CN112199820B - Oil well productivity curve testing method under digital condition - Google Patents
Oil well productivity curve testing method under digital condition Download PDFInfo
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Abstract
The invention relates to the technical field of deepened application of the Internet of things, in particular to a method for testing an oil well productivity curve under a digital condition. The testing method comprises the steps of collecting at least three groups of oil well parameters at different testing points, and obtaining an initial value of the liquid production amount according to the type of a ground indicator diagram, the theoretical discharge capacity and a preset multiple; calculating a submergence load according to a load separation method, and calculating an initial value of a corresponding working fluid level; respectively calculating the initial values of the fluid production amount and the dynamic liquid level to obtain at least three groups of numerical values; calculating a flow pressure value according to the initial value of the liquid production amount, and further calculating a liquid extraction index; calculating to obtain multiple groups of liquid production amounts and working fluid levels; comparing the liquid production amount and the dynamic liquid level with the initial liquid production amount value, if the comparison precision meets 5%, recalculating the initial liquid production amount value and the initial dynamic liquid level value if the comparison precision does not meet the requirement; if so, diagnosing the working condition of the oil pumping well according to the output liquid production amount, the working fluid level and the liquid production index. The testing method provided by the invention can effectively improve the working condition diagnosis efficiency and accuracy of the rod-pumped well.
Description
Technical Field
The invention relates to the technical field of deepened application of the Internet of things, in particular to a method for testing an oil well productivity curve under a digital condition.
Background
Currently, with the advancement of information technology, there are a considerable number of oil fields that have been or are being digitized. But the digitally collected real-time production data is still mainly used for simple monitoring and presentation. Along with the further reduction of the cost of the single-well production monitoring device, the popularization degree of automatic instruments in the field of oil well production is greatly improved, and the preliminary combination of a production management software system and an oil extraction engineering technology is applied to the real-time diagnosis of production working conditions and the real-time calculation of liquid quantities. The application mainly aims at the relatively stable production state, the utilization of data mainly focuses on the analysis of the shape of a work diagram, the application of load data changing along with time is less, and the oil reservoir seepage rule and the pumping rule are not combined.
According to the actual situation of field feedback, the method of simply relying on the shape of the diagram is nearly suitable for the analysis and calculation of the stable state, and the production application effect of the unstable state needs to be improved.
Disclosure of Invention
Technical problem to be solved
The invention provides a method for testing an oil well productivity curve under a digital condition, which overcomes the defects of low efficiency, low accuracy and the like of working condition diagnosis of an oil pumping well caused by analyzing productivity only by a diagram shape in the prior art.
(II) technical scheme
In order to solve the problems, the invention provides a method for testing an oil well productivity curve under a digital condition, which comprises the following steps:
s1, collecting at least three groups of oil well parameters at different time test points, wherein the oil well parameters comprise oil pressure, casing pressure, a ground indicator diagram, stroke and stroke frequency;
s2, obtaining an initial value of the liquid production amount according to the type of the ground indicator diagram and the multiple of the theoretical displacement and a preset threshold value; calculating a submergence load according to a load separation method, and calculating an initial value of a corresponding working fluid level; respectively calculating the initial values of the liquid production amount and the dynamic liquid level to obtain at least three groups of values;
s3, calculating a flow pressure value according to the initial value of the liquid production amount, and further calculating a liquid extraction index;
s4, establishing an integral relation formula according to the fluid collection index, the collection time, the darcy law of seepage mechanics and the relationship between the flowing pressure and the yield of the characteristics of the oil well pump, and calculating to obtain a plurality of groups of fluid production amounts and working fluid levels;
s5, comparing the liquid yield and the working fluid level obtained in the step S4 with the initial liquid yield value obtained in the step S2, if the comparison precision meets 5%, executing the step S6, if the comparison precision does not meet the requirement, returning to the step S2, and recalculating the initial liquid yield value and the initial working fluid level value;
and S6, diagnosing the working condition of the pumping well according to the output liquid production amount, the working fluid level and the liquid production index.
Preferably, in the step S2, obtaining the initial value of the fluid production amount according to the type of the ground indicator diagram and the multiple of the theoretical displacement and the preset threshold specifically includes:
if the ground indicator diagram is a full indicator diagram, taking 80% of theoretical discharge capacity as an initial value of calculated yield:
Q E ＝0.8Q T ；
if the ground indicator diagram is an unsaturated indicator diagram, taking 85% of the theoretical discharge capacity as an initial value of the calculated yield:
Q E ＝0.85Q T ；
Q E for estimating daily liquid production m 3 /d；Q T Is a theoretical displacement m 3 /d。
Preferably, in the step S2, the calculating of the initial value of the working fluid level according to the load separation method includes:
F＝f(Rs，ρo，hs)
wherein D is the diameter of the oil pipe, m; ap is the plunger area, m 2 (ii) a h is the lower pump depth, m; g is gravity acceleration, and is 9.8m/s 2 ，ρ l The density of the mixed solution is expressed as kg/m3; ρ is a unit of a gradient o Denotes the oil density, kg/m3; f up Is the mean value of the upstroke load, N; f down Is the mean value of the load on the down stroke, N; f pt Load generated by oil pressure, N; f is liquid level correction factor, rs is gas-oil ratio, m 3 /m 3 Rho is crude oil density, hs is water content,%;
through at least three groups of calculation, respectively obtaining (Q) E1 ，H1，T 1 )(Q E1 ，H2,T 2 )(Q E1 ，H3,T 3 )…(Q En ，Hn，T n )(n>＝3)；T 1 ,T 2 ,T 3 …T n Is the test time.
Preferably, in step S3, calculating a flow pressure value according to the initial value of the fluid production amount, and further calculating the fluid production index specifically includes:
the calculation formula of the flowing pressure is as follows:
Pwf＝(H-h)ρ l g+Pc
through calculation of at least three groups, respectively obtaining (Q) E1 ，Pwf 1 ，T 1 )(Q E2 ，Pwf 2 ,T 2 )(Q E3 ，Pwf 3 ,T 3 )…(Q En ，Pwf n ，T n )(n>＝3)
Calculating formula of liquid production index:
Jn-1＝(Q En -Q En-1 )/(Pwf n -Pwf n-1 )(n>＝2)
obtain a group (J) 1 ，J 2 …J n-1 ) Taking an average value;
Javr＝(J 1 +J 2 +…J n-1 )/(n-1)
and (3) solving reservoir pressure according to an extrapolation method:
Pr＝Pwf 2 +Q E2 /Javr
fitting the IPR equation:
Q(pwf)＝(Pr-pwf)*Javr
pwf is bottom hole flow pressure Pa; pc is wellhead casing pressure Pa; h is the lower pump depth, m; ρ is a unit of a gradient l The density of the mixed solution is kg/m3; g is the gravity acceleration, and 9.8m/s2 is taken; j is the oil recovery index: m is 3 V (d × Pa); javr is the average oil recovery index: m 3/(d × Pa); pr is the formation pressure, pa.
Preferably, in step S4,
and (3) calculating the liquid yield at the point 2:
inching liquid level:
calculating the fluid yield at the 3 rd point:
3 rd inching liquid level
…
The m +1 th fluid yield:
(m + 1) th inching liquid level
Wherein the 2 nd point is T 1 To T 2 The time period in between; point 3 is T 2 To T 3 The time period in between; point m +1 is T m To T m+1 The time period in between;
wherein S is the annular area, m 2 ；f pump (Pwf) is the flow pressure versus production based pump characteristics,
η is pump efficiency,%; p is the sinking pressure, pa; μ is crude oil viscosity, mpa.
(III) advantageous effects
The method for testing the oil well productivity curve under the digital condition has the following advantages:
(1) The online digital application level of the rod pumping system is improved, the application potential of the oil field Internet of things system is fully exerted, and the fine management degree of oil and gas production is improved;
(2) The accuracy of online measurement of the liquid amount of the oil pumping well is improved, the required calibration and correction workload is reduced, and the operation cost of a software oil measuring system is reduced;
(3) The liquid level descending and recovery curve of the intermittent pumping well, which avoids conventional tests, is provided, and the more accurate and lower-cost intermittent pumping design of the oil well is realized;
(4) The efficiency and the accuracy of the working condition diagnosis of the pumping well are improved.
Drawings
FIG. 1 is a flow chart of a method for testing an oil well productivity curve under a digital condition according to an embodiment of the invention.
Detailed Description
The present invention will be described in detail below with reference to the drawings and examples.
As shown in fig. 1, the invention provides a method for testing an oil well productivity curve under a digital condition, which specifically comprises the following steps:
s1, collecting at least three groups of oil well parameters at different time test points, wherein the oil well parameters comprise oil pressure, casing pressure, a ground indicator diagram, stroke and stroke frequency;
specifically, an Internet of things instrument deployed on an oil well site is mainly used for collecting oil pressure, casing pressure, a ground indicator diagram and the like; the main instruments comprise an oil gas production Internet of things gateway (RTU) which is responsible for data acquisition, data processing and sending, background instruction receiving and executing, a load and displacement sensor which is responsible for indicator diagram data acquisition, a pressure transmitter which is responsible for pressure acquisition, and an electric quantity parameter module which is responsible for current, voltage and power acquisition. At least three sets of valid data containing test times are required.
S2, obtaining an initial value of the liquid production amount according to the type of the ground indicator diagram and the multiple of the theoretical displacement and a preset threshold value; calculating a submergence load according to a load separation method, and calculating an initial value of a corresponding working fluid level; respectively calculating the initial value of the liquid production amount and the initial value of the working fluid level to obtain at least three groups of numerical values;
specifically, according to the shape of the acquired indicator diagram, a graph characteristic algorithm is applied to identify two states of fullness and unsaturations.
If the ground indicator diagram is a full indicator diagram, taking 80% of theoretical discharge capacity as an initial value of calculated yield:
Q E ＝0.8Q T ；
if the ground indicator diagram is an unsaturated indicator diagram, taking 85% of the theoretical discharge capacity as an initial value of the calculated yield:
Q E ＝0.85Q T ；
Q E for estimating daily liquid production m 3 /d；Q T Is theoretical displacement m 3 /d；
According to the load separation method, the step of calculating the initial value of the working fluid level comprises the following steps:
F＝f(Rs，ρo，hs)
wherein D is the diameter of the oil pipe and m; ap is the plunger area, m 2 (ii) a h is the lower pump depth, m; g is gravity acceleration, and is 9.8m/s 2 ，ρ l The density of the mixed solution is expressed as kg/m3; rho represents the oil density, kg/m3; f up Is the mean value of the up-stroke load, N; f down Is the mean value of the down stroke load, N; f pt Load generated by oil pressure, N; f is liquid level correction factor, rs is gas-oil ratio, m 3 /m 3 Rho is the density of the crude oil, hs is the water content,%.
Through calculation of at least three groups, respectively obtaining (Q) E1 ，H1，T 1 )(Q E1 ，H2,T 2 )(Q E1 ，H3,T 3 )…(Q En ，Hn，T n )(n>＝3)；T 1 ,T 2 ,T 3 …T n Is the test time.
S3, calculating a flow pressure value according to the initial value of the liquid production amount, and further calculating a liquid extraction index;
specifically, a calculation formula of the flow pressure is as follows:
Pwf＝(H-h)ρ l g+Pc
through at least three groups of calculation, respectively obtaining (Q) E1 ，Pwf 1 ，T 1 )(Q E2 ，Pwf 2 ,T 2 )(Q E3 ，Pwf 3 ,T 3 )…(Q En ，Pwf n ，T n )(n>＝3)
Calculating formula of liquid production index:
Jn-1＝(Q En -Q En-1 )/(Pwf n -Pwf n-1 )(n>＝2)
obtain a group (J) 1 ，J 2 …J n-1 ) Taking an average value;
Javr＝(J 1 +J 2 +…J n-1 )/(n-1)
and (3) solving the reservoir pressure according to an extrapolation method:
Pr＝Pwf 2 +Q E2 /Javr
fit IPR equation:
Q(pwf)＝(Pr-pwf)*Javr
pwf is bottom hole flow pressure Pa; pc is wellhead casing pressure Pa; h is the lower pump depth, m; rho l The density of the mixed solution is kg/m3; g is the gravity acceleration, and 9.8m/s2 is taken; j is the oil recovery index: m is a unit of 3 V (d × Pa); javr is the average oil recovery index: m 3/(d × Pa); pr is the formation pressure, pa.
S4, calculating to obtain a plurality of groups of liquid production amounts and working fluid levels according to the liquid production indexes, the collection time, the darcy law of seepage mechanics, the relationship between the flowing pressure and the yield of the characteristics of the oil well pump and an integral formula;
specifically, the fluid production at point 2 is calculated:
inching liquid level:
and (3) calculating the liquid yield at the point:
3 rd inching liquid level
…
The m +1 th point fluid production:
(m + 1) th inching liquid level
Wherein the 2 nd point is T 1 To T 2 The time period in between; point 3 is T 2 To T 3 The time period in between; point m +1 is T m To T m+1 The time period in between;
wherein S is the annular area, m 2 ；f pump (Pwf) is the relationship between the flow pressure and the production based on the characteristics of the oil well pump, and the recommended formula is as follows:
f pump (Pwf)＝Qt[ln(0.0000006Pwf)-A]/B
eta is pumping efficiency,%; p is the sinking pressure, pa; μ is crude oil viscosity, mpa; a is a coefficient, and the value is 0.001463 (default value). For oil fields with special working conditions, fitting of values A and B based on actual data is recommended.
Step S5, comparing the liquid production amount and the working fluid level obtained in the step S4 with the initial liquid production amount value obtained in the step S2, if the comparison precision meets 5%, outputting the liquid production amount and the working fluid level obtained in the step S4 and the liquid collection index obtained in the step S3, and if the comparison precision does not meet the requirement, returning to the step S2, and recalculating the initial liquid production amount value and the initial working fluid level value;
and S6, diagnosing the working condition of the pumping well according to the output liquid production amount, the working fluid level and the liquid production index.
In the step, the working condition of the pumping well is diagnosed by adopting the existing mature diagnosis means.
Three points can be calculated for the oil wells with the IPR curves in the linear relation, and at most five points can be calculated for the oil wells with the IPR curves in the nonlinear relation.
The method for testing the oil well productivity curve under the digital condition has the following advantages:
(1) Providing a relatively accurate liquid production amount design reference for oil well parameter adjustment optimization design;
(2) Providing a relatively accurate liquid level recovery curve and a liquid level descending curve under any parameter for the oil well interval pumping design;
(3) An IPR curve based on a large number of real-time data fitting calculations is provided for the optimal design of an oil well.
The above embodiments are only for illustrating the invention and are not to be construed as limiting the invention, and those skilled in the art can make various changes and modifications without departing from the spirit and scope of the invention, therefore, all equivalent technical solutions also belong to the scope of the invention, and the scope of the invention is defined by the claims.
Claims (1)
1. A method for testing an oil well productivity curve under a digital condition is characterized by comprising the following steps:
s1, collecting at least three groups of oil well parameters at different time test points, wherein the oil well parameters comprise oil pressure, casing pressure, a ground indicator diagram, stroke and stroke frequency;
s2, obtaining an initial value of the liquid production amount according to the type of the ground indicator diagram and the multiple of the theoretical displacement and a preset threshold value; calculating the submergence load according to a load separation method, and calculating the initial value of the corresponding working liquid level; respectively calculating the initial value of the liquid production amount and the initial value of the working fluid level to obtain at least three groups of numerical values;
s3, calculating a flow pressure value according to the initial value of the liquid production amount, and further calculating a liquid extraction index;
s4, establishing an integral relation formula according to the fluid collection index, the collection time, the Darcy' S law of seepage mechanics and the relationship between the flowing pressure and the yield of the characteristics of the oil well pump, and calculating to obtain a plurality of groups of fluid production amounts and working fluid levels;
s5, comparing the liquid yield and the working fluid level obtained in the step S4 with the initial liquid yield value obtained in the step S2, if the comparison precision meets 5%, executing the step S6, if the comparison precision does not meet the requirement, returning to the step S2, and recalculating the initial liquid yield value and the initial working fluid level value;
s6, diagnosing the working condition of the oil pumping well according to the output liquid production amount, the working fluid level and the liquid production index;
wherein: in step S2, obtaining an initial value of the fluid production according to the type of the ground indicator diagram and a multiple of the theoretical displacement and a preset threshold specifically includes:
if the ground indicator diagram is a full indicator diagram, taking 80% of theoretical discharge capacity as an initial value of calculated yield:
Q E ＝0.8Q T ；
if the ground indicator diagram is an unsaturated indicator diagram, taking 85% of the theoretical discharge capacity as an initial value of the calculated yield:
Q E ＝0.85Q T ；
Q E for estimating daily liquid production m 3 /d；Q T Is a theoretical displacement m 3 /d；
According to the load separation method, the step of calculating the initial value of the working fluid level comprises the following steps:
F＝f(Rs，ρo，hs)
wherein D is the diameter of the oil pipe and m; ap is the plunger area, m 2 (ii) a h is the lower pump depth, m; g is gravity acceleration, and is 9.8m/s 2 ，ρ l The density of the mixed solution is expressed as kg/m3; rho represents the oil density, kg/m3; f up Is the mean value of the up-stroke load, N; f down Is the mean value of the load on the down stroke, N; f pt Load generated by oil pressure, N; f is liquid level correction factor, rs is gas-oil ratio, m 3 /m 3 Rho is crude oil density, hs is water content,%;
through calculation of at least three groups, respectively obtaining (Q) E1 ，H1，T 1 )(Q E1 ，H2,T 2 )(Q E1 ，H3,T 3 )…(Q En ，Hn，T n )(n>＝3)；T 1 ,T 2 ,T 3 …T n Is the test time;
in step S3, calculating a flow pressure value according to the initial value of the fluid production amount, and further calculating a fluid production index specifically includes:
the calculation formula of the flow pressure is as follows:
Pwf＝(H-h)ρ l g+Pc
through at least three groups of calculation, respectively obtaining (Q) E1 ，Pwf 1 ，T 1 )(Q E2 ，Pwf 2 ,T 2 )(Q E3 ，Pwf 3 ,T 3 )…(Q En ，Pwf n ，T n )(n>＝3)
The formula for calculating the oil recovery index is as follows:
Jn-1＝(Q En -Q En-1 )/(Pwf n -Pwf n-1 )(n>＝2)
obtain a group (J) 1 ，J 2 …J n-1 ) Taking an average value;
Javr＝(J 1 +J 2 +…J n-1 )/(n-1)
and (3) solving the formation pressure according to an extrapolation method:
Pr＝Pwf 2 +Q E2 /Javr
fitting the IPR equation:
Q(pwf)＝(Pr-pwf)*Javr
pwf is bottom hole flow pressure Pa; pc is wellhead casing pressure Pa; h is the lower pump depth, m; rho l The density of the mixed solution is kg/m3; g is gravity acceleration, and is 9.8m/s 2 (ii) a J is the oil recovery index: m is 3 V (d × Pa); javr is the average oil recovery index: m is 3 V (d × Pa); pr is the formation pressure, pa;
wherein, in the step S4,
and (3) calculating the liquid yield at the point 2:
inching liquid level:
and (3) calculating the liquid yield at the point:
3 rd inching liquid level
…
The m +1 th point fluid production:
(m + 1) th inching liquid level
Wherein the 2 nd point is T 1 To T 2 The time period in between; point 3 is T 2 To T 3 The time period in between; the m +1 th point is T m To T m+1 The time period in between;
wherein S is the annular area, m 2 ；f pump (Pwf) is the relationship between flow pressure and production based on pump characteristics.
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| CN107288617A (en) * | 2016-07-21 | 2017-10-24 | 中国石油大学(北京) | A kind of method and system for improving rod-pumped well indicator card gauging precision |
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