CN110610435B - Method for selecting drainage gas production process of liquid production natural gas well and control system - Google Patents
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Abstract
The invention relates to a method for selecting and controlling a drainage gas production process of a liquid production natural gas well, which comprises the following steps: (1) in a coordinate system formed by daily gas production and bottom hole flowing pressure, drawing inflow curves of different production stages, oil pipe dynamic curves corresponding to the lowest wellhead oil pressure, critical liquid carrying curves and critical bubble carrying curves to form a dynamic analysis plate; (2) selecting related intersection points of the four curves, dividing the graph into a plurality of intervals with different liquid carrying capacity characteristics, and determining a drainage and gas production process corresponding to each interval; (3) and mapping the historical production data of the gas well into a chart, determining the corresponding interval of the current production stage, and finding the corresponding drainage gas production process. The method has the advantages that the number of influence factors is large, the influence factors are analyzed and processed to obtain a plurality of intervals, and the corresponding drainage gas production process is obtained according to the interval where the gas well is located, so that the proper drainage gas production process can be accurately obtained, and the reliability is high.
Description
Technical Field
The invention relates to a selection method and a control system for a drainage gas production process of a liquid production natural gas well, belonging to the technical field of gas production of gas wells.
Background
The Ordos basin is an important natural gas production area in China, and a gas reservoir has the characteristics of low pressure, low yield and liquid production. Well drainage and gas production are well done, gas well accumulated liquid and yield reduction and even water flooding shut-in are avoided, and the method is an important task for guaranteeing stable yield of a gas field. Because the pressure of the gas well is low, the liquid carrying capacity of the gas well is insufficient, and the yield is low, the requirement on the cost of the drainage gas production process is strict, so that how to optimize the drainage gas production process is an important problem for realizing economic and effective development of the gas field. In order to complete drainage and gas production, the following factors need to be comprehensively considered:
the intervention time of the drainage and gas production process is delayed to reduce the production cost, and the difference of the liquid carrying capacity of the well is determined by the productivity difference of the gas wells; wells with weak fluid carrying capacity need to intervene in time to avoid fluid accumulation and yield reduction.
The effectiveness of the drainage and gas production process and the drainage and gas production process have certain applicable conditions, part of the process is invalid as the yield energy is reduced, and the drainage and gas production process needs to be replaced so as to reduce invalid investment and avoid gas well liquid accumulation and yield reduction.
The economical efficiency of the drainage and gas production process is determined whether a specific drainage and gas production process needs to be selected for one gas well or not in economic benefit according to potential indexes such as unobstructed flow, dynamic reserves and the like of the gas well.
The Chinese patent application publication No. CN107237614A discloses a method for water drainage and gas production of a water-containing compact gas reservoir gas well, which comprises the following steps: dividing the static liquid production types of the gas wells according to the average daily gas production and the average daily water production of the gas wells; drawing a corresponding relation curve of the single well accumulated water-gas ratio and dimensionless time in the production history of the gas well according to the accumulated water-gas ratio, and dividing the dynamic liquid production type of the gas well; establishing a cross analysis model according to the static liquid production type of the gas well and the dynamic liquid production type of the gas well, and determining the fine liquid production type of the gas well; and according to the fine liquid production types of the gas wells, taking corresponding drainage and gas production measures by combining drainage and gas production suggestions corresponding to each fine liquid production type. The drainage gas production problem faced by the gas well is obtained while the drainage gas production measure is obtained. Although the method can find the water drainage and gas production problems according to the type of the gas well and adopt corresponding water drainage and gas production measures, the method only finds the corresponding water drainage and gas production measures according to the fine liquid production type of the gas well. Because the factors influencing water drainage and gas production are many, the method does not consider a plurality of influencing factors, finds out the water drainage and gas production problem and corresponding water drainage and gas production measures according to the single factor of the fine production liquid type of the gas well, and has low reliability.
Disclosure of Invention
The invention aims to provide a method for selecting a drainage gas production process of a liquid production natural gas well, which is used for solving the problem of low reliability caused by less consideration factors of a traditional method for determining drainage gas production measures. The invention also provides a selection control system for the drainage and gas production process of the liquid production natural gas well.
In order to achieve the above object, the present invention includes the following technical solutions.
A method for selecting a drainage gas production process of a liquid production natural gas well comprises the following steps:
(1) in a coordinate system formed by daily gas production and bottom hole flowing pressure, drawing inflow curves of different production stages, oil pipe dynamic curves corresponding to the lowest wellhead oil pressure, critical liquid carrying curves and critical bubble carrying curves to form a dynamic analysis plate;
(2) selecting related intersection points of the four curves, dividing the chart into a plurality of intervals with different liquid carrying capacity characteristics, and determining a drainage and gas production process corresponding to each interval;
(3) and mapping the historical production data of the gas well into the chart, determining the interval corresponding to the current production stage of the gas well, and finding out the corresponding drainage gas production process.
According to the selection method of the drainage and gas production process of the liquid production natural gas well, inflow curves of different production stages, an oil pipe dynamic curve corresponding to the lowest wellhead oil pressure, a critical liquid carrying curve and a critical bubble carrying curve are drawn in a corresponding coordinate system to form a dynamic analysis chart; then, determining to divide the plate into a plurality of intervals with different liquid carrying capacity characteristics, and determining a drainage and gas production process corresponding to each interval; and finally, determining the interval corresponding to the current production stage according to the actual data of the gas well, and finding out the corresponding drainage gas production process. Therefore, the influence factors involved in the method are more, the influence factors are analyzed and processed to obtain a plurality of intervals, and the corresponding drainage gas production process is obtained according to the interval where the gas well is located.
And further, reading the formation pressure and the unimpeded flow rate of the current stage in the chart, and determining the production potential of the gas well by combining the dynamic reserve and the residual dynamic reserve of the gas well.
And further, according to the interval and the production potential of the current stage, a preferred drainage gas recovery process which meets the drainage requirement and has the best economic benefit is further determined.
Further, the inflow curve calculation formula is as follows:
in the formula: q. q.saofFor unimpeded flow, onlyBit is 104m3/d；PeThe unit is the stratum pressure at the appointed time point and is MPa; pwfObtaining the bottom hole flowing pressure at a specified time point by a flowing pressure test, wherein the unit is MPa; q. q.sgAcquiring the daily gas production rate of the gas well at a specified time point by using production data, wherein the unit is MPa; alpha is an empirical parameter; the inflow curve of different production stages can be obtained by using the inflow curve calculation formula, and the required data is P corresponding to the production stagee、PwfAnd q isg。
Further, the calculation formula of the oil pipe dynamic curve is as follows:
in the formula: ptfIs the wellhead pressure in MPa; t istfIs the well head temperature in K; pwfObtaining the bottom hole flowing pressure at a specified time point by a flowing pressure test, wherein the unit is MPa; t iswfIs the bottom hole temperature in K;
the compression factor is the average pressure and average temperature of the well head and the well bottom, and is dimensionless; q. q.sgAcquiring the daily gas production rate of the gas well at a specified time point by using production data, wherein the unit is MPa; s is the epidermis coefficient and is dimensionless; and f (x) is a two-phase flow function and is selected according to the actual characteristics of the gas field.
Further, the critical liquid carrying curve and the critical bubble carrying curve have the following calculation formulas:
in the formula: g is the acceleration of gravity; theta is the inclination angle of the shaft and has the unit of degree; z is a natural gas compression factor and is dimensionless; t is the thermodynamic temperature in K; v. ofcl1、vcl2、vcl3Respectively are the critical liquid carrying flow velocity of a straight well section, an inclined section and a horizontal section, and the unit is m3/d；vcb1、vcb2、vcb3Respectively are a straight well section, a deflecting section and a horizontal section, and the unit is m3/d；σlg、σbgRespectively liquid-gas, foam-gas surface tension, with the unit of MT-2；ρl、ρg、ρbRespectively the density of liquid, gas and foam under the condition of specified temperature and pressure, and the unit is Kg/m3(ii) a A is the cross-sectional area of the oil pipe in mm2(ii) a P is a designated pressure in MPa; qcIs the critical liquid/bubble carrying flow, and the unit is m3D; wherein, v iscl1、vcl2And vcl3Substitution vcWhen the position is determined, the critical liquid carrying flow of the vertical well section, the deflecting section and the horizontal section is respectively obtained, and v iscb1、vcb2And vcb3Substitution vcAnd when the device is in position, respectively obtaining the critical bubble carrying flow of the straight well section, the deflecting section and the horizontal section.
Furthermore, three inflow curves can be obtained according to different production stages, wherein the first inflow curve is an inflow curve corresponding to the original formation pressure, the second inflow curve is an inflow curve intersected with the oil pipe dynamic curve and the critical liquid carrying curve at the same time, and the third inflow curve is an inflow curve intersected with the oil pipe dynamic curve and the critical bubble carrying curve at the same time; the relevant intersection points of the four types of curves are selected as follows: the second inflow curve is simultaneously connected with the intersection point of the oil pipe dynamic curve and the critical bubble carrying curve, the intersection point of the second inflow curve and the critical bubble carrying curve, and the third inflow curve is simultaneously connected with the intersection point of the oil pipe dynamic curve and the critical bubble carrying curve; dividing the plate into 6 intervals according to the intersection points, wherein the range of the first interval is more than that of the second inflow curve, the right side of the critical liquid carrying curve and the left side of the oil pipe dynamic curve; the range of the second interval is above the second inflow curve, the right side of the critical bubble carrying curve and the left side of the critical liquid carrying curve; the range of the third interval is above the second inflow curve and on the left side of the critical bubble carrying curve; the range of the fourth interval is a closed area formed by the right side of the critical bubble carrying curve below the second inflow curve and above the oil pipe dynamic curve; the range of the fifth interval is below the second inflow curve, above the third inflow curve and on the left side of the critical bubble carrying curve; the range of the sixth interval is a closed area formed below the third inflow curve and above the oil pipe dynamic curve.
A selection control system for a drainage and gas production process of a liquid production natural gas well comprises a control module, wherein the control module comprises a memory, a processor and a computer program which is stored in the memory and can be run on the processor, and the processor executes the program to realize the following steps:
(1) in a coordinate system formed by daily gas production and bottom hole flowing pressure, drawing inflow curves of different production stages, oil pipe dynamic curves corresponding to the lowest wellhead oil pressure, critical liquid carrying curves and critical bubble carrying curves to form a dynamic analysis plate;
(2) selecting related intersection points of the four curves, dividing the chart into a plurality of intervals with different liquid carrying capacity characteristics, and determining a drainage and gas production process corresponding to each interval;
(3) and mapping the historical production data of the gas well into the chart, determining the interval corresponding to the current production stage of the gas well, and finding out the corresponding drainage gas production process.
And further, reading the formation pressure and the unimpeded flow rate of the current stage in the chart, and determining the production potential of the gas well by combining the dynamic reserve and the residual dynamic reserve of the gas well.
And further, according to the interval and the production potential of the current stage, a preferred drainage gas recovery process which meets the drainage requirement and has the best economic benefit is further determined.
Further, the inflow curve calculation formula is as follows:
in the formula: q. q.saofFor unimpeded flow, the unit is 104m3/d；PeThe unit is the stratum pressure at the appointed time point and is MPa; pwfObtaining the bottom hole flowing pressure at a specified time point by a flowing pressure test, wherein the unit is MPa; q. q.sgAcquiring the daily gas production rate of the gas well at a specified time point by using production data, wherein the unit is MPa; alpha is an empirical parameter; the inflow curve of different production stages can be obtained by using the inflow curve calculation formula, and the required data is P corresponding to the production stagee、PwfAnd q isg。
Further, the calculation formula of the oil pipe dynamic curve is as follows:
in the formula: ptfIs the wellhead pressure in MPa; t istfIs the well head temperature in K; pwfObtaining the bottom hole flowing pressure at a specified time point by a flowing pressure test, wherein the unit is MPa; t iswfIs the bottom hole temperature in K;
the compression factor is the average pressure and average temperature of the well head and the well bottom, and is dimensionless; q. q.sgAcquiring the daily gas production rate of the gas well at a specified time point by using production data, wherein the unit is MPa; s is the epidermis coefficient and is dimensionless; and f (x) is a two-phase flow function and is selected according to the actual characteristics of the gas field.
Further, the critical liquid carrying curve and the critical bubble carrying curve have the following calculation formulas:
in the formula: g is the acceleration of gravity; theta is the inclination angle of the shaft and has the unit of degree; z is a natural gas compression factor and is dimensionless; t is the thermodynamic temperature in K; v. ofcl1、vcl2、vcl3Respectively are the critical liquid carrying flow velocity of a straight well section, an inclined section and a horizontal section, and the unit is m3/d；vcb1、vcb2、vcb3Respectively are a straight well section, a deflecting section and a horizontal section, and the unit is m3/d；σlg、σbgRespectively liquid-gas, foam-gas surface tension, with the unit of MT-2；ρl、ρg、ρbRespectively liquid, gas and foam under the condition of specified temperature and pressureLower density in Kg/m3(ii) a A is the cross-sectional area of the oil pipe in mm2(ii) a P is a designated pressure in MPa; qcIs the critical liquid/bubble carrying flow, and the unit is m3D; wherein, v iscl1、vcl2And vcl3Substitution vcWhen the position is determined, the critical liquid carrying flow of the vertical well section, the deflecting section and the horizontal section is respectively obtained, and v iscb1、vcb2And vcb3Substitution vcAnd when the device is in position, respectively obtaining the critical bubble carrying flow of the straight well section, the deflecting section and the horizontal section.
Furthermore, three inflow curves can be obtained according to different production stages, wherein the first inflow curve is an inflow curve corresponding to the original formation pressure, the second inflow curve is an inflow curve intersected with the oil pipe dynamic curve and the critical liquid carrying curve at the same time, and the third inflow curve is an inflow curve intersected with the oil pipe dynamic curve and the critical bubble carrying curve at the same time; the relevant intersection points of the four types of curves are selected as follows: the second inflow curve is simultaneously connected with the intersection point of the oil pipe dynamic curve and the critical bubble carrying curve, the intersection point of the second inflow curve and the critical bubble carrying curve, and the third inflow curve is simultaneously connected with the intersection point of the oil pipe dynamic curve and the critical bubble carrying curve; dividing the plate into 6 intervals according to the intersection points, wherein the range of the first interval is more than that of the second inflow curve, the right side of the critical liquid carrying curve and the left side of the oil pipe dynamic curve; the range of the second interval is above the second inflow curve, the right side of the critical bubble carrying curve and the left side of the critical liquid carrying curve; the range of the third interval is above the second inflow curve and on the left side of the critical bubble carrying curve; the range of the fourth interval is a closed area formed by the right side of the critical bubble carrying curve below the second inflow curve and above the oil pipe dynamic curve; the range of the fifth interval is below the second inflow curve, above the third inflow curve and on the left side of the critical bubble carrying curve; the range of the sixth interval is a closed area formed below the third inflow curve and above the oil pipe dynamic curve.
Drawings
FIG. 1 is a flow chart of a method for selecting a drainage gas production process of a liquid production natural gas well;
FIG. 2 is a simulation of gas well unsteady flow theory calculations of formation pressure, dynamic reserves and residual dynamic reserves;
FIG. 3 is a schematic diagram of an implementation of a dynamic analysis plate;
fig. 4 is a section division diagram of the dynamic analysis plate.
Detailed Description
The invention provides a drainage and gas production process selection method of a liquid production natural gas well, which comprises the following steps: (1) in a coordinate system formed by daily gas production and bottom hole flowing pressure, drawing inflow curves of different production stages, oil pipe dynamic curves corresponding to the lowest wellhead oil pressure, critical liquid carrying curves and critical bubble carrying curves to form a dynamic analysis plate; (2) selecting related intersection points of the four curves, dividing the graph into a plurality of intervals with different liquid carrying capacity characteristics, and determining a drainage and gas production process corresponding to each interval; (3) and mapping the historical production data of the gas well into a chart, determining an interval corresponding to the current production stage of the gas well, and finding a corresponding drainage gas production process.
Based on the basic technical scheme, specific implementation processes of the method are given for each step.
As shown in fig. 1, a specific implementation process of the method for selecting the drainage gas production process of the liquid-producing natural gas well comprises the following steps:
step 101: this step is a dynamic analysis plate drawing step. And in a coordinate system formed by daily gas production and bottom hole flowing pressure, drawing inflow curves of different production stages of the gas well, an oil pipe dynamic curve corresponding to the lowest wellhead oil pressure, a critical liquid carrying curve and a critical bubble carrying curve to form a dynamic analysis plate.
Wherein, the formula of the inflow curve is as follows:
in the formula: q. q.saofFor unimpeded flow, the unit is 104m3/d；PeThe unit is the stratum pressure at the appointed time point and is MPa; pwfObtaining the bottom hole flowing pressure at a specified time point by a flowing pressure test, wherein the unit is MPa; q. q.sgAcquiring the daily gas production rate of the gas well at a specified time point by using production data, wherein the unit is MPa; alpha is an empirical parameter, can be derived by counting the data of the gas field correction isochronous well test, and is dimensionless. Further, the formation pressure PeThe formation pressure of the gas well at the appointed time point can be calculated by calculating the unstable seepage theory and adopting common gas reservoir engineering commercial software (such as Topaze), and meanwhile, the dynamic reserves and the residual dynamic reserves required in the subsequent potential evaluation process can also be calculated.
Specifically, as shown in fig. 2, the production data (oil pressure, daily gas production rate, and daily liquid production rate) of the gas well in the full history is loaded into the toadoze software, and the change data of the full history of the formation pressure is calculated by using the unstable seepage theory. The measured flow pressure data in the gas well production history is shown in table 1, for example, and the formation pressure data and the daily gas production data on the current test day are matched according to the flow pressure measurement date to obtain basic data of an inflow dynamic curve calculated by a one-point method. Substituting the basic data into the inflow curve calculation formula, and calculating to obtain the unimpeded flow rate of different production stages. It can be seen from the inflow curve calculation formula that when the unobstructed flow and the formation pressure are known, the formula reflects the functional relationship between the daily gas production and the flow pressure, and the curve form in the daily gas production-bottom flow pressure coordinate system is the inflow curve, as shown in fig. 3. The inflow curves of different production stages (or time points) can be obtained by using the calculation formula of the inflow curves, and the required data is P corresponding to the production stagee、PwfAnd q isg. In this embodiment, three inflow curves can be obtained according to different production stages, and the three inflow curves are three more specific curves, which are: the system comprises a first inflow curve, a second inflow curve and a third inflow curve, wherein the first inflow curve is an inflow curve corresponding to the original formation pressure, the second inflow curve is an inflow curve intersected with an oil pipe dynamic curve and a critical liquid carrying curve at the same time, and the third inflow curve is an inflow curve intersected with the oil pipe dynamic curve and the critical bubble carrying curve at the same time.
TABLE 1
The calculation formula of the oil pipe dynamic curve is as follows:
in the formula: ptfIs the wellhead pressure in MPa; t istfIs the well head temperature in K; t iswfIs the bottom hole temperature in K;
the compression factor is the average pressure and average temperature of the well head and the well bottom, and is dimensionless; s is the epidermis coefficient and is dimensionless; (x) is a two-phase flow function selected according to the actual characteristics of the gas field; the meaning of other parameters can be referred to the meaning of each relevant parameter in the above inflow curve calculation formula. By adopting common gas production engineering commercial software (such as Pipesim), the dynamic curve of the oil pipe can be drawn rapidly, which specifically comprises the following steps: selecting an H-B two-phase flow model by using the production string parameter data, the natural gas component data, the liquid-gas ratio data and the pipe network pressure data of the gas well, loading the H-B two-phase flow model into Pipesim software, and completing the drawing of the oil pipe dynamic curve of the gas well according to the calculation formula of the oil pipe dynamic curve, as shown in figure 3.
The critical liquid carrying curve and the critical bubble carrying curve are calculated according to the following formulas:
in the formula: g is gravity acceleration and can take 9.81m/s2(ii) a Theta is the inclination angle of the shaft and has the unit of degree; z is a natural gas compression factor and is dimensionless; t is the thermodynamic temperature in K; v. ofcl1、vcl2、vcl3Respectively are the critical liquid carrying flow velocity of a straight well section, an inclined section and a horizontal section, and the unit is m3/d；vcb1、vcb2、vcb3Respectively are a straight well section, a deflecting section and a horizontal section, and the unit is m3/d；σlg、σbgRespectively liquid-gas, foam-gas surface tension, with the unit of MT-2；ρl、ρg、ρbRespectively the density of liquid, gas and foam under the condition of specified temperature and pressure, and the unit is Kg/m3(ii) a A is the cross-sectional area of the oil pipe in mm2(ii) a P is a designated pressure in MPa; qcIs the critical liquid/bubble carrying flow, and the unit is m3/d。
Wherein, v iscl1、vcl2And vcl3Substitution vcWhen the vertical well section is positioned, critical liquid carrying flow rates of the vertical well section, the deflecting section and the horizontal section are respectively obtained; v is to becb1、vcb2And vcb3Substitution vcAnd when the device is in position, respectively obtaining the critical bubble carrying flow of the straight well section, the deflecting section and the horizontal section. According toSelecting corresponding v for actual type of gas wellclAnd vcl。
As shown in table 2, according to the gas well tubular column structure data, the critical liquid carrying flow curve and the critical bubble carrying flow curve of the gas well are drawn according to the above critical liquid carrying curve and critical bubble carrying curve calculation formula, as shown in fig. 3.
TABLE 2
Therefore, according to the calculation formulas of the inflow curve, the oil pipe dynamic curve, the critical liquid carrying flow curve and the critical bubble carrying flow curve, the drawing of the relevant curves is completed, and a dynamic analysis chart is formed, as shown in fig. 3.
In addition, in the gas reservoir engineering and the gas production engineering, various algorithms can be used for calculating a gas well inflow curve, an oil pipe dynamic curve, a critical liquid carrying curve and a critical bubble carrying curve, and the method is not limited to the given method. Therefore, it should be noted that, as long as the concept of the dynamic analysis plate obtaining method is adopted, plates drawn by calculating the inflow curve, the oil pipe dynamic curve, the critical liquid carrying curve and the critical bubble carrying curve by using other algorithms are within the protection scope of the present invention.
Step 102: this step is a production interval dividing step. In the embodiment, the selected intersection points are the following three key intersection points: the intersection point 1 is the intersection point of the second inflow curve and the oil pipe dynamic curve and the critical bubble carrying curve at the same time, the intersection point 2 is the intersection point of the second inflow curve and the critical bubble carrying curve, and the intersection point 3 is the intersection point of the third inflow curve and the oil pipe dynamic curve and the critical bubble carrying curve at the same time. Therefore, the plate can be divided into 6 production intervals by the three key intersection points, and the six intervals have different liquid carrying capacity characteristics. Of course, the positions and the numbers of the selected intersection points are different, and the number of the divided intervals is changed correspondingly.
The 6 production intervals were: the range of the area I is above the second inflow curve, the right side of the critical liquid carrying curve and the left side of the oil pipe dynamic curve; the range of the area II is above the second inflow curve, the right side of the critical bubble carrying curve and the left side of the critical liquid carrying curve; the range of the area III is above the second inflow curve and on the left side of the critical bubble carrying curve; the range of the area IV is a closed area formed by the right side of the critical bubble carrying curve below the second inflow curve, above the oil pipe dynamic curve; the range of the V zone is below the second inflow curve, above the third inflow curve and on the left side of the critical bubble carrying curve; the area VI is a closed area formed below the third inflow curve and above the dynamic curve of the oil pipe, and is shown in figure 4.
Therefore, the dynamic analysis chart is established as a four-line six-area dynamic analysis chart.
As a specific embodiment, table 3 is a liquid carrying capacity characteristic for 6 production intervals.
TABLE 3
Step 103: the step is a step of compiling a drainage and gas production process guide table. According to the principle of the common drainage gas production process, the pressure applicable condition, the gas production applicable condition, the liquid production applicable condition, the process cost and other factors, and the liquid carrying capacity characteristics of 6 intervals, the proper drainage gas production process and the production allocation adjustment suggestion are determined for each interval, and a process guide table is formed.
Common drainage gas recovery processes, such as those of a cattle land gas field, include: preferably selecting a pipe column process, a foam drainage gas production process, a plunger gas lift drainage gas production process, an ultrasonic atomization drainage gas production process, a vortex drainage gas production process, a jet drainage gas production process and a machine pumping drainage gas production process. According to the production characteristics and the process cost of different discharging and mining processes, the discharging and mining process is matched for each production interval, and the process is shown in table 3.
Step 104: the step is a gas well drainage problem diagnosis step. And mapping the gas well production history data into a chart, describing production history evolution, determining an interval corresponding to the current production stage of the gas well, further determining the problem of water drainage and gas production and also finding a corresponding water drainage and gas production process preliminarily.
As shown in fig. 3, the gas well production history data is mapped into a "four-line six-zone" dynamic analysis chart. From the production history data of the gas well, the gas well production is mainly divided into three production stages:
and in the stable production stage, the well is positioned in a zone III, the auxiliary bubble exhaust well cannot carry liquid normally, and the flow pressure monitoring data shows that after 1 year of production, the well has obvious lower gradient, which indicates that the liquid carrying capacity of the gas well is insufficient, and the liquid slips and stays at the bottom of the well (Table 4). Because the well has high initial well bottom pressure (15 MPa) and small liquid production amount (0.5 ten thousand square/day of daily liquid production), although liquid is continuously accumulated at the well bottom, the accumulated liquid and the production reduction are not caused, and the gas well keeps a stable production period of nearly 4 years.
In the cliff type decreasing stage, along with the increase of accumulated liquid at the bottom of the well and the reduction of pressure, the well has obvious yield decrease when the well transits from a zone III to a zone V. The daily gas production is reduced from 1.8 ten thousand parts per day to 0.46 ten thousand parts per day. Because the yield suddenly drops obviously, the gas well has relatively sufficient capacity to maintain the dynamic balance under low gas production rate, and therefore the daily gas production rate of the gas well is basically kept stable in the whole cliff type production stage. However, the flow pressure monitoring data showed that the fluid carrying capacity of the well continued to decrease (table 4, upper flow pressure gradient decreased) and the level of fluid loading in the well increased.
And in a further decreasing stage, when the well transits from the zone V to the zone VI, the gas production rate is suddenly reduced again, the daily gas production rate of the well is about 0.1 ten thousand square per day at present, and basically no liquid is produced.
TABLE 4
In summary, the gas well is affected by unreasonable pipe column structures during the whole production history period, and the influence of liquid accumulation is obvious. At present, the gas well is in a VI area, the foam drainage process and the depressurization zone are gradually ineffective, the working difficulty of drainage and gas production is high, and the corresponding drainage and gas production process, namely the drainage and gas production process corresponding to the VI area, can be found preliminarily according to the area (VI area) where the gas well is located.
Further, in order to evaluate the production potential of the gas well, the method provided by the invention further comprises a step 105.
Step 105: this step is the step of evaluating the production potential of the gas well. And reading the formation pressure and the unimpeded flow rate of the current stage in the chart, and determining the production potential of the gas well by combining the dynamic reserves and the residual dynamic reserves of the gas well.
According to the calculation result of the unsteady seepage theory mentioned above, the current unimpeded flow rate of the gas well is 2 x 104m3D, reasonable production allocation of 0.4-0.5 multiplied by 104m3D, and actual gas production (0.1X 10)4m3The difference is obvious. The current formation pressure of the well is 10.36MPa, and the dynamic reserve is 5300 multiplied by 104m3The residual dynamic reserve is 2150 × 104m3. Therefore, the gas well has higher production potential from short-term yield increase to long-term accumulated gas production, and therefore, the gas well is matched with other related drainage and production processes, and has better economic benefit for recovering the normal production of the gas well.
Step 106: the step is the preferable step of the gas well drainage gas production process. According to the interval of the current stage and the production potential determined in the step 105, a gas well drainage gas production process is further optimized, namely the gas well drainage gas production process which can meet the drainage requirement and has the best economic benefit is selected.
As a specific implementation mode, because the gas well is in the VI area, liquid cannot be effectively drained through the foam drainage process and the optimized tubular column process, and in view of the large production potential of the gas well, the plunger gas lift drainage gas production process matched with the gas well is determined according to the characteristics of different drainage gas production processes, so that liquid drainage of the gas well is assisted, and the productivity of the gas well is released.
Therefore, the process establishes a method for economically and effectively optimizing the drainage gas production process, and the method is easy to implement, strong in operability and good in expansibility.
Therefore, a set of four-line six-area dynamic analysis method is formed on the basis of the analysis principle of a gas well production system according to the years of drainage and gas production working experience of the cattle land gas field, intervention time, effective time and economic benefit of a drainage and gas production process are comprehensively considered, appropriate drainage and gas production process means in different production stages are determined, and gas well production is guided.
The specific embodiments are given above, but the present invention is not limited to the described embodiments. The basic idea of the present invention lies in the above basic scheme, and it is obvious to those skilled in the art that no creative effort is needed to design various modified models, formulas and parameters according to the teaching of the present invention. Variations, modifications, substitutions and alterations may be made to the embodiments without departing from the principles and spirit of the invention, and still fall within the scope of the invention.
The method can be used as a computer program, is stored in a memory in a control module in a drainage and gas production process selection control system of the liquid production natural gas well and can be operated on a processor in the control module.
Claims (12)
1. A method for selecting a drainage gas production process of a liquid production natural gas well is characterized by comprising the following steps:
(1) in a coordinate system formed by daily gas production and bottom hole flowing pressure, drawing inflow curves of different production stages, oil pipe dynamic curves corresponding to the lowest wellhead oil pressure, critical liquid carrying curves and critical bubble carrying curves to form dynamic analysis plates;
(2) selecting related intersection points of the four curves, dividing the chart into a plurality of intervals with different liquid carrying capacity characteristics, and determining a drainage and gas production process corresponding to each interval;
(3) mapping historical production data of the gas well into the chart, determining an interval corresponding to the current production stage of the gas well, and finding a corresponding drainage gas production process;
the inflow curve calculation formula in the step (1) is as follows:
wherein P isDIs an intermediate variable of the formula, an
In the formula: q. q.saofFor unimpeded flow, the unit is 104m3/d；PeThe unit is the stratum pressure at the appointed time point and is MPa; pwfObtaining the bottom hole flowing pressure at a specified time point by a flowing pressure test, wherein the unit is MPa; q. q.sgAcquiring the daily gas production rate of the gas well at a specified time point by using production data, wherein the unit is MPa; alpha is an empirical parameter; the inflow curve of different production stages can be obtained by using the inflow curve calculation formula, and the required data is P corresponding to the production stagee、PwfAnd q isg。
2. The method for selecting the drainage and gas production process of the liquid production natural gas well as claimed in claim 1, wherein the formation pressure and the unimpeded flow rate of the current stage are read in a chart, and the production potential of the gas well is determined by combining the dynamic reserve and the residual dynamic reserve of the gas well.
3. The method for selecting the drainage gas recovery process of the liquid production natural gas well according to claim 2, wherein the drainage gas recovery process which meets the drainage requirement and has the best economic benefit of the gas well is determined according to the interval and the production potential of the current stage.
4. The method for selecting the drainage and gas production process of the liquid production natural gas well according to claim 1, 2 or 3, wherein the calculation formula of the oil pipe dynamic curve is as follows:
wherein the content of the first and second substances,
is an intermediate variable of the formula, an
In the formula: ptfIs the wellhead pressure in MPa; t istfIs the well head temperature in K; pwfObtaining the bottom hole flowing pressure at a specified time point by a flowing pressure test, wherein the unit is MPa; t iswfIs the bottom hole temperature in K;
the compression factor is the average pressure and average temperature of the well head and the well bottom, and is dimensionless; q. q.sgAcquiring the daily gas production rate of the gas well at a specified time point by using production data, wherein the unit is MPa; s is the epidermis coefficient and is dimensionless; and f (x) is a two-phase flow function and is selected according to the actual characteristics of the gas field.
5. The method for selecting the drainage and gas production process of the liquid production natural gas well according to claim 1, 2 or 3, wherein the critical liquid carrying curve and the critical bubble carrying curve have the following calculation formulas:
in the formula: g is the acceleration of gravity; theta is the inclination angle of the shaft and has the unit of degree; z is a natural gas compression factor and is dimensionless; t is the thermodynamic temperature in K; v. ofcl1、vcl2、vcl3Respectively are the critical liquid carrying flow velocity of a straight well section, an inclined section and a horizontal section, and the unit is m3/d；vcb1、vcb2、vcb3Respectively are a straight well section, a deflecting section and a horizontal section, and the unit is m3/d；σlg、σbgRespectively liquid-gas, foam-gas surface tension, with the unit of MT-2；ρl、ρg、ρbRespectively the density of liquid, gas and foam under the condition of specified temperature and pressure, and the unit is Kg/m3(ii) a A is the cross-sectional area of the oil pipe in mm2(ii) a P is a designated pressure in MPa; qcIs the critical liquid/bubble carrying flow, and the unit is m3/d；
Wherein, v iscl1、vcl2And vcl3Substitution vcWhen the position is determined, the critical liquid carrying flow of the vertical well section, the deflecting section and the horizontal section is respectively obtained, and v iscb1、vcb2And vcb3Substitution vcAnd when the device is in position, respectively obtaining the critical bubble carrying flow of the straight well section, the deflecting section and the horizontal section.
6. The method for selecting the drainage and gas production process of the liquid-producing natural gas well as claimed in claim 1, 2 or 3, wherein three inflow curves can be obtained according to different production stages, wherein the first inflow curve is an inflow curve corresponding to the original formation pressure, the second inflow curve is an inflow curve which is intersected with the oil pipe dynamic curve and the critical liquid-carrying curve at the same time, and the third inflow curve is an inflow curve which is intersected with the oil pipe dynamic curve and the critical liquid-carrying curve at the same time;
the relevant intersection points of the four types of curves are selected as follows: the second inflow curve is simultaneously connected with the intersection point of the oil pipe dynamic curve and the critical bubble carrying curve, the intersection point of the second inflow curve and the critical bubble carrying curve, and the third inflow curve is simultaneously connected with the intersection point of the oil pipe dynamic curve and the critical bubble carrying curve;
dividing the chart into 6 intervals according to the relevant intersection points of the four types of curves, wherein the range of the first interval is more than that of the second inflow curve, the right side of the critical liquid carrying curve and the left side of the oil pipe dynamic curve; the range of the second interval is above the second inflow curve, the right side of the critical bubble carrying curve and the left side of the critical liquid carrying curve; the range of the third interval is above the second inflow curve and on the left side of the critical bubble carrying curve; the range of the fourth interval is a closed area formed by the right side of the critical bubble carrying curve below the second inflow curve and above the oil pipe dynamic curve; the range of the fifth interval is below the second inflow curve, above the third inflow curve and on the left side of the critical bubble carrying curve; the range of the sixth interval is a closed area formed below the third inflow curve and above the oil pipe dynamic curve.
7. A selection control system for a drainage and gas production process of a liquid production natural gas well comprises a control module, wherein the control module comprises a memory, a processor and a computer program which is stored in the memory and can be run on the processor, and the selection control system is characterized in that the processor executes the program to realize the following steps:
(1) in a coordinate system formed by daily gas production and bottom hole flowing pressure, drawing inflow curves of different production stages, oil pipe dynamic curves corresponding to the lowest wellhead oil pressure, critical liquid carrying curves and critical bubble carrying curves to form dynamic analysis plates;
(2) selecting related intersection points of the four curves, dividing the chart into a plurality of intervals with different liquid carrying capacity characteristics, and determining a drainage and gas production process corresponding to each interval;
(3) mapping historical production data of the gas well into the chart, determining an interval corresponding to the current production stage of the gas well, and finding a corresponding drainage gas production process;
the inflow curve calculation formula in the step (1) is as follows:
wherein P isDIs an intermediate variable of the formula, an
In the formula: q. q.saofFor unimpeded flow, the unit is 104m3/d；PeThe unit is the stratum pressure at the appointed time point and is MPa; pwfObtaining the bottom hole flowing pressure at a specified time point by a flowing pressure test, wherein the unit is MPa; q. q.sgAcquiring the daily gas production rate of the gas well at a specified time point by using production data, wherein the unit is MPa; alpha is an empirical parameter; the inflow curve of different production stages can be obtained by using the inflow curve calculation formula, and the required data is P corresponding to the production stagee、PwfAnd q isg。
8. The selection control system for the drainage and gas production process of the liquid production natural gas well as the drainage and gas production process of the liquid production natural gas well is characterized in that the formation pressure and the unimpeded flow rate of the current stage are read in a chart, and the production potential of the gas well is determined by combining the dynamic reserve capacity and the residual dynamic reserve capacity of the gas well.
9. The selection control system for the drainage gas recovery process of the liquid production natural gas well is characterized in that the drainage gas recovery process which meets the drainage requirement and has the best economic benefit of the gas well is determined according to the interval of the current stage and the production potential.
10. The selection control system for the drainage and gas production process of the liquid production natural gas well as the gas production process of the liquid production natural gas well as the liquid production process of the liquid production natural gas well as the liquid production process of the liquid production natural gas well as the liquid production process of the claim 7, 8 or 9 is characterized in that the calculation formula of the oil pipe dynamic curve is as follows:
wherein the content of the first and second substances,
is an intermediate variable of the formula, an
In the formula: ptfIs the wellhead pressure in MPa; t istfIs the well head temperature in K; pwfObtaining the bottom hole flowing pressure at a specified time point by a flowing pressure test, wherein the unit is MPa; t iswfIs the bottom hole temperature in K;
the compression factors are the average pressure and average temperature of the bottom of the well head, and are dimensionless; q. q.sgAcquiring the daily gas production rate of the gas well at a specified time point by using production data, wherein the unit is MPa; s is the epidermis coefficient and is dimensionless; and f (x) is a two-phase flow function and is selected according to the actual characteristics of the gas field.
11. The selection control system for the drainage and gas production process of the liquid production natural gas well as the gas production process of the claim 7, 8 or 9 is characterized in that the critical liquid carrying curve and bubble carrying curve carrying the critical bubble carrying curve carrying the critical carrying curve carrying the critical bubble carrying the calculation formula:
in the formula: g is the acceleration of gravity; theta is the inclination angle of the shaft and has the unit of degree; z is a natural gas compression factor and is dimensionless; t is the thermodynamic temperature in K; v. ofcl1、vcl2、vcl3Respectively are the critical liquid carrying flow velocity of a straight well section, an inclined section and a horizontal section, and the unit is m3/d；vcb1、vcb2、vcb3Respectively are a straight well section, a deflecting section and a horizontal section, and the unit is m3/d；σlg、σbgRespectively liquid-gas, foam-gas surface tension, with the unit of MT-2；ρl、ρg、ρbRespectively the density of liquid, gas and foam under the condition of specified temperature and pressure, and the unit is Kg/m3(ii) a A is the cross-sectional area of the oil pipe in mm2(ii) a P is a designated pressure in MPa; qcIs the critical liquid/bubble carrying flow, and the unit is m3/d；
Wherein, v iscl1、vcl2And vcl3Substitution vcWhen the position is determined, the critical liquid carrying flow of the vertical well section, the deflecting section and the horizontal section is respectively obtained, and v iscb1、vcb2And vcb3Substitution vcAnd when the device is in position, respectively obtaining the critical bubble carrying flow of the straight well section, the deflecting section and the horizontal section.
12. The selection control system for the drainage and gas production process of the liquid-producing natural gas well as defined in claim 7, 8 or 9, characterized in that three inflow curves can be obtained according to different production stages, wherein the first inflow curve is an inflow curve corresponding to the original formation pressure, the second inflow curve is an inflow curve which is intersected with both the oil pipe dynamic curve and the critical liquid-carrying curve, and the third inflow curve is an inflow curve which is intersected with both the oil pipe dynamic curve and the critical bubble-carrying curve;
the relevant intersection points of the four types of curves are selected as follows: the second inflow curve is simultaneously connected with the intersection point of the oil pipe dynamic curve and the critical bubble carrying curve, the intersection point of the second inflow curve and the critical bubble carrying curve, and the third inflow curve is simultaneously connected with the intersection point of the oil pipe dynamic curve and the critical bubble carrying curve;
dividing the chart into 6 intervals according to the relevant intersection points of the four types of curves, wherein the range of the first interval is more than that of the second inflow curve, the right side of the critical liquid carrying curve and the left side of the oil pipe dynamic curve; the range of the second interval is above the second inflow curve, the right side of the critical bubble carrying curve and the left side of the critical liquid carrying curve; the range of the third interval is above the second inflow curve and on the left side of the critical bubble carrying curve; the range of the fourth interval is a closed area formed by the right side of the critical bubble carrying curve below the second inflow curve and above the oil pipe dynamic curve; the range of the fifth interval is below the second inflow curve, above the third inflow curve and on the left side of the critical bubble carrying curve; the range of the sixth interval is a closed area formed below the third inflow curve and above the oil pipe dynamic curve.
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| CN111723531A (en) * | 2020-05-25 | 2020-09-29 | 长江大学 | Shale gas reservoir horizontal well critical liquid-carrying gas production rate prediction method and device |
| CN113931621B (en) * | 2020-07-14 | 2023-08-22 | 中国石油天然气股份有限公司 | Method, device and storage medium for determining gas well hydrops information |
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