Multi-information fusion grey sandstone reservoir evaluation method

Abstract

The invention belongs to the field of petroleum development, particularly relates to a multi-information fusion grey sandstone reservoir evaluation method, and aims to solve the problem of low coincidence rate of a grey sandstone reservoir evaluation method in the prior art. The method comprises the steps that whether the sandstone reservoir has reservoir forming conditions or not is judged based on whether the sandstone reservoir has tectonic high points, sand body development and oil source faults or not; whether the sandstone reservoir has reservoir effectiveness or not is judged based on whether the matrix void of the sandstone reservoir is larger than a first threshold value or not and whether the depth resistivity, the medium resistivity and the shallow resistivity of the crack of the sandstone reservoir have amplitude differences or not; judging the first oiliness of the sandstone reservoir based on the rock debris color of the sandstone reservoir; judging the second oiliness of the sandstone reservoir; and when the sandstone reservoir has reservoir forming conditions and reservoir effectiveness, the first oil property is oily, and the second oil property is oily, judging that the sandstone reservoir is oily. The method improves the interpretation coincidence rate of the grey sandstone reservoir.

Description

Technical Field

[0001] This invention belongs to the field of petroleum development, and specifically relates to a multi-information fusion method for evaluating argillaceous sandstone reservoirs. Background Technology

[0002] Several oilfields in China have developed calcareous sandstone reservoirs in the Shahejie Formation. These reservoirs are characterized by tight lithology and complex pore structures, making reservoir effectiveness and fluid property evaluation a persistent challenge in oilfield development. While previous researchers have established various evaluation methods, such as core analysis and chart methods, none possess universality, and their interpretation accuracy is low. Existing calcareous sandstone reservoir evaluation methods are mainly based on two aspects: first, using conventional logging data to analyze the logging response characteristics of different lithologies, and then combining this with oil testing data to establish resistivity-density relationship charts to identify reservoir fluid properties; second, taking the tuffaceous sandstone reservoirs in the Erlian Basin's Ar Depression as a case study, based on the analysis of core test data, geological data, logging data, and their response characteristics in this area, further research has been conducted on an effective method for calculating tuff content using logging curves, thereby establishing a calculation model for physical parameters based on tuff content; and using conventional logging data to conduct calcareous sandstone reservoir evaluation. In the evaluation of the effectiveness of sandstone reservoirs, porosity and permeability are often used. However, considering the impact of fractures on reservoir effectiveness can lead to biases in the evaluation results and a decrease in the accuracy of interpretation. When using conventional well logging data for reservoir fluid identification, fluid properties are often identified by establishing a resistivity-lithology or physical property relationship chart based on well test data. However, the carbonate rock content in different layers of calcareous sandstone reservoirs has a significant impact on resistivity measurements, and the influence of lithology is often greater than that of oil content. Therefore, the accuracy of well logging interpretation based on fluid property identification charts is relatively low.

[0003] Therefore, existing methods for evaluating calcareous sandstone reservoirs suffer from low accuracy. Summary of the Invention

[0004] To address the aforementioned problems in existing technologies, namely the low accuracy of existing methods for evaluating calcareous sandstone reservoirs, this invention provides a multi-information fusion method for evaluating calcareous sandstone reservoirs, the method comprising:

[0005] The presence of structural highs, sand body development, and oil source faults in sandstone reservoirs is used to determine whether the sandstone reservoirs have the conditions for hydrocarbon accumulation.

[0006] Calculate the matrix porosity of the sandstone reservoir; determine the reservoir's effectiveness based on whether the matrix porosity of the sandstone reservoir is greater than a first threshold and whether there is an amplitude difference between the depth resistivity, intermediate resistivity, and shallow resistivity of the fractures in the sandstone reservoir.

[0007] The primary oil content of the sandstone reservoir is determined based on the color of the rock fragments.

[0008] The secondary oil content of the sandstone reservoir is determined based on the magnitude of the peak value ratio of total hydrocarbons in gas logging, the magnitude of the ethane to propane ratio, the time shift of the peak value of total hydrocarbons in gas logging, the ratio of gas components, and the ratio of derived parameters.

[0009] When the sandstone reservoir has the conditions for reservoir formation and is effective, and its first oil property is oil-bearing and its second oil property is oil-bearing, then the sandstone reservoir is determined to be oil-bearing; otherwise, it is non-oil-bearing.

[0010] In a preferred embodiment, the method for determining whether the sandstone reservoir has the conditions for hydrocarbon accumulation is as follows:

[0011] If the difference between the geological height of the sandstone reservoir and the geological height of its surrounding area is greater than a second threshold, then the sandstone reservoir has a structural high point.

[0012] If the size of the sandstone body in the sandstone reservoir is greater than the third threshold, then the sandstone reservoir has sand body development.

[0013] If the sandstone reservoir has an oil source fault, then the sandstone reservoir has an oil source fault.

[0014] If the sandstone reservoir simultaneously possesses structural highs, well-developed sand bodies, and oil-source faults, then the sandstone reservoir has the conditions for hydrocarbon accumulation.

[0015] In a preferred embodiment, the method for calculating the matrix porosity of the sandstone reservoir is as follows:

[0016] Where ΦA is the matrix porosity, Δt is the target layer acoustic transit time logging value, Δtma is the rock skeleton acoustic transit time, Δtf is the formation fluid acoustic transit time, and Cp is the compaction correction coefficient.

[0017] In a preferred embodiment, the method for determining whether the sandstone reservoir has reservoir effectiveness is as follows:

[0018] If the matrix porosity of the sandstone reservoir is greater than a first threshold and the depth resistivity, medium resistivity, and shallow resistivity of the fractures in the sandstone reservoir have amplitude differences, then the sandstone reservoir is considered to have reservoir effectiveness.

[0019] In a preferred embodiment, the method for determining that the depth resistivity, intermediate resistivity, and shallow resistivity of the fractures in the sandstone reservoir have a difference in amplitude is as follows:

[0020] If the difference between the depth resistivity and the intermediate resistivity of the fractures in the sandstone reservoir is greater than the fourth threshold, and the difference between the intermediate resistivity and the shallow resistivity of the fractures in the sandstone reservoir is greater than the fifth threshold, then the depth resistivity, intermediate resistivity, and shallow resistivity of the fractures in the sandstone reservoir have amplitude differences.

[0021] In a preferred embodiment, the method for determining the primary oil content of the sandstone reservoir is as follows:

[0022] If the rock fragments of the sandstone reservoir are gray or grayish-white, the sandstone reservoir is determined to be non-oil-bearing; if the rock fragments of the sandstone reservoir are grayish-brown, dark brown, brownish-red, or brownish-yellow, the sandstone reservoir is determined to be oil-bearing.

[0023] In a preferred embodiment, the method for determining the second oil content of the sandstone reservoir is as follows: if the sandstone reservoir meets the five conditions of gas measurement values, then the second oil content of the sandstone reservoir is oil-bearing.

[0024] In a preferred embodiment, the five conditions for the gas measurement value are a first condition, a second condition, a third condition, a fourth condition, and a fifth condition.

[0025] The first condition is that the ratio of the peak value of total hydrocarbons measured by gas analysis to the lowest value of total hydrocarbons in the upper and lower surrounding rocks is more than 3 times.

[0026] The second condition is: the ratio of ethane to propane is less than 1.4;

[0027] The third condition is: when drilling to the sandstone reservoir interface, if the delay time of the occurrence of the peak value of total hydrocarbons in the gas measurement is greater than the fourth threshold, then the sandstone reservoir is an oil-bearing layer.

[0028] The fourth condition is: 2≤C1 / C2≤10, 2≤C1 / C3≤14, and 2≤C1 / C4≤21, where C1 is the methane number, C2 is the ethane number, C3 is the propane number, and C4 is the butane number.

[0029] The fifth condition is: the humidity ratio is greater than the equilibrium ratio.

[0030] In a preferred embodiment, the humidity ratio is:

[0031] WH=(C2+C3+C4+C5) / (C1+C2+C3+C4+C5);

[0032] Wherein, WH is the humidity ratio, C1 is the methane number, C2 is the ethane number, C3 is the propane number, C4 is the butane number, and C5 is the pentane number.

[0033] In a preferred embodiment, the balance ratio is:

[0034] BH = (C1 + C2) / (C3 + C4 + C5);

[0035] Wherein, BH is the humidity ratio, C1 is the methane number, C2 is the ethane number, C3 is the propane number, C4 is the butane number, and C5 is the pentane number.

[0036] The beneficial effects of this invention are:

[0037] (1) This invention addresses the technical challenges in evaluating calcareous sandstone reservoirs. It comprehensively considers various factors such as the geological conditions of the study area and the reservoir conditions of the calcareous sandstone reservoirs. Based on the evaluation of reservoir effectiveness using well logging data, it achieves accurate identification of fluid properties of calcareous sandstone reservoirs through comprehensive analysis of multiple information from cuttings logging and gas logging, thereby improving the interpretation accuracy of calcareous sandstone reservoirs.

[0038] (2) This method only uses conventional logging data and well logging data for comprehensive analysis, and can achieve accurate evaluation of calcareous sandstone reservoirs without the need for additional special methods. This is of great significance for improving the exploration and development level of domestic oilfields. This invention uses well logging data to realize the reservoir accumulation conditions and seepage conditions, i.e., reservoir effectiveness identification. On this basis, well logging is used to realize the identification of reservoir fluid properties. Through the integration of multiple information and the integrated application of multiple technologies, a method for evaluating calcareous sandstone reservoirs has been formed, which solves the technical problems of evaluating the effectiveness of calcareous sandstone reservoirs and identifying fluid properties, improves the accuracy of calcareous sandstone reservoir evaluation, and provides strong technical support for oilfield exploration and development.

[0039] (3) This invention considers various factors such as structural high points of sandstone reservoirs, sand body development and source faults, matrix porosity, resistivity of fractures in sandstone reservoirs, rock cutting color, the magnitude of the peak value ratio of total hydrocarbons in gas logging, the magnitude of the ethane to propane ratio, the time shift of the peak value of total hydrocarbons in gas logging, the ratio of gas components, and the ratio of derived parameters to determine the oil-bearing potential of sandstone reservoirs. This method is scientific, accurate, and reasonable. The various stages of this invention are interconnected and closely integrated. Through the mining of various information from geological, logging, and well logging data, an innovative evaluation method for calcareous sandstone reservoirs has been formed. This method overcomes the limitations of previous applications that relied solely on logging or well logging methods. In practical application, it is both universal and operable, and it improves the accuracy of calcareous sandstone reservoir evaluation. It also provides methodological support for the evaluation of similar reservoirs in domestic oilfields. The innovation of this method is of great significance for improving the level of oil and gas exploration and development in my country in the future. Attached Figure Description

[0040] Other features, objects, and advantages of this application will become more apparent from the following detailed description of non-limiting embodiments with reference to the accompanying drawings:

[0041] Figure 1This is an embodiment of the present invention of a multi-information fusion method for evaluating argillaceous sandstone reservoirs;

[0042] Figure 2 This is a well location map of the ZH5-3 fault block structure in Oilfield A, according to an embodiment of the present invention.

[0043] Figure 3 This is a diagram showing the comprehensive logging interpretation results of well ZH5-5 according to an embodiment of the present invention;

[0044] Figure 4 This is a multi-information result diagram of well ZH5-5 according to an embodiment of the present invention;

[0045] Figure 5 This is a production curve diagram of well ZH5-5 according to an embodiment of the present invention;

[0046] Figure 6 This is a schematic diagram of the structure of a computer system used to implement the methods, systems, and devices of this application. Detailed Implementation

[0047] The present application will now be described in further detail with reference to the accompanying drawings and embodiments. It should be understood that the specific embodiments described herein are for illustrative purposes only and are not intended to limit the invention. Furthermore, it should be noted that, for ease of description, only the parts relevant to the invention are shown in the accompanying drawings.

[0048] It should be noted that, unless otherwise specified, the embodiments and features described in this application can be combined with each other. This application will now be described in detail with reference to the accompanying drawings and embodiments.

[0049] This invention provides a multi-information fusion method for evaluating argillaceous sandstone reservoirs, the method comprising:

[0050] The presence of structural highs, sand body development, and oil source faults in sandstone reservoirs is used to determine whether the sandstone reservoirs have the conditions for hydrocarbon accumulation.

[0051] Calculate the matrix porosity of the sandstone reservoir; determine the reservoir's effectiveness based on whether the matrix porosity of the sandstone reservoir is greater than a first threshold and whether there is an amplitude difference between the depth resistivity, intermediate resistivity, and shallow resistivity of the fractures in the sandstone reservoir.

[0052] The primary oil content of the sandstone reservoir is determined based on the color of the rock fragments.

[0053] The secondary oil content of the sandstone reservoir is determined based on the magnitude of the peak value ratio of total hydrocarbons in gas logging, the magnitude of the ethane to propane ratio, the time shift of the peak value of total hydrocarbons in gas logging, the ratio of gas components, and the ratio of derived parameters.

[0054] When the sandstone reservoir has the conditions for reservoir formation and is effective, and its first oil property is oil-bearing and its second oil property is oil-bearing, then the sandstone reservoir is determined to be oil-bearing; otherwise, it is non-oil-bearing.

[0055] To more clearly explain the multi-information fusion method for evaluating argillaceous sandstone reservoirs of this invention, the following will be combined with... Figure 1 The steps in the embodiments of the present invention will be described in detail below.

[0056] The multi-information fusion method for evaluating argillaceous sandstone reservoirs according to the first embodiment of the present invention is described in detail below:

[0057] The presence of structural highs, sand body development, and oil source faults in sandstone reservoirs is used to determine whether the sandstone reservoirs have the conditions for hydrocarbon accumulation.

[0058] In this embodiment, the method for determining whether the sandstone reservoir has the conditions for hydrocarbon accumulation is as follows:

[0059] If the difference in geological height between the sandstone reservoir and its surrounding area is greater than a second threshold, the sandstone reservoir has a structural high point; if the size of the sandstone body in the sandstone reservoir is greater than a third threshold, the sandstone reservoir has sand body development; if the sandstone reservoir has an oil-source fault, the sandstone reservoir has an oil-source fault; if the sandstone reservoir simultaneously has a structural high point, sand body development, and an oil-source fault, the sandstone reservoir has reservoir accumulation conditions.

[0060] The second threshold is set based on the difference in geological height between the sandstone reservoir and its surrounding area. Generally, there is a significant difference in geological height between the sandstone reservoir and its surrounding area, and this difference is the second threshold. Alternatively, the second threshold can be set to half the geological height of the surrounding area. The third threshold is selected based on actual conditions. Generally, the sandstone body of the sandstone reservoir has a certain scale.

[0061] Calculate the matrix porosity of the sandstone reservoir; determine the reservoir's effectiveness based on whether the matrix porosity of the sandstone reservoir is greater than a first threshold and whether there is an amplitude difference between the depth resistivity, intermediate resistivity, and shallow resistivity of the fractures in the sandstone reservoir.

[0062] In this embodiment, the method for calculating the matrix porosity of the sandstone reservoir is as follows:

[0063] Where ΦA is the matrix porosity, and Δt is the sonic transit time logging value of the target layer. ma For the acoustic transit time of the rock skeleton, Δt f C represents the acoustic transit time of formation fluids. p This is the compaction correction factor.

[0064] In this embodiment, the method for determining whether the sandstone reservoir has reservoir effectiveness is as follows: if the matrix porosity of the sandstone reservoir is greater than a first threshold and the depth resistivity, intermediate resistivity, and shallow resistivity of the fractures in the sandstone reservoir have amplitude differences, then the sandstone reservoir has reservoir effectiveness. Optionally, the first threshold is taken as 2%.

[0065] In this embodiment, the method for determining that the depth resistivity, intermediate resistivity, and shallow resistivity of the fractures in the sandstone reservoir have an amplitude difference is as follows: if the difference between the depth resistivity and intermediate resistivity of the fractures in the sandstone reservoir is greater than a fourth threshold, and the difference between the intermediate resistivity and shallow resistivity of the fractures in the sandstone reservoir is greater than a fifth threshold, then the depth resistivity, intermediate resistivity, and shallow resistivity of the fractures in the sandstone reservoir have an amplitude difference.

[0066] In this embodiment, the fourth threshold can be referenced to one-quarter of the moderate resistivity, and the fifth threshold can be referenced to one-quarter of the shallow resistivity.

[0067] The primary oil content of the sandstone reservoir is determined based on the color of the rock fragments.

[0068] In this embodiment, the method for determining the primary oil content of the sandstone reservoir is as follows: if the rock fragments of the sandstone reservoir are gray or grayish-white, the sandstone reservoir is determined to be non-oil-bearing; if the rock fragments of the sandstone reservoir are grayish-brown, dark brown, brownish-red, or brownish-yellow, the primary oil content of the sandstone reservoir is determined to be oil-bearing.

[0069] The secondary oil content of the sandstone reservoir is determined based on the magnitude of the peak value ratio of total hydrocarbons in gas logging, the magnitude of the ethane to propane ratio, the time shift of the peak value of total hydrocarbons in gas logging, the ratio of gas components, and the ratio of derived parameters.

[0070] When the sandstone reservoir has the conditions for reservoir formation and is effective, and its first oil property is oil-bearing and its second oil property is oil-bearing, then the sandstone reservoir is determined to be oil-bearing; otherwise, it is non-oil-bearing.

[0071] If the sandstone reservoir meets the five conditions for gas measurement, then the second oil content of the sandstone reservoir is oil-bearing.

[0072] In this embodiment, the five conditions for the gas measurement value are the first condition, the second condition, the third condition, the fourth condition, and the fifth condition.

[0073] The first condition is that the ratio of the peak value of total hydrocarbons measured by gas analysis to the lowest value of total hydrocarbons in the upper and lower surrounding rocks is more than 3 times.

[0074] The second condition is: the ratio of ethane to propane is less than 1.4;

[0075] The third condition is: when drilling to the sandstone reservoir interface, if the delay time of the occurrence of the peak value of total hydrocarbons in the gas measurement is greater than the fourth threshold, then the sandstone reservoir is an oil-bearing layer.

[0076] The fourth condition is: 2≤C1 / C2≤10, 2≤C1 / C3≤14, and 2≤C1 / C4≤21, where C1 is the methane number, C2 is the ethane number, C3 is the propane number, and C4 is the butane number.

[0077] The fifth condition is: the humidity ratio is greater than the equilibrium ratio.

[0078] The humidity ratio is: WH=(C2+C3+C4+C5) / (C1+C2+C3+C4+C5);

[0079] Wherein, WH is the humidity ratio, C1 is the methane number, C2 is the ethane number, C3 is the propane number, C4 is the butane number, and C5 is the pentane number.

[0080] The balance ratio is: BH = (C1 + C2) / (C3 + C4 + C5);

[0081] Wherein, BH is the humidity ratio, C1 is the methane number, C2 is the ethane number, C3 is the propane number, C4 is the butane number, and C5 is the pentane number.

[0082] To better illustrate the multi-information fusion method for evaluating argillaceous sandstone reservoirs of the present invention, an example is provided, taking well ZH5-5 in oilfield A as an example:

[0083] like Figure 2 As shown, well ZH5-5 is located in the ZH5-3 fault block of oilfield A. The well used saline cement drilling fluid with a resistivity of 0.9 ohm-meters. Conventional lateral logging was employed, recording three resistivity curves (deep, medium, and shallow), three porosity curves (sonic transit time, compensated neutron, compensated density), and nine logging parameters (natural gamma, spontaneous potential, and well diameter). The well originally produced layer 16, with a final crude oil production of 0.56 tons / day and a water cut of 84.1%. Layer 19 is a calcareous sandstone reservoir, previously interpreted as a dry layer. To determine the potential of this layer, a new evaluation of geological formation conditions, reservoir effectiveness, and oil-bearing properties was conducted. The steps are as follows:

[0084] (1) Geological conditions for reservoir formation: Well ZH5-5 is located in the waist of the ZH5-3 fault block, which is sandwiched by faults on the east and west sides, forming a favorable structural trap in the ZH5-5 well area. Figure 3 As shown, the 19# layer of calcareous sandstone reservoir is well-developed, and the faults on the east and west sides of the ZH5-3 fault block are oil-source faults. Therefore, the reservoir formation background of this trap is favorable and it has the conditions for oil and gas accumulation.

[0085] (2) Determination of the effectiveness of the calcareous sandstone reservoir. As shown in Figure (3), the 19# layer of well ZH5-5 is a calcareous sandstone reservoir. The logging curves show three lows and one high: the natural gamma (GR) curve value is low, with an average of 35 API; the compensated sonic (AC) curve value is low, with an average of 230 μs / m; the neutron curve value is low, with an average of 5.5%; and the density curve value is high, with an average of 2.6 g / m³. 3 The calculated average matrix porosity is 2.91%, which meets the 2% lower limit standard for calcareous sandstone reservoirs. Without considering fracture development, this layer can be evaluated as an ineffective reservoir, i.e., a dry layer. However, the resistivity curves at the shallow, medium, and deep levels show that the shallow resistivity value decreases due to mud intrusion during drilling, with a maximum decrease of 25 ohm-meters compared to the deep resistivity. Mud intrusion is also present at the medium resistivity depth (0.6 meters), with a difference of 5.6 ohm-meters compared to the deep resistivity. These characteristics indicate that mud intrusion can occur during drilling in ultra-low porosity and ultra-low permeability calcareous sandstone reservoirs, reaching a depth equivalent to the radial resistivity depth of 0.6 meters, suggesting the presence of fractures. Since the shallow and deep resistivities of layer #19 show a continuous and varying amplitude difference from top to bottom, it indicates that this layer primarily develops a network of microfractures. Based on the above analysis, the 19# layer of well ZH5-5 is a fracture-porosity reservoir and is identified as an effective reservoir.

[0086] (3) Determining the oil-bearing potential of calcareous reservoirs. Since the resistivity of calcareous sandstone reservoirs is significantly affected by the carbonate rock content, it is difficult to evaluate oil-water layers using well logging methods. However, evaluating this type of reservoir using well logging data is more effective. The evaluation steps are as follows:

[0087] First, the oil-bearing capacity of the reservoir is determined by cuttings logging. Figure 4 As shown, the cuttings logging of layer 19# shows grayish-brown oil traces, thus layer 19# is identified as an oil-bearing reservoir;

[0088] Then, gas logging was used to determine the reservoir's oil-bearing capacity. The reservoir's oil-bearing capacity was evaluated using peak-to-base ratio, ethane (C2) to propane (C3) ratio, gas logging peak shift, gas logging component ratio, and derived parameter ratio. The results are as follows:

[0089] ① Peak-to-base ratio, Figure 4 As shown, the ratio of the peak value of gas measurement in layer 19 to the baseline value of gas measurement in the surrounding rock reaches 9 times, which is more than 3 times the oil-bearing discrimination standard.

[0090] ② Ethane (C2) to propane (C3) ratio: The C2 / C3 ratio of layer 19 is 1.25, which meets the oil layer identification standard of less than 1.4;

[0091] ③ The gas logging peak shift: When the well encountered the interface of layer 19#, the gas logging peak did not rise immediately, but rose after drilling into the reservoir. Therefore, layer 19# is an oil layer.

[0092] ④ Gas composition ratios: For layer 19, C1 / C2 = 13, C1 / C3 = 16.25, and C1 / C4 = 32.5. According to the calculation results, the ratios of C1 / C2, C1 / C3, and C1 / C4 are close to the lower limit values ​​of oil layers of 10, 14, and 21, respectively. Therefore, this layer is an oil layer containing a small amount of natural gas.

[0093] ⑤ Derived parameter ratios: The calculated humidity ratio WH = 16.7 and the equilibrium ratio BH = 11.6 for layer #19, and WH > BH, which meets the criteria for oil layer identification.

[0094] Based on the above analysis, No. 19 possesses favorable geological conditions for reservoir formation and has been identified as an effective reservoir. Cuttings logging also confirms it as an oil-bearing reservoir. Furthermore, gas logging meets the oil layer identification criteria ①, ②, ③, and ⑤. Therefore, the comprehensive evaluation conclusion for No. 19 is that it is an oil layer, realizing the potential upgrade from a dry layer to an oil layer. Oil testing was conducted on this layer in January 2024, with a daily oil production of 9.7 tons. The evaluation results are consistent with the actual oil testing conclusions. Production is as follows... Figure 5 As shown.

[0095] Although the steps in the above embodiments are described in the above order, those skilled in the art will understand that in order to achieve the effect of this embodiment, different steps do not need to be executed in such an order. They can be executed simultaneously (in parallel) or in a reverse order. These simple variations are all within the protection scope of this invention.

[0096] The second embodiment of the multi-information fusion evaluation system for argillaceous sandstone reservoirs of the present invention includes:

[0097] The first judgment module is used to determine whether the sandstone reservoir has the conditions for oil accumulation based on whether the sandstone reservoir has structural high points, sand body development and oil source faults.

[0098] The second judgment module is used to calculate the matrix porosity of the sandstone reservoir; and to judge whether the sandstone reservoir has reservoir effectiveness based on whether the matrix porosity of the sandstone reservoir is greater than a first threshold and whether the depth resistivity, medium resistivity and shallow resistivity of the fractures in the sandstone reservoir have amplitude differences.

[0099] The third judgment module is used to determine the first oil content of the sandstone reservoir based on the color of the rock fragments in the sandstone reservoir.

[0100] The fourth judgment module is used to judge the secondary oil content of the sandstone reservoir based on the magnitude of the peak value ratio of total hydrocarbons in gas logging, the magnitude of the ethane to propane ratio, the time shift of the peak value of total hydrocarbons in gas logging, the ratio of gas components, and the ratio of derived parameters.

[0101] The oiliness determination module is used to determine the oiliness of the sandstone reservoir. When the sandstone reservoir has the conditions for reservoir formation and has reservoir effectiveness, and its first oiliness is oil-bearing and its second oiliness is oil-bearing, then the sandstone reservoir is determined to be oily; otherwise, it is non-oily.

[0102] Those skilled in the art will understand that, for the sake of convenience and brevity, the specific working process and related descriptions of the system described above can be found in the corresponding processes in the foregoing method embodiments, and will not be repeated here.

[0103] It should be noted that the multi-information fusion evaluation system for argillaceous sandstone reservoirs provided in the above embodiments is only an example of the division of the above functional modules. In practical applications, the above functions can be assigned to different functional modules as needed, that is, the modules or steps in the embodiments of the present invention can be further decomposed or combined. For example, the modules in the above embodiments can be merged into one module, or further divided into multiple sub-modules to complete all or part of the functions described above. The names of the modules and steps involved in the embodiments of the present invention are only for distinguishing the various modules or steps and are not considered as an improper limitation of the present invention.

[0104] An electronic device according to a third embodiment of the present invention includes: at least one processor; and a memory communicatively connected to at least one of the processors; wherein the memory stores instructions executable by the processor, the instructions being executed by the processor to implement the above-described multi-information fusion method for evaluating argillaceous sandstone reservoirs.

[0105] A computer-readable storage medium according to a fourth embodiment of the present invention stores computer instructions, which are executed by the computer to implement the above-described multi-information fusion method for evaluating argillaceous sandstone reservoirs.

[0106] Those skilled in the art will understand that, for the sake of convenience and brevity, the specific working process and related descriptions of the electronic devices and storage media described above can be referred to the corresponding processes in the foregoing method embodiments, and will not be repeated here.

[0107] Those skilled in the art will recognize that the modules and method steps of the various examples described in conjunction with the embodiments disclosed herein can be implemented in electronic hardware, computer software, or a combination of both. The programs corresponding to the software modules and method steps can be placed in random access memory (RAM), main memory, read-only memory (ROM), electrically programmable ROM, electrically erasable programmable ROM, registers, hard disks, removable disks, CD-ROMs, or any other form of storage medium known in the art. To clearly illustrate the interchangeability of electronic hardware and software, the components and steps of the various examples have been generally described in terms of functionality in the foregoing description. Whether these functions are implemented in electronic hardware or software depends on the specific application and design constraints of the technical solution. Those skilled in the art can use different methods to implement the described functions for each specific application, but such implementation should not be considered beyond the scope of the invention.

[0108] The following is for reference. Figure 6 It shows a schematic diagram of the structure of a computer system for implementing the methods, systems, and devices of this application. Figure 6 The server shown is merely an example and should not impose any limitations on the functionality and scope of use of the embodiments of this application.

[0109] like Figure 6 As shown, the computer system includes a Central Processing Unit (CPU) 601, which can perform various appropriate actions and processes based on programs stored in Read Only Memory (ROM) 602 or programs loaded from storage section 608 into Random Access Memory (RAM) 603. The RAM 603 also stores various programs and data required for system operation. The CPU 601, ROM 602, and RAM 603 are interconnected via a bus 604. An Input / Output (I / O) interface 605 is also connected to the bus 604.

[0110] The following components are connected to I / O interface 605: an input section 606 including a keyboard, mouse, etc.; an output section 607 including a cathode ray tube (CRT), liquid crystal display (LCD), etc., and speakers, etc.; a storage section 608 including a hard disk, etc.; and a communication section 609 including a network interface card such as a LAN (Local Area Network) card, modem, etc. The communication section 609 performs communication processing via a network such as the Internet. A drive 610 is also connected to I / O interface 605 as needed. A removable medium 611, such as a disk, optical disk, magneto-optical disk, semiconductor memory, etc., is installed on drive 610 as needed so that computer programs read from it can be installed into storage section 608 as needed.

[0111] Specifically, according to embodiments of this disclosure, the processes described above with reference to the flowcharts can be implemented as computer software programs. For example, embodiments of this disclosure include a computer program product comprising a computer program carried on a computer-readable medium, the computer program containing program code for performing the methods shown in the flowcharts. In such embodiments, the computer program can be downloaded and installed from a network via communication section 609, and / or installed from removable medium 611. When the computer program is executed by central processing unit (CPU) 601, it performs the functions defined in the methods of this application. It should be noted that the computer-readable medium described above in this application can be a computer-readable signal medium or a computer-readable storage medium, or any combination of the two. A computer-readable storage medium can be, for example,—but not limited to—an electrical, magnetic, optical, electromagnetic, infrared, or semiconductor system, apparatus, or device, or any combination thereof. More specific examples of computer-readable storage media may include, but are not limited to: electrical connections having one or more wires, portable computer disks, hard disks, random access memory (RAM), read-only memory (ROM), erasable programmable read-only memory (EPROM or flash memory), optical fiber, portable compact disk read-only memory (CD-ROM), optical storage devices, magnetic storage devices, or any suitable combination thereof. In this application, a computer-readable storage medium can be any tangible medium containing or storing a program that can be used by or in connection with an instruction execution system, apparatus, or device. In this application, a computer-readable signal medium may include a data signal propagated in baseband or as part of a carrier wave, carrying computer-readable program code. Such propagated data signals can take various forms, including but not limited to electromagnetic signals, optical signals, or any suitable combination thereof. A computer-readable signal medium can also be any computer-readable medium other than a computer-readable storage medium, which can send, propagate, or transmit a program for use by or in connection with an instruction execution system, apparatus, or device. The program code contained on a computer-readable medium can be transmitted using any suitable medium, including but not limited to: wireless, wire, optical fiber, RF, etc., or any suitable combination thereof.

[0112] Computer program code for performing the operations of this application can be written in one or more programming languages ​​or a combination thereof, including object-oriented programming languages ​​such as Java, Smalltalk, and C++, and conventional procedural programming languages ​​such as the "C" language or similar programming languages. The program code can be executed entirely on the user's computer, partially on the user's computer, as a standalone software package, partially on the user's computer and partially on a remote computer, or entirely on a remote computer or server. In cases involving remote computers, the remote computer can be connected to the user's computer via any type of network—including a local area network (LAN) or a wide area network (WAN)—or can be connected to an external computer (e.g., via the Internet using an Internet service provider).

[0113] The flowcharts and block diagrams in the accompanying drawings illustrate the architecture, functionality, and operation of possible implementations of systems, methods, and computer program products according to various embodiments of this application. In this regard, each block in a flowchart or block diagram may represent a module, segment, or portion of code containing one or more executable instructions for implementing a specified logical function. It should also be noted that in some alternative implementations, the functions indicated in the blocks may occur in a different order than those indicated in the drawings. For example, two consecutively indicated blocks may actually be executed substantially in parallel, and they may sometimes be executed in reverse order, depending on the functions involved. It should also be noted that each block in the block diagrams and / or flowcharts, and combinations of blocks in the block diagrams and / or flowcharts, can be implemented using a dedicated hardware-based system that performs the specified function or operation, or using a combination of dedicated hardware and computer instructions.

[0114] The terms “first”, “second”, etc., are used to distinguish similar objects, not to describe or indicate a specific order or sequence.

[0115] The term "comprising" or any other similar term is intended to cover non-exclusive inclusion, such that a process, method, article, or apparatus / device that comprises a list of elements includes not only those elements but also other elements not expressly listed, or elements inherent in such process, method, article, or apparatus / device.

[0116] The technical solution of the present invention has been described above with reference to the preferred embodiments shown in the accompanying drawings. However, it will be readily understood by those skilled in the art that the scope of protection of the present invention is obviously not limited to these specific embodiments. Without departing from the principles of the present invention, those skilled in the art can make equivalent changes or substitutions to the relevant technical features, and the technical solutions after these changes or substitutions will all fall within the scope of protection of the present invention.

Claims

1. A multi-information fusion method for evaluating argillaceous sandstone reservoirs, characterized in that, The method includes: The presence of structural highs, sand body development, and oil source faults in sandstone reservoirs are used to determine whether the sandstone reservoirs have the conditions for hydrocarbon accumulation. Calculate the matrix porosity of the sandstone reservoir; determine the reservoir's effectiveness based on whether the matrix porosity of the sandstone reservoir is greater than a first threshold and whether there is an amplitude difference between the depth resistivity, intermediate resistivity, and shallow resistivity of the fractures in the sandstone reservoir. The primary oil content of the sandstone reservoir is determined based on the color of the rock fragments. The secondary oil content of the sandstone reservoir is determined based on the magnitude of the peak value ratio of total hydrocarbons in gas logging, the magnitude of the ethane to propane ratio, the time shift of the peak value of total hydrocarbons in gas logging, the ratio of gas components, and the ratio of derived parameters. When the sandstone reservoir has the conditions for reservoir formation and is effective, and its first oil property is oil-bearing and its second oil property is oil-bearing, then the sandstone reservoir is determined to be oil-bearing; otherwise, it is non-oil-bearing.

2. The multi-information fusion method for evaluating calcareous sandstone reservoirs according to claim 1, characterized in that, The method for determining whether the sandstone reservoir has the conditions for hydrocarbon accumulation is as follows: If the difference between the geological height of the sandstone reservoir and the geological height of its surrounding area is greater than a second threshold, then the sandstone reservoir has a structural high point. If the size of the sandstone body in the sandstone reservoir is greater than the third threshold, then the sandstone reservoir has sand body development. If the sandstone reservoir simultaneously possesses structural highs, well-developed sand bodies, and oil-source faults, then the sandstone reservoir has the conditions for hydrocarbon accumulation.

3. The multi-information fusion method for evaluating argillaceous sandstone reservoirs according to claim 2, characterized in that, The method for calculating the matrix porosity of the sandstone reservoir is as follows: Where ΦA is the matrix porosity, and Δt is the sonic transit time logging value of the target layer. ma For the acoustic transit time of the rock skeleton, Δt f C represents the acoustic transit time of formation fluids. p This is the compaction correction factor.

4. The multi-information fusion method for evaluating calcareous sandstone reservoirs according to claim 3, characterized in that, The method for determining whether the sandstone reservoir has reservoir effectiveness is as follows: If the matrix porosity of the sandstone reservoir is greater than a first threshold and the depth resistivity, medium resistivity, and shallow resistivity of the fractures in the sandstone reservoir have amplitude differences, then the sandstone reservoir is considered to have reservoir effectiveness.

5. The multi-information fusion method for evaluating calcareous sandstone reservoirs according to claim 4, characterized in that, The method for determining the amplitude difference in the depth resistivity, intermediate resistivity, and shallow resistivity of fractures in the sandstone reservoir is as follows: If the difference between the depth resistivity and the intermediate resistivity of the fractures in the sandstone reservoir is greater than the fourth threshold, and the difference between the intermediate resistivity and the shallow resistivity of the fractures in the sandstone reservoir is greater than the fifth threshold, then the depth resistivity, intermediate resistivity, and shallow resistivity of the fractures in the sandstone reservoir have amplitude differences.

6. The multi-information fusion method for evaluating calcareous sandstone reservoirs according to claim 5, characterized in that, The method for determining the primary oil content of the sandstone reservoir is as follows: If the rock fragments of the sandstone reservoir are gray or grayish-white, the sandstone reservoir is determined to be non-oil-bearing; if the rock fragments of the sandstone reservoir are grayish-brown, dark brown, brownish-red, or brownish-yellow, the sandstone reservoir is determined to be oil-bearing.

7. The multi-information fusion method for evaluating calcareous sandstone reservoirs according to claim 6, characterized in that, The method for determining the secondary oil content of the sandstone reservoir is as follows: If the sandstone reservoir meets the five conditions for gas measurement, then the second oil content of the sandstone reservoir is oil-bearing.

8. The multi-information fusion method for evaluating calcareous sandstone reservoirs according to claim 7, characterized in that, The five conditions for the gas measurement value are the first condition, the second condition, the third condition, the fourth condition, and the fifth condition. The first condition is that the ratio of the peak value of total hydrocarbons measured by gas analysis to the lowest value of total hydrocarbons in the upper and lower surrounding rocks is more than 3 times. The second condition is: the ratio of ethane to propane is less than 1.4; The third condition is: when drilling to the sandstone reservoir interface, if the delay time of the occurrence of the peak value of total hydrocarbons in the gas measurement is greater than the fourth threshold, then the sandstone reservoir is an oil-bearing layer. The fourth condition is: 2≤C1 / C2≤10, 2≤C1 / C3≤14, and 2≤C1 / C4≤21, where C1 is the methane number, C2 is the ethane number, C3 is the propane number, and C4 is the butane number. The fifth condition is: the humidity ratio is greater than the equilibrium ratio.

9. The multi-information fusion method for evaluating calcareous sandstone reservoirs according to claim 8, characterized in that, The humidity ratio is: WH=(C2+C3+C4+C5) / (C1+C2+C3+C4+C5); Wherein, WH is the humidity ratio, C1 is the methane number, C2 is the ethane number, C3 is the propane number, C4 is the butane number, and C5 is the pentane number.

10. The multi-information fusion method for evaluating calcareous sandstone reservoirs according to claim 9, characterized in that, The balance ratio is: BH = (C1 + C2) / (C3 + C4 + C5); Wherein, BH is the humidity ratio, C1 is the methane number, C2 is the ethane number, C3 is the propane number, C4 is the butane number, and C5 is the pentane number.

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