CN115977586B - Novel method for evaluating productivity of offshore gas well - Google Patents
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Abstract
The invention discloses a new method for evaluating productivity of an offshore gas well, which relates to the field of dynamic analysis of gas reservoirs, and comprises the following steps: drawing a gas well productivity coefficient determining chart according to offshore gas well production data; determining a map according to the initial formation pressure and the gas well productivity coefficient, and determining an initial maximum productivity coefficient; determining the current formation pressure and calculating the productivity coefficient under the current formation pressure; calculating a current productivity coefficient according to the initial stratum pressure, the initial maximum productivity coefficient and the current stratum pressure; determining a final productivity coefficient according to the productivity coefficient under the current stratum pressure and the current productivity coefficient; and calculating the productivity of the gas well according to the current formation pressure and the final productivity coefficient. The invention has convenient operation, can effectively measure the productivity of the offshore gas well, and further obviously reduces the testing cost of the productivity of the offshore gas well.
Description
Technical Field
The invention relates to the field of dynamic analysis of gas reservoirs, in particular to a novel method for evaluating productivity of an offshore gas well.
Background
The productivity evaluation is one of important contents of gas reservoir dynamic analysis and research, and the accurate prediction of the gas well productivity is also a basis for the scientific and reasonable development of gas fields. The main method for analyzing the productivity of the gas well at present comprises the following steps: (1) Knowing physical parameters of a reservoir of a gas layer, calculating the productivity of the gas well by using a yield formula of the gas well, and simply called a formula method; (2) According to the seepage principle of fluid in a reservoir, a stable gas production test is adopted, and gas well productivity analysis is carried out according to the relation between the flow pressure and the gas well productivity, and the method is called a productivity test method.
The productivity of the gas well is calculated by a formula method: the production of the gas well can be predicted as long as the physical parameters of the reservoir are accurately determined. However, in the method, physical parameters of the reservoir are required to be experimentally measured, particularly the reservoir permeability difference is large, and the productivity deviation is calculated to be large, so that the method is inconvenient to use in field production.
The test method calculates the productivity of the gas well: by changing the working system of the gas well for a plurality of times, measuring the stable yield and the corresponding stable bottom hole flow pressure under each working system, drawing a gas well productivity coefficient analysis curve according to the test data and the formation pressure as the known condition, as shown in figure 1,a is the current productivity coefficient, and m is the slope of the tangent line, so that the productivity of the gas well is obtained. The method has to perform bottom hole flow pressure and gas production test, and requires to test under the same formation pressure during the test, but the production test cost of the offshore gas field is high, so the production test is generally less.
Disclosure of Invention
Aiming at the defects in the prior art, the novel method for evaluating the productivity of the offshore gas well can avoid the productivity testing cost of the offshore gas well, and conveniently and effectively measure the productivity of the offshore gas well.
In order to achieve the aim of the invention, the invention adopts the following technical scheme:
the new method for evaluating the productivity of the offshore gas well comprises the following steps:
s1, drawing a gas well productivity coefficient determination chart according to offshore gas well production data;
s2, determining a graph according to the initial stratum pressure and the gas well productivity coefficient in the step S1, and determining an initial maximum productivity coefficient;
s3, determining the current formation pressure and calculating the productivity coefficient under the current formation pressure;
s4, calculating a current productivity coefficient according to the initial stratum pressure in the step S2, the initial maximum productivity coefficient and the current stratum pressure in the step S3;
s5, determining a final productivity coefficient according to the productivity coefficient under the current stratum pressure in the step S3 and the current productivity coefficient in the step S4;
and S6, calculating the productivity of the gas well according to the current stratum pressure in the step S3 and the final productivity coefficient in the step S5.
Further, step S1 includes the following sub-steps:
s11, determining daily gas production data and offshore wellhead pressure data according to offshore gas well production data;
s12, calculating the bottom hole flow pressure according to the offshore wellhead pressure data and the shaft flow characteristics in the substep S11, and calculating the square of the bottom hole flow pressure;
s13, establishing a coordinate system by taking daily gas production as an abscissa and taking the square of bottom hole flow pressure as an ordinate;
and S14, drawing a gas well productivity coefficient determination chart according to daily gas production data in the substep S11, the square of the bottom hole flow pressure in the substep S12 and the coordinate system established in the substep S13.
Further, step S2 includes the following sub-steps:
s21, determining an initial stratum pressure coordinate point according to the initial stratum pressure;
s22, making a tangent line of the gas well productivity coefficient determination chart in the step S1 through the initial stratum pressure coordinate point;
s23, calculating the slope of the tangent line in the substep S22, and determining the slope of the tangent line as the initial maximum productivity coefficient.
Further, step S3 includes the following sub-steps:
s31, determining the current stratum pressure;
s32, calculating the productivity coefficient under the current formation pressure according to the current formation pressure in the substep S31.
Further, in substep S32, a productivity coefficient at the current formation pressure is calculated, expressed as:
wherein: a is that * For the current stratumCoefficient of productivity under pressure, q g For gas well production, p e For the current formation pressure, p wf Is the bottom hole flow pressure.
Further, step S4 includes the following sub-steps:
s41, calculating a deviation factor of natural gas under the initial formation pressure according to the initial formation pressure in the step S2, wherein the deviation factor is expressed as:
wherein: z is Z i Is the deviation factor of natural gas under the initial formation pressure, A 1 ＝0.3156237，A 2 ＝-1.0467099，A 3 ＝-0.57832729，A 4 ＝0.53530771，A 5 ＝-0.61232032，A 6 ＝-0.10488813，A 7 ＝0.68157001，A 8 ＝0.68446549，T pr To be the temperature to be compared at the initial formation temperature ρ pr ＝(0.27×p pri )/(Z i ×T pr )，p pri The pressure is to be compared under the initial formation pressure;
s42, calculating the viscosity of the natural gas under the initial formation pressure according to the initial formation pressure in the step S2, wherein the viscosity is expressed as follows:
wherein: mu (mu) gi To the viscosity of the natural gas at the initial formation pressure,
μ 1 ＝(1.709×10 -5 -2.062×10 -6 γ g )(1.8T+32)+8.188×10 -3 -6.15×10 -5 lgγ g ，γ g for the relative density of the gases, T is the formation temperature, exp (x) =e x ；
S43, calculating a deviation factor of the natural gas under the current formation pressure according to the current formation pressure in the step S3, wherein the deviation factor is expressed as follows:
wherein: z is the deviation factor of natural gas under the current formation pressure, T' pr For the temperature to be compared at the current formation temperature ρ' pr ＝(0.87×p′ pri )/(Z×T′ pr )，p′ pri The pressure is to be compared under the current stratum pressure;
s44, calculating the viscosity of the natural gas under the current formation pressure according to the current formation pressure in the step S3, wherein the viscosity is expressed as follows:
wherein: mu (mu) g The viscosity of the natural gas under the current formation pressure;
s45, calculating a current productivity coefficient according to the initial maximum productivity coefficient in the step S2, the deviation factor of the natural gas under the initial formation pressure in the substep S41, the viscosity of the natural gas under the initial formation pressure in the substep S42, the deviation factor of the natural gas under the current formation pressure in the substep S43 and the viscosity of the natural gas under the current formation pressure in the substep S44, wherein the current productivity coefficient is expressed as follows:
wherein: a is the current productivity coefficient, mu gi Z is the viscosity of natural gas at the initial formation pressure i Mu, the deviation factor of natural gas under the initial formation pressure g For the viscosity of the natural gas under the current formation pressure, z is the deviation factor of the natural gas under the current formation pressure, A i Is the initial maximum capacity coefficient.
Further, step S5 includes the following sub-steps:
s51, comparing the current productivity coefficient in the step S4 with the productivity coefficient under the current stratum pressure in the step S3;
s52, judging whether the current productivity coefficient in the substep S51 meets the calculation precision; if yes, determining the current productivity coefficient as the final productivity coefficient, otherwise, increasing the formation pressure by one step and jumping to the step S3.
Further, in step S6, the capacity of the gas well is calculated, expressed as:
wherein: q AOF For the capacity of a gas well, A 'is the final energy production coefficient, p' e And the formation pressure corresponding to the final productivity coefficient.
The beneficial effects of the invention are as follows:
(1) Under the condition of knowing the initial formation pressure, the invention can calculate the initial maximum productivity coefficient so as to obtain the productivity coefficient under any formation pressure;
(2) Compared with a formula method and a test method, the invention has simple operation, can effectively measure the productivity of the offshore gas well, and reduces the test cost of the productivity of the offshore gas well.
Drawings
FIG. 1 is a graph of a test method calculation gas well capacity analysis;
FIG. 2 is a flow chart of a new method for evaluating the productivity of an offshore gas well;
FIG. 3 is a schematic diagram of determining the capacity coefficient of a new method for evaluating the capacity of an offshore gas well.
Detailed Description
The following description of the embodiments of the present invention is provided to facilitate understanding of the present invention by those skilled in the art, but it should be understood that the present invention is not limited to the scope of the embodiments, and all the inventions which make use of the inventive concept are protected by the spirit and scope of the present invention as defined and defined in the appended claims to those skilled in the art.
As shown in FIG. 2, the novel method for evaluating the productivity of the offshore gas well comprises the following steps of S1-S6:
s1, drawing a gas well productivity coefficient determination chart according to offshore gas well production data.
In an alternative embodiment of the invention, the invention determines the production capacity of a gas well from production data because the production test costs are high and many gas wells are not being tested for production and pressure recovery during production in offshore gas fields. According to the seepage law, when the flow does not reach the boundary, the bottom hole flow pressure continuously drops, when the flow reaches the boundary or the stratum energy drops, the yield starts to drop, and at the moment, the bottom hole flow pressure also starts to drop, as shown in figure 3, the bottom hole flow pressure drops along with the increase of the gas yield, the tangential state of the bottom hole flow pressure and the production data is the result of the gradual failure of the stratum energy, at the moment, the stratum energy failure is slowest, the stratum energy failure reaches stability according to the moment, the tangential state of the stratum energy failure is an initial yield curve, the slope of the initial yield curve corresponds to an initial maximum yield coefficient, and the yield corresponding to the slope of the initial yield curve is the initial maximum yield.
Step S1 comprises the following sub-steps:
s11, determining daily gas production data and offshore wellhead pressure data according to offshore gas well production data.
Specifically, when the production data of the offshore gas well is selected, the production data with the production time of more than 16 hours per day is selected for analysis, and the analysis result is influenced due to the fact that the fluctuation of the flow pressure is large when the production time is too short.
And S12, calculating the bottom hole flow pressure according to the offshore wellhead pressure data and the shaft flow characteristics in the substep S11, and calculating the square of the bottom hole flow pressure.
S13, establishing a coordinate system by taking daily gas production as an abscissa and taking the square of bottom hole flow pressure as an ordinate.
And S14, drawing a gas well productivity coefficient determination chart according to daily gas production data in the substep S11, the square of the bottom hole flow pressure in the substep S12 and the coordinate system established in the substep S13.
S2, determining an initial maximum productivity coefficient according to the initial stratum pressure and the gas well productivity coefficient determining chart in the step S1.
In an alternative embodiment of the present invention, the present invention calculates the square value of the initial formation pressure according to the initial formation pressure, and takes the ordinate as the square value of the initial formation pressure, and takes the coordinate point of the initial formation pressure with the abscissa as zero, and the tangent line of the gas well productivity coefficient determination map in step S1 is made by passing the coordinate point, and the initial maximum productivity coefficient can be determined by calculating the slope of the tangent line.
Step S2 comprises the following sub-steps:
s21, determining an initial stratum pressure coordinate point according to the initial stratum pressure.
Specifically, the method calculates the square value of the initial formation pressure according to the initial formation pressure, determines the initial formation pressure coordinate point with the ordinate being the square value of the initial formation pressure and the abscissa being zero, namely the initial formation pressure coordinate point
S22, making a tangent line of the gas well productivity coefficient determination chart in the step S1 through the initial stratum pressure coordinate point.
S23, calculating the slope of the tangent line in the substep S22, and determining the slope of the tangent line as the initial maximum productivity coefficient.
S3, determining the current stratum pressure and calculating the productivity coefficient under the current stratum pressure.
In an alternative embodiment of the invention, formation pressure is increased from bottom hole pressure by a step size set to p e ＝p wf +0.0001MPa, and calculating the current formation pressure p from the current formation pressure e The productivity coefficient.
Step S3 comprises the following sub-steps:
s31, determining the current formation pressure.
S32, calculating the productivity coefficient under the current formation pressure according to the current formation pressure in the substep S31.
In substep S32, a productivity coefficient at the current formation pressure is calculated, expressed as:
wherein: a is that * Q is the productivity coefficient at the current formation pressure g For gas well production, p e For the current formation pressure, p wf Is the bottom hole flow pressure.
S4, calculating the current productivity coefficient according to the initial stratum pressure in the step S2, the initial maximum productivity coefficient and the current stratum pressure in the step S3.
In an alternative embodiment of the invention, the invention first calculates the initial formation pressure p i Deviation factor z of lower natural gas i And viscosity μ of natural gas gi Then calculate the current formation pressure p e Deviation factor z of natural gas and viscosity mu of natural gas g And obtaining the deviation factors of the corresponding natural gas and the viscosity of the natural gas under different formation pressures, so as to calculate the current productivity coefficient A.
Step S4 comprises the following sub-steps:
s41, calculating a deviation factor of natural gas under the initial formation pressure according to the initial formation pressure in the step S2, wherein the deviation factor is expressed as:
wherein: z is Z i Is the deviation factor of natural gas under the initial formation pressure, A 1 ＝0.31506237，A 2 ＝-1.0467099，A 3 ＝-0.57832729，A 4 ＝0.53530771，A 5 ＝-0.61232032，A 6 ＝-0.10488813，A 7 ＝0.68157001，A 8 ＝0.68446549，T pr To be the temperature to be compared at the initial formation temperature ρ pr ＝(0.27×p pri )/(Z i ×T pr )，p pri The pressure is to be compared at the initial formation pressure.
S42, calculating the viscosity of the natural gas under the initial formation pressure according to the initial formation pressure in the step S2, wherein the viscosity is expressed as follows:
wherein: mu (mu) gi To the viscosity of the natural gas at the initial formation pressure,
μ 1 ＝(1.709×10 -5 -2.062×10 -6 γ g )(1.8T+32)+8.188×10 -3 -6.15×10 -5 lgγ g ，γ g for the relative density of the gases, T is the formation temperature, exp (x) =e x 。
Specifically, when the invention calculates the above formula, the logarithm is calculated firstExpressed as:
wherein: a0 -2.46211820, 1= 2.97054714, 2= -0.286264054, 3= 0.00805420522, a4= 2.80860949, a5= -3.49803305, 6= 0.360373020, a7= -0.0104432413, a8= -0.793385684, a9= 1.39643306, a10= -0.149144925, a11= 0.00441015512, a12= 0.0839387178, a13= -0.186408848, a14= 0.0203367881, a15= -6.09579263E-3.
S43, calculating a deviation factor of the natural gas under the current formation pressure according to the current formation pressure in the step S3, wherein the deviation factor is expressed as follows:
wherein: z is the deviation factor of natural gas under the current formation pressure, T' pr For the temperature to be compared at the current formation temperature ρ' pr ＝(0.27×p′ pri )/(Z×T′ pr )，p′ pri The pressure is to be compared for the current formation pressure.
S44, calculating the viscosity of the natural gas under the current formation pressure according to the current formation pressure in the step S3, wherein the viscosity is expressed as follows:
wherein: mu (mu) g Is the viscosity of natural gas at the current formation pressure.
Specifically, when the invention calculates the above formula, the logarithm is calculated firstExpressed as:
s45, calculating a current productivity coefficient according to the initial maximum productivity coefficient in the step S2, the deviation factor of the natural gas under the initial formation pressure in the substep S41, the viscosity of the natural gas under the initial formation pressure in the substep S42, the deviation factor of the natural gas under the current formation pressure in the substep S43 and the viscosity of the natural gas under the current formation pressure in the substep S44, wherein the current productivity coefficient is expressed as follows:
wherein: a is the current productivity coefficient, mu gi Z is the viscosity of natural gas at the initial formation pressure i Mu, the deviation factor of natural gas under the initial formation pressure g For the viscosity of the natural gas under the current formation pressure, z is the deviation factor of the natural gas under the current formation pressure, A i Is the initial maximum capacity coefficient.
And S5, determining a final productivity coefficient according to the productivity coefficient under the current stratum pressure in the step S3 and the current productivity coefficient in the step S4.
In an alternative embodiment of the present invention, the present invention compares the productivity coefficient at the current formation pressure in step S3 with the current productivity coefficient in step S4, and determines whether the current productivity coefficient in step S4 satisfies the calculation accuracy (generally, the calculation accuracy e=0.0001 is taken, if the calculation result does not converge, the calculation accuracy may be adjusted), if so, the current productivity coefficient is determined to be the final productivity coefficient, otherwise, the formation pressure of one step is increased and the process jumps to step S3 until the current productivity coefficient in step S4 satisfies the calculation accuracy.
Step S5 comprises the following sub-steps:
s51, comparing the current productivity coefficient in the step S4 with the productivity coefficient under the current stratum pressure in the step S3.
S52, judging whether the current productivity coefficient in the substep S51 meets the calculation precision; if yes, determining the current productivity coefficient as the final productivity coefficient, otherwise, increasing the formation pressure by one step and jumping to the step S3.
Specifically, the calculation accuracy can be set according to actual demands, so that the final productivity coefficient obtained by calculation is more in line with the actual situation.
And S6, calculating the productivity of the gas well according to the current stratum pressure in the step S3 and the final productivity coefficient in the step S5.
The invention calculates the productivity of the gas well, expressed as:
wherein: q AOF For the capacity of a gas well, A 'is the final energy production coefficient, p' e And the formation pressure corresponding to the final productivity coefficient.
Those of ordinary skill in the art will recognize that the embodiments described herein are for the purpose of aiding the reader in understanding the principles of the present invention and should be understood that the scope of the invention is not limited to such specific statements and embodiments. Those of ordinary skill in the art can make various other specific modifications and combinations from the teachings of the present disclosure without departing from the spirit thereof, and such modifications and combinations remain within the scope of the present disclosure.
Claims (5)
1. The new method for evaluating the productivity of the offshore gas well is characterized by comprising the following steps of:
s1, drawing a gas well productivity coefficient determination chart according to offshore gas well production data;
step S1 comprises the following sub-steps:
s11, selecting offshore gas well production data, and determining daily gas production data and offshore wellhead pressure data according to the offshore gas well production data;
selecting production data with the production time of more than 16 hours per day;
s12, calculating the bottom hole flow pressure according to the offshore wellhead pressure data and the shaft flow characteristics in the substep S11, and calculating the square of the bottom hole flow pressure;
s13, establishing a coordinate system by taking daily gas production as an abscissa and taking the square of bottom hole flow pressure as an ordinate;
s14, drawing a gas well productivity coefficient determination chart according to daily gas production data in the substep S11, the square of the bottom hole flow pressure in the substep S12 and the coordinate system established in the substep S13;
s2, determining a graph according to the initial stratum pressure and the gas well productivity coefficient in the step S1, and determining an initial maximum productivity coefficient;
step S2 comprises the following sub-steps:
s21, determining an initial stratum pressure coordinate point according to the initial stratum pressure;
calculating to obtain a square value of the initial formation pressure according to the initial formation pressure, and determining an initial formation pressure coordinate point with an ordinate being the square value of the initial formation pressure and an abscissa being zero;
s22, making a tangent line of the gas well productivity coefficient determination chart in the step S1 through the initial stratum pressure coordinate point;
s23, calculating the slope of the tangent line in the substep S22, and determining the slope of the tangent line as the initial maximum productivity coefficient;
s3, determining the current formation pressure and calculating the productivity coefficient under the current formation pressure;
step S3 comprises the following sub-steps:
s31, determining the current stratum pressure;
the current formation pressure increases from the bottom hole pressure by a step size set to 0.0001, expressed as:
p e ＝p wf +0.0001
wherein: p is p e For the current formation pressure, p wf Is the bottom hole flow pressure;
s32, calculating the productivity coefficient under the current formation pressure according to the current formation pressure in the substep S31;
s4, calculating a current productivity coefficient according to the initial stratum pressure in the step S2, the initial maximum productivity coefficient and the current stratum pressure in the step S3;
s5, determining a final productivity coefficient according to the productivity coefficient under the current stratum pressure in the step S3 and the current productivity coefficient in the step S4;
and S6, calculating the productivity of the gas well according to the current stratum pressure in the step S3 and the final productivity coefficient in the step S5.
2. A new method for evaluating capacity of an offshore gas well according to claim 1, wherein in substep S32, the capacity coefficient at the current formation pressure is calculated as:
wherein: a is that * Q is the productivity coefficient at the current formation pressure g For gas well production, p e For the current formation pressure, p wf Is the bottom hole flow pressure.
3. The new method for evaluating the productivity of an offshore gas well according to claim 1, wherein the step S4 comprises the following sub-steps:
s41, calculating a deviation factor of natural gas under the initial formation pressure according to the initial formation pressure in the step S2, wherein the deviation factor is expressed as:
wherein: z is Z i Is the deviation factor of natural gas under the initial formation pressure, A 1 ＝0.31506237，A 2 ＝-1.0467099，A 3 ＝-0.57832729，A 4 ＝0.53530771，A 5 ＝-0.61232032，A 6 ＝-0.10488813，A 7 ＝0.68157001，A 8 ＝0.68446549，T pr To be the temperature to be compared at the initial formation temperature ρ pr ＝(0.27×P pri )/(Z i ×T pr )，p pri The pressure is to be compared under the initial formation pressure;
s42, calculating the viscosity of the natural gas under the initial formation pressure according to the initial formation pressure in the step S2, wherein the viscosity is expressed as follows:
wherein: mu (mu) gi To the viscosity of the natural gas at the initial formation pressure,
μ 1 ＝(1.709×10 -5 -2.062×10 -6 γ g )(1.8T+32)+8.188×10 -3 -6.15×10 -5 lgγ g ，γ g for the relative density of the gases, T is the formation temperature, exp (x) =e x ；
S43, calculating a deviation factor of the natural gas under the current formation pressure according to the current formation pressure in the step S3, wherein the deviation factor is expressed as follows:
wherein: z is the current formation pressureDeviation factor of lower natural gas, T' pr For the temperature to be compared at the current formation temperature ρ' pr ＝(0.27×p′ pri )/(Z×T′ pr )，p′ pri The pressure is to be compared under the current stratum pressure;
s44, calculating the viscosity of the natural gas under the current formation pressure according to the current formation pressure in the step S3, wherein the viscosity is expressed as follows:
wherein: mu (mu) g The viscosity of the natural gas under the current formation pressure;
s45, calculating a current productivity coefficient according to the initial maximum productivity coefficient in the step S2, the deviation factor of the natural gas under the initial formation pressure in the substep S41, the viscosity of the natural gas under the initial formation pressure in the substep S42, the deviation factor of the natural gas under the current formation pressure in the substep S43 and the viscosity of the natural gas under the current formation pressure in the substep S44, wherein the current productivity coefficient is expressed as follows:
wherein: a is the current productivity coefficient, mu gi Z is the viscosity of natural gas at the initial formation pressure i Mu, the deviation factor of natural gas under the initial formation pressure g For the viscosity of the natural gas under the current formation pressure, z is the deviation factor of the natural gas under the current formation pressure, A i Is the initial maximum capacity coefficient.
4. The new method for evaluating the productivity of an offshore gas well according to claim 1, wherein the step S5 comprises the following sub-steps:
s51, comparing the current productivity coefficient in the step S4 with the productivity coefficient under the current stratum pressure in the step S3;
s52, judging whether the current productivity coefficient in the substep S51 meets the calculation precision; if yes, determining the current productivity coefficient as the final productivity coefficient, otherwise, increasing the formation pressure by one step and jumping to the step S3.
5. A new method for evaluating the capacity of an offshore gas well according to claim 1, wherein in step S6, the capacity of the gas well is calculated as:
wherein: q AOF For the capacity of a gas well, A 'is the final energy production coefficient, p' e And the formation pressure corresponding to the final productivity coefficient.
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