A drilling fluid total gas content quantitative calculation method based on multi-source data correction, a storage medium, a device and equipment

Abstract

This invention provides a method, apparatus, electronic device, and computer-readable storage medium for quantitatively calculating the total surface gas content of drilling fluid based on loss rate, degassing efficiency, and temperature correction. The method acquires field gas composition data, loss rate K1, degassing efficiency η, and temperature correction coefficient K3 during gas logging; wherein, the original field gas logging data G... 测 The total gas composition is represented by K1; the loss rate K1 is defined as the ratio of free gas content to the total gas content of the drilling fluid at the surface; the degassing efficiency η represents the proportion of the initial degassing detection volume to the amount of gas entering the degasser. Based on the degassing efficiency η, a degassing efficiency correction coefficient K2 is determined, and the temperature correction coefficient K3 is included in the adsorbed gas calculation item to calculate the adsorbed gas content; the relationship of free gas content is established based on the loss rate K1; and then G is calculated. 总 =K3×G 测 / [η×(1-K1)]. This invention reduces parameter redundancy and improves the accuracy of calculating the total surface gas content of drilling fluid.

Description

Technical Field

[0001] This invention relates to the field of oil and gas well logging data correction and drilling fluid gas content quantitative evaluation technology, and particularly to a method, device, electronic device and computer-readable storage medium for quantitatively calculating the total surface gas content of drilling fluid based on loss rate, degassing efficiency and temperature correction. Background Technology

[0002] Gas logging is a crucial field technique for discovering oil and gas shows, identifying fluid properties, and evaluating reservoir gas content during oil and gas well drilling. During drilling, formation fluids are returned to the surface from the wellbore along with cuttings and drilling fluid. The logging system typically releases gas from the returned drilling fluid using a degasser, and then a chromatograph or other gas detection equipment continuously acquires the detection values ​​for hydrocarbon gas components such as methane, ethane, propane, butane, and pentane.

[0003] Field gas measurements offer advantages such as strong continuity, rapid response, and sensitivity to oil and gas indications. However, the raw field gas measurements are not directly equivalent to the total surface gas content of the drilling fluid. This is mainly because, during the process of the drilling fluid flowing from the wellhead back to the degasser sampling location, some gas is lost or dissipates from the drilling fluid; this portion can be defined as free gas. Another portion of the gas remains in the drilling fluid and can enter the degasser detection process; this portion can be defined as adsorbed gas or retained gas.

[0004] Meanwhile, the degasser's ability to release gas remaining in the drilling fluid varies depending on the drilling fluid system and its properties, and the degassing efficiency is typically less than 1. Directly using the field measurement value as the actual amount of gas remaining in the drilling fluid would underestimate the adsorbed gas content. Therefore, correction is needed using the reciprocal of the degassing efficiency.

[0005] Furthermore, changes in drilling fluid temperature at the wellhead or degasser inlet can affect the release, diffusion, and detection response of gases remaining in the drilling fluid. The temperature correction factor K3 can be obtained experimentally or through field calibration. It is more suitable to include it in the adsorbed gas calculation item than to perform an overall correction on the sum of free gas and adsorbed gas; otherwise, the actual physical meaning and quantification method of K3 would be difficult to clarify.

[0006] The common processing methods in existing technologies mainly rely on the original on-site gas measurement values ​​G. 测 To evaluate the gas content of drilling fluid, G is typically used. 测 It is directly used as a characterization of drilling fluid gas content, without further distinguishing the free gas G lost from the drilling fluid. 自由 Adsorbed gas G that remains in the drilling fluid and enters the degassing process 吸附 Furthermore, no compensation or correction relationship has been established corresponding to free gas loss, degassing efficiency, and temperature effects, leading to reliance solely on G... 测It is difficult to accurately reflect the total gas content of drilling fluid at the surface. Therefore, there is an urgent need to establish a method that can accurately reflect the total gas content of drilling fluid at the surface. 测 Introducing G on the basis 自由 G 吸附 and corresponding compensation or correction coefficients, and with G 总 =G 自由 +G 吸附 Method for calculating the total surface gas content of drilling fluids that are connected. Summary of the Invention

[0007] The purpose of this invention is to provide a method, device, electronic device, and computer-readable storage medium for quantitatively calculating the total surface gas content of drilling fluid based on loss rate, degassing efficiency, and temperature correction, in order to solve the problem of inconsistent standards for loss rate, retention rate, degassing efficiency, and temperature correction parameters in the prior art.

[0008] This invention protects a method for quantitatively calculating the total surface gas content of drilling fluid based on loss rate, degassing efficiency, and temperature correction. The method is implemented by a computer and includes the following steps:

[0009] Acquire a real-time detection dataset during the gas logging process, wherein the real-time detection dataset includes at least field gas composition data, loss rate K1, degassing efficiency η, and temperature correction coefficient K3;

[0010] Based on the on-site gas composition data, determine the original on-site gas measurement data G. 测 Among them, G 测 It is the sum of the detected values ​​of multiple gas components;

[0011] Based on free gas content G 自由 Total surface gas content G of drilling fluid 总 Determine the loss rate K1, define free gas as the gas lost from the drilling fluid to the air, and adsorbed gas as the gas remaining in the drilling fluid and entering the degassing device detection process; establish the free gas content G based on the loss rate K1. 自由 Total surface gas content G of drilling fluid 总 The relationship between them, where: K1=G 自由 / G 总 , 0≤K1<1;

[0012] The degassing efficiency correction coefficient K2 is determined based on the degassing efficiency η, where: K2=1 / η, 0<η≤1, K2≥1;

[0013] The adsorbed gas content G was determined by correcting with temperature correction factor K3. 吸附 The temperature correction coefficient K3, which increases with increasing temperature, is added to the adsorbed gas calculation item to calculate the adsorbed gas content G. 吸附 , where: G 吸附 =K3×G 测×K2=K3×G 测 / η;

[0014] Inverse kinematics determines the total surface gas content G of the drilling fluid. 总 Based on G 总 =G 自由 +G 吸附 The inverse kinematics yields the total surface gas content G of the drilling fluid. 总 , where: G 总 =K3×G 测 / [η×(1-K1)].

[0015] Raw gas measurement data at the site G 测 The sum of gaseous components:

[0016] G 测 =C1+C2+C3+C4+C5.

[0017] Loss rate K1 is defined as the ratio of free gas content to total surface gas content:

[0018] K1=G 自由 / G 总 .

[0019] Where K1 is a dimensionless parameter, or expressed as a percentage; when expressed as a decimal, 0 ≤ K1 < 1. Therefore:

[0020] G 自由 =G 总 ×K1.

[0021] Degassing efficiency η represents the proportion of gas entering the degasser that is effectively detected by the on-site degassing detection process. η is a dimensionless parameter that satisfies:

[0022] 0 < η ≤ 1.

[0023] The degassing efficiency correction factor K2 is defined as the reciprocal of the degassing efficiency η:

[0024] K2=1 / η.

[0025] The temperature correction factor K3 is added to the adsorbed gas calculation item, and the adsorbed gas content is calculated as follows:

[0026] G 吸附 = K3 × G 测 × K2 = K3 × G 测 / η.

[0027] G 自由 =G 总 ×K1 and G 吸附 =K3×G 测 / η Substitute into G 总 =G 自由+G 吸附 ,get:

[0028] G 总 =G 总 ×K1+K3×G 测 / η.

[0029] The inverse kinematics yields the total surface gas content of the drilling fluid:

[0030] G 总 =K3×G 测 / [η×(1-K1)].

[0031] Equivalently, since K2 = 1 / η, the above equation can also be expressed as:

[0032] G 总 = K3 × K2 × G 测 / (1-K1).

[0033] This invention eliminates the need for independent, essential parameters that overlap with the meaning of loss rate. When it is necessary to represent the proportion of gas remaining in the drilling fluid and entering the degasser detection process, 1-K1 can be directly used to avoid parameter redundancy. Through the above technical means, the following can be achieved: First, it clarifies that free gas is the gas that has been lost, and adsorbed gas is the gas that remains in the drilling fluid and enters the degasser; Second, it clarifies that K1=G 自由 / G 总 The units are dimensionless or percentages; third, it is clear that η is less than or equal to 1, and K2 = 1 / η; fourth, it is clear that K3 is only included in G. 吸附 In the calculation, the problem of K3 being difficult to quantify during overall correction is avoided; fifth, the number of parameters is reduced to avoid multiple lost or retained parameters existing simultaneously. Attached Figure Description

[0034] Figure 1 A flowchart illustrating a method for quantitatively calculating the total surface gas content of drilling fluid, provided in an embodiment of the present invention;

[0035] Figure 2 A flowchart for determining the loss rate K1 is provided in an embodiment of the present invention;

[0036] Figure 3 A flowchart for determining degassing efficiency η and K2 is provided in an embodiment of the present invention;

[0037] Figure 4 A schematic diagram of the application position of the temperature correction coefficient K3 provided in an embodiment of the present invention;

[0038] Figure 5 This is a schematic diagram of a drilling fluid surface total gas content quantitative calculation device provided in an embodiment of the present invention;

[0039] Figure 6 A schematic diagram of an electronic device structure provided in an embodiment of the present invention;

[0040] Figure 7 This is a flowchart for quantitatively determining the total surface gas content, provided as an embodiment of the present invention. Detailed Implementation

[0041] The technical solution of the present invention will be further described below with reference to the accompanying drawings and embodiments. It should be understood that the described embodiments are only used to explain the present invention and are not intended to limit the scope of protection of the present invention.

[0042] In the description of this invention, unless otherwise expressly stated, the terms "comprising," "including," or any other variations thereof are intended to cover non-exclusive inclusion. The terms "first," "second," etc., are used only to distinguish different modules or steps and are not used to limit the order or importance of a particular module or step.

[0043] In this invention, free gas refers to gas lost from the drilling fluid; adsorbed gas refers to gas that remains in the drilling fluid and enters the degassing device detection process. The total surface gas content of the drilling fluid is:

[0044] G 总 = G 自由 + G 吸附 .

[0045] This invention preferably uses two core proportional parameters, K1 and η. K1 is the loss rate, defined as G. 自由 / G 总 η represents the degassing efficiency, indicating the proportion effectively detected by the on-site degassing testing process. Both are dimensionless parameters. K2 is not an independently measured parameter, but a degassing efficiency correction coefficient calculated from η, i.e., K2 = 1 / η.

[0046] Example 1: Quantitative Calculation Method for Total Gas Content of Drilling Fluid at the Surface

[0047] like Figure 1 , 7 As shown, this embodiment provides a method for quantitatively calculating the total surface gas content of drilling fluid based on loss rate, degassing efficiency, and temperature correction, including steps S101 to S107.

[0048] S101: Acquire real-time detection dataset during gas logging process

[0049] Acquire a real-time detection dataset during the gas logging process. The real-time detection dataset includes at least field gas composition data, loss rate K1, degassing efficiency η, and temperature correction coefficient K3.

[0050] Gas composition data can include C1, C2, C3, C4, and C5. C1 represents the methane detection value, C2 represents the ethane detection value, C3 represents the propane detection value, C4 represents the butane detection value, and C5 represents the pentane detection value. According to the output format of the on-site gas analyzer, C4 can be the sum of isobutane and n-butane, and C5 can be the sum of isopentane and n-pentane.

[0051] S102: Determine the original on-site gas measurement data G based on the on-site gas composition data. 测

[0052] Based on the gas composition data, determine the original on-site gas measurement data G. 测 :

[0053] G 测 = C1 + C2 + C3 + C4 + C5.

[0054] G 测 This is the sum of gas components detected by the on-site gas analyzer, and it is the basic input for adsorbed gas calculation.

[0055] S103: Based on free gas content G 自由 Total surface gas content G of drilling fluid 总 Determine the loss rate K1

[0056] The loss rate K1 is determined based on at least one of the following parameters: degasser installation location parameters, reflux trough structure parameters, drilling fluid flow parameters, and drilling fluid type parameters.

[0057] The loss rate K1 is defined as the ratio of free gas content to the total surface gas content of the drilling fluid, i.e.:

[0058] K1=G 自由 / G 总 .

[0059] K1 is dimensionless and can also be expressed as a percentage. When expressed as a decimal:

[0060] 0 ≤ K1 < 1.

[0061] From the definition of K1, we can obtain:

[0062] G 自由 =G 总 ×K1.

[0063] In this embodiment, no other loss or retention ratio parameters are set separately to avoid multiple parameters expressing similar meanings.

[0064] S104: Determine the degassing efficiency correction coefficient K2 based on the degassing efficiency η.

[0065] The degassing efficiency η is determined based on drilling fluid density, plastic viscosity, yield value, funnel viscosity, drilling fluid type, degasser operating parameters, experimental calibration data, or field multi-stage degassing comparison data. Figure 3 ).

[0066] Degassing efficiency η represents the proportion of gas entering the degasser that is effectively detected by the on-site degassing detection process, satisfying:

[0067] 0 < η ≤ 1.

[0068] The lower the degassing efficiency, the greater the actual amount of gas entering the degasser for the same G measurement. This invention defines the degassing efficiency correction coefficient K2 as:

[0069] K2=1 / η.

[0070] Therefore, K2 is a dimensionless parameter, and K2≥1.

[0071] S105: Determine the adsorbed gas content G by correcting for temperature correction factor K3. 吸附

[0072] The temperature correction coefficient K3 is determined based on the wellhead reflux channel temperature, the degasser inlet temperature, the temperature-gas measurement response model, or experimental calibration data.

[0073] K3 is a dimensionless parameter, preferably obtained through experimentation or field calibration. K3 is only included in the adsorbed gas calculation item and is not used for the calculation of G. 自由 +G 吸附 Perform overall calibration. This ensures that K3 corresponds to the portion of adsorbed gas that enters the degasser and is detected, facilitating measurement and quantification.

[0074] According to G 测 Calculate the adsorbed gas content using η and K3:

[0075] G 吸附 =K3×G 测 / η.

[0076] Since K2 = 1 / η, the above equation can also be expressed as:

[0077] G 吸附 =K3×G 测 ×K2.

[0078] When temperature correction is not enabled or experimental data for the corresponding temperature range is lacking, K3 can be set to 1. In this case:

[0079] G 吸附 =G 测 / η=G 测 ×K2.

[0080] S106: Inverse kinematics to determine the total surface gas content G of drilling fluid总

[0081] According to the definition of total surface gas content in drilling fluid:

[0082] G 总 =G 自由 +G 吸附 .

[0083] Substitute G 自由 =G 总 ×K1 and G 吸附 =K3×G 测 / η, resulting in:

[0084] G 总 =G 总 ×K1+K3×G 测 / η.

[0085] Solving the above equation inversely yields:

[0086] G 总 =K3×G 测 / [η×(1-K1)].

[0087] Or it can be expressed as:

[0088] G 总 =K3×K2×G 测 / (1-K1).

[0089] Calculate G 总 The free gas content can then be further expressed as:

[0090] G 自由 =G 总 ×K1.

[0091] Example 2: Method for determining the loss rate K1 ( Figure 2 )

[0092] This embodiment further illustrates the process of determining the loss rate K1.

[0093] The loss rate K1 can be determined based on the installation location of the degasser, the degree of openness of the return channel, the flow time of the drilling fluid from the wellhead return location to the sampling location of the degasser, the drilling fluid flow rate, the drilling fluid flow rate, and the drilling fluid type.

[0094] In one approach, a loss rate data table is established through field comparative experiments. For different equivalent flow distances, different degrees of return channel opening, and different drilling fluid types, the corresponding loss rate K1 is recorded. The system retrieves K1 from the data table based on the current well site parameters.

[0095] In another approach, K1 is determined using a loss rate calculation model. This model can be expressed as:

[0096] K1=f(L,t,A,v,Q,M).

[0097] Where L is the equivalent flow distance, t is the flow time, A is the degree of opening of the return channel, v is the drilling fluid velocity, Q is the drilling fluid flow rate, and M is the drilling fluid type. The model output K1 satisfies 0 ≤ K1 < 1.

[0098] If the engineering process requires describing the proportion that remains in the drilling fluid and enters the degassing unit testing process, it can be directly represented by 1-K1.

[0099] Example 3: Methods for determining degassing efficiency η and K2

[0100] This embodiment further illustrates the process of determining the degassing efficiency η and the degassing efficiency correction coefficient K2.

[0101] In one implementation, η is determined using a multi-stage degassing experiment. A single on-site degassing test is performed on the same drilling fluid sample to obtain the on-site test value G. 测 Subsequently, the same sample was subjected to supplemental degassing or complete degassing in the laboratory to obtain the amount of releasable gas G entering the degasser. 可释放 At this point, the degassing efficiency η can be expressed as:

[0102] η=G 测 / G 可释放 .

[0103] Due to G 测 Not greater than G 可释放 Therefore, η satisfies 0 < η ≤ 1. Correspondingly, the degassing efficiency correction coefficient is:

[0104] K2=1 / η=G 可释放 / G 测 .

[0105] Therefore, the adsorbed gas content can be expressed as:

[0106] G 吸附 =K3×G 测 ×K2.

[0107] For example, if the degassing efficiency η = 0.80 in a certain drilling fluid system, then K2 = 1 / 0.80 = 1.25. If K3 = 1.10, then G 吸附 =1.10×1.25×G 测 =1.375×G 测 .

[0108] Example 4: Method for determining the temperature correction coefficient K3 ( Figure 4 )

[0109] This embodiment further illustrates the method for determining the temperature correction coefficient K3.

[0110] Obtain the current wellhead reflux trough temperature or degasser inlet temperature T, and with the preset reference temperature T0 or experimental calibration temperature conditions as a reference, call the temperature-gas measurement response relationship model or experimental calibration data table to obtain the temperature correction coefficient K3.

[0111] K3 is only used for calculations involving adsorbed gases, i.e., G 吸附 =K3×G 测 / η. K3 is not used in G. 总 =G 自由 +G 吸附 The reason for the overall correction is that the free gas has been lost, and its temperature effect is not easy to be directly measured through on-site degassing experiments; while the adsorbed gas remains in the drilling fluid and enters the degasser, and K3 can be quantified by the relationship between the degasser inlet temperature and experimental calibration.

[0112] If experimental data or field calibration data for the corresponding temperature range are lacking, extrapolation without basis should not be performed, and K3 can be set to 1.

[0113] Example 5: Comprehensive Calculation of All Hydrocarbons

[0114] This example illustrates the calculation process under the comprehensive hydrocarbon calculation mode.

[0115] Assuming the on-site gas analyzer detects five components: C1, C2, C3, C4, and C5, the original on-site gas analysis data is as follows:

[0116] G 测 = C1 + C2 + C3 + C4 + C5.

[0117] Assuming a loss rate K1 = 0.20 and a degassing efficiency η = 0.80, then K2 = 1 / 0.80 = 1.25. If the temperature correction coefficient K3 = 1.10, then:

[0118] G 吸附 =K3×G 测 / η=1.10×G 测 / 0.80=1.375×G 测 .

[0119] According to G 总 = G 自由 +G 吸附 And G 自由 =G 总 ×K1, we can obtain:

[0120] G 总 =1.10×G 测 / [0.80×(1-0.20)]=1.71875×G 测 .

[0121] Furthermore, we can obtain:

[0122] G 自由 =G 总 ×0.20 = 0.34375 × G 测 ;

[0123] G 吸附 =1.375×G 测 .

[0124] The above results satisfy G 总 =G 自由 +G 吸附 .

[0125] Example 6: Grouping and Calculation Example

[0126] If the degassing efficiency η is set separately for different gas components i With the temperature correction coefficient K3,i, the adsorbed gas content can be expressed as:

[0127] G 吸附 =Σ(K3,i×G 测 ,i / η i ).

[0128] When using a uniform loss rate K1, the total surface gas content of the drilling fluid is:

[0129] G 总 =Σ(K3,i×G 测 ,i / ηi) / (1-K1).

[0130] This method can take into account the differences in degassing efficiency and temperature response of different components, and is suitable for scenarios where gas component data is complete and experimental calibration data is sufficient.

[0131] Example 7: Quantitative Calculation Device for Total Gas Content at the Surface of Drilling Fluid

[0132] like Figure 5 As shown, this embodiment provides a quantitative calculation device 500 for the total surface gas content of drilling fluid based on loss rate, degassing efficiency, and temperature correction. It includes a data acquisition module, a component summation module, a loss rate determination module, a degassing efficiency correction module, an adsorbed gas calculation module, and a total gas content reverse decomposition module.

[0133] The data acquisition module 510 is used to acquire real-time detection datasets during the gas logging process.

[0134] The component summation module 520 is used to determine G based on C1, C2, C3, C4, and C5. 测 .

[0135] The loss rate determination module 530 is used to determine K1=G自由 / G 总 .

[0136] The degassing efficiency correction module 540 is used to determine the degassing efficiency correction coefficient K2 based on K2=1 / η.

[0137] The adsorbed gas calculation module 550 is used to determine the temperature correction factor K3 that applies only to the adsorbed gas calculation item, and to determine the adsorbed gas content G based on the temperature correction factor K3. 吸附 = K3×G 测 ×K2.

[0138] The total gas content reverse analysis module 560 is used to determine the total gas content based on G. 总 =G 自由 +G 吸附 and G 自由 =G 总 ×K1, inverse solution yields G 总 =K3×G 测 / [η×(1-K1)].

[0139] Example 8: Electronic Equipment

[0140] like Figure 6 As shown, this embodiment provides an electronic device 600, including a processor 610, a memory 620, and a bus 630.

[0141] The memory stores machine-readable instructions executable by the processor. When the electronic device is running, the processor communicates with the memory via the bus, and when the machine-readable instructions are executed by the processor, the method for quantitatively calculating the total surface gas content of drilling fluid as described in any of the above embodiments is implemented.

[0142] The electronic device can be a field computer for logging, a server, an edge computing terminal, an industrial control computer, a portable computing device, or a computing node deployed in a logging software platform.

[0143] Example 9: Computer-readable storage medium

[0144] This embodiment provides a computer-readable storage medium on which a computer program is stored. When the computer program is executed by a processor, it implements the method for quantitatively calculating the total surface gas content of drilling fluid as described in any of the above embodiments.

[0145] The computer-readable storage medium may include, but is not limited to, a hard disk, an optical disk, a read-only memory, a random access memory, a flash memory, a portable hard disk, a solid-state drive, or other media capable of storing computer programs.

[0146] Note: Regarding the handling of parameter caliber

[0147] In this application, K1 is defined as the loss rate, satisfying K1=G 自由 / G 总 The unit is dimensionless or percentage.

[0148] In this application, η is defined as the degassing efficiency, satisfying 0 < η ≤ 1; K2 is defined as the degassing efficiency correction coefficient, satisfying K2 = 1 / η.

[0149] In this application document, K3 is included in the adsorption gas calculation item, and G... 吸附 =K3×G 测 / η, instead of using it for G 自由 + G 吸附 Perform overall calibration.

[0150] In this application, no independent necessary parameters that overlap with the meaning of loss rate are introduced. If it is necessary to express the proportion of gas remaining in the drilling fluid, 1-K1 is used directly.

[0151] The above description is merely a preferred embodiment of the present invention and is not intended to limit the invention. For those skilled in the art, various modifications, equivalent substitutions, and improvements can be made to the present invention without departing from its principles and spirit. Any modifications, equivalent substitutions, and improvements made within the spirit and principles of the present invention should be included within the scope of protection of the present invention.

Claims

1. A quantitative calculation method for the total surface gas content of drilling fluid based on loss rate, degassing efficiency, and temperature correction, wherein the method is implemented by a computer, characterized in that... Includes the following steps: Acquire a real-time detection dataset during the gas logging process, wherein the real-time detection dataset includes at least field gas composition data, loss rate K1, degassing efficiency η, and temperature correction coefficient K3; Based on the on-site gas composition data, determine the original on-site gas measurement data G. 测 Among them, G 测 It is the sum of the detected values ​​of multiple gas components; Based on free gas content G 自由 Total surface gas content G of drilling fluid 总 Determine the loss rate K1, define free gas as the gas lost from the drilling fluid to the air, and adsorbed gas as the gas remaining in the drilling fluid and entering the degassing device detection process; establish the free gas content G based on the loss rate K1. 自由 Total surface gas content G of drilling fluid 总 The relationship between them, where: K1=G 自由 / G 总 , 0≤K1<1; The degassing efficiency correction coefficient K2 is determined based on the degassing efficiency η, where: K2=1 / η, 0<η≤1, K2≥1; The adsorbed gas content G was determined by correcting with temperature correction factor K3. 吸附 The temperature correction coefficient K3, which increases with increasing temperature, is added to the adsorbed gas calculation item to calculate the adsorbed gas content G. 吸附 , where: G 吸附 =K3×G 测 ×K2=K3×G 测 / η; Inverse kinematics determines the total surface gas content G of the drilling fluid. 总 Based on G 总 =G 自由 +G 吸附 The inverse kinematics yields the total surface gas content G of the drilling fluid. 总 , where: G 总 =K3×G 测 / [η×(1-K1)].

2. The method for quantitatively calculating the total surface gas content of drilling fluid according to claim 1, characterized in that, The original on-site gas measurement data G 测 Determine using the following formula: G 测 =C1+C2+C3+C4+C5; Wherein, C1, C2, C3, C4 and C5 represent the methane, ethane, propane, butane and pentane component detection values ​​detected by the on-site gas analyzer, respectively. C4 includes isobutane and / or n-butane, and C5 includes isopentane and / or n-pentane.

3. The method for quantitatively calculating the total surface gas content of drilling fluid according to claim 1, characterized in that, The loss rate K1 is a dimensionless parameter, or expressed as a percentage; when expressed as a decimal, the value range of K1 is 0 ≤ K1 < 1; when expressed as a percentage, the value range of K1 is 0% ≤ K1 < 100%.

4. The method for quantitatively calculating the total surface gas content of drilling fluid according to claim 1, characterized in that, The loss rate K1 is determined based on at least one of the following parameters: degasser installation location parameters, reflux tank structure parameters, drilling fluid flow parameters, and drilling fluid type parameters. The degasser installation location parameters include at least one of the following: vertical distance from the degasser sampling point to the wellhead return point, horizontal distance, equivalent flow distance, sampling tube length, and sampling point depth. The reflux tank structure parameters include at least one of the following: reflux tank open section length, closed section length, tank width, tank depth, slope, fluid flow velocity, drilling fluid flow rate, and fluid level height. The degassing efficiency η is a dimensionless parameter representing the proportion of gas entering the degasser that is effectively detected by the on-site degassing detection process, and satisfies the following: 0 < η ≤ 1; the degassing efficiency correction coefficient K2 is the reciprocal of the degassing efficiency η, and satisfies: K2 = 1 / η, K2 ≥ 1; The adsorbed gas content G 吸附 It can also be expressed as: G 吸附 =K3×G 测 ×K2。 5. The method for quantitatively calculating the total surface gas content of drilling fluid according to claim 1, characterized in that, The temperature correction coefficient K3 is a dimensionless parameter, determined based on at least one of the following: wellhead reflux channel temperature, degasser inlet temperature, temperature-gas measurement response model, and experimental calibration data. Furthermore, the temperature correction coefficient K3 is used only to correct for the adsorbed gas content G. 吸附 K3 is used to normalize the total surface gas content under different wellhead temperatures or degasser inlet temperatures to a preset reference temperature caliber, and is not used for G. 自由 +G 吸附 Perform overall calibration; When temperature correction is not enabled or experimental calibration data for the corresponding temperature range is lacking, K3=1 is taken, then: G 吸附 =G 测 / or; G 总 =G 测 / [η×(1-K1)].

6. The method for quantitatively calculating the total surface gas content of drilling fluid according to any one of claims 1 to 5, characterized in that, The real-time detection dataset no longer sets independent calculation parameters that overlap with the meaning of loss rate; when it is necessary to represent the proportion of gas remaining in the drilling fluid and entering the degasser detection process, 1-K1 is used.

7. The method for quantitatively calculating the total surface gas content of drilling fluid according to any one of claims 1 to 5, characterized in that, The total surface gas content G of the drilling fluid 总 After the calculation is completed, the free gas content is also determined according to the following formula: G 自由 =G 总 ×K1; The adsorbed gas content is determined according to the following formula: G 吸附 =K3×G 测 / or.

8. The method for quantitatively calculating the total surface gas content of drilling fluid according to any one of claims 1 to 5, characterized in that, When using a group-based calculation method, the adsorbed gas content is determined according to the following formula: G 吸附 = Σ(K3,i × G measured,i / η[[ID=,3]] i ); It should be noted that there seems to be a potential error in your original text where there is an unexpected comma in "[[ID=,3]]". If this is a typo, please correct it in the original text for a more accurate translation process. The above translation is based on the provided text as is. Among them, G 测 ,i is the detected value of the i-th gas component, ηi is the degassing efficiency corresponding to the i-th gas component, and K3,i is the temperature correction coefficient corresponding to the i-th gas component; when a uniform loss rate K1 is used, the total surface gas content of the drilling fluid is: G 总 =Σ(K3,i×G 测 ,i / h i ) / (1-K1).

9. The method for quantitatively calculating the total surface gas content of drilling fluid according to any one of claims 1 to 5, characterized in that, The degassing efficiency η is determined based on at least one of the following: drilling fluid density, plastic viscosity, yield value, funnel viscosity, oil content, water content, solid content, drilling fluid type, degasser operating parameters, experimental calibration data, and field multi-stage degassing comparison data.

10. A quantitative calculation device for the total surface gas content of drilling fluid based on loss rate, degassing efficiency, and temperature correction, characterized in that, include: The data acquisition module is used to acquire real-time detection datasets during the gas logging process. The real-time detection datasets include at least field gas composition data, loss rate K1, degassing efficiency η, and temperature correction coefficient K3. The component summation module is used to determine G based on gas component data. 测 =C1+C2+C3+C4+C5; The loss rate determination module is used to determine K1=G 自由 / G 总 ; The degassing efficiency correction module is used to determine the degassing efficiency correction coefficient K2 based on K2=1 / η; The adsorption gas calculation module is used to calculate based on G. 吸附 =K3×G 测 Calculate the adsorbed gas content using ×K2; Total gas content reverse analysis module, used to determine the total gas content based on G 总 =G 自由 +G 吸附 and G 自由 =G 总 The inverse solution of ×K1 yields G. 总 =K3×G 测 / [η×(1-K1)]; further, it also includes a free gas calculation module, which is used to calculate the total gas content G of the drilling fluid at the surface. 总 After the calculation is completed, according to G 自由 =G 总 Calculate the free gas content using ×K1.

11. An electronic device, characterized in that, It includes a processor, a memory, and a bus; the memory stores machine-readable instructions executable by the processor; when the electronic device is running, the processor communicates with the memory via the bus, and when the machine-readable instructions are executed by the processor, they implement the method for quantitatively calculating the total surface gas content of drilling fluid as described in any one of claims 1 to 9.

12. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores a computer program, which, when executed by a processor, implements the method for quantitatively calculating the total surface gas content of drilling fluid as described in any one of claims 1 to 9.

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