Reservoir natural production capability qualitative evaluation method and device

Abstract

The invention provides a reservoir natural commissioning capability qualitative evaluation method and device, and solves the problem that whether a reservoir can be naturally commissioned or not cannot be judged by using logging data. Comprising the following steps: acquiring logging curves and logging gas logging data of all logging wells in a target area; drawing a cross plot based on the logging curve of the logging well, and dividing a first area where a reservoir capable of being put into production naturally is located in the cross plot; a first chart is drawn based on logging gas logging data of logging, and a second area where a reservoir capable of being put into production naturally is located is counted in the first chart; obtaining a first seepage capacity parameter and a first oil-gas-bearing property parameter based on a logging curve of the reservoir to be evaluated, plumbing the seepage capacity parameter and the oil-gas-bearing property parameter into the cross plot, and judging whether the plumbing point is located in the first area or not; and if yes, drawing a second chart based on the gas logging data of the to-be-evaluated reservoir, judging whether a preset number of data points in the second chart fall in the second area, and if yes, determining that the to-be-evaluated reservoir is a reservoir capable of being put into production naturally.

Description

Technical Field

[0001] The present invention relates to the technical field of oil exploration and development, and particularly relates to a method and device for qualitatively evaluating the natural production capacity of a reservoir. Background Art

[0002] The natural production of an oil and gas reservoir means that without stimulation measures such as fracturing, a production well can stably produce above a certain production rate at a certain stage. If an oil reservoir has the conditions for natural production testing, it can save high fracturing costs, shorten the construction period, and at the same time avoid large-scale water production caused by communicating with water layers during the fracturing process, which has both economic benefits and practical significance. Therefore, it is of great significance to evaluate whether an oil reservoir can be naturally produced.

[0003] Currently, determining whether an oil (gas) well can produce oil (gas) and has industrial value mainly relies on the well testing (oil testing) process. However, the well testing process often takes several months, which is time-consuming and costly. Therefore, using logging data to timely and accurately determine whether a reservoir can be naturally produced without fracturing is of great significance for cost reduction and efficiency improvement in oil and gas reservoir exploration and development. However, there are currently no relevant models and evaluation methods. Summary of the Invention

[0004] In view of this, an embodiment of the present invention provides a method and device for qualitatively evaluating the natural production capacity of a reservoir, which solves the problem that at the current stage, it is impossible to use logging data to timely and accurately determine whether a reservoir can be naturally produced without fracturing.

[0005] In a first aspect, a method for qualitatively evaluating the natural production capacity of a reservoir provided by an embodiment of the present invention includes:

[0006] Obtaining logging curves and mud logging gas logging data of all logging wells in a target area; the logging wells include logging wells that can be naturally produced and logging wells that cannot be naturally produced;

[0007] Drawing a cross plot based on the logging curves of the logging wells, and dividing a first area where the reservoir that can be naturally produced is located in the cross plot;

[0008] Drawing a first chart based on the mud logging gas logging data of the logging wells, and counting a second area where the reservoir that can be naturally produced is located in the first chart;

[0009] Obtaining logging curves and mud logging gas logging data of a reservoir to be evaluated;

[0010] Obtaining a first seepage capacity parameter and a first oil and gas bearing property parameter based on the logging curves of the reservoir to be evaluated, plotting the seepage capacity parameter and the oil and gas bearing property parameter on the cross plot, and determining whether the plotted point falls in the first area;

[0011] If the throwing point falls within the first region, a second plot is drawn based on the gas logging data of the reservoir to be evaluated, and it is determined whether a preset number of data points in the second plot fall within the second region. If so, the reservoir to be evaluated is a reservoir that can be put into production naturally; if not, the reservoir to be evaluated is a reservoir that cannot be put into production naturally.

[0012] In one embodiment, the logging curves of the logging include a first spontaneous potential curve;

[0013] The drawing of the cross plot based on the logging curves of the logging includes:

[0014] For a reservoir that can be put into production naturally and a reservoir that cannot be put into production naturally, a first spontaneous potential difference of the non-pure water layer reservoir section in the logging reservoir is obtained based on the first spontaneous potential curve;

[0015] Obtain the first parameter representative values of the respective logging curves of the reservoir that can be put into production naturally and the reservoir that cannot be put into production naturally, and obtain a second seepage capacity parameter and a second oil and gas bearing property parameter based on the first parameter representative values and the first spontaneous potential difference;

[0016] Draw a cross plot based on the second seepage capacity parameter and the second oil and gas bearing property parameter.

[0017] In one embodiment, the obtaining of the first spontaneous potential difference of the non-pure water layer reservoir section in the logging reservoir based on the first spontaneous potential curve includes:

[0018] Read the spontaneous potential values in the reservoir of the logging, eliminate the abnormal points, and arrange them in a preset order;

[0019] Select a preset number of data after the arrangement according to a preset position, and take the average value as the representative value of the first spontaneous potential;

[0020] Obtain the average value of the spontaneous potential of the stable mudstone section with a thickness greater than a preset threshold as the mudstone baseline value;

[0021] Take the absolute value of the difference between the representative value of the first spontaneous potential and the mudstone baseline value as the first spontaneous potential difference.

[0022] In one embodiment, the logging curves include: a first porosity curve, a first density curve, and a first deep induction resistivity curve;

[0023] The obtaining of the first parameter representative values of the respective logging curves of the reservoir that can be put into production naturally and the reservoir that cannot be put into production naturally includes: respectively obtaining the first porosity representative value, the first density representative value, and the first deep induction resistivity representative value of the non-pure water layer section of the reservoir that can be put into production naturally and the reservoir that cannot be put into production naturally.

[0024] In one embodiment, obtaining the second seepage capacity parameter and the second oil and gas bearing property parameter based on the representative value of the first parameter and the first spontaneous potential difference includes:

[0025] Obtaining the second seepage capacity parameter based on the first spontaneous potential difference and the representative value of the first porosity;

[0026] Obtaining the second oil and gas bearing property parameter based on the representative value of the first density and the representative value of the first deep induction resistivity curve.

[0027] In one embodiment, drawing the first chart based on the logging gas measurement data of well logging includes:

[0028] Sampling each layer of the reservoir that can be naturally put into production and the reservoir that cannot be naturally put into production based on the logging gas measurement data of well logging to obtain multiple sampling points in each layer;

[0029] Drawing the first chart based on the multiple sampling points obtained in each layer.

[0030] In one embodiment, drawing the first chart based on the logging gas measurement data of well logging includes:

[0031] Sampling each layer of the reservoir that can be naturally put into production and the reservoir that cannot be naturally put into production based on the logging gas measurement data of well logging to obtain three sampling points in each layer;

[0032] Obtaining the proportional parameters of the three sampling points based on the three sampling points and drawing a triangular chart with the proportional parameters of the three sampling points as vertices.

[0033] In one embodiment, the well logging curves of the reservoir to be evaluated include the second spontaneous potential curve;

[0034] Obtaining the first seepage capacity parameter and the first oil and gas bearing property parameter based on the well logging curves of the reservoir to be evaluated includes:

[0035] Obtaining the second spontaneous potential difference of the non-pure water layer reservoir section of the reservoir to be evaluated based on the second spontaneous potential curve;

[0036] Obtaining the second parameter representative value of each well logging curve of the reservoir to be evaluated, and obtaining the first seepage capacity parameter and the first oil and gas bearing property parameter based on the second parameter representative value and the second spontaneous potential difference.

[0037] In one embodiment, drawing the second chart based on the gas logging data of the reservoir to be evaluated includes:

[0038] Sampling the reservoir to be evaluated based on the logging gas measurement data of the reservoir to be evaluated to obtain a plurality of sampling points;

[0039] Drawing a second chart based on the plurality of sampling points obtained from the reservoir to be evaluated.

[0040] In a second aspect, a device for qualitatively evaluating the natural production capacity of a reservoir according to an embodiment of the present invention includes:

[0041] A data acquisition unit for acquiring logging curves and logging gas measurement data of all logging wells in the target area; acquiring logging curves and logging gas measurement data of the reservoir to be evaluated;

[0042] An image drawing unit for drawing a cross plot based on the logging curves of the logging wells and dividing a first area where the reservoir that can be naturally produced is located in the cross plot; drawing a first chart based on the logging gas measurement data of the logging wells and counting a second area where the reservoir that can be naturally produced is located in the first chart; then drawing a second chart based on the gas logging data of the reservoir to be evaluated;

[0043] A data processing unit for obtaining a first seepage capacity parameter and a first oil and gas bearing property parameter based on the logging curves of the reservoir to be evaluated, plotting the seepage capacity parameter and the oil and gas bearing property parameter on the cross plot, and determining whether the plotted point falls in the first area; and / or, for determining whether a preset number of data points in the second chart fall in the second area; if so, the reservoir to be evaluated is a reservoir that can be naturally produced; if not, the reservoir to be evaluated is a reservoir that cannot be naturally produced.

[0044] In a third aspect, an electronic device according to an embodiment of the present invention includes a memory and a processor, the memory is used to store one or more computer instructions, wherein, when the one or more computer instructions are executed by the processor, the method for qualitatively evaluating the natural production capacity of a reservoir as described above is implemented.

[0045] In a fourth aspect, a computer-readable storage medium according to an embodiment of the present invention stores a computer program, and when the computer program is executed by a processor, it is used to implement the method for qualitatively evaluating the natural production capacity of a reservoir as described above.

[0046] Compared with the prior art, the present invention provides a method and device for qualitatively evaluating the natural production capacity of a reservoir, which for the first time realizes the qualitative discrimination of whether a reservoir can produce naturally without fracturing based on logging data, can improve the timeliness of discrimination, reduce the evaluation cost, and provide strong support for formulating an oil reservoir development plan and reducing costs and increasing efficiency. Description of the Drawings

[0047] Figure 1The figure shows a schematic flow chart of a method for qualitatively evaluating the natural production capacity of a reservoir provided by an embodiment of the present invention.

[0048] Figure 2 The figure shows a crossplot of X1 and X2 in a certain work area provided by an embodiment of the present invention.

[0049] Figure 3 The figure shows a triangular plot of gas logging data for reservoirs that cannot be naturally put into production in a certain work area provided by an embodiment of the present invention.

[0050] Figure 4 The figure shows a triangular plot of gas logging data for reservoirs that can be naturally put into production in a certain work area provided by an embodiment of the present invention.

[0051] Figure 5 The figure shows the projection results of the crossplot of X1 and X2 in the gas layer of Well A1 and the triangular plot of logging gas logging data in a certain work area provided by an embodiment of the present invention.

[0052] Figure 6 The figure shows the projection results of the crossplot of X1 and X2 in the gas layer of Well A2 in a certain work area provided by an embodiment of the present invention.

[0053] Figure 7 The figure shows a schematic structural diagram of a device for qualitatively evaluating the natural production capacity of a reservoir provided by an embodiment of the present invention. Detailed implementation manners

[0054] Next, the technical solutions in the embodiments of the present invention will be clearly and completely described in conjunction with the accompanying drawings in the embodiments of the present invention. Obviously, the described embodiments are only a part of the embodiments of the present invention, rather than all the embodiments. Based on the embodiments of the present invention, all other embodiments obtained by those of ordinary skill in the art without creative efforts shall fall within the protection scope of the present invention.

[0055] In view of the current situation that the natural production of oil and gas reservoirs highly depends on the well testing (oil) process, which is time-consuming and costly, the main purpose of the present invention is to qualitatively determine whether an oil and gas reservoir can be naturally produced without fracturing based on the logging data measured during the drilling process, without adding new technical means, improve the timeliness of discrimination, reduce the evaluation cost, effectively guide the next development plan, and provide strong support for cost reduction and efficiency improvement in the exploration and development of oil and gas reservoirs. The detailed implementation manners are as described in the following embodiments.

[0056] Example 1:

[0057] This embodiment provides a method for qualitatively evaluating the natural production capacity of a reservoir. As Figure 1 shown, the method for qualitatively evaluating the natural production capacity of the reservoir includes:

[0058] Step 01: Obtain the well logging curves and mud logging gas logging data of all the logging and mud logging wells within the target area; the logging and mud logging wells include: logging and mud logging wells that can be put into production naturally and those that cannot be put into production naturally.

[0059] Whether a logging and mud logging well can be put into production naturally depends on the actual production data and is judged according to the reservoir conditions.

[0060] The well logging curves include natural gamma, spontaneous potential, density, neutron, acoustic wave, deep induction resistivity curve, interpreted porosity curve, reservoir division and fluid conclusion, etc.

[0061] The mud logging gas logging data includes the calibration of C1, C2, C3, and C4 hydrocarbon components.

[0062] Step 02: Based on the well logging curves of the logging and mud logging wells, draw a cross plot, and divide the first area where the reservoirs that can be put into production naturally are located in the cross plot.

[0063] The well logging curves of the logging and mud logging wells include the first spontaneous potential curve.

[0064] The drawing of the cross plot based on the well logging curves of the logging and mud logging wells includes:

[0065] Step 021: For the reservoirs that can be put into production naturally and those that cannot be put into production naturally, obtain the first spontaneous potential difference of the non-pure water layer reservoir section within the logging and mud logging well reservoir based on the first spontaneous potential curve;

[0066] Among them, the obtaining of the first spontaneous potential difference of the non-pure water layer reservoir section within the logging and mud logging well reservoir based on the first spontaneous potential curve includes:

[0067] Step 0211: Read the spontaneous potential values within the reservoir of the logging and mud logging well, eliminate the abnormal points, and arrange them in a preset order;

[0068] Step 0212: Select a preset number of data after arrangement according to a preset position, and take the average value as the representative value of the first spontaneous potential;

[0069] Step 0213: Obtain the average value of the spontaneous potential of the stable mudstone section with a thickness greater than a preset threshold as the mudstone baseline value;

[0070] Step 0214: Take the absolute value of the difference between the representative value of the first spontaneous potential and the mudstone baseline value as the first spontaneous potential difference.

[0071] Optionally, read the spontaneous potential values in the reservoir of the logging data, eliminate the abnormal points, and arrange them in ascending order. For fresh water mud, select the average value of the first 20% of the data as the representative value SP1 of the spontaneous potential of this layer; for salt water mud, select the average value of the last 20% of the data as the representative value SP1 of the spontaneous potential of this layer; read the average value of the spontaneous potential SP of the stable mudstone section of the large formation (thickness greater than a certain threshold) as the mudstone baseline value SP2. Therefore, the first spontaneous potential difference ΔSP = |SP1 - SP2|.

[0072] Step 022: Obtain the first parameter representative values of the logging curves of the reservoirs that can be naturally put into production and the reservoirs that cannot be naturally put into production, and obtain the second seepage capacity parameter and the second oil and gas bearing property parameter based on the first parameter representative values and the first spontaneous potential difference.

[0073] Among them, the logging curves include: the first porosity curve, the first density curve, and the first deep induction resistivity curve;

[0074] The obtaining of the first parameter representative values of the logging curves of the reservoirs that can be naturally put into production and the reservoirs that cannot be naturally put into production includes: respectively obtaining the first porosity representative value, the first density representative value, and the first deep induction resistivity representative value of the non-pure water layer sections of the reservoirs that can be naturally put into production and the reservoirs that cannot be naturally put into production.

[0075] The obtaining of the second seepage capacity parameter and the second oil and gas bearing property parameter based on the first parameter representative values and the first spontaneous potential difference includes: obtaining the second seepage capacity parameter based on the first spontaneous potential difference and the first porosity representative value; obtaining the second oil and gas bearing property parameter based on the first density representative value and the representative value of the first deep induction resistivity curve.

[0076] Specifically, respectively read the representative values of the porosity curve, the density curve, and the deep induction resistivity curve of the non-pure water layer sections that can be naturally put into production and cannot be naturally put into production, and calculate the seepage capacity parameter and the oil and gas bearing property parameter based on each representative value. The seepage capacity parameter X1 that characterizes the physical properties and seepage capacity is X1 = porosity × ΔSP / 100; the oil and gas bearing property parameter X2 that characterizes the physical properties and oil and gas bearing property is X2 = 100 × density / deep induction resistivity.

[0077] Among them, the method for reading the representative value is as follows: Remove 1 / 10 of the data from the top and bottom of the layer, and calculate the average value of the remaining data (eliminating the abnormal points).

[0078] Step 023: Draw a cross plot based on the second seepage capacity parameter and the second oil and gas bearing property parameter.

[0079] Taking the two physical quantities X1 and X2 in the above steps as the coordinate axes respectively to make a cross plot, and dividing the area where the reservoir that can be put into production naturally is located according to statistical laws. Optionally, all reservoir positions that can be put into production naturally should be covered in the natural production area, and the number of wells that cannot be put into production naturally in the natural production area should be less than 20% of the number of layers.

[0080] Step 03: Draw a first plot based on the logging gas measurement data of the logging while drilling, and count the second area where the reservoir that can be put into production naturally is located in the first plot.

[0081] Among them, the drawing of the first plot based on the logging gas measurement data of the logging while drilling includes:

[0082] Step 031: Sampling each layer of the reservoir that can be put into production naturally and the reservoir that cannot be put into production naturally based on the logging gas measurement data of the logging while drilling, so as to obtain multiple sampling points in each layer;

[0083] Step 032: Draw a first plot based on the multiple sampling points obtained in each layer.

[0084] Specifically, the drawing of the first plot based on the logging gas measurement data of the logging while drilling includes: sampling each layer of the reservoir that can be put into production naturally and the reservoir that cannot be put into production naturally based on the logging gas measurement data of the logging while drilling, so as to obtain three sampling points in each layer; obtaining the proportional parameters of the three sampling points based on the three sampling points, and drawing a triangular plot with the proportional parameters of the three sampling points as vertices.

[0085] Based on the gas logging data, calculate three parameters of C2 / ∑Ci, C3 / ∑Ci, and C4 / ∑Ci for each sampling point of each layer of the reservoir that can be put into production naturally and the reservoir that cannot be put into production naturally, draw a triangular plot with the three parameters as vertices, and count the area where the reservoir that can be put into production naturally is located.

[0086] Step 04: Obtain the logging curves and logging gas measurement data of the reservoir to be evaluated.

[0087] As described in step 01, the logging curves of the reservoir to be evaluated include the natural gamma, natural potential, density, neutron, acoustic wave, deep induction resistivity curve, interpreted porosity curve, reservoir division and fluid conclusion, etc. of the reservoir to be evaluated.

[0088] The logging gas measurement data of the reservoir to be evaluated includes the calibration of C1, C2, C3, and C4 hydrocarbon components of the reservoir to be evaluated.

[0089] Step 05: Obtain a first seepage capacity parameter and a first oil and gas bearing property parameter based on the logging curves of the reservoir to be evaluated, project the seepage capacity parameter and the oil and gas bearing property parameter onto the cross plot, and judge whether the projected point falls within the first area.

[0090] Among them, the logging curve of the reservoir to be evaluated includes a second spontaneous potential curve;

[0091] Obtaining a first seepage capacity parameter and a first oil and gas bearing property parameter based on the logging curves of the reservoir to be evaluated includes:

[0092] Step 051: Obtaining a second spontaneous potential difference of the non-pure water layer reservoir section of the reservoir to be evaluated based on the second spontaneous potential curve;

[0093] Step 052: Obtaining representative values of second parameters of each logging curve of the reservoir to be evaluated, and obtaining a first seepage capacity parameter and a first oil and gas bearing property parameter based on the representative values of the second parameters and the second spontaneous potential difference.

[0094] The method for obtaining the second spontaneous potential difference, the first seepage capacity parameter, and the first oil and gas bearing property parameter in Step 05 is similar to that in Step 02, and will not be elaborated here.

[0095] Step 06: If the plotted point falls within the first region, draw a second graph based on the gas logging data of the reservoir to be evaluated, and determine whether a preset number of data points in the second graph fall within the second region. If so, the reservoir to be evaluated is a reservoir that can be naturally produced; if not, the reservoir to be evaluated is a reservoir that cannot be naturally produced.

[0096] Among them, drawing a second graph based on the gas logging data of the reservoir to be evaluated includes:

[0097] Step 061: Sampling the reservoir to be evaluated based on the logging gas measurement data of the reservoir to be evaluated to obtain multiple sampling points;

[0098] Step 062: Drawing a second graph based on the multiple sampling points obtained from the reservoir to be evaluated.

[0099] For a reservoir to be evaluated, we do not know whether it can be naturally produced. First, calculate the first seepage capacity parameter and the first oil and gas bearing property parameter according to the method in Step 05, and then plot the point in the cross plot. In the cross plot, if the plotted point falls within the non-natural production region, the reservoir does not have the ability to be naturally produced; if it falls within the natural production region, then based on the gas logging data of the reservoir to be evaluated, calculate the three parameters of C2 / ∑Ci, C3 / ∑Ci, and C4 / ∑Ci for each sampling point of each layer, and draw a triangular graph with the three parameters as vertices. If more than 80% of the data points fall within the natural production region statistically obtained in the first graph, the layer can be naturally produced; if more than 80% of the data points fall within the non-production region statistically obtained in the first graph, the reservoir does not have the ability to be naturally produced.

[0100] The qualitative evaluation method for the natural production capacity of a reservoir provided in this embodiment does not require the addition of new technical means. For the first time, it realizes the qualitative judgment of whether a reservoir can produce naturally without fracturing based on the fusion of logging and well data. This can improve the timeliness of the judgment, reduce the evaluation cost, and provide strong support for the formulation of oil field development plans and cost reduction and efficiency improvement.

[0101] Example 2:

[0102] This embodiment provides a qualitative evaluation method for the natural production capacity of a reservoir, and the qualitative evaluation method for the natural production capacity of a reservoir includes:

[0103] (1) Collect conventional logging curves such as natural gamma ray (GR), density (DEN), spontaneous potential (SP), and deep induction resistivity (ILD), porosity (POR) interpretation results, and gas logging data from 21 sandstone and mudstone wells in a certain area (10 wells can be put into production naturally and 11 wells cannot be put into production naturally);

[0104] The area is a land gas reservoir. According to the standard, it can be put into natural production if it can produce more than 0.5×104m3 / d stably for more than one month. Otherwise, it is considered that it cannot be put into natural production.

[0105] (2) For reservoirs that can be put into production naturally and those that cannot be put into production naturally, the pure water layer is excluded and the representative SP value of the reservoir section is read: the abnormal points are excluded and arranged from small to large. The mud used in this area is fresh water mud. The average value of the first 20% of the data is selected as the representative value SP1 of this layer. The SP mean value of a large set (thickness greater than 5m) of stable mudstone sections is read as the mudstone baseline value SP2. ΔSP = |SP1-SP2|. The mudstone baseline value of each well is fixed, but it is slightly different for different wells.

[0106] (3) For reservoirs that can be put into production naturally and those that cannot be put into production naturally, the pure water layer is eliminated, and 1 / 10 of the data at the top and bottom of the reservoir layer is removed. The remaining data is averaged to obtain the layers that can be put into production naturally and those that cannot be put into production naturally.

[0107] Representative values ​​of POR, DEN and ILD, based on which X1 = POR × ΔSP / 100 representing physical properties and permeability and X2 = 100 × DEN / ILD representing physical properties and oil and gas content are calculated;

[0108] (4) Figure 2 As shown, the intersection diagram is made with the two physical quantities X1 and X2 as the coordinate axes. According to the statistical law, the area where the layer that can be put into production naturally is located (the shaded part in the figure) is divided. All the wells that can be put into production naturally fall in this area, and there are 2 wells that cannot be put into production naturally in this area, accounting for 2 / 11 = 18.2% of the total number of layers, which is less than 20%;

[0109] (5) Based on the gas logging data, for each layer that can be naturally put into production and each layer that cannot be naturally put into production, calculate the three parameters of C2 / ∑Ci, C3 / ∑Ci, and C4 / ∑Ci for each sampling point, draw a triangular chart with the three parameters as vertices, and count the area where the layers that can be naturally put into production fall. For example, Figure 3 , Figure 4 As shown, more than 80% of the data points of the wells that can be naturally put into production fall within the shaded area of the triangular chart, and more than 80% of the data points of the wells that cannot be naturally put into production fall in the non-shaded area of the triangular chart;

[0110] (6) For Well A1 whose natural production ability is unknown, first calculate X1 and X2 according to steps (2) and (3). X1 = 3.8, X2 = 15.8, and plot the point into the chart drawn in step (4) (as Figure 5 shown). It can be seen that the reservoir section of this well falls within the shaded area of the cross plot. Then calculate the three parameters of C2 / ∑Ci, C3 / ∑Ci, and C4 / ∑Ci according to step (5). 80% of the points fall within the area where natural production can occur in the triangular chart ( Figure 5 ). In summary, it is determined that this well has the ability of natural production;

[0111] (6) For Well A2 whose natural production ability is unknown, first calculate X1 and X2 according to steps (2) and (3). X1 = 2.4, X2 = 29.3, and plot the point into the chart drawn in step (4) (as Figure 6 shown). It can be seen that the reservoir section of this well falls outside the cross plot. It is determined that this well does not have the ability of natural production and needs to be fractured for transformation.

[0112] The qualitative evaluation method for the natural production ability of the reservoir provided in this embodiment does not require adding new technical means, and for the first time realizes the qualitative discrimination of whether the reservoir can produce naturally without fracturing based on the integration of logging and gas logging data. It can improve the timeliness of discrimination, reduce the evaluation cost, and provide strong support for the formulation of reservoir development plans and cost reduction and efficiency improvement.

[0113] Example 3:

[0114] This embodiment provides a qualitative evaluation device 100 for the natural production ability of a reservoir, as Figure 7 shown. The qualitative evaluation device 100 for the natural production ability of the reservoir includes: a data acquisition unit 10, an image drawing unit 20, and a data processing unit 30. Among them,

[0115] The data acquisition unit 10 is used to acquire the logging curves and gas logging data of all logging and gas logging in the target area; acquire the logging curves and gas logging data of the reservoir to be evaluated;

[0116] The image drawing unit 20 is used to draw a cross-plot based on the logging curve of the logging, and divide the first area where the reservoir that can be put into production naturally is located in the cross-plot; draw a first map based on the logging gas logging data of the logging, and count the second area where the reservoir that can be put into production naturally is located in the first map; and draw a second map based on the gas logging data of the reservoir to be evaluated;

[0117] The data processing unit 30 is used to obtain a first permeability parameter and a first oil and gas content parameter based on the logging curve of the reservoir to be evaluated, project the permeability parameter and the oil and gas content parameter into the intersection diagram, and determine whether the projected points fall in the first area; and / or, to determine whether a preset number of data points in the second map fall in the second area; if so, the reservoir to be evaluated is a reservoir that can be put into production naturally; if not, the reservoir to be evaluated is a reservoir that cannot be put into production naturally.

[0118] Furthermore, the logging curve of the well logging includes a first natural potential curve; the data processing unit 30 is also used to obtain a first natural potential difference of the non-pure water layer reservoir section in the well logging reservoir for the reservoir that can be naturally put into production and the reservoir that cannot be naturally put into production based on the first natural potential curve; obtain the first parameter representative value of each logging curve of the reservoir that can be naturally put into production and the reservoir that cannot be naturally put into production, and obtain a second permeability parameter and a second oil and gas content parameter based on the first parameter representative value and the first natural potential difference; the image drawing unit 20 is also used to draw an intersection diagram based on the second permeability parameter and the second oil and gas content parameter.

[0119] Furthermore, the data acquisition unit 30 is also used to read the natural potential value in the reservoir of the logging and well logging, eliminate abnormal points, and arrange them in a preset order; the data processing unit 30 is also used to select a preset number of arranged data according to a preset position, and take the average value as the representative value of the first natural potential; obtain the mean value of the natural potential of the stable mudstone section with a thickness greater than a preset threshold as the mudstone baseline value; take the absolute value of the difference between the representative value of the first natural potential and the mudstone baseline value as the first natural potential difference.

[0120] Furthermore, the logging curve includes: a first porosity curve, a first density curve and a first deep induction resistivity curve; the data processing unit 30 is also used to obtain the first porosity representative value, the first density representative value and the first deep induction resistivity representative value of the reservoir that can be put into production naturally and the non-pure water layer section of the reservoir that cannot be put into production naturally, respectively.

[0121] Further, the data processing unit 30 is further configured to obtain the second seepage capacity parameter based on the first natural potential difference and the representative value of the first porosity; and obtain the second oil and gas bearing property parameter based on the representative value of the first density and the representative value of the first deep induction resistivity curve. Specifically, the seepage capacity parameter is X1 = porosity × ΔSP / 100, which characterizes physical properties and seepage capacity; the oil and gas bearing property parameter is X2 = 100 × density / deep induction resistivity, which characterizes physical properties and oil and gas bearing properties.

[0122] Further, the qualitative evaluation device for the natural production capacity of the reservoir further includes a data sampling unit 40; the data sampling unit 40 is configured to sample each layer of the reservoir that can be naturally produced and the reservoir that cannot be naturally produced based on the logging gas measurement data of the logging, so as to obtain multiple sampling points in each layer; the image drawing unit 20 is further configured to draw a first chart based on the multiple sampling points obtained in each layer. Specifically, the data processing unit 30 is further configured to sample each layer of the reservoir that can be naturally produced and the reservoir that cannot be naturally produced based on the logging gas measurement data of the logging, so as to obtain three sampling points in each layer, and obtain the proportional parameters of the three sampling points based on the three sampling points; the image drawing unit 20 is further configured to draw a triangular chart with the proportional parameters of the three sampling points as vertices.

[0123] Further, the data processing unit 30 is further configured to obtain the second natural potential difference of the non-pure water layer reservoir section of the reservoir to be evaluated based on the second natural potential curve; obtain the representative value of the second parameter of each logging curve of the reservoir to be evaluated, and obtain the first seepage capacity parameter and the first oil and gas bearing property parameter based on the representative value of the second parameter and the second natural potential difference.

[0124] Further, the data sampling unit 40 is further configured to sample the reservoir to be evaluated based on the logging gas measurement data of the reservoir to be evaluated, so as to obtain multiple sampling points; the image drawing unit 20 is further configured to draw a second chart based on the multiple sampling points obtained in the reservoir to be evaluated.

[0125] Example 4:

[0126] This embodiment provides an electronic device, which may be a mobile phone, a computer, a tablet computer, etc., including a memory and a processor. A computer program is stored on the memory, and when the computer program is executed by the processor, the drilling temperature prediction method described in Embodiment 1 is implemented. It can be understood that the electronic device may further include an input / output (I / O) interface and a communication component.

[0127] Among them, the processor is used to execute all or part of the steps in the drilling temperature prediction method in the first embodiment. The memory is used to store various types of data, which may include, for example, instructions of any application or method in the electronic device, as well as application-related data.

[0128] The processor can be implemented by an application specific integrated circuit (ASIC), a digital signal processor (DSP), a programmable logic device (PLD), a field programmable gate array (FPGA), a controller, a microcontroller, a microprocessor or other electronic components, and is used to execute the drilling temperature prediction method in the first embodiment above.

[0129] The memory can be implemented by any type of volatile or non-volatile storage device or a combination thereof, such as a static random access memory (SRAM), an electrically erasable programmable read-only memory (EEPROM), an erasable programmable read-only memory (EPROM), a programmable read-only memory (PROM), a read-only memory (ROM), a magnetic memory, a flash memory, a magnetic disk or an optical disk.

[0130] The execution of the drilling temperature prediction method based on the above modules includes:

[0131] Step 01: Obtain the logging curves and mud logging gas logging data of all logging wells in the target area; the logging wells include: logging wells that can be put into production naturally and logging wells that cannot be put into production naturally.

[0132] Whether a logging well can be put into production naturally depends on actual production data and is judged according to the reservoir conditions.

[0133] The logging curves include natural gamma, natural potential, density, neutron, acoustic wave, deep induction resistivity curve, interpreted porosity curve, reservoir division and fluid conclusion, etc.

[0134] The logging gas measurement data includes the calibration of hydrocarbon components C1, C2, C3, and C4.

[0135] Step 02: Draw a crossplot based on the logging curves of the logging and well logging, and divide the first region where the reservoir that can be naturally put into production is located in the crossplot.

[0136] The logging curves of the logging and well logging include the first spontaneous potential curve.

[0137] The drawing of the crossplot based on the logging curves of the logging and well logging includes:

[0138] Step 021: For the reservoir that can be naturally put into production and the reservoir that cannot be naturally put into production, obtain the first spontaneous potential difference of the non-pure water layer reservoir section in the logging and well logging reservoir based on the first spontaneous potential curve;

[0139] Among them, the obtaining of the first spontaneous potential difference of the non-pure water layer reservoir section in the logging and well logging reservoir based on the first spontaneous potential curve includes:

[0140] Step 0211: Read the spontaneous potential values in the reservoir of the logging and well logging, eliminate the abnormal points, and arrange them in a preset order;

[0141] Step 0212: Select a preset number of data after arrangement according to a preset position, and take the average value as the representative value of the first spontaneous potential;

[0142] Step 0213: Obtain the average value of the spontaneous potential of the stable mudstone section with a thickness greater than a preset threshold as the mudstone baseline value;

[0143] Step 0214: Take the absolute value of the difference between the representative value of the first spontaneous potential and the mudstone baseline value as the first spontaneous potential difference.

[0144] Optionally, read the spontaneous potential values in the reservoir of the logging and well logging, eliminate the abnormal points, and arrange them from small to large. For fresh water mud, select the average value of the first 20% data as the representative value of the spontaneous potential of this layer SP1; for salt water mud, select the average value of the last 20% data as the representative value of the spontaneous potential of this layer SP1; read the average value of the spontaneous potential SP of the large set (thickness greater than a certain threshold) of stable mudstone section as the mudstone baseline value SP2. Therefore, the first spontaneous potential difference ΔSP = |SP1 - SP2|.

[0145] Step 022: Obtain the first parameter representative values of the logging curves of the reservoir that can be naturally put into production and the reservoir that cannot be naturally put into production, and obtain the second seepage capacity parameter and the second oil and gas bearing property parameter based on the first parameter representative value and the first spontaneous potential difference.

[0146] Among them, the logging curves include: the first porosity curve, the first density curve, and the first deep induction resistivity curve;

[0147] Obtaining the first parameter representative values of the logging curves of the reservoir capable of natural production and the reservoir incapable of natural production includes: respectively obtaining the first porosity representative value, the first density representative value, and the first deep induction resistivity representative value of the non-pure water layer sections of the reservoir capable of natural production and the reservoir incapable of natural production.

[0148] Based on the first parameter representative values and the first natural potential difference to obtain the second seepage capacity parameter and the second oil and gas bearing property parameter includes: obtaining the second seepage capacity parameter based on the first natural potential difference and the first porosity representative value; obtaining the second oil and gas bearing property parameter based on the first density representative value and the first deep induction resistivity curve representative value.

[0149] Specifically, respectively read the representative values of the porosity curve, density curve, and deep induction resistivity curve of the non-pure water layer sections capable of natural production and incapable of natural production, and calculate the seepage capacity parameter and the oil and gas bearing property parameter based on each representative value. The seepage capacity parameter is X1 = porosity × ΔSP / 100, which characterizes physical properties and seepage capacity; the oil and gas bearing property parameter is X2 = 100 × density / deep induction resistivity, which characterizes physical properties and oil and gas bearing properties.

[0150] Among them, the method for reading the representative value is as follows: remove 1 / 10 of the data from the top and bottom of the layer, and calculate the average value of the remaining data (excluding abnormal points).

[0151] Step 023: Draw a cross plot based on the second seepage capacity parameter and the second oil and gas bearing property parameter.

[0152] Use the two physical quantities X1 and X2 in the above steps as the coordinate axes to draw a cross plot. According to the statistical law, divide the area where the reservoir capable of natural production is located. Optionally, all reservoir positions capable of natural production should be covered in the natural production area, and the number of wells incapable of natural production in the natural production area should be less than 20% of the number of layers.

[0153] Step 03: Draw the first chart based on the logging gas measurement data of the logging and well logging, and count the second area where the reservoir capable of natural production is located in the first chart.

[0154] Among them, drawing the first chart based on the logging gas measurement data of the logging and well logging includes:

[0155] Step 031: Sample each layer of the reservoir capable of natural production and the reservoir incapable of natural production based on the logging gas measurement data of the logging and well logging to obtain multiple sampling points in each layer;

[0156] Step 032: Draw the first chart based on the multiple sampling points obtained in each layer.

[0157] Specifically, drawing the first graph based on the well logging gas logging data of the logging while drilling includes: sampling each layer of the reservoir that can be naturally put into production and the reservoir that cannot be naturally put into production based on the well logging gas logging data of the logging while drilling to obtain three sampling points in each layer; obtaining the proportional parameters of the three sampling points based on the three sampling points, and drawing a triangular graph with the proportional parameters of the three sampling points as vertices.

[0158] Based on the gas logging data of the logging while drilling, calculate three parameters of C2 / ∑Ci, C3 / ∑Ci, and C4 / ∑Ci for each sampling point of the layer that can be naturally put into production and the layer that cannot be naturally put into production, draw a triangular graph with the three parameters as vertices, and count the area where the layer that can be naturally put into production falls.

[0159] Step 04: Obtain the well logging curves and the well logging gas logging data of the reservoir to be evaluated.

[0160] As described in step 01, the well logging curves of the reservoir to be evaluated include the natural gamma ray, spontaneous potential, density, neutron, acoustic wave, deep induction resistivity curve, interpreted porosity curve, reservoir division and fluid conclusion, etc. of the reservoir to be evaluated.

[0161] The well logging gas logging data of the reservoir to be evaluated includes the calibration of C1, C2, C3, and C4 hydrocarbon components of the reservoir to be evaluated.

[0162] Step 05: Obtain the first seepage capacity parameter and the first oil and gas bearing property parameter based on the well logging curves of the reservoir to be evaluated, project the seepage capacity parameter and the oil and gas bearing property parameter onto the cross plot, and determine whether the projected point falls within the first area.

[0163] Among them, the well logging curves of the reservoir to be evaluated include the second spontaneous potential curve;

[0164] Obtaining the first seepage capacity parameter and the first oil and gas bearing property parameter based on the well logging curves of the reservoir to be evaluated includes:

[0165] Step 051: Obtain the second spontaneous potential difference of the non-pure water layer reservoir section of the reservoir to be evaluated based on the second spontaneous potential curve.

[0166] Step 052: Obtain the second parameter representative values of each well logging curve of the reservoir to be evaluated, and obtain the first seepage capacity parameter and the first oil and gas bearing property parameter based on the second parameter representative values and the second spontaneous potential difference.

[0167] The method for obtaining the second spontaneous potential difference, the first seepage capacity parameter, and the first oil and gas bearing property parameter in step 05 is similar to that in step 02, and will not be elaborated here.

[0168] Step 06: If the dropped point falls within the first region, draw a second plot based on the gas logging data of the reservoir to be evaluated, and determine whether a preset number of data points in the second plot fall within the second region. If so, the reservoir to be evaluated is a reservoir that can be naturally put into production; if not, the reservoir to be evaluated is a reservoir that cannot be naturally put into production.

[0169] Among them, drawing the second plot based on the gas logging data of the reservoir to be evaluated includes:

[0170] Step 061: Sample the reservoir to be evaluated based on the logging gas measurement data of the reservoir to be evaluated to obtain multiple sampling points;

[0171] Step 062: Draw a second plot based on the multiple sampling points obtained from the reservoir to be evaluated.

[0172] For a reservoir to be evaluated, we do not know whether it is a reservoir that can be naturally put into production. First, calculate the first seepage capacity parameter and the first oil and gas bearing property parameter according to the method in step 05, and then drop the point into the cross plot. In the cross plot, if the dropped point falls within the non-naturally put into production region, the reservoir does not have the ability to be naturally put into production; if it falls within the region where it can be naturally put into production, then based on the gas logging data of the reservoir to be evaluated, calculate the three parameters of C2 / ∑Ci, C3 / ∑Ci, and C4 / ∑Ci for each sampling point layer by layer, and draw a triangular plot with the three parameters as vertices. If more than 80% of the data points fall within the region where it can be naturally put into production statistically in the first plot, then this layer can be naturally put into production; if more than 80% of the data points fall within the region where it cannot be put into production statistically in the first plot, then the reservoir does not have the ability to be naturally put into production.

[0173] The qualitative evaluation method for the natural production capacity of the reservoir provided in this embodiment does not require adding new technical means, and for the first time realizes the qualitative discrimination of whether the reservoir can produce naturally without fracturing based on the integration of logging data, which can improve the timeliness of discrimination, reduce the evaluation cost, and provide strong support for the formulation of the reservoir development plan and cost reduction and efficiency increase.

[0174] Example 5:

[0175] This embodiment also provides a computer-readable storage medium. In each embodiment of the present invention, each functional unit can be integrated into a processing unit, or each unit can exist physically alone, or two or more units can be integrated into one unit. If the function 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.

[0176] Based on such understanding, the technical solution of the present invention, in essence, or the part that contributes to the prior art, or a part of the technical solution, can be embodied in the form of a software product. The computer software product is stored in a storage medium and includes several instructions for causing a computer device (which may be a personal computer, a server, or a network device, etc.) to execute all or part of the steps of the methods described in various embodiments of the present invention.

[0177] The foregoing storage medium includes: flash memory, hard disk, multimedia card, card-type memory (such as SD or DX memory, etc.), random access memory (RAM), static random access memory (SRAM), read-only memory (ROM), electrically erasable programmable read-only memory (EEPROM), programmable read-only memory (PROM), magnetic memory, magnetic disk, optical disk, server, APP application mall, and other various media that can store program check codes. A computer program is stored thereon, and when the computer program is executed by a processor, the following method steps can be implemented:

[0178] Step 01: Obtain well logging curves and mud logging gas logging data of all well logging and mud logging in the target area; the well logging and mud logging include: well logging and mud logging that can be put into production naturally and well logging and mud logging that cannot be put into production naturally.

[0179] Whether the well logging and mud logging can be put into production naturally depends on actual production data and is judged according to reservoir conditions.

[0180] The well logging curves include natural gamma, spontaneous potential, density, neutron, acoustic wave, deep induction resistivity curve, interpreted porosity curve, reservoir division and fluid conclusion, etc.

[0181] The mud logging gas logging data includes calibration of C1, C2, C3, and C4 hydrocarbon components.

[0182] Step 02: Draw a cross plot based on the well logging curves of the well logging and mud logging, and divide the first area where the reservoir that can be put into production naturally is located in the cross plot.

[0183] The well logging curves of the well logging and mud logging include a first spontaneous potential curve.

[0184] The drawing of the cross plot based on the well logging curves of the well logging and mud logging includes:

[0185] Step 021: For the reservoir that can be put into production naturally and the reservoir that cannot be put into production naturally, obtain the first spontaneous potential difference of the non-pure water layer reservoir section in the well logging and mud logging reservoir based on the first spontaneous potential curve;

[0186] Among them, the obtaining of the first spontaneous potential difference of the non-pure water layer reservoir section in the well logging and mud logging reservoir based on the first spontaneous potential curve includes:

[0187] Step 0211: Read the spontaneous potential values in the reservoir of the logging data, eliminate the abnormal points, and arrange them in a preset order.

[0188] Step 0212: Select a preset number of data after arrangement according to a preset position, and take the average value as the representative value of the first spontaneous potential.

[0189] Step 0213: Obtain the average value of the spontaneous potential of the stable mudstone section with a thickness greater than a preset threshold as the mudstone baseline value.

[0190] Step 0214: Take the absolute value of the difference between the representative value of the first spontaneous potential and the mudstone baseline value as the first spontaneous potential difference.

[0191] Optionally, read the spontaneous potential values in the reservoir of the logging data, eliminate the abnormal points, and arrange them from small to large. For fresh mud, select the average value of the first 20% of the data as the representative value SP1 of the spontaneous potential of this layer; for salt mud, select the average value of the last 20% of the data as the representative value SP1 of the spontaneous potential of this layer; read the average value SP of the spontaneous potential of the large set (thickness greater than a certain threshold) of stable mudstone sections as the mudstone baseline value SP2. Therefore, the first spontaneous potential difference ΔSP = |SP1 - SP2|.

[0192] Step 022: Obtain the first parameter representative values of each logging curve of the reservoir that can be naturally put into production and the reservoir that cannot be naturally put into production, and obtain the second seepage capacity parameter and the second oil and gas bearing property parameter based on the first parameter representative value and the first spontaneous potential difference.

[0193] Among them, the logging curves include: the first porosity curve, the first density curve, and the first deep induction resistivity curve.

[0194] The obtaining of the first parameter representative values of each logging curve of the reservoir that can be naturally put into production and the reservoir that cannot be naturally put into production includes: respectively obtaining the first porosity representative value, the first density representative value, and the first deep induction resistivity representative value of the non-pure water layer section of the reservoir that can be naturally put into production and the reservoir that cannot be naturally put into production.

[0195] The obtaining of the second seepage capacity parameter and the second oil and gas bearing property parameter based on the first parameter representative value and the first spontaneous potential difference includes: obtaining the second seepage capacity parameter based on the first spontaneous potential difference and the first porosity representative value; obtaining the second oil and gas bearing property parameter based on the first density representative value and the representative value of the first deep induction resistivity curve.

[0196] Specifically, representative values of the porosity curve, density curve, and deep induction resistivity curve of the non-pure water layer sections that can and cannot be naturally put into production are read separately, and the seepage capacity parameter and oil and gas bearing property parameter are calculated based on each representative value. The seepage capacity parameter is X1 = porosity × ΔSP / 100, which characterizes the physical property and seepage capacity; the oil and gas bearing property parameter is X2 = 100 × density / deep induction resistivity, which characterizes the physical property and oil and gas bearing property.

[0197] Among them, the method for reading the representative value is as follows: 1 / 10 of the data at the top and bottom of the layer is removed respectively, and the average value of the remaining data (abnormal points are excluded) is calculated.

[0198] Step 023: Draw a cross plot based on the second seepage capacity parameter and the second oil and gas bearing property parameter.

[0199] Using the two physical quantities X1 and X2 in the above steps as the coordinate axes respectively to draw a cross plot, according to the statistical law, the area where the reservoir that can be naturally put into production is located is divided. Optionally, all reservoir positions that can be naturally put into production should be covered in the natural production area, and the number of wells that cannot be naturally put into production in the natural production area should be less than 20% of the number of layers.

[0200] Step 03: Draw the first chart based on the logging gas measurement data of the logging and well logging, and count the second area where the reservoir that can be naturally put into production is located in the first chart.

[0201] Among them, the drawing of the first chart based on the logging gas measurement data of the logging and well logging includes:

[0202] Step 031: Sample each layer of the reservoir that can be naturally put into production and the reservoir that cannot be naturally put into production based on the logging gas measurement data of the logging and well logging, so as to obtain multiple sampling points in each layer;

[0203] Step 032: Draw the first chart based on the multiple sampling points obtained in each layer.

[0204] Specifically, the drawing of the first chart based on the logging gas measurement data of the logging and well logging includes: sampling each layer of the reservoir that can be naturally put into production and the reservoir that cannot be naturally put into production based on the logging gas measurement data of the logging and well logging, so as to obtain three sampling points in each layer; obtaining the proportional parameters of the three sampling points based on the three sampling points, and drawing a triangular chart with the proportional parameters of the three sampling points as the vertices.

[0205] Based on the gas logging data, for each layer of the layer that can be naturally put into production and the layer that cannot be naturally put into production, calculate three parameters of C2 / ∑Ci, C3 / ∑Ci, and C4 / ∑Ci for each sampling point, draw a triangular chart with the three parameters as the vertices, and count the area where the layer that can be naturally put into production is located.

[0206] Step 04: Obtain the well logging curves and mud logging gas logging data of the reservoir to be evaluated.

[0207] As described in Step 01, the well logging curves of the reservoir to be evaluated include the natural gamma, spontaneous potential, density, neutron, acoustic wave, deep induction resistivity curve, interpreted porosity curve, reservoir division and fluid conclusion, etc. of the reservoir to be evaluated.

[0208] The mud logging gas logging data of the reservoir to be evaluated includes the calibration of C1, C2, C3, and C4 hydrocarbon components of the reservoir to be evaluated.

[0209] Step 05: Obtain the first seepage capacity parameter and the first hydrocarbon-bearing property parameter based on the well logging curves of the reservoir to be evaluated, plot the seepage capacity parameter and the hydrocarbon-bearing property parameter on the cross plot, and determine whether the plotted point falls within the first region.

[0210] Among them, the well logging curves of the reservoir to be evaluated include the second spontaneous potential curve;

[0211] Obtaining the first seepage capacity parameter and the first hydrocarbon-bearing property parameter based on the well logging curves of the reservoir to be evaluated includes:

[0212] Step 051: Obtain the second spontaneous potential difference of the non-pure water layer reservoir section of the reservoir to be evaluated based on the second spontaneous potential curve.

[0213] Step 052: Obtain the second parameter representative values of each well logging curve of the reservoir to be evaluated, and obtain the first seepage capacity parameter and the first hydrocarbon-bearing property parameter based on the second parameter representative values and the second spontaneous potential difference.

[0214] The method for obtaining the second spontaneous potential difference, the first seepage capacity parameter, and the first hydrocarbon-bearing property parameter in Step 05 is similar to that in Step 02, and will not be elaborated here.

[0215] Step 06: If the plotted point falls within the first region, draw a second chart based on the gas logging data of the reservoir to be evaluated, and determine whether a preset number of data points in the second chart fall within the second region. If so, the reservoir to be evaluated is a reservoir that can be naturally put into production; if not, the reservoir to be evaluated is a reservoir that cannot be naturally put into production.

[0216] Among them, drawing the second chart based on the gas logging data of the reservoir to be evaluated includes:

[0217] Step 061: Sample the reservoir to be evaluated based on the mud logging gas logging data of the reservoir to be evaluated to obtain multiple sampling points;

[0218] Step 062: Draw a second chart based on the multiple sampling points obtained from the reservoir to be evaluated.

[0219] For a reservoir to be evaluated, we do not know whether it is a layer that can be naturally put into production. First, calculate the first seepage capacity parameter and the first oil and gas bearing property parameter according to the method in step 05, and then plot the points on the step cross plot. In the cross plot, if the plotted points fall in the non-naturally producing area, then this reservoir does not have the ability to be naturally put into production; if they fall in the area where it can be naturally put into production, then based on the gas logging data of the reservoir to be evaluated, calculate the three parameters of C2 / ∑Ci, C3 / ∑Ci, and C4 / ∑Ci for each sampling point of each layer, and draw a triangular plot with the three parameters as vertices. If more than 80% of the data points fall in the area where it can be naturally put into production statistically obtained in the first plot, then this layer can be naturally put into production; if more than 80% of the data points fall in the area where it cannot be put into production statistically obtained in the first plot, then this reservoir does not have the ability to be naturally put into production.

[0220] The qualitative evaluation method for the natural production capacity of the reservoir provided in this embodiment does not require adding new technical means, and for the first time realizes the qualitative discrimination of whether the reservoir can produce naturally without fracturing based on the integration of logging data, which can improve the timeliness of discrimination, reduce the evaluation cost, and provide strong support for the formulation of reservoir development plans and cost reduction and efficiency increase.

[0221] Those of ordinary skill in the art can realize that the units and algorithm steps of each example described in combination with the embodiments disclosed herein can be implemented by electronic hardware, or a combination of computer software and electronic hardware. Whether these functions are executed in a hardware or software manner depends on the specific application and design constraints of the technical solution. Professional technicians 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 present invention. Those skilled in the art can clearly understand that for the convenience and conciseness of description, the specific working processes of the systems, devices, and units described above can refer to the corresponding processes in the foregoing method embodiments, and will not be repeated here.

[0222] In several embodiments provided by this application, 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 merely illustrative. For example, the division of the units is only a logical function division. In actual implementation, there may be other division methods. For example, multiple units or components can be combined or integrated into another system, or some features can be ignored or not executed. Another point is that the displayed or discussed couplings or direct couplings or communication connections to each other can be through some interfaces. The indirect couplings or communication connections of the devices or units can be in electrical, mechanical, or other forms. The units described as separate components may or may not be physically separated. The components displayed as units may or may not be physical units, that is, they can be located in one place or distributed to multiple network units. Some or all of the units can be selected according to actual needs to achieve the purpose of the solution of this embodiment.

[0223] The basic principles of this application have been described above in conjunction with specific embodiments. However, it should be noted that the advantages, benefits, effects, etc. mentioned in this application are only examples and not limitations. It cannot be considered that these advantages, benefits, effects, etc. are essential for each embodiment of this application. In addition, the above-disclosed specific details are only for the purposes of illustration and facilitating understanding, rather than limitations. These details do not limit this application to necessarily adopt the above specific details for implementation.

[0224] The block diagrams of the devices, apparatuses, equipment, and systems involved in this application are only illustrative examples and do not intend to require or imply that they must be connected, arranged, and configured in the manner shown in the block diagrams. As those skilled in the art will recognize, these devices, apparatuses, equipment, and systems can be connected, arranged, and configured in any way.

[0225] It should also be noted that in the devices, equipment, and methods of this application, each component or each step can be decomposed and / or recombined. These decompositions and / or recombinations should be regarded as equivalent solutions of this application.

[0226] The above description of the disclosed aspects enables any person skilled in the art to make or use this application. Various modifications to these aspects are very obvious to those skilled in the art, and the general principles defined herein can be applied to other aspects without departing from the scope of this application. Therefore, this application is not intended to be limited to the aspects shown herein, but rather to the broadest scope consistent with the principles and novel features disclosed herein.

[0227] In the description of this application, the meaning of "a plurality of" is at least two, such as two, three, etc., unless otherwise specifically defined. In the embodiments of this application, all directional indications (such as up, down, left, right, front, back, top, bottom...) are only used to explain the relative positional relationship and movement conditions between components in a specific posture (as shown in the drawings). If the specific posture changes, the directional indications will also change accordingly. In addition, the terms "comprising" and "having" and any variations thereof are intended to cover non-exclusive inclusion. For example, a process, method, system, product or device that includes a series of steps or units is not limited to the listed steps or units, but optionally also includes steps or units not listed, or optionally also includes other steps or units inherent to these processes, methods, products or devices.

[0228] In addition, referring to "embodiments" herein means that the specific features, structures or characteristics described in connection with the embodiments may be included in at least one embodiment of this application. The phrase appears in various places in the specification and does not necessarily refer to the same embodiment, nor is it an independent or alternative embodiment mutually exclusive with other embodiments. Those skilled in the art will explicitly and implicitly understand that the embodiments described herein may be combined with other embodiments.

[0229] As described above, it is only the specific implementation manner of the present invention, but the protection scope of the present invention is not limited thereto. Any person skilled in the art can easily think of changes or substitutions within the technical scope disclosed by the present invention, and all should be covered by the protection scope of the present invention. Therefore, the protection scope of the present invention should be subject to the protection scope of the claims. The above is only a preferred embodiment of the present invention and is not intended to limit the present invention. Any modifications, equivalent substitutions, etc. made within the spirit and principle of the present invention should be included in the protection scope of the present invention.

Claims

1. A qualitative evaluation method for the natural production capacity of a reservoir, characterized in that, Including: Obtaining well logging curves and mud logging gas logging data of all well logging and mud logging in the target area; The well logging and mud logging include: well logging and mud logging that can be naturally put into production and well logging and mud logging that cannot be naturally put into production; Drawing a cross plot based on the well logging curves of the well logging and mud logging, and dividing a first area where the reservoir that can be naturally put into production is located in the cross plot; Drawing a first chart based on the mud logging gas logging data of the well logging and mud logging, and counting a second area where the reservoir that can be naturally put into production is located in the first chart; Obtaining well logging curves and mud logging gas logging data of the reservoir to be evaluated; Obtaining a first seepage capacity parameter and a first oil and gas bearing property parameter based on the well logging curves of the reservoir to be evaluated, plotting the seepage capacity parameter and the oil and gas bearing property parameter on the cross plot, and determining whether the plotted point falls within the first area; If the plotted point falls within the first area, drawing a second chart based on the gas logging data of the reservoir to be evaluated, and determining whether a preset number of data points in the second chart fall within the second area. If so, the reservoir to be evaluated is a reservoir that can be naturally put into production; if not, the reservoir to be evaluated is a reservoir that cannot be naturally put into production.

2. The qualitative evaluation method for the natural production capacity of a reservoir according to claim 1, characterized in that The well logging curves of the well logging and mud logging include a first spontaneous potential curve; The drawing of the cross plot based on the well logging curves of the well logging and mud logging includes: For the reservoir that can be naturally put into production and the reservoir that cannot be naturally put into production, obtaining a first spontaneous potential difference of the non-pure water layer reservoir section in the well logging reservoir based on the first spontaneous potential curve; Obtaining first parameter representative values of each well logging curve of the reservoir that can be naturally put into production and the reservoir that cannot be naturally put into production, and obtaining a second seepage capacity parameter and a second oil and gas bearing property parameter based on the first parameter representative values and the first spontaneous potential difference; Drawing a cross plot based on the second seepage capacity parameter and the second oil and gas bearing property parameter.

3. The qualitative evaluation method for the natural production capacity of a reservoir according to claim 2, characterized in that The obtaining of the first spontaneous potential difference of the non-pure water layer reservoir section in the well logging reservoir based on the first spontaneous potential curve includes: Reading the spontaneous potential values in the reservoir of the well logging and mud logging, eliminating abnormal points, and arranging them in a preset order; Selecting a preset number of data after arrangement according to a preset position, and taking the average value as the representative value of the first spontaneous potential; Obtaining the average value of the spontaneous potential of the stable mudstone section with a thickness greater than a preset threshold as the mudstone baseline value; Taking the absolute value of the difference between the representative value of the first spontaneous potential and the mudstone baseline value as the first spontaneous potential difference.

4. The qualitative evaluation method for the natural production capacity of a reservoir according to claim 2, characterized in that, The well logging curves include: a first porosity curve, a first density curve, and a first deep induction resistivity curve; The obtaining of the first parameter representative values of each well logging curve of the reservoir that can be naturally put into production and the reservoir that cannot be naturally put into production includes: respectively obtaining the first porosity representative value, the first density representative value, and the first deep induction resistivity representative value of the non-pure water layer section of the reservoir that can be naturally put into production and the reservoir that cannot be naturally put into production.

5. The qualitative evaluation method for the natural production capacity of a reservoir according to claim 4, characterized in that, The obtaining of the second seepage capacity parameter and the second oil and gas bearing property parameter based on the first parameter representative values and the first spontaneous potential difference includes: Obtaining the second seepage capacity parameter based on the first spontaneous potential difference and the first porosity representative value; The second hydrocarbon-bearing parameter is obtained based on the first density representative value and the first deep induction resistivity curve representative value.

6. The qualitative evaluation method for the natural production capacity of a reservoir according to claim 1, characterized in that, The method of drawing the first chart based on the logging gas logging data of logging while drilling includes: Sampling each layer of the reservoir that can be naturally put into production and the reservoir that cannot be naturally put into production based on the logging gas logging data of logging while drilling, so as to obtain multiple sampling points in each layer; Drawing the first chart based on the multiple sampling points obtained in each layer.

7. The qualitative evaluation method for the natural production capacity of a reservoir according to claim 1, characterized in that, The method of drawing the first chart based on the logging gas logging data of logging while drilling includes: Sampling each layer of the reservoir that can be naturally put into production and the reservoir that cannot be naturally put into production based on the logging gas logging data of logging while drilling, so as to obtain three sampling points in each layer; Obtaining the proportional parameters of the three sampling points based on the three sampling points, and drawing a triangular chart with the proportional parameters of the three sampling points as vertices.

8. The qualitative evaluation method for the natural production capacity of a reservoir according to claim 1, characterized in that The logging curve of the reservoir to be evaluated includes a second spontaneous potential curve; Obtaining the first seepage capacity parameter and the first hydrocarbon-bearing parameter based on the logging curve of the reservoir to be evaluated, including: Obtaining the second spontaneous potential difference of the non-pure water layer reservoir section of the reservoir to be evaluated based on the second spontaneous potential curve; Obtaining the second parameter representative value of each logging curve of the reservoir to be evaluated, and obtaining the first seepage capacity parameter and the first hydrocarbon-bearing parameter based on the second parameter representative value and the second spontaneous potential difference.

9. The qualitative evaluation method for the natural production capacity of a reservoir according to claim 1, wherein Drawing the second chart based on the gas logging data of the reservoir to be evaluated, including: Sampling the reservoir to be evaluated based on the logging gas logging data of the reservoir to be evaluated to obtain multiple sampling points; Drawing the second chart based on the multiple sampling points obtained in the reservoir to be evaluated.

10. A device for qualitatively evaluating the natural production capacity of a reservoir, characterized in that, Including: A data acquisition unit for acquiring the logging curves and logging gas logging data of all logging while drilling in the target area; Obtaining the logging curves and logging gas logging data of the reservoir to be evaluated; An image drawing unit for drawing a cross plot based on the logging curves of logging while drilling, and dividing the first area where the reservoir that can be naturally put into production is located in the cross plot; drawing the first chart based on the logging gas logging data of logging while drilling, and counting the second area where the reservoir that can be naturally put into production is located in the first chart; then drawing the second chart based on the gas logging data of the reservoir to be evaluated; A data processing unit for obtaining the first seepage capacity parameter and the first hydrocarbon-bearing parameter based on the logging curves of the reservoir to be evaluated, plotting the seepage capacity parameter and the hydrocarbon-bearing parameter on the cross plot, and judging whether the plotted point falls in the first area; And / or, for judging whether a preset number of data points in the second chart fall in the second area; if so, the reservoir to be evaluated is a reservoir that can be naturally put into production; if not, the reservoir to be evaluated is a reservoir that cannot be naturally put into production.

11. An electronic device, characterized in that, Including a memory and a processor, the memory is used to store one or more computer instructions, wherein when the one or more computer instructions are executed by the processor, the qualitative evaluation method for the natural production capacity of the reservoir as described in any one of claims 1-9 above is implemented.

12. A computer-readable storage medium, characterized in that, A computer program is stored in the computer-readable storage medium, and when the computer program is executed by a processor, it is used to implement the qualitative evaluation method for the natural production capacity of a reservoir as described in any one of claims 1-9 above.

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