CN102953726A - Method and device for water drive oilfield advantage channel recognition - Google Patents

Abstract

The invention discloses a method and a device for water drive oilfield advantage channel recognition. Unstable pressure restore well testing data are applied to recognize advantage channels formed during development of water drive oilfields. The method includes: step of setting a well testing typical characteristic curve layout, step of calculating well testing bottom pressure derivatives, step of drawing a testing well relation curve and step of judging existence and development level of the advantage channels, and the device comprises a typical characteristic curve layout setting module, a well bottom pressure measuring module, a well bottom pressure derivative calculation module, a testing well relation curve drawing module and a judging module. Compared with the prior art, the method for water drive oilfield advantage channel recognition is high in accuracy, high in generality, easy to implement, high in operability and capable of providing technical support for implementation of subsequent oilfield yield-increasing measures and designing of recovery ratio improving schemes.

Description

A kind of water controlled field advantage channel recognition method and device

Technical field

The present invention relates to the recognition technology of water controlled field advantage passage, particularly a kind of water controlled field advantage channel recognition method and device that utilizes the transient well test method that formed advantage passage in the water controlled field development process is identified.

Background technology

In the long-term injecting water development process in oil field, RESERVOIR PORE STRUCTURE can great changes will take place.The variation of the Development Factors such as the geologic(al) factors such as reservoir heterogeneity, exploitation rate are too fast and formation pressure etc. all can make reservoir pore throat radius increase, and permeability increases, thereby forms secondary high permeable strip, i.e. advantage passage in reservoir.In oilfield development process, the most responsive development parameters of advantage passage is pressure and output, and the data that well testing is enrolled is unique data of enrolling under the reservoir fluid flow regime in the various data, so analysis result also can represent the dynamic characteristic of oil-gas reservoir.Because the advantage passage forms in oilfield development process gradually, so the growth rank of advantage passage is not unalterable, but a dynamic changing process that grows from weak to strong.The flow regime of advantage inner fluid passage also gradually changes, and developing gradually from darcy flow is non-darcy flow.The appearance of advantage passage will cause the poor efficiency of great amount of injection water, invalid circulation, and it has aggravated reservoir heterogeneity on the one hand, reduce the sweep efficiency of injected water, reduce the injected water utilization rate; Aggravated on the other hand layer interior, an interlayer contradiction, the fuel-displaced situation of the suction of other oil reservoir of severe jamming, it is fast to cause well water to rise, and the water drive development degree is low; Simultaneously, it also can cause other well stimulation to implement relatively difficulty, strengthens the workload of gathering line and multi-purpose station, and the oil field development cost is increased, and has reduced the economic recovery in oil field, affects the raising of oil field development benefit.

Therefore, how effectively to identify the advantage passage and choose suitable technological measure it is administered, increase the injected water sweep efficiency with this, improve the oilfield water flooding development effectiveness, become and be badly in need of the major issue that solves in the middle High Water Cut Reservoir exploitation.And the crucial and primary work that addresses this problem is exactly accurately and effectively the advantage passage to be identified.Advantage channel recognition method commonly used mainly contains at present: interwell tracer test method, logging method, hydraulic detection method and reservoir engineering method.Mainly the tracer output concentration by detect injecting responding well around the tracer well is over time for tracer method, utilize analytic method or method for numerical simulation, simulate concentration curve, by adjusting formation parameter, utilize parameter to change the feature of coming simulate formation advantage passage; The suction situation of change of each substratum is mainly determined in logging method according to the abnormal response of well-log information, and then substantially determines to exist because of the advantage passage layer position of abnormal water absorption; The variation that the hydraulic detection method mainly utilizes compression wave to pass to the change interpretation oil-yielding stratum permeability of pressure reduction between required time of producing well and well by water injection well, and then quantitative interpretation goes out the parameter of advantage passage; Reservoir engineering method is mainly with the mobile one dimensional flow that is considered as of water in the advantage passage, the Mathematical Modeling after setting up macropore and forming, and then adopt stream-tube method to calculate the parameter of advantage passage.Yet existing advantage channel recognition theoretical method basis imperfection, when setting up Mathematical Modeling often only based on the hypothesis of darcy flow or pipe stream, do not consider the corresponding different seepage states of different stage advantage passage and on the impact of advantage channel recognition, can not accurately reflect the feature of advantage passage; In addition, tracer test and hydraulic detection method somewhat expensive, and also the qualitative composition of parameter interpretation process is more, affected by force by artificial subjectivity, operability is weak, be unfavorable for field conduct; The layer position that logging method can qualitative discrimination advantage passage exists, but can't judge the rank that the advantage passage is grown, awareness is lower, and can affect the normal production in oil field in the test process, and cost is higher; Reservoir engineering method is with the Guan Liuwei basic model, calculates simplely, but hypothesis is too idealized, does not meet the actual conditions of advantage passage.

Therefore, the recognition methods of research different stage advantage passage has important theory and realistic meaning for the exploitation of middle High Water Cut Reservoir.

Summary of the invention

Technical problem to be solved by this invention provides that a kind of accuracy is high, highly versatile and simple method and the device that formed advantage passage in the water controlled field development process is identified.

To achieve these goals, the invention provides a kind of water controlled field advantage channel recognition method, wherein, use transient pressure recovery well test data formed advantage passage in the water controlled field development process is identified, comprise the steps:

A, well testing characteristic feature curve plate step is set: the well testing characteristic feature curve plate that the advantage channel recognition is set;

B, well testing bottom hole pressure measurement step: pressure gauge is lowered to well testing test purpose layer middle part, surface shut-in, the information well bottom pressure that utilizes pressure gauge record well testing bottom pressure to recover with the testing time;

C, well testing bottom pressure derivative calculations step: the bottom pressure that calculates described well testing to the first derivative of time natural logrithm as the bottom pressure derivative;

D, draw actual measurement well testing relation curve step: take the testing time as abscissa, take flowing bottomhole pressure (FBHP) and pressure derivative as ordinate, in log-log coordinate system, draw described bottom pressure or the time dependent actual measurement well testing of described bottom pressure derivative relation curve;

E, the existence of judging the advantage passage and growth rank step thereof: the described well testing characteristic feature curve of described actual measurement well testing relation curve and advantage channel recognition is carried out form relatively, judge whether the advantage passage exists and determine its growth rank.

Above-mentioned water controlled field advantage channel recognition method wherein, before described drafting actual measurement well testing relation curve step, also comprises:

D0, data smoothing treatment step: described bottom pressure or described bottom pressure derivative and the relation of time are carried out data smoothing process to reduce noise.

Above-mentioned water controlled field advantage channel recognition method, wherein, described data smoothing treatment step adopts Wavelet Transform, linear interpolation exponential smoothing or Fourier transform that described bottom pressure or described bottom pressure derivative are carried out the data smoothing processing.

Above-mentioned water controlled field advantage channel recognition method, wherein, the described well testing characteristic feature curve plate step that arranges comprises and normal reservoir well test curve plate is set and advantage passage well testing characteristic feature curve plate is set.

Above-mentioned water controlled field advantage channel recognition method, wherein, described normal reservoir well test curve plate is the transient seepage flow model curve plate of center, the infinitely great stratum of homogeneous a bite well.

Above-mentioned water controlled field advantage channel recognition method, wherein, the described advantage passage well testing characteristic feature curve plate that arranges comprises:

A1, setting models assumed condition: according to the origin cause of formation of advantage passage and the assumed condition of growth rank setting models;

A2, set up Mathematical Modeling: according to the origin cause of formation of described advantage passage and grow other assumed condition of level and set up respectively corresponding Mathematical Modeling;

A3, model solution and characteristic feature Drawing of Curve: respectively described Mathematical Modeling is found the solution and drawn corresponding advantage passage well testing characteristic feature curve plate according to solving result.

Above-mentioned water controlled field advantage channel recognition method, wherein, described advantage passage well testing characteristic feature curve plate grows from weak to strong according to the origin cause of formation and the growth rank of advantage passage, comprises common high permeability zone indicatrix plate, strong high infiltration strip indicatrix plate and macropore indicatrix plate.

In order to realize better above-mentioned purpose, the present invention also provides a kind of water controlled field advantage passage identification device, wherein, uses transient pressure recovery well test data formed advantage passage in the water controlled field development process is identified, and comprising:

Characteristic feature curve plate module is set: the well testing characteristic feature curve plate that is used for setting and storage advantage channel recognition;

The bottom hole pressure measurement module: comprise pressure gauge and pressure record unit, described pressure gauge is used for the bottom pressure that the test well testing recovered with the testing time, and the described bottom pressure that test obtains is conveyed into described pressure record unit;

Bottom pressure derivative calculations module: be used for calculating described bottom pressure to the first derivative of time natural logrithm, as the bottom pressure derivative and store this bottom pressure derivative;

Draw well testing relation curve module: be used for drawing described bottom pressure or the time dependent actual measurement well testing of described bottom pressure derivative relation curve in log-log coordinate system;

Judge module: be used for the described well testing characteristic feature curve of described actual measurement well testing relation curve and advantage channel recognition is carried out form relatively, judge whether the advantage passage exists and determine its growth rank.

Above-mentioned water controlled field advantage passage identification device wherein, also comprises:

The data smoothing processing module: be used for described bottom pressure or described bottom pressure derivative and the relation of time carry out data smoothing process after the described drafting of input survey well testing relation curve module.

Technique effect of the present invention is: the present invention is on the basis of transient well test test, by the theory analysis to different stage advantage passage seepage characteristics, drawn the characteristic feature curve for different stage advantage passage, set up one and overlapped the new method of identifying accurately and effectively water controlled field advantage passage.The present invention reaches the checking of carrying out with routine techniques through field conduct, has all obtained preferably effect.This technology is compared with routine techniques, and high, the highly versatile of accuracy is simple, has stronger operability, can provide technical support for the enforcement of next step well stimulation of oil field and the design that improves the recovery ratio scheme.

Describe the present invention below in conjunction with the drawings and specific embodiments, but not as a limitation of the invention.

Description of drawings

Fig. 1 is water controlled field advantage channel recognition method flow diagram of the present invention;

Fig. 2 is that reservoir is the well testing characteristic feature curve of normal reservoir when (not having the advantage passage in the reservoir);

Fig. 3 is the well testing characteristic feature curve when having common high permeability zone in the reservoir;

Fig. 4 is the well testing characteristic feature curve when having strong high infiltration strip in the reservoir;

Fig. 5 A is the WELL TEST INTERPRETATION MODEL schematic diagram of macropore;

Fig. 5 B is the well testing characteristic feature curve when having macropore in the reservoir;

Fig. 6 is water controlled field advantage passage identification device block diagram of the present invention;

Fig. 7 is the transient well test test result of one embodiment of the invention;

Fig. 8 is the transient well test second time test result of one embodiment of the invention;

Fig. 9 is the transient well test test result of one embodiment of the invention.

Wherein, Reference numeral

1 arranges characteristic feature curve plate module

2 bottom hole pressure measurement modules

3 bottom pressure derivative calculations modules

4 data smoothing processing modules

5 draw well testing relation curve module

6 judge modules

The M pressure derivative is curve over time

N pressure is curve over time

A～e, b0, a1～a3 step

The specific embodiment

Below in conjunction with accompanying drawing structural principle of the present invention and operating principle are done concrete description:

The invention discloses a kind of water controlled field advantage channel recognition method and device based on transient well test.Mainly by oil well is carried out pressure buildup test, utilize bottom pressure and the time dependent curve of derivative thereof of actual measurement, formed advantage passage in the water controlled field development process is identified.The advantage passage is identified the problem that is mainly concerned with two broad aspect: (1) determines whether there is the advantage passage in the reservoir; (2) degree of Diagnostic Superiority passage growth.

The present invention is in order to solve the above-mentioned two large problems in the advantage channel recognition process, overcome that conventional advantage channel recognition method is inaccurate, imperfection, be subjected to the large shortcoming of subjective factor affecting, take the transient well test test as the basis, set up a kind of recognition technology for different stage advantage passage, provide technical support as the enforcement of next step well stimulation of oil field and the design of raising recovery ratio scheme.

Referring to Fig. 1, Fig. 1 is water controlled field advantage channel recognition method flow diagram of the present invention.The invention provides a kind of water drive advantage channel recognition method based on transient well test.It mainly is to use transient pressure recovery well test data formed advantage passage in the water controlled field development process is identified, by oil well is carried out pressure buildup test, utilize resulting pressure and differential of pressure curve that formed advantage passage in the water controlled field development process is identified.Comprise the steps:

Well testing characteristic feature curve plate step a is set: the well testing characteristic feature curve plate that the advantage channel recognition is set;

Well testing bottom hole pressure measurement step b: pressure gauge (present embodiment is preferably high-precise electronic pressure manometer) is lowered to well testing test purpose layer middle part, surface shut-in, the bottom pressure that utilizes the well testing of pressure gauge record to recover with the testing time;

Well testing bottom pressure derivative calculations step c: the bottom pressure that calculates described well testing to the first derivative of time natural logrithm as the bottom pressure derivative;

Draw actual measurement well testing relation curve steps d: take the testing time as abscissa, take flowing bottomhole pressure (FBHP) and pressure derivative as ordinate, in log-log coordinate system, draw described bottom pressure or the time dependent actual measurement well testing of described bottom pressure derivative relation curve; Described actual measurement well testing relation curve is the double-log relation curve of zero dimension bottom pressure and non dimensional time or the double-log relation curve of zero dimension bottom pressure derivative and non dimensional time.

The existence of judgement advantage passage and growth rank step e thereof: the described well testing characteristic feature curve of described actual measurement well testing relation curve and advantage channel recognition is carried out form relatively, judge whether the advantage passage exists and determine its growth rank.

Before described drafting actual measurement well testing relation curve steps d, also comprise:

Data smoothing treatment step d0: described bottom pressure or described bottom pressure derivative and the relation of time are carried out data smoothing process to reduce noise.Wherein, described data smoothing treatment step can adopt Wavelet Transform, linear interpolation exponential smoothing or Fourier transform that described bottom pressure or described bottom pressure derivative are carried out the data smoothing processing.Owing to exist many uncertain factors in the transient well test process, sneak into interfering signal (noise) in the bottom pressure signal that these uncertain factors can make high-grade pressure gauge record.If do not adopt suitable algorithm to carry out noise reduction, then can cause bottom pressure and differential of pressure curve larger fluctuation to occur, cause curvilinear characteristic not obvious, may affect the practical application effect of this invention.Therefore present embodiment preferably adopts the small wave converting method in the mathematics that the bottom pressure data of actual measurement are carried out smooth treatment, to reach the purpose of noise reduction.

The described well testing characteristic feature curve plate step that arranges comprises and normal reservoir well test curve plate is set and advantage passage well testing characteristic feature curve plate is set.Wherein, reservoir is normal reservoir when (not having the advantage passage in the reservoir), and it is considered as Homogeneous Reservoir.The WELL TEST INTERPRETATION MODEL of such reservoir is the transient seepage flow model of center, the infinitely great stratum of traditional homogeneous a bite well, can adopt the laplace conversion to carry out Analytical Solution or finite difference method is carried out numerical solution.The typie well-testing curve of such reservoir is curve commonly used of the prior art, and the concrete solution procedure of model and typical curve are ripe prior art, and therefore not to repeat here.In the present embodiment, described normal reservoir well test curve plate is the transient seepage flow model curve plate of center, the infinitely great stratum of homogeneous a bite well.Referring to Fig. 2, Fig. 2 is that reservoir is the well testing characteristic feature curve of normal reservoir when (not having the advantage passage in the reservoir).Wherein, M is over time curve of pressure derivative in the accompanying drawing, and N is over time curve of pressure, below M among each figure, N implication identical.Pressure and pressure derivative have fixing implication in the well testing subject.

In the present embodiment, the origin cause of formation and growth rank according to the advantage passage, the advantage passage grown from weak to strong be divided into three classes: common high permeability zone, strong high infiltration strip and macropore, take out typical physical model according to its seepage characteristics respectively, set up corresponding well test analysis Mathematical Modeling with this, and it is found the solution, draw the characteristic feature curve of different stage advantage channel recognition.

Wherein, the described advantage passage well testing characteristic feature curve plate that arranges specifically comprises:

Set up model condition step a1 is set: the origin cause of formation and growth rank according to the advantage passage are set up the assumed condition that model arranges;

Set up Mathematical Modeling step a2: the origin cause of formation and other assumed condition of growth level according to described advantage passage are set up respectively corresponding Mathematical Modeling;

Model solution and characteristic feature Drawing of Curve step a3: respectively described Mathematical Modeling is found the solution and drawn corresponding advantage passage well testing characteristic feature curve plate according to solving result.

Wherein, described advantage passage well testing characteristic feature curve plate is according to the origin cause of formation of advantage passage and grow rank and grow from weak to strong and comprise common high permeability zone indicatrix plate, strong high infiltration strip indicatrix plate and macropore indicatrix plate.

The below specifies the process of setting up of common high permeability zone indicatrix plate, strong high infiltration strip indicatrix plate and macropore indicatrix plate.

Referring to Fig. 3, Fig. 3 is the well testing characteristic feature curve when having common high permeability zone in the reservoir.When having common high permeability zone in the reservoir, it is considered as stratified reservoir.

A1, model hypothesis condition are as follows:

1. oil well is produced with the fixed output quota amount;

2. formation fluid and rock are all little compressible, and compression coefficient is constant;

3. formation fluid is single-phase, and flowing in two seepage fields all meets Darcy's law;

4. consider the impact of well hole storage and skin effect;

5. each point pressure is identical in the front stratum of oil well test, is p _i

6. ignore the impact of gravity and capillary force, and barometric gradient is less in the stratum;

7. the pressure of the degree of porosity of every kind of medium and another kind of medium changes separate;

8. be connected between two-layer, and the quasi-stable state channelling occurs between the two;

A2, set up Mathematical Modeling

The nondimensional number definition

The normal reservoir of subscript 1 representative in the model, the common high permeability zone of subscript 2 representatives.

1. zero dimension pressure:

$P_{\mathrm{Dj}}=\frac{k_1{\mathrm{<figure-callout\; id="1"\; label="h"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">h</figure-callout>}}_1+k_2{\mathrm{<figure-callout\; id="2"\; label="h"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">h</figure-callout>}}_2}{1.842\&times;{10}^{-3}\mathrm{q\&mu;B}}\mathrm{\&Delta;}{p}_j$

In the formula: Δ p _j=p _i-p _j, j=1,2

2. non dimensional time:

$t_D=\frac{3.6(k_1{\mathrm{<figure-callout\; id="1"\; label="h"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">h</figure-callout>}}_1+k_2{h}_2)}{[{\left(\mathrm{\&phi;}{C}_{t}h\right)}_1+{\left(\mathrm{\&phi;}{C}_{t}h\right)}_2]\mathrm{\&mu;}{r}_w^2}t$

3. zero dimension well hole storage coefficient

${\mathrm{<figure-callout\; id="1"\; label="C\; D"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">C</figure-callout>}}_D=\frac{\mathrm{<figure-callout\; id="2"\; label="C"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">C</figure-callout>}}{2\mathrm{\&pi;}{\left(\mathrm{\&phi;}{C}_{t}h\right)}_1{\mathrm{<figure-callout\; id="2"\; label="r\; w"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">r</figure-callout>}}_w^{}},$ ${\mathrm{<figure-callout\; id="2"\; label="C\; D"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">C</figure-callout>}}_D=\frac{\mathrm{<figure-callout\; id="2"\; label="C"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">C</figure-callout>}}{2\mathrm{\&pi;}{\left(\mathrm{\&phi;}{C}_{t}h\right)}_2{\mathrm{<figure-callout\; id="2"\; label="r\; w"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">r</figure-callout>}}_w^{}}$

$C_D=\frac{\mathrm{<figure-callout\; id="2"\; label="C"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">C</figure-callout>}}{2\mathrm{\&pi;}[{\left(\mathrm{\&phi;}{C}_{t}h\right)}_1+{\left(\mathrm{\&phi;}{C}_{t}h\right)}_2]{\mathrm{<figure-callout\; id="2"\; label="r\; w"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">r</figure-callout>}}_w^{}}$

4. stored energy ratio

$\mathrm{\&omega;}=\frac{{\left(\mathrm{\&phi;}{C}_{t}h\right)}_1}{{\left(\mathrm{\&phi;}{C}_{t}h\right)}_1+{\left(\mathrm{\&phi;}{C}_{t}h\right)}_2}$

5. interporosity flow coefficient

$\mathrm{\&lambda;}={\mathrm{\&alpha;r}}_w^2\frac{k_1{h}_1}{k_1{\mathrm{<figure-callout\; id="1"\; label="h"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">h</figure-callout>}}_1+k_2{\mathrm{<figure-callout\; id="2"\; label="h"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">h</figure-callout>}}_2}$

6. formation capacity ratio

$\mathrm{\&kappa;}=\frac{k_1{h}_1}{k_1{\mathrm{<figure-callout\; id="1"\; label="h"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">h</figure-callout>}}_1+k_2{\mathrm{<figure-callout\; id="2"\; label="h"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">h</figure-callout>}}_2}$

7. zero dimension radius

$r_D=\frac{r}{r_w}$

Mathematical Modeling

$\left\{\begin{array}{c}\mathrm{\&kappa;}\frac{1}{r_D}\frac{\&PartialD;}{\&PartialD;r_D}\left(r_D\frac{\&PartialD;{\mathrm{<figure-callout\; id="1"\; label="P\; D"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">P</figure-callout>}}_D}{\&PartialD;r_D}\right)-\mathrm{\&lambda;}(P_{D1}-P_{D2})=\mathrm{\&omega;}\frac{\&PartialD;{\mathrm{<figure-callout\; id="1"\; label="P\; D"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">P</figure-callout>}}_D}{\&PartialD;t_D}\\ (1-\mathrm{\&kappa;})\frac{1}{r_D}\frac{\&PartialD;}{\&PartialD;r_D}\left(r_D\frac{\&PartialD;{\mathrm{<figure-callout\; id="2"\; label="P\; D"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">P</figure-callout>}}_D}{\&PartialD;r_D}\right)+\mathrm{\&lambda;}(P_{D1}-P_{D2})=(1-\mathrm{\&omega;})\frac{\&PartialD;{\mathrm{<figure-callout\; id="2"\; label="P\; D"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">P</figure-callout>}}_D}{\&PartialD;t_D}\\ P_{D1}(r_D,0)=P_{D2}(r_D,0)=0\\ C_D\frac{{\mathrm{dP}}_{\mathrm{wD}}}{\mathrm{dt}}-\mathrm{\&kappa;}\frac{\&PartialD;{\mathrm{<figure-callout\; id="1"\; label="P\; D"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">P</figure-callout>}}_D}{\&PartialD;r_D}{|}_{r_D=1}-(1-\mathrm{\&kappa;})\frac{\&PartialD;{\mathrm{<figure-callout\; id="2"\; label="P\; D"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">P</figure-callout>}}_D}{\&PartialD;r_D}{|}_{r_D=1}=1\\ P_{\mathrm{wD}}={[P_{D1}-S_1\left(r_D\frac{{\&PartialD;\mathrm{<figure-callout\; id="1"\; label="P\; D"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">P</figure-callout>}}_D}{\&PartialD;r_D}\right)]}_{r_D=1}{[P_{D2}-S_2\left(r_D\frac{\&PartialD;{\mathrm{<figure-callout\; id="2"\; label="P\; D"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">P</figure-callout>}}_D}{\&PartialD;r_D}\right)]}_{r_D=1}\\ P_{D1}(r_{\mathrm{eD}},t_D)=P_{D2}(r_{\mathrm{eD}},t_D)=0\end{array}\right.$

A3, model solution

Adopt the Douglas-Jones predictor-corrector method can realize the difference of this model is found the solution herein.The result that utilization is found the solution can draw the well testing typical curve (referring to Fig. 3) of common high permeability zone.

Referring to Fig. 4, Fig. 4 is the well testing characteristic feature curve when having strong high infiltration strip in the reservoir.When having strong high infiltration strip in the reservoir, it is considered as horizontal fracture.

Under the infinite reservoir condition of little compressible, the up-and-down boundary sealing of fluid, a continuous point source is positioned at (x _w, y _w, z _w) locate, observation point is positioned at (x, y, z) to be located, and Laplce's Space Solutions of the pressure distribution that point source produces is:

$\stackrel{\&OverBar;}{\mathrm{\&Delta;p}}=\frac{\tilde{q}\mathrm{<figure-callout\; id="2"\; label="u"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">u</figure-callout>}}{2\mathrm{\&pi;kL}{h}_{D}s}[K_0\left(r_D\sqrt{u}\right)+2\underset{n=1}{\overset{\&infin;}{\mathrm{\&Sigma;}}}{K}_0\left(r_D{\mathrm{\&epsiv;}}_n\right)\cos \mathrm{n\&pi;}\frac{z}{h}\cos \mathrm{n\&pi;}\frac{z_w}{h}]$

In the formula

---Laplce's Space Solutions of Pressure difference distribution;

---the output of point source, cm ³/ s;

μ---liquid viscosity, mPas;

K---in-place permeability, μ m ²

L---reference length, cm;

S---Laplce's space variable;

K ₀---the Bessel function of Equations of The Second Kind correction;

H---reservoir thickness, cm;

U---u=sf (s), wherein f (s) is the amount relevant with reservoir properties.When oil reservoir is Homogeneous Reservoir, f (s)=1; When oil reservoir was Double Porosity Reservoir, f (s) was the function of interporosity flow coefficient, elastic storativity ratio and Laplce's space variable.

The definition dimensionless variable is as follows:

$x_D=\frac{x}{L};$ $y_D=\frac{y}{L};$ $h_D=\frac{h}{L}\sqrt{\frac{k}{k_z}};$

${\mathrm{\&epsiv;}}_n=\sqrt{u+{\mathrm{<figure-callout\; id="2"\; label="n"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">n</figure-callout>}}^2{\mathrm{\&pi;}}^2/{\mathrm{<figure-callout\; id="2"\; label="h\; D"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">h</figure-callout>}}_D^{}};$

${\mathrm{<figure-callout\; id="2"\; label="r\; D"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">r</figure-callout>}}_D^{}={(x_D-x_{\mathrm{wD}})}^2+{(y_D-y_{\mathrm{wD}})}^2.$

According to principle of stacking, the continuous point source solution is carried out integration on the strong high infiltration strip plane of rectangle, the pressure-responsive formula that can get the strong high infiltration strip of uniform flux is

$\stackrel{\&OverBar;}{\mathrm{\&Delta;p}}={\&Integral;}_{X-L_f}^{X+L_f}{\&Integral;}_{Y-\frac{b}{2}}^{Y+\frac{b}{2}}\frac{\tilde{q}\mathrm{\&mu;}}{2\mathrm{\&pi;kL}{h}_{D}s}[K_0\left(r_D\sqrt{u}\right)+2\underset{n=1}{\overset{\&infin;}{\mathrm{\&Sigma;}}}{K}_0\left(r_D{\mathrm{\&epsiv;}}_n\right)\cos \mathrm{n\&pi;}\frac{z}{h}\cos \mathrm{n\&pi;}\frac{z_w}{h}]d{y}_w{\mathrm{dx}}_w$

In the formula (X, Y)---the position in the plane, well point of advantage passage well;

L _f---half length of advantage passage, cm;

B---the width of advantage passage, cm.

Definition $\widetilde{L_f}=\frac{L_f}{L},$ $\tilde{b}=\frac{b}{L},$ Then

$\stackrel{\&OverBar;}{\mathrm{\&Delta;p}}=\frac{\tilde{q}\mathrm{\&mu;}}{2\mathrm{\&pi;kL}{h}_{D}s}\left[{\mathrm{<figure-callout\; id="2"\; label="L"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">L</figure-callout>}}^2{\&Integral;}_{X-\widetilde{L_f}}^{X+\widetilde{L_f}}{\&Integral;}_{Y-0.5\tilde{b}}^{Y+0.5\tilde{b}}{K}_0(\sqrt{{(x_D-x_{\mathrm{wD}})}^2+{(y_D-y_{\mathrm{wD}})}^2}\&CenterDot;\sqrt{u}){\mathrm{dy}}_{\mathrm{wD}}{\mathrm{dx}}_{\mathrm{wD}}\right]$

$+\frac{\tilde{q}\mathrm{\&mu;}}{2\mathrm{\&pi;kL}{h}_{D}s}\left[2{\mathrm{<figure-callout\; id="2"\; label="L"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">L</figure-callout>}}^2\underset{n=1}{\overset{\&infin;}{\mathrm{\&Sigma;}}}\cos \mathrm{n\&pi;}\frac{z}{h}\cos \mathrm{n\&pi;}\frac{z_w}{h}{\&Integral;}_{X-\widetilde{L_f}}^{X+\widetilde{L_f}}{\&Integral;}_{Y-0.5\tilde{b}}^{Y+0.5\tilde{b}}{K}_0(\sqrt{{(x_D-x_{\mathrm{wD}})}^2+{(y_D-y_{\mathrm{wD}})}^2}\&CenterDot;{\mathrm{\&epsiv;}}_n)\right]{\mathrm{dy}}_{\mathrm{wD}}{\mathrm{dx}}_{\mathrm{wD}}$

Definition α, β is integration variable, represents respectively the poor of the nondimensional transverse and longitudinal coordinate in certain point source and well point, can obtain:

On the x direction: x _WD-X _D=α

On the y direction: y _WD-Y _D=β

Then:

x _D-x _wD＝x _D-(X _D+α)＝x _D-X _D-α

y _D-y _wD＝y _D-(Y _D+β)＝y _D-Y _D-β

Definition $\widetilde{x_D}=x_D-X_D-\mathrm{\&alpha;},$ $\widetilde{y_D}=y_D-Y_D-\mathrm{\&beta;},$ Then can obtain

$\stackrel{\&OverBar;}{\mathrm{\&Delta;p}}=\frac{\tilde{q}\mathrm{\&mu;<figure-callout\; id="2"\; label="L"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">L</figure-callout>}}{2\mathrm{\&pi;k}{h}_{D}s}[{\&Integral;}_{-\mathrm{Lf}}^{\mathrm{Lf}}{\&Integral;}_{-0.5b}^{0.5b}{K}_0(\sqrt{{\widetilde{x_D}}^2+{\widetilde{y_D}}^2}\&CenterDot;\sqrt{u})\mathrm{d\&alpha;d\&beta;}+2\underset{n=1}{\overset{\&infin;}{\mathrm{\&Sigma;}}}\cos \mathrm{n\&pi;}\frac{z}{h}\cos \mathrm{n\&pi;}\frac{z_w}{h}\&times;$

${\&Integral;}_{-\mathrm{Lf}}^{\mathrm{Lf}}{\&Integral;}_{-0.5b}^{0.5b}{K}_0(\sqrt{{\widetilde{x_D}}^2+{\widetilde{y_D}}^2}\&CenterDot;{\mathrm{\&epsiv;}}_n)\mathrm{d\&alpha;d\&beta;}$

The coordinate of getting the well point is (0,0, z _w), reference length is half length of strong high infiltration strip, utilizes following relational expression that it is carried out zero dimension:

$q=\tilde{q}\&CenterDot;2\mathrm{Lfb}$

$\stackrel{\&OverBar;}{p_D}=\frac{2\mathrm{\&pi;kh}\stackrel{\&OverBar;}{\mathrm{\&Delta;p}}}{\mathrm{q\&mu;}}$

$\stackrel{\&OverBar;}{p_D}=\frac{\mathrm{<figure-callout\; id="2"\; label="h"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">h</figure-callout>}}{2\mathrm{bs}{h}_S}[{\&Integral;}_{-\widetilde{L_f}}^{\widetilde{L_f}}{\&Integral;}_{-0.5\tilde{b}}^{0.5\tilde{b}}{K}_0(\sqrt{{(x_D-\mathrm{\&alpha;})}^2+{(y_D-\mathrm{\&beta;})}^2}\&CenterDot;\sqrt{u})\mathrm{d\&alpha;d\&beta;}+$

$2\underset{n=1}{\overset{\&infin;}{\mathrm{\&Sigma;}}}{\mathrm{<figure-callout\; id="2"\; label="cos"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">cos</figure-callout>}}^2\mathrm{n\&pi;}\frac{z_w}{h}{\&Integral;}_{-L_f}^{L_f}{\&Integral;}_{-0.5b}^{0.5b}{K}_0(\sqrt{{(x_D-\mathrm{\&alpha;})}^2+{(y_D-\mathrm{\&beta;})}^2}\&CenterDot;{\mathrm{\&epsiv;}}_n)\mathrm{d\&alpha;d\&beta;}]$

Definition $L_D=\frac{1}{h_D}=\frac{L_f}{h},$ $e=\frac{b}{L_f},$ Can get

$\stackrel{\&OverBar;}{p_D}=\frac{1}{2\mathrm{se}}[{\&Integral;}_{-1}^1{\&Integral;}_{-0.5e}^{0.5e}{K}_0(\sqrt{{(x_D-\mathrm{\&alpha;})}^2+{(y_D-\mathrm{\&beta;})}^2}\&CenterDot;\sqrt{u})\mathrm{d\&alpha;d\&beta;}+$

$2\underset{n=1}{\overset{\&infin;}{\mathrm{\&Sigma;}}}{\mathrm{<figure-callout\; id="2"\; label="cos"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">cos</figure-callout>}}^2\mathrm{n\&pi;}\frac{z_w}{h}{\&Integral;}_{-1}^1{\&Integral;}_{-0.5e}^{0.5e}{K}_0(\sqrt{{(x_D-\mathrm{\&alpha;})}^2+{(y_D-\mathrm{\&beta;})}^2}\&CenterDot;{\mathrm{\&epsiv;}}_n)\mathrm{d\&alpha;d\&beta;}]$

Then Laplce's Space Solutions of bottom hole pressure difference is:

$\stackrel{\&OverBar;}{p_D}=\frac{1}{2\mathrm{se}}[{\&Integral;}_{-1}^1{\&Integral;}_{-0.5e}^{0.5e}{K}_0(\sqrt{{\mathrm{\&alpha;}}^2+{\mathrm{\&beta;}}^2}\&CenterDot;\sqrt{u})\mathrm{d\&alpha;d\&beta;}+$

$2\underset{n=1}{\overset{\&infin;}{\mathrm{\&Sigma;}}}{\mathrm{<figure-callout\; id="2"\; label="cos"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">cos</figure-callout>}}^2\mathrm{n\&pi;}\frac{z_w}{h}{\&Integral;}_{-1}^1{\&Integral;}_{-0.5e}^{0.5e}{K}_0(\sqrt{{\mathrm{\&alpha;}}^2+{\mathrm{\&beta;}}^2}\&CenterDot;{\mathrm{\&epsiv;}}_n)\mathrm{d\&alpha;d\&beta;}]$

In the formula ${\mathrm{\&epsiv;}}_n-$ ${\mathrm{\&epsiv;}}_n=\sqrt{u+{\mathrm{<figure-callout\; id="2"\; label="n"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">n</figure-callout>}}^2{\mathrm{\&pi;}}^2{\mathrm{<figure-callout\; id="2"\; label="L\; D"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">L</figure-callout>}}_D^{}};$

U---u=sf (s), f in the Homogeneous Reservoir (s)=1, f in the Double Porosity Reservoir (s) is the function of elastic storativity ratio, interporosity flow coefficient.

Further utilize Laplce's flow convolution relation, consider well hole storage coefficient C _DDuring with the affecting of skin factor S, Laplce's Space Solutions of strong high infiltration strip model is:

$\stackrel{\&OverBar;}{p_{\mathrm{wD}}}=\frac{s\stackrel{\&OverBar;}{p_D}+S}{s+C_D{s}^2(s\stackrel{\&OverBar;}{p_D}+S)}$

Employing Stehfest the Method for Numerical Inversion can be with the inverting of Laplce's Space Solutions in real space.Then utilize solving result can draw the well testing typical curve (referring to Fig. 4) of strong high infiltration strip.

Referring to Fig. 5 A and Fig. 5 B, Fig. 5 A is the WELL TEST INTERPRETATION MODEL schematic diagram of macropore, and Fig. 5 B is the well testing characteristic feature curve when having macropore in the reservoir.When having macropore in the reservoir, it flows and is the one dimension non-darcy flow.

This part is the mobile one dimension non-darcy flow that is considered as of fluid in the macropore, set up the Coupled Flow model with flow through oil reservoir, and adopts and resolve the numerical value mixed method this model is found the solution.The model schematic diagram is shown in Fig. 5 A.

A1, assumed condition

1. single-phase, isothermal, little compressible fluid, system compressibility is C, fluid viscosity is μ;

2. Reservoir anisotropy, the horizontal direction permeability is k, the vertical direction permeability is k _z

3. top bottom interface sealing, i.e. z=0, the z=h place is impermeable;

4. external boundary is infinitely great;

5. because the volume of macropore is very little, suppose to be in the macropore non-darcy flow of one dimension;

6. the output q of x=0 place is definite value, and x=L place flow is 0, and fluid only flows in the well by the wall of macropore;

7. different time diverse location place is different by the flow that oil reservoir flows in the well, and the amount by fluid in the oil reservoir inflow macropore in the unit interval unit length is q _h(x, t), then the flow in the position x place macropore is:

$q_d(x,t)={\&Integral;}_x^L{q}_h(x^{\&prime;},t)d{x}^{\&prime;}.$

A2, set up Mathematical Modeling

Zero dimension

1. zero dimension pressure:

$p_D=\frac{\mathrm{kh}(p_i-p)}{1.842\&times;{10}^{-3}\mathrm{q\&mu;}}$

2. non dimensional time:

$t_D=\frac{3.6\mathrm{kt}}{\mathrm{\&phi;\&mu;}{C}_t\&CenterDot;{(L/2)}^2}$

3. dimensionless coordinate:

$x_D=\frac{x}{L/2},$ $y_D=\frac{y}{L/2},$ $z_{\mathrm{wD}}=\frac{z_w}{h},$ $L_D=\frac{L}{2h}\sqrt{\frac{k_v}{k}}$

4. the zero dimension radius of macropore:

$r_{\mathrm{wD}}=\frac{r_{\mathrm{we}}}{h}=\frac{r_w}{2h}[{\left(\frac{k}{k_v}\right)}^{\frac{1}{4}}+{\left(\frac{k_v}{k}\right)}^{\frac{1}{4}}]$

In the formula: r _WeBe the equivalent redius of macropore in anisotropic reservoir;

5. nondimensional mass flow is:

$q_{\mathrm{dD}}=\frac{q_d}{q};$ $q_{\mathrm{hD}}=\frac{q_{h}L}{q}$

6. the zero dimension flow conductivity of macropore is:

$C_{\mathrm{dD}}=\frac{k_f{\mathrm{\&pi;<figure-callout\; id="2"\; label="r\; w"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">r</figure-callout>}}_w^{}}{\mathrm{kh}(L/2)}$

7. the nondimensional mass flow constant is:

${\left(q_{\mathrm{DND}}\right)}_d=\frac{{10}^{-3}}{86400}\&CenterDot;\frac{k_f\mathrm{\&rho;\&beta;q}}{\mathrm{\&pi;}{\mathrm{<figure-callout\; id="2"\; label="r\; w"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">r</figure-callout>}}_w^{}\mathrm{\&mu;}}$

Mathematical Modeling

1. the non-Darcy flow model in the macropore

$p_{\mathrm{wD}}-p_{\mathrm{dDj}}=\frac{2\mathrm{\&pi;}}{C_{\mathrm{dD}}}{\&Integral;}_0^{x_{\mathrm{Dj}}}{q}_{\mathrm{dD}}{\mathrm{dx}}_D^{\&prime;}+\frac{2\mathrm{\&pi;}}{C_{\mathrm{dD}}}{\left(q_{\mathrm{DND}}\right)}_d{\&Integral;}_0^{x_{\mathrm{<figure-callout\; id="2"\; label="Dj\; q\; dD"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">Dj</figure-callout>}}}{q}_{\mathrm{dD}}^{}{}_2^{}{\mathrm{dx}}_D^{\&prime;}$

Following formula is carried out difference discrete:

${\&Integral;}_0^{x_{\mathrm{Dj}}}{q}_{\mathrm{dD}}{\mathrm{dx}}_D^{\&prime;}=\underset{i=1}{\overset{j-1}{\mathrm{\&Sigma;}}}(\frac{\mathrm{\&Delta;x}}{2}{q}_{\mathrm{dDi}}+\frac{\mathrm{\&Delta;x}}{2}{q}_{\mathrm{dDi}+1})+\frac{3}{8}\mathrm{\&Delta;x}\&CenterDot;q_{\mathrm{dDj}}+\frac{1}{8}\mathrm{\&Delta;x}\&CenterDot;{\mathrm{<figure-callout\; id="1"\; label="q\; dDj\; +"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">q</figure-callout>}}_{\mathrm{dDj}+}$

${\&Integral;}_0^{x_{\mathrm{<figure-callout\; id="2"\; label="Dj\; q\; dD"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">Dj</figure-callout>}}}{q}_{\mathrm{dD}}^{}{}_2^{}{\mathrm{dx}}_D^{\&prime;}=\underset{i=1}{\overset{j-1}{\mathrm{\&Sigma;}}}(\frac{\mathrm{\&Delta;x}}{3}{\mathrm{<figure-callout\; id="2"\; label="q\; dDi"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">q</figure-callout>}}_{\mathrm{dDi}}^{}+\frac{\mathrm{\&Delta;x}}{3}{q}_{\mathrm{dDi}}{q}_{\mathrm{dDi}+1}+\frac{\mathrm{\&Delta;x}}{3}{q}_{\mathrm{dDi}+1}^2)+\frac{7}{24}\mathrm{\&Delta;<figure-callout\; id="2"\; label="x\; q\; dDj"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">x</figure-callout>}{q}_{\mathrm{dDj}}^{}{}_2^{}+\frac{1}{6}\mathrm{\&Delta;x}{q}_{\mathrm{dDj}}{\&CenterDot;q}_{\mathrm{dDj}+1}+\frac{1}{24}{\mathrm{\&Delta;xq}}_{\mathrm{dDj}+1}^2$

2. reservoir model

$p_{\mathrm{dD}}(x_{\mathrm{Dj}},r_{\mathrm{wD}},t_D)=\widehat{p_{\mathrm{dD}}}(x_{\mathrm{Dj}},r_{\mathrm{wD}},t_{\mathrm{DN}})+\underset{i=1}{\overset{M}{\mathrm{\&Sigma;}}}\frac{2(q_{\mathrm{dDi}}-q_{\mathrm{dDi}+1})}{\mathrm{\&Delta;x}}{\&Integral;}_0^{t_{\mathrm{DN}}-t_{\mathrm{DN}-1}}{S}_i(x_{\mathrm{Dj}},t_D^{\&prime;})d{t}_D^{\&prime;}$

In the formula:

$\widehat{p_{\mathrm{dD}}}(x_{\mathrm{Dj}},r_{\mathrm{wD}},t_{\mathrm{DN}})=\underset{k=1}{\overset{N-1}{\mathrm{\&Sigma;}}}\underset{i=1}{\overset{M}{\mathrm{\&Sigma;}}}{q}_{\mathrm{hDi}}\left(t_{\mathrm{Dk}}\right)[{\&Integral;}_0^{t_{\mathrm{DN}}-t_{\mathrm{Dn}-1}}{S}_i(x_{\mathrm{Dj}},t_D^{\&prime;}){\mathrm{dt}}_D^{\&prime;}-{\&Integral;}_0^{t_{\mathrm{DN}}-t_{\mathrm{Dn}}}{S}_i(x_{\mathrm{Dj}},t_D^{\&prime;})d{t}_D^{\&prime;}]$

$S_i(x_D,\mathrm{\&tau;})=\frac{\sqrt{\mathrm{\&pi;}}}{4}[\mathrm{erf}\left(\frac{x_D-\frac{2i-2}{\mathrm{<figure-callout\; id="2"\; label="M"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">M</figure-callout>}}}{2\sqrt{\mathrm{\&tau;}}}\right)-\mathrm{erf}\left(\frac{x_D-\frac{2i}{M}}{2\sqrt{\mathrm{\&tau;}}}\right)]$

$\{1+2\underset{n=1}{\overset{\&infin;}{\mathrm{\&Sigma;}}}\exp [-{\mathrm{<figure-callout\; id="2"\; label="n"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">n</figure-callout>}}^2{\mathrm{\&pi;}}^2{\mathrm{<figure-callout\; id="2"\; label="L\; D"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">L</figure-callout>}}_D^{}\mathrm{\&tau;}\left]\cos \right[\mathrm{n\&pi;}(z_{\mathrm{wD}}+r_{\mathrm{wD}})\left]\cos \left({\mathrm{n\&pi;z}}_{\mathrm{wD}}\right)\right\}$

A3, model solution

The darcy flow model of the non-darcy flow model in the macropore and oil reservoir is coupled, can gets:

$p_{\mathrm{wD}}-\widehat{p_{\mathrm{dD}}}(x_{\mathrm{Dj}},r_{\mathrm{wD}},t_{\mathrm{DN}})-\underset{i=1}{\overset{M}{\mathrm{\&Sigma;}}}\frac{2(q_{\mathrm{dDi}}-q_{\mathrm{dDi}+1})}{\mathrm{\&Delta;x}}{\&Integral;}_0^{t_{\mathrm{DN}}-t_{\mathrm{DN}-1}}{S}_i(x_{\mathrm{Dj}},t_D^{\&prime;}){\mathrm{dt}}_D^{\&prime;}$

$=\frac{2\mathrm{\&pi;}}{C_{\mathrm{dD}}}[\underset{i=1}{\overset{j-1}{\mathrm{\&Sigma;}}}(\frac{\mathrm{\&Delta;x}}{2}{q}_{\mathrm{dDi}}+\frac{\mathrm{\&Delta;x}}{2}{q}_{\mathrm{dDi}+1})+\frac{3}{8}\mathrm{\&Delta;x}\&CenterDot;q_{\mathrm{dDj}}+\frac{1}{8}\mathrm{\&Delta;x}\&CenterDot;q_{\mathrm{dDj}+1}]+$

$\frac{2\mathrm{\&pi;}}{C_{\mathrm{dD}}}{\left(q_{\mathrm{DND}}\right)}_d\left[\begin{array}{c}\underset{i=1}{\overset{j-1}{\mathrm{\&Sigma;}}}(\frac{\mathrm{\&Delta;x}}{3}{\mathrm{<figure-callout\; id="2"\; label="q\; dDi"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">q</figure-callout>}}_{\mathrm{dDi}}^{}+\frac{\mathrm{\&Delta;x}}{3}{q}_{\mathrm{dDi}}{q}_{\mathrm{dDi}+1}+\frac{\mathrm{\&Delta;x}}{3}{q}_{\mathrm{dDi}+1}^2)\\ +\frac{7}{24}\mathrm{\&Delta;<figure-callout\; id="2"\; label="x\; q\; dDj"\; filenames="HDA0000085061060000041.png"\; state="\{\{state\}\}">x</figure-callout>}{q}_{\mathrm{dDj}}^{}{}_2^{}+\frac{1}{6}\mathrm{\&Delta;x}{q}_{\mathrm{dDj}}\&CenterDot;q_{\mathrm{dDj}+1}+\frac{1}{24}\mathrm{\&Delta;x}{q}_{\mathrm{dDj}+1}^2\end{array}\right]$

Macropore is divided into the M section, q is then arranged _DDi(i=1,2 ..., M+1).Therefore have M+2 unknown number: p altogether in the following formula _WD, q _DDi(i=1,2 ..., M+1).

The formula following formula of utilization can be listed as M equation, adds two fringe conditionss:

q _dD(1)＝q，q _dD(M)＝0

Therefore following formula can be found the solution.But it is nonlinear equation, therefore adopts the Newton-Raphson alternative manner to find the solution.Utilize solving result can draw the well testing typical curve of macropore (referring to Fig. 5 B).

Referring to Fig. 6, Fig. 6 is water controlled field advantage passage identification device block diagram of the present invention.Water controlled field advantage passage identification device of the present invention is used transient pressure recovery well test data formed advantage passage in the water controlled field development process is identified, and comprising:

Characteristic feature curve plate module 1 is set: the well testing characteristic feature curve plate that is used for setting and storage advantage channel recognition;

Bottom hole pressure measurement module 2: comprise pressure gauge and pressure record unit, described pressure gauge is used for the test well testing and is conveyed into described pressure record unit with the bottom pressure of testing time recovery and with the described bottom pressure that test obtains;

Bottom pressure derivative calculations module 3: be used for calculating described bottom pressure to the first derivative of time natural logrithm as the bottom pressure derivative and store this bottom pressure derivative;

Draw well testing relation curve module 5: be used for drawing described bottom pressure or the time dependent actual measurement well testing of described bottom pressure derivative relation curve in log-log coordinate system;

Judge module 6: be used for the described well testing characteristic feature curve of described actual measurement well testing relation curve and advantage channel recognition is carried out form relatively, judge whether the advantage passage exists and determine its growth rank.

Also can comprise:

Data smoothing processing module 4: be used for described bottom pressure or described bottom pressure derivative and the relation of time carry out data smoothing process after the described drafting of input survey well testing relation curve module.

Above-mentioned modules can be arranged in the computer, by the control of setting computer to each module, can realize automatically detecting and judging.Can utilize simultaneously the demonstration output module of computer and show output equipment (such as display screen, printer etc.), with detection and judgment result displays or output.Also drawn characteristic feature curve plate can be stored in advance in the store-memory module of computer, directly execution in step b～step e.The circulation of this step in computer carried out and judged whether the advantage passage exists and determine that its other idiographic flow of growth level all can adopt ripe prior art, and therefore not to repeat here.

The below take concrete three test results as example Benq in the practical situations of the advantage channel recognition method of transient well test.

Embodiment one

Selected well testing oilfield reservoir physical property is good, is high hole middle and high infiltration reservoir, the rock loose cementation, and chink content is less.Through exploitation for many years, entered at present high water-cut stage, the advantage passage is grown seriously in the block, causes the oil-well drainage remaining oil saturation high, and the well draining is flooded seriously, and vertically intake profile is widely different, and the waterline tempo of penetration is very fast.The existence of advantage passage has caused the further raising of this oil recovery rate and has seriously influenced.

The below illustrates the practical situations based on the advantage channel recognition method of transient well test as an example of this oil field A well example.In advance this oil field A well has been carried out respectively twice transient well test test, this twice testing time was separated by more than 1 year.Twice test process all carries out according to " SY/T6172-2006 People's Republic of China (PRC) oil and gas industry standard---oil well Well Test Technology standard ", and the flowing bottomhole pressure (FBHP) in the record test process, the calculating pressure derivative is drawn flowing bottomhole pressure (FBHP) and the time dependent test curve of pressure derivative thereof of actual measurement under log-log coordinate system.The test curve that twice test result in front and back drawn is respectively such as accompanying drawing 7, shown in Figure 8.

This oil field A well is tested for the first time the well testing characteristic feature curve of resulting flowing bottomhole pressure (FBHP) and the time dependent curve of pressure derivative (seeing accompanying drawing 7) and different stage advantage passage provided by the invention and (seen accompanying drawing 2, accompanying drawing 3, accompanying drawing 4 and accompanying drawing 5A) compare, can find in the accompanying drawing 7 that the trend of characteristic feature curve is in full accord in the test curve and Fig. 3, and differ greatly with other characteristic feature curve, therefore can judge the A well and when testing for the first time, have the advantage passage on every side, but the growth rank of advantage passage is lower, can be classified as common high permeability zone.

According to same step, flowing bottomhole pressure (FBHP) and the time dependent curve of pressure derivative (seeing accompanying drawing 8) thereof that the A well records are for the second time analyzed.The trend of characteristic feature curve is in full accord among test curve in the discovery accompanying drawing 8 and Fig. 4, and differ greatly with other characteristic feature curve, therefore can judge the A well and when testing for the second time, still have the advantage passage on every side, and the raising of the growth rank of advantage passage, can be classified as strong high infiltration strip.

This well has all carried out the Interwell tracer monitoring after twice transient well test test.The tracer monitoring explanation results is also in full accord with the explanation results of transient well test method.

Embodiment two

Take test oil field B well as the practical situations of example explanation based on the advantage channel recognition method of transient well test.The well testing characteristic feature curve (seeing accompanying drawing 2, accompanying drawing 3, accompanying drawing 4 and accompanying drawing 5A) that the B well surveying is tried resulting flowing bottomhole pressure (FBHP) and the time dependent curve of pressure derivative (seeing accompanying drawing 9) and different stage advantage passage provided by the invention compares, the trend that can find characteristic feature curve among test curve in the accompanying drawing 9 and Fig. 5 is in full accord, and differ greatly with other characteristic feature curve, therefore can judge the B well and when test, have the very high advantage passage of growth rank on every side, can be classified as macropore.

The explanation results of this well and the understanding of Oil Field are in full accord, and after this well is carried out transient well test, well corresponding to this well are injected gel particle carry out profile control.There is macropore in well when blocking agent is injected around dynamically showing the B well, conforms to the recognition result of transient well test method.

The present invention is by carrying out pressure buildup test to oil well, and the data that bottom pressure recovers in time in the record test process is calculated the bottom pressure derivative; In log-log coordinate system, draw the zero dimension bottom pressure of actual measurement and the relation curve that derivative changes with non dimensional time thereof; The well testing typical curve of the different stage advantage passage that provides among measured curve and the present invention is compared, can detect and judge whether exist around this well the advantage passage with and grow rank, the method has accuracy height, the characteristics such as workable, and the enforcement that can be the oilfield stimulation measure provides guidance.

Certainly; the present invention also can have other various embodiments; in the situation that does not deviate from spirit of the present invention and essence thereof; those of ordinary skill in the art work as can make according to the present invention various corresponding changes and distortion, but these corresponding changes and distortion all should belong to the protection domain of the appended claim of the present invention.

Claims (10)

1. a water controlled field advantage channel recognition method is characterized in that, uses transient pressure recovery well test data formed advantage passage in the water controlled field development process is identified, and comprises the steps:

A, well testing characteristic feature curve plate step is set: the well testing characteristic feature curve plate that the advantage channel recognition is set;

B, well testing bottom hole pressure measurement step: pressure gauge is lowered to well testing test purpose layer middle part, surface shut-in, the data of utilizing pressure gauge record bottom pressure to recover with the testing time;

C, well testing bottom pressure derivative calculations step: the bottom pressure that calculates described well testing to the first derivative of time natural logrithm as the bottom pressure derivative;

D, actual measurement well testing relation curve plot step: take the testing time as abscissa, take flowing bottomhole pressure (FBHP) and pressure derivative as ordinate, in log-log coordinate system, draw described bottom pressure or the time dependent actual measurement well testing of described bottom pressure derivative relation curve;

E, the existence of judging the advantage passage and growth rank step thereof: the described well testing characteristic feature curve of described actual measurement well testing relation curve and advantage channel recognition is carried out form relatively, judge whether the advantage passage exists and determine its growth rank.

2. water controlled field advantage channel recognition method as claimed in claim 1 is characterized in that, before described drafting actual measurement well testing relation curve step, also comprises:

D0, data smoothing treatment step: described bottom pressure or described bottom pressure derivative and the relation of time are carried out data smoothing process to reduce noise.

3. water controlled field advantage channel recognition method as claimed in claim 2, it is characterized in that described data smoothing treatment step adopts Wavelet Transform, linear interpolation exponential smoothing or Fourier transform that described bottom pressure or described bottom pressure derivative are carried out the data smoothing processing.

4. such as claim 1,2 or 3 described water controlled field advantage channel recognition methods, it is characterized in that described actual measurement well testing relation curve is the double-log relation curve of zero dimension bottom pressure and non dimensional time or the double-log relation curve of zero dimension bottom pressure derivative and non dimensional time.

5. such as claim 1,2 or 3 described water controlled field advantage channel recognition methods, it is characterized in that the described well testing characteristic feature curve plate step that arranges comprises and normal reservoir well test curve plate is set and advantage passage well testing characteristic feature curve plate is set.

6. water controlled field advantage channel recognition method as claimed in claim 5 is characterized in that, described normal reservoir well test curve plate is the transient seepage flow model curve plate of center, the infinitely great stratum of homogeneous a bite well.

7. water controlled field advantage channel recognition method as claimed in claim 5 is characterized in that, the described advantage passage well testing characteristic feature curve plate that arranges comprises:

A1, set up model condition is set: according to the origin cause of formation of advantage passage and grow rank and set up the assumed condition that model arranges;

A2, set up Mathematical Modeling: according to the origin cause of formation of described advantage passage and grow other assumed condition of level and set up respectively corresponding Mathematical Modeling;

A3, model solution and characteristic feature Drawing of Curve: respectively described Mathematical Modeling is found the solution and drawn corresponding advantage passage well testing characteristic feature curve plate according to solving result.

8. water controlled field advantage channel recognition method as claimed in claim 7, it is characterized in that described advantage passage well testing characteristic feature curve plate is according to the origin cause of formation of advantage passage and grow rank and grow from weak to strong and comprise common high permeability zone indicatrix plate, strong high infiltration strip indicatrix plate and macropore indicatrix plate.

9. a water controlled field advantage passage identification device is characterized in that, uses transient pressure recovery well test data formed advantage passage in the water controlled field development process is identified, and comprising:

Characteristic feature curve plate module is set: the well testing characteristic feature curve plate that is used for setting and storage advantage channel recognition;

The bottom hole pressure measurement module: comprise pressure gauge and pressure record unit, described pressure gauge is used for the test well testing and is conveyed into described pressure record unit with the bottom pressure of testing time recovery and with the described bottom pressure that test obtains;

Bottom pressure derivative calculations module: be used for calculating described bottom pressure to the first derivative of time natural logrithm as the bottom pressure derivative and store this bottom pressure derivative;

Draw well testing relation curve module: be used for drawing described bottom pressure or the time dependent actual measurement well testing of described bottom pressure derivative relation curve in log-log coordinate system;

Judge module: be used for the described well testing characteristic feature curve of described actual measurement well testing relation curve and advantage channel recognition is carried out form relatively, judge whether the advantage passage exists and determine its growth rank.

10. water controlled field advantage passage identification device as claimed in claim 9 is characterized in that, also comprises:

The data smoothing processing module: be used for described bottom pressure or described bottom pressure derivative and the relation of time carry out data smoothing process after the described drafting of input survey well testing relation curve module.

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