RU2323332C2 - Thermal treatment of in-situ hydrocarbon-containing reservoir with the use of naturally-distributed combustion chambers - Google Patents

Abstract

FIELD: hydrocarbon, hydrogen and/or other product extraction methods and systems, particularly enhanced recovery methods thereof with the use of heat, namely in-situ hydrocarbon conversion.

SUBSTANCE: method for in-situ hydrocarbon reservoir treatment involves supplying heat from one or several sources to at least one reservoir section, wherein heat sources may include natural distributed combustion chamber. Natural distribution combustion chamber comprises oxidizing fluid source to supply oxidizing fluids to reaction reservoir zone for heat generation in reaction zone. Heat is transferred from reaction zone to selected transversal reservoir section so that heat from one or several heat sources provide pyrolysis of at least one part of hydrocarbons in selected zone. Hydrocarbons are produced from said reservoir.

EFFECT: increased method efficiency and production system reliability.

31 cl, 10 dwg

Description

FIELD OF THE INVENTION

The present invention generally relates to methods and systems for producing hydrocarbons, hydrogen and / or other products from various hydrocarbon containing formations. Certain implementation options relate to in situ conversion of hydrocarbons for hydrocarbon, hydrogen and / or new product streams from underground hydrocarbon containing formations using naturally distributed combustion chambers.

State of the art

Hydrocarbons obtained from underground (e.g., sedimentary) formations are often used as energy resources, feedstocks and consumer goods. Concern over the depletion of available hydrocarbon resources and the deterioration in the overall quality of produced hydrocarbons has led to the development of methods for more efficient extraction, processing and / or use of available hydrocarbon resources. To remove hydrocarbon materials from underground formations, you can use the methods implemented at the place of occurrence. In order for the hydrocarbon material to be easier to remove from the subterranean formation, it may be necessary to change the chemical and / or physical properties of the hydrocarbon material in the subterranean formation. Chemical and physical changes may include in situ reactions that result in removal of fluids, changes in composition, changes in solubility, changes in density, phase changes and / or changes in viscosity of the hydrocarbon material in the formation. The fluid may include, but is not limited to the following, a gas, liquid, emulsion, suspension and / or solid particle stream, the flow characteristics of which are similar to the corresponding characteristics of a liquid stream.

Examples of location-based methods using downhole heating plants are illustrated in U.S. Pat.

A heat source can be used to heat the subterranean formation. Electric heaters and / or electric heating elements are described in US Pat. No. 2,548,360 to Germain, US Pat. No. 4,716,960 to Eastlund et al., US Pat. No. 5,065,818 to Van Egmond and US Pat. No. 4,570,715 to Van Meurs et al.

Fuel can be used to heat the formation. Burning fuel to heat the formation may be more economical than using electricity to heat the formation. Several different types of heaters can use fuel combustion as a heat source that will heat the formation. Burning can occur in the formation, in the well and / or near the surface. Burning in the reservoir can be carried out in the form of an in-situ moving combustion zone. An oxidizing agent can be pumped into the reservoir. The oxidizing agent can be ignited to advance the combustion front towards the production well. The oxidizing agent pumped into the formation by the pump can flow through the formation along fault lines in the formation. The ignition of the oxidizing agent as a result may not even lead to a uniform advance of the combustion front through the formation.

Disclosure of invention

In one embodiment, it is possible to convert hydrocarbons of a hydrocarbon-containing formation (e.g., a coal-containing formation, bituminous shale, heavy hydrocarbons, or a combination thereof) in the formation at the location and a mixture of relatively high-quality hydrocarbon products, hydrogen, and / or other products is obtained. One or more heat sources can be used to heat a portion of a hydrocarbon containing formation to temperatures that will make possible the pyrolysis of hydrocarbons. Hydrocarbons, hydrogen, and other formation fluids can be removed from the formation through one or more production wells. In some embodiments, formation fluids may be removed in the vapor phase. In other embodiments, formation fluids can be removed in the liquid and vapor phases or in the liquid phase. In order to obtain improved products from the formation, the temperature and pressure during pyrolysis can be controlled in at least part of the formation.

In one embodiment, a naturally distributed combustion chamber may provide heating for the hydrocarbon containing formation. A naturally distributed combustion chamber may include a heater located in the opening barrel in the formation. The heater may provide heating for at least a portion of the formation. A naturally distributed combustion chamber may include an oxidizing fluid source. The source of oxidizing fluid may provide oxidizing fluid to the reaction zone of the formation in order to obtain heat in the reaction zone. Part of the reaction zone can be pre-heated using a heater. The natural distributed combustion chamber may include a first channel located in the opening barrel. The first channel may provide oxidizing fluid from a source of oxidizing fluid to the reaction zone in the formation. The oxidizing fluid may oxidize at least a portion of the hydrocarbons in the reaction zone to generate heat. Heat generated in the reaction zone can be transferred from the reaction zone to the formation.

In one embodiment, the oxidizing fluid may be transported through the reaction zone essentially by diffusion. The diffusion rate can be controlled by changing the temperature of the reaction zone. In some embodiments, it is possible to substantially suppress the flow of oxidizing fluid from the reaction zone to the surrounding portion of the formation. It may turn out that the heat transfer from the reaction zone to the formation will be essentially due to heat conduction. It may be possible to transfer heat resulting from oxidation from the reaction zone to the pyrolysis zone in the formation. Heat that can be transferred to the pyrolysis zone can lead to the pyrolysis of at least a portion of the hydrocarbons in the pyrolysis zone of the formation.

In some embodiments, for controlling temperature, at least throughout the segment of the first channel, at least throughout the segment of the first channel, the flow rate of the oxidizing fluid can be controlled. The flow rate can be adjusted to control the heating rate, at least in the transverse part of the formation. The first channel may include openings for supplying oxidizing fluid to the opening barrel. In some embodiments, the first channel may include critical flow openings that control the flow of oxidizing fluid to control the rate of oxidation in the formation.

In some embodiments, molecular hydrogen may be supplied to the reaction zone. At least a portion of the supplied hydrogen can be obtained in the reaction zone. At least a portion of the supplied molecular hydrogen can be produced in the heat-treated portion of the formation. Molecular hydrogen can be fed to the reaction zone to suppress the formation of carbon dioxide.

In one embodiment, the natural distributed combustion chamber may include a second channel. The second channel may provide for the removal of oxidation product from the formation. The second channel may provide for the removal of the oxidation product to maintain a substantially constant temperature in the formation. The second channel may allow you to adjust the oxygen concentration in the opening barrel so that the oxygen concentration would remain substantially constant. The first channel may include openings that direct the oxidizing fluid in a direction substantially opposite to the direction in which the oxidation products are removed by the openings of the second channel. For the second channel, there may be a larger concentration of holes in the region of the upper end of the second channel. The second channel may allow heat transfer from the oxidation product to the oxidizing fluid in the first channel. The pressure of the fluids in the first and second channels can be controlled so that the concentration of the oxidizing fluid along the length of the first channel is essentially uniform.

In one embodiment, a method of supplying heat to a hydrocarbon containing formation at a location may include heating a portion of the formation to a temperature sufficient to maintain a reaction between the hydrocarbons in that part and the oxidizing fluid. The oxidizing fluid can be fed into the reaction zone in the formation. In order to obtain heat in the reaction zone, it may be possible to react the oxidizing fluid with at least a portion of the hydrocarbons in the reaction zone. Heat generated in the reaction zone can be transferred to the formation.

Brief Description of the Drawings

For a person skilled in the relevant field, the advantages of the present invention may become apparent when using the following detailed description of preferred embodiments and when referring to the accompanying drawings, including:

Figure 1 is an illustration of the stages of heating a hydrocarbon containing formation.

Figure 2 is a schematic illustration of an embodiment of a portion of the in situ conversion system for treating a hydrocarbon containing formation.

Figure 3 illustrates an embodiment of a heat source in the form of a naturally distributed combustion chamber.

Figure 4 illustrates a cross-sectional view of an embodiment of a natural distributed combustion chamber having a second channel.

Figure 5 illustrates a schematic representation of an embodiment of a well with a heater located in a hydrocarbon containing formation.

Figure 6 illustrates a portion of the overburden for the formation with a heat source in the form of a naturally distributed combustion chamber.

Figure 7 illustrates an embodiment of a heat source in the form of a naturally distributed combustion chamber.

Figure 8 illustrates an embodiment of a heat source in the form of a naturally distributed combustion chamber.

Figure 9 illustrates an embodiment of a natural distributed combustion chamber system for heating a formation.

Figure 10 illustrates an embodiment of a natural distributed combustion chamber system for heating a formation.

Although the invention is capable of various modifications and alternative forms, by way of example, its specific embodiments are shown in the drawings, and they can be described in detail herein. Drawings may not be to scale. However, it should be understood that the drawings and the detailed description thereto do not imply limiting the invention to the specific forms described, but, on the contrary, the invention should include all modifications, equivalents, and alternatives corresponding to the scope and spirit of the present invention defined in the attached claims.

The implementation of the invention

The following description generally relates to systems and methods for treating a hydrocarbon containing formation (e.g., a coal containing formation (including lignite, sapropelic coal, and the like), tar shale, coal shale, shungite, kerogen, bitumen, oil, kerogen, and oil in a matrix with low permeability, heavy hydrocarbons, asphaltites, natural mineral waxes, formations in which kerogen blocks the production of other hydrocarbons and the like). Such formations can be processed to produce relatively high quality hydrocarbon products, hydrogen, and other products.

“Hydrocarbons” are generally defined as molecules, primarily formed from carbon and hydrogen atoms. Hydrocarbons may also include other elements, such as, but not limited to, halogens, metal elements, nitrogen, oxygen and / or sulfur.

A "formation" includes one or more hydrocarbon-containing layers, one or more non-hydrocarbon layers covering the rock and / or the underlying rock. The “overburden” and / or “underburden” includes one or more different types of impermeable minerals. For example, overburden and / or bedrock may include rock, shale, mudstone, or wet / dense carbonate (i.e., impermeable carbonate without hydrocarbons). In some embodiments of the on-site conversion methods, the overburden and / or bedrock may include a hydrocarbon-containing layer or hydrocarbon-containing layers that are relatively impermeable and that are not exposed to temperatures during processing to undergo a conversion at the location, which results in significant characteristic changes in hydrocarbon-containing layers of the overburden and / or bedrock. For example, the underlying rock may contain shale or mudstone. In some cases, the overburden and / or bedrock may be somewhat permeable.

A “heat source” is any system for providing heat to at least a portion of a formation substantially as a result of heat transfer due to heat conduction and / or radiation. For example, the heat source may include electric heaters, such as an insulated conductor, an elongated part and / or a conductor located inside the channel. The heat source may also include heat sources that allow heat to be generated by burning fuel outside or inside the formation, such as ground burners, downhole gas burners, flameless distributed combustion chambers, and natural distributed combustion chambers. In addition, it is contemplated that in some embodiments, heat supplied to or obtained from one or more heat sources can be supplied using other energy sources. Other energy sources may directly heat the formation, or energy may be transferred to a coolant that will directly or indirectly heat the formation. It must be understood that one or more heat sources that supply heat to the formation can use various energy sources. For example, for a given formation, some heat sources can provide heat from electric heaters, some heat sources can provide heat from combustion, and some heat sources can provide heat from one or more other energy sources (e.g., chemical reactions, solar energy, wind energy, biomass or from other sources of renewable energy). A chemical reaction may include an exothermic reaction (e.g., an oxidation reaction). The heat source may include a heater that provides heat to an area adjacent to and / or surrounding the location of the heating, such as a well with a heater.

A “heater” is any system for generating heat in a well or in a near-wellbore zone. Heaters may include, but are not limited to, electric heaters, burners, and combustion chambers that provide a reaction to material present in or derived from the formation (e.g., natural distributed combustion chambers) and / or combinations thereof. “Heat source module” refers to several heat sources that make up the pattern that will be repeated to create a pattern of heat sources in the formation.

"Naturally distributed combustion chamber" means a heater that uses an oxidizing agent to generate heat to oxidize at least a portion of the carbon in the formation and where oxidation occurs in the area immediately adjacent to the wellbore. The main part of the combustion products obtained in a naturally distributed combustion chamber is removed through the wellbore.

“Holes” means openings (for example, openings in channels) with a wide variety of sizes and cross-sectional shapes, including, but not limited to the following, circles, ovals, squares, rectangles, triangles, slots, or other regular or irregular shapes.

Hydrocarbons in formations can be processed in various ways to produce many different products. In certain embodiments, such formations may be processed in stages. Figure 1 illustrates several stages of heating a hydrocarbon containing formation. Figure 1 also shows an example of yield (barrels of oil equivalent per tonne) (y axis) for formation fluids from a hydrocarbon containing formation depending on the temperature (° C) (x axis) of the formation.

During heating in stage 1, methane desorption and water evaporation occur. The heating of the formation in stage 1 can be carried out as quickly as possible. For example, upon initial heating of a hydrocarbon containing formation, hydrocarbons in the formation may desorb adsorbed methane. Desorbed methane can be extracted from the reservoir. If the hydrocarbon containing formation is further heated, water can be evaporated in the hydrocarbon containing formation. In some hydrocarbon containing formations, water may occupy from about 10% to about 50% of the pore volume in the formation. In other layers, water may occupy larger or smaller fractions of the pore volume. Typically, water evaporates in the formation in the range of about 160 ° C to about 285 ° C for pressures in the range of about 6 bar absolute pressure to 70 bar absolute pressure. During the on-site conversion method, in some embodiments, the pressure in the formation can be maintained in the range of from about 2 bar absolute pressure to about 70 bar absolute pressure. In some embodiments, evaporated water may cause changes in wettability in the formation and / or increase in reservoir pressure. Changes in wettability and / or increased pressure can affect pyrolysis reactions or other reactions in the formation. In certain embodiments, evaporated water from the formation may be produced. In other embodiments, evaporated water may be used for steam extraction and / or steam distillation in or out of the formation. Removing water from the pore volume and increasing the pore volume in the formation can increase the space containing hydrocarbons within the pore volume.

After heating in step 1, the formation can be heated further so that the temperature in the formation reaches (at least) the initial pyrolysis temperature (for example, the temperature at the lower end of the temperature range shown as stage 2). Hydrocarbons in the formation may be pyrolyzed during step 2. The pyrolysis temperature range may vary depending on the types of hydrocarbons in the formation. The pyrolysis temperature range may include temperatures ranging from about 250 ° C to about 900 ° C. The pyrolysis temperature range for obtaining the desired products may include only part of the full pyrolysis temperature range. In some embodiments, the pyrolysis temperature range for obtaining the desired products may include temperatures ranging from about 250 ° C to about 400 ° C. If the temperature of hydrocarbons in the formation slowly increases over the temperature range from about 250 ° C to about 400 ° C, the production of pyrolysis products can be essentially completed when the temperature approaches 400 ° C. Heating a hydrocarbon-containing formation using several heat sources can lead to the establishment of temperature gradients in the vicinity of heat sources, which will provide a slow increase in the temperature of hydrocarbons in the formation over the temperature range of pyrolysis.

In some embodiments of the on-site processing, the temperature of the hydrocarbons subjected to pyrolysis may not undergo a slow increase in the temperature range from about 250 ° C to about 400 ° C. Hydrocarbons in the formation can be heated until the desired temperature is reached (for example, approximately 325 ° C). Other temperatures can also be selected as the desired temperature. The supply of energy to the formation from heat sources can be controlled by maintaining the temperature in the formation at substantially the desired temperature. Hydrocarbons can be maintained essentially at the desired temperature until the pyrolysis efficiency begins to decline so that the production of the desired formation fluids from the formation becomes unprofitable.

In one embodiment of the on-site conversion method, the heating rate can be adjusted to minimize the costs associated with heating the selected area. Costs may include, for example, the cost of energy supplied and the cost of equipment. In certain embodiments, the costs associated with heating the selected cross section can be minimized by decreasing the heating rate when the costs associated with heating are relatively large and increasing the heating rate when the costs associated with heating are relatively small. For example, a heating rate of approximately 330 W / m can be used when the associated costs are relatively large, and a heating rate of approximately 1640 W / m can be used when the associated costs are relatively small. In certain embodiments, the heating rates may range from about 300 W / m to about 800 W / m when the associated costs are relatively high, and in the range from about 1000 W / m to 1800 W / m when the related costs are relatively small. The costs associated with heating can be relatively high during periods of peak energy consumption, such as during the daytime. For example, energy consumption can be large in warm climates during the daytime in summer due to energy consumption for air conditioning. Periods of low energy consumption can be, for example, at night or during weekends at the end of the week, when there is a tendency to reduce energy demand. In one embodiment, the heating rate may vary from a higher heating rate during periods of low energy consumption, such as during nighttime, to a lower heating rate during periods of high energy consumption, such as during daytime.

As shown in FIG. 2, in addition to heat sources 100, one or more production wells 106 will typically be located in a portion of a hydrocarbon containing formation. Formation fluids may be produced through production well 106. In some embodiments, production well 106 may include a heat source. The heat source can heat part of the formation at or near the location of the production well, and it can make it possible to remove formation fluids in the form of a vapor phase. The need for pumping fluids from a production well using a high temperature pump can be reduced or eliminated. Eliminating or limiting the pumping of liquids using a high-temperature pump can significantly reduce production costs. Conducting heating at or through the location of the production well can: (1) suppress condensation and / or reflux of the production well fluid when such production well fluid moves in the production well near the overburden, (2) increase heat input to the formation and / or (3) increase the permeability of the formation at or near the location of the production well. In some embodiments of the on-site conversion method, the amount of heat supplied to production wells is significantly less than the amount of heat supplied to heat sources that provide heating to the formation.

As permeability and / or porosity increase in a heat-treated formation, the resulting vapors can flow considerable distances along the formation with a relatively small pressure drop. An increase in permeability can occur as a result of a decrease in the mass of the part subjected to heating due to the evaporation of water, as a result of the removal of hydrocarbons and / or the creation of fractures. Vibes can more easily flow through a portion exposed to heat. In some embodiments, production wells may be present in the upper portions of the hydrocarbon layers.

The fluid obtained in the hydrocarbon containing formation may travel as a vapor over a considerable distance through the hydrocarbon containing formation. A significant distance can exceed 1000 m, depending on various factors (for example, permeability of the formation, properties of the fluid, temperature of the formation and pressure gradient, which makes it possible to move the fluid). Due to the increase in permeability in the formation, which undergoes conversion at the place of occurrence and removal of formation fluids, it may be necessary to equip production wells only with every second module of heat sources or every third, fourth, fifth or sixth module of heat sources.

During the implementation of the method at the location, production wells can function in such a way that the pressure in production wells is less than the pressure in other parts of the formation. In some embodiments, a vacuum may be created in production wells. Maintaining production wells at lower pressures can inhibit fluid migration in the formation beyond the treatment area at the location.

Certain embodiments may include controlling the amount of heat supplied to at least a portion of the formation, so that less desirable products are substantially suppressed in the portion. Adjusting the amount of heat supplied to at least a portion of the formation can also increase uniformity of permeability in the formation. For example, adjusting the heating of the formation to suppress the production of less desirable products in some embodiments may include controlling the heating rate so that it is kept at a level less than a selected value (e.g., 10 ° C, 5 ° C, 3 ° C, 1 ° C, 0, 5 ° C or 0.1 ° C) per day.

In some embodiments, a superposition (eg, overlapping) of heat from one or more heat sources may result in substantially uniform heating of a portion of the hydrocarbon containing formation. Since the layers during heating will usually be characterized by the presence of temperature profiles passing through them, in the context of this patent, “substantially uniform” heating means heating, such that temperatures in most of the cross section would not differ by more than 100 ° C from the estimated average temperature in most of the selected cross-section (volume) subjected to processing.

Substantially uniform heating of the hydrocarbon containing formation can result in a substantially uniform increase in permeability. For example, uniform heating can lead to the formation of a series of substantially uniform faults within the portion subjected to heating due to thermal stresses in the formation. Essentially uniform heating can lead to the formation of fluids obtained by pyrolysis in this part in a substantially uniform manner. The removal of water due to evaporation and production as a result can lead to an increase in permeability for the portion subjected to heating. In addition to the formation of faults due to thermal stresses, faults can also occur due to an increase in fluid pressure. Since fluids are produced inside the heated portion, the pressure of the fluids inside the heated portion may also increase. Then, when the fluid pressure approaches the lithostatic pressure of the portion subjected to heating, faults may form. Substantially uniform heating and uniform fluid formation can result in substantially uniform fractures within the portion subjected to heating. In some embodiments, the permeability of the heat-cross-section of the hydrocarbon containing formation may not differ by more than a factor of approximately 10.

Formation fluids, including fluids obtained by pyrolysis, can be extracted from the reservoir. Fluids produced by pyrolysis may include, but are not limited to the following, hydrocarbons, hydrogen, carbon dioxide, carbon monoxide, hydrogen sulfide, ammonia, nitrogen, water, and mixtures thereof. As the temperature of the formation increases, a tendency to decrease will be observed for the amount of condensable hydrocarbons in the produced formation fluid. At high temperatures, mainly methane and / or hydrogen can be produced from the formation. If the hydrocarbon-containing formation is subjected to heating, passing the full range of pyrolysis, then only small amounts of hydrogen can be produced from the formation in the region of the upper limit of the pyrolysis range. After all available hydrogen has been exhausted, there will usually be a minimum amount of fluid production from the formation.

Certain implementation options for treating heavy hydrocarbons in a relatively low permeability formation may include providing heat from one or more heat sources to pyrolyze a certain amount of heavy hydrocarbons and then evaporate some of the heavy hydrocarbons. Heat sources can cause pyrolysis of at least a portion of the heavy hydrocarbons in a selected part of the formation and can lead to an increase in pressure in at least a smaller part of the selected part of the formation. During heating, the pressure in the formation can increase significantly. The pressure in the formation can be adjusted so that the pressure in the formation can be maintained at a level that ensures the production of fluid of the desired composition. The fluid obtained by pyrolysis can be removed from the formation in the form of steam through one or more wells for heaters using back pressure created by heating the formation.

After pyrolysis of hydrocarbons, a large amount of carbon and a certain amount of hydrogen may still be in the formation. A significant portion of the carbon remaining in the formation can be produced from the formation in the form of synthesis gas. The production of synthesis gas may occur during heating in step 3 of FIG. 1. Step 3 may include heating the hydrocarbon containing formation to a temperature sufficient to make synthesis gas possible. For example, synthesis gas can be obtained within the temperature range from about 400 ° C to about 1200 ° C. The temperature of the formation when a fluid is introduced into the formation that produces synthesis gas can determine the composition of the synthesis gas produced in the formation. If the fluid leading to the production of synthesis gas is introduced into the formation at a temperature sufficient to make synthesis gas possible, synthesis gas can be produced in the formation. The resulting synthesis gas can be removed from the reservoir through a production well or production wells. During the formation of synthesis gas, it is possible to obtain synthesis gas in large volumes.

Figure 2 shows a schematic representation of an embodiment of a portion of the in situ conversion system for treating a hydrocarbon containing formation. Heat sources 100 can be placed inside at least a portion of the hydrocarbon containing formation. Heat sources 100 may include, for example, electric heaters such as insulated conductors, heaters with a conductor located in the channel, ground burners, flameless distributed combustion chambers and / or natural distributed combustion chambers. Heat sources 100 may also include other types of heaters. Heat sources 100 may provide heat to at least a portion of a hydrocarbon containing formation. Energy can be supplied to the heat sources 100 through the supply lines 116. The supply lines can be structurally different depending on the type of heat source or the heat sources used to heat the formation. The supply lines for heat sources can transmit electricity for electric heaters, can transport fuel for combustion chambers, or they can transport fluid heat carrier that circulates inside the formation.

Production wells 106 may be used to remove formation fluid from the formation. The formation fluid obtained from production wells 106 can be transported through collection pipe 118 to processing plants 120. The formation fluids can also be extracted from heat sources 100. For example, fluid can be extracted from heat sources 100 to control pressure inside the formation adjacent to the sources heat. Fluid recovered from heat sources 100 can be transported through a piping system or piping to a collection pipe 118 or recovered fluid can be transported through a piping system or piping directly to processing plants 120. Processing plants 120 may include separation plants, reaction plants, refinement plants, fuel cells, turbines, storage tanks and other systems and devices for processing produced reservoir fluids.

The in situ conversion system for treating hydrocarbons may include barrier wells 122. In some embodiments, barriers can be used to inhibit the migration of fluids (eg, produced fluids and / or groundwater) to a portion of the formation and / or from a portion of the formation subjected to the conversion method at the place of occurrence. Barriers may include, but are not limited to the following, naturally occurring parts (e.g., overburden and / or underlying rock), freeze wells, frozen barrier zones, low temperature barrier zones, cemented walls, sulfur wells, dewatering wells, injection wells, a barrier, formed by the gel obtained in the formation, the barrier formed by the precipitation of salts in the formation, the barrier formed by the polymerization reaction in the formation, the interlayer , Is pushed into the formation, or combinations thereof.

Formation fluids produced from a hydrocarbon containing formation during processing may contain a mixture of various components. To increase the economic value of the products obtained from the formation, the formation fluid can be processed using a wide range of processing methods. Methods used to treat the formation fluid may include distillation (e.g., atmospheric distillation, fractionated distillation and / or vacuum distillation), condensation (e.g. fractionated), cracking (e.g. thermal cracking, catalytic cracking, fluid catalytic cracking, hydrocracking, fuel oil hydrocracking and / or vapor cracking), reforming (e.g., thermal reforming, catalytic reforming and / or vapor phase hydroforming), hydrogenation, coking, ra solvents, solvent dewaxing, polymerization (e.g., catalytic polymerisation and / or catalytic isomerization), light cracking, alkylation, isomerization, deasphalting, hydrodesulfurization, catalytic dewaxing, demineralization, extraction (e.g., phenols, other aromatic compounds and the like) and / or distillation of light fractions.

Formation fluids can be exposed to treatment methods in the first treatment area at the location where the formation fluid is received and produced, in the second treatment area at the location where the specific treatment method is implemented, and / or in surface treatment plants. "Surface treatment plant" is a plant used to process at least a portion of the formation fluid on the surface of the earth. Ground processing plants may include, but are not limited to the following, reactors (e.g., hydrotreatment plants, cracking plants, ammonia plants, fertilizer plants and / or oxidation plants), separation plants (e.g. air separation plants, plants for liquid-liquid extraction, adsorption plants, absorbers, plants for the extraction and / or production of ammonia, plants for vapor / liquid separation, distillation columns, reaction vessels tifikatsionnye column and / or condensing units), units for reboiling, heat exchangers, pumps, pipes, storage tanks and / or plant for producing energy (e.g., fuel cells and / or gas turbines). Several ground processing installations used in series, parallel and / or in a combination of serial and parallel versions are called ground objects configuration. The configuration of ground objects can radically differ, which is explained by the composition of the reservoir fluid, as well as the resulting products.

For a wide range of ground handling configuration products, you can combine with the processing processes in various ground handling systems. On-site products may vary depending on local and / or global market conditions, formation characteristics, proximity of the formation to the customer, and / or available feedstock. The resulting products can be used locally, transported to another place for use and / or sold to the buyer.

The composition of the obtained products can be changed as a result of the regulation of conditions in the processing zone and / or in one or more installations for ground processing. Conditions in the treatment area and / or in one or more ground processing installations that affect the composition of the products include, but are not limited to the following, average temperature, fluid pressure, partial pressure H ₂ , temperature gradients, composition of the formation material, speed heating and the composition of the fluids entering the treatment area and / or installation for ground processing. For the synthesis and / or separation of specific components from the reservoir fluid, there are many different configurations of terrestrial objects.

Adjusting the conditions in the formation to control the pressure of hydrogen in the produced fluid can result in improved quality of the produced fluids. In some embodiments, it may be desirable to control the conditions in the formation so that the partial pressure of hydrogen in the produced fluid is greater than about 0.5 bar absolute pressure when measured at the location of the production well.

In one embodiment, the on-site treatment of a hydrocarbon containing formation may include adding hydrogen to the selected cross section after the temperature in the selected cross section has at least become approximately 270 ° C. Other embodiments may include controlling the temperature of the formation by selectively adding hydrogen to the formation.

In one embodiment, a portion of the hydrocarbon containing formation may be heated to increase the partial pressure of H ₂ . In some embodiments, the increased partial pressure of H ₂ may include a partial pressure of H ₂ in the range of from about 0.5 bar to about 7 bar. Alternatively, the range of increased partial pressure of H ₂ may include partial pressures of H ₂ ranging from about 5 bar to about 7 bar. For example, most hydrocarbon fluids can be produced when the partial pressure of H ₂ is in the range of from about 5 bar to about 7 bar. The range of partial pressures of H ₂ within the range of partial pressures of H ₂ during pyrolysis may vary depending, for example, on the temperature and pressure in the portion of the formation subjected to heating.

Maintaining the partial pressure of H ₂ inside the reservoir at a level exceeding atmospheric pressure can lead to an increase in the density in degrees of API for produced condensed hydrocarbon fluids. Maintaining an increased partial pressure of H ₂ can lead to an increase in the density in degrees of API for produced condensed hydrocarbon fluids to a value exceeding approximately 25 ° or in some cases exceeding approximately 30 °. Maintaining an increased partial pressure of H ₂ inside the heated portion of the hydrocarbon containing formation may increase the concentration of H ₂ within the heated portion. H ₂ may be available for reaction between it and the pyrolyzed hydrocarbon components. The reaction of H ₂ with the pyrolyzed hydrocarbon components can eliminate the polymerization of olefins to produce tar and other crosslinked products that are difficult to refine. Therefore, it is possible to suppress the production of hydrocarbon fluids characterized by low density values in degrees ANI.

The in situ conversion method can result in significant quantities of H ₂ and hydrocarbon fluids in the formation. The production of hydrogen in the formation and the pressure in the formation sufficient to stimulate the transition of hydrogen to a liquid state inside the formation can lead to the formation of a reducing medium in the formation without the need for introducing a reducing fluid into the formation (for example, Н ₂ and / or non-condensable saturated hydrocarbons). The hydrogen component of the formation fluid extracted from the formation can be separated and used for desired purposes. Desirable goals may include, but are not limited to, fuel for fuel cells, fuel for combustion chambers, and / or a feed stream for surface hydrogenation plants.

In one embodiment, a method of treating a hydrocarbon containing formation at the location may include adding hydrogen to a selected area of the formation, where the selected area is under certain conditions or undergoes their effect. For example, hydrogen can be added through a heater well or a production well located in or near a selected area. Since hydrogen is sometimes in relative scarcity (or relatively expensive to obtain or acquire), hydrogen can be added when conditions in the formation optimize the use of added hydrogen. For example, hydrogen produced in a part of a formation in which synthesis gas is produced can be added to a part of a formation in which pyrolysis proceeds. The addition of hydrogen to the cross-section of the formation in which pyrolysis proceeds can stimulate the production of aliphatic compounds and suppress the formation of olefin compounds, which impair the quality of hydrocarbon fluids extracted from the formation.

In some embodiments, hydrogen may be added to the selected cross-section after the average formation temperature reaches the pyrolysis temperature level (for example, when the selected cross-section is at a temperature of at least about 270 ° C). In some embodiments, hydrogen may be added to the selected region after the average temperature has at least become approximately 290 ° C, 320 ° C, 375 ° C, or 400 ° C. Hydrogen can be added to the selected cross section before the average temperature of the formation becomes approximately 400 ° C. In some embodiments, hydrogen can be added to the selected cross-section before the average temperature becomes approximately 300 ° C or approximately 325 ° C.

The average temperature of the formation can be controlled by selectively adding hydrogen to a selected area of the formation. Hydrogen added to the reservoir can take part in exothermic reactions. Exothermic reactions can cause the formation to heat up and lead to a decrease in the amount of energy that will need to be supplied to the formation from heat sources. In some embodiments, an amount of hydrogen may be added to the selected cross section of the formation so that the average temperature of the formation does not exceed about 400 ° C.

The pressure within the heated portion of the hydrocarbon containing formation may be maintained, varied, and / or controlled by a valve. For example, a heat source located within a hydrocarbon containing formation may be coupled to the valve. The valve can lead to the release of fluid from the reservoir due to the action of a heat source. In addition, the injection valve can be connected to a production well in a hydrocarbon containing formation. In some embodiments, the fluids released by using the valves can be collected and transported to a surface facility for subsequent processing and / or processing.

The in situ conversion method for hydrocarbons may include supplying heat to a portion of the hydrocarbon containing formation and controlling temperature, rate of increase in temperature and / or pressure in the portion subjected to heating. The temperature and / or the rate of temperature increase for the heated portion can be controlled by changing the amount of energy supplied to the heat sources in the formation.

Hydrocarbons subjected to conversion at the place of occurrence can be located under large areas of the earth's surface. The in situ conversion system can be used to treat small parts of the formation, and other parts of the formation can be processed after. In one embodiment of the implementation of a reservoir treatment system (eg, tar shale reservoir), a field plan for 24 years of development can be divided into 24 separate massifs, which will be individual drilling years. Each array can include 120 "cells" (repeating matrix elements), where each section is formed of cells in 6 rows of 20 columns. Each cell can include 1 production well and 12 or 18 wells for heaters. Wells for heaters can be placed in the pattern of an equilateral triangle with a distance between wells of approximately 12 m. Production wells can be located in the centers of equilateral triangles formed by wells for heaters, or production wells can be located at a point approximately in the middle between two adjacent wells for heaters.

The exact location of the wells for heaters, production wells, and the like will depend on variables specific to a particular formation (e.g., layer thickness or layer composition), profitability of the project, and the like. In certain embodiments, heater wells may be substantially horizontal, while production wells may be vertical, or vice versa. In some embodiments, the wells may be positioned along a dip or strike or orientated at an angle between the dip and strike.

The distance between heat sources may vary depending on a number of factors. Factors may include, but are not limited to, the type of hydrocarbon containing formation, the selected heating rate, and / or the selected average temperature obtained inside the portion subjected to heating. In some embodiments of the well location system, the distance between the heat sources may be in the range of about 5 m to about 25 m. In some embodiments of the well location system, the distance between the heat sources can be in the range of about 8 m to about 15 m.

In certain embodiments, one or more channels may be provided for supplying additional components (e.g., nitrogen, carbon dioxide, reducing agents such as a gas containing hydrogen, and the like) to the formation wells, for bleeding fluids and / or for regulating pressure . There is a trend in which reservoir pressures will be maximum near heat sources. It may be beneficial to have pressure control equipment in heat sources. In some embodiments, the addition of a reducing agent in the vicinity of the heat source contributes to creating a more favorable environment for pyrolysis (for example, creating a higher partial pressure of hydrogen). Since permeability and porosity tend to increase more rapidly in the vicinity of a heat source, it is often the best option to add a reductant in the vicinity of the heat source so that the reductant can more easily pass into the formation.

In one embodiment, the hydrocarbon containing formation may be heated using a naturally distributed combustion chamber system located in the formation. You can create the conditions under which the received heat will be transferred to the selected cross section of the reservoir. A naturally distributed combustion chamber can provide oxidation of hydrocarbons in the formation in the vicinity of the wellbore to supply heat to the selected cross section of the formation.

A temperature sufficient to maintain oxidation may be at least equal to about 200 ° C or 250 ° C. A temperature sufficient to maintain oxidation will tend to vary depending on many factors (for example, the composition of the hydrocarbons in the hydrocarbon containing formation, the water content in the formation and / or the type and amount of oxidizing agent). Prior to heating, some water may be removed from the formation. For example, water can be pumped out of the formation by a pump using dewatering wells. The heated portion of the formation may be located in the vicinity of the opening stem in the hydrocarbon containing formation or substantially adjacent to it. An opening barrel in the formation may be a well for a heater created in the formation. The heated portion of the hydrocarbon containing formation may extend from the opening trunk in a radial direction to a width in the range of about 0.3 m to about 1.2 m. However, the width may also be less than about 0.9 m. The width of the heated portion may vary depending on time. In certain embodiments, the variations depend on factors including the width of the formation necessary to produce enough heat during carbon oxidation to maintain the oxidation reaction without introducing heat from an additional heat source.

Once the temperature of a portion of the formation reaches a temperature sufficient to maintain oxidation, an oxidizing fluid may be supplied to the opening to oxidize at least a portion of the hydrocarbons in the reaction zone or in the zone of the heat source within the formation. The oxidation of hydrocarbons in the reaction zone will lead to heat. The heat generated in most embodiments will be transferred from the reaction zone to the pyrolysis zone in the formation. In certain embodiments, the heat generated is transferred at a speed in the range of about 650 W / m to 1650 W / m as measured by the depth of the reaction zone. After the oxidation of at least a certain amount of hydrocarbons in the formation, the supply of energy supplied to the heater to initially heat the formation to a temperature sufficient to maintain oxidation can be reduced or stopped. The cost of supplying energy can be significantly reduced by using naturally distributed combustion chambers, thereby creating a much more efficient system for heating the formation.

In one embodiment, a channel may be placed in the opening for supplying oxidizing fluid to the opening barrel. The channel may be provided with openings for regulating the flow rate or other flow control mechanisms (i.e., slots, venturi flow meters, valves, and the like) to allow oxidizing fluid to enter the opening barrel. The term “openings” includes openings with a wide variety of cross-sectional shapes, including, but not limited to the following, circles, ovals, squares, rectangles, triangles, slots, or other regular or irregular shapes. The flow control holes in some embodiments may be critical flow holes. The openings for controlling the flow rate can provide a substantially constant flow of oxidizing fluid to the opening bore regardless of the pressure in the opening bore.

In some embodiments, the number of holes for controlling the flow rate may be limited by the diameter of the holes and the desired distance between the holes along the length of the channel. For example, as the diameter of the holes decreases, the number of holes for controlling the flow rate may increase, and vice versa. In addition to this, as the desired distance will increase, the number of holes for regulating the flow rate may decrease, and vice versa. The diameter of the holes can be determined by the pressure in the channel and / or the desired flow rate through the holes. For example, for a flow rate of approximately 1.7 normal cubic meters per minute and a pressure of approximately 7 bar absolute pressure, the diameter of the hole may be approximately 1.3 mm with a distance between the holes of approximately 2 m. Holes with a smaller diameter can clog easier than large diameter holes. Holes can become clogged for various reasons. Reasons may include, but are not limited to, the presence of contaminants in the fluid flowing in the channel and / or solid deposits in or near the openings.

In some embodiments, the number and diameter of the holes is selected so that a more uniform or almost uniform heating profile is obtained along the depth of the opening trunk in the formation. The depth of the heated formation, which provides for the creation of an approximately uniform heating profile, can exceed approximately 300 m or even exceed approximately 600 m. However, this depth can vary depending on, for example, the type of the heated formation and / or the desired productivity.

In some embodiments, the openings for controlling the flow rate may be located along the contour of the spiral around the channel inside the opening barrel. The holes for regulating the flow rate when arranged along the contour of the spiral may have a distance between each other in the range of from about 0.3 m to about 3 m. In some embodiments, the distance may be in the range of from about 1 m to about 2 m, for example, be equal to approximately 1.5 m

The flow of oxidizing fluid into the opening can be controlled so as to control the rate of oxidation in the reaction zone. The heat transfer between the incoming oxidizing agent and the oxidation off-products can provide heating for the oxidizing fluid. Heat transfer can also keep the channel temperature below the maximum operating temperature of the channel.

Figure 3 illustrates an embodiment of a natural distributed combustion chamber. The flow of oxidizing fluid 130 can be controlled along the length of the tamper 132 or the reaction zone 134. The tamper 132 can be considered an “elongated tamper”, such that the reaction zone 134 and the tamper 132 can share a common boundary along the defined length of the tamper. The flow of oxidizing fluid can be controlled using one or more openings 136 (the openings may be openings with a critical flow regime). The flow of oxidizing fluid can be controlled by the diameter of the holes 136, the number of holes 136 and / or the pressure in the inner channel 138 (pressure behind the holes 136). Regulation of the flow of oxidizing fluid can provide temperature control on the outer surface of the reaction zone 134 in the opening barrel 132. For example, an increased flow rate of oxidizing fluid 130 will tend to increase the temperature on the outer surface of the reaction zone 134. Increasing the flow of oxidizing fluid in the opening barrel tends to lead to increase the rate of oxidation of hydrocarbons in the reaction zone. Since the oxidation of hydrocarbons is an exothermic reaction, an increase in the oxidation rate will tend to increase the temperature in the reaction zone.

In some embodiments of naturally distributed combustion chambers, the flow of oxidizing fluid 130 may vary along the length of the inner channel 138 (for example, when using holes with a critical flow regime 136) so that the temperature on the outer surface of the reaction zone 134 will be variable. The temperature on the outer surface of the reaction zone 134 or inside the opening barrel 132 can be varied to control the heat transfer rate inside the reaction zone 134 and / or the heating rate within the selected cross section 140. An increase in temperature on the outer surface of the reaction zone 134 can lead to an increase in the heating rate within selected cross section 140. You can track any property of the oxidation product 144 (for example, oxygen content, nitrogen content, temperature, and so on Noah). The property of oxidation product 144 can be monitored and used to control properties at the inlet to a naturally distributed combustion chamber (e.g., the amount of oxidizing fluid at the inlet).

The diffusion rate of the oxidizing fluid 130 through the reaction zone 134 may vary depending on the temperature of the reaction zone and the region adjacent to it. In general, the higher the temperature, the faster the gas will diffuse due to the increase in gas energy. The temperature inside the opening can be estimated (for example, measured using a thermocouple) and correlated with the temperature of the reaction zone. The temperature inside the opening can be controlled by controlling the flow of oxidizing fluid into the opening from the internal channel 138. For example, increasing the flow of oxidizing fluid into the opening can lead to an increase in temperature inside the opening. Reducing the flow of oxidizing fluid into the opening can lead to a decrease in temperature inside the opening. In one embodiment, the oxidizing fluid flow can be increased until a selected temperature is reached below the metallurgical temperature limits for the equipment used. For example, the flow of oxidizing fluid can be increased until the maximum operating temperature for the metal used in the channel located in the opening barrel is reached. The temperature of the metal can be measured directly using a thermocouple or other device for measuring temperature.

In one embodiment of the natural distributed combustion chamber, carbon dioxide production within the reaction zone 134 can be suppressed. An increase in hydrogen concentration in the reaction zone can inhibit the production of carbon dioxide in the reaction zone. The concentration of hydrogen may increase as a result of hydrogen entering the reaction zone. In one embodiment, hydrogen can enter the reaction zone from a selected cross section 140. Hydrogen can be produced during the pyrolysis of hydrocarbons in a selected cross section. Hydrogen can enter the reaction zone from a selected cross section due to diffusion and / or convection. In addition, an additional amount of hydrogen can be supplied to the autopsy 132 or another autopsy in the formation through a channel located in the autopsy. Additional hydrogen may enter the reaction zone from the autopsy barrel 132.

In some embodiments of naturally distributed combustion chambers, heat may be supplied to the formation from a second heat source located in the wellbore of the naturally distributed combustion chamber. For example, along with the heat from a naturally distributed combustion chamber, an electric heater (for example, a heater with an insulated conductor or a heater with a conductor located in the channel), used to preheat part of the formation, can also be used to supply heat to the formation. In addition, in order to supply additional heat to the formation, an additional electric heater can be arranged in the opening in the formation. An electric heater can be used to supply heat to the formation so that for the heat supplied from the combination of an electric heater and a naturally distributed combustion chamber, a constant rate of heat input is maintained. The heat input to the formation from the electric heater can vary as the heat input from the naturally distributed combustion chamber varies, or vice versa. Providing heat input from more than one type of heat source may make it possible to substantially uniformly heat the formation.

In certain embodiments of the method of conversion at the place of occurrence from electric heaters into the formation, up to 10%, 25% or 50% of the total heat input can be supplied. The percentage of heat input to the formation from electric heaters can vary depending, for example, on the cost of electricity, heat supply from a naturally distributed combustion chamber, and the like. Heat from electric heaters can be used to compensate for the low thermal power of naturally distributed combustion chambers while maintaining a substantially constant heating rate in the formation. If the cost of electricity increases, then to reduce the amount of heat supplied from electric heaters, you can get more heat from naturally distributed combustion chambers. In some embodiments, heat from electric heaters may vary depending on the source of electricity (for example, solar or wind energy). In such embodiments, to compensate for changes in the heat supply from the electric heaters, it is possible to more or less provide heat from the naturally distributed combustion chambers.

In one embodiment of a heat source, an electric heater may be used to suppress "extinction" of a naturally distributed combustion chamber. A naturally distributed combustion chamber may “go out” if part of the formation cools below a temperature sufficient to sustain combustion. To provide heat to this part and / or another part of the formation to heat the part to a temperature sufficient to maintain the oxidation of hydrocarbons and to withstand the conditions of the heating method of a naturally distributed combustion chamber, it may be necessary to use additional heat from an electric heater.

In some embodiments of a natural distributed combustion chamber, electric heaters can be used to supply more heat to the formation near the top and / or bottom of the formation. The use of additional heat from electric heaters can compensate for heat loss in the upper and / or lower parts of the formation. The supply of additional heat using electric heaters located near the upper and / or lower parts can allow for more uniform heating of the formation. In some embodiments, for such purposes (e.g., supplying heat in the upper and / or lower parts, supplying additional heat, supplying heat to maintain a minimum combustion temperature, and the like), electric heaters can be used in combination with other types of fuel heaters, such as flameless distributed combustion chambers or downhole combustion chambers.

In some embodiments of the method for locally converting the combustion products, fluids from a fuel heater (e.g., a naturally distributed combustion chamber or a downhole combustion chamber) can be used in an air compressor located on the surface of the formation near the opening hole used for the fuel heater. Combustion fluids can be used to drive an air compressor and reduce the costs associated with compressing air for use in a fuel heater. By using fluids of combustion products in a turbine or similar device, electricity can also be obtained. In some embodiments, the supply of fluids (eg, oxidizing fluid and / or fuel) used for one or more fuel heaters can be accomplished using a compressor or a series of compressors. The compressor may provide oxidizing fluid and / or fuel for a single heater or more than one heater. In addition, the supply of oxidizing fluid and / or fuel for use in an individual heater or in more than one heater may be provided from a centralized structure.

Hydrocarbon pyrolysis or other temperature-controlled processes can take place in a heat treated selected region 140. During pyrolysis, the temperature of the selected region 140 can range from about 270 ° C to about 400 ° C. The temperature of the selected region 140 can be increased by heat transfer from the reaction zone 134.

The temperature inside the opening 132 can be monitored using a thermocouple located in the opening 132. Alternatively, the thermocouple can be connected to a channel 142 and / or placed on the outer surface of the reaction zone 134. The power supply or the oxidizing agent introduced into the formation can be adjusted based on at a monitored temperature to withstand temperatures in a selected range. The selected range may or may vary depending on the location of the thermocouple, the desired heating rate of the hydrocarbon layer 108, and other factors. If the temperature inside the opening bore 132 drops to a temperature lower than the minimum temperature for the selected temperature range, it will be possible to increase the flow rate of the oxidizing fluid 130 to enhance combustion and thus increase the temperature inside the opening bore 132.

In certain embodiments, one or more naturally distributed combustion chambers may be positioned along the strike of the hydrocarbon layer and / or horizontally. The location of the natural distributed combustion chambers along the strike or horizontally can lead to a decrease in pressure drops along the length of the heated part of the heat source. Reducing pressure drops can provide greater uniformity and ease of regulation for the temperature obtained along the length of the heater.

In some embodiments, it is possible to track the presence of 144 air or oxygen (O ₂ ) in the oxidation product. Alternatively, the amount of nitrogen, carbon monoxide, carbon dioxide, nitrogen oxides, sulfur oxides and the like can be monitored in oxidation product 144. Tracking the composition and / or quantity of combustion products (e.g., oxidation product 144) may be useful for heat balances, process diagnostics, process control, and the like.

Figure 4 illustrates a cross-sectional view of an embodiment of a natural distributed combustion chamber having a second channel 146 located in the opening barrel 132 in the hydrocarbon layer 108. The second channel 146 can be used to remove oxidation products from the opening barrel 132. The second channel 146 may have holes 136 located along its length. In certain embodiments, oxidation products are removed from the upper region of the tamper 132 through openings 136 located on the second channel 146. Holes 136 can be positioned along the length of the channel 146 so that more oxidation products are removed from the upper region of the tamper 132.

In certain embodiments of the natural distributed combustion chamber, the openings 136 on the second channel 146 can be facing in the opposite direction from the openings 136 on the channel 138. Orientation may prevent oxidizing fluid supplied through the channel 138 directly into the second channel 146.

In some embodiments, the channel 146 may have a higher density of holes 136 (and / or the presence of holes of a relatively larger diameter 136) in the upper region of the tamper 132. Preferred removal of oxidation products from the upper region of the tamper 132 can provide a substantially uniform concentration of oxidizing fluid medium along the length of the opening 132. Oxidation products obtained from reaction zone 134 tend to concentrate to a greater extent near the upper region of the opening digging 132. There is a tendency in which a large concentration of oxidation products 144 in the upper region of the opening 132 causes dilution of the concentration of oxidizing fluid 130 in the upper region. Removing a significant portion of the more concentrated oxidation products from the upper region of the tamper 132 can achieve greater uniformity for the concentration of the oxidizing fluid 130 along the tamper 132. Having a more uniform concentration of the oxidizing fluid along the tamper can provide a more uniform motive force for the flow of oxidizing fluid media into the reaction zone 134. A more uniform driving force may allow greater uniformity in the rate of oxidation in the reaction. constant area 134 and thus allow for greater uniformity of heating rate for the selected region 140 and / or greater uniformity of temperature inside the opening 132 of the barrel.

In one embodiment of a natural distributed combustion chamber in the reaction zone, the concentration of air and / or oxygen can be controlled. A more uniform distribution of oxygen (or oxygen concentration) in the reaction zone may be desirable. The reaction rate can be adjusted depending on the rate at which oxygen diffuses into the reaction zone. Oxygen diffusion rate correlates with oxygen concentration. Thus, the regulation of the oxygen concentration in the reaction zone (for example, as a result of the regulation of the flow rate of the oxidizing fluid, the removal of oxidation products on some part of the length of the reaction zone or along its entire length and / or the distribution of the oxidizing fluid on some part of the length of the reaction zone or throughout its length) can provide regulation of oxygen diffusion in the reaction zone and, thus, regulation of reaction rates in the reaction zone.

In this embodiment, 170 is placed in the opening barrel 132. The conductor 170 can extend from the first end 148 of the opening barrel 132 to the second end 150 of the opening barrel 132. In certain embodiments, the conductor 170 can be located in the opening barrel 132 inside the hydrocarbon layer 108. One or more low impedance sections 174 may be connected to conductor 170 and used in overburden 158. In some embodiments, conductor 170 and / or low impedance sections 174 may extend above the surface of the formation.

In some embodiments of the heat sources, an electric current can be supplied to the conductor 170 to increase the temperature of the conductor. Heat can be transferred from the conductor 170 to the heated portion 152 of the hydrocarbon layer 108. Heat can be transferred from the conductor 170 to the heated portion 152 essentially by radiation. Some of the heat can also be transferred due to convection or thermal conductivity. An electric current can be passed through the conductor until the temperature in the heated portion 152 is sufficient to maintain oxidation of the hydrocarbons in the heated portion. As shown in FIG. 5, oxidizing fluid can be supplied to conductor 170 from an oxidizing fluid source 154 at one or both ends 148, 150 of the tamper 132. The flow of oxidizing fluid from the conductor 170 to the tamper 132 can be controlled using openings 136 Holes can be holes with critical flow conditions. The flow of oxidizing fluid from the openings 136 can be controlled using the diameter of the openings, the number of openings and / or the pressure inside the conductor 170 (i.e., pressure behind the openings).

As a result of the reaction of oxidizing fluids with hydrocarbons in the reaction zone 134, heat can be generated. The rate of heat release in reaction zone 134 can be controlled using a change in the rate of oxidizing fluid entering the formation, the diffusion rate of the oxidizing fluid through the reaction zone, and / or the rate of removal of oxidation products from the formation. In one embodiment, the oxidation products obtained by reacting the oxidizing fluid with hydrocarbons in the formation are removed through one or both ends of the opening 132. In some embodiments, a channel may be provided to remove the oxidation products in the opening. All oxidation products, or parts thereof, can be recycled and / or reused in other oxidation type heaters (e.g., natural distributed combustion chambers, surface burners, downhole combustion chambers, and the like). Heat generated in reaction zone 134 may be transferred to the surrounding portion (e.g., selected cross section) of the formation. The heat transfer between the reaction zone 134 and the selected cross section can be carried out essentially due to thermal conductivity. In certain embodiments, the heat transferred may increase the temperature of the selected cross section to a level that exceeds the minimum hydrocarbon dilution temperature to the flow state and / or the minimum hydrocarbon pyrolysis temperature.

In some embodiments of the heat sources, the channel may be located in the opening barrel. The opening can pass through the formation in contact with the surface of the earth at the first point of the well and at the second point of the well. The oxidizing fluid can be fed into the channel from an oxidizing fluid source located at a first well location and / or at a second well location after a portion of the formation has been heated to a temperature sufficient to maintain oxidation of the hydrocarbons by the oxidizing fluid.

Figure 6 illustrates an embodiment of a cross-section of a cover rock with a naturally distributed combustion chamber described in Figure 3. The casing for cover rock 156 can be positioned in the cover rock 158 of hydrocarbon layer 108. The casing for cover rock 156 can be surrounded by materials (eg, insulating material , such as cement), which will prevent the heating of the overburden 158. The casing for the overburden 156 may be made of a metal material such as but not limited to the following, carbon steel or stainless steel 304.

The casing pipe for the overburden 156 may be positioned in the reinforcing material 160 in the overburden 158. The reinforcing material 160 may include, but is not limited to, cement, gravel, sand, and / or concrete. Between the casing of the overburden 156 and the opening bore 132 in the formation, sealing material 162 may be provided. The sealing material 162 may be any substantially non-porous material (e.g., cement, concrete, mortar, and the like). Sealing material 162 may prevent fluid from flowing out of the channel 142 and between the opening bore 132 and the surface 110. The internal channel 138 may allow fluid to enter the opening bore 132 in the hydrocarbon layer 108. The channel 142 may allow for the removal of the combustion product (or excess oxidizing fluid) from the opening barrel 132 in the hydrocarbon layer 108. The diameter of the channel 142 can be determined by the amount of combustion product obtained by oxidation in a naturally distributed chamber wounding. For example, a larger diameter may be necessary for a larger amount of the combustion product obtained by the heater in the form of a naturally distributed combustion chamber.

In some embodiments of heat sources, a portion of the formation adjacent to the well can be heated to a temperature at a heating rate such that hydrocarbons can be converted to coke or coal adjacent to the well under the action of the first heat source. Coke and / or coal can form at temperatures exceeding approximately 400 ° C. In the presence of an oxidizing fluid, coke or coal will oxidize. After the formation of coke and / or coal, the well can be used as a naturally distributed combustion chamber. Heat can be obtained as a result of the oxidation of coke or coal.

Figure 7 illustrates an embodiment of a heater in the form of a naturally distributed combustion chamber. The insulated conductor 164 can be connected to the channel 166 and located in the borehole 132 in the hydrocarbon layer 108. The insulated conductor 164 can be located inside the channel 166 (thereby making it possible to remove the insulated conductor 164) or, alternatively, it can be connected to the outer surface of the channel 166. The conductor insulation material may include, but is not limited to, the mineral coating and / or ceramic coating. On the channel 166, over the length of the opening of the opening 132, holes with a critical flow regime 136 can be arranged. An electric current can be supplied to the insulated conductor 164 in order to receive radiant heat in the opening opening 132. Channel 166 can serve as a return wire for electric current. Insulated conductor 164 can provide heat to portion 152 of hydrocarbon layer 108 to a temperature sufficient to support hydrocarbon oxidation.

The source of oxidizing fluid 154 may provide an oxidizing fluid to channel 166. The oxidizing fluid can be fed into the opening barrel 132 through critical flow openings 136 in the channel 166. The oxidizing fluid can oxidize at least a portion of the hydrocarbon layer in the reaction zone 134. Part of the heat generated in the reaction zone 134 can be transferred to selected cross section 140 due to convection, radiation and / or thermal conductivity. The oxidation product can be removed through a separate channel located in the opening bore 132, or through the opening bore 168 in the casing for the overburden 156.

Figure 8 illustrates an embodiment of a heater in the form of a naturally distributed combustion chamber with an added fuel channel. The fuel channel 170 can be positioned in the opening barrel 132. In some embodiments, the fuel channel can be positioned adjacent to the channel 172. The fuel channel 170 may have openings with critical flow rates 174 over a portion of the length within the opening barrel 132. Channel 172 over part of the length within the opening bore 132 may have holes with a critical flow regime 136. The holes with a critical flow regime 174, 136 can be positioned so that the fuel fluid supplied through the fuel channel 170, and the oxidizing fluid is fed via the passageway 172, would not enter into the reaction and would not heated fuel channel and the channel. The heat generated in the reaction of the fuel fluid and the oxidizing fluid can lead to heating of the fuel channel 170 and / or channel 172 to a temperature sufficient to start melting metallurgical materials in the fuel channel 170 and / or channel 172 if the reaction proceeds close to the fuel channel 170 and / or channel 172. Critical flow holes 174 on the fuel channel 170 and critical flow holes 136 on channel 172 can be positioned so that the fuel fluid and oxidizing fluid eds would not react near the canals. For example, the channels 170 and 172 can be positioned so that the holes that are arranged in a spiral around the channels are oriented in opposite directions.

The reaction of the fuel fluid and the oxidizing fluid can produce heat. In some embodiments, the fuel fluid may be methane, ethane, hydrogen, or synthesis gas, which is obtained by in situ conversion in another part of the formation. The resulting heat can provide heating of part 152 to a temperature sufficient to maintain oxidation of hydrocarbons. After heating part 152 to a temperature sufficient to maintain oxidation, the flow of fuel fluid into the opening 132 can be reduced or can be stopped. In some embodiments, the fuel supply can be continued all the time during the heating of the formation.

The oxidizing fluid may oxidize at least a portion of the hydrocarbons in the reaction zone 134. The resulting heat may be transferred to the selected cross section 140 through radiation, convection, and / or thermal conductivity. The oxidation product can be removed through a separate channel located in the opening bore 132, or through the opening bore 168 in the casing for the overburden 156.

Figure 9 illustrates an embodiment of a system that can provide heating for a hydrocarbon containing formation. An electric heater 176 may be positioned within the opening bore 132 in the hydrocarbon layer 108. The opening bore 132 can be passed through the overburden 158 into the hydrocarbon layer 108. The opening bore 132 may be at least about 5 cm in diameter. By way of example, the opening bore 132 may have a diameter of approximately 13 cm. An electric heater 176 may heat at least a portion 152 of the hydrocarbon layer 108 to a temperature sufficient to maintain oxidation (eg, about 260 ° C.). Part 152 may have a width of approximately 1 m. The oxidizing fluid may be fed into the opening barrel through channel 142 or any other suitable fluid transfer mechanism. Channel 142 may have critical flow openings 136 located along the length of the channel.

Channel 142 may be a pipe or pipe that delivers oxidizing fluid from the source of oxidizing fluid 154 into the opening barrel 132. In one embodiment, the portion of the channel 142 that may be exposed to high temperatures is a stainless steel pipe, and part a channel that will not be exposed to high temperatures (i.e., the part of the pipe that passes through the overburden) is formed of carbon steel. The oxidizing fluid may include air or any other oxygen-containing fluid (for example, hydrogen peroxide, nitrogen oxides, ozone). Mixtures of oxidizing fluids are possible. A mixture of oxidizing fluids may be a fluid comprising fifty percent oxygen and fifty percent nitrogen. In some embodiments, the oxidizing fluid may include compounds that release oxygen when heated, such as hydrogen peroxide. The oxidizing fluid may oxidize at least a portion of the hydrocarbons in the formation.

Figure 10 illustrates an embodiment of a system that provides heating for a hydrocarbon containing formation. A heat exchanger 178 can be located outside the opening barrel 132 in the hydrocarbon layer 108. The opening barrel 132 can be passed through the overburden 158 into the hydrocarbon layer 108. The heat exchanger 178 can supply heat from another ground process or it can include a heater (for example, an electric heater or a heater in type of combustion chamber). The oxidizing fluid source 154 may provide oxidizing fluid to the heat exchanger 178. The heat exchanger 178 can heat an oxidizing fluid (for example, above 200 ° C or to a temperature sufficient to maintain the oxidation of hydrocarbons). The heated oxidizing fluid can be supplied to the opening barrel 132 through the channel 180. On the channel 180 along the length of the channel, holes with a critical flow regime 136 can be arranged. The heated oxidizing fluid can provide heating, or at least contribute to heating, at least at least part 152 of the formation to a temperature sufficient to maintain the oxidation of hydrocarbons. The oxidizing fluid may oxidize at least a portion of the hydrocarbons in the formation. Once the temperature in the formation is sufficient to maintain oxidation, the use of heat exchanger 178 can be reduced or discontinued.

An embodiment of a natural distributed combustion chamber may include a ground-based combustion chamber (e.g., a torch ignition heater). The fuel fluid in the combustion chamber can be oxidized. The oxidized fuel fluid may be supplied from the heater through a channel to an opening barrel in the formation. Oxidation products and unreacted fuel can be returned to the earth's surface through another channel. In some embodiments, one of the channels may be located within another channel. The oxidized fuel fluid may provide heating or contribute to heating a portion of the formation to a temperature sufficient to support hydrocarbon oxidation. After reaching a temperature sufficient to maintain oxidation, the oxidized fluid of the fuel can be replaced by an oxidizing fluid. The oxidizing fluid may oxidize at least a portion of the hydrocarbons in the reaction zone in the formation.

An electric heater may provide heating of a portion of a hydrocarbon containing formation to a temperature sufficient to maintain hydrocarbon oxidation. The part may be located near the opening trunk in the formation or substantially adjacent to it. The portion may extend radially from the opening trunk to a width of less than about 1 m. An oxidizing fluid may be supplied to the opening to oxidize hydrocarbons. In a naturally distributed combustion process, the oxidation of hydrocarbons can provide heating for a hydrocarbon containing formation. The electric current supplied to the electric heater can subsequently be reduced or can be turned off. To implement the method of heating a hydrocarbon-containing formation with reduced energy input compared to using only an electric heater, natural distributed combustion can be used in combination with an electric heater.

Given this description, the specialist in the relevant field may become apparent and subsequent modifications and alternative implementations of various aspects of the invention. Accordingly, this description should be taken only as illustrative and intended for the purpose of presentation to specialists in the relevant field of the General method of implementing this invention. You must understand that the forms of this invention, shown and described herein, should be construed as currently preferred embodiments. The elements and materials illustrated and described herein can be replaced, parts and methods can be reversed, and some features of the invention can be used independently, all of which will become apparent to those skilled in the art after using this description of the invention. The elements described herein may be modified without departing from the scope and spirit of the invention described in the following claims.

Claims (31)

1. A system configured to provide heating for a hydrocarbon containing formation, including a heater located in the opening barrel in the formation, where the heater can be configured to supply, during use, heat to at least a portion of the formation; an oxidizing fluid source for supplying the oxidizing fluid to the reaction zone of the formation to produce heat in the reaction zone as it is used; a first channel for placement in the opening barrel, where the first channel can be configured to supply oxidizing fluid from a source of oxidizing fluid to the reaction zone, as used, in the formation; moreover, the entire system can be configured to transfer the received heat from the reaction zone to the formation, as it is used, and the whole system can be configured to transport the oxidizing fluid through the reaction zone essentially due to diffusion, as it is used; the system further includes a second channel configured to be placed in the opening barrel, the second channel can additionally be configured so that during use to ensure the removal of the oxidation product, and the second channel can be further configured so that during use to ensure the removal of the oxidation product in such a way so that the reaction zone would have a substantially uniform temperature profile. 2. The system of claim 1, wherein during use, at least a portion of the reaction zone is preheated using a heater. 3. The system according to claim 1 or 2, where during use the oxidizing fluid oxidizes at least a portion of the hydrocarbons in the reaction zone as it is used. 4. The system according to claim 1 or 2, where the oxidizing fluid, in fact, is delayed when it flows from the reaction zone to the surrounding part of the formation, as it is used. 5. The system according to claim 1 or 2, where the system can be configured so that during use it becomes possible to transfer the received heat from the reaction zone to the pyrolysis zone in the formation. 6. The system according to claim 1 or 2, where the system can be configured so that during use it becomes possible to transfer the received heat from the reaction zone to the formation essentially due to thermal conductivity, as it is used. 7. The system according to claim 1 or 2, where during use the flow of oxidizing fluid can be controlled at least throughout the portion of the first channel so that at least throughout the portion of the first channel the temperature can be controlled. 8. The system according to claim 1 or 2, where the flow rate of the oxidizing fluid can be controlled at least over the area of the first channel so that at least in part of the formation it would be possible to control the heating rate. 9. The system according to claim 1 or 2, where you can create a configuration in which during use the oxidizing fluid would move through the reaction zone essentially due to diffusion, as it is used, where the diffusion rate can be controlled as a result of changes in temperature in the reaction zone . 10. The system according to claim 1 or 2, where the first channel includes openings, and where the openings can be configured to provide oxidizing fluid to the opening barrel during use. 11. The system according to claim 1 or 2, where the first channel includes holes with a critical flow regime, and where the holes with a critical flow regime can be configured to adjust the flow of oxidizing fluid during use to adjust the rate of oxidation in the formation. 12. The system according to claim 1 or 2, where the flow rate of at least part of the oxidizing fluid can be controlled at least during the segment of the first channel. 13. The system according to claim 1 or 2, where at least a portion of the formation extends from the opening trunk in the radial direction to a distance less than about 3 m 14. The system according to claim 1 or 2, where the reaction zone extends from the opening barrel in the radial direction to a distance less than about 3 m 15. The system according to claim 1 or 2, where the system can be configured so that heat transfer is possible for the pyrolysis of at least a portion of the hydrocarbons in the pyrolysis zone in the formation. 16. The system according to claim 1 or 2, where the system can be configured so that during use to ensure the supply of molecular hydrogen to the reaction zone. 17. The system according to clause 16, where during use, at least part of the supplied hydrogen is obtained in the pyrolysis zone. 18. The system of claim 17, wherein during use, at least a portion of the hydrogen feed is obtained in the reaction zone. 19. The system of claim 17, wherein during use, at least a portion of the hydrogen supplied is obtained in at least a portion of the formation subjected to heating. 20. The system according to 17, where the system can be configured so that during use to ensure the supply of hydrogen to the reaction zone so as to suppress the receipt in the reaction zone of carbon dioxide. 21. The system according to claim 1, where the second channel can be configured so that during use to adjust the oxygen concentration in the opening barrel so that the oxygen concentration in the opening barrel is essentially constant in the opening barrel. 22. The system of claim 21, wherein the second channel includes openings that remove the oxidation product from a direction substantially opposite the first channel. 23. The system according to item 21, where the second channel includes holes, and where the second channel has a higher concentration of holes at the upper end of the second channel. 24. The system of claim 21, wherein the first channel includes openings that guide the oxidizing fluid in a direction substantially opposite to the second channel. 25. The system according to item 21, where the second channel can optionally be configured to provide heat to the oxidation product of the oxidizing fluid in the first channel. 26. The system of claim 21, wherein during use, the pressure of the oxidizing fluid in the first channel and the pressure of the oxidizing product in the second channel are controlled so that the concentration of the oxidizing fluid along the length of the first channel is substantially uniform. 27. The system according to claim 1, where the first end of the opening hole is in contact with the surface of the earth at the first point of the well, and the second end of the opening line is in contact with the surface of the earth at the second point of the well. 28. A system configured to provide heating for a hydrocarbon containing formation, including a heater configured to be placed in the opening barrel in the formation, where the heater is configured to supply, during use, heat to at least a portion of the formation; an oxidizing fluid source configured to supply, during use, an oxidizing fluid to the formation reaction zone to produce heat in the reaction zone; a first channel configured to be placed in the opening barrel, where the first channel is configured to supply, during use, an oxidizing fluid from an oxidizing fluid source to the reaction zone in the formation, wherein the system is configured so that during use it becomes possible to transfer the received heat from the reaction zone to the formation, the system further includes a second channel configured to be placed in the opening barrel, the second channel can additionally be configured so that during use to ensure the removal of the oxidation product, and the second channel can be further configured so that during use to ensure the removal of the oxidation product in such a way so that the reaction zone would have a substantially uniform temperature profile. 29. The system of claim 28, wherein the first end of the opening barrel contacts the ground at the first well location and the second end of the opening contacts the ground at the second well location. 30. A system that provides heating of a hydrocarbon containing formation, including a heater located in the opening barrel in the formation, where the heater during use provides heat to at least a portion of the formation; an oxidizing fluid source for supplying, during use, an oxidizing fluid to the formation reaction zone to produce heat in the reaction zone; a first channel located in the opening barrel, where the first channel during use provides the supply of oxidizing fluid from a source of oxidizing fluid to the reaction zone in the formation; the system during use makes it possible to transfer the received heat from the reaction zone to the formation, the system further includes a second channel configured to be placed in the opening barrel, the second channel can additionally be configured so that during use to ensure the removal of the oxidation product, and the second channel can be further configured so that during use to ensure the removal of the oxidation product in such a way so that the reaction zone would have a substantially uniform temperature profile. 31. The system of claim 30, wherein the first end of the opening barrel contacts the ground at the first well location and where the second end of the opening contacts the ground at the second well location.

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