MEMS 110 sensors may be paired with Radio Frequency Identification (RFIDs) devices
Devices) and can detect and transmit parameters and / or characteristic data of the well cement to monitor the cement during its service life. RFIDs combine a microchip with an antenna (the RFID chip and antenna are collectively referred to as a transponder or tag). The antenna provides power to the RFID chip when exposed to a high-frequency electromagnetic field, a narrow band from a transceiver. A dipole or coil antenna, depending on the operating frequency, connected to the RFID chip, energizes the transponder when current is induced in the antenna by an RF signal from the transceiver antenna. Such a device can return a unique identification number (ID) by modulating and re-radiating the radio frequency (RF) wave,
Radio Frequency). Passive RF labels are gaining widespread use due to their low cost, long life,
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MEXICAN INSTITUTE OF PROPERTY>
INDUSTRIAL simplicity, efficiency, ability to identify parts at a contactless distance (linkless information transmission capability). These robust and small labels are attractive from an environmental point of view as they do not require a battery. The MEMS sensor and RFID tag are preferably integrated into a single component 110 (eg, chip or substrate), or may alternatively be separate components 110 operatively coupled to one another. In some implementations, a built-in passive MEMS / RFID 110 sensor may contain a data detection component, an optional memory, and an RFID antenna, through which excitation energy is received and energizes the sensor, thereby detecting a present condition and / or accessing one or more detected conditions stored in the memory and transmitting them through the RFID antenna.
Within the United States, the commonly used operating bands for RFID systems focus on one of three government-assigned frequencies: 125 kHz, 13.56 MHz, or 2.45 GHz. A fourth frequency, 27,125 MHz, has also been assigned. . When the 2.45 GHz carrier frequency is used, the range of an RFID chip can be many meters. While this is useful for remote sensing, there may be multiple transponders within the
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RF field. In order to prevent these devices from interacting and altering data, anti-collision schemes are used, as are known in the art. In deployments, the data sensors integrate with local tracking hardware to transmit their position as they flow within a sealant grout. Data sensors 110 can form a network using wireless links to neighboring data sensors and have location and positioning capabilities by, for example, local positioning algorithms as are known in the art. Sensors 110 can organize themselves within a network by listening to each other, thereby allowing signal communication from the farthest sensors to the sensors closest to the interrogation tool to allow for uninterrupted transmission and capture of data. In these implementations, the interrogation tool may not require traversing the entire section of the well containing the MEMS sensors in order to read the data collected by such sensors.
For example, the interrogation tool may only need to be lowered halfway along the vertical length of the well containing the MEMS sensors.
Alternatively or in combination, the interrogator tool can be lowered vertically into the well
<img file="MX339042B_D0035.tif" />
IMPI
INSTITUTO MEXICANO OE INDUSTRIAL PROPERTY to a location adjacent to a horizontal arm of a well 106, whereby MEMS sensors 110 can be located on the horizontal arm and can be read without the need for the interrogator tool to traverse the horizontal arm. Alternatively or in combination, the interrogator tool can be used on or near the surface and can read the data collected by sensors distributed along all or a portion of the well. For example, sensors 110 may be located distal to the interrogator, they can communicate through the network that is formed with the sensors as described above.
In some implementations, MEMS 110 sensors are ultra small, eg 1mm<sup>2</sup>, in such a way that they can be immersed in a grout of sealant. In some implementations, the MEMS 110 device may be approximately 1 pm<sup>2</sup> at 1 mm<sup>2</sup>, 1 mm<sup>2</sup> at 3 mm<sup>2</sup>, 3 mm<sup>2</sup> at 5 mm<sup>2</sup>, 5 mm<sup>2</sup> at 100 mm<sup>2</sup>, and / or other dimensions. In some implementations, data sensors 110 may be able to provide data throughout the service life of the cement. In some implementations, data sensors 110 can provide data for up to 100 years. In some implementations, the well composition
108 can comprise an effective MEMS quantity to measure
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one or more desired parameters. In various implementations, the composition of well 108 can comprise an effective amount of MEMS such that the detected readings can be obtained at intervals of approximately 30.48 cm,
15.24 cm, 2.54 cm, and / or other interval along the portion of well 106 that contains MEMS 110. MEMS may be present in the composition of well 108 in an amount of about 0.01 to 50% by weight.
In some implementations, the MEMS sensors 110 may comprise passive sensors (which remain powerless when not interrogated) powered by the energy radiated from a data interrogation tool.
The data interrogating tool may comprise a power transceiver that sends power to (eg, radio waves) and receives signals from MEMS sensors 110 and a processor that processes the received signals. The data interrogation tool may further comprise a memory component, a communication component, or both. The memory component can store raw and / or processed data received from MEMS sensors 110, and the communication component can transmit raw data to the processor and / or transmit processed data to another receiver, for example located on the surface. Tool components (eg, transceiver, processor, component of
IMP
<img file="MX339042B_D0037.tif" />
memory, and communication component) are coupled together and in signal communication with each other.
In some implementations, one or more of the data interrogation tool components (not shown) can be integrated into a tool or unit that is placed inside the well temporarily or permanently (eg, a module inside the well). . In some implementations, a module within the removable well comprises a transceiver and a memory component, and the module within the well is placed inside the well, reads the data from the MEMS sensors, stores the data in the memory component, is removed from the well, and raw data is accessed. Alternatively or in combination, the module within the removable well may have a processor to process and store the data in the memory component, which is subsequently accessed on the surface when the tool is removed from the well.
Alternatively, or in combination, the module within the removable well may have a communication component to transmit the raw data to a processor and / or transmit the processed data to another receiver, for example located on the surface. The communication component can communicate through wired or wireless communication.
For example, the component within the well can communicate
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with a component or other node on the surface through a cable or other communication / telemetry device such as an electromagnetic, radio frequency telemetry device, or an acoustic telemetry device. The component within the removable well can be intermittently positioned within the well by any suitable transportation, for example a wire line, flexible pipe, straight pipe, gravity, pumping, etc., to monitor conditions multiple times over the life of the well.
In some implementations, the data interrogation tool comprises a permanent or semi-permanent component within the well that remains within the well for extended periods of time. For example, a module within the semi-permanent well can be retrieved and downloaded once every few years.
Alternatively, or in combination, a module within the permanent well may remain in the well for the life of the well. In one implementation, a permanent or semi-permanent module inside the well comprises a transceiver and a memory component, and the module inside the well is placed inside the well, reading data from the sensors of
MEMS, optionally stores the data in the memory component, and transmits the reading and data optionally
Wicked ^
INSTITUTE Μ EX ICA NO
OF THE PROPERTY * --· -**
INDUSTRIAL stored surface. Alternatively in combination, the module within the permanent or semi-permanent well may have a processor to process and detect the data in processed data, which can be stored in memory and / or transmitted to the surface. The module within the permanent or semi-permanent well may have a communication component to transmit raw data to a processor and / or transmit processed data to another receiver, for example located on the surface. The communication component can communicate through wired or wireless communication. For example, the component within the well may communicate with a component at another node on the surface through a cable or other communication / telemetry device such as an electromagnetic, radio frequency telemetry device, or an acoustic telemetry device.
In some implementations, the data interrogation tool comprises an RF energy source built into its internal circuits and the data sensors are passively energized using an RF antenna, which captures the energy from the RF energy source. The data interrogation tool can be integrated with an RF transceiver. In some implementations, MEMS sensors (eg MEMS / RFID sensors) are energized
<img file="MX339042B_D0039.tif" />
MEXICAN INSTITUTE OF INDUSTRIAL PROPERTY and are interrogated by the RF transceiver from a distance, for example a distance greater than 10 m, or alternatively from the surface or from an adjacent offset well. In some implementations, the data interrogator tool goes through a casing in the well and reads the sensors from
MEMS located in a liner of sealant (eg, cement) that surrounds the casing and is located in the annular space between the casing and the wall of the well. In the implementation, the interrogator detects the MEMS sensors when it is very close to the sensors, typically passing through a component within the removable well along a length of the well comprising the MEMS sensors. In some implementations, proximity includes a radial distance from a point within the casing to a point in the plane within an annular space between the casing and the well. In some implementations, proximity includes a distance of O. lmalm, lma5m, 5m to 10m, or other ranges. In some implementations, the transceiver interrogates the sensor with 125 kHz RF energy and the proximity ranges from 0.1 m to 0.25 m. Alternatively or in combination, the transceiver interrogates the sensor with 13.5 MHz RF energy and the proximity comprises 0.25 m to 0.5 m.
<img file="MX339042B_D0040.tif" />
Alternatively or in combination
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MEXICAN INSTITUTE OF THE (“ROFIEDAU INDUSTRIAL
<img file="MX339042B_D0041.tif" />
the sensor with 915 MHz RF energy and the proximity comprises 0.5 m to 1 m. Alternatively or in combination, the transceiver interrogates the sensor with 2.4 GHz RF energy and the proximity ranges from 1 m to 2 m.
While grout 108 is referred to as a cement grout, grout 108 may include cement and / or non-cement sealants without departing from the scope of this disclosure. In some implementations, non-cement sealers comprise resin based systems, latex based systems, or combinations thereof. In implementations, the sealant comprises a styrene-butadiene latex cement grout (eg, as disclosed in US Patent Document No.
5,588,488 which is incorporated by reference herein in its entirety). Sealants can be used in the setting of expandable casing, which is described in more detail below. In some implementations, the sealant may be a cement that is used for primary or secondary well cementing operations, as discussed in more detail below.
In some implementations, sealant 108 may be cement and comprises a hydraulic cement that sets and hardens upon reaction with water. Examples of cement
<img file="MX339042B_D0042.tif" />
Hydraulic IMPI include but are not limited to cement
Portland (eg Portland class A, B, C, G, and H cements), pozzolanic cement, gypsum cement, 'phosphate cement, high alumina cement, silica cement, high alkalinity cement, slate cement, acid / base cement, magnesia cement, fly ash cement, zeolite cement systems, kiln powder cement systems, slag cement, micro fine cement, metakaolin, and combinations thereof. Examples of sealants are disclosed in the United States Patent documents.
Nos. 6,457,524;
7,077,203; and 7,174,962, each of which is incorporated by reference herein in its entirety. In some implementations, sealant 108 may comprise a sorel cement composition, which typically comprises magnesium oxide and a chloride or phosphate salt which together form eg magnesium oxychloride.
Examples of magnesium oxychloride sealants are disclosed in US Patent Nos.
6,664,215 and 7,044,222, each of which is incorporated by reference herein in its entirety.
Well composition 108 (eg, sealant) can include a sufficient amount of water to form a pumpable slurry. The water can be fresh water or salt water (eg, an unsaturated aqueous salt solution or
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a saturated aqueous salt solution such as brine or sea water). In some implementations, the cement grout
108 it may be a lightweight cementitious grout containing foam (eg foam cement) and / or hollow beads / microspheres. In some implementations, MEMS sensors 110 can be incorporated into or attached to all or a portion of the hollow microspheres. Therefore, MEMS 110 sensors can be scattered within the cement along with the microspheres. Examples of sealants containing microspheres are disclosed in the documents of
United States Patent Nos. 4,234,344; 6,457,524; and
7,174,962, each of which is incorporated by reference throughout this document. In some implementations, the MEMS 110 sensors are incorporated into a foam cement such as those described in greater detail in US Patent Documents Nos.
6,063,738; 6,367,550; 6,547,871; and 7,174,962, each of which is incorporated by reference herein in its entirety.
In some implementations, additives may be included in the cement composition to improve or change the properties of the cement. Examples of such additives include but are not limited to accelerators, setting retarders, deformers, liquid loss agents,
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bulking agents, dispersants, density reducing agents, formative conditioning agents, loss of circulation agents, thixotropic agents, suspending aids, or combinations thereof. Other mechanical property modification additives, eg, fibers, polymers, resins, latex, and the like can be added to further modify the mechanical properties. These additives can be included individually or in combination. The methods for introducing these additives and their effective amounts are known to someone skilled in the art.
With respect to activator implementations, cementitious grout 108 may comprise delayed setting cementitious compositions that are maintained in a grout state (eg, resistant to gelatinization) for an extended period of time. In such implementations, a delayed setting cement slurry 108 may include a cement, a base fluid, and a setting retarder. In these and other implementations, activation can change the state of the cement grout from delayed setting to neutral, accelerated, or less delayed. Cement grout 108 may include other additives. Delayed-setting cement slurry 108 is typically maintained in a slurry state for a range of about 6 hours to about 7 days under in-hole or other conditions. Saying
<img file="MX339042B_D0045.tif" />
That, the cement grout 108 may include components that result in a grout state for a greater or lesser amount of time. For example, cement grout 108 can be mixed or otherwise long before positioning grout 108 in ring 122. Delayed-setting cement grout 108 may, in some implementations, include a cement, a base fluid, and a setting retarder. Delayed setting cement grout 108 can be set at a desired time, such as after placement, by activating the
<td>devices</td><td>of</td><td>activation 110</td><td>to liberate</td><td>one</td><td>or</td><td>plus</td>
<td colspan="2">activators. With regard</td><td>to cements</td><td>included in the</td><td colspan="2">grout</td><td>of</td>
<td>cement 108,</td><td colspan="2">any cement</td><td>suitable for</td><td>its</td><td>use</td><td>in</td>
underground applications may be suitable for use in the present invention. For example, delayed setting cement slurry 108 may include hydraulic cement. In general, hydraulic cements typically include calcium, aluminum, silicon, oxygen, and / or sulfur and can be set and hardened by reaction with water. Hydraulic cements include, but are not limited to, Portland cement, pozzolanic cement, high alumina cement, gypsum cement, silica cement, and high alkalinity cement. Also, the cement grout
<img file="MX339042B_D0046.tif" />
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108 Delayed setting may include Ha slate based cements or blast furnace slag. In these cases, the slate may include vitrified slate, natural slate (eg, uncooked slate), and / or a mixture of natural slate and vitrified slate.
With respect to the base fluids included in the cement slurry 108, the delayed setting cement slurry 108 may include one or more base fluids such as, for example, a water based base fluid, a non-blast base fluid, or mixtures thereof. Water-based ones can include water from any source that does not contain an excess of compounds (eg, dissolved organic, such as tannins) that can adversely affect other compounds in the cement slurry 108. For example, cement grout
108 Delayed setting may include fresh water, salt water (eg, water containing one or more salts), brine (eg, water saturated with salt), and / or sea water. Water-based ones can include one or more organic liquids such as, for example, mineral oils, synthetic oils, esters, and / or others. Generally, any organic liquid in which a salt water solution can be emulsified may be suitable for use as a base fluid in the delayed setting cement slurry 108. In some implementations, the base fluid exceeds a concentration
<img file="MX339042B_D0047.tif" />
enough to form a grout that can be pumped. For example, the base fluid may be water in an amount in the range of about 25% to 150% by weight of cement (bwoc, by wheight of cement) such as one of the following ranges: about 30% to about 75 % bwoc;
about 35% to 50% bwoc; about 38% to a
46% bwoc; and / or others.
With respect to setting retarders in cement slurry 108, cement slurry 108 may include one or more different types of setting retarders such as, for example, phosphonic acid, phosphonic acid derivatives, lignosulfonates, salts, organic acids , carboxymethylated hydroxyethylated celluloses, synthetic co- or terpolymers comprising sulfonate and carboxylic acid groups, and / or borate compounds. In some implementations, the setting retarders used in the present invention are derived from phosphonic acid. Examples of setting retarders can include phosphonic acid derivatives commercially available from, for example, Solutia Corporation of St.
Louis, Mo., under the trade name DEQUEST. Another example of a setting retarder may include a phosphonic acid derivative commercially available from Halliburton Energy.
Services, Inc., under the trade name MICRO MATRIX CEMENT
<img file="MX339042B_D0048.tif" />
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INSTITUTO MiXIUANG!) E LA 'OHEDAI' INDUSTRIAL
RETARDER. Exemplary borate compounds can include sodium tetraborate, potassium pentaborate, and / or others. A commercially available example of a suitable setting retarder comprising potassium pentaborate is available from Halliburton Energy Services, Inc., under the trade name Component R. Exemplary organic acids can include gluconic acid, tartaric acid, and / or others.
An example of a suitable organic acid may be commercially available from Halliburton Energy Services,
Inc., under the trade name HR.RTM. 25. Other examples of retarders may be commercially available from
Halliburton Energy Services, Inc., under the trade names SCR-100 and SCR-500. Generally, the setting retarder in delayed setting cement slurry 108 may be in an amount sufficient to delay setting in an underground formation for a specified time. The amount of the setting retarder included in the grout 108 may be in one or more of the following ranges: approximately 0.1% to 10% bwoc; about 0.5% to 4% bwoc; and / or others.
In some implementations, the cement grout 108 may not include a setting retarder. For example, cement grout 108 may include high alumina cements and / or phosphate cements independent of
<img file="MX339042B_D0049.tif" />
<sub>46</sub> IMPI β MEXICAN INSTITUTE
OF THE PROPERTY
INDUSTRIAL a setting retarder. In these cases, the activators can initiate the setting of the slurry 108. For example, these activators can include alkali metal phosphate salts. The high alumina cement may comprise calcium aluminate in an amount in the range of about 15% to 45% by weight of the high alumina cement, Class F fly ash in an amount in the range of about 25% 45% by weight of the high alumina cement, and sodium polyphosphate in an amount in the range of about 5% to a
15% by weight of the high alumina cement. In certain implementations of the present invention where a cement composition comprising a phosphate is used, a reactive component of the cement composition (eg, the alkali metal phosphate salt) can be used as an activator.
Figures 2A and 2B illustrate a cross sectional view of the well system 100 including the set cement 202 in at least a portion of the ring 122. In particular, the activating devices 110 released the activators in at least a portion of the grout. of cement
108 to form the set cement 202. In Figure 2A, the cement slurry 108 flowed into ring 122 through pipe column 116, and in response to at least
IMPI
V.RXICANO INSTITUTE
SAY THE VW PROPERTY *. INDUSTRIAL a signal, the activation devices 110 in the grout
108 released an activator. In the illustrated example, substantially all of the devices 110 in the ring 122 released the activators to form the set cement 202 along substantially the entire length of the ring
122. Referring to Figure 2B, the cement slurry 108 flowed into ring 122 through the pipe column.
116, and in response to at least one signal, activating devices 110 in grout 108 released activators within a specified location 204. In the example illustrated, region or location 204 is located proximate to zone 102 In other words, activating devices 110 near zone 102 can release activators and form set cement 202 located in region 204. The activation signal can be located in the region identified by 204, and in response to at least the localized signal, the set cement 202 is formed. In some implementations, an initial amount of cement grout 108 may be exposed to a activation signal such that the setting period can be substantially equal to a period of time for the setting cement slurry 108 to flow to location 204. In these examples, the cement grout 108 may be exposed to the activation signal
<img file="MX339042B_D0050.tif" />
IMPI as the slurry 108 including the devices 110 enters the pipe column 116. As the bottom edge of the cement slurry 108 begins to set, the flow of fluid through the ring 122 may become more restricted and may cease eventually. Therefore, the cement grout 108 can be substantially prevented from flowing onto surface 112 through ring 122. The remainder of the cement grout 108 may set in ring 122 behind the leading edge as illustrated in
Figure 2A or the cement grout 108 may set at a later time as illustrated in Figure 2B. In the latter case, the remaining cement grout 108 may be exposed to activation signals at a later time to initiate or accelerate the setting process.
Figure 3 illustrates an exemplary activating device 110 of Figure 1 in accordance with some implementations of the present disclosure. In these implementations, trigger device 110 releases one or more stored triggers in response to at least one wireless signal. The illustrated device 110 is for example purposes only, and the device 110 may include some, none, or all of the elements illustrated without departing from the scope of this disclosure.
ΙΜΡΙ
Mexican Institute of Industrial Property
As illustrated, activator device 110 includes a substrate 302 and a passivation layer 304 that is formed on substrate 302. Passivation layer 304 includes or is adjacent to an activator module 306 for releasing activators, a transducer 308 to receive wireless signals, logic 310 to control trigger module 306, and a power module 312 to supply power to device 110. Substrate 302 can provide a mechanical structure to support the elements of the device and / or a surface for routing electrical and / or fluidic signals. The substrate
302 It can be made of silicon, quartz, glass, organic (eg, kapton tape or other flexible material), FR-4, duraid, and / or other materials. In some implementations, passivation layer 304 may protect one or more modules from the surrounding cement slurry 108 and / or may provide direct access to cement slurry 108 to, for example, release activators.
Activator module 306 can release one or more activators to initiate or accelerate the setting of cement grout 108. In some implementations, activator module 306 may receive one or more logic signals
310 and executing a process to initiate a reaction with, for example, cement slurry 108. Activator module 306
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it can include a membrane or other element that contains the activators. In these examples, activator module 306 can move, remove, or otherwise open the element to release activators within cement grout 108.
Activator module 306 may include a heating element in the contained element containing a unitary chemical, a binary chemical with a rupture membrane, a unitary chemical with a rupture membrane, and / or other configurations that release the contained activators.
Transducer 308 can convert external stimuli into one or more transduction signals that are processed by logic 310. For example, transducer 308 can detect signals such as ultrasonic, pressure, magnetic, electrical, electromagnetic (eg, RF, infrared, rays
x), acoustic, optical, VCF, nuclear (eg, gamma, alpha, beta, neutron), and / or other signals.
Logic 310 can generate voltages to operate trigger module 306 using power module 312 and in response to at least the transducer signal. For example, logic 310 may dynamically switch between a go / no go state in response to at least the transducer signals. In some implementations, logic 310 may execute one or more of the following: receive power from the power module
IMPI
MEXICAN INSTITUTE OF THE PROPIF.VAL
INDUSTRIAL
312; receiving one or more transducer signals from transducer 308; generating one or more signals for trigger module 306 using the received energy; transmitting one or more signals to trigger module 306 to trigger the release of one or more triggers; and / or other processes. Logic 310 can be Complementary Metal-OxideSemiconductor (CMOS) semiconductor, Transistor-Transistor (TTL,
Transistor-Transistor Logic), bipolar, radio frequency (RF), and / or other type of device. Power module 312 provides power to device 110. For example, power module 312 may be a voltage generator that provides enough current to operate logic 310.
The power module 312 may be a thin and / or thick film battery, components of a battery, one or more capacitors, one or more induction pickup coils, and / or other elements that store energy.
Figures 4A-C illustrate exemplary implementations of trigger devices 110 that release one or more triggers. In these implementations, device 110 may comprise an acoustic activating MEMS for the controlled delivery of command additives in a cement grout.
Devices 110 can enable cement properties to be tailored once the cement grout
IMPI
MEXICAN INSTITUTE OF INDUSTRIAL PROPERTY has been pumped into the well (eg, delayed, accelerated in place). Devices 110 can release activators by moving one or more elements, by resistively heating one or more elements to form at least one opening, chemically etching one or more elements, and / or other processes. In some implementations, each device 110 may retransmit the trigger signals to other devices 110. The following implementations are for illustration purposes only, and devices 110 may release triggers using some, all, or none of these processes.
Referring to Figure 4A, the trigger device
110 mechanically moves element 402 to release triggers 404. In some implementations, the device
110 it may include a MEMS device containing triggers 404 when element 402 is in a first position. In response to at least one signal, the element
402 it can rotate about an axis to a second position that releases activators 404 in grout 108. In some implementations, the activation signal can directly move element 402. For example, the activation signal can structurally change the shape of the element 402 through, for example, an ultrasonic signal. In some implementations,
<img file="MX339042B_D0052.tif" />
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MEXICAN INSTITUTE
FROM PROPERTY I ·· V * or INDUSTRIAL device 110 can switch element 402 between the two positions at a specified frequency to assist or otherwise increase the dispersion rate of activators 404 within cement grout 108. Referring to Figure 4B, activator device 110 resistively heats element 402 to form an opening that releases activators 404. For example, element 402 may be a gold membrane that includes a tungsten filament that generates heat from an applied current. In these cases, the heat generated can melt or otherwise deform the membrane to form an opening that releases activators 404. In addition to the metal membranes, element 402 can be of other materials such as a polymer. With reference to Figure
4C, device 110 includes activators 404 and release chemicals 406 that remove at least a portion of element 402 to release activators. In the illustrated example, device 110 includes a first tank
412 containing 404 triggers and a second repository
414 containing the release chemicals 406 using a retainer 410. The first reservoir 412 and the second reservoir 414 may be configured to communicate fluidly through valve system 408.
In a first position, valve system 408 can
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INDUSTRIAL * ”substantially prevent the flow of release chemicals 406 into the first tank 412. In the second position, the release chemicals 406 can flow from the second tank 414 to the first tank 412 through valve system 408. In the illustrated implementation, release chemicals 406 react with element 402 to form an opening that releases activators 404 in cement slurry 108. For example, release chemicals 406 can etch or otherwise dissolve element 402.
Figures 5 and 6 are flow charts illustrating exemplary methods 500 and 600 for implementing and manufacturing devices that include one or more activators. The illustrated methods are described with respect to the well system.
100 from Figure 1, but these methods can be used by any other system. Furthermore, the well system 100 can use any other technique to carry out these tasks. Therefore, many of the steps in these flow charts can take place simultaneously and / or in different order than shown. Well system 100 may also use methods with additional steps, fewer steps, and / or different steps, as long as the methods are maintained as appropriate.
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Referring to Figure 5, method 500 begins at step 502 where trigger devices are selected based, at least in part, on one or more parameters. For example, activating devices 110 and contained activators may be based, at least in part, on components of cement grout 108. In some implementations, activating devices 110 can be selected based on conditions within the wellbore. (eg, temperature). In step 504, the selected activating devices are mixed with a cement slurry. In some examples, activation devices
110 they can be mixed with cement grout 108 while truck 130 pumps the grout into ring 122. In some examples, activating devices 110 can be mixed with dry cement before generating cement grout 108. Then, in step 506, the grout that includes the triggering devices is pumped into the well. In some cases, the cement slurry 108 including the activating devices 110 can be pumped into the ring 122 at a specified rate. In step 508 one or more trigger signals are transmitted to at least a portion of the cement grout within the well. Again in the example, the transmitter can be lowered into the
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coating to transmit signals in a portion of the cement slurry 108. In this example, the transmitted signals can activate the devices 110 next to the pad 132 to set that portion of the cement slurry 108 as illustrated in Figure 2B. In some cases, pipe column 116 can be moved (eg, up / down) to aid in the distribution of triggers as desired.
Referring to Figure 6, method 600 begins at step 602 where a substrate with a passivation layer is identified. For example, substrate 302 including passivation layer 304 of Figure 3 can be identified. In steps 604 and 606, the power, transducer, and logic modules and at least a portion of the trigger module are manufactured. . A reservoir is also manufactured in the activation module. In the example, transducer modules 308, logic 310, power 312, and at least a portion of the trigger module 306 are manufactured. In this example, a reservoir to hold at least a portion of the triggers such as those deposits illustrated in the
Figures 4A-C. In step 608, the triggers are deposited into the reservoir. As for example, activators 404 can be deposited in the reservoirs illustrated in Figures 4AC. Then, in step 610, a membrane is manufactured over the
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Again in the example, element 402 can be manufactured to contain activators 404 in the reservoir.
FIG. 7 illustrates an exemplary well system 100 in relation to transmitting trigger signals to cement grout 122. For example, system 100 can wirelessly transmit electromagnetic signals to cement grout 108 including a request to release triggers in cement grout 108. In the illustrated example, system 100 includes an interior means 702 and a signal source 706 connected to interior medium 702 and to pipeline column 116 through connections 708a and
708b, respectively. Connections 708a and 708b can be ohmic, capacitively coupled, and / or other contacts. In some implementations, pipe column 116 may be a hot path for signals. For example, pipe column 116 can be a continuous metal path or a metal path with a finite number of discontinuities. In the latter, each slice can result in modest step attenuation. Also, the inner environment
702 it may be at least partially contained in one or more layers or the inner tube 704.
In some implementations, system 100 may enable signal transduction downward along the
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Leaky Feeder Principies). In these cases, system 100 can transduce a signal using one or more of the following: pipe column 116; the surface casing pipe 124; and / or one or more inner tubes 704. The surface pipe column 116 may be 100 m or more in length. Inner tube 704 can be 100m or less in length. The inner environment
702 it can be metal, air, and / or a liquid. In some implementations, pipe column 116 and / or surface inner tube 704 can be used as an additional hot path that is out of phase with the casing signal and / or a different signaling waveform . Signal source 706 can be any hardware, software, and / or firmware that generates an electrical signal. A connection between signal source 706 and pipe column 116 can include return paths through one or more of the following: cement grout 108; the surface casing pipe 120; non-production zone 104; the inner environment
702; tube layers 704; and / or others. The cement grout
108 It can be very basic (eg pH 13) and a loss medium that attenuates the return signal. Signal source 706 can produce voltages that vary in time to propagate
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down through ducts such as the pipe column
116. Signal source 706 can propagate one or more of the following frequencies: Ultra Low Frequency (ULF, Ultra Low
Frequency) such as 0.1 Hz to 10 Hz; very low frequency (VLF,
Very Low Frequency) such as 10 Hz to 30 kHz; low frequency (LF) such as 30 kHz to 30 MHz; high frequency (HF) such as 3 MHz to 30 MHz; Very High Frequency (VHF) such as 30 MHz to 300 MHz;
and / or Ultra High Frequency (UHF) such as greater than 300 MHz. In some implementations, signal source 706 may produce 12-bit modulated signal reception (OOK) code with a baud rate of 4800 and f<sub>EC</sub>r.tro <sup>=</sup> 13.5 MHz. In these implementations, signal source 706 can bring pipe column 116 and bring surface coating pipe 120 180 ° out of phase. Also, inner tube 704 may not be worn and connections 706 may be capacitively coupled.
Figures 8A and 8B illustrate an exemplary power module 312 of Figure 3 according to some implementations of the present disclosure. In the illustrated implementation, the power module 312 can use an alkaline or acidic environment generated by, for example, cement grout 108. In these cases, the module
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312 can generate a voltage difference using cement slurry 108 and independent of energy storage using, for example, a battery or a capacitor. In some implementations, the 312 power module can be manufactured using thin and / or thick film photolithography techniques to create sub-millimeter (sub-mm) scale batteries. Example power module 312 is for illustration purposes only, and module 312 may include some, all, or none of the elements illustrated without departing from the scope of this disclosure.
The illustrated power module 312 includes a first metallic element 802 and a second metallic element
804 forming the terminals of the power module 312. In this case, the first metallic element 802 and the second metallic element 804 react with the cement slurry
108 surrounding to generate a different voltage between the two terminals. The first metallic element 802 and the second metallic element 804 are at least partially contained by passivation layer 304 and substrate 302. As discussed above, substrate 302 can comprise silicon, glass, sapphire, organic flexible material, and / or other materials. Passivation layer 304 includes a first opening 806a that exposes at least one surface or
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portion of the first metal element 802 and a second opening 806b exposing at least one surface or portion of the second metal element 804. By exposing the first metal element 802 and the second metal element 804, a voltage difference is generated between these terminals.
Furthermore, this voltage difference supplies power to load 808 such as logic 310. Terminals are connected to load 808 via leads 810a and
810b. Apertures 806a and 806b can be formed, for example, by photolithography or a thick film printing process. In some implementations, the substrate 302 may be silica and approximately 1mm by 1mm by 100 pm, and the cement slurry 108 may be in a pre-cured wet state. In these implementations, the first metallic element 802 can be a metal such as zinc, and the second metallic element 804 can be a metallic salt such as manganese dioxide. Elements 802 and 804 can be deposited using thick film projection printing and can each be from about 150 pm by 150 pm by 50 pm. Again in these implementations, openings 806a and 806b can be 100 pm by 100 pm, and layer 304 can be photosensitive BCB. The 810a and 810b leads or connections can be thin-film mentalizations.
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Referring to Figures 9-11, methods for detecting and / or monitoring the position and / or condition of well compositions are illustrated, such as, for example, sealant conditions (eg, cement) using data sensors. 110 based on MEMS, previously discussed regarding the
Figure 1. Even more particularly, the present disclosure describes methods for monitoring the integrity and performance of well compositions throughout the life of the well using MEMS-based data sensors. Performance can be indicated by changes, for example, in various parameters, including, but not limited to, moisture content, temperature, pH, and various concentrations of ions (eg, sodium, chlorine, and potassium ions) of cement. In implementations, the methods comprise the use of integrable data sensors 110 capable of detecting parameters in a well composition 108, for example a sealant such as cement. In some implementations, the methods provide evaluation of sealant 108 during mixing, placement, and / or curing of sealant 108 within well 106. In some implementations, the method can be used to evaluate the sealant from placement and cure throughout its useful service life, and where applicable for a period of deterioration and repair. In implementations, the methods of this disclosure can be
INDUSTRIAL PROPERTY use to prolong the service life of the sealant, decrease costs, and / or improve the creation of improved correction methods. Additionally, the methods can be used to determine the location of sealant 108 within a well 106, such as to determine the location of a cement slurry 108 during the primary cementing of a well 106 as discussed in greater detail below.
The methods disclosed in this document comprise the use of various well compositions 108, including sealants and other well service fluids. As used herein, well composition includes any composition that can be prepared or otherwise provided on the surface and placed down the well
106, typically by pumping. As used herein, a sealant refers to a fluid that is used to secure components within a well or to plug or seal an empty space within well 106. Sealants 108, and in particular cement grouts and non-cement compositions, are used as well compositions in various implementations described herein, and it should be understood that the methods described herein are Applicable for use with other well compositions. As used in this document, service fluid refers to a
<img file="MX339042B_D0059.tif" />
Fluid IMPL that is used to drill, complete, work on, fracture, repair, treat, or in any way prepare or service a well 106 for the recovery of materials residing in an underground formation 102 that is penetrated by the well 106. Examples of service fluids include, but are not limited to, cement slurries, non-cement sealants, drilling fluids or muds, spacer fluids, fracturing fluids, or completion fluids, all of which are well known in the art. The matter. The service fluid is for use in a well 106 that penetrates an underground formation 102. It should be understood that the underground formation encompasses both areas below exposed land and areas below land covered by water such as the ocean or fresh water. Well 106 may be a substantially vertical well and / or may contain one or more side wells, for example as produced by directional drilling. As used herein, components are referred to as being integrated if they are formed into a common support structure placed in relatively small packages, or otherwise assembled in close proximity to each other.
Referring to Figure 9, method 900 is an exemplary method of placing MEMS sensors in a well and collecting
<img file="MX339042B_D0060.tif" />
data. At block 902, data sensors are selected based on the parameter (s) or other conditions to be determined or detected within the well. At block 904, a number of data sensors are mixed with a composition of the well, for example a grout of sealant. In some implementations, the data sensors are added to a sealant by any method known to those of skill in the art. For example, sensors can be mixed with a dry material, mixed with one or more liquid components (eg, water or a non-aqueous fluid), or combinations thereof. Mixing can take place on-site, for example adding the sensors to a bulk mixer such as a cement grout mixer. The sensors can be added directly to the mixer, can be added to one or more component streams, and then added to the mixer, can be added downstream of the mixer, or combinations thereof. In some implementations, data sensors can be added after a mixing unit and slurry pump, for example, through a side bypass pass. The sensors can be measured and mixed at the well site, or they can be pre-mixed into the composition (or one or more components thereof) and then transported to the well site.
For example, sensors can be dry mixed with
<img file="MX339042B_D0061.tif" />
IMPI
Ό Ό MEXICAN INSTITUTE
FROM PROPERTY! ND «ISTRIAL dry cement and transport to the well site where a cement grout comprising the sensors is formed.
Alternatively or additionally, the sensors can be pre-mixed with one or more liquid components (eg, mixing water) and transported to the well site where a cement slurry comprising the sensors is formed. The properties of the well composition or the components thereof may be such that the sensors distributed or scattered therein do not settle substantially during transport or placement.
The sealant slurry is then pumped into the well at block 906, whereby the sensors are positioned within the well. For example, sensors can be extended along all or a portion of the length of the well adjacent to the casing. The sealant grout can be placed within the well as part of a primary cementation, secondary cementation, or other sealant operation as described in greater detail herein. At block 908, its position to a data interrogation tool at an operable location to collect data from the sensors, for example, is lowered into the well near the sensors. At block 910, the data interrogating tool interrogates the data sensors (eg, sending an RF signal) while the
<img file="MX339042B_D0062.tif" />
ΙΜΡΪ data interrogation tool goes through an entire portion of the well containing the sensors. The data sensors are activated to record and / or transmit data at block 912 by the signal from the data interrogating tool.
At block 914, the data interrogating tool communicates the data to one or more computer components (eg, memory and / or microprocessor) that may be located within the tool, on the surface, or both.
Data can be used locally or remotely from the tool to calculate the location of each data sensor and correlate the measured parameter (s) with those locations to assess the performance of the sealant.
Referring again to Figure 1, during cementing, or subsequent setting of the cement, the data interrogation tool may be positioned in well 106, as in block 908 of Figure 9. For example, the pipe cleaner may be equipped with a data interrogator tool and can read data from
MEMS while pumping into the well and transmitting them to the surface. Alternatively or in combination, an interrogating tool can be brought into the well after the cementation of a casing pipe segment is complete, for example as part of the drill string during drilling operations.
MEXICAN INSTITUTE
PROPERTY OwjM-rSst-fc ^ INDUSTRIAL drilling resumed. Alternatively or in combination, the interrogating tool can be brought into the well by wire line or other transportation. The data interrogating tool can then be signaled to interrogate the sensors (block 910 in Figure 9) whereby the sensors are activated to record and / or transmit the data, block 912 in Figure 9. The data interrogation tool communicates the data to a 914 processor whereby the position of the data sensor (and likewise the cement grout) and the integrity of the cement can be determined by analyzing the detected parameters for changes, trends , expected values, etc. For example, such data may reveal conditions that may be adverse to cement cure. The sensors can provide a temperature profile over the length of the cement liner, with a uniform temperature profile indicating likewise a uniform cure (eg, produced by heat from hydration of the cement during curing) or an area Cooler may indicate the presence of water that can degrade cement during the transition from grout to set cement.
Alternatively or in combination, such data may indicate a zone of reduced, minimal, or missing sensors, indicating a loss of cement corresponding to the area
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(eg, a waste / empty or flow / wash zone). Such methods may be available with various cement techniques described in this document such as conventional or reverse primary cementation.
Due to the high pressure at which the cement is pumped during conventional primary cementation (it is pumped down through the casing and up through the ring), the cement slurry fluid can leak into existing areas of low pressure that are crossed by the well. This can adversely affect the cement, and incur unwanted costs for corrective cementing operations (eg, pressure cementing as discussed below) to position the cement in the ring. Such leakage can be detected by the present disclosure as described above. Additionally, conventional circulation cementing can be very time consuming, and therefore relatively expensive, because the cement is pumped all the way down the pipe column 116 and back up the ring 122.
One method of avoiding the problems associated with conventional primary cementation is to employ reverse circulation primary cementation. Reverse circulation cementing is a term in the matter that is
<img file="MX339042B_D0064.tif" />
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used to describe a method where a cement grout is pumped down the liner ring
122 instead of into the pipe column
116. The cement slurry displaces any fluid as it is pumped down the ring 122. The fluid in the ring is forced down the ring 122, into the pipe column 116 (along with any fluid in the casing pipe. ), and then up to the surface of the earth 112. When reverse circulation cementation is performed, the casing shoe 132 comprises a valve that is adjusted to allow flow into the pipe column
116 and then sealed after the cementing operation is complete. Once the grout is pumped to the bottom of pipe column 116 and fills the ring
122, the pumping is terminated and the cement is allowed to set in ring 122. Examples of applications of reverse cementation are disclosed in the US Patent documents.
United States Nos. 6,920,929 and 6,244,342, each of which is incorporated by reference throughout this document.
In some implementations of the present disclosure, seUador grouts are believed to comprise data sensors from
MEMS are pumped in down the ring in applications
<img file="MX339042B_D0066.tif" />
IMPIC ηκτπυτυ reverse circulation Mexican, a data interrogator is located within the well (eg, integrated within the casing shoe) and the performance of the sealant is monitored as described with respect to the conventional primary sealing method that is previously disclosed. Additionally, the data sensors of the present disclosure can also be used to determine the completion of a reverse circulation operation, as discussed in greater detail below.
Secondary cementation within a well can be carried out after primary cementation operations. A common example of secondary cementation is pressure cementation where the sealant such as a cement composition is forced under pressure into one or more permeable zones within the well to seal such zones. Examples of such permeable zones include fissures, cracks, fractures, veins, flow channels, voids, high permeability veins, annular voids, or combinations thereof. Permeable zones may be present in the cement column residing in the ring, a conduit wall in the well, a micro ring between the cement column and the underground formation, and / or a micro ring between the cement column and the duct. The sealant (eg, secondary cement composition) sets
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within the permeable zones, thereby forming a hard mass to cover those zones and prevent fluid from passing through, that is, substantially prevent fluid communication between the well and formation through the permeable zone. Various procedures that can be followed to use a sealant composition in a well are described in US Patent No.
5,346,012, which is incorporated by reference herein in its entirety. In various implementations, a sealant composition comprising MEMS sensors is used to prepare holes, channels, voids, and micro rings in the casing, cement liner, etch packages, and the like as described in the Patent documents. of the United States Nos.
5,121,795; 5,123,487; and 5,127,473, each of which is incorporated by reference herein in its entirety.
In some implementations, the method of the present disclosure can be employed in a secondary cementing operation. In these implementations, the data sensors are mixed with a sealant composition (eg, a secondary grout) in block 904 of the Figure and after or during cement placement and hardening, the sensors are interrogated to monitor the performance of secondary cement in a manner analogous to
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incorporation and monitoring of data sensors in the primary cementation methods previously disclosed. For example, MEMS sensors can be used to verify that the secondary sealant is working properly and / or to monitor its integrity over the long term.
In implementations, the methods of the present disclosure are used to monitor cement sealants (eg, hydraulic cement), non-cement sealants (eg, polymer, latex, or resin systems), or combinations thereof, which can be used in primary, secondary, or other applications. For example, expandable tubulars such as tube, tube column, casing, liner, or the like are often sealed in an underground formation. The expandable tubular (eg, casing) is placed in the well, a sealing composition is placed inside the well, the expandable tubular is expanded, and the sealing composition is allowed to set in the well. For example, after the expandable casing is placed into the well, a mandrel can be driven through the casing to expand the casing diametrically, with possible expansions of up to 25%. The expandable tubular can be placed in the well before or
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after placing the sealing composition in the well. The expandable tubular can be expanded before, during, or after the setting of the sealing composition. When the tubular expands during or after the setting of the sealing composition, the resistant compositions will remain fit due to their elasticity and compressibility.
Additional tubulars can be used to extend the well into the underground formation below the first tubular as known to those of skill in the art. Sealant compositions and methods of using the expandable tubular compositions are disclosed in US Patent documents.
Nos. 6,722,433 and 7,040,404 and the Publication document of
United States Patent No. 2004/0167248, each of which is incorporated by reference herein in its entirety. In expandable tubular implementations, the sealants may comprise compressible hydraulic cement compositions and / or non-cement compositions.
Compressible hydraulic cement compositions have been developed that remain fit (continue to support and seal the tube) when compressed, and such compositions may comprise MEMS sensors. The sealant composition is placed in the ring between the well and the tube or column
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of pipe, the sealant is allowed to harden into an impermeable mass, and thereafter, the expandable pipe or column of pipe expands thereby compressing the hardened sealant composition. In implementations, the compressible foam sealant composition comprises a hydraulic cement, a rubber latex, a rubber latex stabilizer, a gas, and a mixture of foaming and foam stabilizing surfactants. Suitable hydraulic cements include, but are not limited to, cement.
Portland and calcium aluminate cement. In some implementations, the settable composition may include a polymeric additive. The polymer additive can be a monomer, a pre-polymer, an oligomer, or a short-chain polymer that polymerizes in response to the sonic signal. In these examples, activators can include a free radical dopant that releases autocatalytic free radicals in response to the sonic signal such that the released autocatalytic free radicals initiate polymerization of at least a portion of the settable composition.
Often strong, non-cement sealants with comparable strength to cement, but with greater elasticity and compressibility, are required to cement expandable casing. In some
<img file="MX339042B_D0071.tif" />
IMPI implementations, these sealants comprise polymeric sealing compositions, and such compositions may comprise MEMS sensors. In some implementations, the sealant composition comprises a polymer and a metal-containing compound. In some implementations, the polymer comprises copolymers, terpolymers, and interpolymers. Metal-containing compounds can comprise zinc, tin, iron, selenium, magnesium, chromium, or cadmium. The compounds may be in the form of an oxide, carboxylic acid salt, a complex with a dithiocarbamate binder, or a complex with a mercaptobenzothiazole binder. In some implementations, the sealant comprises a mixture of latex, dithiocarbamate, zinc oxide, and sulfur.
In some implementations, the methods of the present disclosure include adding data sensors to a sealant to be used behind the expandable casing to monitor the integrity of the sealant with the expansion of the casing and for the service life of the sealant . In this implementation, the sensors may comprise MEMS sensors capable of measuring, for example, humidity and / or temperature change. If the sealant develops cracks, the inflow of water can then be detected by indicating humidity and / or temperature.
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MEXICAN INSTITUTE OF INDUSTRIAL PROPERTY
In one implementation, MEMS sensors are added to one or more well service compositions that are used or placed within the well in the drilling or completion of a single diameter well as disclosed in US Patent Document No. 7,066,284 and United States Patent Publication Document number
2005/0241855, each of which is incorporated by reference throughout this document. In one implementation, MEMS sensors are included in a chemical coating composition that is used in a single diameter well. In another implementation, MEMS sensors are included in compositions (eg, sealants) that are used to place casing or expandable tubing in a single diameter well. Examples of chemical coatings are disclosed in the documents of
United States Patent Nos. 6,702,044; 6,823,940; and
6,848,519, each of which is incorporated herein by reference in its entirety.
In some implementations, MEMS sensors are used to collect sealant data and to monitor the long-term integrity of the sealant composition placed in the well, for example, a well for the recovery of natural resources such as water or hydrocarbons or an injection well for treatment or
<img file="MX339042B_D0072.tif" />
IMPI storage. In one implementation, the data / information collected and / or derived from the MEMS sensors in a sealant within the well comprises at least a portion of the input and / or output to one or more calculators, stimulations, or models used to predict, select, and / or monitor the performance of well sealant compositions throughout the life of a well. Such models and stimulators can be used to select a sealant composition comprising MEMS for use in a well. After placement in the well, the sensors
MEMS can provide data that can be used to refine, recalibrate, or correct models and simulators.
In addition, MEMS sensors can be used to monitor and record the conditions within the well to which the sealant is subjected, and the performance of the sealant can be correlated to such long-term data to provide an indication of problems or the potential for problems in the same well or different wells. In several implementations, the data collected from the sensors of
MEMS are used to select a sealant composition or otherwise evaluate or monitor such sealants, as disclosed in United States Patent documents.
Nos. 6,697,738; 6,922,637; and 7,133,778, each of which is incorporated by reference herein in its entirety.
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Referring to Figure 11, a method 1100 for selecting a sealant (eg, luting composition) to seal an underground zone penetrated by a well in accordance with the present implementation basically comprises determining a group of effective compositions from a group of compositions given the estimated conditions experienced during the life of the well, and estimate the risk parameters for each of the effective compositions of the group. In an alternative implementation, the actual measured conditions experienced over the life of the well can be used in addition to or instead of the estimated conditions.
Such actual measured conditions can be obtained for example by sealant compositions comprising MEMS sensors as described herein. Effectiveness considerations include concerns that the sealant composition is stable under conditions within the pressure and temperature well, resists chemicals within the well, and possesses the mechanical properties to withstand the stresses of various operations within the well to provide insulation. zonal for the life of the well.
In step 1102, the well input data for a particular well is determined. Well input data includes medial or calculable parameters
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OU OF PROPERTY SsLJS /
INDUSTRIAL routinely inherent in a well, including vertical well depth, overburden gradient, pore pressure, maximum and minimum horizontal stresses, hole size, casing pipe OD, casing ID, density of drilling fluid, desired density of pump grout sealant, density of completion fluid, and top of sealant.
As will be discussed in greater detail with reference to step
1104, the well can be modeled by computer. In modeling, the stress state in the well at the end of drilling, and before the sealant slurry is pumped into the annulus, affects the stress state for the interface boundary between the rock and the sealant composition. Therefore, the stress state in the rock is evaluated with the drilling fluid, and rock properties such as Young's modulus, Poisson's ratio, and yield parameters are used to analyze the stress state. of the rock. These terms and their determination methods are well known to those skilled in the art. It is understood that the well input data will vary between individual wells. In an alternative implementation, the well input data includes data that is obtained through the compositions
IMPI
INSTITUTO MEXICANO, -1 IflMIlU IV ΜΕΑΚ, ΛΠυ C-¿TiSfc.-W · '1 OE PROPERTY' C'iw ^ -J & LgÍxí of sealant comprising MEMS sensors as described in this document.
In step 1104, the well events applicable to the well are determined. For example, cement hydration (setting) is a well event. Other well events include pressure assessment, well completions, hydraulic fracturing, hydrocarbon production, fluid injection, drilling, subsequent drilling, formation movement as a result of hydrocarbon production at high rates from the unconsolidated formation, and the tectonic motion after the sealant composition has been pumped into place. Well events include those events that are certain to occur during the life of the well, such as cement hydration, and those events that are predicted to occur easily during the life of the well, given a particular well location, type of rock, and other factors well known in the art. In one implementation, the well events and the data associated therewith can be obtained by the sealant compositions comprising MEMS sensors as described herein.
Each event in the well is associated with a certain type of stress, for example, the hydration of cement is
<img file="MX339042B_D0074.tif" />
associated with contraction, pressure assessment is associated with pressure, well terminations, hydraulic fracturing, and hydrocarbon production are associated with pressure and temperature, fluid injection is associated with temperature, movement of the formation is associated with the load, and drilling and subsequent drilling are associated with the dynamic load.
As can be seen, each type of stress can be characterized by an equation for the stress state (collectively well event stress states), as described in greater detail in the
United States Patent No. 7,133,778 which is incorporated by reference herein in its entirety.
In step 1106, the well input data, the well event stress states, and the sealant data are used to determine the effect of well events on the integrity of the sealant liner over the life of the well to each of the sealant compositions. The sealant compositions that would be effective to seal the underground zone and its capacity are determined from its elastic limit. In an alternative implementation, the estimated effects on well life are compared to and / or corrected compared to the corresponding actual data collected on the
IMPI
<img file="MX339042B_D0075.tif" />
INDUSTRIAL well life using sealant compositions comprising MEMS sensors as described in this document. Step 1106 concludes by determining which sealant composition would be effective in maintaining the integrity of the resulting cement liner for the life of the well.
In step 1108, the sealant failure risk parameters are determined for the effective sealant compositions. For example, even when one sealant composition is considered effective, one sealant composition may be more effective than another. In one implementation, the risk parameters are calculated as percentages of the sealant capacity during the determination of effectiveness in step 1106. In an alternative implementation, the risk parameters are compared to and / or corrected compared to the actual data collected on the life of the well through the sealant compositions comprising MEMS sensors as described herein.
Step 1108 provides data that enables a user to perform a cost benefit analysis. Due to the high cost of corrective operations, it is important that an effective sealant composition is selected for the conditions that are anticipated to be experienced during the
<img file="MX339042B_D0076.tif" />
well life. Each of the sealant compositions is understood to have a monetary cost that can be easily calculated. Under certain conditions, various sealant compositions can be equally effective, yet one can have the added virtue of being more economical. Therefore, it should be used to minimize costs. More commonly, a sealant composition will be more effective, but also more expensive. Accordingly, in step 1110, an effective sealant composition with acceptable risk parameters is selected given the desired cost. Furthermore, the general results of steps 1102-1110 can be compared to the actual data obtained through the sealant compositions comprising MEMS sensors as described herein, and such data can be used to modify and / or or correct the inputs and / or outputs for the various steps 1102-1110 to improve their precision.
As discussed above and with reference to the
Figure 1, pipe cleaners are often used during conventional primary cementing to force the cement grout out of the casing. The pipe cleaner plug also serves another purpose: Typically, the end of a cementing operation is signaled when the pipe cleaner plug contacts a restriction
<img file="MX339042B_D0077.tif" />
IMPI (eg casing shoe) inside the pipe column
116 at the bottom of the column. When the plug contacts the restriction, a sudden increase in pressure is recorded in pump 130. In this way, it can be determined when the cement has moved from the pipe column.
116 and the flow of fluid returning to the surface through the liner ring 122 is stopped.
In reverse circulation cementing, it may also be necessary to correctly determine when the cement grout completely fills ring 122. Continue pumping the cement into ring 122 after the cement has reached the far end of ring 122 forces the cement into from the farthest end of pipe column 116, which can be time consuming if the cement has to be drilled to continue drilling operations.
The methods disclosed in this document can be used to determine when the cement grout has been properly positioned within the well. Furthermore, as discussed further below, the methods of the present disclosure may further comprise using a MEMS sensor to actuate a valve or other mechanical means to close and prevent cement from entering the casing with determination of the termination of an operation of
<img file="MX339042B_D0078.tif" />
cementation.
The way in which the method of the present disclosure can be used to signal when cement is properly positioned within ring 122 will now be described within the context of a reverse circulation cementing operation. Figure 10 is a flow chart of a method for determining the completion of a cementing operation and optionally also driving a tool within the well with the completion (or to initiate the
Ί0 completion) of the cementing operation. This description will refer to the flow diagram in Figure 10, as well as the representation of the well in Figure 1.
At block 1002, a data interrogator tool such as the one described above is positioned at the far end of pipe column 116. In one implementation, the data interrogator tool is incorporated with or adjacent to a positioned casing shoe. at the bottom end of the casing and in communication with operators on the surface. At block 1004, MEMS sensors are added to a fluid (eg, grout, spacer fluid,
<td>fluid</td><td colspan="2">scroll etc.)</td><td colspan="2">which will be pumped</td><td>inside</td><td>of the</td>
<td>ring</td><td>122. In the</td><td>block 1006</td><td>grout</td><td>of</td><td>cement</td><td>I know</td>
<td>pumps</td><td>to him</td><td>inside</td><td>From the ring</td><td> 122 .</td><td>In</td><td>a</td>
<img file="MX339042B_D0079.tif" />
Implementation, MEMS sensors can be placed substantially across the entire grout that is pumped into the well. In some implementations, the sensors
MEMS can be placed on a starter cap or another place on an initial portion of the cement to indicate a starting edge of the cement grout. In one implementation, MEMS sensors are placed on start and end plugs to signal the beginning and end of the cement grout. While the cement is continuously pumped into ring 122, in decision 1008, the Data Interrogator (DIT)
Tool) tries to detect if the data sensors are communicatively close with the data interrogation tool. As long as no data sensors are detected, additional cement is pumped into the ring. When the data interrogator tool detects the sensors at block 1010 indicating that the leading edge of the cement has reached the bottom of the casing, the interrogator sends a signal to end pumping. The cement in the ring is allowed to set and form a substantially impermeable mass that physically supports and positions the casing in the well and joins the casing with the walls of the well in block 1020.
<img file="MX339042B_D0080.tif" />
·. , Tur 'Tur) MEXICAN Ul. LA mOHEDAD
INDUSTRIAL
<img file="MX339042B_D0081.tif" />
If the block 1004 fluid is the cement slurry, MEMS-based data sensors are incorporated into the set cement, and the parameters of the cement (eg, temperature, pressure, ion concentration, stress, etc.) can be monitored. deformation, etc.) during the laying and during the service life of the cement according to the methods previously disclosed. Alternatively or in combination, the data sensors can be added to an interface fluid (eg, spacing fluid or other fluid plug) that is introduced to the ring before and / or after the introduction of the cement slurry in the ring.
The method just described for determining the completion of a primary well cementing operation may further comprise activating a tool within the well. For example, at block 1002, a valve or other tool may be operatively associated with a data interrogation tool at the far end of the liner column. This valve may be contained within the float shoe
132, for example, as previously disclosed. Again, float shoe 132 may contain an integral data interrogation tool, or it may otherwise be coupled to a data interrogation tool. For example, the data interrogation tool may be
IMPI
<img file="MX339042B_D0082.tif" />
positioned between the pipe column 116 and the float shoe 132. Following the method described above and blocks 1004 to 1008, the pumping continues while the data interrogator tool detects the presence or absence of data sensors close to the interrogator tool (depending of the specific cementing method being used, eg reverse circulation, and the positioning of the sensors within the cement flow). Upon detection of a deterministic presence or absence of nearby sensors indicating the completion of the cement grout, the data interrogating tool sends a signal to operate the tool (eg, valve) in block 1012. In block
1014, the valve closes, sealing the casing and preventing cement from entering the portion of the pipe column above the valve in a reverse cementing operation. In block 1016, closing the valve at 1016 causes an increase in back pressure that is detected in hydraulic pump 130. In block 1018, pumping is discontinuous, and the cement is allowed to set in the ring in the block 1020. In implementations where data sensors have been incorporated throughout the cement, the parameters of the cement (and thus the
IMPI
<img file="MX339042B_D0083.tif" />
cement integrity) during the laying and during the service life of the cement according to the methods previously disclosed.
The improved methods for monitoring the condition of the wellhead sealant from placement and throughout the service life of the sealant as disclosed in this document provide a number of advantages. Such methods are capable of detecting changes in parameters in the well sealant such as moisture content, temperature, pH, and ion concentration (eg, chloride, sodium, and potassium ions). Such methods provide these data to monitor the condition of the sealant from the initial period of quality control during mixing and / or placement, through the service life of the sealant, and through its period of deterioration and / or repair. Such methods are cost-effective and allow real-time data determination using sensors capable of operating without the need for a direct power source (i.e. passive rather than active sensors), such that the size of the sensor can be minimal. to maintain the strength of the sealant and the pumping capacity of the sealant grout. The use of MEMS sensors to determine the characteristics or parameters of the well can also be used in the pricing methods of a service treatment of the well.
<img file="MX339042B_D0084.tif" />
IMPI well, select a treatment for the well's service operation, and / or monitor a well's service treatment during its real-time performance, for example, as described in the Publication of
United States Patent No. 2006/0047527 Al, which is incorporated by reference herein in its entirety.
While preferred implementations of the methods have been shown and described, modifications may be made thereto by someone skilled in the art without departing from the teachings of the present disclosure. The implementations described in this document are exemplary only, and are not intended to be limiting. Many variations and modifications of the methods disclosed in this document are possible and are within the scope of this disclosure. When numerical ranges or limitations are explicitly stated, such explicit ranges or limitations should be understood to include iterative ranges or limitations of equal magnitude that fall within explicitly established ranges or limitations (eg, from about 1 to about 10 includes, 2, 3, 4, etc .; greater than 0.10 includes 0.11, 0.12,
0.13, etc.). The use of the term optionally with respect to any element of a claim is intended to mean that the element is required, or alternatively,
<img file="MX339042B_D0085.tif" />
IMPI
INSTTTUTL) MEXICAN INDUSTRIAL PROPERTY is not required. Both alternatives are intended to be within the scope of the claim. It should be understood that the use of broader terms such as understand, include, have, etc. provides support for specific terms such as consisting of, consisting essentially of, comprising substantially of, and so on.
Accordingly, the scope of protection is not limited by the description set forth above but is only limited by the claims that follow, the scope that includes all equivalents of the subject matter of the claims. Each and every claim is incorporated into the specification as an implementation of the present disclosure. Therefore, the claims are a further description and addition to preferred implementations of the disclosure. Discussion of a reference in this is not an admission that it is current art for disclosure, especially any reference that may have a publication date after the priority date of this application. The regulations of all patents, patent applications, and publications cited in this document are incorporated herein by reference, to the extent that they provide exemplary, procedural, or other supplemental details for this present document.
<img file="MX339042B_D0086.tif" />
IMPI
MEXICAN INSTITUTE OF INDUSTRIAL PROPERTY those established in this document.
A number of implementations of the invention have been described. However, it will be understood that various modifications can be made without departing from the scope of the invention. Accordingly, other implementations are within the scope of the following claims.
<img file="MX339042B_D0087.tif" />
IA4 ΡI
MEXICAN INSTITUTE AND EU THE INIl'JSI KIAL PROPERTY
NOVELTY OF THE INVENTION
Having described the present invention as above, it is considered as a novelty and, therefore, the content of the following is claimed as property:
Contents68
98 sheets
Sheet 1 Sheet 2 Sheet 3 Sheet 4 Sheet 5 Sheet 6 Sheet 7 Sheet 8 Sheet 9 Sheet 10 Sheet 11 Sheet 12 Sheet 13 Sheet 14 Sheet 15 Sheet 16 Sheet 17 Sheet 18 Sheet 19 Sheet 20 Sheet 21 Sheet 22 Sheet 23 Sheet 24 Sheet 25 Sheet 26 Sheet 27 Sheet 28 Sheet 29 Sheet 30 Sheet 31 Sheet 32 Sheet 33 Sheet 34 Sheet 35 Sheet 36 Sheet 37 Sheet 38 Sheet 39 Sheet 40 Sheet 41 Sheet 42 Sheet 43 Sheet 44 Sheet 45 Sheet 46 Sheet 47 Sheet 48 Sheet 49 Sheet 50 Sheet 51 Sheet 52 Sheet 53 Sheet 54 Sheet 55 Sheet 56 Sheet 57 Sheet 58 Sheet 59 Sheet 60 Sheet 61 Sheet 62 Sheet 63 Sheet 64 Sheet 65 Sheet 66 Sheet 67 Sheet 68 Sheet 69 Sheet 70 Sheet 71 Sheet 72 Sheet 73 Sheet 74 Sheet 75 Sheet 76 Sheet 77 Sheet 78 Sheet 79 Sheet 80 Sheet 81 Sheet 82 Sheet 83 Sheet 84 Sheet 85 Sheet 86 Sheet 87 Sheet 88 Sheet 89 Sheet 90 Sheet 91 Sheet 92 Sheet 93 Sheet 94 Sheet 95 Sheet 96 Sheet 97 Sheet 98
184 members in 10 offices
Priority claims9
| Document | Office | Kind | Date |
|---|---|---|---|
| 12547233 | United States of America | – | |
| 54723309 | United States of America | A | |
| 54723309 | United States of America | A | |
| 2010001590 | United Kingdom | W | |
| 2010001590 | United Kingdom | W | |
| 12547233 | – | – | – |
| GB1001590 | – | – | – |
| US20090547233 | – | – | – |
| WO2010GB01590 | – | – | – |
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1 legal event, as the office reported them to INPADOC
Events
| Event | Code | |
|---|---|---|
| Grant or registrationFG | FG |
Numbers
- Publication
- 339042
- Publication, DOCDB
- 339042
- Publication, EPODOC
- MX339042
- Application
- 2012002397
- Application, DOCDB
- 2012002397
- Application, EPODOC
- MX20120002397
Titles2
- Spanish
- METODOS DE COMPOSICIONES DE ACTIVACION EN ZONAS SUBTERRANEAS.
- English
- METHODS OF ACTIVATING COMPOSITIONS IN SUBTERRANEAN ZONES.
Classification
- CPC, 13
- E21B23/00
- E21B33/13
- C04B28/02
- E21B33/14
- E21B27/02
- C04B28/06
- C04B40/0633
- C04B40/0641
- C09K8/426
- C09K8/428
- E21B47/005
- E21B47/13
- Y02W30/91
- IPC, 2
- E21B33 14
- C04B40 02