CN107563899A

CN107563899A - Oil ＆ Gas Productivity Forecasting Methodology and device

Info

Publication number: CN107563899A
Application number: CN201610509568.5A
Authority: CN
Inventors: 郭秀庭; 强华; 葛党科; 单桂栋; 杨继军; 翁博; 任世举; 王军恒
Original assignee: China Petroleum and Natural Gas Co Ltd
Current assignee: China Petroleum and Natural Gas Co Ltd
Priority date: 2016-06-30
Filing date: 2016-06-30
Publication date: 2018-01-09
Anticipated expiration: 2036-06-30
Also published as: CN107563899B

Abstract

The invention discloses a kind of Oil ＆ Gas Productivity Forecasting Methodology and device, belong to petroleum exploration domain.This method includes：Obtain the test information of Oil/gas Well；According to the test information, inflow performance model of the Oil/gas Well within the current capability forecasting cycle is determined；According to the inflow performance model in the current capability forecasting cycle, it is determined that the following mean reservoir pressure in yield and next capability forecasting cycle in the current capability forecasting cycle；According to the following mean reservoir pressure of the Oil/gas Well in inflow performance model of the Oil/gas Well within the current capability forecasting cycle and next capability forecasting cycle, inflow performance model of the Oil/gas Well within next capability forecasting cycle is determined, and predicts production capacity of the Oil/gas Well within next capability forecasting cycle.Method provided by the invention, the test information that formation testing or gas testing can be utilized to obtain, thermally coupled flow of the Oil/gas Well under some following production time is determined, so as to be predicted to the following production capacity of the Oil/gas Well.

Description

Oil ＆ Gas Productivity Forecasting Methodology and device

Technical field

The present invention relates to petroleum exploration domain, more particularly to a kind of Oil ＆ Gas Productivity Forecasting Methodology and device.

Background technology

At oil-gas exploration and development initial stage, it is determined that and prediction prospect pit or new production well capacity, be in oilfield exploitation procedure An essential important process.Prospect pit or new production well capacity are predicted, are related to the EARLY STAGE EVALUATION of oil-gas reservoir, It is not only the needs of the planning of establishment new district oil-gas field development or development plan, and the foundation of surface construction and basis.

Current PRODUCTION FORECASTING METHODS is mainly the production period in Oil/gas Well, and oil gas well yield and flowing bottomhole pressure (FBHP) are entered Row test, and the yield data obtained using test and corresponding flowing bottomhole pressure (FBHP) data establish productivity prediction model, so as to follow-up Yield under different flowing bottomhole pressure (FBHP)s is predicted according to the productivity prediction model.Productivity prediction model is also referred to as inflow performance model, represents The dynamic relationship of yield and flowing bottomhole pressure (FBHP), oil-gas reservoir is reflected to the ability of the well fuel feeding or supply.

During the present invention is realized, inventor has found that prior art at least has problems with：

Strata pressure under the different production phases may be different, and the productivity prediction model under Different Strata pressure is not yet Together, and by the above method what is obtained is only productivity prediction model under the current production phase, that is to say and is currently fifty-fifty laminated Productivity prediction model under power, therefore, the production capacity under the following production phase can not be carried out according to the productivity prediction model pre- Survey.

The content of the invention

In order to solve problem of the prior art, the embodiments of the invention provide a kind of Oil ＆ Gas Productivity Forecasting Methodology and dress Put.The technical scheme is as follows：

First aspect, there is provided a kind of Oil ＆ Gas Productivity Forecasting Methodology, methods described include：

The test information of Oil/gas Well is obtained, when the Oil/gas Well is oil well, the test information is that the oil well is entered Row formation testing obtains, and when the Oil/gas Well is gas well, the test information is to carry out gas testing to the gas well to obtain；

According to the test information, inflow performance model of the Oil/gas Well within the current capability forecasting cycle is determined；

According to inflow performance model of the Oil/gas Well within the current capability forecasting cycle, next capability forecasting cycle is determined The following mean reservoir pressure of the interior Oil/gas Well；

According to inflow performance model of the Oil/gas Well within the current capability forecasting cycle and next capability forecasting week The following mean reservoir pressure of the Oil/gas Well in phase, determine inflow of the Oil/gas Well within next capability forecasting cycle Dynamic model；

According to inflow performance model of the Oil/gas Well within next capability forecasting cycle, predict that the Oil/gas Well exists Production capacity in next capability forecasting cycle.

Alternatively, the inflow performance model according to the Oil/gas Well within the current capability forecasting cycle, is determined next The following mean reservoir pressure of the Oil/gas Well in the capability forecasting cycle, including：

According to inflow performance model of the Oil/gas Well within the current capability forecasting cycle, the current capability forecasting is determined Oil gas well production corresponding to cycle；

According to oil gas well production corresponding to the current capability forecasting cycle, the current capability forecasting end cycle is determined When cumulative production；

According to cumulative production during the current capability forecasting end cycle, using specified oil-gas reservoir material balance model, The mean reservoir pressure of Oil/gas Well when calculating the current capability forecasting end cycle；

The mean reservoir pressure of Oil/gas Well during the current capability forecasting end cycle is defined as next production The following mean reservoir pressure of the Oil/gas Well in energy predetermined period.

Alternatively, the current inflow performance model according to the Oil/gas Well within the current capability forecasting cycle and described The following mean reservoir pressure of the Oil/gas Well in next capability forecasting cycle, determine that the Oil/gas Well is pre- in next production capacity The inflow performance model surveyed in the cycle, including：

According to inflow performance model of the Oil/gas Well within the current capability forecasting cycle, calculate the oil well and put down currently Production capacity index under equal strata pressure, wherein, when the Oil/gas Well is oil well, the production capacity index is fluid productivity index, works as institute When to state Oil/gas Well be gas well, the production capacity index is maximum open-flow capacity；

According to the current production capacity index and institute of mean reservoir pressure, the Oil/gas Well under current mean reservoir pressure The following mean reservoir pressure in next capability forecasting cycle is stated, calculates the Oil/gas Well within next capability forecasting cycle Following mean reservoir pressure under production capacity index；

According to the following mean reservoir pressure in next capability forecasting cycle and the Oil/gas Well in next production The production capacity index under following mean reservoir pressure in energy predetermined period, determine the Oil/gas Well in next capability forecasting week Inflow performance model in phase.

Alternatively, the inflow performance model according to the Oil/gas Well within the current capability forecasting cycle, determine described current Oil gas well production corresponding to the capability forecasting cycle, including：

Prediction flowing bottomhole pressure (FBHP) corresponding to determining the current capability forecasting cycle, according to the prediction flowing bottomhole pressure (FBHP), is utilized Inflow performance model of the Oil/gas Well within the current capability forecasting cycle calculates pre- corresponding to the current capability forecasting cycle Geodetic laminar flow enters yield；

Determine the oil gas mouth size that production is used in the current capability forecasting cycle, according to the prediction flowing bottomhole pressure (FBHP), The predictably laminar flow enters yield and the oil gas mouth size, determines prediction surface flow corresponding to the current capability forecasting cycle Yield；

It is less than default miss when the predictably laminar flow enters the relative error between yield and the prediction surface flow yield When poor, the predictably laminar flow is entered into yield and is defined as oil gas well production corresponding to the current capability forecasting cycle.

It is alternatively, described that yield and the oil gas mouth size are entered according to the prediction flowing bottomhole pressure (FBHP), the predictably laminar flow, Prediction surface flow yield corresponding to the current capability forecasting cycle is determined, including：

Yield is entered according to prediction shaft bottom stream and the predictably laminar flow, using described in the calculating of specified wellbore flow model Prediction well head oil pressure corresponding to the current capability forecasting cycle；

According to the prediction well head oil pressure and the oil gas mouth size, described work as is calculated using specified Oil/gas Well mouth flow model Prediction surface flow yield corresponding to the preceding capability forecasting cycle.

Alternatively, the yield according to corresponding to the current capability forecasting cycle, the current capability forecasting week is determined Cumulative production at the end of phase, including：

When the predictably laminar flow enters yield and the relative error predicted between surface flow yield less than described pre- If during error, the prediction well head oil pressure is defined as well head oil pressure corresponding to the current capability forecasting cycle；

Determine the Oil/gas Well back pressure that production is used in the current capability forecasting cycle；

When yield corresponding to the current capability forecasting cycle is more than minimum output threshold value, the current capability forecasting cycle Corresponding well head oil pressure is more than minimum well head oil pressure threshold value and the currently well head oil pressure corresponding to the capability forecasting cycle is more than institute When stating twice of Oil/gas Well back pressure, determine that the Oil/gas Well meets blowing condition, and perform described pre- according to the current production capacity Oil gas well production corresponding to surveying the cycle, the step of cumulative production when determining the current capability forecasting end cycle.

Alternatively, the cumulative production according to during the current capability forecasting end cycle, utilizes specified oil-gas reservoir thing Matter balance model, the mean reservoir pressure of Oil/gas Well when calculating the current capability forecasting end cycle, including：

When the Oil/gas Well is oil well, according to the cumulative oil production of the oil well, oil reservoir material balance model meter is utilized Calculate reservoir formation pressure drop during the current capability forecasting end cycle；

The reservoir formation pressure drop is added with the prediction flowing bottomhole pressure (FBHP), obtains the current capability forecasting cycle At the end of the Oil/gas Well mean reservoir pressure.

Alternatively, the cumulative production according to during the current capability forecasting end cycle, utilizes specified oil-gas reservoir thing Matter balance model, following mean reservoir pressure when calculating the current capability forecasting end cycle in the Oil/gas Well, including：

When the Oil/gas Well is gas well, according to the cumulative gas production of the gas well, gas reservoirs balance model meter is utilized The mean reservoir pressure of gas well when calculating the current capability forecasting end cycle.

Alternatively, the inflow performance model according to the Oil/gas Well within next capability forecasting cycle, prediction After production capacity of the Oil/gas Well within next capability forecasting cycle, in addition to：

According to inflow performance model of the Oil/gas Well within next capability forecasting cycle, predict in next production Can in predetermined period the Oil/gas Well whether blowing.

Second aspect, there is provided a kind of Oil ＆ Gas Productivity prediction meanss, described device include：

Acquisition module, for obtaining the test information of Oil/gas Well, when the Oil/gas Well is oil well, the test information is Formation testing is carried out to the oil well to obtain, when the Oil/gas Well is gas well, the test information is to carry out gas testing to the gas well Obtain；

First determining module, for according to the test information, determining the Oil/gas Well within the current capability forecasting cycle Inflow performance model；

Second determining module, for the inflow performance model according to the Oil/gas Well within the current capability forecasting cycle, really Fix the following mean reservoir pressure of the Oil/gas Well in a capability forecasting cycle；

3rd determining module, for according to inflow performance model of the Oil/gas Well within the current capability forecasting cycle and institute The following mean reservoir pressure of the Oil/gas Well in next capability forecasting cycle is stated, determines the Oil/gas Well in next production capacity Inflow performance model in predetermined period；

First prediction module, for the thermally coupled flow mould according to the Oil/gas Well within next capability forecasting cycle Type, predict production capacity of the Oil/gas Well within next capability forecasting cycle.

The beneficial effect that technical scheme provided in an embodiment of the present invention is brought is：

Technical method provided in an embodiment of the present invention, the test letter that can be obtained using formation testing or gas testing is carried out to Oil/gas Well Breath, determines inflow performance model of the Oil/gas Well within the current capability forecasting cycle, and determines to be somebody's turn to do in next capability forecasting cycle The following mean reservoir pressure of Oil/gas Well, so as to according to the inflow performance model in the current capability forecasting cycle and this not Carry out mean reservoir pressure and determine inflow performance model of the Oil/gas Well within next capability forecasting cycle, afterwards, you can according to Inflow performance model in next capability forecasting cycle predicts the production capacity in next capability forecasting cycle.It that is to say, can be with The test information obtained using formation testing or gas testing, inflow performance model of the Oil/gas Well in the following production phase is determined, and should Inflow performance model is the inflow performance model under following mean reservoir pressure, therefore can be to this according to the inflow performance model The following production capacity of Oil/gas Well is predicted, so as in new prospecting area, prospector be helped to understand and predict not same order in time The prospect pit of section or new production well capacity, have to further understanding oil-gas reservoir and the development of deployment next stage and instruct to anticipate Justice.

Brief description of the drawings

Technical scheme in order to illustrate the embodiments of the present invention more clearly, make required in being described below to embodiment Accompanying drawing is briefly described, it should be apparent that, drawings in the following description are only some embodiments of the present invention, for For those of ordinary skill in the art, on the premise of not paying creative work, other can also be obtained according to these accompanying drawings Accompanying drawing.

Fig. 1 is a kind of Oil ＆ Gas Productivity Forecasting Methodology flow chart provided in an embodiment of the present invention；

Fig. 2 is a kind of Oil ＆ Gas Productivity Forecasting Methodology flow chart provided in an embodiment of the present invention；

Fig. 3 is a kind of Oil ＆ Gas Productivity prediction meanss block diagram provided in an embodiment of the present invention.

Embodiment

To make the object, technical solutions and advantages of the present invention clearer, below in conjunction with accompanying drawing to embodiment party of the present invention Formula is described in further detail.

Fig. 1 is a kind of Oil ＆ Gas Productivity Forecasting Methodology flow chart provided in an embodiment of the present invention, and referring to Fig. 1, this method can With including the following steps：

Step 101：The test information of Oil/gas Well is obtained, when the Oil/gas Well is oil well, the test information is to the oil well Carry out formation testing to obtain, when the Oil/gas Well is gas well, the test information is to carry out gas testing to the gas well to obtain.

Step 102：According to the test information, thermally coupled flow mould of the Oil/gas Well within the current capability forecasting cycle is determined Type.

Step 103：According to inflow performance model of the Oil/gas Well within the current capability forecasting cycle, determine that next production capacity is pre- Survey the following mean reservoir pressure of the Oil/gas Well in the cycle.

Step 104：It is pre- according to inflow performance model of the Oil/gas Well within the current capability forecasting cycle and next production capacity The following mean reservoir pressure of the Oil/gas Well in the cycle is surveyed, determines that inflow of the Oil/gas Well within next capability forecasting cycle is moved States model.

Step 105：According to inflow performance model of the Oil/gas Well within next capability forecasting cycle, the Oil/gas Well is predicted Production capacity within next capability forecasting cycle.

In summary, Oil ＆ Gas Productivity Forecasting Methodology provided in an embodiment of the present invention, formation testing or gas testing can be utilized to obtain Test information, determine inflow performance model of the Oil/gas Well in the following production phase, and the inflow performance model is future Inflow performance model under mean reservoir pressure, therefore the following production capacity of the Oil/gas Well can be entered according to the inflow performance model The accurate prediction of row, so as in new prospecting area, prospector be helped to understand and predict prospect pit or the new life of different phase in time Well capacity is produced, there is directive significance to further understanding oil-gas reservoir and the development for disposing the next stage.

Alternatively, the inflow performance model according to the Oil/gas Well within the current capability forecasting cycle, determine that next production capacity is pre- The mean reservoir pressure of the Oil/gas Well in the cycle is surveyed, including：

According to inflow performance model of the Oil/gas Well within the current capability forecasting cycle, the current capability forecasting cycle is determined Corresponding oil gas well production；

According to oil gas well production corresponding to the current capability forecasting cycle, when determining the current capability forecasting end cycle Cumulative production；

According to cumulative production during the current capability forecasting end cycle, specified oil-gas reservoir material balance model, meter are utilized The mean reservoir pressure of Oil/gas Well when calculating the current capability forecasting end cycle；

The mean reservoir pressure of Oil/gas Well during the current capability forecasting end cycle is defined as next capability forecasting The following mean reservoir pressure of the Oil/gas Well in cycle.

Alternatively, the current inflow performance model and next production capacity according to the Oil/gas Well within the current capability forecasting cycle The following mean reservoir pressure of the Oil/gas Well, determines inflow of the Oil/gas Well within next capability forecasting cycle in predetermined period Dynamic model, including：

According to inflow performance model of the Oil/gas Well within the current capability forecasting cycle, the oil well is calculated currently fifty-fifty Production capacity index under stressor layer, wherein, when the Oil/gas Well is oil well, the production capacity index is fluid productivity index, when the Oil/gas Well is During gas well, the production capacity index is maximum open-flow capacity；

According to production capacity index under current mean reservoir pressure of the current mean reservoir pressure, the Oil/gas Well and this is next Following mean reservoir pressure in the capability forecasting cycle, calculating future of the Oil/gas Well within next capability forecasting cycle is averaged Production capacity index under strata pressure；

According to the following mean reservoir pressure in next capability forecasting cycle and the Oil/gas Well in next capability forecasting The production capacity index under following mean reservoir pressure in cycle, determine inflow of the Oil/gas Well within next capability forecasting cycle Dynamic model.

Alternatively, the inflow performance model according to the Oil/gas Well within the current capability forecasting cycle, the current production capacity is determined Oil gas well production corresponding to predetermined period, including：

Prediction flowing bottomhole pressure (FBHP) corresponding to the current capability forecasting cycle is determined, according to the prediction flowing bottomhole pressure (FBHP), utilizes the oil Inflow performance model of the gas well within the current capability forecasting cycle calculates corresponding to the current capability forecasting cycle predictably laminar flow Enter yield；

The oil gas mouth size that production is used in the current capability forecasting cycle is determined, according to the prediction flowing bottomhole pressure (FBHP), this is pre- Geodetic laminar flow enters yield and the oil gas mouth size, determines prediction surface flow yield corresponding to the current capability forecasting cycle；

When the relative error that predictably laminar flow enters between yield and the prediction surface flow yield is less than default error, By this, predictably laminar flow enters yield and is defined as yield corresponding to the current capability forecasting cycle.

Alternatively, according to the prediction flowing bottomhole pressure (FBHP), predictably laminar flow enters yield and the oil gas mouth size for this, determine that this is current Prediction surface flow yield corresponding to the capability forecasting cycle, including：

According to the prediction shaft bottom stream and this predictably laminar flow enters yield, calculate the current production using specified wellbore flow model Can prediction well head oil pressure corresponding to predetermined period；

According to the prediction well head oil pressure and the oil gas mouth size, the current production capacity is calculated using specified Oil/gas Well mouth flow model Prediction surface flow yield corresponding to predetermined period.

Alternatively, the oil gas well production according to corresponding to the current capability forecasting cycle, determines the current capability forecasting cycle At the end of cumulative production, including：

When the relative error that predictably laminar flow enters between yield and the prediction surface flow yield is less than the default error When, the prediction well head oil pressure is defined as well head oil pressure corresponding to the current capability forecasting cycle；

When yield corresponding to the current capability forecasting cycle is more than minimum output threshold value, the current capability forecasting cycle corresponds to Well head oil pressure be more than minimum well head oil pressure threshold value and the current capability forecasting cycle corresponding to well head oil pressure be more than the Oil/gas Well At twice of back pressure, determine that the Oil/gas Well meets blowing condition, and it is oily according to corresponding to the current capability forecasting cycle to perform this Gas well yield, the step of cumulative production when determining the current capability forecasting end cycle.

Alternatively, according to cumulative production during the current capability forecasting end cycle, specified oil-gas reservoir material balance is utilized Model, the mean reservoir pressure of Oil/gas Well when calculating the current capability forecasting end cycle, including：

When the Oil/gas Well is oil well, according to the cumulative oil production of the oil well, being calculated using oil reservoir material balance model should Reservoir formation pressure drop during current capability forecasting end cycle；

The reservoir formation pressure drop is added with the prediction flowing bottomhole pressure (FBHP), when obtaining the current capability forecasting end cycle The mean reservoir pressure of the Oil/gas Well.

When the Oil/gas Well is gas well, according to the cumulative gas production of the gas well, being calculated using gas reservoirs balance model should The mean reservoir pressure of Oil/gas Well during current capability forecasting end cycle.

Alternatively, the inflow performance model according to the Oil/gas Well within next capability forecasting cycle, predicts the Oil/gas Well After production capacity within next capability forecasting cycle, in addition to：

According to inflow performance model of the Oil/gas Well within next capability forecasting cycle, predict in next capability forecasting In cycle the Oil/gas Well whether blowing.

Above-mentioned all optional technical schemes, can form the alternative embodiment of the disclosure according to any combination, and the disclosure is real Example is applied no longer to repeat this one by one.

Fig. 2 is a kind of Oil ＆ Gas Productivity Forecasting Methodology flow chart provided in an embodiment of the present invention, and the embodiment of the present invention is with this The executive agent of Oil ＆ Gas Productivity Forecasting Methodology is illustrates exemplified by Oil ＆ Gas Productivity prediction meanss, Oil ＆ Gas Productivity prediction Device can be computer etc., and referring to Fig. 2, this method can include the following steps：

Step 201：The test information of Oil/gas Well is obtained, when the Oil/gas Well is oil well, the test information is to the oil well Carry out formation testing to obtain, when the Oil/gas Well is gas well, the test information is to carry out gas testing to the gas well to obtain.

It should be noted that the Oil/gas Well shown in the embodiment of the present invention can be oil well, or gas well, and work as the oil When gas well is gas well, the gas well can be gas-water well, dry gas well etc., and the present invention is not limited this.

In the embodiment of the present invention, at Oil/gas Well exploration and development initial stage, in order to test the oil gas well capacity, this that is to say Oil gas well yield, the test information of the Oil/gas Well, phase during formation testing or gas testing is carried out to the Oil/gas Well, can be obtained Ying Di, when the Oil/gas Well is oil well, the test information can include the formation testing information of the oil well, when the Oil/gas Well is gas well When, the test information can include the gas testing information of the gas well.

Wherein, during test information is obtained, the oil and gas productivity prediction device can directly gather the Oil/gas Well Information is tested, so as to obtain the test information of the Oil/gas Well, the Oil/gas Well can also be obtained by testing information collecting device Information is tested, that is to say, the test information of the Oil/gas Well is gathered by test information collecting device, and the test information is sent to The oil and gas productivity prediction device, the embodiment of the present invention are not limited this.

It should be noted that in the embodiment of the present invention, according to the difference of acquisition method, the test information collected it is interior Hold also different.

Specifically, when the Oil/gas Well is oil well, according to the difference of formation testing information collecting method, the formation testing letter collected Breath can include any one of following several information：

1. one group of strata pressure, flowing bottomhole pressure (FBHP) and yield；2. one group of strata pressure, well head oil pressure and yield；3. one group quiet Liquid level, well head oil pressure and yield；4. one group of flowing bottomhole pressure (FBHP) and yield, one group of well head oil pressure and yield；5. two groups of well head oil pressure and Yield；6. two groups of flowing bottomhole pressure (FBHP)s and yield etc..

Wherein, the yield in above-mentioned formation testing information can include oil production, aquifer yield and gas production etc., the embodiment of the present invention This is not limited.

Specifically, when the Oil/gas Well is gas well, the acquisition method of gas testing information can include in following several method It is any：1. one point method method of testing；2. conventional back pressure method of testing；3. isochronal well testing method of testing；4. modified isochronal Method of testing etc..Correspondingly, corresponding to above-mentioned several acquisition methods, the gas testing information collected can include following several letters Any one of breath：

1. one point method tests information：The yield and flowing bottomhole pressure (FBHP) measured under one working system, or a working system Under the yield that measures and well head oil pressure；2. conventional back pressure tests information：The yield measured under 3-4 working system and shaft bottom stream Pressure, or the yield and well head oil pressure measured under 3-4 working system；3. isochronal well testing tests information：Several identical productions The different yield and stream measured under time are pressed, or the different yield and well head oil measured under several identical production times Pressure；4. modified isochronal information：The yield and stream measured under several identical production times and closed-in time is pressed, or some The yield and well head oil pressure measured under individual identical production time and closed-in time.

Wherein, it is described several can be 3 or 4 etc., the embodiment of the present invention is not limited this.

Further, since when being predicted to the oil gas well capacity, in addition to above-mentioned formation testing information and gas testing information, also The other information of the Oil/gas Well can be used, therefore, the test information of the Oil/gas Well can also include the Back ground Information of the Oil/gas Well With the reservoir of the Oil/gas Well and physical properties of fluids information etc., the embodiment of the present invention is not limited this.

Wherein, the Back ground Information of the Oil/gas Well can include：Oil Reservoir Types, original formation pressure, prime stratum temperature, list Well control reserve, raw pay thickness, Oil/gas Well control area, wellbore radius, midpoint of pay zone, oil pipe depth of setting, oil well MTD, hole angle corresponding with well measurement depth, sleeve outer, casing inner diameter, oil pipe external diameter, pipe aperture etc.；Should The reservoir of oil well can include with physical properties of fluids information：Reservoir average pore, reservoir mean permeability, system compressibility, Original water saturation, crude oil saturation pressure, relative oil density, condensate mean molecule quantity, water relative density etc..

Step 202：According to the test information, thermally coupled flow mould of the Oil/gas Well within the current capability forecasting cycle is determined Type.

Wherein, the inflow performance model in the current capability forecasting cycle refers to that the Oil/gas Well is given birth in current formation testing or gas testing The inflow performance model in production stage, the capability forecasting cycle can be 1 day, 2 days etc., and the embodiment of the present invention is not limited this. Preferably, the capability forecasting cycle is defined as 1 day.

Wherein, the inflow performance model refers to that the corresponding relation between the flowing bottomhole pressure (FBHP) of the Oil/gas Well and yield can be indicated Model, be specifically as follows inflow performance equation etc., the embodiment of the present invention is not limited this.

Wherein, for the difference of oil well and gas well, according to the test information, determine the Oil/gas Well in current capability forecasting week The process of inflow performance model in phase is also different.Specifically, for oil well, can be used according to the test information Petrobras oil gas water three phases flow into dynamic model and calculate thermally coupled flow mould of the Oil/gas Well within the current capability forecasting cycle Type；For gas well, the Oil/gas Well can be calculated within the current capability forecasting cycle using binomial equation according to the test information Inflow performance model.Wherein, specific calculating process may be referred to correlation technique, and the embodiment of the present invention will not be repeated here.

It should be noted that due to must can just determine the current production capacity of the Oil/gas Well according to the flowing bottomhole pressure (FBHP) of the Oil/gas Well Inflow performance model in predetermined period, therefore, in the embodiment of the present invention, in above-mentioned acquisition formation testing information and the mistake of gas testing information Cheng Zhong, when only getting well head oil pressure and yield and do not get flowing bottomhole pressure (FBHP), the oil and gas productivity prediction device can also be first According to the well head oil pressure and yield got, corresponding flowing bottomhole pressure (FBHP) is calculated using specified wellbore flow model, further according to this The flowing bottomhole pressure (FBHP) being calculated determines the inflow performance model in the current predetermined period.

Wherein, it can be pit shaft Multiphase Flow model that this, which specifies wellbore flow model, or pit shaft single-phase flow dynamic model Type.Specifically, when the Oil/gas Well is oil well, pit shaft Multiphase Flow model can be used to calculate the flowing bottomhole pressure (FBHP) of the oil well；When The Oil/gas Well is gas well and when being gas-water well, and pit shaft Multiphase Flow model can be used to calculate the flowing bottomhole pressure (FBHP) of the gas well； When the Oil/gas Well is gas well and when being dry gas well, pit shaft single-phase flow model can be used to calculate the flowing bottomhole pressure (FBHP) of the gas well.

Wherein, the pit shaft Multiphase Flow model can be Hagedorn-Brown methods, Gray methods, Asheim methods, Duns-Ros methods, Orkiszewski methods, Aziz methods, Chierici methods, Beggs-Brill methods or Mukherjee-Brill methods etc., the embodiment of the present invention is not limited this.

Step 203：According to inflow performance model of the Oil/gas Well within the current capability forecasting cycle, determine that next production capacity is pre- Survey the following mean reservoir pressure of the Oil/gas Well in the cycle.

Wherein, next capability forecasting cycle can by the Oil ＆ Gas Productivity prediction meanss default setting, can also by with Family is set, and the embodiment of the present invention is not limited this.For example, next capability forecasting cycle can be arranged to 1 day, 2 days etc., Preferably, next capability forecasting cycle is arranged to 1 day.

Because in the production process of Oil/gas Well, with the progress of production, the mean reservoir pressure in the Oil/gas Well will Change, when mean reservoir pressure changes, the inflow performance model of the Oil/gas Well will also change, and therefore, be Inflow performance model of the Oil/gas Well under following mean reservoir pressure corresponding to the following production phase that calculate to a nicety, this hair In bright embodiment, inflow performance model that can first according to the Oil/gas Well within the current capability forecasting cycle determines next production The following mean reservoir pressure of the Oil/gas Well in energy predetermined period.For example, can be according to the thermally coupled flow mould on the day of the Oil/gas Well Type, determine following mean reservoir pressure of the Oil/gas Well at second day.

Further, since Average Formation Pressure of Oil And Gas Well during current capability forecasting end cycle is next capability forecasting The mean reservoir pressure of Oil/gas Well when cycle starts, therefore, can be first according to the Oil/gas Well current in the embodiment of the present invention Inflow performance model in the capability forecasting cycle determines average stratum of the Oil/gas Well in current capability forecasting end cycle Pressure, and the mean reservoir pressure of Oil/gas Well during the current capability forecasting end cycle is defined as next capability forecasting cycle The following mean reservoir pressure of the interior Oil/gas Well.

Specifically, the inflow performance model according to the Oil/gas Well within the current capability forecasting cycle, determine that next production capacity is pre- The process of the following mean reservoir pressure of the Oil/gas Well in the cycle is surveyed, can be included：

According to inflow performance model of the Oil/gas Well within the current capability forecasting cycle, the current capability forecasting cycle is determined Corresponding yield；According to yield corresponding to the current capability forecasting cycle, tiring out during the current capability forecasting end cycle is determined Product yield；According to cumulative production during the current capability forecasting end cycle, using specified oil-gas reservoir material balance model, calculate The mean reservoir pressure of Oil/gas Well during the current capability forecasting end cycle；By oil during the current capability forecasting end cycle The mean reservoir pressure of gas well is defined as the following mean reservoir pressure of the Oil/gas Well next capability forecasting cycle Nei.

Wherein, can be first according to the oil it is determined that during cumulative production during the current capability forecasting end cycle Inflow performance model of the gas well within the current capability forecasting cycle, determine that Oil/gas Well corresponding to the current capability forecasting cycle produces Amount, and then by before oil gas well production corresponding to the Oil/gas Well current capability forecasting cycle and the current capability forecasting cycle The oil gas well yield is added, the cumulative production of Oil/gas Well during so as to obtain the current capability forecasting end cycle.

In the embodiment of the present invention, according to inflow performance model of the Oil/gas Well within the current capability forecasting cycle, it is determined that should The process of oil gas well production, can include corresponding to the current capability forecasting cycle：

Prediction flowing bottomhole pressure (FBHP) corresponding to the current capability forecasting cycle is determined, according to the prediction flowing bottomhole pressure (FBHP), utilizes the oil Inflow performance model of the gas well within the current capability forecasting cycle calculates corresponding to the current capability forecasting cycle predictably laminar flow Enter yield；The oil gas mouth size that production is used in the current capability forecasting cycle is determined, according to the prediction flowing bottomhole pressure (FBHP), the prediction Stratum flows into yield and the oil gas mouth size, determines prediction surface flow yield corresponding to the current capability forecasting cycle；When this When the relative error that predictably laminar flow enters between yield and the prediction surface flow yield is less than default error, by the prediction stratum Flow into yield and be defined as oil gas well production corresponding to the current capability forecasting cycle.

Wherein, the default error can also can be set by the Oil ＆ Gas Productivity prediction meanss default setting by user, this Inventive embodiments are not limited this.For example, the default error could be arranged to 1%, 2%, 5%, 10% etc., it is preferable that will The default error is arranged to less than 10%.

Wherein it is determined that prediction flowing bottomhole pressure (FBHP) corresponding to the current capability forecasting cycle, that is to say, the current production is given Flowing bottomhole pressure (FBHP) can be assumed corresponding to predetermined period, afterwards, for oil well, you can based on the prediction flowing bottomhole pressure (FBHP), utilize the oil well Inflow performance model within the current capability forecasting cycle, calculate well oil output corresponding to the current capability forecasting cycle； For gas well, you can based on the prediction flowing bottomhole pressure (FBHP), using inflow performance model of the gas well within the current capability forecasting cycle, Calculate gas well gas production corresponding to the current capability forecasting cycle.

In addition, the Oil ＆ Gas Productivity prediction meanss can also be predicted to yield corresponding to the current capability forecasting cycle Before, Oil/gas Well capability forecasting cycle production oil gas mouth size used in this prior is first determined, the outspoken footpath of such as oil gas, And then according to the prediction flowing bottomhole pressure (FBHP), predictably laminar flow enters yield and the oil gas mouth size for this, determine the current capability forecasting Prediction surface flow yield corresponding to cycle.Further, the Oil ＆ Gas Productivity prediction meanss can also determine the Oil/gas Well Capability forecasting cycle production Oil/gas Well back pressure used, minimum output threshold value, minimum well head oil pressure etc. in this prior, so as to follow-up During to the Oil/gas Well whether can blowing judge that the embodiment of the present invention is not limited this.

Wherein, current capability forecasting cycle production oil gas mouth size used, Oil/gas Well back pressure, minimum output threshold value, The parameters such as minimum well head oil pressure can be set by user in advance, such as user can be by the Oil ＆ Gas Productivity prediction meanss Input above-mentioned parameter is configured, naturally it is also possible to by the Oil ＆ Gas Productivity prediction meanss default setting, the embodiment of the present invention pair This is not limited.

Wherein, the oil production and gas production calculated using the inflow performance model in the current capability forecasting cycle, can be with The oil and gas content that the oil-gas reservoir under the Oil/gas Well inputs to the Oil/gas Well is represented, therefore, can will utilize the current capability forecasting cycle The oil production and gas production that interior inflow performance model calculates are referred to as predictably laminar flow and enter yield.Correspondingly, it is pre- according to this Survey flowing bottomhole pressure (FBHP), predictably laminar flow enters yield and the oil gas mouth size for this, the corresponding production of the current capability forecasting cycle calculated Oil mass or gas production, the oil and gas content that the Oil/gas Well is flowed out by oil gas mouth can be represented, therefore, can will be according to the prediction shaft bottom Miscarriage pressure, the oil production that predictably laminar flow enters yield and the oil gas mouth Size calculation goes out and gas production are referred to as to predict outflow Amount.

When the predictably laminar flow being calculated enter yield and predict surface flow yield between relative error, that is to say, Predictably laminar flow enters yield to the difference that predictably laminar flow enters between yield and the prediction surface flow yield or this is pre- with this When the ratio of any yield is less than the default error in geodetic surface current yield, represent that predictably laminar flow enters yield and the prediction for this Surface flow yield is closer to, and the input and output of the Oil/gas Well are in poised state, and the prediction flowing bottomhole pressure (FBHP) is exactly the oil The capability forecasting cycle corresponds to flowing bottomhole pressure (FBHP) to gas well in this prior, therefore, will can now be calculated by the prediction flowing bottomhole pressure (FBHP) The predictably laminar flow gone out enters yield and is defined as oil gas well production corresponding to the current capability forecasting cycle.

In the embodiment of the present invention, according to the prediction flowing bottomhole pressure (FBHP), predictably laminar flow enters yield and the oil gas mouth size for this, really The process of prediction surface flow yield, can include corresponding to the fixed current capability forecasting cycle：

According to the prediction flowing bottomhole pressure (FBHP), predictably laminar flow enters yield with this, and it is current to calculate this using specified wellbore flow model Prediction well head oil pressure corresponding to the capability forecasting cycle；According to the prediction well head oil pressure and the oil gas mouth size, specified oil gas is utilized Well mouth flow model calculates prediction surface flow yield corresponding to the current capability forecasting cycle.

Wherein, it can be oil well mouth stream formula or gas well mouth stream formula that this, which specifies Oil/gas Well mouth flow model,.

In the first way, for oil well, can be calculated using pit shaft Multiphase Flow model the prediction flowing bottomhole pressure (FBHP) and Predictably laminar flow enters prediction well head oil pressure corresponding to yield for this.Afterwards, you can used according to the prediction well head oil pressure and production Choke size, calculated using oil well mouth stream formula and predict that the prediction of well head oil pressure exports oil production herein.

Wherein, oil well mouth stream formula can be：

Wherein, P_tTo predict well head oil pressure；R is production gas-oil ratio；Q_obLiquid output is exported for prediction；D is oil nozzle diameter；f_w For water content.

In the second way, for gas well, when the gas well is gas-water well, pit shaft multiphase flow dynamic model can be used Type calculates the prediction flowing bottomhole pressure (FBHP), and predictably laminar flow enters prediction well head oil pressure corresponding to yield with this；When the gas well is dry gas well When, can be calculated using pit shaft single-phase flow model the prediction flowing bottomhole pressure (FBHP) and this predictably laminar flow enters and logged well in advance corresponding to yield Mouth oil pressure.Afterwards, you can according to the prediction well head oil pressure and production valve size used, calculated using gas well mouth stream formula The prediction surface flow of this prediction well head oil pressure produces tolerance.

Wherein, the gas well mouth stream formula can be：

Wherein, Q_gbFor the volume flow under standard state by valve, that is, predict that surface flow produces tolerance；D is that valve is straight Footpath；P_tFor the pressure on valve entrance face, that is, predict well head oil pressure；p_hFor the pressure on valve exit end face, i.e., used in production Valve back pressure；γ_gFor the relative density of natural gas；T₁For the temperature of valve entrance face；Z₁For the gas under valve entry condition Volume compressibility；K is the adiabatic exponent of natural gas.

In the embodiment of the present invention, according to yield corresponding to the current capability forecasting cycle, the current capability forecasting week is determined The process of cumulative production at the end of phase, it can include：

When the relative error that predictably laminar flow enters between yield and the prediction surface flow yield is less than the default error When, the prediction well head oil pressure is defined as well head oil pressure corresponding to the current capability forecasting cycle；Determine the current capability forecasting Production Oil/gas Well back pressure used in cycle；When yield corresponding to the current capability forecasting cycle be more than minimum output threshold value, should Well head oil pressure corresponding to the current capability forecasting cycle was more than corresponding to minimum well head oil pressure threshold value and the current capability forecasting cycle When well head oil pressure is more than twice of the Oil/gas Well back pressure, determine that the Oil/gas Well meets blowing condition, and it is pre- according to the current production capacity Yield corresponding to surveying the cycle, determines cumulative production during the current capability forecasting end cycle.

Wherein, the minimum output threshold value includes minimum oil production threshold value or minimum gas production threshold value, correspondingly, when the oil When gas well is oil well, oil production corresponding to the capability forecasting cycle it can be more than minimum oil production threshold value, the current production in this prior Well head oil corresponding to minimum well head oil pressure threshold value and the current capability forecasting cycle can be more than by well head oil pressure corresponding to predetermined period When pressure is more than twice of Oil Well Back Pressure, determine that the oil well meets blowing condition；, can be in this prior when the Oil/gas Well is gas well Gas production corresponding to the capability forecasting cycle is big more than well head oil pressure corresponding to minimum gas production threshold value, the current capability forecasting cycle When well head oil pressure corresponding to minimum well head oil pressure threshold value and the current capability forecasting cycle is more than twice of gas well back pressure, it is determined that The gas well meets blowing condition.

It should be noted that in the embodiment of the present invention, yield and well head corresponding to the current capability forecasting cycle are being obtained , can be by the yield and well head oil pressure most low yield used with production in the predetermined current capability forecasting cycle after oil pressure Amount threshold value, minimum well head oil pressure threshold value and Oil/gas Well back pressure are compared.When it is determined that the Oil/gas Well meets blowing condition, represent The Oil/gas Well can blowing, so as to the yield according to corresponding to the current capability forecasting cycle, determine the current capability forecasting Cumulative production during end cycle, continue to be predicted the production capacity in next capability forecasting cycle；And work as and determine the Oil/gas Well not When meeting blowing condition, represent that the Oil/gas Well is unable to blowing, so as to stop the production capacity progress to next capability forecasting cycle Prediction.

In addition, for the difference of oil well and gas well, according to cumulative production during the current capability forecasting end cycle, utilize Specify oil-gas reservoir material balance model, the mistake of the mean reservoir pressure of Oil/gas Well when calculating the current capability forecasting end cycle Journey is also different, and detailed process can include any of in the following manner：

In the first way, when the Oil/gas Well is oil well, oil reservoir can be utilized according to the cumulative oil production of the oil well Material balance model calculates reservoir formation pressure drop during the current capability forecasting end cycle, and then by the reservoir formation pressure Drop is added with the prediction flowing bottomhole pressure (FBHP), obtain during next capability forecasting end cycle in the Oil/gas Well it is following fifty-fifty Stressor layer.

Wherein, the oil reservoir material balance model can be oil reservoir matter balance equation, and should according to different type of drive Oil reservoir matter balance equation can be write as different forms, and oil reservoir material balance model can be employed in the embodiment of the present invention Following oil reservoir matter balance equation formula：

Wherein, B_t=B_o+(R_si-R_s)B_g；B_ti=B_oi；

Wherein, N is the initial reserves of crude oil；N_pFor cumulative oil production；R_siFor reset condition dissolved gas oil ratio；B_gTo be current The gas formation volume factor of state；W_eFor natural water encroachment amount；W_iFor cumulative water injected；W_pFor cumulative water production；B_wFor water volume system Number；B_gFor air volume coefficient；G_pFor cumulative gas production；M is the hole that the pore volume that reset condition pneumatic jack accounts for accounts for reset condition oil The ratio between gap volume；B_giFor reset condition gas formation volume factor；C_wFor the stratum water compressed coefficient；S_wcFor irreducible water saturation；C_f For pore compressibility；B_oFor the oil volume factor of current pressure state；B_oiFor reset condition oil volume factor；R_sTo be molten Solve gas-oil ratio；Δ p is reservoir formation pressure drop.

Therefore, the cumulative oil production of the oil well is substituted into above-mentioned formula (3), you can calculate the reservoir formation pressure of the oil well Drop, the mean reservoir pressure of oil well and the difference of flowing bottomhole pressure (FBHP) are referred to due to reservoir formation pressure drop, therefore, calculates the reservoir formation After pressure drop, the reservoir formation pressure drop is added with the prediction flowing bottomhole pressure (FBHP), you can obtain the current capability forecasting cycle At the end of the Oil/gas Well mean reservoir pressure.

In the second way, when the Oil/gas Well is gas well, gas reservoir can be utilized according to the cumulative gas production of the gas well The mean reservoir pressure of Oil/gas Well when material balance model calculates the current capability forecasting end cycle.

Wherein, the gas reservoirs balance model can be material balance equation for gas reservoir, gas used by the embodiment of the present invention It can be following material balance equation for gas reservoir formula to hide material balance model：

Wherein, mean reservoir pressure in gas well when P is current capability forecasting end cycle；Z is the mean reservoir pressure Under deviation factor；P_iFor original formation pressure；Z_iFor the deviation factor under original formation pressure；G_pFor cumulative gas production；G is Prime stratum reserves；W_eFor natural water encroachment amount；W_pFor cumulative water production；B_wFor water volume coefficient；B_giFor reset condition natural-gas Product coefficient.

Therefore, cumulative gas production substitution above-mentioned formula (4) can be calculated into the gas well to tie in the current capability forecasting cycle The mean reservoir pressure of gas well during beam.

Step 204：It is pre- according to inflow performance model of the Oil/gas Well within the current capability forecasting cycle and next production capacity The following mean reservoir pressure of the Oil/gas Well in the cycle is surveyed, determines that inflow of the Oil/gas Well within next capability forecasting cycle is moved States model.

Wherein, this is according to current inflow performance model of the Oil/gas Well within the current capability forecasting cycle and next production capacity The following mean reservoir pressure of the Oil/gas Well, determines inflow of the Oil/gas Well within next capability forecasting cycle in predetermined period The process of dynamic model, it can include：

According to inflow performance model of the Oil/gas Well within the current capability forecasting cycle, the oil well is calculated currently fifty-fifty Production capacity index under stressor layer, wherein, when the Oil/gas Well is oil well, the production capacity index is fluid productivity index, when the Oil/gas Well is During gas well, the production capacity index is maximum open-flow capacity；According to the current mean reservoir pressure, the Oil/gas Well on the stratum that is currently averaged Production capacity index and the following mean reservoir pressure under pressure, calculate production capacity of the Oil/gas Well under the following mean reservoir pressure Index；According to the following mean reservoir pressure and production capacity index of the Oil/gas Well under the following mean reservoir pressure, it is determined that should Inflow performance model of the Oil/gas Well within next capability forecasting cycle.

Wherein, in formation testing or gas testing stage, the current mean reservoir pressure can be the basis money based on above-mentioned Oil/gas Well Expect the original formation pressure of the Oil/gas Well obtained, the embodiment of the present invention is not limited this.

In the first way, can be according to the oil well within the current capability forecasting cycle when the Oil/gas Well is oil well Inflow performance model, calculate fluid productivity index of the oil well under current mean reservoir pressure, afterwards, can be according to current average The relation between the fluid productivity index under fluid productivity index and following mean reservoir pressure under strata pressure, using below equation (5) Calculate the fluid productivity index under the following mean reservoir pressure：

Wherein, JL_fFor the fluid productivity index under the following mean reservoir pressure；JL_pTo adopt liquid under current mean reservoir pressure Index；p_r2For the following mean reservoir pressure；p_r1For the current mean reservoir pressure.

Therefore, it is the fluid productivity index under the current mean reservoir pressure, the current mean reservoir pressure and the future is average Strata pressure substitutes into above-mentioned formula (5), you can calculates the fluid productivity index under the following mean reservoir pressure.

After calculating the fluid productivity index under the following mean reservoir pressure, you can according to the following mean reservoir pressure and be somebody's turn to do Fluid productivity index of the Oil/gas Well under the following mean reservoir pressure, determine stream of the oil well within next capability forecasting cycle Enter dynamic model.

, can be according to the gas well within the current capability forecasting cycle when the Oil/gas Well is gas well in the second way Inflow performance model, calculate maximum open-flow capacity of the gas well under current mean reservoir pressure, afterwards, can be according to current The relation of maximum open-flow capacity and the maximum open-flow capacity under following mean reservoir pressure under mean reservoir pressure, use are following Formula (6) calculates the maximum open-flow capacity under the following mean reservoir pressure：

Wherein, p_r1For the current mean reservoir pressure；p_r2For the following mean reservoir pressure；q_AOF1It is current fifty-fifty for this Stressor layer p_r1Under maximum open-flow capacity；q_AOF2For the following mean reservoir pressure p_r2Under maximum open-flow capacity；Z₁To deserve Preceding mean reservoir pressure p_r1Corresponding gas deviation factor；Z₂For the current mean reservoir pressure p_r2Corresponding natural gas deviation Coefficient；μ_g1For the current mean reservoir pressure p_r1Corresponding Natural Gas Viscosity；μ_g2For the current mean reservoir pressure p_r2It is corresponding Natural Gas Viscosity.

After calculating the maximum open-flow capacity under the following mean reservoir pressure, you can according to the following mean reservoir pressure With maximum open-flow capacity of the Oil/gas Well under the following mean reservoir pressure, determine the Oil/gas Well in next capability forecasting Inflow performance model in cycle.

Step 205：According to inflow performance model of the Oil/gas Well within next capability forecasting cycle, the Oil/gas Well is predicted Production capacity within next capability forecasting cycle.

After inflow performance model of the Oil/gas Well within next capability forecasting cycle being determined by above-mentioned steps, you can According to the inflow performance model in next capability forecasting cycle, production of the Oil/gas Well within next capability forecasting cycle is predicted Energy.For example, the inflow performance model in next capability forecasting cycle can be utilized, predict in next capability forecasting cycle Maximum oil gas well yield corresponding to any flowing bottomhole pressure (FBHP) in oil gas well production, or next capability forecasting cycle etc..

, can be with further, it is determined that after going out inflow performance model of the Oil/gas Well within next capability forecasting cycle According to inflow performance model of the Oil/gas Well within next capability forecasting cycle, predicting should within next capability forecasting cycle Oil/gas Well whether blowing.Specifically, inflow performance model that can be according to the Oil/gas Well within next capability forecasting cycle, sentences Whether the disconnected Oil/gas Well meets blowing condition within next capability forecasting cycle, is determined according to judged result in next production capacity In predetermined period the Oil/gas Well whether blowing.

Wherein, the inflow performance model according to the Oil/gas Well within next capability forecasting cycle, judges that the Oil/gas Well exists Whether meet the detailed process of blowing condition in next capability forecasting cycle, may be referred to it is above-mentioned according to Oil/gas Well in this prior Inflow performance model in the capability forecasting cycle, determines whether the Oil/gas Well meets blowing bar in the capability forecasting cycle in this prior The description of part, the embodiment of the present invention will not be repeated here.

Further, in the embodiment of the present invention, the test information that is obtained based on formation testing or gas testing is predicted the Oil/gas Well and existed After inflow performance model in next capability forecasting cycle, the Oil ＆ Gas Productivity prediction meanss can also be pre- with next production capacity Survey based on the inflow performance model in the cycle, repeat step 203-204, so as to predict again in next capability forecasting cycle Inflow performance model, or determine whether this again in next capability forecasting cycle the Oil/gas Well whether blowing.

, for convenience of description, can be pre- by the current production capacity of the Oil/gas Well formation testing or gas testing stage in the embodiment of the present invention The survey cycle was referred to as the first capability forecasting cycle, and next capability forecasting cycle described above is referred to as into the second capability forecasting week Phase, therefore, the inflow performance model based on the Oil/gas Well within the second capability forecasting cycle, repeat step 203-204, you can pre- Inflow performance model of the Oil/gas Well in the 3rd production capacity predetermined period is measured, or determines whether the 3rd capability forecasting week In phase the Oil/gas Well whether blowing.Specifically, the Oil ＆ Gas Productivity prediction meanss can be first according to the Oil/gas Well in the second production capacity Inflow performance model in predetermined period, the following mean reservoir pressure of the Oil/gas Well the 3rd production capacity predetermined period Nei is determined, So as to according to the Oil/gas Well oil gas in inflow performance model and the 3rd production capacity predetermined period within the second capability forecasting cycle The following mean reservoir pressure of well, determines inflow performance model of the Oil/gas Well in the 3rd production capacity predetermined period, and can be with According to inflow performance model of the Oil/gas Well in the 3rd production capacity predetermined period, the oil gas in the 3rd production capacity predetermined period is predicted Can well blowing.

Correspondingly, the inflow performance model based on the Oil/gas Well in the 3rd production capacity predetermined period, repeat step 203- 204, inflow performance model of the Oil/gas Well within the 4th capability forecasting cycle can also be predicted, or determine whether this In four capability forecasting cycles the Oil/gas Well whether blowing；Thermally coupled flow mould based on the Oil/gas Well within the 4th capability forecasting cycle Type, repeat step 203-204, inflow performance model of the Oil/gas Well within the 5th capability forecasting cycle can also be predicted, or Person determine whether in the 5th capability forecasting cycle the Oil/gas Well whether blowing；So constantly circulation, you can continue to predict Inflow performance model of the Oil/gas Well within the following different capability forecasting cycles, it is different raw so as to the future to the Oil/gas Well The production capacity in production stage is predicted, and realizes the test information obtained using Oil/gas Well formation testing or gas testing, to the new well of new prospecting area Following production capacity and blowing state dynamic prediction.

If for example, the capability forecasting cycle is one day, the Oil ＆ Gas Productivity prediction meanss can be based on formation testing or gas testing The inflow performance model on the same day, predict the inflow performance model of second day and judge whether blowing, and can utilize second day Inflow performance model, predict the inflow performance model of the 3rd day and judge whether blowing, utilize the thermally coupled flow of the 3rd day Model, predict the inflow performance model of the 4th day and judge whether blowing etc., so constantly circulation, you can predict following several Daily inflow performance model and blowing state in individual month, so as to production capacity of the Oil/gas Well within coming few months and from Spray state is predicted.

In addition, existing Oil ＆ Gas Productivity Forecasting Methodology can also establish yield and stream from permeation fluid mechanics basic theories The relation of pressure, so that it is determined that go out the productivity prediction model of Oil/gas Well, but this method needs the high pressure property information of fluid, life The reservoir properties information such as oil-gas ratio, permeability saturation curve, water saturation are produced, and computational methods complexity is cumbersome.In addition, for For new exploration areas initial stage of development, because Oil/gas Well quantity is few, reservoir properties information and Production development information etc. all lack very much, Therefore the difficulty that following capability forecasting is carried out using this kind of method is also very big.And the embodiment of the present invention is directed to existing capability forecasting side The deficiency of method, the current productivity prediction model that the test information obtained using formation testing or gas testing is determined, puts down with reference to oil-gas reservoir material Weigh model, a kind of prospect pit, the following PRODUCTION FORECASTING METHODS of new producer is established, due to without reservoir properties such as relative permeabilities Information, so as to overcome the problem of new prospecting area data are few, and execute-in-place is simple, practical, is more applied to exploration The short-term production capacity dynamic prediction of the new well in new district, for instructing conversion oil recovery or gas production mode, ensureing new prospecting area Oil/gas Well just Often produce significant.Further, deepening continuously with oil-gas field development, the quantity of Oil/gas Well will more be come More, this also provides more chances for the application of Oil ＆ Gas Productivity Forecasting Methodology provided in an embodiment of the present invention.

In summary, Oil ＆ Gas Productivity Forecasting Methodology provided in an embodiment of the present invention, formation testing or gas testing can be utilized to obtain Test information, determine inflow performance model of the Oil/gas Well in the following production phase, and the inflow performance model is future Inflow performance model under mean reservoir pressure, therefore the following production capacity of the Oil/gas Well can be entered according to the inflow performance model Row prediction, so as in new prospecting area, prospector be helped to understand and predict prospect pit or the new producer of different phase in time Production capacity, to further understanding oil-gas reservoir and dispose the next stage development there is directive significance.

Fig. 3 is a kind of Oil ＆ Gas Productivity prediction meanss block diagram provided in an embodiment of the present invention, referring to Fig. 2, Oil/gas Well production Energy prediction meanss include：

Acquisition module 301, for obtaining the test information of Oil/gas Well, when the Oil/gas Well is oil well, the test information is Formation testing is carried out to the oil well to obtain, when the Oil/gas Well is gas well, the test information is to carry out gas testing to the gas well to obtain；

First determining module 302, for according to the test information, determining the Oil/gas Well within the current capability forecasting cycle Inflow performance model；

Second determining module 303, for the inflow performance model according to the Oil/gas Well within the current capability forecasting cycle, really Fix the following mean reservoir pressure of an Oil/gas Well capability forecasting cycle Nei；

3rd determining module 304, for according to inflow performance model of the Oil/gas Well within the current capability forecasting cycle and Following mean reservoir pressure during next capability forecasting end cycle in the Oil/gas Well, determine the Oil/gas Well in next production capacity Inflow performance model in predetermined period；

First prediction module 305, for the inflow performance model according to the Oil/gas Well within next capability forecasting cycle, Predict production capacity of the Oil/gas Well within next capability forecasting cycle.

Alternatively, second determining module 303, including：

First determining unit, for the inflow performance model according to the Oil/gas Well within the current capability forecasting cycle, it is determined that Oil gas well production corresponding to the current capability forecasting cycle；

Second determining unit, for the oil gas well production according to corresponding to the current capability forecasting cycle, it is determined that current production capacity is pre- Survey cumulative production during end cycle；

First computing unit, for according to cumulative production during the current capability forecasting end cycle, utilizing specified oil gas Hide material balance model, the mean reservoir pressure of Oil/gas Well when calculating current capability forecasting end cycle；

3rd determining unit, for the mean reservoir pressure of Oil/gas Well during the current capability forecasting end cycle to be determined For the following mean reservoir pressure of the Oil/gas Well in next capability forecasting cycle.

Alternatively, the 3rd determining module 304, including：

Second computing unit, for the inflow performance model according to the Oil/gas Well within the current capability forecasting cycle, calculate Production capacity index of the oil well under current mean reservoir pressure, wherein, when the Oil/gas Well is oil well, the production capacity index is to adopt liquid Index, when the Oil/gas Well is gas well, the production capacity index is maximum open-flow capacity；

3rd computing unit, for according to the current mean reservoir pressure, the Oil/gas Well under current mean reservoir pressure Production capacity index and next capability forecasting cycle in following mean reservoir pressure, it is pre- in next production capacity to calculate the Oil/gas Well The production capacity index surveyed under the following mean reservoir pressure in the cycle；

4th determining unit, for according to the following mean reservoir pressure in next capability forecasting cycle and the Oil/gas Well Production capacity index under the following mean reservoir pressure, determine thermally coupled flow of the Oil/gas Well within next capability forecasting cycle Model.

Alternatively, first determining unit is used for：

When the relative error that predictably laminar flow enters between yield and the prediction surface flow yield is less than default error, By this, predictably laminar flow enters yield and is defined as oil gas well production corresponding to the current capability forecasting cycle.

Alternatively, first determining unit is used for：

Alternatively, second determining unit is used for：

When yield corresponding to the current capability forecasting cycle is more than minimum output threshold value, the current capability forecasting cycle corresponds to Well head oil pressure be more than minimum well head oil pressure threshold value and the current capability forecasting cycle corresponding to well head oil pressure be more than the Oil/gas Well At twice of back pressure, determine that the Oil/gas Well meets blowing condition, and Oil/gas Well produces according to corresponding to the current capability forecasting cycle Amount, determines cumulative production during the current capability forecasting end cycle.

Alternatively, first computing unit is used for：

When the Oil/gas Well is gas well, according to the cumulative gas production of the gas well, being calculated using gas reservoirs balance model should The following mean reservoir pressure of Oil/gas Well during current capability forecasting end cycle.

Alternatively, the device also includes：

Second prediction module, for the inflow performance model according to the Oil/gas Well within next capability forecasting cycle, in advance Survey within a capability forecasting cycle Oil/gas Well whether blowing.

In summary, Oil ＆ Gas Productivity prediction meanss provided in an embodiment of the present invention, formation testing or gas testing can be utilized to obtain Test information, determine inflow performance model of the Oil/gas Well in the following production phase, and the inflow performance model is future Inflow performance model under mean reservoir pressure, therefore the following production capacity of the Oil/gas Well can be entered according to the inflow performance model Row prediction, so as in new prospecting area, prospector be helped to understand and predict prospect pit or the new producer of different phase in time Production capacity, to further understanding oil-gas reservoir and dispose the next stage development there is directive significance.

It should be noted that：The Oil ＆ Gas Productivity prediction meanss that above-described embodiment provides are predicting the following production of the Oil/gas Well Can when, can be as needed and by above-mentioned function only with the division progress of above-mentioned each functional module for example, in practical application Distribution is completed by different functional modules, i.e., the internal structure of equipment is divided into different functional modules, to complete to retouch above The all or part of function of stating.In addition, the Oil ＆ Gas Productivity prediction meanss that above-described embodiment provides are predicted with Oil ＆ Gas Productivity Embodiment of the method belongs to same design, and its specific implementation process refers to embodiment of the method, repeats no more here.

The embodiments of the present invention are for illustration only, do not represent the quality of embodiment.

One of ordinary skill in the art will appreciate that hardware can be passed through by realizing all or part of step of above-described embodiment To complete, by program the hardware of correlation can also be instructed to complete, described program can be stored in a kind of computer-readable In storage medium, storage medium mentioned above can be read-only storage, disk or CD etc..

The foregoing is only presently preferred embodiments of the present invention, be not intended to limit the invention, it is all the present invention spirit and Within principle, any modification, equivalent substitution and improvements made etc., it should be included in the scope of the protection.

Claims

1. a kind of Oil ＆ Gas Productivity Forecasting Methodology, it is characterised in that methods described includes：

The test information of Oil/gas Well is obtained, when the Oil/gas Well is oil well, the test information is that the oil well is tried Oil obtains, and when the Oil/gas Well is gas well, the test information is to carry out gas testing to the gas well to obtain；

According to inflow performance model of the Oil/gas Well within the current capability forecasting cycle, institute in next capability forecasting cycle is determined State the following mean reservoir pressure of Oil/gas Well；

According to the Oil/gas Well in the inflow performance model and next capability forecasting cycle within the current capability forecasting cycle The following mean reservoir pressure of the Oil/gas Well, determine thermally coupled flow of the Oil/gas Well within next capability forecasting cycle Model；

According to inflow performance model of the Oil/gas Well within next capability forecasting cycle, predict the Oil/gas Well described Production capacity in next capability forecasting cycle.

2. according to the method for claim 1, it is characterised in that it is described according to the Oil/gas Well in the current capability forecasting cycle Interior inflow performance model, the following mean reservoir pressure of the Oil/gas Well in next capability forecasting cycle is determined, including：

According to cumulative production during the current capability forecasting end cycle, using specified oil-gas reservoir material balance model, calculate The mean reservoir pressure of Oil/gas Well during the current capability forecasting end cycle；

It is pre- that the mean reservoir pressure of Oil/gas Well during the current capability forecasting end cycle is defined as next production capacity Survey the following mean reservoir pressure of the Oil/gas Well in the cycle.

3. according to the method for claim 1, it is characterised in that it is described according to the Oil/gas Well in the current capability forecasting cycle Interior current inflow performance model and in next capability forecasting cycle the Oil/gas Well following mean reservoir pressure, it is determined that Inflow performance model of the Oil/gas Well within next capability forecasting cycle, including：

According to inflow performance model of the Oil/gas Well within the current capability forecasting cycle, the oil well is calculated currently fifty-fifty Index under stressor layer, wherein, when the Oil/gas Well is oil well, the production capacity index is fluid productivity index, when the Oil/gas Well For gas well when, the production capacity index is maximum open-flow capacity；

According to production capacity index under current mean reservoir pressure of current mean reservoir pressure, the Oil/gas Well and it is described under Following mean reservoir pressure in one capability forecasting cycle, calculate the Oil/gas Well within next capability forecasting cycle not The production capacity index come under mean reservoir pressure；

It is pre- in next production capacity according to the following mean reservoir pressure in next capability forecasting cycle and the Oil/gas Well The production capacity index surveyed under the following mean reservoir pressure in the cycle, determines the Oil/gas Well within next capability forecasting cycle Inflow performance model.

4. according to the method for claim 2, it is characterised in that it is described according to the Oil/gas Well in the current capability forecasting cycle Interior inflow performance model, oil gas well production corresponding to the current capability forecasting cycle is determined, including：

Prediction flowing bottomhole pressure (FBHP) corresponding to the current capability forecasting cycle is determined, according to the prediction flowing bottomhole pressure (FBHP), using described Inflow performance model of the Oil/gas Well within the current capability forecasting cycle is calculated corresponding to the current capability forecasting cycle predictably Laminar flow enters yield；

The oil gas mouth size that production is used in the current capability forecasting cycle is determined, according to the prediction flowing bottomhole pressure (FBHP), described Predictably laminar flow enters yield and the oil gas mouth size, determines that prediction surface flow corresponding to the current capability forecasting cycle is produced Amount；

When the relative error that the predictably laminar flow enters between yield and the prediction surface flow yield is less than default error, The predictably laminar flow is entered into yield and is defined as oil gas well production corresponding to the current capability forecasting cycle.

5. according to the method for claim 4, it is characterised in that it is described according to it is described prediction flowing bottomhole pressure (FBHP), it is described predictably Laminar flow enters yield and the oil gas mouth size, determines prediction surface flow yield corresponding to the current capability forecasting cycle, bag Include：

Yield is entered according to the prediction flowing bottomhole pressure (FBHP) and the predictably laminar flow, described work as is calculated using specified wellbore flow model Prediction well head oil pressure corresponding to the preceding capability forecasting cycle；

According to the prediction well head oil pressure and the oil gas mouth size, the current production is calculated using specified Oil/gas Well mouth flow model Can prediction surface flow yield corresponding to predetermined period.

6. according to the method for claim 5, it is characterised in that the oil according to corresponding to the current capability forecasting cycle Gas well yield, cumulative production during the current capability forecasting end cycle is determined, including：

It is less than the default mistake when the predictably laminar flow enters the relative error between yield and the prediction surface flow yield When poor, the prediction well head oil pressure is defined as well head oil pressure corresponding to the current capability forecasting cycle；

When yield corresponding to the current capability forecasting cycle is more than minimum output threshold value, the current capability forecasting cycle corresponds to Well head oil pressure be more than minimum well head oil pressure threshold value and the current capability forecasting cycle corresponding to well head oil pressure be more than the oil At twice of gas well back pressure, determine that the Oil/gas Well meets blowing condition, and perform described according to the current capability forecasting week Oil gas well production corresponding to phase, the step of cumulative production when determining the current capability forecasting end cycle.

7. according to the method for claim 4, it is characterised in that described according to during the current capability forecasting end cycle Cumulative production, using specified oil-gas reservoir material balance model, Oil/gas Well when calculating the current capability forecasting end cycle Mean reservoir pressure, including：

When the Oil/gas Well is oil well, according to the accumulation oil gas ＆ water yielding of the oil well, oil reservoir material balance model meter is utilized Calculate reservoir formation pressure drop during the current capability forecasting end cycle；

The reservoir formation pressure drop is added with the prediction flowing bottomhole pressure (FBHP), obtains the current capability forecasting end cycle The mean reservoir pressure of Shi Suoshu Oil/gas Wells.

8. according to the method for claim 2, it is characterised in that described according to during the current capability forecasting end cycle Cumulative production, using specified oil-gas reservoir material balance model, Oil/gas Well when calculating the current capability forecasting end cycle Mean reservoir pressure, including：

When the Oil/gas Well is gas well, according to the accumulation gas yield of the gas well, institute is calculated using gas reservoirs balance model State the mean reservoir pressure of Oil/gas Well during current capability forecasting end cycle.

9. according to the method for claim 1, it is characterised in that it is described according to the Oil/gas Well in next capability forecasting Inflow performance model in cycle, after predicting yield of the Oil/gas Well within next capability forecasting cycle, in addition to：

According to inflow performance model of the Oil/gas Well within next capability forecasting cycle, predict pre- in next production capacity Survey the cycle in the Oil/gas Well whether blowing.

10. a kind of Oil ＆ Gas Productivity prediction meanss, it is characterised in that described device includes：

Acquisition module, for obtaining the test information of Oil/gas Well, when the Oil/gas Well is oil well, the test information is to institute State oil well progress formation testing to obtain, when the Oil/gas Well is gas well, the test information is to carry out gas testing to the gas well to obtain；

First determining module, for according to the test information, determining stream of the Oil/gas Well within the current capability forecasting cycle Enter dynamic model；

Second determining module, for the inflow performance model according to the Oil/gas Well within the current capability forecasting cycle, it is determined that under The following mean reservoir pressure of the Oil/gas Well in one capability forecasting cycle；

3rd determining module, for according to inflow performance model of the Oil/gas Well within the current capability forecasting cycle and it is described under The following mean reservoir pressure of the Oil/gas Well in one capability forecasting cycle, determine the Oil/gas Well in next capability forecasting Inflow performance model in cycle；

First prediction module, for the inflow performance model according to the Oil/gas Well within next capability forecasting cycle, in advance Survey production capacity of the Oil/gas Well within next capability forecasting cycle.