CN104948163A - Method for measuring shale gas well capacity - Google Patents

Method for measuring shale gas well capacity Download PDF

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Publication number
CN104948163A
CN104948163A CN201410112840.7A CN201410112840A CN104948163A CN 104948163 A CN104948163 A CN 104948163A CN 201410112840 A CN201410112840 A CN 201410112840A CN 104948163 A CN104948163 A CN 104948163A
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district
fracturing reform
gas well
gas
fracturing
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CN104948163B (en
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胡小虎
王卫红
刘华
杨小松
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China Petroleum and Chemical Corp
Sinopec Exploration and Production Research Institute
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China Petroleum and Chemical Corp
Sinopec Exploration and Production Research Institute
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Abstract

The invention relates to a method for measuring shale gas well capacity. According to the method, according to the characteristic that a fracturing transformation area and a non-fracturing transformation area exist in the control area of a shale gas reservoir single well, the affect to the shale gas well capacity from adsorbed gas desorption-diffusion, the fracturing transformation area and the non-fracturing transformation area is taken into comprehensive consideration, a double-area composite shale gas reservoir material balance equation for considering the adsorbed gas is established, and by combining a gas well capacity equation and a fluid channeling equation between the two areas, a fast and accurate shale gas well capacity calculating method is established. In the calculation process through the method, a complex shale gas reservoir geologic model is not needed, and many geology and fracturing dynamic parameters are not needed either. The calculation results are suitable for various types of application such as shale gas well rational producing, technological policy development and scheme optimization development.

Description

A kind of shale gas well capacity assay method
Technical field
The present invention relates to geophysical exploration technology, particularly about a kind of shale gas well capacity assay method.
Background technology
Shale gas refers to that main body is arranged in and is rich in organic furvous mud shale, and to adsorb or free state is main oil-gas accumulation of composing mode of depositing, shale is reservoir, is again source bed and capping layer.
The dual media gas reservoir that shale gas reservoir is made up of the intrinsic fracture of the hypotonic matrix pores of spy and Natural closure, matrix is that space is deposited in the main tax of free gas and adsorbed gas.Shale gas well natural production capacity is very low, and just have industrial production capacity after forming " artificial gas reservoir " mainly through the transformation of horizontal well multistage pressure break volume, now fracture network is the central core of circulation of seepage flow, and in recovery process, there are the desorb diffusion phenomena of adsorbed gas.
Gas well deliverability measures and refers to the production rate-maintenance capability of Evaluation and Prediction gas well, the lapse rate of depletion stage and final cumulative gas.Evaluation and Prediction gas well deliverability is the basis of gas well rational proration exactly, is also the important evidence of optimized well pattern spacing, establishment gas reservoir development scheme.
Normal gas pools is generally come by Geologic modeling, numerical simulation on geological knowledge basis.It is much more complicated than normal gas pools that the geologic feature of shale gas reservoir and development scheme determine its production capacity measuring method.External mainly through method estimation shale gas well capacitys such as rule-of-thumb relation, Production Decline Analysis and single well numerical simulation at present, the open-flow capacity at the method estimation shale gas well operation initial stage of the domestic gas reservoir flow-after-flow test test that mainly follows conventional lines.Be different from the general external shale gas well adopting the mode that bleeds off pressure to produce, at the operation initial stage, domestic shale gas well requires that stable yields is to keep stable air feed.Because the domestic and international shale gas well mode of production is different, the domestic rule-of-thumb relation abroad formed based on a large amount of creation data statistics that cannot adopt calculates shale gas well capacity.Production Decline Analysis require bottom pressure change little and gas well enters more than depletion stage half a year time could use, and domestic gas well was mainly produced in pressure control stable yields mode at the operation initial stage, therefore Production Decline Analysis method also cannot be used for the measuring and calculating of the gas well deliverability at the initial stage of going into operation.Single well numerical simulation method requires given much strict geology and fracturing parameter, and these parameter values are often difficult to accurately setting, causes the shale gas well capacity resultant error of single well numerical simulation method stage measuring and calculating in early days large.Flow-after-flow test test can only reflect the maximum production potential of the gas well at operation initial stage, cannot obtain the stable production period of gas well, production decline and final cumulative gas directly and accurately.
In sum, although existing shale gas reservoir production capacity measuring method has his own strong points, due to the restriction of the objective factors such as the mode of production, during use, difficulty is large, and be difficult to obtain shale gas Well Productivity Analysis result effectively accurately, especially at the commitment of shale gas reservoir exploitation.
Summary of the invention
For the problems referred to above, the present invention proposes a kind of well capacity of shale gas fast and accurately assay method newly.The present invention has considered adsorbed gas desorb diffusion phenomena, and fracturing reform district and non-fracturing reform district are on the impact of shale gas well capacity, propose a kind of based on shale gas reservoir matter balance equation and the method calculating shale gas well capacity in conjunction with Gas Well Productivity.
The method, comprises the following steps:
S10, test, collect and arrange gas reservoir engineering parameter, and set up Gas Well Productivity;
S20, consideration adsorbed gas desorb diffusion, set up the shale gas reservoir matter balance equation in gas well fracturing transformation district and non-fracturing reform district respectively;
S30, according to Gas Well Productivity, calculate the initil output of initial time gas well;
S40, step by step long when arranging, the time that when calculating next, step is corresponding, and walk when upgrading current;
S50, shale gas reservoir matter balance equation according to fracturing reform district, walk the mean reservoir pressure in fracturing transformation district when iterative computation is current;
S60, according to the mean reservoir pressure walking fracturing transformation district time current, and the shale gas reservoir matter balance equation in non-fracturing reform district, the mean reservoir pressure in iterative computation current Shi Buxiawei fracturing reform district;
S70, according to walking fracturing transformation district and the mean reservoir pressure in non-fracturing reform district time current, shale gas well capacity when calculating current under step;
S80, judge whether current time is greater than given maximum evaluation number of days:
If not, using the mean reservoir pressure value walked time current as the initial value walking iteration during the next one, step S40 is returned;
If so, shale gas well deliverability result of calculation is exported.
According to embodiments of the invention, above-mentioned Gas Well Productivity is:
p i 2 - p wf 2 q = A + Bq
In above formula, A is Gas Well Productivity Monomial coefficient; B is Gas Well Productivity quadratic term coefficient; p ifor original formation pressure; Q is gas well daily output tolerance, 10 4m 3/ d; p wffor the stable flowing bottomhole pressure (FBHP) that gas well is corresponding to stable yields output q, MPa.
According to embodiments of the invention, in above-mentioned steps S20,
The shale gas reservoir matter balance equation in fracturing reform district is:
p 1 Z 1 a = p i Z i a ( 1 - G p 1 - G p 2 G 1 )
The shale gas reservoir matter balance equation in non-fracturing reform district is:
p 2 Z 2 a = p i Z i a ( 1 - G p 2 G 2 )
In above formula, G p1for the cumulative gas of gas well, 10 4m 3; G p2for fracturing reform district is to the accumulative channelling amount in non-fracturing reform district, 10 4m 3; G 1for fracturing reform district reserves; G 2for non-fracturing reform district reserves; p 1for the mean reservoir pressure in fracturing reform district, MPa; p 2for the mean reservoir pressure in non-fracturing reform district, MPa; p ifor original formation pressure; Z 1 a, Z 2 aand Z i abe defined as follows respectively:
Z j a = z [ 1 - s w 0 ] + z ( t 0 + 273.15 ) p SC ρ B V L 293.15 Z SC φ ( p L + p j ) , = 1,2 , i
In above formula, z is equation of gas state deviation factors, is the function of gas reservoir pressure; p scfor standard atmospheric pressure, MPa; z scfor the equation of gas state deviation factors under standard state, ρ bfor density, t/m 3, V lfor Lan Shi volume, m 3/ t, P lfor Lan Shi pressure, MPa, Ф are effecive porosity, t 0for formation temperature, s w0for water saturation.
According to embodiments of the invention, above-mentioned steps S50 comprises the following steps further:
The initial value p of S51, fracturing reform district mean reservoir pressure when making current under step 1for the mean reservoir pressure value p in the fracturing reform district of step when upper 10;
The shale gas reservoir matter balance equation in S52, the non-fracturing reform district of basis, the mean reservoir pressure value under step, when fracturing reform district when iterative computation is current is p 1time corresponding non-fracturing reform district mean reservoir pressure p 2;
S53, according to fracturing reform district and the current mean reservoir pressure value p in non-fracturing reform district 1and p 2gas well gas production when calculating current under step and the channelling amount between Liang Ge district;
S54, according to time long and output step by step, calculate the total accumulative channelling amount between total cumulative gas of gas well and Liang Ge district;
S55, calculating fracturing reform district matter balance equation residual error;
S56, when the absolute value of residual error is less than assigned error, exit iteration; Otherwise continue the mean reservoir pressure value in the new fracturing reform district of iterative computation, and return step S52.
According to embodiments of the invention, in above-mentioned steps S53, according to the mean reservoir pressure value p walking fracturing transformation district time current 1, and Gas Well Productivity, according to stable yields output q gscalculate flowing bottomhole pressure (FBHP) square value p 2 wf: if this square value is less than 0, then p pressed by gas well wLlevel pressure is produced; If p wfhigher than the stable yields end of term minimum flowing bottomhole pressure (FBHP) p wL, then gas well gas production is q gw=q gs, otherwise according to the following formula with minimum flowing bottomhole pressure (FBHP) p wLproduce the gas production q calculating gas well gw:
q gw = - A + A 2 + 4 B [ p 1 2 - p wL 2 2 B .
According to embodiments of the invention, calculate fracturing reform district matter balance equation residual error rsd according to the following formula:
rsd = p 1 Z 1 a - p i Z i a ( 1 - G p 1 - G p 2 G 1 ) ;
In above formula, p 1for the fracturing reform district mean reservoir pressure under step time current; p ifor original formation pressure; G p1for the cumulative gas of gas well, 10 4m 3; G p2for fracturing reform district is to the accumulative channelling amount in non-fracturing reform district, 10 4m 3; G 1for fracturing reform district reserves; Z 1 aand Z i abe defined as follows respectively:
Z j a = z [ 1 - s w 0 ] + z ( t 0 + 273.15 ) p SC ρ B V L 293.15 Z SC φ ( p L + p j ) , j = 1 , i
In above formula, z is equation of gas state deviation factors, is the function of gas reservoir pressure; p scfor standard atmospheric pressure, MPa; z scfor the equation of gas state deviation factors under standard state, ρ bfor density, t/m 3, V lfor Lan Shi volume, m 3/ t, P lfor Lan Shi pressure, MPa, Ф are effecive porosity, t 0for formation temperature, s w0for water saturation.
According to embodiments of the invention, above-mentioned steps S60 comprises the following steps further:
The initial value p of S61, non-fracturing reform district mean reservoir pressure when making current under step 2for the mean reservoir pressure value p in the non-fracturing reform district of step when upper 20;
S62, the mean reservoir pressure value p in the fracturing reform district that step iteration is corresponding when obtaining current 1,
S63, according to fracturing reform district and the current mean reservoir pressure value p in non-fracturing reform district 1and p 2channelling amount when calculating current between Bu Xialiangge district;
S64, according to time long and output step by step, calculate the total accumulative channelling amount between Liang Ge district;
S65, calculate non-fracturing reform district matter balance equation residual error;
S66, when the absolute value of residual error is less than assigned error, exit iteration; Otherwise continue the mean reservoir pressure value in the non-fracturing reform district of iterative computation, and return step S62.
According to embodiments of the invention, calculate non-fracturing reform district matter balance equation residual error rsd according to the following formula:
rsd = p 2 Z 2 a - p i Z i a ( 1 - G p 2 G 2 )
In above formula, p 2for the non-fracturing reform district mean reservoir pressure under step time current; p ifor original formation pressure; G p2for fracturing reform district is to the accumulative channelling amount in non-fracturing reform district, 10 4m 3; G 2for non-fracturing reform district reserves; Z 2 aand Z i abe defined as follows respectively:
Z j a = z [ 1 - s w 0 ] + z ( t 0 + 273.15 ) p SC ρ B V L 293.15 Z SC φ ( p L + p j ) , j = 2 , i
In above formula, z is equation of gas state deviation factors, is the function of gas reservoir pressure; p scfor standard atmospheric pressure, MPa; z scfor the equation of gas state deviation factors under standard state, ρ bfor density, t/m 3, V lfor Lan Shi volume, m 3/ t, P lfor Lan Shi pressure, MPa, Ф are effecive porosity, t 0for formation temperature, s w0for water saturation.
According to embodiments of the invention, above-mentioned shale gas well capacity results of measuring can comprise the gas production of gas well, total cumulative gas, and the channelling amount between fracturing reform district and non-fracturing reform district, total accumulative channelling amount.
According to embodiments of the invention, Newton Raphson method can be adopted to carry out iterative computation.
Compared with prior art, the shale gas well capacity assay method that the present invention proposes has the following advantages:
1) do not need to set up complicated shale gas reservoir geological model, do not need to obtain a lot of geology and pressure break dynamic parameter yet, significantly can shorten operation time during enforcement, obtain results of measuring more quickly and easily;
2) consider the impact on shale gas well capacity such as adsorbed gas desorb, fracturing reform district and non-fracturing reform district, results of measuring is more accurate;
3) Gas Well Productivity needed for measuring and calculating generally can obtain easily in Productivity Testing of Gas Well test, and the restriction by objective factors such as working conditions is less.
The method is particularly useful for the shale gas well capacity that analytical calculation initial stage of development does not set up shale gas reservoir geological model.Other features and advantages of the present invention will be set forth in the following description, and partly become apparent from manual, or understand by implementing the present invention.Object of the present invention and other advantages realize by structure specifically noted in manual, claims and accompanying drawing and obtain.
Accompanying drawing explanation
Accompanying drawing is used to provide a further understanding of the present invention, and forms a part for manual, with embodiments of the invention jointly for explaining the present invention, is not construed as limiting the invention.In the accompanying drawings:
Fig. 1 is certain shale gas reservoir multistage pressure break horizontal well Area of a well schematic diagram in the embodiment of the present invention;
Fig. 2 is the flow chart of the shale gas well capacity assay method that the present invention proposes;
Fig. 3 is according to the Gas Well Productivity that burnt page 1-HF well stable productivity test is set up in the embodiment of the present invention;
Fig. 4 is the schematic diagram calculating shale gas well capacity in the embodiment of the present invention;
Fig. 5 is the iterative process schematic diagram solving fracturing reform district mean reservoir pressure in the embodiment of the present invention;
Fig. 6 is the iterative process schematic diagram solving non-fracturing reform district mean reservoir pressure in the embodiment of the present invention;
Fig. 7 be the embodiment of the present invention burnt page 1-HF well respectively by 80,000 sides/sky and 6.5 ten thousand sides/sky join product time the daily output tolerance calculated and cumulative gas;
Fig. 8 is the embodiment of the present invention burnt page 1-HF well joins flowing bottomhole pressure (FBHP) and fracturing reform district and non-fracturing reform district strata pressure when generation is produced variation diagram by 80,000 sides/sky.
Detailed description of the invention
In order to make disclosed technology contents more detailed and complete, explain object of the present invention, technical scheme and technique effect with specific embodiment with reference to the accompanying drawings.It should be noted that, although be described for accompanying drawing, it will be understood by those of skill in the art that drawings and Examples are not used for limiting the scope that contains of the present invention.
As shown in Figure 1, the present invention is shale gas reservoir multistage pressure break horizontal well Area of a well schematic diagram.Shale gas reservoir Area of a well can be divided into fracturing reform district 100 and non-fracturing reform district 200 two parts according to well pattern spacing.Fracturing reform district 100 forms the region of complex fracture network in reservoir after being through volume fracturing transformation; Non-fracturing reform district 200 is not by the region of fracturing reform in the middle of adjacent two mouthfuls of wells.Along with the growth of recovery time, the strata pressure in fracturing reform district 100 progressively reduces, and and pressure reduction between non-fracturing reform district 200 amplify gradually and form channelling, the strata pressure difference between channelling Liang Yuliangge district is relevant.After strata pressure is reduced to desorption pressures, the adsorbed gas on matrix granule surface there will be desorb diffusion, and enters Fracture System.
The feature in fracturing reform district and non-fracturing reform district is there is in the present invention according to shale gas reservoir Area of a well, set up the two-region compound shale material balance equation for gas reservoir considering adsorbed gas, and in conjunction with the channelling equation between the binomial potential curve and equation of gas well and Liang Ge district, set up one shale gas well capacity assay method fast and accurately.
The method measuring and calculating shale gas well capacity using the present invention to propose needs given or tests following parameter:
The manufacturing parameter of given gas well, the stable production period such as comprising gas well joins product q gs(10 4m 3/ d), the stable yields end of term minimum flowing bottomhole pressure (FBHP) p wL(MPa), maximum evaluation number of days t max(d);
Given shale gas reservoir geologic parameter, such as, comprise original formation pressure p i(MPa), formation temperature t 0( oc) the interporosity flow coefficient λ (10, between fracturing reform district and non-fracturing reform district 4m 3/ (d.MPa 2)), fracturing reform district reserves G 1(10 4m 3), non-fracturing reform district reserves G 2(10 4m 3);
Given shale gas PVT physical parameter, such as, comprise gas relative density γ;
Measure shale core parameter, such as, comprise effecive porosity Ф, density p b(t/m 3), water saturation s w0, Lan Shi volume V that shale adsorption isothermal curve under formation condition is corresponding l(m 3/ t) and Lan Shi pressure P L (MPa);
Measure gas well parameter, such as, comprise binomial potential curve and equation coefficient A and B being obtained gas well by stable productivity well testing test.
As shown in Figure 2, the shale gas well capacity assay method that the present invention proposes mainly comprises the following steps:
S10, test, collect and arrange gas reservoir engineering parameter, and set up Gas Well Productivity.
Collect and manufacturing parameter, the geologic parameter of gas well are set; Test and shale gas PVT parameter, shale core parameter etc. are set.In the present embodiment, the gas reservoir engineering parameter of burnt page 1-HF well can see table 1:
Table 1
According to People's Republic of China (PRC) oil and gas industry standard SY/T5440-2000, carry out shale gas well operation initial stage stable productivity well testing test.Can select 4 ~ 5 working systems during test, measuring point output is ascending, progressively increases progressively.After the gas well gas production under each working system and flowing bottomhole pressure (FBHP) are stablized, record corresponding gas well gas production and flowing bottomhole pressure (FBHP) data.After having tested, returned by following formula and set up Gas Well Productivity (binomial equation):
p i 2 - p wf 2 q = A + Bq - - - ( 1 )
In above formula, A is Gas Well Productivity Monomial coefficient; B is Gas Well Productivity quadratic term coefficient; Q is gas well daily output tolerance, 10 4m 3/ d; p ifor original formation pressure, p wffor the stable flowing bottomhole pressure (FBHP) that gas well is corresponding to stable yields output q, MPa.As shown in Figure 3, in the present embodiment, for burnt page 1-HF well, gas well binomial potential curve and equation coefficient is respectively A=21.107, B=2.9494.
S20, point fracturing reform district and non-fracturing reform district, set up the two-region compound shale material balance equation for gas reservoir considering adsorbed gas desorb diffusion phenomena:
1. the shale gas reservoir matter balance equation in fracturing reform district:
The shale gas reservoir matter balance equation in ②Wei fracturing reform district:
In above formula, G p1 is the cumulative gas of gas well, 10 4m 3; G p2for fracturing reform district is to the accumulative channelling amount in non-fracturing reform district, 10 4m 3; p 1for the mean reservoir pressure in fracturing reform district, MPa; p 2for the mean reservoir pressure in non-fracturing reform district, MPa; Z 1 a, Z 2 aand Z i aconsidered free gas and adsorbed gas respectively to the impact of shale gas reservoir matter balance equation, it is defined as follows:
Z j a = z [ 1 - s w 0 ] + z ( t 0 + 273.15 ) p SC ρ B V L 293.15 Z SC φ ( p L + p j ) , = 1,2 , i - - - ( 4 )
In above formula, z is equation of gas state deviation factors, is the function of gas reservoir pressure; p scfor standard atmospheric pressure, MPa; z scfor the equation of gas state deviation factors under standard state.
S30, according to Gas Well Productivity, calculate the initil output of t=0 moment (also claiming initial time) gas well.
According to the gas well binomial potential curve and equation (as shown in Equation (1)) under original formation pressure, join product q stable production period according to gas well given in advance gscalculate flowing bottomhole pressure (FBHP) square value p 2 wf.If this square value is less than 0, then illustrate that gas well cannot with output q gsstable yields, needs with the stable yields end of term minimum bottom pressure p wLcarry out level pressure to produce; If flowing bottomhole pressure (FBHP) is higher than the stable yields end of term minimum flowing bottomhole pressure (FBHP) p wL, then gas well is q according to initil output gspressure control stable yields mode produce, otherwise gas well is according to the stable yields end of term minimum flowing bottomhole pressure (FBHP) p wLproduce.
When gas well can stable yields time, the flowing bottomhole pressure (FBHP) of gas well can be calculated according to Gas Well Productivity, otherwise need according to minimum flowing bottomhole pressure (FBHP) p wLcalculate the gas production of gas well.Circular is as follows:
1. flowing bottomhole pressure (FBHP) when gas well is produced according to stable yields output qgs:
2. gas well is according to minimum flowing bottomhole pressure (FBHP) p wLoutput during production:
Wherein, between initial time fracturing reform district and non-fracturing reform district, do not have producing pressure differential, channelling amount is 0.
In addition, preferably arranging the t=0 moment, is also that under original state, the cumulative gas of gas well is G p1=0, non-fracturing reform district is G to the accumulative channelling amount in fracturing reform district p2=0.
S40, step step delta t when arranging, the time that when calculating next, step is corresponding: t=t+ Δ t, and when it can be used as current step to perform step when following steps S50 and S60(also upgrades current).
S50, shale gas reservoir matter balance equation according to fracturing reform district, the mean reservoir pressure p in fracturing reform district time current according to Newton method (Newton Raphson) iterative computation under step 1.
Composition graphs 4 and Fig. 5 known, in the specific implementation, this step S50 can comprise the following steps further:
S51, by the mean reservoir pressure value p in fracturing reform district of step when upper 10as the initial value of the fracturing reform district mean reservoir pressure under step time current, even p 1=p 10.
The shale gas reservoir matter balance equation in S52, the non-fracturing reform district of basis, the mean reservoir pressure value under step, when fracturing reform district when calculating current according to Newton iteration method is p 1time corresponding non-fracturing reform district mean reservoir pressure p 2.
S53, gas well gas production when calculating current under step.
According to the mean reservoir pressure value p walking fracturing transformation district time current 1, and Gas Well Productivity, according to stable yields output q gscalculate flowing bottomhole pressure (FBHP) square value p 2 wf.If this square value is less than 0, then p pressed by gas well wLlevel pressure is produced; If p wfhigher than the stable yields end of term minimum flowing bottomhole pressure (FBHP) p wL, then gas well gas production is q gw=q gs, otherwise according to the following formula with minimum flowing bottomhole pressure (FBHP) p wLproduce the gas production q calculating gas well gw:
q gw = - A + A 2 + 4 B [ p 1 2 - p wL 2 2 B - - - ( 7 )
And according to fracturing reform district and the current mean reservoir pressure value p in non-fracturing reform district 1and p 2, channelling amount q when calculating current according to following channelling equation between Bu Xialiangge district 2:
q 2 = λ [ p 2 2 - p 1 2 ] - - - ( 8 )
S54, according to time step step delta t and output, calculate total cumulative gas G of gas well p1, total accumulative channelling amount G between Liang Ge district p2:
The accumulative aerogenesis of gas well in current step:
Total cumulative gas of gas well:
Accumulative channelling amount between current step Nei Liangge district:
Total accumulative channelling amount between Liang Ge district:
In above formula, q gw0for the gas well gas production walked time last, 10 4m 3/ d; q 20for the channelling amount between last Shi Buliangge district, 10 4m 3/ d; G p10for the total cumulative gas of the gas well walked time last, 10 4m 3; G p20for total accumulative channelling amount time last between Bu Liangge district, 10 4m 3.
S55, according to time current step under fracturing reform district mean reservoir pressure p 1, calculate equation of gas state deviation factors z and matter balance equation coefficient Z 1 a, according to original formation pressure p icalculate Z i a, bring following formula into and calculate fracturing reform district matter balance equation residual error rsd:
rsd = p 1 Z 1 a - p i Z i a ( 1 - G p 1 - G p 2 G 1 ) - - - ( 13 )
S56, when the absolute value of residual error rsd is less than assigned error ε 0, exit iteration; Otherwise, calculate new p according to Newton iteration method 1value, and return step 52), continue iteration.
S60, p according to step during iterative computation current 1value, according to the shale gas reservoir matter balance equation in non-fracturing reform district, the mean reservoir pressure p in iterative computation current Shi Buxiawei fracturing reform district 2.
It should be noted that, the process of this step iterative computation is the same with above-mentioned steps S52 iterative process.Wherein, S52 calculates p 1need the pilot process called during value, be work as p herein 1after value is finally determined through iteration, based on this p 1value calculates corresponding p 2value.
Composition graphs 4 and Fig. 6 known, in the specific implementation, this step S60 can comprise the following steps further:
S61, by the mean reservoir pressure value p in non-fracturing reform district of step when upper 20as the initial value of the non-fracturing reform district mean reservoir pressure under step time current, even p 2=p 20.
S62, the mean reservoir pressure value p in the fracturing reform district that step iteration is corresponding when obtaining current 1.
S63, according to fracturing reform district and the current mean reservoir pressure value p in non-fracturing reform district 1and p 2, channelling amount q when calculating current according to following channelling equation (same to formula (8)) between Bu Xialiangge district 2:
q 2 = λ [ p 2 2 - p 1 2 ] - - - ( 14 )
S64, according to time step step delta t and output, calculate the total accumulative channelling amount G between Liang Ge district p2:
Accumulative channelling amount between current step Nei Liangge district:
Total accumulative channelling amount between Liang Ge district:
In above formula, q 2for the channelling amount between current Shi Buliangge district, 10 4m 3/ d; q 20for the channelling amount between last Shi Buliangge district, 10 4m 3/ d; G p20for total accumulative channelling amount time last between Bu Liangge district, 10 4m 3.
S65, according to time current step under non-fracturing reform district mean reservoir pressure p 2, calculate equation of gas state deviation factors z and matter balance equation coefficient Z 2 a, according to original formation pressure p icalculate Z i a, bring following formula into and calculate non-fracturing reform district matter balance equation residual error rsd:
rsd = p 2 Z 2 a - p i Z i a ( 1 - G p 2 - G p 2 G 2 ) - - - ( 17 )
S66, when the absolute value of residual error rsd is less than assigned error ε 0, exit iteration; Otherwise calculate new p according to Newton iteration method 2value, and return step 62), continue iteration.
S70, according to step S50 and S60 obtain current time step fracturing transformation district and the mean reservoir pressure in non-fracturing reform district, shale gas well capacity when calculating current under step, comprise the gas production of gas well, total cumulative gas, and the channelling amount between fracturing reform district and non-fracturing reform district, total accumulative channelling amount.
According to the fracturing reform district mean reservoir pressure value p walked time current 1, calculate gas well gas production according to step S53;
According to the mean reservoir pressure in fracturing reform district and non-fracturing reform district, calculate the channelling amount between Liang Ge district according to formula (8);
According to step time current and last time step gas production, and total cumulative gas of step time last, total cumulative gas of step when calculating current according to formula (10), and when formula (12) calculates current step always add up channelling amount.
S80, judge whether current time t is greater than given maximum evaluation number of days t max:
If not, return step S40, continue to calculate.
If so, shale gas well deliverability result of calculation is exported, the result of calculations such as such as gas well gas production, total cumulative gas, and the channelling amount between fracturing reform district and non-fracturing reform district, total accumulative channelling amount.
As shown in Figure 7, in the present embodiment, burnt page 1-HF well, respectively according to joining product the stable production period in 80,000 sides/sky and 6.5 ten thousand sides/sky, adopts said method to estimate gas well deliverability.Wherein, the estimation result of the total cumulative gas of gas well at the end of the cumulative gas and time span of forecast in stable production period, the stable yields end of term can see table 2.Because this gas well requires reach 1.5 years stable production period, therefore according to the AOF calculation result that the present invention obtains, product joined by this well should more than 6.5 ten thousand sides/sky.
Index Join product scheme one Join product scheme two
Stable production period output (10 4m 3/d） 8 6.5
Stable production period (year) 1.08 1.66
Stable yields end of term cumulative gas (10 4m 3） 2935.6 3815.2
Final tired gas production (10 4m 3） 9084.5 9079
Table 2
Accordingly, Fig. 8 shows the flowing bottomhole pressure (FBHP) of this gas well, fracturing reform district and non-fracturing reform district strata pressure situation over time.
Although the embodiment disclosed by the present invention is as above, the embodiment that described content just adopts for the ease of understanding the present invention, and be not used to limit the present invention.Technician in any the technical field of the invention, under the prerequisite not departing from the spirit and scope disclosed by the present invention, any amendment that the formal and details implemented is done and change, all should in scope of patent protection of the present invention.

Claims (10)

1. a shale gas well capacity assay method, comprises the following steps:
S10, test, collect and arrange gas reservoir engineering parameter, and set up Gas Well Productivity;
S20, consideration adsorbed gas desorb diffusion, set up the shale gas reservoir matter balance equation in gas well fracturing transformation district and non-fracturing reform district respectively;
S30, according to Gas Well Productivity, calculate the initil output of initial time gas well;
S40, step by step long when arranging, the time that when calculating next, step is corresponding, and walk when upgrading current;
S50, shale gas reservoir matter balance equation according to fracturing reform district, walk the mean reservoir pressure in fracturing transformation district when iterative computation is current;
S60, according to the mean reservoir pressure walking fracturing transformation district time current, and the shale gas reservoir matter balance equation in non-fracturing reform district, the mean reservoir pressure in iterative computation current Shi Buxiawei fracturing reform district;
S70, according to walking fracturing transformation district and the mean reservoir pressure in non-fracturing reform district time current, shale gas well capacity when calculating current under step;
S80, judge whether current time is greater than given maximum evaluation number of days:
If not, using the mean reservoir pressure value walked time current as the initial value walking iteration during the next one, step S40 is returned;
If so, shale gas well deliverability result of calculation is exported.
2. shale gas well capacity assay method as claimed in claim 1, it is characterized in that, described Gas Well Productivity is:
p i 2 - p wf 2 q = A + Bq
In above formula, A is Gas Well Productivity Monomial coefficient; B is Gas Well Productivity quadratic term coefficient; p ifor original formation pressure; Q is gas well daily output tolerance, 10 4m 3/ d; p wffor the stable flowing bottomhole pressure (FBHP) that gas well is corresponding to stable yields output q, MPa.
3. shale gas well capacity assay method as claimed in claim 1, is characterized in that, in described step S20,
The shale gas reservoir matter balance equation in fracturing reform district is:
p 1 Z 1 a = p i Z i a ( 1 - G p 1 - G p 2 G 1 )
The shale gas reservoir matter balance equation in non-fracturing reform district is:
p 2 Z 2 a = p i Z i a ( 1 - G p 2 G 2 )
In above formula, G p1for the cumulative gas of gas well, 10 4m 3; G p2for fracturing reform district is to the accumulative channelling amount in non-fracturing reform district, 10 4m 3; G 1for fracturing reform district reserves; G 2for non-fracturing reform district reserves; p 1for the mean reservoir pressure in fracturing reform district, MPa; p 2for the mean reservoir pressure in non-fracturing reform district, MPa; p ifor original formation pressure; Z 1 a, Z 2 aand Z i abe defined as follows respectively:
Z j a = z [ 1 - s w 0 ] + z ( t 0 + 273.15 ) p SC ρ B V L 293.15 Z SC φ ( p L + p j ) , = 1,2 , i
In above formula, z is equation of gas state deviation factors, is the function of gas reservoir pressure; p scfor standard atmospheric pressure, MPa; z scfor the equation of gas state deviation factors under standard state, ρ bfor density, t/m 3, V lfor Lan Shi volume, m 3/ t, P lfor Lan Shi pressure, MP a, Ф is effecive porosity, t 0for formation temperature, s w0for water saturation.
4. shale gas well capacity assay method as claimed in claim 1, it is characterized in that, described step S50 comprises the following steps further:
The initial value p of S51, fracturing reform district mean reservoir pressure when making current under step 1for the mean reservoir pressure value p in the fracturing reform district of step when upper 10;
The shale gas reservoir matter balance equation in S52, the non-fracturing reform district of basis, the mean reservoir pressure value under step, when fracturing reform district when iterative computation is current is p 1time corresponding non-fracturing reform district mean reservoir pressure p 2;
S53, according to fracturing reform district and the current mean reservoir pressure value p in non-fracturing reform district 1and p 2gas well gas production when calculating current under step and the channelling amount between Liang Ge district;
S54, according to time long and output step by step, calculate the total accumulative channelling amount between total cumulative gas of gas well and Liang Ge district;
S55, calculating fracturing reform district matter balance equation residual error;
S56, when the absolute value of residual error is less than assigned error, exit iteration; Otherwise continue the mean reservoir pressure value in the new fracturing reform district of iterative computation, and return step S52.
5. shale gas well capacity assay method as claimed in claim 4, is characterized in that, in described step S53, according to the mean reservoir pressure value p walking fracturing transformation district time current 1, and Gas Well Productivity, according to stable yields output q gscalculate flowing bottomhole pressure (FBHP) square value p 2 wf: if this square value is less than 0, then p pressed by gas well wLlevel pressure is produced; If p wfhigher than the stable yields end of term minimum flowing bottomhole pressure (FBHP) p wL, then gas well gas production is q gw=q gs, otherwise according to the following formula with minimum flowing bottomhole pressure (FBHP) p wLproduce the gas production q calculating gas well gw:
q gw = - A + A 2 + 4 B [ p 1 2 - p wL 2 2 B .
6. shale gas well capacity assay method as claimed in claim 4, is characterized in that, calculates fracturing reform district matter balance equation residual error rsd according to the following formula:
rsd = p 1 Z 1 a - p i Z i a ( 1 - G p 1 - G p 2 G 1 ) ;
In above formula, p 1for the fracturing reform district mean reservoir pressure under step time current; p ifor original formation pressure; G p1for the cumulative gas of gas well, 10 4m 3; G p2for fracturing reform district is to the accumulative channelling amount in non-fracturing reform district, 10 4m 3; G 1for fracturing reform district reserves; Z 1 aand Z i abe defined as follows respectively:
Z j a = z [ 1 - s w 0 ] + z ( t 0 + 273.15 ) p SC ρ B V L 293.15 Z SC φ ( p L + p j ) , j = 1 , i
In above formula, z is equation of gas state deviation factors, is the function of gas reservoir pressure; p scfor standard atmospheric pressure, MPa; z scfor the equation of gas state deviation factors under standard state, ρ bfor density, t/m3, V lfor Lan Shi volume, m 3/ t, P lfor Lan Shi pressure, MPa, Ф are effecive porosity, t 0for formation temperature, s w0for water saturation.
7. the shale gas well capacity assay method as described in claim 1 ~ 6 any one, it is characterized in that, described step S60 comprises the following steps further:
The initial value p of S61, non-fracturing reform district mean reservoir pressure when making current under step 2for the mean reservoir pressure value p in the non-fracturing reform district of step when upper 20;
S62, the mean reservoir pressure value p in the fracturing reform district that step iteration is corresponding when obtaining current 1,
S63, according to fracturing reform district and the current mean reservoir pressure value p in non-fracturing reform district 1and p 2channelling amount when calculating current between Bu Xialiangge district;
S64, according to time long and output step by step, calculate the total accumulative channelling amount between Liang Ge district;
S65, calculate non-fracturing reform district matter balance equation residual error;
S66, when the absolute value of residual error is less than assigned error, exit iteration; Otherwise continue the mean reservoir pressure value in the non-fracturing reform district of iterative computation, and return step S62.
8. shale gas well capacity assay method as claimed in claim 7, is characterized in that, calculate non-fracturing reform district matter balance equation residual error rsd according to the following formula:
rsd = p 2 Z 2 a - p i Z i a ( 1 - G p 2 G 2 )
In above formula, p 2for the non-fracturing reform district mean reservoir pressure under step time current; p ifor original formation pressure; G p2for fracturing reform district is to the accumulative channelling amount in non-fracturing reform district, 10 4m 3; G 2for non-fracturing reform district reserves; Z 2 aand Z i abe defined as follows respectively:
Z j a = z [ 1 - s w 0 ] + z ( t 0 + 273.15 ) p SC ρ B V L 293.15 Z SC φ ( p L + p j ) , j = 2 , i
In above formula, z is equation of gas state deviation factors, is the function of gas reservoir pressure; p scfor standard atmospheric pressure, MPa; z scfor the equation of gas state deviation factors under standard state, ρ bfor density, t/m3, V lfor Lan Shi volume, m 3/ t, P lfor Lan Shi pressure, MPa, Ф are effecive porosity, t 0for formation temperature, s w0for water saturation.
9. shale gas well capacity assay method as claimed in claim 1, it is characterized in that, described shale gas well capacity result of calculation comprises the gas production of gas well, total cumulative gas, and the channelling amount between fracturing reform district and non-fracturing reform district, total accumulative channelling amount.
10. shale gas well capacity assay method as claimed in claim 1, is characterized in that, adopts Newton Raphson method to carry out iterative computation.
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