CN103628850B - A kind of waterflooding oil field integral profile control water blockoff decision-making technique - Google Patents

Abstract

The invention provides a kind of waterflooding oil field integral profile control water blockoff decision-making technique, belong to reservoir engineering field.Described method utilizes oil reservoir basic parameter, oil reservoir development data and oil reservoir creation data to obtain six parameters, and these six parameters are respectively plane heterogeneity decision-making coefficient A, plain heterogeneity property coefficient extreme difference R _a, longitudinal permeability coefficient of variation V _k, longitudinal permeability coefficient of variation R _v, intake profile decision-making coefficient SP and intake profile decision-making coefficient extreme difference R _sP, then utilize these six parameters to realize the decision-making of waterflooding oil field integral profile control water blockoff according to criterion.The inventive method is mainly for the oil field lacking correlation technique data, especially overseas oil field and offshore oilfield are owing to being subject to the restriction of Exploitation policy and engineering characteristic, the situation that some data can not be collected completely, the inventive method can carry out decision-making by basic data and parameter.

Description

A kind of waterflooding oil field integral profile control water blockoff decision-making technique

Technical field

The invention belongs to reservoir engineering field, be specifically related to a kind of waterflooding oil field integral profile control water blockoff decision-making technique.

Background technology

Complicated type oil field is in waterflooding extraction process, due to the non-homogeneity of oil reservoir, along with deepening continuously of waterflooding extraction, inject water to advance by leaps and bounds along high permeability zone, cause oil reservoir interlayer contradiction, horizontal contradiction aggravates gradually, development effectiveness is deteriorated, oil reservoir rate of water cut increase is accelerated, water drive mining-employed reserves and waterflooding result reduce, and waterflood recovery efficiency factor reduces, and has had a strong impact on the whole economic efficiency in oil field.Therefore implementing Profile Control in Injection Well and oilwell water shutoff at high water-cut stage is the main path improving flood effectiveness.For controlling the speed that oil reservoir comprehensive water cut rises, block integral must be carried out and adjust stifled improvement.Block integral is adjusted to block up and can be improved oil reservoir whole development effect; Scattered tune can be eliminated block up caused oil-water well contradiction and transform, improve oil well and to take effect rate.At present, propose two kinds of block integrals and adjust stifled decision-making technic, a kind of is the RE decision-making technic of carrying out decision-making on Reservoir Description basis by optimal method; Another kind is carrying out decision-making by the wellhead of water injection well drop of pressure curve calculating water injection well pressure index of gained and the basis of other test data, and this technology is called PI decision-making technic.

But RE decision-making technic is based upon on static data basis, only reflection oil reservoir quiescent conditions, PI decision-making technic is based upon on dynamic data basis, only reflection Production development situation, and only more applicable to profile control well.

Summary of the invention

The object of the invention is to solve the difficult problem existed in above-mentioned prior art, a kind of waterflooding oil field integral profile control water blockoff decision-making technique is provided---(AVS is that the present invention innovates to AVS decision-making technique, AVS is three parameters, judge with three major parameters, Aclinicheterogeneousindex (A), LongitudinalheterogeneousVariationcoefficientofpermeabil ity (VK) andprofileofwatersopupindex (SP)), for the oil field lacking correlation technique data, especially overseas oil field and offshore oilfield are owing to being subject to the restriction of Exploitation policy and engineering characteristic, some data can not be collected completely, utilize the inventive method can carry out decision-making by basic data and dynamic parameter.The inventive method Integrated Static and dynamic two kinds of factors, the profile control decision-making that can either be used for water injection well also can be used in oilwell water shutoff.

The present invention is achieved by the following technical solutions:

A kind of waterflooding oil field integral profile control water blockoff decision-making technique, utilize oil reservoir basic parameter, oil reservoir development data and oil reservoir creation data to obtain six parameters, these six parameters are respectively plane heterogeneity decision-making coefficient A, plain heterogeneity property coefficient extreme difference R _a, longitudinal permeability coefficient of variation V _k, longitudinal permeability coefficient of variation R _v, intake profile decision-making coefficient SP and intake profile decision-making coefficient extreme difference R _sP, then utilize these six parameters to realize the decision-making of waterflooding oil field integral profile control water blockoff according to criterion.

Described oil reservoir basic parameter comprises: the mean permeability k of all wells, substratum permeability K _σ, degree of porosity Φ, rock compressibility C, formation thickness h and fluid viscosity μ;

Described oil reservoir development data comprise: theoretical injection-production ratio B _ideal, water injection well Control Radius r _e, perforation thickness h _penetrate, actual injection-production ratio B _real, segment the little number of plies and perforation number of plies n _penetrate;

Described oil reservoir creation data comprises: injectivity index Iw and water suction number of plies n _inhale.

Described plane heterogeneity decision-making coefficient A obtains like this:

$A=\frac{\mathrm{WI}}{\frac{\mathrm{\μ}}{15K}\ln \frac{12.5{r_e}^2\mathrm{\Φ\μC}}{\mathrm{Kt}}}---\left(4\right),$

Wherein k is substratum permeability K _σ, t is the time;

Described plain heterogeneity property coefficient extreme difference R _aobtain like this: for whole block, calculate the plain heterogeneity coefficient Ai of every mouthful of well, obtain plane heterogeneity coefficient matrix: [A ₁a ₂... A _i... A _n], then

$R_{\mathrm{Ai}}=|\mathrm{Ai}-\frac{\underset{i=1}{\overset{n}{\mathrm{\Σ}}}\mathrm{Ai}}{n}|---\left(5\right)$

Described longitudinal permeability coefficient of variation V _kobtain like this:

$V_K=\frac{k-K_{\mathrm{\σ}}}{k}---\left(6\right),$

Described longitudinal permeability coefficient of variation R _vobtain like this:

$R_V=|V_{\mathrm{ki}}-\frac{\underset{i=1}{\overset{n}{\mathrm{\Σ}}}{V}_{\mathrm{ki}}}{n}|---\left(7\right);$

Described calculating intake profile decision-making coefficient SP obtains like this:

ΔB＝B _ideal-B _real(9)，

(8) h in formula _inhalerefer to water accepting layer thickness;

Described intake profile decision-making coefficient extreme difference (R _sP) obtain like this:

$R_{\mathrm{SP}}=|{\mathrm{SP}}_i-\frac{\underset{i=1}{\overset{n}{\mathrm{\Σ}}}S{P}_i}{n}|---\left(10\right).$

Described criterion comprises block and adjusts stifled discrimination standard, adjusts criterion and the block influence factor criterion of stifled well choice criteria, oil-water well connected relation.

Described block adjusts stifled discrimination standard as follows:

For Low-mid permeability pools, if A > 0.04, then need to adjust and block up, for high permeable cement, if A > 10, then need to adjust and block up;

For Low-mid permeability pools, if R _a> 0.05, then need to adjust and block up, for high permeable cement, if R _a> 20, then need to adjust and block up;

If V _k> 0.3, then need to adjust and block up;

If R _v> 0.5, then need to adjust and block up;

If SP > 60, then high strength profile control;

If 20 < SP < 60, then appropriateness is adjusted stifled;

If during SP < 20, then do not need profile control.

It is as follows that described tune blocks up well choice criteria:

For Low-mid permeability pools, if A > 0.05, then need to adjust and block up;

For high permeable cement, if A > 3 or then need to adjust and block up; refer to the average of A;

If V _k> 0.6 or then need to adjust and block up;

If SP > 20 or then need to adjust and block up.

The criterion of described oil-water well connected relation is as follows:

By the A value sequence of corresponding for well all oil wells, the direction that A is larger and water injection well inject the main flow direction of water; By the A value sequence of corresponding for oil well all wells, the main watering of the well direction that A value is larger and sewage from oil-well, obtains this profit connected relation like this, is used for judging crossfire direction;

Described block influence factor criterion is as follows:

By each well or corresponding plane heterogeneity decision-making coefficient A, the longitudinal permeability coefficient of variation V of oil well _khousing in row A is listed in intake profile decision-making coefficient SP _ijin, determine by normalized range analysis method the factor sequence affecting each well, finally determine the Main way of profile control and water plugging:

$A_{\mathrm{ij}}=\left[\begin{array}{cccc}{A}_1& A_2& ......& A_n\\ V_1& V_2& ......& V_n\\ S{P}_1& {\mathrm{SP}}_2& ......& {\mathrm{SP}}_n\end{array}\right]---\left(11\right)$

Use X _ijfor matrix A _ijthe average of horizontal j the index of i, make B _ij=| A _ij-X _ij|, then

$B_{\mathrm{ij}}=\left[\begin{array}{cccc}{B}_{11}& B_{12}& ......& B_{1n}\\ B_{21}& B_{22}& ......& B_{2n}\\ B_{31}& B_{32}& ......& B_{3n}\end{array}\right]---\left(12\right)$

Use Y _ijfor matrix B _ijj erect row i index average, use Π _ijrepresent matrix B _ijaverage, use X _irepresent extreme difference, then X _i=| Π _ij-Y _ij|, then

X _i＝[X ₁X ₂......X _n](13)

Use X _i ^*what represent after normalization is differential, then

$X_i^{*}=\frac{\mathrm{Xi}}{\underset{i=1}{\overset{n}{\mathrm{\&Sigma;}}}{X}_i};$ $X_i^{*}=\left[\begin{array}{cccc}{X}_1^{*}& X_2^{*}& ......& X_n^{*}\end{array}\right]---\left(14\right)$

By comparing X _i ^*size can find out that each well is to block effect;

Use C _ijfor matrix B _iji j erect the average of row index, use Π _ijrepresent matrix B _ijaverage, use ζ _irepresent extreme difference, then ζ _i=| Π _ij-C _ij|, then

ζ _i＝[ζ ₁ζ ₂ζ ₃](15)

Use ζ _i ^*what represent after normalization is differential, then

${\mathrm{\&zeta;}}_i^{*}=\frac{{\mathrm{\&zeta;}}_i}{\underset{i=1}{\overset{3}{\mathrm{\&Sigma;}}}{\mathrm{\&zeta;}}_i};$ ${\mathrm{\&zeta;}}_i^{*}=\left[\begin{array}{ccc}{\mathrm{\&zeta;}}_1& {\mathrm{\&zeta;}}_2& {\mathrm{\&zeta;}}_3\end{array}\right]---\left(16\right)$

By comparing ζ _i ^*size can determine factor that whole block is had the greatest impact.

Compared with prior art, the invention has the beneficial effects as follows: the inventive method utilizes plane heterogeneity decision-making coefficient (A) and extreme difference, the longitudinal permeability coefficient of variation (Vk) and extreme difference thereof and intake profile decision-making coefficient (SP) and extreme difference six discriminant parameters thereof to solve following problem:

(1) selection of stifled well location is adjusted;

(2) connected relation of oil-water well is determined;

(3) the whole block factor degree of impact is judged;

(4) each well is to the influence degree of overall block;

The present invention can apply in the decision-making of high water-cut reservoir profile control and water plugging, especially for the oil field lacking correlation technique data, if overseas oil field and offshore oilfield are owing to being subject to the restriction of Exploitation policy and engineering characteristic, some data can not be collected completely, and this technology can carry out decision-making by basic data and parameter.

Accompanying drawing explanation

Fig. 1 is the step block diagram of waterflooding oil field integral profile control water blockoff decision-making technique of the present invention.

Fig. 2 is the selection figure of the dimension constitution layer decision part in the embodiment of the present invention.

Fig. 3 is the W layer substratum distribution map in the embodiment of the present invention.

Fig. 4 is the Production development curve map of 331 wells in the embodiment of the present invention.

Fig. 5 is the Production development curve map of the 3U well in the embodiment of the present invention.

Fig. 6 is the Production development curve map of 330 wells in the embodiment of the present invention.

Fig. 7 is the Production development curve map of 334 wells in the embodiment of the present invention.

Fig. 8 is the production profile situation map of 331 wells in the embodiment of the present invention.

Fig. 9 is the production profile situation map of 334 wells in the embodiment of the present invention.

Detailed description of the invention

Below in conjunction with accompanying drawing, the present invention is described in further detail:

The inventive method comprises the following steps as shown in Figure 1:

1) Calculation Plane non-homogeneity decision-making coefficient (A):

This parameter is used for evaluating block plane heterogeneity to the adaptedness of profile control and water plugging measure.

From PI decision-making technic, $\mathrm{PI}-P_m=\frac{\mathrm{q\&mu;}}{15\mathrm{Kh}}\ln \frac{12.5{r_e}^2\mathrm{\&Phi;\&mu;C}}{\mathrm{Kt}}---\left(1\right);$

With by PI-P _mcarry out the pressure index change being converted into unit subterranean formation production,

$\frac{\mathrm{PI}-P_m}{\frac{q}{h}}=\frac{\mathrm{\&mu;}}{15K}\ln \frac{12.5\mathrm{re}2\mathrm{\&Phi;\&mu;C}}{\mathrm{Kt}}---\left(2\right);$

Order $A=\frac{\mathrm{WI}}{\frac{\left({\mathrm{PI}-P}_m\right)h}{q}}$ (3); Wherein $\mathrm{WI}=\frac{1}{I_w};$

(2) are substituted into (3) obtain $A=\frac{\mathrm{WI}}{\frac{\mathrm{\&mu;}}{15K}\ln \frac{12.5{r_e}^2\mathrm{\&Phi;\&mu;C}}{\mathrm{Kt}}}---\left(4\right).$

Wherein WI is the pressure reduction of water injection well unit water injection rate, and unit is MPa/ (m ³/ d.m); Iw is injectivity index, and unit is (m ³/ d.m)/MPa; PI is pressure index, and unit is MPa; Pm is stratum injection threshold pressure (well head), and unit is MPa; Q is water injection well daily water-injection rate, and unit is m ³/ d; μ is fluid viscosity, and unit is mPa.S; K is in-place permeability, and unit is μm ²; H is formation thickness (h has reduced in formula (2), but in order to state all alphabetical implications, still lists herein), and unit is m; r _efor water injection well Control Radius, unit is m; Φ is degree of porosity, and unit is %; C is rock compressibility, and unit is Pa ^-1; K is in-place permeability, i.e. substratum permeability K _σ, t is the time.

Plain heterogeneity property coefficient extreme difference (R _a): for whole block, calculate the plain heterogeneity coefficient Ai (being exactly this coefficient calculating every mouthful of well by (4) formula) of every mouthful of well, obtain plane heterogeneity coefficient matrix: [A ₁a ₂... A _i... A _n], then

$R_{\mathrm{Ai}}=|\mathrm{Ai}-\frac{\underset{i=1}{\overset{n}{\mathrm{\&Sigma;}}}\mathrm{Ai}}{n}|---\left(5\right)$

2) the longitudinal permeability coefficient of variation (V is calculated _k): this parameter is used for evaluating the vertical heterogeneity of oil reservoir.

$V_K=\frac{k-K_{\mathrm{\&sigma;}}}{k}---\left(6\right);$

Wherein k is the mean permeability of all wells, and unit is μm ²; K _σfor the in-place permeability (just referring to the substratum permeability in Fig. 1) of a certain well.

The longitudinal permeability coefficient of variation (R _v):

$R_V=|V_{\mathrm{ki}}-\frac{\underset{i=1}{\overset{n}{\mathrm{\&Sigma;}}}{V}_{\mathrm{ki}}}{n}|---\left(7\right)$

3) intake profile decision-making coefficient (SP) is calculated

Intake profile data reflects the non-homogeneity of reservoir to a certain extent, and it is that coefficient of permeability variation is in one performance macroscopically.

ΔB＝B _ideal-B _real(9)；

Wherein, B _idealfor theoretical injection-production ratio (being the injection-production ratio in development plan); B _realfor actual injection-production ratio; h _inhalefor water sucting thickness, unit is m; n _inhalefor the water suction number of plies, unit is individual; h _penetratefor perforation thickness, unit is m; n _penetratefor the perforation number of plies, unit is individual.

Intake profile decision-making coefficient extreme difference (R _sP):

$R_{\mathrm{SP}}=|{\mathrm{SP}}_i-\frac{\underset{i=1}{\overset{n}{\mathrm{\&Sigma;}}}{\mathrm{SP}}_i}{n}|---\left(10\right)$

4) block adjusts stifled discrimination standard as shown in table 1:

Table 1

5) adjust stifled well choice criteria as shown in table 2:

Table 2

6) judgement of oil-water well connected relation

By the A value sequence of corresponding for well all oil wells (" correspondence " refers to have connective well), the direction that A is larger and water injection well inject the main flow direction of water; By the A value sequence of corresponding for oil well all wells, the main watering of the well direction that A value is larger and sewage from oil-well, obtains this connected relation and is used for judging crossfire direction.

7) block influence factor judges

By each well or corresponding plane heterogeneity decision-making coefficient (A), the longitudinal permeability coefficient of variation (V of oil well _k) and intake profile decision-making coefficient (SP) list housing in row (A in _ij) in, determine by normalized range analysis method the factor sequence affecting each well, finally determine the Main way of profile control and water plugging.

$A_{\mathrm{ij}}=\left[\begin{array}{cccc}{A}_1& A_2& ......& A_n\\ V_1& V_2& ......& V_n\\ S{P}_1& {\mathrm{SP}}_2& ......& {\mathrm{SP}}_n\end{array}\right]---\left(11\right)$

Use X _ijfor matrix A _ijthe average of horizontal j the index of i, make B _ij=| A _ij-X _ij|, then

$B_{\mathrm{ij}}=\left[\begin{array}{cccc}{B}_{11}& B_{12}& ......& B_{1n}\\ B_{21}& B_{22}& ......& B_{2n}\\ B_{31}& B_{32}& ......& B_{3n}\end{array}\right]---\left(12\right)$

Use Y _ijfor matrix B _ijj erect row i index average, use Π _ijrepresent matrix B _ijaverage, use X _irepresent extreme difference, then X _i=| Π _ij-Y _ij|, then

X _i＝[X ₁X ₂......X _n](13)

Use X _i ^*what represent after normalization is differential, then

$X_i^{*}=\frac{\mathrm{Xi}}{\underset{i=1}{\overset{n}{\mathrm{\&Sigma;}}}{X}_i};$ $X_i^{*}=\left[\begin{array}{cccc}{X}_1^{*}& X_2^{*}& ......& X_n^{*}\end{array}\right]---\left(14\right)$

By comparing X _i ^*size can find out that each well is to block effect (this value is larger, affects larger).Use C _ijfor matrix B _iji j erect the average of row index, use Π _ijrepresent matrix B _ijaverage, use ζ _irepresent extreme difference, then ζ i=| Π _ij-C _ij|, then

ζ _i＝[ζ ₁ζ ₂ζ ₃](15)

Use ζ _i ^*what represent after normalization is differential, then

${\mathrm{\&zeta;}}_i^{*}=\frac{{\mathrm{\&zeta;}}_i}{\underset{i=1}{\overset{3}{\mathrm{\&Sigma;}}}{\mathrm{\&zeta;}}_i};$ ${\mathrm{\&zeta;}}_i^{*}=\left[\begin{array}{ccc}{\mathrm{\&zeta;}}_1& {\mathrm{\&zeta;}}_2& {\mathrm{\&zeta;}}_3\end{array}\right]---\left(16\right)$

The factor (this value is maximum is exactly the factor had the greatest impact) that whole block is had the greatest impact can be determined by the size comparing ζ i*.Table 1, table 2, oil-water well connected relation form described criterion together with ζ i*.

Utilize specific embodiments of the invention as follows:

The W layer in Z oil field belongs to the High water cut stage, and this layer of position comprehensive water cut is higher at present, and this layer of position needs to carry out integral profile control water blockoff.Utilize the profile control and water plugging measure of the inventive method to this layer of position to carry out decision-making, concrete steps are as follows:

(1) decision parameters calculate

1) plane heterogeneity decision-making coefficient (A) calculates

Select moisture relatively high position to apply, as shown in Figure 2, in Fig. 2, saturate place is moisture higher position in the selection of dimension constitution layer decision part.

According to the parametric technique formula of three in the inventive method and relevant parameter (formula (4), (6), (9)), and carry out the oil field integral profile control water blockoff decision-making at this position (i.e. above-mentioned moisture relatively high position) in conjunction with discrimination standard of the present invention.

The A value result of calculation that plane heterogeneity decision-making coefficient (A) obtains after calculating is as shown in table 3 with sequence,

Pound sign	A	A value sorts
			332	0.02074876	9
1U	0.003730114	11
			327	0.063679058	7
330	0.125845737	4
			328	0.090836101	5
301	0.051420839	8
			348	0.013567885	10
3U	0.281691475	2
			331	0.306720794	1
2U	0.071458732	6
			334	0.137637734	3

Table 3

Can obtain the sequence of A value from table 3 is:

331＞3U＞334＞330＞328＞2U＞327＞301

According to A value criterion, sequence be 9,10,11 well do not need to adjust stifled, and this position needs the well of profile control and water plugging to be 8 mouthfuls altogether, be badly in need of carrying out for coming 4 mouthfuls of wells above.

Single well analysis is carried out to 331 wells, the A value of the oil well around 331 wells is sorted, as shown in table 4:

Table 4

${\mathrm{\&zeta;}}_i^{*}=\left[\begin{array}{ccc}{\mathrm{\&zeta;}}_{3U}& {\mathrm{\&zeta;}}_{330}& {\mathrm{\&zeta;}}_{2U}\end{array}\right]=\left[\begin{array}{ccc}0.019& 0.626& 0.355\end{array}\right]$

Can obtain A value ranking results from table 4 is 330 > 2U > 1U, then can judge that the direction of 331 main channelling is 331 towards 330 directions.Differential from normalization, 330 have the greatest impact (numerical value is larger, affects larger) to this position.

2) the longitudinal permeability coefficient of variation (Vk) calculates

W layer substratum V _kvalue result of calculation is as shown in table 5 with sequence:

Layer position	V k	Sequence
			C1-II	0.39	6
C1-III-1	3.63	2
			C1-III-2	1.64	4
C1-IV-1	2.73	3
			C1-IV-2	0.69	5
C1-V	4.26	1
			C1-VI	0.13	7

Table 5

V _kranking results is C1-V > C1-III-1 > C1-IV-1 > C1-III-2 > C1-IV-2.According to V _kcriterion, sequence be 6 and 7 well do not need to adjust stifled, and 6 substratums tieing up constitution layer need to adjust stifled.As shown in Figure 3, Fig. 3 gives the Vk value of 7 corresponding respectively substratums of four mouthfuls of wells to the distribution of dimension constitution layer, also can find out this kind of situation from the water layer change Fig. 3.

3) section decision-making coefficient (SP) result of calculation

Dimension constitution layer SP value result of calculation is as shown in table 6 with sequence:

Pound sign	SP	Adjust stifled intensity
			332	18.22	Do not need
1U	5.16	Do not need
			327	21.15	Appropriateness
330	62.98	Appropriateness
			328	29.35	Appropriateness
301	20.65	Appropriateness
			348	10.86	Do not need
3U	72.64	High strength
			331	97.81	High strength
2U	22.53	Appropriateness
			334	67.24	Appropriateness

Table 6

According to the result that table 6 calculates, SP value sorts: 331 > 3U > 334 > 330,331 and > 3U need the tune of high strength to block up, and 1U, 332,328 3 mouthfuls of wells, do not need to adjust stifled at present.It is stifled that remaining well needs appropriateness to adjust.

(2) result of decision:

According to dimension constitution layer decision parameters A, V _k, SP result of calculation, utilize AVS profile control and water plugging decision-making technic criterion, obtain following result and (obtain according to criterion.One is numerical values recited, and one is arrangement priority, and the applicable tune being greater than criterion blocks up, and the applicable high strength that numerical value is larger is adjusted stifled.)：

1) 331,3U, 334,330 larger to the entire effect of this layer of position;

2) C1-V, C1-III-1, C1-IV-1 substratum is larger on block integral impact;

3) 331 and 3U adopt high strength to adjust stifled measure, 334 and 330 adopt appropriateness to adjust stifled measure;

4) 332,348,1U does not need to take to adjust stifled measure.

(3) interpretation of result

1) dynamic analysis

By 331,3U, 330, the Production development of 334 wells (respectively as shown in Figure 4, Figure 5, Figure 6 and Figure 7.) analyze known, 331 and 3U moisture basic close to 100% more than 95%, Liquid output constantly increases, and oil production declines obviously, illustrates that these two mouthfuls of wells need to carry out the profile control and water plugging of high strength really.334 and 330 is moisture between 90%-95%, and while Liquid output rises, produce oil obviously declines, so the tune that these two mouthfuls of wells also should carry out appropriateness blocks up measure.The result that decision-making obtains is carried out consistent with utilizing the inventive method.

2) production profile analysis

The industry section situation of 331 wells as can be seen from Figure 8, C1-V substratum Liquid output accounts for 100%, and remaining three substratum penetrated out all not production fluids, so need to carry out water blockoff measure to the C1-V substratum of 331 wells.The result that decision-making obtains is carried out consistent with utilizing the inventive method.

The industry section situation of 334 wells as can be seen from Figure 9, C1-III-2 substratum Liquid output accounts for 20%, C1-IV-1 substratum Liquid output accounts for 80%, and remaining three substratum penetrated out all not production fluids, so need C1-III-1, C1-IV-2 and C1-V substratum to 334 to carry out water blockoff measure.The result that decision-making obtains is carried out consistent with utilizing the inventive method.

Technique scheme is one embodiment of the present invention, for those skilled in the art, on the basis that the invention discloses application process and principle, be easy to make various types of improvement or distortion, and the method be not limited only to described by the above-mentioned detailed description of the invention of the present invention, therefore previously described mode is just preferred, and does not have restrictive meaning.

Claims (6)

1. a waterflooding oil field integral profile control water blockoff decision-making technique, it is characterized in that: described method utilizes oil reservoir basic parameter, oil reservoir development data and oil reservoir creation data to obtain six parameters, these six parameters are respectively plane heterogeneity decision-making coefficient A, plain heterogeneity property coefficient extreme difference R _a, longitudinal permeability coefficient of variation V _k, longitudinal permeability coefficient of variation R _v, intake profile decision-making coefficient SP and intake profile decision-making coefficient extreme difference R _sP, then utilize these six parameters to realize the decision-making of waterflooding oil field integral profile control water blockoff according to criterion;

Described oil reservoir basic parameter comprises: the mean permeability k of all wells, substratum permeability K _σ, degree of porosity Φ, rock compressibility C, formation thickness h and fluid viscosity μ;

Described oil reservoir development data comprise: theoretical injection-production ratio B _ideal, water injection well Control Radius r _e, perforation thickness h _penetrate, actual injection-production ratio B _real, segment the little number of plies and perforation number of plies n _penetrate;

Described oil reservoir creation data comprises: injectivity index I _wwith water suction number of plies n _inhale;

Described plane heterogeneity decision-making coefficient A obtains like this:

$A=\frac{WI}{\frac{\mathrm{\&mu;}}{15K}ln\frac{12.5{r_e}^2\mathrm{\&Phi;}\mathrm{\&mu;}C}{Kt}}---\left(4\right),$

Wherein k is substratum permeability K _σ, t is the time;

Described plain heterogeneity property coefficient extreme difference R _aobtain like this: for whole block, calculate the plain heterogeneity coefficient Ai of every mouthful of well, obtain plane heterogeneity coefficient matrix: [A ₁a ₂... A _i... A _n], then

$R_{Ai}=\left|Ai-\frac{\underset{i=1}{\overset{n}{\&Sigma;}}Ai}{n}\right|---\left(5\right)$

Described longitudinal permeability coefficient of variation V _kobtain like this:

$V_k=\frac{k-K_{\mathrm{\&sigma;}}}{k}---\left(6\right);$

Described longitudinal permeability coefficient of variation R _vobtain like this:

$R_V=\left|V_{ki}-\frac{\underset{i=1}{\overset{n}{\&Sigma;}}{V}_{ki}}{n}\right|---\left(7\right);$

Described calculating intake profile decision-making coefficient SP obtains like this:

ΔB＝B _ideal-B _real(9)，

(8) h in formula _inhalerefer to water accepting layer thickness;

Described intake profile decision-making coefficient extreme difference (R _sP) obtain like this:

$R_{SP}=\left|{\mathrm{SP}}_i-\frac{\underset{i=1}{\overset{n}{\&Sigma;}}{\mathrm{SP}}_i}{n}\right|---\left(10\right).$

2. waterflooding oil field integral profile control water blockoff decision-making technique according to claim 1, is characterized in that: described criterion comprises block and adjusts stifled discrimination standard, adjusts criterion and the block influence factor criterion of stifled well choice criteria, oil-water well connected relation.

3. waterflooding oil field integral profile control water blockoff decision-making technique according to claim 2, is characterized in that: described block adjusts stifled discrimination standard as follows:

For Low-mid permeability pools, if A > 0.04, then need to adjust and block up, for high permeable cement, if A > 10, then need to adjust and block up;

For Low-mid permeability pools, if R _a> 0.05, needs to adjust and blocks up, for high permeable cement, if R _a> 20, then need to adjust and block up;

If V _k> 0.3, then need to adjust and block up;

If R _v> 0.5, then need to adjust and block up;

If SP > 60, then high strength profile control;

If 20 < SP < 60, then appropriateness is adjusted stifled;

If during SP < 20, then do not need profile control.

4. waterflooding oil field integral profile control water blockoff decision-making technique according to claim 2, is characterized in that: it is as follows that described tune blocks up well choice criteria:

For Low-mid permeability pools, if A > 0.05, then need to adjust and block up;

For high permeable cement, if A > 3 or then need to adjust and block up; refer to the average of A;

If V _k> 0.6 or then need to adjust and block up;

If SP > 20 or then need to adjust and block up.

5. waterflooding oil field integral profile control water blockoff decision-making technique according to claim 2, is characterized in that: the criterion of described oil-water well connected relation is as follows:

By the A value sequence of corresponding for well all oil wells, the direction that A is larger and water injection well inject the main flow direction of water; By the A value sequence of corresponding for oil well all wells, the main watering of the well direction that A value is larger and sewage from oil-well, obtains this profit connected relation like this, is used for judging crossfire direction.

6. waterflooding oil field integral profile control water blockoff decision-making technique according to claim 2, is characterized in that: the criterion of described oil-water well connected relation is as follows: described block influence factor criterion is as follows:

By each well or corresponding plane heterogeneity decision-making coefficient A, the longitudinal permeability coefficient of variation V of oil well _khousing in row A is listed in intake profile decision-making coefficient SP _ijin, determine by normalized range analysis method the factor sequence affecting each well, finally determine the Main way of profile control and water plugging:

$A_{ij}=\left[\begin{array}{cccc}{A}_1& A_2& ......& A_n\\ V_1& V_2& ......& V_n\\ {\mathrm{SP}}_1& {\mathrm{SP}}_2& ......& {\mathrm{SP}}_n\end{array}\right]---\left(11\right)$

Use X _ijfor matrix A _ijthe average of horizontal j the index of i, make B _ij=| A _ij– X _ij|, then

$B_{ij}=\left[\begin{array}{cccc}{B}_{11}& B_{12}& ......& B_{1n}\\ B_{21}& B_{22}& ......& B_{2n}\\ B_{31}& B_{32}& ......& B_{3n}\end{array}\right]---\left(12\right)$

Use Y _ijfor matrix B _ijj erect row i index average, use П _ijrepresent matrix B _ijaverage, use X _irepresent extreme difference, then X _i=| П _ij-Y _ij|, then

X _i＝[X ₁X ₂......X _n](13)

Use X _i ^*what represent after normalization is differential, then

$X_i^{*}=\frac{Xi}{\underset{i=1}{\overset{n}{\&Sigma;}}{X}_i};X_i^{*}=\&lsqb;\begin{array}{cccc}{X}_1^{*}& X_2^{*}& \mathrm{......}& X_n^{*}\end{array}\&rsqb;---\left(14\right)$

By comparing X _i ^*size can find out that each well is to block effect;

Use C _ijfor matrix B _iji j erect the average of row index, use П _ijrepresent matrix B _ijaverage, use ζ _irepresent extreme difference, then ζ _i=| П _ij-C _ij|, then

ζ _i＝[ζ ₁ζ ₂ζ ₃](15)

Use ζ _i ^*what represent after normalization is differential, then

${\mathrm{\&zeta;}}_i^{*}=\frac{{\mathrm{\&zeta;}}_i}{\underset{i=1}{\overset{3}{\&Sigma;}}{\mathrm{\&zeta;}}_i};{\mathrm{\&zeta;}}_i^{*}=\&lsqb;\begin{array}{ccc}{\mathrm{\&zeta;}}_1& {\mathrm{\&zeta;}}_2& {\mathrm{\&zeta;}}_3\end{array}\&rsqb;---\left(16\right)$

By comparing ζ _i ^*size can determine factor that whole block is had the greatest impact.