Method and device for determining conditions for inhibiting generation of hydrogen sulfide by in-situ heating of shale

Abstract

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

Description

Technical Field

[0001] The embodiments of this specification relate to the field of oil and gas exploration and development, and in particular, to a method and device for determining conditions for in-situ heating of shale to inhibit the generation of hydrogen sulfide. Background Art

[0002] The development of shale oil and gas includes shale oil and gas naturally formed under geological conditions and shale oil and gas heated in situ. For shale oil resources with heavy oil quality, high viscosity and low gas-oil ratio, it is impossible to achieve large-scale and economical development using existing horizontal wells and volume fracturing technologies. In-situ conversion uses electric heating technology to heat the shale formation (340-400°C), which can quickly crack heavy oil and solid organic matter (kerogen) into light oil and natural gas and produce them through conventional technology. However, thermal simulation experiments on hydrocarbon generation under shale in-situ conversion conditions show that for shales with high sulfur content, while cracking to generate light oil and hydrocarbon gas, a large amount of hydrogen sulfide gas is also produced. Hydrogen sulfide not only causes serious pollution to the environment, but also corrodes pipelines, increases engineering difficulty, and easily causes production safety accidents. Therefore, hydrogen sulfide is the most concerned non-hydrocarbon gas among the gas products of shale in-situ conversion. However, although the development of in-situ heated shale oil and gas pays more attention to oil and gas production and oil and gas characteristics, the hydrogen sulfide produced by in-situ heating of shale is almost not involved.

[0003] A large number of previous studies on hydrogen sulfide gas have focused on hydrogen sulfide gas in oil and gas naturally formed under geological conditions, mainly focusing on the formation mechanism and distribution characteristics of hydrogen sulfide in natural gas. For high hydrogen sulfide natural gas reservoirs, the sources of hydrogen sulfide include biogenic, thermal cracking of sulfur-containing compounds, and thermochemical reduction of sulfates. In the existing technology, there is almost no research on hydrogen sulfide produced during the in-situ conversion of shale to produce oil and gas through later heating.

[0004] Therefore, there is an urgent need for a method to determine the conditions for in-situ heating of shale to inhibit the formation of hydrogen sulfide, so as to provide technical support and basis for selecting a heating procedure with high oil and gas production and low hydrogen sulfide production during in-situ heating to develop shale oil and gas. Summary of the invention

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

[0006] To achieve the above objectives, on the one hand, the embodiments of this specification provide a method for determining conditions for inhibiting hydrogen sulfide generation by in-situ heating of shale, comprising:

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

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

[0009] Based on the evaluation information of each product characterization quantity, the control factor range for inhibiting the formation of hydrogen sulfide is determined, so that the control factor range can be used to guide the in-situ heating of shale.

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

[0011] Pre-prepare multiple shale samples;

[0012] An in-situ shale heating simulation experiment was carried out on shale samples. The heating rates of various shale samples were different, and they were all heated to multiple preset temperatures at their respective heating rates. Each time the shale samples were heated to a preset temperature, the characterization quantity of each product was determined.

[0013] Preferably, each time the heating reaches a preset temperature, determining the characteristic amount of each product further comprises:

[0014] Each time the temperature is heated to a preset temperature, the amount of each product generated is measured;

[0015] Calculate the stage concentration, cumulative generation and / or cumulative concentration of hydrogen sulfide according to the stage generation amount of hydrogen sulfide;

[0016] Calculate the cumulative production of oil and gas based on the stage production of oil and gas;

[0017] The staged generation amount and / or cumulative generation amount of oil and gas is used as the characterization amount of oil and gas;

[0018] At least one of the stage generation amount, stage concentration, cumulative generation amount and cumulative concentration of hydrogen sulfide is used as the characteristic amount of hydrogen sulfide.

[0019] Preferably, the evaluation information of the characteristic quantity of each product of shale in-situ heating under the control factor based on the characteristic quantity of each product in the shale in-situ heating simulation experiment further includes:

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

[0021] Based on the characterization quantity of each product in each stage of the shale in-situ heating simulation experiment, the numerical value of the control factor in each stage is taken as the independent variable, and the characterization quantity of each product of shale in-situ heating is taken as the dependent variable to construct the evaluation function;

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

[0023] Preferably, the evaluation information of the characteristic quantity of each product of shale in-situ heating under the control factor based on the characteristic quantity of each product in the shale in-situ heating simulation experiment further includes:

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

[0025] Based on the characterization quantity of each product in each stage of the shale in-situ heating simulation experiment process, an evaluation chart is drawn with the value of the control factor in each stage as the horizontal axis and the characterization quantity of each product of the shale in-situ heating as the vertical axis;

[0026] The evaluation information of the characteristic quantity of each product of shale in-situ heating under the control factor is determined from the evaluation chart corresponding to each product.

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

[0028] The heating device is used to heat the shale sample in situ;

[0029] The crude oil collection quantitative equipment and the light hydrocarbon collection quantitative equipment both include: an extraction control device, a collector, and a weighing device; the extraction control device is arranged on the collector, the weighing device is arranged at the bottom of the weighing device, the collector of the crude oil collection quantitative equipment is connected to the heating device, and the collector of the light hydrocarbon collection quantitative equipment is connected to the collector of the crude oil collection quantitative equipment;

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

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

[0032] The gas collection and quantitative device comprises: a vacuum air bag and a measuring device; the vacuum air bag is connected to the collector of the light hydrocarbon collection and quantitative device and is used to collect gas; the measuring device is arranged at the inlet of the vacuum air bag and is used to measure the gas volume and the pressure inside the vacuum air bag;

[0033] The gas analysis device is connected to the gas collection and quantitative device for analyzing the amount of hydrogen sulfide generated;

[0034] The data measured by the weighing device, the measuring device and the gas analysis device are experimental data.

[0035] Preferably, the extraction control device comprises: a ring condenser and a condensation controller;

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

[0037] Preferably, the system for the in-situ heating simulation experiment further includes: a flushing device and an analysis device;

[0038] The flushing device is connected to the connecting pipeline between the heating device and the crude oil collection and quantitative device, and the flushing device is provided with petroleum flushing liquid for flushing the connecting pipeline;

[0039] The flushing device is turned on after the shale sample is heated to each preset temperature and the crude oil in the crude oil collecting and quantitative device is discharged, and the petroleum flushing liquid flows into the connecting pipeline to obtain a mixed liquid, and the mixed liquid enters the collector in the crude oil collecting and quantitative device; the analysis device is connected to the collector in the crude oil collecting and quantitative device, and is used to analyze the mixed liquid and determine the amount of crude oil in the connecting pipeline.

[0040] Preferably, the step of determining the range of control factors for inhibiting the generation of hydrogen sulfide based on the evaluation information of the characteristic quantities of each product, and guiding the in-situ heating of shale using the range of control factors further comprises:

[0041] Determine the initial range of control factors based on the evaluation information of oil and gas characterization quantities and production requirements;

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

[0043] On the other hand, an embodiment of this specification provides a device for determining conditions for inhibiting hydrogen sulfide generation by in-situ heating of shale, the device comprising:

[0044] A characterization quantity determination unit is used to determine the characterization quantity of each product in the shale in-situ heating simulation experiment based on the shale in-situ heating simulation experiment, using temperature and heating rate as control factors, wherein each product includes hydrogen sulfide and oil and gas;

[0045] An evaluation information determination unit, used to determine evaluation information of the characterization quantity of each product of shale in-situ heating under a control factor based on the characterization quantity of each product during the shale in-situ heating simulation experiment;

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

[0047] On the other hand, an embodiment of the present specification further provides a computer device, including a memory, a processor, and a computer program stored in the memory, wherein when the computer program is executed by the processor, the instructions according to any one of the methods described above are executed.

[0048] On the other hand, an embodiment of the present specification further provides a computer-readable storage medium having a computer program stored thereon, wherein when the computer program is executed by a processor of a computer device, the computer program executes instructions according to any one of the methods described above.

[0049] It can be seen from the technical solutions provided in the above embodiments of this specification that the embodiments of this specification realize determining the evaluation information of the characterization quantity of each product by measuring the characterization quantity of each product when heated to each temperature at different temperatures and different heating rates; further, determining the range of control factors for inhibiting the formation of hydrogen sulfide based on the evaluation information of the characterization quantity of each product, thereby providing technical support and basis for selecting a heating procedure that can inhibit the production of hydrogen sulfide without affecting the mining needs during the in-situ heating development of shale oil and gas.

[0050] In order to make the above and other purposes, features and advantages of the present specification more obvious and easy to understand, the following specifically cites preferred embodiments and describes them in detail with reference to the accompanying drawings. BRIEF DESCRIPTION OF THE DRAWINGS

[0051] In order to more clearly illustrate the embodiments of this specification or the technical solutions in the prior art, the drawings required for use in the embodiments or the description of the prior art will be briefly introduced below. Obviously, the drawings described below are only some embodiments of this specification. For ordinary technicians in this field, other drawings can be obtained based on these drawings without paying creative work.

[0052] Figure 1 A schematic flow chart of a method for determining conditions for inhibiting hydrogen sulfide generation by in-situ heating of shale provided in an embodiment of this specification is shown;

[0053] Figure 2 A schematic flow chart of a method for determining the characteristic amount of each product during a shale in-situ heating simulation experiment provided in an embodiment of this specification is shown;

[0054] Figure 3 A schematic diagram of a shale in-situ heating simulation experimental device provided in an embodiment of this specification is shown;

[0055] Figure 4A schematic diagram of a process for measuring the characteristic quantity of each product when heated to a preset temperature provided in the embodiments of this specification is shown;

[0056] Figure 5 A schematic diagram of a process for determining evaluation information of the characteristic quantity of each product of shale in-situ heating under control factors based on the characteristic quantity of each product in the shale in-situ heating simulation experiment provided in an embodiment of this specification is shown;

[0057] Figure 6 Another schematic diagram of a process for determining evaluation information of the characteristic quantity of each product of shale in-situ heating under control factors based on the characteristic quantity of each product in the shale in-situ heating simulation experiment provided in an embodiment of this specification is shown;

[0058] Figure 7 A schematic diagram of a process for determining a control factor range for inhibiting hydrogen sulfide generation based on evaluation information of each product characteristic quantity provided in an embodiment of this specification, so as to guide in-situ heating of shale using the control factor range;

[0059] Figure 8 A graph showing the variation of the stage generation amount of hydrogen sulfide gas with temperature in an in-situ heating experiment corresponding to a heating rate of 20°C / day, 10°C / day, 5°C / day and 2°C / day provided in an embodiment of this specification;

[0060] Fig. 9 A graph showing the change in stage concentration of hydrogen sulfide gas with temperature in an in-situ heating experiment corresponding to a heating rate of 20°C / day, 10°C / day, 5°C / day and 2°C / day provided in an embodiment of this specification is shown;

[0061] Fig.10 A graph showing the change in cumulative concentration of hydrogen sulfide gas with temperature in an in-situ heating experiment corresponding to a heating rate of 20°C / day, 10°C / day, 5°C / day and 2°C / day provided in an embodiment of this specification;

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

[0063] Fig.12 A schematic diagram showing the structure of a computer device provided in an embodiment of this specification is shown;

[0064] Fig.13 The cumulative oil production variation diagram of the in-situ heating of Chang 7 shale under the same temperature and different heating rates is shown in the embodiment of this specification;

[0065] Fig.14 The cumulative oil production variation diagram of the in-situ heating of Chang 7 shale under the same heating rate and different temperature conditions is shown in the embodiment of this specification;

[0066] Fig.15 The graph showing the cumulative amount of gas generated by in-situ heating of Chang 7 shale under the same temperature and different heating rates in the embodiment of this specification is shown;

[0067] Fig.16 The graph shows the change in the cumulative amount of gas generated by in-situ heating of Chang 7 shale under the same heating rate and different temperature conditions in the embodiment of this specification.

[0068] Description of the accompanying symbols:

[0069] 21. Heating equipment;

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

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

[0072] 24. Gas collection and quantitative equipment;

[0073] 25. Gas analysis equipment;

[0074] 221. Extraction control equipment;

[0075] 222. Collector;

[0076] 223. Weighing device;

[0077] 231. Extraction control equipment;

[0078] 232. Collector;

[0079] 233. Weighing device;

[0080] 2211, condensation controller;

[0081] 2212, annular condensing device;

[0082] 2311, condensation controller;

[0083] 2312, annular condensation device;

[0084] 241. Gas collection tank;

[0085] 242. Measuring equipment;

[0086] 243. Vacuum pump;

[0087] 2421, gas flow meter;

[0088] 2422, pressure gauge;

[0089] 100. Characterization 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, driving mechanism;

[0096] 1210, input / output module;

[0097] 1212. Input device;

[0098] 1214. Output device;

[0099] 1216. Presentation equipment;

[0100] 1218. Graphical user interface;

[0101] 1220, network interface;

[0102] 1222, communication link;

[0103] 1224. Communication bus. DETAILED DESCRIPTION

[0104] The following will be combined with the drawings in the embodiments of this specification to clearly and completely describe the technical solutions in the embodiments of this specification. Obviously, the described embodiments are only part of the embodiments of this specification, not all of the embodiments. Based on the embodiments in this specification, all other embodiments obtained by ordinary technicians in this field without creative work are within the scope of protection of the embodiments of this specification.

[0105] Figure 1 This is a flow chart of a method for determining conditions for in-situ heating of shale to inhibit the formation of hydrogen sulfide, provided in an embodiment of this specification. This specification provides method operation steps as described in the embodiment or flow chart, but may include more or fewer operation steps based on conventional or non-creative labor. The order of steps listed in the embodiment is only one way of executing the order of many steps and does not represent the only order of execution. When the system or device product is executed in practice, it can be executed in the order of the method shown in the embodiment or the drawings or in parallel.

[0106] It should be noted that the terms "first", "second", etc. in the description and claims of the embodiments of this specification and the above-mentioned drawings are used to distinguish similar objects, and are not necessarily used to describe a specific order or sequence. It should be understood that the data used in this way can be interchanged where appropriate, so that the embodiments of this specification described herein can be implemented in an order other than those illustrated or described herein. In addition, the terms "including" and "having" and any variations thereof are intended to cover non-exclusive inclusions, for example, a process, method, device, product or equipment that includes a series of steps or units is not necessarily limited to those steps or units clearly listed, but may include other steps or units that are not clearly listed or inherent to these processes, methods, products or equipment.

[0107] Reference Figure 1 The present specification provides a method for determining conditions for inhibiting hydrogen sulfide generation by in-situ heating of shale, comprising:

[0108] S101: Based on the shale in-situ heating simulation experiment, the temperature and the heating rate are used as control factors to determine the characterization quantity of each product in the shale in-situ heating simulation experiment, wherein each product includes hydrogen sulfide and oil and gas;

[0109] S102: based on the characterization quantity of each product in the shale in-situ heating simulation experiment, determining evaluation information of the characterization quantity of each product of shale in-situ heating under the control factor;

[0110] S103: Determine a control factor range for inhibiting hydrogen sulfide generation based on evaluation information of each product characterization quantity, so as to guide in-situ heating of shale using the control factor range.

[0111] In the embodiment of this specification, through S101 to S102, the characterization quantity of each product when heated to each temperature at different temperatures and different heating rates can be used to determine the evaluation information of the characterization quantity of each product. Further, through S103, the control factor range for inhibiting the generation of hydrogen sulfide can be determined, providing technical support and basis for selecting a heating procedure that can inhibit the production of hydrogen sulfide without affecting the production demand during the in-situ heating process for shale oil and gas development.

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

[0113] S201: Pre-prepare a plurality of shale samples;

[0114] S202: Performing an in-situ heating simulation experiment on the shale samples, wherein the heating rates of the shale samples are different, and the shale samples are heated to a plurality of preset temperatures at their respective heating rates, and determining the characterization quantity of each product each time the shale samples are heated to a preset temperature.

[0115] In the specific implementation, multiple shale samples of the same quality are selected, and the treated shale samples are first loaded into a special reactor body that is resistant to acid and hydrogen sulfide corrosion, and then heated. The heating process of the shale samples can be controlled by a computer. During the heating simulation experiment, a reactor with heating rate and temperature control functions can be used for the experiment, and a collection and quantitative equipment is set for each product to achieve the measurement of the generation of each product and the amount of each product that can be produced. The heating rate of each shale sample is different, and it is heated to the preset temperature at each set heating rate, so as to obtain the characterization amount of each product generated and produced when the preset heating rate is heated to each preset temperature.

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

[0117] In one embodiment, the heating simulation experiment is performed using a device such as Figure 3 As shown, it includes: a heating device 21, a crude oil collection and quantitative device 22, a light hydrocarbon collection and quantitative device 23, a gas collection and quantitative device 24 and a gas analysis device 25.

[0118] The heating device 21 is used to heat the rock sample in situ. Specifically, the heating device 21 includes a reactor, a temperature controller, and a temperature sensor. The reactor is used to accommodate the rock sample. The temperature sensor is arranged inside the reactor to measure the temperature inside the reactor. The temperature controller can adjust the heating rate to control the temperature inside the reactor to reach a predetermined temperature.

[0119] The crude oil collection quantitative device 22 includes: an extraction control device 221, a collector 222, and a weighing device 223. The extraction control device 221 is arranged on the collector 222, and is used to control the temperature in the collector 222 so that the collector 222 reaches the crude oil condensation temperature. The weighing device 223 is arranged 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 a 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, and the annular condensation device 2212 is sleeved on 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 arranged on the collector 232, and is used to control the temperature in the collector 232 so that the light hydrocarbon condensation temperature is reached in the collector 232. The weighing device 233 is arranged 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 a 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, and the annular condensation device 2312 is sleeved on the outside of the collector 232, and is used to control the solidification of light hydrocarbons in the condenser.

[0121] The gas collection quantitative device 24 includes: a vacuum air bag 241, a measuring device 242, and a vacuum pump 243. The vacuum air bag 241 is connected to the collector 232 and is used to collect gas, including hydrocarbon gas and hydrogen sulfide. The measuring device 242 is arranged at the entrance of the vacuum air bag and is used to measure the gas volume and the pressure inside the vacuum air 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 air bag; the vacuum pump is used to evacuate the vacuum air bag before gas collection.

[0122] The gas analysis device 25 is connected to the gas collection and quantitative device 24 for analyzing the amount of hydrogen sulfide generated. In some embodiments, the gas analysis device 25 uses a Wasson-Agilent 7890 gas chromatograph. Specifically, the gas chromatograph contains a flame ionization detector and two thermal conductivity detectors, and one analysis can detect hydrogen sulfide in the gas. In addition, the gas volume can be measured by the whole air bag drainage method.

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

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

[0125] In specific implementation, the distance between the annular condenser and the collector in the crude oil quantitative collection equipment and the light hydrocarbon collection equipment is 2-3 mm. Through this setting, the product in the collector can be condensed without affecting the real-time weighing of crude oil and light hydrocarbons.

[0126] The collector in the crude oil collection quantitative equipment 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 quantitative equipment, which leads to Figure 3 The system shown cannot accurately measure the amount of crude oil. Taking this into consideration, in one embodiment of the present invention, the system used for the in-situ heating simulation experiment also includes: a flushing device and an analysis device.

[0127] The flushing device is connected to the connecting pipeline between the heating device and the crude oil collection and quantitative device, and a petroleum flushing liquid is provided in the flushing device for flushing the connecting pipeline. In some embodiments, the petroleum flushing liquid is selected from dichloromethane.

[0128] The flushing device is turned on after the shale sample is heated to each preset temperature and the crude oil in the crude oil collecting and quantitative device is discharged, and the petroleum flushing liquid flows into the connecting pipeline to obtain a mixed liquid, and the mixed liquid enters the collector in the crude oil collecting and quantitative device.

[0129] The analysis device is connected to the collector in the crude oil collection and quantitative device, and is used to receive the mixed liquid in the collector and analyze the mixed liquid to determine the amount of crude oil in the connecting pipeline. During implementation, the mixed liquid in the collector can also be placed in the analysis device manually. The analysis device uses the internal standard method to calibrate the crude oil content in the mixed liquid. Specifically, the internal standard is C 24 H 49 D. The analytical equipment determines the amount of crude oil by comparing the areas of all peaks in the chromatogram of the mixed liquid with the area of ​​the internal standard.

[0130] In a specific embodiment, the preset temperature can be: 270°C, 320°C, 350°C, 380°C, 410°C, 440°C, 450°C. Four Chang 7 shale samples were prepared, and the corresponding heating rates were 20°C / day, 10°C / day, 5°C / day and 2°C / day, respectively. The sample heating procedure is: first, the four shale samples are heated from room temperature (20°C) to 270°C in 3 days, and then the simulation experiments are carried out according to the above four heating rates. The four shale samples are heated to the above multiple preset temperatures at their respective heating rates, where the highest preset temperature is 450°C. For each shale sample, each time it is heated to a preset temperature, the characterization quantity of each product is measured once.

[0131] In the shale in-situ heating simulation experiment, reference Figure 4 , each time the heating reaches a preset temperature, determining the characteristic amount of each product, further comprising:

[0132] S301: When heating to a preset temperature, measuring the stage production amount of each product;

[0133] S302: Calculating the stage concentration, cumulative generation amount and / or cumulative concentration of hydrogen sulfide according to the stage generation amount of hydrogen sulfide;

[0134] S303: Calculating the cumulative generation of oil and gas according to the stage generation of oil and gas;

[0135] S304: taking the staged generation amount and / or cumulative generation amount of oil and gas as the characterization amount of oil and gas;

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

[0137] For example, the generation of hydrogen sulfide gas at each stage in the in-situ heating experiment under the condition of a heating rate of 20°C / day is as follows: at 270°C, the generation of hydrogen sulfide is 0; at 320°C, the generation of hydrogen sulfide is 0.06m 3 / t shale; at 350℃, the amount of hydrogen sulfide produced is 0.38m 3 / t shale; at 380℃, the amount of hydrogen sulfide produced is 0.77m 3 / t shale; at 410℃, the amount of hydrogen sulfide produced is 0.63m 3 / t shale; at 440℃, the amount of hydrogen sulfide produced is 0.24m 3 / t shale; at 450℃, the amount of hydrogen sulfide generated is 0. Similarly, the amount of oil and gas generated in each stage under the condition of a heating rate of 20℃ / day can be obtained.

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

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

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

[0141] According to the stage generation amount of hydrogen sulfide, the stage concentration, cumulative generation amount and / or cumulative concentration of hydrogen sulfide can be further calculated, wherein the stage concentration is the concentration of hydrogen sulfide generated in each stage, the cumulative generation amount is the gas amount of hydrogen sulfide generated in the current stage and all previous stages, and the cumulative concentration is the concentration of hydrogen sulfide generated in the current stage and all previous stages. According to the stage generation amount of oil and gas, the cumulative generation amount of oil and gas can be further calculated, and the cumulative generation amount is the generation amount of oil and gas generated in the current stage and all previous stages.

[0142] In the embodiments of this specification, refer to Figure 5 The evaluation information of the characterization quantity of each product of shale in-situ heating under the control factor based on the characterization quantity of each product in the shale in-situ heating simulation experiment further includes:

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

[0144] S402: Based on the characterization quantity of each product in each stage of the shale in-situ heating simulation experiment process, the value of the control factor in each stage is used as an independent variable, and the characterization quantity of each product of the shale in-situ heating is used as a dependent variable to construct an evaluation function;

[0145] S403: Determine evaluation information of each product characterization quantity of shale in-situ heating under control factors based on the evaluation function corresponding to each product.

[0146] The evaluation information may be an evaluation function. Taking the evaluation function corresponding to hydrogen sulfide as an example, there are four different heating rates corresponding to 20°C / day, 10°C / day, 5°C / day and 2°C / 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 the characterization quantity of hydrogen sulfide, such as the cumulative concentration of hydrogen sulfide. Since the cumulative concentrations of hydrogen sulfide corresponding to the preset temperatures of 270°C, 320°C, 350°C, 380°C, 410°C, 440°C and 450°C have been obtained through in-situ heating experiments, the evaluation function corresponding to hydrogen sulfide can be fitted. Oil and gas include light hydrocarbons, crude oil and hydrocarbon gas. Light hydrocarbons belong to light oil, crude oil belongs to heavy oil, and both light hydrocarbons and crude oil belong to oil. The evaluation function corresponding to crude oil / light hydrocarbons and the evaluation function corresponding to hydrocarbon gas can also be obtained through the above method.

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

[0148] In the embodiments of this specification, refer to Figure 6 The evaluation information of the characterization quantity of each product of shale in-situ heating under the control factor based on the characterization quantity of each product in the shale in-situ heating simulation experiment further includes:

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

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

[0151] S503: Determine evaluation information of the characteristic quantity of each product of shale in-situ heating under the control factor from the evaluation chart corresponding to each product.

[0152] The evaluation information may be an evaluation chart. Taking the evaluation function corresponding to hydrogen sulfide as an example, there are four different heating rates corresponding to 20°C / day, 10°C / day, 5°C / day and 2°C / day. Each heating rate corresponds to an evaluation chart. The horizontal axis of the evaluation chart is the temperature corresponding to each stage, and the vertical axis is the characterization amount of hydrogen sulfide, such as the cumulative concentration of hydrogen sulfide. Since the cumulative concentrations of hydrogen sulfide corresponding to the preset temperatures of 270°C, 320°C, 350°C, 380°C, 410°C, 440°C and 450°C have been obtained through in-situ heating experiments, an evaluation chart can be drawn. The above method can also be used to obtain evaluation charts corresponding to crude oil / light hydrocarbons and evaluation charts corresponding to hydrocarbon gases.

[0153] In addition, each preset temperature may correspond to an evaluation chart, in which the horizontal axis is the heating rate corresponding to each preset temperature, and the vertical axis is the characteristic quantity of each product.

[0154] Whether it is the above evaluation function or evaluation chart, the control factor range for inhibiting the formation of hydrogen sulfide can be determined. For details, refer to Figure 7 The step of determining the control factor range for inhibiting hydrogen sulfide generation based on the evaluation information of each product characteristic quantity, and using the control factor range to guide shale in-situ heating further includes:

[0155] S601: Determine the initial range of the control factor based on the evaluation information of the oil and gas characterization quantity and the production demand;

[0156] S602: According to the evaluation information of the hydrogen sulfide characterization amount, determine, from the initial range of the control factor, a range in which the hydrogen sulfide characterization amount is less than a predetermined amount, and use the determined range as the final range of the control factor.

[0157] Generally speaking, in order to ensure the normal exploitation of oil and gas, a reasonable temperature and heating rate need to be maintained during the in-situ heating of shale, so that a certain oil and gas production can be achieved under this temperature and heating rate. 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] On this basis, the range in which the hydrogen sulfide characterization amount is less than the predetermined amount is determined. The predetermined amount can be determined according to the actual working conditions, with the aim of maintaining a low hydrogen sulfide output, thereby determining the final range of the temperature and the heating rate within the initial range of the temperature and the heating rate.

[0159] Figure 8-Figure 10 The graphs of the stage generation, stage concentration and cumulative concentration of hydrogen sulfide gas in the in-situ heating experiment corresponding to the four heating rates of 20℃ / day, 10℃ / day, 5℃ / day and 2℃ / day respectively are as follows. The stage generation, stage concentration and cumulative concentration of hydrogen sulfide in the gas products produced by the in-situ heating experiment at a heating rate of 20℃ / day are the highest, followed by 10℃ / day, 5℃ / day, and 2℃ / day is the lowest.

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

[0161] Reference Fig. 9As shown in Figure 10, the H2S stage concentration has the same characteristics as the stage generation amount, showing a trend of first high and then low as the temperature rises. The temperature range corresponding to the highest peak is 350℃-380℃, and the stage concentration can reach up to 20%. As shown in Figure 10, the cumulative concentration of hydrogen sulfide increases rapidly before 350℃-380℃, reaches a peak in the temperature range of 350℃-380℃, and then slowly decreases as the temperature rises, and the cumulative concentration can reach up to 18.33%.

[0162] The evaluation function is described in detail through the following specific examples. Four Chang 7 shale samples are set, and the heating rates of each shale sample are 2°C / day, 5°C / day, 10°C / day and 20°C / day. All shale samples are preheated from room temperature (20°C) to 270°C in 3 days, and 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°C. In this embodiment, the preset temperature includes five temperature points of 320°C, 350°C, 380°C, 410°C, 440°C and 450°C.

[0163] According to the experimental data, the cumulative production of each product of the Chang 7 shale sample at each preset heating rate and each preset temperature (the cumulative production of each output per ton of shale in situ heating) is calculated. According to the cumulative production of each product at each preset heating rate and each preset temperature, the following evaluation functions corresponding to each product of the Chang 7 shale in situ heating are fitted respectively:

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

[0165] (1) Fig.13 As shown in the figure, the evaluation function corresponding to the cumulative oil generation in the in-situ heating of 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 is the cumulative amount of oil produced when shale is heated in situ to temperature x, in kg; r is the heating rate, in ℃ / d.

[0173] The cumulative production of oil in situ heated Chang 7 shale under the same temperature and different heating rates is shown in the figure below. Figure 4 The correlation coefficients (R 2 ) ranges from 0.790 to 0.987.

[0174] (2) Fig.14 As shown in the figure, the evaluation function corresponding to the cumulative oil generation in the in-situ heating of Chang 7 shale under the same heating rate and 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 It is the cumulative amount of oil produced when shale is heated in situ at a heating rate of w, in kg; T is the temperature, in ℃.

[0180] like Fig.14 As shown in the figure, the experimental data of the cumulative oil production of Chang 73 shale heated to different temperatures are compared with the fitting data. The fitting degree of the two is very high. The correlation coefficients (R 2 ) ranges from 0.996 to 0.998.

[0181] (3) The evaluation function corresponding to the cumulative oil generation of Chang 7 shale under different heating rates and temperature conditions 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 is the cumulative amount of oil produced, the heating rate r ranges from 2 to 20 °C / day, and the temperature T ranges from 320 to 450 °C.

[0184] Depend on Fig.13 and Fig.14 It can be seen that the maximum oil output of the in-situ heating simulation experiments with different heating rates is roughly in the range of 41.07-43.94 kg / ton. rock. In the four in-situ heating simulation experiments with different heating rates, almost no oil was produced before 300°C. The maximum oil output of the heating rates of 2°C / day, 5°C / day and 10°C / day was between 350°C and 380°C, and the maximum oil outputs were 20.30 kg / ton. rock, 20.93 kg / ton. rock and 20.69 kg / ton. rock respectively; the maximum oil output of 20°C / day was between 380°C and 410°C, and the maximum oil output was 22.77 kg / ton. rock. In the four experiments with different heating rates, an average of 94.18% of the oil output (89.53%-96.20%) was before 410°C. The oil output above 440℃ is low (0.25-0.62 kg / ton.rock), with an average of 0.47 kg / ton.rock.

[0185] 2) Evaluation function of the cumulative generation of gas and the cumulative generation of hydrogen sulfide in the gas.

[0186] (1) This embodiment takes six temperature points of 320°C, 350°C, 380°C, 410°C, 440°C and 450°C as examples. Fig.15 As shown in the figure, the evaluation function of the cumulative gas generation from in-situ heating of 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 is 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 cumulative amount of gas generated by in-situ heating of Chang 7 shale under the same temperature and different heating rates is shown in the figure below. Fig.15 shown.

[0195] (2) Fig.16 As shown in the figure, the evaluation function of the cumulative gas generation from in-situ heating of Chang 7 shale under the same heating rate and 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 It is the cumulative amount of gas generated when the shale is heated in situ at a heating rate w, in kg; T is the temperature, in ℃.

[0201] like Fig.16 As shown, Fig.16 The graph shows the variation of cumulative gas production with temperature when Chang 7 shale is heated at different heating rates. Fig.16 The correlation coefficient R2 of the four regression curves ranges from 0.990 to 0.997, and the fit is very high.

[0202] (3) The evaluation function of the cumulative gas generation from in-situ heating of 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 is the cumulative amount of gas generated, the heating rate r ranges from 2 to 20 °C / day, and the temperature T ranges from 320 to 450 °C.

[0205] (4) The evaluation function of the cumulative generation of hydrogen sulfide during in-situ heating of 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 ℃ / d, and the value range is 5-20℃ / day; T is the temperature, in ℃, and LN() is a function of r, with a value range of 380-450℃.

[0208] Depend on Fig.15 , Fig.16 It can be seen that the cumulative gas generation at the preset maximum simulation temperature of the four sequential experiments with heating rates of 2℃ / day, 5℃ / day, 10℃ / day and 20℃ / day increases slightly with the decrease of heating rate. According to the heating rate from high to low, the cumulative gas generation at the preset maximum simulation temperature of 450℃ of the four heating rates is 17.09m 3 / ton. rock, 16.71m 3 / ton. rock, 16.22m 3 / tons. rock and 15.34m 3 / ton. rock. The cumulative amount of hydrogen sulfide produced is 0.01m 3 / ton. Rock, 0.98m 3 / ton. Rock, 1.58m 3 / ton. rock and 2.08m 3 / ton. rock (not shown).

[0209] From the above example, it can be seen that when the user demand is to produce 40kg oil from 1t shale, 15-20m 3 When the total gas volume is used, the rock heating temperature ranges from 400 to 450°C (by Fig.13 and Fig.15 It can be seen that the heating rate can be selected from 5℃ / d to 20℃ / d (by Fig. 9 and Fig.10It can be seen that, considering the hydrogen sulfide production and energy consumption, the heating rate can be selected to be 5℃ / d-10℃ / d (by Fig.16 can be known).

[0210] Based on the above-mentioned method for determining the conditions for inhibiting the formation of hydrogen sulfide by in-situ heating of shale, the embodiments of this specification also provide a device for determining the conditions for inhibiting the formation of hydrogen sulfide 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 and a device combined with necessary implementation hardware. Based on the same innovative concept, the device in one or more embodiments provided in the embodiments of this specification is as described in the following embodiments. Since the implementation scheme and method of the device to solve the problem are similar, the implementation of the specific device in the embodiments of this specification can refer to the implementation of the aforementioned method, and the repetitions will not be repeated. As used below, the term "unit" or "module" can implement a combination of software and / or hardware for predetermined functions. Although the device described in the following embodiments is preferably implemented in software, the implementation of hardware, or a combination of software and hardware, is also possible and conceived.

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

[0212] The characterization quantity determination unit 100 is used to determine the characterization quantity of each product in the shale in-situ heating simulation experiment based on the shale in-situ heating simulation experiment, using temperature and heating rate as control factors, wherein each product includes hydrogen sulfide, crude oil and light hydrocarbons;

[0213] An evaluation information determination unit 200 is used to determine evaluation information of the characteristic quantities of each product of shale in-situ heating under control factors based on the characteristic quantities of each product during the shale in-situ heating simulation experiment;

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

[0215] Reference Fig.12As shown, based on the above-mentioned method for determining the conditions for inhibiting the generation of hydrogen sulfide by in-situ heating of shale, a computer device 1202 is also provided in one embodiment of this specification, wherein the above-mentioned 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), and each processing unit may implement one or more hardware threads. The computer device 1202 may also include any memory 1206, which is used to store any kind of information such as code, settings, data, etc. In a specific embodiment, the computer program on the memory 1206 and which can be run on the processor 1204, when the computer program is run by the processor 1204, can execute instructions according to the above-mentioned method. Non-limitingly, for example, the memory 1206 may include any one or more combinations of the following: any type of RAM, any type of ROM, flash memory device, hard disk, optical disk, etc. More generally, any memory may use any technology to store information. Further, any memory may provide volatile or non-volatile retention of information. Further, any memory may represent a fixed or removable component of the computer device 1202. In one case, when the processor 1204 executes the 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 mechanism, an optical disk drive mechanism, etc.

[0216] The computer device 1202 may also include an input / output module 1210 (I / O) for receiving various inputs (via input devices 1212) and for providing various outputs (via output devices 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 not be included, and the computer device 1202 may be used as a computer device in a network. The 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] The communication link 1222 may be implemented in any manner, for example, through a local area network, a wide area network (e.g., the Internet), a point-to-point connection, etc., or any combination thereof. The 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] Corresponds to Figure 1-Figure 7 The method in the embodiment of the present specification also provides a computer-readable storage medium, on which a computer program is stored, and when the computer program is executed by a processor, the steps of the above method are executed.

[0219] The embodiment of the present specification also provides a computer-readable instruction, wherein when the processor executes the instruction, the program therein causes the processor to execute the following Figures 1 to 7 The method shown.

[0220] It should be understood that in the various embodiments of this specification, the size of the serial numbers of the above-mentioned processes does not mean 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 only a description of the association relationship of the associated objects, indicating that three relationships can exist. For example, A and / or B can represent: A exists alone, A and B exist at the same time, and B exists alone. In addition, the character " / " in the embodiments of this specification generally indicates that the associated objects before and after are in an "or" relationship.

[0222] Those of ordinary skill in the art will appreciate that the units and algorithm steps of each example described in conjunction with the embodiments disclosed in the embodiments of this specification can be implemented with electronic hardware, computer software, or a combination of the two. In order to clearly illustrate the interchangeability of hardware and software, the composition and steps of each example have been generally described in terms of function in the above description. Whether these functions are performed in hardware or software depends on the specific application and design constraints of the technical solution. Professional and technical personnel can use different methods to implement the described functions for each specific application, but such implementation should not be considered to exceed the scope of the embodiments of this specification.

[0223] Those skilled in the art can clearly understand that, for the convenience and brevity of description, the specific working processes of the systems, devices and units described above can refer to the corresponding processes in the aforementioned 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, devices and methods can be implemented in other ways. For example, the device embodiments described above are only schematic. For example, the division of the units is only a logical function division. There may be other division methods in actual implementation, such as multiple units or components can be combined or integrated into another system, or some features can be ignored or not executed. In addition, the mutual coupling or direct coupling or communication connection shown or discussed can be an indirect coupling or communication connection through some interfaces, devices or units, or it can be an electrical, mechanical or other form of connection.

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

[0226] In addition, each functional unit in each embodiment of this specification may be integrated into one processing unit, or each unit may exist physically separately, or two or more units may be integrated into one unit. The above integrated unit may be implemented in the form of hardware or in the form of software functional units.

[0227] If the integrated unit is implemented in the form of 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 solution of the embodiment of this specification is essentially or the part that contributes to the prior art, or all or part of the technical solution can be embodied in the form of a software product, and the computer software product is stored in a storage medium, including a number of instructions to enable a computer device (which can be a personal computer, a server, or a network device, etc.) to perform all or part of the steps of the method described in each embodiment of this specification. The aforementioned storage medium includes: U disk, mobile hard disk, read-only memory (ROM, Read-Only Memory), random access memory (RAM, Random Access Memory), disk or optical disk and other media that can store program code.

[0228] Specific embodiments are used in this specification to illustrate the principles and implementation methods of the embodiments of this specification. The description of the above embodiments is only used to help understand the methods and core ideas of the embodiments of this specification. At the same time, for those skilled in the art, according to the ideas of the embodiments of this specification, there will be changes in the specific implementation methods and application scopes. In summary, the content of this specification should not be understood as a limitation on the embodiments of this specification.

Claims

1. A method for determining conditions for inhibiting hydrogen sulfide generation by in-situ heating of shale, characterized in that: include: Based on the shale in-situ heating simulation experiment, the temperature and heating rate are used as control factors to determine the characterization quantity of each product in the shale in-situ heating simulation experiment, where each product includes hydrogen sulfide and oil and gas; Based on the characterization quantity of each product in the shale in-situ heating simulation experiment, the evaluation information of the characterization quantity of each product of shale in-situ heating under the control factor is determined; Based on the evaluation information of each product characterization quantity, the control factor range for inhibiting the formation of hydrogen sulfide is determined, so that the control factor range can be used to guide the in-situ heating of shale.

2. The method for determining conditions for inhibiting hydrogen sulfide generation by in-situ heating of shale according to claim 1, characterized in that: The method for determining the characterization amount of each product during the shale in-situ heating simulation experiment includes: Pre-prepare multiple shale samples; An in-situ shale heating simulation experiment was carried out on shale samples. The heating rates of various shale samples were different, and they were all heated to multiple preset temperatures at their respective heating rates. Each time the shale samples were heated to a preset temperature, the characterization quantity of each product was determined.

3. The method for determining conditions for inhibiting hydrogen sulfide generation by in-situ heating of shale according to claim 2, characterized in that: Each time the heating reaches a preset temperature, determining the characteristic amount of each product further comprises: Each time the temperature is heated to a preset temperature, the amount of each product generated is measured; Calculate the stage concentration, cumulative generation and / or cumulative concentration of hydrogen sulfide according to the stage generation amount of hydrogen sulfide; Calculate the cumulative production of oil and gas based on the stage production of oil and gas; The staged generation amount and / or cumulative generation amount of oil and gas is used as the characterization amount of oil and gas; At least one of the stage generation amount, stage concentration, cumulative generation amount and cumulative concentration of hydrogen sulfide is used as the characteristic amount of hydrogen sulfide.

4. The method for determining conditions for inhibiting hydrogen sulfide generation by in-situ heating of shale according to claim 2, characterized in that: The evaluation information of the characteristic quantity of each product of shale in-situ heating under the control factor based on the characteristic quantity of each product in the shale in-situ heating simulation experiment further includes: Each heating to a preset temperature is regarded as a stage; Based on the characterization quantity of each product in each stage of the shale in-situ heating simulation experiment, the numerical value of the control factor in each stage is taken as the independent variable, and the characterization quantity of each product of shale in-situ heating is taken as the dependent variable to construct the evaluation function; The evaluation information of the characterization quantity of each product of shale in-situ heating under the control factor is determined by the evaluation function corresponding to each product.

5. The method for determining conditions for inhibiting hydrogen sulfide generation by in-situ heating of shale according to claim 2, characterized in that: The evaluation information of the characteristic quantity of each product of shale in-situ heating under the control factor based on the characteristic quantity of each product in the shale in-situ heating simulation experiment further includes: Each heating to a preset temperature is regarded as a stage; Based on the characterization quantity of each product in each stage of the shale in-situ heating simulation experiment process, an evaluation chart is drawn with the value of the control factor in each stage as the horizontal axis and the characterization quantity of each product of the shale in-situ heating as the vertical axis; The evaluation information of the characteristic quantity of each product of shale in-situ heating under the control factor is determined from the evaluation chart corresponding to each product.

6. The method for determining conditions for inhibiting hydrogen sulfide generation by in-situ heating of shale according to claim 2, characterized in that: The oil and gas include light hydrocarbons, hydrocarbon gas 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 to heat the shale sample in situ; The crude oil collection quantitative equipment and the light hydrocarbon collection quantitative equipment both include: an extraction control device, a collector, and a weighing device; the extraction control device is arranged on the collector, the weighing device is arranged at the bottom of the weighing device, the collector of the crude oil collection quantitative equipment is connected to the heating device, and the collector of the light hydrocarbon collection quantitative equipment is connected to the collector of the crude oil collection quantitative equipment; The extraction control device of the crude oil collection quantitative device is used to control the crude oil to be collected in the collector of the crude oil collection quantitative device, and the extraction control device of the light hydrocarbon collection quantitative device is used to control the light hydrocarbon to be collected in the collector of the light hydrocarbon collection quantitative device; The weighing device is used to measure the amount of crude oil / light hydrocarbons produced; The gas collection and quantitative device comprises: a vacuum air bag and a measuring device; the vacuum air bag is connected to the collector of the light hydrocarbon collection and quantitative device and is used to collect gas; the measuring device is arranged at the inlet of the vacuum air bag and is used to measure the gas volume and the pressure inside the vacuum air bag; The gas analysis device is connected to the gas collection and quantitative device for analyzing the amount of hydrogen sulfide generated; The data measured by the weighing device, the measuring device and the gas analysis device are experimental data.

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

8. The method for determining conditions for inhibiting hydrogen sulfide generation by in-situ heating of shale according to claim 6, characterized in that: The system for the in-situ heating simulation experiment also includes: a flushing device and an analysis device; The flushing device is connected to the connecting pipeline between the heating device and the crude oil collection and quantitative device, and the flushing device is provided with petroleum flushing liquid for flushing the connecting pipeline; The flushing device is turned on after the shale sample is heated to each preset temperature and the crude oil in the crude oil collecting and quantitative device is discharged, and the petroleum flushing liquid flows into the connecting pipeline to obtain a mixed liquid, and the mixed liquid enters the collector in the crude oil collecting and quantitative device; the analysis device is connected to the collector in the crude oil collecting and quantitative device, and is used to analyze the mixed liquid and determine the amount of crude oil in the connecting pipeline.

9. The method for determining conditions for inhibiting hydrogen sulfide generation by in-situ heating of shale according to claim 1, characterized in that: The step of determining the control factor range for inhibiting hydrogen sulfide generation based on the evaluation information of each product characteristic quantity, and using the control factor range to guide shale in-situ heating further includes: Determine the initial range of control factors based on the evaluation information of oil and gas characterization quantities and production requirements; According to the evaluation information of the hydrogen sulfide characterization amount, a range in which the hydrogen sulfide characterization amount is less than a predetermined amount is determined from the initial range of the control factor, and the determined range is used as the final range of the control factor.

10. A device for determining conditions for inhibiting hydrogen sulfide generation by in-situ heating of shale, characterized in that: The device comprises: A characterization quantity determination unit is used to determine the characterization quantity of each product in the shale in-situ heating simulation experiment based on the shale in-situ heating simulation experiment, using temperature and heating rate as control factors, wherein each product includes hydrogen sulfide and oil and gas; An evaluation information determination unit, used to determine evaluation information of the characterization quantity of each product of shale in-situ heating under a control factor based on the characterization quantity of each product during the shale in-situ heating simulation experiment; The guidance unit is used to determine the control factor range for inhibiting the generation of hydrogen sulfide according to the evaluation information of each product characterization quantity, so as to guide the in-situ heating of shale using the control factor range.

11. A computer device comprising a memory, a processor, and a computer program stored in the memory, characterized in that: When the computer program is executed by the processor, the computer program executes the instructions of the method according to any one of claims 1 to 9.

12. A computer-readable storage medium having a computer program stored thereon, characterized in that: When the computer program is executed by a processor of a computer device, the computer program executes the instructions of the method according to any one of claims 1 to 9.

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