MX2014006127A

MX2014006127A - Releasing activators during wellbore operations.

Info

Publication number: MX2014006127A
Application number: MX2014006127A
Authority: MX
Inventors: Ronald Sweatman; Carl Thaemlitz; Gregory Perez; Daniel Lee Bour
Original assignee: Halliburton Energy Serv Inc
Priority date: 2011-11-22
Filing date: 2012-10-10
Publication date: 2014-08-27
Also published as: WO2013077947A1; BR112014012266A2; AU2016202803A1; EP2783067A1; US20130126164A1; CA2853441A1; EP2783067A4; EA201490848A1; AR088878A1; AU2012341053A1; CA2853441C; MX348275B

Abstract

In some implementations, a method for reducing material loss includes adding, to a downhole fluid circulated through a drill string, encapsulants encapsulating one or more activators. One or more parameters in a wellbore associated with a fault in operating conditions are determined. One or more energy waves in the downhole fluid configured to release the one or more activators from the encapsulants are emitted.

Description

RELEASE OF ACTIVATORS DURING OPERATIONS OF WELLS FIELD OF THE INVENTION This invention relates to well operations and, more particularly, to the release of encapsulated activators during well operations.

BACKGROUND OF THE INVENTION Some wells, for example, those of some oil and gas wells, use fluids inside the well during operations such as drilling, cementing, and others. For example, a fluid inside the well can be introduced into an annular space between the coating / perforation chain and the surrounding earth. As for the cementation, the fluid inside the well can ensure the lining in the well and prevent fluids from flowing vertically in the ring between the lining and the surrounding earth. Different formulations of fluid are designed for a variety of conditions that well and operating conditions, which may be above the ambient temperature and pressure. In the design of the fluid formulation, a number of potential mixtures can be evaluated to determine their mechanical properties under different conditions.

BRIEF DESCRIPTION OF THE INVENTION In some implementations, a method to reduce the loss of material includes adding, to a fluid inside the well that circulates through a drill string, encapsulants that encapsulate one or more activators. One or more parameters are determined in a well associated with a fault in operating conditions. One or more energy waves are emitted in the fluid inside the well configured to release said one or more activators from the encapsulants.

The details of one or more embodiments of the invention are set forth in the accompanying drawings and the description below. Other features, objects, and advantages of the invention will be apparent from the description and drawings, and from the claims.

BRIEF DESCRIPTION OF THE DRAWINGS Figure 1 is an exemplary well system for producing fluids from a production zone.

Figure 2 is an exemplary well system for producing fluids from a production zone.

Figures 3A and 3B illustrate an exemplary activating device for activating cement slurry in a well.

Figures 4A and 4B illustrate exemplary processes for releasing activators in cement slurries.

Figure 5 is a flow diagram illustrating an exemplary method for updating one or more properties of the fluid within the wellbore.

The symbols of similar references in the different drawings indicate similar elements.

DETAILED DESCRIPTION OF THE INVENTION The present disclosure is directed to one or more well systems having a fluid delivery system that selectively releases activators configured to update one or more properties of a fluid inside the well. For example, the described system can release encapsulated active ingredients at selected subsurface locations in wells to substantially prevent the loss of the drilling fluid through a subsurface fracture or to control an influx of fluid from the formation. A fluid inside the well may include a settable material (eg, a cementitious fluid), a drilling fluid, a termination fluid, a "kill" fluid (controls inflows), and / or others. For example, the fluid inside the well can be a cementing fluid in such a way that released chemicals accelerate the speed of associated setting. Said one or more updated properties may include a setting speed, viscosities, solubility, lubrication, development of static gel strength (SGS, Static Gel Strenght), density, development of compressive strength, and / or others. The activators may be released in response to at least detect influx of pore fluid from the formation of or loss of fluid within the well within one or more subterranean areas exceeding a predefined threshold and may be configured to activate and / or Accelerate the setting process for a fluid or grout in a well. By dynamically altering the properties of a fluid inside the well, the system can provide one or more of the following: greater savings to the client would include savings in rig time (~ $ 500K / day (dollars per day) for deepwater drilling equipment); savings of lost drilling and cementing fluids; reduction in the WOC time of the cement, elimination of costs of cementing by correction; savings of waiting time in less effective systems (that is, like Portland cement) so that they set in +/- 8 hours; mitigate losses and / or inflows that cause loss of well control incidents (costs of damage of millions of dollars) and / or others.

In some implementations, triggers are enclosed in a housing and released in response to the encapsulation failure activated or otherwise initiated by the system. Failure of shell encapsulation (ESF, Encapsulations Shell Failure) can include molecular resonance of chemical bonds fail you by fatigue, interruption of oriented structures of emulsified interfacial phases of the carcasses, alter the molecular surface loads of the carcass membranes, exceed the resistance to the attention or joining of the casing to generate cracks or other openings in the encapsulation housings, resonance heating and expansion of the internal phases to stress cracking the casings to induce leaks and / or internal phase releases, and / or other types of failure caused or otherwise associated with energy waves. Energy waves may include sonic / ultrasonic acoustic sound signals, tuned pulses of frequency and / or amplitude oscillating pressure (eg, Coanda effect), induced ultra-fast laser pulse desorption, vibrationally mediated dissociation photo, forms of electromagnetic wave, radio, and / or microwave, laser ablation, and / or other types of waves. In some implementations, the described systems may use energy waves (eg, ultrasound, pressure pulses, lasers, radiation) to release triggers configured to update one or more properties of the fluid inside the well in response, for example, for the detection of a fault in well operation conditions. An operational failure may include losses of circulating fluid above a specific threshold, a stuck drill pipe, a partially or completely occluded well, uncontrolled inflow of fluid from the formation (called "kicks"), underground explosions (flows no fluid control of the formation from one zone to another zone), surface bursts (fluxes without fluid control from the formation to the surface), and / or others. Alternatively or in combination, energy waves can directly update the physical properties of chemicals in the fluid inside the well by using one or more different mechanisms sensitive to energy waves. Said one or more different mechanisms may include modifying the chemical properties, releasing chemicals, modifying the physical properties (eg, particle size), updating the operating conditions (eg, pressure, temperature), and / or other mechanisms sensitive to energy waves. For example, the systems described may use energy waves to directly heat chemicals to increase their rate of reaction with other materials.

Referring to Figure 1, system 100 is a well system in cross section 100 that updates the properties of fluids inside the well in response to detecting at least one operational failure. In the illustrated implementation, the well system 100 includes a production zone 102, a non-production zone 104, the well 106, the fluid inside the well 108, and the encapsulants 110. The production zone 102 can be an underground formation that includes resources (eg, oil, gas, water). The non-production zone 104 can be one or more formations that are isolated from the well 106 using cement and / or other insulators. For example, zone 104 includes contaminants that, if mixed with resources, may result in requiring additional processing of resources and / or making production economically unfeasible. The fluid inside the well 108 can be selectively pumped or positioned in the well 106, and the properties of the fluid inside the well 108 can be updated using the encapsulants 110. In some implementations, the encapsulants 110 can release activators in response to the energy waves initiated by, for example, a user of the system 100. By remotely controlling the properties, a user can configure the system 100 without substantially interfering with the well operations. While the figure illustrates using the encapsulants with the carburizing operations, the encapsulants 108 can be used during other types of operations such as drilling without departing from the scope of this disclosure.

Turning to a more detailed description of the elements of the system 100, the well 106 extends from a surface 112 to the production area 102. The well 106 may include a drilling equipment 114 which is located near the surface 112. The equipment perforation 114 may be coupled to a liner 116 extending the entire length of the well or a substantial portion of the length of the well 106 from approximately the surface 112 to the production zones 102 (e.g., reservoir containing hydrocarbons) . In some implementations, the cladding 116 may extend past the production zone 102. The cladding 116 may extend to about a terminus 118 of the well 106. In some implementations, the well 106 may be completed with the cladding 116 extending at a predetermined depth near the production zone 102. In short, the well 106 initially extends in a vertical direction to the production zone 102. In some implementations, the well 106 may include other portions that are horizontal, inclined or deflected of other shape of the vertical.

The drilling equipment 114 may be centered over an underground oil or gas formation 102 located below the surface of the ground 112. The drilling equipment 114 includes a work cover 124 that supports a drilling tower 126. The tower perforation 126 supports an extraction apparatus 128 for raising and lowering chains such as coating 116. Pump 130 is capable of pumping a variety of fluids into well 108 (eg, drilling fluid, cement) within of the well and includes a pressure measuring device that provides a pressure reading on the discharge of the pump. Well 106 has been drilled through the different layers of soil, including formation 102. Upon completion of the well borehole, liner 116 is often placed in well 106 to facilitate the production of oil and gas from the well. formation 102. The liner 116 is a chain of tubes that extends down into the well 106, through which the oil and gas will eventually be extracted. A cement or tubing shoe 132 is typically attached to the end of the coating chain when the coating chain is run into the well. The lining shoe 132 guides the liner 116 towards the center of the hole and can to minimize or otherwise reduce the problems associated with hitting rock overhangs or landslides in the well 106 as the casing chain is lowered into the well. The lining shoe 132 may be a guided shoe or a float shoe equipped with the open bottom part and a valve that serves to prevent the reverse flow, or U-pipe, of the fluid inside the well 108 from the ring 122 to the interior of the liner 116 after the fluid inside the well 108 has been placed inside the ring 122. The region between the liner 116 and the wall of the well 106 is known as the lining ring 122. To fill the lining ring 122 and securing the liner 116 in place, the liner 116 is usually "cemented" into the well 106, which is termed as "primary carburizing." In some implementations, the fluid inside the well 108 can be injected into the well 106 through one or more ports 134 in the lining shoe 132. The fluid inside the well 108 can flow through a hose 136 within the liner 116. In some cases, where the liner 116 does not extend the full length in the well 106 to the surface 112, the liner 116 may be supported by a liner hanger 138 near the bottom of a pre-lining 120 In the implementation that illustrated, the lining shoe 132 includes a wave generator 140 that includes any hardware, software, or firmware configured to generate one or more energy waves near the term of the liner 116.

As previously mentioned, the wave generator 140 can generate energy waves including one or more of the following: sonic and / or ultrasonic acoustic sound signals, tuned pulses of frequency and / or amplitude oscillating pressure (e.g., Coanda Effect), induced ultra-fast laser pulse desorption, vibrationally mediated dissociation photo, electromagnetic, radio, and / or microwave waveforms, laser ablation, and / or other types of waves. The types and characteristics of ESF waves (frequency, amplitude, bandwidth, intensity, duration, etc.) can be selected to substantially match the wave attributes configured to break or otherwise form openings in the specific encapsulation housings . For example, the selected wave attributes can isolate and bring the internal phase materials into well 106 and deliver them to the desired location without significant leakage. In addition, the selected wave attributes can be used to spatially tune the release of the encapsulates within the confines of the well 106 or also material infiltrated in the formation. In In these cases, the activators can be delivered within the pore space before activation, which can enable the introduction of co-reactive in place with the mixed encapsulant systems. With respect to the radio and / or microwave, the inverted emulsion sludge can be decomposed to facilitate the recycling of water and oil in refineries, oil production facilities, etc. The application can work by microwave (electromagnetic fields that oscillate in the 915 MHz) that treat oil / water emulsions to destabilize them by breaking down the physical bonds that hold the emulsion together. This type of wave energy can be absorbed by polar and / or charged molecules, including water and surfactants, charged solids and aggregates of polar asphaltenes that stabilize the interface of the emulsion. As the wave fields oscillate, a temperature gradient can be stabilized through the oil / water interface, and the active molecules on the surface can begin to rotate and move around as they react with the changing fields. This can result in a decomposition of the stability of the surface and the emulsion. With respect to ultrasonic waves, these waves can break nano bubbles to release the activators. For example, micro-emulsions called nano bubbles in the fluid inside the well can transport activators to precise locations within the well where they are released by ultrasonic waves that break the encapsulating micro-emulsions. In other words, the ultrasonic ESF waveguide tools in the well can release encapsulated chemicals from nano bubbles at the desired locations inside the well without being exposed to contaminants that degrade performance in conventional placement methods.

In some implementations, the system 100 can update the properties of the fluid inside the well 108 using the encapsulants 110 during one or more well operations. In some implementations, the encapsulants 110 can be mixed in the fluid inside the well 108 before entering the casing 116, and the fluid inside the well 108 can then be pumped down into the interior of the casing 116. As mentioned previously, the encapsulants 110 may include one or more activators that update the properties of the fluid within the well 108 in response to at least one energy wave. For example, the leak or otherwise released activators can activate rapid gelation, hydration, swelling, expansion, foaming, and / or setting of at least a portion of the fluid in the interior of the well 108. For example, the activators can activate, initiate or increase the setting speed of the material of loss of circulation (LCM, Lost Circulation Material) and / or other materials of drilling / finishing / cementing fluid. The LCM and / or other material systems can be placed either by pumping them to an area and / or behind a tube (liner, sleeves, drill pipe), and / or can be activated as they pass through the tool in the inside the ESF wave well such as the generator 140 while being pumped in and out of a working chain (as illustrated). The encapsulants 110 may infiltrate the pore space of the formation, which may allow in-situ reactions such as pore throat sealing and / or stabilization of the formation. Other encapsulants 110 can be released at selected intervals from the well, which can increase the viscosity of the fluid inside the well to help slow down and control the kicks that migrate to the surface and to decrease or stop the uncontrolled flows in the well. bursts underground or on the surface. Additionally, infiltrated encapsulants 110 can be adapted for subsequent PE applications such as acidification. The activation or subsequent release of acidic materials may be able to acidify from behind of the filter cake. For example, in response to the detection that the loss of fluid reaches a specific threshold, the operator of the drilling equipment 114 can turn on the ESF 140 wave tool positioned near the end of a work chain by means of, for example , controls on the surface.

During cementing operations (as illustrated), both primary and corrective cementation can also use encapsulated LCM or other encapsulated materials such as accelerators, surfactants, blowing agents (aluminum powder, etc.), foam generation agents , etc. For primary cementation, the ESF 140 wave tool can be installed in the lining shoe or float collar 132 as discussed above. In some implementations, the tool 140 may be a non-recoverable, inexpensive, and very small ESF tool such as the "Pulsonix" device (PE PSL product) or modified version thereof that produces frequency / amplitude oscillating pressure pulses. tuned (Coanda effect) mounted on either side of the lower cleaning plug or inside the float collar. When the lower cleaning plug sits on the float collar and its rupture disc opens to derive the cement grout, part of the grout flows into the channel flow of the ESF wave tool to initiate the sending of ESF waves within the entire slurry flowing within the ring 122. As the encapsulation shells 110 are broken by the molecular resonance action of the ESF waves, they can be release the encapsulated materials and react in the ring 122 and carry out different functions such as sealing the loss zones, accelerating the development of the strength of the cement, controlling the migration of gas (shortening the transit times of SGS, activating the Latex or GasCheck additives, etc.), create in-situ foam cement, etc. For corrective cementing, the ESF 140 wave tool is mounted on a submersible at or near the bottom of the work chain and operated continuously or selectively (sending ESF waves). The latter can be initiated by dropping a dart or ball or by the same tool on / off control signal on the surface described above for drilling operations.

During drilling operations, ESF waves may be incident to a pill of the LCM loaded fluid while being pumped out of the drill (not shown). As the ESF waves pass through the LCM system, the encapsulated materials can be released to activate other LCM components creating the types of compounds for the LCM. effective sealing of the formation loss zone. After the activated LCM passes out of the drill and travels to the loss zone, the activators can rapidly react chemically in soft sealing agglomerates, hard osmotically swelling particles, and / or a combination of both and seal the zone. If this does not prove to be effective enough, a second type of LCM pill can be pumped in a similar manner. In this case after passing the ESF wave tool and leaving the zone of loss of circulation, the LCM can begin to set quickly in a hard sealing system. In other cases, the customer may add the encapsulated LCM into the total volume of the circulation sludge that is pumped in and out of the well such as during drilling operations. When drilling fluid losses occur, the operator can activate a switch on the surface control panel to initiate the sending of ESF waves from the ESF tool (located in or near the drill bit) to convert the LCM encapsulated in an LCM system for sealing of loss zones. The ESF tool can be turned off as losses decrease and returns are re-established within specific guidelines. An example of non-LCM applications related to well drilling, material Encapsulants can be used for mud property alterations in real time. The drilling fluid can be formulated to contain an encapsulated viscosity modifier, which with its release must specifically alter the rheology of the fluid in a region close to the drill bit instead of when compared to the fluid cyclization. Such spatial / temporal control can allow rapid tuning of the fluid or can be used to establish highly viscous "pills" in real time for zone isolation and / or other applications.

The potential encapsulated materials and the descriptions of their system recipes and applications can be customized for a plurality of different types of operation. For example, a well may be drilling with synthetic-based mud (SBM) and severe losses indicate that a large fracture size is pulling SBM out of the well. The operator can decide whether to apply the encapsulated LCM systems and have an ESF wave tool installed in the drill bit. An encapsulated LCM component may be in the water phase of the inverted SBM emulsion containing high concentrations of cement acceleration chemicals such as CaCl2. Other LCM system components can be selected based on the properties of the sealant in the inside the well to seal large fractures. The operator can select a "pill" of hard setting sealant with dry powder cement and a second encapsulated component such as "dry emulsion" powder of LATEX 2000 (cement) added to the synthetic oil phase of the SBM to make a " pill "in the" liquid pit "in the drilling rig. This pill can be a substantially improved version of the old LCM system called diesel-oil cement (DOC), where oil is an inert carrier fluid for cement. The new LCM system can also use synthetic petroleum as an inert carrier fluid for both cement and encapsulated latex. In addition, the water phase of the SBM can bring the agent to make the cement and water of hydration mixture elegant. The ESF wave tool can be tuned to decompose the inverted emulsion of SBM and can turn on as the new LCM "pill" comes out of the drill bit. The ESF waves decompose the inverted emulsion and release the water phase of SBM that mixes and reacts with the cement and latex to create a fast-setting sealant that is pressed into the interior and plugged into the fracture near the well.

As the fluid 108 reaches the bottom of the liner 116, it flows out of the liner 116 and into the interior of the lining ring 122 between the liner 116 and the wall of the well 106. In connection with the pumping of the fluid inside the well 108 into the ring, the generator 140 can emit one or more energy waves before, during , and / or after the pumping is complete to release one or more chemicals from the encapsulants 110. In response to at least the signal, the encapsulants 110 can release chemicals that update the properties of the fluid within the well 108 in the ring 122. Part or all of the liner 116 may be fixed to the adjacent floor material with set cement as illustrated in Figure 2. In some implementations, the liner 116 comprises a metal. After setting, the liner 116 may be configured to carry a fluid, such as air, water, natural gas, or to carry a power line, tubular chain, or other elements.

After positioning the liner 116, a settable grout 108 including the encapsulants 110 can be pumped into the ring 122 by means of a pump truck (not shown). While the following discussion will focus on the settable slurry 108 comprising a fluid inside the well 108, the settable slurry 108 may include other compounds such as resin systems, settable slurries, compliance fluids, loss of circulation, and / or other settable compositions. The cement slurries are discussed in more detail below. In connection with depositing or otherwise positioning the fluid within the well 108 in the ring 122, the encapsulants 110 can release activators to activate or otherwise increase the rate of setting of the fluid within the well 108 in response to at least ultrasound. In other words, the released activators can activate the fluid inside the well 108 to set cement in the ring 122.

In some implementations, the encapsulants 110 may release an activator that initiates or accelerates the setting of the fluid within the well 108. For example, the fluid within the well 108 may remain substantially in a slurry state for a period of time specific, and the encapsulants 110 can activate the grout in response to ultrasound. In some cases, the ultrasound may crack, break or otherwise form one or more holes in the encapsulants 110 to release the activators. In some cases, the ultrasound can generate heat that melts one or more holes in the encapsulants 110. The encapsulants 110 enclose the activators with eg a membrane such as a polymer (eg, polystyrene, ethylene copolymer / vinyl acetate, polymethyl methacrylate, polyurethanes, polylactic acid, polyglycolic acid, polyvinyl alcohol, polyvinyl acetate, ethylene / hydrolyzed vinyl acetate, or copolymers thereof). Encapsulant 110 may include other materials sensitive to ultrasound. In these implementations, the encapsulant 110 may include a polymer membrane that is ultrasonically degraded to release the entrapped activators. In some examples, an ultrasonic signal may structurally change the membrane to release the activators such as, for example, by opening a preformed slot in the encapsulants 110. In some implementations, at least one dimension of the encapsulants 110 may be microscopic such as in the range from 10 nanometers (nm) to 15,000 nm. For example, the dimensions of the encapsulants 110 can be on a scale of a few tens to about a thousand nanometers and can have one or more external shapes including spherical, cubic, oval and / or bar shapes. In some implementations, the encapsulants 110 may be housings with diameters in the range from about 10 nm to about 1000 nm. In other implementations, the encapsulants 110 may include a diameter in a range from about 15 micrometers to 10,000 micrometers. Alternatively or in combination, the encapsulants 110 may be made from metal (eg, gold) and / or non-metallic material (eg, carbon). In some implementations, the encapsulants 110 are coated with materials to improve their tendency to disperse in the fluid within the well 108. The encapsulants 110 can be dispersed in the cement slurry at a concentration of 105 to 109 capsules / cm 3. In some implementations, the encapsulants 110 are a housing selected from the group consisting of a polystyrene, ethylene / vinyl acetate copolymer, and polymethyl methacrylate, polyurethanes, polylactic acid, polyglycolic acid, polyvinyl alcohol, polyvinyl acetate, ethylene / vinyl acetate hydrolyzate, or copolymers thereof.

Figure 2 illustrates a cross-sectional view of the well system 100 including the activated setting cement 202 in at least a portion of the underground zone 104. In particular, the encapsulants 110 release activators in response to at least detect a loss of the fluid inside the well 108 in such a way that the fluid 108 including the chemicals was positioned at the fault 204 in the set cement 202. In some implementations, the cement grout 108 flows into the ring 122 through the liner 116. and further to the interior of the fault 204. In response to at least one signal, the encapsulants 110 in the slurry 108 release one or more chemicals configured to accelerate the setting speed of the slurry 108. In the illustrated example, substantially all of the encapsulants 110 in the ring 122 release the activators to form the set cement 202 along substantially the entire length of the ring 122. In some implementations, the energy waves can be emitted for a specific period of time to substantially limit the formation of the set cement 204 at the fault 202. In other words, the initial amount of the cement slurry 108 can be exposed to the energy waves in such a way that the setting period can be substantially equal to a period of time for the cement grout 108 that sets to enter the failure 204.

Figures 3A and 3B illustrate an exemplary encapsulant 110 of Figure 1 according to some implementations of the present disclosure. In this implementation, the encapsulant 110 is substantially spherical but may be in other ways as discussed above. The encapsulant 110 is a housing 302 that encapsulates one or more activators 304 as illustrated in Figure 3B. The encapsulant 110 releases one or more triggers 304 stored in response to at least one or more energy waves. For example, the encapsulant 110 may break or otherwise form one or more holes in response to at least the energy waves. The encapsulant illustrated 110 is for exemplary purposes only, and the encapsulant 110 may include some, none, or all of the elements illustrated without departing from the scope of the disclosure.

Figures 4A and 4B illustrate an exemplary implementation of the encapsulant 110 that includes an aperture configured to release one or more activators. The encapsulants 110 can release activators by heating one or more portions to form at least one opening, destroying or otherwise removing one or more portions, and / or other processes to form an opening in the housing 302. The following implementations are for purposes of of illustration only, and the encapsulants 110 can release activators using some, all or none of these processes.

Referring to Figure 4A, the encapsulant 110 forms an opening by means of heat that is formed from the wave energy. For example, the ultrasonic signals can directly heat the membrane of the encapsulant 110 and / or heat the fluid inside the surrounding well 108 to a temperature above the melting point. The encapsulant 110 can be a gold shell that when vibrated in its natural frequency melts at least a portion of the shell to release the activators locked. In these cases, the heat generated can melt or otherwise deform the housing to form an opening. In addition to the metal membranes, the encapsulant 110 may be of other materials such as a polymer. Referring to Figure 4B, the encapsulant 110 forms cracks, breaks, or openings in the housing in response to one or more energy waves. For example, an ultrasonic signal may break or otherwise destroy portions of the encapsulant 110. In some implementations, the ultrasound may form defects in the membrane of the housing 302 and, as a result, form one or more openings as illustrated.

Figure 5 is a flow chart illustrating an exemplary method 500 for the release of one or more chemicals in response to at least one operational failure. The methods illustrated are described with respect to the well system 100 of Figure 1, but these methods could be used by any other system. In addition, the well system 100 can use any other technique to carry out these tasks. Therefore, many of the steps in these flow charts can occur simultaneously and / or in 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.

Referring to Figure 5, the method 500 starts at step 502 where the triggers are selected based, at least in part, on one or more parameters. For example, the encapsulants 110 and the enclosed chemicals may be selected based, at least in part, on components of the fluid within the well 108 and / or the current operations of the well. In some implementations, the encapsulants 110 can be selected based on the conditions inside the well (eg, temperature). In step 504, the selected activators are mixed with a fluid inside the well. In some examples, the encapsulants 110 can be mixed with the fluid inside the well 108 as the truck 130 pumps fluid 108 into the interior 116. In some examples, the encapsulants 110 can be mixed with dry ingredients before generating the fluid inside the well 108. Then, in step 506, the fluid inside the well, including the activators, is pumped into the well. In some cases, the fluid inside the well 108 that includes the encapsulants 110 can be pumped into the ring 122 at a specific rate. In step 508, an indication of operation failure is received. For example, the system 100 can detect that fluid loss exceeds a threshold, a partially occluded well, a stuck pipe, and / or other operational failures. Then, in step 510, an energy wave is selected based on the type of fault. For example, the fluid inside the well 108 may include a plurality of different types of encapsulants 110 such that each type releases the associated chemicals in response to a different energy wave. In doing so, the system 100 can be prepared to handle a plurality of different operating faults. One or more energy waves are transmitted to at least a portion of the fluid inside the well in step 512. Again in the example, the generator 134 can transmit signals to a portion of the fluid inside the well 108. In In this example, the transmitted signals can release chemicals near the shoe 132 to update one or more properties of that portion of the fluid inside the well 108. In some cases, the liner 116 can be moved (eg, upwards). / down) to help in the distribution of activators as desired.

A number of embodiments of the invention have been described.

However, it will be understood that different modifications can be made without departing from the spirit and scope of the invention. Accordingly, other embodiments are within the scope of the following claims.

Claims

NOVELTY OF THE INVENTION Having described the present invention as above, it is considered as a novelty and, therefore, the content of the following is claimed as property: CLAIMS

1. A method to reduce loss of material, comprising: add encapsulants to a fluid inside the well that circulates through a drill string that encapsulate one or more activators; determine one or more parameters in a well associated with a fault in operating conditions; Y emitting one or more energy waves in the fluid inside the well configured to release said one or more activators from the encapsulants.

2. The method according to claim 1 further comprises determining a location associated with a subset of encapsulants, wherein said one or more activators are released at least near the determined location.

3. The method according to claim 1, characterized in that the chemicals released are configured to react with the fluid inside the well.

4. The method according to claim 1, characterized in that said one or more energy waves are emitted in response to at least the determination that a rate of fluid loss in the interior of the well exceeds a specific threshold.

5. The method according to claim 1, characterized in that the fluid inside the well includes a settable composition, and said one or more released activators are configured to increase a set rate of the settable composition.

6. The method according to claim 5, characterized in that the settable composition comprises at least one of a cement composition, a resin composition, a settable slurry, a conformance fluid, or a polymeric additive.

7. The method according to claim 5, characterized in that the settable composition is set in a range from about one minute to about 24 hours after reacting with said one or more chemicals.

8. The method according to claim 2, characterized in that said one or more conditions comprise a drill pipe positioned incorrectly in the well.

9. The method according to claim 1, characterized in that said one or more activators are enclosed in a housing that releases said one or more activators in response to at least one or more energy waves.

10. The method according to claim 9, characterized in that at least one dimension of the housing is from about 10 nanometers to about 1 millimeter.

11. The method according to claim 1, characterized in that said one or more parameters comprise an obstruction in the well.

12. The method according to claim 1, characterized in that the fluid inside the well comprises a drilling fluid, and said one or more released activators alter a viscosity of the filtration fluid.

13. The method according to claim 1, characterized in that said one or more energy waves comprise at least one of sonic signals, ultrasonic signals, microwaves, or radio waves.

14. The method according to claim 1, further comprises remotely activating, at a surface of the well, a fixed signal generator at least about one end of a drill string.

15. A system, comprising: a dispenser configured to add encapsulants, to a fluid inside the well that circulates through a drill string, which encapsulate one or more activators; one or more sensors configured to determine one or more parameters in a well associated with a fault in operating conditions; Y a transmitter configured to emit one or more energy waves in the fluid inside the well configured to release said one or more activators from the encapsulants.

16. The system according to claim 15, characterized in that it includes a location module configured to determine a location associated with a subset of encapsulants, wherein said one or more activators are released at least near the determined location.

17. The system according to claim 15, characterized in that the released chemicals are configured to react with the fluid inside the well.

18. The system according to claim 15, characterized in that said one or more energy waves are issued in response to at least the determination that a rate of fluid loss inside the well exceeds a specific threshold.

19. The system according to claim 15, characterized in that the fluid inside the well includes a settable composition, and said one or more released activators are configured to increase a set rate of the settable composition.

20. The system according to claim 19, characterized in that the settable composition comprises at least one of a cement composition, a resin composition, a settable slurry, a compliance fluid, a circulation loss composition, a control fluid, inflow or burst, or a polymeric additive.

21. The system according to claim 19, characterized in that the settable composition is set in a range from about one minute to about 24 hours after reacting with said one or more chemicals.

22. The system according to claim 16, characterized in that said one or more conditions comprise a drill pipe positioned incorrectly in the well.

23. The system according to claim 15, characterized in that said one or more activators are enclosed in a housing that releases said one or more activators in response to at least one or more energy waves.

24. The system according to claim 23, characterized in that at least one dimension of the housing is from about 10 nanometers to about 1 millimeter.

25. The system according to claim 15, characterized in that said one or more parameters comprise an obstruction in the well.

26. The system according to claim 15, characterized in that the fluid in the interior of the well comprises a drilling fluid, and said one or more triggers released alter a viscosity of the drilling fluid.

27. The system according to claim 15, characterized in that said one or more energy waves comprise at least one of sonic signals, ultrasonic signals, microwaves, or radio waves.

28. The system according to claim 15 further comprises an activator configured to remotely activate, on a well surface, a fixed signal generator at least about one end of a drill string.