CN117874988A - Method for solving oil well single well control reserves and dynamic stratum pressure based on production data - Google Patents
Method for solving oil well single well control reserves and dynamic stratum pressure based on production data Download PDFInfo
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Abstract
The invention belongs to the technical field of oil and gas field development, and discloses a method for solving oil well single well control reserves and dynamic stratum pressure based on production data, which comprises the following steps: acquiring analysis production data; constructing a dynamic combined calculation model of the flow pressure, and calculating the bottom hole flow pressure; smoothing data; establishing a relation among production data, formation pressure, single well control reserves and bottom hole stream pressure by using a material balance equation and a horizontal well reserve control equation; presetting a single well control reserve, and calculating dynamic stratum pressure by utilizing a material balance equation and combining production data; construction of N p /△pC t The relation with q/[ delta ] p is adopted to calculate new single well control reserves by fitting a horizontal well reserve control equation; will beComparing the calculated value of the single well control reserve with the absolute value of the difference value and the error value of the preset value, and judging whether to carry out iterative calculation again; and outputting the single well control reserves and the dynamic stratum pressure of the oil well. The invention solves the problem of simultaneously acquiring the single well control reserves and the dynamic stratum pressure of the oil well by utilizing the production dynamic data.
Description
Technical Field
The invention belongs to the technical field of oil and gas field development, and particularly relates to a method for solving oil well single well control reserves and dynamic stratum pressure based on production data.
Background
The single well control reserves and the dynamic stratum pressure are important indexes for evaluating the oil field development effect, the single well control reserves are accurately calculated, the stratum pressure of the oil reservoir is known in real time, and the single well control reserves and the dynamic stratum pressure have important significance for evaluating and analyzing the recovery ratio and the stratum energy condition, developing well pattern deployment, designing fracturing parameters, optimizing production system, guiding and adjusting oil reservoir development scheme deployment and the like. Dynamic formation pressure is often obtained through testing, but formation pressure of any well over production time is difficult to obtain. The single well control reserves are important indexes for evaluating the single well production degree, and two main methods for acquiring the single well control reserves exist at present: one is a static method and the other is a dynamic method. The method is mainly used for calculating single well control reserves by adopting a defined area, and parameters are derived from geophysical logging, so that the method has small error on a conventional oil reservoir, but actual reserve utilization of a tight oil reservoir is often controlled by compression fracture transformation degree, and the method is used for calculating single well control reserves to evaluate single well recovery ratio, so that the calculated recovery ratio is often abnormal, and the actual production effect is not reflected. The conventional dynamic method mainly comprises a pressure drop slope calculation method, a pressure curve fitting method, a detection radius calculation method, a modern yield progressive method and the like, and has the problems of high theoretical level requirements on operators, difficult model diversity selection, low fitting precision when the data quality is poor and the like, and has poor fitting effect and low prediction result reliability on unconventional tight reservoirs, particularly tight conglomerate reservoirs. Therefore, a method for solving the control reserves and the dynamic stratum pressure of a single well, which is convenient, reliable and does not affect the production, is lacking at present, and has great significance for the development of unconventional oil reservoirs.
Currently, in field application technology, the methods for controlling reserves of single well commonly used in the field include a volumetric method based on a well pattern control area, a well test inversion method based on a pressure test, and a modern yield decreasing analysis method based on yield data. Wherein, the volumetric method is difficult to characterize the influence degree of the manual net sewing on the single well control reserves; the inversion of the well test method of the pressure test needs to carry out a shut-in well test, thereby generating additional action cost and influencing production; the common decreasing analysis method is unstable, complex in operation and high in data quality requirement, and is time-consuming and labor-consuming in multi-well evaluation. Aiming at dynamic stratum pressure, the on-site common method is a mode of acquiring stratum pressure and adjacent well pressure by a shut-in pressure measuring method and a system well test extrapolation method; the well shut-in pressure measurement method and the system well test extrapolation method influence production, and meanwhile, dynamic stratum pressure change is difficult to obtain; the pressure measurement mode of the adjacent well is difficult to reflect the dynamic change characteristics of the formation pressure after the volume fracturing transformation.
In the prior art, patent document CN112878987a discloses a method for calculating shale gas well control reserves by using production data, and proposes the idea of calculating formation pressure and well control reserves by using single well production data on the assumption of single well control reserves by using a shale gas reservoir pressure drop equation considering free gas in cracks; patent document CN110929462a discloses a method for calculating the true pressure and gas reservoir reserves of a hypotonic gas reservoir using production data, and based on a binomial capacity equation, the pressure for forming a straight line by a material balance equation is obtained by continuously trying the pressures, that is, the formation pressure is obtained, and the single well control reserves are also obtained; patent document CN113868975a discloses a method for predicting single-well control geological reserves of a shale oil horizontal well, which is based on the principle of pressure change and material balance of shale oil reservoir failure type development stratum, establishes a model for predicting the recovery rate of the shale oil failure type development full life cycle, simultaneously dynamically predicts the accumulated oil yield of the single well according to the production of the shale oil development horizontal well, and obtains the single-well control reserves according to the division of accumulated oil yield and recovery rate. Meanwhile, journal literature (complex oil and gas reservoirs, 2019,12 (0.2)) discloses a simple calculation method for single well control reserves of low permeability gas reservoirs, wherein gas reservoir pressures at different times are calculated by utilizing a gas well productivity equation, and then single well control reserves are calculated according to a closed gas reservoir pressure drop equation; the journal literature (Xinjiang petroleum geology, 2007,28 (06)) derives an equation for conveniently determining the single well control reserve of the oil well from a quasi-steady state seepage equation, and the single well control reserve can be obtained by extrapolation through linear regression by utilizing yield data and the equation, but the journal literature does not provide a method for how formation pressure is acquired and is only suitable for an unsaturated oil reservoir.
However, in the process of implementing the technical solution according to the embodiment of the present invention, the present inventors have found that at least the following technical problems exist in the above-mentioned technology: (1) The existing patent or journal literature is mainly used for calculating formation pressure and single well control reserves of a gas well, and because an oil reservoir system is more complex than an independent gas reservoir system and the oil reservoir needs to consider the influence of fracturing fluid on energy supplement, the oil reservoir is obviously different from an oil reservoir model and a theoretical calculation formula, and is not suitable for the oil reservoir; (2) In a small number of patent and journal documents aiming at oil reservoir calculation, only single well control reserves are usually calculated, but the technical scheme of simultaneously acquiring two indexes of dynamic formation pressure and single well control reserves is not seen, the dynamic formation pressure is obtained by calculation on the basis of acquiring the single well control reserves, the calculation process is complicated, and the reliability of the calculation result is difficult to ensure.
Disclosure of Invention
The invention aims to solve at least one technical problem existing in the prior art or related technologies, provides a method for solving the single well control reserve and dynamic formation pressure of an oil well based on production data, can simultaneously acquire the single well control reserve and dynamic formation pressure of the oil well by utilizing the production dynamic data, and has great significance in evaluating the residual production capacity, the recovery degree and the recovery ratio of the single well, analyzing the rationality of development deployment and guiding the adjustment of development deployment.
In order to achieve the technical purpose, the invention adopts the following technical scheme:
a method for deriving well individual well control reserves and dynamic formation pressure based on production data, the method comprising the steps of:
step S101: acquiring and analyzing mining field production data, PVT physical parameters, well depth track data and fracturing data;
step S102: calculating the bottom hole flow pressure by utilizing a plurality of wellbore multiphase pipe flow models, and screening and constructing a dynamic combination calculation model of the flow pressure in the production process according to the principle of minimum error when the oil-gas ratio is changed in the production process; calculating the bottom hole flow pressure at different production time according to the flow pressure dynamic combination calculation model;
step S103: smoothing the data based on the pressure identification;
step S104: establishing a relation among production data, formation pressure, single well control reserves and bottom hole stream pressure by using a material balance equation and a horizontal well reserve control equation;
step S105: presetting single well control reserve as N Estimation of Calculating dynamic formation pressure by combining production data with a material balance equation;
step S106: construction of N using calculated dynamic formation pressure, bottom hole flow pressure and accumulated oil production data p /△pC t And the scattered point relation graph of q/[ delta ] p, then adopting a horizontal well reserve control equation to perform linear fitting on scattered point data after boundary flow time nodes to obtain a correlation coefficient A, B, and calculating new single well control reserve N according to the regression of the following formula Meter with a meter body ；
Wherein N is p For accumulating oil production, m 3 The method comprises the steps of carrying out a first treatment on the surface of the Δp is the differential pressure of production, MPa; c (C) t To synthesize the compression coefficient, MPa -1 The method comprises the steps of carrying out a first treatment on the surface of the q is daily oil production, m 3 /d；
Step S107: calculated value N of single well control reserve Meter with a meter body And a preset value N Estimation of Is compared with the error value epsilon,
if |N Estimation of -N Meter with a meter body Outputting the finally calculated single well control reserves and dynamic stratum pressure of the oil well;
if |N Estimation of -N Meter with a meter body |>Epsilon, then take the single well control reserve n=0.5 (N Estimation of +N Meter with a meter body ) As a new preset value N Estimation of Returning to step S105, recalculating to obtain a calculated value N of the single well control reserves Meter with a meter body The method comprises the steps of carrying out a first treatment on the surface of the And iterating according to the loop until the calculation result meets the error requirement, and outputting the finally calculated oil well single well control reserve and dynamic stratum pressure.
Further, the step S101 includes:
analyzing PVT physical parameters, and fitting a formula of each parameter and pressure;
analyzing whether fracturing interference exists between the single well fracturing fluid and other well groups, and correcting the effective injection fracturing fluid W of the single well injected stratum according to the following condition if the fracturing interference exists i ：
W i ＝W si -W pi
In the above, W si For injection of fracturing fluid volume, m 3 ；W pi Fluid quantity, m, of adjacent well channeling 3 。
Further, the step S102 specifically includes:
calculating the bottom hole flow pressure by using a multi-class multiphase pipe flow calculation method, comparing the bottom hole flow pressure with actual flow pressure production test data, calculating the absolute value of the relative error of the bottom hole flow pressure and the actual flow pressure production test data, constructing error line intersection diagrams of different flow pressure models under different oil-gas ratios, and obtaining a calculation model with the minimum error under different oil-gas ratio intervals, wherein the calculation models with the minimum error jointly form a flow pressure dynamic combination calculation model in the production process; and calculating the change value of the position flow pressure along with the production time according to the dynamic flow pressure combination calculation model.
Still further, the multiphase pipe flow calculation method comprises a Beggs-Bril method, an Orkiszewski method, an Aziz-Govier-Fogarasi method and a Hagedorn-Brown method.
Further, the step S103 specifically includes:
identifying abnormal points of the flow pressure by using an MAD method, and judging abnormal points of the production data according to the abnormal points of the flow pressure; and carrying out interpolation calculation processing on the abnormal point of the flow pressure and the abnormal point of the production data according to a cubic spline method, obtaining a numerical value by interpolation to replace the numerical value at the abnormal point, and carrying out movement smoothing processing on the whole data after interpolation.
Further, in the step S103, the method of identifying the abnormal point of the flow pressure by the MAD method, and determining the abnormal point of the production data according to the abnormal point of the flow pressure specifically includes:
setting the threshold MAD as a local average value, and if the value of the data point is greater than or equal to the threshold MAD which is 3 times, considering the data point as an outlier, thereby obtaining the abnormal flow pressure point, and the production data corresponding to the abnormal flow pressure point is the abnormal production data point.
Further, in the step S104, the formation pressure P is considered r And saturation pressure P b The relation between the materials is that the material balance equation is specifically:
when P r ≥P b In the time-course of which the first and second contact surfaces,
when P r <P b In the time-course of which the first and second contact surfaces,
in the above formula: p is p i Is the original formation pressure, MPa;is the formation pressure in the production process, MPa; n (N) p For accumulating oil production, m 3 The method comprises the steps of carrying out a first treatment on the surface of the N is single well control reserve, m 3 ；C w Is the compression coefficient of water, MPa -1 ；C f Is the compression coefficient of rock, MPa -1 ；B o Is the volume coefficient of crude oil; b (B) g Is the volume coefficient of the solution gas; b (B) oi Is the original volume coefficient of crude oil; b (B) w Is the volume coefficient of formation water; b (B) T Is the two-phase volume coefficient of crude oil; b (B) Ti Is the two-phase volume coefficient of the original crude oil, B Ti ＝B o +(R si -R s )B gi ，B gi Is the original volume coefficient of the dissolved gas; r is R p To accumulate the oil-gas ratio, m 3 /m 3 ；R s To dissolve the oil-gas ratio, m 3 /m 3 ；R si For the original dissolved gas ratio, m 3 /m 3 ；S wc To irreducible water saturation, decimal; w (W) i For effective injection of fracturing fluid volume, m 3 ；W p For accumulating the water yield, m 3 。
Further, in the step S104, the horizontal well reserve control equation is derived by combining a dimensionless pressure expression of a quasi-steady-state stage of the horizontal well with an Agarwal-Gardner equation;
the dimensionless pressure expression of the quasi-steady-state stage of the horizontal well is as follows:
the Agarwal-Gardner equation is:
the reserve control equation of the horizontal well is as follows:
in the above formula: p is p D Is dimensionless pressure; t is t D Is dimensionless time; r is (r) eD Is the dimensionless oil drainage radius; l (L) D Is dimensionless horizontal segment long; r is (r) wD Is a dimensionless wellbore radius; z wD The dimensionless height of the horizontal well from the bottom of the oil layer; k is the reservoir permeability, mD; r is (r) w Is the radius of the shaft, m; c (C) t Is the compression coefficient, MPa -1 The method comprises the steps of carrying out a first treatment on the surface of the Phi is the porosity, decimal; mu is the viscosity of crude oil, mPa.s; s is the oil drainage area, m 2 ；For the production of pressure differences, MPa; p (P) wf Is the bottom hole flow pressure, MPa; q is daily oil production, m 3 /d; A. b is the slope and intercept of the fitting respectively; beta, b pss Is a correlation coefficient in which: />
Further, in the step S106, the method for determining the boundary stream time node is as follows:
at a regulated pressure P d And normalized pressure derivative P d ' on the ordinate, in terms of the mass balance time t c Drawing a double-logarithmic curve graph for the abscissa, wherein when the slope of the double-logarithmic curve reaches 1, the corresponding material balance time is a boundary flow time node;
wherein,
in the above, P i Is the initial formation pressure, MPa; p (P) wf Is the bottom hole flow pressure, MPa; q o For daily oil production, m 3 /d；N p Cumulative oil production, m 3 。
Compared with the prior art, the invention has the beneficial effects that:
(1) The invention uses the static material balance equation and the dynamic Agarwal-Gardner deformation equation to be combined, uses the yield, the single well control reserve and the formation pressure as related parameters, and performs cyclic iteration solution by assuming the single well control reserve, so that two important indexes of the single well control reserve and the dynamic formation pressure can be obtained simultaneously, the matching property of the two indexes is ensured, the reliability of the result is ensured, the calculation of the single well control reserve and the dynamic monitoring of the formation pressure in the production process are realized, and the invention has important guiding significance for evaluating the production capacity, the recovery degree and the recovery ratio of the single well, analyzing, developing and deploying rationality, guiding, adjusting, developing and deploying and the like;
(2) The invention adopts the material balance based on the common production dynamic dataThe equation and linear characteristic horizontal well reserve control equation is used for solving single well control reserve and dynamic stratum pressure, the single well control reserve is obtained only through simple linear fitting, the calculation method is simple, convenient and economical, the professional level requirement on operators is not high, programming can be used for realizing programmed batch calculation, limitation of interpretation model selection is avoided, and meanwhile daily output data fitting correlation degree R 2 The calculation result is reliable and can reach more than 60%;
(3) The method is based on a substance balance equation and a horizontal well reserve control equation deduced when the horizontal well reaches a quasi-steady state stage, can be suitable for calculating conventional oil reservoir control reserves, is also suitable for calculating tight reservoir oil reservoir control reserves, evaluates the recovery ratio by analyzing production effects at different well distances, and can guide optimization of development parameters such as well pattern, well distance and the like of the fractured horizontal well by combining with the benefit to optimize the scheme, so that the problem that the static method evaluation reserves are high or low due to overlarge well distance or fracturing channeling in the volume fractured horizontal well can be effectively solved; the problems of complex operation, poor fitting precision caused by poor quality of partial well data and time waste when more wells exist in the unstable progressive method can be avoided;
(4) The dynamic combined calculation model of the flow pressure is the bottom hole flow pressure calculated by adopting the model with the minimum error when the oil gas ratio changes in the production process, so that the expansion of the error of the flow pressure calculation caused by single model calculation can be effectively avoided, and the accuracy of a calculation result is ensured.
Drawings
FIG. 1 is a flow chart of a method for simultaneously obtaining single well control reserves and dynamic formation pressure for an oil well in accordance with an embodiment of the present invention;
FIG. 2 is a graph showing error line intersections of different flow pressure models at different gas-oil ratios in accordance with an embodiment of the present invention;
FIG. 3 is a graph of dynamic tracking of the bottom hole flow pressure of a horizontal well in accordance with an embodiment of the present invention;
FIG. 4 is a graph of data processing for a tight reservoir horizontal well according to an embodiment of the present invention;
FIG. 5 is a graph of iterative calculations of horizontal well dynamic formation pressure in accordance with an embodiment of the present invention;
FIG. 6 is a fitting iteration diagram of a horizontal well reserve control equation according to an embodiment of the present invention;
FIG. 7 is a graph showing a determination of a horizontal well boundary flow time node according to an embodiment of the present invention;
FIG. 8 is a graph of dynamic formation pressure for an embodiment of the present invention.
Detailed Description
The following description of the embodiments of the present invention will be made clearly and completely with reference to the accompanying drawings, in which it is apparent that the embodiments described are only some embodiments of the present invention, but not all embodiments. All other embodiments, which can be made by those skilled in the art based on the embodiments of the invention without making any inventive effort, are intended to be within the scope of the invention.
Example 1
As shown in fig. 1, the method for obtaining the control reserves and the dynamic formation pressure of the single well of the oil well based on the production data provided by the invention comprises the following steps:
step S101: acquiring and analyzing mining field production data, PVT physical parameters, well depth track and fracturing data;
the method comprises the following steps: analyzing PVT physical parameters, and fitting a related calculation formula of each parameter and pressure by adopting a multiple regression method; related methods such as Standing, beggs-Robinson, vasquez-Beggs can also be adopted to obtain related formulas of each parameter and pressure so as to facilitate subsequent calculation and use;
analyzing production data of a mining field, analyzing whether fracturing interference exists between fracturing fluid and other well groups according to wellhead pressure and water content of a temporary well (when the fracturing interference occurs, the pressure and the water content are suddenly increased), and correcting effective injected fracturing fluid W injected into a stratum by the well according to the following steps if the fracturing interference exists i :
W i ＝W si -W pi (1)
W pi ＝(q 2 -q 1 )*t (2)
In the above formulas (1) and (2), W si For injection of fracturing fluid volume, m 3 ；W pi Fluid quantity, m, of adjacent well channeling 3 ；q 1 To disturb the pre-produced water flow, m 3 /d；q 2 To produce water flow during disturbance, m 3 /d; t is the disturbance time (the time from the sudden rise of the water content to the restoration of the pre-disturbance water content) d.
Step S102: calculating the bottom hole flow pressure by utilizing a plurality of wellbore multiphase pipe flow models, and screening and constructing a dynamic combination calculation model of the flow pressure in the production process according to the principle of minimum error when the oil-gas ratio is changed in the production process; and calculating the bottom hole flow pressure at different production time according to the flow pressure dynamic combination calculation model.
The purpose of the step S102 is to select the flow pressure calculation model under the condition of different production time, calculate the bottom hole flow pressure under the condition of different production time, so as to accurately calculate the normalized output data and ensure the reliable fitting result; the specific implementation process is as follows:
calculating the bottom hole flow pressure by using a multi-class multiphase pipe flow calculation method (Beggs-Bril method, orkiszewski method, aziz-Govier-Fogarasi method, hagedorn-Brown method and the like), comparing with actual flow pressure production test data, taking absolute values of relative errors, constructing error line intersection diagrams of different flow pressure models under different oil-gas ratios as shown in figure 2, thereby obtaining a calculation model with the minimum errors under different oil-gas ratio intervals (see table 1), forming a dynamic flow pressure combination calculation model in the production process by the calculation model with the minimum errors under different oil-gas ratio intervals, and calculating the change value of the flow pressure along with the production time according to the dynamic flow pressure combination calculation model (see figure 3). The dynamic combined calculation model of the flow pressure is used for calculating the bottom hole flow pressure by adopting a model with the minimum error when the oil gas ratio changes in the production process, so that the expansion of the error of the flow pressure calculation caused by single-model calculation can be effectively avoided, and the accuracy of a calculation result is ensured.
TABLE 1 optimal flow pressure calculation model for different gas-oil ratios
Step S103: the data is subjected to a movement smoothing process based on the pressure recognition (see fig. 4).
Specifically, in order to avoid calculation errors caused by poor data quality and abnormal point transition deletion, identifying abnormal points of the flow pressure by using an MAD method, defining a threshold MAD in the MAD method, and setting the threshold MAD as a local average value; if the numerical value of the data point is greater than or equal to the threshold MAD which is 3 times, the data point is considered to be an outlier, so that the abnormal point of the flow pressure can be obtained, and the production data corresponding to the abnormal point of the flow pressure is the abnormal point of the production data; according to the cubic spline interpolation calculation processing, the numerical value is obtained by interpolation to replace the numerical value at the abnormal point, meanwhile, the whole data is subjected to mobile smoothing processing after interpolation, namely, a curve is fitted by taking n adjacent data points, and then the numerical value at the corresponding position on the curve is used as a result after data point filtering (in the prior art, the method can be realized by adopting various methods, such as a smooth function in Matlab software), so that the whole data mobile smoothing processing process is completed.
Because the production data is more influenced by external factors, certain noise points can be generated, and the purpose of smoothing the data is as follows: the influence of noise points can be reduced, so that the subsequent fitting calculation is more accurate; meanwhile, in the step, the abnormal points are judged by utilizing pressure identification, so that the excessive deletion of the production data points can be reduced, and the subsequent fitting calculation accuracy is further ensured compared with the direct utilization of the yield to judge the abnormal points.
Step S104: and establishing the relation among production data, formation pressure, single well control reserves and bottom hole flow pressure by using a material balance equation and a horizontal well reserve control equation.
Specifically, the process mainly comprises the steps of establishing a relation model, determining known parameters and unknown parameters related to each model, simultaneously analyzing whether production data reach a boundary flow state, combining the relation model in a subsequent solving process, performing loop iteration fitting calculation according to steps S105-S107, and simultaneously obtaining oil well single well control reserves and dynamic stratum pressure.
(1) Equation of mass balance
The material balance equation mainly considers formation pressure P r At least the saturation pressure P b Formation pressure P r Less than saturation pressure P b In both cases, the following formulas (3) and (4) are obtained:
when P r ≥P b In the time-course of which the first and second contact surfaces,
when P r <P b In the time-course of which the first and second contact surfaces,
in the above formulas (3), (4): p (P) i Is the original formation pressure, MPa;is the formation pressure in the production process, MPa; n (N) p For accumulating oil production, m 3 The method comprises the steps of carrying out a first treatment on the surface of the N is single well control reserve, m 3 ；C w Is the compression coefficient of water, MPa -1 ；C f Is the compression coefficient of rock, MPa -1 ；B o Is the volume coefficient of crude oil; b (B) g Is the volume coefficient of the solution gas; b (B) oi Is the original volume coefficient of crude oil; b (B) w Is the volume coefficient of formation water; b (B) T Is the two-phase volume coefficient of crude oil; b (B) Ti Is the two-phase volume coefficient of the original crude oil, B Ti ＝B o +(R si -R s )B gi ，B gi Is the original volume coefficient of the dissolved gas; r is R p To accumulate the oil-gas ratio, m 3 /m 3 ；R s To dissolve the oil-gas ratio, m 3 /m 3 ；R si For the original dissolved gas ratio, m 3 /m 3 ；S wc To irreducible water saturation, decimal; w (W) i For effective injection of fracturing fluid volume, m 3 ；W p For accumulating the water yield, m 3 。
The correlation between the parameters such as the compression coefficient and the two-phase coefficient and the pressure can be obtained through the PVT physical parameters in step S101, so that the unknown variables in the equation are: formation pressureSingle well control reserves N.
(2) Reservoir control equation for horizontal well
The horizontal well reserve control equation is obtained by deducting the dimensionless pressure expression of the quasi-steady-state stage of the horizontal well in combination with the Agarwal-Gardner equation.
The dimensionless pressure expression of the quasi-steady-state stage of the horizontal well is as follows:
Agarwal-Gardner (Argarval-Gardner) equation was introduced:
the reduction of bringing equation (6) into equation (5) yields:
p D ＝2πt DA +ln r eD -α (7)
the formula (7) is factorized:
simplifying and converting the formula (8):
material balance time t for time t in formula (9) c ＝N p Substitution of/q:
multiplying both sides of equation (10) by q/Δpb simultaneously pss The reserve control equation of the horizontal well is deduced as follows:
in the above formulas (5) to (11): p is p D Is dimensionless pressure; t is t D Is dimensionless time; r is (r) eD Is the dimensionless oil drainage radius; l (L) D Is dimensionless horizontal segment long; r is (r) wD Is a dimensionless wellbore radius; z wD The dimensionless height of the horizontal well from the bottom of the oil layer; t is t DA Dimensionless time for well control area; k is the reservoir permeability, mD; r is (r) w Is the radius of the shaft, m; c (C) t Is the compression coefficient, MPa -1 The method comprises the steps of carrying out a first treatment on the surface of the Phi is the porosity, decimal; mu is the viscosity of crude oil, mPa.s; s is the oil drainage area, m 2 ；For the production of pressure differences, MPa; p (P) wf Is the bottom hole flow pressure, MPa; h is the thickness of the oil layer, m; t is t c Is the material equilibration time; q is daily oil production, m 3 /d; A. b is the slope and intercept of the fitting respectively; alpha, beta, m, b pss Is a correlation coefficient in which:
the deduced equation (11) for controlling the reserve of the horizontal well mainly relates to parameters related to yield, formation pressure, bottom hole flow pressure and compression coefficient, wherein dynamic yield and flow pressure can be obtained from production data and are known parameters; the dependence of the integrated compression coefficient on pressure can be achieved byThe PVT physical property parameters in the step S101 are obtained; thus, the unknown variables in this equation are also: formation pressureSingle well control reserves N.
Therefore, multiple relations among production data, formation pressure, single well control reserves and bottom hole flow pressure can be established through correlation of a material balance equation and a horizontal well reserve control equation, so that in the subsequent steps, the control reserves are further assumed, and through cyclic iterative fitting calculation, the single well control reserves and the dynamic formation pressure of the oil well are obtained.
Step S105: presetting single well control reserve as N Estimation of And calculating the dynamic formation pressure by using a material balance equation and combining production data.
Specifically, a single well is given control reserves to a preset value N Estimation of According to the material balance equation formulas (3) and (4), the relation between the formation pressure and the accumulated oil yield can be calculated, and the dynamic formation pressure can be obtained, and the formation pressure curve is calculated by 1 iteration shown in fig. 5.
Step S106: construction of N using calculated dynamic formation pressure, flow pressure and cumulative oil production data p /△pC t And the scattered point relation graph of q/[ delta ] p, then adopting a horizontal well reserve control equation to perform linear fitting on scattered point data after boundary flow time to obtain a correlation coefficient A, B, and calculating new single well control reserve N according to the following regression equation Meter with a meter body ；
Wherein N is p For accumulating oil production, m 3 The method comprises the steps of carrying out a first treatment on the surface of the Δp is the differential pressure of production, MPa; c (C) t To synthesize the compression coefficient, MPa -1 The method comprises the steps of carrying out a first treatment on the surface of the q is daily oil production, m 3 /d。
Specifically, the calculated dynamic formation pressure, flow pressure and yield data are in one-to-one correspondence with each other according to time, and the accumulated oil yield N is calculated respectively p The production pressure difference delta p can construct N p /△pC t A scatter plot with q/DELTAp; then, linear fitting is carried out on scattered data after boundary flow time nodes by adopting a horizontal well reserve control equation, the correlation coefficient A, B (first iterative calculation data shown in fig. 6) in the formula (11) is obtained by fitting, and a new single well control reserve N can be calculated by regression of the formula (12) Meter with a meter body 。
The heart of this fit demarcation point is the determination of the boundary flow control reserve. According to classical percolation theory, the slope of the pressure, pressure derivative vs. time log curve is 1 when the boundary flow is reached. According to the feature, the method for determining the boundary stream time node comprises the following steps:
as shown in FIG. 7, at a regulated pressure P d And normalized pressure derivative P d ' on the ordinate, in terms of the mass balance time t c Drawing a double-logarithmic curve graph for the abscissa, wherein when the slope of the double-logarithmic curve reaches 1, the corresponding material balance time is a boundary flow time node;
wherein,
in the above formulae (13) to (15), P i Is the initial formation pressure, MPa; p (P) wf Is the bottom hole flow pressure, MPa; q o For daily oil production, m 3 /d；N p Cumulative oil production, m 3 。
Step S107: calculated value N of single well control reserve Meter with a meter body And a preset value N Estimation of Is compared with the error value epsilon,
if |N Estimation of -N Recording device Outputting the finally calculated single well control reserves and movements of the oil well when the I is less than or equal to epsilonA formation pressure in a state;
if |N Estimation of -N Recording device |>Epsilon, then take the single well control reserve n=0.5 (N Estimation of +N Recording device ) As a new preset value N Estimation of Returning to step S105, recalculating to obtain a calculated value N of the single well control reserves Meter with a meter body The method comprises the steps of carrying out a first treatment on the surface of the And iterating according to the loop until the calculation result meets the error requirement, and outputting the finally calculated oil well single well control reserve and dynamic stratum pressure. The resulting dynamic formation pressure profile of an embodiment of the present invention is shown in FIG. 8.
The foregoing description is only exemplary of the invention and is not intended to limit the invention. Any modification, equivalent replacement, improvement, etc. made within the scope of the present invention should be included in the protection scope of the present invention.
Claims (9)
1. A method for determining oil well single well control reserves and dynamic formation pressure based on production data, the method comprising the steps of:
step S101: acquiring and analyzing mining field production data, PVT physical parameters, well depth track data and fracturing data;
step S102: calculating the bottom hole flow pressure by utilizing a plurality of wellbore multiphase pipe flow models, and screening and constructing a dynamic combination calculation model of the flow pressure in the production process according to the principle of minimum error when the oil-gas ratio is changed in the production process; calculating the bottom hole flow pressure at different production time according to the flow pressure dynamic combination calculation model;
step S103: smoothing the data based on the pressure identification;
step S104: establishing a relation among production data, formation pressure, single well control reserves and bottom hole stream pressure by using a material balance equation and a horizontal well reserve control equation;
step S105: presetting single well control reserve as N Estimation of Calculating dynamic formation pressure by combining production data with a material balance equation;
step S106: construction of N using calculated dynamic formation pressure, bottom hole flow pressure and accumulated oil production data p /△pC t A scatter plot with q/. DELTA.p,then, linear fitting is carried out on scattered data after boundary flow time nodes by adopting a horizontal well reserve control equation, a correlation coefficient A, B is obtained by fitting, and a new single well control reserve N can be calculated by regression according to the following formula Meter with a meter body ；
Wherein N is p For accumulating oil production, m 3 The method comprises the steps of carrying out a first treatment on the surface of the Δp is the differential pressure of production, MPa; c (C) t To synthesize the compression coefficient, MPa -1 The method comprises the steps of carrying out a first treatment on the surface of the q is daily oil production, m 3 /d；
Step S107: calculated value N of single well control reserve Meter with a meter body And a preset value N Estimation of Is compared with the error value epsilon,
if |N Estimation of -N Meter with a meter body Outputting the finally calculated single well control reserves and dynamic stratum pressure of the oil well;
if |N Estimation of -N Meter with a meter body |>Epsilon, then take the single well control reserve n=0.5 (N Estimation of +N Meter with a meter body ) As a new preset value N Estimation of Returning to step S105, recalculating to obtain a calculated value N of the single well control reserves Meter with a meter body The method comprises the steps of carrying out a first treatment on the surface of the And iterating according to the loop until the calculation result meets the error requirement, and outputting the finally calculated oil well single well control reserve and dynamic stratum pressure.
2. The method according to claim 1, wherein the step S101 includes:
analyzing PVT physical parameters, and fitting a formula of each parameter and pressure;
analyzing whether fracturing interference exists between the single well fracturing fluid and other well groups, and correcting the effective injection fracturing fluid W of the single well injected stratum according to the following condition if the fracturing interference exists i ：
W i ＝W si -W pi
In the above, W si For injection of fracturing fluid volume, m 3 ；W pi Fluid quantity, m, of adjacent well channeling 3 。
3. The method according to claim 1, wherein the step S102 specifically includes:
calculating the bottom hole flow pressure by using a multi-class multiphase pipe flow calculation method, comparing the bottom hole flow pressure with actual flow pressure production test data, calculating the absolute value of the relative error of the bottom hole flow pressure and the actual flow pressure production test data, constructing error line intersection diagrams of different flow pressure models under different oil-gas ratios, and obtaining a calculation model with the minimum error under different oil-gas ratio intervals, wherein the calculation models with the minimum error jointly form a flow pressure dynamic combination calculation model in the production process; and calculating the change value of the position flow pressure along with the production time according to the dynamic flow pressure combination calculation model.
4. A method according to claim 3, wherein the multiphase pipe flow computing method comprises Beggs-Bril method, orkiszewski method, aziz-Govier-Fogarasi method, and Hagedorn-Brown method.
5. The method according to claim 1, wherein the step S103 specifically includes:
identifying abnormal points of the flow pressure by using an MAD method, and judging abnormal points of the production data according to the abnormal points of the flow pressure; and carrying out interpolation calculation processing on the abnormal point of the flow pressure and the abnormal point of the production data according to a cubic spline method, obtaining a numerical value by interpolation to replace the numerical value at the abnormal point, and carrying out movement smoothing processing on the whole data after interpolation.
6. The method according to claim 5, wherein in the step S103, the abnormal point of the flow pressure is identified by the MAD method, and the abnormal point of the production data is determined according to the abnormal point of the flow pressure, specifically comprising:
setting the threshold MAD as a local average value, and if the value of the data point is greater than or equal to the threshold MAD which is 3 times, considering the data point as an outlier, thereby obtaining the abnormal flow pressure point, and the production data corresponding to the abnormal flow pressure point is the abnormal production data point.
7. Root of Chinese characterThe method according to claim 1, wherein in step S104, the formation pressure P is taken into account r And saturation pressure P b The relation between the materials is that the material balance equation is specifically:
when P r ≥P b In the time-course of which the first and second contact surfaces,
when P r <P b In the time-course of which the first and second contact surfaces,
in the above formula: p is p i Is the original formation pressure, MPa;is the formation pressure in the production process, MPa; n (N) p For accumulating oil production, m 3 The method comprises the steps of carrying out a first treatment on the surface of the N is single well control reserve, m 3 ；C w Is the compression coefficient of water, MPa -1 ；C f Is the compression coefficient of rock, MPa -1 ；B o Is the volume coefficient of crude oil; b (B) g Is the volume coefficient of the solution gas; b (B) oi Is the original volume coefficient of crude oil; b (B) w Is the volume coefficient of formation water; b (B) T Is the two-phase volume coefficient of crude oil; b (B) Ti Is the two-phase volume coefficient of the original crude oil, B Ti ＝B o +(R si -R s )B gi ，B gi Is the original volume coefficient of the dissolved gas; r is R p To accumulate the oil-gas ratio, m 3 /m 3 ；R s To dissolve the oil-gas ratio, m 3 /m 3 ；R si For the original dissolved gas ratio, m 3 /m 3 ；S wc To irreducible water saturation, decimal; w (W) i For effective injection of fracturing fluid volume, m 3 ；W p For accumulating the water yield, m 3 。
8. The method according to claim 7, wherein in the step S104, the horizontal well reserve control equation is derived by combining a dimensionless pressure expression of a quasi-steady-state phase of a horizontal well with an Agarwal-Gardner equation;
the dimensionless pressure expression of the quasi-steady-state stage of the horizontal well is as follows:
the Agarwal-Gardner equation is:
the reserve control equation of the horizontal well is as follows:
in the above formula: p is p D Is dimensionless pressure; t is t D Is dimensionless time; r is (r) eD Is the dimensionless oil drainage radius; l (L) D Is dimensionless horizontal segment long; r is (r) wD Is a dimensionless wellbore radius; z wD The dimensionless height of the horizontal well from the bottom of the oil layer; k is the reservoir permeability, mD; r is (r) w Is the radius of the shaft, m; c (C) t Is the compression coefficient, MPa -1 The method comprises the steps of carrying out a first treatment on the surface of the Phi is the porosity, decimal; mu is the viscosity of crude oil, mPa.s; s is the oil drainage area, m 2 ；For the production of pressure differences, MPa; p (P) wf Is the bottom hole flow pressure, MPa; q is daily oil production, m 3 /d; A. b is the slope and intercept of the fitting respectively; beta, b pss Is a correlation coefficient in which: />
9. The method according to claim 8, wherein in the step S106, the determining method of the boundary stream time node is:
at a regulated pressure P d And normalized pressure derivative P d ' on the ordinate, in terms of the mass balance time t c Drawing a double-logarithmic curve graph for the abscissa, wherein when the slope of the double-logarithmic curve reaches 1, the corresponding material balance time is a boundary flow time node;
wherein,
in the above, P i Is the initial formation pressure, MPa; p (P) wf Is the bottom hole flow pressure, MPa; q o For daily oil production, m 3 /d；N p Cumulative oil production, m 3 。
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