Method and system for evaluating type of gas well output liquid

Abstract

The invention discloses a gas well output liquid type evaluation method and system.The method comprises the steps that firstly, isotope values of hydrogen in formation water, foreign water and output liquid are used for conducting qualitative evaluation on the output liquid type, in the process, the isotope values of hydrogen in the formation water and the foreign water are stable, and therefore the isotope values of hydrogen in the formation water and the foreign water are stable; the isotope value of hydrogen in the output liquid is compared with the isotope value of hydrogen in the formation water and the external water, and the type of the formation water can be quantitatively judged. When the output liquid is the mixed liquid of the formation water and the extraneous water, the concentrations of a plurality of characteristic ions in the formation water, the extraneous water and the output liquid are obtained; and determining the volume ratio of the formation water to the extraneous water in the output liquid according to the concentrations of the plurality of characteristic ions in the formation water, the extraneous water and the output liquid, and quantitatively evaluating the type of the output liquid to complete the evaluation process of the type of the gas well output liquid. According to the method, the type of the gas well output liquid can be accurately, effectively and timely judged in each stage of gas reservoir production, and qualitative, quantitative and accurate judgment of the type of the output liquid is effectively realized.

Description

Technical Field

[0001] The invention belongs to the technical field of oil and gas production, and relates to a method and system for evaluating the type of produced fluid from a gas well. Background Art

[0002] Currently, the development and production process of most gas reservoirs, from the initial stage to the final stage, is a struggle with formation water. Therefore, accurately determining whether the gas well output fluid is formation water is crucial for adjusting and formulating the next development strategy for the gas well and gas reservoir. The series of gas reservoirs currently discovered in the Kuqa piedmont are all ultra-deep, high-pressure, fractured, tight sandstone gas reservoirs. Due to the complex gas reservoir structure, strong reservoir heterogeneity, poor physical properties, complex gas-water distribution relationships, and low matrix porosity and permeability, it is generally necessary to perform reservoir transformation methods such as sand fracturing during the oil testing phase to improve seepage capacity and increase single-well production capacity. This also means that in the current actual production process, the gas well output fluid includes not only formation water, but also external water such as transformation fluid and drilling fluid. However, the current chloride ion monitoring technology has large variations in chloride ion with different production time, making it impossible to accurately and timely determine the specific source of the gas well output fluid, which is extremely unfavorable for gas well development management and production strategy formulation. Summary of the Invention

[0003] In response to the problems existing in the prior art, the present invention provides a method and system for evaluating the type of gas well produced fluid, thereby solving the technical problem in the prior art that the chloride ion content cannot be used to accurately and effectively determine the source of the gas well produced fluid.

[0004] The present invention is achieved through the following technical solutions:

[0005] A method for evaluating the type of produced fluid from a gas well comprises the following steps:

[0006] S1: Obtain the isotope values ​​of hydrogen in formation water, external water and produced fluid;

[0007] S2: comparing the hydrogen isotope value in the produced fluid with the hydrogen isotope values ​​in formation water and external water to qualitatively evaluate the type of the produced fluid;

[0008] S3: When the produced fluid is a mixture of formation water and external water, the concentrations of several characteristic ions in the formation water, external water, and produced fluid are obtained;

[0009] S4: Determine the volume proportion of formation water and external water in the produced fluid by measuring the concentrations of several characteristic ions in the formation water, external water and produced fluid, quantitatively evaluate the type of the produced fluid, and complete the evaluation process of the gas well produced fluid type.

[0010] Preferably, the isotope of hydrogen includes at least one of protium, deuterium and tritium.

[0011] Preferably, step S2 is specifically as follows:

[0012] If the absolute value of the difference between the hydrogen isotope value in the produced fluid and the hydrogen isotope value in the formation water is not greater than a preset first threshold, the produced fluid is formation water;

[0013] If the absolute value of the difference between the hydrogen isotope value in the produced liquid and the hydrogen isotope value in the external water is not greater than a preset first threshold value, the produced liquid is external water;

[0014] If the absolute value of the difference between the hydrogen isotope value in the produced fluid and the hydrogen isotope value in the formation water is greater than the preset first threshold, and the absolute value of the difference between the hydrogen isotope value in the produced fluid and the hydrogen isotope value in the external water is greater than the preset first threshold, then the produced fluid is a mixture of formation water and external water.

[0015] Preferably, in step S3, the characteristic ions include at least two of bicarbonate, chloride, sulfate, calcium, magnesium, barium, strontium, potassium, sodium, boron, lithium and bromide.

[0016] Preferably, in step S3, when comparing the concentrations of several characteristic ions in the formation water, external water and produced fluid, ions with a concentration change rate greater than a preset second threshold are selected for quantitative calculation to quantitatively evaluate the type of produced fluid.

[0017] Preferably, when quantitatively evaluating the type of produced fluid, specifically:

[0018]

[0019] V2%=1-V1%

[0020] Where V1% is the volume percentage of formation water in the produced fluid;

[0021] V2% is the volume percentage of external water in the produced fluid;

[0022] ρ1 is the concentration of characteristic ions in formation water;

[0023] ρ2 is the concentration of characteristic ions in external water;

[0024] ρ3 is the concentration of characteristic ions in the produced fluid.

[0025] A gas well production fluid type evaluation system, comprising:

[0026] a first data acquisition unit, configured to acquire isotope values ​​of hydrogen in formation water, external water, and produced fluid;

[0027] a first data processing unit, configured to compare the hydrogen isotope value in the produced fluid with the hydrogen isotope values ​​in formation water and external water, and to perform a qualitative evaluation on the type of the produced fluid;

[0028] a second data acquisition unit, configured to acquire concentrations of several characteristic ions in the formation water, the external water, and the produced fluid when the produced fluid is a mixture of formation water and external water;

[0029] The second data processing unit is used to determine the volume proportion of formation water and external water in the production fluid through the concentration of several characteristic ions in the formation water, external water and production fluid, quantitatively evaluate the type of the production fluid, and complete the evaluation process of the gas well production fluid type.

[0030] A computer device / apparatus / system comprises a memory, a processor and a computer program stored in the memory, wherein the processor executes the computer program to implement the steps of the above method.

[0031] A computer-readable storage medium stores a computer program, wherein the computer program / instructions are executed by a processor to implement the steps of the above method.

[0032] A computer program product comprises a computer program / instruction, which implements the steps of the above method when executed by a processor.

[0033] Compared with the prior art, the present invention has the following beneficial technical effects:

[0034] The present invention discloses a method for evaluating the type of gas well produced fluid. First, the type of produced fluid is qualitatively evaluated using the isotope values ​​of hydrogen in formation water, external water, and produced fluid. During this process, the isotope values ​​of hydrogen in formation water and external water are stable. Therefore, by comparing the isotope values ​​of hydrogen in the produced fluid with the isotope values ​​of hydrogen in formation water and external water, the type of formation water can be qualitatively determined. When the produced fluid is a mixture of formation water and external water, the concentrations of several characteristic ions in the formation water, external water, and produced fluid are obtained; the volume proportions of formation water and external water in the produced fluid are determined based on the concentrations of several characteristic ions in the formation water, external water, and produced fluid, and the type of the produced fluid is quantitatively evaluated, completing the evaluation process for the type of gas well produced fluid. This method can accurately, effectively, and timely determine the type of gas well produced fluid at all stages of gas reservoir production, effectively achieving accurate qualitative and quantitative determination of the type of produced fluid. BRIEF DESCRIPTION OF THE DRAWINGS

[0035] In order to more clearly illustrate the technical solutions of the embodiments of the present invention, the following briefly introduces the drawings required for use in the embodiments. It should be understood that the following drawings only illustrate certain embodiments of the present invention and therefore should not be regarded as limiting the scope. For ordinary technicians in this field, other relevant drawings can be obtained based on these drawings without paying any creative work.

[0036] Figure 1 Schematic diagram of a flow chart of a method for evaluating the type of produced fluid from a gas well in the present invention;

[0037] Figure 2 This is a schematic structural diagram of a system for evaluating the type of produced fluid from a gas well in the present invention;

[0038] Figure 3 is the hydrogen isotope value in the formation water, external water and produced fluid obtained in Example 2 of the present invention;

[0039] Figure 4 are the concentration values ​​of several characteristic ions obtained in Example 2 of the present invention;

[0040] Figure 5 These are the hydrogen isotope values ​​in the formation water, external water, and produced fluid obtained in Example 3 of the present invention. DETAILED DESCRIPTION

[0041] To make the objectives, technical solutions, and advantages of the embodiments of the present invention more clear, the technical solutions of the embodiments of the present invention will be clearly and completely described below in conjunction with the accompanying drawings of the embodiments of the present invention. Obviously, the described embodiments are only part of the embodiments of the present invention, not all of the embodiments. Generally, the components of the embodiments of the present invention described and shown in the drawings herein can be arranged and designed in various different configurations.

[0042] Therefore, the following detailed description of the embodiments of the present invention provided in the accompanying drawings is not intended to limit the scope of the invention as claimed, but rather merely represents selected embodiments of the present invention. All other embodiments derived by persons of ordinary skill in the art based on the embodiments of the present invention without creative effort shall fall within the scope of protection of the present invention.

[0043] It should be noted that similar reference numerals and letters denote similar items in the following drawings, and therefore, once an item is defined in one drawing, it does not need to be further defined or explained in subsequent drawings.

[0044] In the description of the embodiments of the present invention, it should be noted that if the terms "upper," "lower," "horizontal," "inner," etc. appear, the orientation or positional relationship indicated is based on the orientation or positional relationship shown in the accompanying drawings, or the orientation or positional relationship in which the inventive product is typically placed when in use. These terms are merely for the convenience of describing the present invention and simplifying the description, and do not indicate or imply that the device or component referred to must have a specific orientation, be constructed, or operate in a specific orientation. Therefore, they should not be construed as limitations on the present invention. In addition, the terms "first," "second," etc. are used only to distinguish descriptions and should not be construed as indicating or implying relative importance.

[0045] In addition, if the term "horizontal" appears, it does not mean that the component must be absolutely horizontal, but can be slightly tilted. For example, "horizontal" only means that its direction is more horizontal than "vertical", and does not mean that the structure must be completely horizontal, but can be slightly tilted.

[0046] In the description of the embodiments of the present invention, it should be noted that, unless otherwise expressly specified or limited, the terms "disposed," "installed," "connected," and "connected" should be understood in a broad sense. For example, they can refer to fixed connections, detachable connections, or integral connections; they can refer to mechanical connections or electrical connections; they can refer to direct connections or indirect connections through an intermediate medium; and they can refer to internal connections between two components. Those skilled in the art will understand the specific meanings of the above terms in the present invention based on specific circumstances.

[0047] The present invention is described in further detail below with reference to the accompanying drawings:

[0048] Example 1

[0049] like Figure 1 As shown, the present invention discloses a method for evaluating the type of gas well produced fluid, comprising the following steps:

[0050] S1: Obtain the isotope values ​​of hydrogen in formation water, external water, and produced fluids; wherein the isotopes of hydrogen include at least one of protium, deuterium, and tritium. Specifically, the isotope analysis of hydrogen in the produced fluids of the gas well can be performed by chromatography, spectroscopy, or other methods;

[0051] In addition, it is understood that during conventional production, the gas well production fluid may be formation water, external water, or a mixture of formation water and external water, wherein the external water may be at least one of a reservoir reforming fluid and a drilling fluid. External water is external water.

[0052] S2: comparing the hydrogen isotope value in the produced fluid with the hydrogen isotope values ​​in formation water and external water to qualitatively evaluate the type of the produced fluid;

[0053] If the absolute value of the difference between the hydrogen isotope value in the produced fluid and the hydrogen isotope value in the formation water is not greater than a preset first threshold, the produced fluid is formation water;

[0054] If the absolute value of the difference between the hydrogen isotope value in the produced liquid and the hydrogen isotope value in the external water is not greater than a preset first threshold value, the produced liquid is external water;

[0055] If the absolute value of the difference between the hydrogen isotope value in the produced fluid and the hydrogen isotope value in the formation water is greater than the preset first threshold, and the absolute value of the difference between the hydrogen isotope value in the produced fluid and the hydrogen isotope value in the external water is greater than the preset first threshold, then the produced fluid is a mixture of formation water and external water.

[0056] Here, the first threshold can be set to 1‰. That is, when the degree of change is within 1‰, it can be considered as this type.

[0057] It is understandable that, because in the gas well construction process, the higher the temperature, the smaller the isotope fractionation situation, at the high temperature of the formation, the isotope fractionation situation is very small. After the mixed liquid enters the formation, the oxygen in the mixed liquid and the oxygen in the formation rock will gradually balance, which makes the oxygen isotope value change, and the higher the temperature, the greater the change value. The hydrogen content in the rock is extremely small, so the hydrogen isotope in the neutral-alkaline liquid hardly changes, so the hydrogen isotope is more stable than the oxygen isotope value. In order to more accurately determine the type of gas well output fluid, better provide support for the efficient development and management of oil and gas fields, the present invention adopts the rate of change of hydrogen isotopes as the qualitative judgment of the output fluid type.

[0058] S3: When the produced fluid is a mixture of formation water and external water, the concentrations of several characteristic ions in the formation water, external water, and produced fluid are obtained;

[0059] Specifically, the characteristic ions include at least two of bicarbonate, chloride, sulfate, calcium, magnesium, barium, strontium, potassium, sodium, boron, lithium, and bromide. When comparing the concentrations of the characteristic ions in the formation water, external water, and produced fluid, ions with a concentration change rate greater than a preset second threshold are selected for quantitative calculation to quantitatively evaluate the type of the produced fluid. The second threshold can be 10%. That is, when the concentration change rate is greater than 10%, it is considered that the concentration change of the ion is significant, and the concentration of the ion is then used to quantitatively evaluate the type of the produced fluid. The concentration of the characteristic ions can be analyzed using plasma emission spectroscopy or other methods.

[0060] Here, the concentration change rate is the ratio of the difference between the concentration value of a certain characteristic ion in the produced fluid and the concentration value of a certain characteristic ion in the formation water or external water to the concentration value of a certain characteristic ion in the formation water or external water;

[0061] S4: Determine the volume proportion of formation water and external water in the produced fluid by measuring the concentrations of several characteristic ions in the formation water, external water and produced fluid, quantitatively evaluate the type of the produced fluid, and complete the evaluation process of the gas well produced fluid type.

[0062] In the quantitative evaluation process of this step, specifically:

[0063]

[0064] V2%=1-V1%

[0065] Where V1% is the volume percentage of formation water in the produced fluid;

[0066] V2% is the volume percentage of external water in the produced fluid;

[0067] ρ1 is the concentration of characteristic ions in formation water;

[0068] ρ2 is the concentration of characteristic ions in external water;

[0069] ρ3 is the concentration of characteristic ions in the produced fluid.

[0070] The present invention effectively solves the needs of researchers in oil and gas reservoir development. It aims to solve the problem that the chloride ion content cannot accurately and effectively determine the source of gas well output fluid. 2 The contents of H and trace elements such as barium, strontium, boron, lithium, and bromine are relatively stable during the drilling, completion, construction, and production of gas wells, with almost no ion exchange. By comparing the stable isotope δ 2 The value of H and the contents of trace elements such as barium, strontium, boron, lithium, and bromine can be used to effectively, accurately, and timely determine the type and source of gas well production fluid, providing a basis for formulating the next development strategy.

[0071] In addition, if Figure 2 As shown, the present invention also discloses a gas well production fluid type evaluation system, comprising:

[0072] a first data acquisition unit, configured to acquire isotope values ​​of hydrogen in formation water, external water, and produced fluid;

[0073] a first data processing unit, configured to compare the hydrogen isotope value in the produced fluid with the hydrogen isotope values ​​in formation water and external water, and to perform a qualitative evaluation on the type of the produced fluid;

[0074] a second data acquisition unit, configured to acquire concentrations of several characteristic ions in the formation water, the external water, and the produced fluid when the produced fluid is a mixture of formation water and external water;

[0075] The second data processing unit is used to determine the volume proportion of formation water and external water in the production fluid through the concentration of several characteristic ions in the formation water, external water and production fluid, quantitatively evaluate the type of the production fluid, and complete the evaluation process of the gas well production fluid type.

[0076] Example 2

[0077] A method for evaluating the type of produced fluid from a gas well comprises the following steps:

[0078] S1: Take well water samples from the entire area to identify formation water as pure formation water samples, and analyze and detect them by mass spectrometry to obtain the stable isotope value of hydrogen, including protium (1H), deuterium (2H), tritium (3H) or one of the three;

[0079] S1: Take external water samples (surface water or reconstituted fluid) from the entire area and analyze them using a mass spectrometer to obtain the stable isotope value of hydrogen (protium (1H), deuterium (2H), tritium (3H) or one of the three);

[0080] S3: The gas well production fluid is analyzed by mass spectrometry to obtain the stable isotope value of hydrogen (protium (1H), deuterium (2H), tritium (3H) or one of the three). The corresponding stable isotope value of hydrogen is compared with the above-mentioned formation water, external water or reforming fluid value. Usually, the reforming fluid is obtained by mixing with surface water, so it is considered to be close to surface water. This produced fluid is the reforming fluid. The test results are shown in Figure 3 ;

[0081] S4: Take well water samples from the entire area to identify formation water as pure formation water samples and analyze them using plasma emission spectrometry or other methods to obtain the average ion concentration of trace elements such as barium, strontium, boron, lithium, and bromine in the formation water. This can provide the more stable trace elements in the area and the elements with a larger variation range, such as Figure 4 As shown;

[0082] S5: Take samples of external water (surface water or reconstructed fluid) from the entire area and analyze them using plasma emission spectrometry or other methods to obtain the theoretical average ion concentrations of trace elements such as barium, strontium, boron, lithium, and bromine in the external water or reconstructed fluid;

[0083] S6: Analyze the gas well produced fluid using plasma emission spectrometry or other methods to obtain the ion concentrations of trace elements such as barium, strontium, boron, lithium, and bromine. The ion concentrations of trace elements such as strontium and bromine vary very little, and ion exchange is not easy to occur. Therefore, the concentrations of two or more ions such as strontium and bromine in the corresponding produced fluid that are not easy to exchange are compared with the corresponding ion concentrations in the above-mentioned formation water and external water. If the values ​​are close to those of formation water, it means that the proportion of formation water in the produced fluid is high, and vice versa. This comparison can be used to further determine the type of produced fluid.

[0084] S7: If the gas well production fluid type has characteristics such as formation water and reforming fluid, here, the changes in potassium ions and sodium ions are the largest, then the concentrations of elemental ions such as sodium and potassium in the standard formation water sample and the theoretical ion concentrations of elemental ions such as sodium and potassium in the production fluid sample, standard formation water or reforming fluid are measured. Through the changes in potassium and sodium ion concentrations, the volume ratio of industrial liquid mixed liquid 2 to mixed liquid 1 is calculated using formula (1), that is, formula (2). Then, the volume of mixed liquid 3 is equal to the sum of the volumes of mixed liquid 1 and mixed liquid 2, that is, formula (3). Set mixed liquid 3 as unit volume, use formula (4) to calculate the volume percentage of mixed liquid 1 in the production fluid, and then use formula (5) to obtain the volume percentage of mixed liquid 2 in the production fluid, and the volume proportion of each liquid mixed in the production fluid can be obtained.

[0085]

[0086]

[0087] V3=V1+V2 (3)

[0088]

[0089] V2%=1-V1% (5) In the above formula, ρ1: the concentration of potassium or sodium ions mixed in the produced fluid, mg / L, that is, the concentration of characteristic ions in the formation water mixed in the produced fluid;

[0090] ρ2: The concentration of potassium or sodium ions in the produced fluid, mg / L, i.e., the concentration of characteristic ions in the external water mixed in the produced fluid;

[0091] ρ3: The concentration of potassium ions or sodium ions in the produced fluid, mg / L, the concentration of characteristic ions in the produced fluid.

[0092] V1: The theoretical unit volume of liquid 1 mixed in the produced fluid, L, that is, the volume of formation water mixed in the produced fluid;

[0093] V2: The theoretical unit volume of liquid 2 mixed in the produced fluid, L, that is, the volume of external water mixed in the produced fluid;

[0094] V3: volume of produced fluid, L;

[0095] V1%: The theoretical volume percentage of liquid 1 mixed in the produced fluid, i.e., the volume percentage of formation water in the produced fluid;

[0096] V2%: The theoretical volume percentage of liquid 2 mixed in the produced fluid, that is, the volume percentage of external water in the produced fluid.

[0097] Example 3

[0098] In order to further explain the technical solution of the present invention, the following examples are used for illustration:

[0099] Gas reservoir A has Well A1. After sand fracturing, a 6mm oil nozzle was used for oil test. The daily gas production was 250,000 cubic meters, the daily liquid production was 6 cubic meters, and the chloride ion was 161,446 mg / L. The type of produced fluid could not be accurately determined, and it was even suspected to be formation water.

[0100] The average chloride content of formation water in this area is 100,000 to 120,000 mg / L, the chloride content of brine is 160,000 mg / L, the hydrogen isotope value of formation water is about -50‰, and the hydrogen isotope value of external water (surface water) is about -65‰.

[0101] Step 1: Compare the chloride values ​​and find that chloride can no longer determine the type of fluid produced by the well.

[0102] Step 2: Take water samples and perform hydrogen isotope detection. Take samples at the same location every 1 hour for 3 consecutive times to obtain the hydrogen isotope δ 2 The values ​​of H are -65.75‰

[0103] , -66.69‰, -66.34‰ (e.g. Figure 5 As shown), the hydrogen isotope δ 2 The value of H is almost consistent with that of surface water, from which it can be inferred that the produced fluid is reformed fluid (the reformed fluid is obtained by mixing surface water).

[0104] Example 4

[0105] In order to further explain the technical solution of the present invention, the following examples are used for illustration:

[0106] Well B1 in gas reservoir B was put into production after a sand fracturing and oil testing. During the oil testing period, the cumulative flowback rate reached 100%. One month after the start of production, the liquid production rate increased, indicating the suspicion of formation water breakthrough.

[0107] The average chloride concentration in the formation water in this area is 100,000-130,000 mg / L, with a hydrogen isotope value of approximately -50‰ and a surface water hydrogen isotope value of approximately -65‰. The average strontium ion concentration in the formation water is 292 mg / L, the average bromide ion concentration is 52 mg / L, and the average sodium ion concentration is 60,070 mg / L. The theoretical chloride concentration of the reformed solution is 32,046 mg / L, and the theoretical sodium ion concentration is 20,730 mg / L.

[0108] Step 1: A comprehensive analysis of the formation water samples identified in the area revealed that the more stable trace elements in the area are strontium, boron, bromine, etc., while the elements with the largest variation range are potassium and sodium ions.

[0109] Step 2: Take output liquid samples at the same location once every 1 hour for 3 consecutive times, and perform water sample component analysis and hydrogen isotope detection.

[0110] Step 3: Organize the test results and first compare the chloride ion concentration with the concentrations of elemental ions such as potassium and sodium. As shown in Table 1 below, it is found through the chloride and sodium ion concentrations that the concentrations of the produced fluid and the reformed fluid are quite different.

[0111] Table 1 Concentrations of chloride ions, bicarbonate ions, sulfate ions, and sodium ions in the tertiary output liquids of Example 4

[0112]

[0113] Step 4: The trace element test results were statistically collated and compared with Table 2. It was found that the concentrations of trace element ions such as strontium and bromine in the produced fluid and formation water were similar, and there was a downward trend, showing a characteristic of being close to that of formation water and gradually diluted.

[0114] Table 2 Concentration of trace elements in the three output liquids in this embodiment

[0115]

[0116] Step 5: Calculate the mixing ratio based on the change in sodium ion concentration.

[0117]

[0118]

[0119]

[0120] V2%=1-V1%=18.01%

[0121] Through calculation, the formation water accounts for 81.99% of the produced fluid and the reforming fluid accounts for 18.01%.

[0122] In addition, a schematic diagram of a terminal device is provided in one embodiment of the present invention. The terminal device in this embodiment includes: a processor, a memory, and a computer program stored in the memory and executable on the processor. When the processor executes the computer program, the steps of each of the aforementioned method embodiments are implemented. Alternatively, when the processor executes the computer program, the functions of each module / unit in each of the aforementioned device embodiments are implemented.

[0123] The computer program may be divided into one or more modules / units, which are stored in the memory and executed by the processor to accomplish the present invention.

[0124] The terminal device may be a computing device such as a desktop computer, a notebook computer, a PDA, a cloud server, etc. The terminal device may include, but is not limited to, a processor and a memory.

[0125] The processor may be a central processing unit (CPU), or other general-purpose processors, digital signal processors (DSP), application-specific integrated circuits (ASIC), field-programmable gate arrays (FPGA) or other programmable logic devices, discrete gate or transistor logic devices, discrete hardware components, etc.

[0126] The memory may be used to store the computer programs and / or modules, and the processor implements various functions of the terminal device by running or executing the computer programs and / or modules stored in the memory and calling the data stored in the memory.

[0127] If the module / unit integrated in the terminal device is implemented in the form of 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 present invention implements all or part of the process in the above-mentioned embodiment method, and can also be completed by a computer program to instruct the relevant hardware. The computer program can be stored in a computer-readable storage medium. When the computer program is executed by a processor, it can implement the steps of each of the above-mentioned method embodiments. The computer program includes computer program code, which can be in source code form, object code form, executable file or some intermediate form. The computer-readable medium can include: any entity or device capable of carrying the computer program code, recording medium, USB flash drive, mobile hard disk, magnetic disk, optical disk, computer memory, read-only memory (ROM), random access memory (RAM), electric carrier signal, telecommunication signal and software distribution medium. It should be noted that the content contained in the computer-readable medium can be appropriately increased or decreased according to the requirements of legislation and patent practice in the jurisdiction. For example, in some jurisdictions, according to legislation and patent practice, computer-readable media does not include electric carrier signals and telecommunication signals.

[0128] The above are merely preferred embodiments of the present invention and are not intended to limit the present invention. Those skilled in the art will readily appreciate that various modifications and variations of the present invention are possible. Any modifications, equivalent substitutions, or improvements made within the spirit and principles of the present invention shall be included within the scope of protection of the present invention.

Claims

1. A method for evaluating the type of gas well produced fluid, characterized in that: The following steps are involved: S1: Obtain the isotope values ​​of hydrogen in formation water, external water and produced fluid; S2: comparing the hydrogen isotope value in the produced fluid with the hydrogen isotope values ​​in formation water and external water to qualitatively evaluate the type of the produced fluid; S3: When the produced fluid is a mixture of formation water and external water, the concentrations of several characteristic ions in the formation water, external water, and produced fluid are obtained; S4: Determine the volume proportion of formation water and external water in the produced fluid by measuring the concentrations of several characteristic ions in the formation water, external water and produced fluid, quantitatively evaluate the type of the produced fluid, and complete the evaluation process of the gas well produced fluid type.

2. The method for evaluating the type of gas well produced fluid according to claim 1, wherein: The isotope of hydrogen includes at least one of protium, deuterium and tritium.

3. The method for evaluating the type of gas well produced fluid according to claim 1, wherein: Step S2 is specifically as follows: If the absolute value of the difference between the hydrogen isotope value in the produced fluid and the hydrogen isotope value in the formation water is not greater than a preset first threshold, the produced fluid is formation water; If the absolute value of the difference between the hydrogen isotope value in the produced liquid and the hydrogen isotope value in the external water is not greater than a preset first threshold value, the produced liquid is external water; If the absolute value of the difference between the hydrogen isotope value in the produced fluid and the hydrogen isotope value in the formation water is greater than the preset first threshold, and the absolute value of the difference between the hydrogen isotope value in the produced fluid and the hydrogen isotope value in the external water is greater than the preset first threshold, then the produced fluid is a mixture of formation water and external water.

4. The method for evaluating the type of gas well produced fluid according to claim 1, wherein: In step S3, the characteristic ions include at least two of bicarbonate, chloride, sulfate, calcium, magnesium, barium, strontium, potassium, sodium, boron, lithium, and bromide.

5. The method for evaluating the type of gas well produced fluid according to claim 1, wherein: In step S3, when comparing the concentrations of several characteristic ions in the formation water, external water and produced fluid, ions with a concentration change rate greater than a preset second threshold are selected for quantitative calculation to quantitatively evaluate the type of produced fluid.

6. The method for evaluating the type of gas well produced fluid according to claim 1, characterized in that: When quantitatively evaluating the type of produced fluid, specifically: V2%=1-V1% Where V1% is the volume percentage of formation water in the produced fluid; V2% is the volume percentage of external water in the produced fluid; ρ1 is the concentration of characteristic ions in formation water; ρ2 is the concentration of characteristic ions in external water; ρ3 is the concentration of characteristic ions in the produced fluid.

7. A gas well production fluid type evaluation system, characterized in that: include: a first data acquisition unit, configured to acquire isotope values ​​of hydrogen in formation water, external water, and produced fluid; a first data processing unit, configured to compare the hydrogen isotope value in the produced fluid with the hydrogen isotope values ​​in formation water and external water, and to perform a qualitative evaluation on the type of the produced fluid; a second data acquisition unit, configured to acquire concentrations of several characteristic ions in the formation water, the external water, and the produced fluid when the produced fluid is a mixture of formation water and external water; The second data processing unit is used to determine the volume proportion of formation water and external water in the production fluid through the concentration of several characteristic ions in the formation water, external water and production fluid, quantitatively evaluate the type of the production fluid, and complete the evaluation process of the gas well production fluid type.

8. A computer device / apparatus / system comprising a memory, a processor, and a computer program stored in the memory, characterized in that: The processor executes the computer program to implement the steps of the method according to any one of claims 1 to 6.

9. A computer-readable storage medium storing a computer program, characterized in that: When the computer program / instructions are executed by a processor, the steps of the method according to any one of claims 1 to 6 are implemented.

10. A computer program product comprising a computer program / instructions, characterized in that When the computer program / instruction is executed by a processor, the steps of the method according to any one of claims 1 to 6 are implemented.

Images