A method and apparatus for determining conditions for in situ shale heating to inhibit hydrogen sulfide generation

Abstract

The embodiment of the present specification provides a shale in-situ heating hydrogen sulfide generation inhibition condition determination method and device, wherein the method comprises: based on shale in-situ heating simulation experiment, taking temperature and heating rate as control factors respectively, determining the characterization quantity of each product in the shale in-situ heating simulation experiment process, wherein the each product comprises hydrogen sulfide and oil and gas; based on the characterization quantity of each product in the shale in-situ heating simulation experiment process, determining the evaluation information of the characterization quantity of each product of the shale in-situ heating under the control factor; according to the evaluation information of the characterization quantity of each product, determining the control factor range for inhibiting the generation of hydrogen sulfide, so as to guide the shale in-situ heating by using the control factor range. The present specification can provide technical support and basis for selecting the heating program with good oil and gas yield and less hydrogen sulfide yield in the process of developing shale oil and gas by in-situ heating.

Description

Technical Field

[0001] The embodiments in this specification relate to the field of oil and gas exploration and development, and in particular, to a method and apparatus for determining the conditions for suppressing hydrogen sulfide formation by in-situ heating of shale. Background Technology

[0002] Shale oil and gas development includes naturally formed shale oil and gas under geological conditions and in-situ heated shale oil and gas. For shale oil resources with heavy oil content, high viscosity, and low gas-oil ratio, large-scale and economical development cannot be achieved using existing horizontal wells and volumetric fracturing technologies. In-situ conversion, through electric heating technology to heat the shale formation (340–400°C), can rapidly crack heavy oil and solid organic matter (kerogen) into light oil and natural gas, which can then be extracted using conventional techniques. However, hydrocarbon generation thermal simulation experiments under shale in-situ conversion conditions show that for shale with high sulfur content, while cracking to produce light oil and hydrocarbon gases, it also generates a large amount of hydrogen sulfide gas. Hydrogen sulfide not only causes serious environmental pollution but also corrodes pipelines, increases engineering difficulty, and easily causes production safety accidents. Therefore, hydrogen sulfide is the most concerning non-hydrocarbon gas among the gas products of shale in-situ conversion. However, although in-situ heated shale oil and gas development focuses more on oil and gas production and characteristics, it has received almost no attention regarding hydrogen sulfide produced by shale in-situ heating.

[0003] Previous research on hydrogen sulfide gas has primarily focused on hydrogen sulfide in naturally formed oil and gas under geological conditions, mainly examining its formation mechanism and distribution characteristics in natural gas. For high-hydrogen sulfide natural gas reservoirs, hydrogen sulfide sources include biogenicity, thermal cracking of sulfur-containing compounds, and thermochemical reduction of sulfates. Current technologies have almost no research on hydrogen sulfide produced during in-situ shale conversion, which involves subsequent heating to produce oil and gas.

[0004] Therefore, there is an urgent need for a method to determine the conditions for suppressing hydrogen sulfide generation during in-situ heating of shale, so as to provide technical support and basis for selecting heating procedures with good oil and gas production and low hydrogen sulfide production during the in-situ heating development of shale oil and gas. Summary of the Invention

[0005] The purpose of the embodiments in this specification is to provide a method and apparatus for determining the conditions for suppressing hydrogen sulfide generation during in-situ heating of shale, providing technical support and basis for selecting a heating procedure with good oil and gas production and the ability to suppress hydrogen sulfide production during the in-situ heating development of shale oil and gas.

[0006] To achieve the above objectives, this specification provides, in one aspect, a method for determining the conditions for suppressing hydrogen sulfide formation through in-situ heating of shale, comprising:

[0007] Based on the shale in-situ heating simulation experiment, temperature and heating rate were used as control factors to determine the characterization of each product during the shale in-situ heating simulation experiment. Each product includes hydrogen sulfide and oil and gas.

[0008] Based on the characterization of each product during the shale in-situ heating simulation experiment, the evaluation information of the characterization of each product under the control factor is determined.

[0009] Based on the evaluation information of each product characterization quantity, the range of control factors for inhibiting hydrogen sulfide formation was determined, so as to guide the in-situ heating of shale using the range of control factors.

[0010] Preferably, the method for determining the characterization quantities of each product during the shale in-situ heating simulation experiment includes:

[0011] Multiple shale samples were prepared in advance;

[0012] Shale samples were subjected to in-situ heating simulation experiments. The heating rates of each shale sample were different, and each sample was heated to multiple preset temperatures at its own heating rate. The characterization of each product was determined when each preset temperature was reached.

[0013] Preferably, determining the characterization quantity of each product each time it is heated to a preset temperature further includes:

[0014] The amount of each product generated at each stage is measured when the temperature is heated to a preset temperature.

[0015] Calculate the stage concentration, cumulative generation, and / or cumulative concentration of hydrogen sulfide based on the stage generation of hydrogen sulfide.

[0016] Calculate the cumulative amount of oil and gas generated based on the stage generation of oil and gas.

[0017] The stage formation and / or cumulative formation of oil and gas are used as the characterization of oil and gas.

[0018] The stage generation amount, stage concentration, cumulative generation amount, and cumulative concentration of hydrogen sulfide are used as characterization quantities for hydrogen sulfide.

[0019] Preferably, the evaluation information for determining the characterization of each product during shale in-situ heating simulation experiments, based on the characterization of each product, further includes:

[0020] Each heating to a preset temperature is considered a stage;

[0021] Based on the characterization of each product in each stage of the shale in-situ heating simulation experiment, with the value of the control factor in each stage as the independent variable and the characterization of each product of shale in-situ heating as the dependent variable, an evaluation function is constructed.

[0022] The evaluation information of the characterization of each product under in-situ shale heating is determined by the evaluation function corresponding to each product under the control factor.

[0023] Preferably, the evaluation information for determining the characterization of each product during shale in-situ heating simulation experiments, based on the characterization of each product, further includes:

[0024] Each heating to a preset temperature is considered a stage;

[0025] Based on the characterization of each product in each stage of the shale in-situ heating simulation experiment, an evaluation chart is drawn with the value of the control factor in each stage as the x-axis and the characterization of each product of shale in-situ heating as the y-axis.

[0026] The evaluation information of the characterization of each product under in-situ shale heating was determined by the evaluation charts corresponding to each product under the control factor.

[0027] Preferably, the oil and gas includes light hydrocarbons, hydrocarbon gases, and crude oil, and the system used for the in-situ heating simulation experiment includes: heating equipment, crude oil collection and quantitative equipment, light hydrocarbon collection and quantitative equipment, gas collection and quantitative equipment, and gas analysis equipment;

[0028] The heating device is used for in-situ heating of shale samples;

[0029] Both the crude oil collection and metering device and the light hydrocarbon collection and metering device include: an extraction control device, a collector, and a weighing device; the extraction control device is installed on the collector, the weighing device is installed at the bottom of the weighing device, the collector of the crude oil collection and metering device is connected to the heating device, and the collector of the light hydrocarbon collection and metering device is connected to the collector of the crude oil collection and metering device.

[0030] The extraction control device of the crude oil collection and metering device is used to control the collection of crude oil in the collector of the crude oil collection and metering device, and the extraction control device of the light hydrocarbon collection and metering device is used to control the collection of light hydrocarbons in the collector of the light hydrocarbon collection and metering device;

[0031] The weighing instrument is used to measure the amount of crude oil / light hydrocarbons generated;

[0032] The gas collection and metering device includes: a vacuum bag and a measuring device; the vacuum bag is connected to the collector of the light hydrocarbon collection and metering device and is used to collect gas; the measuring device is located at the inlet of the vacuum bag and is used to measure the gas volume and the pressure inside the vacuum bag.

[0033] The gas analysis device is connected to the gas collection and quantification device and is used to analyze the amount of hydrogen sulfide generated.

[0034] The data obtained by the weighing instrument, measuring equipment, and gas analysis equipment are experimental data.

[0035] Preferably, the extraction control device includes: an annular condenser and a condensation controller;

[0036] The annular condenser is fitted outside the collector and connected to the condensation controller, and is used to bring the inside of the collector to the condensation temperature for collecting crude oil / light hydrocarbons under the control of the condensation controller.

[0037] Preferably, the system used for the in-situ heating simulation experiment further includes: rinsing equipment and analytical equipment;

[0038] The flushing device is connected to the connecting pipeline between the heating device and the crude oil collection and metering device. The flushing device is equipped with petroleum flushing fluid for flushing the connecting pipeline.

[0039] The flushing device is activated after the shale sample is heated to each preset temperature and the crude oil is discharged from the crude oil collection and metering device. The petroleum flushing fluid flows into the connecting pipeline to form a mixture, which enters the collector in the crude oil collection and metering device. The analysis device is connected to the collector in the crude oil collection and metering device and is used to analyze the mixture to determine the amount of crude oil in the connecting pipeline.

[0040] Preferably, the step of determining the range of control factors for inhibiting hydrogen sulfide formation based on the evaluation information of each product characterization quantity, so as to guide the in-situ heating of shale using the range of control factors, further includes:

[0041] Based on the evaluation information of oil and gas characterization and the needs of extraction, the initial range of control factors is determined;

[0042] Based on the evaluation information of hydrogen sulfide characterization, the range in which the hydrogen sulfide characterization is less than the predetermined amount is determined from the initial range of the control factor, and the determined range is taken as the final range of the control factor.

[0043] On the other hand, embodiments of this specification provide an apparatus for determining conditions for suppressing hydrogen sulfide formation through in-situ heating of shale, the apparatus comprising:

[0044] The characterization quantity determination unit is used to determine the characterization quantities of each product in the shale in-situ heating simulation experiment based on the in-situ heating simulation experiment of shale, with temperature and heating rate as control factors respectively. The products include hydrogen sulfide and oil and gas.

[0045] The evaluation information determination unit is used to determine the evaluation information of the characterization of each product during the shale in-situ heating simulation experiment under the control factor.

[0046] The guidance unit is used to determine the range of control factors for inhibiting hydrogen sulfide formation based on the evaluation information of each product characterization quantity, so as to guide the in-situ heating of shale using the range of control factors.

[0047] In another aspect, embodiments of this specification also provide a computer device, including a memory, a processor, and a computer program stored in the memory, wherein the computer program, when executed by the processor, performs instructions according to any of the methods described above.

[0048] In another aspect, embodiments of this specification also provide a computer-readable storage medium having a computer program stored thereon, which, when executed by a processor of a computer device, performs instructions according to any one of the methods described above.

[0049] As can be seen from the technical solutions provided in the embodiments of this specification above, the embodiments of this specification realize the determination of the evaluation information of each product's characterization quantity by heating to each temperature at different temperatures and heating rates; furthermore, the range of control factors for inhibiting hydrogen sulfide generation is determined based on the evaluation information of each product's characterization quantity, providing technical support and basis for selecting a heating procedure that can inhibit hydrogen sulfide production without affecting the extraction needs during the in-situ heating development of shale oil and gas.

[0050] To make the above and other objects, features and advantages of this specification more apparent and understandable, preferred embodiments are described below in detail with reference to the accompanying drawings. Attached Figure Description

[0051] To more clearly illustrate the technical solutions in the embodiments or prior art of this specification, the drawings used in the description of the embodiments or prior art will be briefly introduced below. Obviously, the drawings described below are only some embodiments of this specification. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0052] Figure 1 A flowchart illustrating a method for determining conditions for suppressing hydrogen sulfide formation through in-situ heating of shale, as provided in an embodiment of this specification, is shown.

[0053] Figure 2 A flowchart illustrating the method for determining the characterization quantities of each product during the shale in-situ heating simulation experiment provided in the embodiments of this specification is shown.

[0054] Figure 3 A schematic diagram of the shale in-situ heating simulation experimental equipment provided in the embodiments of this specification is shown;

[0055] Figure 4A schematic flowchart illustrating the measurement of characterization quantities of each product when heated to a preset temperature is shown in the embodiments of this specification.

[0056] Figure 5 This document illustrates a flowchart of an embodiment of the method for determining the evaluation information of the characterization of each product during a shale in-situ heating simulation experiment under control factors.

[0057] Figure 6 This document illustrates another flowchart illustrating the evaluation information for determining the characterization of each product during shale in-situ heating under control factors, based on the characterization of each product during a shale in-situ heating simulation experiment.

[0058] Figure 7 This specification provides a schematic diagram illustrating the process of determining the range of control factors for inhibiting hydrogen sulfide generation based on evaluation information of each product characterization quantity, in order to guide in-situ heating of shale using the range of control factors.

[0059] Figure 8 The diagram shows the variation of hydrogen sulfide gas generation as a function of temperature in in-situ heating experiments with heating rates of 20°C / day, 10°C / day, 5°C / day, and 2°C / day, as provided in the embodiments of this specification.

[0060] Figure 9 The diagram shows the phased concentration of hydrogen sulfide gas as a function of temperature in in-situ heating experiments with heating rates of 20°C / day, 10°C / day, 5°C / day and 2°C / day, as provided in the embodiments of this specification.

[0061] Figure 10 The graph shows the cumulative concentration of hydrogen sulfide gas as a function of temperature in in-situ heating experiments provided in the embodiments of this specification, corresponding to heating rates of 20°C / day, 10°C / day, 5°C / day, and 2°C / day.

[0062] Figure 11 A schematic diagram of the module structure of a device for determining conditions for suppressing hydrogen sulfide generation by in-situ heating of shale provided in an embodiment of this specification is shown.

[0063] Figure 12 This specification shows a schematic diagram of the structure of a computer device provided in an embodiment.

[0064] Figure 13 This document shows a graph illustrating the cumulative oil production variation under in-situ heating of the Chang 7 shale under the same temperature and different heating rates, as described in the embodiments of this specification.

[0065] Figure 14 This document shows a graph illustrating the cumulative oil production variation under in-situ heating of the Chang 7 shale at different temperatures with the same heating rate, according to embodiments of this specification.

[0066] Figure 15 This diagram illustrates the variation in the cumulative gas generation during in-situ heating of the Chang 7 shale under the same temperature and different heating rates, according to embodiments of this specification.

[0067] Figure 16 The diagram illustrates the variation in the cumulative amount of gas generated during in-situ heating of the Chang 7 shale under different temperature conditions at the same heating rate, according to embodiments of this specification.

[0068] Explanation of symbols in the attached drawings:

[0069] 21. Heating equipment;

[0070] 22. Crude oil collection and metering equipment;

[0071] 23. Light hydrocarbon collection and metering equipment;

[0072] 24. Gas collection and metering equipment;

[0073] 25. Gas analysis equipment;

[0074] 221. Extraction control equipment;

[0075] 222. Collector;

[0076] 223. Weighing instrument;

[0077] 231. Extraction control equipment;

[0078] 232. Collector;

[0079] 233. Weighing instrument;

[0080] 2211. Condensation controller;

[0081] 2212. Annular condenser;

[0082] 2311. Condensation controller;

[0083] 2312. Annular condenser;

[0084] 241. Gas collection tank;

[0085] 242. Measuring equipment;

[0086] 243. Vacuum pump;

[0087] 2421. Gas flow meter;

[0088] 2422. Pressure gauge;

[0089] 100. Characteristic quantity determination unit;

[0090] 200. Evaluation Information Determination Unit;

[0091] 300. Guidance Unit;

[0092] 1202. Computer equipment;

[0093] 1204, Processor;

[0094] 1206. Memory;

[0095] 1208. Drive mechanism;

[0096] 1210. Input / output module;

[0097] 1212. Input devices;

[0098] 1214. Output devices;

[0099] 1216. Presentation equipment;

[0100] 1218. Graphical User Interface;

[0101] 1220. Network interface;

[0102] 1222. Communication link;

[0103] 1224. Communication bus. Detailed Implementation

[0104] The technical solutions in the embodiments of this specification will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of this specification, and not all embodiments. Based on the embodiments in this specification, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of the embodiments of this specification.

[0105] Figure 1 This is a flowchart illustrating a method for determining conditions to suppress hydrogen sulfide formation through in-situ heating of shale, as provided in the embodiments of this specification. This specification provides the operational steps of the method described in the embodiments or flowcharts, but based on conventional or non-inventive labor, more or fewer operational steps may be included. The order of steps listed in the embodiments is merely one possible execution order among many and does not represent the only possible execution order. In actual system or device products, the methods shown in the embodiments or accompanying drawings can be executed sequentially or in parallel.

[0106] It should be noted that the terms "first," "second," etc., in the description, claims, and accompanying drawings of the embodiments in this specification are used to distinguish similar objects and are not necessarily used to describe a specific order or sequence. It should be understood that such data can be interchanged where appropriate so that the embodiments described herein can be implemented in orders other than those illustrated or described herein. Furthermore, the terms "comprising" and "having," and any variations thereof, are intended to cover non-exclusive inclusion; for example, a process, method, apparatus, product, or device that includes a series of steps or units is not necessarily limited to those steps or units explicitly listed, but may include other steps or units not explicitly listed or inherent to such processes, methods, products, or devices.

[0107] Reference Figure 1 This specification provides a method for determining the conditions for suppressing hydrogen sulfide formation through in-situ heating of shale, including:

[0108] S101: Based on the shale in-situ heating simulation experiment, the characterization quantities of each product in the shale in-situ heating simulation experiment were determined by using temperature and heating rate as control factors. The products include hydrogen sulfide and oil and gas.

[0109] S102: Based on the characterization of each product during the shale in-situ heating simulation experiment, determine the evaluation information of the characterization of each product under the control factor.

[0110] S103: Based on the evaluation information of each product characterization quantity, determine the range of control factors for inhibiting hydrogen sulfide formation, so as to guide the in-situ heating of shale using the range of control factors.

[0111] The embodiments in this specification, through steps S101 to S102, enable the determination of evaluation information for the characterization of each product by measuring its characteristics at different temperatures and heating rates. Furthermore, step S103 determines the range of control factors for suppressing hydrogen sulfide formation, providing technical support and a basis for selecting a heating procedure that suppresses hydrogen sulfide production without affecting extraction needs during in-situ heating development of shale oil and gas.

[0112] In the embodiments described in this specification, reference is made to Figure 2 The method for determining the characterization parameters of each product during the shale in-situ heating simulation experiment includes:

[0113] S201: Multiple shale samples were prepared in advance;

[0114] S202: Conduct in-situ heating simulation experiments on shale samples. The heating rates of each shale sample are different, and each sample is heated to multiple preset temperatures at its own heating rate. When each preset temperature is reached, the characterization quantity of each product is determined.

[0115] In practice, multiple shale samples of equal mass are selected. The treated shale samples are first placed in a specially designed reactor resistant to acid and hydrogen sulfide corrosion, and then heated. The heating process of the shale samples can be controlled by a computer. The heating simulation experiment can be conducted using a reactor with heating rate and temperature control functions. Quantitative collection devices are set up for each product to measure the amount of each product generated and recoverable. Since the heating rates of each shale sample are different, they are heated to a preset temperature at their respective preset heating rates, thereby obtaining the characterization quantities of each product generated and recoverable at each preset temperature.

[0116] The products include hydrogen sulfide and oil and gas, wherein the oil and gas includes light hydrocarbons, hydrocarbon gases, and crude oil, wherein light hydrocarbons refer to C6-C hydrocarbons. 14 The sum of components, crude oil refers to the C content of hydrocarbons produced. 15+ The sum of the components. For gases like hydrogen sulfide, the characterization of each product refers to the amount produced, the stage concentration, or the cumulative concentration of each product. For crude oil and light hydrocarbons, the characterization of each product is the amount produced or the cumulative amount produced.

[0117] In one specific embodiment, the equipment used for the heating simulation experiment is as follows: Figure 3 As shown, it includes: heating equipment 21, crude oil collection and metering equipment 22, light hydrocarbon collection and metering equipment 23, gas collection and metering equipment 24, and gas analysis equipment 25.

[0118] Heating device 21 is used for in-situ heating of rock samples. Specifically, heating device 21 includes a reaction vessel, a temperature controller, and a temperature sensor. The reaction vessel is used to hold the rock sample, the temperature sensor is located inside the reaction vessel to measure the internal temperature, and the temperature controller can adjust the heating rate to control the internal temperature of the reaction vessel to reach a predetermined temperature.

[0119] The crude oil collection and metering device 22 includes: an extraction control device 221, a collector 222, and a weighing device 223. The extraction control device 221 is mounted on the collector 222 and is used to control the temperature inside the collector 222 to ensure that the crude oil reaches its condensation temperature. The weighing device 223 is located at the bottom of the collector 222 and is used to quantitatively measure the crude oil in the collector 222. The collector 222 is connected to the heating device 21. In one specific embodiment, the extraction control device 221 includes a condensation controller 2211 and an annular condensation device 2212. The condensation controller 2211 is connected to the annular condensation device and is used to control the temperature in the annular condensation device 2212. The annular condensation device 2212 is fitted onto the outside of the collector 222 and is used to control the solidification of the crude oil in the condenser.

[0120] The light hydrocarbon collection and quantitative device 23 includes: an extraction control device 231, a collector 232, and a weighing device 233. The extraction control device 231 is installed on the collector 232 and is used to control the temperature inside the collector 232 to ensure that the collector 232 reaches the light hydrocarbon condensation temperature. The weighing device 233 is installed at the bottom of the collector 232 and is used to quantitatively measure the light hydrocarbons in the collector 232. The collector 222 is connected to the collector 232. In one specific embodiment, the extraction control device 231 includes a condensation controller 2311 and an annular condensation device 2312. The condensation controller 2311 is connected to the annular condensation device and is used to control the temperature in the annular condensation device 2312. The annular condensation device 2312 is fitted onto the outside of the collector 232 and is used to control the solidification of light hydrocarbons in the condenser.

[0121] The gas collection and metering device 24 includes: a vacuum bag 241, a measuring device 242, and a vacuum pump 243. The vacuum bag 241 is connected to a collector 232 and is used to collect gases, including hydrocarbon gases and hydrogen sulfide. The measuring device 242 is located at the inlet of the vacuum bag and is used to measure the gas volume and the pressure inside the vacuum bag. Specifically, the measuring device 242 includes a gas flow meter 2421 and a pressure gauge 2422. The gas flow meter 2421 is used to measure the gas volume, and the pressure gauge 2422 is used to measure the pressure inside the vacuum bag. The vacuum pump is used to evacuate the vacuum bag before gas collection.

[0122] Gas analysis device 25 is connected to gas collection and quantification device 24 for analyzing the amount of hydrogen sulfide generated. In some embodiments, gas analysis device 25 is a Wasson-Agilent 7890 gas chromatograph, specifically, the gas chromatograph contains a flame ionization detector and two thermal conductivity detectors, allowing for the detection of hydrogen sulfide in the gas in a single analysis. Alternatively, the gas volume can be measured using the whole gas bag displacement method.

[0123] The data obtained by the weighing instruments 223 and 233, the measuring device 242, and the gas analysis device 25 are experimental data.

[0124] This embodiment enables accurate fractional collection of crude oil, light hydrocarbons, and hydrogen sulfide by setting up extraction control equipment. Furthermore, by setting up a weighing device, measuring equipment, and gas analysis equipment, it can realize the generation amount of each product during the shale in-situ heating simulation process.

[0125] In practice, the distance between the annular condenser and the collector in the crude oil collection and metering equipment and the light hydrocarbon collection equipment is 2-3 mm. This setting allows for the condensation of the products in the collector without affecting the real-time weighing of crude oil and light hydrocarbons.

[0126] The collector in the crude oil collection and metering device can collect most of the crude oil, but some crude oil adheres to the connecting pipeline from the heating equipment to the crude oil collection and metering device, which leads to... Figure 3 The system shown cannot accurately measure the amount of crude oil. Considering this problem, in one embodiment of this paper, the system used for the in-situ heating simulation experiment also includes: rinsing equipment and analysis equipment.

[0127] The flushing equipment connects the heating equipment to the crude oil collection and metering equipment via a pipeline. The flushing equipment contains petroleum flushing fluid for flushing the connecting pipeline. In some embodiments, dichloromethane is used as the petroleum flushing fluid.

[0128] The flushing equipment is activated after the shale sample is heated to each preset temperature and the crude oil is discharged from the crude oil collection and metering equipment. The petroleum flushing fluid flows into the connecting pipeline to obtain a mixture, which then enters the collector in the crude oil collection and metering equipment.

[0129] The analytical equipment is connected to the collector in the crude oil collection and metering device to receive the mixture in the collector and analyze it to determine the amount of crude oil in the connecting pipeline. Alternatively, the mixture from the collector can be manually placed into the analytical equipment. The analytical equipment uses the internal standard method to calibrate the crude oil content in the mixture; specifically, the internal standard is C at a concentration of 0.205 mg / ml. 24 H 49 D. The analytical equipment determines the crude oil quantity by comparing the area of ​​all peaks in the chromatogram of the mixed solution with the area of ​​the internal standard.

[0130] In one specific embodiment, the preset temperatures can be: 270℃, 320℃, 350℃, 380℃, 410℃, 440℃, and 450℃. Four shale samples of Long 7 were prepared, with corresponding heating rates of 20℃ / day, 10℃ / day, 5℃ / day, and 2℃ / day, respectively. The sample heating program was as follows: the four shale samples were first heated from room temperature (20℃) to 270℃ over three days. Then, simulation experiments were conducted according to the above four heating rates. The four shale samples were heated to the above preset temperatures at their respective heating rates, with the highest preset temperature being 450℃. For each shale sample, the characterization amount of each product was measured once after heating to each preset temperature.

[0131] In the shale in-situ heating simulation experiment, referring to Figure 4 Each time the temperature is heated to a preset temperature, the characterization amount of each product is determined, further including:

[0132] S301: Measure the amount of each product generated at each stage when heated to a preset temperature;

[0133] S302: Calculate the stage concentration, cumulative generation and / or cumulative concentration of hydrogen sulfide based on the stage generation of hydrogen sulfide;

[0134] S303: Calculate the cumulative amount of oil and gas generated based on the stage generation amount;

[0135] S304: The stage generation and / or cumulative generation of oil and gas are used as the characterization of oil and gas.

[0136] S305: At least one of the following is used as a characterization of hydrogen sulfide: stage generation amount, stage concentration, cumulative generation amount, and cumulative concentration.

[0137] For example, in an in-situ heating experiment at a heating rate of 20℃ / day, the generation amounts of hydrogen sulfide gas at each stage were as follows: at 270℃, the hydrogen sulfide generation was 0; at 320℃, the hydrogen sulfide generation was 0.06m³. 3 / t shale; at 350℃, the hydrogen sulfide production is 0.38m³. 3 / t shale; at 380℃, the hydrogen sulfide production is 0.77m³. 3 / t shale; at 410℃, the hydrogen sulfide production is 0.63m³. 3 / t shale; at 440℃, the hydrogen sulfide production is 0.24m³. 3 / t shale; at 450℃, hydrogen sulfide formation is 0. Similarly, the stage formation of oil and gas at each stage can be obtained under a heating rate of 20℃ / day.

[0138] The generation amounts of hydrogen sulfide gas at each stage in the in-situ heating experiment under a heating rate of 10℃ / day were as follows: 0 at 270℃; 0.05 at 320℃; and 0.41 m³ at 350℃. 3 / t shale; at 380℃, the hydrogen sulfide production is 0.61m³. 3 / t shale; at 410℃, the hydrogen sulfide production is 0.38m³. 3 / t shale; at 440℃, the hydrogen sulfide formation is 0.13; at 450℃, the hydrogen sulfide formation is 0. Similarly, the stage formation of oil and gas at each stage under a heating rate of 10℃ / day can be obtained.

[0139] The generation amounts of hydrogen sulfide gas at each stage in the in-situ heating experiment under a heating rate of 5℃ / day were as follows: 0 at 270℃; 0.05 at 320℃; and 0.28 m³ at 350℃. 3 / t shale; at 380℃, the hydrogen sulfide production is 0.38m³. 3 / t shale; at 410℃, the hydrogen sulfide production is 0.22m³. 3 / t shale; at 440℃, the hydrogen sulfide formation is 0.05; at 450℃, the hydrogen sulfide formation is 0. Similarly, the stage formation of oil and gas at each stage can be obtained under a heating rate of 5℃ / day.

[0140] The generation amounts of hydrogen sulfide gas at each stage in the in-situ heating experiment under a heating rate of 2℃ / day were as follows: 0 at 270℃; 0 at 320℃; and 0 at 350℃. 3 / t shale; at 380℃, the hydrogen sulfide formation is 0.01; at 410℃, the hydrogen sulfide formation is 0; at 440℃, the hydrogen sulfide formation is 0; at 450℃, the hydrogen sulfide formation is 0. Similarly, the stage formation of oil and gas at each stage under a heating rate of 2℃ / day can be obtained.

[0141] Based on the stage-by-stage generation of hydrogen sulfide, the stage concentration, cumulative generation, and / or cumulative concentration of hydrogen sulfide can be further calculated. The stage concentration is the concentration of hydrogen sulfide generated in each stage, the cumulative generation is the total amount of hydrogen sulfide gas generated including the current stage and all previous stages, and the cumulative concentration is the total concentration of hydrogen sulfide generated including the current stage and all previous stages. Based on the stage-by-stage generation of oil and gas, the cumulative generation of oil and gas can be further calculated, which is the total amount of oil and gas generated including the current stage and all previous stages.

[0142] In the embodiments described in this specification, reference is made to Figure 5 The evaluation information for determining the characterization of each product during shale in-situ heating simulation experiments, based on the characterization of each product, further includes:

[0143] S401: Each heating to a preset temperature is considered a stage;

[0144] S402: Based on the characterization of each product in each stage of the shale in-situ heating simulation experiment, with the value of the control factor in each stage as the independent variable and the characterization of each product of shale in-situ heating as the dependent variable, an evaluation function is constructed.

[0145] S403: The evaluation information of the characterization of each product under the control factor is determined by the evaluation function corresponding to each product.

[0146] The evaluation information can be an evaluation function. Taking the evaluation function for hydrogen sulfide as an example, it corresponds to four different heating rates: 20℃ / day, 10℃ / day, 5℃ / day, and 2℃ / day. Each heating rate corresponds to an evaluation function. The independent variable in the evaluation function is the temperature corresponding to each stage, and the dependent variable is a characteristic of hydrogen sulfide, such as the cumulative concentration of hydrogen sulfide. Since the cumulative concentration of hydrogen sulfide corresponding to preset temperatures of 270℃, 320℃, 350℃, 380℃, 410℃, 440℃, and 450℃ has been obtained through in-situ heating experiments, the evaluation function for hydrogen sulfide can be fitted. Oil and gas include light hydrocarbons, crude oil, and hydrocarbon gases. Light hydrocarbons belong to light oils, and crude oil belongs to heavy oils. Both light hydrocarbons and crude oil belong to oils. Using the above method, the evaluation functions corresponding to crude oil / light hydrocarbons and hydrocarbon gases can also be obtained.

[0147] In addition, the evaluation function can also use the heating rate and the preset temperature corresponding to each stage as independent variables, and the characterization of each product as dependent variables.

[0148] In the embodiments described in this specification, reference is made to Figure 6 The evaluation information for determining the characterization of each product during shale in-situ heating simulation experiments, based on the characterization of each product, further includes:

[0149] S501: Each heating to a preset temperature is considered a stage;

[0150] S502: Based on the characterization of each product in each stage of the shale in-situ heating simulation experiment, an evaluation chart is drawn with the value of the control factor in each stage as the abscissa and the characterization of each product of shale in-situ heating as the ordinate.

[0151] S503: Based on the evaluation charts corresponding to each product, determine the evaluation information of the characterization of each product under the control factor during in-situ heating of shale.

[0152] The evaluation information can be presented in the form of evaluation charts. Taking the evaluation function for hydrogen sulfide as an example, it corresponds to four different heating rates: 20℃ / day, 10℃ / day, 5℃ / day, and 2℃ / day. Each heating rate corresponds to an evaluation chart. In the evaluation chart, the horizontal axis represents the temperature corresponding to each stage, and the vertical axis represents the characterization quantity of hydrogen sulfide, such as the cumulative concentration of hydrogen sulfide. Since the cumulative concentration of hydrogen sulfide corresponding to the preset temperatures of 270℃, 320℃, 350℃, 380℃, 410℃, 440℃, and 450℃ has been obtained through in-situ heating experiments, evaluation charts can be drawn. The same method can also be used to obtain evaluation charts for crude oil / light hydrocarbons and evaluation charts for hydrocarbon gases.

[0153] In addition, each preset temperature can be associated with an evaluation chart, where the horizontal axis represents the heating rate at each preset temperature and the vertical axis represents the characterization of each product.

[0154] Both the evaluation function and the evaluation chart mentioned above can be used to determine the range of control factors for inhibiting hydrogen sulfide formation. For details, please refer to... Figure 7 The step of determining the range of control factors for inhibiting hydrogen sulfide formation based on the evaluation information of each product characterization quantity, so as to guide the in-situ heating of shale using the range of control factors, further includes:

[0155] S601: Determine the initial range of control factors based on the evaluation information of oil and gas characterization quantities and the needs of extraction;

[0156] S602: Based on the evaluation information of the hydrogen sulfide characterization quantity, determine the range in which the hydrogen sulfide characterization quantity is less than the predetermined quantity from the initial range of the control factor, and take the determined range as the final range of the control factor.

[0157] Generally speaking, in order to ensure the normal extraction of oil and gas, it is necessary to maintain a reasonable temperature and heating rate during the in-situ heating process of shale so that oil and gas can be produced at a certain temperature and heating rate. Thus, the initial range of temperature and heating rate can be determined, that is, the normal production of oil and gas can be guaranteed within the initial range of temperature and heating rate.

[0158] Based on this, the range in which the characterization amount of hydrogen sulfide is less than the predetermined amount is determined. The predetermined amount can be determined according to the actual working conditions, with the aim of keeping the hydrogen sulfide production at a low level. Thus, within the initial range of temperature and heating rate, the final range of temperature and heating rate is determined.

[0159] Figures 8-10 The graphs show the changes in the stage generation, stage concentration, and cumulative concentration of hydrogen sulfide gas as a function of temperature in in-situ heating experiments at four heating rates: 20℃ / day, 10℃ / day, 5℃ / day, and 2℃ / day. The in-situ heating experiment at a heating rate of 20℃ / day produced the highest stage generation, stage concentration, and cumulative concentration of hydrogen sulfide gas, followed by 10℃ / day, then 5℃ / day, and finally 2℃ / day.

[0160] Reference Figure 8 As shown, under four different heating rates to 450℃, the temperature range with higher H2S (hydrogen sulfide) generation is 350-410℃. The H2S generation shows a pattern of first high and then low as the temperature increases.

[0161] Reference Figure 9As shown, the H2S concentration and generation rate exhibit similar characteristics, showing a trend of initially high and then low with increasing temperature. The highest peak temperature range is 350℃-380℃, with the highest concentration reaching 20%. Referring to Figure 10, the cumulative concentration of hydrogen sulfide increases rapidly before reaching 350℃-380℃, peaks in the 350℃-380℃ temperature range, and then slowly decreases with increasing temperature, with the highest cumulative concentration reaching 18.33%.

[0162] The evaluation function is explained in detail through the following specific embodiments. Four shale samples with a length of 7 are set, and the heating rate of each shale sample is 2℃ / day, 5℃ / day, 10℃ / day and 20℃ / day. All shale samples are heated from room temperature (20℃) to 270℃ in advance for 3 days. Then, in-situ heating simulation experiments are carried out according to the above four heating rates. The highest preset temperature of the four sequence experiments is 450℃. In this embodiment, the preset temperature includes 5 temperature points: 320℃, 350℃, 380℃, 410℃, 440℃ and 450℃.

[0163] Based on experimental data, the cumulative production of each product in the Chang 7 shale sample at each preset heating rate and temperature (cumulative production of each product per ton of shale during in-situ heating) was calculated. Based on the cumulative production of each product at each preset heating rate and temperature, the following evaluation functions corresponding to each product of the Chang 7 shale in-situ heating were fitted:

[0164] 1) Evaluation function for cumulative oil production, where oil includes crude oil and light hydrocarbons.

[0165] (1) As Figure 13 As shown, the evaluation function corresponding to the cumulative oil production during in-situ heating of the Chang 7 shale under the same temperature and different heating rates is as follows:

[0166] Y oil320 =-0.2249×r+5.1315 Formula 1

[0167] Y oil350 =-0.5179×r+14.179 Formula 2

[0168] Y oil380 =-0.9427×r+36.588 Formula 3

[0169] Y oil410 = 0.0701×r+38.716 Formula 4

[0170] Y oil440 = 0.0458×r+42.495 Formula 5

[0171] Y oil450= 0.0601×r+42.855 Formula 6

[0172] Formula 1-Y in Formula 6 oilx The cumulative amount of oil generated when shale is heated in situ to temperature x, in kg; r is the heating rate, in °C / d.

[0173] The cumulative generation of oil from in-situ heating of the Chang 7 shale under the same temperature but different heating rates is shown in the figure below. Figure 4 As shown. The correlation coefficients (R²) of the 5 regression curves. 2 The range is 0.790 to 0.987.

[0174] (2) Figure 14 As shown, the evaluation function corresponding to the cumulative oil production during in-situ heating of the Chang 7 shale under the same heating rate but different temperature conditions is as follows:

[0175] Y oil2℃ / d =40.29-39.11 / (1+exp((T-359.48) / 13.51)) Formula 7

[0176] Y oil5℃ / d =42.87-42.66 / (1+exp((T-363.10) / 15.38)) Formula 8

[0177] Y oil10℃ / d =43.64-43.41 / (1+exp((T-374.10) / 14.39)) Formula 9

[0178] Y oil20℃ / d =44.14-43.59 / (1+exp((T-384.63) / 12.19)) Formula 10

[0179] Formula 7-Y in Formula 10 oilw The cumulative amount of oil generated when shale is heated in situ at a heating rate w, expressed in kg; T represents temperature, expressed in °C.

[0180] like Figure 14 As shown, the experimental data and fitted data on the cumulative oil production of the Chang 73 shale when heated to different temperatures show a very high degree of fit between the two, with a correlation coefficient (R²) of 4 curves. 2 The range is 0.996 to 0.998.

[0181] (3) The evaluation function corresponding to the cumulative oil production of the Chang 7 shale under different heating rates and different temperatures is as follows:

[0182] Y oil=2.821-0.198r+42.06 / (1+exp((T-371.243) / -15.482)) Formula 11

[0183] In this formula, Y oil The cumulative amount of oil produced is represented by the heating rate r, which ranges from 2 to 20℃ / day, and the temperature T, which ranges from 320 to 450℃.

[0184] Depend on Figure 13 and Figure 14 It can be seen that the maximum oil yield produced by the in-situ heating simulation experiments at different heating rates ranged from approximately 41.07 to 43.94 kg / ton·rock. In the four in-situ heating simulation experiments with different heating rates, almost no oil was produced before reaching 300℃. The maximum oil yields at heating rates of 2℃ / day, 5℃ / day, and 10℃ / day were between 350℃ and 380℃, with maximum yields of 20.30 kg / ton·rock, 20.93 kg / ton·rock, and 20.69 kg / ton·rock, respectively; the maximum oil yield at 20℃ / day was between 380℃ and 410℃, with a maximum yield of 22.77 kg / ton·rock. On average, 94.18% of the oil yield (89.53%–96.20%) occurred before reaching 410℃ in the four experiments with different heating rates. Oil yields are low above 440°C (0.25-0.62 kg / ton·rock), with an average of 0.47 kg / ton·rock.

[0185] 2) Evaluation function for cumulative gas generation and evaluation function for cumulative hydrogen sulfide generation in gas.

[0186] (1) This embodiment takes six temperature points of 320℃, 350℃, 380℃, 410℃, 440℃ and 450℃ as examples, such as Figure 15 As shown, the evaluation function for the cumulative generation of in-situ heated gas in the Chang 7 shale under the same temperature and different heating rates is as follows:

[0187] Y gas320 = -0.0046×r+0.5317 Formula 12

[0188] Y gas350 = -0.1106×r+4.3087 Formula 13

[0189] Y gas380 = -0.0390×r+8.5107 Formula 14

[0190] Y gas410 = -0.0170×r+12.737 Formula 15

[0191] Y gas440 = -0.0398×r+16.348 Formula 16

[0192] Y gas450 = -0.04361×r+17.00 Formula 17

[0193] Y in formula 12-17 gasx The cumulative amount of gas generated when shale is heated in situ to temperature x, in kg; r is the heating rate, in °C / d.

[0194] The graph shows the variation of cumulative gas generation during in-situ heating of the Chang 7 shale under the same temperature but different heating rates. Figure 15 As shown.

[0195] (2) Figure 16 As shown, the evaluation function for the cumulative generation of in-situ heated gas in the Chang 7 shale under the same heating rate but different temperature conditions is as follows:

[0196] Y gas2℃ / d =16.79-16.86 / (1+exp((T-383.46) / 19.26)) Formula 18

[0197] Y gas5℃ / d =17.66-17.96 / (1+exp((T-385.41) / 24.27)) Formula 19

[0198] Y gas10℃ / d =17.91-18.32 / (1+exp((T-384.10) / 26.10)) Formula 20

[0199] Y gas20℃ / d =19.63-20.55 / (1+exp((T-387.28) / 32.40)) Formula 21

[0200] Y in formula 18-21 gasw The cumulative amount of gas generated when shale is heated in situ at a heating rate w, expressed in kg; T is the temperature, expressed in °C.

[0201] like Figure 16 As shown, Figure 16 The graph shows the cumulative gas generation of the Chang 7 shale as a function of temperature when heated at different heating rates. Figure 16 The correlation coefficients (R²) of the four regression curves ranged from 0.990 to 0.997, indicating a very high degree of fit.

[0202] (3) The evaluation function for the cumulative generation of in-situ heated gas in the Chang 7 shale under different heating rates and temperatures is as follows:

[0203] Y gas=232436.197-0.042r-270585.244 / (1+exp((T-454001.086) / 251055.053))) Formula 25

[0204] In this formula, Y gas The cumulative amount of gas generated is represented by the heating rate r, which ranges from 2 to 20℃ / day, and the temperature T, which ranges from 320 to 450℃.

[0205] (4) The evaluation function for the cumulative generation of hydrogen sulfide from in-situ heating of the Chang 7 shale under different heating rates and temperatures is as follows:

[0206] Y H2S = -1.514 / (1+EXP((T-365.147) / 16.199))+0.669*LN(r) Formula 22

[0207] Among them, Y H2S is the cumulative amount of hydrogen sulfide generated, in kg; r is the heating rate, in °C / d, ranging from 5 to 20 °C / day; T is the temperature, in °C; LN() is a function of r, ranging from 380 to 450 °C.

[0208] Depend on Figure 15 , Figure 16 It can be seen that for the four experimental sequences with heating rates of 2℃ / day, 5℃ / day, 10℃ / day, and 20℃ / day, the cumulative gas production at the preset maximum simulated temperature slightly increases as the heating rate decreases. According to the heating rate from highest to lowest, the cumulative gas production at the preset maximum simulated temperature of 450℃ for the four heating rates is 17.09 m³ / day. 3 / ton. rock, 16.71m 3 / ton. rock, 16.22m 3 / ton. rock and 15.34m 3 / ton.rock. The cumulative hydrogen sulfide formation was 0.01m³. 3 / ton. rock, 0.98m 3 / ton. rock, 1.58m 3 / ton. rock and 2.08m 3 / ton. rock (not shown in the figure).

[0209] As can be seen from the above examples, when the user's requirement is 40kg of oil production per ton of shale, 15-20m 3 When the total gas volume is [amount], the rock heating temperature range is 400-450℃ (from [other temperature range]). Figure 13 and Figure 15 It can be seen that the heating rate can be selected from 5℃ / d to 20℃ / d (from...). Figure 9 and Figure 10It can be seen that, considering both hydrogen sulfide production and energy consumption, a heating rate of 5℃ / d-10℃ / d can be selected (from...). Figure 16 It can be known that...

[0210] Based on the method for determining the conditions for suppressing hydrogen sulfide formation by in-situ heating of shale as described above, this specification also provides a corresponding device for determining the conditions for suppressing hydrogen sulfide formation by in-situ heating of shale. The device may include a system (including a distributed system), software (application), module, component, server, client, etc., using the method described in the embodiments of this specification, combined with necessary implementation hardware. Based on the same innovative concept, the devices in one or more embodiments provided in this specification are as described in the following embodiments. Since the implementation schemes and methods for solving the problem by the device are similar, the implementation of the specific device in the embodiments of this specification can refer to the implementation of the aforementioned method, and repeated details will not be repeated. As used below, the terms "unit" or "module" can refer to a combination of software and / or hardware that performs a predetermined function. Although the device described in the following embodiments is preferably implemented in software, hardware implementation, or a combination of software and hardware, is also possible and contemplated.

[0211] Specifically, Figure 11 This is a schematic diagram of the module structure of an embodiment of a device for determining conditions for suppressing hydrogen sulfide formation through in-situ heating of shale, as provided in this specification. (Refer to...) Figure 11 As shown in the embodiments of this specification, an apparatus for determining the conditions for inhibiting hydrogen sulfide formation by in-situ heating of shale includes: a characterization quantity determination unit 100, an evaluation information determination unit 200, and a guidance unit 300.

[0212] Characterization unit 100 is used to determine the characterization of each product in the shale in-situ heating simulation experiment based on shale in-situ heating simulation experiment, with temperature and heating rate as control factors respectively. The products include hydrogen sulfide, crude oil and light hydrocarbons.

[0213] The evaluation information determination unit 200 is used to determine the evaluation information of the characterization of each product during the shale in-situ heating simulation experiment under the control factor.

[0214] The guidance unit 300 is used to determine the range of control factors for inhibiting hydrogen sulfide generation based on the evaluation information of each product characterization quantity, so as to guide the in-situ heating of shale using the range of control factors.

[0215] Reference Figure 12As shown, based on the method for determining conditions for suppressing hydrogen sulfide generation through in-situ heating of shale as described above, one embodiment of this specification also provides a computer device 1202, wherein the above method is run on the computer device 1202. The computer device 1202 may include one or more processors 1204, such as one or more central processing units (CPUs) or graphics processing units (GPUs), each processing unit capable of implementing one or more hardware threads. The computer device 1202 may also include any memory 1206 for storing any kind of information such as code, settings, data, etc. In one specific embodiment, a computer program is stored on the memory 1206 and can run on the processor 1204. When the computer program is run by the processor 1204, it can execute instructions according to the above method. Non-limitingly, for example, the memory 1206 may include any type of RAM, any type of ROM, flash memory, hard disk, optical disk, etc. More generally, any memory can use any technology to store information. Furthermore, any memory can provide volatile or non-volatile retention of information. Furthermore, any memory can represent a fixed or removable component of the computer device 1202. In one case, when the processor 1204 executes associated instructions stored in any memory or combination of memories, the computer device 1202 can perform any operation of the associated instructions. The computer device 1202 also includes one or more drive mechanisms 1208 for interacting with any memory, such as a hard disk drive, an optical disk drive, etc.

[0216] Computer device 1202 may further include an input / output module 1210 (I / O) for receiving various inputs (via input device 1212) and providing various outputs (via output device 1214). A specific output mechanism may include a presentation device 1216 and an associated graphical user interface 1218 (GUI). In other embodiments, the input / output module 1210 (I / O), input device 1212, and output device 1214 may be omitted, and the device may function solely as a computer device within a network. Computer device 1202 may also include one or more network interfaces 1220 for exchanging data with other devices via one or more communication links 1222. One or more communication buses 1224 couple the components described above together.

[0217] Communication link 1222 can be implemented in any way, such as via a local area network, a wide area network (e.g., the Internet), a point-to-point connection, or any combination thereof. Communication link 1222 may include any combination of hardwired links, wireless links, routers, gateway functions, name servers, etc., governed by any protocol or combination of protocols.

[0218] Corresponding to Figures 1-7 In addition to the methods described above, embodiments of this specification also provide a computer-readable storage medium storing a computer program that, when executed by a processor, performs the steps of the methods described above.

[0219] This specification also provides computer-readable instructions, wherein when a processor executes the instructions, the program therein causes the processor to perform the following: Figures 1 to 7 The method shown.

[0220] It should be understood that in the various embodiments of this specification, the sequence number of each process does not imply the order of execution. The execution order of each process should be determined by its function and internal logic, and should not constitute any limitation on the implementation process of the embodiments of this specification.

[0221] It should also be understood that, in the embodiments of this specification, the term "and / or" is merely a description of the relationship between related objects, indicating that three relationships can exist. For example, A and / or B can represent: A existing alone, A and B existing simultaneously, and B existing alone. Furthermore, in the embodiments of this specification, the character " / " generally indicates that the preceding and following related objects have an "or" relationship.

[0222] Those skilled in the art will recognize that the units and algorithm steps of the various examples described in conjunction with the embodiments disclosed in this specification can be implemented in electronic hardware, computer software, or a combination of both. To clearly illustrate the interchangeability of hardware and software, the components and steps of each example have been generally described in terms of functionality in the foregoing description. Whether these functions are implemented in hardware or software depends on the specific application and design constraints of the technical solution. Those skilled in the art can use different methods to implement the described functions for each specific application, but such implementations should not be considered beyond the scope of the embodiments in this specification.

[0223] Those skilled in the art will clearly understand that, for the sake of convenience and brevity, the specific working processes of the systems, devices, and units described above can be referred to the corresponding processes in the foregoing method embodiments, and will not be repeated here.

[0224] In the several embodiments provided in this specification, it should be understood that the disclosed systems, apparatuses, and methods can be implemented in other ways. For example, the apparatus embodiments described above are merely illustrative; for instance, the division of units is only a logical functional division, and in actual implementation, there may be other division methods. For example, multiple units or components may be combined or integrated into another system, or some features may be ignored or not executed. Furthermore, the couplings or direct couplings or communication connections shown or discussed may be indirect couplings or communication connections through some interfaces, devices, or units, or they may be electrical, mechanical, or other forms of connection.

[0225] The units described as separate components may or may not be physically separate. The components shown as units may or may not be physical units; that is, they may be located in one place or distributed across multiple network units. Some or all of the units can be selected to achieve the purpose of the embodiments described in this specification, depending on actual needs.

[0226] Furthermore, the functional units in the various embodiments of this specification can be integrated into one processing unit, or each unit can exist physically separately, or two or more units can be integrated into one unit. The integrated unit can be implemented in hardware or as a software functional unit.

[0227] If the integrated unit is implemented as a software functional unit and sold or used as an independent product, it can be stored in a computer-readable storage medium. Based on this understanding, the technical solutions of the embodiments of this specification, in essence, or the parts that contribute to the prior art, or all or part of the technical solutions, can be embodied in the form of a software product. This computer software product is stored in a storage medium and includes several instructions to cause a computer device (which may be a personal computer, server, or network device, etc.) to execute all or part of the steps of the methods described in the various embodiments of this specification. The aforementioned storage medium includes various media capable of storing program code, such as USB flash drives, portable hard drives, read-only memory (ROM), random access memory (RAM), magnetic disks, or optical disks.

[0228] This specification uses specific embodiments to illustrate the principles and implementation methods of the embodiments. The above description of the embodiments is only for the purpose of helping to understand the methods and core ideas of the embodiments in this specification. At the same time, for those skilled in the art, there will be changes in the specific implementation methods and application scope based on the ideas of the embodiments in this specification. Therefore, the content of this specification should not be construed as a limitation on the embodiments in this specification.

Claims

1. A method for determining the conditions for suppressing hydrogen sulfide formation by in-situ heating of shale, characterized in that, include: Multiple shale samples were prepared in advance; Shale samples were subjected to in-situ heating simulation experiments. The heating rates of each shale sample were different, and each sample was heated to multiple preset temperatures at its own heating rate. When each preset temperature was reached, the characterization quantity of each product was determined. Based on the shale in-situ heating simulation experiment, temperature and heating rate were used as control factors to determine the characterization of each product during the shale in-situ heating simulation experiment. Each product includes hydrogen sulfide and oil and gas. Based on the characterization of each product during the shale in-situ heating simulation experiment, the evaluation information of the characterization of each product under the control factor is determined. Based on the evaluation information of each product characterization quantity, the range of control factors for inhibiting hydrogen sulfide formation was determined, so as to guide the in-situ heating of shale using the range of control factors.

2. The method for determining the conditions for inhibiting hydrogen sulfide formation by in-situ heating of shale according to claim 1, characterized in that, The determination of the characterization quantity of each product at each preset temperature further includes: The amount of each product generated at each stage is measured when the temperature is heated to a preset temperature. Calculate the stage concentration, cumulative generation, and / or cumulative concentration of hydrogen sulfide based on the stage generation of hydrogen sulfide. Calculate the cumulative amount of oil and gas generated based on the stage generation of oil and gas. The stage formation and / or cumulative formation of oil and gas are used as the characterization of oil and gas. The stage generation amount, stage concentration, cumulative generation amount, and cumulative concentration of hydrogen sulfide are used as characterization quantities for hydrogen sulfide.

3. The method for determining the conditions for inhibiting hydrogen sulfide formation by in-situ heating of shale according to claim 1, characterized in that, The evaluation information for determining the characterization of each product during shale in-situ heating simulation experiments, based on the characterization of each product, further includes: Each heating to a preset temperature is considered a stage; Based on the characterization of each product in each stage of the shale in-situ heating simulation experiment, with the value of the control factor in each stage as the independent variable and the characterization of each product of shale in-situ heating as the dependent variable, an evaluation function is constructed. The evaluation information of the characterization of each product under in-situ shale heating is determined by the evaluation function corresponding to each product under the control factor.

4. The method for determining the conditions for inhibiting hydrogen sulfide formation by in-situ heating of shale according to claim 1, characterized in that, The evaluation information for determining the characterization of each product during shale in-situ heating simulation experiments, based on the characterization of each product, further includes: Each heating to a preset temperature is considered a stage; Based on the characterization of each product in each stage of the shale in-situ heating simulation experiment, an evaluation chart is drawn with the value of the control factor in each stage as the x-axis and the characterization of each product of shale in-situ heating as the y-axis. The evaluation information of the characterization of each product under in-situ shale heating was determined by the evaluation charts corresponding to each product under the control factor.

5. The method for determining the conditions for inhibiting hydrogen sulfide formation by in-situ heating of shale according to claim 1, characterized in that, The oil and gas include light hydrocarbons, hydrocarbon gases and crude oil. The system used for the in-situ heating simulation experiment includes: heating equipment, crude oil collection and quantitative equipment, light hydrocarbon collection and quantitative equipment, gas collection and quantitative equipment and gas analysis equipment. The heating device is used for in-situ heating of shale samples; Both the crude oil collection and metering device and the light hydrocarbon collection and metering device include: an extraction control device, a collector, and a weighing device; the extraction control device is installed on the collector, the weighing device is installed at the bottom of the collector, the collector of the crude oil collection and metering device is connected to the heating device, and the collector of the light hydrocarbon collection and metering device is connected to the collector of the crude oil collection and metering device. The extraction control device of the crude oil collection and metering device is used to control the collection of crude oil in the collector of the crude oil collection and metering device, and the extraction control device of the light hydrocarbon collection and metering device is used to control the collection of light hydrocarbons in the collector of the light hydrocarbon collection and metering device; The weighing instrument is used to measure the amount of crude oil / light hydrocarbons generated; The gas collection and metering device includes: a vacuum bag and a measuring device; the vacuum bag is connected to the collector of the light hydrocarbon collection and metering device and is used to collect gas; the measuring device is located at the inlet of the vacuum bag and is used to measure the gas volume and the pressure inside the vacuum bag. The gas analysis device is connected to the gas collection and quantification device and is used to analyze the amount of hydrogen sulfide generated. The data obtained by the weighing instrument, measuring equipment, and gas analysis equipment are experimental data.

6. The method for determining the conditions for inhibiting hydrogen sulfide formation by in-situ heating of shale according to claim 5, characterized in that, The extraction control device includes: a ring condenser and a condenser controller; The annular condenser is fitted outside the collector and connected to the condensation controller, and is used to bring the inside of the collector to the condensation temperature for collecting crude oil / light hydrocarbons under the control of the condensation controller.

7. The method for determining the conditions for inhibiting hydrogen sulfide formation by in-situ heating of shale according to claim 5, characterized in that, The system used for the in-situ heating simulation experiment also includes: rinsing equipment and analytical equipment; The flushing device is connected to the connecting pipeline between the heating device and the crude oil collection and metering device. The flushing device is equipped with petroleum flushing fluid for flushing the connecting pipeline. The flushing device is activated after the shale sample is heated to each preset temperature and the crude oil is discharged from the crude oil collection and metering device. The petroleum flushing fluid flows into the connecting pipeline to form a mixture, which enters the collector in the crude oil collection and metering device. The analysis device is connected to the collector in the crude oil collection and metering device and is used to analyze the mixture to determine the amount of crude oil in the connecting pipeline.

8. The method for determining the conditions for inhibiting hydrogen sulfide formation by in-situ heating of shale according to claim 1, characterized in that, The step of determining the range of control factors for inhibiting hydrogen sulfide formation based on the evaluation information of each product characterization quantity, so as to guide the in-situ heating of shale using the range of control factors, further includes: Based on the evaluation information of oil and gas characterization and the needs of extraction, the initial range of control factors is determined; Based on the evaluation information of hydrogen sulfide characterization, the range in which the hydrogen sulfide characterization is less than the predetermined amount is determined from the initial range of the control factor, and the determined range is taken as the final range of the control factor.

9. A device for determining the conditions for suppressing hydrogen sulfide formation by in-situ heating of shale, characterized in that, The device includes: The characterization unit is used to pre-prepare multiple shale samples; conduct in-situ heating simulation experiments on the shale samples, with each shale sample having a different heating rate and being heated to multiple preset temperatures at its own heating rate; and determine the characterization of each product at each preset temperature. Based on the in-situ heating simulation experiments, the characterization of each product during the in-situ heating simulation experiments is determined using temperature and heating rate as control factors, including hydrogen sulfide and oil and gas. The evaluation information determination unit is used to determine the evaluation information of the characterization of each product during the shale in-situ heating simulation experiment under the control factor. The guidance unit is used to determine the range of control factors for inhibiting hydrogen sulfide formation based on the evaluation information of each product characterization quantity, so as to guide the in-situ heating of shale using the range of control factors.

10. A computer device comprising a memory, a processor, and a computer program stored in the memory, characterized in that, When the computer program is run by the processor, it executes the instructions of the method according to any one of claims 1-8.

11. A computer-readable storage medium having a computer program stored thereon, characterized in that, When the computer program is run by the processor of the computer device, it executes the instructions of the method according to any one of claims 1-8.

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