CN113605878B - Stratum information inversion system and method in pressure control drilling process - Google Patents
Stratum information inversion system and method in pressure control drilling process Download PDFInfo
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- CN113605878B CN113605878B CN202110909145.3A CN202110909145A CN113605878B CN 113605878 B CN113605878 B CN 113605878B CN 202110909145 A CN202110909145 A CN 202110909145A CN 113605878 B CN113605878 B CN 113605878B
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
- E21B21/08—Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/06—Measuring temperature or pressure
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/06—Measuring temperature or pressure
- E21B47/07—Temperature
Abstract
The invention provides a stratum information inversion system and method in a pressure control drilling process. By means of the system, control of the fluid flow process and accurate measurement of flow parameters, and then a real-time inversion method of stratum information (comprising stratum pressure and permeability) is constructed based on the measured parameters; the system and the method can determine the formation pressure and the permeability in the pressure control drilling process, and solve the problem that the conventional method cannot cooperatively invert the formation information.
Description
Technical Field
The invention relates to a stratum information inversion system and method in a pressure control drilling process, and belongs to the field of petroleum and natural gas engineering.
Background
Formation information evaluation is a key content of risk control of well completion in the field of oil and gas well engineering, and particularly relates to well control scheme design after overflow, including well control method selection, well control parameter (well control fluid density, displacement) design and the like. And the formation pressure information is timely and accurately acquired, so that overflow is rapidly treated, and the risk of blowout is reduced. In addition, accurate prediction of formation pressure and permeability properties can provide theoretical guidance for follow-up test production and optimization of production system.
In current drilling and completion processes, formation pressure is estimated primarily as a function of Guan Jingqiu pressure. But it is limited mainly by the following: (1) the well closing operation can cause the leakage of the stratum or the out-of-control of the well by the limitation of the stratum strength or the pressure endurance capacity of well control equipment, and an effective well closing pressure change curve cannot be obtained; (2) the back pressure valve is not arranged in the drilling tool, so that the gas in the drilling rod is contained, and the stratum pressure value predicted based on Guan Jingli pressure is larger; (3) under the conditions of small stratum permeability or large overflow amount, guan Jingli pressure and casing pressure are stable for more than 2-3 hours, so that the well killing time is muster. In addition to the above limitations, conventional methods that rely on shut-in pressure recovery curve analysis can only be used for formation pressure evaluation and cannot invert reservoir permeability.
Disclosure of Invention
In order to overcome the defects in the prior art, the invention provides a stratum information inversion system and method in the pressure control drilling process. By means of control of the fluid flow process and accurate measurement of flow parameters, a real-time inversion method of formation information (including formation pressure and permeability) is then constructed based on the measured parameters; the method can determine the formation pressure and the permeability in the pressure control drilling process, and solves the problem that the existing method can not cooperatively invert the formation information.
In order to achieve the above purpose, the technical scheme adopted by the invention is as follows:
the stratum information inversion system in the pressure control drilling process is characterized by comprising a ground flow parameter measurement system and a data information inversion system;
the surface flow parameter measurement system comprises: the well head four-way joint, the rotary control head, the throttle manifold, the gas-liquid separator, the temperature sensor, the pressure sensor, the venturi tube, the liquid discharge pipeline pressure gauge, the mass flowmeter, the slurry pond, the slurry pump and the vertical pipe pressure gauge;
the wellhead four-way joint is arranged at the top of the wellhead, the rotary control head wraps the drill rod, the surface of the rotary control head is provided with a rotary control head discharge pipeline, and the rotary control head discharge pipeline is communicated with the annular space of the shaft; the choke manifold is connected with the rotary control head exhaust pipeline through a choke manifold input pipeline; the choke manifold is connected with the gas-liquid separator through a choke manifold output pipeline; the upper part of the gas-liquid separator is connected with an exhaust pipeline, and a temperature sensor, a pressure sensor and a venturi tube are arranged on the exhaust pipeline; the lower part of the gas-liquid separator is connected with the mud pit through a liquid discharge pipeline, and a liquid discharge pipeline pressure gauge and a mass flowmeter are arranged on the liquid discharge pipeline; the drill rod is connected with a slurry pump through a slurry pump output pipeline, a riser pressure gauge is arranged on the slurry pump output pipeline, and the slurry pump is connected with a slurry tank through a slurry pump input pipeline;
the data information inversion system includes: a data acquisition pipeline, a computer and a display;
the data acquisition pipeline is connected with the computer and the flow parameter measuring equipment, the flow parameter measuring equipment is a temperature sensor, a pressure sensor, a venturi tube, a liquid discharge pipeline pressure gauge, a mass flowmeter and a riser pressure gauge, and flow parameter measuring data are transmitted to the computer; the computer performs stratum information inversion according to the obtained flow parameter measurement data to obtain stratum pressure and permeability information; the display is connected with the computer and is used for intuitively outputting stratum information inversion results, namely stratum pressure and permeability information.
According to the invention, the rotary control head is used for wrapping a drill string, realizing dynamic sealing in the pressure control drilling process and providing pressure control. The choke manifold adopts the prior art to throttle the fluid returned from the well bore annulus and simultaneously control the annulus pressure. The gas-liquid separator is mainly used for separating gas and drilling liquid phase under the action of gravity. The venturi is used to measure the flow of gas in the exhaust line. The mass flowmeter is used for measuring the flow of the drilling fluid returned from the drainage pipeline.
According to the invention, the gas-liquid separator is a vertical gas-liquid separator, the upper part of the gas-liquid separator is a hemispherical body, and the lower part of the gas-liquid separator is a cylinder; the top end of the hemisphere is connected with an exhaust pipeline, and the bottom surface of the cylinder is connected with a liquid discharge pipeline.
According to the invention, a gate valve is also arranged on the output pipeline of the choke manifold.
According to the invention, the connection of the data acquisition line to the flow parameter measuring device is sufficient according to the prior art. The computer is used for analyzing the formation pressure and permeability information by adopting the inventive formation information inversion method; the display is connected with the computer and is mainly used for intuitively outputting stratum information inversion results in the process of continuously enriching the measurement data.
The working method of the stratum information inversion system in the pressure control drilling process comprises the following steps:
under the driving action of the slurry pump, drilling fluid in the slurry tank sequentially flows through the slurry pump input pipeline, the slurry pump output pipeline and the riser pressure gauge to enter the drill rod, flows in the drill rod from top to bottom, and returns out through the drill bit water hole to enter the shaft annulus. When the formation pressure is greater than the fluid pressure at the bottom of the well, reservoir gas invades the wellbore from the formation under the action of the pressure differential; the invaded gas and drilling fluid flow in the well bore annulus from bottom to top, enter a choke manifold through a rotary control head exhaust pipeline and a choke manifold input pipeline, and then flow into a gas-liquid separator for separation through a choke manifold output pipeline; the separated gas flows out from the exhaust pipeline, and the flow, the temperature and the pressure are monitored in real time; the separated liquid phase flows out of the liquid discharge pipeline, the flow and the pressure are monitored in real time, and the liquid phase enters the slurry pool through the liquid discharge pipeline; the measured flow parameters, namely the temperature, pressure and flow of the gas, the pressure and flow of the liquid phase are led into a computer through a data acquisition pipeline, and are processed and analyzed through stratum information inversion, so that stratum pressure and permeability information is obtained through inversion.
The invention also provides a stratum information inversion method, which comprises the following steps:
(1) Determining engineering parameters required by inversion of stratum information according to on-site drilling construction data;
(2) Analyzing the circulation time of drilling fluid in a shaft, and calculating the time for the drilling fluid to circulate for one week by adopting a formula i:
t cir ＝(V DP +V A )/Q in i
wherein: t is t cir The time spent for one week of drilling fluid circulation, i.e. the time from the injection of drilling fluid by the drill pipe until the drilling fluid returns from the annulus, s; v (V) DP Is the internal volume of the drill rod, m 3 ；V A Is the annular inner volume, m 3 ；Q in Displacement of drilling fluid injected into drill rod, m 3 And/s. The displacement of drilling fluid injected into the drill pipe is determined according to the pumping stroke and the stroke of the slurry pump.
(3) Real-time measurement of wellhead drilling fluid injection pressure P using riser manometer injection Calculating the corresponding real-time bottom hole pressure P by adopting a formula ii wf ：
Wherein: p (P) wf Is bottom hole pressure, pa; p (P) injection Pa is the injection pressure; ρ L To density of drilling fluid, kg/m 3 The method comprises the steps of carrying out a first treatment on the surface of the g is 9.8m/s 2 ；μ L Is the plastic viscosity of the drilling fluid, pa.s; the integral variable L is different depths in the shaft, m; l (L) w Is the well depth, m; d, d c The inner diameter of the drill rod or the drill collar, m; determining d from different depths L within a wellbore c I.e. the inner diameter of the drill rod or drill collar corresponding to the depth L of the shaft; q (Q) in The meaning of (2) is as in formula i.
(4) The ground flow parameter measuring system is adopted to measure and record the gas phase displacement Q in the exhaust pipeline connected with the upper part of the gas-liquid separator in real time g,out Pressure P g,out Temperature T g,out Drilling fluid displacement Q in liquid discharge pipeline connected with lower part of gas-liquid separator L,out And pressure P L,out ；
(5) Analyzing the real gas phase flow Q in the annulus return fluid according to the real-time measurement data and the structure of the gas-liquid separator g Flow rate Q of liquid phase L Downhole gas production rate q g ；
The real-time gas phase volume in the gas-liquid separator is calculated using equation iii:
wherein: v (V) g Is the gas phase volume in the gas-liquid separator, m 3 ；V ball Is the volume of the upper hemisphere of the gas-liquid separator, m 3 The method comprises the steps of carrying out a first treatment on the surface of the H is the volume of a space formed by the bottom end of the hemispherical upper part of the gas-liquid separator and the bottom end of the gas-liquid separator, m 3 The method comprises the steps of carrying out a first treatment on the surface of the A is the cross-sectional area of the cylinder of the gas-liquid separator.
The calculation method of the pressure change rate of the gas phase separated by the gas-liquid separator is shown as formula iv, and the calculation method of the pressure change rate of the liquid phase separated by the gas-liquid separator is shown as formula v:
wherein Δt is a time interval, Δt=1s; p (P) 1 g,out And P 2 g,out The pressure of the gas phase in the exhaust line before and after the time interval Deltat, P 1 L,out And P 2 L,out The pressure of the liquid phase in the drain line before and after the time interval deltat, respectively. The rate of pressure change described above is related to the gas intrusion process.
Calculating the change rate of the drilling fluid volume in the gas-liquid separator according to the pressure change in the exhaust pipeline and the drain pipeline, wherein the change rate is shown as a formula vi:
in the standard state, the volume change rate of the gas in the gas-liquid separator is calculated by a gas state equation vii:
wherein: t (T) 0 And P 0 Are standard temperature and standard pressure, namely 273.15K and 101.325KPa.
The calculation of the real-time gas phase flow and liquid phase flow in the annulus return fluid is shown in formulas viii, ix respectively:
Q g ＝Q g,out +V' g viii
Q L ＝Q L,out +V' L ix
calculating downhole gas production rate, i.e., fluid invasion rate q, using equation x g ：
Wherein: t (T) wf Is the fluid temperature at the bottom of the well, K. The fluid temperature at the bottom of the well is obtained using existing methods.
The steps (1) to (5) are used for measuring the real-time bottom hole pressure P in the process of controlling the pressure of the drilling gas to invade wf Rate of fluid intrusion q g And real-time liquid phase flow Q in annulus return fluid L 。
(6) Drilling to a zone depth of deltaz 1 When the drilling is stopped, the drilling is continued, and the injection displacement Q of the drilling fluid is maintained in Constant until the flow rate Q of liquid phase in annulus return fluid L When substantially constant, a steady state is considered to be reached. Thereafter, based on steps (1) - (5), continuously recording the downhole gas production rate q within 10 minutes g And calculate the average value q g1 And establishes the following equation xi;
wherein: k is the reservoir permeability, is an unknown quantity, and is inverted based on the method of the invention, m 2 ；p res Inverting Pa for reservoir pressure, unknown quantity, based on the method in the invention; p is p wf1 For continuously recording the average value of the bottom hole pressure in 10min, determining by adopting the step (3), and Pa; s is the surface coefficient of the reservoir, dimensionless, is related to the pollution degree of the reservoir, and can be evaluated according to the existing method by combining drilling fluid soaking experiments according to the property of the reservoir rock and soil under normal conditions, wherein S=0; t is the time of continuous invasion of gas at the bottom of the well, s, according to the existing gas invasion monitoring means, monitoring the gas invasionTime of generation; γ is euler constant, γ= 0.5772;
is reservoir porosity; mu is the viscosity of the gas in the reservoir, and the bottom hole temperature and the pressure value are estimated according to the prior method, and Pa.s; r is (r) w Is the radius of the shaft, m; c is reservoir pressure coefficient, 1/Pa, and according to geological evaluation before drilling, parameters such as lithology, porosity, fluid type and the like are estimated according to the prior method.
(7) Continuing to drill to the depth of the producing zone to deltaz 2 When the drilling is stopped, the drilling is continued, and the injection displacement Q of the drilling fluid is maintained in Constant until the flow rate Q of liquid phase in annulus return fluid L When substantially constant, a steady state is considered to be reached. Thereafter, based on steps (1) - (5), continuously recording the downhole gas production rate q within 10 minutes g And calculate the average value q g2 And establishes the following equation xii;
wherein p is wf2 To keep track of the average bottom hole pressure over 10 minutes, step (3) was used to determine Pa.
(8) Constructing a numerical solved objective function of reservoir permeability inversion analysis, wherein the objective function is expressed as formula xiii, and solving by adopting a Newton Laplasen iteration method to obtain reservoir permeability K;
(9) Substituting the reservoir permeability K determined in the step (8) into formulas (xi) and (xii), calculating to obtain two reservoir pressure values, and taking an average value to obtain an average reservoir pressure, namely inverting according to a formula xiv to obtain an average value of the formation pressure.
Wherein: k is the reservoir permeability calculated in the step (8), m 2 。
According to the invention, in step (1), the engineering parameters include: well bore structure, wellbore trajectory, drilling tool assembly, zone location, produced gas relative density, geothermal gradient, drilling fluid displacement, drilling fluid density, and the like.
According to the invention, in the step (1), the drilling fluid circulates for one circle to refer to the process that the drilling fluid is injected from a wellhead, flows from top to bottom through a drill rod, enters an annulus from a drill bit water hole at a bottom of the well, and flows from bottom to top until returning from the wellhead.
According to the present invention, it is preferable that in step (6), drilling is performed to a depth of zone Δz 1 ＝H res /3，H res Is the reservoir thickness.
According to the invention, it is preferred that in step (6), the time taken for the drilling fluid to circulate after the drilling is stopped for one week is 1.5 times the time taken for the drilling fluid to circulate for one week during the drilling, i.e. 1.5t cir The steady state is considered to be reached.
According to the present invention, it is preferable that in step (7), drilling is performed to a depth of zone Δz 2 ＝2H res /3，H res Is the reservoir thickness.
According to the invention, it is preferred that in step (7), the time taken for the drilling fluid to circulate after the drilling is stopped for one week is 1.5 times the time taken for the drilling fluid to circulate for one week during the drilling, i.e. 1.5t cir The steady state is considered to be reached.
Compared with the prior art, the invention has the following beneficial effects:
the system and the method can accurately, effectively and timely determine the formation pressure and the permeability in the pressure control drilling process, and solve the problem that the conventional method cannot cooperatively invert the formation information. The method is not limited by stratum strength, pressure resistance and the like, and the safety problem that the pressure required by closing the well is easy to cause the leakage of the stratum or the out-of-control of the well is avoided; the process and the measurement method are simple and suitable for field application.
The system and the method can timely and accurately acquire formation pressure information, are beneficial to quickly treating overflow and reducing blowout risk; accurate prediction of formation pressure and permeability properties can provide basis for well control design and subsequent exploitation system optimization in the well drilling process.
Drawings
FIG. 1 is a schematic diagram of a formation information inversion system in the pressure control drilling process of the present invention;
wherein, 1: drilling fluid; 2: a slurry pool; 3: a mud pump input line; 4: a slurry pump; 5: a mud pump output line; 6: a riser pressure gauge; 7: a drill rod; 8: rotating the control head; 9: a wellhead four-way joint; 10: a drill bit; 11: a formation; 12: formation fluids; 13: an annulus; 14: a choke manifold input line; 15: a choke manifold; 16: a choke manifold output line; 17: a gate valve; 18: a gas-liquid separator; 19: an exhaust line; 20: a drain line; 21: a venturi tube; 22: a pressure sensor; 23: a temperature sensor; 24: a drain line pressure gauge; 25: a mass flowmeter; 26: and a computer.
Detailed Description
For a better understanding of the present invention, reference will be made to the following specific examples. The experimental methods used in the examples are conventional methods unless otherwise specified. The equipment used in the examples and the like are commercially available unless otherwise specified.
Example 1
A stratum information inversion system in the pressure control drilling process is shown in fig. 1, and comprises a ground flow parameter measurement system and a data information inversion system;
the surface flow parameter measurement system comprises: a wellhead four-way valve 9, a rotary control head 8, a throttle manifold 15, a gas-liquid separator 18, a temperature sensor 23, a pressure sensor 22, a venturi tube 21, a drain line pressure gauge 24, a mass flowmeter 25, a mud pit 2, a mud pump 4 and a riser pressure gauge 6;
the wellhead four-way valve 9 is arranged at the top of the wellhead, the rotary control head 8 wraps the drill rod 7, a rotary control head discharge pipeline is arranged on the surface of the rotary control head 8, and the rotary control head discharge pipeline is communicated with the shaft annulus 13; the choke manifold 15 is connected to the rotary control head exhaust line via a choke manifold input line 14; the choke manifold 15 is connected with a gas-liquid separator 18 through a choke manifold output line 16; the upper part of the gas-liquid separator 18 is connected with an exhaust pipeline 19, and a temperature sensor 23, a pressure sensor 22 and a venturi tube 21 are arranged on the exhaust pipeline 19; the lower part of the gas-liquid separator 18 is connected with the mud pit 2 through a liquid discharge pipeline 20, and a liquid discharge pipeline pressure gauge 24 and a mass flowmeter 25 are arranged on the liquid discharge pipeline 20; the drill rod 7 is connected with the slurry pump 4 through a slurry pump output pipeline 5, a riser pressure gauge 6 is arranged on the slurry pump output pipeline 5, and the slurry pump 4 is connected with the slurry tank 2 through a slurry pump input pipeline 3;
the rotary control head 8 is of prior art for wrapping the drill string, achieving dynamic sealing during pressure control drilling, and providing pressure control. The choke manifold 15 is prior art to choke the flow back out of the wellbore annulus 13 while controlling the annulus pressure. The gas-liquid separator 18 is primarily used to separate gas and drilling fluid phases under the force of gravity. The venturi 21 is used to measure the flow of gas in the exhaust line. The mass flow meter 25 is used to measure the flow of drilling fluid back out of the drainage line.
The gas-liquid separator 18 is a vertical gas-liquid separator, the upper part is a hemispherical body, and the lower part is a cylinder; the top of the hemisphere is connected with an exhaust pipeline 19, and the bottom of the cylinder is connected with a liquid discharge pipeline 20. A gate valve 17 is also provided on the choke manifold outlet line 16.
The data information inversion system includes: a data acquisition pipeline, a computer 26, a display;
the data acquisition pipeline is connected with a computer 26 and flow parameter measuring equipment, wherein the flow parameter measuring equipment comprises a temperature sensor 23, a pressure sensor 22, a venturi tube 21, a liquid discharge pipeline pressure meter 24, a mass flowmeter 25 and a vertical pipe pressure meter 6, and flow parameter measuring data are transmitted to the computer 26; the computer 26 performs inversion of formation information according to the method of example 2 based on the obtained flow parameter measurement data to obtain formation pressure and permeability information; the display is connected to the computer 26 for visually outputting inversion results of formation information, i.e., formation pressure and permeability information.
The connection of the data acquisition line to the flow parameter measuring device is according to the prior art. The computer 26 is used to analyze formation pressure and permeability information using the inversion method of formation information of inventive example 2; the display is connected with the computer 26 and is mainly used for visually outputting stratum information inversion results in the process of continuously enriching the measured data.
The working method of the stratum information inversion system comprises the following steps:
under the driving action of the slurry pump 4, the drilling fluid 1 in the slurry tank 2 sequentially flows through the slurry pump input pipeline 3, the slurry pump 4, the slurry pump output pipeline 5 and the riser pressure gauge 6 to enter the drill pipe 7, flows in the drill pipe 7 from top to bottom, and returns out through the drill bit water hole to enter the shaft annular space 13. When the formation pressure is greater than the fluid pressure at the bottom of the well, reservoir gas invades the wellbore from the formation under the action of the pressure differential; the invaded gas and drilling fluid flow in the well bore annulus from bottom to top, enter the choke manifold 15 through the rotary control head exhaust line and the choke manifold input line 14, and then flow into the gas-liquid separator 18 for separation through the choke manifold output line 16; the separated gas flows out of the exhaust pipeline 19 and is monitored in real time for flow, temperature and pressure; the separated liquid phase flows out of the liquid discharge pipeline 20, and the flow and the pressure are monitored in real time, and the liquid phase enters the mud pit 2 through the liquid discharge pipeline 20; the measured flow parameters, i.e., temperature, pressure, flow of gas, pressure, flow of liquid phase, are directed through the data acquisition line to the computer 26 for processing analysis by inversion of formation information (method of example 2), which is inverted to obtain formation pressure and permeability information.
Example 2
A method of inversion of formation information, comprising the steps of:
(1) Determining engineering parameters required by inversion of stratum information according to on-site drilling construction data; the engineering parameters include: well bore structure, wellbore trajectory, drilling tool assembly, zone location, produced gas relative density, geothermal gradient, drilling fluid displacement, drilling fluid density, and the like.
(2) Analyzing the circulation time of drilling fluid in a shaft, and calculating the time for the drilling fluid to circulate for one week by adopting a formula i:
t cir ＝(V DP +V A )/Q in i
wherein: t is t cir The time spent for one week of drilling fluid circulation, i.e. the time from the injection of drilling fluid by the drill pipe until the drilling fluid returns from the annulus, s; v (V) DP Is the internal volume of the drill rod, m 3 ；V A Is the annular inner volume, m 3 ；Q in Displacement of drilling fluid injected into drill rod, m 3 And/s. The displacement of drilling fluid injected into the drill pipe is determined according to the pumping stroke and the stroke of the slurry pump.
(3) Real-time measurement of wellhead drilling fluid injection pressure P using riser manometer injection Calculating the corresponding real-time bottom hole pressure P by adopting a formula ii wf ：
Wherein: p (P) wf Is bottom hole pressure, pa; p (P) injection Pa is the injection pressure; ρ L To density of drilling fluid, kg/m 3 The method comprises the steps of carrying out a first treatment on the surface of the g is 9.8m/s 2 ；μ L Is the plastic viscosity of the drilling fluid, pa.s; the integral variable L is different depths in the shaft, m; l (L) w Is the well depth, m; d, d c The inner diameter of the drill rod or the drill collar, m; determining d from different depths L within a wellbore c I.e. the inner diameter of the drill rod or drill collar corresponding to the depth L of the shaft; q (Q) in The meaning of (2) is as in formula i.
(4) The ground flow parameter measuring system is adopted to measure and record the gas phase displacement Q in the exhaust pipeline connected with the upper part of the gas-liquid separator in real time g,out Pressure P g,out Temperature T g,out Drilling fluid displacement Q in liquid discharge pipeline connected with lower part of gas-liquid separator L,out And pressure P L,out ；
(5) Analyzing the real gas phase flow Q in the annulus return fluid according to the real-time measurement data and the structure of the gas-liquid separator g Flow rate Q of liquid phase L Downhole gas production rate q g ；
The real-time gas phase volume in the gas-liquid separator is calculated using equation iii:
wherein: v (V) g Is the gas phase volume in the gas-liquid separator, m 3 ；V ball Is the volume of the upper hemisphere of the gas-liquid separator, m 3 The method comprises the steps of carrying out a first treatment on the surface of the H is the volume of a space formed by the bottom end of the hemispherical upper part of the gas-liquid separator and the bottom end of the gas-liquid separator, m 3 The method comprises the steps of carrying out a first treatment on the surface of the A is the cross-sectional area of the cylinder of the gas-liquid separator.
The calculation method of the pressure change rate of the gas phase separated by the gas-liquid separator is shown as formula iv, and the calculation method of the pressure change rate of the liquid phase separated by the gas-liquid separator is shown as formula v:
wherein Δt is a time interval, Δt=1s; p (P) 1 g,out And P 2 g,out The pressure of the gas phase in the exhaust line before and after the time interval Deltat, P 1 L,out And P 2 L,out The pressure of the liquid phase in the drain line before and after the time interval deltat, respectively. The rate of pressure change described above is related to the gas intrusion process and may be positive or negative.
Calculating the change rate of the drilling fluid volume in the gas-liquid separator according to the pressure change in the exhaust pipeline and the drain pipeline, wherein the change rate is shown as a formula vi:
in the standard state, the volume change rate of the gas in the gas-liquid separator is calculated by a gas state equation vii:
wherein: t (T) 0 And P 0 Are standard temperature and standard pressure, namely 273.15K and 101.325KPa.
The calculation of the real-time gas phase flow and liquid phase flow in the annulus return fluid is shown in formulas viii, ix respectively:
Q g ＝Q g,out +V' g viii
Q L ＝Q L,out +V' L ix
calculating downhole gas production rate, i.e., fluid invasion rate q, using equation x g ：
Wherein: t (T) wf Is the fluid temperature at the bottom of the well, K. The fluid temperature at the bottom of the well is obtained using existing methods.
The steps (1) to (5) are used for measuring the real-time bottom hole pressure P in the process of controlling the pressure of the drilling gas to invade wf Rate of fluid intrusion q g And real-time liquid phase flow Q in annulus return fluid L 。
(6) Drilling to a zone depth of deltaz 1 ＝H res Time/3 (H) res For reservoir thickness), stopping drilling continues, maintaining drilling fluid injection displacement Q in Constant, when the drilling fluid circulates for 1.5 times the drilling fluid circulates for one week in the drilling process, namely 1.5t cir At this time, the flow rate Q of the liquid phase in the annulus return fluid L Substantially constant, a steady state is considered to be reached. Thereafter, based on steps (1) - (5), continuously recording the downhole gas production rate q within 10 minutes g And calculate the average value q g1 And establishes the following equation xi;
wherein: k is the reservoir permeability, is an unknown quantity, and is inverted based on the method of the invention, m 2 ；p res Inverting Pa for reservoir pressure, unknown quantity, based on the method in the invention; p is p wf1 In order to continuously record the average value of the bottom hole pressure within 10 minutes, determining the bottom hole pressure by adopting the step (3), and Pa; s is the surface coefficient of the reservoir, dimensionless, is related to the pollution degree of the reservoir, and can be evaluated according to the existing method by combining drilling fluid soaking experiments according to the property of the reservoir rock and soil under normal conditions, wherein S=0; t is the continuous invasion time of gas at the bottom of a well, s, and the occurrence time of gas invasion is monitored according to the existing gas invasion monitoring means; γ is euler constant, γ= 0.5772;
is reservoir porosity; mu is the viscosity of the gas in the reservoir, and the bottom hole temperature and the pressure value are estimated according to the prior method, and Pa.s; r is (r) w Is the radius of the shaft, m; c is reservoir pressure coefficient, 1/Pa, and according to geological evaluation before drilling, parameters such as lithology, porosity, fluid type and the like are estimated according to the prior method.
(7) Continuing to drill to the depth of the producing zone to deltaz 2 ＝2H res /3(H res For reservoir thickness), stopping drilling, maintaining drilling fluid injection displacement Q in Constant, when the drilling fluid circulates for 1.5 times the drilling fluid circulates for one week in the drilling process, namely 1.5t cir At this time, the flow rate Q of the liquid phase in the annulus return fluid L Substantially constant, a steady state is considered to be reached. Thereafter, based on steps (1) - (5), continuously recording the downhole gas production rate q within 10 minutes g And calculate the average value q g2 And establishes the following equation xii;
wherein p is wf2 To continuously record the average value of the bottom hole pressure in 10min, the bottom hole pressure is determined by adopting the step (3)，Pa。
(8) Constructing a numerical solved objective function of reservoir permeability inversion analysis, wherein the objective function is expressed as formula xiii, and solving by adopting a Newton Laplasen iteration method to obtain reservoir permeability K;
(9) Substituting the reservoir permeability K determined in the step (8) into formulas (xi) and (xii), calculating to obtain two reservoir pressure values, and taking an average value to obtain an average reservoir pressure, namely inverting according to a formula xiv to obtain an average value of the formation pressure.
Wherein: k is the reservoir permeability calculated in the step (8), m 2 。
Claims (7)
1. The stratum information inversion system in the pressure control drilling process is characterized by comprising a ground flow parameter measurement system and a data information inversion system;
the surface flow parameter measurement system comprises: the well head four-way joint, the rotary control head, the throttle manifold, the gas-liquid separator, the temperature sensor, the pressure sensor, the venturi tube, the liquid discharge pipeline pressure gauge, the mass flowmeter, the slurry pond, the slurry pump and the vertical pipe pressure gauge;
the wellhead four-way joint is arranged at the top of the wellhead, the rotary control head wraps the drill rod, the surface of the rotary control head is provided with a rotary control head discharge pipeline, and the rotary control head discharge pipeline is communicated with the annular space of the shaft; the choke manifold is connected with the rotary control head exhaust pipeline through a choke manifold input pipeline; the choke manifold is connected with the gas-liquid separator through a choke manifold output pipeline; the upper part of the gas-liquid separator is connected with an exhaust pipeline, and a temperature sensor, a pressure sensor and a venturi tube are arranged on the exhaust pipeline; the lower part of the gas-liquid separator is connected with the mud pit through a liquid discharge pipeline, and a liquid discharge pipeline pressure gauge and a mass flowmeter are arranged on the liquid discharge pipeline; the drill rod is connected with a slurry pump through a slurry pump output pipeline, a riser pressure gauge is arranged on the slurry pump output pipeline, and the slurry pump is connected with a slurry tank through a slurry pump input pipeline;
the data information inversion system includes: a data acquisition pipeline, a computer and a display;
the data acquisition pipeline is connected with the computer and the flow parameter measuring equipment, the flow parameter measuring equipment is a temperature sensor, a pressure sensor, a venturi tube, a liquid discharge pipeline pressure gauge, a mass flowmeter and a riser pressure gauge, and flow parameter measuring data are transmitted to the computer; the computer performs stratum information inversion according to the obtained flow parameter measurement data to obtain stratum pressure and permeability information; the display is connected with the computer and is used for intuitively outputting stratum information inversion results, namely stratum pressure and permeability information;
the working method of the stratum information inversion system in the pressure control drilling process comprises the following steps:
under the driving action of the slurry pump, drilling fluid in the slurry tank sequentially flows through the slurry pump input pipeline, the slurry pump output pipeline and the riser pressure gauge to enter the drill pipe, the drilling fluid flows in the drill pipe from top to bottom, and returns out through the drill bit water hole to enter the annular space of the shaft; when the formation pressure is greater than the fluid pressure at the bottom of the well, reservoir gas invades the wellbore from the formation under the action of the pressure differential; the invaded gas and drilling fluid flow in the well bore annulus from bottom to top, enter a choke manifold through a rotary control head exhaust pipeline and a choke manifold input pipeline, and then flow into a gas-liquid separator for separation through a choke manifold output pipeline; the separated gas flows out from the exhaust pipeline, and the flow, the temperature and the pressure are monitored in real time; the separated liquid phase flows out of the liquid discharge pipeline, the flow and the pressure are monitored in real time, and the liquid phase enters the slurry pool through the liquid discharge pipeline; the measured flow parameters, namely the temperature, pressure and flow of the gas, the pressure and flow of the liquid phase are led into a computer through a data acquisition pipeline, and are processed and analyzed through stratum information inversion, so that stratum pressure and permeability information is obtained through inversion;
the stratum information inversion method comprises the following steps:
(1) Determining engineering parameters required by inversion of stratum information according to on-site drilling construction data;
(2) Analyzing the circulation time of drilling fluid in a shaft, and calculating the time for the drilling fluid to circulate for one week by adopting a formula i:
t cir ＝(V DP +V A )/Q in i
wherein: t is t cir The time spent for one week of drilling fluid circulation, i.e. the time from the injection of drilling fluid by the drill pipe until the drilling fluid returns from the annulus, s; v (V) DP Is the internal volume of the drill rod, m 3 ；V A Is the annular inner volume, m 3 ；Q in Displacement of drilling fluid injected into drill rod, m 3 /s；
(3) Real-time measurement of wellhead drilling fluid injection pressure P using riser manometer injection Calculating the corresponding real-time bottom hole pressure P by adopting a formula ii wf ：
Wherein: p (P) wf Is bottom hole pressure, pa; p (P) injection Pa is the injection pressure; ρ L To density of drilling fluid, kg/m 3 The method comprises the steps of carrying out a first treatment on the surface of the g is 9.8m/s 2 ；μ L Is the plastic viscosity of the drilling fluid, pa.s; the integral variable L is different depths in the shaft, m; l (L) w Is the well depth, m; d, d c The inner diameter of the drill rod or the drill collar, m; q (Q) in Is as defined for formula i;
(4) The ground flow parameter measuring system is adopted to measure and record the gas phase displacement Q in the exhaust pipeline connected with the upper part of the gas-liquid separator in real time g,out Pressure P g,out Temperature T g,out Drilling fluid displacement Q in liquid discharge pipeline connected with lower part of gas-liquid separator L,out And pressure P L,out ；
(5) Analyzing the real gas phase flow Q in the annulus return fluid according to the real-time measurement data and the structure of the gas-liquid separator g Flow rate Q of liquid phase L Downhole gas production rate q g ；
The real-time gas phase volume in the gas-liquid separator is calculated using equation iii:
wherein: v (V) g Is the gas phase volume in the gas-liquid separator, m 3 ；V ball Is the volume of the upper hemisphere of the gas-liquid separator, m 3 The method comprises the steps of carrying out a first treatment on the surface of the H is the volume of a space formed by the bottom end of the hemispherical upper part of the gas-liquid separator and the bottom end of the gas-liquid separator, m 3 The method comprises the steps of carrying out a first treatment on the surface of the A is the cross-sectional area of the cylinder of the gas-liquid separator;
the calculation method of the pressure change rate of the gas phase separated by the gas-liquid separator is shown as formula iv, and the calculation method of the pressure change rate of the liquid phase separated by the gas-liquid separator is shown as formula v:
wherein Δt is a time interval, Δt=1s; p (P) 1 g,out And P 2 g,out The pressure of the gas phase in the exhaust line before and after the time interval Deltat, P 1 L,out And P 2 L,out The pressure of the liquid phase in the liquid discharge pipeline before and after the time interval delta t is respectively; calculating the change rate of the drilling fluid volume in the gas-liquid separator according to the pressure change in the exhaust pipeline and the drain pipeline, wherein the change rate is shown as a formula vi:
in the standard state, the volume change rate of the gas in the gas-liquid separator is calculated by a gas state equation vii:
wherein: t (T) 0 And P 0 Standard temperature and standard pressure, namely 273.15K and 101.325KPa;
the calculation of the real-time gas phase flow and liquid phase flow in the annulus return fluid is shown in formulas viii, ix respectively:
Q g ＝Q g,out +V' g viii
Q L ＝Q L,out +V' L ix
calculating downhole gas production rate, i.e., fluid invasion rate q, using equation x g ：
Wherein: t (T) wf Is the fluid temperature at the bottom of the well, K;
(6) Drilling to a zone depth of deltaz 1 When the drilling is stopped, the drilling is continued, and the injection displacement Q of the drilling fluid is maintained in Constant until the flow rate Q of liquid phase in annulus return fluid L When substantially constant, a steady state is considered to be reached; thereafter, based on steps (1) - (5), continuously recording the downhole gas production rate q within 10 minutes g And calculate the average value q g1 And establishes the following equation xi;
wherein: k is the reservoir permeability, is the unknown, m 2 ；p res Is reservoir pressure, is unknown, pa; p is p wf1 For continuously recording the average value of the bottom hole pressure in 10min, determining by adopting the step (3), and Pa; s is the skin coefficient of the reservoir, dimensionless; t is the time of continuous invasion of gas at the bottom of the wellS; γ is euler constant, γ= 0.5772;
is reservoir porosity; mu is the viscosity of the gas in the reservoir, pa.s; r is (r) w Is the radius of the shaft, m; c is the reservoir pressure coefficient, 1/Pa;
(7) Continuing to drill to the depth of the producing zone to deltaz 2 When the drilling is stopped, the drilling is continued, and the injection displacement Q of the drilling fluid is maintained in Constant until the flow rate Q of liquid phase in annulus return fluid L When substantially constant, a steady state is considered to be reached; thereafter, based on steps (1) - (5), continuously recording the downhole gas production rate q within 10 minutes g And calculate the average value q g2 And establishes the following equation xii;
wherein p is wf2 For continuously recording the average value of the bottom hole pressure in 10min, determining by adopting the step (3), and Pa;
(8) Constructing a numerical solved objective function of reservoir permeability inversion analysis, wherein the objective function is expressed as formula xiii, and solving by adopting a Newton Laplasen iteration method to obtain reservoir permeability K;
(9) Substituting the reservoir permeability K determined in the step (8) into formulas (xi) and (xii), calculating to obtain two reservoir pressure values, and taking an average value to obtain an average reservoir pressure, namely inverting according to a formula xiv to obtain an average value of the formation pressure;
wherein: k is the reservoir permeability calculated in the step (8), m 2 。
2. The stratum information inversion system in the pressure control drilling process according to claim 1, wherein the gas-liquid separator is a vertical gas-liquid separator, the upper part of the gas-liquid separator is a hemisphere, and the lower part of the gas-liquid separator is a cylinder; the top end of the hemisphere is connected with an exhaust pipeline, and the bottom surface of the cylinder is connected with a liquid discharge pipeline.
3. The system for inversion of formation information during pressure controlled drilling of claim 1 wherein the choke manifold output line is further provided with a gate valve.
4. The system for inversion of formation information during pressure controlled drilling of claim 1 wherein in step (6) of the inversion method, the formation is drilled to a depth of zone Δz 1 ＝H res /3，H res Is the reservoir thickness.
5. The system for inversion of formation information during pressure controlled drilling according to claim 1, wherein in step (6) of the inversion method, the time for circulation of drilling fluid after stopping drilling is 1.5 times of the time for circulation of drilling fluid during drilling, i.e. 1.5t cir The steady state is considered to be reached.
6. The system for inversion of formation information during pressure controlled drilling of claim 1 wherein in step (7) of the inversion method, the formation is drilled to a depth of zone Δz 2 ＝2H res /3，H res Is the reservoir thickness.
7. The system for inversion of formation information during pressure controlled drilling according to claim 1, wherein in step (7) of the inversion method, the time for circulation of drilling fluid after stopping drilling is 1.5 times of the time for circulation of drilling fluid during drilling, i.e. 1.5t cir The steady state is considered to be reached.
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| US20020112888A1 (en) * | 2000-12-18 | 2002-08-22 | Christian Leuchtenberg | Drilling system and method |
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