CN112836442A - Method for determining hydraulic fracture injection amount of old well of shale oil horizontal well pattern - Google Patents
Method for determining hydraulic fracture injection amount of old well of shale oil horizontal well pattern Download PDFInfo
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Abstract
The invention relates to a method for determining the hydraulic fracture injection amount of an old well of a shale oil horizontal well pattern, which comprises the following steps: establishing an initial three-dimensional reservoir model and a three-dimensional geological model containing an old well of a horizontal well and a hydraulic fracture network of the old well, and calculating stratum depletion and ground stress evolution caused by the production of the old well by using a fluid-solid coupling method; and (3) simulating an encrypted well pressure fracture network by adopting an old well liquid injection mode, representing the protection effect of the old well liquid injection on the encrypted well fracturing, taking the stratum void filling amount and the ground stress recovery degree as criteria, ensuring that the inter-well interference effect cannot induce the encrypted well fracturing to cause unfavorable damage to the old well fracture of the horizontal well, and preferably selecting the old well fracture protection liquid injection amount. The method can analyze the geostress deficit and geostress evolution mode induced by old well production, and perform optimal analysis on the injection amount of the old well.
Description
Technical Field
The invention relates to the technical field of yield increase of shale oil reservoir hydraulic fracturing reconstruction, in particular to a method for determining the optimal liquid amount for shale oil horizontal well pattern old well hydraulic fracture liquid injection protection.
Background
Under the background that the dependence of crude oil on the outside continuously rises in China, the unconventional shale oil resource has the characteristics of large ascertained reserves and good exploitation prospect, and has great significance for improving the yield of the crude oil. Compared with a conventional oil and gas reservoir, the permeability of the shale oil reservoir is generally low, industrial oil flow is difficult to form naturally in the process of exploitation, the permeability of an oil reservoir is improved by adopting a mode of tight cutting and fracturing of a tight horizontal well, and a hydraulic fracture network connected with a well shaft of the horizontal well is formed, so that crude oil in a low-permeability reservoir can flow to the well shaft more easily to provide productivity.
The hydraulic fracture network shape is the key for determining the shale oil productivity, and the reservoir stratum stress is an important main control factor for influencing the hydraulic fracture expansion rule. In hydraulic fracturing, the direction of the minimum horizontal principal stress is critical to determine the fracture direction of the fracture. Quantitative representation of the reservoir stratum ground stress field states of each stage of shale oil fracturing and production and the corresponding hydraulic fracture initiation and expansion rules are important means for improving the shale oil production efficiency.
The obvious difference between the encrypted horizontal well and the old horizontal well is that the geomechanical environment in which the old horizontal well is fractured is not influenced by fracturing and production, one or more old horizontal wells exist in the area when the encrypted horizontal well is fractured, and stratum pressure depletion and ground stress spatial and temporal evolution caused by production of the old well both greatly change an in-situ ground stress field of a reservoir, so that the fracturing effect of the encrypted well can be influenced, inter-well interference between the old well and the encrypted well is induced, and well pattern productivity is damaged. By means of old well liquid injection, the method can fill up the stratum defect and partially recover the ground stress state of the reservoir, inhibit the inter-well interference phenomenon induced by the fracturing of the encrypted well, protect the cracks of the old well and the well pattern productivity, and quantitatively calculate the liquid injection amount of the old well is the key for realizing the technology. Therefore, a method for determining the optimal liquid amount for hydraulic fracture liquid injection protection of the shale oil horizontal well pattern old well is needed.
Disclosure of Invention
Aiming at the defects of the prior art, the invention aims to provide an optimal old well protection liquid injection amount analysis method, which can fill up the stratum deficit and partially recover the ground stress state of a reservoir, inhibit the inter-well interference phenomenon induced by the fracturing of an encrypted well, protect the cracks and the well pattern productivity of the old well and quantitatively calculate the liquid injection amount of the old well.
The invention provides a method for determining hydraulic fracture injection amount of an old well of a shale oil horizontal well pattern, which comprises the following steps:
establishing an initial three-dimensional reservoir model and a three-dimensional geological model containing an old well of a horizontal well and a hydraulic fracture network of the old well, and calculating stratum depletion and ground stress evolution caused by the production of the old well by using a fluid-solid coupling method;
and (3) simulating an encrypted well pressure fracture network by adopting an old well liquid injection mode, representing the protection effect of the old well liquid injection on the encrypted well fracturing, taking the stratum void filling amount and the ground stress recovery degree as criteria, ensuring that the inter-well interference effect cannot induce the encrypted well fracturing to cause unfavorable damage to the old well fracture of the horizontal well, and preferably selecting the old well fracture protection liquid injection amount.
According to an embodiment of the present invention, when the fluid-solid coupling method is used for calculation, the method further includes:
fitting the calculated data of stratum deficit and ground stress evolution caused by old well production with field real data, and calibrating the analysis model of the fluid-solid coupling method.
According to an embodiment of the invention, the method further includes analyzing according to the analysis model of the fluid-solid coupling method to obtain formation pressure depletion conditions and ground stress variation conditions under different old well production modes, and obtaining respective three-dimensional formation pressure and three-dimensional ground stress field at each time step.
According to an embodiment of the present invention, in the case of obtaining the three-dimensional formation pressure and the three-dimensional ground stress field at each time step, the method further includes:
preliminarily selecting the well position of the encrypted horizontal well and the position of the hydraulic fracturing section cluster, and further comprising the following steps of:
firstly, carrying out primary selection according to porosity, permeability, saturation and brittleness index parameters obtained by geological engineering integrated evaluation, and preferentially determining a coincidence point of a geological dessert and an engineering dessert;
and preliminarily determining the interval of the hydraulic fracturing segment cluster of the encrypted horizontal well according to the determined stratum pressure deficit range and the ground stress evolution spread range, wherein the screening condition is that the influence of the stratum pressure deficit and the ground stress evolution spread on the interval of the segment cluster is small.
According to one embodiment of the invention, the method further comprises simulating the encrypted well fracture without injecting fluid into the old well, and characterizing the interaction and interference between the old well fracture and the encrypted well fracture; the method is used for simulating the fracturing of the encrypted well under the condition of not adopting the injection of the old well, and comprises the following steps:
selecting a section from the preliminarily selected interval of the encrypted horizontal well and the hydraulic fracturing section cluster to perform fracture initiation-propagation calculation of multiple clusters of hydraulic fractures based on fracture mechanics, analyzing the fracture network occurrence of the encrypted horizontal well hydraulic fractures under various section cluster conditions, and acquiring the interaction condition of the fracture network with old well fractures;
and continuously completing the subsequent calculation of the hydraulic fracture network occurrence of all the to-be-fractured sections of the encrypted well, obtaining the interaction condition of fracture channeling and communication between the old well and the encrypted well, and determining the fracture interference and the inter-well interference degree of the encrypted well under the condition of not using the old well for liquid injection protection.
According to an embodiment of the invention, the method further comprises, without taking old well injection conditions:
and calculating the hydraulic fracture network occurrence at the candidate encrypted well position to obtain the hydraulic fracture network condition between the corresponding encrypted well and the old well, and analyzing the fracture interaction condition.
According to an embodiment of the invention, when the old well injection mode is adopted, old well injection calculation is carried out through an analysis model of the fluid-solid coupling method, the filling effect of the old well injection amount and the injection mode on formation pressure depletion and the ground stress recovery condition are analyzed, and the proportion of the injection amount and the depletion amount is analyzed.
According to an embodiment of the present invention, when the old well injection mode is adopted, the method further includes:
and comprehensively analyzing the inter-well crack communication and interaction characteristics corresponding to various old well injection amounts by referring to the hydraulic seam network condition between the encrypted well and the old well under the condition that the old well injection amount is not adopted, repeatedly optimizing the old well injection amount, and determining the optimal injection amount and injection mode capable of effectively protecting the old well.
In accordance with one embodiment of the present invention, in constructing the three-dimensional reservoir model,
and establishing a three-dimensional reservoir model containing the old well of the horizontal well and the hydraulic fracture network of the old well by using the non-structural grid based on geological data, well body structure data, fracturing segmentation clustering data, construction data and microseism data.
According to one embodiment of the invention, when the three-dimensional geological model is established, the three-dimensional geological model is established on the basis of the three-dimensional reservoir model according to a core experiment and a logging interpretation method of rock mechanics parameters so as to represent formation elasticity characteristics and initial ground stress distribution characteristics.
The method can analyze the geostress deficit and geostress evolution mode induced by old well production, analyze the filling effect and the geostress recovery effect of different old well protection injection quantities on the formation pressure deficit on the basis, and simultaneously can optimally analyze the old well injection quantity by combining with the calculation of fracture occurrence of the encrypted well, thereby providing an optimal old well protection injection quantity analysis method.
Drawings
FIG. 1 is a flow chart of a method of an embodiment of the present invention;
FIG. 2 is a schematic diagram of an old well and an uncracked pattern of wells in accordance with one embodiment of the present invention;
FIG. 3 is a schematic diagram illustrating the interference effect of the infill fracturing on the old well fractures when the old well injection protection is not employed in one embodiment of the present invention;
FIG. 4 is a schematic diagram of the effect of effectively protecting old well fractures from being disturbed by the fractures of the encrypted well after old well injection protection.
Detailed Description
The preferred embodiments of the present invention will be described in detail below with reference to the accompanying drawings so that the objects, features and advantages of the invention can be more clearly understood. It should be understood that the embodiments shown in the drawings are not intended to limit the scope of the present invention, but are merely intended to illustrate the spirit of the technical solution of the present invention.
At present, domestic shale oil faces a severe problem of interwell fracturing interference between an encrypted well and an old well, corresponding old well protection strategies are insufficient, effective old well injection optimization can protect old well cracks from adverse interference of interwell fracturing, horizontal well pattern productivity is protected, and cost reduction and efficiency improvement requirements of domestic shale oil drilling and production at present are met. Due to the fact that formation pore pressure and ground stress evolution are difficult to accurately and quantitatively evaluate, and the filling of old well injection liquid to formation defect and the ground stress recovery effect are difficult to determine. The invention solves the problems and can provide a method for determining the optimal liquid amount for hydraulic fracture liquid injection protection of the shale oil horizontal well pattern old well.
The method can analyze the geostress deficit and geostress evolution mode induced by old well production, analyze the filling effect and the geostress recovery effect of different old well protection injection quantities on the formation pressure deficit on the basis, and simultaneously can perform optimal analysis on the old well injection quantity by combining with the calculation of fracture occurrence of the encrypted well, thereby providing an optimal old well protection injection quantity analysis method.
The invention relates to a method for determining the optimal liquid amount for hydraulic fracture injection protection of an old well of a horizontal well pattern. And then, simulating the fracturing of the encrypted well under the condition of not adopting old well injection liquid, and representing the interaction and interference conditions of the old well fracture and the encrypted well fracture. And simulating the encrypted well pressure fracture network by adopting an old well liquid injection mode, representing the protection effect of old well liquid injection on the encrypted well fracturing, and preferably selecting the old well fracture protection liquid injection amount.
Specifically, according to an embodiment of the present invention, the present invention adopts a geostress spatiotemporal evolution analysis technique and a hydraulic fracture network analysis technique under a complex geostress field to achieve the above object, and the provided technical solution mainly includes the following steps:
step 1: establishing a three-dimensional reservoir model comprising an old well of a horizontal well and a hydraulic fracture network of the old well by using a non-structural grid based on geological data, well structure data, fracturing segmentation clustering data, construction data, micro seismic data and the like;
step 2: on the basis of a reservoir model, a three-dimensional geomechanical model is established according to methods such as a rock core experiment, well logging interpretation of rock mechanical parameters and the like, and elastic characteristics and initial ground stress distribution characteristics of a stratum are represented;
and step 3: based on a three-dimensional reservoir model and a three-dimensional geomechanical model, calculating the change conditions of stratum pressure deficit and ground stress in a three-dimensional space induced by production of an old well along with time by using a fluid-solid coupling analysis method;
and 4, step 4: fitting the calculated old well production data (pressure drop, yield and the like) with the field real data, and calibrating the fluid-solid coupling analysis model in the step 3;
and 5: according to the analysis result, obtaining stratum pressure depletion conditions and ground stress change conditions under different old well production modes, and obtaining respective three-dimensional stratum pressure and three-dimensional ground stress fields of all historical time steps;
step 6: under the respective three-dimensional stratum pressure and three-dimensional ground stress field of each time step, preliminarily selecting a well position of an encrypted horizontal well and a fracturing segment cluster position, and specifically comprising the following two steps of:
step 6 (I): firstly, carrying out primary selection according to parameters such as porosity, permeability, saturation, brittleness index and the like obtained by geological engineering integrated evaluation, and preferentially determining a coincidence point of a geological dessert and an engineering dessert;
step 6 (II): according to the stratum pressure deficit range and the ground stress evolution spread range determined in the step 5, preliminarily determining a hydraulic fracturing segment cluster interval of the encrypted horizontal well, wherein the screening condition is that the influence of the stratum pressure deficit range and the ground stress evolution spread on the segment cluster interval is small
And 7: as a contrast item, when a method for protecting old well injection liquid is not adopted, the interaction condition of the horizontal well fracture and the old well fracture is encrypted, and the method specifically comprises the following two steps:
step 7 (I): selecting a section from the interval of the primarily selected encrypted horizontal well and hydraulic fracturing section clusters in the step 6 to perform fracture initiation-propagation calculation of multiple clusters of hydraulic fractures based on fracture mechanics, analyzing the fracture network occurrence of the encrypted horizontal well hydraulic fractures under various section cluster conditions, and acquiring the interaction condition of the fracture network with old well fractures;
step 7 (II): continuously completing the subsequent hydraulic fracture network occurrence calculation of all the sections to be fractured of the encrypted well, obtaining the interaction condition of fracture channeling and communication between the old well and the encrypted well, and determining the fracture interference and the inter-well interference degree of the encrypted well under the condition of not using the old well for liquid injection protection;
and 8: on the basis of the step 6, old well liquid injection calculation is carried out through a fluid-solid coupling model, the filling effect of the old well liquid injection amount and the liquid injection mode on formation pressure depletion and the ground stress recovery condition are analyzed, and the proportion of the liquid injection amount and the depletion amount is analyzed;
and step 9: under the condition that old well liquid injection is not adopted, hydraulic fracture occurrence calculation which is the same as that in the step 7 is adopted in the candidate encrypted well position, the hydraulic fracture network condition between the corresponding encrypted well and the old well is obtained, and the fracture interaction condition is analyzed;
step 10: and 9, comprehensively analyzing the inter-well crack communication and interaction characteristics corresponding to the injection amount of various old wells, and determining the optimal injection amount and injection mode capable of effectively protecting the old wells.
The invention provides a shale oil reservoir production and fracturing whole-process fluid-solid coupling and hydraulic fracturing numerical simulation process, and innovatively provides a specific application of the process in the aspect of old well liquid injection protection.
According to the method, through a modeling simulation flow, stratum deficit filling and ground stress recovery effects of old well injection in adverse effects of ground stress evolution recovery are represented, and the defect that the traditional calculation method cannot represent the process is overcome.
The invention innovatively provides a method for determining the optimal liquid amount for hydraulic fracture injection protection of an old horizontal well pattern, which takes stratum deficit filling amount and ground stress recovery degree as criteria, ensures that the inter-well interference effect cannot induce the fracturing of an encrypted well to cause unfavorable damage to the old horizontal well fracture, and provides technical support for efficient development of a shale oil encrypted well pattern.
Examples
A method for determining the optimal liquid amount for hydraulic fracture injection protection of an old well of a shale oil horizontal well pattern is shown in figure 1 and comprises the following steps:
1. establishing a three-dimensional oil reservoir model capable of describing reservoir characteristics according to the on-site oil reservoir and construction data, wherein the model comprises an old well horizontal well and an old well fracturing network;
2. establishing a three-dimensional geomechanical model, wherein the distribution condition of rock mechanical properties in a three-dimensional space can be represented;
3. carrying out fluid-solid coupling simulation aiming at an old well horizontal well, calculating a pore pressure field and ground stress evolution characteristics in a three-dimensional space, and describing a stratum depletion condition;
4. historical fitting is carried out on the simulation result in the step 3 and the field pressure drop and yield data, so that the accuracy and reliability of the simulation result are improved;
5. based on the calibrated model in the step 4, obtaining quantitative calculation results of pore pressure fields and ground stress fields under different depletion degrees of the old well;
6. preliminarily selecting a well position of the encrypted well according to geological and engineering survey books, and representing the mutual position relation between the well position and the old well, as shown in figure 2;
7. the control group encrypted well fracture results were obtained without old well injection as shown in fig. 3. Representing the interference characteristics of the fracture of the encrypted well on the fracture of the old well;
8. performing old well liquid injection fluid-solid coupling simulation on an old well to obtain formation pressure deficit filling conditions and ground stress recovery conditions under various liquid injection quantity conditions;
9. carrying out the fracturing simulation of the encrypted well at the candidate well position based on the old well liquid injection fluid-solid coupling simulation, obtaining the characteristics of the cracks of the encrypted well and the cracks of the old well in the old well liquid injection mode, and judging whether the old well liquid injection effectively protects the cracks of the old well from being interfered by the fracturing of the encrypted well;
10. based on old well liquid injection fluid-solid coupling simulation, old well liquid injection amount is repeatedly optimized, so that the fracturing crack of the encrypted well does not interfere with the crack of the old well, the optimal liquid injection amount capable of effectively protecting the crack of the old well is finally obtained, and liquid injection cost and the protection effect of the crack of the old well are considered, as shown in fig. 4.
Technical contents not described in detail in the present invention belong to the well-known techniques of those skilled in the art.
It should be noted that, in this document, the terms "center", "upper", "lower", "left", "right", "vertical", "horizontal", "inner", "outer", etc. indicate orientations or positional relationships based on the orientations or positional relationships shown in the drawings, and are only for convenience of describing the present invention and simplifying the description, but do not indicate or imply that the system or element referred to must have a specific orientation, be constructed and operated in a specific orientation, and thus, should not be construed as limiting the present invention; relational terms such as "first" and "second," and the like, may be used solely to distinguish one entity or action from another entity or action without necessarily requiring or implying any actual such relationship or order between such entities or actions. Also, the terms "comprises," "comprising," or any other variation thereof, are intended to cover a non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements does not include only those elements but may include other elements not expressly listed or inherent to such process, method, article, or apparatus. Without further limitation, an element defined by the phrase "comprising an … …" does not exclude the presence of other identical elements in a process, method, article, or apparatus that comprises the element.
In addition, in the description of the present invention, it should be noted that, unless otherwise explicitly specified or limited, the terms "mounted," "connected," and "connected" are to be construed broadly, and may be, for example, fixedly connected, detachably connected, or integrally connected; can be mechanically or electrically connected; they may be connected directly or indirectly through intervening media, or they may be interconnected between two elements. The specific meanings of the above terms in the present invention can be understood in specific cases to those skilled in the art.
The foregoing embodiments are merely illustrative of the present invention, and various components and devices of the embodiments may be changed or eliminated as desired, not all components shown in the drawings are necessarily required, and the general principles defined herein may be implemented in other embodiments without departing from the spirit or scope of the present application. Therefore, the present application is not limited to the embodiments described herein, and all equivalent changes and modifications based on the technical solutions of the present invention should not be excluded from the scope of the present invention.
Claims (10)
1. A method for determining hydraulic fracture injection quantity of an old well of a shale oil horizontal well pattern is characterized by comprising the following steps:
establishing an initial three-dimensional reservoir model and a three-dimensional geological model containing an old well of a horizontal well and a hydraulic fracture network of the old well, and calculating stratum depletion and ground stress evolution caused by the production of the old well by using a fluid-solid coupling method;
and (3) simulating an encrypted well pressure fracture network by adopting an old well liquid injection mode, representing the protection effect of the old well liquid injection on the encrypted well fracturing, taking the stratum void filling amount and the ground stress recovery degree as criteria, ensuring that the inter-well interference effect cannot induce the encrypted well fracturing to cause unfavorable damage to the old well fracture of the horizontal well, and preferably selecting the old well fracture protection liquid injection amount.
2. The method for determining the hydraulic fracture injection amount of the shale oil horizontal well pattern old well, according to claim 1, wherein when the fluid-solid coupling method is used for calculation, the method further comprises the following steps:
fitting the calculated data of stratum deficit and ground stress evolution caused by old well production with field real data, and calibrating the analysis model of the fluid-solid coupling method.
3. The method for determining the hydraulic fracture injection amount of the shale oil horizontal well pattern old well as claimed in claim 2, wherein the method further comprises analyzing according to an analysis model of the fluid-solid coupling method to obtain a formation pressure depletion condition and a ground stress change condition under different old well production modes, and obtaining a three-dimensional formation pressure and a three-dimensional ground stress field of each time step.
4. The method for determining the hydraulic fracture injection amount of the shale oil horizontal well pattern old well according to claim 3, wherein under the condition that the three-dimensional formation pressure and the three-dimensional ground stress field of each time step are obtained, the method further comprises the following steps:
preliminarily selecting the well position of the encrypted horizontal well and the position of the hydraulic fracturing section cluster, and further comprising the following steps of:
firstly, carrying out primary selection according to porosity, permeability, saturation and brittleness index parameters obtained by geological engineering integrated evaluation, and preferentially determining a coincidence point of a geological dessert and an engineering dessert;
and preliminarily determining the interval of the hydraulic fracturing segment cluster of the encrypted horizontal well according to the determined stratum pressure deficit range and the ground stress evolution spread range, wherein the screening condition is that the influence of the stratum pressure deficit and the ground stress evolution spread on the interval of the segment cluster is small.
5. The method for determining the hydraulic fracture injection amount of the shale oil horizontal well pattern old well is characterized by further comprising simulating the fracturing of the encryption well under the condition that the old well injection liquid is not adopted, and representing the interaction and interference between the old well fracture and the encryption well fracture;
the method is used for simulating the fracturing of the encrypted well under the condition of not adopting the injection of the old well, and comprises the following steps:
selecting a section from the preliminarily selected interval of the encrypted horizontal well and the hydraulic fracturing section cluster to perform fracture initiation-propagation calculation of multiple clusters of hydraulic fractures based on fracture mechanics, analyzing the fracture network occurrence of the encrypted horizontal well hydraulic fractures under various section cluster conditions, and acquiring the interaction condition of the fracture network with old well fractures;
and continuously completing the subsequent calculation of the hydraulic fracture network occurrence of all the to-be-fractured sections of the encrypted well, obtaining the interaction condition of fracture channeling and communication between the old well and the encrypted well, and determining the fracture interference and the inter-well interference degree of the encrypted well under the condition of not using the old well for liquid injection protection.
6. The method for determining the hydraulic fracture injection amount of the shale oil horizontal well pattern old well, as claimed in claim 5, wherein under the condition that old well injection liquid is not adopted, the method further comprises:
and calculating the hydraulic fracture network occurrence at the candidate encrypted well position to obtain the hydraulic fracture network condition between the corresponding encrypted well and the old well, and analyzing the fracture interaction condition.
7. The method for determining the hydraulic fracture injection amount of the shale oil horizontal well pattern old well is characterized in that when the old well injection mode is adopted, old well injection calculation is carried out through an analysis model of the fluid-solid coupling method, the filling effect of the old well injection amount and the injection mode on formation pressure depletion and the ground stress recovery condition are analyzed, and the proportion of the injection amount and the depletion amount is analyzed.
8. The method for determining the hydraulic fracture injection amount of the shale oil horizontal well pattern old well is characterized by further comprising the following steps when the old well injection mode is adopted:
and comprehensively analyzing the inter-well crack communication and interaction characteristics corresponding to various old well injection amounts by referring to the hydraulic seam network condition between the encrypted well and the old well under the condition that the old well injection amount is not adopted, repeatedly optimizing the old well injection amount, and determining the optimal injection amount and injection mode capable of effectively protecting the old well.
9. The method for determining the hydraulic fracture injection amount of the shale oil horizontal well pattern old well according to any one of claims 1 to 4 or 6 to 8, characterized in that when the three-dimensional reservoir model is established,
and establishing a three-dimensional reservoir model containing the old well of the horizontal well and the hydraulic fracture network of the old well by using the non-structural grid based on geological data, well body structure data, fracturing segmentation clustering data, construction data and microseism data.
10. The method for determining the hydraulic fracture injection amount of the shale oil horizontal well pattern old well as claimed in claim 9, wherein when the three-dimensional geological model is established, the three-dimensional geological model is established according to a core experiment and a logging interpretation method of rock mechanical parameters on the basis of the three-dimensional reservoir model so as to represent formation elasticity characteristics and initial ground stress distribution characteristics.
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