A method, storage medium and electronic device for determining the amount of liquid sulfur precipitation

Abstract

The present invention discloses a method, a storage medium and an electronic device for determining the amount of liquid sulfur precipitation. The first abscissa of the end point of the first horizontal section and the second abscissa of the end point of the second horizontal section are obtained according to the shut-in recovery test pressure derivative curve of the commingled production reservoir; according to the first abscissa, the radius of the commingled production wellbore and the pressure conduction coefficient of the sulfur deposition reservoir, the minimum range of the outer boundary of the liquid sulfur precipitation area is determined; according to the first abscissa, the second abscissa, the minimum range, the pressure conduction coefficient of the sulfur deposition reservoir and the pressure conduction coefficient of the reservoir without sulfur deposition, the equivalent range of the outer boundary of the liquid sulfur precipitation area is determined; according to the equivalent range, the wellbore radius r w and the thickness of the commingled production reservoir, the spatial volume of the commingled production reservoir is determined; according to the spatial volume and the porosity change value of the commingled production reservoir, the amount of liquid sulfur precipitation in the commingled production reservoir is determined. This method is more in line with the actual situation and more accurate compared with the method that only uses numerical simulation.

Description

Technical Field

[0001] The invention relates to the technical field of high-sulfur gas reservoir exploration and development, and relates to a method, a storage medium and an electronic device for determining the amount of liquid sulfur precipitation. Background Art

[0002] The northeastern Sichuan region of the Sichuan Basin in my country is rich in resources. For example, the Puguang of the Feixianguan Formation and the Yuanba of the Changxing Formation are both high-temperature, high-pressure, and high-sulfur gas reservoirs. However, during the exploitation of gas from high-sulfur gas reservoirs, as the gas is produced, the formation pressure continues to drop, and elemental sulfur will precipitate from the sulfur-containing acid gas in the form of monomers.

[0003] At present, a laboratory has confirmed for the first time that liquid sulfur precipitates during the development of Yuanba's high-temperature, high-pressure, and high-sulfur gas reservoirs, and has determined that the conditions for liquid sulfur precipitation in Yuanba's reservoirs are 150°C and 24.8MPa. The Puguang gas field currently uses a thick-layer combined production method, but due to the difference in vertical physical properties between layers and the uneven advancement of edge and bottom water, some production gas wells have also seen and produced water, resulting in a significant decrease in bottom hole production pressure. It can be seen that when the reservoir pressure of a high-temperature, high-pressure, and high-sulfur gas reservoir is reduced to the critical conditions for liquid sulfur precipitation (150°C, 24.8MPa), it will cause the precipitation of acid gas and liquid sulfur in the reservoir, changes in the reservoir porosity and permeability structure, and a decrease in gas well production capacity.

[0004] It can be seen that in the actual production process, the occurrence of sulfur deposition in the commingled reservoir will affect the reduction of natural gas production. However, there is no specific method in the prior art to determine the amount of liquid sulfur precipitation in the commingled reservoir based on the unstable data of the bottom hole pressure change of the gas well in the commingled reservoir. Summary of the invention

[0005] In order to solve the above technical problems, the present invention provides a method for determining the amount of liquid sulfur precipitation, comprising the following steps:

[0006] Obtain the first horizontal coordinate T of the end point of the first horizontal section according to the shut-in recovery test pressure derivative curve of the combined production reservoir c and the second horizontal coordinate T of the end point of the second horizontal segment b , wherein the commingled production reservoir includes a sulfur deposition reservoir and a non-sulfur deposition reservoir;

[0007] According to the first horizontal coordinate T c , joint production wellbore radius r w and the pressure conductivity coefficient η′ of the sulfur deposition reservoir, determine the minimum range r of the outer boundary of the liquid sulfur precipitation area of ​​the commingled reservoir min ;

[0008] According to the first horizontal coordinate T c The second horizontal coordinate T b , the minimum range r min, the pressure conductivity coefficient η′ of the sulfur deposition reservoir and the pressure conductivity coefficient η of the non-sulfur deposition reservoir, and determine the equivalent range r of the outer boundary of the liquid sulfur precipitation area of ​​the commingled reservoir equ ;

[0009] According to the equivalent range r equ , the wellbore radius r w and the thickness h of the commingled reservoir, determine the spatial volume V of the commingled reservoir f ;

[0010] According to the space volume V f and the porosity change value Δφ of the commingled reservoir, determine the liquid sulfur precipitation amount V of the commingled reservoir s .

[0011] Furthermore, the above method for determining the amount of liquid sulfur precipitation also includes:

[0012] It is predicted whether there is liquid sulfur precipitation in the commingled production reservoir. When it is confirmed that there is liquid sulfur precipitation in the commingled production reservoir, the first horizontal coordinate T of the end point of the first horizontal section is obtained according to the shut-in recovery test pressure derivative curve of the commingled production reservoir. c and the second horizontal coordinate T of the end point of the second horizontal segment b ,

[0013] Among them, predicting whether there is liquid sulfur precipitation in the combined production reservoir includes:

[0014] Draw a shut-in recovery test pressure derivative curve of the commingled production reservoir according to bottom hole pressure change data of the gas wells in the commingled production reservoir;

[0015] Based on the comparison result of the shut-in recovery test pressure derivative curve and the composite model, predicting whether there is liquid sulfur precipitation in the commingled production reservoir;

[0016] When the shut-in recovery test pressure derivative curve has the characteristics of a composite model, it is confirmed that liquid sulfur precipitation exists in the combined production reservoir.

[0017] Furthermore, in the above method for determining the amount of liquid sulfur precipitation, the first horizontal coordinate T c , wellbore radius r w and the pressure conductivity coefficient η′ of the sulfur deposition reservoir, determine the minimum range r of the outer boundary of the liquid sulfur precipitation area of ​​the commingled reservoir min include:

[0018] Based on the first horizontal coordinate T c , the wellbore radius r w , the pressure conductivity coefficient η′ of the sulfur deposition reservoir, the minimum range r is determined according to the following expressionmin :

[0019] πr min 2 =πr w 2 +η′T c .

[0020] Furthermore, in the above method for determining the amount of liquid sulfur precipitation, the first horizontal coordinate T c The second horizontal coordinate T b , the minimum range r min , the pressure conductivity coefficient η′ of the sulfur deposition reservoir and the pressure conductivity coefficient η of the reservoir without sulfur deposition, and determine the equivalent range r of the outer boundary of the liquid sulfur precipitation area of ​​the commingled reservoir equ include:

[0021] Based on the first horizontal coordinate T c The second horizontal coordinate T b , the minimum range r min , the wellbore radius r w , the pressure conductivity coefficient η′ of the sulfur deposition reservoir, the pressure conductivity coefficient η of the non-sulfur deposition reservoir, and the equivalent range r is determined according to the following expression equ :

[0022] πr equ 2 =πr min 2 +ηT b -η′T c .

[0023] Furthermore, in the above method for determining the amount of liquid sulfur precipitation, the pressure conductivity coefficient η of the reservoir without sulfur deposition is determined according to the following expression:

[0024]

[0025] Wherein, k is the permeability of the commingled reservoir, μ is the fluid viscosity, φ is the porosity of the commingled reservoir, and c t is the comprehensive compression coefficient of the commingled reservoir;

[0026] And / or, based on the pressure conductivity coefficient η of the reservoir without sulfur deposition, the pressure conductivity coefficient η′ of the sulfur deposition reservoir is determined according to the following expression:

[0027]

[0028] Where M is the mobility ratio and D is the diffusion ratio.

[0029] Furthermore, the method for determining the amount of liquid sulfur precipitation further includes: obtaining a first ordinate L of the end point of the first horizontal section according to the shut-in recovery test pressure derivative curve of the co-production reservoir. c and the second ordinate L of the end point of the second horizontal segment b ;

[0030] The mobility ratio M is determined according to the following expression:

[0031]

[0032] Wherein, UL is the unit length of the ordinate of the shut-in recovery test pressure derivative curve, and DL is the unit length of the second ordinate L b and the first ordinate L c The difference obtained by subtracting is recorded as DL = L b -L c ;

[0033] And / or, the diffusion ratio D is determined according to the following expression:

[0034]

[0035] Among them, coefficients a and b are fitted by the mine empirical formula based on the porosity and permeability intersection diagram of the rock core in the actual target area. get.

[0036] Furthermore, in the above method for determining the amount of liquid sulfur precipitation, the equivalent range r equ , the wellbore radius r w , the thickness h of the commingled reservoir, and determine the spatial volume V of the commingled reservoir f include:

[0037] Based on the equivalent range r equ , the wellbore radius r w , the thickness h, and the spatial volume V are determined according to the following expression f :

[0038] V f =πh(r equ 2 -r w 2 ).

[0039] Furthermore, in the above method for determining the amount of liquid sulfur precipitation, the volume V of the space is f and the porosity change value Δφ of the commingled reservoir, determine the liquid sulfur precipitation amount V of the commingled reservoir s include:

[0040] The liquid sulfur precipitation amount V is determined according to the following expression s :

[0041] V s =V f Δφ,

[0042] The porosity change value Δφ is determined according to the following expression:

[0043] Δφ=φ(1-D).

[0044] The present invention also provides a storage medium, wherein the storage medium stores a program, and when the program is run, the steps of any of the above methods for determining the amount of liquid sulfur precipitation are executed.

[0045] The present invention also provides an electronic device, comprising a memory and a processor, wherein a computer program is stored in the memory, and when the processor executes the computer program, the steps of the method for determining the amount of liquid sulfur precipitation as described in any one of the above items can be implemented.

[0046] Compared with the prior art, one or more embodiments of the above scheme may have the following advantages or beneficial effects.

[0047] The method for determining the amount of liquid sulfur precipitation disclosed in the present invention obtains the minimum range of the liquid sulfur precipitation area of ​​the co-production reservoir based on the shut-in recovery test pressure derivative curve; further based on the above minimum range and taking into account the sulfur deposition reservoir and the non-sulfur deposition reservoir, obtains the equivalent range of the liquid sulfur precipitation area of ​​the co-production reservoir; based on the equivalent range and other existing parameters, obtains the spatial volume; based on the spatial volume and the porosity change value of the co-production reservoir, determines the amount of liquid sulfur precipitation in the co-production reservoir. This method obtains the shut-in recovery test pressure derivative curve based on unstable dynamic pressure data, and can obtain dynamic data in real time; determines the minimum range of the liquid sulfur precipitation area based on the shut-in recovery test pressure derivative curve, providing a basis for the subsequent design of the interpretation plan of the co-production reservoir; determines the equivalent range based on the minimum range and taking into account the sulfur deposition reservoir and the non-sulfur deposition layer, and further determines the amount of liquid sulfur precipitation based on the equivalent range. Compared with the method that is limited to the use of numerical simulation, this method is more in line with the actual situation, more accurate, does not require experiments, and avoids the professional requirements for experimental equipment and experimental personnel. The amount of liquid sulfur precipitation can be determined through simple and fast calculations, which is further helpful in judging the damage of sulfur deposition to the combined production reservoir and providing guidance for the subsequent evaluation of gas well capacity and adjustment of production system. BRIEF DESCRIPTION OF THE DRAWINGS

[0048] The scope of the present disclosure may be better understood by reading the following detailed description of exemplary embodiments in conjunction with the accompanying drawings. The drawings included are:

[0049] Figure 1A flow chart of a method for determining the amount of liquid sulfur precipitation provided in Example 1 of the present invention;

[0050] Figure 2 A flow chart of a method for determining the amount of liquid sulfur precipitation provided in Embodiment 2 of the present invention;

[0051] Figure 3 A flow chart of a method for determining the amount of liquid sulfur precipitation provided in Embodiment 3 of the present invention;

[0052] Figure 4 A flow chart of a method for predicting whether liquid sulfur precipitation occurs in a combined production reservoir provided in Embodiment 3 of the present invention;

[0053] Figure 5 It is a pressure derivative curve of shut-in recovery test in double logarithmic coordinates;

[0054] Figure 6 A structural diagram of an electronic device for determining the amount of liquid sulfur precipitation provided by an embodiment of the present invention. DETAILED DESCRIPTION

[0055] The following will describe the implementation methods of the present invention in detail with reference to the accompanying drawings and embodiments, so that the implementation process of how the present invention applies technical means to solve technical problems and achieve technical effects can be fully understood and implemented accordingly. It should be noted that as long as there is no conflict, the various embodiments of the present invention and the various features in the embodiments can be combined with each other, and the technical solutions formed are all within the protection scope of the present invention.

[0056] In existing high-sulfur gas reservoirs, due to the temperature and pressure conditions of the gas reservoir itself, the sulfur precipitated when the gas well pressure is reduced is in solid state, and the solid sulfur permanently retained in the rock pores will damage the reservoir. Therefore, the current research focuses on parameters such as reservoir porosity and permeability after damage, in order to facilitate the adjustment of subsequent gas well production systems. However, the fluidity of liquid sulfur is much greater than that of solid sulfur, so it is expected that the liquid sulfur can be carried and displaced out of the reservoir by adjusting the gas well production rate and taking reasonable injection and production measures. Based on this, determining the amount of liquid sulfur precipitation is of great significance to the design of gas well production rate and output, as well as the design of injection and production fluid parameters.

[0057] At present, the research and improvement directions for liquid sulfur precipitation in high-sulfur gas fields mainly include: providing a sulfur deposition device based on a magnetic suspension balance, simulating the high-temperature, high-pressure and high-sulfur environment of the real formation, improving the test accuracy of sulfur deposition, calculating the viscosity, volume coefficient and deviation factor of the gas in real time, and measuring the dynamic changes of core permeability caused by sulfur deposition online in real time; improving existing equipment, and providing a gas-liquid sulfur phase permeability test device and method that meets the actual production of high-sulfur gas reservoirs; innovating on the basis of existing experimental devices, proposing an experimental method for real-time online testing of sulfur solubility, using a fluorescent sulfur determination system to accurately determine the solubility of elemental sulfur in sulfur-containing gas samples, and using a high-temperature and high-pressure piston-type quantitative container to achieve real-time data collection; using a self-developed numerical simulator, the influence of liquid sulfur on gas well production is studied through numerical simulation methods; providing an experimental device for evaluating the damage of sulfur deposition to fractured reservoirs in high-sulfur gas reservoirs, simulating the high-temperature and high-pressure environment of the formation, and monitoring the flow of high-sulfur gas through fractured rock samples, which can The invention can quickly and accurately evaluate the degree of damage of sulfur deposition to fractured rock samples; in view of the technical deficiency that "the experimental data of sulfur solubility calculated by the widely used Roberts sulfur solubility model is the solubility of sulfur in hydrogen sulfide, not the solubility in acidic gas mixture", a method is proposed: "by establishing a relationship between sulfur deposition saturation and the dimensionless coefficient of permeability modulus and pressure function in stress sensitivity, the dynamic distribution of sulfur deposition in carbonate sulfur-containing gas reservoirs is obtained, and then the sulfur-containing gas reservoirs are mined according to the obtained dynamic distribution curve of sulfur deposition saturation"; through the test results of gas-liquid sulfur two-phase seepage in Puguang Gas Field, it is confirmed that the sulfur element precipitated in Puguang Gas Field under the current reservoir conditions is liquid; a sulfur deposition simulation test device for high-sulfur gas reservoirs is provided, and the sulfur deposition in the actual high-sulfur gas reservoir is simulated by the sulfur-containing gas tank and the corresponding control system of the device and the control of sulfur-containing gas passing through the core in the core holder; a measurement method for measuring the change of pore size distribution of sulfur deposition in the core after liquid sulfur displacement using a nuclear magnetic resonance instrument is proposed.

[0058] It can be seen that the current research on liquid sulfur precipitation in high-sulfur gas fields mostly uses experimental methods to determine the impact of liquid sulfur precipitation on reservoir porosity and permeability, and the experimental devices and experimental instruments used have strict requirements on the professional level and safe operation skills of the experimental personnel. In addition, the current research on liquid sulfur deposition in reservoirs is limited to using numerical simulation methods to explore the impact of liquid sulfur on the production of production wells, and there are few studies on the specific determination of the amount of liquid sulfur precipitation.

[0059] In view of this, the present invention provides a method for determining the amount of liquid sulfur precipitation, based on the shut-in recovery test pressure derivative curve, the minimum range of the liquid sulfur precipitation area of ​​the co-production reservoir is obtained; further based on the above minimum range and taking into account the sulfur deposition reservoir and the non-sulfur deposition reservoir, the equivalent range of the liquid sulfur precipitation area of ​​the co-production reservoir is obtained; based on the equivalent range and other existing parameters, the spatial volume is obtained; based on the spatial volume and the porosity change value of the co-production reservoir, the amount of liquid sulfur precipitation in the co-production reservoir is determined. This method obtains the shut-in recovery test pressure derivative curve based on unstable dynamic pressure data, and can obtain dynamic data in real time; based on the shut-in recovery test pressure derivative curve, the minimum range of the liquid sulfur precipitation area is determined, which provides a basis for the subsequent design of the interpretation plan of the co-production reservoir; based on the minimum range and taking into account the sulfur deposition reservoir and the non-sulfur deposition layer, the equivalent range is determined and the amount of liquid sulfur precipitation is further determined based on the equivalent range. Compared with the method that is limited to the use of numerical simulation, this method is more in line with the actual situation, more accurate, does not require experiments, and avoids the professional requirements for experimental equipment and experimental personnel. The amount of liquid sulfur precipitation can be determined through simple and fast calculations, which is further helpful in judging the damage of sulfur deposition to the combined production reservoir and providing guidance for the subsequent evaluation of gas well capacity and adjustment of production system.

[0060] Embodiment 1

[0061] In order to solve the above technical problems existing in the prior art, an embodiment of the present invention provides a method for determining the amount of liquid sulfur precipitation.

[0062] Figure 1 A flow chart of a method for determining the amount of liquid sulfur precipitation provided by an embodiment of the present invention. Figure 1 As shown, the method for determining the amount of liquid sulfur precipitation in this embodiment may include the following steps:

[0063] S110: Obtaining the first horizontal coordinate T of the end point of the first horizontal section according to the shut-in recovery test pressure derivative curve of the co-production reservoir c and the second horizontal coordinate T of the end point of the second horizontal segment b Among them, the combined production reservoir includes sulfur deposition reservoirs and non-sulfur deposition reservoirs.

[0064] In a specific implementation process, the shut-in recovery test pressure derivative curve can be established based on the bottom hole pressure change data of the gas well in the commingled production reservoir, and the shut-in recovery test pressure derivative curve comprehensively considers the unstable data of the bottom hole pressure at different times. When the shut-in recovery test pressure derivative curve appears to meet the model characteristics, it is confirmed that liquid sulfur precipitation exists in the commingled production reservoir.

[0065] Specifically, the above composite model features include that the shut-in recovery test pressure derivative curve has a first horizontal segment and a second horizontal segment. The horizontal segment represents the permeability. When a horizontal segment appears, it means that the permeability of the near-well area is inconsistent, which is called the plane mirror flow phenomenon. The difference between the first horizontal segment and the second horizontal segment is reflected in the different physical properties of the two. The higher the horizontal segment, the worse the physical properties.

[0066] S120: According to the first horizontal coordinate T c , joint production wellbore radius r w and the pressure conductivity coefficient η′ of the sulfur deposition reservoir to determine the minimum range r of the outer boundary of the liquid sulfur precipitation area of ​​the combined production reservoir min .

[0067] Among them, r w The unit is m, which refers to the wellbore radius of the gas well used to measure the shut-in recovery test pressure in the combined production reservoir; η' is in m 2 / s refers to the pressure conductivity coefficient of the sulfur deposition reservoir in the combined production reservoir.

[0068] In step S120, the minimum range may be determined using the following expression:

[0069] πr min 2 =πr w 2 +η′T c .

[0070] Based on the pressure derivative curve of the shut-in recovery test, the minimum range of the liquid sulfur precipitation area of ​​the combined production reservoir can be determined, and this minimum range can provide a basis for the subsequent design of the blockage removal plan for the combined production reservoir.

[0071] S130: According to the first horizontal coordinate T c , the second horizontal coordinate T b , minimum range r min , the pressure conductivity coefficient η′ of the sulfur deposition reservoir and the pressure conductivity coefficient η of the reservoir without sulfur deposition, and determine the equivalent range r of the outer boundary of the liquid sulfur precipitation area of ​​the combined production reservoir equ .

[0072] Among them, η is in m 2 / s refers to the pressure conductivity coefficient of the combined production reservoir where sulfur deposition has not occurred.

[0073] In step S130, the equivalent range may be determined using the following expression:

[0074] πr equ 2 =πr min 2 +ηT b -η′Tc .

[0075] S140: According to the equivalent range r equ , wellbore radius r w and the thickness h of the combined production reservoir to determine the spatial volume V of the combined production reservoir f .

[0076] Among them, h is in meters and refers to the reservoir thickness of the combined production reservoir.

[0077] In step S140, the spatial volume may be determined using the following expression:

[0078] V f =πh(r equ 2 -r w 2 ).

[0079] S150: According to the space volume V f and the porosity change value △φ of the combined production reservoir to determine the liquid sulfur precipitation amount V of the combined production reservoir s .

[0080] In step S150, the amount of liquid sulfur precipitation can be determined using the following expression:

[0081] V s =V f Δφ,

[0082] In a specific implementation process, the porosity change value △φ can be determined according to the following expression:

[0083] Δφ=φ(1-D).

[0084] Among them, △φ has no unit and refers to the porosity change value of the combined production reservoir after sulfur deposition occurs; D refers to the diffusion ratio, which can be obtained by conventional methods in the field in some embodiments; in other embodiments, it can also be obtained based on the mobility ratio and the coefficient obtained by fitting the mine empirical formula based on the porosity and permeability intersection diagram of the rock core taken from the actual target area. For details, please refer to the description in the following Example 2.

[0085] Based on this, the present invention provides a method for determining the amount of liquid sulfur precipitation, which obtains the minimum range of the liquid sulfur precipitation area of ​​the co-production reservoir based on the shut-in recovery test pressure derivative curve; further based on the above minimum range and taking into account the sulfur deposition reservoir and the non-sulfur deposition reservoir, the equivalent range of the liquid sulfur precipitation area of ​​the co-production reservoir is obtained; based on the equivalent range and other existing parameters, the spatial volume is obtained; based on the spatial volume and the porosity change value of the co-production reservoir, the amount of liquid sulfur precipitation in the co-production reservoir is determined. This method obtains the shut-in recovery test pressure derivative curve based on unstable dynamic pressure data, and can obtain dynamic data in real time; based on the shut-in recovery test pressure derivative curve, the minimum range of the liquid sulfur precipitation area is determined, which provides a basis for the subsequent design of the interpretation plan of the co-production reservoir; based on the minimum range and taking into account the sulfur deposition reservoir and the non-sulfur deposition layer, the equivalent range is determined and the amount of liquid sulfur precipitation is further determined based on the equivalent range. Compared with the method that is limited to the use of numerical simulation, this method is more in line with the actual situation, more accurate, does not require experiments, and avoids the professional requirements for experimental equipment and experimental personnel. The amount of liquid sulfur precipitation can be determined through simple and fast calculations, which is further helpful in judging the damage of sulfur deposition to the combined production reservoir and providing guidance for the subsequent evaluation of gas well capacity and adjustment of production system.

[0086] Embodiment 2

[0087] In order to solve the above technical problems existing in the prior art, a second embodiment of the present invention provides a method for determining the amount of liquid sulfur precipitation.

[0088] Figure 2 A flow chart of a method for determining the amount of liquid sulfur precipitation provided by an embodiment of the present invention. Figure 2 As shown, the method for determining the amount of liquid sulfur precipitation in this embodiment may include the following steps.

[0089] S210: Obtaining the first horizontal coordinate T of the end point of the first horizontal section according to the shut-in recovery test pressure derivative curve of the co-production reservoir c and the first ordinate L c and the second horizontal coordinate T of the end point of the second horizontal segment b and the second ordinate L b Among them, the combined production reservoir includes sulfur deposition reservoirs and non-sulfur deposition reservoirs.

[0090] In a specific implementation process, the shut-in recovery test pressure derivative curve can be established based on the bottom hole pressure change data of the gas well in the commingled production reservoir, and the shut-in recovery test pressure derivative curve comprehensively considers the unstable data of the bottom hole pressure at different times. When the shut-in recovery test pressure derivative curve appears to meet the model characteristics, it is confirmed that liquid sulfur precipitation exists in the commingled production reservoir.

[0091] Specifically, the above composite model features include that the shut-in recovery test pressure derivative curve has a first horizontal segment and a second horizontal segment. The horizontal segment represents the permeability. When a horizontal segment appears, it means that the permeability of the near-well area is inconsistent, which is called the plane mirror flow phenomenon. The difference between the first horizontal segment and the second horizontal segment is reflected in the different physical properties of the two. The higher the horizontal segment, the worse the physical properties.

[0092] S220: According to the first ordinate L c and the second ordinate L b The mobility ratio M is determined, and the diffusion ratio D is determined based on M. The pressure conductivity coefficient η′ of the sulfur deposition reservoir is further determined based on M, D and the pressure conductivity coefficient η of the reservoir without sulfur deposition.

[0093] In a specific implementation process, step S220 may be specifically as follows:

[0094] The mobility ratio M is determined according to the following expression:

[0095]

[0096] Among them, UL has no unit and refers to the unit length of the ordinate of the shut-in recovery test pressure derivative curve; DL has no unit and refers to the second ordinate L b and the first ordinate L c The difference obtained by subtracting is recorded as DL = L b -L c ;

[0097] The diffusion ratio D can be determined according to the following expression:

[0098]

[0099] Among them, coefficients a and b are fitted by the mine empirical formula based on the porosity and permeability intersection diagram of the rock core in the actual target area. get.

[0100] Specifically, in the above fitting process, the permeability data k under each porosity φ is plotted in a rectangular coordinate system, and the data points are fitted by the least square method according to the mine empirical formula. When the error between the drawn curve and the data point is the smallest, the fitting is completed. At this time, the coefficients a and b in the mine empirical formula can be obtained. The above process can be achieved using the "Add Trend Line to Data" function in Excel.

[0101] Specifically, the pressure conductivity coefficient η of the reservoir without sulfur deposition is determined according to the following expression:

[0102]

[0103] Among them, η is in m 2 / s, refers to the pressure conductivity coefficient of the commingled reservoir without sulfur deposition; k is in units of 10 -12 m 2 , refers to the permeability of the commingled reservoir; μ is in Pa·s and refers to the fluid viscosity; φ is a decimal and refers to the porosity of the commingled reservoir; c t The unit is 1 / Pa, which refers to the comprehensive compression coefficient of the combined production reservoir.

[0104] Specifically, based on the pressure conductivity η of the reservoir without sulfur deposition, the pressure conductivity η′ of the sulfur deposition reservoir is determined according to the following expression:

[0105]

[0106] Among them, η' is in m 2 / s refers to the pressure conductivity coefficient of the sulfur deposition reservoir in the combined production reservoir; M has no unit and refers to the mobility ratio; D has no unit and refers to the diffusion ratio.

[0107] S230: According to the first horizontal coordinate T c , joint production wellbore radius r w and the pressure conductivity coefficient η′ of the sulfur deposition reservoir to determine the minimum range r of the outer boundary of the liquid sulfur precipitation area of ​​the combined production reservoir min .

[0108] In a specific implementation process, based on the first horizontal coordinate T c , wellbore radius r w , the pressure conductivity coefficient η′ of the sulfur deposition reservoir is determined by the following expression: min :

[0109] πr min 2 =πr w 2 +η′T c .

[0110] Among them, r w The unit is m, which refers to the wellbore radius of the gas well in the combined production reservoir used to measure the shut-in recovery test pressure.

[0111] Based on this, the present invention utilizes the unstable data of the bottom hole pressure changes of the gas wells in the combined production reservoir to draw the shut-in recovery test pressure derivative curve of the combined production reservoir; based on the shut-in recovery test pressure derivative curve, the minimum range of the liquid sulfur precipitation area of ​​the combined production reservoir is obtained, and this minimum range can provide a basis for the subsequent design of the deblocking plan for the combined production reservoir.

[0112] S240: According to the first horizontal coordinate T c , the second horizontal coordinate T b , minimum range r min, the pressure conductivity coefficient η′ of the sulfur deposition reservoir and the pressure conductivity coefficient η of the reservoir without sulfur deposition, and determine the equivalent range r of the outer boundary of the liquid sulfur precipitation area of ​​the combined production reservoir equ .

[0113] In a specific implementation process, based on the first horizontal coordinate T c , the second horizontal coordinate T b , minimum range r min , wellbore radius r w , the pressure conductivity coefficient η′ of the sulfur deposition reservoir, the pressure conductivity coefficient η of the non-sulfur deposition reservoir, and the equivalent range r is determined according to the following expression equ :

[0114] πr equ 2 =πr min 2 +ηT b -η′T c .

[0115] S250: According to the equivalent range r equ , wellbore radius r w and the thickness h of the combined production reservoir to determine the spatial volume V of the combined production reservoir f .

[0116] In a specific implementation process, based on the equivalent range r equ , wellbore radius r w , thickness h, and determine the spatial volume V according to the following expression f :

[0117] V f =πh(r equ 2 -r w 2 ).

[0118] Among them, h is in meters and refers to the reservoir thickness of the combined production reservoir.

[0119] S260: According to the space volume V f and the porosity change value △φ of the combined production reservoir to determine the liquid sulfur precipitation amount V of the combined production reservoir s .

[0120] In a specific implementation process, the amount of liquid sulfur precipitation V is determined according to the following expression: s :

[0121] V s =V f Δφ.

[0122] Among them, △φ has no unit and refers to the porosity change of the combined production reservoir after sulfur deposition occurs.

[0123] Specifically, the porosity change value Δφ is determined according to the following expression:

[0124] Δφ=φ(1-D).

[0125] Based on this, the present invention provides a method for determining the amount of liquid sulfur precipitation, which obtains the minimum range of the liquid sulfur precipitation area of ​​the combined production reservoir based on the shut-in recovery test pressure derivative curve; further based on the above minimum range and taking into account the sulfur deposition reservoir and the non-sulfur deposition reservoir, the equivalent range of the liquid sulfur precipitation area of ​​the combined production reservoir is obtained; based on the equivalent range and other existing parameters, the spatial volume is obtained; based on the spatial volume and the porosity change value of the combined production reservoir, the amount of liquid sulfur precipitation in the combined production reservoir is determined. This method obtains the shut-in recovery test pressure derivative curve based on unstable dynamic pressure data, and can obtain dynamic data in real time; in this embodiment, the mobility ratio M, the diffusion ratio D, the pressure conductivity coefficient η of the non-sulfur deposition reservoir, and the pressure conductivity coefficient η′ of the sulfur deposition reservoir are also determined based on the dynamic data. Based on this, on the basis of being able to achieve the same beneficial effects as Example 1, this embodiment is further conducive to improving the accuracy of determining the precipitation amount. In addition, this embodiment determines the minimum range of the liquid sulfur precipitation area based on the shut-in recovery test pressure derivative curve, which provides a basis for the subsequent design of the interpretation plan for the combined production reservoir; based on the minimum range and taking into account the sulfur deposition reservoir and the non-sulfur deposition layer, the equivalent range is determined and the liquid sulfur precipitation amount is further determined based on the equivalent range. Compared with the method that is limited to the use of numerical simulation, this method is more in line with the actual situation, more accurate, does not require experiments, avoids professional requirements for experimental equipment and experimental personnel, and can determine the liquid sulfur precipitation amount through simple and fast calculations, which is further conducive to judging the damage of sulfur deposition to the combined production reservoir, and provides guidance for the subsequent evaluation of gas well capacity and adjustment of production system.

[0126] The above is a method for determining the amount of liquid sulfur precipitation provided by the second embodiment of the present invention. In addition, in the embodiment of the present invention, it is also possible to pre-judge whether liquid sulfur precipitation occurs before determining the amount of liquid sulfur precipitation. For details, please refer to the description of the following third embodiment.

[0127] Embodiment 3

[0128] In order to solve the above technical problems existing in the prior art, an embodiment of the present invention provides a method for determining the amount of liquid sulfur precipitation.

[0129] Figure 3 A flow chart of a method for determining the amount of liquid sulfur precipitation provided by an embodiment of the present invention. Figure 3As shown, the method for determining the amount of liquid sulfur precipitation in this embodiment may include the following steps:

[0130] S310: Predict whether liquid sulfur precipitation occurs in the combined production reservoir.

[0131] Among them, the combined production reservoir may include sulfur deposition reservoirs and non-sulfur deposition reservoirs.

[0132] See also Figure 4 , Figure 4 A flow chart for predicting whether liquid sulfur precipitation occurs in a combined production reservoir provided by an embodiment of the present invention is shown, which includes:

[0133] S311: Draw a shut-in recovery test pressure derivative curve of the commingled production reservoir based on the bottom hole pressure change data of the gas wells in the commingled production reservoir.

[0134] Specifically, step S311 includes the following steps:

[0135] Place a pressure gauge at the bottom of a gas well in the combined production reservoir, close the gas well, and record the time at this time as the initial time t 0 , the bottom hole pressure at this time is the initial pressure p 0 ;

[0136] At time t j Measure the bottom hole pressure p of the target well j ;

[0137] Set the time t j With the initial time t 0 Subtract the shut-in time △t of the target well. j =t j -t 0 ;

[0138] The bottom hole pressure p j With initial pressure p 0 Subtract the shut-in recovery test pressure △p of the target well. j =p j -p 0 ;

[0139] The shut-in recovery test pressure derivative △p'·△t of the target well is obtained by using the three-point derivation method;

[0140] The shut-in recovery test pressure curve and the shut-in recovery test pressure derivative curve are plotted in a double logarithmic coordinate system.

[0141] The horizontal axis of the double logarithmic coordinate system is time, and the vertical axis is the shut-in recovery test pressure curve and the shut-in recovery test pressure derivative curve.

[0142] Among them, the shut-in recovery test pressure curve represents the relationship between the shut-in time △t and the shut-in recovery test pressure △p, recorded as △p(△t); the shut-in recovery test pressure derivative curve represents the relationship between the shut-in time △t and the shut-in recovery test pressure derivative △p'·△t, recorded as △p'·△t(△t).

[0143] Figure 5 The shut-in recovery test pressure derivative curve in double logarithmic coordinates drawn according to the above steps is shown.

[0144] S312: Based on the comparison results of the shut-in recovery test pressure derivative curve and the composite model, predict whether liquid sulfur precipitation occurs in the combined production reservoir.

[0145] Specifically, the composite model feature includes a shut-in recovery test pressure derivative curve having a first horizontal segment and a second horizontal segment.

[0146] Specifically, the horizontal segment represents the permeability. When a horizontal segment appears, it means that the permeability of the near-wellbore area is inconsistent, which is called the plane mirror flow phenomenon. The difference between the first horizontal segment and the second horizontal segment is reflected in the different physical properties of the two. The higher the horizontal segment, the worse the physical properties.

[0147] S313: When the shut-in recovery test pressure derivative curve has the characteristics of a composite model, it is confirmed that liquid sulfur precipitation exists in the combined production reservoir.

[0148] S320: When it is confirmed that liquid sulfur precipitation exists in the commingled production reservoir, the first horizontal coordinate T of the end point of the first horizontal section is obtained according to the shut-in recovery test pressure derivative curve of the commingled production reservoir. c and the second horizontal coordinate T of the end point of the second horizontal segment b .

[0149] S330: According to the first horizontal coordinate T c , joint production wellbore radius r w and the pressure conductivity coefficient η′ of the sulfur deposition reservoir to determine the minimum range r of the outer boundary of the liquid sulfur precipitation area of ​​the combined production reservoir min .

[0150] In a specific implementation process, based on the first horizontal coordinate T c , wellbore radius r w , the pressure conductivity coefficient η′ of the sulfur deposition reservoir is determined by the following expression: min :

[0151] πr min 2 =πr w 2 +η′T c .

[0152] Among them, rw The unit is m, which refers to the wellbore radius of the gas well used to measure the shut-in recovery test pressure in the combined production reservoir; η' is in m 2 / s refers to the pressure conductivity coefficient of the sulfur deposition reservoir in the combined production reservoir.

[0153] Based on this, the present invention utilizes the unstable data of the bottom hole pressure changes of the gas wells in the combined production reservoir to draw the shut-in recovery test pressure derivative curve of the combined production reservoir; based on the shut-in recovery test pressure derivative curve, the minimum range of the liquid sulfur precipitation area of ​​the combined production reservoir is obtained, and this minimum range can provide a basis for the subsequent design of the deblocking plan for the combined production reservoir.

[0154] S340: According to the first horizontal coordinate T c , the second horizontal coordinate T b , minimum range r min , the pressure conductivity coefficient η′ of the sulfur deposition reservoir and the pressure conductivity coefficient η of the reservoir without sulfur deposition, and determine the equivalent range r of the outer boundary of the liquid sulfur precipitation area of ​​the combined production reservoir equ .

[0155] In a specific implementation process, based on the first horizontal coordinate T c , the second horizontal coordinate T b , minimum range r min , wellbore radius r w , the pressure conductivity coefficient η′ of the sulfur deposition reservoir, the pressure conductivity coefficient η of the non-sulfur deposition reservoir, and the equivalent range r is determined according to the following expression equ :

[0156] πr equ 2 =πr min 2 +ηT b -η′T c .

[0157] Among them, η is in m 2 / s refers to the pressure conductivity coefficient of the combined production reservoir where sulfur deposition has not occurred.

[0158] Specifically, the pressure conductivity coefficient η of the reservoir without sulfur deposition is determined according to the following expression:

[0159]

[0160] Among them, k unit is 10 -12 m 2 , refers to the permeability of the commingled reservoir; μ is in Pa·s and refers to the fluid viscosity; φ is a decimal and refers to the porosity of the commingled reservoir; c t The unit is 1 / Pa, which refers to the comprehensive compression coefficient of the combined production reservoir.

[0161] Specifically, based on the pressure conductivity η of the reservoir without sulfur deposition, the pressure conductivity η′ of the sulfur deposition reservoir is determined according to the following expression:

[0162]

[0163] Among them, M has no unit and refers to the mobility ratio; D has no unit and refers to the diffusion ratio.

[0164] In a specific implementation process, step S340 also includes obtaining the first ordinate L of the end point of the first horizontal section according to the shut-in recovery test pressure derivative curve of the co-production reservoir. c and the second ordinate L of the end point of the second horizontal segment b .

[0165] Specifically, the mobility ratio M is determined according to the following expression:

[0166]

[0167] Among them, UL has no unit and refers to the unit length of the ordinate of the shut-in recovery test pressure derivative curve; DL has no unit and refers to the second ordinate L b and the first ordinate L c The difference obtained by subtracting is recorded as DL = L b -L c .

[0168] Specifically, the diffusion ratio D is determined according to the following expression:

[0169]

[0170] Among them, coefficients a and b are fitted by the mine empirical formula based on the porosity and permeability intersection diagram of the rock core in the actual target area. get.

[0171] Specifically, in the above fitting process, the permeability data k under each porosity φ is plotted in a rectangular coordinate system, and the data points are fitted by the least square method according to the mine empirical formula. When the error between the drawn curve and the data point is the smallest, the fitting is completed. At this time, the coefficients a and b in the mine empirical formula can be obtained. The above process can be achieved using the "Add Trend Line to Data" function in Excel.

[0172] S350: According to the equivalent range r equ , wellbore radius r w and the thickness h of the combined production reservoir to determine the spatial volume V of the combined production reservoir f .

[0173] In a specific implementation process, based on the equivalent range r equ, wellbore radius r w , thickness h, and determine the spatial volume V according to the following expression f :

[0174] V f =πh(r equ 2 -r w 2 ).

[0175] Among them, h is in meters and refers to the reservoir thickness of the combined production reservoir.

[0176] S360: According to the space volume V f and the porosity change value △φ of the combined production reservoir to determine the liquid sulfur precipitation amount V of the combined production reservoir s .

[0177] In a specific implementation process, the amount of liquid sulfur precipitation V is determined according to the following expression: s :

[0178] V s =V f Δφ.

[0179] Among them, △φ has no unit and refers to the porosity change of the combined production reservoir after sulfur deposition occurs.

[0180] Specifically, the porosity change value Δφ is determined according to the following expression:

[0181] Δφ=φ(1-D).

[0182] Based on this, the present invention provides a method for determining the amount of liquid sulfur precipitation, which uses unstable data of bottom hole pressure changes of gas wells in a combined production reservoir to draw a shut-in recovery test pressure derivative curve of the combined production reservoir; based on the shut-in recovery test pressure derivative curve, the minimum range of the liquid sulfur precipitation area of ​​the combined production reservoir is obtained; further based on the above minimum range and taking into account the sulfur deposition reservoir and the non-sulfur deposition reservoir, the equivalent range of the liquid sulfur precipitation area of ​​the combined production reservoir is obtained; based on the equivalent range and other existing parameters, the spatial volume is obtained; based on the spatial volume and the porosity change value of the combined production reservoir, the amount of liquid sulfur precipitation of the combined production reservoir is determined. This method obtains a shut-in recovery test pressure derivative curve based on unstable dynamic pressure data, and dynamic data can be obtained in real time; based on the shut-in recovery test pressure derivative curve, the minimum range of the liquid sulfur precipitation area is determined, which provides a basis for the subsequent design of the interpretation plan of the combined production reservoir; based on the minimum range and taking into account the sulfur deposition reservoir and the non-sulfur deposition layer, the equivalent range is determined and the liquid sulfur precipitation amount is further determined based on the equivalent range. Compared with the method that is limited to the use of numerical simulation, this method is more in line with the actual situation, more accurate, does not require experiments, and avoids the professional requirements for experimental equipment and experimental personnel. The amount of liquid sulfur precipitation can be determined through simple and fast calculations, which is further helpful in judging the damage of sulfur deposition to the combined production reservoir and providing guidance for the subsequent evaluation of gas well capacity and adjustment of production system.

[0183] Embodiment 4

[0184] This embodiment provides a storage medium, which stores a computer program. When the storage medium is executed by one or more processors, the method for determining the amount of liquid sulfur precipitation in any one of Embodiments 1 to 3 is implemented.

[0185] The above-mentioned storage media can be flash memory, hard disk, multimedia card, card-type memory (for example, SD or DX memory, etc.), random access memory (RAM), static random access memory (SRAM), read-only memory (ROM), electrically erasable programmable read-only memory (EEPROM), programmable read-only memory (PROM), magnetic memory, disk, CD, server, App application store, etc.

[0186] When the computer program stored in the storage medium is executed by a processor, the following method steps can be implemented:

[0187] Obtain the first horizontal coordinate T of the end point of the first horizontal section according to the shut-in recovery test pressure derivative curve of the combined production reservoir c and the second horizontal coordinate T of the end point of the second horizontal segment b ;

[0188] According to the first horizontal coordinate T c , joint production wellbore radius rw and the pressure conductivity coefficient η′ of the sulfur deposition reservoir to determine the minimum range r of the outer boundary of the liquid sulfur precipitation area of ​​the combined production reservoir min ;

[0189] According to the first horizontal coordinate T c , the second horizontal coordinate T b , minimum range r min , the pressure conductivity coefficient η′ of the sulfur deposition reservoir and the pressure conductivity coefficient η of the reservoir without sulfur deposition, and determine the equivalent range r of the outer boundary of the liquid sulfur precipitation area of ​​the combined production reservoir equ ;

[0190] According to the equivalent range r equ , wellbore radius r w and the thickness h of the combined production reservoir to determine the spatial volume V of the combined production reservoir f ;

[0191] According to the space volume V f and the porosity change value △φ of the combined production reservoir to determine the liquid sulfur precipitation amount V of the combined production reservoir s .

[0192] Furthermore, when the above computer program is executed by a processor, the following method steps can be implemented:

[0193] Predict whether there is liquid sulfur precipitation in the combined production reservoir;

[0194] When it is confirmed that liquid sulfur precipitation exists in the commingled production reservoir, the first horizontal coordinate T of the end point of the first horizontal section is obtained according to the shut-in recovery test pressure derivative curve of the commingled production reservoir. c and the second horizontal coordinate T of the end point of the second horizontal segment b .

[0195] Furthermore, when the above computer program is executed by a processor, the following method steps may be implemented:

[0196] Draw a shut-in recovery test pressure derivative curve of the commingled production reservoir based on the bottom hole pressure change data of the gas well in the commingled production reservoir;

[0197] Based on the comparison results of the shut-in recovery test pressure derivative curve and the composite model, it is predicted whether there is liquid sulfur precipitation in the combined production reservoir;

[0198] When the pressure derivative curve of the shut-in recovery test has the characteristics of a composite model, it is confirmed that liquid sulfur precipitation exists in the combined production reservoir.

[0199] Furthermore, when the above computer program is executed by a processor, the following method steps may be implemented:

[0200] Based on the first horizontal coordinate T c , wellbore radius rw , the pressure conductivity coefficient η′ of the sulfur deposition reservoir is determined by the following expression: min :

[0201] πr min 2 =πr w 2 +η′T c ;

[0202] Among them, η is in m 2 / s refers to the pressure conductivity coefficient of the combined production reservoir where sulfur deposition has not occurred.

[0203] Furthermore, when the above computer program is executed by a processor, the following method steps may be implemented:

[0204] Based on the first horizontal coordinate T c , the second horizontal coordinate T b , minimum range r min , wellbore radius r w , the pressure conductivity coefficient η′ of the sulfur deposition reservoir, the pressure conductivity coefficient η of the non-sulfur deposition reservoir, and the equivalent range r is determined according to the following expression equ :

[0205] πr equ 2 =πr min 2 +ηT b -η′T c .

[0206] Furthermore, when the above computer program is executed by a processor, the following method steps may be implemented:

[0207] The pressure conductivity coefficient η of the reservoir without sulfur deposition is determined according to the following expression:

[0208]

[0209] Among them, k unit is 10 -12 m 2 , refers to the permeability of the commingled reservoir; μ is in Pa·s and refers to the fluid viscosity; φ is a decimal and refers to the porosity of the commingled reservoir; c t The unit is 1 / Pa, which refers to the comprehensive compressibility of the commingled reservoir;

[0210] Furthermore, when the above computer program is executed by a processor, the following method steps may be implemented:

[0211] Based on the pressure conductivity η of the reservoir without sulfur deposition, the pressure conductivity η′ of the sulfur deposition reservoir is determined according to the following expression:

[0212]

[0213] Among them, M has no unit and refers to the mobility ratio; D has no unit and refers to the diffusion ratio.

[0214] Furthermore, when the above computer program is executed by a processor, the following method steps may be implemented:

[0215] According to the shut-in recovery test pressure derivative curve of the combined production reservoir, the first ordinate L of the end point of the first horizontal section is obtained. c and the second ordinate L of the end point of the second horizontal segment b .

[0216] Furthermore, when the above computer program is executed by a processor, the following method steps may be implemented:

[0217] The mobility ratio M is determined according to the following expression:

[0218]

[0219] Among them, UL has no unit and refers to the unit length of the ordinate of the shut-in recovery test pressure derivative curve; DL has no unit and refers to the second ordinate L b and the first ordinate L c The difference obtained by subtracting is recorded as DL = L b -L c .

[0220] Furthermore, when the above computer program is executed by a processor, the following method steps may be implemented:

[0221] The diffusion ratio D is determined according to the following expression:

[0222]

[0223] Among them, coefficients a and b are fitted by the mine empirical formula based on the porosity and permeability intersection diagram of the rock core in the actual target area. get.

[0224] Specifically, in the above fitting process, the permeability data k under each porosity φ is plotted in a rectangular coordinate system, and the data points are fitted by the least square method according to the mine empirical formula. When the error between the drawn curve and the data point is the smallest, the fitting is completed. At this time, the coefficients a and b in the mine empirical formula can be obtained. The above process can be achieved using the "Add Trend Line to Data" function in Excel.

[0225] Furthermore, when the above computer program is executed by a processor, the following method steps may be implemented:

[0226] Based on the equivalent range requ , wellbore radius r w , thickness h, and determine the spatial volume V according to the following expression f :

[0227] V f =πh(r equ 2 -r w 2 );

[0228] Among them, h is in meters and refers to the reservoir thickness of the combined production reservoir.

[0229] Furthermore, when the above computer program is executed by a processor, the following method steps may be implemented:

[0230] The amount of liquid sulfur precipitation V is determined according to the following expression s :

[0231] V s =V f Δφ;

[0232] Among them, △φ has no unit and refers to the porosity change of the combined production reservoir after sulfur deposition occurs.

[0233] Furthermore, when the above computer program is executed by a processor, the following method steps may be implemented:

[0234] The porosity change value ∆φ is determined according to the following expression:

[0235] Δφ=φ(1-D).

[0236] Based on this, the present invention provides a storage medium for determining the amount of liquid sulfur precipitation, which obtains the minimum range of the liquid sulfur precipitation area of ​​the co-production reservoir based on the shut-in recovery test pressure derivative curve; further based on the above minimum range and taking into account the sulfur deposition reservoir and the non-sulfur deposition reservoir, the equivalent range of the liquid sulfur precipitation area of ​​the co-production reservoir is obtained; based on the equivalent range and other existing parameters, the spatial volume is obtained; based on the spatial volume and the porosity change value of the co-production reservoir, the amount of liquid sulfur precipitation in the co-production reservoir is determined. This storage medium obtains the shut-in recovery test pressure derivative curve based on unstable dynamic pressure data, and can obtain dynamic data in real time; based on the shut-in recovery test pressure derivative curve, the minimum range of the liquid sulfur precipitation area is determined, which provides a basis for the subsequent design of the interpretation plan of the co-production reservoir; based on the minimum range and taking into account the sulfur deposition reservoir and the non-sulfur deposition layer, the equivalent range is determined and the amount of liquid sulfur precipitation is further determined based on the equivalent range. Compared with the method that is limited to the use of numerical simulation, this method is more in line with the actual situation, more accurate, does not require experiments, and avoids the professional requirements for experimental equipment and experimental personnel. The amount of liquid sulfur precipitation can be determined through simple and fast calculations, which is further helpful in judging the damage of sulfur deposition to the combined production reservoir and providing guidance for the subsequent evaluation of gas well capacity and adjustment of production system.

[0237] Embodiment 5

[0238] This embodiment provides an electronic device, which includes a memory and a processor. The memory stores a computer program. When the computer program is executed by the processor, the method for determining the amount of liquid sulfur precipitation in any one of Embodiments 1 to 3 is executed. Figure 6 The structure diagram of an electronic device provided by an embodiment of the present invention is shown. It can be understood that the electronic device may also include a multimedia component, an input / output (I / O) interface, and a communication component.

[0239] The processor is used to execute all or part of the steps in the map information display method in Embodiment 1. The memory is used to store various types of data, which may include instructions of any application or method in the electronic device, and data related to the application.

[0240] The processor can be an application specific integrated circuit (ASIC), a digital signal processor (DSP), a digital signal processing device (DSPD), a programmable logic device (PLD), a field programmable gate array (FPGA), a controller, a microcontroller, a microprocessor or other electronic components, and is used to execute the home appliance control method in any one of the above-mentioned embodiments 1 to 7.

[0241] The memory can be implemented by any type of volatile or non-volatile storage device or a combination of them, such as static random access memory (SRAM), electrically erasable programmable read-only memory (EEPROM), erasable programmable read-only memory (EPROM), programmable read-only memory (PROM), read-only memory (ROM), magnetic storage, flash memory, magnetic disk or optical disk.

[0242] The multimedia component may include a screen and an audio component, wherein the screen may be a touch screen, and the audio component is used to output and / or input audio signals. For example, the audio component may include a microphone, and the microphone is used to receive external audio signals. The received audio signal may be further stored in a memory or sent via a communication component. The audio component also includes at least one speaker for outputting audio signals.

[0243] The I / O interface provides an interface between the processor and other interface modules, which may be a keyboard, a mouse, buttons, etc. These buttons may be virtual buttons or physical buttons.

[0244] The communication component is used for wired or wireless communication between the electronic device and other devices. Wireless communication, such as Wi-Fi, Bluetooth, Near Field Communication (NFC), 2G, 3G or 4G, or one or a combination of them, so the corresponding communication component 405 may include: Wi-Fi module, Bluetooth module, NFC module.

[0245] When the above computer program is executed by a processor, the following method steps can be implemented:

[0246] Obtain the first horizontal coordinate T of the end point of the first horizontal section according to the shut-in recovery test pressure derivative curve of the combined production reservoir c and the second horizontal coordinate T of the end point of the second horizontal segment b ;

[0247] According to the first horizontal coordinate T c , joint production wellbore radius r w and the pressure conductivity coefficient η′ of the sulfur deposition reservoir to determine the minimum range r of the outer boundary of the liquid sulfur precipitation area of ​​the combined production reservoir min ;

[0248] According to the first horizontal coordinate T c , the second horizontal coordinate T b , minimum range r min , the pressure conductivity coefficient η′ of the sulfur deposition reservoir and the pressure conductivity coefficient η of the reservoir without sulfur deposition, and determine the equivalent range r of the outer boundary of the liquid sulfur precipitation area of ​​the combined production reservoir equ ;

[0249] According to the equivalent range r equ , wellbore radius r w and the thickness h of the combined production reservoir to determine the spatial volume V of the combined production reservoir f ;

[0250] According to the space volume V f and the porosity change value △φ of the combined production reservoir to determine the liquid sulfur precipitation amount V of the combined production reservoir s .

[0251] Furthermore, when the above computer program is executed by a processor, the following method steps can be implemented:

[0252] Predict whether there is liquid sulfur precipitation in the combined production reservoir;

[0253] When it is confirmed that liquid sulfur precipitation exists in the commingled production reservoir, the first horizontal coordinate T of the end point of the first horizontal section is obtained according to the shut-in recovery test pressure derivative curve of the commingled production reservoir. c and the second horizontal coordinate T of the end point of the second horizontal segment b .

[0254] Furthermore, when the above computer program is executed by a processor, the following method steps may be implemented:

[0255] Draw a shut-in recovery test pressure derivative curve of the commingled production reservoir based on the bottom hole pressure change data of the gas well in the commingled production reservoir;

[0256] Based on the comparison results of the shut-in recovery test pressure derivative curve and the composite model, it is predicted whether there is liquid sulfur precipitation in the combined production reservoir;

[0257] When the pressure derivative curve of the shut-in recovery test has the characteristics of a composite model, it is confirmed that liquid sulfur precipitation exists in the combined production reservoir.

[0258] Furthermore, when the above computer program is executed by a processor, the following method steps may be implemented:

[0259] Based on the first horizontal coordinate T c , wellbore radius r w , the pressure conductivity coefficient η′ of the sulfur deposition reservoir is determined by the following expression: min :

[0260] πr min 2 =πr w 2 +η′T c ;

[0261] Among them, η is in m 2 / s refers to the pressure conductivity coefficient of the combined production reservoir where sulfur deposition has not occurred.

[0262] Furthermore, when the above computer program is executed by a processor, the following method steps may be implemented:

[0263] Based on the first horizontal coordinate T c , the second horizontal coordinate T b , minimum range r min , wellbore radius r w , the pressure conductivity coefficient η′ of the sulfur deposition reservoir, the pressure conductivity coefficient η of the non-sulfur deposition reservoir, and the equivalent range r is determined according to the following expression equ :

[0264] πr equ 2 =πr min 2 +ηT b -η′T c .

[0265] Furthermore, when the above computer program is executed by a processor, the following method steps may be implemented:

[0266] The pressure conductivity coefficient η of the reservoir without sulfur deposition is determined according to the following expression:

[0267]

[0268] Among them, k unit is 10 -12 m 2 , refers to the permeability of the commingled reservoir; μ is in Pa·s and refers to the fluid viscosity; φ is a decimal and refers to the porosity of the commingled reservoir; c t The unit is 1 / Pa, which refers to the comprehensive compressibility of the commingled reservoir;

[0269] Furthermore, when the above computer program is executed by a processor, the following method steps may be implemented:

[0270] Based on the pressure conductivity η of the reservoir without sulfur deposition, the pressure conductivity η′ of the sulfur deposition reservoir is determined according to the following expression:

[0271]

[0272] Among them, M has no unit and refers to the mobility ratio; D has no unit and refers to the diffusion ratio.

[0273] Furthermore, when the above computer program is executed by a processor, the following method steps may be implemented:

[0274] According to the shut-in recovery test pressure derivative curve of the combined production reservoir, the first ordinate L of the end point of the first horizontal section is obtained. c and the second ordinate L of the end point of the second horizontal segment b .

[0275] Furthermore, when the above computer program is executed by a processor, the following method steps may be implemented:

[0276] The mobility ratio M is determined according to the following expression:

[0277]

[0278] Among them, UL has no unit and refers to the unit length of the ordinate of the shut-in recovery test pressure derivative curve; DL has no unit and refers to the second ordinate L b and the first ordinate L c The difference obtained by subtracting is recorded as DL = L b -L c .

[0279] Furthermore, when the above computer program is executed by a processor, the following method steps may be implemented:

[0280] The diffusion ratio D is determined according to the following expression:

[0281]

[0282] Among them, coefficients a and b are fitted by the mine empirical formula based on the porosity and permeability intersection diagram of the rock core in the actual target area. get.

[0283] Specifically, in the above fitting process, the permeability data k under each porosity φ is plotted in a rectangular coordinate system, and the data points are fitted by the least square method according to the mine empirical formula. When the error between the drawn curve and the data point is the smallest, the fitting is completed. At this time, the coefficients a and b in the mine empirical formula can be obtained. The above process can be achieved using the "Add Trend Line to Data" function in Excel.

[0284] Furthermore, when the above computer program is executed by a processor, the following method steps may be implemented:

[0285] Based on the equivalent range r equ , wellbore radius r w , thickness h, and determine the spatial volume V according to the following expression f :

[0286] V f =πh(r equ 2 -r w 2 );

[0287] Among them, h is in meters and refers to the reservoir thickness of the combined production reservoir.

[0288] Furthermore, when the above computer program is executed by a processor, the following method steps may be implemented:

[0289] The amount of liquid sulfur precipitation V is determined according to the following expression s :

[0290] V s =V f Δφ;

[0291] Among them, △φ has no unit and refers to the porosity change of the combined production reservoir after sulfur deposition occurs.

[0292] Furthermore, when the above computer program is executed by a processor, the following method steps may be implemented:

[0293] The porosity change value ∆φ is determined according to the following expression:

[0294] Δφ=φ(1-D).

[0295] Based on this, the present invention provides an electronic device for determining the amount of liquid sulfur precipitation, which obtains the minimum range of the liquid sulfur precipitation area of ​​the co-production reservoir based on the shut-in recovery test pressure derivative curve; further based on the above minimum range and taking into account the sulfur deposition reservoir and the non-sulfur deposition reservoir, obtains the equivalent range of the liquid sulfur precipitation area of ​​the co-production reservoir; based on the equivalent range and other existing parameters, obtains the spatial volume; based on the spatial volume and the porosity change value of the co-production reservoir, determines the amount of liquid sulfur precipitation in the co-production reservoir. The electronic device obtains the shut-in recovery test pressure derivative curve based on unstable dynamic pressure data, and can obtain dynamic data in real time; determines the minimum range of the liquid sulfur precipitation area based on the shut-in recovery test pressure derivative curve, which provides a basis for the subsequent design of the interpretation plan for the co-production reservoir; determines the equivalent range based on the minimum range and taking into account the sulfur deposition reservoir and the non-sulfur deposition layer, and further determines the amount of liquid sulfur precipitation based on the equivalent range. Compared with the method that is limited to the use of numerical simulation, this method is more in line with the actual situation, more accurate, does not require experiments, and avoids the professional requirements for experimental equipment and experimental personnel. The amount of liquid sulfur precipitation can be determined through simple and fast calculations, which is further helpful in judging the damage of sulfur deposition to the combined production reservoir and providing guidance for the subsequent evaluation of gas well capacity and adjustment of production system.

[0296] In the embodiments provided by the present invention, it should be understood that the disclosed devices and methods can also be implemented in other ways. The device embodiments described above are merely schematic. For example, the flowcharts and block diagrams in the accompanying drawings show the possible architecture, functions and operations of the devices, methods and computer program products according to multiple embodiments of the present invention. In this regard, each box in the flowchart or block diagram can represent a module, a program segment or a part of a code, and the above-mentioned module, a program segment or a part of a code contains one or more executable instructions for implementing the specified logical functions. It should also be noted that in some alternative implementations, the functions marked in the box can also occur in an order different from that marked in the accompanying drawings. For example, two consecutive boxes can actually be executed substantially in parallel, and they can sometimes be executed in the opposite order, depending on the functions involved. It should also be noted that each box in the block diagram and / or flowchart, and the combination of boxes in the block diagram and / or flowchart can be implemented with a dedicated hardware-based system that performs a specified function or action, or can be implemented with a combination of dedicated hardware and computer instructions.

[0297] It should be noted that, in the present invention, the terms "include", "comprise" or any other variants thereof are intended to cover non-exclusive inclusion, so that a process, method, article or device including a series of elements includes not only those elements, but also other elements not explicitly listed, or also includes elements inherent to such process, method, article or device. In the absence of further restrictions, an element defined by the sentence "comprises a ..." does not exclude the existence of other identical elements in the process, method, article or device including the element.

[0298] Although the embodiments disclosed in the present invention are as above, the above contents are only embodiments adopted for facilitating the understanding of the present invention and are not intended to limit the present invention. Any technician in the technical field to which the present invention belongs can make any modifications and changes in the form and details of the implementation without departing from the spirit and scope disclosed in the present invention, but the patent protection scope of the present invention shall still be subject to the scope defined in the attached claims.

Claims

1. A method for determining the amount of liquid sulfur precipitation, It is characterized in that The following steps are involved: Obtain the first horizontal coordinate T of the end point of the first horizontal section according to the shut-in recovery test pressure derivative curve of the combined production reservoir c and the second horizontal coordinate T of the end point of the second horizontal segment b , wherein the commingled production reservoir includes a sulfur deposition reservoir and a non-sulfur deposition reservoir; According to the first horizontal coordinate T c , joint production wellbore radius r w and the pressure conductivity coefficient η′ of the sulfur deposition reservoir, determine the minimum range r of the outer boundary of the liquid sulfur precipitation area of ​​the commingled reservoir min ; According to the first horizontal coordinate T c The second horizontal coordinate T b , the minimum range r min , the pressure conductivity coefficient η′ of the sulfur deposition reservoir and the pressure conductivity coefficient η of the non-sulfur deposition reservoir, and determine the equivalent range r of the outer boundary of the liquid sulfur precipitation area of ​​the commingled reservoir equ ; According to the equivalent range r equ , the wellbore radius r w and the thickness h of the commingled reservoir, determine the spatial volume V of the commingled reservoir f ; According to the space volume V f and the porosity change value Δφ of the commingled reservoir, determine the liquid sulfur precipitation amount V of the commingled reservoir s ; According to the first horizontal coordinate T c , wellbore radius r w and the pressure conductivity coefficient η′ of the sulfur deposition reservoir, determine the minimum range r of the outer boundary of the liquid sulfur precipitation area of ​​the commingled reservoir min include: Based on the first horizontal coordinate T c , the wellbore radius r w , the pressure conductivity coefficient η′ of the sulfur deposition reservoir, the minimum range r is determined according to the following expression min : pr min 2 =πr w 2 +η′T c ; According to the first horizontal coordinate T c The second horizontal coordinate T b , the minimum range r min , the pressure conductivity coefficient η′ of the sulfur deposition reservoir and the pressure conductivity coefficient η of the reservoir without sulfur deposition, and determine the equivalent range r of the outer boundary of the liquid sulfur precipitation area of ​​the commingled reservoir equ include: Based on the first horizontal coordinate T c The second horizontal coordinate T b , the minimum range r min , the wellbore radius r w , the pressure conductivity coefficient η′ of the sulfur deposition reservoir, the pressure conductivity coefficient η of the non-sulfur deposition reservoir, and the equivalent range r is determined according to the following expression equ : pr equ 2 =πr min 2 +V b -η′T c ; According to the equivalent range r equ , the wellbore radius r w , the thickness h of the commingled reservoir, and determine the spatial volume V of the commingled reservoir f include: Based on the equivalent range r equ , the wellbore radius r w , the thickness h, and the spatial volume V are determined according to the following expression f : V f =πh(r equ 2 -r w 2 ); According to the space volume V f and the porosity change value Δφ of the commingled reservoir, determine the liquid sulfur precipitation amount V of the commingled reservoir s include: The liquid sulfur precipitation amount V is determined according to the following expression s : V s =V f Δφ, The porosity change value Δφ is determined according to the following expression: Δφ=φ(1-D).

2. The method according to claim 1, It is characterized in that The method further comprises: It is predicted whether there is liquid sulfur precipitation in the commingled production reservoir. When it is confirmed that there is liquid sulfur precipitation in the commingled production reservoir, the first horizontal coordinate T of the end point of the first horizontal section is obtained according to the shut-in recovery test pressure derivative curve of the commingled production reservoir. c and the second horizontal coordinate T of the end point of the second horizontal segment b , Among them, predicting whether there is liquid sulfur precipitation in the combined production reservoir includes: Draw a shut-in recovery test pressure derivative curve of the commingled production reservoir according to bottom hole pressure change data of the gas wells in the commingled production reservoir; Based on the comparison result of the shut-in recovery test pressure derivative curve and the composite model, predict whether there is liquid sulfur precipitation in the combined production reservoir; When the shut-in recovery test pressure derivative curve has the characteristics of a composite model, it is confirmed that liquid sulfur precipitation exists in the combined production reservoir.

3. The method according to claim 1, It is characterized in that The pressure conductivity coefficient η of the reservoir without sulfur deposition is determined according to the following expression: Wherein, k is the permeability of the commingled reservoir, μ is the fluid viscosity, φ is the porosity of the commingled reservoir, and c t is the comprehensive compression coefficient of the commingled reservoir; And / or, based on the pressure conductivity coefficient η of the reservoir without sulfur deposition, the pressure conductivity coefficient η′ of the sulfur deposition reservoir is determined according to the following expression: Where M is the mobility ratio and D is the diffusion ratio.

4. The method according to claim 3, It is characterized in that The method further comprises: obtaining a first ordinate L of the end point of the first horizontal section according to the shut-in recovery test pressure derivative curve of the co-production reservoir c and the second ordinate L of the end point of the second horizontal segment b ; The mobility ratio M is determined according to the following expression: Wherein, UL is the unit length of the ordinate of the shut-in recovery test pressure derivative curve, and DL is the unit length of the second ordinate L b and the first ordinate L c The difference obtained by subtracting is recorded as DL = L b -L c ; And / or, the diffusion ratio D is determined according to the following expression: Among them, coefficients a and b are fitted by the mine empirical formula based on the porosity and permeability intersection diagram of the rock core in the actual target area. get.

5. A storage medium, It is characterized in that The storage medium stores a program, and when the program is executed, the method described in any one of claims 1 to 4 is executed.

6. An electronic device, It is characterized in that The electronic device comprises a memory and a processor, wherein a computer program is stored in the memory, and when the processor executes the computer program, the method as described in any one of claims 1 to 4 can be implemented.

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