CN112147300A - Device and method for simulating diagenesis reaction of hydrocarbon-containing fluid and reservoir rock formation - Google Patents
Device and method for simulating diagenesis reaction of hydrocarbon-containing fluid and reservoir rock formation Download PDFInfo
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Abstract
Apparatus and methods for simulating a petrographic reaction of a hydrocarbon-containing fluid with a reservoir rock formation are disclosed. The device includes: the hydrocarbon source layer fluid generation and discharge unit is used for applying a first preset temperature and pressure to a hydrocarbon source rock sample to enable the hydrocarbon source rock sample to become hydrocarbon and evolve to discharge oil-gas-containing fluid; the fluid-reservoir interaction unit is used for applying a second preset pressure to the discharged hydrocarbon-containing fluid, injecting the hydrocarbon-containing fluid into a reservoir rock core at a third preset temperature and a confining pressure, and applying a third preset pressure to the hydrocarbon-containing fluid discharged from the reservoir rock core; and the product collecting unit is used for gas-liquid separation of the oil-gas-containing fluid discharged from the reservoir core, and collecting and metering the gas-liquid products obtained after separation. The scheme avoids the use of a single-component artificially prepared hydrocarbon-containing fluid for diagenesis reaction, realizes the generation and preparation of the full-component hydrocarbon-containing fluid, matches boundary reaction conditions corresponding to the diagenesis of rocks in geological history, and accurately simulates diagenesis reaction which is extremely consistent with actual conditions.
Description
Technical Field
The application relates to the field of petroleum geology and oil-gas exploration, in particular to a device for simulating diagenesis reaction of hydrocarbon-containing fluid and reservoir rock stratum and a method for simulating diagenesis reaction by adopting the device.
Background
The formation of scale-up dense oil and gas resources generally has the following geological features: the method has the advantages of stable and gradual construction background, large-area distribution of high-quality hydrocarbon source rocks and compact reservoir rocks, close contact between the hydrocarbon source rocks and the reservoir rocks, and short-distance migration and aggregation. The reservoir rock stratum (reservoir for short) with oil-gas reservoir capacity and the organic hydrocarbon source rock stratum (hydrocarbon source layer for short) with oil-gas generation capacity undergo similar diagenetic evolution processes, and become a complete diagenetic hydrocarbon system due to the hydrocarbon-containing fluid, wherein the hydrocarbon-containing fluid discharged by the diagenetic hydrocarbon evolution of the hydrocarbon source rock has important influence on the diagenetic action process and the oil-gas diagenetic hydrocarbon process of the reservoir rock stratum.
Diagenesis is referred to asUnder the influence of constant pressure and temperature, various physical, chemical and biochemical actions occur in the process of converting loose sediments into sedimentary rocks. Through the research on diagenesis, the transformation degree of the diagenesis on the oil-gas-containing reservoir rock stratum can be known, so that the reservoir stratum can be evaluated and predicted more reasonably. At present, the simulation experiment of fluid-rock interaction in a laboratory is one of important means for understanding and understanding the underground diagenesis process. Fluid-rock interaction refers to the chemical reaction of a deposit during lengthy geologic time where the fluid and mineral rock undergo exchange of biomass components. During the process of burying, heating and compacting the sediment, fluid in the sediment is discharged, and along with the migration of the fluid, the fluid reacts with rock minerals in other rock formations, so that the lithogenesis action such as erosion, cementation, regeneration and the like is generated. Since the hydrocarbon source layer discharges oil-containing gas with unique material composition (oil containing acid substances, high-abundance CO)2Etc.) and thus the fluids it discharges undergo a complex series of physicochemical reactions with the rock minerals in the reservoir, resulting in a completely different process for diagenesis of hydrocarbon-bearing reservoir rock formations than other rock formations.
Chinese patent of invention CN201110396426.X discloses a diagenesis simulation experiment device and method. FIG. 1 shows the diagenesis simulation experiment device, which comprises a rock core clamping mechanism, a heating mechanism, a gas porosity and permeability measuring process, a liquid injection and liquid permeability testing process, an outlet fluid automatic continuous metering and sampling mechanism, an overlying pressure pressurization control mechanism, a fluid physical property detection mechanism and a data acquisition, calculation and automatic control mechanism; the inlet and the outlet of the core clamping mechanism are respectively connected with a gas porosity and permeability measuring process, a liquid injection process and a liquid permeability testing process; the periphery of the core clamping mechanism is sleeved with a heating mechanism, an overlying pressure injection port of the core clamping mechanism is connected with an overlying pressure pressurization control mechanism, an outlet of a liquid injection and liquid permeability test process is connected with an outlet fluid automatic continuous metering and sampling mechanism, and a fluid physical property detection mechanism detects a fluid sample of the outlet fluid automatic continuous metering and sampling mechanism; the data acquisition and calculation and automatic control mechanism acquires, records, stores and calculates the temperature, pressure and flow rate in the experiment, and controls the corresponding electromagnetic valve action and the action of the outlet fluid automatic continuous metering and sampling mechanism according to the experiment condition.
Chinese invention patent CN201120344178.X is a diagenesis simulation experiment device. FIG. 2 shows the diagenesis simulation experiment device, which comprises a control device, a reaction solution supply device, a multi-stage continuous flow reaction device, a solution composition in-situ analysis device and a core permeability evolution on-line detection device; the control device is respectively connected with the reaction solution supply device, the multi-stage continuous flow reaction device and the core permeability evolution online detection device; the reaction solution supply device is respectively connected with the multi-stage continuous flow reaction device and the core permeability evolution online detection device; the multi-stage continuous flow reaction device is connected with the solution component in-situ analysis device; the core permeability evolution online detection device is respectively connected with the multi-stage continuous flow reaction device and the reaction solution supply device. The utility model provides a diagenesis simulation experiment device can accomplish temperature and pressure condition and keep the fluid continuous flow condition under more than two stages water rock reaction processes of condition different, realizes continuous multistage water rock reaction experiment simulation.
The Chinese invention patent CN201711351145.6 discloses an open system chemical kinetics high-temperature high-pressure experimental device. Fig. 3 shows the open system chemical kinetics high temperature high pressure experimental apparatus disclosed therein. The system comprises a cold-seal tubular autoclave, a temperature control furnace, a pressurization system, an online feeding device, an online sampling device, a multi-parameter detector and a computer, wherein the cold-seal tubular autoclave is embedded in the temperature control furnace and comprises a tubular autoclave body with a sealed lower end and a kettle cover in threaded connection with the tubular autoclave body, an output port of the pressurization system is communicated with the cold-seal tubular autoclave, the online feeding device and the online sampling device are communicated with the top and the bottom of the cold-seal tubular autoclave, a probe of the multi-parameter detector extends into a sampling bottle of the online sampling device for online detection, the computer is in signal connection with the multi-parameter detector, and a thermocouple and the temperature control furnace of the cold-seal tubular autoclave are connected with a temperature. The autoclave is connected with the online feeding and discharging device and the multi-parameter detector, samples in the autoclave are in an open flowing state in the experimental process, and the dynamic process of element migration, hydrolysis and water-rock interaction can be detected.
The existing diagenesis simulation experiment technology realizes the simulation of the influence of various diagenesis fluids on the diagenesis action (such as acid diagenesis action, alkaline diagenesis action, corrosion action and the like) of the rock when the rock is in dynamic and static contact with the rock under the condition of high temperature and high pressure, and can dynamically monitor the porosity and permeability of the rock and the change condition of the fluid property in real time in the diagenesis simulation process. However, the existing simulation experiment device can only provide single-stage diagenesis reaction simulation at first, and is difficult to well simulate diagenesis such as corrosion, cementation, substitution and the like caused by temperature, pressure and fluid property changes in actual stratum due to geological actions such as tectonic evolution, sedimentation and burial; secondly, the performed experiment still stays in the physicochemical reaction between the fluid and the surface of the rock mineral, and the corrosion experiment of the migration and reaction of the fluid in the internal pore space of the rock cannot be realized; furthermore, it is mostly a fluid (containing CO) with certain components2Or HS2Aqueous solution) to chemically interact with the rock. In fact, hydrocarbon source fluids (a type of formation water, oil, gas and raw oil gas) generated during the hydrocarbon evolution phase due to the hydrocarbon source layer being flushed out of the hydrocarbon-bearing reservoir rock formation2Mixtures of other products, organic acids, etc.), the diagenesis becomes extremely complex.
Disclosure of Invention
In view of the above, the present application provides a simulation experiment apparatus for synchronously generating hydrocarbon source fluid and performing reservoir diagenesis, and a method for simulating diagenesis reaction by using the apparatus.
According to an aspect of the present application, there is provided an apparatus for simulating the diagenetic reaction of a hydrocarbon-containing fluid with a reservoir rock formation, the apparatus comprising: the hydrocarbon source layer fluid generation and discharge unit is used for applying a first preset temperature and a first preset pressure to the hydrocarbon source rock sample (102) so that the hydrocarbon source rock sample (102) evolves into hydrocarbon and discharges hydrocarbon-containing fluid; the fluid-reservoir interaction unit is connected with the hydrocarbon source layer fluid generation and discharge unit and is used for applying a second preset pressure to hydrocarbon-bearing fluid discharged by hydrocarbon source rock samples (102) in hydrocarbon evolution, injecting the hydrocarbon-bearing fluid into a reservoir rock core (202) at a third preset temperature and a preset confining pressure and applying a third preset pressure to the hydrocarbon-bearing fluid discharged from the reservoir rock core (202); and the product collecting unit is connected with the fluid-reservoir interaction unit and is used for carrying out gas-liquid separation on the oil-gas-containing fluid discharged from the reservoir core (202) and respectively collecting and metering the gas product and the liquid product obtained after separation.
In a possible embodiment, the apparatus further comprises a reservoir void determination unit connected to the fluid-reservoir interaction unit for measuring a pore volume of the pre-lithogenesis reservoir core (202) and a pore volume of the post-lithogenesis reservoir core (202).
In one possible embodiment, the hydrocarbon source layer fluid generation and discharge unit comprises a high pressure autoclave (101), a lithostatic pressure applicator (103), a seal pressure applicator (104), a two-way hydraulic machine (105), a hydrocarbon production furnace (106), a fluid discharge automatic valve (107), a discharge fluid pressurization intermediate vessel (108), a discharge fluid pressurization pump (109), a hydrocarbon production fluid pressure sensor (110), wherein: the high-pressure reaction kettle (101) is of a cylindrical structure with two open ends, and a hydrocarbon source rock sample (102) is filled in the high-pressure reaction kettle; inserting a static rock pressure applicator (103) from the upper end of the high-pressure reaction kettle (101) to mechanically compact the hydrocarbon source rock sample (102) so as to apply a first preset pressure to the hydrocarbon source rock sample (102); the lower end of the high-pressure reaction kettle (101) is sealed by applying pressure through a sealing pressure applicator (104); the bidirectional hydraulic machine (105) system controls the static rock pressure applicator (103) and the sealing pressure applicator (104) and provides compaction and sealing power for the static rock pressure applicator (103) and the sealing pressure applicator (104); the whole high-pressure reaction kettle (101) is arranged in a hydrocarbon generation heating furnace (106) to apply a first preset temperature to a hydrocarbon source rock sample; one end of the fluid discharge automatic valve (107) is connected with the high-pressure reaction kettle (101) through a hydrocarbon fluid pressure sensor (110) and a stainless steel pipeline, and the other end is connected with the upper end of the discharge fluid pressurization intermediate container (108) and is used for controlling the flow of the oil-gas-containing fluid from the high-pressure reaction kettle (101) to the discharge fluid pressurization intermediate container (108); the discharge fluid booster pump (109) is connected with the lower end of the discharge fluid pressurizing intermediate container (108) through a pipeline, and is used for regulating and controlling the pressure of the oil-gas-containing fluid in the discharge fluid pressurizing intermediate container (108).
In one possible embodiment, the fluid-reservoir interaction unit comprises a core holder (201), a reservoir heater (203), a confining pressure high pressure pump (204), an input end pressure sensor (205), an output end pressure sensor (206), an output fluid intermediate container (207), an output fluid booster pump (208), a fluid input three-way valve (209) and a fluid output shutoff valve (210), wherein: one end of the core holder (201) is connected with the hydrocarbon source fluid generation and discharge unit through a fluid input three-way valve (209), an input end pressure sensor (205) and a high-pressure pipeline, and the other end is connected with an output end pressure sensor (206) and an output fluid intermediate container (207) through pipelines; the core clamp (201) is used for loading a reservoir core (202) and applying preset confining pressure to the reservoir core (202) in the core clamp (201) through a surrounding pressure high-pressure pump (204); the core holder (201) and the reservoir core (202) are placed in a reservoir heating furnace (203) and heated to a third preset temperature; the input end pressure sensor (205) and the discharge fluid booster pump (109) are used for controlling the oil-gas-containing fluid pressure at the input end of the core clamper (201) to be boosted to a second preset pressure; the output end pressure sensor (206) and the output fluid booster pump (208) are used for controlling the oil-gas-containing fluid pressure at the output end of the rock core holder (201) to boost the oil-gas-containing fluid pressure to a third preset pressure; the output fluid intermediate container (207) is used for receiving hydrocarbon-containing fluid flowing through the reservoir rock core (202); one end of the fluid output stop valve (210) is connected with the output fluid intermediate container (207), and the other end is connected with the product collection unit.
In one possible embodiment, the reservoir pore volume measuring unit comprises an evacuation valve (301), a gas input valve (302), a gas pressure sensor (303), a standard chamber a valve (304), a standard chamber a (305), a gas pressure regulating valve (306), a gas inlet valve (308), and a gas source cylinder (307), wherein: one end of the emptying valve (301) is connected with a fluid input three-way valve (209); one end of the gas input valve (302) is connected with the fluid input three-way valve (209), and the other end is connected with the gas source steel cylinder (307) through the gas pressure sensor (303), the gas pressure regulating valve (306) and the gas inlet valve (308); the standard chamber A (305) is connected to a line between the gas pressure sensor (303) and the gas pressure regulating valve (306) via a standard chamber A valve (304).
In one possible embodiment, the product collection unit comprises a liquid product collector (401), a cryogenic electron trap (402), a gas flowmeter (403), and a collection valve (404), wherein: the liquid product collector (401) is arranged in a low-temperature electronic cold trap (402), the oily gas passing through the fluid output stop valve (210) passes through the cooled liquid product collector (401), the liquid product is frozen in the liquid product collector (401), and the gas product is collected after passing through a collecting valve (404) after being metered by a gas flowmeter (403).
According to another aspect of the application, a method for simulating diagenesis reaction by using the device is further disclosed, and the method comprises the following steps: drilling an immature or low-maturity source rock sample buried in a stratum, and cutting the source rock sample into a cylinder matched with an inner cavity of a high-pressure reaction kettle (101); placing a cylindrical source rock sample (102) in a high-pressure reaction kettle (101), applying a first preset pressure on the source rock sample through a static rock pressure applicator (103), sealing the high-pressure reaction kettle (101) through a sealing pressure applicator (104), and controlling the power of the static rock pressure applicator (103) and the sealing pressure applicator (104) through a two-way hydraulic press (105); heating a source rock sample (102) to a first preset temperature through a hydrocarbon generation heating furnace (106), maintaining the preset heating time, and collecting oil-gas-containing fluid generated in a high-pressure reaction kettle (101) by the source rock sample (102) in the heating process to a discharge fluid pressurization intermediate container (108) through a fluid discharge automatic valve (107); the speed and the degree of the discharge of the hydrocarbon-containing fluid are controlled by an exhaust fluid booster pump (109) and a hydrocarbon fluid pressure sensor (110); placing a drilled reservoir rock core (202) into a rock core holder (201), applying preset surrounding pressure to the reservoir rock core (202) in the rock core holder (201) through a surrounding pressure high-pressure pump (204), pressurizing oil-gas-containing fluid in a discharge fluid pressurizing middle container (108) to a second preset pressure through a discharge fluid pressurizing pump (109) and an input end pressure sensor (205), injecting the oil-gas-containing fluid to the front end of the reservoir rock core (202) through a fluid input three-way valve (209), starting a reservoir heating furnace (203) to heat the reservoir rock core (202) to a third preset temperature, and enabling the oil-gas-containing fluid and the reservoir rock layer (202) to perform diagenesis reaction; the hydrocarbon-containing fluid after diagenesis reaction flows into an output fluid intermediate container (207) from the rear end of the core holder (201), and the pressure of the hydrocarbon-containing fluid after diagenesis reaction is boosted to a third preset pressure by an output end pressure sensor (206) and an output fluid booster pump (208); after the diagenesis reaction of the hydrocarbon-containing fluid and the reservoir rock core (202) is completed, the fluid in the rock core holder (201) is released to a product collecting unit through a fluid output stop valve (210), gas-liquid product separation is carried out, and gas products and liquid products are respectively measured and collected; before carrying out diagenesis reaction and after discharging all hydrocarbon-containing fluid, respectively starting a reservoir pore volume measuring unit to carry out pore volume measurement on a reservoir rock core (202) in a rock core holder (201) so as to obtain the pore volume change of the reservoir rock core (202) before and after diagenesis reaction.
In one possible embodiment, the method further comprises: reservoir cores (202) after diagenesis reactions are removed and micro-regional measurements are made to assess the effect of hydrocarbon-containing fluids on diagenesis reactions.
In one possible embodiment, the microscopic region assay is a scanning electron microscope or a thin slice assay.
According to the technical scheme, the generation and discharge of the hydrocarbon-containing fluid in the hydrocarbon source layer and a series of complex physicochemical reaction processes of migration and flushing in the pore space inside the reservoir rock layer under certain formation temperature and pressure conditions are simulated, the simulation experiment of carrying out the diagenesis reaction on the reservoir rock layer by using the artificially prepared hydrocarbon-containing fluid with single component is avoided, the generation and preparation of the full-component hydrocarbon-containing fluid are realized, and the migration and diagenesis reaction of the hydrocarbon-containing fluid in the pore space inside the reservoir rock is realized. In the technical scheme provided by the application, boundary reaction conditions (temperature, formation pressure, static rock compaction pressure, full-component hydrocarbon-containing fluid composition and the like) corresponding to the rock diagenesis in geological history are matched, so that diagenesis processes such as corrosion, cementation, alternation and the like of a reservoir rock stratum caused by changes of temperature, pressure and fluid properties in an actual stratum can be better simulated in geological action processes such as structural evolution, sedimentation and burial, changes of fluid components and rock physical properties can be monitored in real time, and the influence degree of hydrocarbon-containing fluid on the diagenesis of the reservoir rock stratum can be more objectively known.
Drawings
The foregoing and other objects, features and advantages of the application will be apparent from the following more particular descriptions of exemplary embodiments of the application, as illustrated in the accompanying drawings wherein like reference numbers generally represent like parts throughout the exemplary embodiments of the application.
Fig. 1 shows a diagenesis simulation experiment device in the prior art.
Fig. 2 shows another diagenesis simulation experiment device in the prior art.
FIG. 3 shows an open system chemical kinetics high temperature high pressure experimental apparatus in the prior art.
FIG. 4 shows a schematic diagram of an apparatus for simulating a petrographic reaction of a hydrocarbon-containing fluid with a reservoir rock formation according to an exemplary embodiment of the present application.
Description of the reference numerals
101-high pressure reactor; 102-a source rock sample; 103-a lithostatic pressure applicator; 104-a sealing pressure applicator; 105-two-way hydraulic press; 106-a hydrocarbon-generating furnace; 107-fluid discharge automatic valve; 108-discharge fluid pressurizing intermediate vessel; 109-exhaust fluid booster pump; 110-hydrocarbon fluid production fluid pressure sensor; 201-core holder; 202-reservoir core; 203-reservoir heating furnace; 204-surrounding high pressure pump; 205-input pressure sensor; 206-output pressure sensor; 207-output fluid intermediate container; 208-an output fluid booster pump; 209-fluid input three-way valve; 210-fluid output shut-off valve; 301-evacuation valve; 302-gas input valve; 303-gas pressure sensor; 304-standard chamber a valve; 305 — standard chamber a; 306-a gas pressure regulating valve; 307-gas source cylinder; 308-an intake valve; 401-liquid product collector; 402-low temperature electron cold trap; 403-a gas flow meter; 404-collecting valve
Detailed Description
Preferred embodiments of the present application will be described in more detail below with reference to the accompanying drawings. While the preferred embodiments of the present application are shown in the drawings, it should be understood that the present application may be embodied in various forms and should not be limited to the embodiments set forth herein. Rather, these embodiments are provided so that this disclosure will be thorough and complete, and will fully convey the scope of the disclosure to those skilled in the art.
The present application provides an apparatus for simulating the diagenetic reaction of a hydrocarbon-containing fluid with a reservoir rock formation, the apparatus comprising: the hydrocarbon source layer fluid generation and discharge unit is used for applying a first preset temperature and a first preset pressure to the hydrocarbon source rock sample (102) so that the hydrocarbon source rock sample (102) evolves into hydrocarbon and discharges hydrocarbon-containing fluid; the fluid-reservoir interaction unit is connected with the hydrocarbon source layer fluid generation and discharge unit and is used for applying a second preset pressure to hydrocarbon-bearing fluid discharged by hydrocarbon source rock samples (102) in hydrocarbon evolution, injecting the hydrocarbon-bearing fluid into a reservoir rock core (202) at a third preset temperature and a preset confining pressure and applying a third preset pressure to the hydrocarbon-bearing fluid discharged from the reservoir rock core (202); and the product collecting unit is connected with the fluid-reservoir interaction unit and is used for carrying out gas-liquid separation on the oil-gas-containing fluid discharged from the reservoir core (202) and respectively collecting and metering the gas product and the liquid product obtained after separation.
In a possible embodiment, the apparatus further comprises a reservoir void determination unit connected to the fluid-reservoir interaction unit for measuring a pore volume of the pre-lithogenesis reservoir core (202) and a pore volume of the post-lithogenesis reservoir core (202).
FIG. 4 shows a schematic diagram of an apparatus for simulating a petrographic reaction of a hydrocarbon-containing fluid with a reservoir rock formation according to an exemplary embodiment of the present application.
As shown, the hydrocarbon source layer fluid generation and removal unit may include: a high-pressure reactor 101, a lithostatic pressure applicator 103, a seal pressure applicator 104, a two-way hydraulic press 105, a hydrocarbon-producing heating furnace 106, a fluid discharge automatic valve 107, a discharge fluid pressurization intermediate vessel 108, a discharge fluid booster pump 109, and a hydrocarbon-producing fluid pressure sensor 110.
The high-pressure reaction kettle 101 is a cylindrical structure with two open ends, and a hydrocarbon source rock sample 102 is filled in the high-pressure reaction kettle. The high pressure reactor 101 is preferably a high temperature resistant high strength alloy steel.
A lithostatic pressure applicator 103 is inserted from the upper end of the autoclave 101 to mechanically compact the source rock sample 102 so as to apply a first preset pressure to the source rock sample 102, thereby simulating the pressure of the overburden, also called lithostatic compaction pressure, to which the source rock is buried at a certain depth. The lower end of the autoclave 101 is sealed by applying pressure through a sealing pressure applicator 104. The bi-directional hydraulic press 105 system controls the statics pressure applicator 103 and the sealing pressure applicator 104 and provides the power for compaction and sealing for the statics pressure applicator 103 and the sealing pressure applicator 104.
The static rock pressure applicator 103 and the seal pressure applicator 104 are respectively disposed at both ends of the high-pressure reaction tank 101. The static rock pressure applicator 103 and the seal pressure applicator 104 are both parallel to the axis of the autoclave 101. The fluid outlets of the two-way hydraulic machine 105 are connected by lines to the fluid inlets and outlets of the hydrostatic pressure applicator 103 and the seal pressure applicator 104, respectively.
The whole high-pressure reaction kettle 101 is placed in a hydrocarbon generation heating furnace 106 to apply a first preset temperature to a hydrocarbon source rock sample so as to simulate the actual formation temperature and promote the formation to generate high-temperature high-pressure fluid such as oil, gas and water. The hydrocarbon-generating heating furnace 106 is preferably an internal circulation wind power heating furnace.
One end of the fluid discharge automatic valve 107 is connected to the high-pressure reactor 101 through a hydrocarbon fluid pressure sensor 110 and a stainless steel pipeline, and the other end is connected to the upper end of the discharge fluid pressurizing intermediate container 108, and is used for controlling the flow of the oil-containing fluid from the high-pressure reactor 101 to the discharge fluid pressurizing intermediate container 108.
The discharge fluid booster pump 109 is connected to the lower end of the discharge fluid pressurizing intermediate container 108 through a pipeline to regulate the pressure of the hydrocarbon-containing fluid in the discharge fluid pressurizing intermediate container 108.
The discharge fluid pressurizing intermediate container 108 is connected to a pipe extending from the top end of the high-pressure reactor 101 through a fluid discharge automatic valve 107, and the pressure of the hydrocarbon-containing fluid therein is adjusted by a discharge fluid pressurizing pump 109 and a hydrocarbon-generating fluid pressure sensor 110, thereby applying a charging pressure to the hydrocarbon-containing fluid injected into the reservoir lithology 202 to simulate the actual situation. The discharge fluid pressurizing intermediate container 108 is configured in a cylindrical shape, and is preferably made of high-temperature-resistant high-strength alloy steel.
The flow of use of the hydrocarbon source layer fluid generation and removal unit is as follows: loading a source rock sample 102 into a high-pressure reaction kettle 101, starting a bidirectional hydraulic press 105, applying a first preset pressure static rock compaction pressure to the source rock sample 102 through a static rock pressure applicator 103 and a sealing pressure applicator 104, and sealing two ends of the high-pressure reaction kettle; starting a hydrocarbon generation heating furnace 106, and heating a hydrocarbon source rock sample 102 containing formation water to a set temperature; for a predetermined time, a quantity of hydrocarbon-bearing fluid product may be generated by heating source rock sample 102; after the hydrocarbon generation process is finished, the fluid discharge automatic valve 107 is opened, the hydrocarbon-containing fluid in the hydrocarbon generation high-pressure reaction kettle 101 is released to the upper cavity of the discharge fluid pressurization intermediate container 108 to be stored, and the pressure of the hydrocarbon-containing fluid is regulated by the discharge fluid pressurization pump 109 and is used for inputting to the fluid-reservoir interaction unit.
The fluid-reservoir interaction unit may include: a core clamper 201, a reservoir heating furnace 203, a confining pressure high pressure pump 204, an input end pressure sensor 205, an output end pressure sensor 206, an output fluid intermediate container 207, an output fluid booster pump 208, a fluid input three-way valve 209 and a fluid output stop valve 210.
The core holder 201 is connected at one end to the hydrocarbon source fluid generation and discharge unit via a fluid input three-way valve 209, an input pressure sensor 205 and a high pressure line, and at the other end to an output pressure sensor 206 and an output fluid intermediate container 207 via lines.
The core holder 201 is used for loading a reservoir core 202, and preset confining pressure is applied to the reservoir core 202 in the core holder 201 through a confining pressure high-pressure pump 204, so that hydrocarbon-containing fluid is prevented from flowing through only the surface of the reservoir core, but not through pores or fracture fluid inside the reservoir core.
The core holder 201 and the reservoir core 202 are placed in a reservoir heating furnace 203 and heated to a third preset temperature so as to simulate the diagenesis of the hydrocarbon-containing fluid on the reservoir core 202 by the underground temperature.
The input pressure sensor 205 and the exhaust fluid booster pump 109 are used to control the hydrocarbon-containing fluid pressure at the input of the core holder 201 to a second predetermined pressure.
The outlet pressure sensor 206 and the outlet fluid booster pump 208 are used to control the hydrocarbon-containing fluid pressure at the outlet of the core holder 201 to a third predetermined pressure.
The output fluid intermediate reservoir 207 is adapted to receive hydrocarbon-containing fluid that flows through the reservoir core 202.
The effluent fluid pressurizing intermediate vessel 108 and the effluent fluid pressurizing pump 109, the export fluid intermediate vessel 207 and the export fluid pressurizing pump 208, and the confining pressure high pressure pump 204 form a hydrocarbon-containing fluid flow system that ensures fluid flow in the reservoir core 202.
Fluid outlet shut-off valve 210 is connected at one end to outlet fluid intermediate vessel 207 and at the other end to a product collection unit.
The flow of use of the fluid-reservoir interaction unit is as follows: closing the automatic fluid discharge valve 107, placing the reservoir core 202 into the core holder 201, and starting the confining pressure high-pressure pump 204 to apply a preset confining pressure to the reservoir core 202; opening the reservoir heating furnace 203 to rise to a third preset temperature; starting the discharge fluid booster pump 109, opening the fluid input three-way valve 209 to communicate with the front end of the core holder 201, boosting the hydrocarbon-containing fluid in the upper cavity of the discharge fluid boosting intermediate container 108 to a second preset pressure to drive the hydrocarbon-containing fluid to the core holder 201, and observing the changes of the front end input pressure sensor 205 and the rear end output end pressure sensor 206 of the core holder 201; when the pressure value of the output end pressure sensor 206 changes, it indicates that the hydrocarbon-containing fluid has completely flowed through the reservoir core 202, and the flowed-out hydrocarbon-containing fluid pressurized to the third preset pressure is discharged to the upper cavity of the output fluid intermediate container 207 for storage.
The hydrocarbon-containing fluid, when flowing through the reservoir core 202, can undergo a series of complex physicochemical reactions with the rock minerals in the reservoir core, thereby affecting the diagenesis process of the reservoir core.
The reservoir pore volume determining unit may include: an evacuation valve 301, a gas input valve 302, a gas pressure sensor 303, a standard chamber a valve 304, a standard chamber a305, a gas pressure regulating valve 306, an air inlet valve 308, and a gas source cylinder 307.
The drain valve 301 is connected at one end to the three-way fluid inlet valve 209 and at the other end to a container.
One end of the gas input valve 302 is connected with the fluid input three-way valve 209, and the other end is connected with the gas source steel cylinder 307 through the gas pressure sensor 303, the gas pressure regulating valve 306 and the gas inlet valve 308.
The standard chamber a305 is connected to a line between the gas pressure sensor 303 and the gas pressure regulating valve 306 via a standard chamber a valve 304.
The usage flow of the reservoir pore volume determination unit is as follows: firstly, closing a connecting channel of a fluid input three-way valve 209 and a reservoir pore volume measuring unit, a fluid output stop valve 210, an emptying valve 301 and a gas input valve 302; slowly opening the air inlet valve 308 and the valve of the gas source steel cylinder 307, regulating and injecting nitrogen gas with certain pressure into the standard chamber A304 with known volume through the gas pressure regulating valve 307, and measuring the pressure P through the gas pressure sensor; the connection between the fluid input three-way valve 209 and the reservoir pore volume measuring unit is opened, the standard chamber A valve 304 is slowly opened, the nitrogen gas in the standard chamber A305 is input into the fluid-reservoir interaction unit, and the pressure sensor 303 records the pressure P after the pressure is balanced2(ii) a And then calculating the pore volume of the reservoir rock core before and after the diagenesis reaction according to the Boma law.
The product collection unit may include: liquid product collector 401, cryoelectron cold trap 402, gas flow meter 403, collection valve 404. A product collection unit may be connected by a line to the fluid output shutoff valve 210 of the fluid-reservoir interaction unit for collecting hydrocarbon-containing fluid that has undergone a diagenesis reaction with the reservoir rock formation.
The liquid product collector 401 is arranged in the low-temperature electronic cold trap 402, the oil-containing gas passing through the fluid output stop valve 210 passes through the cooled liquid product collector 401, the oil-water liquid products are frozen in the liquid product collector 401, and the hydrocarbon gas and CO2After the gas product is metered by the gas flow meter 403, it is collected by the collection valve 404.
The use scheme of the product collection unit is as follows: and (3) opening the fluid output stop valve 210, starting the output fluid booster pump 208, driving the oily gas-water fluid product in the cavity on the output fluid intermediate container 207 to the liquid product collector 401, separating the oily gas-water fluid product through the low-temperature electronic cold trap 402, retaining the liquid product in the collector 401, metering the gas product in the gas flow meter 403, discharging the gas product through the collecting valve 404 and then collecting the gas product.
An exemplary method of simulating diagenesis reactions using the apparatus is described below, using the example of an extended group length of 7 sections of the Ordos basin.
In order to research the influence of the discharged oil-gas-containing fluid generated by 7 sections of hydrocarbon source rocks with prolonged group length in the Ordos basin on the reservoir rock stratum, Ordos Zhang Jia beach low-maturity hydrocarbon source rock YC-1 with the organic carbon content of 14.3 percent and the vitrinite reflectivity R is selectedo0.56 percent, 1 rock core of the extended reservoir group is selected, the porosity is 8.02 percent, and the permeability is 0.90 md. Simulation of source rock at peak production R using the apparatus of the present applicationoThe interaction process of the resulting hydrocarbon-containing fluid with reservoir rock is around 1.0%.
Drilling a hydrocarbon source rock sample and cutting the hydrocarbon source rock sample into a cylinder matched with the inner cavity of the high-pressure reaction kettle; the source rock sample was placed in autoclave 101, the two-way hydraulic press was started, and a pressure of 78.8MPa, corresponding to the compaction pressure of the overburden to which the source rock was subjected when buried underground at a depth of about 3 km, was applied to the source rock sample by the static rock pressure applicator. Meanwhile, the high-pressure reaction kettle is pressurized by a sealing pressure applicator to seal, so that the oil-gas-containing fluid generated by the hydrocarbon source rock in the high-pressure reaction kettle is ensured to be leak-proof when the pressure is 34.7 MPa.
The automatic fluid discharge valve 107 and the three-way fluid input valve 209 are closed, the hydrocarbon generation heating furnace 106 is opened, and the hydrocarbon source rock sample containing the formation water is heated to 350 ℃ and is kept at the constant temperature for 72 hours. Under the condition of the temperature and the pressure, a large amount of hydrocarbon-containing fluid is generated by the hydrocarbon source rock, the fluid pressure in the high-pressure reaction kettle increases, when the pressure exceeds the set pressure of 34.7MPa, the fluid discharge automatic valve can be automatically opened, part of the hydrocarbon-containing fluid is discharged into the discharge fluid pressurization intermediate container 108, and the pressure in the discharge fluid pressurization intermediate container is controlled to be lower than the set hydrocarbon-generating pressure of 34.7MPa by the discharge fluid pressurization pump 109, so that the generated hydrocarbon-containing fluid is prevented from flowing back to the high-pressure kettle.
The cut reservoir rock core 202 is placed into a rock core holder, a confining pressure high-pressure pump 204 is started to apply confining pressure of 50MPa to the reservoir rock core 202, and a reservoir heating furnace 203 is started to be heated to a set temperature of 144 ℃ to heat the reservoir rock core. The fluid output shutoff valve 210 is closed and the vent fluid booster pump 109 is opened to drive the hydrocarbon-containing fluid in the vent fluid booster intermediate vessel upper cavity into the reservoir core in the core holder 305. Observing the changes of the front input pressure sensor 205 and the rear output end pressure sensor 206 of the core holder 201, when the pressure value of the output end pressure sensor 206 changes, indicating that the hydrocarbon-containing fluid completely flows through the reservoir core 202, and discharging the discharged hydrocarbon-containing fluid to the upper cavity of the output fluid intermediate container 207 for storage. The rate of fluid flow through the reservoir core and the diagenesis reaction time, which is typically not less than 168 hours, are controlled by the input and output end pressure sensors and the exhaust fluid booster pump and the output fluid booster pump.
After the reaction is finished, the fluid output stop valve 210 is opened, the oily gas-water fluid product in the upper cavity of the output fluid intermediate container 207 is driven to the liquid product collector 401 through the pressurization of the output fluid booster pump, the liquid product is retained in the collector 401 after being separated by the low-temperature electronic cold trap 402, and the gas product is metered in the gas flow meter 403 and is discharged through the collecting valve 404 to be collected. .
Measuring the pore volume of the reservoir rock core, slowly opening a gas inlet valve 308 and a valve of a gas source steel cylinder 307, regulating and injecting nitrogen gas with certain pressure into a standard chamber A304 with known volume through a gas pressure regulating valve 308, and measuring the pressure through a gas pressure sensor. Opening the fluid input three-way valve 209 to connect with the reservoir pore volume measuring unit, slowly opening the standard chamber A valve 304, inputting the nitrogen in the standard chamber A305 into the fluid-reservoir interaction unit, after pressure balancing, recording the pressure P by the pressure sensor 3031And then calculating the porosity of the reservoir rock core before and after diagenesis reaction to be 7.56% and 10.13% respectively according to the Boma's law. It can be seen that the hydrocarbon-containing fluid has a greater improvement in the pore volume of the reservoir rock at this temperature and pressure.
And finally, taking out the reacted reservoir rock core 202, and carrying out microscopic region determination such as scanning electron microscopy, sheet identification and the like to observe the influence of the hydrocarbon-containing fluid on the diagenesis of the reservoir rock stratum.
According to the technical scheme, the generation and discharge of the hydrocarbon-containing fluid in the hydrocarbon source layer and a series of complex physicochemical reaction processes of migration and flushing in the pore space inside the reservoir rock layer under certain formation temperature and pressure conditions are simulated, the simulation experiment of carrying out the diagenesis reaction on the reservoir rock layer by using the artificially prepared hydrocarbon-containing fluid with single component is avoided, the generation and preparation of the full-component hydrocarbon-containing fluid are realized, and the migration and diagenesis reaction of the hydrocarbon-containing fluid in the pore space inside the reservoir rock is realized. In the technical scheme provided by the application, boundary reaction conditions (temperature, formation pressure, static rock compaction pressure, full-component hydrocarbon-containing fluid composition and the like) corresponding to the rock diagenesis in geological history are matched, so that diagenesis processes such as corrosion, cementation, alternation and the like of a reservoir rock stratum caused by changes of temperature, pressure and fluid properties in an actual stratum can be better simulated in geological action processes such as structural evolution, sedimentation and burial, changes of fluid components and rock physical properties can be monitored in real time, and the influence degree of hydrocarbon-containing fluid on the diagenesis of the reservoir rock stratum can be more objectively known.
Having described embodiments of the present application, the foregoing description is intended to be exemplary, not exhaustive, and not limited to the disclosed embodiments. Many modifications and variations will be apparent to those of ordinary skill in the art without departing from the scope and spirit of the described embodiments. The terms used herein were chosen in order to best explain the principles of the embodiments, the practical application, or technical improvements to the techniques in the marketplace, or to enable others of ordinary skill in the art to understand the embodiments disclosed herein.
Claims (9)
1. An apparatus for simulating a petrophysical reaction of a hydrocarbon-containing fluid with a reservoir rock formation, the apparatus comprising:
the hydrocarbon source layer fluid generation and discharge unit is used for applying a first preset temperature and a first preset pressure to the hydrocarbon source rock sample (102) so that the hydrocarbon source rock sample (102) evolves into hydrocarbon and discharges hydrocarbon-containing fluid;
the fluid-reservoir interaction unit is connected with the hydrocarbon source layer fluid generation and discharge unit and is used for applying a second preset pressure to hydrocarbon-bearing fluid discharged by hydrocarbon source rock samples (102) in hydrocarbon evolution, injecting the hydrocarbon-bearing fluid into a reservoir rock core (202) at a third preset temperature and a preset confining pressure and applying a third preset pressure to the hydrocarbon-bearing fluid discharged from the reservoir rock core (202);
and the product collecting unit is connected with the fluid-reservoir interaction unit and is used for carrying out gas-liquid separation on the oil-gas-containing fluid discharged from the reservoir core (202) and respectively collecting and metering the gas product and the liquid product obtained after separation.
2. The apparatus according to claim 1, further comprising a reservoir void determination unit connected to the fluid-reservoir interaction unit for measuring a pore volume of the pre-diagenesis reservoir core (202) and a pore volume of the post-diagenesis reservoir core (202).
3. The apparatus of claim 2, wherein the hydrocarbon source layer fluid generation and discharge unit comprises a high pressure autoclave (101), a lithostatic pressure applicator (103), a seal pressure applicator (104), a two-way hydraulic machine (105), a hydrocarbon production furnace (106), a fluid discharge automatic valve (107), a discharge fluid pressurization intermediate vessel (108), a discharge fluid pressurization pump (109), a hydrocarbon production fluid pressure sensor (110), wherein:
the high-pressure reaction kettle (101) is of a cylindrical structure with two open ends, and a hydrocarbon source rock sample (102) is filled in the high-pressure reaction kettle;
inserting a static rock pressure applicator (103) from the upper end of the high-pressure reaction kettle (101) to mechanically compact the hydrocarbon source rock sample (102) so as to apply a first preset pressure to the hydrocarbon source rock sample (102);
the lower end of the high-pressure reaction kettle (101) is sealed by applying pressure through a sealing pressure applicator (104);
the bidirectional hydraulic machine (105) system controls the static rock pressure applicator (103) and the sealing pressure applicator (104) and provides compaction and sealing power for the static rock pressure applicator (103) and the sealing pressure applicator (104);
the whole high-pressure reaction kettle (101) is arranged in a hydrocarbon generation heating furnace (106) to apply a first preset temperature to a hydrocarbon source rock sample;
one end of the fluid discharge automatic valve (107) is connected with the high-pressure reaction kettle (101) through a hydrocarbon fluid pressure sensor (110) and a stainless steel pipeline, and the other end is connected with the upper end of the discharge fluid pressurization intermediate container (108) and is used for controlling the flow of the oil-gas-containing fluid from the high-pressure reaction kettle (101) to the discharge fluid pressurization intermediate container (108);
the discharge fluid booster pump (109) is connected with the lower end of the discharge fluid pressurizing intermediate container (108) through a pipeline, and is used for regulating and controlling the pressure of the oil-gas-containing fluid in the discharge fluid pressurizing intermediate container (108).
4. The apparatus according to claim 3, wherein the fluid-reservoir interaction unit comprises a core holder (201), a reservoir heater (203), a confining pressure high pressure pump (204), an input end pressure sensor (205), an output end pressure sensor (206), an output fluid intermediate container (207), an output fluid booster pump (208), a fluid input three-way valve (209) and a fluid output shut-off valve (210), wherein:
one end of the core holder (201) is connected with the hydrocarbon source fluid generation and discharge unit through a fluid input three-way valve (209), an input end pressure sensor (205) and a high-pressure pipeline, and the other end is connected with an output end pressure sensor (206) and an output fluid intermediate container (207) through pipelines;
the core clamp (201) is used for loading a reservoir core (202) and applying preset confining pressure to the reservoir core (202) in the core clamp (201) through a surrounding pressure high-pressure pump (204);
the core holder (201) and the reservoir core (202) are placed in a reservoir heating furnace (203) and heated to a third preset temperature;
the input end pressure sensor (205) and the discharge fluid booster pump (109) are used for controlling the oil-gas-containing fluid pressure at the input end of the core clamper (201) to be boosted to a second preset pressure;
the output end pressure sensor (206) and the output fluid booster pump (208) are used for controlling the oil-gas-containing fluid pressure at the output end of the rock core holder (201) to boost the oil-gas-containing fluid pressure to a third preset pressure;
the output fluid intermediate container (207) is used for receiving hydrocarbon-containing fluid flowing through the reservoir rock core (202);
one end of the fluid output stop valve (210) is connected with the output fluid intermediate container (207), and the other end is connected with the product collection unit.
5. The apparatus of claim 4, wherein the reservoir pore volume measuring unit comprises an evacuation valve (301), a gas input valve (302), a gas pressure sensor (303), a standard chamber A valve (304), a standard chamber A (305), a gas pressure regulating valve (306), a gas inlet valve (308), and a gas source cylinder (307), wherein:
one end of the emptying valve (301) is connected with a fluid input three-way valve (209);
one end of the gas input valve (302) is connected with the fluid input three-way valve (209), and the other end is connected with the gas source steel cylinder (307) through the gas pressure sensor (303), the gas pressure regulating valve (306) and the gas inlet valve (308);
the standard chamber A (305) is connected to a line between the gas pressure sensor (303) and the gas pressure regulating valve (306) via a standard chamber A valve (304).
6. The apparatus of claim 5, wherein the product collection unit comprises a liquid product collector (401), a cryotrap (402), a gas flowmeter (403), and a collection valve (404), wherein:
the liquid product collector (401) is arranged in a low-temperature electronic cold trap (402), the oily gas passing through the fluid output stop valve (210) passes through the cooled liquid product collector (401), the liquid product is frozen in the liquid product collector (401), and the gas product is collected after passing through a collecting valve (404) after being metered by a gas flowmeter (403).
7. A method of simulating diagenesis reactions using the apparatus of claim 6, the method comprising:
drilling an immature or low-maturity source rock sample buried in a stratum, and cutting the source rock sample into a cylinder matched with an inner cavity of a high-pressure reaction kettle (101);
placing a cylindrical source rock sample (102) in a high-pressure reaction kettle (101), applying a first preset pressure on the source rock sample through a static rock pressure applicator (103), sealing the high-pressure reaction kettle (101) through a sealing pressure applicator (104), and controlling the power of the static rock pressure applicator (103) and the sealing pressure applicator (104) through a two-way hydraulic press (105);
heating a source rock sample (102) to a first preset temperature through a hydrocarbon generation heating furnace (106), maintaining the preset heating time, and collecting oil-gas-containing fluid generated in a high-pressure reaction kettle (101) by the source rock sample (102) in the heating process to a discharge fluid pressurization intermediate container (108) through a fluid discharge automatic valve (107);
the speed and the degree of the discharge of the hydrocarbon-containing fluid are controlled by an exhaust fluid booster pump (109) and a hydrocarbon fluid pressure sensor (110);
placing a drilled reservoir rock core (202) into a rock core holder (201), applying preset surrounding pressure to the reservoir rock core (202) in the rock core holder (201) through a surrounding pressure high-pressure pump (204), pressurizing oil-gas-containing fluid in a discharge fluid pressurizing middle container (108) to a second preset pressure through a discharge fluid pressurizing pump (109) and an input end pressure sensor (205), injecting the oil-gas-containing fluid to the front end of the reservoir rock core (202) through a fluid input three-way valve (209), starting a reservoir heating furnace (203) to heat the reservoir rock core (202) to a third preset temperature, and enabling the oil-gas-containing fluid and the reservoir rock layer (202) to perform diagenesis reaction;
the hydrocarbon-containing fluid after diagenesis reaction flows into an output fluid intermediate container (207) from the rear end of the core holder (201), and the pressure of the hydrocarbon-containing fluid after diagenesis reaction is boosted to a third preset pressure by an output end pressure sensor (206) and an output fluid booster pump (208);
after the diagenesis reaction of the hydrocarbon-containing fluid and the reservoir rock core (202) is completed, the fluid in the rock core holder (201) is released to a product collecting unit through a fluid output stop valve (210), gas-liquid product separation is carried out, and gas products and liquid products are respectively measured and collected;
before carrying out diagenesis reaction and after discharging all hydrocarbon-containing fluid, respectively starting a reservoir pore volume measuring unit to carry out pore volume measurement on a reservoir rock core (202) in a rock core holder (201) so as to obtain the pore volume change of the reservoir rock core (202) before and after diagenesis reaction.
8. The method of claim 7, further comprising:
reservoir cores (202) after diagenesis reactions are removed and micro-regional measurements are made to assess the effect of hydrocarbon-containing fluids on diagenesis reactions.
9. The method of claim 8, wherein the microscopic region assay is a scanning electron microscope or a thin slice assay.
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| WO2025011606A1 (en) * | 2023-07-12 | 2025-01-16 | 中国石油化工股份有限公司 | Oil and gas migration, accumulation and reservoir formation simulation device and method |
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