Method, device and equipment for judging oil-gas phase state and medium

Abstract

The invention discloses a method, a device, equipment and a medium for judging an oil-gas phase state, and the method comprises the steps: finding out a nonlinear mutation point of thermal response Ro and a sample depth H based on the relation between the sample depth H and the thermal response Ro of an unknown oil-gas phase state characterization oil-gas reservoir, and calculating a mutation amplitude delta Ro; the gas-oil ratio GOR of the oil-gas reservoir with the unknown characterization oil-gas phase state is obtained through calculation on the basis of the mutation amplitude delta Ro, and the oil-gas phase state in the oil-gas reservoir is obtained on the basis of the GOR; and obtaining the daily gas production representing the natural gas production in the oil-gas reservoir based on the CO2 content in the oil-gas reservoir unknown to represent the oil-gas phase state, and quantitatively predicting the natural gas production in the oil-gas reservoir. Therefore, the oil-gas phase state is quantitatively judged based on the thermal response and the CO2 content, the deep oil-gas phase state can be quickly and accurately judged, and the defects that an existing judgment method is high in cost, low in accuracy and not suitable for complex basins are simply, quickly and efficiently overcome.

Description

Technical Field

[0001] The present invention relates to a method based on thermal response and CO 2 The invention discloses a method, device, equipment and medium for judging the phase state of oil and gas by content, and relates to the technical field of oil and gas exploration. Background Art

[0002] In the global energy distribution, oil and gas are still the main energy sources in the world today. Under the global warming world pattern, the exploration and production of clean energy has always been a model that countries have strongly advocated. China's oil and gas exploration is advancing into deep layers and deep waters. Among them, deep natural gas exploration plays an increasingly important role in clean energy. Quickly and efficiently identify the oil and gas phase state, predict whether it is a pure gas reservoir, condensate gas reservoir or oil reservoir, and then determine the choice of drilling engineering, operation mode and mining method, so as to achieve efficient exploration and development. On the premise of ensuring energy security, increasing the proportion of clean energy has important practical and strategic significance.

[0003] However, in recent years, deep exploration has become increasingly difficult. We often encounter good oil and gas displays, which are interpreted as oil layers by logging, but later tested as gas layers. That is, there is a great deal of uncertainty in the identification of deep oil and gas phases using traditional logging and mud logging technologies. This means that the commonly used classical technologies and methods for judging oil and gas phases are likely to bring uncertainty. Therefore, finding a new method for judging oil and gas phases is an urgent need to clarify the nature of deep oil and gas reservoirs, and it is also the primary task of deep exploration to discover large oil and gas fields.

[0004] At present, the judgment of oil and gas phase is often based on the burial depth combined with the geothermal gradient to roughly predict the possible oil and gas phase, which is mainly qualitative; or the phase and occurrence state of oil and gas reservoirs are judged based on geochemical indicators and fluorescence display in the logging test during the drilling process. However, the above methods all have their own limitations. For example, judging the oil and gas phase based on the fluorescence display level often relies on the experience of the drilling personnel, which often leads to inaccurate or even wrong judgments; judging the oil and gas phase based on geochemical logging data is a qualitative method, because the response to crude oil is much higher than that of natural gas, resulting in distortion of oil and gas phase judgment; the method of using burial depth combined with geothermal comprehensive judgment is more suitable for primary oil and gas reservoirs, but the subsequent accumulation of oil and gas is often affected by secondary effects, such as gas washing, gas invasion, migration fractionation, etc., and these factors are often difficult to judge. Therefore, in general, the existing technology has the following shortcomings in determining the oil and gas phase: (1) The existing method basically uses traditional logging curves for manual interpretation to indirectly judge the oil and gas phase. The traditional logging curve is very accurate in interpreting shallow oil and gas layers, but in deep layers, due to the differences in reservoir physical properties and temperature and pressure conditions, the traditional logging interpretation method has great uncertainty, making it difficult to accurately judge the oil and gas phase. (2) The method of logging oil and gas geochemical parameters is selected to judge the oil and gas phase. The logging technology analyzes the geochemical parameters of the fluid stored in the reservoir during the drilling process, and then makes a comprehensive judgment. Since the amount of crude oil stored in the reservoir is much higher than that of natural gas, the reservoir often retains more information about crude oil, so the identification and judgment of crude oil is relatively accurate, but natural gas is often easily lost and missed. (3) The oil and gas phases are roughly predicted by combining the burial depth with the geothermal gradient. This method can often identify the phases of primary oil reservoirs in strata with continuous stable sedimentation and the premise that the geothermal gradient remains unchanged. However, it is often easy to distort the actual geological conditions such as changes in geothermal gradients and unstable formation deposition, and the depth error of the judgment is very large. In addition, if there is stratum erosion or geological events, it is basically wrong to use burial depth and geothermal gradient to make judgments: that is, this method of using macroscopic geological conditions to infer oil and gas phases has many limitations. Under ideal conditions, the oil and gas phases can be identified, but it is basically not applicable to actual geological conditions. Summary of the invention

[0005] The present invention aims to solve at least one of the technical problems existing in the prior art. To this end, in view of the above problems, the purpose of the present invention is to provide a method, device, equipment and medium for judging the phase state of oil and gas, which can intuitively and efficiently judge the phase state of oil and gas from the thermal response and CO 2 The content of oil and gas can be used to determine the phase state of deep oil and gas.

[0006] In order to achieve the above-mentioned object of the invention, the technical solution of the present invention is:

[0007] In a first aspect, the present invention provides a method for determining the phase state of oil and gas, the method comprising:

[0008] Based on the relationship between the unknown sample depth H and thermal response Ro of the oil and gas reservoir characterizing the oil and gas phase, the nonlinear mutation point between the thermal response Ro and the sample depth H is found, and the mutation amplitude ΔRo is calculated;

[0009] The gas-oil ratio GOR of the unknown oil and gas reservoir characterizing the oil and gas phase is calculated based on the mutation amplitude ΔRo, and the oil and gas phase in the oil and gas reservoir is known based on the GOR;

[0010] Characterizing the phase state of oil and gas based on unknown CO 2 The daily gas production in the oil and gas reservoir can be obtained by using the content to characterize the natural gas production, and the natural gas production in the oil and gas reservoir can be quantitatively predicted.

[0011] Furthermore, the gas-oil ratio GOR of the unknown reservoir characterizing the oil and gas phase is calculated based on the mutation amplitude ΔRo:

[0012] GOR=3.5628e 2.0918x R 2 =0.7772;

[0013] Where x is the parameter ΔRo, R 2 is the correlation coefficient.

[0014] Furthermore, GOR=daily gas production / daily oil production.

[0015] Furthermore, based on GOR, the oil and gas phase states in the oil and gas reservoirs are known: GOR less than 2000 is black oil, GOR between 2000-3000 is volatile oil, GOR between 3300-50000 is condensate gas, GOR between 50000-100000 is wet gas, and GOR greater than 100000 is dry gas.

[0016] Furthermore, based on the unknown characterization of the oil and gas phase state, CO 2 The daily gas production in the oil and gas reservoir is obtained by the content:

[0017] Daily gas production = 7840e 0.059x R 2 =0.891;

[0018] Where x is the CO in the oil and gas reservoir. 2 Content, R 2 is the correlation coefficient.

[0019] Furthermore, the process of calculating the mutation amplitude ΔRo is as follows: the thermal response Ro and the depth H have a positive linear relationship, that is, a straight line. The mutation means that the thermal response Ro suddenly increases at a certain depth, and after a certain depth, the Ro value returns to the normal straight line. Within the depth range of the mutation, a virtual normal linear straight line is made, and the Ro value of the mutation point at the same depth and the Ro value at the corresponding depth in the virtual normal linear relationship straight line are measured. The difference between the two is ΔRo.

[0020] Furthermore, the thermal response Ro is obtained by conducting geochemical pyrolysis experimental analysis on the obtained rock samples.

[0021] In a second aspect, the present invention provides a device for determining the phase state of oil and gas, comprising:

[0022] The mutation amplitude calculation unit is configured to find the mutation point of the nonlinearity between the thermal response Ro and the sample depth H based on the relationship between the unknown sample depth H and the thermal response Ro that characterizes the oil and gas phase state of the oil and gas reservoir, and calculate the mutation amplitude ΔRo;

[0023] The oil and gas phase state judgment unit is configured to calculate the gas-oil ratio GOR of the unknown oil and gas reservoir characterizing the oil and gas phase state based on the mutation amplitude ΔRo, so as to obtain the oil and gas phase state in the oil and gas reservoir;

[0024] The natural gas production prediction unit is configured to predict the CO 2 The daily gas production in the oil and gas reservoir can be obtained by using the content to characterize the natural gas production, and the natural gas production in the oil and gas reservoir can be quantitatively predicted.

[0025] In a third aspect, the present invention also provides an electronic device, comprising: at least one processor; and a memory communicatively connected to the processor; wherein the memory stores instructions executable by the processor, and the instructions are executed by the processor so that the processor can execute any one of the methods described.

[0026] In a fourth aspect, the present invention further provides a computer-readable storage medium storing one or more programs, wherein the one or more programs include computer instructions, and the computer instructions are used to enable a computer to execute any one of the methods described.

[0027] The present invention adopts the above technical solution, and has the following characteristics:

[0028] 1. The present invention is based on simple, fast and cheap experimental test parameter Ro analysis in rock samples to judge the oil and gas phase and natural gas production in oil and gas reservoirs. This method effectively avoids the distortion and error of parameter judgment adopted by conventional methods such as well logging and mud logging, solves the shortcoming of unknown phase in the exploration stage of oil and gas reservoirs, and avoids the lag of waiting until the development stage to find out the oil and gas phase in the oil and gas reservoirs, which greatly speeds up the timeliness and shortens the long waiting time.

[0029] 2. The present invention fully considers the heterogeneity of oil and gas reservoirs, and judges the oil and gas phase state and daily gas production quickly, efficiently, conveniently and cheaply from a microscopic perspective by dense sampling, thus avoiding the problems of time-consuming, expensive and distorted common methods. This method can simply and efficiently judge the oil and gas phase state of deep oil and gas reservoirs, greatly improving timeliness. At the same time, from the perspective of price promotion, it also has the advantages of high quality and low price.

[0030] 3. The present invention is based on thermal response and CO 2 Quantitative determination of oil and gas phases by content can quickly and accurately determine the deep oil and gas phases, and simply, quickly and efficiently solve the defects of existing identification methods such as high cost, low accuracy and unsuitability for complex basins.

[0031] In summary, the present invention provides a new method with great promotion and application value, which can be widely used in oil and gas exploration. BRIEF DESCRIPTION OF THE DRAWINGS

[0032] Various other advantages and benefits will become apparent to those of ordinary skill in the art by reading the detailed description of the preferred embodiments below. The accompanying drawings are only for the purpose of illustrating the preferred embodiments and are not to be considered as limiting the present invention. Throughout the accompanying drawings, the same reference numerals are used to represent the same components. In the accompanying drawings:

[0033] Figure 1 is a graph showing the relationship between thermal response Ro and time according to an embodiment of the present invention;

[0034] Figure 2 The relationship between the thermal response Ro and the depth H and the ΔRo identification diagram of the embodiment of the present invention;

[0035] Figure 3 is a relationship diagram between ΔRo and ΔPI according to an embodiment of the present invention;

[0036] Figure 4 ΔRo and hydrocarbon production rate increment (ΔPI) according to an embodiment of the present invention;

[0037] Figure 5 ΔRo and CO in the embodiment of the present invention 2 Correlation diagram;

[0038] Figure 6is a correlation diagram between ΔRo and gas-oil ratio GOR according to an embodiment of the present invention;

[0039] Figure 7 CO of the embodiment of the present invention 2 Correlation diagram between content and GOR;

[0040] Figure 8 CO of the embodiment of the present invention 2 Correlation diagram between content and daily gas production;

[0041] Fig. 9 are different oil and gas phase parameters of the embodiments of the present invention;

[0042] Fig.10 FIG. 4 is a structural diagram of an electronic device according to an embodiment of the present invention. DETAILED DESCRIPTION

[0043] It should be understood that the terms used herein are only for the purpose of describing specific example embodiments and are not intended to be limiting. Unless the context clearly indicates otherwise, the singular forms "one", "an" and "said" as used herein may also be meant to include plural forms. The terms "include", "comprise", "contain", and "have" are inclusive, and therefore specify the existence of stated features, steps, operations, elements and / or parts, but do not exclude the existence or addition of one or more other features, steps, operations, elements, parts, and / or combinations thereof. The method steps, processes, and operations described herein are not interpreted as necessarily requiring them to be performed in the specific order described or illustrated, unless the execution order is clearly indicated. It should also be understood that additional or alternative steps may be used.

[0044] Although the terms first, second, third, etc. can be used in the text to describe multiple elements, components, regions, layers and / or sections, these elements, components, regions, layers and / or sections should not be limited by these terms. These terms can only be used to distinguish an element, component, region, layer or section from another region, layer or section. Unless the context clearly indicates, terms such as "first", "second" and other numerical terms do not imply order or sequence when used in the text. Therefore, the first element, component, region, layer or section discussed below can be referred to as the second element, component, region, layer or section without departing from the teaching of the example embodiments.

[0045] For ease of description, spatially relative terms may be used herein to describe the relationship of one element or feature relative to another element or feature as shown in the figures, such as "inside", "outside", "inner side", "outer side", "below", "above", etc. Such spatially relative terms are intended to include different orientations of the device in use or operation in addition to the orientation depicted in the figures.

[0046] The complexity of deep oil and gas phase states lies in the following points: 1. Temperature and pressure environment of the deposited strata; 2. Openness of the deposited strata; 3. Type of parent material for oil and gas generation; 4. Oil and gas accumulation process. Among them, parent material type and accumulation process are the most important influencing factors. Although there are many influencing factors for the identification of deep oil and gas phase states, from the perspective of the deep oil and gas discovered so far, oil and gas reservoirs are often accompanied by CO enrichment. 2 Moreover, from the perspective of deep condensate gas and natural gas reservoirs around the world, CO 2 The content of CO has a certain relationship with the proportion of natural gas, that is, the oil and gas phase, and the thermal maturity of oil and gas is generally high. 2 Judging the oil and gas phase from the perspectives of content and thermal response Ro is an intuitive and accurate means. At the same time, from the perspective of economic cost and operability, measuring thermal response Ro and CO 2 The content is an economical, efficient and mature experimental analysis method. Therefore, in order to identify the phase state of deep oil and gas, the CO2 associated with condensate oil and gas is selected. 2 The method, device, equipment and medium for judging the oil and gas phase state provided by the present invention include: based on the relationship between the sample depth H and the thermal response Ro of the unknown oil and gas phase characterizing the oil and gas reservoir, finding the nonlinear mutation point between the thermal response Ro and the sample depth H, and calculating the mutation amplitude ΔRo; calculating the gas-oil ratio GOR of the unknown oil and gas phase characterizing the oil and gas reservoir based on the mutation amplitude ΔRo, and knowing the oil and gas phase state in the oil and gas reservoir based on the GOR; based on the CO in the unknown oil and gas reservoir characterizing the oil and gas phase 2 The daily gas production in the oil and gas reservoir is obtained by using the content to quantitatively predict the natural gas production in the oil and gas reservoir. 2 The method of identifying deep oil and gas phase state by content is based on the determination and analysis of rock thermal response Ro parameters, and quantitatively calculates the oil and gas phase parameter GOR and daily gas production. This method effectively avoids the problems of distortion and error in judging the test parameters commonly used in well logging and mud logging.

[0047] The exemplary embodiments of the present invention will be described in more detail below with reference to the accompanying drawings. Although the exemplary embodiments of the present invention are shown in the accompanying drawings, it should be understood that the present invention can be implemented in various forms and should not be limited by the embodiments described herein. On the contrary, these embodiments are provided in order to enable a more thorough understanding of the present invention and to fully convey the scope of the present invention to those skilled in the art.

[0048] Embodiment 1: This embodiment provides a method based on thermal response and CO 2 The method for judging the phase state of oil and gas by content includes the following steps:

[0049] S1. In the study area, exploration wells that encountered deep formations were selected and systematic sampling was carried out in the exploration wells.

[0050] In this embodiment, the specific process of systematic sampling of exploration wells is: sampling is performed at equal intervals for reservoirs of different depths, and the interval depends on the overall thickness of the reservoir. For reservoirs with an overall thickness greater than 100m, sampling is performed at equal intervals of 10m in the vertical direction; for thin reservoirs with small thickness, sampling is performed at intervals of 1m, and it is appropriate to have no less than 10 reservoir samples for each reservoir. This is taken as an example and is not limited to this.

[0051] S2. Perform geochemical pyrolysis experimental analysis on the obtained rock samples to obtain the experimental results of thermal response Ro (%), free hydrocarbon S 1 (mg / g) and cracked hydrocarbon S 2 (mg / g), calculate the hydrocarbon production rate PI = S 1 / (S 1 +S 2 ).

[0052] S3. The depth H (m) at which the rock samples were taken was calibrated to correspond to the Ro value, and the basin simulation software petromod was used to input the corresponding stratigraphic age and thickness to obtain the stratigraphic burial history. On this basis, the heat flow value was adjusted to make the Ro data output by the software consistent with the measured Ro data, thereby establishing the evolution relationship of the thermal response Ro over time and obtaining the corresponding formula and correlation coefficient.

[0053] In this embodiment, Figure 1 As shown in the figure, due to the change of heat flow in the process of geological evolution, there is a phenomenon of first cold and then hot or first hot and then cold, which leads to a multi-stage relationship between thermal response Ro and age:

[0054] The relationship between thermal response Ro(y) and time T(decade / Ma) before 10Ma (million years):

[0055] y=1.6313e -0.033x R 2 =0.9886;

[0056] The relationship between thermal response Ro(y) and time T(decade / Ma) after 10Ma (million years):

[0057] y=2.8448e -0.083x R 2 =0.989.

[0058] In the formula, R 2 refers to the correlation coefficient; x refers to the time T.

[0059] S4, such as Figure 2 As shown, based on the established relationship between the sample depth H and the thermal response Ro, the mutation point of the nonlinearity between the thermal response Ro and the sample depth H is found, and the mutation amplitude is calculated and marked with ΔRo.

[0060] In this embodiment, the normal thermal response Ro is in a positive linear relationship with the depth H, that is, a straight line. The mutation means that Ro suddenly increases at a certain depth, and after a certain depth, the Ro value returns to the normal straight line. In this depth range of the mutation, a virtual normal linear straight line is made, and the Ro value of the mutation point at the same depth and the Ro value of the corresponding depth in the virtual normal linear relationship straight line are measured. The difference between the two is ΔRo.

[0061] S5. Establish a relationship diagram between thermal response Ro and sample depth H for all rock samples, and read all ΔRo values.

[0062] S6. Establish a relationship diagram between PI and sample depth H of all rock samples, and read all PI increment ΔPI values.

[0063] In this embodiment, PI = S 1 / (S 1 +S 2 ), S1 and S2 are obtained from sample experimental tests. The depth will be used to calibrate the sample collection process, so each test result has a depth. Normal PI has a negative linear relationship with H, that is, as the depth increases, PI is a straight line. A sudden change means that PI suddenly increases at a certain depth, and after a certain depth, the PI value returns to the normal straight line. In this depth range of the sudden change, a virtual normal linear straight line is made, and the PI value of the sudden change point at the same depth and the corresponding depth PI value in the virtual normal linear relationship straight line are measured. The difference between the two is ΔPI.

[0064] S7. Calibrate the values ​​of ΔRo and ΔPI for each well. The two are consistent at the same depth. That is, the higher the depth range of ΔRo, the higher the ΔPI. That is, ΔRo and ΔPI appear at the same depth and time. Figure 3 shown.

[0065] S8. Establish the correlation between ΔRo and ΔPI. The two have an obvious positive correlation, and obtain the corresponding formula and correlation coefficient ΔPI=0.1016ln(ΔRo)+0.3009R 2 =0.8651. The above formula shows that ΔRo has the ability to characterize the abnormal hydrocarbon generation intensity under thermal action and the proportion of light components in the hydrocarbon generation components.

[0066] In this embodiment, Figure 4 As shown in the figure, ΔRo(y) in the rock sample is obtained based on the equal spacing method, and the hydrocarbon production rate ΔPI(x) in the rock sample selected by the equal spacing method is fitted to obtain a logarithmic formula:

[0067] y=0.1016ln(x)+0.3009R 2 =0.8651.

[0068] S9. Count the CO in all oil and gas reservoirs 2 content, test daily gas and oil production.

[0069] In this embodiment, the corresponding drilling instrument is used to test the CO in natural gas during the oil and gas drilling process. 2 content.

[0070] In this embodiment, the daily gas production and daily oil production are tested. The specific process is: if oil and gas are encountered during the drilling process of each well, a blowdown will be carried out to allow the oil and gas to flow to the ground and be contained in a container. The amount that can be contained in a day is the daily production, or the amount that can be contained in an hour is converted into a day. This is an example and is not limited to this.

[0071] S10. Calculate the gas-oil ratio, a parameter characterizing the oil-gas phase state, where gas-oil ratio (GOR) = daily gas production / daily oil production.

[0072] S11, such as Figure 5 As shown, the hydrothermal composition CO 2 The correlation with ΔRo gives the corresponding formula and correlation coefficient: CO 2 =3.563e 2.092ΔRo R 2 =0.798.

[0073] In this embodiment, Figure 5 As shown in Figure 2, based on the relationship between ΔRo(x) and CO in rock samples 2 (y) The content fitting resulted in a one-dimensional index formula:

[0074] y=3.563e 2.092x R 2 =0.798.

[0075] S12. Establish the correlation between ΔRo and GOR, fit the correlation between the Ro parameter representing the thermal response and the GOR parameter representing the oil and gas phase, and obtain the corresponding formula and correlation coefficient: GOR = 3.5628e 2.0918ΔRo R 2 =0.7772.

[0076] In this embodiment, Figure 6 As shown in the figure, a one-dimensional exponential formula is obtained based on the fitting of the ΔRo parameter (x) in the rock sample and the gas-oil ratio (GOR) (y), a characterization parameter of the oil and gas phase:

[0077] y=3.5628e 2.0918x R 2 =0.7772.

[0078] S13. Establish CO 2 The correlation between the content and GOR, fitting CO 2 The correlation between the content and the GOR(y) parameter characterizing the oil and gas phase state is obtained, and the corresponding formula and correlation coefficient are obtained.

[0079] In this embodiment, Figure 7 As shown, based on CO 2 The content (x) and the gas-oil ratio (GOR) (y), a characteristic parameter of oil and gas phase, are fitted to obtain a linear formula:

[0080] GOR=178.21x-88.83R 2 =0.7612;

[0081] Where x is the hydrothermal component CO 2 content.

[0082] S14, such as Figure 8 As shown, establish CO 2 The correlation between the content and the daily gas production in the oil and gas reservoirs is fitted with the CO 2 The quantitative relationship between the parameters and the daily gas production that characterizes natural gas production is obtained, and the corresponding formula and correlation coefficient are obtained.

[0083] In this embodiment, Figure 8 As shown, based on CO 2 The content (x) was fitted with the daily gas production (y) tested in the oil and gas reservoir to obtain a linear formula:

[0084] y=7840e 0.059x R 2 =0.891;

[0085] Where x is the hydrothermal component CO 2 content.

[0086] S15, substituting the unknown gas-oil ratio and daily gas production ΔRo of the oil and gas reservoir characterizing the oil and gas phase into the correlation equation determined in step S8, so as to obtain the abnormal hydrocarbon generation intensity of the oil and gas reservoir and the incremental proportion of light components.

[0087] In this embodiment, ΔRo is substituted into step S8 to calculate ΔPI, which indicates the abnormal difference of hydrocarbon generation intensity relative to the normal value. The larger the difference, the greater the abnormal hydrocarbon generation intensity. PI=S 1 / (S 1 +S 2 ), ΔPI is S 1 Increment, that is, the increment of light components.

[0088] S16, the unknown gas-oil ratio and daily gas production of the oil and gas reservoir are substituted into the correlation equation determined in step S11, and the CO in the oil and gas reservoir is obtained. 2 content.

[0089] S17, CO in the oil and gas reservoir calculated in S16 can be 2 Content and measured CO 2 The contents were compared and verified one by one.

[0090] S18, substituting the unknown gas-oil ratio and daily gas production ΔRo of the oil and gas reservoir into the correlation equation determined in step S12, so as to obtain the gas-oil ratio GOR parameter value indicating the oil and gas phase state in the oil and gas reservoir.

[0091] S19, CO in the oil and gas reservoir calculated in S16 2 The content is brought into the correlation equation determined in step S13 to obtain the gas-oil ratio GOR parameter value indicating the oil and gas phase state in the oil and gas reservoir, and the GOR parameter value obtained in S18 is further verified to identify the oil and gas phase state.

[0092] S19, CO in oil and gas reservoirs 2 The content is brought into the correlation equation determined in step S14, so as to obtain the daily gas production in the oil and gas reservoir, which characterizes the natural gas production, and quantitatively predict the natural gas production in the oil and gas reservoir.

[0093] The following describes in detail the use of the method of the present invention to determine the phase characteristics of oil and gas in the deep buried hill of the Bohai Sea area of ​​the Bohai Bay Basin through specific embodiments.

[0094] 1. Select typical wells in the deep buried hills in the Bohai Sea area of ​​the Bohai Bay Basin for equally spaced sampling with a sampling interval of 10m. For thin reservoirs, dense sampling is carried out with a sampling interval of 1m. It is advisable that each well has no less than 10 rock samples.

[0095] 2. Perform geochemical pyrolysis experimental analysis on the obtained rock samples to obtain the thermal response Ro of the experimental results. According to the sample collection depth, the parameters and depth are calibrated one by one. Specifically, the sampled rocks are marked with depth, so each value of the test has a depth value, and the calibration is completed one by one.

[0096] 3. Measure the thermal response parameters and oil and gas composition in the oil and gas reservoirs, and count the CO 2 The content is detected and calibrated with the depth (in drilling test oil and gas reservoirs, CO 2 During the content process, the depth is used to calibrate the test section, that is, each CO 2 The natural gas production in the oil and gas reservoir is tested, marked with daily gas production, and calibrated with depth (in the process of drilling to test the natural gas production in the oil and gas reservoir, the depth is used to calibrate the test section, that is, each natural gas production has a depth).

[0097] 4. Thermal response Ro, CO 2 The corresponding formula and correlation coefficient are obtained by fitting the content, oil and gas phase parameters gas-oil ratio GOR and natural gas daily production, among which:

[0098] 1) The parameter ΔRo and the gas-oil ratio GOR, a parameter characterizing the oil-gas phase state, are fitted to obtain a univariate exponential formula:

[0099] y=3.5628e 2.0918x R 2 =0.7772.

[0100] 2) CO 2 The content was fitted with the daily gas production tested in the oil and gas reservoir to obtain a linear formula:

[0101] y=7840e 0.059x R 2 =0.891.

[0102] 5. Substituting the thermal response parameter ΔRo of the unknown oil and gas reservoir characterizing the gas-oil ratio and daily gas production into the above equation, we can quickly obtain the gas-oil ratio and daily gas production of the unknown oil and gas reservoir. From the gas-oil ratio and daily gas production, we can know the oil and gas phase in the oil and gas reservoir, the oil and gas reservoir with the highest natural gas production and its depth.

[0103] In this embodiment, gas-oil ratio GOR = natural gas / liquid crude oil. According to industry standards, different GORs represent different oil and gas reservoir properties, that is, different oil and gas phases. Fig. 9 As shown, if there is no crude oil but only natural gas, the daily gas production, that is, the production value, can be calculated according to the method of the present invention.

[0104] The ΔRo variation rate of the rock samples selected in this embodiment ranges from 0.1% to 1.5%, with the highest being the oil and gas reservoir at 3600m, where ΔRo reaches 1.5%. Figure 4 The equation shown in the figure shows that the hydrocarbon generation rate is abnormal, increasing from 0.1% to 0.25%, an increase of 2.5 times, CO 2 The content is as high as 72.8%. Figure 7 The equation shown in the figure gives the parameter characterizing the oil-gas phase state, the gas-oil ratio GOR, which is 1288.4. Substituting it into Figure 8 The equation shown gives a daily gas production of 402426m 3 / d. The CO obtained by the above three equations 2 The error of content, oil and gas phase parameter GOR and daily gas production is less than 5.0%, indicating that the present invention has high accuracy.

[0105] Embodiment 2: Embodiment 1 above provides a method for determining the oil and gas phase state, and correspondingly, this embodiment provides a device for determining the oil and gas phase state. The device provided in this embodiment can implement the method for determining the oil and gas phase state of Embodiment 1, and the device can be implemented by software, hardware, or a combination of software and hardware. For the convenience of description, this embodiment is described by dividing the functions into various units and describing them separately. Of course, the functions of each unit can be implemented in the same or one or more software and / or hardware during implementation. For example, the device may include integrated or separate functional modules or functional units to execute the corresponding steps in each method of Embodiment 1. Since the device of this embodiment is basically similar to the method embodiment, the description process of this embodiment is relatively simple, and the relevant parts can refer to the partial description of Embodiment 1. The embodiment of the device for determining the oil and gas phase state provided by the present invention is merely schematic.

[0106] Specifically, this embodiment provides a device for determining the phase state of oil and gas, including:

[0107] The mutation amplitude calculation unit is configured to find the mutation point of the nonlinearity between the thermal response Ro and the sample depth H based on the relationship between the unknown sample depth H and the thermal response Ro that characterizes the oil and gas phase state of the oil and gas reservoir, and calculate the mutation amplitude ΔRo;

[0108] The oil and gas phase state judgment unit is configured to calculate the gas-oil ratio GOR of the unknown oil and gas reservoir characterizing the oil and gas phase state based on the mutation amplitude ΔRo, so as to obtain the oil and gas phase state in the oil and gas reservoir;

[0109] The natural gas production prediction unit is configured to predict the CO 2 The daily gas production in the oil and gas reservoir can be obtained by using the content to characterize the natural gas production, and the natural gas production in the oil and gas reservoir can be quantitatively predicted.

[0110] Embodiment 3: This embodiment provides an electronic device corresponding to the method for determining the oil and gas phase provided in Embodiment 1. The electronic device may be an electronic device used for a client, such as a mobile phone, a laptop computer, a tablet computer, a desktop computer, etc., to execute the method of Embodiment 1.

[0111] like Fig.10 As shown, the electronic device includes a processor, a memory, a communication interface and a bus, and the processor, the memory and the communication interface are connected through the bus to complete mutual communication. The bus can be an Industry Standard Architecture (ISA) bus, a Peripheral Component Interconnect (PCI) bus or an Extended Industry Standard Component (EISA) bus, etc. The memory stores a computer program that can be run on the processor, and the processor executes the method of embodiment 1 when running the computer program. The implementation principle and technical effect are similar to those of embodiment 1, and will not be repeated here. Those skilled in the art can understand that Fig.10 The structure shown in the figure is only a block diagram of a part of the structure related to the scheme of the present application, and does not constitute a limitation on the computing device to which the scheme of the present application is applied. The specific computing device may include more or fewer components than shown in the figure, or combine certain components, or have a different arrangement of components.

[0112] In a preferred embodiment, the logic instructions in the above-mentioned memory can be implemented in the form of a software functional unit and can be stored in a computer-readable storage medium when it is sold or used as an independent product. Based on this understanding, the technical solution of the present application can be essentially or partly embodied in the form of a software product that contributes to the prior art. The computer software product is stored in a storage medium, including several 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 the present application. The aforementioned storage medium includes: U disk, mobile hard disk, read-only memory (ROM, Read-Only Memory), random access memory (RAM, Random Access Memory), optical disk and other media that can store program codes.

[0113] In a preferred embodiment, the processor may be a central processing unit (CPU), a digital signal processor (DSP) or other general-purpose processors of various types, which are not limited here.

[0114] Embodiment 4: This embodiment provides a computer-readable storage medium storing one or more programs, wherein the one or more programs include computer instructions. When the computer instructions are executed by a computer, the computer executes the method provided in the above-mentioned embodiment 1.

[0115] Embodiment 5: This embodiment provides a computer program product. The computer program product may include a computer program stored on a computer-readable storage medium. The computer program includes program instructions. When the program instructions are executed by a computer, the computer can execute the method provided in the above-mentioned embodiment 1. Its implementation principle and technical effects are similar to those of embodiment 1 and will not be repeated here.

[0116] In a preferred embodiment, the computer-readable storage medium may be a tangible device that holds and stores instructions used by the instruction execution device, such as but not limited to an electrical storage device, a magnetic storage device, an optical storage device, an electromagnetic storage device, a semiconductor storage device, or any combination thereof. The computer-readable storage medium stores computer program instructions that cause the computer to execute the method provided in the first embodiment.

[0117] The present application is described with reference to the flowcharts and / or block diagrams of the methods, devices (apparatus), and computer program products according to the embodiments of the present application. It should be understood that each process and / or box in the flowchart and / or block diagram, as well as the combination of the processes and / or boxes in the flowchart and / or block diagram, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, a special-purpose computer, an embedded processor, or other programmable data processing device to generate a machine, so that the instructions executed by the processor of the computer or other programmable data processing device generate instructions for implementing the processes in the flowchart and / or block diagram. Figure 1 A process or multiple processes and / or boxes Figure 1 A device that provides the functions specified in a block or multiple blocks.

[0118] These computer program instructions may also be stored in a computer-readable memory capable of directing a computer or other programmable data processing device to operate in a specific manner, so that the instructions stored in the computer-readable memory produce an article of manufacture comprising an instruction device, which implements the process Figure 1 A process or multiple processes and / or boxes Figure 1 A function specified in one or more boxes.

[0119] These computer program instructions can also be loaded onto a computer or other programmable data processing device so that a series of operating steps are executed on the computer or other programmable device to produce a computer-implemented process, thereby providing instructions for implementing the process. Figure 1 A process or multiple processes and / or boxes Figure 1 The steps for the functions specified in one or more boxes.

[0120] Each embodiment in this specification is described in a progressive manner, and the same and similar parts between the embodiments can be referred to each other, and each embodiment focuses on the differences from other embodiments. In the description of this specification, the description of reference terms "a preferred embodiment", "further", "specifically", "in the present embodiment", etc. means that the specific features, structures, materials or characteristics described in conjunction with the embodiment or example are included in at least one embodiment or example of the embodiment of this specification. In this specification, the schematic representation of the above terms does not necessarily refer to the same embodiment or example. Moreover, the specific features, structures, materials or characteristics described can be combined in any one or more embodiments or examples in a suitable manner. In addition, those skilled in the art can combine and combine the different embodiments or examples described in this specification and the features of the different embodiments or examples without contradiction.

[0121] Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of the present invention, rather than to limit it. Although the present invention has been described in detail with reference to the aforementioned embodiments, those skilled in the art should understand that they can still modify the technical solutions described in the aforementioned embodiments, or make equivalent replacements for some of the technical features therein. However, these modifications or replacements do not deviate the essence of the corresponding technical solutions from the spirit and scope of the technical solutions of the embodiments of the present invention.

Claims

1. A method for determining the phase state of oil and gas, characterized in that: The method includes: Based on the relationship between the unknown sample depth H and thermal response Ro of the oil and gas reservoir characterizing the oil and gas phase, the nonlinear mutation point between the thermal response Ro and the sample depth H is found, and the mutation amplitude ΔRo is calculated; The gas-oil ratio GOR of the unknown oil and gas reservoir characterizing the oil and gas phase is calculated based on the mutation amplitude ΔRo, and the oil and gas phase in the oil and gas reservoir is known based on the GOR; Based on the unknown CO2 content in the oil and gas reservoir that characterizes the oil and gas phase, the daily gas production in the oil and gas reservoir that characterizes the natural gas production is obtained, and the natural gas production in the oil and gas reservoir is quantitatively predicted.

2. The method for determining the oil and gas phase state according to claim 1, characterized in that: The gas-oil ratio GOR of the unknown oil and gas reservoir characterizing the oil and gas phase is calculated based on the mutation amplitude ΔRo: GOR=3.5628e 2.0918x R 2 =0.7772; Where x is the parameter ΔRo, R 2 is the correlation coefficient.

3. The method for determining the oil and gas phase state according to claim 2, characterized in that: GOR = daily gas production / daily oil production.

4. The method for determining the oil and gas phase state according to claim 1, characterized in that: Based on GOR, the oil and gas phase states in the oil and gas reservoirs are known: GOR less than 2000 is black oil, GOR between 2000-3000 is volatile oil, GOR between 3300-50000 is condensate gas, GOR between 50000-100000 is wet gas, and GOR greater than 100000 is dry gas.

5. The method for determining the oil and gas phase state according to claim 1, characterized in that: Based on the unknown CO2 content in the oil and gas reservoir that characterizes the oil and gas phase, the daily gas production in the oil and gas reservoir that characterizes the natural gas production is obtained: Daily gas production = 7840e 0.059x R 2 =0.891; Where x is the CO2 content in the oil and gas reservoir, R 2 is the correlation coefficient.

6. The method for determining the oil and gas phase state according to claim 1, characterized in that: The process of calculating the mutation amplitude ΔRo is: The thermal response Ro and depth H have a positive linear relationship, that is, a straight line. A mutation means that the thermal response Ro suddenly increases at a certain depth. After a certain depth, the Ro value returns to the normal straight line. Within the depth range of the mutation, a virtual normal linear straight line is made, and the Ro value at the mutation point at the same depth and the Ro value at the corresponding depth in the virtual normal linear relationship line are measured. The difference between the two is ΔRo.

7. The method for determining the oil and gas phase state according to claim 1, characterized in that: The thermal response Ro is obtained by conducting geochemical pyrolysis experimental analysis on the obtained rock samples.

8. A device for determining the phase state of oil and gas, characterized in that: include: The mutation amplitude calculation unit is configured to find the mutation point of the nonlinearity between the thermal response Ro and the sample depth H based on the relationship between the unknown sample depth H and the thermal response Ro that characterizes the oil and gas phase state of the oil and gas reservoir, and calculate the mutation amplitude ΔRo; The oil and gas phase state judgment unit is configured to calculate the gas-oil ratio GOR of the unknown oil and gas reservoir characterizing the oil and gas phase state based on the mutation amplitude ΔRo, so as to obtain the oil and gas phase state in the oil and gas reservoir; The natural gas production prediction unit is configured to obtain the daily gas production in the oil and gas reservoir that represents the natural gas production based on the unknown CO2 content in the oil and gas reservoir that represents the oil and gas phase, and quantitatively predict the natural gas production in the oil and gas reservoir.

9. An electronic device, characterized in that: include: at least one processor; and a memory communicatively connected to the processor; wherein the memory stores instructions executable by the processor, and the instructions are executed by the processor so that the processor can execute the method according to any one of claims 1-7.

10. A computer-readable storage medium storing one or more programs, characterized in that: The one or more programs include computer instructions for causing a computer to execute the method according to any one of claims 1-7.

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