An overflow risk early warning method, device and equipment based on single gas monitoring

Abstract

This article pertains to the petroleum industry, specifically relating to a method, device, and equipment for overflow risk early warning based on single-hole gas monitoring. The method includes: real-time collection of drilling data, including drill bit position, well depth, total hydrocarbon content, and drill string height; determining the drill bit position when the drill string is pulled up based on the collected drilling data; determining the location data of the risky well section and the location data of the first section to be monitored based on the drill bit position and single drill string length; determining the location data of a single connecting section based on the location data of the single connecting section and the risky well section; monitoring for single-hole gas anomalies based on total hydrocarbon content data obtained at the location of the first section to be monitored; and determining whether to send an overflow risk warning based on the single-hole gas anomaly. This article solves the problems of high cost and poor effectiveness in overflow risk monitoring during drilling.

Description

Technical Field

[0001] This invention relates to the petroleum industry, and in particular to a method, apparatus and equipment for early warning of overflow risks based on single gas monitoring. Background Technology

[0002] In drilling operations, a severe blowout can cause significant safety problems and substantial economic losses. The overflow of formation fluids is a precursor to a blowout, and early detection and handling of such overflows can greatly reduce the probability of a blowout accident.

[0003] Currently, overflow risk monitoring during drilling mainly relies on manual on-site personnel. However, due to varying levels of experience and limited energy among on-site staff, as well as differing abilities to identify complex incidents, false alarms and missed alarms are frequent occurrences, resulting in both high time and manpower consumption and poor prevention and handling effectiveness. Therefore, there is an urgent need for an intelligent method for real-time overflow risk monitoring. Summary of the Invention

[0004] This invention provides a method, device, and equipment for early warning of overflow risk based on single gas monitoring, which solves the problems of high cost and poor effectiveness of overflow risk monitoring during drilling.

[0005] To address the aforementioned technical problems, the first aspect of this paper provides an overflow risk early warning method based on single-channel gas monitoring, the method comprising:

[0006] Real-time collection of drilling data, including drill bit position, well depth, total hydrocarbon content, and hook height;

[0007] Based on the collected drilling data, determine the position of the drill bit when the hook is pulled up;

[0008] Based on the drill bit position when the large hook is pulled up, determine the location data of the risk section and the location data of the first section to be tested;

[0009] Based on the real-time collected drill bit position and single drill rod length, determine the position data of a single connecting section;

[0010] Based on the location data of the single connecting section and the location data of the risk well section, determine whether the single connecting section is located in the risk well section; if the single connecting section is located in the risk well section, monitor the gas anomaly of the single connecting section based on the total hydrocarbon content data in the drilling data obtained at the location of the first test well section.

[0011] Based on the abnormality of a single gas flow, determine whether to send an overflow risk warning.

[0012] Furthermore, based on the real-time collected drill bit position and single drill pipe length, the position data of a single connecting section is determined, including:

[0013] Subtract the preset single drill pipe length from the well depth at the real-time collected drill bit position to obtain the single connection reference position;

[0014] The position data of a single connection segment are determined based on the reference position of the single connection and the length of the first preset interval.

[0015] Furthermore, based on the total hydrocarbon content data obtained at the location of the first well section to be tested, anomalies in single gas streams are monitored, including:

[0016] Based on the total hydrocarbon content data corresponding to the first well section to be tested, the first well depth is determined. The first well depth is the well depth corresponding to the highest total hydrocarbon content in the first well section to be tested.

[0017] The second well section to be tested is determined based on the first well depth and the second preset interval length;

[0018] The presence of a single gas anomaly is determined by the ratio of the highest total hydrocarbon content in the first well section to be tested to the lowest total hydrocarbon content in the second well section to be tested.

[0019] Furthermore, based on the total hydrocarbon content data obtained at the location of the first well section to be tested, monitoring for single-channel gas anomalies also includes:

[0020] Subtract the first preset value from the first well depth to obtain the reference well depth for the total hydrocarbon content baseline value;

[0021] The well section for determining the total hydrocarbon content baseline value is determined by subtracting the length of the third preset interval from the reference well depth.

[0022] The base value of total hydrocarbon content is determined based on the total hydrocarbon content data corresponding to the well section with the base value of total hydrocarbon content.

[0023] The step of determining whether a single gas anomaly exists further involves: determining whether a single gas anomaly exists based on the ratio of the highest total hydrocarbon content in the first well section to be tested to the lowest total hydrocarbon content in the second well section to be tested, and the ratio of the highest total hydrocarbon content in the first well section to the base value of the total hydrocarbon content.

[0024] Furthermore, the drilling data also includes the methane content corresponding to the well depth;

[0025] The overflow risk early warning method based on single-gas monitoring also includes:

[0026] Based on the methane content data corresponding to the first well section to be tested, the second well depth is determined. The second well depth is the well depth corresponding to the highest methane content in the first well section to be tested.

[0027] The third well section to be measured is determined based on the second well depth and the fourth preset interval length;

[0028] The step of determining whether a single gas anomaly exists further involves: determining whether a single gas anomaly exists based on the ratio of the highest total hydrocarbon content in the first well section to be tested to the lowest total hydrocarbon content in the second well section to be tested, the ratio of the highest total hydrocarbon content in the first well section to the base value of total hydrocarbon content, and the ratio of the highest methane content in the first well section to the lowest methane content in the third well section to be tested.

[0029] Furthermore, the overflow risk early warning method based on single gas monitoring also includes:

[0030] Subtracting the second preset value from the second well depth yields the reference well depth for the methane content baseline value.

[0031] Subtract the length of the fifth preset interval from the reference well depth of the methane content baseline value to determine the well section of the methane content baseline value;

[0032] The base methane content value is determined based on the methane content data corresponding to the well section with the base methane content value.

[0033] The step of determining whether a single gas anomaly exists further involves: determining whether a single gas anomaly exists based on the ratio of the highest total hydrocarbon content in the first well section to be tested to the lowest total hydrocarbon content in the second well section to be tested, the ratio of the highest total hydrocarbon content in the first well section to the baseline value of total hydrocarbon content, the ratio of the highest methane content in the first well section to the lowest methane content in the third well section to the baseline value of methane content.

[0034] Furthermore, the step of determining whether a single gas anomaly exists is as follows: based on the difference between the highest total hydrocarbon content in the first well section to be tested and the lowest total hydrocarbon content in the second well section to be tested, it is determined whether a single gas anomaly exists.

[0035] Furthermore, the step of determining whether a single gas anomaly exists is further as follows: based on the difference between the highest total hydrocarbon content in the first test section and the lowest total hydrocarbon content in the second test section, and whether the total hydrocarbon content baseline value meets the first preset threshold, it is determined whether a single gas anomaly exists.

[0036] Furthermore, the step of determining whether a single gas anomaly exists is further as follows: based on the difference between the highest total hydrocarbon content in the first test section and the lowest total hydrocarbon content in the second test section, whether the total hydrocarbon content base value meets the first preset threshold, and the difference between the highest methane content in the first test section and the lowest methane content in the third test section, it is determined whether a single gas anomaly exists.

[0037] Furthermore, the step of determining whether a single gas anomaly exists is further as follows: based on the difference between the highest total hydrocarbon content in the first test section and the lowest total hydrocarbon content in the second test section, whether the total hydrocarbon content baseline value meets the first preset threshold, the difference between the highest methane content in the first test section and the lowest methane content in the third test section, and the difference between the highest methane content in the first test section and the methane content baseline value, it is determined whether a single gas anomaly exists.

[0038] Furthermore, based on the anomaly of a single gas outlet, determine whether to send an overflow risk warning, including:

[0039] The first well depths are sorted according to the determination time of the first well depth determined multiple times;

[0040] Calculate the depth difference between adjacent first well depths to obtain a depth difference sequence;

[0041] Based on the well depth difference sequence, the variation law of well depth difference is determined, and an overflow risk warning is sent when the well depth law changes.

[0042] Furthermore, the overflow risk early warning method based on single gas monitoring also includes:

[0043] Based on the total hydrocarbon content corresponding to the first well depth determined multiple times, determine whether the total hydrocarbon content is not monotonically decreasing.

[0044] If the determination is yes, send an overflow risk warning.

[0045] The second aspect of this article provides an overflow risk early warning device based on single-gas monitoring, the device comprising:

[0046] The acquisition module is used to collect drilling data in real time, including drill bit position, well depth, total hydrocarbon content, and hook height;

[0047] The first determining module is used to determine the position of the drill bit when the hook is pulled up, based on the collected drilling data.

[0048] The second determining module is used to determine the location data of the risk well section and the location data of the first well section to be tested based on the position of the drill bit when the hook is lifted.

[0049] The third determination module is used to determine the position data of a single connecting section based on the real-time collected drill bit position and single drill rod length;

[0050] The fourth determining module is used to determine whether a single connecting segment is located in a risky well section based on the location data of the single connecting segment and the location data of the risky well section; if the single connecting segment is located in a risky well section, the module monitors the gas anomaly of the single connecting segment based on the total hydrocarbon content data in the drilling data obtained at the location of the first test well section.

[0051] The analysis and early warning module is used to determine whether to send an overflow risk warning based on the abnormal situation of a single gas pipe.

[0052] A third aspect of this document provides a computer device including a memory, a processor, and a computer program stored in the memory, wherein the computer program, when executed by the processor, performs instructions for the overflow risk warning method based on single gas monitoring as described in any of the foregoing embodiments.

[0053] The fourth aspect of this document provides a computer storage medium having a computer program stored thereon, which, when run by a processor of a computer device, executes instructions for the overflow risk warning method based on single gas monitoring as described in any of the foregoing embodiments.

[0054] The fifth aspect of this document provides a computer program product comprising a computer program that, when executed by a processor of a computer device, performs instructions for the overflow risk warning method based on single-gas monitoring as described in any of the foregoing embodiments.

[0055] The method, device, and equipment for overflow risk early warning based on single gas monitoring provided in this paper collect drilling data in real time and determine the location of the risky well section and the single connecting section based on the drilling data to determine whether the single connecting section is in a risky area. When it is in a risky area, the single gas anomaly is judged, which reduces the risk identification cost. The method automatically judges the single gas anomaly by using total hydrocarbon content data and analyzes whether to send an overflow risk warning based on the single gas anomaly, which further reduces the labor cost and improves the real-time performance of overflow risk warning.

[0056] To make the above and other objects, features and advantages of this document more apparent and understandable, preferred embodiments are described below in detail with reference to the accompanying drawings. Attached Figure Description

[0057] To more clearly illustrate the technical solutions in the embodiments or prior art described herein, the accompanying drawings used in the description of the embodiments or prior art will be briefly introduced below. Obviously, the accompanying drawings described below are only some embodiments of this article. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0058] Figure 1 The first flowchart of the overflow risk early warning method based on single gas monitoring in this embodiment is shown;

[0059] Figure 2 A flowchart illustrating the method for determining the location data of a single connection segment according to an embodiment of this paper is shown.

[0060] Figure 3 This document shows a first flowchart of an embodiment for monitoring abnormal conditions of a single gas stream;

[0061] Figure 4 This document shows a second flowchart for monitoring abnormal conditions of a single gas stream in an embodiment of the invention.

[0062] Figure 5 The third flowchart for monitoring single gas anomalies in the embodiments of this article is shown;

[0063] Figure 6 The fourth flowchart for monitoring single gas anomalies in the embodiments of this article is shown;

[0064] Figure 7 This document illustrates a first flowchart of an embodiment for determining whether to send an overflow risk warning;

[0065] Figure 8 This document illustrates a second flowchart of an embodiment for determining whether to send an overflow risk warning;

[0066] Figure 9 The diagram shows the structure of the overflow risk early warning device based on single gas monitoring in the embodiments of this paper;

[0067] Figure 10 A structural diagram of the computer device described in this embodiment is shown.

[0068] Explanation of symbols in the attached drawings:

[0069] 910. Acquisition Module;

[0070] 920. First Determined Module;

[0071] 930. Second Determination Module;

[0072] 940. The third determination module;

[0073] 950. Fourth Determination Module;

[0074] 960. Analysis and Early Warning Module;

[0075] 1002. Computer equipment;

[0076] 1004, Processor;

[0077] 1006. Memory;

[0078] 1008. Drive mechanism;

[0079] 1010. Input / Output Module;

[0080] 1012. Input devices;

[0081] 1014. Output devices;

[0082] 1016. Presentation device;

[0083] 1018. Graphical User Interface;

[0084] 1020. Network interface;

[0085] 1022. Communication link;

[0086] 1024. Communication bus. Detailed Implementation

[0087] The technical solutions in the embodiments described below will be clearly and completely described with reference to the accompanying drawings. Obviously, the described embodiments are only a part of the embodiments described herein, and not all of the embodiments. Based on the embodiments described herein, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of this document.

[0088] It should be noted that the terms "first," "second," etc., used in the specification, claims, and accompanying drawings herein are used to distinguish similar objects and are not necessarily used to describe a specific order or sequence. It should be understood that such data can be interchanged where appropriate so that the embodiments described herein can be implemented in orders other than those illustrated or described herein. Furthermore, the terms "comprising" and "having," and any variations thereof, are intended to cover a non-exclusive inclusion; for example, a process, method, apparatus, product, or device that comprises a series of steps or units is not necessarily limited to those steps or units explicitly listed, but may include other steps or units not explicitly listed or inherent to such processes, methods, products, or devices.

[0089] This specification provides the operational steps of the methods described in the embodiments or flowcharts, but based on conventional or non-inventive labor, more or fewer operational steps may be included. The order of steps listed in the embodiments is merely one possible execution order among many and does not represent the only possible execution order. In actual system or device products, the methods shown in the embodiments or drawings can be executed sequentially or in parallel.

[0090] It should be noted that the acquisition, storage, use, and processing of data in the technical solutions of the embodiments of this specification all comply with the relevant provisions of national laws and regulations.

[0091] It should be noted that in the embodiments of this application, certain software, components, models and other existing solutions in the industry may be mentioned. These should be regarded as exemplary and are only intended to illustrate the feasibility of implementing the technical solution of this application. However, it does not mean that the applicant has used or necessarily used the solution.

[0092] In one embodiment of this paper, a method for early warning of overflow risk based on single gas monitoring is provided to solve the problems of high cost and poor effectiveness of overflow risk monitoring during drilling.

[0093] Specifically, such as Figure 1 As shown, the overflow risk early warning method based on single gas monitoring includes:

[0094] Step 110: Collect drilling data in real time, including drill bit position, well depth, total hydrocarbon content, and hook height;

[0095] Step 120: Determine the drill bit position when the hook is pulled up, based on the collected drilling data;

[0096] Step 130: Determine the location data of the risk section and the location data of the first section to be tested based on the drill bit position when the large hook is lifted.

[0097] Step 140: Determine the position data of a single connecting section based on the real-time collected drill bit position and single drill rod length;

[0098] Step 150: Based on the location data of the single connecting section and the location data of the risk well section, determine whether the single connecting section is located in the risk well section; if the single connecting section is located in the risk well section, monitor the gas anomaly of the single connecting section based on the total hydrocarbon content data in the drilling data obtained at the location of the first test well section.

[0099] Step 160: Based on the abnormal situation of a single gas pipe, determine whether to send an overflow risk warning.

[0100] This embodiment takes into account that when the large hook is used to add drill pipe, the drill string will be lifted, causing the drill string to pump and stop the pump, which can easily lead to oil and gas entering the wellbore, resulting in single gas anomalies and causing overflow risks. Therefore, the risk section is determined based on the drill bit position when the large hook is lifted. At the same time, considering that single connection sections are susceptible to oil and gas intrusion, single gas anomaly detection is only performed when the single connection section is located in the risk section, reducing risk identification costs. The single gas anomaly is automatically judged by total hydrocarbon content data, and overflow risk warning is sent based on the analysis of the single gas anomaly, further reducing labor costs and improving the real-time performance of overflow risk warnings.

[0101] In this embodiment, in order to obtain real-time well depth data, a data conversion process from time series to depth series is established based on drilling time and drilling speed, and the converted dataset is saved to the drilling database. At the same time, the well depth, total hydrocarbon content, drill bit position, and the height of the hook used to hold the drill pipe deep into the well bottom are recorded in real time in the drilling database for the analysis of overflow risk. The data stored in the drilling database is shown in Table 1.

[0102] Table 1

[0103] time Well depth(m) Drill bit position (m) Hook height (m) Total hydrocarbon content (%) 2023-3-4 00:00:00 2005.83 2005.83 20.53 4.57 2023-3-4 00:00:01 2005.84 2005.84 20.52 4.42 2023-3-4 00:00:02 2005.84 2005.84 20.52 5.06 …… …… …… …… ……

[0104] Before saving real-time data to the drilling database, data standardization is performed to address data gaps and noise issues commonly caused by equipment failures, acquisition errors, and inconsistent units in the initial data. Missing data is filled in using methods such as weighted interpolation, mean interpolation, linear interpolation, and nearest neighbor interpolation. Outlier data is corrected using techniques such as fixed threshold determination and K-Sigma methods to identify and handle outliers and abnormal fluctuations, ensuring data accuracy and continuity.

[0105] In this embodiment, the distance between the hook and the ground is recorded as the hook height. Considering that the hook height will continuously decrease as drilling progresses, when the hook reaches a certain distance from the ground, drill pipe will be added. At this time, the hook height will start to rise from a continuously decreasing position, and then continue to decrease after the drill pipe is added. The hook height (i.e., the distance between the hook and the ground) will have a minimum and a maximum value. However, the well depth at the bottom of the well will not change when the hook is lifted. Therefore, after obtaining the data from the drilling database, the well section near the well depth corresponding to the minimum or maximum value of the hook height can be identified as a risk well section, thereby obtaining the location data of the risk well section in terms of well depth.

[0106] In some embodiments described herein, to further reduce the cost of overflow risk identification, the current drilling condition is determined based on the drill bit position and the bottom depth of the well. Preferably, when the distance between the drill bit position and the bottom depth of the well is less than 30 meters, the current drilling condition is determined, and overflow risk identification is performed. The distance between the drill bit position and the bottom depth of the well used to determine whether the current drilling condition is being performed can also take other values, which are not limited herein.

[0107] When a single connecting segment is identified as being located in a high-risk well section, the total hydrocarbon content data of the first test segment is selected to determine the gas anomaly of the single segment. The first test segment is generally located deeper into the well bottom than the high-risk well section because there will be a certain lag when obtaining the total hydrocarbon content data corresponding to the well section. At the same time, the minimum or maximum value of the hook height is taken as the starting point of the first test segment and extended to the bottom of the well by a preset length (e.g., 6 meters) to obtain the end point of the first test segment, and thus obtain the location data of the first test segment.

[0108] In one embodiment of this article, such as Figure 2 As shown, based on the real-time collected drill bit position and single drill pipe length, the position data of a single connecting section is determined, including:

[0109] Step 210: Subtract the preset length of a single drill pipe from the well depth at the drill bit position collected in real time to obtain the reference position of a single connection.

[0110] Step 220: Determine the position data of the single connection segment based on the reference position of the single connection and the length of the first preset interval.

[0111] In this embodiment, the top of the first drill pipe is connected to the drill string, and its end is connected to the second drill pipe. The connection reference position of the first drill pipe and the second drill pipe is obtained by subtracting the preset length of a single drill pipe from the position of the drill bit. Based on the single connection reference position and the nearby well section, the position data of the single connection segment is determined.

[0112] Preferably, considering the actual situation, the length of the first preset interval is 1 meter, and the well section within 1 meter of the single connection reference position is determined as the single connection section.

[0113] In one embodiment of this article, such as Figure 3 As shown, based on the total hydrocarbon content data obtained at the location of the first well section to be tested, the monitoring of single-channel gas anomalies includes:

[0114] Step 310: Determine the first well depth based on the total hydrocarbon content data corresponding to the first well section to be tested. The first well depth is the well depth corresponding to the highest total hydrocarbon content in the first well section to be tested.

[0115] Step 320: Determine the second well section to be tested based on the first well depth and the second preset interval length;

[0116] Step 330: Determine whether there is a single gas anomaly based on the ratio of the highest total hydrocarbon content in the first test section to the lowest total hydrocarbon content in the second test section.

[0117] This embodiment takes into account that the total hydrocarbon content will have a sharp peak when there is a single gas anomaly. Therefore, the sharpness of the total hydrocarbon content peak is determined by the ratio of the highest total hydrocarbon content in the first test section to the lowest total hydrocarbon content in the second test section, so as to determine whether there is a single gas anomaly.

[0118] In some embodiments of this paper, to better determine the sharpness of the peak value of total hydrocarbon content, a second preset interval length is extended from the first well depth into the shallow or deep part of the wellbore to determine the second well section to be tested. The preferred length of the second preset interval is 2 meters, because when the total hydrocarbon content reaches approximately 2 meters from the peak value, the total hydrocarbon content shows a strong upward trend, resulting in a sharp peak. Preferably, a single gas anomaly is considered to exist when the ratio of the highest to the lowest total hydrocarbon content is greater than or equal to 3.

[0119] In one embodiment of this article, such as Figure 4 As shown, monitoring single-channel gas anomalies based on the total hydrocarbon content data obtained at the location of the first well section to be tested also includes:

[0120] Step 410: Subtract the first preset value from the first well depth to obtain the reference well depth for the total hydrocarbon content baseline value;

[0121] Step 420: Subtract the length of the third preset interval from the reference well depth of the total hydrocarbon content baseline value to determine the well section of the total hydrocarbon content baseline value;

[0122] Step 430: Determine the base value of total hydrocarbon content based on the total hydrocarbon content data corresponding to the well section with the base value of total hydrocarbon content;

[0123] Step 440, the step of determining whether there is a single gas anomaly, further comprises: determining whether there is a single gas anomaly based on the ratio of the highest total hydrocarbon content in the first well section to be tested to the lowest total hydrocarbon content in the second well section to be tested, and the ratio of the highest total hydrocarbon content in the first well section to the base value of the total hydrocarbon content.

[0124] This embodiment also considers the baseline value of total hydrocarbon content. The ratio of the highest total hydrocarbon content to the baseline value of total hydrocarbon content is used to determine whether there is an abnormal height in the total hydrocarbon content, which further ensures the accuracy of identifying single gas anomalies.

[0125] Because there is a risk of single-channel gas anomaly at the first well depth, the total hydrocarbon content collected thereafter is not normal. Therefore, using the section preceding it as the baseline for total hydrocarbon content allows us to obtain a normal baseline value that is close to the first well depth. Preferably, based on actual experimental results, the first preset value can be 2 meters, and the third preset interval length can be 8 meters. The baseline range for total hydrocarbon content is the section formed by subtracting 2 meters and 8 meters from the first well depth. Preferably, a single-channel gas anomaly can be considered to exist when the ratio of the highest total hydrocarbon content to the baseline total hydrocarbon content is greater than or equal to 4.

[0126] In one embodiment of this article, the drilling data also includes the methane content corresponding to the well depth, as shown in Table 2.

[0127] Table 2

[0128]

[0129] like Figure 5 As shown, the overflow risk early warning method based on single gas monitoring also includes:

[0130] Step 510: Determine the second well depth based on the methane content data corresponding to the first well section to be tested. The second well depth is the well depth corresponding to the highest methane content in the first well section to be tested.

[0131] Step 520: Determine the third well section to be tested based on the second well depth and the fourth preset interval length;

[0132] Step 530, the step of determining whether there is a single gas anomaly, further comprises: determining whether there is a single gas anomaly based on the ratio of the highest total hydrocarbon content in the first well section to be tested to the lowest total hydrocarbon content in the second well section to be tested, the ratio of the highest total hydrocarbon content in the first well section to the base value of the total hydrocarbon content, and the ratio of the highest methane content in the first well section to the lowest methane content in the third well section to be tested.

[0133] This embodiment takes into account that methane is an important component of total hydrocarbon gases, and also considers the methane content. Based on the ratio of the highest methane content in the first test section to the lowest methane content in the third test section, the sharpness of the methane content peak is determined, thereby determining whether there is a single gas anomaly, further ensuring the accuracy of identifying single gas anomalies.

[0134] In some embodiments of this paper, to better determine the sharpness of the methane content peak in the total hydrocarbon content, a second well depth corresponding to the methane peak is determined based on the methane content data corresponding to the first well section to be tested. Starting from the second well depth, a fourth preset interval length is extended towards the shallow or deep part of the wellbore to determine the third well section to be tested. The fourth preset interval length can preferably be 2 meters, or it can be slightly adjusted based on the actual situation based on the second preset interval length. When the methane content peak is reached approximately 2 meters away, the methane content will also show a sharp upward trend, resulting in a sharp peak. Preferably, a single gas anomaly can be considered to exist when the ratio of the highest methane content to the lowest methane content is greater than or equal to 2.5.

[0135] In one embodiment of this article, such as Figure 6 As shown, the overflow risk early warning method based on single gas monitoring also includes:

[0136] Step 610: Subtract the second preset value from the second well depth to obtain the reference well depth for the methane content baseline value;

[0137] Step 620: Subtract the length of the fifth preset interval from the reference well depth of the methane content baseline value to determine the well section of the methane content baseline value;

[0138] Step 630: Determine the base methane content value based on the methane content data corresponding to the well section with the base methane content value;

[0139] Step 640, the step of determining whether there is a single gas anomaly, further comprises: determining whether there is a single gas anomaly based on the ratio of the highest total hydrocarbon content in the first well section to be tested to the lowest total hydrocarbon content in the second well section to be tested, the ratio of the highest total hydrocarbon content in the first well section to the base value of total hydrocarbon content, the ratio of the highest methane content in the first well section to the lowest methane content in the third well section to the base value of methane content in the third well section to the highest methane content in the first well section to be tested.

[0140] This embodiment also considers the baseline value of methane content, and determines whether there is an abnormal height of methane content by the ratio of the highest methane content to the baseline value of methane content, thereby further ensuring the accuracy of identifying single gas anomalies.

[0141] Because there is a risk of single-channel gas anomaly at the second well depth, the methane content collected thereafter is not normal. Therefore, using the section before it as the base methane content section can yield a normal methane content base value close to the second well depth. Preferably, based on actual experimental results, the second preset value can also be 2 meters, and the fifth preset interval length can be 8 meters. The base methane content section is the section formed by subtracting 2 meters and 8 meters from the first well depth; alternatively, the first preset value and the third preset interval length can be finely adjusted based on actual conditions to obtain a finely adjusted second preset value and fifth preset interval length. Preferably, a single-channel gas anomaly can be considered to exist when the ratio of the highest methane content to the base methane content is greater than or equal to 3.

[0142] In one embodiment of this paper, the existence of a single gas anomaly can also be determined based on the difference between the highest total hydrocarbon content in the first well section to be tested and the lowest total hydrocarbon content in the second well section to be tested, thereby reflecting the sharpness of the peak value of the total hydrocarbon content from the perspective of the difference. Preferably, a single gas anomaly can be considered to exist when the difference between the highest and lowest total hydrocarbon content is greater than or equal to 15%.

[0143] In one embodiment of this paper, further, the existence of a single gas anomaly can be determined based on the difference between the highest total hydrocarbon content in the first well section to be tested and the lowest total hydrocarbon content in the second well section to be tested, and whether the baseline value of the total hydrocarbon content meets a first preset threshold. Based on determining the difference between the highest and lowest total hydrocarbon content in the second well section to be tested, the baseline value of the total hydrocarbon content is further judged to be whether it meets the first preset threshold, thereby determining whether the baseline value of the total hydrocarbon content is abnormal, and thus serving as a condition for identifying a single gas anomaly. Preferably, the first preset threshold can be 20%.

[0144] In one embodiment of this paper, further, the existence of a single gas anomaly can be determined based on the difference between the highest total hydrocarbon content in the first well section to be tested and the lowest total hydrocarbon content in the second well section to be tested, whether the baseline value of the total hydrocarbon content meets a first preset threshold, and the difference between the highest methane content in the first well section to be tested and the lowest methane content in the third well section to be tested. This further reflects the sharpness of the methane content peak from the perspective of the difference. Preferably, a difference between the highest and lowest methane content of 10% or more can be considered a condition for the existence of a single gas anomaly.

[0145] In one embodiment of this paper, further, the existence of a single gas anomaly can be determined based on the difference between the highest total hydrocarbon content in the first well section to be tested and the lowest total hydrocarbon content in the second well section to be tested, whether the base value of the total hydrocarbon content meets a first preset threshold, the difference between the highest methane content in the first well section to be tested and the lowest methane content in the third well section to be tested, and the difference between the highest methane content in the first well section to be tested and the base value of methane content. This further reflects the degree of methane content anomaly from the perspective of the difference. Preferably, a condition for the existence of a single gas anomaly can be considered when the difference between the highest methane content and the base value of methane content is greater than or equal to 5%.

[0146] In one embodiment of this article, such as Figure 7 As shown, based on the abnormal situation of a single gas outlet, it is determined whether to send an overflow risk warning, including:

[0147] Step 710: Sort the first well depths according to the determination time of the first well depth determined multiple times;

[0148] Step 720: Calculate the depth difference between adjacent first well depths to obtain a depth difference sequence;

[0149] Step 730: Determine the well depth difference variation pattern based on the well depth difference sequence, and send an overflow risk warning when the well depth variation pattern changes.

[0150] This embodiment determines whether the single gas anomaly occurs regularly by analyzing the well depth corresponding to multiple single gas anomalies, thereby ensuring the accuracy of determining the overflow risk.

[0151] In some embodiments of this paper, three first well depths are selected and sorted to obtain well depths of 4500m, 4529.5m and 4560m. By calculating the well depth difference between adjacent first well depths, the well depth difference sequence is obtained as (29.5, 30.5). At this time, the well depth difference is close, and the detected single gas anomaly appears in an equally spaced pattern. According to drilling experience, there is a large risk of overflow, and an overflow risk warning needs to be sent. Preferably, the well depth where the single gas anomaly occurs can be determined to have a certain regularity when the well depth difference is within 2.

[0152] In one embodiment of this article, such as Figure 8 As shown, the overflow risk early warning method based on single gas monitoring also includes:

[0153] Step 810: Based on the total hydrocarbon content corresponding to the first well depth determined multiple times, determine whether the total hydrocarbon content is not monotonically decreasing. If the determination is yes, proceed to step 820.

[0154] Step 820: Send an overflow risk warning.

[0155] This embodiment determines whether the total hydrocarbon content is not monotonically decreasing by analyzing the total hydrocarbon content corresponding to multiple single gas anomalies. It also determines whether the total hydrocarbon content meets the normal phenomenon of gradually decreasing and disappearing after reaching a peak. When the normal phenomenon is not met, it indicates a significant overflow risk, and an overflow risk warning needs to be sent, thus ensuring the accuracy of overflow risk determination.

[0156] In one embodiment of this paper, the warning information for sending overflow risk warnings is shown in Table 3.

[0157] Table 3

[0158]

[0159] Based on the early warning information, staff can take timely measures to prevent the risk of overflow.

[0160] Based on the same inventive concept, this paper also provides an overflow risk warning device based on single gas monitoring, as described in the following embodiments. Since the principle of solving the problem based on single gas monitoring is similar to that of the overflow risk warning method based on single gas monitoring, the implementation of the overflow risk warning device based on single gas monitoring can refer to the overflow risk warning method based on single gas monitoring, and the repeated parts will not be described again.

[0161] Specifically, such as Figure 9 As shown, the overflow risk early warning device based on single gas monitoring includes:

[0162] The acquisition module 910 is used to collect drilling data in real time, including drill bit position, well depth, total hydrocarbon content and hook height;

[0163] The first determining module 920 is used to determine the position of the drill bit when the hook is pulled up, based on the collected drilling data.

[0164] The second determining module 930 is used to determine the location data of the risk well section and the location data of the first well section to be tested based on the position of the drill bit when the hook is lifted.

[0165] The third determining module 940 is used to determine the position data of a single connecting section based on the real-time collected drill bit position and single drill rod length;

[0166] The fourth determining module 950 is used to determine whether a single connecting segment is located in a risky well section based on the location data of the single connecting segment and the location data of the risky well section; if the single connecting segment is located in a risky well section, the module monitors the gas anomaly of the single connecting segment based on the total hydrocarbon content data in the drilling data obtained at the location of the first test well section.

[0167] The analysis and early warning module 960 is used to determine whether to send an overflow risk warning based on the abnormal situation of a single gas pipe.

[0168] This embodiment takes into account that when the large hook is used to add drill pipe, the drill string will be lifted, causing the drill string to pump and stop the pump, which can easily lead to oil and gas entering the wellbore, resulting in single gas anomalies and causing overflow risks. Therefore, the risk section is determined based on the drill bit position when the large hook is lifted. At the same time, considering that single connection sections are susceptible to oil and gas intrusion, single gas anomaly detection is only performed when the single connection section is located in the risk section, reducing risk identification costs. The single gas anomaly is automatically judged by total hydrocarbon content data, and overflow risk warning is sent based on the analysis of the single gas anomaly, further reducing labor costs and improving the real-time performance of overflow risk warnings.

[0169] The method, device, and equipment for overflow risk early warning based on single gas monitoring provided in this paper collect drilling data in real time and determine the location of the risky well section and the single connecting section based on the drilling data to determine whether the single connecting section is in a risky area. When it is in a risky area, the single gas anomaly is judged, which reduces the risk identification cost. The method automatically judges the single gas anomaly by using total hydrocarbon content data and analyzes whether to send an overflow risk warning based on the single gas anomaly, which further reduces the labor cost and improves the real-time performance of overflow risk warning.

[0170] In one embodiment of this document, a computer device is also provided for implementing the methods described in any of the above embodiments, such as... Figure 10 The diagram illustrates the structure of a computer device according to an embodiment of this document. The computer device 1002 may include one or more processors 1004, such as one or more central processing units (CPUs), each of which may implement one or more hardware threads. The computer device 1002 may also include any memory 1006 for storing information of any kind, such as code, settings, data, etc. Without limitation, for example, the memory 1006 may include any type of RAM, any type of ROM, flash memory, hard disk, optical disk, etc. More generally, any memory can use any technology to store information. Furthermore, any memory may provide volatile or non-volatile retention of information. Furthermore, any memory may represent a fixed or removable component of the computer device 1002. In one case, when the processor 1004 executes associated instructions stored in any memory or combination of memories, the computer device 1002 may perform any operation of the associated instructions. The computer device 1002 also includes one or more drive mechanisms 1008 for interacting with any memory, such as hard disk drive mechanisms, optical disk drive mechanisms, etc.

[0171] Computer device 1002 may further include an input / output module 1010 (I / O) for receiving various inputs (via input device 1012) and providing various outputs (via output device 1014). A specific output mechanism may include a presentation device 1016 and an associated graphical user interface (GUI) 1018. In other embodiments, the input / output module 1010 (I / O), input device 1010, and output device 1014 may be omitted, and the device may function solely as a computer device within a network. Computer device 1002 may also include one or more network interfaces 1020 for exchanging data with other devices via one or more communication links 1022. One or more communication buses 1024 couple the components described above together.

[0172] The communication link 1022 can be implemented in any way, such as via a local area network, a wide area network (e.g., the Internet), a point-to-point connection, or any combination thereof. The communication link 1022 may include any combination of hardwired links, wireless links, routers, gateway functions, name servers, etc., governed by any protocol or combination of protocols.

[0173] Corresponding to Figures 1 to 8 In addition to the methods described above, this embodiment also provides a computer-readable storage medium storing a computer program that, when executed by a processor, performs the steps of the above-described methods.

[0174] This embodiment also provides a computer-readable instruction, wherein when a processor executes the instruction, the program therein causes the processor to perform the following: Figures 1 to 8 The method shown.

[0175] It should be understood that in the various embodiments of this document, the sequence number of each process does not imply the order of execution. The execution order of each process should be determined by its function and internal logic, and should not constitute any limitation on the implementation process of the embodiments of this document.

[0176] It should also be understood that, in the embodiments herein, the term "and / or" is merely a description of the relationship between associated objects, indicating that three relationships can exist. For example, A and / or B can represent: A existing alone, A and B existing simultaneously, and B existing alone. Additionally, the character " / " in this document generally indicates that the preceding and following associated objects have an "or" relationship.

[0177] Those skilled in the art will recognize that the units and algorithm 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. To clearly illustrate the interchangeability of 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 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 this document.

[0178] Those skilled in the art will clearly understand that, for the sake of convenience and brevity, the specific working processes of the systems, devices, and units described above can be referred to the corresponding processes in the foregoing method embodiments, and will not be repeated here.

[0179] In the embodiments provided herein, it should be understood that the disclosed systems, apparatuses, and methods can be implemented in other ways. For example, the apparatus embodiments described above are merely illustrative; for instance, the division of units is only a logical functional division, and in actual implementation, there may be other division methods. For example, multiple units or components may be combined or integrated into another system, or some features may be ignored or not executed. Furthermore, the couplings or direct couplings or communication connections shown or discussed may be indirect couplings or communication connections through some interfaces, devices, or units, or they may be electrical, mechanical, or other forms of connection.

[0180] The units described as separate components may or may not be physically separate. The components shown as units may or may not be physical units; that is, they may be located in one place or distributed across multiple network units. Some or all of the units can be selected to achieve the purpose of the embodiments described herein, depending on actual needs.

[0181] Furthermore, the functional units in the various embodiments of this document can be integrated into one processing unit, or each unit can exist physically separately, or two or more units can be integrated into one unit. The integrated unit can be implemented in hardware or as a software functional unit.

[0182] If the integrated unit is implemented as a software functional unit and sold or used as an independent product, it can be stored in a computer-readable storage medium. Based on this understanding, the technical solution of this paper, in essence, or the part that contributes to the prior art, or all or part of the technical solution, can be embodied in the form of a software product. This computer software product is stored in a storage medium and includes several instructions to cause a computer device (which may be a personal computer, server, or network device, etc.) to execute all or part of the steps of the methods described in the various embodiments of this paper. The aforementioned storage medium includes various media capable of storing program code, such as USB flash drives, portable hard drives, read-only memory (ROM), random access memory (RAM), magnetic disks, or optical disks.

[0183] This document uses specific embodiments to illustrate the principles and implementation methods of this document. The descriptions of the embodiments above are only for the purpose of helping to understand the methods and core ideas of this document. At the same time, for those skilled in the art, there will be changes in the specific implementation methods and application scope based on the ideas of this document. Therefore, the content of this specification should not be construed as a limitation of this document.

Claims

1. A method for early warning of overflow risk based on single gas monitoring, characterized in that, The method includes: Real-time collection of drilling data, including drill bit position, well depth, total hydrocarbon content, and hook height; Based on the collected drilling data, determine the position of the drill bit when the hook is pulled up; Based on the drill bit position when the large hook is pulled up, determine the location data of the risk section and the location data of the first section to be tested; Based on the real-time collected drill bit position and single drill rod length, determine the position data of a single connecting section; Based on the location data of the single connecting section and the location data of the risk well section, determine whether the single connecting section is located in the risk well section; if the single connecting section is located in the risk well section, monitor the gas anomaly of the single connecting section based on the total hydrocarbon content data obtained at the location of the first test well section. Based on the abnormal situation of a single gas outlet, determine whether to send an overflow risk warning.

2. The method as described in claim 1, characterized in that, Based on the real-time collected drill bit position and single drill pipe length, the position data of a single connecting section is determined, including: Subtract the preset single drill pipe length from the well depth at the real-time collected drill bit position to obtain the single connection reference position; The position data of a single connection segment are determined based on the reference position of the single connection and the length of the first preset interval.

3. The method as described in claim 1, characterized in that, Based on the total hydrocarbon content data obtained at the location of the first well section to be tested, monitor single-channel gas anomalies, including: Based on the total hydrocarbon content data corresponding to the first well section to be tested, the first well depth is determined. The first well depth is the well depth corresponding to the highest total hydrocarbon content in the first well section to be tested. The second well section to be tested is determined based on the first well depth and the second preset interval length; The presence of a single gas anomaly is determined by the ratio of the highest total hydrocarbon content in the first well section to be tested to the lowest total hydrocarbon content in the second well section to be tested.

4. The method as described in claim 3, characterized in that, Based on the total hydrocarbon content data obtained at the location of the first well section to be monitored, monitoring of single gas anomalies also includes: Subtract the first preset value from the first well depth to obtain the reference well depth for the total hydrocarbon content baseline value; The well section for determining the total hydrocarbon content baseline value is determined by subtracting the length of the third preset interval from the reference well depth. The base value of total hydrocarbon content is determined based on the total hydrocarbon content data corresponding to the well section with the base value of total hydrocarbon content. The step of determining whether a single gas anomaly exists further involves: determining whether a single gas anomaly exists based on the ratio of the highest total hydrocarbon content in the first well section to be tested to the lowest total hydrocarbon content in the second well section to be tested, and the ratio of the highest total hydrocarbon content in the first well section to the base value of the total hydrocarbon content.

5. The method as described in claim 4, characterized in that, The drilling data also includes the methane content corresponding to the well depth; The method further includes: Based on the methane content data corresponding to the first well section to be tested, the second well depth is determined. The second well depth is the well depth corresponding to the highest methane content in the first well section to be tested. The third well section to be measured is determined based on the second well depth and the fourth preset interval length; The step of determining whether a single gas anomaly exists further involves: determining whether a single gas anomaly exists based on the ratio of the highest total hydrocarbon content in the first well section to be tested to the lowest total hydrocarbon content in the second well section to be tested, the ratio of the highest total hydrocarbon content in the first well section to the base value of total hydrocarbon content, and the ratio of the highest methane content in the first well section to the lowest methane content in the third well section to be tested.

6. The method as described in claim 5, characterized in that, The method further includes: Subtracting the second preset value from the second well depth yields the reference well depth for the methane content baseline value. Subtract the length of the fifth preset interval from the reference well depth of the methane content baseline value to determine the well section of the methane content baseline value; The base methane content value is determined based on the methane content data corresponding to the well section with the base methane content value. The step of determining whether a single gas anomaly exists further involves: determining whether a single gas anomaly exists based on the ratio of the highest total hydrocarbon content in the first well section to be tested to the lowest total hydrocarbon content in the second well section to be tested, the ratio of the highest total hydrocarbon content in the first well section to the baseline value of total hydrocarbon content, the ratio of the highest methane content in the first well section to the lowest methane content in the third well section to the baseline value of methane content.

7. The method as described in claim 3, characterized in that, The further steps to determine whether a single gas anomaly exists are as follows: based on the difference between the highest total hydrocarbon content in the first well section to be tested and the lowest total hydrocarbon content in the second well section to be tested, determine whether a single gas anomaly exists.

8. The method as described in claim 4, characterized in that, The step of determining whether a single gas anomaly exists further involves: determining whether a single gas anomaly exists based on the difference between the highest total hydrocarbon content in the first test well section and the lowest total hydrocarbon content in the second test well section, and whether the total hydrocarbon content baseline value meets the first preset threshold.

9. The method as described in claim 5, characterized in that, The step of determining whether a single gas anomaly exists further includes: determining whether a single gas anomaly exists based on the difference between the highest total hydrocarbon content in the first test section and the lowest total hydrocarbon content in the second test section, whether the total hydrocarbon content base value meets the first preset threshold, and the difference between the highest methane content in the first test section and the lowest methane content in the third test section.

10. The method as described in claim 6, characterized in that, The step of determining whether a single gas anomaly exists further comprises: determining whether a single gas anomaly exists based on the difference between the highest total hydrocarbon content in the first test section and the lowest total hydrocarbon content in the second test section, whether the total hydrocarbon content baseline value meets the first preset threshold, the difference between the highest methane content in the first test section and the lowest methane content in the third test section, and the difference between the highest methane content in the first test section and the methane content baseline value.

11. The method as described in claim 3, characterized in that, Based on the abnormality of a single gas outlet, determine whether to send an overflow risk warning, including: The first well depths are sorted according to the determination time of the first well depth determined multiple times; Calculate the depth difference between adjacent first well depths to obtain a depth difference sequence; Based on the well depth difference sequence, the variation law of well depth difference is determined, and an overflow risk warning is sent when the well depth law changes.

12. The method as described in claim 11, characterized in that, The method further includes: Based on the total hydrocarbon content corresponding to the first well depth determined multiple times, determine whether the total hydrocarbon content is not monotonically decreasing. If the determination is yes, send an overflow risk warning.

13. An overflow risk early warning device based on single-gas monitoring, characterized in that, The device includes: The acquisition module is used to collect drilling data in real time, including drill bit position, well depth, total hydrocarbon content, and hook height; The first determining module is used to determine the position of the drill bit when the hook is pulled up, based on the collected drilling data. The second determining module is used to determine the location data of the risk well section and the location data of the first well section to be tested based on the position of the drill bit when the hook is lifted. The third determination module is used to determine the position data of a single connecting section based on the real-time collected drill bit position and single drill rod length; The fourth determining module is used to determine whether a single connecting segment is located in a risky well section based on the location data of the single connecting segment and the location data of the risky well section; if the single connecting segment is located in a risky well section, the module monitors the gas anomaly of the single connecting segment based on the total hydrocarbon content data in the drilling data obtained at the location of the first test well section. The analysis and early warning module is used to determine whether to send an overflow risk warning based on the abnormal situation of a single gas pipe.

14. A computer device comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, characterized in that, When the processor executes the computer program, it implements the method according to any one of claims 1 to 12.

15. A computer-readable storage medium storing a computer program, characterized in that, When the computer program is executed by the processor of a computer device, it implements the method according to any one of claims 1 to 12.

16. A computer program product, the computer program product comprising a computer program, characterized in that, When the computer program is executed by the processor of a computer device, it implements the method according to any one of claims 1 to 12.

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