Method for judging front edge position of heavy oil fireflooding live wire and related equipment

Abstract

The invention discloses a method and related equipment for judging the front edge position of a heavy oil fireflooding live wire, and relates to the technical field of petroleum exploration and development, and the method comprises the steps: obtaining an associated gas sample and the yield data of a production well; performing qualitative and quantitative analysis on the associated gas sample to obtain component contents including carbon monoxide content and hydrogen content; and according to the carbon monoxide content, the hydrogen content and the yield data, predicting the front edge position of the live wire to obtain a prediction result.

Description

TECHNICAL FIELD

[0001] The present application relates to the technical field of oil exploration and development, and in particular to a method for determining the position of a fire front in a heavy oil fire flooding and related equipment. BACKGROUND

[0002] At present, heavy oil fire flooding is a new effective development method for heavy oil reservoirs after steam huff and puff, steam flooding and SAGD. This development method has the advantages of wide application range, low operation cost and high recovery degree. Industrial application and test have been carried out in Romania, Canada, the United States, India and China. Through investigation, it is found that only high-temperature oxidation combustion state can be achieved and maintained in the process of heavy oil reservoir fire flooding development to ensure the development effect. Whether the position of the fire front and the advancing speed of the fire front can be accurately determined has become one of the technical difficulties of fire flooding development, and is also an important basis for evaluating the development effect and adjusting the scheme of fire flooding.

[0003] However, the potential method is affected by the work area and low surface resistivity, the production performance method is affected by the accuracy of basic parameters and the heterogeneity of the formation, the tracer method has high requirements for the number and frequency of sample collection, the infrared photography method is easily distorted by the overlying formation, and the detection distance and economic feasibility of the microseismic method are restricted. At present, there is no appropriate method to solve the above problems. Therefore, it is necessary to propose a method for determining the position of the fire front in heavy oil fire flooding to at least solve part of the above problems. SUMMARY

[0004] A series of simplified concepts are introduced in the summary section, which will be further described in detail in the specific embodiments section. The summary section of the present application does not mean to attempt to limit the key features and essential technical features of the claimed technical solutions, and even less to determine the protection scope of the claimed technical solutions.

[0005] In a first aspect, an embodiment of the present application provides a method for determining the position of a fire front in heavy oil fire flooding, comprising:

[0006] obtaining a sample of associated gas and production data of a production well;

[0007] qualitatively and quantitatively analyzing the sample of associated gas to obtain component content, the component content including carbon monoxide content and hydrogen content;

[0008] predicting the position of the fire front according to the carbon monoxide content, the hydrogen content and the production data to obtain a prediction result.

[0009] In an embodiment of the present application, the step of qualitatively and quantitatively analyzing the sample of associated gas to obtain component content comprises:

[0010] Obtain the peak area values ​​of standard gas chromatography;

[0011] The associated gas sample was analyzed by gas chromatography to obtain the associated gas components;

[0012] The associated gas components were analyzed using quantitative analysis methods to obtain the component contents.

[0013] In one embodiment of the present invention, the step of performing gas chromatography analysis on the associated gas sample to obtain associated gas components includes:

[0014] Obtain the retention time of the standard components;

[0015] The associated gas sample was analyzed by gas chromatography to obtain the retention times of the components;

[0016] The retention time of the component is matched with the retention time of the standard component to obtain the associated gas component.

[0017] In one embodiment of the present invention, the step of analyzing the associated gas components according to a quantitative analysis method to obtain the component content includes:

[0018] The associated gas components were analyzed using the external standard method to obtain the peak area values ​​of the sample chromatogram.

[0019] The component content is obtained by comparing the peak area values ​​of the sample chromatogram with those of the standard gas chromatogram.

[0020] In one embodiment of the present invention, the step of analyzing the associated gas components according to a quantitative analysis method to obtain the component content includes:

[0021] The associated gas components were analyzed using the corrected area normalization method to obtain the component content.

[0022] In one embodiment of the present invention, the component content further includes: nitrogen content, carbon dioxide content, oxygen conversion rate, and apparent hydrogen-to-carbon atomic ratio;

[0023] The steps following the qualitative and quantitative analysis of the associated gas sample to obtain the component content include:

[0024] The nitrogen content, carbon dioxide content, oxygen conversion rate, and apparent hydrogen-carbon atomic ratio are judged to obtain the judgment result;

[0025] If the nitrogen content is within a first preset range, the carbon dioxide content is within a second preset range, the oxygen conversion rate is within a preset conversion rate range, and the apparent hydrogen-carbon atomic ratio is within a preset ratio range, then the judgment result is that the combustion state is accurately identified.

[0026] If the determination result indicates that the combustion state is accurately identified, the position of the leading edge of the fire line is predicted based on the carbon monoxide content, the hydrogen content, and the production data.

[0027] In one embodiment of the present invention, the step of predicting the position of the fire front based on the carbon monoxide content, the hydrogen content, and the production data, and obtaining the prediction result, includes:

[0028] A change graph was generated based on the carbon monoxide content, hydrogen content, and production data.

[0029] The predicted position of the leading edge of the fire line is obtained based on the aforementioned change diagram.

[0030] Secondly, this application proposes a system for determining the position of the leading edge of a heavy oil fire drive fire line, the system comprising: a data acquisition module, an analysis module, and a prediction module;

[0031] The data acquisition module is configured to acquire associated gas sample and production well production data;

[0032] The analysis module is configured to perform qualitative and quantitative analysis on the associated gas sample to obtain the component content, which includes carbon monoxide content, hydrogen content, nitrogen content, carbon dioxide content, oxygen conversion rate, and apparent hydrogen-carbon atomic ratio.

[0033] The prediction module is configured to predict the position of the leading edge of the fire line based on the carbon monoxide content, the hydrogen content, and the production data, and obtain the prediction result.

[0034] Thirdly, an electronic device includes: a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor executes the computer program stored in the memory to perform a step of determining the position of the leading edge of a heavy oil fire-driving line as described in any of the first aspects above.

[0035] Fourthly, this application also proposes a computer-readable storage medium having a computer program stored thereon, wherein when the computer program is executed by a processor, it implements the steps of a method for determining the position of the leading edge of a heavy oil fire-driving line as described in any of the first aspects.

[0036] In summary, a method for determining the leading edge position of a heavy oil fire-flooding fire front according to an embodiment of this application includes: acquiring associated gas samples and production data from production wells; performing qualitative and quantitative analysis on the associated gas samples to obtain component contents, including carbon monoxide and hydrogen content; and predicting the leading edge position of the fire front based on the carbon monoxide content, the hydrogen content, and the production data to obtain a prediction result. The fire front position and advance speed are determined by the composition of associated gas from production wells in heavy oil reservoirs. Furthermore, this method has advantages such as low operating costs, ease of promotion, and fewer interfering factors. Long-term monitoring of associated gas from production wells not only deepens the understanding of fire-flooding mechanisms and dynamic characteristics of fire-flooding operations but also provides reliable data support for dynamic control of fire-flooding operations.

[0037] The method for determining the leading edge of the fire line in heavy oil fire drive proposed in this application, along with other advantages, objectives, and features of this application, will be partly apparent from the following description and partly understood by those skilled in the art through study and practice of this application. Attached Figure Description

[0038] Various other advantages and benefits will become apparent to those skilled in the art upon reading the following detailed description of preferred embodiments. The accompanying drawings are for illustrative purposes only and are not intended to limit this specification. Furthermore, the same reference numerals denote the same parts throughout the drawings. In the drawings:

[0039] Figure 1 This is a flowchart illustrating a method for determining the leading edge position of a heavy oil fire drive fire line, provided in an embodiment of this application.

[0040] Figure 2 A gas chromatogram for qualitative analysis of associated gas in a method for determining the leading edge position of a heavy oil fire-driven fire line provided in an embodiment of this application;

[0041] Figure 3 The graph showing the change of associated gas generated during high-temperature oxidation in heavy oil reservoirs during fire flooding, provided in an embodiment of this application, is shown in the figure.

[0042] Figure 4 A method for determining the leading edge position of a heavy oil fire flooding fireline provided in this application embodiment includes a graph showing the change of associated gas in a heavy oil reservoir without high-temperature oxidation during fire flooding over time.

[0043] Figure 5 This is a schematic diagram illustrating a method for determining the position of the leading edge of a fire-flooding line in heavy oil, provided in an embodiment of this application, in which the leading edge of the fire line approaches the production well and reaches peak production.

[0044] Figure 6This is a schematic diagram illustrating a method for determining the position of the leading edge of a fire-driven heavy oil fire line, provided in an embodiment of this application, in which the leading edge of the fire line approaches the production well from the injection well.

[0045] Figure 7 This is a schematic diagram illustrating a method for determining the leading edge position of a heavy oil fire-drive fire line in an embodiment of this application, in which the fire line has not yet moved towards the production well.

[0046] Figure 8 A schematic diagram of a system structure for determining the position of the leading edge of a heavy oil fire drive fire line, provided in an embodiment of this application;

[0047] Figure 9 This is a schematic diagram of an electronic device for determining the position of the leading edge of a heavy oil fire drive line, provided in an embodiment of this application. Detailed Implementation

[0048] To better understand the technical solutions provided in the embodiments of this specification, the technical solutions of the embodiments of this specification will be described in detail below with reference to the accompanying drawings and specific embodiments. It should be understood that the embodiments of this specification and the specific features in the embodiments are detailed descriptions of the technical solutions of the embodiments of this specification, rather than limitations on the technical solutions of this specification. In the absence of conflict, the embodiments of this specification and the technical features in the embodiments can be combined with each other.

[0049] In this document, relational terms such as "first" and "second" are used merely to distinguish one entity or operation from another, without necessarily requiring or implying any such actual relationship or order between these entities or operations. Furthermore, the terms "comprising," "including," or any other variations thereof are intended to cover non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements includes not only those elements but also other elements not expressly listed, or elements inherent to such a process, method, article, or apparatus. Without further limitation, an element defined by the phrase "comprising one..." does not exclude the presence of other identical elements in the process, method, article, or apparatus that includes said element. The term "two or more" includes two or more cases.

[0050] In recent years, the main methods for predicting the location of the fire front edge in heavy oil reservoirs include the following: (1) Potential method: By analyzing the resistivity change characteristics of different zones, a resistivity change model is established and combined with the measured data from the production site to describe the distribution characteristics of the burned zone, steam zone and remaining oil zone; (2) Production dynamic method: Based on the material balance method, combined with production dynamics and gas intake profile monitoring, the fire front edge location is predicted; (3) Tracer method: Isotope-labeled tracers are injected into the reservoir along with air in the gas injection well, and the change characteristics of the tracers are monitored regularly in the production well; (4) Infrared photography method: Generally, an infrared camera device is used to move and measure the location of the fire front edge in the test area; (5) Microseismic method: Based on the slight vibration caused by the heat fracture of the reservoir during the formation combustion process, the spatial location at a certain moment is determined to determine the change of the micro position of the fire drive.

[0051] Please see Figure 1 This is a flowchart illustrating a method for determining the leading edge position of a heavy oil fire drive fire line according to an embodiment of this application. Specifically, it may include:

[0052] S110. Obtain associated gas samples and production data from production wells;

[0053] For example, after successful reservoir ignition, associated gas samples are periodically collected from the production well. Gas samples can be collected using gas bags or cylinders, with a collection volume of no less than 500 ml and a collection frequency of no less than once per month.

[0054] S120. Perform qualitative and quantitative analysis on the associated gas sample to obtain the component content, wherein the component content includes carbon monoxide content and hydrogen content;

[0055] For example, to obtain the component content of the associated gas sample, qualitative and quantitative analysis of the collected associated gas sample is required. During qualitative and quantitative analysis, it is necessary to ensure that the collected associated gas sample represents the gas composition of the entire production process. The analytical instrument should be calibrated regularly to ensure the accuracy of the analytical results. Appropriate standard substances should be used for qualitative and quantitative analysis to improve the reliability of the results. Reasonable processing and quality control of the analytical data should be implemented, such as removing outliers and performing repeatability and reproducibility analysis.

[0056] S130. The position of the leading edge of the fire line is predicted based on the carbon monoxide content, the hydrogen content, and the production data, and the prediction result is obtained.

[0057] For example, carbon monoxide and hydrogen are strong reducing gases with highly reactive chemical properties. During their migration towards the production well, carbon monoxide and hydrogen undergo oxidation reactions with residual oxygen in the associated gas, gradually consuming them. Furthermore, the minerals in the reservoir are oxidizing and also consume some carbon monoxide and hydrogen. As the fire front approaches the production well, the migration distance of carbon monoxide and hydrogen is shorter, and they do not have enough time to react with the associated oxygen or reservoir minerals. The content of carbon monoxide and hydrogen rises sharply in a short period and remains so for a certain time. After the fire front crosses the production well, the content decreases rapidly. Therefore, the location of the fire front can be predicted using carbon monoxide content, hydrogen content, and production data, yielding a prediction result.

[0058] In summary, the method for determining the leading edge of the fire line in heavy oil fire flooding proposed in this application determines the fire line location and advance speed by analyzing the composition of associated gas from production wells in heavy oil reservoirs. Furthermore, it has advantages such as low operating costs, ease of promotion, and fewer interfering factors. Long-term monitoring of associated gas from production wells not only deepens the understanding of fire flooding mechanisms and the dynamic characteristics of on-site production, but also provides reliable data support for dynamic control of fire flooding operations.

[0059] In some examples, the step of performing qualitative and quantitative analysis on the associated gas sample to obtain the component content includes:

[0060] Obtain the peak area values ​​of standard gas chromatography;

[0061] The associated gas sample was analyzed by gas chromatography to obtain the associated gas components;

[0062] The associated gas components were analyzed using quantitative analysis methods to obtain the component contents.

[0063] For example, the associated gas samples collected above are analyzed by gas chromatography using either direct injection via a catheter or injection via syringe. Qualitative analysis is based on the retention times of known components in the gas chromatograph. The gas chromatograph should be a dual-path system, equipped with a thermal conductivity detector (TCD) and a flame ionization detector (FID) and a six-way valve, or two or more chromatographs can be used to achieve this function. Under the same operating conditions, quantitative analysis methods are used to analyze the associated gas components and obtain their concentrations.

[0064] In some examples, the step of performing gas chromatography analysis on the associated gas sample to obtain the associated gas components includes:

[0065] Obtain the retention time of the standard components;

[0066] The associated gas sample was analyzed by gas chromatography to obtain the retention times of the components;

[0067] The retention time of the component is matched with the retention time of the standard component to obtain the associated gas component.

[0068] For example, such as Figure 2 The image shown is a gas chromatogram for the qualitative analysis of associated gas in a method for determining the leading edge position of a heavy oil fire-propelled zone, provided in an embodiment of this application. The associated gas sample is analyzed by gas chromatography using either direct injection via a catheter or injection after extraction with a syringe. Qualitative analysis is based on the retention times of known components in the gas chromatogram. In gas chromatography, retention time refers to the time elapsed from injection of a component in the sample to the appearance of a response signal on the detector. Different components have different retention times in the chromatographic column, depending on their physicochemical properties, the type of chromatographic column, and operating conditions.

[0069] Once the retention times of the standard components are obtained, the presence of these known components in the associated gas sample can be determined by comparing their retention times with those of the standard components. If the retention time of a component in the associated gas sample matches that of the standard component, it can be preliminarily determined that the component is the same as the standard component, thus identifying the associated gas component. To improve the accuracy of qualitative analysis, multiple standard components can be used simultaneously for comparison, and the analysis can be performed under the same chromatographic conditions.

[0070] In some examples, the step of analyzing the associated gas components according to a quantitative analysis method to obtain the component content includes:

[0071] The associated gas components were analyzed using the external standard method to obtain the peak area values ​​of the sample chromatogram.

[0072] The component content is obtained by comparing the peak area values ​​of the sample chromatogram with those of the standard gas chromatogram.

[0073] For example, standard gas is injected into the gas chromatograph using either direct injection via catheter or injection via syringe. The retention times of the chromatographic peaks of each component in the associated gas sample are recorded. The external standard method involves performing chromatographic analysis of the associated gas sample and a standard gas of known concentration under the same analytical conditions. The peak areas (or peak heights) of the target components in the associated gas sample and the standard gas are compared. Then, based on the ratio of the concentration and peak area (or peak height) of the target component in the standard gas to the peak area (or peak height) of the target component in the associated gas sample, the content of each component in the associated gas sample is calculated.

[0074] In some examples, the step of analyzing the associated gas components according to a quantitative analysis method to obtain the component content includes:

[0075] The associated gas components were analyzed using the corrected area normalization method to obtain the component content.

[0076] For example, the corrected area normalization method is based on the premise that the sum of the peak areas of all components equals the total peak area. The content of each component is obtained by calculating the proportion of its peak area to the total peak area and then multiplying this proportion by a correction factor. The correction factor is determined based on the relative response value of each component, which can be experimentally measured.

[0077] Both the external standard method and the calibration area normalization method can be used to analyze standard gas or associated gas samples with known component contents. In practical applications, the appropriate method can be selected based on the specific circumstances. If a standard gas is available and the injection volume can be well controlled, the external standard method may be a better choice; if a standard gas is not available, or if it is necessary to determine the contents of all components simultaneously, the calibration area normalization method may be more suitable.

[0078] In some examples, the component content also includes: nitrogen content, carbon dioxide content, oxygen conversion rate, and apparent hydrogen-to-carbon atomic ratio;

[0079] The steps following the qualitative and quantitative analysis of the associated gas sample to obtain the component content include:

[0080] The nitrogen content, carbon dioxide content, oxygen conversion rate, and apparent hydrogen-carbon atomic ratio are judged to obtain the judgment result;

[0081] If the nitrogen content is within a first preset range, the carbon dioxide content is within a second preset range, the oxygen conversion rate is within a preset conversion rate range, and the apparent hydrogen-carbon atomic ratio is within a preset ratio range, then the judgment result is that the combustion state is accurately identified.

[0082] If the determination result indicates that the combustion state is accurately identified, the position of the leading edge of the fire line is predicted based on the carbon monoxide content, the hydrogen content, and the production data.

[0083] For example, the content of each component of the associated gas obtained above can be used to determine whether the reservoir has achieved high-temperature oxidation. Specifically, the nitrogen content, carbon dioxide content, oxygen conversion rate, and apparent hydrogen-to-carbon ratio are assessed to obtain the results. If the nitrogen content is within a first preset range, the carbon dioxide content is within a second preset range, the oxygen conversion rate is within a preset range, and the apparent hydrogen-to-carbon ratio is within a preset range, then the combustion state identification is accurate. Generally, it is considered that a nitrogen content of 70%–82%, a carbon dioxide content of 12%–18%, an oxygen conversion rate of 70%–100%, and an apparent hydrogen-to-carbon ratio of 0–2 in the associated gas sample represent that the reservoir has achieved high-temperature oxidation. It should be noted that for the same production well, there may be situations where the four indicators do not fully meet the characteristics of high-temperature oxidation, or even special cases such as a negative apparent hydrogen-to-carbon ratio and an oxygen conversion rate exceeding 100%. Misjudgments of the fire-driven combustion state should be avoided by using a single indicator for identification. Accurate identification of the combustion state is the prerequisite and foundation for predicting the leading edge position of the fire line. If the combustion state is not accurately identified, the leading edge position cannot be predicted. If the combustion state is accurately identified, the leading edge position can be predicted based on the carbon monoxide content, hydrogen content, and production data.

[0084] In some examples, the step of predicting the leading edge position of the fire line based on the carbon monoxide content, the hydrogen content, and the production data, and obtaining the prediction result, includes:

[0085] A change graph was generated based on the carbon monoxide content, hydrogen content, and production data.

[0086] The predicted position of the leading edge of the fire line is obtained based on the aforementioned change diagram.

[0087] For example, the carbon monoxide and hydrogen contents in the associated gas from fire-driven flooding are used as parameters reflecting the migration characteristics of the fire front. Combined with production data from the production well, a time-varying graph is plotted. Carbon monoxide and hydrogen are strong reducing gases with reactive chemical properties. During their migration towards the production well, they undergo oxidation reactions with residual oxygen in the associated gas, gradually consuming them. Additionally, the minerals in the reservoir are oxidizing and also consume some carbon monoxide and hydrogen. As the fire front approaches the production well, the migration distance of carbon monoxide and hydrogen is shorter, and they do not have enough time to react with the oxygen or reservoir minerals. The carbon monoxide and hydrogen contents rise sharply in a short period and remain elevated for a certain time. After the fire front crosses the production well, the contents decrease rapidly. The fire front location and advance speed can be predicted based on the graph.

[0088] The present invention will be described in detail below with reference to the embodiments, but these should not be construed as limiting the scope of protection of the present invention.

[0089] Example:

[0090] Three production wells in the D66 block of Liaohe Oilfield's heavy oil fire-flooded reservoir collected associated gas samples using 500ml gas sampling bags, with a sampling frequency of once per month.

[0091] The associated gas samples collected above were analyzed by gas chromatography using direct injection via a tubing. Qualitative analysis was based on the retention times of known components in the gas chromatograph. The gas chromatograph should be a dual-path system, equipped with a thermal conductivity detector (TCD) and a flame ionization detector (FID) and a six-way valve. The associated gas from fire-driven combustion contains hydrocarbons (methane, ethane, propane, etc.), alkenes (ethylene, n-butene, isobutene, etc.), oxides (carbon monoxide, carbon dioxide), and components such as nitrogen, hydrogen, and oxygen.

[0092] Under the same operating conditions, the external standard method is used to analyze standard gases with known component contents. The content of each component is calculated by comparing the measured peak area values ​​of the sample chromatogram with those of the standard gas chromatogram.

[0093] Using the associated gas component contents obtained above, well S1-040 has a nitrogen content of 77.49%–82.93%, a carbon dioxide content of 14.13%–17.83%, an apparent hydrogen-to-carbon atomic ratio of 0.19–1.73, and an oxygen conversion rate of 69.75%–95.51%. All indicators are consistent with the characteristics of high-temperature oxidation. Additionally, the gas components contain small amounts of olefins and hydrogen, indicating that the tail gas from fire-driven high-temperature oxidation is related to the cracking reaction. Well S1-40 has a nitrogen content of 71.24%–82.49%, a carbon dioxide content of 12.32%–16.84%, an apparent hydrogen-to-carbon atomic ratio of 0.63–1.74, an oxygen conversion rate of 69.60%–86.43%, an olefin content of 0.006%–0.070%, and a hydrogen content of 0.001%–0.238%. All indicators are consistent with the characteristics of high-temperature oxidation. The gas parameters of well S1-041 fluctuate significantly. The nitrogen content in this well ranges from 57.38% to 81.91%, the carbon dioxide content from 14.55% to 21.19%, the apparent hydrogen-to-carbon atomic ratio from -0.58 to 1.58, and the oxygen conversion rate from 72% to 117%. These four indicators do not fully meet the characteristics of high-temperature oxidation. There are even cases where the apparent hydrogen-to-carbon atomic ratio is negative and the oxygen conversion rate exceeds 100%. The associated gas characteristic analysis did not show high-temperature oxidation.

[0094] like Figure 3 The image shown is a graph illustrating the change of associated gas generated during high-temperature oxidation in heavy oil reservoirs during a method for determining the leading edge position of a fire line in heavy oil flooding, as provided in an embodiment of this application. Figure 4 The image shown is a graph illustrating the change in associated gas generated during heavy oil reservoir fire flooding without high-temperature oxidation over time, as provided in an embodiment of this application for determining the position of the leading edge of the fire line in heavy oil fire flooding.Figure 5 The diagram shown illustrates a method for determining the position of the leading edge of a heavy oil fire-flooding fire line according to an embodiment of this application, where the leading edge of the fire line approaches the production well and reaches peak production. Figure 6 The diagram shown illustrates a method for determining the position of the leading edge of a heavy oil fire-flooding fire line according to an embodiment of this application, where the leading edge of the fire line approaches the production well from the injection well. Figure 7 The diagram illustrates a method for determining the leading edge of a heavy oil fire-flooding fire line according to an embodiment of this application, where the fire line has not yet migrated towards the production well. The carbon monoxide content in well S1-040 gradually increased from 0.229% in May 2014, nearly doubling to 0.392% in August of that year. Afterward, the content remained above 0.400% for almost a year, gradually decreasing after July 2015, dropping to 0.061% in September 2016, and remaining in a low range of 0.003% to 0.173% until November 2018. The trend of hydrogen content over time is similar to that of carbon monoxide content, but slightly less significant. Based on the analysis of production data, it is believed that the Shu 1-040 well achieved high-temperature oxidation in May 2014. The combustion front of the fire-driven well continued to advance from the injection well to the production well, forming a peak production period from May 2014 to April 2016. However, due to factors such as the gas injection rate or reservoir heterogeneity, the oil production during the peak period fluctuated, and the peak production period ended around September 2016. It is speculated that at this time, the combustion front had already crossed the S16-040 well. The production curve and gas parameter curve of this well represent the dynamic characteristics of the fire-driven well approaching the production well, reaching the production peak, and gradually crossing the production well to end the fire-driven operation.

[0095] The carbon monoxide content in well S1-40 remained low (0–0.084%) from May 2014 to April 2016. Starting from 0.172% in June 2016, it rapidly increased and doubled within three months, reaching 0.364% in September 2016. This level remained within this range until March 2018, before decreasing to 0.097% in June 2018. The hydrogen content showed a similar trend over time as the carbon monoxide content. Based on the oil production data, it is believed that well S1-40 achieved high-temperature oxidation in May 2014. However, at this time, the fire line was far from the production well. The production curve and gas parameter curve of this well represent the dynamic characteristics of fire-driven high-temperature oxidation reaching peak production, after which the fire line gradually moved closer to and eventually crossed the production well, ending the fire-driven process.

[0096] During the monitoring period, almost no carbon monoxide was detected in well S1-041, with only hydrogen fluctuating within a small range (0–0.032%), and oil production never showed a significant peak. Based on previous assessments of the combustion state, it is believed that the production curve and gas parameter curve of this well represent the dynamic characteristics of the fire line not yet migrating towards this production well.

[0097] like Figure 8 As shown, this application proposes a system for determining the position of the leading edge of a heavy oil fire drive fire line. The system includes: a data acquisition module 21, an analysis module 22, and a prediction module 23.

[0098] The data acquisition module 21 is configured to acquire associated gas sample and production well production data;

[0099] The analysis module 22 is configured to perform qualitative and quantitative analysis on the associated gas sample to obtain the component content, wherein the component content includes carbon monoxide content, hydrogen content, nitrogen content, carbon dioxide content, oxygen conversion rate, and apparent hydrogen-carbon atomic ratio.

[0100] The prediction module 23 is configured to predict the position of the leading edge of the fire line based on the carbon monoxide content, the hydrogen content, and the production data, and obtain the prediction result.

[0101] The effects of applying the aforementioned method in the above system can be found in the description of the aforementioned method embodiments, and will not be repeated here.

[0102] like Figure 9 As shown, this application embodiment also provides an electronic device 300, including a memory 310, a processor 320, and a computer program 311 stored in the memory 310 and executable on the processor. When the processor 320 executes the computer program 311, it implements any of the steps of the above-mentioned method for determining the position of the leading edge of the heavy oil fire drive fire line.

[0103] Since the electronic device described in this embodiment is the device used to implement the device for determining the position of the leading edge of a heavy oil fire drive line in the embodiments of this application, those skilled in the art can understand the specific implementation method and various variations of the electronic device in this embodiment based on the method described in the embodiments of this application. Therefore, how the electronic device implements the method in the embodiments of this application will not be described in detail here. Any device used by those skilled in the art to implement the method in the embodiments of this application falls within the scope of protection of this application.

[0104] In practical implementation, when the computer program 311 is executed by the processor, it can achieve the following: Figure 1 Any of the corresponding implementation methods in the embodiments.

[0105] It should be noted that the descriptions of each embodiment in the above embodiments have different focuses. For parts that are not described in detail in a certain embodiment, please refer to the relevant descriptions in other embodiments.

[0106] Those skilled in the art will understand that embodiments of this application can be provided as methods, systems, or computer program products. Therefore, this application can take the form of a completely hardware embodiment, a completely software embodiment, or an embodiment combining software and hardware aspects. Furthermore, this application can take the form of a computer program product embodied on one or more computer-readable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) containing computer-readable program code.

[0107] This application is described with reference to flowchart illustrations and / or block diagrams of methods, apparatus (systems), and computer program products according to embodiments of this application. It will be understood that each block of the flowchart illustrations and / or block diagrams, and combinations of blocks in the flowchart illustrations and / or block diagrams, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, special-purpose computer, embedded computer, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, create a machine for implementing the flowchart illustrations. Figure 1 One or more processes and / or boxes Figure 1 A device that provides the functions specified in one or more boxes.

[0108] These computer program instructions may also be stored in a computer-readable storage medium that can direct a computer or other programmable data processing device to function in a particular manner, such that the instructions stored in the computer-readable storage medium produce an article of manufacture including instruction means, which are implemented in a process Figure 1 One or more processes and / or boxes Figure 1 The function specified in one or more boxes.

[0109] These computer program instructions may also be loaded onto a computer or other programmable data processing equipment to cause a series of operational steps to be performed on the computer or other programmable equipment to produce a computer-implemented process, thereby providing instructions that execute on the computer or other programmable equipment for implementing the process. Figure 1 One or more processes and / or boxes Figure 1 The steps of the function specified in one or more boxes.

[0110] This application also provides a computer program product, which includes computer software instructions that, when executed on a processing device, cause the processing device to execute the LDPC decoding method of a solid-state drive controller.

[0111] A computer program product includes one or more computer instructions. When the computer program instructions are loaded and executed on a computer, all or part of the flow or function according to the embodiments of this application is generated. The computer may be a general-purpose computer, a special-purpose computer, a computer network, or other programmable device. The computer instructions may be stored in a computer-readable storage medium or transmitted from one computer-readable storage medium to another. For example, computer instructions may be transmitted from one website, computer, server, or data center to another website, computer, server, or data center via wired (e.g., coaxial cable, fiber optic, digital subscriber line (DSL)) or wireless (e.g., infrared, wireless, microwave, etc.) means. The computer-readable storage medium may be any available medium that a computer can store or a data storage device such as a server or data center that integrates one or more available media. The available medium may be a magnetic medium (e.g., floppy disk, hard disk, magnetic tape), an optical medium (e.g., DVD), or a semiconductor medium (e.g., solid-state disk (SSD)).

[0112] Those skilled in the art will clearly understand that, for the sake of convenience and brevity, the specific working processes of the systems, devices, and units described above can be referred to the corresponding processes in the foregoing method embodiments, and will not be repeated here.

[0113] In the several embodiments provided in this application, it should be understood that the disclosed devices, apparatuses, and methods can be implemented in other ways. For example, the apparatus embodiments described above are merely illustrative; for instance, the division of units is only a logical functional division, and in actual implementation, there may be other division methods. For example, multiple units or components may be combined or integrated into another system, or some features may be ignored or not executed. Furthermore, the coupling or direct coupling or communication connection shown or discussed may be through some interfaces, or indirect coupling or communication connection between devices or units, and may be electrical, mechanical, or other forms.

[0114] The units described as separate components may or may not be physically separate. The components shown as units may or may not be physical units; that is, they may be located in one place or distributed across multiple network units. Some or all of the units can be selected to achieve the purpose of this embodiment according to actual needs.

[0115] Furthermore, the functional units in the various embodiments of this application can be integrated into one processing unit, or each unit can exist physically separately, or two or more units can be integrated into one unit. The integrated unit can be implemented in hardware or as a software functional unit.

[0116] If the integrated unit is implemented as a software functional unit and sold or used as an independent product, it can be stored in a computer-readable storage medium. Based on this understanding, the technical solution of this application, in essence, or the part that contributes to the prior art, or all or part of the technical solution, can be embodied in the form of a software product. This computer software product is stored in a storage medium and includes several instructions to cause a computer device (which may be a personal computer, server, or network device, etc.) to execute all or part of the steps of the methods of the various embodiments of this application. The aforementioned storage medium includes various media capable of storing program code, such as USB flash drives, portable hard drives, read-only memory (ROM), random access memory (RAM), magnetic disks, or optical disks.

[0117] The above embodiments are only used to illustrate the technical solutions of this application, and are not intended to limit them. Although this application has been described in detail with reference to the foregoing embodiments, those skilled in the art should understand that modifications can still be made to the technical solutions described in the foregoing embodiments, or equivalent substitutions can be made to some of the technical features. Such modifications or substitutions do not cause the essence of the corresponding technical solutions to deviate from the spirit and scope of the technical solutions of the embodiments of this application.

[0118] Although preferred embodiments have been described in this specification, those skilled in the art, upon learning the basic inventive concept, can make other changes and modifications to these embodiments. Therefore, the appended claims are intended to be interpreted as including the preferred embodiments as well as all changes and modifications falling within the scope of this specification.

[0119] Obviously, those skilled in the art can make various modifications and variations to this specification without departing from its spirit and scope. Therefore, if such modifications and variations fall within the scope of the claims and their equivalents, this specification is also intended to include such modifications and variations.

Claims

1. A method for determining the position of the leading edge of a heavy oil fire-driving line, characterized in that, The method includes: Obtain associated gas samples and production data from production wells; Qualitative and quantitative analysis was performed on the associated gas sample to obtain the component content, which included carbon monoxide content and hydrogen content. The position of the leading edge of the fire line is predicted based on the carbon monoxide content, the hydrogen content, and the production data, and the prediction result is obtained.

2. The method for determining the leading edge position of a heavy oil fire-driven fire line according to claim 1, characterized in that, The step of performing qualitative and quantitative analysis on the associated gas sample to obtain the component content includes: Obtain the peak area values ​​of standard gas chromatography; The associated gas sample was analyzed by gas chromatography to obtain the associated gas components; The associated gas components were analyzed using quantitative analysis methods to obtain the component contents.

3. The method for determining the leading edge position of a heavy oil fire-driven fire line according to claim 2, characterized in that, The step of performing gas chromatography analysis on the associated gas sample to obtain the associated gas components includes: Obtain the retention time of the standard components; The associated gas sample was analyzed by gas chromatography to obtain the retention times of the components; The retention time of the component is matched with the retention time of the standard component to obtain the associated gas component.

4. The method for determining the leading edge position of a heavy oil fire-driven fire line according to claim 2, characterized in that, The step of analyzing the associated gas components using a quantitative analysis method to obtain the component content includes: The associated gas components were analyzed using the external standard method to obtain the peak area values ​​of the sample chromatogram. The component content is obtained by comparing the peak area values ​​of the sample chromatogram with those of the standard gas chromatogram.

5. The method for determining the leading edge position of a heavy oil fire-driven fire line according to claim 2, characterized in that, The step of analyzing the associated gas components using a quantitative analysis method to obtain the component content includes: The associated gas components were analyzed using the corrected area normalization method to obtain the component content.

6. The method for determining the leading edge position of a heavy oil fire-driven fire line according to claim 1, characterized in that, The component content also includes: nitrogen content, carbon dioxide content, oxygen conversion rate, and apparent hydrogen-to-carbon atomic ratio; The steps following the qualitative and quantitative analysis of the associated gas sample to obtain the component content include: The nitrogen content, carbon dioxide content, oxygen conversion rate, and apparent hydrogen-carbon atomic ratio are judged to obtain the judgment result; If the nitrogen content is within a first preset range, the carbon dioxide content is within a second preset range, the oxygen conversion rate is within a preset conversion rate range, and the apparent hydrogen-carbon atomic ratio is within a preset ratio range, then the judgment result is that the combustion state is accurately identified. If the determination result indicates that the combustion state is accurately identified, the position of the leading edge of the fire line is predicted based on the carbon monoxide content, the hydrogen content, and the production data.

7. The method for determining the position of the leading edge of a heavy oil fire-driven fire line according to claim 1, characterized in that, The step of predicting the leading edge position of the fire line based on the carbon monoxide content, the hydrogen content, and the production data, and obtaining the prediction result, includes: A change graph was generated based on the carbon monoxide content, hydrogen content, and production data. The predicted position of the leading edge of the fire line is obtained based on the aforementioned change diagram.

8. A system for determining the position of the leading edge of a heavy oil fire-driving line, characterized in that, The system includes: a data acquisition module, an analysis module, and a prediction module; The data acquisition module is configured to acquire associated gas sample and production well production data; The analysis module is configured to perform qualitative and quantitative analysis on the associated gas sample to obtain the component content, which includes carbon monoxide content, hydrogen content, nitrogen content, carbon dioxide content, oxygen conversion rate, and apparent hydrogen-carbon atomic ratio. The prediction module is configured to predict the position of the leading edge of the fire line based on the carbon monoxide content, the hydrogen content, and the production data, and obtain the prediction result.

9. An electronic device, comprising: The memory and processor are characterized in that the processor, when executing a computer program stored in the memory, implements the steps of a method for determining the position of the leading edge of a heavy oil fire-driving line as described in any one of claims 1-7.

10. A computer-readable storage medium having a computer program stored thereon, characterized in that, When the computer program is executed by the processor, it implements the steps of a method for determining the leading edge position of a heavy oil fire drive line as described in any one of claims 1-7.

Images