RU2641681C1 - Use of ionized fluid during hydraulic fracturing of formation - Google Patents

Abstract

FIELD: oil and gas industry.SUBSTANCE: method includes: introducing a fluid containing positively charged ions into at least some of the fractures; provision of said ions to convert shales along cracks into aragonite crystals so that some of the aragonite crystals become suspended in the fluid; removing some of the fluid with the weighted aragonite crystals from said formation. Removal of the aragonite crystals opens or expands the fractures and increases the permeability of the formation by increasing the amount and production rate of hydrocarbons from said formation. The fluid remaining in the mass continues to convert the following calcite crystals along cracks into aragonite crystals, so that aragonite becomes more weighted in the fluid, a certain amount of the weighted aragonite fluid is removed from said formation, thereby further increasing or maintaining the permeability of said formation.EFFECT: increased hydrocarbon production efficiency.11 cl, 39 dwg

Description

Link to related applications

This application is a partial continuation of the application for the grant of US patent No. 14/095346, filed December 3, 2013, which is the application continuing the application for US patent No. 13/832759, filed March 15, 2013, which is a partial continuation of the application for grant US patent No. 13/594497, filed August 24, 2012, claiming priority in accordance with provisional application for US patent No. 61/676628, filed July 27, 2012. According to this application claims priority in accordance with the above applications, and is also claimed a priority U.S. Patent Application Laid-Open No. 13/753310, filed January 29, 2013.

BACKGROUND OF THE INVENTION

Hydraulic fracturing (Fracturing) in oil wells began to be used in the late 1940s. as a means of stimulation in an attempt to extend the period of cost-effective operation of depleted oil wells. In those days, most oil wells were drilled vertically. The placement of cumulative explosive charges in a thin-walled enclosure was limited by the placement of these explosive charges in predetermined productive hydrocarbon formations, mainly in sandy formations. Cumulative explosive charges exploded in order to cause the formation of gaps or channels in these layers. To stimulate the well, a mixture of water and sand was pumped into the wellbore under pressure.

This method of stimulation of wells used in vertically drilled wells to date. That was until Mitchell Energy in the mid-1990s. I didn’t start using two new technologies that changed the way we cost-effectively develop unconventional hydrocarbon shales. The first of the new technologies used is the development of controlled and controlled drilling technologies, in which it was possible to change the direction of the drill bit moving in the vertical direction, and its rotation in the horizontal direction. Such a turn could be performed with a sufficiently small bend radius, and then the drill bit could continue drilling in the shale formation for a considerable distance in the horizontal direction.

The second technology that was needed included the development of high-pressure pumps for hydraulic fracturing, which could provide surface water pressures in the range of 9,000 to 10,000 psi. The answer was the development of hydraulic fracturing pumps that could achieve this pressure level during injection. Both technologies are important for the cost-effective recovery of hydrocarbon gases and liquids from hard and soft shale formations. Currently, companies produce gaseous and liquid hydrocarbons and use mainly chemicals to control the growth of microorganisms. Microorganisms can ultimately migrate to aquifers with drinking water.

Currently, for the destruction of microorganisms in an aqueous mixture, either chemical or other types of biocides are usually used (initially or in the reservoir), so that gaseous and liquid hydrocarbons contained in the matrix of the thickness of oil-saturated shales can easily move along channels and fractures, released by the reverse flow of the aqueous mixture. The channels created during the hydraulic fracturing process should be maintained open with proppants, which are initially introduced together with the injected water mixture into the fractures in the hydraulic fracturing sections (in the hydraulic fracturing intervals). If microorganisms are not destroyed, they will multiply rapidly, and if they remain in the gaps, they will grow and reduce or completely block the flow of hydrocarbons through these gaps. Another significant problem associated with the type of microorganism is the possible presence of a strain of microbes capable of searching for and assimilating all free sulfur or sulfur-containing compounds, eventually producing hydrogen sulfide, which should be removed from all flows of the produced gas, since it is a very dangerous and carcinogenic substance. To avoid such problems, all these types of microorganisms must be destroyed.

In addition to the possible propagation of microorganisms and blocking the flow of a hydrocarbon product, the presence of dissolved solids may be a problem during the injection of an aqueous solution. They can be deposited in the same channels of the inflow and breaks (cracks) in the form of sediment or plaque. The deposition of such plaque in these channels also reduces or blocks the flow of hydrocarbons to the surface. To avoid such situations in modern industry practice, they try to achieve coagulation of dissolved solids and their attachment to suspended or other colloidal particles present in an aqueous solution in order to remove them before injection into the well; however, such attempts are only partially effective. See, for example, Denny, Dennis, (March 2012) The effect of hydraulic fracturing fluid on shale and proppant penetration. Jpt. p. 59-61. Kealser, Vic. (April 2012). Real-time field monitoring to optimize microbial control. Jpt. p. 30, 32-33. Lowry, Jeff, et al. (December 2011). The use of environmentally friendly shale technology in the Hainesville test well. World Oil. p. 39-40, 42. Rassenfoss, Stephen, (April 2012). Companies seek to better explore shale wells. Jpt. p. 44-48. Ditoro, Lori K. (2011). Shales of the Hainesville Formation. Upstream Pumping Solutions, pp. 31-33. Walser, Doug. (2011). What is the difference between hydraulic fracturing in shales of the Hainesville Formation? Upstream Pumping Solutions, pp. 34-36. Denney, Dennis, (March 2012). The effect of stimulation on shale mining of the Hainesville formation: oil and gas exploration studies. Jpt. p. 62-66. Denney, Dennis, (January 2011). Technology applications. Jpt. p. 20, 22, 26. All of the above works are fully incorporated into this application by reference.

In recent years, the oil industry has made attempts to develop a number of ways to solve these problems. The use of ultraviolet light in combination with a reduced volume of chemical biocides for the destruction of water-borne microorganisms was only partially effective. The same applies to attempts to destroy microorganisms using ultra-high frequency sound waves. However, for the effective destruction of water-borne microorganisms in both of these systems, the intensity and strength are insufficient, since they have only a weak single exposure and have practically no residual effectiveness. In both systems, chemical biocides are required to effectively destroy waterborne and waterborne microorganisms. Some companies use low frequency or low power electromagnetic wave generators as biocides; however, it has been proven that their effectiveness is very negligible.

Therefore, the goal of further examples is to practically and satisfactorily solve some important environmental problems that are relevant to the entire industry. The objectives of further examples are to eliminate the need for wells to inject salt water into the formation, to abandon the use of toxic chemicals as biocides to kill microorganisms or to prevent the formation of sediment and to restore all return water or formation water for reuse in subsequent works Hydraulic fracturing. Examples of the invention are technically sound and cost-effective solutions to a variety of public safety issues that worried the industry in connection with hydraulic fracturing.

Summary of Examples of the Invention

The advantages of various examples of the present invention include the need to reduce (or eliminate) the utilization of saline water, since almost all dissolved salts coagulate and turn into suspended particles, which are separated and combined with recoverable proppant and finely divided material for inclusion in a material that is loaded for sintering by pyrolysis into a rotary kiln. Similarly, examples of the present invention eliminate the need for chemical biocides, since a microwave generator of high intensity electromagnetic waves with adjustable frequency destroys the microorganisms present in the water before the water is pumped into the formation. Electromagnetic waves also prevent the deposition of plaque; thus eliminating the need to add scale inhibitors to the hydraulic mixture for hydraulic fracturing. As a result, almost all of the return water during hydraulic fracturing is reused with all the solid materials remaining in it that have been processed and converted into proppant particles of the corresponding shape and size for subsequent use in hydraulic fracturing operations. In addition, since volatile organic compounds burn and evaporate, there is no need to dispose of sludge or other types of solid waste.

In accordance with one aspect of the invention, there is provided a system for use in hydraulic fracturing operations in wells, including: a first separator with pulp at the inlet and pulp and water at the outlet; a second separator with pulp from the first separator at the inlet and with pulp containing less water at the outlet; kiln with pulp from the second separator at the inlet and with the product at the exit; cooler with slag inlet exiting the kiln; crusher with chilled slag from inlet cooler; chopper with crushed material in the crusher inlet material; the first mesh filter with the material inlet crushed in the grinder, the mesh cell sizes in it define the upper boundary of the proppant particle size; a second mesh filter with material emerging from the first filter and a mesh size that defines a lower bound for proppant particle size. In at least one example, the system further includes a proppant storage bin located between the first and second strainers. In some examples, the system also includes a mixer, the input of which receives proppant from the hopper. In a more specific example, the first separator gives water out, and the system further includes: a water tank, which is located so that it receives water from the first separator, a coagulator with an outlet to the mixer inlet, and at least one hydraulic fracturing pump , which receives at least proppant and water from the mixer, and in which the hydraulic fracturing pump generates a stream of water for hydraulic fracturing.

In accordance with another example of the present invention, there is provided a method for preparing a proppant of a particular size from pulp separated at the well exit after hydraulic fracturing; this method includes: separating water from the pulp to obtain a pulp stream and a liquid stream; mixing the flow of pulp with solid particles to obtain feed material; sintering of proppant material with feed material; cooling the sintered proppant material; grinding sintered proppant material; sorting of crushed material in accordance with a specific size; mixing with the feed material crushed material that does not correspond to a specific particle size. In some examples of the present invention, the method also includes separating the pulp from the fluid flow produced in the hydrocarbon well, the formation fluid containing water and pulp; while the pulp is divided into at least two streams, one of which practically contains a liquid stream of water, and the second contains pulp. Examples of acceptable means of separating the pulp from the fluid flow produced from the hydrocarbon well include a conventional three-phase separator.

In at least one example, mixing includes: loading a stream of solid material into the kiln and loading solid particles into the kiln, wherein loading the solid particles changes the viscosity of the slag-forming material, and the slag-forming material contains a stream of solid particles and loaded solid particles. In yet another example, the loading of solid particles into the kiln depends on the viscosity of the slag-forming material in the kiln, while when the slag-forming material is too viscous for uniform flow in the kiln, the loading of solid particles is increased. In some examples, solids loading is reduced when the viscosity of the slag-forming material is so low that the flow rate through the kiln is too high to sinter the proppant material.

In yet another example, rapid cooling involves irrigating the sintered proppant material with a liquid stream, and grinding includes: crushing the cooled proppant material and grinding the crushed proppant material.

In yet another example, sorting involves screening through a strainer and / or weight separation.

In some examples, sintering involves heating the slag-forming material, while volatile components from the slag-forming material come out in a gaseous form, and the proppant material in the slag-forming material is sintered. In some such examples, the flow rate of the sintered material at the outlet of the kiln is measured, and the heating in the kiln is controlled based on these measurements.

In another example of the present invention, the method also includes separating the pulp from the fluid stream extracted from the hydrocarbon well, the produced fluid containing water and solids; however, the mentioned separation of the pulp gives at least two streams, one of which practically contains a liquid stream of water, and the second contains pulp. In at least one of such examples, this method also includes exposure to an electromagnetic pulse on a substantially liquid water stream, wherein the proppant is mixed with the substantially liquid water stream before or after exposure.

In accordance with another aspect of the present invention, there is provided a system for preparing a series of proppants with specific particle sizes from the pulp obtained at the well exit after hydraulic fracturing; this system includes: means for separating water from the pulp to produce a pulp stream and a liquid stream; means for mixing the flow of pulp with solid particles to obtain a feed material; means for sintering proppant material with feed material; means for cooling the sintered proppant material; means for grinding the sintered proppant material; means for sorting the crushed material by a specific size; means for mixing crushed material that does not correspond to a specific particle size with the feed material. In at least one example, a means for mixing ground material that does not meet a specific particle size includes a sintering means.

An example of a separation means includes a two-phase separation vessel with a funnel at the bottom and a chute going to the inlet of the screw conveyor. The tank for two-phase separation uses the principle of setting the deposition under the action of gravity (with or without partitions). An alternative to gravity-assisted deposition is a pressure vessel from a hydrocyclone system that guides the pulp to a feed hopper using a screw conveyor.

In another example, a means for mixing a pulp stream with solid particles includes: a means for loading a stream of solid material into a calcining furnace and means for loading solid particles into a calcining furnace, wherein loading of solid particles changes the viscosity of the slag-forming material and the slag-forming material contains a stream pulps and solids loaded. One example of a useful means for loading the pulp stream into the kiln includes: a screw conveyor from the separation means to the hopper of the kiln. As the pulp stream moves to the funnel, more water is separated by means of a screw conveyor. Alternatives are the conveyor belt, bucket conveyor system and others known to those skilled in the art. Specific examples of useful means for loading sand into a kiln include: an elevator belt with buckets and an adjustable drive feeding solid particles (e.g. sand) from a silo in which said sand is located. An adjustable drive allows you to change the amount of sand depending on the temperature, which is measured at the outlet of the kiln. This temperature is related to viscosity. For example, if the temperature fluctuates around a predetermined value of approximately 2200 F, sand will increase as the temperature decreases. With increasing temperature, it will be reduced. In a more specific example, there will be no changes with fluctuations within 5%, while fluctuations of more than 5% will increase or decrease the amount of sand depending on the specific kiln for firing, supply of solid proppant material and other conditions known to specialists in this field of technology. Other examples of loading means include a conveyor belt or bucket conveyor and other analogs known to those skilled in the art.

In yet another example, the means for cooling includes means for spraying the sintered proppant material with a stream of liquid that has been separated from the pulp (for example, using a spray nozzle and / or water screen). Another option for cooling this material is air cooling. In at least one example, a mixture of hot solid materials from a kiln is placed on a moving perforated steel conveyor belt that extends above the catchment. Water acts on the mixture while it is on the tape.

до

дюйма.In yet another example, the means for grinding includes: means for crushing the cooled proppant material and means for grinding the crushed proppant material. In one such example, the means for crushing includes a crusher with the following technical data: an eccentric cone crusher with the ability to change the crushing space and obtain material of different sizes. Alternative crushers include: jaw crushers, roller crushers, ball crushers and other analogues known to specialists in this field of technology. In some examples, the crusher brings the hardened sintered mixture to fragments with sizes from about

before

inches.

In some examples, the means for grinding includes a mill of one of the following types: core mill, ball mill, self-grinding mill (ballless), roller mill and other analogues known to specialists in this field of technology. In at least some of these examples, the crushed material is conveyed and conveyed to a mixing / grinding assembly where material is reduced in size; in at least one example, 98-99% of the material passes through mesh No. 30 with gaps of approximately 590 microns; the passed material is similar in size and strength to fine acute-angled sand.

In some examples, the sorting means includes a screening unit (screen) with at least one screen. An example of a suitable screening plant is a vibrating screen / vibrating screen. If the material passes through a strainer, it is referred to the “required” size. If it is too small, it falls into the line for material of insufficient size and is loaded back to the inlet of the loading funnel of the kiln. If it is too large, it is separated into a line with excess material and fed back to the inlet of the loading funnel of the kiln. In at least one example, flows of too coarse and too fine material are combined prior to loading into the kiln. Other suitable screening media are fixed screens, rotating screens, and also means for separating by weight (for example, a cyclone separator through which the crushed material passes) and / or separating by specific gravity in a liquid solution. Examples of valid cyclone separators are known to those skilled in the art. Other acceptable means for separation include separators by specific gravity in a liquid solution. Suitable separator systems of this type are known to those skilled in the art.

In another example, the sintering means includes means for heating the slag-forming material, while volatile components from the slag-forming material come out in a gaseous form, and the proppant material is sintered into the slag-forming material. One example of such a means for heating the slag-forming material includes a rotary slag kiln for firing, an inclined rotary kiln for firing and a horizontal kiln with the possibility of direct and indirect (reflected flame) heating. Alternative means for sintering the proppant material into the feed material include: a slagless kiln, a vertical furnace (e.g., a Gerreshof furnace, a Pacific multi-hearth vertical furnace), a horizontal sintering furnace with a chain grate, and other analogues known to those skilled in the art technicians. In some examples, kiln firing operations include loading the pulp material into the kiln and adding proppant to begin the process of co-sintering the pulp and proppant material into the bulk of the agglomerate. As the mixture moves down to the outlet of the kiln, the temperature of the mixture rises due to the heat generated by the burner of the kiln. At the same time, the viscosity of this mixture decreases as the temperature rises. At the same time, the organic substances that are transported in this mixture burn up, evaporate and enter the ventilation pipe, leaving the moving mixture of solid materials. The viscosity of this moving mixture is controlled by increasing or decreasing the heat generated by the burner of the kiln, either by adding more or less proppant to the mixture, or both.

Some examples of the present invention also include means for measuring the flow rate of the sintered material exiting the kiln. Examples of means for measuring the flow of sintered material at the outlet of the kiln include a temperature sensor transmitting signals. Other similar means are known to those skilled in the art. Means for adjusting heating in a calcining furnace based on measurement (temperature) are provided in other embodiments. Examples of measurement-based heating control means in a kiln include: changing the proppant flow at the inlet to the kiln based on temperature measurements and changing the flow rate of fuel to the burner of the kiln to increase or decrease the amount of heat that is generated in kilns for roasting.

As mentioned above, separating the pulp from the well stream produces at least two streams, wherein at least one of the two streams is substantially a liquid water stream. In an even more detailed example, a means is provided for exposing an electromagnetic pulse to practically a liquid water stream. At least one example of a means for applying an electromagnetic pulse to a substantially liquid water stream is disclosed in US Pat. No. 6,063,267, which is incorporated herein by reference in its entirety. Alternatives to the device described in this patent for use in various examples of the present invention include traditional biocides / coagulators (chemical, electrical and mechanical), which is obvious to experts in this field of technology.

In at least one example, a particular impact pulse has the following characteristics: variable, superhigh frequency in the range of about 10 to 80 kHz. Other pulses that have a sufficient frequency to destroy microorganisms present in the water and cause coagulation of dissolved solids are known to those skilled in the art and may depend on the specific properties of the water in a particular well. Typically, an impulse will destroy the cells of microorganisms.

In another example of the present invention, there is provided a means for mixing proppant with a substantially liquid stream of water (for mixing either before or after exposure). Examples of means for mixing proppant with water include a mixer known to those skilled in the art (for example, a strainer or an open container with a grill). In some examples, surface tension reagents as well as other components known to those skilled in the art are added to the mixer. Then the mixture enters the tool, which increases the pressure of the mixture (for example, hydraulic fracturing pump or “amplifier”, known to specialists in this field of technology), and the mixture is pumped under pressure into the well.

In other examples, a proppant of a particular size is made from the associated and / or return water, as well as from other sources, using a combination of a kiln, grinder, grinder and strainers to produce proppant of different sizes; specialists in this field of technology will understand that this is in demand during hydraulic fracturing. See, for example, Mining Engineering, "Industrial Materials", pp. 59-61, June 2012 (www.miningengineering magazine.com), which is incorporated herein by reference. Different sizes are obtained by adjusting the choppers and strainers used.

In another example, a method is proposed for treating water after hydraulic fracturing in hydrocarbon wells (this is return water and “associated” water), which includes: separating solids from water after hydraulic fracturing, and a water stream with suspended solids is obtained ; dividing the water flow into a number of water flows; generating a positive charge in a number of streams of water, while receiving a certain number of streams of positively charged water; mixing a certain number of streams of positively charged water after said creation of a charge. In another example, this method also includes monitoring the level of the water-oil interface and controlling the level of the water-oil interface in the separator.

In a more specific example, this method further includes reducing the flow rate in a certain amount of water flows so that it is lower than the flow rate of water with suspended solids. Reducing the flow rate allows you to increase the exposure time of a positive charge. This increases the amount of positive charge in water, which is considered useful for destroying microbes in water and providing a residual positive charge for a period of time when water is pumped into formations from which hydrocarbons are supposed to be extracted. It is believed that a positive charge of water in the formation is favorable for reducing various structures in the formation that interfere with flow.

In yet another specific example, a method of creating a positive charge in water streams involves treating each of a number of water streams with a stream of electromagnetic energy.

In yet another example, most suspended solids are less than 100 microns in size. In some such examples, almost all suspended solids are less than 100 microns in size. In a more limited number of examples, most suspended solids are less than 10 microns in size. In an even more limited number of examples, almost all suspended solids are less than 10 microns in size. Reducing the size of suspended solids allows water to pass through devices that are suitable for creating a positive charge in water at reasonable costs, for example, by using stainless steel pipes in the case of suspended particles of about 100 microns in size and from softer materials (e.g. PVC) in the case of particles with a size of 10 microns or less.

In some examples, the separation includes a two-stage separation. In at least one example, two-stage separation includes: the passage of water after hydraulic fracturing through a three-phase separator, at the outlet of which water is obtained, into the water after a three-phase separator is passed through a two-phase separator. In at least one such method, a three-phase separator includes separation into four substances, including: pulp, water containing suspended solids, a hydrocarbon liquid, a hydrocarbon gas.

In accordance with another example of the present invention, there is provided a system for treating water after hydraulic fracturing in hydrocarbon wells, the system includes: means for separating solids from water after hydraulic fracturing, thereby obtaining a stream of water with suspended solids; means for dividing the water stream into a number of water streams; means for creating a positive charge in a certain number of streams of water, while receiving a certain number of streams of positively charged water; means for mixing a certain number of streams of positively charged water.

In at least one of these systems, the separation means includes a three-phase separator with separation into four substances. For example, in a more specific example, the separation means further includes a second two-phase separator, this two-phase separator includes an inlet for a water stream from a three-phase gas-oil separator and an outlet for a water stream with suspended solids. In another example, the following is also proposed: means for monitoring the level of the water-oil interface and means for controlling the level of the water-oil interface in the first and second separator. In one such example, the monitoring tool includes a water-oil interface level indicator and a control valve sensor (e.g., a cascade control system).

In some examples, the means for dividing the water stream into a number of water streams includes a manifold with an inlet for supplying a water stream with suspended solids and a number of outlet openings, each of which has a cross-sectional area smaller than the cross-sectional area at the inlet to the manifold; the sum of the cross-sectional areas of the outlet openings is greater than the cross-sectional area of the inlet openings, so that the flow rate leaving the manifold is lower than the flow velocity entering the manifold. In at least one example, the manifold includes a 1:12 manifold (for example, with a cross sectional diameter of the outlet openings of 4 inches and a large cross-sectional diameter of the inlet openings). In another example, a means for dividing a water stream into a number of water streams includes a water tank with a number of compartments, each compartment being positioned to receive a portion of the water stream.

In another example, the means for creating a positive charge includes means for treating each of a number of water streams with a stream of electromagnetic energy. In at least one such example, the means for treating each of a number of water streams with an electromagnetic energy stream includes a pipe and at least one electric coil that is substantially coaxial with the pipe. In some such examples, the pipe consists of a practically non-conductive material. In some such examples, the pipe consists of stainless steel. In various examples, an oscillatory current switching circuit connected to a coil is used. In some such examples, the switching circuit of the oscillatory current operates in a half-wave mode with a frequency of 10 to 80 kHz.

In another example, the mixing means includes a manifold with inlets for a number of positively charged water flows and an outlet. In one such example, the mixing means further includes a water and proppant mixer for hydraulic fracturing. In various examples, most suspended solids are less than 100 microns in size. In some such examples, virtually all suspended solids are less than 100 microns in size. In a more limited number of examples, most suspended solids are less than 10 microns in size. In an even more limited number of examples, almost all suspended solids are less than 10 microns in size.

In a more specific example, the separation means includes a two-stage separator. In one such example, a two-stage separator includes: a three-phase separator with an outlet for water, which is connected to the input of the two-phase separator. In another example, a three-phase separator includes a separation into four substances, including: pulp, water containing suspended solids, hydrocarbon liquid, hydrocarbon gas.

In another example, the present invention provides a system for treating water from wells after hydraulic fracturing; this system includes: a multiphase separator; a manifold, the inlet of which is connected to the outlet of the multiphase separator, and which has several outlet openings; a number of pipes, on each of which a coil is wound, each pipe having an inlet end connected to the outlet of the manifold and an outlet end; a mixing manifold, the inlet of which is connected to the outlet ends of a certain number of pipes.

In at least one such system, a proppant-water mixer is also provided which is connected to the outlet of the combining mixing manifold.

In at least one of these systems, a multiphase separator includes a multi-stage separator. In a more specific example, the multi-stage separator includes a two-stage separator, in which: the first stage of the two-stage separator includes a three-phase separator, and the second stage of the two-stage separator includes a two-phase separator. In an even more specific example, a three-phase separator includes a four-substance separator with a water-oil interface level control system.

In yet another example of the present invention, there is provided a method for controlling a water-liquid hydrocarbon interface in a three-phase separator; this method includes: establishing the level of the water-liquid HC interface in a three-phase separator; measuring the level of the water-liquid HC interface in a three-phase separator, the result of which is a signal about measuring the level of the water-liquid HC interface; comparing the signal about the measured level of the water-liquid HC interface with a given value, the result of which is a signal about the result of the comparison; a decrease in the return of return water or associated water to the three-phase separator for water from the well after hydraulic fracturing, when the signal from the comparison indicates that the level of the water-liquid HC interface is higher than the set value; an increase in the flow of return water or associated water into the three-phase separator for water from the well after hydraulic fracturing, when the signal from the comparison indicates that the level of the water-liquid HC interface is below the set value, while the increased flow contains water from the hydrocarbon well after hydraulic fracturing and additional water from a storage tank or storage pond.

In another example, this method also includes: reducing the flow that leaves the three-phase separator at the same speed balanced with the flow as it decreases to the three-phase separator, and increasing the flow that leaves the three-phase separator with the same speed balanced with the flow as it increases in the three-phase separator.

In another example, a system is proposed for controlling the level of the water-liquid HC interface in a three-phase separator; moreover, the system includes: means for establishing the level of the water-liquid HC interface in a three-phase separator; means for measuring the level of the water-liquid HC interface in a three-phase separator, the result of which is a signal about measuring the level of the water-liquid HC interface; means for comparing the signal about the measured level of the water-liquid HC interface with a predetermined value, the result of which is a signal about the result of the comparison; means for reducing the flow at the inlet to the three-phase separator for water from the well after hydraulic fracturing, when the comparison signal indicates that the level of the water-liquid HC interface is higher than the set value, and to increase the flow of return water or associated water into the three-phase separator for water from the well after hydraulic fracturing, when the signal from the comparison indicates that the level of the water-liquid HC interface is below the set value, while the increased flow contains water from the HC of the well e fracturing and added water.

In at least one example, the means for establishing the level of the water-liquid HC interface includes a membrane membrane. In yet another example, the means for measuring the level of the water-liquid HC interface includes a liquid level indicator with a controller type sensor. In another example, the comparison of the signal of the measured level of the water-liquid HC interface includes a constant level sensor of the electric capacitance.

In some examples, the means for reducing and increasing the flow to the three-phase separator includes a turbine flow meter and an adjustable inlet valve at the inlet of the three-phase separator.

In another example, the following is also proposed: a means for reducing and balancing the flow leaving the three-phase separator as the flow decreases to the three-phase separator, and to increase the flow leaving the three-phase separator with the same balanced speed as the flow increases to the three-phase separator.

In at least one such example, the means for increasing and decreasing the flow exiting the three-phase separator includes: a flow meter, coupled in concert with the water outlet of the three-phase separator. In another example, the means for increasing and decreasing the flow exiting the three-phase separator includes a diaphragm type flow regulator that controls the exit of water from the three-phase separator.

Examples of the proposed inventions are further illustrated by the attached drawings, which are illustrations and are not intended to be used as technological drawings or assembly drawings, they are given without scaling. The various components are represented symbolically; the “windows” in the components shown in different places illustrate the flow of matter from one place to another. However, those skilled in the art will understand which components are typically closed. Nothing in the figures or in the detailed description can be interpreted as a limitation of any conditions of the application, and in this description does not mean anything other than its usual meaning for specialists in different technologies.

In at least one example, a method of increasing hydrocarbon production from subterranean formations includes: obtaining ionized fluid, pumping the ionized fluid from a surface location in a hydrocarbon well to at least one location underground, increasing the pressure of the ionized fluid at least at one location underground, reducing the pressure of the ionized fluid at the perforation location, with at least a portion of the ionized fluid returning to the above-mentioned location on the surface STI and contains suspended solids. In another example, this method further includes perforating blasting (perforation) at least at one location underground.

In at least one such example, this method also includes hydraulic fracturing (Fracturing) at least one location underground. In yet another example, this method also includes isolating at least one location underground from at least one portion of the hydrocarbon well.

In another example, with this method, said ionized fluid prevents corrosion in a hydrocarbon well. In yet another example, with such a method, at least fifty volume percent of water is included in the composition of the ionized fluid.

In another example, the ionized fluid contains positively charged water. In yet another example, this method also includes mixing the ionized fluid with the proppant.

In accordance with another example of this method, an ionized fluid is created by exposing water to electromagnetic fields. In another example, with this method, the acting electromagnetic field pulsates with a full period of up to three hundred and sixty times per second. In another example, with this method, the acting electromagnetic field pulsates with a full period of more than eighty times per second.

In another example, with this method, the suspended particles contain suspended particles of calcium compounds.

In another example, this method also includes recovering a portion of the return fluid from the well. In another example, this method also includes recovering a portion of the produced fluid from the well. In yet another example, this method also includes ionizing a portion of the produced fluid. In another example, with this method, the generated ionized fluid contains reduced fluid, produced fluid, and additional fluid.

In a more specific example, a system of means for increasing hydrocarbon production from an underground formation includes: means for generating an ionized fluid; means for pumping the ionized fluid from the surface in at least one fracturing interval (region) in the underground formation, means for increasing the pressure of the ionized fluid in at least one fracturing interval; means for reducing the pressure of the ionized fluid in at least one fracturing interval; moreover, part of the ionized fluid is returned to the surface, and it contains suspended particles from the formation. In yet another example, a means for generating an ionized fluid includes a means for treating water by exposure to electromagnetic fields.

In another example, with such a system, the means for generating the acting electromagnetic waves includes: a pipe and at least one electric coil, which is practically coaxial with the pipe. In another example, with such a system, the acting electromagnetic fields are created at a half-wave frequency of more than eighty pulses per second.

In yet another example, with such a system, the ionized fluid consists of at least fifty volume percent water.

In another example, with such a system, acting electromagnetic fields are generated at a half-wave frequency of up to three hundred and sixty pulses per second. In another example, with such a system, acting electromagnetic fields destroy most of the microorganisms in the ionized fluid.

In another example, this system further includes means for adding proppant to the ionized fluid. In yet another example with such a system, said means for adding proppant to the ionized fluid includes a mixer.

In another example, with such a system, said means for pumping ionized fluid from a surface into a fracturing interval in an underground formation includes flexible tubing.

In yet another example, said means for increasing the pressure of an ionized fluid in a fracturing interval include at least one hydraulic fracturing pump.

In yet another example, the system of said means for maintaining pressure in the fracturing interval includes at least one packer.

In yet another example, the system of said means for reducing the pressure of an ionized fluid in a fracturing interval includes flexible tubing. In another example, this system further includes a drilling mechanism coupled to flexible tubing with the ability to span at least one packer.

In another example, this system further includes means for restoring the backflow fluid, wherein a portion of the recovered backflow fluid is used to create the ionized fluid. In yet another example, this system further includes means for separating the backflow fluid into water and at least one further material.

In yet another example, with such a system, the ionized fluid contains positively charged water. In another example, this system further includes means for recovering the produced fluid, wherein a portion of the recovered produced fluid is used to create the ionized fluid. In one example, this system further includes means for separating the produced fluid into water and at least one other material.

In a more specific example, a method of increasing hydrocarbon production from subterranean formations includes: obtaining ionized fluid, re-opening the formation; access to at least one selected location in the hydrocarbon well; pumping the ionized fluid from the surface location into the subterranean formation into at least one selected location in the hydrocarbon well, increasing the pressure of the ionized fluid in at least one selected location, reducing the pressure of the ionized fluid in at least one selected location, at least a portion The ionized fluid returns to the surface location and contains suspended solids. In yet another example, this method further includes killing most of the microorganisms in the ionized fluid. In yet another example, with such a method, at least fifty volume percent of water is included in the composition of the ionized fluid.

In yet another example, with such a system, the ionized fluid contains positively charged water.

In another example, with this method, an ionized fluid is created by exposing the fluid to electromagnetic fields. In another example, with this method, the acting electromagnetic fields pulsate in a half-wave mode with a frequency of more than eighty times per second. In another example, with this method, the acting electromagnetic fields pulsate in a half-wave mode with a frequency of up to three hundred sixty times per second.

In another example, in this method, the suspended particles contain suspended particles of calcium compounds. In another example, this method further includes isolating at least one selected location in at least one part of the hydrocarbon well.

In yet another example, this method further includes perforating at least one selected location.

In yet another example, this method further includes fracturing at least one selected location.

In another example, this method further includes mixing the ionized fluid with the proppant. In yet another example, this method further includes isolating at least one selected location from another selected location.

In another example, this method further includes installing at least one packer to isolate at least one selected location from at least one part of the hydrocarbon well.

In one example, this method further includes drilling at least one packer.

In a more specific example, a method of increasing production from underground shale formations includes: obtaining ionized fluid under the influence of electromagnetic fields; injection of ionized fluid into the underground shale formation; the impact of the ionized fluid under pressure on the pre-perforated interval; while production from the shale formation increases after the pressure of the ionized fluid decreases, and in the pre-perforated interval, hydraulic fracturing is preliminarily performed, the method further includes hydraulic fracturing of the pre-perforated interval and, in addition, includes the selection of the interval of exposure to the ionized fluid.

In another example, this method further includes perforating the selected interval. In another example, this method further includes hydraulic fracturing of the selected interval and isolation of the selected interval. In yet another example, this method further includes supplying an ionized liquid under pressure to a selected interval. In yet another example, this method further includes maintaining pressure in a selected range for a predetermined period of time. In yet another example, this method further includes reducing pressure in a selected range. In yet another example, this method further includes mixing the ionized fluid with the proppant.

In a more specific example, a device for use in hydraulic fracturing operations in a hydrocarbon well includes: an electromagnetic field generator that has a first fluid inlet and a first fluid outlet; at least one hydraulic fracturing pump, the second inlet of which is connected to the first outlet of the electromagnetic field generator; a flexible tubing arrangement, the inlet of which is connected to a second fluid outlet; and further includes at least one fracturing tool coupled to the flexible tubing. In yet another example, this device further includes at least one well punch tool coupled to a flexible tubing. In yet another example, this device further includes at least one pipe inside an electromagnetic field generator located between a first fluid inlet and a first fluid outlet.

In yet another example, this device further includes at least one electromagnetic coil that spans at least one pipe. In another example, this device further includes at least one completion tool connected to the end of the flexible tubing.

In yet another example, this device further includes wellhead equipment for a hydrocarbon well at a surface in which a flexible tubing interacts with a hydrocarbon well through this wellhead equipment. In another example, this device further includes a return (return) line from the wellhead equipment with an outlet. In another example, this device further includes an outlet of a return line connected to a separator, this separator has an inlet and at least one outlet. In yet another example, this device further includes at least one separator outlet connected to a second inlet of the electromagnetic field generator.

Description of drawings

In FIG. 1 is a diagram of a well site with flows of various substances used in various examples of the invention.

In FIG. 2A and 2B, when connecting them along the respective dashed lines, a side view of an example of the invention is shown.

FIG. 2A1 is another example of the embodiment of FIG. 2A.

In FIG. 2C is a diagram of a control system that is used in at least one example of the invention.

In FIG. 3A and 3B, when matching image elements are aligned next to respective dashed lines, a top view of the example shown in FIG. 2A and 2B.

In FIG. 3C and 3D are, respectively, an isometric view and a side view of one aspect of the examples shown in FIG. 2A-2B and FIG. 3A-3B.

In FIG. 4 is a side view of yet another example of the invention.

In FIG. 5 is a top view of the example of FIG. four.

In FIG. 6 is a diagram of a well site with flows of various substances used in various examples of the invention.

In FIG. 7 is a diagram of a well site with flows of various substances used in various examples of the invention.

In FIG. 8 is a top view of one example of the invention.

In FIG. 9 is a side view of one example of the invention.

In FIG. 10A is a side view of the support 100 of FIG. 8.

In FIG. 10B is a plan view of the base 101 of FIG. 10A.

In FIG. 11 is a sectional view taken along line A of FIG. 9.

In FIG. 12 is a sectional view taken along line C of FIG. 8.

In FIG. 13 is a sectional view taken along line B of FIG. 8.

In FIG. 14A is a top view of one component of one example of the invention.

In FIG. 14B is a sectional view of the component of FIG. 14A.

In FIG. 15 is a diagram of a control system that can be used in the examples of the invention.

In FIG. 16 is a diagram of one system useful in the examples of the invention.

In FIG. 17 shows a diagram of a control system useful in accordance with examples of the invention.

In FIG. 18 is a perspective view of examples of the invention.

In FIG. 19 is a perspective view of one device that is an embodiment of the invention.

In FIG. 20 is an exploded view of the pipe assembly shown in FIG. 19.

In FIG. 21 is a longitudinal sectional view of the socket assembly shown in FIG. 19.

In FIG. 22 is a simplified circuit diagram of the pipe assembly shown in FIG. 19.

In FIG. 23 is a detailed electrical diagram of the pipe assembly shown in FIG. 19.

In FIG. 24 shows the specific waveforms that the pipe assembly of FIG. 19.

In FIG. 25 is a circuit diagram similar to that shown in FIG. 22, but showing a modified embodiment of the invention.

In FIG. 26 is a view similar to FIG. 21, but showing a modified embodiment of the invention in which the pipe assembly has only one coil spanning a pipe with a fluid stream.

In FIG. 27 is a detailed electrical diagram of a pipe assembly similar to that shown in FIG. 23 but showing an electrical diagram for use with the socket assembly shown in FIG. 27.

In FIG. 28 is a table showing the values of the specific parameters of the device depicted in FIG. 19-24.

In FIG. 29 is a diagram of a well site with flows of various substances used in various examples of the invention, which include the injection of ionized water into the formation.

In FIG. 30 is a diagram of a perforation interval that is exposed to an ionized fluid.

In FIG. 31 is an electrokinetic diagram that depicts the arrangement of fields and forces.

Detailed description of examples of the invention

Consider FIG. 1 is a flow chart of the use of the invention in a hydrocarbon well, where wellbore 1 with cemented casing 3 passes through hydraulic fracturing intervals that are isolated by packers. Flexible tubing 9 is lowered into the well using a drilling machine 11 for hydraulic fracturing operations, known to specialists in this field of technology.

Return water (and / or associated water) is directed to a three-phase separator 10 (solids - liquids - gas - HC - water), from which all HC liquids and gases are obtained; water from the separator 10 is directed to a reservoir 17 for storing hydraulic fracturing water, which may also contain water from another source (so-called supplementary water). Wet solids are sent from a three-phase separator 10 to a two-phase separator 14, which delivers water (it is sent to the cooling system 32) and pulp (it is sent to the kiln 24 for firing). Slag is sent from the kiln 24 through the cooling system 32 to the crusher 40, and then to the grinder 46. The crushed material on the strainer 50 is separated in accordance with a predetermined size and sent to the hopper 26 for storing proppant, which may also contain proppant from another source (e.g., from a sand supplier). Water is supplied to the biocide / coagulator unit 13. The proppant from the hopper 26 is fed to the mixer 15, water is fed to the mixer 15 from the biocide / coagulator unit 13; the mixed water and proppant are then fed to the hydraulic fracturing pump 19, which pumps the mixture into the well, where it hydraulic fractures the shale oil reservoir 21. Other additives can be added to the mixer 15 if desired. In other examples, proppant may be added to the water prior to setting the 13 biocide / coagulator.

Examples of the invention provide a number of proppants of specific sizes from the pulp extracted from the HC wells after hydraulic fracturing.

In FIG. 2A and 2C and FIG. 3A-3D depicts a more specific example. In this example, the pulp is removed from the pulp after precipitation by gravity, this pulp accumulates at the bottom of a conventional three-phase separation vessel 10 (the conventional construction of which is known to those skilled in the art). In the specific example shown in FIG. 2A, it will be understood by those skilled in the art that the level of the water-liquid hydrocarbon interface facilitates the separation and extraction of any liquid hydrocarbon product from the return flow water or associated water (which is pressurized at the inlet of the separator 10) by means of an external or internal water level indicator (not shown in FIG.). This indicator sends a signal about the measured water level to a pre-programmed data integrator designed to control low / high water flow. When the water level in the separator 10 reaches the set high level, the data integrator actuates a control valve (not shown) that controls the flow through the water supply pipe 10a (labeled “inlet water”) in order to reduce the amount of water, flowing into the three-phase separator, and the flow rate continues to decrease until the set value is reached, at which the incoming amount of water equalizes and balances the volume of water that is taken from the three-phase separator. Conversely, if the water level in the three-phase separator 10 falls below the set value of the lower level, the data integrator activates and additionally opens the control valve in the inlet pipe 10a in order to increase the amount or speed of the water flow to a value sufficient to stabilize the level of the interface . If this additional amount of water is not sufficient to stabilize the water level at the interface, the integrator activates a pump (not shown) and opens another control valve (not shown), which is located in the outlet pipe (not shown) of the water storage tank 17 (FIG. one). This exhaust pipe is connected to the inlet pipe 10a; thus, the water from the hydraulic storage tank 17 continues to flow into the three-phase separator together with the return water or associated water until the water level in the separator 10 reaches the desired level of the interface. Then the control valve for controlling the additional water is closed and the pump for additional water is turned off. Such a control sequence is necessary to achieve a steady state and continuous stable operation during the separation and extraction of any liquid HC products, and these processes occur in a three-phase separator with a flow of water flow back flow or associated water.

The configuration of thresholds and partitions (commonly known in gas and oil separation plants) facilitates the separation and recovery of liquid hydrocarbon product (if any), using the interface level as the maximum height of the water in the separator and allowing lighter liquid hydrocarbons to float on the surface of the water layer ; then they are selected as a liquid HC product after they flow through the threshold for liquid HC products, and output through an outlet flange connection for liquid HC products. A horizontal partition below the threshold limits the amount of potentially escaping water that can mix with the flow of liquid HC product. As the flow of return water or associated water enters the three-phase separator 10, a decrease in pressure releases lighter hydrocarbon gases, their release contributes to the flotation of liquid hydrocarbon products, as well as the exit of gaseous hydrocarbon products through the outlet 10c. Water flows from the separator 10 into the surge tank (not shown) through the pipe 10b, and then it is pumped back into the water tank 17 (Fig. 1).

From the separator 10, a slurry diaphragm piston pump 12 with a mechanical drive pumps the pulp up to the inlet of the tank 14 for two-phase separation (water / solids); the result is a solid stream 16 and a liquid stream 18, which is pumped by pump 19 into the kiln (indicated by the letter "Q"). From the bottom of the two-phase separation vessel 14 (water / solids), the elevator conveyor 20 with buckets conveys the pulp materials deposited in the lower part of the two-phase separation vessel (water / solids) upward and unloads them into the loading funnel 22 (Fig. 2B). This download in FIG. 2A extends beyond the dashed line that connects to the dashed line on the left side of FIG. 2B, where it is seen how the pulp accumulates in the feed funnel 22 of the rotary slag kiln 24 for precipitation, is precipitated from the liquid pulp and remains in the tank 14 for two-phase separation (water / solids) and the elevator 20. As a result, all separation is performed at atmospheric pressure, and not in pressure vessels (as is the case in existing practice).

In the feed hopper 22, the pulp substances from the two-phase separation vessel (water / solids) are mixed with the required proppant from hopper 26 (Fig. 1), as well as with solid material of insufficient and excessive size, which comes from the final sieving unit 50 through the filter ( described below).

During the proppant material sintering process, inorganic proppant materials are sintered into a homogeneous mass, and volatile organic substances that could be present in the material stream coming from the two-phase separation vessel 14 (water / solids) are burned and evaporated before the gases, which ultimately discharge into the air vent 30.

The proppant material that exits the rotary kiln 24 is cooled by a stream of water to lower the temperature of this material as it exits from the outlet of the kiln 24. In some examples, the material being discharged falls onto a perforated stainless steel belt 35 of a mechanically driven conveyor and water is supplied from above through spray nozzles 34 to a moving belt 35, whereby the proppant material is cured and cooled. The water used to cool the proppant material comes from a two-phase separation vessel 14 (water / solids) (FIG. 2A) using, for example, a centrifugal pump 19 with a mechanical drive that delivers water to the nozzles 34 of the cooler shown in FIG. . 3B. A container 36 for collecting excess water is placed under the conveyor belt 35 for collecting and regenerating all excess cooling water and feeding it back to the two-phase separation tank 14 (water / solids) using a centrifugal pump 21 with a mechanical drive through the pipeline, which in FIG. 2A goes to exit "R".

The cooling of the hot proppant material as it is discharged from the kiln 24 results in the formation of many random cracks due to temperature differences or splits due to uneven resizing of the proppant material and high internal stress caused by rapid cooling. Pieces of proppant material of different sizes are discharged directly into the crusher 40.

The crushing or destruction of large unequal pieces of proppant material and their size reduction in some examples is carried out using a cone or jaw, eccentric crusher with a mechanical drive and a vertical shaft, known to specialists in this field of technology. The degree of size reduction is controlled by changing the gap or gap of the crusher, thereby allowing the production of material in a certain range of sizes, as is well known to specialists in this field of technology.

Proppant material is sorted by grinding or grinding the crushed proppant material after the proppant material is discharged at the bottom of the crusher. In the illustrated example, the material is transported upward to the ball mill 46 using an elevator conveyor 44 with buckets. In at least one alternative example, a core mill is used. The grinder 46 is adjusted to grind the proppant material to different sizes in a predetermined range, for which the rotation parameters, dimensions and the distance between the rods or balls in the grinder 46 (or its rotation) are changed.

The crushed proppant material under the influence of gravity passes down through the grinding zone of the grinder and it is discharged onto a vibrating sieve 50, where the size of the mesh opening is specially selected so that it matches the desired sieve number. For example, for shales from soft minerals, the mesh openings are in the range of 590 microns (sieve No. 30). For shale from solid minerals (for example), the mesh openings can be in the range of 150 microns (sieve No. 100). The proper sized proppant material is lowered down through strainers of selected sizes by gravity and exits through hole “A”. The proppant material, which is too large to pass through the inclined vibrating sieve 53, is discharged onto the belt 51a (better seen in FIG. 3B), and the rest of the material falls onto the sieve 55. The proppant material having medium sizes (between screens 53 and 55) unload as the proppant of the desired size through the hole "A" and transported to the hopper 26 (Fig. 1). The smaller proppant enters the belt 51a, which conveys too large and too small proppant to the belt 51b, which returns this proppant to the elevator 25 and then back to the kiln 24. In FIG. 3A and 3B show a top view of one example of the invention, where the components are mounted on a car trailer or on skids, assembled at the well site and contain biocides and other components (for example, FIGS. 4 and 5). In some examples, such car trailers or skids are aligned using jacks 81.

As seen in FIG. 3C and 3D, the elevator 25 unloads the material into the top of the feed hopper 22, and the elevator 23 unloads the material from the hopper into the feed hopper 22 below, through an opening in the feed hopper 22.

An appropriately sized proppant material, by gravity, enters a container for the desired proppant (not shown) for transportation to hopper 26 and storage of the desired proppant (FIG. 1), which may also contain the desired proppant from another source.

Consider FIG. 2B; in order to maintain the optimum sintering temperature (in some examples, it is approximately 2200 degrees Fahrenheit), it is desirable to control the viscosity of the initial proppant mixture. As the temperature of the initial proppant mixture rises due to heating in the kiln 24, the process of sintering various inorganic substances into a uniform viscous mass begins when the temperature of the proppant mixture reaches the sintering temperature of silicon dioxide or sand. The viscosity of the proppant material depends on the temperature of the substance itself. Such management is carried out in various ways.

In at least one example, the temperature of the sintering material is measured by any means known to those skilled in the art, for example, optical pyrometer sensors in the cooler system 32, at the outlet of the material from the kiln. If the temperature is above the sintering point of the material, it will be too liquid, and the fuel supply to the kiln will be reduced. At the same time, more than the required proppant can be added to the feed hopper 22. This affects the temperature, since the material obtained from the pulp is heterogeneous and not dry; adding proppant from the feed funnel increases uniformity.

Consider FIG. 2C; this is a diagram in which the sensor 67 transmits to the integrator 69 signals about the temperature at the outlet of the kiln 24 for firing. Then the integrator 69 controls a variable-speed motor 90 (Fig. 3A), which drives the elevator 23 (see also Fig. 3B), transporting proppant from the bottom of the hopper 26 with proppant and unloading it into the feed funnel 22 of a rotary slag furnace for roasting. Different streams of material are mixed in the feed funnel 22 before they enter the rotary drum of the kiln 24. The proportion or volume of proppant to be added to the material stream from the two-phase separation vessel 14 (water / solids) is adjusted depending on changes in the composition of the materials coming from the two-phase separation vessel 14 (water / solids). This increases the uniformity of the proppant starting material used in the sintering furnace 24. In at least one example, the fuel supply to the burner is reduced at too high a temperature; if this does not lead to a temperature change, increase the amount of proppant in the kiln. Similarly, if the temperature is too low, the fuel supply to the burner is increased, and if this does not help, the amount of proppant is reduced. Alternative settings will be apparent to those skilled in the art.

Returning to FIG. 2C; the integrator 69 also controls the valve 63 to increase or decrease the supply of fuel 61 to the burner 65 of the kiln.

Referring again to FIG. 1, which shows one example of the invention, where the separator 10 feeds the pulp to the separator 14, and the water from the separator 10 is combined with a new "additional" (from the tank 17) injection water with a new hydraulic fracturing. The combined streams are treated with type 13 electromagnetic biocide / coagulator, which is described in US Pat. No. 6,063,267 (commercially available as Dolphin Model 2000) and is incorporated herein by reference in its entirety; in at least one example, it is set for exposure to an electromagnetic pulse with the following characteristics: the pulse can be selected from several options; variable; with adjustable frequency in the range of approximately 10-80 kHz. Such an impulse is enough to destroy biological organisms and form a positive charge, which is applied to water, which makes dissolved solids capable of sedimentation or coagulation in the well.

FIG. 4 and 5 are, respectively, side and top views of one example of a system mounted on a car trailer or on runners and including a number of biocides / coagulators 70a-70l; they are grouped in such a way as to receive commercial water after hydraulic fracturing at a rate that is usually used in hydraulic fracturing in shales. Such installations operate from an electric control panel 72, which is connected to the electrical distribution cabinet 73 of the contact network with the control panel, which in turn is connected to the power supply components 71a-71l of the contact network. The generator 77 is powered by an engine 75 and is connected to a power supply 79 to supply power in a manner known to those skilled in the art.

In FIG. 2A1 shows an alternative embodiment to that of FIG. 2A; in this embodiment, the water levels in the two-phase separator 14 and the three-phase separator 10 are the same. In such an embodiment, the fluid is communicated through the diaphragm pump 12, and the containers are at atmospheric pressure, so that their liquid-gas interfaces are at the same level.

In accordance with another example of the present invention in FIG. 6 proposes a system for treating water from a well after hydraulic fracturing; this system includes a means for separating solids from water after hydraulic fracturing, comprising a three-phase separator 10 with separation into four substances, from which the resulting stream of water with suspended solids is sent to a reservoir 17 for storing hydraulic fracturing water. This so-called “additional water” can be added to the reservoir 17 for storing hydraulic fracturing water and the water stream passes through a means for dividing the water stream into several streams (described in more detail below); means for creating a positive charge in a certain number of water flows (for example, a group of biocidal coagulators or plants, as described above), in which a certain number of positively charged water flows are obtained. The means for mixing a certain number of positively charged water flows more evenly distributes the positive charge in the water before it enters the mixer 15 for use in subsequent hydraulic fracturing operations in the well.

In FIG. 7 shows an example in which the separation means further includes a second step, a two-phase separator 14; this two-phase separator includes an inlet for water from the three-phase gas-oil separator. The flow of water from the three-phase separator is taken from the middle part of the separator, while most solids fall to the bottom, as described above. However, water from a three-phase separator contains suspended solids that can damage the biocidal coagulator or plant. Accordingly, in one embodiment, the water flow from the three-phase separator 10 is fed to the inlet of the two-phase separator 14, which also includes an outlet for water with finer suspended solids. The biphasic separator 14 also releases pulp-shaped solids from its lower portion. The pulp from the three-phase separator 10 and the two-phase separator 14 is then processed (for example, as described above) or disposed of in another way.

In FIG. 8 and 9 show an example of a three-phase separator 90 with a separation into four substances, it is useful in some embodiments of the present invention and is a replacement for the three-phase separator 10. The separator 90 includes an inlet 92, an outlet 94 for pulp, an outlet 98 for liquid hydrocarbon and a gas outlet 80. In FIG. 10A, the separator 90 is located on supports 100 (which include a base 101 shown in FIG. 10B) that are welded to the sides of the separator 90.

In FIG. 9, as well as in FIG. 11 (which shows a section along line A shown in FIG. 9) and FIG. 13 (which shows a section along line B shown in FIG. 8), the baffle 111 allows water with a certain suspended solids content to exit the separator 90, while larger solid particles exit the pulp from the bottom opening 94. FIG. . 12 is a sectional view of the inlet 92 (along line C shown in FIG. 8), where the inlet pipe 92 is supported by a support 120 connected to the bottom of the separator 90, which supports the inlet pipe 92 and the bracket.

In another example, the following is also proposed: means for monitoring the level of the water-oil interface and means for controlling the level of the water-oil interface in the first and second separator. In one such example, the monitoring means includes a water-oil interface level indicator and a control valve sensor (e.g., a cascade control system).

As can be seen from FIG. 18, in some examples, the means for separating the water stream into a number of water streams includes a manifold 181 with an inlet valve 183 for supplying a water stream with suspended solids from the separation means and a number of outlet openings connected to biocidal coagulator units 184 moreover, the cross-sectional area of each outlet is less than the cross-sectional area of the inlet of the manifold. In some examples, the sum of the cross-sectional areas of the outlet openings is larger than the cross-sectional area of the inlet openings, so that the velocity of the stream exiting the manifold is lower than the velocity of the flow that enters the manifold. In at least one example, manifold 181 includes a 1:12 manifold (for example, with a 4-inch outlet cross-sectional diameter and a large inlet cross-sectional diameter). In another example, the means for dividing the water stream into a number of water streams includes a water tank (not shown) for water, as is known in the art, with a number of compartments, each compartment being positioned to receive part of the water flow. During operation, water passes through the valve 183 to the manifold 181 and the flow slows down, since it is divided into parallel flows passing through the parallel connected nodes of the biocidal coagulator 184 in order to increase the residence time in them for exposure to the flow of electromagnetic energy and maximize the positive charge of water. In the manifold 186, what is leaving the nodes 184 is mixed, and the valve 188 controls the outlet of the manifold. In some examples, the entire group of manifolds and biocidal coagulation units is mounted on a frame 184, which can be lifted by suspension 186 to the base at the well site or onto the cargo platform vehicle for transportation.

In another example, the means for creating a positive charge includes means for treating each of a number of water streams with a stream of electromagnetic energy. At least one such example is shown in FIG. 19-28, where the means for treating each of a number of water streams with an electromagnetic energy stream includes: a pipe and at least one electric coil that is substantially coaxial with the pipe. In some such examples, the pipe consists of a practically non-conductive material. In some such examples, the pipe consists of stainless steel. In various examples, an oscillatory current switching circuit connected to a coil is used. In some such examples, the switching circuit of the oscillatory current operates in a half-wave mode with a frequency of 10 to 80 kHz.

Turning to FIG. 19-28 and first consider FIG. 19, where the device, an embodiment of the present invention and generally indicated at 910, mainly includes a pipe assembly 912 and an alternating current power supply 914. The pipe assembly 912 includes a pipe 916 through which the fluid to be processed passes, the direction of the fluid flow being indicated by arrows A. The pipe 916 may be made of different materials, but since the treatment of the liquid in the pipe assembly 912 includes the passage of electromagnetic energy through this wall pipes and into the liquid passing through the pipe, it is preferable that the pipe was made of a non-conductive material to avoid a decrease in the volume of the liquid reaching the flow due to sweat Some part of the flow is due to eddy currents in the pipe material. Other parts of the pipe assembly 912 are contained in or installed, typically in a cylindrical body 918 surrounding the pipe 916.

As described below, it is preferable that the pipe assembly 912 be designed to operate with a sufficiently low voltage power source, for example, a power source with a voltage of 11 V (rms) to 37 V (rms) and a frequency of 60 Hz, and thus shown the source of electric power 914 is a step-down transformer, its primary winding is connected to the input cable 920 with a plug 922 for connecting to a standard electric network so that it supplies an electric current with a voltage of 120 V and a frequency of 60 Hz or 240 V and 60 Hz, and the output cable 924 is connected to the secondary winding of the transformer 924 and supplies a lower voltage current to the pipe assembly 912. The socket assembly 912 may be designed for use with pipes 916 of different diameters, and the specific voltage at the output of the electric power source 914 is selected so that it matches the pipe diameter, size and arrangement of the interconnected components of the pipe assembly.

In addition to the housing 918 and pipe 916, the pipe assembly 912 consists mainly of an electric coil device covering this pipe and a switching circuit that controls the current through the coil device in such a way that it generates successive periods of oscillating current through the coil device and the resulting successive periods of electromagnetic flow energies pass through the liquid in the pipe 916. The number, design and layout of the coils making up the coil device may be different; in the examples shown in FIG. 20 and 21, the coil device includes four coils (L ₁ , L ₂ external, L ₂ internal and L ₃ ) arranged in a similar manner to that described in US Pat. No. 5,702,600, which is incorporated herein by reference in its entirety. . As shown in FIG. 20 and 21, the coils are connected to three different longitudinal sections 926, 928 and 930 of the pipe 916. That is, the coil L _{1 is} wound on and along the frame 932, which in turn runs along the pipe section 926, the coil L _{3 is} wound on and along the frame 934 , which itself runs along the pipe section 930, and two L ₂ coils are internal and L ₂ external are wound on a frame 926 passing along the pipe section 928, the L ₂ external coil being wound over the L ₂ internal coil. The fact that the two coils L ₂ -internal and L _2- outer wound one on top of the other or otherwise closely connected to each other, gives an inter-turn capacitance between these two coils, which forms all or part of the capacitance of the series resonant circuit, as described below.

Presented in FIG. 20, the housing 918 of the nozzle assembly 912 consists of a cylindrical shell 938 and two plugs 940 and 942 with holes. The components of the switching circuit pass through the plug 940, at least some of them are mounted on a radiator 944 attached to the plug 940 by screws 946. In the assembly of the pipe assembly 912, the plug 940 is first put on the pipe 916 from the right end of the pipe, as shown in FIG. 20, to a position at some distance from the right end of this pipe, and then fasten to this pipe with fixing screws 948. Then three frames of coils 932, 936 and 934 together with coils are sequentially put on pipe 916 from the left end of this pipe until they touch with each other and with plug 940, a binder should be applied between the frames and the pipe to secure the coils on the pipe. Then, sleeve 958 is put on the pipe from the left end until it contacts the coil L ₃ and secured to this pipe with fixing screws 960. Then, sheath 938 is put on the pipe and fastened to the plug 940 on the right side with screws 962. Finally, plug 942 is put on the pipe 916 from the left end of this pipe, and then attached to the sheath 938 using screws 964 and to the pipe using fixing screws 966.

The basic circuitry for the socket assembly 912 is shown in FIG. 22. The input terminals connected to the electric power source 914 are designated 968 and 970. A connection means including the conductors shown connects the input terminals 968 and 970 to the coils and to the switching circuit 972 in the manner shown, the connection means including a switch 974 which is triggered by overheating. Arrow B indicates the direction of winding the coil counterclockwise, and accordingly, the coil L ₃ and the coil L ₂ outer are wound around the pipe 916 clockwise, and the coils L ₁ and L _{2 are} inner wound around the pipe counterclockwise. Given these winding directions and the electrical connections shown, it is understood that when the current i _c flows through the coils in the direction indicated by arrows C, the magnetic fluxes passing through the center of each of the coils and thus through the liquid in the pipe have the direction shown in FIG. 22 by arrows E, F, G and N. That is, the flows passing through the centers of the coils L ₁ , L _{2 are} internal and L ₃ have the same direction along the pipe, and the flow passing through the center of the coils L _{2 is} external, has the opposite direction . Depending on the design of the switching circuit 972, it may be necessary or desirable to provide local grounding for the switching circuit 972, in which case the switching circuit may be connected to the input terminals 968 and 970 via an isolation transformer 976, as shown in FIG. 22.

The electrical circuit shown in FIG. 23 shows in detail the connection means and the switching circuit 972 shown in FIG. 22. In FIG. 23, the switching circuit 972 includes a 12 V power supply section 976, a comparator circuit section 978, a timer circuit section 980, a switch 982, and an indicator circuit section 984.

Components D2, R5, C5, R6, and Z1 include a 12 V DC power supply circuit 976 that supplies power to other components of the trigger circuit. Resistors R1 and R2 and operational amplifier U1 form a comparator circuit section 978. These resistors R1 and R2 form a voltage divider that sends a signal proportional to the AC voltage that is supplied to the operational amplifier U1. Capacitor C1 serves to filter out “interference” voltages that may be present in the input AC voltage in order to prevent voltage surges at the output of amplifier U1. Amplifier U1 is connected so that it produces a “low” (zero) voltage on line 986 when the applied AC voltage is positive, and produces a “high” (+12 V) voltage when the AC voltage is negative.

When the AC supply voltage goes over zero and starts to become positive, the amplifier U1 switches to low voltage mode. This triggers the U2 chip of timer 555 to obtain a high output voltage at pin 93. Capacitor C2 and resistor R3 act as a high-pass filter so that the switching pulse is short-term rather than stationary. The voltage at pin 92 of U2 remains low for about half a millisecond. This short-time low switching voltage maintains a stable high voltage (+12 V) on pin 93 of the U2 chip.

The switch 982 may take various forms and may be a section of the circuit that includes a number of separate components, and in any case it is a T-shaped switch or a triode with the first, second and third terminals 988, 990 and 992, respectively, with the third terminal 992 - this is the control terminal, and the switching is performed so that when electrical signals are applied to the control terminal 992, the switch can be in a position between ON, in which the first and second terminals are closed, and OFF, in which the first and second terminals are open friend with q ugom. In the preferred and depicted in FIG. 23 case, the switch 982 is a MOSFET (Q1). The MOSFET (Q1) conducts current, that is, it closes the terminals 988 and 990 with each other as soon as the signal supplied to the control terminal 992 becomes positive due to the fact that the input AC voltage at the input terminals 968 and 970 becomes positive. In turn, this allows you to create current in the coils L ₁ , L ₂ internal, L ₂ external and L ₃ . When a time elapses that corresponds to a time constant equal to the product of the resistance R4 and the capacitance C3, the U2 chip of the timer 555 returns to the low voltage mode at terminal 93, turning the MOSFET (Q1) to the OFF position. When Q1 turns off, all the current, still flowing in the coils, is redirected to a capacitor connected to terminals 988 and 990 (Q1). As can be seen from FIG. 23, this capacitance is made up of the inter-turn capacitance C _c and mainly arises due to the close relationship of the two coils of L ₂ -internal and L ₂ -external. This inter-turn capacitance in itself may be sufficient to create a useful series resonant circuit, but if additional capacitance is required, it can be obtained using a separate additional tuning capacitor (C _t ).

When the switch (Q1) switches to the OFF position or is in the open state, any current still flowing in the coils is redirected to the capacitor (C _c and / or C _t ), and together with the coils and the electric power source, this capacitor forms a series resonant circuit, as a result of which the current through the coils takes the form of oscillations and, thereby, creates an alternating flow of electromagnetic energy through the liquid in the pipe 916. By setting the variable resistor R4, you can adjust the opening time of the switch (Q1) to open of happened earlier or later in each operating half-period of the input AC voltage. It is preferable to adjust the circuit starting from R4 at its maximum resistance value, and then slowly adjust it to the direction of lower resistance until the LED indicator 994 of section 984 of the indicator circuit lights up. This occurs when the maximum voltage received at the capacitor (C _c and / or C _t ) exceeds 150 V; at this voltage, two Z2 Zener diodes can conduct current. Zener diodes charge the capacitor 962 and the received voltage turns on the 994 LED. When this LED is on, then the resistor R4 is adjusted in the opposite direction until the LED goes out, while the switch (Q1) generates a 150-volt oscillating signal.

In FIG. 24 illustrates the operation of the circuit of FIG. 23 in the form of waveforms that occur during operation of this circuit. In FIG. 24, the waveform 996 coincides with the shape of the AC supply voltage applied to the input terminals 968 and 970, the voltage being alternating — half-periods 998 of positive voltage will be replaced by half-periods 900 of negative voltage. The circuit in FIG. 23 operates in a half-cycle mode with periods of current fluctuations in the coils of the tube assembly only in response to each of the positive half-cycles 998. The waveform 902 represents the periods of opening and closing of the switch (Q1), it should be noted here that during each positive half-cycle 998 of the supply voltage, the switch (Q1) is closed during the initial part of the half-cycle and opens long before the end of this half-cycle (the exact time is adjusted by adjusting the resistor R4).

Opening and closing the switch (Q1) gives the current waveform 904 shown in FIG. 24; for each positive half-period of the supply voltage, it is such that the current through the coils increases from zero during the initial part of the half-cycle, at this time the switch (Q1) is closed, and then when the switch (Q1) opens, the current flows for a certain period of time. The voltage that appears on the coils of the pipe assembly corresponds to the waveform 906 shown in FIG. 24, moreover, the voltage upon opening the switch (Q1) takes the form of an oscillating signal with a maximum voltage many times higher than the voltage provided by the electric power source 914.

The frequency of the vibrational current generated in the coils and the vibrational voltage generated on the coils can be changed by changing the capacitance (C _c and / or C _t ) that occurs on the switch (Q1); it is preferable to set the frequency in the range from 10 kHz to 80 kHz.

The parameters of the device shown in FIG. 19-24, including the nominal pipe size, coil arrangement (number of turns, wire diameter and length), the capacitance of the trimmer capacitor, and the corresponding nominal voltage of the power source are shown in the table in FIG. 28.

As indicated above, the switching circuit depicted and described in connection with FIG. 22, 23 and 24, this is a circuit during operation of which one period of action of the vibrational current and vibrational voltage is obtained for each of the alternating half-periods of the applied supply voltage. However, if desired, the switching circuit can be designed to operate in a half-wave mode, and the period of action of the vibrational current and vibrational voltage is formed for each half-cycle of the supply voltage. As shown in FIG. 25, this can be achieved by changing the circuit shown in FIG. 22, namely, adding a second switching circuit 908, which is identical to the first switching circuit 972 with the exception of the opposite current direction and opposite voltage compared to the first circuit 972. That is, the first circuit 972 shown in FIG. 25 operates as described above during each positive half-cycle of the applied voltage, and the second circuit 908 also works during the negative half-cycle of the supplied voltage, and as a result, the number of periods of current and voltage fluctuations for a given period of time is doubled compared to the number of periods for the same time in the circuit of FIG. 22.

As indicated above, the number of coils used in the pipe assembly 912 may also vary, and if necessary, without going beyond the scope of the present invention, the pipe assembly 912 may include only one coil. FIG. 26 and 27 relate to such a construction; in FIG. 26 shows a pipe assembly with one coil 910 wound around a frame 912 and spanning a pipe 916. FIG. 27 shows the switching circuit that is used with the single-coil pipe assembly shown in FIG. 26; in general, it is similar to the circuit depicted in FIG. 23 except that if there is one coil 910 giving a small inter-turn capacitance, it is necessary to use a tuning capacitor (C _t ) at the first and second terminals 988 and 990 of the switch (Q1). Furthermore, since the coil means is made of one coil 910 and is located entirely on one side of the switch (Q1), the isolation transformer 976 shown in FIG. 23 and providing local grounding for switching circuit components.

In yet another example shown in FIG. 18, the mixing means includes a manifold 186 with inlets for a number of positively charged water flows from several means for generating a positive charge 184 and an outlet that is connected to a valve 188 directing the outgoing positively charged water flow to the mixer for use in operations hydraulic fracturing. In various examples, most suspended solids are less than 100 microns in size. In some such examples, virtually all suspended solids are less than 100 microns in size. In a more limited number of examples, most suspended solids are less than 10 microns in size. In an even more limited number of examples, almost all suspended solids are less than 10 microns in size.

In FIG. 16 and 17 show a system for controlling the level of the water-liquid HC interface in a three-phase separator; moreover, the system includes: means for establishing the level of the water-liquid HC interface in a three-phase separator; means for measuring the level of the water-liquid HC interface in a three-phase separator, the result of its operation is a signal about measuring the level of the water-liquid HC interface; means for comparing the signal about the measured level of the water-liquid HC interface with a given value, the result of its operation is a signal about the result of the comparison; means for reducing the flow at the inlet to the three-phase separator for water from the well after hydraulic fracturing, if the comparison signal indicates that the level of the water-liquid HC interface is higher than the set value, and to increase the flow of return water or associated water into the three-phase separator for water from the well after hydraulic fracturing, if the signal from the comparison indicates that the level of the water-liquid HC interface is below the set value, while the increased flow contains water from the HC after Hydraulic fracturing and additional water.

In at least one example, best represented in FIG. 14A and 14B, the means for determining the level of the water-liquid HC interface includes a partition 140 and, ideally, an oil-water interface is installed in the lower part of the partition 140b. Control by means of flow meters and control valves is shown in FIG. 15 and 16.

In FIG. 17 shows in more detail an example of controlling the level of the interface of a three-phase separator with separation into four substances. As can be seen in this figure, the return flow water flow entering the separator is measured by a turbine flow meter (FE-101) / transmitter (FT-101) and controlled by a flow control valve (FV-101) through a flow regulator (FIC-101) . The incoming flow of additional water is measured by a measuring diaphragm (FE-103) / differential pressure sensor (FT-103) and controlled by a flow control valve (FV-103) through a flow regulator (FIC-103). The outgoing water flow is measured by a measuring diaphragm (FE-102) / differential pressure sensor (FT-102) and controlled by a flow control valve (FV-102) through a flow regulator (FIC-102). The level of the oil-water interface in the separator is measured with a magnetic level sensor (LG-100) and also with a constant level sensor (LT-100) of the electric capacitance level. Both level gauges are mounted on an external level gauge made of a 2-inch diameter pipe. The column includes manual valves (HV-1, HV-2, HV-3, HV-4, HV-5, HV-6, HV-9 and HV-10) for maintenance of the column and devices attached to it, such as known to specialists in this field of technology. HV-1 and HV-2 are used to exclude columns from the process. HV-3 and HV-4 are used, respectively, to drain and dry the column. HV-5 and HV-6 are used to exclude the level indicator from the process. HV-9 and HV-10 are used to exclude the level sensor chamber from the process. Each instrument on the column is equipped with valves for maintenance. HV-7 and HV-8 are part of the level indicator, and they are used, respectively, to drain and dry the level indicator. The HV-11 is part of the level sensor chamber; this valve is used to drain from this chamber.

The level of the water-liquid HC interface (also known as the "oil-water interface") in the separator is maintained using a level controller (LIC-100) with step control, a regulator (FIC-101) at the inlet of the return water flow, and a regulator ( FIC-103) at the inlet of the additional water flow and the regulator (FIC-102) of the outlet water flow. Step control is carried out with the help of a level controller, which sends a remotely set setpoint to the corresponding flow controllers and resets the set values to maintain the level of the interface.

All regulators in stationary conditions maintain a normal liquid level (NLL = 50%). The set values on individual controllers are determined depending on the required capacity and size of the separator.

In one valid example, as the level of the interface increases, the level regulator opens the outlet flow regulator and at the same time covers the inlet water regulator of the return flow to maintain a normal liquid level. The high-level liquid level switch (HLL = 80%) is triggered by a signal from an analog transmitter of the interface level, which allows the operator to take appropriate measures to restore control of the interface level or operating conditions.

As the level of the interface decreases, the level regulator covers the regulator of the outlet water flow, while opening the regulator of the inlet water flow of the return flow to maintain a normal liquid level. If the interface level drops to below the minimum level (LLL = 10%), this system switches the additional water flow regulator to stepwise regulation from the interface of the interface level using the LX-100 programmable switch.

In FIG. 29 is a flow chart for using an example of the invention in a hydrocarbon well, where a wellbore 301 with cemented casing 303 passes through hydraulic fracturing intervals 340, which are isolated by packers 341. Flexible tubing 309 is lowered into the well by a drilling rig 311 for hydraulic fracturing operations known to specialists in this technical field. Holes 356 are made in the shale formation 321. During the perforation and installation of the cement bridge, packers 341 are placed in the wellbore to isolate the different zones of the hydraulic fracturing. Flexible tubing 309 is lowered into predetermined areas where hydraulic fracturing is required. In this case, the fluid, mainly consisting of water, is pumped through the ion generator 313. The ion generator 313 uses the effects of electromagnetic fields described herein to ionize the fluid. This freshly ionized fluid 353 is pumped into hydraulic fracturing intervals 340 using hydraulic fracturing pumps 319.

Ionized fluid 353 is pumped into gaps 351, as shown in FIG. 30. The ionized fluid 353 is under sufficient pressure to grow and widen the gaps 351. The pressure of the ionized fluid 353 is maintained for a predetermined time. Under pressure, ionized fluid 353 interacts with shale formation 321 (in the present example, layered calcite 350) to create layers 352 of aragonite crystals. In the present example, the pressure in the interval of 340 hydraulic fracturing is reduced using a flexible tubing 309. The process of hydraulic fracturing can be different depending on the service provider and the situation around the well. For example, in an open wellbore, a point fracturing system may be used, rather than a system with perforation and a cement bridge. These different variations of hydraulic fracturing processes in shale formations are well known to those skilled in the art.

During fracturing operations in the shale formation 321, gaps 351 are created or enlarged. These fractures can be created by perforating blasting (perforation), high pressure abrasion, or other methods known in the art. These fractures 351, located in the interval 340 of the hydraulic fracturing, provide access from the wellbore 301 to layered calcite crystals 350. When rhombic crystals of layered calcite 350 are exposed to ionized fluid 353, the crystalline structure of insoluble particles of layered calcite 350 is transformed into layered aragonite 352 with linear rhombic crystals forms. This layered aragonite 352 is in suspension.

Ionized fluid 353 has the property not to precipitate with the formation of a crust, since its particles, causing the formation of a precipitate, are now in suspension, and not in solution. Under the influence of ionized fluid 353 on layered calcite 350, particles form faster than in the absence of ions. This phenomenon reduces the size of the particles, not allowing them to become so large as to cause the formation of plaque or sediment on the surface of the fractures 351 exposed.

Ionized fluid 353 (in this example, ionized water) also eliminates the growth problem of non-biological suspended particles, as it affects the prevention of deposition on the surface. In addition, the effect of ionized water prevents corrosion. The paracolloid particles of calcium carbonate (CaCO ₃ ) are charged by absorption of ions, while they decrease in size, become insoluble and remain in suspension. They are converted into suspended crystalline "nuclei" of rhombic aragonite from calcium carbonate and remain in suspension.

When the pressure of ionized fluid 353 in fractures 351 at target hydraulic fracturing intervals 340 is reduced using a flexible tubing (in this example), suspended particles of calcium carbonate 352 (in this example, aragonite crystals) are removed from the fractures 351 with return water or washed out of the produced fluids .

Ionized water can prevent the accumulation of non-biological substances in gaps 351. Water is ionized by electromagnetic fields using an ion generator 313, for example, a Dolphin installation, which uses periodic low-frequency oscillations, thereby causing the electroporation of the signal and amplification of the oscillations due to resonance. High-frequency, low-power electromagnetic waves ultimately tear apart membranes or kill microorganisms in an ionized fluid. As a result of these reactions, encapsulation of organic residues also occurs. Microorganisms cannot multiply and form a biofilm, which clogs gaps 351. In this example, an ionized fluid, which consists mainly of water, is formed in an ion generator 313, where electromagnetic fields act in a half-wave mode with a frequency of eighty kilohertz (80 kHz) up to three hundred and sixty kilohertz (360 kHz). In other embodiments, the frequency may be above eighty kilohertz (80 kHz). In the present example, a frequency of three hundred and sixty kilohertz (360 kHz) can cause fluctuations in the fluid, which is mainly composed of water. In other words, the natural frequency is excited in the fluid. In other fluids with a different natural frequency other than water, a different natural frequency can be excited. The composition of the fluid will determine the frequency at which the ion generator must work with the acting electromagnetic fields. A frequency higher than eighty kilohertz (80 kHz) in the half-wave mode can have the expected effect of fluid ionization and minimization of the presence of biological organisms in this fluid.

When the excess of positive ions delivered by water falls into the gap 351, positively charged ions have a physicochemical effect on the deposits of layered calcite 350 in the shales. This mineralization alters the crystalline structure of the plaque that has been deposited in this matrix. A preferred calcium carbonate polymorph (CaCO ₃ ) is called layered calcite 350 (rhombohedral), while other polymorphs are called aragonite (rhombic) and valerite (hexagonal). Ionization of water by means of pulsed power at high frequencies includes a continuously changing induced electric field, which is set by a specific low-frequency AC signal and a periodic pulsed signal with a certain range (medium to low) frequencies.

A low-frequency AC signal affects the method of formation of "nuclei" of solid precipitate and the mode of growth of crystals of solid precipitate. Due to this, such growth leads to the formation of a precipitate, but it does not form on the surfaces, but in the bulk of the solution, and microscopic suspended particles (both organic and inorganic) serve as a source of surfaces for the formation of “nuclei” and particle growth. In hydraulic fracturing water, calcium carbonate is the main solid crystalline substance that precipitates in water; usually it is the “nucleus” for sediment. When ionized fluid 353 enters the fractures 351, the calcium carbonate precipitate includes other solution cations, including magnesium, silicon, aluminum, iron, and, together with other components, is converted into suspended particles.

Together with the resulting aragonite structure, changes in the kinetics of the formation of "nuclei" of crystals exclude the formation of a surface precipitate and place the crystalline structures in suspension in the form of separate or coagulated particles. The difference in the relative magnitudes of electromotive forces between higher relatively positive values of calcium and lower values for radicals leads to the transition of the precipitate into suspension particles. A positively charged ionized water makes these selective changes possible on the surface of the stratified calcite, which are affected by cumulative charges in underground shale formations. This effect is the same for both hard and soft shales.

In another example, the layers of calcium carbonate sediment are physically exposed using cumulative charges that explode in the wellbore before pumping water carrying positive ions into the gaps 351 under pressure. Ionized fluid 353 is pumped into the fractures 351 under pressure, thereby delivering positive ions to the exposed fractures 351. The ionized fluid 353 is left in the range of 340 frac for several days. After that, the pressure of ionized water is reduced using a flexible tubing 309, and the return water flow and the flow of associated water through the wellbore removes released hydrocarbons, suspended particles 352, proppant, and other materials that may be expected by those skilled in the art from the fractures 351. Being in these gaps 351, positive ions (in this water example) selectively interact with layered calcite and change its crystalline structure from calcite (rhombohedral) to the preferred form of suspended particles - polymorphic aragonite crystals (rhombic), which the backflow water carries out from the gaps 351 .

The pressure reduction removes layers of the crust or solid sediment, which are shown here as layers of suspended particles 352 in the gaps 351, and opens the channels providing a higher rate of transfer of gaseous and liquid hydrocarbons in the flow of water to the surface. This layer by layer reduces the bottomhole pressure in the cracks and allows to achieve an initially higher flow rate of hydrocarbons for a longer time than would otherwise be possible. Calcium carbonate exists in solution in the form of colloidal particles with sizes, as a rule, in the range of 0.01-100 microns; each of the particles has a common electric charge, known as the zeta potential (or electrokinetic or electrochemical potential). The magnitude of this potential is equal to the force with which each particle repels the particle with the same charge. This force must be large enough to overcome the force of attraction of the particles as the particles approach each other so much that the van der Waals forces bring these particles together or force them to coagulate.

Positive ions move in water by magnetic and electric fields and interact with the resulting zeta-force, which arises in the direction perpendicular to the plane formed by the vectors of the magnetic and electric fields. This is illustrated in FIG. 31. This zeta-force acts on ions - causing the current particles, and slows down suspended particles. The positively charged particles will move in the direction that corresponds to the rule of the right hand, where the zeta force corresponds to the thumb, and the remaining fingers correspond to the electric and magnetic fields. Negatively charged particles will move in the opposite direction.

The result of the action of these zeta forces on ions as a whole is that positively charged ions, for example, calcium and magnesium, and negatively charged ions (for example, carbonates and sulfates) are directed towards each other with increasing speed. The increase in speed leads to an increase in the number of collisions between particles, as a result, a substance is formed from insoluble solid particles. After a precipitate forms, it serves as the basis for further growth of the crystalline structure or polymorph of aragonite or rhombic structure, thereby particles are formed in the suspension. In FIG. Figure 31 illustrates the zeta principle and shows the effect of the zeta potential on suspended particles. In FIG. 31 shows the arrangement of fields and forces.

The zeta potential determines the force with which each particle repels particles with the same charge. This value of the zeta potential is used in order to overcome the convergence of the particles with each other so much that the forces of van der Waals will unite the particles and stable growth will occur. Induced resonant electromagnetic fields generated by pulsed ion generators 313 reduce the zeta potential, as a result of the van der Waals forces contribute to the growth of particles.

In FIG. 31 shows the achievement of the desired effect of the zeta potential using a pulse signal. The zeta potential “forces” particles to prefer one polymorph to another. This is achieved by preventing the growth of one polymorph until another polymorph reaches the saturation limit. The growth of a crystalline form, in which suspended particles act as “nuclei” in the bulk of the solution, also facilitates the incorporation of microbes into the suspended sediment. This effect is called encapsulation.

A periodic pulse signal from the ion generator 313 into ionized water exerts a microphysical and chemical effect on the cell membrane, which is called electroporation or chemical destruction or rupture of cells; this leads to the destruction of microorganisms. A pulsed signal uses the physical principle of resonant frequencies, also called harmonic frequencies or vibrational frequencies, to amplify the energy required to ionize a fluid using relatively low power levels.

Ionized fluid 353 is also able to prevent clogging of the fractures by 351 particles due to flocculation. In turn, ionized water also reduces the problem of clogging, as it prevents precipitation on the surface. As a result of these interactions, the hydrocarbon flow rate due to bottomhole pressure will increase. This will prolong the life of the HC wells for a long time and increase the share of reserves recovered from this shale formation. This process allows you to extract more hydrocarbons with a higher inflow rate; this applies to both gases and liquids.

In another example, the techniques described above can be used to re-conserve a well. A well that has previously been perforated and in which hydraulic fracturing has been performed can be mothballed to increase production from it. In this case, the ionized fluid 353 can be pumped into the shale layer 321 through a flexible tubing 309 during conventional reconservation operations with hydraulic fracturing. The hammer can be lowered into the borehole to shoot holes 356 in new places. Packers 341 may be installed to isolate the new hydraulic fracturing intervals 340. Then, ionized fluid 353 containing ionized water and proppants can be pumped into the formation using hydraulic fracturing pumps 319. After that, the pressure of the ionized fluid 353 is increased to create and increase the gaps 351 that formed near the perforation holes 356. As a result of the action of ionized fluid 353 on cracks 351, layers of suspended particles 352 are formed. After a period of maintaining pressure in the required interval of 340 hydraulic fracturing, the pressure will be reduced, in this case using a flexible tubing to cover one or more packers 341. A decrease in pressure will cause suspended particles 352 leave gaps 351. Such re-conservation work can increase the productivity of an already producing well and extend the overall life of the well.

It should be remembered that the previously described examples of implementation are presented only as an example and can not be construed as limiting the idea of the invention to any specific configurations. Specialists in the art will be able to make changes to the present description without departing from the essence and scope of the present invention. Each element or step according to any one of the following claims should be construed as including all equivalent elements or steps. The claims cover the present invention as broadly as possible under the law, in any wording in which it can be applied. Equivalents of the inventions described in the claims are also intended to be within the scope of the claims. All patents, patent applications, and other documents referenced herein are hereby incorporated by reference in their entirety.

Claims (16)

1. A method of increasing the efficiency of hydrocarbon production from an underground formation, which includes oil and gas shales containing calcite with cracks in it, and this method includes: introducing a fluid containing positively charged ions into at least some of the cracks; enabling said ions to convert shale along cracks into aragonite crystals in such a way that some aragonite crystals become suspended in the fluid; removal of a certain amount of fluid with suspended aragonite crystals from this formation; moreover, the aforementioned removal of aragonite crystals opens or widens cracks and increases the permeability of this formation, thereby increasing the amount and rate of hydrocarbon production from this formation; moreover, the fluid remaining in the bulk continues to transform the following calcite crystals along the cracks into aragonite crystals, so that there is more suspended aragonite in the fluid, after which a certain amount of said fluid with suspended aragonite is removed from this formation, whereby the permeability of this formation is further increased or maintained. 2. The method according to claim 1, in which cracks were created by hydraulic fracturing of this formation. 3. The method according to claim 2, in which the fluid was used for hydraulic fracturing. 4. The method according to claim 1, in which to create positive ions in the fluid using a pulsed ion generator that uses electromagnetic fields. 5. The method according to claim 4, in which the acting electromagnetic fields pulsate with a full period of up to three hundred and sixty times per second. 6. The method according to claim 4, in which the acting electromagnetic fields pulsate with a half-cycle of up to one hundred and eighty kilohertz. 7. The method according to claim 4, in which the ion generator operates at frequencies in the range from about 80 kilohertz to 360 kilohertz. 8. The method according to claim 1, further comprising removing suspended aragonite from the fluid and reusing the fluid. 9. The method according to claim 1, in which the fluid prevents clogging of the cracks. 10. The method according to claim 1, in which the fluid acts in the formation as a biocidal coagulator. 11. The method according to claim 1, in which the fluid has a water base.

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