RU2510454C2 - Oil and/or gas extraction system and method (versions) - Google Patents

Abstract

FIELD: oil and gas industry.

SUBSTANCE: extraction method of oil and/or gas from an underground formation involves the following: the first well in the formation; a transfer mechanism to the first well of a mixed composition improving oil recovery; the second well in the formation; a mechanism for extraction from the second well of oil and/or gas; with that, the first well and the second well is an internal part of the system; a set of barrier wells outside the first well and the second well; and a mechanism for transfer to the barrier wells of a barrier agent for displacement of the mixed composition improving oil recovery and/or oil or gas in the formation to the second well for extraction of the product from the above second well.

EFFECT: improving efficiency of solutions based on use of a mixing displacement technology.

26 cl, 8 dwg

Description

FIELD OF THE INVENTION

The present invention relates to systems and methods for producing oil and / or gas.

State of the art

In order to increase oil recovery in fields, oil recovery enhancement methods can be used everywhere. Along with traditional methods of oil production, three main types of MPPOs can be used to increase oil recovery: thermal, reagent / polymer, and gas injection, which can be used to extend the life of the field or increase the oil recovery coefficient.

Thermally stimulated production is carried out by supplying heat to the collector. The most common form is oil vapor displacement, which reduces the viscosity of the oil to such an extent that it acquires the ability to flow in the direction of production wells. The injection of reagents increases the return due to the weakening of the capillary forces that block the residual oil. Injection of polymers increases the efficiency of oil displacement by injected water. Pumping a miscible medium acts like pumping a reagent. By pumping a fluid that is miscible with oil, it is possible to produce locked residual oil.

Turning to FIG. 1, the current system 100 is illustrated. System 100 includes an underground formation 102, an underground formation 104, an underground formation 106, and an underground formation 108. A production unit 110 is located on the surface. Well 112 intersects the formation 102 and 104 and ends in the formation 106. One of the sections of the formation 106 is indicated at 114. Oil and gas are produced from the formation 106 through the well 112 towards the production unit 110. The gas and liquid are separated, after which the gas is stored in the gas storage 116 and the liquid is stored in the liquid storage 118.

US Pat. No. 7,225,866 discloses that a formation formed by oil shale can be treated using an in situ thermal process. A mixture of hydrocarbons, H ₂ and / or formation fluids can be produced from such a formation. Heat may be supplied to the formation in order to raise the temperature of a portion of the formation to the pyrolysis temperature. Heat sources can be used to heat the formation. Heat sources can be located inside the formation in a specific order. US patent No. 7225866 is fully incorporated into this application by reference.

U.S. Patent Application Publication No. 2006/0254769, published Nov. 16, 2006 and having patent attorney registration number TH2616, discloses a system including a mechanism for extracting oil and / or gas from an underground formation that contains one or more sulfur compounds; a mechanism for converting at least a portion of the sulfur compounds from the produced oil and / or gas into a carbon disulfide composition; and a mechanism for releasing at least a portion of the carbon disulfide composition into the formation. US Patent Application Publication No. 2006/0254769 is fully incorporated into this application by reference.

There is a need in the art for improved systems and methods for secondary oil recovery. At the same time, there is a need in the art for improved systems and methods for the secondary recovery of oil using a solvent, for example, by reducing the viscosity, the effect of reagents and introducing miscible substances. In addition, there is a need in the art for improved systems and methods for introducing miscible solvents.

Disclosure of invention

In one aspect of the invention, there is provided a system for producing oil and / or gas from an underground formation, including: a first well in the formation; a mechanism for pumping into the first well a miscible, enhanced oil recovery composition; a second well in the formation; a mechanism for producing oil and / or gas from a second formation; where the first layer and the second layer include the interior of the system; a plurality of barrier wells outside the first well and the second well; and a mechanism for pumping a barrier agent into the barrier wells.

In another aspect of the invention, there is provided a method for producing oil and / or gas, comprising pumping a carbon disulfide composition into a formation through a first well; production of oil and / or gas from the formation through a second well; and pumping the barrier agent into the formation from a variety of barrier wells. In some embodiments, the method also includes recovering from the oil and / or gas the carbon disulfide composition (if present) and then injecting at least a portion of the recovered carbon disulfide composition into the formation.

In yet another aspect of the invention, there is provided a method for producing oil and / or gas, comprising injecting into the formation a miscible, enhanced oil recovery composition through a first well; production of oil and / or gas from the formation through a second well; and pumping a barrier agent into the formation through barrier wells.

Advantages of the invention include one or more of the following:

Improved systems and methods for increasing the production of hydrocarbons from the formation using a solvent.

Improved systems and methods for increasing production of hydrocarbons from a formation using a fluid containing a miscible solvent.

Improved compositions and / or methods for secondary hydrocarbon production.

Improved oil recovery systems and methods.

Improved systems and methods for enhancing oil recovery using a miscible solvent.

Improved oil recovery systems and methods using a compound that mixes with oil in the reservoir.

Brief Description of the Drawings

Figure 1 - oil and / or gas production system.

Figure 2a is an illustration of well placement.

Fig.2b and 2c is an illustration of the placement of wells in Fig.2a in the conditions of the processes of secondary oil production.

Figa-3c is an illustration of oil and / or gas production systems.

Figure 4 is an illustration of the placement of wells.

The implementation of the invention

Figa:

Turning now to FIG. 2a, which illustrates some embodiments of an array of 200 wells. The well array 200 includes a group of 202 wells (indicated by horizontal lines) and a group of 204 wells (indicated by diagonal lines).

Array 200 delimits a production area enclosed in a rectangle. Array 200 limits the interior of the system. Outside the array 200, there are many barrier wells 250.

Each well from group 202 wells is spaced horizontally from its neighboring well from group 202 wells at a distance of 230. Each well from group 202 wells is spaced vertically from its neighboring well from group 202 wells at a distance of 232.

Each well from a group of 204 wells is horizontally separated from a neighboring well from a group of 204 wells at a distance of 236. Each well from a group of 204 wells is separated vertically from a neighboring well from a group of 204 wells at a distance of 238.

2a, horizontal distance 230 and horizontal distance 236 assume distances from left to right on the page, and vertical distance 232 and vertical distance 238 assume distances from top to bottom on the page. In practice, an array may consist of vertical wells that are perpendicular to the surface of the earth, horizontal wells that are parallel to the surface of the earth, or wells that are inclined to the surface of the earth at a certain angle, for example, at an angle of 30 to 60 °.

Each well in the group of 202 wells is separated from its neighboring wells from a group of 204 wells at a distance of 234. Each well in a group of 204 wells is separated from its neighboring wells from a group of 202 wells at a distance of 234.

In some embodiments, each well in a group of 202 wells is surrounded by four wells in a group of 204 wells. In some embodiments, at a distance of 238, each well in the well group 204 is surrounded by four wells from the well group 202.

In some embodiments, the horizontal distance 230 is from about 5 to about 1000 m, or from about 10 to about 500 m, or from about 20 to about 250 m, or from about 30 to about 200 m, or from about 50 to about 150 m, or from about 90 to about 120 m, or about 100 m.

In some embodiments, the vertical distance 232 is from about 5 to about 1000 m, or from about 10 to about 500 m, or from about 20 to about 250 m, or from about 30 to about 200 m, or from about 50 to about 150 m, or from about 90 to about 120 m, or about 100 m.

In some embodiments, the horizontal distance 236 is from about 5 to about 1000 m, or from about 10 to about 500 m, or from about 20 to about 250 m, or from about 30 to about 200 m, or from about 50 to about 150 m, or from about 90 to about 120 m, or about 100 m.

In some embodiments, the vertical distance 238 is from about 5 to about 1000 m, or from about 10 to about 500 m, or from about 20 to about 250 m, or from about 30 to about 200 m, or from about 50 to about 150 m, or from about 90 to about 120 m, or about 100 m.

In some embodiments, the distance 234 is from about 5 to about 1000 m, or from about 10 to about 500 m, or from about 20 to about 250 m, or from about 30 to about 200 m, or from about 50 to about 150 m , or from about 90 to about 120 m, or about 100 m.

In some embodiments, an array of 200 wells may include from about 10 to about 1000 wells, for example from about 5 to about 500 wells in a group of 202 wells and from about 5 to about 500 wells in a group of 204 wells. In this arrangement, from about 2 to about 1000 barrier wells 250, for example from about 5 to about 500, or from about 10 to about 200, can be placed.

In some embodiments, the implementation of the array of 200 wells is represented as a top view, where a group of 202 wells and a group of 204 wells are vertical wells, distributed on a piece of land. In some embodiments, an array of 200 wells is presented as a cross-sectional view where a group of 202 wells and a group of 204 wells are horizontal wells distributed within a formation.

The production of oil and / or gas from an underground reservoir using an array of 200 wells may be carried out in any known manner. Suitable methods include subsea production, surface mining, primary, secondary or tertiary mining. The choice of the method used for the extraction of oil and / or gas from an underground reservoir is not fundamental.

Barrier shielding of oil and / or gas and / or agent for secondary oil production using barrier wells 250 may be carried out in any known manner. Suitable methods include injecting water, peroxide, such as hydrogen peroxide or a solution of hydrogen peroxide in water, carbon dioxide, natural gas or other gaseous or liquid hydrocarbons, nitrogen, air, brine or other liquids or gases into the barrier wells 250. In another embodiment, barrier wells 250 may be used to create a frozen wall barrier. One such frozen wall barrier is described in US Pat. No. 7,225,866, which is incorporated herein by reference in its entirety. The selection of a method for a barrier enclosure of oil and / or gas and / or an agent for the secondary recovery of oil using barrier wells 250 is not critical.

In some embodiments, the implementation of oil and / or gas may be removed from the formation into the well and pass further down the well and the pipeline leaving the well to any installation. In some embodiments, secondary oil recovery using any agent, such as water vapor, water, a surfactant, polymer injection, and / or some miscible agent, can be used to enhance the flow of oil and / or gas from the formation. as a carbon disulfide composition or carbon dioxide.

In some embodiments, oil and / or gas produced from the formation may include any sulfur compound. The sulfur compound may be hydrogen sulfide, mercaptans, sulfides and disulfides other than hydrogen sulfide, or heterocyclic sulfur compounds, for example thiophenes, benzothiophenes, or substituted and condensed dibenzothiophenes or mixtures thereof.

In some embodiments, a sulfur compound from the formation may be converted to a carbon disulfide composition. The conversion of at least a portion of the sulfur compound to a carbon disulfide composition may be carried out by any known methods. Suitable methods may include the reaction of oxidizing the sulfur compound to sulfur or sulfur dioxide, and the reaction of sulfur and / or sulfur dioxide with carbon and / or with some carbon-containing compound to form a carbon disulfide composition. The selection of a method for converting at least a portion of a sulfur compound into a carbon disulfide composition is not critical.

In some embodiments, a suitable miscible oil recovery agent may be a carbon disulfide composition. The carbon disulfide composition may include carbon disulfide and / or carbon disulfide derivatives, for example thiocarbonates, xanthates and mixtures thereof and, optionally, one or more of the following compounds: hydrogen sulfide, sulfur, carbon dioxide, hydrocarbons and mixtures thereof.

A suitable process for producing a carbon disulfide composition for some embodiments is disclosed in US Patent Application Serial No. 11 / 409,436, filed April 19, 2006, and having patent attorney registration number TH2616. U.S. Patent Application No. 11 / 409,436 is fully incorporated into this application by reference.

Fig.2b:

Turning now to FIG. 2b, some embodiments of an array of 200 wells are illustrated. An array of 200 wells includes a group of 202 wells (indicated by horizontal lines) and a group of 204 wells (indicated by diagonal lines). Around the array of 200 wells are located barrier wells 250.

In some embodiments, a miscible oil recovery agent is pumped into a group of 204 wells, and oil is produced from a group of 202 wells. As follows from the illustration, the miscible agent for secondary oil production has an injection circuit 208, and for a group of 202 wells, an oil production circuit 206 operates. In some embodiments, the barrier agent is pumped into the barrier wells 250. As follows from the illustration, the barrier agent has an injection circuit around each of the barrier wells 250. The barrier agent can be used to displace the miscible agent for the secondary production of oil and / or oil and / or gas into direction of the group 202 production wells.

In some embodiments, a miscible oil recovery agent is pumped into a group of 204 wells, and oil is produced from a group of 202 wells. As follows from the illustration, the miscible agent for secondary oil production has an injection circuit 206, and for the group of 204 wells, an oil production circuit 208 operates. In some embodiments, the barrier agent is pumped into the barrier wells 250. As follows from the illustration, the barrier agent has an injection circuit around each of the barrier wells 250. The barrier agent can be used to displace a miscible agent for the secondary production of oil and / or oil and / or gas in the direction of a group of 204 producing wells.

In some embodiments, a group of 202 wells may be used to pump a miscible agent for secondary oil production, and a group of 204 wells may be used to produce oil and / or gas from the formation for a first period of time; after which a group of 204 wells can be used to pump a miscible agent for secondary oil production, and a group of 202 wells can be used to produce oil and / or gas from the reservoir during a second period of time, and the first and second time periods make up a certain cycle .

In some embodiments, many cycles may be performed that include alternating between groups 202 and 204 of injecting a miscible agent for secondary oil production and oil and / or gas production from the reservoir, during which one group of wells is injection and the other is producing during the first period of time, while during the second period of time the functions of these groups are switched.

In some embodiments, a cycle may be from about 12 hours to about 1 year, or from about 3 days to about 6 months, or from about 5 days to about 3 months. In some embodiments, each cycle can be extended over time, for example, each cycle can be about 5% to about 10% longer than the previous cycle, for example, about 8% longer.

In some embodiments, a miscible oil recovery agent or a mixture containing a miscible oil recovery agent may be pumped at the beginning of the cycle, while at the end of the cycle an immiscible oil recovery agent or a mixture containing an immiscible secondary oil agent may be pumped. oil production. In some embodiments, the start of the cycle may be from the first 10 to about 80% of the cycle, or from the first 20 to about 60% of the cycle, or from the first 25 to about 40% of the cycle, and the end of the cycle may be the remainder.

In some embodiments, suitable secondary miscible oil miscible agents may include carbon disulfide, hydrogen sulfide, carbon dioxide, octane, pentane, liquefied natural gas, aliphatic C ₂ -C ₆ hydrocarbons, nitrogen, diesel, white spirits, naphtha, asphalt solvent, kerosene, acetone, xylene, trichloroethane or mixtures of two or more of them, or other agents for the secondary oil recovery known in the art. In some embodiments, suitable secondary miscible oil miscible agents are secondary oil miscible miscible agents upon first contact or multiple contact with oil in the formation.

In some embodiments, suitable non-miscible agents for secondary oil recovery may be water in gaseous or liquid form, air, a mixture of two or more of them, or other agents known in the art for secondary oil recovery. In some embodiments, suitable secondary oil miscible agents are secondary oil miscible agents which are not miscible upon first contact or multiple contact with oil in the formation.

In some embodiments, an immiscible agent for secondary oil recovery and / or a miscible agent for secondary oil recovery can be used as a barrier agent and pumped into barrier wells 250.

In some embodiments, non-miscible and / or miscible secondary oil-injected agents injected into the formation may be recovered from the produced oil and / or gas and re-injected into the formation.

In some embodiments, the oil contained in the formation prior to injecting any secondary oil recovery agent has a viscosity of at least about 100 cps, or at least about 500 cps, or at least about 1000 cps, or at least about 2,000 cps, or at least about 5,000 cps, or at least about 10,000 cps. In some embodiments, the oil contained in the formation prior to injection of any secondary oil recovery agent has a viscosity of up to about 5,000,000 spr, or up to about 2,000,000 spf, or up to about 1,000,000 spf, or up to about 500,000 spf.

Fig.2c:

Turning now to FIG. 2c, some embodiments of an array of 200 wells are illustrated. The well array 200 includes a group of 202 wells (indicated by horizontal lines) and a group of 204 wells (indicated by diagonal lines). Outside the array 200, there are many barrier wells 250, forming a perimeter around the array 200.

In some embodiments, a miscible oil recovery agent is pumped into a group of 204 wells, and oil is produced from a group of 204 wells. As follows from the illustration, the miscible agent for secondary oil production has an injection circuit 208, which overlaps with the oil production circuit 206, which operates for a group of 202 wells. In some embodiments, the barrier agent is pumped into the barrier wells 250. As follows from the illustration, the barrier agent has an injection circuit around each of the barrier wells 250. The barrier agent can be used to displace the miscible agent for the secondary production of oil and / or oil and / or gas into direction of the group 202 production wells. After a sufficient period of time, the injection circuit of the barrier agent may overlap with one or more circuits: the injection circuit 208 and the oil production circuit 206, as a result of which the agent for secondary oil production is within the array 200, and / or as a result, the oil and / or gas is in within the array 200, and / or as a result, the barrier agent is withdrawn to the group 202 wells.

In some embodiments, a miscible oil recovery agent is pumped into a group of 202 wells, and oil is produced from a group of 204 wells. As follows from the illustration, the miscible agent for secondary oil production has an injection circuit 206 that overlaps in section 210 with an oil production circuit 208 that is valid for a group of 204 wells. In some embodiments, the barrier agent is pumped into the barrier wells 250. As follows from the illustration, the barrier agent has an injection circuit around each of the barrier wells 250. The barrier agent can be used to displace the miscible agent for the secondary production of oil and / or oil and / or gas into direction of the group 204 production wells. After a sufficient period of time, the injection circuit of the barrier agent may overlap with one or more circuits: the injection circuit 208 and the oil production circuit 206, as a result of which the agent for secondary oil production is within the array 200, and / or as a result, the oil and / or gas is in within the array 200, and / or as a result, the barrier agent is withdrawn to a group of 204 wells.

The release of at least a portion of the miscible agent for the secondary recovery of oil and / or other liquids and / or gases may be carried out by any known method. One suitable method is to pump a miscible [carbon disulfide] that improves the oil recovery of the composition into a separate pipeline in a separate well, followed by soaking to absorb the carbon disulfide composition and pumping at least a portion of the carbon disulfide composition with gas and / or liquids. Another suitable method is to pump a miscible, enhanced oil recovery composition into the first well, followed by pumping at least a portion of the miscible, enhanced oil recovery composition together with gas and / or liquids through the second well. The choice of the method used to pump at least part of a miscible, enhanced oil recovery composition and / or other liquids and / or gases is not critical.

In some embodiments, a miscible, enhanced oil recovery composition and / or other fluids and / or gases can be injected into the formation under pressure up to the fracture pressure.

In some embodiments, a miscible, enhanced oil recovery composition may be mixed with oil or gas in the formation to form a mixture that can be withdrawn from the well. In some embodiments, a certain amount of a miscible, enhanced oil recovery composition can be pumped into the well and some other component pumped to push the composition through the formation. For squeezing a miscible, enhanced oil recovery composition along the formation, for example, air, water in liquid or gaseous form, carbon dioxide, other gases, other liquids and / or mixtures thereof can be used.

In some embodiments, a miscible, enhanced oil recovery composition can be heated before it is injected into the formation to reduce the viscosity of the fluids in the formation, such as heavy oils, paraffins, asphaltenes, etc.

In some embodiments, in order to reduce the viscosity of the fluids in the formation, the miscible, enhanced oil recovery composition may be heated and / or boiled while inside the formation using a heated fluid or some kind of heater. In some embodiments, hot water and / or steam may be used to heat and / or vaporize the miscible, enhanced oil recovery composition in the formation.

In some embodiments, a miscible, enhanced oil recovery composition may be heated and / or boiled while inside the formation using a heater. One suitable heater is disclosed in the concurrently filed United States Patent Application No. 10 / 693,816, registered October 24, 2003, and having patent attorney registration number TH2557. United States Application No. 10 / 693,816 is hereby incorporated by reference in its entirety.

Figa and 3b:

Referring now to FIGS. 3a and 3b, which illustrate some embodiments of the invention regarding system 300. System 300 includes an underground formation 302, an underground formation 304, an underground formation 306, and an underground formation 308. A production unit 310 is located on the surface. Well 312 crosses strata 302 and 304 and has openings in stratum 306. Sections 314 of stratum 306 may in some cases be fractured and / or perforated. During the initial production, oil and gas from the reservoir 306 are discharged to sections 314, to the well 312 and sent to the installation 310. Next, the installation 310 is divided into gas, which is sent to the gas processing unit 316, and the liquid, which is sent to the liquid storage 318 . Installation 310 also has a storage 330 for a miscible, enhanced oil recovery composition. 3a, a miscible, enhanced oil recovery composition can be pumped down a well 312, which is shown by a downward arrow, and then into reservoir 306. A mixed, enhanced oil recovery composition can be left to soak in the formation for a period of time from about 1 hour to about 15 days, for example from about 5 to about 50 hours.

To hold a miscible, enhanced oil recovery composition between the barrier well 350 and the barrier well 360, the barrier well 350 has an injection mechanism 352, and the barrier well 360 has an injection mechanism 362. The injection mechanisms 352 and 362 can be used to inject a barrier agent, such as refrigerant, to create a frozen wall, cement, liquid sulfur, or any liquid or gas such as water, peroxide, peroxide solution, carbon dioxide, natural gas, other C ₁ -C ₁₅ hydrocarbons, nitrogen or air.

After an absorption period, as shown in FIG. 3b, the miscible, enhanced oil recovery composition and oil and / or gas are returned uphole 312 to the installation 310. The installation 310 is designed to separate and / or recycle the miscible, enhanced oil recovery composition, for example by boiling composition, thickening, filtration or chemical reaction, followed by re-injection of the composition into the well 312, and the absorption cycle shown in FIGS. 3a and 3b is repeated from about 2 to about 5 times.

In some embodiments, a miscible, enhanced oil recovery composition may be injected into the formation 306 at a pressure below the hydraulic fracture pressure of, for example, from about 40 to about 90% of the hydraulic fracture pressure.

In some embodiments, the injection well 312 shown in FIG. 3a may serve as a representative well from a group of 202 wells, and the well 312 shown in FIG. 3b may serve as a representative well from a group of 204 wells .

In some embodiments, the injection well 312 shown in FIG. 3a may serve as a representative well from a group of 204 wells, and the well 312 shown in FIG. 3b may be a representative well from a group of 206 wells .

Fig. 3c:

Referring now to FIG. 3c, which illustrates some embodiments of the invention regarding system 400. System 400 includes an underground formation 402, an underground formation 404, an underground formation 406, and an underground formation 408. A production unit 410 is located on the surface. Well 412 crosses the formation 402 and 404 and has holes in the formation 406. The portions 414 may in some cases be fractured and / or perforated. After the removal of oil and gas from the formation 406, they enter sections 414 and are directed uphole 412 to the production unit 410. Gas and liquid can be separated, after which the gas can be directed to the gas storage 416, and the liquid can be sent to the liquid storage 418. A miscible, oil recovery enhancing composition that can be manufactured and stored in a production / storage unit 430 may be produced and / or stored at a production facility 410. Hydrogen sulfide and / or other sulfur-containing compounds from the formation 412 may be sent to the unit 430 for the production and storage of a miscible, enhanced oil recovery composition. The miscible, enhanced oil recovery composition is pumped downhole 432 to portions 434 of the formation 406. The mixed, enhanced oil recovery composition passes through the formation 406 to facilitate oil and / or gas production, after which the miscible, enhanced oil recovery composition with oil and / or gas can be brought to the well 412 and then to the production unit 410. After that, the mixing, enhanced oil recovery composition can be recycled, for which purpose the composition is subjected, for example, to boiling, condensed w, filtration or chemical reaction with subsequent reinjection of the composition into the well 432.

To hold a miscible, enhanced oil recovery composition between barrier well 450 and barrier well 460, barrier well 450 has an injection mechanism 452 and barrier well 460 has an injection mechanism 462. Injection mechanisms 452 and 462 can be used to inject a barrier agent, such as refrigerant, to create a frozen wall cement, liquid sulfur or any liquid or gas such as water, peroxide, peroxide solution, carbon dioxide, natural gas, other C ₁ -C ₁₅ hydrocarbons, nitrogen or air , or mixtures thereof.

In some embodiments, a quantity of a miscible, enhanced oil recovery composition, or a miscible enhanced oil recovery composition mixed with other components may be pumped into well 432, and thereafter, some other component may be pumped to push the miscible enhanced oil recovery composition or miscible increasing oil recovery of the composition mixed with other components through the formation 406, for example, air, water in a gaseous or liquid form, carbon dioxide, other gases, other liquids and / or mixtures thereof.

In some embodiments, a well 412 for producing oil and / or gas may serve as a representative well from a group of 202 wells, and a well 432 for injecting a miscible, enhanced oil recovery composition may serve as a representative well from a group of 204 wells.

In some embodiments, a well 412 for producing oil and / or gas may serve as a representative well from a group of 204 wells, and a well 432 for injecting a miscible, enhanced oil recovery composition may serve as a representative well from a group of 202 wells.

Figure 4:

Turning now to FIG. 4, which illustrates some embodiments of the invention regarding an array of 500 wells. An array of 500 wells includes a group of 502 wells (indicated by horizontal lines) and a group of 504 wells (indicated by diagonal lines).

Array 500 delimits a production area enclosed in a rectangle. Array 200 limits the interior of the system. Outside the array 200, internal barrier wells 550 and external barrier wells 552 are located. Other barrier well lines (not shown) may be created.

In some embodiments, the barrier agent may be pumped into the internal barrier wells 550 and into the external barrier wells 552. In other embodiments, the barrier agent may be pumped into the external barrier wells 552, and the barrier agent, oil, and / or gas may be discharged from the internal barrier wells 550. , and / or an agent for secondary oil recovery.

Each well from group 502 wells is spaced horizontally from an adjacent well from group 502 wells at a distance of 530. Each well from group 502 wells is spaced vertically from an adjacent well from group 502 wells at a distance of 532.

Each well from group 504 wells is spaced horizontally from an adjacent well from group 504 wells at a distance of 536. Each well from group 504 wells is spaced vertically from an adjacent well from group 504 wells at a distance of 538.

Each well in group 502 wells is separated from its neighboring wells from group 504 wells at a distance of 534. Each well in group 504 wells is separated from neighboring wells from group 502 wells at a distance of 534.

In some embodiments, each well in group 502 wells is surrounded by four wells from group 504 wells. In some embodiments, each well in a group of 504 wells is surrounded by four wells in a group of 502 wells.

Alternatives:

In some embodiments, oil and / or gas produced from the well 212 and / or 312 may be transported to some refinery and / or some processing facility. Oil and / or gas can be processed to produce industrial products, such as transport fuels (gasoline and diesel), heating systems, lubricants, chemicals and / or polymers. Processing may include distillation and / or fractional distillation of oil and / or gas in order to obtain one or more distillate fractions. In some embodiments, the oil and / or gas and / or one or more distillate fractions can be subjected to one or more of the following processes: catalytic cracking, hydrocracking, hydrotreating, coking, thermal cracking, distillation, reforming, polymerization, isomerization, alkylation, mixing various fractions and dewaxing.

Illustrative Embodiments

In one embodiment, a system is disclosed for producing oil and / or gas from an underground formation, including: a first well in the formation; a mechanism for pumping a miscible, enhanced oil recovery composition into the first well; a second well in the formation; a mechanism for producing oil and / or gas from a second well; where the first well and the second well comprise the interior of the system; many barrier wells outside the first well and the second well; and a mechanism for pumping the barrier agent into the barrier wells. In some embodiments, the first well is located at a distance of 10 m to 1 km from the second well. In some embodiments, the formation is located near a large mass of water. In some embodiments, the system also includes a mechanism for injecting an immiscible, enhanced oil recovery composition into the formation after releasing a mixed, enhanced oil recovery composition into the formation. In some embodiments, the system also includes a miscible, enhanced oil recovery composition selected from the group consisting of a carbon disulfide composition, hydrogen sulfide, carbon dioxide, octane, pentane, liquefied natural gas, aliphatic C ₂ -C ₆ hydrocarbons, nitrogen, diesel, white -spirits, naphtha solvent, asphalt solvent, kerosene, acetone, xylene, trichloroethane and mixtures thereof. In some embodiments, the system also includes an immiscible, enhanced oil recovery composition selected from the group consisting of water in a gaseous or liquid form, air, and mixtures thereof. In some embodiments, the system also includes a first array of wells, comprising from 5 to 500 wells, and a second array of wells, comprising from 5 to 500 wells. In some embodiments, the system also includes a miscible, enhanced oil recovery composition comprising a carbon disulfide composition. In some embodiments, the system also includes a mechanism for withdrawing a carbon disulfide composition from the formation. In some embodiments, the subterranean formation comprises oil having a viscosity of 100 to 5,000,000 cps. In some embodiments, the first well has a miscible oil recovery enhancement composition in the formation, and the second well has an oil production enhancement in the formation, and there is overlap in the system between the miscible oil enhancement composition and the oil recovery. In some embodiments, the barrier agent is selected from the group consisting of refrigerant, water, brine, peroxide, solutions of peroxide, nitrogen, air, carbon dioxide, natural gas, other C ₁ -C ₁₅ hydrocarbons, and mixtures thereof. In some embodiments, the implementation of the barrier agent contains water. In some embodiments, a barrier agent is withdrawn from a second well. In some embodiments, a barrier agent, a miscible, enhanced oil recovery composition and oil and / or gas are discharged from a second well.

In one embodiment of the invention, a method for producing oil and / or gas is described, comprising pumping a carbon disulfide composition through a first well; production of oil and / or gas from the formation through a second well; and pumping the barrier agent into the formation through multiple barrier wells. In some embodiments, the method also includes recovering the carbon disulfide composition from oil and / or gas (if present), and then injecting at least a portion of the recovered carbon disulfide composition into the formation. In some embodiments, injecting a carbon disulfide composition includes injecting at least a portion of the carbon disulfide composition into the formation in admixture with one or more hydrocarbons; sulfur compounds other than carbon disulfide; carbon dioxide; carbon monoxide; or mixtures thereof. In some embodiments, the method also includes heating the carbon disulfide composition before pumping the carbon disulfide composition into the formation or while it is inside the formation. In some embodiments, the carbon disulfide composition is injected at a pressure of 0 to 37,000 kPa above the initial pressure in the reservoir, measured prior to the start of carbon disulfide injection. In some embodiments, the subterranean formation has a permeability of from 0.0001 to 15 Darcy, for example a permeability of from 0.001 to 1 Darcy. In some embodiments, the oil contained in the subterranean formation prior to injection of the carbon disulfide composition contains sulfur in an amount of from 0.5 to 5%, for example from 1 to 3%. In some embodiments, the method also includes converting at least a portion of the produced oil and / or gas into a material selected from the group consisting of transport fuels, such as gasoline and diesel fuel, heating oil, chemicals, lubricants, chemicals and / or polymers.

In one embodiment, a method for producing oil and / or gas is disclosed, which comprises injecting into the formation a miscible, enhanced oil recovery composition through a first well; production of oil and / or gas from the formation through a second well; and pumping the barrier agent into the formation through multiple barrier wells. In some embodiments, the method also includes injecting a non-miscible, enhanced oil recovery composition into the formation after injecting a miscible, enhanced oil recovery composition to push the mixed, enhanced oil recovery composition through the formation. In some embodiments, a miscible, enhanced oil recovery composition comprises a carbon disulfide composition.

For specialists, it is obvious that numerous modifications and variations are possible within the scope of the disclosed embodiments of the invention, configurations, materials and methods without departing from their essence and scope. Accordingly, the scope of the appended claims and their functional equivalents should not be limited to the specific embodiments described and illustrated in the application, which by their nature are nothing more than examples.

Claims (26)

1. A system for producing oil and / or gas from an underground reservoir, comprising:
the first well in the formation;
a mechanism for pumping into the first well a miscible composition that improves oil recovery;
a second well in the formation;
a mechanism for producing oil and / or gas from a second well;
wherein the first well and the second well are an internal part of the system;
a plurality of barrier wells outside the first well and the second well; and
a mechanism for pumping a barrier agent into barrier wells to displace a miscible oil recovery enhancing composition and / or oil or gas in the formation to a second well for production from said second well. 2. The system according to claim 1, in which the first well is located at a distance of 10 m to 1 km from the second well. 3. The system according to claim 1 or 2, in which the underground reservoir is located below the mass of water. 4. The system according to claim 1, additionally containing a mechanism for injecting into the formation an immiscible enhanced oil recovery composition after releasing into the formation a mixed enhanced oil recovery composition. 5. The system according to claim 1, further comprising a miscible oil recovery enhancing composition selected from the group consisting of a carbon disulfide composition, hydrogen sulfide, carbon dioxide, octane, pentane, liquefied natural gas, aliphatic C ₂ -C ₆ hydrocarbons, nitrogen, diesel fuel , white spirits, naphtha solvent, asphalt solvent, kerosene, acetone, xylene, trichloroethane and mixtures thereof. 6. The system of claim 1, further comprising an immiscible enhanced oil recovery composition selected from the group consisting of water in a gaseous or liquid form, air, and mixtures thereof. 7. The system according to claim 1, additionally containing a first array of wells, comprising from 5 to 500 wells, and a second array of wells, comprising from 5 to 500 wells. 8. The system of claim 1, further comprising a miscible enhanced oil recovery composition comprising a carbon disulfide composition. 9. The system of claim 1, further comprising a mechanism for producing a carbon disulfide composition. 10. The system according to claim 1, in which the subterranean formation contains oil having a viscosity of from 100 to 5,000,000 cP. 11. The system according to claim 1, in which the first well has a profile of a miscible enhanced oil recovery composition in the formation, and the second well has a profile of oil production in the formation, while the profile of the mixed enhanced oil recovery composition and the oil production profile overlap. 12. The system according to claim 1, in which the barrier agent is selected from the group consisting of refrigerant, water, brine, peroxide, solutions of peroxide, nitrogen, air, carbon dioxide, natural gas, other C ₁ -C ₁₅ hydrocarbons and mixtures thereof . 13. The system of claim 12, wherein the barrier agent comprises water. 14. The system of claim 1, wherein the second well is provided with the ability to produce a barrier agent. 15. The system according to claim 1, in which from the second well, it is possible to produce a barrier agent that mixes up oil recovery of the composition and oil and / or gas. 16. A method of producing oil and / or gas, including:
injection into the formation of a carbon disulfide composition through the first well;
production of oil and / or gas from the formation through a second well; and
pumping the barrier agent into the formation through multiple barrier wells to displace the carbon disulfide composition and / or oil or gas through the formation to produce from said second well. 17. The method according to clause 16, further comprising extracting the carbon disulfide composition from oil and / or gas, if any, and then injecting into the reservoir at least part of the recovered carbon disulfide composition. 18. The method according to clause 16 or 17, in which the injection of the carbon disulfide composition includes pumping into the reservoir at least part of the carbon disulfide composition in a mixture with hydrocarbons; and / or sulfur compounds other than carbon disulfide; and / or carbon dioxide; and / or carbon monoxide; and / or mixtures thereof. 19. The method according to clause 16, further comprising heating the carbon disulfide composition before pumping the carbon disulfide composition into the formation or while it is inside the formation. 20. The method according to clause 16, in which the carbon disulfide composition is pumped under a pressure exceeding the initial pressure in the reservoir, measured before the start of the carbon disulfide injection, by a value from 0 to 37000 kPa. 21. The method according to clause 16, in which the underground reservoir has a permeability of from 0.0001 to 15 D, for example from 0.001 to 1 D. 22. The method according to clause 16, in which the oil contained in the subterranean formation before the injection of the carbon disulfide composition, contains sulfur in an amount of from 0.5 to 5%, for example from 1 to 3%. 23. The method according to clause 16, further comprising converting at least part of the extracted oil and / or gas into a material selected from the group consisting of transport fuel, such as gasoline and diesel fuel, heating system fuels, lubricants, chemicals and / or polymers. 24. A method of producing oil and / or gas, including:
injection into the reservoir of a miscible, enhanced oil recovery composition, through the first well;
production of oil and / or gas from the formation through a second well; and
pumping the barrier agent into the formation through a plurality of barrier wells to displace the miscible oil recovery enhancing composition and / or oil or gas through the formation to produce from said second well. 25. The production method according to paragraph 24, further comprising:
injecting an immiscible enhanced oil recovery composition into the formation after injecting a miscible enhanced oil recovery composition to force the miscible enhanced oil recovery composition through the formation. 26. The method according to paragraph 24 or 25, in which the miscible enhanced oil recovery composition contains a carbon disulfide composition.

Images