Drilling fluid additive detection apparatus, drilling fluid testing method and device

Abstract

The application provides a drilling fluid additive detection device, a drilling fluid testing method and device, and the method comprises the following steps: setting an initial injection temperature and pressure, performing injection treatment on the drilling fluid to obtain a gas to be analyzed; analyzing the gas to be analyzed to obtain a gas logging component under the initial injection temperature and pressure; modifying the injection temperature and pressure, performing injection treatment and analysis on the drilling fluid again under the modified injection temperature and pressure to obtain a gas logging component under the modified injection temperature and pressure; and determining the influence of the drilling fluid additive on the gas logging component under different injection temperatures and pressures according to the gas logging components under different injection temperatures and pressures. Compared with the prior art, the drilling fluid is treated and analyzed under different injection temperatures and pressures, the influence degree and result of the drilling fluid additive on the gas logging component under different temperatures and pressures are obtained, and thus the accuracy of the gas logging oil and gas layer evaluation of the reservoir logging is improved.

Description

Technical Field

[0001] This application relates to the field of oil and gas exploration and development technology, and in particular to a drilling fluid additive testing device, a drilling fluid testing method and apparatus. Background Technology

[0002] Gas logging is a method for identifying oil and gas reservoirs and an important tool for oil and gas exploration. Although gas logging plays a crucial role in discovering and evaluating oil and gas reservoirs, it cannot fully reflect the oil and gas content of the formation. This is because gas logging is affected by various factors, which significantly impact its accuracy.

[0003] To improve specific properties of drilling fluids or protect oil and gas reservoirs, various additives are typically added to drilling fluids. Commonly used additives include zwitterionic filtration reducers (ZRH series), white oil, sulfonated asphalt, emulsifiers, defoamers, sodium dehydroacetate (MG-1), and calcium sulfonate ester additives (FT-1). Crude oil or diesel oil may be added to handle drilling accidents. For specific purposes, oil-mixed or oil-based drilling fluids may be used. Therefore, the addition of various organic additives and oil mixing in drilling is practically unavoidable, creating a conflict between obtaining complete and accurate data and drilling safety.

[0004] The main reason why additives in water-based and oil-based drilling fluids affect gas logging parameters is that the various organic processing agents, crude oil, and diesel oil in these fluids are mostly composed of unsaturated hydrocarbons, which can crack under high temperature and pressure conditions in the well, producing hydrocarbons. This poses certain difficulties and impacts on conventional logging operations. Currently, the extent to which additives in water-based and oil-based drilling fluids affect gas logging parameters, and consequently, the accuracy of reservoir logging and oil and gas layer evaluation, remains unclear. Summary of the Invention

[0005] This application provides a drilling fluid additive testing device, a drilling fluid testing method, and an apparatus to solve the problem in the prior art where the influence of drilling fluid additives on gas logging components is uncertain, thus affecting the accuracy of reservoir logging oil and gas layer evaluation.

[0006] The first aspect of this application provides a drilling fluid additive testing device, the device comprising: an injection component, an analysis component, and a control component;

[0007] The injection component is used to inject the drilling fluid at a set temperature and pressure, and to transmit the gas to be analyzed generated after the injection to the analysis component; the drilling fluid includes at least one additive.

[0008] The analysis component is used to analyze the gas to be analyzed and transmit the analysis results to the control component;

[0009] The control component is used to control the injection component and the analysis component, process the analysis results of the analysis component, adjust the temperature and pressure of the injection component, and based on the adjusted temperature and pressure, control the injection component and the analysis component to continue injection processing and analysis.

[0010] In one alternative implementation, the injection assembly includes: an injection container, a filter, and a dehydrator;

[0011] The filter and the dehydrator are connected in sequence to the degassing port of the injection container. The filter and the dehydrator are used to remove impurities and moisture from the gas.

[0012] In one alternative embodiment, the injection container is equipped with a stirrer for stirring the drilling fluid to allow gas in the drilling fluid to escape.

[0013] In one alternative embodiment, the injection container is provided with a temperature regulator and a pressure regulator;

[0014] The temperature regulator is used to adjust the temperature of the injection container to the temperature set by the control component;

[0015] The pressure regulator is used to adjust the pressure of the injection container to the pressure set by the control component.

[0016] In one alternative embodiment, the pressure relief port of the injection container is connected to a vacuum pump for extracting gas from the injection container.

[0017] In one alternative implementation, the analytical component is a complete desorption analyzer or a gas measuring instrument.

[0018] In one optional embodiment, the injection process includes: stirring the drilling fluid to allow gas to escape from the drilling fluid; filtering and dehydrating the escaped gas to obtain the gas to be analyzed.

[0019] A second aspect of this application provides a method for testing drilling fluid, comprising:

[0020] An initial injection temperature and pressure are set, and the drilling fluid is injected to obtain the gas to be analyzed. The drilling fluid includes at least one additive.

[0021] The gas to be analyzed is analyzed to obtain the gas composition at the initial injection temperature and pressure.

[0022] The injection temperature and pressure are modified, and the drilling fluid is injected and analyzed again under the modified injection temperature and pressure to obtain the gas composition under the modified injection temperature and pressure.

[0023] Based on the gas sampling components under different injection temperatures and pressures, the influence of drilling fluid additives on the gas sampling components under different injection temperatures and pressures is determined.

[0024] In one optional implementation, the step of setting an initial injection temperature and pressure, and injecting the drilling fluid to obtain the gas to be analyzed, includes:

[0025] The initial injection temperature and pressure are set based on the temperature and pressure of the original formation.

[0026] Stir the drilling fluid to allow the gas inside the drilling fluid to escape;

[0027] The escaped gas is filtered and dehydrated to obtain the gas to be analyzed.

[0028] In one alternative implementation, the injection temperature and pressure are the temperature and pressure under different well depth conditions.

[0029] In one alternative embodiment, the drilling fluid includes a water-based drilling fluid or an oil-based drilling fluid.

[0030] In one alternative embodiment, the additive includes at least one of the following: clay, weighting material, thickener / coating agent, filtration loss reducer, shale inhibitor, lubricant, viscosity reducer, emulsifier, sealant, and defoamer.

[0031] In one optional embodiment, determining the effect of drilling fluid additives on the gas sampling components at different injection temperatures and pressures, based on the gas sampling components at different injection temperatures and pressures, includes:

[0032] Obtain experimental data from multiple sets of tests of the drilling fluid at the same injection temperature and pressure;

[0033] Based on the experimental data, a total hydrocarbon curve for gas analysis was plotted to obtain the effect of the drilling fluid additives on gas analysis components under the same injection temperature and pressure.

[0034] Obtain experimental data from multiple sets of tests on the drilling fluid at different injection temperatures and pressures;

[0035] Based on the experimental data, the total hydrocarbon curve of the gas was plotted to determine the effect of the drilling fluid additives on the gas components under different injection temperatures and pressures.

[0036] In one optional implementation, plotting the total hydrocarbon curve based on the experimental data includes:

[0037] The total hydrocarbon curve is evaluated, and any abnormal displays are eliminated.

[0038] A third aspect of this application provides a drilling fluid testing apparatus, the apparatus comprising:

[0039] An injection module is used to set the initial injection temperature and pressure, inject the drilling fluid to obtain the gas to be analyzed, wherein the drilling fluid includes at least one additive;

[0040] The analysis module is used to analyze the gas to be analyzed and obtain the gas composition at the initial injection temperature and pressure.

[0041] The processing module is used to modify the injection temperature and pressure, and to perform the injection processing and analysis on the drilling fluid again under the modified injection temperature and pressure to obtain the gas detection components under the modified injection temperature and pressure; based on the gas detection components under different injection temperatures and pressures, the influence of the drilling fluid additives on the gas detection components under different injection temperatures and pressures is determined.

[0042] The drilling fluid additive detection equipment, drilling fluid testing method, and apparatus provided in this application first set an initial injection temperature and pressure, injecting the drilling fluid to obtain the gas to be analyzed. The drilling fluid includes at least one additive. Then, the gas to be analyzed is obtained to obtain the gas composition at the initial injection temperature and pressure. Subsequently, the injection temperature and pressure are modified, and the drilling fluid is injected and analyzed again at the modified injection temperature and pressure to obtain the gas composition at the modified injection temperature and pressure. Finally, based on the gas composition at different injection temperatures and pressures, the influence of drilling fluid additives on the gas composition at different injection temperatures and pressures is determined. Compared with the prior art, this application improves the accuracy of reservoir logging oil and gas layer evaluation by accurately understanding the influence of additives in water-based and oil-based drilling fluids on the gas composition at different temperatures and pressures. Attached Figure Description

[0043] To more clearly illustrate the technical solutions in this invention or the prior art, the drawings used in the description of the embodiments or the prior art will be briefly introduced below. Obviously, the drawings described below are some embodiments of this invention. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0044] Figure 1A schematic diagram illustrating an application scenario of a drilling fluid testing method provided in this application embodiment;

[0045] Figure 2 This is a schematic diagram of the structure of a drilling fluid additive testing device provided in an embodiment of this application;

[0046] Figure 3 A schematic flowchart of a drilling fluid testing method provided in an embodiment of this application;

[0047] Figure 4 A schematic flowchart of another drilling fluid testing method provided in an embodiment of this application;

[0048] Figure 5a A total hydrocarbon curve of gas components from a well in Dabeishan is provided as an embodiment of this application.

[0049] Figure 5b A bar chart of standard sample 1 and test sample provided in this application embodiment;

[0050] Figure 5c A bar chart of standard sample 2 and test sample provided for embodiments of this application;

[0051] Figure 6a A bar chart of the components of oil-based drilling fluid, diesel oil, and emulsifier gas analysis in a well in Dabeishan, provided as an embodiment of this application;

[0052] Figure 6b Another bar chart of the components of oil-based drilling fluid, diesel oil, and emulsifier gas analysis in a well in Dabeishan provided in this application embodiment;

[0053] Figure 6c A bar chart of the components of oil-based drilling fluid, diesel oil, and emulsifier gas analysis in a well in Dabeishan, provided in this application embodiment;

[0054] Figure 7a A total hydrocarbon profile obtained from gas analysis of a water-based drilling fluid (without additives) provided in an embodiment of this application;

[0055] Figure 7b This application provides an embodiment of a total hydrocarbon curve obtained by adding 1% emulsified asphalt to a water-based drilling fluid as a test sample.

[0056] Figure 7c A total hydrocarbon curve for gas analysis is provided in this embodiment of the application when 5% emulsified asphalt is added to a water-based drilling fluid as a test sample.

[0057] Figure 7d This application provides an embodiment of a total hydrocarbon curve obtained by adding 2% diesel oil to a water-based drilling fluid as a test sample.

[0058] Figure 7e This application provides an embodiment of a total hydrocarbon curve obtained by adding 5% diesel oil to a water-based drilling fluid as a test sample.

[0059] Figure 7f A total hydrocarbon curve for gas analysis when 5% diesel and 1% crude oil from Gaotan-1 well are added to a water-based drilling fluid as a sample to be tested, as provided in this application embodiment;

[0060] Figure 7g This application provides a gas-based total hydrocarbon curve when a pure diesel-based drilling fluid is used as a test sample.

[0061] Figure 8a An experimental total hydrocarbon curve for a white oil-based drilling fluid with 2% emulsifier and 3% emulsified asphalt is provided for embodiments of this application.

[0062] Figure 8b An experimental total hydrocarbon curve for adding 1% condensate oil and 0.8% condensate oil to a white oil-based drilling fluid is provided as an embodiment of this application.

[0063] Figure 9a An experimental total hydrocarbon curve for adding 1-2% Gaotan 1 crude oil and 3% emulsifier to a white oil-based drilling fluid is provided in this application embodiment;

[0064] Figure 9b An experimental total hydrocarbon curve for adding 2% Mahu 31 crude oil, 3% emulsifier, and 3% emulsified asphalt to a white oil-based drilling fluid is provided in this application embodiment.

[0065] Figure 10a A bar chart of gas measurement parameters for oil-based drilling fluid with added diesel fuel under different pressures is provided for an embodiment of this application.

[0066] Figure 10b A bar chart of gas logging parameters for oil-based drilling fluid with emulsifier under different pressures is provided for embodiments of this application.

[0067] Figure 11a A bar chart of gas measurement parameters for oil-based drilling fluid with added diesel at different temperatures is provided as an embodiment of this application.

[0068] Figure 11b A bar chart of gas logging parameters for oil-based drilling fluid with emulsifier at different temperatures is provided for embodiments of this application.

[0069] Figure 12 This is a schematic diagram of a drilling fluid testing device provided in an embodiment of this application.

[0070] Figure label:

[0071] 1-Injecting components;

[0072] 2-Analysis components;

[0073] 3-Control components;

[0074] 11-Injection container;

[0075] 12-Filter;

[0076] 13-Dehydrator;

[0077] 111 - Temperature regulator;

[0078] 112 - Pressure regulator. Detailed Implementation

[0079] To make the objectives, technical solutions, and advantages of the embodiments of this application clearer, the technical solutions of the embodiments of this application will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of this application, not all embodiments. Based on the embodiments of this application, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of this application.

[0080] Gas logging is a technical procedure for determining reservoir oil and gas shows and a crucial detection method in oil and gas exploration. Gas logging is influenced by various factors that significantly impact its accuracy. These factors include the addition of various additives to drilling fluids to improve specific properties or protect oil and gas reservoirs; the addition of crude oil or diesel fuel to handle drilling accidents; and the use of mixed-oil or oil-based drilling fluids for specific purposes. Therefore, the addition of various organic additives and the mixing of oils during drilling are practically unavoidable, creating a conflict between obtaining complete and accurate data and ensuring drilling safety.

[0081] Past laboratory and field logging experiments did not consider the physical and chemical changes that occur to drilling fluid additives under high temperature and pressure at the bottom of the well, resulting in inaccurate gas logging interpretation results and consequently affecting the accuracy of reservoir logging oil and gas layer evaluation. The main reason why additives in water-based and oil-based drilling fluids affect gas logging parameters is that the various organic treatment agents in water-based and oil-based drilling fluids, as well as the diesel fuel in oil-based drilling fluids, are mostly composed of unsaturated hydrocarbon organic polymers. Under high temperature and pressure conditions in the well, these compounds will crack, producing hydrocarbons. Therefore, this brings certain difficulties and impacts to conventional gas logging work, thereby affecting the accuracy of reservoir logging oil and gas layer evaluation.

[0082] To address the aforementioned issues, this application provides a drilling fluid additive testing device, a drilling fluid testing method, and an apparatus. By accurately analyzing different temperatures and pressures, it aims to understand the extent and results of the influence of additives in water-based and oil-based drilling fluids on gas logging components, thereby improving the accuracy of reservoir gas logging and oil and gas layer evaluation.

[0083] The application scenarios of this application are described below.

[0084] Figure 1 This is a schematic diagram illustrating an application scenario of a drilling fluid testing method provided in an embodiment of this application. For example... Figure 1 As shown, the system includes: drilling fluid additive testing equipment 001 and a certain well 002. During gas logging of well 002, the drilling fluid additive testing equipment 001 is used to process and analyze the impact of drilling fluid additives on gas logging components, thereby improving the accuracy of reservoir logging oil and gas layer evaluation.

[0085] It should be noted that the application scenarios of this application can be as follows: Figure 1 This can be applied to scenarios in gas logging, but it is not limited to these. It can also be applied to other scenarios in gas logging where drilling fluid additives need to be tested.

[0086] The following will combine Figure 2 The structure and function of drilling fluid additive testing equipment 001 are described. Figure 2 This is a schematic diagram of the structure of a drilling fluid additive testing device provided in an embodiment of this application, as shown below. Figure 2 As shown, the drilling fluid additive testing equipment may include: an injection component 1, an analysis component 2, and a control component 3.

[0087] Injection assembly 1 is used to inject drilling fluid at a set temperature and pressure, and to transfer the resulting gas to be analyzed to analysis assembly 2. Injection assembly 1 includes an injection container 11, a filter 12, and a dehydrator 13. The injection container 11 includes an injection port, a discharge port, a pressure relief port, and a degassing port. The filter 12 and dehydrator 13 are sequentially connected to the degassing port of the injection container 11 to remove impurities and moisture from the gas. An agitator is installed inside the injection container 11 to agitate the drilling fluid, ensuring uniform mixing and allowing gas to escape. The injection container 11 is equipped with a temperature regulator 111 and a pressure regulator 112. The temperature regulator 112 adjusts the temperature of the injection container 11 to the temperature set by control assembly 3; the pressure regulator 113 adjusts the pressure of the injection container 11 to the pressure set by control assembly 3.

[0088] The drilling fluid includes at least one additive. For example, drilling fluids include, but are not limited to, water-based drilling fluids and oil-based drilling fluids. Additives in drilling fluids include, but are not limited to, one or more of the following: clays, such as bentonite, salt-resistant and high-temperature resistant clay, organic clay, etc.; weighting materials, such as barite, limestone powder, hematite powder, ilmenite powder, galena, activated barite, etc.; alkalis, such as caustic soda, potassium hydroxide, soda ash, baking soda, quicklime, etc.; thickeners / coating agents, such as partially hydrolyzed polyacrylamide (PHPA), polyacrylamide (PAM) / potassium polyacrylamide (KPAM), high-viscosity carboxymethyl cellulose (CMC-HV), hydroxyethyl cellulose (HEC), carboxymethyl hydroxyethyl cellulose (CMHEC), polyanionic cellulose (PAC), fine dispersions (PF-PLUS), acrylic copolymers (80A-51), polyacrylates (PAC141, PAC142, PAC143), zwitterionic polymer strong coating agents for drilling fluids (FA-367), xanthan gum (XC... Polymer, Guar Gum, Hydroxypropyl Guar Gum Gum), penetrants (SP-II), etc.; filtration loss reducers, such as low-viscosity carboxymethyl cellulose (CMC-LV), modified starch, sulfonated methyl phenolic resin (high-temperature resistant filtration loss reducer SMP-n), sulfonated lignite resin (SPNH), sulfonated methyl lignite, polyacrylonitrile ammonium salt (NH4-HPAN), polyacrylonitrile potassium salt (K-HPAN), high-temperature salt resistant filtration loss reducer for drilling fluid SPNC, sulfonated phenolic chromium humate (PSC-1, PSC-2), potassium humate, zwitterionic filtration loss reducer (JT-888), etc.; shale inhibitors, such as polyols, small cationic resins, potassium formate (HCOOK), positively charged gel (MMH), sulfonated asphalt, oxidized asphalt, natural asphalt and modified asphalt, cationic emulsified asphalt colloids (YL-80, YL-100, YL-120, SAS-1, etc.), potassium chloride, etc.; lubricants, such as modified graphite (GRA), plastic microspheres, glass microspheres. Oils and liquids formulated with alkane compounds and surfactants, polymeric alcohols, etc.; viscosity reducers, such as tannins, lignin sulfonates (ferrochromium salts), viscosity reducers (X-40 series), zwitterionic polymer viscosity reducers (XY-27), sulfonated styrene-maleic anhydride copolymers, silicone fluorine viscosity reducers and organosilicon diluents, chromium-free lignin sulfonates (CrFree-95), etc.; emulsifiers, such as monooleate (SP-80), emulsifiers (O... P-10, etc.; unblocking agents, such as Quick T, Heavy-Duty Unblocking Agent (WFA-1), etc.; plugging agents, such as walnut shell, mica flakes, single sealant (PF-SEAL), plant fiber, vermiculite powder, cottonseed hull, sawdust, asbestos, comprehensive plugging agent (SLD-1, SLD-2), drilling plugging agent (SQD-98), etc.; defoamers, such as defoamer (PD-100), etc., and other types, such as gypsum, calcium chloride, salt, water glass, dichromate, etc.

[0089] In this embodiment of the application, no specific limitations are imposed on the injection process. For example, the injection process may include: stirring the drilling fluid to allow gas in the drilling fluid to escape; filtering and dehydrating the escaped gas to obtain the gas to be analyzed.

[0090] To ensure the accuracy of drilling fluid test results, in this embodiment, a vacuum pump is connected to the pressure relief port of the injection container 11 to extract the gas inside the injection container 11. After a set of drilling fluid tests is completed, the vacuum pump is used to completely remove the gas from the injection container 11 before injecting the next set of drilling fluid, thus ensuring the accuracy of the test results for each set of drilling fluid.

[0091] Analysis component 2 is used to analyze the gas to be analyzed and transmit the analysis results to control component 3. Analysis component 2 is connected to injection component 1. After the analysis results from analysis component 2 are transmitted to control component 3, control component 3 can process the analyzed gas logging data and generate logging curves.

[0092] In this embodiment, the selection of analytical components is not limited and can be selected according to specific circumstances. For example, analytical component 2 can be a complete desorption analyzer or a gas measuring instrument.

[0093] Control component 3 is used to control injection component 1 and analysis component 2, process the analysis results of analysis component 2, adjust the temperature and pressure of injection component 1, and based on the adjusted temperature and pressure, control injection component 1 and analysis component 2 to continue injection processing and analysis.

[0094] In this embodiment, the control component is used to control the temperature and pressure of the injection component to obtain the effect of drilling fluid additives on gas detection components under different temperatures and pressures.

[0095] This application does not impose any restrictions on the connection method between the injection component, the analysis component, and the control component; the connection can be analyzed according to specific circumstances. For example, the control component and the injection component can be connected via wired or wireless means to transmit control signals and control the temperature and pressure of the injection component. Similarly, the control component and the analysis component can also be connected via wired or wireless means. After receiving the analysis results from the analysis component, the control component plots the corresponding total hydrocarbon curve based on the analysis results.

[0096] This application uses the method of plotting total hydrocarbon curves to demonstrate the analytical results of the influence of drilling fluid additives on gas components. However, it is not limited to the method of plotting total hydrocarbon curves. Any method that can be used to demonstrate the influence of drilling fluid additives on gas components is within the protection scope of the embodiments of this application.

[0097] In one optional implementation, multiple analyses can be performed at a set injection temperature and pressure to obtain multiple total hydrocarbon logging curves at that set injection temperature and pressure. These multiple sets of logging curves are compared to observe the changes in light components (methane (C1), ethane (C2), propane (C3)) and heavy components (isobutane (IC4), n-butane (NC4), isopentane (IC5), n-pentane (NC5)). Light components generally tend towards gas, while heavy components generally tend towards oil, in order to more accurately determine the final impact of a particular drilling fluid additive on the gas logging components under simulated formation temperature and pressure conditions. When the region or well depth of the analyzed object changes, the injection temperature and pressure are adjusted accordingly.

[0098] Specifically, processing the analysis results from the analysis components involves plotting the total hydrocarbon curve for gas logging based on the data obtained from the analysis components. Multiple sets of tests are conducted on a specific drilling fluid additive at the same temperature and pressure; for example, 3-10 sets of experiments can be performed. Based on the experimental data obtained, the total hydrocarbon curve for gas logging is plotted to obtain the effect of the drilling fluid additive on the gas logging components at that injection temperature and pressure. The injection temperature and pressure are then modified, and multiple sets of tests are conducted at the modified injection temperature and pressure to obtain the effect of the drilling fluid additive on the gas logging components at the modified injection temperature and pressure. The above steps are repeated to obtain the effect of the drilling fluid additive on the gas logging components in the gas logging results at different injection temperatures and pressures.

[0099] Alternatively, processing the analysis results of the analytical components involves plotting a total hydrocarbon (TH) curve based on the data obtained from the analytical equipment. Multiple sets of tests are conducted on an additive for a specific drilling fluid at a given injection temperature and pressure; for example, 3-10 sets of experiments can be performed. The TH curve is then plotted based on the obtained experimental data to obtain the effect of the drilling fluid additive on the gas components at that injection temperature and pressure. The above steps are repeated to test the effect of an additive for another drilling fluid on the gas components at the same injection temperature and pressure. This allows for the determination of the effects of different drilling fluid additives on the gas components at that injection temperature and pressure.

[0100] Furthermore, after plotting the total hydrocarbon curve based on the obtained experimental data, the total hydrocarbon curve is evaluated, and abnormal displays are eliminated.

[0101] The injection temperature and pressure settings are based on the well depth of the object being tested, and are set according to the geothermal gradient, measured formation pressure, or formation pressure calculated using drilling fluid density. The bottom hole drilling fluid temperature and pressure are set accordingly for the well depth. Temperature simulation can simulate temperature, but pressure simulation laboratory equipment generally has difficulty simulating the actual formation pressure at a well depth of 7000 meters. Considering safety issues, the pressure of the device of this invention is controlled at 1-10 MPa.

[0102] Furthermore, injection temperature and pressure are not fixed parameters; they exhibit specific patterns in different basins, regions, and well depths. Therefore, the parameters of injection temperature and pressure can be determined based on the actual conditions of the region from which the sample originates.

[0103] The drilling fluid additive testing equipment provided in this application has a simple structure. By controlling the temperature and pressure at simulated actual well depths, it obtains the influence of drilling fluid additives on gas logging components under different injection temperatures and pressures, and thus obtains the influence of drilling fluid additives on gas logging components under different well depth conditions (mainly including temperature and pressure). In this application embodiment, it was found that drilling fluid additives have an impact on gas logging components, especially a significant inhibitory effect on heavy components in gas logging components. Compared with the prior art, this application improves the accuracy of reservoir logging oil and gas layer evaluation by accurately grasping the influence of additives in water-based and oil-based drilling fluids on gas logging parameters. The drilling fluid additive testing equipment provided in this application embodiment solves the problem that existing equipment cannot test the influence of drilling fluid additives on gas logging components. In the past, laboratory or field logging experiments did not consider the physical and chemical changes of drilling fluid additives under high temperature and high pressure at the bottom of the well, resulting in inaccurate gas logging results, which in turn affected the accuracy of reservoir logging oil and gas layer evaluation.

[0104] It can be understood that the above-mentioned drilling fluid testing method can be implemented by the drilling fluid testing device provided in the embodiments of this application, and the drilling fluid testing device can be part or all of a certain device.

[0105] The technical solutions of the embodiments of this application will be described in detail below with specific examples. The following specific examples can be combined with each other, and the same or similar concepts or processes may not be described again in some embodiments.

[0106] Figure 3 This is a flowchart illustrating a drilling fluid testing method provided in an embodiment of this application. The executing entity of this embodiment is a drilling fluid testing device, and it relates to the specific process of testing the effect of drilling fluid additives on gas analysis components. Figure 3 As shown, the method includes:

[0107] S201. Set the initial injection temperature and pressure, inject the drilling fluid to obtain the gas to be analyzed.

[0108] The drilling fluid includes at least one additive. For example, drilling fluids include, but are not limited to, water-based drilling fluids and oil-based drilling fluids. Additives in drilling fluids include, but are not limited to, one or more of the following: clays, such as bentonite, salt-resistant and high-temperature resistant clay, organic clay, etc.; weighting materials, such as barite, limestone powder, hematite powder, ilmenite powder, galena, activated barite, etc.; alkalis, such as caustic soda, potassium hydroxide, soda ash, baking soda, quicklime, etc.; thickeners / coating agents, such as partially hydrolyzed polyacrylamide (PHPA), polyacrylamide (PAM) / potassium polyacrylamide (KPAM), high-viscosity carboxymethyl cellulose (CMC-HV), hydroxyethyl cellulose (HEC), carboxymethyl hydroxyethyl cellulose (CMHEC), polyanionic cellulose (PAC), fine dispersions (PF-PLUS), acrylic copolymers (80A-51), polyacrylates (PAC141, PAC142, PAC143), zwitterionic polymer strong coating agents for drilling fluids (FA-367), xanthan gum (XC... Polymer, Guar Gum, Hydroxypropyl Guar Gum Gum), penetrants (SP-II), etc.; filtration loss reducers, such as low-viscosity carboxymethyl cellulose (CMC-LV), modified starch, sulfonated methyl phenolic resin (high-temperature resistant filtration loss reducer SMP-n), sulfonated lignite resin (SPNH), sulfonated methyl lignite, polyacrylonitrile ammonium salt (NH4-HPAN), polyacrylonitrile potassium salt (K-HPAN), high-temperature salt resistant filtration loss reducer for drilling fluid SPNC, sulfonated phenolic chromium humate (PSC-1, PSC-2), potassium humate, zwitterionic filtration loss reducer (JT-888), etc.; shale inhibitors, such as polyols, small cationic resins, potassium formate (HCOOK), positively charged gel (MMH), sulfonated asphalt, oxidized asphalt, natural asphalt and modified asphalt, cationic emulsified asphalt colloids (YL-80, YL-100, YL-120, SAS-1, etc.), potassium chloride, etc.; lubricants, such as modified graphite (GRA), plastic spheres, glass, etc. Microbeads, alkane compounds, and surfactants are used to formulate oils, liquids, and polymeric alcohols; viscosity reducers, such as tannins, lignin sulfonates (ferrochromium salts), viscosity reducers (X-40 series), zwitterionic polymer viscosity reducers (XY-27), sulfonated styrene-maleic anhydride copolymers, silicone fluorine viscosity reducers and organosilicon diluents, chromium-free lignin sulfonates (CrFree-95), etc.; emulsifiers, such as monooleate (SP-80), emulsifiers... (OP-10), etc.; unblocking agents, such as Quick T, Heavy-Duty Unblocking Agent (WFA-1), etc.; plugging agents, such as walnut shells, mica flakes, single sealant (PF-SEAL), plant fibers, vermiculite powder, cottonseed hulls, sawdust, asbestos, comprehensive plugging agents (SLD-1, SLD-2), drilling plugging agent (SQD-98), etc.; defoamers, such as PD-100, etc., and other types, such as gypsum, calcium chloride, salt, water glass, dichromate, etc.

[0109] This application does not impose specific limitations on the initial injection temperature and pressure settings. Optionally, the initial injection temperature and pressure can be set based on the original formation temperature and pressure. For example, the injection temperature and pressure are set according to the well depth of the test object, based on the geothermal gradient, measured formation pressure, or formation pressure calculated using drilling fluid density, to set the bottom hole drilling fluid temperature and pressure at the corresponding well depth. Temperature simulation can simulate temperature, but pressure simulation laboratory equipment generally has difficulty simulating the actual formation pressure at a well depth of 7000 meters. Considering safety issues, the pressure of the device of this invention is controlled at 1-10 MPa.

[0110] Furthermore, injection temperature and pressure are not fixed parameters; they exhibit specific patterns in different basins, regions, and well depths. Therefore, the parameters of injection temperature and pressure can be determined based on the actual conditions of the region from which the sample originates.

[0111] In this embodiment of the application, no specific limitations are imposed on the injection process. For example, the injection process may include: stirring the drilling fluid to allow gas in the drilling fluid to escape; filtering and dehydrating the escaped gas to obtain the gas to be analyzed.

[0112] S202. Analyze the gas to be analyzed to obtain the gas composition at the initial injection temperature and pressure.

[0113] Among them, the gas analysis test can obtain the total hydrocarbon TG and 7 components: light components C1, C2, and C3, which mainly represent gas components; heavy components IC4, NC4, IC5, and NC5, which mainly represent gas and some light oil components.

[0114] This application does not limit the analysis method for the gas to be analyzed. For example, a complete desorption analyzer or a gas measuring instrument can be used to analyze the gas to be analyzed.

[0115] Optionally, after obtaining the gas composition of the drilling fluid at the initial injection temperature and pressure, a corresponding total hydrocarbon curve can be plotted based on the analysis results. The initial injection temperature and pressure are set according to the original formation temperature and pressure. Multiple analyses can be performed at a set injection temperature and pressure to obtain multiple total hydrocarbon curves at that set injection temperature and pressure. Comparison of multiple sets of logging gas curves allows observation of changes in light and heavy components, enabling a more accurate determination of the final influence of a particular drilling fluid additive on the gas composition under simulated formation temperature and pressure conditions. Different drilling fluids and additives can be used for experiments at the same set injection temperature and pressure.

[0116] S203. Modify the injection temperature and pressure, and re-inject and analyze the drilling fluid under the modified injection temperature and pressure to obtain the gas composition under the modified injection temperature and pressure.

[0117] When the drilling fluid to be analyzed originates from drilling, the location and depth of the drilling site often change, so the injection temperature and pressure need to be modified accordingly based on the changes in formation temperature and pressure.

[0118] S204. Based on the gas sampling components under different injection temperatures and pressures, determine the influence of drilling fluid additives on the gas sampling components under different injection temperatures and pressures.

[0119] This can be understood as follows: by modifying the injection temperature and pressure, and then injecting and analyzing the drilling fluid at different injection temperatures and pressures, the gas composition at different injection temperatures and pressures is obtained. According to actual needs, the well depth is divided into several temperature and pressure ranges, and the gas composition at these temperatures and pressures is tested separately. Finally, the effect of additives added to the drilling fluid at different temperatures and pressures on the gas composition is obtained.

[0120] In some implementations, the injection temperature is 50-150°C and the injection pressure is 1-10 MPa.

[0121] Specifically, when conducting simulation experiments on drilling fluid additives from the same well, steps S201 and S202 are used to obtain the effect of the drilling fluid additive on gas sampling components under the same injection temperature and pressure. When it is necessary to conduct simulation experiments on drilling fluid additives from another well, the injection temperature and pressure are modified accordingly. Steps S203-S204 are repeated to obtain the effect of the drilling fluid additive on gas sampling components under different temperatures and pressures.

[0122] If it is necessary to test the effect of different additives in drilling fluid on gas components, repeat step S203 for each set of additives (a set of additives includes one or more additives) to obtain the effect of the additives in that set of drilling fluid on gas components under different injection temperatures and pressures; then replace another set of additives and test in the same way.

[0123] The drilling fluid testing method provided in this application can obtain the effect of additives in a certain drilling fluid on gas components under different temperatures and pressures, as well as the effect of additives in different drilling fluids on gas components under the same temperature and pressure. The method can be selected according to actual needs.

[0124] The drilling fluid testing method provided in this application first sets an initial injection temperature and pressure, injects the drilling fluid to obtain the gas to be analyzed, and then analyzes the gas to be analyzed to obtain the gas composition at the initial injection temperature and pressure. Subsequently, the injection temperature and pressure are modified, and the drilling fluid is injected and analyzed again at the modified injection temperature and pressure to obtain the gas composition at the modified injection temperature and pressure. Finally, based on the gas composition at different injection temperatures and pressures, the influence of drilling fluid additives on the gas composition at different injection temperatures and pressures is determined. Compared with the prior art, this application sets different injection temperatures and pressures according to well depth requirements, and obtains the influence of drilling fluid additives on the gas composition at different temperatures and pressures by controlling the injection temperature and pressure. By accurately understanding the influence of additives in water-based and oil-based drilling fluids on gas measurement parameters at different temperatures and pressures, the accuracy of reservoir logging oil and gas layer evaluation is improved.

[0125] Based on the above embodiments, the testing method for drilling fluid will be further explained below. Figure 4 A schematic flowchart of another drilling fluid testing method provided in this application embodiment is shown below. Figure 4 As shown, the method includes:

[0126] S301. Obtain the temperature and pressure of the original formation and set the initial injection temperature and pressure.

[0127] S302. Stir the drilling fluid to allow the gas in the drilling fluid to escape.

[0128] S303. The escaped gas is filtered and dehydrated to obtain the gas to be analyzed.

[0129] S304. Analyze the gas to be analyzed to obtain the gas composition at the initial injection temperature and pressure.

[0130] S305. Modify the injection temperature and pressure, and re-inject and analyze the drilling fluid under the modified injection temperature and pressure to obtain the gas composition under the modified injection temperature and pressure.

[0131] S306. Obtain experimental data from multiple sets of tests of drilling fluid at the same injection temperature and pressure.

[0132] The experimental data are obtained after injecting and analyzing the drilling fluid.

[0133] S307. Based on the experimental data, plot the total hydrocarbon curve for gas analysis to obtain the effect of drilling fluid additives on gas analysis components under the same injection temperature and pressure.

[0134] S308. Obtain experimental data from multiple sets of tests on drilling fluid at different injection temperatures and pressures.

[0135] S309. Based on the experimental data, plot the total hydrocarbon curve for gas analysis to determine the effect of drilling fluid additives on gas analysis components under different injection temperatures and pressures.

[0136] The technical terms, effects, features, and optional implementation methods of S301-S309 can be found in [reference]. Figure 3 The explanations of S201-S204 shown are redundant and will not be repeated here.

[0137] The present application will be further described below with reference to specific embodiments, but this should not be construed as a limitation on the scope of protection of the present application. Some non-essential improvements and adjustments made by those skilled in the art based on the above content of the present application are still within the scope of protection of the present application.

[0138] The following four scenarios represent the results of experimental studies on additives for water-based and oil-based drilling fluids conducted in the Karamay and Tarim oilfields of the Junggar Basin, respectively.

[0139] The first scenario involves using a complete desorption analyzer to analyze the gas composition at a depth of 5040 meters in a well in Dabeikou, obtaining results such as... Figure 5a The gas measurement curve shown, Figure 5a This application provides a gas logging component total hydrocarbon curve for a well in Dabeikoudian, where the horizontal axis represents mole fraction concentration (%), ranging from 0.0001 to 100. The scale of the horizontal axis represents the logarithmic function values ​​corresponding to 0.0001 to 100. The vertical axis represents well depth (meters). Figure 5a The curves in the figure represent the total hydrocarbon curves for each gaseous component. Total hydrocarbons refer to hydrocarbons other than methane, primarily C2 to C8 compounds. Under specified conditions, the total hydrocarbons measured are the total amount of hydrocarbons other than methane that have a significant response in a gas chromatograph using a flame ionization detector (FID). C1 represents methane; C2 ethane; C3 propane; IC4 isobutane; NC4 n-butane; IC5 isopentane; NC5 n-pentane, and so on. C4 represents butane, C5 pentane, C6 hexane, C7 heptane, and C8 octane. Figure 5a As shown, only C1, C2, and C3 were found in the gas separation analysis of the drilling fluid at a depth of 5040 meters. This indicates that heavy components such as IC4, NC4, IC5, and NC5 following C3 are very rare, which is inconsistent with the actual theory. In order to find out why there are no heavy components detected in the gas separation analysis of the drilling fluid at a depth of 5040 meters, the following experiment was conducted:

[0140] First, the chromatograms were examined, and the standard mixture of the inlet gas and two samples with different C1 contents were tested. The concentrations of the standard mixture of inlet gas, standard sample 1 and standard sample 2 are shown in Table 1. Figure 5bA bar chart showing a standard sample 1 and a test sample provided in an embodiment of this application. Figure 5c A bar chart of standard sample 2 and test sample provided in this application embodiment is shown, wherein the test sample is a mixed standard sample of inlet gas. Table 1 shows the gas analysis data of standard sample 1 and standard sample 2, wherein ppm is the mole fraction. As shown in Table 1, the data comparison and analysis show that the chromatograph is normal and without fault.

[0141] Secondly, diesel fuel was added to the oil-based drilling fluid for gas analysis, followed by the addition of an emulsifier. The results are shown in Table 2, which contains the gas analysis data for Sample 1 and Sample 2. Sample 1 consisted of 450 ml oil-based drilling mud + 50 ml diesel fuel, and Sample 2 consisted of 450 ml oil-based drilling mud + 50 ml diesel fuel + 50 ml emulsifier. Figure 6b Another bar chart of the components of oil-based drilling fluid, diesel oil, and emulsifier gas analysis in a well in Dabeishan provided in this application embodiment; Figure 6c This application provides another example of a bar chart showing the gas detection components of oil-based drilling fluid, diesel oil, and emulsifier in a well in Dabeishan. The difference lies in the number of gas detection component names on the horizontal axis. The horizontal axis represents the gas detection component names, and the vertical axis represents the mole fraction concentration in parts per million (PPM). Figures 6a-6c As shown in Table 2, the test data shows that the content of heavy components in the prepared sample 1 is high, while the content of gaseous components in sample 2 after adding emulsifier to sample 1 is significantly reduced, especially the inhibitory effect on heavy components such as IC4, NC4, IC5, and NC5.

[0142] Table 1

[0143]

[0144] Table 2

[0145]

[0146] The second scenario involves measuring the water-based drilling fluid-emulsified bitumen in a well in the Karamay oilfield. For example... Figures 7a-7g The figures shown are the total hydrocarbon curves obtained from the experimental gas analysis of water-based drilling fluid-emulsified asphalt and diesel, respectively. Figure 7a A total hydrocarbon profile obtained from gas analysis of a water-based drilling fluid (without additives) provided in an embodiment of this application; Figure 7b This application provides an embodiment of a total hydrocarbon (TH) profile for a water-based drilling fluid with 1% emulsified asphalt added as a test sample. Figure 7b It can be seen that adding 1% emulsified asphalt has no effect on the total hydrocarbon curve of water-based drilling fluid. Figure 7c This application provides an embodiment of a total hydrocarbon (TH) profile for a water-based drilling fluid with 5% emulsified asphalt added as a test sample. Figure 7c It can be seen that adding 5% emulsified asphalt has no effect on the total hydrocarbon curve of water-based drilling fluid. Figure 7d This application provides an embodiment of a total hydrocarbon curve obtained by adding 2% diesel oil to a water-based drilling fluid as a test sample. Figure 7d It can be seen that adding 2% diesel has an impact on the total hydrocarbon curve of water-based drilling fluid, with a three-fold increase in total hydrocarbons, no effect on C1, and no other heavy components. Figure 7e This application provides an embodiment of a total hydrocarbon curve obtained by adding 5% diesel oil to a water-based drilling fluid as a test sample. Figure 7e It can be seen that adding 5% diesel oil affects the total hydrocarbon curve of water-based drilling fluid, with a tenfold increase in total hydrocarbons, no effect on C1, and no other heavy components. Figure 7f This application provides an embodiment of a total hydrocarbon (TH) profile for a water-based drilling fluid containing 5% diesel oil and 1% crude oil from the Gaotan-1 well as a test sample. Figure 7f It can be seen that adding 5% diesel and 1% crude oil from the Gaotan 1 well affects the total hydrocarbon curve of the water-based drilling fluid, with a 400-fold increase in total hydrocarbons. The purpose of adding 1% crude oil from the Gaotan 1 well to observe whether the gas logging data is abnormal is to check whether the current chromatographic operation is normal. Figure 7g This application provides an embodiment of a total hydrocarbon (TH) profile for a pure diesel-based drilling fluid as the sample to be tested, derived from... Figure 7g It is known that the total hydrocarbon content of pure diesel-based drilling fluid is 100 times higher than that of water-based drilling fluid. The C1 content is the same as that of water-based fluid, with no C2, C3, or other heavy components. Among these, Figures 7a-7g The horizontal axis represents the mole fraction concentration, expressed as a percentage (%), ranging from 0.0001 to 100. The scale on the horizontal axis represents the logarithmic function values ​​corresponding to the values ​​from 0.0001 to 100. The vertical axis represents the well depth, expressed in meters (m). Figures 7a-7g The curves in the figure are the total hydrocarbon curves for each gaseous component.

[0147] This embodiment verifies whether and to what extent the addition of diesel fuel to water-based drilling fluid affects the total hydrocarbon and component parameters in gas logging, thereby improving the accuracy of logging interpretation and eliminating interfering factors.

[0148] The third scenario involves measuring the white oil-based drilling fluid-emulsifier in a well in the Karamay oilfield. For example... Figures 8a-8b As shown, the experimental total hydrocarbon curves for oil-based drilling fluid, emulsified drilling fluid, and emulsified asphalt are presented respectively; among them, Figure 8aThis application provides experimental total hydrocarbon (TH) curves for white oil-based drilling fluid with 2% emulsifier and 3% emulsified asphalt, as shown in the embodiments. The horizontal axis represents the mole fraction concentration (%), ranging from 0.0001 to 100. The scale of the horizontal axis represents the logarithmic function value corresponding to 0.0001 to 100. The vertical axis represents the well depth (m). The curves in the figure are the TH curves corresponding to each gas sampling component. Figure 8a It is evident that when white oil-based drilling fluid contains 2% emulsifier or 3% emulsified bitumen, the addition of emulsifier has no effect on the total hydrocarbon content. However, the emulsifier inhibits the content of heavy components such as C4, thus reducing their concentration. The addition of emulsified bitumen slightly increases the total hydrocarbon value, causing C1 to become significantly abnormal, but the circulating value remains at the baseline. C2 initially shows abnormalities, which disappear evenly during circulation. No C5 is observed. Figure 8b This application provides experimental total hydrocarbon (TH) curves for white oil-based drilling fluid with 1% and 0.8% condensate oil added. The horizontal axis represents mole fraction concentration (%), ranging from 0.0001 to 100. The scale of the horizontal axis corresponds to the logarithmic function value from 0.0001 to 100. The vertical axis represents well depth (m). The curves in the figure represent the TH curves for each gas sampling component. Figure 8b It is evident that when 1% and 0.8% condensate oil are added to white oil-based drilling fluid, the total hydrocarbon and component values ​​in the gas analysis show significant increases and anomalies in the background values, which do not significantly interfere with the judgment of formation oil and gas shows.

[0149] like Figures 9a-9b As shown in the figure, the experimental total hydrocarbon curves of oil-based drilling fluid, emulsified asphalt, and crude oil are respectively displayed. It can be seen from the figure that white oil-based drilling fluid with emulsifier significantly inhibits heavy components, while emulsified asphalt has no effect, and the C1 reaction is the most sensitive. Figure 9a This application provides an embodiment of an experimental total hydrocarbon (TH) curve for a white oil-based drilling fluid with 1-2% Gaotan 1 crude oil and 3% emulsifier. The horizontal axis represents the mole fraction concentration (%), ranging from 0.0001 to 100. The scale of the horizontal axis corresponds to the logarithmic function value from 0.0001 to 100. The vertical axis represents the well depth (m). The curves in the figure represent the TH curves for each gas sampling component. Figure 9a As can be seen from continuous testing, when 1-2% of Gaotan 1 crude oil and 3% emulsifier are added to white oil-based drilling fluid, the total hydrocarbon content shows a downward trend. Initially, the light components C1 and C2 are abnormally prominent, but disappear after thorough mixing. This indicates that the presence of light oil makes the light components particularly sensitive, reacting immediately and separating completely without generating background values. The heavy components C4 and C5 are present, and the addition of emulsifier after thorough mixing shows a significant decrease, suggesting an inhibitory effect. Figure 9bThis application provides an embodiment of an experimental total hydrocarbon (TH) curve for a white oil-based drilling fluid with 2% Mahu 31 crude oil, 3% emulsifier, and 3% emulsified asphalt added. The horizontal axis represents the mole fraction concentration (%), ranging from 0.0001 to 100. The scale of the horizontal axis represents the logarithmic function value corresponding to 0.0001 to 100. The vertical axis represents the well depth (m). The curves in the figure are the TH curves corresponding to each gas sampling component. Figure 9b As can be seen from continuous testing, when 2% Mahu 31 crude oil, 3% emulsifier, and 3% emulsified asphalt are added to white oil-based drilling fluid, the total hydrocarbon content is abnormal when medium-quality oil is added, but the mixture remains stable after thorough mixing. Initially, the light components C1 and C2 show significant abnormalities, exceeding those of the heavy components, but the C1 value stabilizes after thorough mixing. This indicates that the light components are particularly sensitive to the presence of medium-quality oil, reacting immediately and separating completely, resulting in a background value for C1. The heavy components C4 and C5 are present, and their content decreases rapidly after the addition of emulsifier, showing a significant inhibitory effect. The addition of emulsified asphalt does not cause significant changes in the components.

[0150] In the fourth scenario, to verify the influence of adding diesel fuel and emulsifier to oil-based drilling fluid on the light and heavy component parameters of gas analysis under different temperature and pressure conditions, two sets of experiments were conducted. The experimental data are listed in Tables 3 and 4. Table 3 shows the gas analysis data of oil-based drilling fluid with diesel fuel emulsifier at different pressures, where the gas pressure of sample 1 is 1 atmosphere, the gas pressure of sample 2 is 3 atmospheres, and the gas pressure of sample 3 is 5 atmospheres. Table 4 shows the gas analysis data of oil-based drilling fluid with diesel fuel emulsifier at different temperatures, where the temperature of sample 1 is 30 degrees Celsius (room temperature), the temperature of sample 2 is 60 degrees Celsius, and the temperature of sample 3 is 100 degrees Celsius. Figure 10a This application provides a bar chart of gas measurement parameters for oil-based drilling fluid with added diesel fuel under different pressures, as shown in the embodiments of this application. Figure 10b A bar chart of gas logging parameters for oil-based drilling fluid with emulsifier under different pressures is provided for an embodiment of this application, wherein the pressures are 1 kPa, 3 kPa and 5 kPa. Figure 11a This application provides a bar chart of gas measurement parameters for oil-based drilling fluid with added diesel fuel at different temperatures, as an embodiment of the present application. Figure 11b This application provides a bar chart of gas logging parameters for oil-based drilling fluid with emulsifier added at different temperatures, as part of an embodiment of the present application. Figures 10a-10b and Figures 11a-11b As can be seen, the emulsifier has different inhibition effects on gas-based heavy components under different temperatures and pressures. The higher the temperature and pressure, the more obvious the reduction of heavy components and the stronger the inhibition effect.

[0151] Table 3

[0152]

[0153] Table 4

[0154]

[0155] The drilling fluid additive testing equipment, drilling fluid testing methods, and apparatus provided in this application have achieved excellent application results through field experiments conducted in the Junggar Basin and Tarim Oilfield on emulsifiers, emulsified asphalt, and crude oils of different densities under water-based, white oil-based, and diesel-based conditions. These experiments have resolved long-standing issues and doubts among logging personnel, such as the inability to detect heavy components in gas logging. The inability to detect heavy components in gas logging affects the discovery and judgment of oil and gas shows, leading to the failure of various gas logging interpretation charts and methods, resulting in errors in comprehensive evaluation and seriously impacting the optimal identification of oil-bearing test zones in exploration decision-making.

[0156] This application also provides a drilling fluid testing device. Figure 12 This is a schematic diagram of a drilling fluid testing device provided in an embodiment of this application. The drilling fluid testing device can be implemented through software, hardware, or a combination of both. Figure 12 As shown, the drilling fluid testing device 400 includes: an injection module 401, an analysis module 402, and a processing module 403.

[0157] The injection module 401 is used to set the initial injection temperature and pressure, inject the drilling fluid to obtain the gas to be analyzed, and the drilling fluid includes at least one additive.

[0158] Analysis module 402 is used to analyze the gas to be analyzed and obtain the gas composition at the initial injection temperature and pressure;

[0159] The processing module 403 is used to modify the injection temperature and pressure, and to re-inject and analyze the drilling fluid under the modified injection temperature and pressure to obtain the gas composition under the modified injection temperature and pressure; based on the gas composition under different injection temperatures and pressures, the influence of drilling fluid additives on the gas composition under different injection temperatures and pressures is determined.

[0160] In one optional embodiment, the injection module 401 is further configured to set an initial injection temperature and pressure based on the temperature and pressure of the original formation; stir the drilling fluid to allow gas in the drilling fluid to escape; and filter and dehydrate the escaped gas to obtain the gas to be analyzed.

[0161] In one alternative implementation, the injection temperature and pressure are the temperature and pressure under different well depth conditions.

[0162] In one alternative embodiment, the drilling fluid includes a water-based drilling fluid or an oil-based drilling fluid.

[0163] In one alternative embodiment, the additive includes at least one of the following: clay, weighting material, thickener / coating agent, filtration loss reducer, shale inhibitor, lubricant, viscosity reducer, emulsifier, sealant, and defoamer.

[0164] In one optional embodiment, the processing module 402 is further configured to acquire experimental data from multiple sets of tests of drilling fluid at the same injection temperature and pressure; plot a total hydrocarbon curve based on the experimental data to obtain the effect of drilling fluid additives on gas components at the same injection temperature and pressure; acquire experimental data from multiple sets of tests of drilling fluid at different injection temperatures and pressures; plot a total hydrocarbon curve based on the experimental data to determine the effect of drilling fluid additives on gas components at different injection temperatures and pressures.

[0165] In one optional implementation, the processing module 402 is further configured to judge the total hydrocarbon curve and eliminate abnormal displays.

[0166] In the description of this application, it should be noted that, unless otherwise expressly specified and limited, the terms "connected" and "linked" should be interpreted broadly. For example, they can refer to a fixed connection, a detachable connection, or an integral connection; they can refer to a mechanical connection or an electrical connection; they can refer to a direct connection or an indirect connection through an intermediate medium; and they can refer to the internal connection of two components. Those skilled in the art can understand the specific meaning of the above terms in this application based on the specific circumstances.

[0167] Other embodiments of this application will readily occur to those skilled in the art upon consideration of the specification and practice of the invention disclosed herein. This application is intended to cover any variations, uses, or adaptations of this application that follow the general principles of this application and include common knowledge or customary techniques in the art not disclosed herein. The specification and examples are to be considered exemplary only, and the true scope and spirit of this application are indicated by the following claims.

[0168] It should be understood that this application is not limited to the precise structure described above and shown in the accompanying drawings, and various modifications and changes can be made without departing from its scope. The scope of this application is limited only by the appended claims.

Claims

1. A drilling fluid additive testing device, characterized in that, The device includes: an injection component, an analysis component, and a control component; The injection component is used to inject the drilling fluid at a set temperature and pressure, agitate the drilling fluid to allow gas to escape from the drilling fluid, filter and dehydrate the escaped gas to obtain the gas to be analyzed, and transfer the gas to be analyzed to the analysis component; the drilling fluid includes at least one additive. The analysis component is used to analyze the gas to be analyzed and transmit the analysis results to the control component; The control component is used to control the injection component and the analysis component, process the analysis results of the analysis component, adjust the temperature and pressure of the injection component according to the requirements of simulating different well depth conditions, and control the injection component and the analysis component to continue injection processing and analysis based on the adjusted temperature and pressure to obtain experimental data of multiple sets of tests of the drilling fluid under the same injection temperature and pressure, and plot the total hydrocarbon curve of gas measurement based on the experimental data to obtain the effect of the drilling fluid additives on the gas measurement components under the same injection temperature and pressure; and obtain experimental data of multiple sets of tests of the drilling fluid under different injection temperatures and pressures; plot the total hydrocarbon curve of gas measurement based on the experimental data to determine the effect of the drilling fluid additives on the gas measurement components under different injection temperatures and pressures.

2. The device according to claim 1, characterized in that, The injection assembly includes: an injection container, a filter, and a dehydrator; The filter and the dehydrator are connected in sequence to the degassing port of the injection container. The filter and the dehydrator are used to remove impurities and moisture from the gas.

3. The device according to claim 2, characterized in that, The injection container is equipped with a stirrer for stirring the drilling fluid, allowing the gas in the drilling fluid to escape.

4. The device according to claim 2, characterized in that, The injection container is equipped with a temperature regulator and a pressure regulator; The temperature regulator is used to adjust the temperature of the injection container to the temperature set by the control component; The pressure regulator is used to adjust the pressure of the injection container to the pressure set by the control component.

5. The device according to claim 2, characterized in that, The pressure relief port of the injection container is connected to a vacuum pump for extracting gas from the injection container.

6. The device according to claim 1, characterized in that, The analytical component is a complete desorption analyzer or a gas measuring instrument.

7. A method for testing drilling fluid, characterized in that, The method is applied to the drilling fluid additive testing equipment according to any one of claims 1-6, and the method includes: An initial injection temperature and pressure are set, and the drilling fluid is injected to obtain the gas to be analyzed. The drilling fluid includes at least one additive. The gas to be analyzed is analyzed to obtain the gas composition at the initial injection temperature and pressure. The injection temperature and pressure are modified, and the drilling fluid is injected and analyzed again under the modified injection temperature and pressure to obtain the gas composition under the modified injection temperature and pressure. Based on the gas sampling components under different injection temperatures and pressures, the influence of drilling fluid additives on the gas sampling components under different injection temperatures and pressures is determined.

8. The method according to claim 7, characterized in that, The drilling fluid is injected at the set initial injection temperature and pressure to obtain the gas to be analyzed, including: The initial injection temperature and pressure are set based on the temperature and pressure of the original formation. Stir the drilling fluid to allow the gas inside the drilling fluid to escape; The escaped gas is filtered and dehydrated to obtain the gas to be analyzed.

9. The method according to claim 7, characterized in that, The injection temperature and pressure refer to the temperature and pressure under different well depth conditions.

10. The method according to claim 7, characterized in that, The drilling fluid includes water-based drilling fluid or oil-based drilling fluid.

11. The method according to claim 7, characterized in that, The additives include at least one of the following: clays, weighting materials, thickeners / coating agents, filtration reducers, shale inhibitors, lubricants, viscosity reducers, emulsifiers, plugging agents, and defoamers.

12. The method according to claim 7, characterized in that, The determination of the effect of drilling fluid additives on the gas sampling components under different injection temperatures and pressures, based on the gas sampling components under different injection temperatures and pressures, includes: Obtain experimental data from multiple sets of tests of the drilling fluid at the same injection temperature and pressure; Based on the experimental data, a total hydrocarbon curve for gas analysis was plotted to obtain the effect of the drilling fluid additives on the gas analysis components under the same injection temperature and pressure. Obtain experimental data from multiple sets of tests on the drilling fluid at different injection temperatures and pressures; Based on the experimental data, the total hydrocarbon curve of the gas was plotted to determine the effect of the drilling fluid additives on the gas components under different injection temperatures and pressures.

13. The method according to claim 12, characterized in that, The step of plotting the total hydrocarbon curve based on the experimental data includes: The total hydrocarbon curve is evaluated, and any abnormal displays are eliminated.

14. A drilling fluid testing device, characterized in that, The apparatus is used to implement the drilling fluid testing method according to any one of claims 7-13, the apparatus comprising: An injection module is used to set the initial injection temperature and pressure, inject the drilling fluid to obtain the gas to be analyzed, wherein the drilling fluid includes at least one additive; The analysis module is used to analyze the gas to be analyzed and obtain the gas composition at the initial injection temperature and pressure. The processing module is used to modify the injection temperature and pressure, and to perform the injection processing and analysis on the drilling fluid again under the modified injection temperature and pressure to obtain the gas detection components under the modified injection temperature and pressure; based on the gas detection components under different injection temperatures and pressures, the influence of the drilling fluid additives on the gas detection components under different injection temperatures and pressures is determined.

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