CN111706317B - Method for determining distribution condition of residual oil in hypotonic reservoir in encryption adjustment area - Google Patents
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Abstract
The invention discloses a method for determining the distribution condition of residual oil in a hypotonic reservoir in an encryption adjustment area, which comprises the steps of selecting standard wells to divide and compare a target stratum, and establishing an isochronous stratum grid; establishing a comparison skeleton section according to the isochronous stratigraphic framework, performing closed comparison of stratigraphic division, and performing fine division of stratigraphic stratum on the well; finely depositing microphase division is carried out on the stratum; determining logging curve characteristics of different microphases, and establishing single well deposition microphasing division; establishing microphase distribution of the profile of the comparative skeleton; establishing microphase distribution of different layers; establishing a stratum three-dimensional geological model, loading data and coarsening to obtain a stratum preliminary numerical simulation model; performing dynamic history fitting after initializing the stratum preliminary numerical simulation model to obtain a stratum correction numerical simulation model; and obtaining the residual oil distribution condition of the low-permeability reservoir in the encryption adjustment area through the stratum correction numerical simulation model. The invention can determine the distribution of the oil layer oil saturation of the residual oil of the whole reservoir in space and the change of the oil layer oil saturation with time.
Description
Technical Field
The invention belongs to the technical field of petroleum exploration, and relates to a method for determining the distribution condition of residual oil in a hypotonic reservoir in an encryption adjustment area.
Background
The remaining oil is the remaining mobile oil, and means underground mobile crude oil which is not produced temporarily. Research on distribution characteristics and rules of residual oil is one of important works for developing geologists. At present, in order to improve the oil gas recovery ratio of an oil field, well distribution is thickened and drilled on the basis of the existing well position, so that quantitative analysis of influence factors of the distribution of residual oil is carried out, the distribution mode and characteristics of the residual oil of the oil field are obtained, a proper well position is provided for the development and encryption well position arrangement of the next oil field, and directional guidance is provided for deep mining of the oil field.
However, the analysis method of the residual oil is various, but has various advantages and disadvantages. The main method comprises the following steps: (1) a core analysis method. And carrying out a displacement test indoors by using the underground rock core to obtain the value of the residual oil after displacement. The method has the advantages of simple principle and direct result; but because the geometric dimension of the core is too small, the actual condition of the underground cannot be reflected. (2) Well logging interpretation methods. The underground oil-water distribution can be explained by using logging data, but the method only obtains the residual oil in a limited range (within 3 m) near the bottom of the well, the residual oil between the wells cannot be obtained, and the whole reservoir residual oil distribution cannot be formed.
Disclosure of Invention
The invention aims to provide a method for determining the distribution condition of residual oil of a hypotonic reservoir in an encryption adjustment area, which can analyze the distribution of the residual oil of the whole reservoir.
The invention is realized by the following technical scheme:
a method of determining the remaining oil distribution of a hypotonic reservoir in an encryption adjustment zone, comprising the steps of:
step 1: selecting standard wells to carry out primary division and comparison on a target stratum, and establishing an isochronous stratum grid;
step 2: establishing a plurality of comparison skeleton sections penetrating through old wells of the whole research area according to the isochronous stratigraphic grid, performing closed comparison of stratigraphic division through the comparison skeleton sections, and then performing stratigraphic division on other wells in the research area;
step 3: selecting a core of a coring well and carrying out sedimentary microphase division on a stratum through sedimentary petrography marks and sedimentary structural features of the core; then determining the logging curve characteristics of different microphases of the target layer, and establishing single well deposition microphasing division; establishing microphase distribution of the contrastive skeleton section according to single well deposition microphase division; establishing microphase distribution of different layers according to microphase distribution on a comparative skeleton section;
step 4: establishing a stratum three-dimensional geological model through the division data of the stratum of the research area sequence obtained in the step 2 and the microphase distribution of the different layers obtained in the step 3, homing the porosity, permeability and oil saturation of logging secondary explanation and dynamic data into a single well, loading the single well into the stratum three-dimensional geological model, and coarsening the single well to obtain a stratum preliminary numerical simulation model;
step 5: initializing the stratum preliminary numerical simulation model, and then performing dynamic history fitting to obtain a stratum correction numerical simulation model; and obtaining the residual oil distribution condition of the low-permeability reservoir in the encryption adjustment area through the stratum correction numerical simulation model.
In step 1, the standard well is a well which is uniformly distributed on a plane, has large drilling depth and has relatively obvious morphological characteristics of the layer position and the logging curve.
Further, the comparative skeleton profile in step 2 includes a plurality of profiles perpendicular to the source direction and a profile parallel to the source direction.
Further, in step 3, the deposited petrographic indicia includes rock color of the core and the detritus component characteristics and interstitial component characteristics of the core;
the deposit formation features include core deposit grain size distribution structural features and core bedding formation features.
In step 4, the formation three-dimensional geological model is built by first building a three-dimensional structural model of the formation, and then loading microphase distribution of different layers into the three-dimensional structural model.
Further, the process of establishing the three-dimensional structural model of the stratum specifically comprises the following steps:
and establishing a superimposed layer model of the stratum by using the single well coordinate data, the well track data, the heart tonifying elevation data and the contrast-divided layered data, establishing a interlayer thickness layer model and a sand thickness layer model by combining the layered sand thickness contour map, interpolating, and then loading an earthquake interpretation structural plane and earthquake interpretation fault data into the superimposed layer model to establish a three-dimensional structural model of the stratum.
Further, in step 4, the dynamic data includes data of well completion, oil and gas annual oil and water production, pressure and well measure with time.
Further, in step 4, the roughening is specifically:
coarsening the net-to-gross ratio and the porosity of the stratum by adopting a volume weighted arithmetic average method; coarsening the permeability of the stratum by adopting a full tensor method.
Further, in step 5, the initialization process specifically includes:
and calculating the original formation pressure of the stratum, reservoir rock, oil, gas and water compression coefficient, oil, gas and water density, oil, gas and water viscosity, original oil and water saturation of the oil reservoir, permeability data and fluid high-pressure physical PTV data by adopting a pretreatment conjugate gradient method to obtain an oil saturation field and a pressure distribution field of the oil reservoir.
Further, in step 5, the data of the dynamic history fit includes daily production, cumulative production, water content and pressure change data for a single well.
Compared with the prior art, the invention has the following beneficial technical effects:
according to the method for determining the distribution condition of residual oil in the low permeability reservoir in the encryption adjustment area, fine stratum division and comparison are carried out on a target stratum according to standard wells, a fine isochronous stratum grid is built, then a comparison skeleton section penetrating through an old well in the whole research area is built according to the isochronous stratum grid, closed comparison of stratum division is carried out, fine division of all wells of the target stratum is finally achieved, and then micro-phase distribution of different layers is built on the basis of fine deposition micro-phase division of the target stratum; establishing a stratum three-dimensional geological model through finely dividing data of stratum of a research area and microphase distribution of different layers, loading related data for initialization processing, and then performing dynamic history fitting to establish a stratum correction numerical simulation model; gradually establishing a stratum correction numerical simulation model of a target layer from point to line to surface and from body to body, so that the established model is close to the actual stratum state; and obtaining the residual oil distribution condition of the hypotonic reservoir through the stratum correction numerical simulation model. According to the invention, factors related to dynamic changes of the oil reservoir are fully considered, and the knowledge of the residual oil can be quantified and visualized; the method can determine the distribution of the oil layer oil saturation of the residual oil of the whole reservoir in space and the change with time, and is not limited to the analysis of the residual oil in a smaller range; the calculation result of the model after history fitting correction recognizes the current residual oil distribution condition of the oil reservoir, determines the next development and adjustment technical countermeasure, formulates the next development and adjustment scheme and predicts the oil and gas reservoir development index.
Further, coarsening the net-to-gross ratio and the porosity of the stratum by adopting a volume weighted arithmetic average method, coarsening the permeability of the stratum by adopting a full tensor method, and converting the fine geological model of the grid into a coarse grid model. In this process, a series of equivalent coarse meshes are used to "replace" the fine meshes in the fine model, and the equivalent coarse mesh model is enabled to reflect the geologic features and flow response of the original model.
Drawings
FIG. 1 is an analytical flow chart of the present method;
FIG. 2 is a reservoir clastic component profile;
FIG. 3 is a reservoir subsea shunt channel log feature;
FIG. 4 is a reservoir estuary dam log characteristic;
FIG. 5 is a reservoir underwater natural dike log feature;
FIG. 6 is a reservoir tributary bay log feature;
FIG. 7 is a reservoir single well deposition microphotograph;
FIG. 8 is a microphase map of a reservoir contrast skeleton profile;
FIG. 9 is a microphase distribution diagram of different layers;
FIG. 10 is a three-dimensional geologic model of a reservoir;
FIG. 11 is an graph of reservoir permeability, kro for oil phase relative permeability, krw for water phase relative permeability, sw for water saturation;
FIG. 12 is a plot of a reservoir single well daily production fit;
FIG. 13 is a plot of reservoir cumulative yield fits;
FIG. 14 is a plot of a reservoir water cut fit.
Detailed Description
The invention will now be described in further detail with reference to specific examples, which are intended to illustrate, but not to limit, the invention.
The invention discloses a method for determining the distribution condition of residual oil in a hypotonic reservoir in an encryption adjustment area, which is shown in figure 1 and specifically comprises the following steps:
step 1: selecting a plurality of wells which are uniformly distributed on a plane, have large drilling depth and obvious morphological characteristics of a layer position complete and well logging curve as standard wells, finely dividing and comparing the target stratum of the standard wells, and establishing a fine isochronous stratum grid; the method adopts a deposition small layer comparison technology of 'mark layer control, deposition rotation comparison, equal elevation and thickness constraint, sand undercut and side area analysis and dynamic monitoring data verification', and utilizes a logging curve for comparison.
The drilling depth is not standard, the data is only good in practical application, the sampling process is not unified standard, and different reservoirs are different in conditions, which is only a relative quantity.
The formation contrast and division is fine to small, following the following principles:
(1) According to the principle of isochronicity, the continuity of the deposited sand body is considered from the principle of layer sequence stratigraphy when comparison is carried out, and the phenomenon of time penetration cannot occur when comparison is carried out;
(2) The control of the marking layer, establish the long-term, medium-term reference surface interface according to the stratigraphy of layer sequence, establish the marking layer of the oil layer group, sand layer group;
(3) The deposition gyratory, deposition rhythm subdivision small layers and single sand bodies are formed, the mudstone interlayer between the small layers is developed, the electrical sign is obvious, and the continuous tracking can be realized in a certain range;
(4) In the layer section with unobvious gyratory property, adopting a thickness rule of thumb or equal elevation constraint to assist in comparison and division;
(5) When the transverse contrast change is large, the contrast and division are assisted according to the lower cutting and side area change rules of the deposited sand body;
(6) The splitting of the thick sand body follows the phase sequence principle and has obvious marks on a logging curve;
(7) Dynamic data verification and comparison are developed, and dynamic data verification such as injection and production, interwell monitoring, tracer monitoring and the like can be obtained according to comparison results so as to ensure effectiveness and rationality of comparison and division results.
Step 2: according to the equal-time stratum grillwork, a plurality of 45 comparison skeleton sections penetrating through the old well of the whole investigation region 278 are established, wherein 16 sections perpendicular to the object source direction and 29 sections parallel to the object source direction are closed and compared in stratum division through the comparison skeleton sections, and then the stratum sequence is divided for other drilling and encountering wells of the investigation region, so that secondary fine division of the target stratum is realized.
Step 3: selecting a core of a coring well, dividing a geographical feature microphase of a reservoir after stratum calculation according to a rock character of core sediment and a sediment structure feature, and carrying out fine sediment microphase division, in particular to divide a sub-water diversion river channel, a river mouth dam, an underwater natural dyke and a tributary bay sediment microphase.
Specifically, the core deposit petrography flag includes rock color of the core and the detritus component characteristics (see fig. 2) and interstitial composition characteristics of the core, and the deposit structure characteristics include core deposit particle size distribution structure characteristics and core layer structure characteristics.
As shown in fig. 3 to 6, determining logging curve characteristics of different microphases, wherein the logging curve characteristics comprise the logging curve characteristics of a reservoir underwater diversion river channel, the logging curve characteristics of a reservoir estuary dam, the logging curve characteristics of a reservoir underwater natural dike and the logging curve characteristics of a reservoir tributary bay; as shown in fig. 7, a single well deposition microphase partition of the old well purpose layer of the investigation region 278 is further established; as shown in fig. 8, the microphase distribution of the contrasted skeleton section is established according to the single well deposition microphase division; as shown in fig. 9, different layered microphase distributions are established from the microphase distributions on the comparative skeleton profile.
Step 4: the following materials and data are needed to prepare a three-dimensional geologic model:
(1) drilling data: well position coordinate data, well track data and heart tonifying elevation data.
(2) Layer data: finely comparing the divided hierarchical data; a layered sand thickness contour map; layered deposition microphase research results.
(3) Logging data: logging secondary interpreted porosity, permeability, and oil saturation yield data.
(4) Seismic data: the seismic interpretation construct plane and the seismic interpretation fault data.
As shown in fig. 10, the above data and data are then used to build a stacked layer model of the formation from the individual well coordinate data, well trajectory data, supplementary altitude data, and finely contrastingly divided layered data in the modeling software Eclipse, a compartment thickness and sand thickness layer model is built in combination with the layered sand thickness contour map and interpolated, then seismic interpretation structural planes and seismic interpretation fault data are added to the stacked layer model, a three-dimensional structural model of the formation is built, and then different layered microphase distributions are loaded to the three-dimensional structural model, which performs interwell interpolation or random simulation according to the quantitative distribution rules of reservoir parameters of different sedimentary phases, sand types, or flow units, thereby building a three-dimensional geological model of the formation.
And establishing a structural model, and the thickness distribution change of the stratum under the structural background, the contact relation between vertical strata and the like. And then homing the porosity, permeability and oil saturation of logging secondary interpretation and dynamic data into a single well, loading the single well into a stratum three-dimensional geological model, coarsening the net wool ratio and the porosity of the stratum by adopting a volume weighted arithmetic average method, coarsening the permeability of the stratum by adopting a full tensor method, and converting the fine geological model of the grid into a coarse grid model. In the process, a series of equivalent coarse grids are used for replacing fine grids in the fine model, and the equivalent coarse grid model can reflect the geological features and flow response of the original model, so that a stratum preliminary numerical simulation model is obtained.
The secondary interpretation model of the porosity is preferably obtained through correlation relation between the porosity analyzed by the core and the porosity series logging data, and specifically, the interpretation model of the porosity is preferably obtained from a core analysis porosity-acoustic wave time difference intersection chart, a core analysis porosity-density intersection chart and a core analysis porosity-neutron porosity intersection chart; and then, manufacturing distribution plates of the porosities and the permeability of different small layers according to the data of the core analysis to obtain an interpretation model of the permeability-the porosity, and obtaining the interpretation model of the permeability based on the porosity interpretation model.
Then, an interpretation model of the water saturation and the permeability is manufactured according to the relation between the water saturation and the permeability of the closed core data of different stratum, and further, an interpretation model of the oil saturation is obtained according to the interpretation model of the water saturation; oil saturation = 100% -water saturation in the formation.
In particular, the dynamic data includes data of completion, oil and gas production over the years, pressure, and well action over time.
Step 5: as shown in fig. 11, the original formation pressure, reservoir rock, oil-gas-water compression coefficient, oil-gas-water density, oil-gas-water viscosity, original oil-water saturation of the reservoir, the permeability data and fluid high-pressure physical PTV data of the stratum are calculated by adopting a pretreatment conjugate gradient method to obtain an oil-containing saturation field and a pressure distribution field of the reservoir, and the initialization of the stratum preliminary numerical simulation model is completed.
As shown in fig. 12 to 14, dynamic history fitting is then performed on the daily output, the accumulated output, the water content and the pressure change data of a single well respectively, so as to obtain a stratum correction numerical simulation model, the stratum correction numerical simulation model obtains the distribution conditions of the residual oil of the reservoir in different periods, further forms the evolution of the distribution of the residual oil in different periods, and obtains the reservoir parameters consistent with the actual production dynamics of the reservoir, so that the distribution of the residual oil can be predicted more accurately, the distribution condition of the residual oil of the hypotonic reservoir can be obtained by cutting the stratum correction numerical simulation model in the transverse and longitudinal directions, a reference is provided for later production, and the credibility of the prediction result of the model can be improved.
According to the distribution state of the reservoir residual oil obtained by the research method, 36 ports of the well site are encrypted in the oil field block, and the newly increased recoverable reserves are 16.51 multiplied by 10 after well pattern encryption adjustment 4 And t, the water flooding recovery ratio is improved by 2.81 percent, and the block development effect is greatly improved.
Claims (6)
1. A method for determining the remaining oil distribution of a hypotonic reservoir in an encryption adjustment zone, comprising the steps of:
step 1: selecting standard wells to carry out primary division and comparison on a target stratum, and establishing an isochronous stratum grid;
step 2: establishing a plurality of comparison skeleton sections penetrating through old wells of the whole research area according to the isochronous stratigraphic grid, performing closed comparison of stratigraphic division through the comparison skeleton sections, and then performing stratigraphic division on other wells in the research area;
step 3: selecting a core of a coring well and carrying out sedimentary microphase division on a stratum through sedimentary petrography marks and sedimentary structural features of the core; then determining the logging curve characteristics of different microphases of the target layer, and establishing single well deposition microphasing division; establishing microphase distribution of the contrastive skeleton section according to single well deposition microphase division; establishing microphase distribution of different layers according to microphase distribution on a comparative skeleton section;
step 4: establishing a stratum three-dimensional geological model through the division data of the stratum of the research area sequence obtained in the step 2 and the microphase distribution of the different layers obtained in the step 3, homing the porosity, permeability and oil saturation of logging secondary explanation and dynamic data into a single well, loading the single well into the stratum three-dimensional geological model, and coarsening the single well to obtain a stratum preliminary numerical simulation model;
in step 4, the formation three-dimensional geological model is built by firstly building a three-dimensional structural model of the formation, and then loading microphase distribution of different layers into the three-dimensional structural model;
the process for establishing the three-dimensional structural model of the stratum specifically comprises the following steps:
establishing a superimposed layer model of the stratum by using the single well coordinate data, the well track data, the heart tonifying elevation data and the contrast-divided layering data, establishing a interlayer thickness layer model and a sand layer thickness layer model by combining the layering sand thickness contour map, interpolating, and then loading an earthquake interpretation structural plane and earthquake interpretation fault data into the superimposed layer model to establish a three-dimensional structural model of the stratum;
the porosity of the logging secondary interpretation is preferably obtained through the correlation relation between the core analysis porosity and the porosity series logging data, and specifically, a porosity interpretation model is preferably obtained from a core analysis porosity-acoustic time difference intersection chart, a core analysis porosity-density intersection chart and a core analysis porosity-neutron porosity intersection chart; then, according to the data of core analysis, making distribution plates of the porosities and the permeabilities of different small layers to obtain a permeability-porosity interpretation model, and obtaining the permeability interpretation model based on the porosity interpretation model;
step 5: initializing the stratum preliminary numerical simulation model, and then performing dynamic history fitting to obtain a stratum correction numerical simulation model; obtaining the residual oil distribution condition of the low-permeability reservoir in the encryption adjustment area through a stratum correction numerical simulation model;
in step 5, the initialization process specifically includes:
calculating the original stratum pressure of stratum, reservoir rock, compression coefficient of oil, gas and water, oil, gas and water density, oil, gas and water viscosity, original oil and water saturation of oil reservoir, permeability data and fluid high-pressure physical PTV data by adopting a pretreatment conjugate gradient method, and obtaining an oil saturation field and a pressure distribution field of the oil reservoir;
the data of the dynamic history fit comprises daily output, accumulated output, water content and pressure change data of a single well.
2. The method for determining the residual oil distribution of a hypotonic reservoir in a well-controlled zone according to claim 1, wherein in step 1, the standard wells are wells with uniform distribution on a plane, large drilling depth, complete horizon and relatively obvious morphological characteristics of a log.
3. The method of claim 1, wherein the comparative skeleton profile of step 2 comprises a plurality of profiles perpendicular to the direction of the source and profiles parallel to the direction of the source.
4. The method of claim 1, wherein in step 3, the sedimentary petrography comprises rock color of the core and the detritus component characteristics and interstitial composition characteristics of the core;
the deposit formation features include core deposit grain size distribution structural features and core bedding formation features.
5. A method of determining the remaining oil profile of a low permeability reservoir in a zone of crypto-graphic regulation according to claim 1, wherein in step 4, the dynamic data includes data of completion, oil and gas annual oil and water production, pressure and well action over time.
6. The method for determining the distribution of the residual oil in the hypotonic reservoir in the encryption adjustment area according to claim 1, wherein in step 4, the roughening is specifically:
coarsening the net-to-gross ratio and the porosity of the stratum by adopting a volume weighted arithmetic average method; coarsening the permeability of the stratum by adopting a full tensor method.
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| CN112576238B (en) * | 2020-12-02 | 2022-10-28 | 中国石油大学(华东) | System, method and application for determining position and content of residual oil in low-permeability reservoir |
| CN113313825A (en) * | 2021-05-17 | 2021-08-27 | 中国石油天然气集团有限公司 | Three-dimensional geological modeling method and device for oil reservoir |
| CN114544459B (en) * | 2022-02-09 | 2024-04-19 | 武汉左晟检测技术有限公司 | Rock core oil-water permeability curve construction method based on reservoir parameters |
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