CN109944582B - Method for analyzing position of stratum containing fractures in shaft - Google Patents
Method for analyzing position of stratum containing fractures in shaft Download PDFInfo
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- CN109944582B CN109944582B CN201811637465.2A CN201811637465A CN109944582B CN 109944582 B CN109944582 B CN 109944582B CN 201811637465 A CN201811637465 A CN 201811637465A CN 109944582 B CN109944582 B CN 109944582B
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Abstract
The invention provides a method for analyzing a position of a stratum containing fractures in a shaft, which comprises the steps of placing a pressure sensor at a specific position in the shaft, acquiring a hydraulic value at the position by using the sensor, rapidly and accurately analyzing a change curve of hydraulic pressure along with time, a change curve of hydraulic pressure change rate along with time and a change curve of a dynamic liquid level along with time in the shaft to obtain a leakage or water burst position of the shaft containing the fractures, calculating corresponding leakage or water burst amount according to the size of the shaft, only arranging the pressure sensor at the bottom of the shaft, and acquiring hydraulic data to indirectly obtain the position of a leakage layer or a water burst layer and the corresponding amount.
Description
Technical Field
The invention relates to a method for analyzing the position of a stratum containing fractures in a shaft.
Background
In the exploration and development of domestic oil and gas resources at present, the condition that a well is frequently leaked or gushed due to the fact that a drill meets a stratum containing fractures is often encountered, and the condition that an upper water-bearing layer flows to a coal bed is encountered in the drainage and exploitation of coal bed gas with shallow burial depth.
In order to solve the problems encountered in the above engineering, it is necessary to provide an analysis method for rapidly and accurately obtaining the position of a leakage layer or a water inrush layer and quantitatively calculating the corresponding leakage amount or water inrush amount, so as to provide a powerful technical support for rapidly providing a countermeasure for solving the leakage or water inrush in a fractured stratum in the exploration and development of oil and gas resources.
Disclosure of Invention
In order to solve the technical problems, the invention provides a method for analyzing the position of a stratum containing fractures in a shaft, which comprises the steps of placing a pressure sensor at a specific position in the shaft, acquiring a hydraulic value at the position by using the sensor, rapidly and accurately analyzing the position of the shaft with the fractures or water burst of the stratum containing fractures by analyzing a change curve of the hydraulic pressure along with time, a change curve of the hydraulic pressure change rate along with time and a change curve of a working fluid level in the shaft along with time, and calculating the leakage or water burst at each position according to the size of the shaft.
The invention is realized by the following technical scheme.
The invention provides a method for analyzing the position of a stratum containing fractures in a shaft, which comprises the following steps:
s1, lowering the pressure sensor in the shaft, and correcting the lowering vertical depth H of the pressure sensor;
s2, collecting the time-varying data of the well bottom hydraulic pressure;
s3, collecting the fluid in the well bore and measuring the density of the fluid;
s4, calculating and analyzing pressure sensor data in the shaft;
s5, determining the position of each leakage layer or water inrush layer in the shaft;
s6, calculating the corresponding leakage quantity or water inflow quantity Q of each leakage layer or water inflow layer in the shaft;
further, the fluid in the wellbore is collected and the density thereof is measured, which can be considered as the following cases according to the actual situation:
a1, if the leakage condition occurs in the shaft in the drilling process, the density value of the fluid in the shaft is the density value of the drilling fluid;
a2, if water gushing occurs in the shaft during drilling, collecting fluid samples at different positions in the shaft, measuring the density of each fluid sample and calculating the average value as the density of the fluid in the shaft;
a3, if the coal bed gas well has water gushing, the density value of the fluid in the shaft is the density value of the produced water;
further, the step of calculating and analyzing the data of the pressure sensor in the well bore comprises the following steps:
s4.1, according to the bottom hole hydraulic data collected in the step S2, making a change curve of the hydraulic pressure P in the shaft at the pressure sensor along with the time T, and making a change curve of the bottom hole hydraulic pressure change rate dP/dT along with the time T;
s5.2, determining a density value rho of fluid in a corresponding oil-gas well shaft, the hydraulic pressure P in the shaft collected in the step S2 and the lowering vertical depth H of the pressure sensor in the step S1 according to the step S3 to obtain a change curve of the vertical depth H of the liquid level in the shaft along with the time T;
further, the calculation formula of the vertical depth h of the liquid level in the shaft is as follows:
further, the method for determining the position of each leakage layer or water gushing layer in the shaft is as follows:
s5.1, according to the change curve of the bottom hole hydraulic pressure change rate dP/dT along with the time T, which is made in the step S4.1, the number of inflection points on the curve is the number of the leakage layers or the water inrush layers;
s5.2, according to the change curve of the vertical depth h of the liquid level in the shaft along with the time T, which is made in the step S4.2, and the vertical depth of the inflection point on the change curve of the bottom hole hydraulic pressure change rate dP/dT along with the time T, which is made in the step S4.1, the vertical depth of each leakage layer or water inrush layer can be judged, and then according to the actual well depth corresponding to the vertical depth, the vertical depth is the position of each leakage layer or water inrush layer;
further, the method for calculating the corresponding leakage amount or water inflow amount Q of each leakage layer or water inflow layer in the shaft comprises the following steps:
s6.1, calculating the distance delta h between the leakage or water inrush layers in the shaft according to the positions of the leakage or water inrush layers obtained in the step S5;
s6.2, calculating corresponding leakage amount or water inflow amount Q according to the radius R of the shaft and the time delta t required by the change of the liquid level in the shaft among the positions of each leakage layer or water inflow layer;
further, for several different situations when collecting the fluid in the shaft and measuring the density of the fluid, calculating the leakage or water inflow Q time is divided into the following two steps:
s6.21, calculating the leakage quantity or the water inflow quantity Q for the A1 and A2 according to the following formula:
s6.22, when the leakage quantity or the water inflow quantity Q is calculated for the A3 condition, the calculation is carried out according to the following formula:
wherein R is the inner radius of the technical sleeve, R out Is the outer radius of the oil pipe, r in Is the inner radius of the oil pipe, r r Is the radius of the polish rod.
The invention has the beneficial effects that: the position and the corresponding amount of a leakage layer or a water burst layer can be indirectly obtained only by arranging a pressure sensor at the bottom of a shaft and acquiring hydraulic data, and accurate inflection points can be acquired by acquiring high-precision hydraulic data and short-interval data, so that powerful technical support can be provided for engineering technicians to determine corresponding scheme countermeasures.
Drawings
FIG. 1 is a flow chart of the method of the present invention;
FIG. 2 is the result of analyzing the first water inrush data of a coal-bed gas well in the invention;
FIG. 3 is the result of the analysis of the second water inrush data from a coal bed gas well according to the present invention;
FIG. 4 is the third water inrush data analysis of a coal-bed gas well in accordance with the present invention;
FIG. 5 is a schematic diagram showing the positions and liquid level changes of three water gushing layers of a coal-bed gas well in the invention;
FIG. 6 shows the position of three water inflow layers and the analysis and calculation result of water inflow of the coal-bed gas well in the invention;
table 1 shows the calculation results of the positions of the water inrush layers in the invention;
table 2 shows the calculation results of the water inflow of each water inflow layer in the present invention.
Detailed Description
The technical solution of the present invention is further described below, but the scope of the claimed invention is not limited to the described.
The invention is illustrated by taking a high-water-cut coal-bed gas well as an example.
The first step is as follows: selecting a certain high-water-content coal-bed gas well as a research object;
the second step is that: installing a pressure sensor in the gas well shaft, and accurately correcting the vertical depth H of the pressure sensor;
the third step: the method comprises the steps that hydraulic pressure change data in a shaft when a pump is stopped for three times are collected by a pressure sensor in the shaft, and the data collected for the first time are taken as an example;
the fourth step: analyzing and calculating the acquired result, making a change curve of the hydraulic pressure P in the shaft at the pressure sensor along with the time T, and making a change curve of the bottom hole hydraulic pressure change rate dP/dT along with the time T as shown in FIG. 2, wherein the change curve of dP/dT along with the time reflects the replenishment rate of the water inrush layer in the shaft, and the change situation of the position of the water inrush layer is judged according to the change situation of the pressure change rate dP/dT, and the change situation analysis is as follows: the positive direction of the dP/dT value is increased, which indicates that the 'exogenous water' begins to invade the shaft; the dP/dT value reaches the maximum value, which indicates that the liquid level position at the moment begins to contact the first water inrush layer A; the dP/dT value is decreased in a positive direction, which indicates that the liquid level is higher than the first water gushing layer A; the forward descending turning point of the dP/dT value indicates that the liquid level in the shaft begins to contact the second water inrush layer B; when the positive direction of the dP/dT value tends to be stable, the liquid level tends to be stable D, and the liquid level is almost close to the ground surface at the moment; the value dP/dT becomes larger in the negative direction, which indicates that the liquid level begins to descend; the point C is turned on in the negative direction of the dP/dT value, which indicates that the drainage speed and the replenishment speed start to be stiff, and the positive direction causes the liquid level to be reduced and slowed down as the liquid level is reduced to the second water gushing layer B and the replenishment water amount starts to be increased; the negative change rate tends to be stable, which indicates that the height of the liquid column in the well and the liquid level outside the well reestablish the balance.
The fifth step: according to the analysis of the fourth step, the position and the water inflow amount of each water inflow layer are calculated by combining the graph 2:
a. first water gushing layer: the peak value of the dP/dT curve is changed between 0.0128 and 0.0124MPa/min, the corresponding hydraulic pressure P is 0.704 to 0.896MPa, and the position change range of the first water gushing layer is 115.7 to 134.8m, the liquid level rises after the pump is stopped 1 34.1-53.3 m, the time T required for the process is 30-45 min, and the increased fluid volume V in the shaft 1 The calculation formula is as follows:
V 1 ＝S·Δh 1
S＝πR 2 -π(r out 2 -r in 2 )-πr r 2
where S is the effective fluid cross-sectional area in the wellbore, V 1 Is the increased fluid volume in the wellbore (sum of water gushes from the three water gushing layers), Δ h 1 The rising height from the static liquid level position to the first water gushing layer, R is the radius of the shaft, R out Is the outer radius of the oil pipe, r in The total water inflow amount of the three water inflow layers at the first water inflow layer is 1.07m calculated according to a calculation formula of the water inflow amount Q of the coal-bed gas well and is the inner radius of an oil pipe 3 /h；
b. Second water gushing layer: the inflection point of the dP/dT curve changes between 0.0040 and 0.0032MPa/min, the corresponding hydraulic pressure P is 1.378 to 1.446MPa, the position change range of the second water inrush layer is 60.7 to 67.5m, and the height delta h of the liquid level rise after the pump is stopped 2 55.0-67.3 m, the time T required by the process is 90-85 min according to V in a 1 The total water inflow of the two water inrush layers above the second water inrush layer is calculated to be 0.65m by a calculation formula and a coal bed gas well water inflow Q calculation formula 3 /h；
c. Third water gushing layer: the pressure of the liquid column is 1.928MPa, the corresponding liquid level rising height is 60.7-67.5 m, the time T required by the process is 385-390 min according to V in a 1 Calculating the water inflow at the first water inflow layer to be 0.16m by a calculation formula and a coal bed gas well water inflow Q calculation formula 3 /h。
According to the calculation, the water inflow of the third water inflow layer is 0.16m 3 H, the water inflow of the second water inflow layer is 0.49m 3 The water inflow amount of the first water inflow layer is 0.42m 3 /h。
And repeating the above process to calculate results of the second data acquisition and the third data acquisition, as shown in fig. 3 and 4, making three groups of calculation results into a table, as shown in tables 1 and 2, wherein a schematic diagram of the liquid level rise after the pumping of the coal-bed gas well is shown in fig. 5, and analysis calculation results of three water inrush layer positions and water inrush amount of the coal-bed gas well are shown in fig. 6.
Claims (2)
1. A method for analyzing the position of a stratum containing fractures in a shaft is characterized by comprising the following steps:
s1, lowering the pressure sensor in the shaft, and correcting the lowering vertical depth H of the pressure sensor;
s2, collecting the time-varying data of the well bottom hydraulic pressure;
s3, collecting the fluid in the well bore and measuring the density of the fluid;
s4, making a change curve of the bottom hole hydraulic pressure change rate dP/dT along with the time T and a change curve of the vertical depth h of the liquid level in the shaft along with the time T;
s5, determining the position of each leakage layer or water inrush layer in the shaft;
s6, calculating the leakage or water inflow Q of each leakage layer or water inflow layer in the shaft;
the steps of making a change curve of the bottom hole hydraulic pressure change rate dP/dT along with the time T and a change curve of the vertical depth h of the liquid level in the shaft along with the time T are as follows:
s4.1, according to the bottom hole hydraulic data collected in the step S2, making a change curve of the hydraulic pressure P in the shaft at the pressure sensor along with the time T and a change curve of the bottom hole hydraulic pressure change rate dP/dT along with the time T;
s4.2, determining a density value rho of fluid in a corresponding oil-gas well shaft, the hydraulic pressure P in the shaft collected in the step S3 and the lowering vertical depth H of the pressure sensor in the step S2 according to the step S4 to obtain a change curve of the vertical depth H of the liquid level in the shaft along with the time T;
the calculation formula of the vertical depth h of the liquid level in the shaft is as follows:
the location of each thief zone or gush zone within the wellbore is determined by the following method:
s5.1, according to the change curve of the bottom hole hydraulic pressure change rate dP/dT along with the time T, which is made in the step S4.1, the number of inflection points on the curve is the number of leakage layers or water inrush layers;
and S5.2, judging the vertical depth of each leakage layer or water inrush layer according to the change curve of the vertical depth h of the liquid level in the shaft along with the time T, which is made in the step S4.2, and the vertical depth of the inflection point on the change curve of the bottom hole hydraulic pressure change rate dP/dT along with the time T, which is made in the step S4.1, and then determining the position of each leakage layer or water inrush layer according to the actual well depth corresponding to the vertical depth.
2. The method of analyzing the location of a fracture-containing formation in a wellbore of claim 1, wherein calculating the respective leak-off or water inflow Q for each leak-off or water inflow in the wellbore is performed by:
s6.1, calculating the distance delta h between the leakage or water inrush layers in the shaft according to the positions of the leakage or water inrush layers obtained in the step S5;
s6.2, calculating the leakage amount or the water inflow amount Q according to the radius R of the shaft and the time delta t required by the liquid level in the shaft to change between the positions of the leakage layers or the water inflow layers.
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| CN101070756B (en) * | 2006-11-29 | 2010-09-08 | 中国石油大学(北京) | Petroleum well-drilling loss-zone position detection method and apparatus |
| CN101338668B (en) * | 2008-08-29 | 2012-02-22 | 北京豪仪测控工程有限公司 | Method and system for determining drilling fluids leakage and overflow |
| CN101446194B (en) * | 2008-12-30 | 2012-07-04 | 西安石油大学 | Drilling fluid leak hunting device based on transient electromagnetic method |
| CN101864924A (en) * | 2010-06-30 | 2010-10-20 | 中国地质大学（武汉） | Method for drilling spot plugging |
| CN102168551B (en) * | 2011-01-19 | 2014-04-16 | 杨平 | Device and method for continuously measuring working fluid level depth of oil well and continuously metering produced liquid |
| CN104111208B (en) * | 2014-01-09 | 2016-11-23 | 中国石油化工股份有限公司 | Water-base drilling fluid shaft bottom density static Forecasting Methodology |
| CN106351650A (en) * | 2015-07-16 | 2017-01-25 | 中国石油化工股份有限公司 | Calculation method of borehole sloughing pressure applicable to the bedding fractured stratum |
| CN107191179A (en) * | 2016-03-15 | 2017-09-22 | 中国石油化工股份有限公司 | A kind of Oil/gas Well hydrodynamic face method of testing |
| CN105672997A (en) * | 2016-03-18 | 2016-06-15 | 西南石油大学 | Monitoring method for formation leakage of drilling fluid |
| CN106285646B (en) * | 2016-09-09 | 2019-10-15 | 中国石油大学(华东) | Drilling well loss horizon recognition methods based on multi-information fusion |
| CN106761699A (en) * | 2017-03-13 | 2017-05-31 | 中国石油集团钻井工程技术研究院 | A kind of leakage real-time detecting system for controlled pressure drilling |
| CN106703789A (en) * | 2017-03-16 | 2017-05-24 | 中国石油化工股份有限公司 | Leakage well drilling fluid level and leakage pressure monitoring system and method |
| CN107246262A (en) * | 2017-04-11 | 2017-10-13 | 西南石油大学 | A kind of leakage amount detecting device and method for simulating oil well pump working environment |
| CN107288603A (en) * | 2017-06-13 | 2017-10-24 | 北京大学 | A kind of experimental provision of simulation fracture turnaround fracture and its application |
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| CN108955649B (en) * | 2018-05-21 | 2020-06-16 | 中国矿业大学 | Method for predicting water inflow in roof process of coal mine working face |
| CN108708711A (en) * | 2018-05-25 | 2018-10-26 | 贵州省非常规天然气勘探开发利用工程研究中心有限公司 | A kind of method of accurate determining loss horizon |
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