A method, system, and device for identifying true and false CO2 emissions.

Abstract

This invention belongs to the field of oil and gas engineering, specifically relating to a method, system, and equipment for identifying true and false CO2 gas detection. It aims to solve the problem in existing technologies that the presence or absence of a single CO2 peak cannot identify the source of CO2 anomalies, thus failing to provide drilling operators with a basis for drilling fluid adjustment. The invention includes: acquiring drilling status; acquiring CO2 measurement values; identifying CO2 anomaly sections; acquiring the peak time; determining the presence of a single peak based on the peak time using a pre-constructed single-peak judgment method; and determining the presence of false detections based on the single peak. This invention effectively solves the problem of identifying true and false CO2 generation from multiple sources during drilling, providing drilling operators with a basis for drilling fluid adjustment and helping construction companies find valuable CO2 gas reservoirs.

Description

Technical Field

[0001] This invention belongs to the field of oil and gas engineering, and specifically relates to a method, system and equipment for identifying true and false CO2 gas detection. Background Technology

[0002] CO2 gas is frequently detected during gas logging in the B depression, with prolonged exposure and concentrations reaching up to 100%. As an acidic gas, high CO2 levels in drilling fluids can alter fluid properties and corrode drilling tools, hindering drilling operations. However, CO2 is also a widely used non-hydrocarbon gas, and finding industrially valuable CO2 reservoirs is a key objective of oil and gas exploration. Analysis of extensive CO2-containing logging data reveals that not all detected CO2 originates from the formation; approximately two-thirds come from drilling fluid additives. For example, FCLS (ferric chromium lignin sulfonate), a commonly used viscosity reducer and diluent in drilling fluids, is produced by fermenting and concentrating papermaking wastewater, adding ferrous sulfate and sodium dichromate for oxidative complexation, followed by spray drying. Its main component is carbon, which can generate CO2 during high-temperature fermentation in the well. Starch derivatives, commonly used fluid loss reducers, are also susceptible to bacterial degradation, producing CO2. Commonly used low-fluorescence liquid lubricants also generate CO2 at high well temperatures. With the advancement of drilling technology, the mechanical drilling speed is getting faster and faster, requiring the continuous preparation of new drilling fluid to replenish the wellbore, which in turn generates false CO2 indications.

[0003] Because CO2 generation has multiple sources, including both true formation indications and false anomalies caused by chemical reactions of drilling fluid additives, it is crucial to distinguish between genuine and false CO2 detections to objectively evaluate the gas content of the formation. The logging response characteristics of CO2 gas share similarities with those of total hydrocarbons, such as the level of the indicated value, curve shape, aftereffects, and single peaks.

[0004] Based on this, the present invention proposes a method, system and device for identifying true and false CO2 gas detection. Summary of the Invention

[0005] To address the aforementioned problems in the prior art, namely the inability to identify the source of CO2 anomalies by the presence or absence of a single CO2 peak and the inability to provide drilling fluid adjustment basis for drilling operators, this invention provides a method, system, and equipment for identifying true and false CO2 gas detection.

[0006] In one aspect, the present invention proposes a method for identifying the authenticity of CO2 gas detectors, the method comprising the following steps:

[0007] Step S10: During the drilling process, a well logging diagram is acquired; features of drilling parameters are extracted from the well logging diagram to obtain the drilling status;

[0008] Step S20: When it is detected that the drilling status is after the column or rod is connected and drilling is carried out again, the CO2 content in the wellbore is detected by the gas monitor and the CO2 measurement value is obtained.

[0009] Step S30: Obtain the baseline value of CO2 content; based on the baseline value and the measured CO2 value, obtain the CO2 anomaly well section;

[0010] Step S40: When the abnormal CO2 well section is obtained, and a non-abnormal CO2 well section appears, the time when the CO2 measurement value of the non-abnormal CO2 well section reaches its maximum is obtained as the first time; the difference between the first time and the start time when the CO2 measurement value is obtained again is calculated as the peak time; wherein, the non-abnormal CO2 well section is determined based on the base value and the CO2 measurement value.

[0011] Step S50: Based on the peak time, determine whether a single peak exists using a pre-constructed single peak determination method;

[0012] If it exists, proceed to step S60; if it does not exist, the CO2 abnormal well section is regarded as a CO2 false display well section, and proceed to step S10 to re-identify the true and false CO2 display until the drilling ends.

[0013] In step S60, the well section with CO2 anomalies before the first CO2 single peak appears is designated as the CO2 true display well section, and the process jumps to step S10 to re-identify the true and false CO2 display until drilling ends.

[0014] In some preferred embodiments, the features for extracting drilling parameters from the well logging chart include: well depth, drilling pressure, hook load, drill string speed, standpipe pressure, pump flush, outlet density, outlet conductivity, outlet temperature, and CO2 measurement.

[0015] In some preferred embodiments, when the drilling pressure, hook load, drill table rotation speed, standpipe pressure, pump flush, outlet density, and outlet conductivity are all zero, the outlet temperature is a set temperature, and the CO2 measurement value is zero, the drilling state is connected to the standpipe or rod.

[0016] In some preferred embodiments, the methods for obtaining the CO2 abnormal well section and the CO2 non-abnormal well section are as follows:

[0017] Well sections where the measured CO2 value is greater than a set multiple of the baseline value are identified as CO2 abnormal well sections; if so, they are CO2 abnormal well sections, otherwise they are CO2 non-abnormal well sections.

[0018] In some preferred embodiments, the presence of a single peak is determined by a pre-constructed single peak determination method, the method being as follows:

[0019] When the peak time corresponding to each non-abnormal CO2 well section is less than or equal to the late time, and the first peak time is equal to the late time, the first measurement value is obtained by combining the maximum CO2 measurement value corresponding to the non-abnormal CO2 well section and the increase in well depth. A single peak is obtained by judging based on the first measurement value and the first preset time.

[0020] The delay time is the time elapsed between the gas being extracted from the bottom of the well to the surface and being detected by the gas measuring instrument.

[0021] In some preferred embodiments, the first measurement value is:

[0022] The maximum CO2 measurement value corresponding to the peak time that does not change with increasing well depth is taken as the first measurement value.

[0023] In some preferred embodiments, the starting point and ending point of CO2 occurrence in the CO2 non-abnormal well section corresponding to the first measurement value are obtained as the CO2 starting inflection point and the CO2 ending inflection point; the maximum CO2 measurement value is obtained between the CO2 starting inflection point and the CO2 ending inflection point.

[0024] The time interval between the time of the initial inflection point of CO2 and the time of the maximum measured CO2 value is calculated and taken as the first time T1;

[0025] The time interval between the time of the CO2 termination inflection point and the time of the maximum CO2 measurement is calculated and used as the second time T2;

[0026] The maximum CO2 measurement value corresponding to the CO2 non-abnormal well section where both T1 and T2 are less than or equal to the first preset time is taken as a single peak.

[0027] In another aspect, the present invention proposes a CO2 true / false display gas meter identification system, based on a CO2 true / false display gas meter identification method, the system comprising:

[0028] The drilling status acquisition module is configured to acquire well logging diagrams during the drilling process; extract features of drilling parameters from the well logging diagrams to obtain the drilling status;

[0029] The measurement value acquisition module is configured to detect the CO2 content in the wellbore through a gas monitor and obtain the CO2 measurement value when the drilling status is detected as the connection of the column or rod and drilling is carried out again.

[0030] An abnormal well section acquisition module is configured to acquire a baseline value of CO2 content; based on the baseline value and the measured CO2 value, an abnormal CO2 well section is obtained;

[0031] The peak time acquisition module, when the abnormal CO2 well section is obtained, and a non-abnormal CO2 well section appears, acquires the time when the CO2 measurement value of the non-abnormal CO2 well section reaches its maximum, as the first time; calculates the difference between the first time and the start time when the CO2 measurement value is acquired again, as the peak time; wherein, the non-abnormal CO2 well section is determined based on the base value and the CO2 measurement value;

[0032] The first true / false display judgment module determines whether a single peak exists based on the peak emergence time and a pre-constructed single peak judgment method.

[0033] If it exists, proceed to the second true / false display judgment module; if it does not exist, the CO2 abnormal well section is regarded as a CO2 false display well section, and the drilling status acquisition module is redirected to re-identify the CO2 true / false display until drilling ends.

[0034] The second true / false display judgment module takes the CO2 abnormal well section before the first single peak appears as the CO2 true display well section, and jumps to the drilling status acquisition module to re-identify the CO2 true / false display until the drilling ends.

[0035] A third aspect of the present invention provides an electronic device comprising:

[0036] At least one processor; and

[0037] A memory communicatively connected to at least one of the processors; wherein,

[0038] The memory stores instructions that can be executed by the processor to implement the above-described method for identifying the authenticity of CO2 gas.

[0039] In a fourth aspect, the present invention provides a computer-readable storage medium storing computer instructions for execution by a computer to implement the above-described method for identifying the authenticity of CO2 gas.

[0040] The beneficial effects of this invention are:

[0041] This invention discloses a method for identifying true and false CO2 gas logging indications. It determines whether a CO2 anomaly is a true indication generated by the formation or a false indication caused by drilling fluid additives based on whether a single CO2 peak appears in the gas logging. If a single CO2 peak appears after the gas logging detects a CO2 anomaly and during single-logging or string connection, the detected CO2 anomaly is a true indication generated by the formation. If no single CO2 peak appears, it is a false indication caused by drilling fluid additives. This invention effectively solves the problem of identifying true and false CO2 sources during drilling, providing drilling operators with a basis for drilling fluid adjustments and helping construction companies find valuable CO2 gas reservoirs. Attached Figure Description

[0042] 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:

[0043] Figure 1 This is a flowchart illustrating a method for identifying the authenticity of CO2 levels according to the present invention.

[0044] Figure 2 This is a schematic diagram of the characteristic curve of true display gas logging parameters in a CO2 true / false display gas logging identification method of the present invention;

[0045] Figure 3 This is a schematic diagram of the characteristic curve of false display gas logging parameters in a CO2 true / false display gas logging identification method of the present invention;

[0046] Figure 4 This is a schematic diagram of single peak judgment in a CO2 true / false display gas measurement identification method of the present invention;

[0047] Figure 5 This is a schematic diagram of the structure of a computer system used to implement the methods, systems, and apparatus embodiments of this application. Detailed Implementation

[0048] 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.

[0049] 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.

[0050] like Figure 1 , Figure 2 , Figure 3 , Figure 4As shown in the first embodiment of the present invention, a method for identifying the authenticity of CO2 gas detectors is provided, the method comprising the following steps:

[0051] Step S10: During the drilling process, a well logging diagram is acquired; features of drilling parameters are extracted from the well logging diagram to obtain the drilling status;

[0052] Step S20: When it is detected that the drilling status is after the column or rod is connected and drilling is carried out again, the CO2 content in the wellbore is detected by the gas monitor and the CO2 measurement value is obtained.

[0053] Step S30: Obtain the baseline value of CO2 content; based on the baseline value and the measured CO2 value, obtain the CO2 anomaly well section;

[0054] Step S40: When the abnormal CO2 well section is obtained, and a non-abnormal CO2 well section appears, the time when the CO2 measurement value of the non-abnormal CO2 well section reaches its maximum is obtained as the first time; the difference between the first time and the start time when the CO2 measurement value is obtained again is calculated as the peak time; wherein, the non-abnormal CO2 well section is determined based on the base value and the CO2 measurement value.

[0055] Step S50: Based on the peak time, determine whether a single peak exists using a pre-constructed single peak determination method;

[0056] If it exists, proceed to step S60; if it does not exist, the CO2 abnormal well section is regarded as a CO2 false display well section, and proceed to step S10 to re-identify the true and false CO2 display until the drilling ends.

[0057] In step S60, the well section with CO2 anomalies before the first CO2 single peak appears is designated as the CO2 true display well section, and the process jumps to step S10 to re-identify the true and false CO2 display until drilling ends.

[0058] In step S10, a well logging diagram is acquired after a certain time interval, the certain time interval being determined by the time it takes to uncover a set of display layers.

[0059] This invention, based on the single peak generation mechanism, effectively identifies true and false CO2 gas indicators. During drilling, after drilling a drill pipe or standpipe, a new drill pipe or standpipe is connected to continue drilling. At this time, the drilling fluid is in a static state. Gas from the previously drilled gas-bearing formation will infiltrate and accumulate in the wellbore under the influence of pressure differential. After connecting the drill pipe or standpipe, the drilling fluid is recirculated for drilling. This gas is detected by the gas meter and is called a single peak. If there is no high-pressure gas-bearing layer in the drilled formation, gas will not accumulate in the wellbore when connecting the drill pipe or standpipe, and therefore no single peak will appear. Generally, single peaks are mostly reactions of hydrocarbon gases; CO2 single peaks are rare. A single peak is the re-detection of gas from a previously drilled gas-bearing formation; it is not a reaction of newly exposed gas-bearing formations, and therefore is called a false indicator, which must be removed from official data. In practice, after a CO2 anomaly occurs, it is necessary to check whether a single peak appears afterward. If a single peak appears, the previous CO2 anomaly was a genuine indication. If no single peak appears, it is a false indication caused by drilling fluid additives.

[0060] Preferably, the features for extracting drilling parameters from the well logging diagram include: well depth, drilling pressure, hook load, drill string rotation speed, standpipe pressure, pump flush, outlet density, outlet conductivity, outlet temperature, and CO2 measurement value.

[0061] Preferably, when the drilling pressure, hook load, drill table rotation speed, standpipe pressure, pump flush, outlet density, and outlet conductivity are all zero, the outlet temperature is the set temperature, and the CO2 measurement value is zero, the drilling state is connected to the standpipe or rod.

[0062] Preferably, the method for obtaining the CO2 abnormal well section and the CO2 non-abnormal well section is as follows:

[0063] Well sections where the measured CO2 value is greater than a set multiple of the baseline value are identified as CO2 abnormal well sections; if so, they are CO2 abnormal well sections, otherwise they are CO2 non-abnormal well sections.

[0064] The set multiple is 2-10 times, and in this embodiment, it is preferably 2 times.

[0065] Preferably, the existence of a single peak is determined by a pre-constructed single peak determination method, the method being as follows:

[0066] When the peak time corresponding to each non-abnormal CO2 well section is less than or equal to the late time, and the first peak time is equal to the late time, the first measurement value is obtained by combining the maximum CO2 measurement value corresponding to the non-abnormal CO2 well section and the increase in well depth. A single peak is obtained by judging based on the first measurement value and the first preset time.

[0067] The delay time is the time elapsed between the gas being extracted from the bottom of the well to the surface and being detected by the gas measuring instrument.

[0068] Preferably, the first measured value is:

[0069] The maximum CO2 measurement value corresponding to the peak time that does not change with increasing well depth is taken as the first measurement value.

[0070] Preferred, see Figure 4 The starting and ending points of CO2 in the non-abnormal CO2 well section corresponding to the first measurement value are obtained as the CO2 starting inflection point and the CO2 ending inflection point; the maximum CO2 measurement value is obtained between the CO2 starting inflection point and the CO2 ending inflection point.

[0071] The time interval between the time of the initial inflection point of CO2 and the time of the maximum measured CO2 value is calculated and taken as the first time T1;

[0072] The time interval between the time of the CO2 termination inflection point and the time of the maximum CO2 measurement is calculated and used as the second time T2;

[0073] The maximum CO2 measurement value corresponding to the CO2 non-abnormal well section where both T1 and T2 are less than or equal to the first preset time is taken as a single peak.

[0074] The single peak is a sharp peak that rises and falls rapidly.

[0075] The first preset time is 5 minutes.

[0076] like Figure 2 As shown, Figure 2 1. CO2 display; 2. Single peak; 3. Single peak; 4. Single peak; 5. Drilling pressure, hook load, rotary table speed; 6. Standpipe pressure, pump #1 flush, pump #2 flush; 7. Outlet density, outlet temperature, outlet conductivity; 8. Total hydrocarbons, CO2; 9. Drilling pressure, hook load, rotary table speed; 10. Standpipe pressure, pump #1 flush, pump #2 flush; 11. Outlet density, outlet temperature, outlet conductivity; 12. Total hydrocarbons, CO2; 13. Drilling pressure, hook load, rotary table speed; 14. Standpipe pressure, pump #1 flush, pump #2 flush; 15. Outlet density, outlet temperature, outlet conductivity; 16. Total hydrocarbons, CO2.

[0077] True embodiment shown, Figure 2 This is the logging diagram of well X9 in the X area of ​​Depression B.

[0078] During the drilling process, the drilling column was connected at depths of 2829.85m, 2858.52m, 2886.95m, and 2915.13m. No CO2 anomalies were detected in the gas logging before the well reached a depth of 2829m, but CO2 activity increased after that depth. Hereinafter, "late well depth" will be referred to as "well depth".

[0079] Based on the criteria for CO2 activity, drilling conditions, and abnormal layer classification, one CO2 abnormal well section and three CO2 abnormal points were identified in the 2820-2920m well section. The abnormal points are the peak points in the non-abnormal well sections. The well sections where abnormal points 2, 3, and 4 are located are non-abnormal well sections.

[0080] Anomaly section 1, well section 2829-2832m, thickness 3m, CO2 readings as follows Figure 2 As shown in Figure 1, the displayed value is 16.4%. The lateness time is 30 minutes.

[0081] Further anomaly point 2, well depth 2857m, CO2 readings as follows Figure 2 As shown in Figure 2, the displayed value is 8.2%, which is a rapid rise and fall peak, lasting for about 4.5 minutes, with the peak exit time being 30 minutes, the same as the late arrival time.

[0082] Further anomaly 2: 30 minutes prior, the well reached a depth of 2858.52m, with zero drilling pressure, hook load, and drill string rotation speed. Figure 2 As shown in Figure 5; the riser pressure, pump #1 flush, and pump #2 flush are all zero, as... Figure 2 As shown in Figure 6; the outlet density and outlet conductivity are both zero, and the outlet temperature is 20℃. Figure 2 As shown in Figure 7; CO2 is zero, as... Figure 2 As shown in Figure 8, based on the above parameter characteristics, this is a connection point for a column.

[0083] Further anomaly 2, based on the above parameter characteristics, is a single peak of anomaly segment 1.

[0084] Further anomaly point 3, well depth 2887m, CO2 reading as follows Figure 2 As shown in Figure 3, the displayed value is 7.6%, which is a rapid rise and fall peak, lasting for about 4.5 minutes, with a peak time of 30 minutes, the same as the peak time of anomaly point 2.

[0085] Further anomaly 3: 30 minutes prior, the well reached a depth of 2886.95m, with zero drilling pressure, hook load, and drill string rotation speed. Figure 2 As shown in Figure 9; the riser pressure, pump #1 flush, and pump #2 flush are all zero, as... Figure 2 As shown in Figure 10; the outlet density and outlet conductivity are both zero, and the outlet temperature is 20℃. Figure 2As shown in Figure 11; CO2 is zero, as... Figure 2 As shown in Figure 12, based on the above parameter characteristics, this is a connection point for a column.

[0086] Further anomaly point 3, as can be seen from the above parameter characteristics, is also a single peak of anomaly segment 1.

[0087] Further anomaly point 4, well depth 2916m, CO2 reading as follows Figure 2 As shown in Figure 4, the displayed value is 6.5%, which is a rapid rise and fall peak, lasting for about 4 minutes, with a peak time of 30 minutes, the same as the peak time of anomalies 2 and 3.

[0088] Further anomaly 4: 30 minutes prior, the well reached a depth of 2915.13m, with zero drilling pressure, hook load, and drill string rotation speed. Figure 2 As shown in Figure 13; the riser pressure, pump #1 flush, and pump #2 flush are all zero, as shown in Figure 13. Figure 2 As shown in Figure 14; the outlet density and outlet conductivity are both zero, and the outlet temperature is 22℃. Figure 2 As shown in Figure 15; CO2 is zero, as... Figure 2 As shown in Figure 16, based on the above parameter characteristics, this is a connection point for a column.

[0089] Further anomaly 4, as can be seen from the above parameter characteristics, is also a single peak of anomaly segment 1.

[0090] Based on the fact that a single CO2 peak appears every time the gas meter detects CO2, it is determined that the CO2 anomaly in section 1 is a true indication of the formation.

[0091] Anomaly layer verification:

[0092] The well was completed at a depth of 3500m. At a depth of 2830m, RDT testing was used to determine formation fluids, yielding a 200cm sample. 3 Gas composition analysis showed that CO2 accounted for 99.5%, which is consistent with the above judgment.

[0093] like Figure 3 As shown, Figure 3In the following parameters: 1. CO2 display; 2. Single peak; 3. Single peak; 4. Single peak; 5. Single peak; 6. Drilling pressure, hook load, rotary table speed; 7. Standpipe pressure, #1 pump flush, #2 pump flush; 8. Outlet density, outlet temperature, outlet conductivity; 9. Total hydrocarbons, CO2; 10. Drilling pressure, hook load, rotary table speed; 11. Standpipe pressure, #1 pump flush, #2 pump flush; 12. Outlet density, outlet temperature, outlet conductivity; 13. Total hydrocarbons, CO2; 14. Drilling pressure, hook load, rotary table speed; 15. Standpipe pressure, #1 pump flush, #2 pump flush; 16. Outlet density, outlet temperature, outlet conductivity; 17. Total hydrocarbons, CO2; 18. Drilling pressure, hook load, rotary table speed; 19. Standpipe pressure, #1 pump flush, #2 pump flush; 20. Outlet density, outlet temperature, outlet conductivity; 21. Total hydrocarbons, CO2.

[0094] Fake display embodiment, Figure 3 This is the logging diagram of well X10 in the X area of ​​Depression B.

[0095] During drilling, CO2 was observed at a depth of 3237.50m, with high values ​​lasting for approximately 22 minutes. Afterward, CO2 levels remained around 4.5% and gradually decreased. Based on the active CO2 indication, drilling conditions, and the criteria for classifying abnormal zones, the 3237.50-3240.00m range was identified as the CO2 anomaly zone.

[0096] The abnormal section is 3237.50-3240.00m, with a thickness of 2.50m. The CO2 reading is as follows: Figure 3 As shown in Figure 1, the displayed value is 12.4%. The lateness time is 40 minutes.

[0097] When drilling reached a depth of 3246.24m and a later depth of 3243.56m, the drilling pressure, hook load, and drill string rotation speed were all zero. Figure 3 As shown in Figure 6; the riser pressure, pump #1 flush, and pump #2 flush are all zero, as shown in Figure 6. Figure 3 As shown in Figure 7; the outlet density and outlet conductivity are both zero, and the outlet temperature is 21℃. Figure 3 As shown in Figure 8; CO2 is zero, as... Figure 3 As shown in Figure 9, based on the above parameter characteristics, this is the first single-core connection after drilling through the CO2 anomaly layer.

[0098] For the first single connection, after the drilling fluid circulation resumes, if a single peak appears, it should appear after 40 minutes. Figure 3 As shown in Figure 2, Figure 3 No single peak was observed at two locations.

[0099] When drilling reached a depth of 3255.81m and a later depth of 3253.24m, the drilling pressure, hook load, and drill string rotation speed were all zero. Figure 3As shown in Figure 10; the riser pressure, pump #1 flush, and pump #2 flush are all zero, as shown in Figure 10. Figure 3 As shown in Figure 11; the outlet density and outlet conductivity are both zero, and the outlet temperature is 25°C. Figure 3 As shown in Figure 12; CO2 is zero, as... Figure 3 As shown in Figure 13, based on the above parameter characteristics, this is the second single-core connection after drilling through the CO2 anomaly layer.

[0100] For the second single-joint drilling, after the drilling fluid circulation resumes, a single-joint peak should appear after 40 minutes. Figure 3 As shown in Figure 3, Figure 3 No single peak was observed at any of the three locations.

[0101] When drilling reached a depth of 3265.37m and a later depth of 3261.76m, the drilling pressure, hook load, and drill string rotation speed were all zero. Figure 3 As shown in Figure 14; the riser pressure, pump #1 flush, and pump #2 flush are all zero, as shown in Figure 14. Figure 3 As shown in Figure 15; the outlet density and outlet conductivity are both zero, and the outlet temperature is 22℃. Figure 3 As shown in Figure 16; CO2 is zero, as... Figure 3 As shown in Figure 17, based on the above parameter characteristics, this is the third single-core connection after drilling through the CO2 anomaly layer.

[0102] For the third single-joint drilling, after the drilling fluid circulation resumes, a single-joint peak should appear after 40 minutes. Figure 3 As shown in Figure 4, Figure 3 No single peak was observed at any of the four locations.

[0103] When drilling reached a depth of 3274.91m and a later depth of 3270.26m, the drilling pressure, hook load, and drill string rotation speed were all zero. Figure 3 As shown in Figure 18; the riser pressure, pump #1 flush, and pump #2 flush are all zero, as shown in Figure 18. Figure 3 As shown in Figure 19; the outlet density and outlet conductivity are both zero, and the outlet temperature is 22℃. Figure 3 As shown in Figure 20; CO2 is zero, as... Figure 3 As shown in Figure 21, based on the above parameter characteristics, this is the fourth single-core connection after drilling through the CO2 anomaly layer.

[0104] For the fourth single-joint drilling, after the drilling fluid circulation resumes, a single-joint peak should appear after 40 minutes. Figure 3 As shown in Figure 5, Figure 3 No single peak was observed at any of the five locations.

[0105] Based on the fact that no single CO2 peak was observed after four consecutive single-line tests following the detection of CO2 by the gas meter, it was determined that the CO2 anomaly in the 3237.50-3240.00m well section was not generated by the formation, but was caused by drilling fluid additives, and was a false indication.

[0106] Anomaly layer verification:

[0107] The well was completed at a depth of 4500m. At a depth of 3239m, the RDT testing process was used to determine the formation fluid, but no fluid was obtained. The test results are consistent with the above judgment.

[0108] 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.

[0109] A CO2 authenticity display gas meter identification system according to a second embodiment of the present invention, based on a CO2 authenticity display gas meter identification method, the system comprising:

[0110] The drilling status acquisition module is configured to acquire well logging diagrams during the drilling process; extract features of drilling parameters from the well logging diagrams to obtain the drilling status;

[0111] The measurement value acquisition module is configured to detect the CO2 content in the wellbore through a gas monitor and obtain the CO2 measurement value when the drilling status is detected as the connection of the column or rod and drilling is carried out again.

[0112] An abnormal well section acquisition module is configured to acquire a baseline value of CO2 content; based on the baseline value and the measured CO2 value, an abnormal CO2 well section is obtained;

[0113] The peak time acquisition module, when the abnormal CO2 well section is obtained, and a non-abnormal CO2 well section appears, acquires the time when the CO2 measurement value of the non-abnormal CO2 well section reaches its maximum, as the first time; calculates the difference between the first time and the start time when the CO2 measurement value is acquired again, as the peak time; wherein, the non-abnormal CO2 well section is determined based on the base value and the CO2 measurement value;

[0114] The first true / false display judgment module determines whether a single peak exists based on the peak emergence time and a pre-constructed single peak judgment method.

[0115] If it exists, proceed to the second true / false display judgment module; if it does not exist, the CO2 abnormal well section is regarded as a CO2 false display well section, and the drilling status acquisition module is redirected to re-identify the CO2 true / false display until drilling ends.

[0116] The second true / false display judgment module takes the CO2 abnormal well section before the first single peak appears as the CO2 true display well section, and jumps to the drilling status acquisition module to re-identify the CO2 true / false display until the drilling ends.

[0117] 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.

[0118] It should be noted that the CO2 true / false display gas measurement and identification system 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.

[0119] An electronic device according to a third embodiment of the present invention includes:

[0120] At least one processor; and

[0121] A memory communicatively connected to at least one of the processors; wherein,

[0122] The memory stores instructions that can be executed by the processor to implement the above-described method for identifying the authenticity of CO2 gas.

[0123] 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 method for identifying the authenticity of CO2 gas.

[0124] Those skilled in the art will understand that, for the sake of convenience and brevity, the specific working process and related descriptions of the storage device and processing device described above can be referred to the corresponding processes in the foregoing method embodiments, and will not be repeated here.

[0125] 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.

[0126] The following is for reference. Figure 5 It shows a schematic diagram of the structure of a computer system for implementing the methods, systems, and devices of this application. Figure 5 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.

[0127] like Figure 5 As shown, the computer system includes a Central Processing Unit (CPU) 501, which can perform various appropriate actions and processes based on programs stored in Read Only Memory (ROM) 502 or programs loaded from storage section 508 into Random Access Memory (RAM) 503. The RAM 503 also stores various programs and data required for system operation. The CPU 501, ROM 502, and RAM 503 are interconnected via a bus 504. An Input / Output (I / O) interface 505 is also connected to the bus 504.

[0128] The following components are connected to I / O interface 505: an input section 506 including a keyboard, mouse, etc.; an output section 507 including a cathode ray tube (CRT), liquid crystal display (LCD), etc., and speakers, etc.; a storage section 508 including a hard disk, etc.; and a communication section 509 including a network interface card such as a LAN (Local Area Network) card, modem, etc. The communication section 509 performs communication processing via a network such as the Internet. A drive 510 is also connected to I / O interface 505 as needed. Removable media 511, such as a disk, optical disk, magneto-optical disk, semiconductor memory, etc., are installed on drive 510 as needed so that computer programs read from them can be installed into storage section 508 as needed.

[0129] 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 509, and / or installed from removable medium 511. When the computer program is executed by central processing unit (CPU) 501, 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.

[0130] 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).

[0131] 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.

[0132] The terms “first”, “second”, etc., are used to distinguish similar objects, not to describe or indicate a specific order or sequence.

[0133] 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.

[0134] 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 method for identifying the authenticity of CO2 gas, characterized in that, The method includes the following steps: Step S10: During the drilling process, a well logging diagram is acquired; features of drilling parameters are extracted from the well logging diagram to obtain the drilling status; Step S20: When it is detected that the drilling status is after the column or rod is connected and drilling is carried out again, the CO2 content in the wellbore is detected by the gas monitoring instrument to obtain the CO2 measurement value. Step S30: Obtain the baseline value of CO2 content; based on the baseline value and the measured CO2 value, obtain the CO2 anomaly well section; Step S40: When the abnormal CO2 well section is obtained, and a non-abnormal CO2 well section appears, the time when the CO2 measurement value of the non-abnormal CO2 well section reaches its maximum is obtained as the first time. The difference between the first time and the start time of the next CO2 measurement is calculated as the peak time; wherein, the non-abnormal CO2 well section is determined based on the baseline value and the CO2 measurement value; Step S50: Based on the peak emergence time, determine whether a single peak exists using a pre-constructed single peak determination method; If it exists, proceed to step S60; if it does not exist, the CO2 abnormal well section is regarded as a CO2 false display well section, and proceed to step S10 to re-identify the true and false CO2 display until the drilling ends. In step S60, the CO2 abnormal well section before the first single peak appears is taken as the CO2 true display well section, and the process jumps to step S10 to re-identify the true and false CO2 display until drilling ends.

2. The CO2 true / false display gas measurement identification method according to claim 1, characterized in that, Features of drilling parameters extracted from the well logging diagram include: well depth, drilling pressure, hook load, drill string rotation speed, standpipe pressure, pump flush, outlet density, outlet conductivity, outlet temperature, and CO2 measurement.

3. The CO2 true / false display gas measurement identification method according to claim 2, characterized in that, When the drilling pressure, hook load, drill table rotation speed, standpipe pressure, pump pressure, outlet density, and outlet conductivity are all zero, the outlet temperature is the set temperature, and the CO2 measurement value is zero, then the drilling status is connected to the standpipe or rod.

4. The CO2 true / false display gas measurement identification method according to claim 1, characterized in that, The method for obtaining the CO2 abnormal well section and the CO2 non-abnormal well section is as follows: Well sections where the measured CO2 value is greater than a set multiple of the baseline value are identified as CO2 abnormal well sections; if so, they are CO2 abnormal well sections, otherwise they are CO2 non-abnormal well sections.

5. The CO2 true / false display gas detection method according to claim 1, characterized in that, The existence of a single peak is determined using a pre-constructed method for identifying single peaks. The method is as follows: When the peak time corresponding to each non-abnormal CO2 well section is less than or equal to the late time, and the first peak time is equal to the late time, the first measurement value is obtained by combining the maximum CO2 measurement value corresponding to the non-abnormal CO2 well section and the increase in well depth. A single peak is obtained by judging based on the first measurement value and the first preset time. The delay time is the time elapsed between the gas being extracted from the bottom of the well to the surface and being detected by the gas measuring instrument.

6. The CO2 true / false display gas measurement identification method according to claim 5, characterized in that, The first measured value is: The maximum CO2 measurement value corresponding to the peak time that does not change with increasing well depth is taken as the first measurement value.

7. The CO2 true / false display gas measurement identification method according to claim 6, characterized in that, Obtain the starting and ending points of CO2 in the non-abnormal CO2 well section corresponding to the first measurement value, and use them as the CO2 inflection point and the CO2 termination inflection point; obtain the maximum CO2 measurement value between the CO2 inflection point and the CO2 termination inflection point. The time interval between the time of the initial inflection point of CO2 and the time of the maximum measured CO2 value is calculated and taken as the first time T1; The time interval between the time of the CO2 termination inflection point and the time of the maximum CO2 measurement is calculated and used as the second time T2; The maximum CO2 measurement value corresponding to the CO2 non-abnormal well section where both T1 and T2 are less than or equal to the first preset time is taken as a single peak.

8. A CO2 authenticity detection system, characterized in that, A method for identifying the authenticity of CO2 gas detectors according to any one of claims 1-7, the system comprising: The drilling status acquisition module is configured to acquire well logging diagrams during the drilling process; extract features of drilling parameters from the well logging diagrams to obtain the drilling status; The measurement value acquisition module is configured to detect the CO2 content in the wellbore through a gas monitor and obtain the CO2 measurement value when the drilling status is detected as the connection of the column or rod and drilling is carried out again. An abnormal well section acquisition module is configured to acquire a baseline value of CO2 content; based on the baseline value and the measured CO2 value, an abnormal CO2 well section is obtained; The peak time acquisition module, when the abnormal CO2 well section is obtained, and a non-abnormal CO2 well section appears, acquires the time when the CO2 measurement value of the non-abnormal CO2 well section reaches its maximum, as the first time; calculates the difference between the first time and the start time when the CO2 measurement value is acquired again, as the peak time; wherein, the non-abnormal CO2 well section is determined based on the base value and the CO2 measurement value; The first true / false display judgment module determines whether a single peak exists based on the peak emergence time and a pre-constructed single peak judgment method. If it exists, proceed to the second true / false display judgment module; if it does not exist, the CO2 abnormal well section is regarded as a CO2 false display well section, and the drilling status acquisition module is redirected to re-identify the CO2 true / false display until drilling ends. The second true / false display judgment module takes the CO2 abnormal well section before the first single peak appears as the CO2 true display well section, and jumps to the drilling status acquisition module to re-identify the CO2 true / false display until the drilling ends.

9. An electronic device, characterized in that, include: At least one processor; as well as A memory communicatively connected to at least one of the processors; wherein, The memory stores instructions that can be executed by the processor to implement the CO2 true / false display gas measurement identification method according to any one of claims 1-7.

10. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores computer instructions that are executed by the computer to implement the CO2 true / false display gas measurement identification method according to any one of claims 1-7.

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