METHOD TO TREAT UNDERGROUND TRAINING AND ACTIVATION DEVICE

专利摘要:
method for treating an underground formation, and activation device the present description is directed to a system and method for administering cement in an underground zone. In some implementations a method of cementing in an underground formation includes positioning a cement slurry that includes a plurality of activation devices in a wellbore. activation devices configured to release an activator that increases a cure rate (hardening) of the cement slurry. A signal is transmitted to at least a portion of the cement slurry to activate the activating devices. The activation device releases the activator in response to at least the signal.
公开号:BR112012004180B1
申请号:R112012004180-0
申请日:2010-08-23
公开日:2019-09-24
发明作者:Sam Lewis；Priscilla Reyes；Craig Roddy；Lynn Davis；Mark Roberson；Anthony Badalamenti
申请人:Halliburton Energy Services, Inc.；
IPC主号:

专利说明:

“METHOD FOR TREATING UNDERGROUND TRAINING, AND, ACTIVATION DEVICE”
Technical field [0001] This invention relates to cementing operations and, more particularly, to methods of activating cement in underground areas
Background [0002] Natural sources such as gas, oil and water that reside in an underground formation, or underground zone, are usually recovered by drilling a well hole into the underground formation while circulating a drilling fluid in the well hole. After completing the circulation of the drilling fluid, a tube column, for example, jacketing is placed in the well hole. The drilling fluid is then usually circulated downward through the inside of the pipe and upward through the circular crown, which is located between the outside of the pipe and the well hole walls. Some well holes, for example, those of some oil and gas wells, are coated with a jacketing. The jacketing stabilizes the sides of the well hole. Then, primary cementation is typically carried out, whereby a cement slurry is placed in the circular crown and allowed to harden to a hard mass (ie sheath), in order to connect the pipe column to the well hole walls, and seal the circular crown. In a cementing operation, cement is introduced under the well hole, into an annular space between the jacketing and the surrounding earth. The cement secures jacketing in the well bore and prevents fluids from flowing vertically into the circular crown between the jacketing and the surrounding earth. Different cement formulations are designed for a variety of well bore conditions, which can be above ambient temperature and pressure. When designing a cement formulation, numerous potential mixtures can be evaluated to determine its mechanical properties under different conditions.
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Subsequent secondary cementing operations can also be carried out. An example of a secondary cementation operation is compressed cementation, by means of which a cement slurry is used to plug and seal undesirable flow passages in the cement sheath and / or in the casing. Non-cement-like seals are also used in the preparation of a borehole. For example, polymer, resin or latex-based sealants may be desirable for placement behind the jacketing.
[0003] To improve the life of the well and minimize costs, sealing sludge is chosen based on calculated stresses and characteristics of the formation to be served. Suitable seals are selected based on the conditions that are expected to be encountered during the service life of the seal. Once a seal is chosen, it is desirable to monitor and evaluate the seal's health so that timely maintenance can be carried out and service life maximized. Seal integrity may be adversely affected by conditions in the well. For example, cracks in the cement can allow water to enter, while acidic conditions can degrade the cement. The initial strength and service life of cement can be significantly affected by its moisture content from the moment it is placed. Humidity and temperature are the primary drivers for the hydration of various cements and are critical factors in the most prevalent deterioration processes, including damage due to freezing and melting, alkali aggregate reaction, sulfate attack and delayed formation of etringitis (hexacalcium aluminate trisulfate ). Thus, it is desirable to measure one or more parameters of the seal, for example, moisture content, temperature, pH and ion concentration, to monitor the integrity of the seal.
[0004] Active sensors that can be embedded can involve disadvantages that make them undesirable for use in a
Petition 870190078938, of 8/14/2019, p. 9/71 / 60 well hole. For example, low-energy electronic humidity 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. In addition, power must be supplied from an internal battery to activate the sensor and transmit data, which increases the size of the sensor and decreases the life of the sensor.
Summary [0005] In accordance with one aspect of the present invention, a method is provided for treating an underground formation comprising: placing a curable (hardenable) composition that includes an activation device in a well bore, in which the activation device it is used to increase a curing speed (hardening) of the curable (curable) composition in response to an activation signal; and transmitting the activation signal to the curable (curable) composition to release an activator from the activation device.
[0006] In another aspect, the invention provides a method of cementing an underground formation, which comprises: placing a cement composition that includes an activation device in a well bore, in which the activation device is configured to release an activator which increases a cure speed (hardening) of the cement composition, and transmits a signal to at least a portion of the cement composition to activate the activation device, where the activation device releases the activator in response to at least the signal.
[0007] In another aspect, the invention provides an activation device comprising: an activation module that encloses an activator that increases a curing speed of a cement composition; a transducer that receives a wireless activation signal, and a logic module that transmits a release signal to the activation module, to release the
Petition 870190078938, of 8/14/2019, p. 10/71 / 60 activator in response to the transducer receiving the activation signal.
[0008] The present description addresses a system and method for managing cement in an underground area. In some implementations, a method of cementing an underground formation includes placing a cement slurry that includes a plurality of activation devices in a well bore. Activation devices are configured to release an activator that increases the cure speed of the cement sludge. A signal is transmitted to at least a portion of the cement sludge to activate the activation devices. The activation device releases the activator in response to at least one signal.
[0009] In addition, a method is described herein which comprises placing a seal composition comprising one or more MEMS sensors in the well bore and allowing the seal composition to cure (harden). [00010] Also described here is a method of serving a well hole, which comprises placing a MEMS interrogator tool in the well hole, initiating the placement of a sealing composition comprising one or more MEMS sensors into the well hole, and finishing the placement of the sealing composition inside the well hole when the interrogator tool comes in close proximity with the one or more MEMS sensors.
[00011] A method is further described here which comprises placing a plurality of MEMS sensors in a well-hole service fluid.
[00012] A well bore composition comprising one or more MEMS sensors is further described herein, in which the well bore composition is a drilling fluid or spacer fluid, a seal, or combinations thereof.
[00013] The above outlined the characteristics and technical advantages of this description in a very broad way, so that the detailed description that follows can be better understood. Features and
Petition 870190078938, of 8/14/2019, p. 11/71 / 60 additional advantages of the apparatus and method will be described hereinafter, which form the subject of the claims of this description. It should be appreciated by those skilled in the art that the specific design and implementations described can easily be used as a basis for modifying or designing other structures to accomplish the same purposes as this description. It should also be imagined by those skilled in the art that such equivalent constructions do not deviate from the scope of the apparatus and method as described in the appended claims.
[00014] Details of one or more implementations of the invention are described in the accompanying drawings and in the description below. Other characteristics, objectives and advantages of the invention will be evident from the description and drawings, and from the claims.
Description of drawings [00015] Figure 1 is an example of a well system for producing fluids from a production area.
[00016] Figures 2A and 2B are examples of the cementation process in the well system of figure 1.
[00017] Figure 3 illustrates an example of an activation device for activating cement sludge in a well hole.
[00018] Figures 4A-C illustrate examples of processes for releasing activators in cement sludge.
[00019] Figure 5 is a flow chart illustrating an example of a method for activating deposited cement sludge.
[00020] Figure 6 is a flow chart that illustrates an example of a method for making activation devices.
[00021] Figure 7 is an example of a well system for transmitting activation signals for cement sludge.
[00022] Figures 8A and 8B illustrate an example of a power module for activation devices in a cement sludge.
Petition 870190078938, of 8/14/2019, p. 12/71 / 60 [00023] Figure 9 is a flowchart that illustrates an implementation of a method according to the present description.
[00024] Figure 10 is a flow chart that details a method for determining when a reverse cementation operation is complete and for subsequent optional activation of a hole tool below.
[00025] Figure 11 is a flow chart of a method for selecting from a group of sealing compositions according to an implementation of the present description.
[00026] Same reference symbols in the different drawings indicate the same elements.
Detailed description [00027] Figure 1 is a cross-sectional view of an example of a well system 100 for administering cement in an underground area. For example, system 100 may include a cement sludge with devices that perform one or more operations associated with administering the cement sludge cure. Operations may include determining one or more parameters of the cement and or cement sludge (for example, moisture content, temperature, pH, ion concentration), releasing an activator that initiates or accelerates the curing process, and / or others. With respect to implementations that include sensors, the system 100 can periodically interrogate sensors in the cement to detect operational conditions over a period of time. For example, system 100 can detect cement properties to assess the state of, for example, a well bore in operation. With respect to activating the cement sludge, system 100 may have a cement distribution system under control that selectively controls the curing of a cement sludge. In these examples, system 100 may include a cement slurry with devices that release an activator into the cement slurry in response to at least one activation signal. An activator typically includes any chemicals that activate and / or
Petition 870190078938, of 8/14/2019, p. 13/71 / 60 accelerate the curing process for a cement sludge in system 100. An activator can also delay or otherwise affect the curing or properties of the cement sludge. For example, system 100 may include one or more of the following activators: sodium hydroxide, sodium carbonate, calcium chloride, calcium nitride, calcium nitrate and / or others. In addition, system 100 may include devices with sensors and activators in such a way that the devices release the activators in response to at least detecting predefined criteria in the cement sludge, such as the pH reaching a specified threshold. In some implementations, activation devices may include elements that substantially terminate the one or more activators and that release the activator in response to at least one event. For example, activation devices can receive a signal (for example, infrared signal) and, in response to the signal, the enclosing element can release one or more activators. When to activate, the enclosing element 100 can mechanically move the enclosing element, chemically remove at least a portion of the enclosing element, resistively heating the enclosing element to form an opening, and / or other processes for release the one or more activators. For example, system 100 may include Micro-Electro-Mechanical System (MEMS) devices in the cement sludge, which mechanically release the activators. In general, system 100 includes a cement slurry in a circular crown formed between a jacketing and a well bore, and when the cement is cured the cement holds jacketing in place. By monitoring and / or selectively controlling the curing of a cement slurry, the system 100 can allow cement properties to be tailored, once the cement sludge has been pumped down the borehole. In addition, system 100 can monitor cement during normal operating conditions.
[00028] In some implementations the well 100 system includes
Petition 870190078938, of 8/14/2019, p. 14/71 / 60 a production zone 102, a non-production zone 104, a well bore 106, a cement sludge 108 and devices 110. Production zone 102 can be an underground formation that includes resources (for example, oil, gas, water). Non-production zone 104 can be one or more formations that are isolated from well bore 106 using cement sludge 108. For example, zone 104 can include contaminants that, if mixed with the resources, may result in requiring further processing resources and / or make production economically unviable. Cement sludge 108 can be pumped or selectively positioned in well bore 106. In some implementations the properties of cement sludge 108 can be monitored using devices 110. Alternatively or in combination, the curing of cement sludge 108 can be activated or accelerated using devices 110. For example, devices 110 can release an activator in response to a signal initiated, for example, by a system user 100, and / or devices 110 that detect specified operating conditions. By monitoring and / or controlling curing, a user can configure system 100 without substantial interference from the curing of cement sludge 108.
[00029] Returning to a more detailed description of the elements of the system 100, the well hole 106 extends from a surface 112 to the production zone 102. The well hole 106 can include an equipment 114 that is placed close to the surface 112 Equipment 114 may be coupled to a pipe column 116, which extends a substantial portion of the length of well hole 106, from approximately surface 112 towards production zone 102 (e.g., hydrocarbon-containing reservoir) . In some implementations the pipe column 116 may extend beyond the production zone 102. The pipe column 116 may extend as close to the end 118 of the well hole 106. In some implementations the well 106 may be completed with
Petition 870190078938, of 8/14/2019, p. 15/71 / 60 the pipe column 116 extending to a predetermined depth, close to the production zone 102. Briefly, the well bore 106 initially extends in a substantially vertical direction towards the production zone 102. In some implementations well bore 106 may include other portions that are horizontal, inclined, or otherwise offset from vertical.
[00030] Equipment 114 can be centered on an underground oil or gas formation 102, located below the surface of the earth 112. Equipment 114 includes a working deck 124 that supports a crane 126. Crane 126 supports a lifting device 128 to raise and lower pipe columns such as pipe column 116. Pump 130 is capable of pumping a variety of borehole compositions (for example, drilling fluid, cement) into the well, and includes a pressure measurement device that provides a pressure reading at the pump discharge. Well hole 106 was drilled through the various strata of soil, including formation 102. When drilling well hole completion, pipe column 116 is often placed in well hole 106 to facilitate oil production and gas from formation 102. Piping column 116 is a column of tubes extending below well hole 106, through which oil and gas can be extracted. A cement or jacketing shoe 132 is typically attached to the end of the jacketing column when the jacketing column is run into the well hole. The jacking shoe 132 guides the pipe column 116 towards the center of the hole and can minimize, or otherwise, lessen problems associated with hitting rock “shelves” or cracks (failures) in the well hole 106 when the column jacketing is lowered into the well. The jacking shoe 132 can be a guide shoe or a floating shoe, and typically comprise a
Petition 870190078938, of 8/14/2019, p. 16/71 / 60 tapered piece, often with projectile nose, of equipment found at the bottom of the jacketing column 116. The jacking shoe 132 can be a floating shoe equipped with an open bottom and a valve that serves to prevent reverse flow , or cement mud “U” pipe 108 from the ring crown 122 into the pipe column 116, when the pipe column 116 is run into the well hole 106. The region between the pipe column pipe 116 and well hole wall 106 is known as the jacketing ring 122. To fill the jacketing ring 122 and hold pipe column 116 in place, pipe column 116 is usually cemented into the well hole 106, which is referred to as “primary cementation”. In some implementations, cement sludge 108 can be injected into the well bore 106 through one or more perforations 134. Cement sludge 108 can flow through a hose 136 into the pipe column 116. In some cases the column of pipe 116 may rest or otherwise meet an edge 138 of surface jacketing 120.
[00031] In some implementations the system 100 can activate the curing of the cement sludge 108 using the activating devices 110 during, for example, conventional primary cementation operation. In conventional primary cementing implementations, devices 110 can mix into cement sludge 108 prior to the introduction of pipe column 116 and cement sludge 108 can then be pumped down inside pipe column 116. For example, devices 110 can be mixed in cement slurry 108 at a density in the range of 4 to 24 pounds per gallon (ppg) (0.47 to 2.88 kg / L). When the mud 108 reaches the bottom of the pipe column 116, it drains out of the pipe column 116 and into the inner lining ring 122 between the pipe column 116 and the well hole wall 106. When the mud of cement
Petition 870190078938, of 8/14/2019, p. 17/71 / 60 flows upward in the circular crown 122, it displaces any fluid in the well bore. To ensure that no cement remains inside the pipe column 116, devices called “scrapers” can be pumped by a service fluid from the well hole (for example, drilling mud) through drilling column 116, behind the cement mud. 108. The scraper contacts the inner surface of the pipe column 116 and pushes any remaining sludge 108 out of the pipe column 116. When the cement sludge reaches the surface of the earth 118, and the circular crown 122 is filled with mud 108, pumping is finished. In connection with pumping cement sludge 108 into the ring, a signal can be transmitted to devices 110 before, during and / or after pumping is completed. The signal can request detected operating conditions, initiate release of activators and / or other operations. For example, devices 110 can release activators that initiate and / or accelerate the curing of cement sludge 108 in circular crown 122, in response to at least the signal. Some or all of the pipe column 116 can be attached to the material of the adjacent land with a cement jacket, as illustrated in figures 2A and 2B. In some implementations the pipe column 116 comprises a metal. After curing, the tubing column 116 can be configured to charge a fluid such as air, water, natural gas, or to charge an electric line, tubular column, or other elements.
[00032] After positioning the pipe column 116, a cement sludge 108 including devices 110 can be pumped into the inner ring 122 by means of a pump truck (not shown). Examples of cement sludge 110 are discussed in more detail below. In connection with depositing or otherwise positioning the cement sludge 108 in the circular crown 122, the devices 110 can release activators to activate or otherwise increase the curing speed of the cement sludge
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108 in response to at least one signal. In other words, devices 110 can activate cement sludge 108 to cure cement in circular crown 122. Alternatively or in combination, devices 110 can detect one or more attributes of cement sludge 108, such as moisture content, temperature , pH, ion concentration, and / or other parameters. In some implementations, substantially all of the cement cures in the circular crown 122, and only a limited portion of the cement, if any, penetrates inside the pipe column 116. In some implementations all of the cement cures in the circular crown 122, and none of the cement sludge 108 penetrates into the pipe column 116.
[00033] With respect to devices 110 that include activators, activation devices 110 can release an activator that initiates or accelerates the curing of cement sludge 108. For example, cement sludge 108 can remain in a substantially sludge state for a specified period of time, and the activation devices 110 can activate the cement sludge in response to at least one signal. Activation devices 110 can receive a signal, and in response to the signal, release activators. In some cases, activation devices 110 terminate activations with, for example, a membrane. In some implementations the membrane can be metallic, 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, polyvinyl acetate, hydrolyzed ethylene / vinyl acetate, silicones, and combinations of copolymers of each. In response to the signal, the activation device 110 may form an opening in the membrane. The activation device 110 can form an opening by mechanically moving a portion of the membrane, and / or 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 can be a
Petition 870190078938, of 8/14/2019, p. 19/71 / 60 ultrasonic signal that vibrates the membrane to form an opening. Activation device 110 may include a polymer membrane that degrades ultrasonically to release enclosed activators. In some instances, an ultrasonic signal can structurally change the membrane to release activators such as, for example, opening the membrane like a flap. 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 in which the radiation signal comprises at least one of neutrons, alpha particles or beta particles. In some implementations the cement composition can cure in a range from one hour to a day after reacting with the activator. The activation device can include at least one dimension in a range from approximately one micron or up to approximately 10,000 pm.
[00034] The release activator may 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, the activation device 110 can release a sodium salt such as sodium chloride, sodium aluminate, and / or sodium silicate. Activation device 110 can release a magnesium salt such as magnesium chloride. In some examples, activation device 110 can release amine compounds, such as triethanol amine, tripropanol amine, triisopropanol amine and / or diethanol amine. In some implementations the activation device 110 can release activator in an amount sufficient to cure cement sludge 108 within approximately 1 minute to approximately 2 hours. Alternatively, the activator may be present in an amount sufficient to cure the sludge within approximately 1 hour to approximately one day. In implementations that include chloride
Petition 870190078938, of 8/14/2019, p. 20/71 / 60 sodium as the released activator, the concentration can be in the range of approximately 3% to approximately 15% by weight of cement in cement slurry 108. In implementations that include calcium chloride as the released activator, the The concentration can be in the range of approximately 0.5% to approximately 5% by weight of the cement in the cement sludge 108.
[00035] In some implementations the activation device 110 can have instant cure of cement sludge 108. As mentioned here, the term "instant cure" will be understood to mean the start of curing of cement sludge 108 within approximately 1 minute until approximately 5 minutes after contacting the released activator. In some implementations the activators identified earlier may have instant cure of cement sludge 108. Instant cure activators may include sodium hydroxide, sodium carbonate, potassium carbonate, and sodium or potassium bicarbonate salts and sodium silicate salts, sodium aluminate salts, ferrous and ferric salts, for example, ferric chloride, ferric sulfate or polyacrylic acid salts, and / or others. In some implementations the following activators may have instant cure of cement sludge 108 based on these activators that exceed a specified concentration: calcium nitrate, calcium acetate, calcium chloride and / or calcium nitride. In some implementations the activation device 110 can release a solid activator.
[00036] In some implementations the 110 devices comprise MEMS devices that contain a micro-reservoir system coated with an ultrasound sensitive polymer, for example, ultrasonic sensitive polymeric membranes (eg, polyanhydrides, polyglycolides, polylactides, ethylene vinyl acetate copolymers , silicones). The micro-reservoirs can be loaded with one or more cement additives (for example, accelerator, retarder). When exposed to waves
Petition 870190078938, of 8/14/2019, p. 21/71 / 60 acoustic, for example, ultrasonic waves, the polymer membrane can start to degrade, break, and cause the release of the desired additives. Speed of release of the additives can be controlled by the intensity of the ultrasound and its duration. Not only can a MEMS device be manufactured to have micro-reservoirs, but it can also include micro pumps. The desired additive can be delivered to the pumps. Upon exposure, the MEMS 110 device may have a sensor / transducer / acoustic / ultrasonic detector that once for ultrasound, the additive can be pumped through cavitation. In addition, the MEMS trigger can cause a cascade of events (for example, increase in temperature and / or pressure) that results in the release of additives.
[00037] With respect to devices 110 that include one or more sensors, the sensors can be positioned within well hole 106. For example, sensors 110 can extend over all or a portion of the length of the well hole 106 adjacent to pipe column 116. Sealing mud 108 can be placed down the hole as part of a primary cementation, secondary cementation, or other sealing operation as described in more detail here. In some implementations a data interrogator tool can be positioned in an operable location to gather data from sensors 110, for example, lowered into well bore 106, next to sensors 110. The data interrogator tool can interrogate sensors from data 110, for example, by sending an RF signal, while the data interrogator tool passes through all or a portion of the well hole 106 containing sensors 110. Data sensors 110 can be activated to record and / or transmit data from the signal from the data interrogator tool. The data interrogator tool can communicate data to one or more computer components, for example, memory and / or microprocessor, which can be located inside the tool, in the
Petition 870190078938, of 8/14/2019, p. 22/71 / 60 surface 112, or both. The data can be used locally or remotely from the tool, to calculate the location of each data sensor and correlate measured parameters with such locations to assess seal performance.
[00038] In some implementations the sensors 110 include MEMS sensors that, for example, detect conditions during drilling (for example, drilling fluid comprising MEMS sensors) or during cementation (for example, cement sludge 108 comprising MEMS sensors) as described in more detail below. Additionally or alternatively, data collection can be performed at one or more times following the initial placement in composition 108 which comprises MEMS 110 sensors. For example, data collection may be performed at the time of initial placement in the well of composition 108 comprising MEMS 110 sensors or shortly thereafter to provide a baseline data set. When the well is operated to recover natural resources, over a period of time data collection can be carried out at additional times, for example, at regular maintenance intervals such as every 1 year, 5 years or 10 years. Data retrieved during subsequent monitoring intervals can be compared to baseline data, as well as any other data obtained from previous monitoring intervals, and such comparisons can indicate the overall conditions of well 106. For example, changes in a or more sensed parameters may indicate one or more well hole problems. Alternatively, consistency or uniformity in sensed parameters may indicate no substantive problems in well bore 106. In some given implementations, for example, seal parameters from a plurality of monitoring intervals are plotted over a period of time and a graph resultant can be provided showing an operation or trend line for the parameters
Petition 870190078938, of 8/14/2019, p. 23/71 / 60 submitted. Typical changes in the graph, as indicated, for example, by a sharp change in the slope, a step change in the graph, can provide an indication of one or more present problems or the potential for a future problem. Consequently, remedial and / or preventive treatments, or services, can be applied to well bore 106 to address present or potential problems.
[00039] In some implementations the MEMS 110 sensors can be contained within a sealing composition 108 placed substantially within the annular space 122, between a pipe column and the well hole wall. That is, substantially all MEMS 110 sensors can be located inside or in close proximity to annular space 122. In some implementations the service fluid from the well bore comprising MEMS 110 sensors (and thus likewise MEMS 110 sensors) may not substantially penetrate, migrate or travel into the formation from well hole 106. In an alternative embodiment, substantially all MEMS 110 sensors are located inside, adjacent to, or in proximity to well hole 106, for example. example, less than or equal to approximately 1 foot, 3 feet, 5 feet, or 10 feet of well bore 106. Such placement in proximity to or adjacent to MEMS 110 sensors in relation to well bore 106, may be in contrast to placing MEMS 110 sensors in a fluid that is pumped into formation 102 in large volumes, or penetrates substantially, migrates or travels into or through formation 102, p for example, as with a fracturing fluid or a flooding fluid. Thus, in modalities the MEMS 110 sensors can be placed close to or adjacent to the well hole 106 (in contrast to the distant formation) and provide relevant information for the well hole itself and compositions (for example, seals 108) used in it (again in contrast to the formation or a remote production area).
Petition 870190078938, of 8/14/2019, p. 24/71 / 60 [00040] In some implementations the data sensors 110 added to the sealing mud 108 can be passive sensors that do not require continuous power from a battery or an external source to transmit data in real time. In some implementations data sensors 110 are micro-electro-mechanical systems (MEMS) that comprise one or more (typically a plurality of) MEMS devices, referred to here as MEMS 110 sensors. MEMS 110 devices are well known, for example, a semiconductor device with mechanical characteristics on the MEMS micrometric scale configures the integration of mechanical elements, sensors, actuators and electronics in a common substrate. In implementations, the substrate comprises silicon. MEMS elements include mechanical elements that are movable through an energy input (electrical or other energy). Using MEMS, a sensor 110 can be designed to emit a detected signal based on a number of physical phenomena that include thermal, biological, optical, chemical, and magnetic effects or stimulation. MEMS 110 devices are minimized in size, have low power requirements, are relatively inexpensive and are rude, and thus are well suited for use in well bore service operations.
[00041] In some implementations data sensors 110 comprise an active material connected to (for example, mounted inside or mounted on the surface of) an enclosure, the active material being reliable to respond to a well bore parameter and the active material being operationally connected to a capacitive MEMS element (for example, in physical contact with, surrounding or coating). In several implementations, the MEMS 110 sensors sense one or more parameters within the well bore 106. In some implementations the parameter may include temperature, pH, moisture content, ion concentration (eg sodium chloride and / or potassium ions) and / or others. MEMS 110 sensors
Petition 870190078938, of 8/14/2019, p. 25/71 / 60 can also sense data characteristic of the well cement, such as stress, deformation or combinations of them. In some implementations the MEMS 110 sensors of the present description may comprise materials and articles that respond to two or more measurers. In this way, two or more parameters can be monitored.
[00042] Suitable active materials such as dielectric materials that respond in a predictable and stable manner 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, “ The Wireless Passive Carbon Nenotube-based Gas Sensor ”, 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”, Sensors and Actuators A, 93 (2001) 33-43, each of which is hereby incorporated by reference in its entirety. MEMS 110 sensors suitable for the methods of the present description that respond to various well bore parameters are described in US Patent No. 7,038,470 B1 which is hereby incorporated by reference in their entirety.
[00043] In some implementations the MEMS 110 sensors can be coupled with radio frequency identification devices (RFIDs) and can detect and transmit characteristic parameters and / or data from the well to monitor the cement during its service life. RFIDs combine with a microchip, with an antenna (the RFID chip and the antenna are collectively referred to as the "transponder" or the "tag"). The antenna provides the RFID chip with power when exposed to a narrowband high frequency electromagnetic field from a “receiving transmitter”. A dipole antenna or a coil, depending on the operating frequency, connected to the RFID chip, energizes the transponder when current is induced in the antenna by an RFID signal from the antenna of the receiving transmitter. Such a device may return an ID number of
Petition 870190078938, of 8/14/2019, p. 26/71 / 60 unique identification modulating and re-radiating the radio frequency (RF) wave. Passive RF tags are gaining widespread use due to their low cost, long life, simplicity, efficiency and the ability to identify parts at a contactless distance (ability to transmit information free of connection). These sturdy, small labels are attractive from an environmental point of view, as they do not require a battery. The MEMS sensor and the RFID tag are preferably integrated into a single component 110 (for example, chip or substrate), or can alternatively be separate components 110, operationally coupled to each other. In some implementations, a passive, integrated MEMS / RFID sensor 110 may contain a data sensing component, an optional memory and an RFID antenna, so excitation energy is received and energizes the sensor by sensing a present condition and / or accessing one or more sensed conditions stored from memory and transmitting them through the RFID antenna.
[00044] Within the US, operating bands commonly used for RFID systems centered on one of the three frequencies designated for the government: 125 kHz, 13.56 MHz or 2.45 GHz. A fourth frequency 27.125 MHz has also been designated. When the 2.45 GHz carrier frequency is used, the range of an RFID chip can be several meters. While this is useful for remote sensing, there may be several transponders within the RF field. To prevent these devices from interacting and mixing data, anti-collision schemes are used as they are known in the art. In implementations, data sensors are integrated with local tracking hardware to transmit their position when they flow into a sealing mud. Data sensors 110 can form a network that uses wireless connections to neighboring data sensors and are able to locate and position using local positioning algorithms, for example, as they are known in
Petition 870190078938, of 8/14/2019, p. 27/71 / 60 technique. The sensors 110 can be organized in a network listening to each other, therefore allowing communication of signals from the most distant sensors towards the sensors closest to the interrogator to allow transmission and non-interrupted data capture. In these implementations, the interrogator tool may not need to go through the entire section of the borehole containing MEMS sensors to read data gathered by such sensors. For example, the interrogator tool only needs to be lowered approximately halfway along the vertical length of the well hole containing MEMS sensors. Alternatively or in combination, the interrogator tool can be lowered vertically into the well hole to a location adjacent to a horizontal arm of a well 106, so MEMS 110 sensors can be located on the horizontal arm and can be read without the need to the interrogating tool crosses the horizontal arm. Alternatively or in combination, the interrogator tool can be used on or near the surface and read the data gathered by the sensors distributed over the whole, or a portion of the well hole. For example, sensors 110 can be located distal to interrogators and can communicate over a network formed by the sensors, as described above.
[00045] In some implementations the MEMS 110 sensors are ultra-small, for example, 1 mm square, such that they are pumped into a sealing mud. In some implementations the MEMS 110 device can be approximately 1 pm ² to 1mm ^2, 1mm ² to 3mm ² , 3mm ² to 5mm ² , 5mm ² to 100mm ² , and / or other dimensions. In some implementations, data sensors 110 may be able to provide data over the entire service life (service life) of the cement. In implementations, data sensors 110 can provide data for up to 100 years. In some implementations the composition of the well hole 108 may comprise an amount of MEMS effective to measure one or more desired parameters.
Petition 870190078938, of 8/14/2019, p. 28/71 / 60
In several implementations the well hole composition 108 may comprise an effective amount of MEMS such that sensed readings can be obtained at intervals of approximately 1 foot, 6 inches, 1 inch, and / or another interval along the well hole portion. 106 containing MEMS 110. MEMS can be present in the well bore composition 108 in an amount from approximately 0.01 to approximately 50% by weight.
[00046] In some implementations, MEMS 110 sensors can comprise passive sensors (remain unenergized when not interrogated) energized by means of energy radiated from a data interrogator tool. The data interrogator tool may comprise an energy receiving transmitter that sends energy (e.g., radio waves) to and receives signals from the MEMS 110 sensors and a processor that processes the received signals. The data interrogator tool may additionally comprise a memory component, a communications component, or both. The memory component can store raw and / or processed data received from MEMS 110 sensors, and the communications component can transmit raw data to the processor and / or transmit processed data to another receiver, for example, located on the surface. The tool components (for example, a receiver transmitter, processor, memory component, and communications component) are coupled together and in signal communication with each other.
[00047] In some implementations one or more of the data interrogator components (not shown) can be integrated in a tool or unit that is placed temporarily or permanently hole below (for example, a module hole below. In some implementations a module removable hole below comprises a transmitter receiver and a memory component, and the hole module below is placed in the well hole,
Petition 870190078938, of 8/14/2019, p. 29/71 / 60 reads data from the MEMS sensors, stores the data in the memory component, is removed from the well hole, and the raw data is accessed. Alternatively or in combination, the removable hole module below may have a processor to process and store data in the memory component, which is then accessed on the surface when the tool is removed from the well hole. Alternatively or in combination, the removable hole module below may have a communications component for transmitting raw data to a processor and / or transmitting processed data to another receiver, for example, located on the surface. The communications component can communicate through wired or wireless communications. For example, the hole component below can communicate with a component or other node on the surface via a cable or other communications / telemetry device, such as a radio frequency, electromagnetic telemetry device, or an acoustic telemetry device. The removable component hole below can be positioned intermittently hole below through any suitable transport, for example, cable line, coiled pipe, straight pipe, gravity, pumping, etc., to monitor conditions at various times during the life of the well .
[00048] In some implementations the data interrogator tool comprises a permanent or semi-permanent hole-down component that remains hole-down for extended periods of time. For example, a semi-permanent module below the hole can be retrieved and data downloaded once every few years. Alternatively or in combination, a permanent borehole module can remain in the well throughout the life of the well. In an implementation, a permanent or semi-permanent bore module comprises a receiver transmitter and a memory component, and the bore module below is placed in the well bore, reads data from the MEMS sensors,
Petition 870190078938, of 8/14/2019, p. 30/71 / 60 optionally stores the data in the memory component and transmits the read and optionally stored data to the surface. Alternatively or in combination, the hole below permanent or semi-permanent hole below module may have a processor for processing and sensing data in processed data, which can be stored in memory and / or transmitted to the surface. The permanent or semi-permanent module bore below may have a communications component to transmit raw data to one processor and / or transmit processed data to another receiver, for example, located on the surface. The communications component can communicate through wired or wireless communications. For example, the hole component below can communicate with a component or other node on the surface via a cable or other communications / telemetry device such as a radio frequency device, electromagnetic telemetry or an acoustic telemetry device.
[00049] In some implementations the data interrogator tool comprises an RF energy source incorporated in its internal circuits and the data sensors are passively energized using an RF antenna that takes energy from the RF energy source. The data interrogator tool can be integrated with an RF receiver transmitter. In implementations, MEMS sensors (eg MEMS / RFID sensors) are energized and interrogated by the RF receiver transmitter from a distance, for example, a distance greater than 10 m, or, alternatively, from the surface or the from an adjacent displaced well. In some implementations, the data interrogator tool traverses within a jacketing in the well and reaches MEMS sensors located in a sealing sheath (for example, cement) that surrounds the jacketing and located in the annular space between the jacketing and the well hole wall . In some implementations the interrogator senses the MEMS sensors when in close proximity to the
Petition 870190078938, of 8/14/2019, p. 31/71 / 60 sensors, typically passing through a removable component down the hole along a length of the well hole comprising the MEMS sensors. In some implementations, proximity together comprises a radial distance from from a point within the jacketing to a flat point within an annular space between the jacketing and the borehole. In some implementations, proximity together comprises a distance of 0.1m to 1m, 1m to 5m, 5m to 10m, or other ranges. In implementations, the receiving transmitter interrogates the sensor with RF energy at 125 kHz and the proximity together comprises 0.1 m to 0.25 m. Alternatively or in combination, the receiving transmitter interrogates the sensor with RF energy at 13.5 MHz and the proximity together comprises 0.25 m to 0.5 m. Alternatively or in combination, the receiving transmitter interrogates the sensor with RF energy at 915 MHz and proximity together comprises 0.5 m to 1 m. Alternatively or in combination, the receiving transmitter interrogates the sensor with RF energy at 2.4 GHz and proximity together comprises 1 m to 2 m.
[00050] Although sludge 108 is referred to as cement sludge, sludge 108 may include cement and / or non-cement sealants, without departing from the scope of this description. In some non-cement sealant implementations they comprise resin based systems, latex based systems or combinations thereof. In implementations, the seal comprises a cement sludge with styrene-butadiene latex (for example, as described in US Patent number 5,588,488, hereby incorporated by reference in its entirety. Seals can be used in curing expandable jacketing which is further described below. In some implementations the seal may be a cement used for primary or secondary well hole cementation operations, as discussed further below.
[00051] In some implementations the seal 108 can be of
Petition 870190078938, of 8/14/2019, p. 32/71 / 60 cement and comprise a hydraulic cement that cures and hardens through reaction like water. Examples of hydraulic cements include, but are not limited to, Portland cements (for example, Portland cements classes A, B, C, G and H) pozzolan cements, plaster cements, phosphate cements, high alumina cements, silica, high alkalinity cements, shale cements, acid / basic cements, magnesium cements, ash cement, zeolite cement systems, cement kiln dust cement systems, slag cement, microfine cement, metakaolin, and combinations of them. Examples of seals are described in US Patent No. 6,457,524; 7,077,203 and 7,174,962, each of which is hereby incorporated by reference in its entirety. In some implementations sealant 108 may comprise a cement and a sorable cement composition that typically comprises magnesium oxide and a chloride or phosphate salt which together form, for example, magnesium oxychloride. Examples of magnesium oxychloride sealants are described in US Patent Nos. 6,664,215 and 7,044,222, each of which is hereby incorporated by reference in its entirety.
[00052] The composition of well hole 108 (for example, sealant) can include a sufficient amount of water to form a pumpable sludge. The water can be clean water or salt water (for example, an unsaturated aqueous salt solution, or a saturated aqueous salt solution, such as brine or sea water). In some implementations, cement sludge 108 may be a lightweight cement sludge containing foam (e.g., foamed cement) and / or hollow beads / microspheres. In some implementations MEMS 110 sensors can be incorporated into, or connected to, all or a portion of the hollow microspheres. Thus, MEMS 110 sensors can be dispersed within the cement together with the microspheres. Examples of seals containing microspheres are described in US Patents 4,234,344, 6,457,524 and 7,174,962, each of which
Petition 870190078938, of 8/14/2019, p. 33/71 / 60 which are hereby incorporated by reference in their entirety. In some implementations, MEMS 110 sensors are incorporated into a foamed cement such as those described in more detail in US Patent Numbers 6,063,738, 6,367,550, 6,547,871; and 7,174,962, each of which is hereby incorporated by reference in its entirety.
[00053] In some implementations, additives can be included in the cement composition to improve or change its properties. Examples of such additives include, but are not limited to, accelerators, curing retardants, foam removers, fluid loss agents, weighing materials, dispersants, density reducing agents, forming conditioning agents, circulation loss materials , thixotropic agents, suspension aids, or combinations thereof. Other additives for modifying mechanical properties, for example, fibers, polymers, resins, latexes, and the like can be added to further modify mechanical properties. These additives can be included singly or in combination. Methods for introducing these additives and their effective amounts are known to someone of ordinary skill in the art.
[00054] With respect to activator implementations, cement sludge 108 may comprise delayed curing cement compositions that remain in a sludge state (e.g., resistant to gelatinization) for an extended period of time. In such implementations a delayed cure cement sludge 108 may include a basic fluid cement and a cure retardant. In these and other implementations, activation can change the state of the retarded curing cement sludge to neutral, to accelerated, or to less delayed. Cement sludge 108 may include other additives. Delayed cure cement sludge 108 typically remains in a sludge state for a range of approximately 6 hours to approximately 7 days under borehole or other conditions. That said, cement sludge 108
Petition 870190078938, of 8/14/2019, p. 34/71 / 60 can include components that result in a muddy state for a shorter or longer amount of time. For example, cement sludge 108 can be mixed or otherwise made in the well before positioning sludge 108 in circular crown 122. Delayed cure cement sludge 108 may, in some implementations, include a cement, a base fluid , and a curing retardant. Delayed cure cement sludge 108 can be cured at a desired time such as after laying, activating activation devices 110 to release one or more activators.
[00055] With respect to cements included in cement slurry 108, any cement suitable for use in underground applications may be suitable for use in the present invention. For example, delayed-curing cement sludge 108 may include hydraulic cement. In general hydraulic cements typically include calcium, aluminum, silicon, oxygen and / or sulfur, and can cure and harden by reacting with water. Hydraulic cements include, but are not limited to, Portland cements, pozzolanic cements, high luminate cements, plaster cements, silica cements, and high alkalinity cements. In addition, delayed-curing cement sludge 108 may include shale-based cement or kiln slag. In these cases shale may include vitrified shale, raw shale (e.g., unburned shale) and / or a mixture of raw shale and vitrified shale.
[00056] With respect to base fluids included in cement slurry 108, delayed-cure cement sludge 108 may include one or more base fluids such as, for example, an aqueous based base fluid, or a base based fluid not aqueous, or mixtures of them. An aqueous base can include water from any source that does not contain an excess of compounds, for example, dissolved organics such as tannins, which can affect differently other compounds in cement slurry 108. For example, delayed curing cement sludge 108 may include clean water, salt water
Petition 870190078938, of 8/14/2019, p. 35/71 / 60 (for example, water containing one or more salts) brine (for example, saturated salt water) and / or sea water. Non-aqueous based, they may include one or more organic liquids such as, for example, mineral oils, synthetic oils, esters and / or others. Generally, any organic liquid in which an aqueous solution of salts can be emulsified may be suitably suitable for use as a base fluid in delayed-curing cement sludge 108. In some implementations, the base fluid exceeds a concentration sufficient to form a pumpable mud. For example, the base fluid can be water in an amount ranging from approximately 25% to approximately 150% by weight of cement ("bwoc") such as one or more of the following ranges: approximately 30% to approximately 75% bwoc approximately 35% to approximately 50% bwoc; approximately 38% to approximately 46% bwoc, and / or others.
[00057] With respect to cement sludge 108 curing retardants, cement sludge 108 may include one or more different types of curing retarders such as, for example, phosphonic acid, phosphonic acid derivatives, lignosulfonates, salts, acids organic, hydroxyethylated carboxymethyl celluloses, co- or terpolymers comprising sulfonate and carboxylic acid groups and / or borate compounds. In some implementations the curing retardants used in the present invention are derived from phosphonic acid. Examples of curing retardants may include commercially available phosphonic acid derivatives, for example, from Solutia Corporation of St, Louis, Mo. Under the trade name “DEQUEST”, another example of a curing retardant may include a commercially available phosphonic acid derivative from Halliburton Energy Services, Inc., under the trade name “MICRO MATRIZ CEMENT RETARDER”.
[00058] Example of cheap compounds may include tetraborate of
Petition 870190078938, of 8/14/2019, p. 36/71 / 60 sodium, potassium pentaborate, and / or others. A commercially available example of a suitable curing retarder comprising potassium pentaborate is available from Halliburton Energy Services, Inc., under the trade name "Component R". Examples of organic acids can include gluconic acid, tartaric acid and / or others. An example of a suitable organic acid can be commercially available from Halliburton Energy Services, Inc., under the trade name “HR.RTM.25”. Other examples of curing retardants may be available from Halliburton Energy Services, Inc., under the trade names "SCR-100" and "SCR-500". Generally, the curing retardant in the retarded curing cement sludge 108 may be in an amount sufficient to delay curing in an underground formation for a specified time. The amount of curing retardant included in cement sludge 108 can be in one or more of the following ranges: approximately 0.1% to approximately 10% bwoc; approximately 0.5% to approximately 4% bwoc, and / or others.
[00059] In some implementations, cement sludge 108 may not include a curing retardant. For example, cement sludge 108 may include high aluminate cements and / or phosphate cements independent of a curing retardant. In these cases, activators can initiate the curing of sludge 108. For example, these activators may include alkali metal phosphate salts. High aluminate cement may comprise calcium aluminate in an amount ranging from approximately 15% to approximately 45% by weight of high aluminate cement, gray class F in an amount ranging from approximately 25% to approximately 45% by weight of high aluminate cement and sodium phosphate in an amount ranging from approximately 5% to approximately 15% by weight of high aluminate cement. In certain implementations of the present invention, where a cement composition comprising a phosphate cement is used, a reactive component of the
Petition 870190078938, of 8/14/2019, p. 37/71 / 60 cement composition (for example, the alkali metal phosphate salt) can be used as an activator.
[00060] Figures 2A and 2B illustrate a cross-sectional view of the well system 100 that includes curing cement 202 in at least a portion of the circular crown 122. In particular, the activation devices 110 release activators in at least a portion of the cement sludge 108, to form the cement cure 202. In figure 2A the cement sludge 108 flowed into the circular crown 122 through the pipe column 116, and in response to at least one signal the activation devices 110 in mud 108 they released an activator. In the illustrated example, substantially all devices 110 in the circular crown 122 have released activators to form the cured cement 202 along substantially the entire length of the circular crown 122. Referring to figure 2B, the cement sludge 108 has flowed into the crown circulate 122 through pipe column 116 and, in response to at least one signal, activation devices 110 in mud 108 have released activators within a specified location 204. In the illustrated example, region or location 204 is located close to zone 102 In other words, activation devices 110 near zone 102 can release activators and form cured cement 202 located in region 204. The activation signal can be located for the region identified by 204 and in response to at least the signal located cured cement 204 forms. In some implementations an initial amount of cement sludge 108 can be exposed to an activation signal, such that the curing period can be substantially equal to a period of time for curing cement sludge 108 to flow to location 204 In these examples, the cement sludge 108 can be exposed to the activation signal when the sludge 108 that includes the devices 110 penetrates the pipe column 116. When the front edge of the cement sludge 108 begins to cure, fluid flow through the crown circular 122 can become more
Petition 870190078938, of 8/14/2019, p. 38/71 / 60 restricted and may eventually cease. Thus, the cement sludge 108 can be substantially prevented from flowing over the surface 112 through the circular crown 122. The remainder of the cement sludge 108 can cure in the circular crown 122 behind the front edge, as shown in figure 2A or the cement 108 can cure at a later time, as illustrated in figure 2B of. In the latter, the remaining cement sludge 108 may be exposed to signs of activation at a later time, to initiate or accelerate the curing processes.
[00061] Figure 3 illustrates an example of activating device 110 of figure 2 according to some implementations of the present description. In these implementations, the activator device 110 releases one or more stored activators in response to at least one wireless signal. The illustrated device 110 is, for example, for example purposes only, and the device 110 may include some or all of the elements illustrated without departing from the scope of this description.
[00062] As illustrated, activator device 110 includes a substrate 302 and a passivation layer 304 formed on substrate 302. Passivation layer 304 includes or is otherwise adjacent to activator module 306 to release activators, a transducer 308 for receiving signals wireless logic 310 to control the activator module 306 and a power module 312 to supply power to device 110. Substrate 302 can provide a mechanical structure to support the device elements and / or a surface to route electrical signals and / or fluid. The substrate 302 can be silica, quartz, glass, organic (e.g., kapton tape or other flexible material) FR-4, duroid, and / or other materials. In some implementations the passivation layer 304 can protect one or more modules from the surrounding cement sludge 108 and / or can provide direct access to the cement sludge 108, for example, to release the activators.
[00063] The activator module 306 can release one or more activators
Petition 870190078938, of 8/14/2019, p. 39/71 / 60 to start or accelerate the curing of the cement sludge 108. In some implementations the activator module 306 can receive one or more signals from logic 310 and execute a process to start a reaction, for example, with the sludge cement 108. The activator module 306 may include a membrane or other element that encloses the activators. In these examples, the activator module 306 can move, remove, or otherwise open the element to release the activators to the cement sludge 108. The activator module 306 can include a heating element in the wrapping element, which encloses a chemical unitary, a binary chemical set, with a rupture membrane, unitary chemical with a rupture membrane, and / or other configurations that release involved activators. Transducer 308 can convert external stimulus to 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 (e.g., RF, infrared, X ray). acoustic, optical, VCF, nuclear (e.g., gamma, alpha, beta, neutron), and / or other signals.
[00064] Logic 310 can generate voltages to operate the activator module 306 using power module 312 and in response to at least the signal from the transducer. For example, logic 310 can dynamically switch between a “GO” state and a “DO NOT GO” state in response to at least the signals from the transducer. In some implementations, logic 310 can perform one or more of the following: receiving power from power module 312, receiving one or more signals from the transducer from transducer 308, generating one or more signals to the activator module 306 using power received; transmit signals to the activator module 306 to activate the release of one or more activators; and / or other processes. The 310 logic can be complementary to metal oxide semiconductor (CMOS), transistortransistor (TTL), bipolar, radiofrequency (RF) logic, and / or other types of
Petition 870190078938, of 8/14/2019, p. 40/71 / 60 devices. Power module 312 provides power to device 110. For example, power module 312 can be a voltage generator that provides enough current to operate logic 310. Module 312 can be a thin and / or thick film battery, components of a battery, one or more capacitors, one or more coils of induction handle, and / or other elements that store energy.
[00065] Figures 4A-C illustrate an example of implementations of activator devices 110 that release the one or more activators. In these implementations the device 110 can comprise a MEMS acoustic trigger for controlled distribution of the additives under command to a cement sludge. The devices 110 can enable the properties of the cement to be made to measure, once the cement sludge has been pumped down the hole (for example, delayed, accelerated "in situ"). Devices 110 can release activators by moving one or more elements, resistively heating one or more elements to form at least one opening, scraping or chemically etching one or more elements, and / or other processes. In some implementations such a device 110 may relay the activation signals to other devices 110. The following implementations are for illustrative purposes only, and the device 110 may release activators using some, all, or none of these processes.
[00066] Referring to figure 4A, the activator device 110 mechanically moves element 402 to release activators 404. In some embodiments, device 110 may include a MEM device that terminates activators 404 when element 402 is in a first position . In response to at least one signal, element 402 can rotate around an axis to a second position that releases activators 404 into cement slurry 108. In some implementations, the activation signal can directly move element 402 For example, the
Petition 870190078938, of 8/14/2019, p. 41/71 / 60 activation can structurally change the shape of element 402 by means of, for example, an ultrasonic signal. In some implementations device 110 may switch element 402 between two positions at a specified frequency to assist or otherwise increase the speed of dispersion of activators 404 into cement sludge 108. Referring to figure 4B, the activating 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 the activators 404. In addition to metal membranes, element 402 may be of other materials such as a polymer. Referring to figure 4C, device 110 includes activators 404 and releases chemicals 406 that remove at least a portion of element 402 to release activators. In the illustrated example, device 110 includes a first reservoir 412 that encloses the activators 404 and a second reservoir 414 that terminates the release of chemicals 404 using a retaining element 410. The first reservoir 412 and the second reservoir 414 can be configured to communicate directly from the case via valve system 408. In a first position, valve system 408 can substantially prevent the flow of chemicals release 406 to the first reservoir 412. In the second position the release of chemicals 406 can flow from the second reservoir 414 for first reservoir 412 through valve system 408. In the illustrated implementation the release of chemicals 406 reacts with element 402 to form an opening that releases activators 404 for cement slurry 108. For example, the release of chemical products 406 can each record or otherwise dissolve element 402.
Petition 870190078938, of 8/14/2019, p. 42/71 / 60 [00067] Figures 5 and 6 are flowcharts that illustrate examples of methods 500 and 600 for implementing and manufacturing devices that include one or more activators. The illustrated methods are described in relation to the well system 100 of figure 1, however these methods could be used by any other system. In addition, well system 100 can use any other techniques to perform these tasks. Thus, several of the steps in these flowcharts can take place simultaneously and / or in a different order than shown. The well system 100 can also use methods with additional steps, fewer steps and / or different steps, as long as the methods remain appropriate.
[00068] Referring to figure 5, method 500 starts at step 502 where activation devices are selected based, at least in part, on one or more parameters. For example, activation devices 110 and enclosed activators can be based, at least in part, on components of cement slurry 108. In some implementations activation devices 110 can be selected based on borehole conditions below, for example, temperature. In step 504 the selected activation devices are mixed with a cement sludge. In some examples, the activation devices 110 can be mixed with the cement sludge 108, when the truck 130 pumps the sludge into the ring crown 122. In some examples the activation devices 110 can be mixed with dry cement before generating cement slurry 108. Then, in step 506, the cement sludge that includes the activation devices is pumped down the hole. In some cases, cement sludge 108, which includes activation devices 110, can be pumped into circular ring 122 at a specified speed. One or more activation signals are transmitted to at least a portion of the cement mud hole below, in step 508. Again, in the example, the transmitter may be lowered into the jacketing to transmit signals to a portion of the
Petition 870190078938, of 8/14/2019, p. 43/71 / 60 cement 108. In this example the transmitted signals can activate the devices 110 next to the shoe 140 to adjust that portion of the cement sludge 108, as illustrated in figure 2B. In some cases the pipe column 116 can be moved, for example, up / down, to assist in distributing the activators as desired.
[00069] Referring to figure 6, method 600 starts at step 602 where a substrate with a passivation layer is identified. For example, the substrate 302 that includes the passivation layer 304 of figure 3 can be identified. In steps 604 and 606 the power modules, transducer and at least a portion of the activation module are manufactured. A reservoir in the activation module is also manufactured. In the example, transducer 308, logic 310, power module 312, and at least a portion of the activation module 306 are manufactured. In this example, a reservoir for enclosing at least a portion of the activators such as the reservoirs illustrated in figures 4A-C. In step 608, activators are deposited in the reservoir. As for the example, activators 404 can be deposited in the reservoirs illustrated in figures 4A-C. Then, in step 610, a membrane is fabricated over the reservoir to substantially enclose the activators. Again in the example, element 402 can be manufactured to wrap activators 404 in the reservoir.
[00070] Figure 7 illustrates an example of well system 100 in connection with transmission of activation signals to cement sludge 122. For example, system 100 can wirelessly transmit electromagnetic signals to cement sludge 108 that include a request to release activators in cement sludge 108. In the illustrated example, system 100 includes an inner medium 702 and a signal source 706 connected to inner medium 702 and to the pipe column 116 via connections 708a and 708b, respectively. The 708 connections can be ohmic contacts capacitively coupled and / or others. In some implementations the column of
Petition 870190078938, of 8/14/2019, p. 44/71 / 60 piping 116 can be a hot path (flap ( )) For signals. For example, the pipe column 116 may be a continuous metal path or a metallic path with a finite number of discontinuities. In the latter, each portion may result in a modest step attenuation. In addition, the inner medium 702 can be at least partially enclosed in one or more shells or inner tube 704.
[00071] In some implementation, system 100 may allow signal transduction down a long tube using leaking feeder principles (LP-LF). In these cases the system 100 can transduce a signal using one or more of the following: the pipe column 116, the surface jacketing 124; and / or one or more inner tubes 704. The surface pipe column 116 may be 100 m or longer in length. Inner tube 704 can be 100 m or less in length. The inner medium 702 can be metal, air and / or a liquid. In some implementations the surface pipe column 116 and / or the inner pipe 704 can be used as an additional hot path that is out of phase with the jacketing signal and / or a different signaling waveform. The 706 signal source can be any hardware, software and / or firmware that generates an electrical signal. A connection between the signal source 706 and the pipe column 116 may include return paths through one or more of the following: cement slurry 108; surface jacketing 120; the non-production zone 104; the inner middle 702 hulls of tube 704; and / or others. Cement sludge 108 can be very basic (e.g., pH 13) and a loss medium that attenuates the return signal. The signal source 706 can produce voltages that vary over time, which are propagated down conduits such as the pipe column 116. The signal source 706 can propagate one or more of the following frequencies: ultra-low frequency (ULF) such as 0.1 Hz to 10 Hz; very low frequency (VLF) such as 10 Hz to 30 Hz; low frequency (LF) such as 30 Hz to 30 MHz, frequency
Petition 870190078938, of 8/14/2019, p. 45/71 / 60 high (HF, such as 3MHz to 30MHz; very high frequency (VHF) such as 30MHz to 300 MHz; and / or ultra high frequency (UHF) such as greater than 300 MHz. In some implementations the source signal strength can produce 12-bit coding on-off (OOK) coding at a rate of 4800 baud and Fventer = 13.5 MHz. In these implementations the signal source 706 can directly drive the column of pipe 116 and trigger the jacketing of surface 120 180 ° out of phase In addition, inner tube 704 may not be activated and connections 706 can be capacitively coupled.
[00072] Figures 8A and 8B illustrate an example of power module 312 of figure 3 according to some implementations of the present description. In the illustrated implementation, energy module 312 can use an alkaline or acid environment, generated for example by means of cement sludge 108. In these cases, energy module 312 can generate a voltage difference using cement sludge 108 and independent of storing energy using, for example, a battery or 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. The power module example 312 is for illustration purposes only and module 312 may include any, all, or none of the elements illustrated, without departing from the scope of this description.
[00073] The illustrated power module 312 includes a first metal element 802 and a second metal element 804, which form the terminals of the power module 312. In this case, the first metal element 802 and the second metal element 804 react with the sludge surrounding cement 108 to generate a different voltage between the two terminals. The first metal element 802 and the second metal element 804 are partially at least surrounded by the passivation layer 304 on substrate 302. As discussed earlier, substrate 302 can
Petition 870190078938, of 8/14/2019, p. 46/71 / 60 comprise silica, glass, sapphire, flexible organic material, and / or other materials. The passivation layer 304 includes a first opening 806a that exposes at least one surface to the portion of the first metal element 802, and a second opening 806b that exposes at least one surface or portion of the second metal element 804. Exposing the first metal element 802 and the second metallic element 804 a voltage difference is generated between these terminals. In addition, this voltage difference provides power for load 808 just like logic 310. The terminal is connected to load 808 through conductors 810a and 810b. The openings 806a and 806b can be formed, for example, by means of photolithography or a thick film printing process. In some implementations the substrate 302 may be silica and approximately 1 mm by 1 mm per 100μηι, and the cement sludge 100 may be in a pre-cured wet state. In these implementations the first metallic element 802 may be a metal such as zinc, and the second metallic element 804 may be a metallic salt such as manganese dioxide. The 802 and 804 elements can be deposited using thin film screening printing and can each be approximately 150μm by 150μm by 50μm. Again in these implementations, openings 806a and 806b can be 100μm by 100μm, and layer 304 can be made by BCB photographic image. The conductors or connections 810a and 810b can be thin film plating.
[00074] Referring to figures 9-11, methods for detecting and / or monitoring the position and / or condition of well bore compositions are illustrated such as, for example, seal conditions (for example, cement) using pressure sensors. MEMS 110-based data discussed earlier in relation to Figure 1. Even more particularly, the present description describes methods of monitoring the integrity and performance of well-hole compositions over the life of the well, using MEMS-based data sensors. Performance can be
Petition 870190078938, of 8/14/2019, p. 47/71 / 60 indicated by changes, for example, in several parameters that include, but are not limited to, moisture content, temperature, pH, and various concentrations of ions, (for example sodium ions, chloride, and potassium) of cement. In implementations, the methods comprise the use of embedded data sensors 110, capable of detecting parameters in a well bore composition 108, for example, a seal, such as cement. In some implementations, the methods provide sealant 108 assessment during mixing, placement and / or curing of seal 108 within well bore 106. In some implementations the method can be used for sealant assessment from placement and curing through its entire service life, and where applicable to a period of deterioration and repair. In implementations, the methods of this description can be used to extend the service life of the sealant, lower costs, and or to improve the creation of improved remediation methods. In addition, methods can be used to determine the location of seal 108 within a well bore 106, such as to determine the location of cement sludge 108 during primary cementation of a well bore 106, as further discussed here below.
[00075] The methods described herein comprise the use of various well bore 108 compositions, including seals and other well bore service fluids. As used herein, "well hole composition" includes any composition that can be prepared or otherwise provided on the surface, and placed down into well hole 106, typically by means of pumping. As used herein, a “seal” refers to a fluid used to hold components within a well bore or to plug or seal the empty space within well bore 106. Seals 108, in particular cement slurries and cement, are used as borehole compositions in several implementations described here, and it should be understood that the methods described
Petition 870190078938, of 8/14/2019, p. 48/71 / 60 here are applicable for use with other well bore compositions. As used herein, “service fluid” refers to a fluid used to drill, complete, rework, fracture, repair, treat, or in any way prepare or service a well bore 106, for recovery of materials residing in an underground formation 102 penetrated by well bore 106. Examples of service fluids include, but are not limited to, cement sludge, non-cement sealants, drilling fluids or sludge, spacer fluids, fracturing fluids, completion fluids, all of which are well known in the art. The service fluid is for use in a well bore 106 that penetrates an underground formation 102. It should be understood that underground formation covers both areas below exposed land and areas below ground covered by water, such as the ocean or clean water . Well hole 106 may be a substantially vertical well hole and / or may contain one or more side well holes, for example, as produced by means of directional drilling. As used herein, "components" are referred to as being integrated if they are formed in a common support structure placed in packaging of relatively small size, or otherwise assembled in close proximity together.
[00076] Referring to figure 9, method 900 is an example of a method of placing MEMS sensors in a well bore and gathering data. In block 902, data sensors are selected based on parameters or other conditions to be determined or sensed within the well bore. In block 904 a number of data sensors are mixed with a borehole composition, for example, a sealing mud. In some implementations, data sensors are added to the sealant by any methods known to those skilled in the art. For example, sensors can be mixed with a dry material, mixed with one or more liquid components, for example, water or a non-aqueous fluid, or
Petition 870190078938, of 8/14/2019, p. 49/71 / 60 combinations of them. Mixing can take place on site, for example, adding the sensors in a volume mixer such as a cement slurry mixer. The sensors can be added directly to the mixer, can be added to one or more component streams and then fed to the mixer, can be added downstream from the mixer, or combinations of them. In some implementations, data sensors can be added after a mixing unit and mud pump, for example, through a side contour. The sensors can be dosed in and mixed at the well site, can be pre-mixed in the composition, or one or more components of it and then transported to the well site. For example, sensors can be mixed dry with surrounding cement and transported to the well site, where a cement slurry is formed comprising the sensors. Alternatively or in addition, the sensors can be pre-mixed with one or more liquid components (for example, mixing water) and transported to the well site, where a cement slurry is formed comprising the sensors. The properties of the well bore composition or components therein may be such that the sensors distributed or dispersed therein do not deposit substantially during transportation or placement.
[00077] The sealing mud is then pumped down the hole in block 906, so the sensors are positioned inside the well hole. For example, sensors can extend over all or a portion of the length of the well hole adjacent to the jacketing. The sealing mud can be placed down the hole as part of a primary cementation, secondary cementation, or other sealing operation, as described in more detail here. In block 908 a data interrogator tool is positioned in an operable location to gather data from the sensors, for example, by lowering it into the well hole next to the sensors. In block 910 the data interrogator tool interrogates the
Petition 870190078938, of 8/14/2019, p. 50/71 / 60 data sensors, for example, sending an RF signal while the data interrogator tool passes through all or a portion of the well hole containing the sensors. The data sensors are activated to record and / or transmit data in block 912 via the signal from the data interrogator tool. In block 914 the data interrogator tool communicates data given to one or more computer components, for example, memory and / or microprocessor, which can be located inside the tool, on the surface, or both. The data can be used locally or remotely from the tool, to calculate the location of each data sensor and correlate the measured parameters to those locations to assess seal performance.
[00078] Referring back to figure 1, during cementation, or after curing the cement, a data interrogating tool can be positioned in the well bore 106 as in block 908 in figure 9. For example, the scraper can be equipped with a data interrogator tool and can read data from the MEMS while being pumped down the hole and transmit it to the surface. Alternatively or in combination, an interrogation tool can be run into the well hole following the completion of the cementation of a jacketing segment, for example, as part of the drill string during resumed drilling operations. Alternatively or in combination, the interrogator tool can be run down the hole via a cable line or other transport. The data interrogator tool can then be signaled to interrogate the sensors (block 910 in figure 9), whereby the sensors are activated to record and / or transmit data (block 912 in figure 9). The data interrogator tool communicates the data to a 914 processor, through the data sensor (and in the same way the cement sludge), position and integrity of cement can be determined by analyzing sensed parameters for changes, trends, values
Petition 870190078938, of 8/14/2019, p. 51/71 / 60 expected, etc. For example, such data can reveal conditions that can be adverse for curing cement. The sensors can provide a temperature profile over the length of the cement sheath with a uniform temperature profile in the same way indicating a uniform cure (for example produced by heat of hydration of the cement during curing) or a colder zone could indicate the presence of water that can degrade the cement during the transition from mud to cured cement. Alternatively or in combination, such data may indicate a zone of missing, reduced, minimal sensors, which could indicate a loss of cement corresponding to the area (eg, lost / empty or water inlet / wash zone). Such methods may be available with several cement techniques described here, such as conventional cementation or reverse primary cementation.
[00079] Due to the high pressure at which the cement is pumped during conventional primary cementation, pumping below the jacketing and over the circular ring fluid from the cement sludge can leak into existing low pressure zones, crossed by the borehole. well. This can adversely affect the cement and incur undesirable expense to remedy cement remediation operations, for example, compression cementation as discussed here below to position the cement in the circular crown. Such a leak can be detected by means of the present description, as previously described. In addition, conventional circulating cementation can be time consuming and therefore relatively expensive, since cement is pumped all the time down the pipe column 116 and back up into the circular crown 122.
[00080] One method of avoiding problems associated with conventional primary cementation is to employ reverse circulation primary cementation. Reverse circulation cementation is a technique term used to
Petition 870190078938, of 8/14/2019, p. 52/71 / 60 describe a method where a cement slurry is pumped down into the circular jacketing crown 122 instead of into the pipe column 116. The cement slurry displaces any fluid when it is pumped down into the crown circular 122. Fluid in the circular crown is forced downward in the circular crown 122 into the inside of the pipe column 116 together with any fluid in the jacketing and then back up to the surface of the earth 112. When cementing in reverse circulation, the shoe The casing 132 comprises a valve which is adjusted to allow flow into the pipe column 116 and then sealed after the cementing operation is completed. Once sludge is pumped to the bottom of the pipe column 116 and fills in the circular crown 122, pumping is finished and the cement is allowed to cure in the circular crown 122. Examples of reverse cementing applications are described in US Patent No. 6,920,929 and 6,244,342, each of which is hereby incorporated by reference in its entirety.
[00081] In some implementations of the present description sealing sludge comprising MEMS data sensors are pumped under the ring in reverse circulation applications, a data interrogator is located inside the well bore, for example, integrated into the jacketing shoe , and seal performance is monitored as described in relation to the conventional primary seal method described here above. In addition, the data sensors of the present description can also be used to determine the completion of a reverse circulation operation, as discussed further below.
[00082] Secondary cementation inside a well hole can be performed following primary cementation operations. A common example of secondary cementation is compressed cementation where a seal, such as a cement composition, is formed under pressure into one or more permeable zones within the well hole to seal
Petition 870190078938, of 8/14/2019, p. 53/71 / 60 such zones. Examples of such permeable zones include cracks, cracks, fractures, stripes, flow channels, voids, high permeability stripes, annular voids, or combinations thereof. More permeable areas may be present in the cement column that resides in the circular crown, a duct wall in the well hole, a circular micro-crown between the cement column and the underground formation and / or a circular micro-crown between the column cement and underground formation and / or a circular micro-crown between the cement column and the conduit. The sealant, for example, secondary cement composition, cures within the permeable zones, thereby forming a hard mass to plug those zones and prevent fluid from passing through it, that is, substantially prevents fluid communication between the well bore and formation through the permeable zone. Various procedures that can be followed to use a sealing composition in a borehole are described in US Patent number 5,346,012 which is hereby incorporated by reference in its entirety. In several implementations, a sealing composition comprising MEMS sensors is used to repair holes, channels, voids, and circular micro-crowns in the jacketing, cement sheath, gravel filling, and the like, as described in US Patent Nos. 5,121,795; 5,123,487 and 5,127,473, each of which is hereby incorporated by reference in its entirety. [00083] In some implementations, the method of the present description can be used in a secondary cementation operation. In these implementations, data sensors are mixed with a sealing composition, for example, a secondary cement sludge, in block 904 in figure 9, after or during positioning and hardening of the cement, the sensors are interrogated to monitor the performance of the cement secondary in a manner analogous to the incorporation and monitoring of data sensors in primary cementation methods described here above. For example, MEMS sensors can be used to check
Petition 870190078938, of 8/14/2019, p. 54/71 / 60 that the secondary seal is functioning properly and / or to monitor its long-term integrity.
[00084] In implementations, the methods of the present description are used to monitor cement sealers (for example, hydraulic cement), non-cement (for example, polymer, latex, or resin systems) or combinations of them, which can be used in primary and secondary applications with other sealant applications. For example, expandable tubulars such as tube, tube column, jacketing, coating, or the like, are often sealed in an underground formation. The expandable tubular (for example, jacketing) is placed in the well hole, a pedantic composition is placed into the well hole, the expandable tubular is expanded, and the sealing composition is allowed to cure in the well hole. For example, after the expandable casing is placed below the hole, a mandrel can be run through the casing to expand the casing diametrically with possible expansions up to 25%. The expandable tubular can be placed in the well hole before or after the seal composition is placed in the well hole. The expandable tubular can be expanded before, during or after curing of the sealing composition. When the tubular is expanded during or after curing of the sealing composition, resilient compositions will remain competent due to their elasticity and compressibility. Additional tubulars can be used to extend the borehole into the underground formation below the first tubular, as is known to those skilled in the art. Sealing compositions and methods of using compositions with expandable tubulars are described in US Patent numbers 6,722,433 and 7,040,404, and US Patent Publication number 2004/0167248, each of which is hereby incorporated by reference in its entirety. In expandable tubular implementations, the seals may comprise compressible hydraulic cement compositions and / or non-cement compositions.
Petition 870190078938, of 8/14/2019, p. 55/71 / 60 [00085] Compressible hydraulic cement compositions have been developed, which remain competent and continue to support and seal the tube when compressed, and such compositions may comprise MEMS sensors. The sealing composition is placed in the circular crown between the well bore and the tube or tube column, the seal is allowed to harden into an impermeable grease and thereafter the expandable tube, or tube column, is expanded by that, the hardened sealing composition is compressed. In implementations, the compressible foam sealing composition comprises a hydraulic cement, a latex rubber, a latex rubber stabilizer, a gas and a mixture of foaming and foam stabilizing surfactants. Suitable hydraulic cements include, but are not limited to, Portland cement and calcium aluminate cement. In some implementations the curable composition may include a polymeric additive. The polymeric additive can be a monomer, a prepolymer, an oligomer or a short chain polymer that polymerizes in response to a 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 self-catalyzing free radicals initiate polymerization of at least a portion of the curable composition.
[00086] Often resilient non-cement seals with comparable strength to cement, but greater elasticity and compressibility, are required to cement an expandable casing. In some implementations these seals comprise polymeric seal compositions, and such compositions can comprise MEMS sensors. In some implementations the sealing 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,
Petition 870190078938, of 8/14/2019, p. 56/71 / 60 chrome and cadmium. The compounds can be in the form of an oxide, carboxylic acid salt, a complex with a dithiocarbonate ligand, or a complex with a mercaptobenzothiazole ligand. In some implementations the seal comprises a mixture of latex, dithiocarbamate, zinc oxide and sulfur.
[00087] In some implementations, the methods of the present description comprise adding data sensors to the seal to be used behind an expandable casing to monitor the integrity of the seal upon expansion of the casing and during the service life of the seal. In this implementation the sensors can comprise MEMS sensors capable of measuring, for example, humidity and / or temperature change. If the sealant develops cracks, water ingress can thus be detected by indicating humidity and / or temperature.
[00088] In one implementation, the MEMS sensor is added to one or more compositions that serve the well hole, used or placed down the hole in drilling or complementing a single diameter well hole, as described in US Patent number 7,066,284 and US Patent Publication number 2005/0241855, each of which is hereby incorporated by reference in its entirety. In one implementation, MEMS sensors are included in a chemical jacketing composition used in a single-diameter borehole. In another implementation, MEMS sensors are included in compositions (for example, seals) used to place expandable or tubular jackets in a single-diameter well bore. Examples of chemical jackets are described in US Patent numbers 6,702,044; 6,823,940 and 6,848,519, each of which is hereby incorporated by reference in its entirety.
[00089] In some implementations MEMS sensors are used to gather seal data and monitor the long-term integrity of the seal composition placed in a borehole, for example, a borehole for the recovery of natural resources such as water or
Petition 870190078938, of 8/14/2019, p. 57/71 / 60 hydrocarbons, or an injection well for disposal or storage. In an implementation, data and information gathered and / or derived from MEMS sensors in a borehole hole seal below, comprises at least a portion of the input and / or output into one or more calculator, simulations or models used to predict, select and / or monitor the performance of well bore seal compositions over the life of a well. Such models and simulators can be used to select a seal composition comprising MEMS for use in a well bore. After placement in the borehole, MEMS sensors 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 hole conditions below which the seal is subjected and seal performance can be correlated to such long-term data, to provide an indication of problems or potential for problems in the same or in different well holes. In several implementations, data gathered from MEMS sensors is used to select a seal composition, or otherwise evaluate or monitor such sealants as described in US Patent numbers 6,697,738; 6,922,637 and 7,133,778, each of which is incorporated herein for reference in its entirety.
[00090] Referring to figure 11, a method 1100 for selecting a sealant (for example, a cementation composition) to seal an underground area penetrated by a well hole according to the present implementation, basically comprises determining a group of compositions effective from a group of compositions given estimated conditions experienced during the life of the well, and estimate the risk parameters for each of the group of effective compositions. In an alternative implementation, actual measured conditions experienced during the life of the well, in addition to or in place of the estimated conditions, may be
Petition 870190078938, of 8/14/2019, p. 58/71 / 60 used. Such actual measured conditions can be obtained, for example, through seal compositions that comprise MEMS sensors as described here. Effectiveness considerations include concerns that the sealing composition is stable under pressure and temperature conditions bore down, resist chemicals bore down, and has mechanical properties to withstand stresses from various bore down operations to provide zonal insulation for well life .
[00091] In step 1102 well input data for a particular well is determined. Well input data includes routinely measurable or calculable parameters inherent in a well, which include vertical well depth, overfill gradient, pore pressure, maximum and minimum horizontal stresses, hole size, outer casing diameter, inner diameter casing density, drilling fluid density, desired density of pumping sealant mud, completion fluid density and sealant top. As will be discussed in more detail with reference to step 1104, the well can be modeled by computer. In modeling, the stress state of the well at the end of drilling and before the sealing mud is pumped into the annular space affects the stress state for the interface limit between the rock and the sealing composition. Thus, the stress state in the rock with the drilling fluid is assessed and rock properties, such as Young's modulus and Poisson's ratio and flow parameters, are used to analyze the rock's stress state. These terms and their methods of determination are well known to those skilled in the art. It is understood that well input data will vary between individual wells. In an alternative implementation, well input data includes data that is obtained by means of sealing compositions that comprise MEMS sensors as described here.
[00092] In step 1104 the well events applicable to the well are
Petition 870190078938, of 8/14/2019, p. 59/71 / 60 determined. For example, cement hydration (curing) is a well event. Other well events include pressure testing, well completions, hydraulic fracturing, hydrocarbon production, fluid injection, drilling, subsequent drilling, formation movement as a result of producing hydrocarbons at high rates from unconsolidated formation, and tectonic movement after the sealing composition has been pumped into place. Well events include those events that are certain to happen during the life of the well, such as cement hydration, and those events that are easily predictable as to occur during the life of the well given the well's particular location, rock type, and other well factors known in the art. In one implementation, well events and data associated with them can be obtained through seal compositions that comprise MEMS sensors as described herein.
[00093] Each well event is associated with a certain type of stress, for example, cement hydration is associated with shrinkage, pressure testing is associated with any pressure, well completions, hydraulic fracturing and hydrocarbon production, are associated with pressure and temperature, fluid injection is associated with temperature, formation movement is associated with loading, and drilling and subsequent drilling are associated with dynamic loading. As can be appreciated, each type of stress can be characterized by an equation for the stress state (collectively “well event stress states”) as described in more detail in US Patent number 7,133,778, which is what is used here incorporated for reference in its entirety.
[00094] In step 1106, well input data, well event stress states, and seal data are used to determine the effect of well events on the integrity of the seal sheath over the life of the well for each sealant compositions. Sealant compositions that could be effective for sealing the zone
Petition 870190078938, of 8/14/2019, p. 60/71 / 60 underground, and its capacity from its elastic limit, are determined. In an alternative implementation, the estimated effects over the life of the well are compared to, and / or corrected against, corresponding real data gathered over the life of the well by means of sealing compositions comprising MEMS sensors as described here. Step 1106 concludes by determining which sealing compositions could be effective in maintaining the integrity of the resulting cement sheath for the life of the well. [00095] In step 1108, seal failure risk parameters for effective seal compositions are determined. For example, even though one sealing composition is considered effective, one sealing composition can be more effective than another. In an implementation, the risk parameters are calculated as percentages of sealing competence during the determination of effectiveness in step 1106. In an alternative implementation, the risk parameters are compared with, and or corrected against, actual data gathered over the lifetime. from the well by means of sealing compositions comprising MEMS sensors as described here.
[00096] Step 1108 provides data that allows a user to perform a cost-benefit analysis. Due to the high cost of remediation operations, it is important that an effective sealing composition is selected for the anticipated conditions to be experienced during the life of the well. It is understood that each of the sealing compositions has an easily calculable monetary cost. Under certain conditions, several sealing compositions can be equally effective, but one can have the additional virtue of being less expensive. Thus, it should be used to minimize costs. More commonly, a sealing composition will be more effective, but also more expensive. Consequently, in step 1110 an effective sealing composition, with acceptable risk parameters, is selected given the desired cost. In addition, the overall results of
Petition 870190078938, of 8/14/2019, p. 61/71 / 60 steps 1102-1110 can be compared to actual data that is obtained by means of sealing compositions comprising MEMS sensors as described here, and such data can be used to modify and / or correct the inputs and / or outputs for the various steps 1102-1110, to improve their accuracy.
[00097] As discussed above, and with reference to figure 1 scrapers are often used during conventional primary cementation to force the cement sludge out of the jacketing. The scraper plug also serves another purpose typically, the end of a cementing operation is signaled when the scraper plug contacts a restriction (e.g., jacketing shoe) within the tubular column 116 at the bottom of the column. When the plug contacts the restriction, a sudden increase in pressure at pump 130 is recorded. In this way, it can be determined when the cement has been displaced from the pipe column 116 and fluid flow returning to the surface through the coating ring 122 to.
[00098] In cementation with reverse circulation it may also be necessary to determine correctly when cement sludge. completely fills the ring crown 122. Continue to pump cement into the ring crown 122 after the cement has reached the far end of the ring crown 122, forces cement into the far end of the pipe column 116, which could incur in lost time whether cement should be drilled to continue drilling operations.
[00099] The methods described here can be used to determine when cement slurry has been properly positioned down the hole. In addition, as discussed here below, the methods of the present description may additionally comprise using a MEMS sensor to actuate a valve or other mechanical device to close, and prevent cement from entering the jacketing when determining the
Petition 870190078938, of 8/14/2019, p. 62/71 / 60 complementing a cementing operation.
[000100] The manner in which the method of the present description can be used to signal when cement is properly positioned within the ring crown 122 will now be described within the context of a reverse circulation cementation operation. Figure 10 is a flowchart of a method to determine the completion of a cementation operation and, optionally, still act a tool bore down when complementing, or to start complementing the cementation operation. This description will make reference to the flowchart of figure 10, as well as the outline of the well hole in figure 1.
[000101] In block 1002 a data interrogator tool as described here below is positioned at the far end of the pipe column 116. In one implementation, the data interrogator tool is incorporated with, or adjacent to, a jacking shoe positioned at the end of bottom of the jacketing, and in communication with operators on the surface. In block 1004 MEMS sensors are added to a fluid (for example, cement slurry, spacer fluid, displacement fluid, etc.) to be pumped into the inner ring 122. In block 1006 cement sludge is pumped into the interior of the ring crown 122. In one implementation, MEMS sensors can be placed substantially across the cement slurry pumped into the well hole. In some implementations, MEMS sensors may be placed in a front plug or otherwise placed in an initial portion of the cement to indicate a leading edge of the cement sludge. In one implementation, MEMS sensors are placed in front and rear plugs to signal the start and end of the cement sludge. Although cement is pumped continuously into the ring 122, in decision 1008, the data interrogator tool (DIT) is trying to detect whether the data sensors are in close proximity to communication with the
Petition 870190078938, of 8/14/2019, p. 63/71 / 60 data interrogation tool. As long as no data sensor is detected, pumping additional cement into the ring continues. When the data interrogator tool detects the sensors in block 1010, which indicates that the front edge of the cement has reached the bottom of the jacketing, the interrogator sends a signal to end pumping. The cement in the circular crown is allowed to cure and form a substantially impermeable mass that physically supports and positions the jacketing in the well hole, and connects the jacketing to the well hole walls in block 1020.
[000102] If the fluid in block 1004 is cement sludge, MEMS-based data sensors are incorporated into the cured cement and cement parameters (eg temperature, pressure, ion concentration, stress, strain, etc.) can be monitored during laying, and for the service life of the cement, according to methods described here above. Alternatively or in combination, the data sensors can be added to an interface fluid (e.g., spacer fluid or other buffer fluid) introduced into the ring before and / or after the introduction of cement sludge into the ring.
[000103] The method just described for determining the completion of a well hole primary cementing operation may additionally comprise the activation of a hole tool below. For example, in block 1002 a valve or other tool can be operationally associated with a data interrogating tool at the far end of the jacketing. This valve can be contained within the floating shoe 132, for example, as described here above. Again, the floating shoe 132 may contain an integrated data interrogator tool or may be otherwise coupled to a data interrogator tool. For example, the data interrogator tool can be positioned between pipe column 116 and floating shoe 132.
Petition 870190078938, of 8/14/2019, p. 64/71 / 60
Following the method described above, and blocks 1004 to 1008, pumping continues when the data interrogator tool detects the presence or absence of data sensors in close proximity to the interrogator tool (depending on the specific method of cementation method being employed, for example example, reverse circulation, and the positioning of the sensors within the cement flow). When detecting a determinant presence or absence of sensors in close proximity, which indicates the end of the cement sludge, the data interrogator tool sends a signal to actuate the tool (for example, valve) in block 1012. In block 1014 a valve closes, sealing the jacketing and preventing cement from penetrating the jacketing column portion above the valve in a reverse cementation operation. In block 1016, closing the valve in 1016 causes an increase in back pressure that is detected in hydraulic pump 130. In block 1018 pumping is discontinued and cement is allowed to cure in the ring in block 1020. In implementations where data sensors have been incorporated through all cement, cement parameters, and thus cement integrity, can be additionally monitored during laying and for the service life of the cement, according to methods described here above.
[000104] Improved methods of monitoring well hole seal condition from placement through seal service life as discussed here, provide numerous advantages. Such methods are able to detect changes in parameters in the well bore seal, such as moisture content, temperature, pH, and ion concentration (eg sodium and potassium chloride ions). Such methods provide this data to monitor the condition of the seal from the initial period of quality control during mixing and / or placement, through the service life of the seal, and through its period of deterioration and / or repair. Such methods
Petition 870190078938, of 8/14/2019, p. 65/71 / 60 are cost efficient and allow the determination of data in real time, using sensors capable of functioning without the need for a direct energy source, that is, passive, instead of active sensors, in such a way that the sensor size is kept to a minimum to maintain seal resistance and pumping capacity of seal mud. The use of MEMS sensors to determine well hole characteristics or parameters can also be employed in methods of pricing a treatment to serve a well, selecting a treatment to serve a well and / or monitoring a treatment to serve a well during its performance in real time, for example, as described in US Patent Publication number 2006/0047527 A1, which is hereby incorporated by reference in its entirety.
[000105] Although preferred implementations of the methods have been shown and described, modifications to them can be made by someone skilled in the art without departing from the teachings of the present description. The implementations described here are only taken as an example, and are not intended to be limiting. Several variations and modifications of the methods described here are possible and are within the scope of this description. Where numerical ranges or limitations are expressly described, such expressed ranges or limitations should be understood to include iterative ranges or limitations of similar magnitude and that fall within the ranges or limitations expressly described (for example, from approximately 1 to approximately 10 includes 2, 3 , 4, etc .; greater than 0.10 includes 011, 012, 0.13, etc.). The use of the term optionally in relation to any element of a claim, is intended to mean that the present element is required or, alternatively, is not required. Both alternatives are designed to be within the scope of the claim. The use of broader terms, such as understand, include, have, etc., should be understood to provide
Petition 870190078938, of 8/14/2019, p. 66/71 / 60 support for narrower terms such as consisting of, consisting essentially of, consisting substantially of, etc.
[000106] Consequently, the scope of protection is not limited by the description provided above, but is only limited by the claims that follow, this scope including all equivalents of the subject of the claims. Each and every claim is incorporated into the specification as an implementation of this description. Thus, the claims are another description and are in addition to the preferred implementations of the present description. The discussion of a reference here is not an admission that it is technical prior to the present description, especially any reference that may have a publication date after the priority date of this Order. The descriptions of all Patents, Patent Applications and Publications cited here are hereby incorporated by reference to the extent that they provide examples, procedures, other details in addition to those described here. Numerous implementations of the invention have been described. However, it will be understood that several modifications can be made without departing from the scope of the invention. Consequently, other implementations are within the scope of the following claims.

权利要求:
Claims (20)
[1]
1. Method to treat an underground formation, characterized by the fact of understanding:
placing a curable composition that includes an activation device in a well bore, in which the activation device is used to increase the curing speed of the curable composition in response to an activation signal; and transmitting the activation signal to the curable composition, to release an activator from the activation device.
[2]
2. Method according to claim 1, characterized by the fact that the curable composition is a cement composition, and in which the signal is transmitted to at least a portion of the cement composition, to activate the activation device, in which the activation device releases the activator in response to at least the signal.
[3]
Method according to either of claims 1 or 2, characterized in that the curable composition cures in a range from one hour to a day, after reacting with the activator.
[4]
Method according to any one of claims 1 to 3, characterized in that the activation device includes at least one dimension in a range from 1 pm to 10,000 pm.
[5]
Method according to any one of claims 1 to 4, characterized in that the signal comprises 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 in which the radiation signal comprises at least one of neutrons, alpha particles, or beta particles.
[6]
Method according to any one of claims 1 to 5, characterized by the fact that the activation device is a Micro-Electro-Mechanical System (MEMS) device.
Petition 870190078938, of 8/14/2019, p. 68/71
2/3
[7]
Method according to any one of claims 1 to 6, characterized in that the activation device mixes with the curable composition at a density in the range of 4 to 24 pounds per gallon (ppg) (0.47 2.88 kg / L).
[8]
Method according to any one of claims 1 to 7, characterized in that the curable composition includes a hydraulic cement, a base fluid, and a retarder.
[9]
Method according to any one of claims 1 to 8, characterized in that it additionally comprises transmitting a signal through a jacketing to activate the activation device.
[10]
10. Activation device, characterized by the fact that it comprises:
an activation module that encloses an activator that increases the curing speed of a cement composition;
a transducer that receives a wireless activation signal; and a logic module that transmits a release signal to the activation module, to release the activator in response to the transducer receiving an activation signal.
[11]
11. Activation device according to claim 10, characterized by the fact that the activation module includes an element that encloses the activator in a reservoir.
[12]
Activation device according to either of claims 10 or 11, characterized in that the activation signal causes an opening in the element to release the activator.
[13]
Activation device according to claim 12, characterized by the fact that the opening is based, at least in part, on resistive heating, chemical reaction or mechanically.
[14]
Activation device according to any of claims 10 to 13, characterized in that the activator module
Petition 870190078938, of 8/14/2019, p. 69/71
3/3 comprises a micro-electrical-mechanical system (MEMS) that moves a portion of the activation module to release the activator in response to an activation signal.
[15]
Activation device according to claim 14, characterized in that the MEMS switches the portion of the activation module between an open position and a closed position at a specified frequency to disperse the activator in the cement composition.
[16]
Activation device according to any one of claims 10 to 15, characterized in that it additionally comprises a power module that energizes the logic module.
[17]
Activation device according to any one of claims 10 to 16, characterized in that the activation device mixes with the cement.
[18]
Activation device according to any one of claims 10 to 17, characterized in that the activation module includes at least one dimension in a range from 1 pm to 10,000 pm.
[19]
Activation device according to any one of claims 10 to 18, characterized in that it additionally comprises a power module that generates a voltage difference between two terminals that use an alkaline environment of the cement composition.
[20]
Activation device according to any one of claims 10 to 19, characterized by at least one of: the activation signal comprises 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 in which the radiation signal comprises at least one of neutrons, alpha particles, or beta particles; and, the activation device mixes with the curable composition at a density in the range of 4 to 24 pounds per gallon (ppg) (0.47 to 2.88 kg / L).

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同族专利:

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公开号 | 公开日

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AR077946A1|2011-10-05|

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CA2771626C|2014-02-25|

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US20100051275A1|2010-03-04|

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US8162055B2|2012-04-24|

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WO2011023942A2|2011-03-03|

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CA2771626A1|2011-03-03|

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MX339042B|2016-05-05|

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GB2486138A|2012-06-06|

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GB2486138B|2014-05-28|

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NO344321B1|2019-11-04|

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BR112012004180A2|2016-03-29|

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MX2012002397A|2012-04-11|

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WO2011023942A3|2011-06-16|

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NO20120198A1|2012-05-25|

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GB201205235D0|2012-05-09|

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法律状态:
2019-01-08| B06F| Objections, documents and/or translations needed after an examination request according [chapter 6.6 patent gazette]|

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2019-06-04| B15K| Others concerning applications: alteration of classification|Free format text: AS CLASSIFICACOES ANTERIORES ERAM: E21B 33/14 , C04B 40/02 Ipc: E21B 23/00 (1968.09), E21B 27/02 (1995.01), E21B 3 |

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2019-07-02| B06A| Patent application procedure suspended [chapter 6.1 patent gazette]|

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2019-09-10| B09A| Decision: intention to grant [chapter 9.1 patent gazette]|

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2021-06-29| B21F| Lapse acc. art. 78, item iv - on non-payment of the annual fees in time|Free format text: REFERENTE A 11A ANUIDADE. |

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2021-10-19| B24J| Lapse because of non-payment of annual fees (definitively: art 78 iv lpi, resolution 113/2013 art. 12)|Free format text: EM VIRTUDE DA EXTINCAO PUBLICADA NA RPI 2634 DE 29-06-2021 E CONSIDERANDO AUSENCIA DE MANIFESTACAO DENTRO DOS PRAZOS LEGAIS, INFORMO QUE CABE SER MANTIDA A EXTINCAO DA PATENTE E SEUS CERTIFICADOS, CONFORME O DISPOSTO NO ARTIGO 12, DA RESOLUCAO 113/2013. |

优先权:

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申请号 | 申请日 | 专利标题

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US12/547,233|US8162055B2|2007-04-02|2009-08-25|Methods of activating compositions in subterranean zones|

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US12/547233|2009-08-25|

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PCT/GB2010/001590|WO2011023942A2|2009-08-25|2010-08-23|Methods of activating compositions in subterranean zones|

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