CN109268004B - Shale gas reservoir medium structure coupling and seam network state identification method - Google Patents
Shale gas reservoir medium structure coupling and seam network state identification method Download PDFInfo
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- 230000035945 sensitivity Effects 0.000 claims abstract description 36
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Abstract
The invention provides a shale gas reservoir medium structure coupling and seam network shape identification method, and belongs to the technical field of oil and natural gas exploitation. The method comprises the steps of firstly, carrying out a fracturing test on a shale core by utilizing an improved Brazilian fracturing test, and classifying the form of a fracture network; secondly, performing shale matrix-fracture structure and stress sensitivity test on rock cores with different fracture forms; thirdly, solving stress sensitivity constant ranges of different seam net forms according to indoor core data; and finally, drawing a seam net shape judging and identifying plate based on an indoor rock core stress sensitivity experiment and in combination with production practice. The chart can be applied to actual fracturing wells, the fracture morphology is directly judged and identified through real-time effective stress and normalized flow, and the chart has profound significance on implementation effect of shale gas reservoir volume fracturing and establishment and development work system.
Description
Technical Field
The invention relates to the technical field of oil and natural gas exploitation, in particular to a shale gas reservoir medium structure coupling and seam network shape identification method.
Background
In 2017, the dependence of natural gas in China on the outside is as high as 39%, nearly 50% is estimated in 2035, and the country faces a severe oil and gas safety problem. The shale gas reservoir resources in China are rich, and the amount of the resources which can be collected by the shale gas in China is about 36 billion cubic meters and about 20 percent of the whole world in 2017. Compared with foreign shale gas reservoirs, the shale gas reservoir in China has the characteristics of deep burial depth (generally 1500-4000 meters and maximally 6950 meters), low permeability (the permeability is 0.01-1 mD), micro-crack development and complex multi-scale flow mechanism.
Reservoir fracturing modification is a main mode for improving the development effect of shale gas reservoirs, and enables a multi-scale pore network consisting of nano-micron pores, micro fractures and artificial fractures to be formed in the shale reservoirs, so that strong nonlinear flow characteristics exist in the shale gas reservoirs. In the process of exploiting the shale reservoir, the structures of nano-micron pores, micro-cracks and artificial cracks are coupled by a seepage field and a stress field, the mechanism is complex, the nonlinearity is strong, and no technology and method for observing and monitoring the crack morphology exist at present, so that a method for determining the shale gas reservoir multi-medium coupling and the crack network morphology is urgently needed to be established.
Disclosure of Invention
The invention aims to provide a shale gas reservoir medium structure coupling and seam network state identification method.
The method comprises the following steps:
(1) classifying the shapes of the sewing nets: carrying out a fracturing test on the shale core by using an improved Brazilian fracturing test, and dividing the fracture morphology into: a tree-shaped seam net, a feather-shaped seam net, a cluster-shaped seam net and a net-shaped seam net; the improved Brazilian fracturing experiment is a method described in the invention patent of a fracture propagation analysis device and an analysis method of a shale core (CN 201410548672.6);
(2) carrying out shale matrix-fracture structure and stress sensitivity experiment tests: selecting the rock cores with different fracture forms in the step (1), carrying out shale matrix-fracture structure and stress sensitivity experiment tests through a rock core displacement experiment (setting the effective stress range to be 4-22 MPa), and recording rock core permeability and effective stress parameters;
(3) and (3) solving stress sensitivity constants of different seam net forms: fitting experimental data in an exponential function mode according to the permeability and effective stress parameters of the rock cores with different fracture forms under different stress conditions in the step (2), and solving a stress sensitivity constant;
(4) drawing a sewing net shape judgment picture version: and (4) establishing a model of effective stress and production well flow according to the actually measured stress sensitivity constants of the four seam network states obtained in the step (3), and carrying out normalization processing on flow parameters to finally form a seam network state identification chart.
Wherein, the fitting of the experimental data in the form of exponential function in the step (3) is specifically as follows:
according to the method with the effect, the mathematical expression of the change rate of the effective stress and the permeability is as follows:
wherein sigma is overburden formation pressure in MPa, p is reservoir pore pressure in MPa, α is effective stress coefficient, and K is0Rock permeability at effective stress zero, in units of 10-3μm2(ii) a K is the permeability under any formation pressure condition and has the unit of 10-3μm2(ii) a b is stress sensitive constant in Mpa-1Wherein the shale reservoir has a microcrack development characteristic, and α is 1.
The stress sensitivity constant b is the basis for distinguishing the shapes of the seam networks, and since K and Q (gas production in the same day) are positively correlated in the actual production process, namely K/K0 is Q/Q0, the exponential relation between the normalized flow and the effective stress can be obtained; therefore, the process of drawing the slot-net shape judging plate in the step (4) comprises the following steps: and (3) drawing stress sensitivity charts of different slit net shapes based on the indoor core stress sensitivity experiment in the step (2), wherein the abscissa is effective stress, and the ordinate is a normalized flow parameter.
Wherein the normalized flow parameters are the daily gas production rate Q and the daily gas production rate peak value QmaxThe ratio of (a) to (b).
The technical scheme of the invention has the following beneficial effects:
in the scheme, the formed chart can be applied to an actual fracturing well, the fracture morphology is directly judged and identified through real-time effective stress and normalized flow, and the method has profound significance on implementation effect of shale gas reservoir volume fracturing and establishment and development work system.
Drawings
FIG. 1 is a flow chart of a shale gas reservoir medium structure coupling and seam network shape identification method of the present invention;
FIG. 2 is a schematic view of different seam net configurations in the present invention, wherein (a) is a feathered seam net, (b) is a tufted seam net, (c) is a net seam net, and (d) is a tree seam net;
fig. 3 is a stress sensitivity characteristic curve of different slot net shapes.
Detailed Description
In order to make the technical problems, technical solutions and advantages of the present invention more apparent, the following detailed description is given with reference to the accompanying drawings and specific embodiments.
The invention provides a shale gas reservoir medium structure coupling and seam network state identification method.
As shown in fig. 1, the method comprises the following steps:
(1) classifying the shapes of the sewing nets: carrying out a fracturing test on the shale core by using an improved Brazilian fracturing test, and dividing the fracture morphology into: a tree-shaped seam net, a feather-shaped seam net, a cluster-shaped seam net and a net-shaped seam net;
(2) carrying out shale matrix-fracture structure and stress sensitivity experiment tests: selecting the rock cores with different fracture forms in the step (1), carrying out shale matrix-fracture structure and stress sensitivity experiment tests through a rock core displacement experiment, and recording rock core permeability and effective stress parameters;
(3) and (3) solving stress sensitivity constants of different seam net forms: fitting experimental data in an exponential function mode according to the permeability and effective stress parameters of the rock cores with different fracture forms under different stress conditions in the step (2), and solving a stress sensitivity constant;
(4) drawing a sewing net shape judgment picture version: and (4) establishing a model of effective stress and production well flow according to the actually measured stress sensitivity constants of the four seam network states obtained in the step (3), and carrying out normalization processing on flow parameters to finally form a seam network state identification chart.
In the specific design, the method is based on the rock core experiment in a certain shale gas reservoir in China, summarizes the shale gas reservoir medium structure coupling and seam net shape identification method, can quantitatively represent the complex seam net formed after the shale gas reservoir is subjected to volume fracturing, and has great significance for on-site actual development and recovery ratio prediction.
The specific implementation mode is as follows:
(1) shale matrix-fracture structure and stress sensitivity experimental test
Matrix shale stress sensitivity test experiments were conducted at room temperature and pressure using nitrogen as the experimental gas to simulate natural gas. Confining pressure equipment uses a high precision plunger displacement pump. The back pressure control system uses a BP-100 air spring back pressure valve produced by American company and uses a high-precision multi-stage plunger displacement pressure pump for control. The adopted experimental method is a differential pressure-flow method, and the effective stresses selected in the experiment are respectively 4MPa, 5MPa, 7MPa, 9MPa, 11MPa, 13MPa, 16MPa, 19MPa and 22 MPa. The experiment is set with a back pressure of 1MPa and an inlet pressure of 3MPa and kept constant.
The experimental steps are as follows:
① drying the core in an oven at a constant temperature of 70 deg.C for 50h, and measuring basic data such as length, diameter, weight, porosity and permeability;
② putting the rock core into a rock core holder, zeroing the initial value of the instrument, adding confining pressure to 4MPa, and adding back pressure to 1MPa to be unchanged;
③ in the whole experiment process, the injection pressure is kept constant at 3MPa, and a gas single-phase seepage experiment is carried out;
④ recording the permeability of rock sample under initial effective stress when the seepage state is stable, adjusting confining pressure according to the pre-designed effective stress value, recording different permeability K in the confining pressure increasing process, determining different confining pressure effective stress values according to the plan, after reaching the maximum effective stress, gradually reducing pressure according to the pressure point drawn up by the boosting experiment, and determining the permeability, and ending the experiment.
The permeability of the manually fractured rock sample is high, and the experimental error is large by adopting a pressure difference-flow method, so that a covering pressure hole permeability instrument KFSY/T08-055 is adopted for testing, the experimental fluid adopts high-purity nitrogen, and the selected rock core is dried in a constant temperature cabinet for 48 hours at 105 ℃. The pressure difference between the inlet and the outlet is 2MPa, and the pressure difference is measured by 4MPa, 7MPa, 14MPa, 21MPa and 27 MPa. The permeability is likewise dimensionless, i.e. expressed as K/K0，K0For initial permeability, see fig. 2 for details.
Experimental results and discussion:
the shale matrix-fracture structure and stress sensitivity experiment result shows that: the shale permeability has larger change amplitude, the initial permeability is lower, the decline amplitude is larger, which is mainly determined by the pore distribution characteristics of the rock sample, the average pore radius of the rock sample with lower permeability is smaller, when the effective stress changes, the small pores are easy to close, thereby leading to the decline of permeability, and the stress sensitivity phenomenon is easier to generate relative to the rock sample with high permeability.
And fitting the experimental curve data, wherein the effective stress and the permeability change rate have a good exponential relationship according to an effective method. The mathematical expression is as follows:
wherein sigma is overburden formation pressure in MPa, p is reservoir pore pressure in MPa, α is effective stress coefficient, and K is0Rock permeability at effective stress zero, in units of 10-3μm2(ii) a K is the permeability under any formation pressure condition and has the unit of 10-3μm2(ii) a b is stress sensitive constant in Mpa-1N.r. warlinski and l.w.teufel in 1992 experimentally given the effective stress coefficients of different porous media, consider a reservoir with fracture development, α → 1. shale reservoir has microfracture development characteristics, therefore α is approximately equal to 1.
Under the condition of a gas reservoir, under the influence of rock pressure of an overlying stratum, pores of the reservoir are in a compressed state, after the reservoir is separated from the gas reservoir condition, the pressure borne by a rock framework is relieved, and partial pore channels in the reservoir are opened or enlarged. The condition of a real reservoir stratum cannot be reflected in a low effective stress region in an experiment, and if the reservoir stratum is evaluated, the stress sensitivity of the shale gas reservoir is tested by taking the initial effective pressure of an original stratum as a starting point. The reservoir burial depth of the target area is about 1600m, the overlying formation pressure and the pore pressure of the shale reservoir are respectively about 34MPa and 25MPa according to the information of field formation testing, well logging and the like, and therefore the effective pressure of 9MPa is selected as the effective stress starting point of the reservoir to be evaluated.
All experimental points of the shale rock sample are summed up to be storedThe permeability with the layer effective stress as a starting point is fitted with the effective stress through an exponential function, and an exponential term coefficient in the formula is a stress sensitive constant. The stress sensitivity constant is a parameter reflecting the deformation degree of the porous medium along with stress, and is related to the physical properties of the rock and the fracture network form. The stress sensitivity constant is 0.101MPa calculated based on all experimental points-1～0.322MPa-1(ii) a The stress sensitivity constant ranges for different seam net forms are shown in table 1.
TABLE 1 corresponding table of different seam net forms and stress sensitivity constants
The analysis is carried out from four different slot-net shapes, namely feather-shaped slots, cluster-shaped slots, net-shaped slots and tree-shaped slots, and is shown in detail in figure 3. The chart can be applied to actual fracturing wells, and the fracture form can be directly judged and identified through real-time effective stress and normalized flow.
Application example:
aiming at a horizontal well of a shale gas reservoir in Chongqing, the burial depth is 1600m, the initial pressure of a stratum is 35MPa, and the daily gas production at the initial stage of volume fracturing is 20 ten thousand square. At present, the daily gas production is 2 ten thousand square, and the bottom hole flowing pressure is 15 MPa.
The effective stress of the stratum rock is 20MPa according to the conversion of the original stratum pressure and the bottom hole flowing pressure, and the daily gas production is reduced by 90 percent at present, namely Q/Qmax0.1, the stress sensitivity constant is 0.1151. The stress sensitivity constant range table is determined to be a tree-shaped seam network, the conclusion can be directly judged that the fracture network is in the shape of the tree-shaped seam network, and the stress sensitivity constant does not need to be calculated again.
While the foregoing is directed to the preferred embodiment of the present invention, it will be understood by those skilled in the art that various changes and modifications may be made without departing from the spirit and scope of the invention as defined in the appended claims.
Claims (3)
1. A shale gas reservoir medium structure coupling and seam network state identification method is characterized by comprising the following steps: the method comprises the following steps:
(1) classifying the shapes of the sewing nets: carrying out a fracturing test on the shale core by using an improved Brazilian fracturing test, and dividing the fracture morphology into: a tree-shaped seam net, a feather-shaped seam net, a cluster-shaped seam net and a net-shaped seam net;
(2) carrying out shale matrix-fracture structure and stress sensitivity experiment tests: selecting the rock cores with different fracture forms in the step (1), carrying out shale matrix-fracture structure and stress sensitivity experiment tests through a rock core displacement experiment, and recording rock core permeability and effective stress parameters;
(3) and (3) solving stress sensitivity constants of different seam net forms: fitting experimental data in an exponential function mode according to the permeability and effective stress parameters of the rock cores with different fracture forms under different stress conditions in the step (2), and solving a stress sensitivity constant;
(4) drawing a sewing net shape judgment picture version: establishing a model of effective stress and production well flow according to the actually measured stress sensitivity constants of the four seam network states obtained in the step (3), and carrying out normalization processing on flow parameters to finally form a seam network state identification chart;
the process of drawing the slot net shape judging plate in the step (4) comprises the following steps: and (3) drawing stress sensitivity charts of different slit net shapes based on the indoor core stress sensitivity experiment in the step (2), wherein the abscissa is effective stress, and the ordinate is a normalized flow parameter.
2. The shale gas reservoir medium structure coupling and seam network form identification method according to claim 1, wherein: the fitting of the experimental data in the form of an exponential function in the step (3) is specifically as follows:
according to the method with the effect, the mathematical expression of the change rate of the effective stress and the permeability is as follows:
wherein sigma is overburden formation pressure in MPa, p is reservoir pore pressure in MPa, αIs the effective stress coefficient; k0Rock permeability at effective stress zero, in units of 10-3μm2(ii) a K is the permeability under any formation pressure condition and has the unit of 10-3μm2(ii) a b is stress sensitive constant in Mpa-1Wherein the shale reservoir has a microcrack development characteristic, and α is 1.
3. The shale gas reservoir medium structure coupling and seam network form identification method according to claim 1, wherein: the normalized flow parameter is the ratio of the daily gas production to the peak daily gas production.
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