CN105041307A - Industrial procedure for identifying preferential seepage channels of oil and gas reservoirs of clastic rock - Google Patents
Industrial procedure for identifying preferential seepage channels of oil and gas reservoirs of clastic rock Download PDFInfo
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Abstract
The invention discloses an industrial procedure for identifying preferential seepage channels of oil and gas reservoirs of clastic rock. The industrial procedure includes steps of 1), dividing n development phases and dividing wells into n groups according to the development phases of well drilling time; 2), dividing data grids of research areas; 3), interpolating permeability parameters of well points of the well groups 1 to obtain permeability planar distribution grids of the development phases 1; 4), sequentially acquiring permeability planar distribution grids R<1>, R<2>, ..., and R<n> of the n development phases by the aid of a method implemented in the step 3); 5), computing a variation coefficient of a permeability value of each grid point by the aid of results obtained in the step 4) so as to obtain variation coefficient grids P; 6), subtracting the R<1> from the R<n>, assigning values of 1 to the grid points with positive difference values and assigning values of -1 to the grid points with negative difference values to obtain grids T; 7), multiplying the grids P by the grids T to obtain grids Q, drawing contour maps of the grids Q, and utilizing regions larger than 0.3 in the contour maps as the preferential seepage channels. The variation coefficients of the permeability values of the grid points change along with change of the development phases. The industrial procedure has the advantage that oilfield water-flooding development and remaining oil prediction can be guided.
Description
Technical field
The present invention relates to oil development geology field, is a kind of industrialization flow process identifying clastic oil and gas reservoir dominant flowing path.
Background technology
In oil gas waterflooding extraction process, the Gao Konggao formed because of long-time waterflooding behavior in reservoir oozes (or extra-high ooze), and band is called dominant flowing path.After oil reservoir enters height (extra-high) Water-cut Period, the effect of reservoir dominant flowing path can manifest, and especially in the reservoir that permeability is higher, this phenomenon is more obvious.Due to the difference of reservoir plane heterogeneity and exploit condition, the inner zones of different of ultra-high water cut stage oil reservoir, reservoir dominant flowing path developmental state has very big-difference, and the dominant flowing path of different stage, and its geologic feature, seepage flow characteristics and remaining oil distribution etc. differ greatly.In order to keep stable yield, large liquid measure is often adopted to produce at high water-cut stage, in this case due to the existence of reservoir dominant flowing path, form poor efficiency and inefficient water injection circulation, have a strong impact on water flooding effectiveness, Tapping Residual Oil difficulty, causes the mass energy in development process and water resource waste simultaneously.
For the Crack cause of reservoir dominant flowing path, Chinese scholars has carried out large quantity research, from the formation mechenism of dominant flowing path, in long-term injecting water development process, degree of porosity and pore structure change, form dominant flowing path, forming the reason that this Microstructure of Reservoirs changes has following several: the 1. effect of water in long-period water drive exploitation, make the fine component in sandstone be injected into water and carry out stratum, lose this part of fine component in reservoir gradually, the space causing it originally to occupy becomes seepage channel; 2. water drive process, the number of reservoir pore space throat radius and large venturi increases; 3. water drive process increases the average pore of reservoir.The difficulty or ease that different oil reservoirs forms dominant flowing path are on stream different, and the four kinds of common situations easily forming reservoir dominant flowing path comprise: 1. reservoir loose cementation, shale content are high; 2. High porosity high permeability reservoirs, plane and in-layer heterogeneity strong; 3. core intersection is large; 4. the oil reservoir that mining rate is large, the development time is long.
Reservoir dominant flowing path can cause invalid and poor efficiency fill cycle, and effective shutoff dominant flowing path can improving ecology development effectiveness effectively, so accurately identify and quantitatively calculate dominant flowing path to have important directive significance in oil reservoir development.Chinese scholars proposes the Forecasting Methodology of multiple reservoir dominant flowing path from different angles, as core analysis method, well logging recognition method, produces and inhales domatic diagnostic method, PI decision-making determining method, well-group tracer interpretative method etc.
2013, Jiang Hanqiao proposes a kind of dominant flowing path sound state multi objective based on early warning thought and principle and differentiates method for early warning, using scene dynamically, geology and monitoring materials as the source of pre-warning indexes system, adopt fuzzy comprehensive estimation, SVMs and fuzzy comprehensive clustering as differentiation Early-warning Model method.The method considers multiple Development Factors, comprises Injection Well injection pressure, injectivity index, waterflood injection rate, water injection intensity and intake profile, producing well moisture content, water_bearing escalating rate, liquid production index, production profile, degree of shaking out and production fluid intensity, well group injection production pressure difference, production fluid speed, injection water retaining in reservoir and note and adopts the indexs such as connective.These parameters is various, calculation of complex, in the reservoir dominant flowing path identification of reality, do not need all to take, but first understand the reservoir studied, determine the Dominated Factors that its reservoir dominant flowing path is grown, according to Dominated Factors to These parameters System For Screening.Also have the situation that scholar (Wang Mount Lushan, 2013) generally grows for water-drive pool high water cut rate block dominant flowing path, propose, according to reservoir engineering principle, adopt WATER FLOODING CHARACTERISTIC CURVE identification dominant flowing path and calculate its volume.
On the basis of reservoir dominant flowing path identification, oil reservoir development work just needs to formulate the solve scheme reducing dominant flowing path, conventional technical cue comprises following several respects: 1. according to the characteristic distributions of reservoir dominant flowing path, carry out flooding pattern segmentation, restructuring and based on the optimization of geological conditions and balanced adjustment, by this adjustment, utilize hydrodynamics method to change the flow direction of water filling, expand the swept volume injecting water; 2. in order to suppress the invalid and poor efficiency fill cycle formed, shutoff reservoir dominant flowing path; 3. carry out tertiary oil recovery, improve Middle-Low Permeability Reservoirs oil-water seepage ability and oil displacement efficiency.
Although Chinese scholars and oily company have carried out large quantifier elimination and field trial for reservoir dominant flowing path, summarize a series of recognition methods, but due to the heterogeneous body of reservoir and the uniqueness of different reservoir geology and development process, also lack simple to operate, universality and practical Method and Technology flow process at present.
Summary of the invention
The object of the invention is the industrialization technology flow process setting up a kind of clastic oil and gas reservoir physical property evolution sign, form workable method step, characterize the change of Clastic Rock Reservoirs in oil and gas development process, instructing the appointment of complicated clastic oil reservoir development measure and a prediction difficult problem for remaining oil forming and distribution, providing support for improving oil recovery rate.
1) the exploitation curve of study area is worked out, comprise moisture ascending curve, produce oil curve and production fluid curve, produce oil tracing pattern is taken into account according to moisture ascending curve, divide the development phase, by oil field from drop into exploitation whole process up till now and be divided into n development phase (n=1,2,3 ...);
2) compile the drilling time data of all wells in study area, according to the development phase residing for every mouthful of well drilling time, all wells are divided into n group, corresponding 1 group of well of each development phase;
3) collect the Permeability Parameters curve of all wells, carry out lump calculating to the Permeability Parameters of exploitation target zone, make for research purpose stratum, every mouthful of well has the typical value of a Permeability Parameters, and lump computational methods are:
A., when research purpose layer is homogeneous single sand body, the arithmetic mean of instantaneous value of this single sand body permeability curve up-sampling point value is got;
B., when target zone is inhomogeneous single sand body, the interlayer of deduction single sand body inside, according to the average weighted method of sandstone thickness, calculates the permeability typical value of this single sand body;
C. when target zone is the combination of multiple single sand body, the permeability value of each single sand body in target zone is calculated respectively according to above-mentioned A and B two kinds of situations, then Permeability Parameters thickness weighted average is carried out to each single sand body in interval of interest, obtain the Permeability Parameters typical value of this interval;
4) Research on partition district plane grid, as the grid of Permeability Parameters interpolation calculation in subsequent step, mesh spacing value should be less than 1/4th of minimum well spacing in study area;
5) the interval of interest lump permeability value of first group of well is used, according to step 4) grid that divides, carries out the interpolation calculation of Permeability Parameters, obtains the permeability plane distribution data grids R of the 1st development phase of study area
1;
6) according to step 5) method, use the interval of interest lump permeability value (i=1 of i-th group of well, 2, n), according to step 4) grid that divides, carries out the interpolation calculation of Permeability Parameters value, obtains the permeability plane distribution grid data R of i-th development phase of study area
i, the Permeability Parameters plane distribution grid data R of n development phase is obtained successively according to this method
1, R
2..., R
n;
7) step 6 is utilized) the different development phases Permeability Parameters plane distribution grid data (R that obtains
1, R
2..., R
n) calculate the coefficient of variation that each plane net lattice point permeability value changes with the development phase, obtain study area reservoir permeability coefficient of variation grid P;
8) the permeability grid of the n-th development phase and the 1st development phase is subtracted each other (i.e. R
n-R
1), difference is positive mesh point assignment is 1, and difference is negative mesh point assignment is-1, obtains grid T;
9) by grid P and T-phase multiplied to grid Q, utilize grid Q to draw coefficient of permeability variation isogram, on this isogram, value is greater than the Regional Representative of 0.3 reservoir dominant flowing path development area.
Detailed description of the invention
The present invention is divided into groups to well by development stage division, then the permeability sea level changes of different phase is calculated, permeability is characterized over time by the coefficient of variation of different phase permeability, thus the dominant flowing path in identification reservoir, instructing the formulation of complicated clastic oil reservoir remaining oil distribution forecast and development stimulation, providing support for improving oil recovery rate.
1) monthly creation data is utilized to work out the productive frontiers figure of study area, comprehensive water cut curve, produce oil curve and production fluid curve is comprised in figure, according to comprehensive water cut ascending curve feature, take into account produce oil tracing pattern, divide the development phase, by oil field from drop into exploitation whole process up till now and be divided into n development phase (n=1,2,3 ...);
2) drilling time of all wells in Revision district, according to the development phase residing for every mouthful of well drilling time, is divided into n group by all wells, corresponding 1 group of well of each development phase;
3) collect the Permeability Parameters curve of all wells, Permeability Parameters Mei Kou Jingyan County being studied carefully to interval of interest carries out lump calculating, makes the interval to conducting a research, and a permeability typical value got by every mouthful of well, and concrete lump computational methods are:
A., when research purpose layer is a homogeneous single sand body, the arithmetic mean of instantaneous value of the permeability curve up-sampling point value of this single sand body is got;
B., when target zone is an inhomogeneous single sand body, the interlayer of deduction single sand body inside, according to the average weighted method of sandstone thickness, obtains the permeability typical value of target zone;
C. when target zone is the combination of multiple single sand body, the permeability typical value of each single sand body in target zone is calculated respectively according to above-mentioned A and B two kinds of situations, then thickness weighted average is carried out to the permeability typical value of each single sand body in interval of interest, obtain the Permeability Parameters typical value of the whole interval of interest of this well;
4) calculating study area minimum well spacing is d, to be less than the length of d/4 as mesh spacing, and Research on partition district plane grid;
5) first group of well target zone permeability lump value is used, according to step 4) plane grid that divides, carries out gridding calculating to Permeability Parameters, obtains the permeability plane distribution data grids R of the 1st development phase of study area
1;
6) according to step 5) method, use the interval of interest lump permeability value (i=1 of i-th group of well, 2, n), according to step 4) plane grid that divides, carries out gridding calculating to permeability lump value, obtains the permeability plane distribution grid data R of i-th development phase of study area
i, the Permeability Parameters plane distribution grid data R of n development phase is obtained successively according to this method
1, R
2..., R
n;
7) step 6 is utilized) the different development phases Permeability Parameters plane distribution grid data (R that obtains
1, R
2..., R
n), the coefficient of variation that the permeability value calculating each plane net lattice point place changed with the development phase, obtains study area reservoir permeability coefficient of variation grid P;
8) the permeability grid of the n-th development phase and the 1st development phase is subtracted each other (i.e. R
n-R
1), difference is positive mesh point assignment is 1, and difference is negative mesh point assignment is-1, obtains grid T;
9) by grid P and T-phase multiplied to grid Q, utilize grid Q to draw reservoir permeability coefficient of variation isogram, on this isogram, value is greater than the region of 0.3 is reservoir dominant flowing path development area.
Embodiment
Neogene System Guantao, Shengli Oil Field Gudong area group grows fluvial facies deposit, growth loose sand deposits, reservoir properties is good, the exploitation that this area's X block have passed through nearly 30 years, waterflooding extraction reaches 27 years. in long-term waterflooding extraction, reservoir permeability changes along with oil reservoir development, interval of interest Ng52 sand group reservoir local creates dominant flowing path, formation inefficient water injection circulates, waterflooding development effect is deteriorated, remaining oil distribution is unclear, need the development position identifying reservoir dominant flowing path, thus instruct next step reservoir waterflooding adjustment and remaining oil prediction and tap the latent power.
The first step, utilizes monthly creation data to work out the productive frontiers figure of study area, according to comprehensive water cut curvilinear characteristic, the Development history of X block is divided into 5 development phases;
Second step, these wells are corresponded to 5 development phases according to every mouthful of well drilling time, thus well are divided into 5 groups by the drilling time of the 120 mouthfuls of wells in Revision district respectively;
3rd step, collect the permeability curve of X block 120 mouthfuls of wells, lump calculating is carried out to the Permeability Parameters of every mouthful of well Ng62 sand group, a permeability typical value got by every mouthful of well, and study area Ng52 sand group grows fluvial facies deposit, and sandstone entirety is thick, but difference is aboveground be there are differences, a single sand body grown by some wells, and two single sand bodies grown by some wells, adopts different permeability lump computational methods to be for different well points:
A., when research purpose layer is a homogeneous single sand body, the arithmetic mean of instantaneous value of the permeability curve up-sampling point value of this single sand body is got;
B., when target zone is an inhomogeneous single sand body, the interlayer of deduction single sand body inside, according to the average weighted method of sandstone thickness, obtains the permeability typical value of target zone;
C. when target zone is two single sand body combinations, the permeability typical value of each single sand body in target zone is calculated respectively according to above-mentioned A and B two kinds of situations, then thickness weighted average is carried out to the permeability typical value of two single sand bodies in Ng52 sand group, obtain the Permeability Parameters typical value of this well Ng52 sand group;
4th step, calculating X block minimum well spacing is 50m, take 5m as mesh spacing, Research on partition district plane grid;
5th step, uses first group of well target zone permeability lump value, and the plane grid divided according to the 4th step, carries out gridding calculating to Permeability Parameters, obtain the permeability plane distribution data grids R of the 1st development phase of study area
1;
6th step, according to the method for the 5th step, use the Ng52 sand group lump permeability value (i=1 of i-th group of well, 2,, 5), the plane grid divided according to the 4th step, gridding calculating is carried out to permeability lump value, obtains the permeability plane distribution grid data R of i-th development phase of study area
i, the Permeability Parameters plane distribution grid data R of 5 development phases is obtained successively according to this method
1, R
2..., R
5;
7th step, 5 the development phase Permeability Parameters plane distribution grid data (R utilizing the 6th step to obtain
1, R
2..., R
5), the coefficient of variation that the permeability value calculating each plane net lattice point place changed with the development phase, obtains X block reservoir coefficient of permeability variation grid P;
8th step, subtracts each other (i.e. R by the permeability grid of the 5th development phase and the 1st development phase
5-R
1), difference is positive mesh point assignment is 1, and difference is negative mesh point assignment is-1, obtains grid T;
9th step, by grid P and T-phase multiplied to grid Q, utilize grid Q to draw reservoir permeability coefficient of variation isogram, on this isogram, value is greater than the region of 0.3 is X block Ng52 sand group reservoir dominant flowing path development area.
From recognition result, X block Ng52 sand group reservoir dominant flowing path major developmental is inner in the point bar deposition of fluvial depositional reservoir, amass body with the side of point bar inside and have good corresponding relation, under the guidance of this understanding, in waterflooding extraction from now on, need to consider that point bar private side amasss the effect of body convection cell seepage flow, choose rational water injection well mode.
Claims (1)
1. the industrialization flow process of clastic oil and gas reservoir dominant flowing path identification, comprise and utilize different development phases reservoir permeability plane distribution to calculate Permeability Parameters with the coefficient of variation of development phase, be further characterized in that comprising step by the following method carries out:
(1) the exploitation curve of study area is worked out, comprise moisture ascending curve, produce oil curve and production fluid curve, produce oil tracing pattern is taken into account according to moisture ascending curve, divide the development phase, by oil field from drop into exploitation whole process up till now and be divided into n development phase (n=1,2,3 ...);
(2) compile the drilling time data of all wells in study area, according to the development phase residing for every mouthful of well drilling time, all wells are divided into n group, corresponding 1 group of well of each development phase;
(3) collect the Permeability Parameters curve of all wells, carry out lump calculating to the Permeability Parameters of exploitation target zone, make for research purpose stratum, every mouthful of well has the typical value of a Permeability Parameters, and lump computational methods are:
A., when research purpose layer is homogeneous single sand body, the arithmetic mean of instantaneous value of this single sand body permeability curve up-sampling point value is got;
B., when target zone is inhomogeneous single sand body, the interlayer of deduction single sand body inside, according to the average weighted method of sandstone thickness, calculates the permeability typical value of this single sand body;
C. when target zone is the combination of multiple single sand body, the permeability value of each single sand body in target zone is calculated respectively according to above-mentioned A and B two kinds of situations, then Permeability Parameters thickness weighted average is carried out to each single sand body in interval of interest, obtain the Permeability Parameters typical value of this interval;
(4) Research on partition district plane grid, as the grid of Permeability Parameters interpolation calculation in subsequent step, mesh spacing value should be less than 1/4th of minimum well spacing in study area;
(5) the interval of interest lump permeability value of first group of well is used, according to step 4) grid that divides, carries out the interpolation calculation of Permeability Parameters, obtains the permeability plane distribution data grids R of the 1st development phase of study area
1;
(6) according to step 5) method, use the interval of interest lump permeability value (i=1 of i-th group of well, 2, n), according to step 4) grid that divides, carries out the interpolation calculation of Permeability Parameters value, obtains the permeability plane distribution grid data R of i-th development phase of study area
i, the Permeability Parameters plane distribution grid data R of n development phase is obtained successively according to this method
1, R
2..., R
n;
(7) step 6 is utilized) the different development phases Permeability Parameters plane distribution grid data (R that obtains
1, R
2..., R
n) calculate the coefficient of variation that each plane net lattice point permeability value changes with the development phase, obtain study area reservoir permeability coefficient of variation grid P;
(8) the permeability grid of the n-th development phase and the 1st development phase is subtracted each other (i.e. R
n-R
1), difference is positive mesh point assignment is 1, and difference is negative mesh point assignment is-1, obtains grid T;
(9) by grid P and T-phase multiplied to grid Q, utilize grid Q to draw coefficient of permeability variation isogram, on this isogram, value is greater than the region of 0.3 is reservoir dominant flowing path development area.
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