CN104278980A - Method for optimizing compact oil horizontal well seam network parameters by adopting improved volume - Google Patents
Method for optimizing compact oil horizontal well seam network parameters by adopting improved volume Download PDFInfo
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Abstract
The invention discloses a method for optimizing seam network parameters of a compact oil horizontal well by adopting a modified volume, and belongs to the field of compact oil horizontal well reservoirs. Aiming at a compact reservoir, the method firstly evaluates the geological characteristics of the reservoir, defines the specific reservoir conditions of a volume fracture network system formed by volume fracturing, then researches the influence of different modification volumes and seam distribution modes of the volume fracturing of the horizontal well on the productivity, and optimizes specific seam network parameters; the method at least comprises the following steps: 1. establishing a fracture network characteristic comprehensive evaluation basic method for tight reservoir volume fracturing; 2. and establishing a compact oil volume fracturing productivity prediction simulation model method. The parameters of the horizontal well fracture network of the compact oil layer are optimized through the transformation volume formed in the fracturing process, a certain transformation volume is formed in the compact oil layer, the matrix seepage to the shortest distance of the fracture is formed, the driving pressure of effective flowing is greatly reduced, and the flowing under the condition of extremely low permeability is realized. Is beneficial to greatly improving the yield of a single well.
Description
Technical Field
The invention relates to the field of tight oil horizontal well reservoirs, in particular to a method for optimizing tight oil horizontal well seam network parameters by adopting a modification volume.
Background
The compact oil is a compact reservoir oil for short, is an unconventional petroleum resource, and has unconventional reservoir beds such as compact sandstone, marl, dolomite and the like as main occurrence spaces. The unconventional reservoirs have the characteristics of small porosity, low permeability and the like, and generally have no natural capacity or low capacity and great exploration and development difficulty.
In the process of developing a compact oil and gas reservoir, effective stress is increased due to reduction of pore pressure, and deformation and permeability of pores and cracks of reservoir rock are influenced. Aiming at the characteristics of compact reservoir stratum, fine pore throat, strong heterogeneity of oil layer, development of natural crack and complex seepage characteristic of the oil layer. At present, no reference method exists for how to develop crack optimization for the oil layer.
In the prior art, a conventional low-permeability reservoir stratum is adopted to transform a hydraulic fracture optimization method in the early stage, so that the low-permeability reservoir usually adopts a horizontal well fracturing method to improve the productivity of an oil layer, and the fracturing fracture parameters of the horizontal well play a decisive role in the fracturing effect due to the complex geological conditions and the polymorphic fault development. The method for modifying the hydraulic fracture optimizes hydraulic fracture parameters by matching fracture conductivity with reservoir seepage capacity, matching fracture orientation, fracture half-length and well pattern, and the traditional fracture parameter design needs to consider penetration ratio which is generally 0.4-0.7 without factors, so that the fracture parameters cannot be superposed together. The method has good application effect on low-permeability and ultra-low-permeability oil layers with relatively good reservoir seepage capability, and a 'bilinear flow' seepage mode from the oil layer to the fracture and from the fracture to the shaft is formed in the reservoir.
However, for dense reservoir oil, due to the reasons of reservoir natural fracture development, reservoir compactness, complex seepage characteristics and the like, the method is not suitable for improving hydraulic fracture optimization by adopting a traditional low-permeability oil layer, and field tests show that the single-well yield of a dense oil horizontal well is improved by adopting the traditional method in a small range, so that the economic and effective development of the dense oil is difficult to realize.
Disclosure of Invention
In order to solve the problems in the prior art, the embodiment of the invention provides a method for optimizing the seam network parameters of a compact oil horizontal well by adopting a modified volume. A certain transformation volume is formed in the compact oil layer, the seam network parameters are optimized according to the optimal transformation volume target, the shortest distance seepage from the matrix to the cracks is formed, the driving pressure of effective flowing is greatly reduced, the flowing under the condition of extremely low permeability is realized, and the economic and effective development of the compact oil is favorably realized. The technical scheme is as follows:
a method for optimizing seam network parameters of a compact oil horizontal well by adopting a modified volume comprises the steps of firstly evaluating geological characteristics of a reservoir, defining specific reservoir conditions of a volume seam network system formed by volume fracturing, then researching the influence of different modified volumes and seam distribution modes of the volume fracturing of the horizontal well on productivity, and optimizing specific seam network parameters; the method at least comprises the following steps: 1. establishing a fracture network characteristic comprehensive evaluation basic method for tight reservoir volume fracturing; 2. and establishing a compact oil volume fracturing productivity prediction simulation model method.
Specifically, 1, establishing a fracture network characteristic comprehensive evaluation basic method for tight reservoir volume fracturing; establishing fracture network characteristics of volume fracturing through reservoir characteristics and fracture evaluation in a research area; the method at least comprises the following steps: step 1) evaluating natural fracture characteristics; step 2), evaluating rock fracture characteristics; step 3) stress field and change evaluation thereof; and 4) testing and evaluating the field crack.
The step 1) natural fracture characteristic evaluation;
evaluating the natural fracture characteristics of the reservoir by means of field outcrop observation, core description and imaging logging interpretation, and integrating the natural fracture occurrence characteristics and rock mechanical characteristics to conclude that the natural fracture has influence on hydraulic fracture extension;
step 2), evaluating rock fracture characteristics;
by evaluating the rock fracture characteristics, the reservoir rock brittleness is concluded to be strong, the reservoir is broken through volume fracturing to form a fault fracture, a slip fracture and a shear fracture, and a volume transformation foundation is formed in the reservoir;
step 3) stress field and change evaluation thereof;
a) by evaluating the stress characteristics of reservoir rock, the conclusion is that the difference of the horizontal two-direction stress of the reservoir is not large and is smaller than the stress difference of the reservoir layer, and branch seams can be generated in an oil layer to form a seam network to a certain degree;
b) the evaluation of the effect of the hydraulic fracturing induced additional stress on the original stress field concludes that an induced stress field is generated near the wall surface of the crack during hydraulic fracturing, and when the induced stress difference reaches a certain degree, the two-way stress difference is reduced, which is beneficial to forming a complex crack network;
c) after the induced additional stress is generated by fracturing the compact reservoir, the horizontal stress difference near the crack is 0.2-3.6MPa, which is beneficial to changing the direction of the crack and generating a crack network;
step 4), testing and evaluating the field crack;
the seam network characteristics are evaluated through underground micro-seismic real-time monitoring, and the conclusion is that a more complex seam network system can be generated through compact reservoir volume fracturing, and a larger-range reconstructed volume foundation is formed through volume fracturing;
the fracture network characteristic comprehensive evaluation foundation formed in each step can easily open natural fractures when hydraulic fractures meet the natural fractures when tight reservoir fracturing is realized, and a network system of artificial fractures and natural fractures is formed.
Specifically, 2, establishing a compact oil volume fracturing productivity prediction simulation model method; the method comprises the steps of optimizing the modification volume and optimizing the fracture distribution mode, the fracture net bandwidth and the parameters of the long fracture net with the horizontal well volume fracturing modification volume through the influence of the horizontal well volume fracturing modification volume on the extraction degree under the specific well pattern condition; the method at least comprises the following steps: step 1), modification volume optimization; step 2), optimizing a cloth sewing mode; step 3), optimizing the sewing parameters; and 4) testing the field crack.
The step 1) transformation volume optimization; establishing a volume fracturing productivity prediction simulation model by combining the characteristics of a compact reservoir, and optimizing the modification volume according to the influence of different well pattern conditions and different modification volumes on the extraction degree; establishing a seam network dual-medium model;
the theoretical model includes the following equations:
(1) flow equation:
in formula (1):
v represents the seepage velocity, K represents the permeability, P represents the pressure, μ represents the fluid viscosity;
(2) the state equation is as follows:
ρ=ρoexp(1+CLP)
in formula (2):
ρ represents the fluid density, C represents the compressibility, and P represents the pressure;
(3) continuity equation:
in formula (3):
phi represents porosity, C represents a compression coefficient, P represents pressure, K represents permeability, mu represents fluid viscosity, and alpha is a parameter related to specific surface and pore structure of the rock and represents characteristics of fractured rock;
the subscript m denotes the parameters of the matrix (matrix) and the subscript f denotes the parameters of the fracture (fracture).
Further, the typical parameters for establishing the seam-net dual-medium model are as follows: the porosity phi of the oil layer is 9 percent, the permeability K of the oil layer is 0.1-0.3mD, the original formation pressure P in the middle of the oil layer is 16-18MP, the pressure coefficient is 0.75-0.85, the viscosity mu of the underground crude oil is 0.7-0.8mPa.s, and the original dissolved oil-gas ratio is 75.7m3T, crude compression coefficient C of 14-16X 10-4/MPa。
The cloth sewing mode in the step 2) is optimized; according to a numerical model established under the optimal reconstruction volume, aiming at the influence of the volume fracturing of the horizontal well under different well pattern modes of natural energy exploitation on the exploitation degree, combining the influence of the length and width parameters of the seam network on the yield, and optimizing to form a) a staggered seam arrangement mode by selecting different seam arrangement modes; b) dumbbell type staggered cloth sewing mode.
The a) staggered seam distribution mode is formed by optimizing a natural energy well pattern; generating multiple cracks by artificial fracturing aiming at a natural energy well pattern, and then carrying out fracturing mesh weaving; and all the adjacent upper and lower n layers of matrix rock mass systems in the horizontal direction form a staggered seam distribution structure between the adjacent vertical seam systems to form a multi-seam network system.
B) a dumbbell type staggered cloth sewing mode; between the adjacent vertical direction crack systems, the middle parts of the upper and lower n layers of matrix rock mass systems in the adjacent horizontal direction form dumbbell type staggered seam distribution structures to form a multi-seam network system.
Step 3), optimizing the sewing parameters; under the optimal reconstruction volume, seam net belt length and width parameters are respectively optimized according to the influences of different seam net belt lengths, different belt widths and different fracturing segment numbers on the extraction degree, so that a method for optimizing seam net parameter superposition according to the reconstruction volume is formed; a) staggered cloth seam mode and b) dumbbell type intersectionThe staggered seam distribution mode is adopted, and the yield of the fractured horizontal well of the low-permeability oilfield is predicted by simultaneous solving of a flow equation, a state equation and a continuity equation of a capacity formula when the fractures are vertical to the horizontal well; for the interlaced portion, by increasing the scale of construction, the liquid amount is 500m3Above, the discharge capacity is 6m3And more than min, obtaining the optimized seam net superposition effect.
The step 4) testing the field crack; and optimizing the seam network parameters through a transformation volume target formed in a compact oil layer in a research area to form the shortest distance seepage of the matrix to the cracks.
The technical scheme provided by the embodiment of the invention has the following beneficial effects:
the embodiment of the invention provides a method for optimizing parameters of a horizontal well fracture network of a compact oil layer by using a 'transformation volume' formed in fracturing aiming at the characteristics of the compact oil layer. The method changes the traditional fracturing optimization design concept of the low-permeability reservoir, forms a certain transformation volume in the compact oil layer, provides a set of method with strong adaptability for the optimization of the compact oil layer horizontal well volume fracture network parameters, and makes up the problem that the conventional optimization method for the fracture network parameters of the low-permeability reservoir is not suitable. Is beneficial to greatly improving the yield of a single well.
Drawings
In order to more clearly illustrate the technical solutions in the embodiments of the present invention, the drawings needed to be used in the description of the embodiments will be briefly introduced below, and it is obvious that the drawings in the following description are only some embodiments of the present invention, and it is obvious for those skilled in the art to obtain other drawings based on these drawings without creative efforts.
FIG. 1 is a flow chart of a method for optimizing tight oil horizontal well seam network parameters by using a modification volume according to an embodiment of the present invention;
FIG. 2 is a schematic diagram of a modified volume optimization elevation structure in the method for optimizing tight oil horizontal well seam network parameters by using modified volume according to the embodiment of the present invention;
FIG. 3 is a schematic diagram illustrating a principle of modification volume optimization in a method for optimizing a tight oil horizontal well gap network parameter by using a modification volume according to an embodiment of the present invention;
FIG. 4 is a schematic structural diagram of a staggered seam distribution mode in the method for optimizing parameters of a seam network of a compact oil-water horizontal well by adopting a modification volume according to the embodiment of the invention;
FIG. 5 is a schematic illustration of a simulated interlaced seam result of the seam web of FIG. 4 in accordance with an embodiment of the present invention;
FIG. 6 is a schematic structural diagram of a dumbbell-type staggered seam distribution manner in the method for optimizing parameters of a tight oil-water horizontal well seam network by adopting a modified volume according to the embodiment of the invention;
fig. 7 is a schematic diagram of a simulated seam net overlapping seam distribution result of fig. 6 according to an embodiment of the present invention.
The symbols in the drawings represent the following meanings:
1 wellbore, 2 matrix rock system, 3 fracture system,
the direction of the arrows in the figure is the direction of flow channeling of the matrix and the fracture.
Detailed Description
In order to make the objects, technical solutions and advantages of the present invention more apparent, embodiments of the present invention will be described in detail with reference to the accompanying drawings.
Referring to fig. 1, the embodiment of the invention provides a method for optimizing compact oil-horizontal well fracture network parameters by using a modification volume, aiming at the problems that the conventional low-permeability oil layer fracturing fracture parameter optimization method is not suitable for reservoir modification of a compact oil layer horizontal well and the yield of a single well is improved by a small extent. Aiming at a compact reservoir, the method firstly evaluates the geological characteristics of the reservoir, defines the specific reservoir conditions of a volume fracture network system formed by volume fracturing, then researches the influence of different modification volumes and seam distribution modes of the volume fracturing of the horizontal well on the productivity, and optimizes specific seam network parameters. The method mainly comprises the following steps: 1. establishing a fracture network characteristic comprehensive evaluation basic method for tight reservoir volume fracturing; 2. establishing a compact oil volume fracturing productivity prediction simulation model method.
1. Establishing a fracture network characteristic comprehensive evaluation basic method for tight reservoir volume fracturing; the fracture network characteristics of volume fracturing are established through reservoir characteristics and fracture evaluation of a research area. In particular, the method comprises at least: step 1) evaluating natural fracture characteristics; step 2), evaluating rock fracture characteristics; step 3) stress field and change evaluation thereof; step 4), testing and evaluating the field crack; wherein,
step 1) evaluating natural fracture characteristics;
evaluating the natural fracture characteristics of the reservoir by means of field outcrop observation, core description and imaging logging interpretation, and integrating the natural fracture occurrence characteristics and rock mechanical characteristics to conclude that the natural fracture has influence on hydraulic fracture extension;
step 2), evaluating rock fracture characteristics;
by evaluating the rock fracture characteristics, the conclusion is that the rock brittleness of the reservoir is high, the reservoir can be broken through volume fracturing to form a fault fracture, a slip fracture and a shear fracture, and artificial permeability is formed in the reservoir, so that a certain volume transformation foundation is formed;
step 3) stress field and change evaluation thereof;
a) by evaluating the stress characteristics of reservoir rock, the conclusion is that the difference of the horizontal two-direction stress of the reservoir is not large and is smaller than the stress difference of the reservoir layer, and branch seams can be generated in an oil layer to form a seam network to a certain degree;
b) the evaluation of the effect of the hydraulic fracturing induced additional stress on the original stress field concludes that an induced stress field is generated near the wall surface of the crack during hydraulic fracturing, and when the induced stress difference reaches a certain degree, the two-way stress difference is reduced, which is beneficial to forming a complex crack network;
c) after the induced additional stress is generated by fracturing the compact reservoir, the horizontal stress difference near the crack is 0.2-3.6MPa, which is beneficial to changing the direction of the crack and generating a crack network;
step 4), testing and evaluating the field crack;
the seam network characteristics are evaluated through underground micro-seismic real-time monitoring, and the conclusion is that a more complex seam network system can be generated through compact reservoir volume fracturing, and a larger-range reconstructed volume foundation is formed through volume fracturing.
The comprehensive evaluation foundation of the fracture network characteristics formed in the steps realizes that when the compact reservoir fracturing is realized, the natural fracture can be easily opened when the hydraulic fracture meets the natural fracture, and a network system of artificial fractures and natural fractures is formed.
2. Establishing a compact oil volume fracturing productivity prediction simulation model method; under the condition of a specific well pattern, the horizontal well volume fracturing reconstruction volume influences the extraction degree, the reconstruction volume is optimized, and the horizontal well volume fracturing seam distribution mode, the seam net bandwidth, the belt length and other seam net parameters are optimized according to the optimal reconstruction volume. In particular, the method comprises at least: step 1), modification volume optimization; step 2), optimizing a cloth sewing mode; step 3), optimizing the sewing parameters; step 4), testing the field crack; wherein,
step 1), modification volume optimization; establishing a volume fracturing productivity prediction simulation model by combining the characteristics of compact reservoirs in a research area, and optimizing the transformation volume according to the influence of different transformation volumes on the extraction degree under different well pattern conditions;
referring to fig. 2 and 3, because the net pressure around the wellbore 1 is relatively high, the probability that the matrix rock system 2 around generates the multi-fracture system 3 is high, and matrix and fracture channeling is formed between grids of the adjacent nth matrix rock system 2, so that the conclusion is that a dense reservoir developing from natural fractures has a dual-medium seepage characteristic, and a fracture-network dual-medium model is established based on the oil reservoir characteristic;
the theoretical model includes the following equations:
(1) flow equation:
in formula (1):
v represents the seepage velocity, K represents the permeability, P represents the pressure, μ represents the fluid viscosity;
(2) the state equation is as follows:
ρ=ρoexp(1+CLP)
in formula (2):
ρ represents the fluid density, C represents the compressibility, and P represents the pressure;
(3) continuity equation:
in formula (3):
phi represents porosity, C represents a compression coefficient, P represents pressure, K represents permeability, mu represents fluid viscosity, and alpha is a parameter which is related to specific surface, pore structure and the like of the rock and represents characteristics of fractured rock;
the subscript m denotes the parameters of the matrix (matrix) and the subscript f denotes the parameters of the fracture (fracture).
Typical parameters for establishing a seam network dual medium model are as follows: the porosity phi of the oil layer is 9 percent, the permeability K of the oil layer is 0.1-0.3mD, the original formation pressure P in the middle of the oil layer is 16-18MP (the pressure coefficient is 0.75-0.85), the viscosity mu of the underground crude oil is 0.7-0.8mPa.s, and the original dissolved oil-gas ratio is 75.7m3T, crude compression coefficient C of 14-16X 10-4/MPa。
Step 2), optimizing a cloth sewing mode; according to a numerical model established under the optimal reconstruction volume, aiming at the influence of the volume fracturing of the horizontal well under different well pattern forms such as natural energy exploitation, a five-point well pattern and a seven-point well pattern on the exploitation degree, and combining the influence of parameters such as the length and the width of a seam pattern on the yield, selecting different seam distribution modes, and optimizing to form a) a staggered seam distribution mode; b) a dumbbell type staggered cloth sewing mode;
a) the staggered seam distribution mode is formed by optimizing a natural energy well pattern; referring to FIG. 4, XfThe length of the crack zone; wfThe fracture bandwidth is defined; specifically, multiple fractures are created by artificial fracturing against a natural energy well pattern and then performedAnd in the fracturing mesh, all the adjacent upper and lower n layers of matrix rock mass systems 2 in the horizontal direction form a staggered seam distribution structure between the adjacent vertical direction seam systems 3 to form a multi-seam mesh system.
b) The dumbbell type staggered cloth sewing mode is optimized to form the dumbbell type staggered cloth sewing mode; referring to FIG. 6, XfThe length of the crack zone; wfThe fracture bandwidth is defined; specifically, taking a five-point well pattern as an example, dumbbell-type staggered seam distribution structures are formed between the adjacent vertical seam systems 3 and in the middle of the adjacent upper and lower n layers of matrix rock mass systems 2 in the horizontal direction, so as to form a multi-seam system.
The optimization of the seam distribution mode is to analyze the mechanical conditions of seam net formation by adopting different plane models according to elasticity mechanics for different types of reservoirs; when the net pressure in the crack exceeds the sum of the horizontal principal stress difference and the rock tensile strength during construction, a new crack can be formed on the basis of the original crack, and a crack network is realized.
Step 3), optimizing the sewing parameters; under the optimal reconstruction volume, seam network parameters such as seam network belt length, belt width and the like are respectively optimized according to the influence of different seam network belt lengths, belt widths, fracturing segment numbers and the like on the extraction degree, and a method for optimizing seam network parameters according to the reconstruction volume and superposing the seam network parameters is formed; specifically, a) a staggered seam distribution mode and b) a dumbbell staggered seam distribution mode are adopted, and the yield of the fractured horizontal well of the low-permeability oilfield is generally predicted by adopting a productivity formula (such as formula 1, formula 2 and formula 3 which are solved simultaneously) when the fracture is vertical to the horizontal well; in the development of fractured reservoirs, the fracture drilling rate of a single well directly influences the single well productivity, and a horizontal well can increase the drilling rate of fractures, so that the horizontal well has certain advantages for the exploitation of the fractured reservoirs; through theoretical simulation, the seam net overlapping design to a certain degree is beneficial to improving the yield of the compact oil single well, and the simulation seam net overlapping seam distribution results shown in figures 5 and 7 are shown.
When the construction is carried out on site, the staggered parts can be generally constructed by increasing the construction scale, and the liquid amount is 500m3Above, the discharge capacity is 6m3More than min, etc. to obtainAnd obtaining the optimized seam net superposition effect.
Step 4), testing the field crack;
through the transformation volume formed in the compact oil layer in the research area, the seam network parameters are optimized according to the optimal transformation volume target, the matrix seepage to the shortest distance of the crack is formed, the driving pressure of effective flowing is greatly reduced, and the flowing under the condition of extremely low permeability is realized.
In addition, the embodiment of the invention has the advantage that a method for optimizing the seam network parameters of the compact oil horizontal well by adopting the improved volume obtains a remarkable effect in a field test. At present, in an Ordors basin Ann 83 well region, a 7-layer-long co-occurrence field test horizontal well with 19 wells is adopted, the average single well yield at the initial production stage is 14.2t/d, and the single well yield is 9.4t/d higher than that of a single well in a conventional fracturing optimization design of a horizontal well in the same region and is more than 8-10 times that of a vertical well.
The above description is only for the purpose of illustrating the preferred embodiments of the present invention and is not to be construed as limiting the invention, and any modifications, equivalents, improvements and the like that fall within the spirit and principle of the present invention are intended to be included therein.
Claims (11)
1. A method for optimizing compact oil horizontal well seam network parameters by adopting modified volume is characterized in that aiming at a compact reservoir, the geological characteristics of the reservoir are firstly evaluated, the specific reservoir conditions of a volume seam network system formed by volume fracturing are clarified, then the influence of different modified volumes and seam distribution modes of the volume fracturing of the horizontal well on the productivity is researched, and the specific seam network parameters are optimized; the method at least comprises the following steps: (1) establishing a fracture network characteristic comprehensive evaluation basic method for tight reservoir volume fracturing; (2) and establishing a compact oil volume fracturing productivity prediction simulation model method.
2. The method for optimizing tight oil horizontal well fracture network parameters by adopting the reformed volume according to claim 1 is characterized in that (1) a fracture network characteristic comprehensive evaluation basic method for tight reservoir volume fracturing is established; establishing fracture network characteristics of volume fracturing through reservoir characteristics and fracture evaluation in a research area; the method at least comprises the following steps: step 1) evaluating natural fracture characteristics; step 2), evaluating rock fracture characteristics; step 3) stress field and change evaluation thereof; and 4) testing and evaluating the field crack.
3. The method for optimizing tight oil horizontal well gap net parameters using rebuild volume of claim 2, wherein the method comprises
Step 1) evaluating natural fracture characteristics;
evaluating the natural fracture characteristics of the reservoir by means of field outcrop observation, core description and imaging logging interpretation, and integrating the natural fracture occurrence characteristics and rock mechanical characteristics to conclude that the natural fracture has influence on hydraulic fracture extension;
step 2), evaluating rock fracture characteristics;
by evaluating the rock fracture characteristics, the reservoir rock brittleness is concluded to be strong, the reservoir is broken through volume fracturing to form a fault fracture, a slip fracture and a shear fracture, and a volume transformation foundation is formed in the reservoir;
step 3) stress field and change evaluation thereof;
a) by evaluating the stress characteristics of reservoir rock, the conclusion is that the difference of the horizontal two-direction stress of the reservoir is not large and is smaller than the stress difference of the reservoir layer, and branch seams can be generated in an oil layer to form a seam network to a certain degree;
b) the evaluation of the effect of the hydraulic fracturing induced additional stress on the original stress field concludes that an induced stress field is generated near the wall surface of the crack during hydraulic fracturing, and when the induced stress difference reaches a certain degree, the two-way stress difference is reduced, which is beneficial to forming a complex crack network;
c) after the induced additional stress is generated by fracturing the compact reservoir, the horizontal stress difference near the crack is 0.2-3.6MPa, which is beneficial to changing the direction of the crack and generating a crack network;
step 4), testing and evaluating the field crack;
the seam network characteristics are evaluated through underground micro-seismic real-time monitoring, and the conclusion is that a more complex seam network system can be generated through compact reservoir volume fracturing, and a larger-range reconstructed volume foundation is formed through volume fracturing;
the fracture network characteristic comprehensive evaluation foundation formed in each step can easily open natural fractures when hydraulic fractures meet the natural fractures when tight reservoir fracturing is realized, and a network system of artificial fractures and natural fractures is formed.
4. The method for optimizing tight oil horizontal well fracture network parameters by adopting the reformed volume according to claim 1, wherein (2) a tight oil volume fracturing productivity prediction simulation model method is established; the method comprises the steps of optimizing the modification volume and optimizing the fracture distribution mode, the fracture net bandwidth and the parameters of the long fracture net with the horizontal well volume fracturing modification volume through the influence of the horizontal well volume fracturing modification volume on the extraction degree under the specific well pattern condition; the method at least comprises the following steps: step 1), modification volume optimization; step 2), optimizing a cloth sewing mode; step 3), optimizing the sewing parameters; and 4) testing the field crack.
5. The method for optimizing tight oil horizontal well gap net parameters using rebuild volume of claim 4, wherein the method comprises
Step 1), modification volume optimization; establishing a volume fracturing productivity prediction simulation model by combining the characteristics of a compact reservoir, and optimizing the modification volume according to the influence of different well pattern conditions and different modification volumes on the extraction degree; establishing a seam network dual-medium model;
the theoretical model includes the following equations:
(1) flow equation:
in formula (1):
v represents the seepage velocity, K represents the permeability, P represents the pressure, μ represents the fluid viscosity;
(2) the state equation is as follows:
ρ=ρoexp(1+CLP)
in formula (2):
ρ represents the fluid density, C represents the compressibility, and P represents the pressure;
(3) continuity equation:
in formula (3):
phi represents porosity, C represents a compression coefficient, P represents pressure, K represents permeability, mu represents fluid viscosity, and alpha is a parameter related to specific surface and pore structure of the rock and represents characteristics of fractured rock;
the subscript m denotes the parameters of the matrix (matrix) and the subscript f denotes the parameters of the fracture (fracture).
6. The method for optimizing tight horizontal well seam network parameters by adopting the reformed volume according to claim 5, wherein the typical parameters of the seam network dual medium model are established as follows: the porosity phi of the oil layer is 9 percent, the permeability K of the oil layer is 0.1-0.3mD, the original formation pressure P in the middle of the oil layer is 16-18MP, the pressure coefficient is 0.75-0.85, the viscosity mu of the underground crude oil is 0.7-0.8mPa.s, and the original dissolved oil-gas ratio is 75.7m3T, crude compression coefficient C of 14-16X 10-4/MPa。
7. The method for optimizing tight oil horizontal well seam network parameters by adopting the reformed volume according to claim 4, wherein the step 2) seam distribution mode optimization; according to a numerical model established under the optimal reconstruction volume, aiming at the influence of the volume fracturing of the horizontal well under different well pattern modes of natural energy exploitation on the exploitation degree, combining the influence of the length and width parameters of the seam network on the yield, and optimizing to form a) a staggered seam arrangement mode by selecting different seam arrangement modes; b) dumbbell type staggered cloth sewing mode.
8. The method for optimizing tight oil horizontal well seam network parameters by reforming volume according to claim 7, wherein the a) staggered seam distribution mode is a staggered seam distribution mode optimized and formed for a natural energy well pattern; generating multiple cracks by artificial fracturing aiming at a natural energy well pattern, and then carrying out fracturing mesh weaving; and all the adjacent upper and lower n layers of matrix rock mass systems (2) in the horizontal direction form a staggered seam distribution structure between the adjacent vertical direction seam systems (3) to form a multi-seam network system.
9. The method for improving the parameters of the volumetrically optimized tight oil horizontal well screen according to claim 7, wherein b) the dumbbell type staggered seam distribution mode; between the adjacent vertical direction crack systems (3), the middle parts of the upper and lower n layers of matrix rock mass systems (2) in the adjacent horizontal direction form dumbbell type staggered seam distribution structures to form a multi-seam network system.
10. The method for optimizing tight oil horizontal well seam network parameters by adopting the reformed volume according to claim 4 or 5, wherein the step 3) seam network parameter optimization; under the optimal reconstruction volume, seam net belt length and width parameters are respectively optimized according to the influences of different seam net belt lengths, different belt widths and different fracturing segment numbers on the extraction degree, so that a method for optimizing seam net parameter superposition according to the reconstruction volume is formed; the method comprises the steps that a) a staggered seam distribution mode and b) a dumbbell staggered seam distribution mode are adopted, and a productivity formula (1) flow equation, (2) state equation, (3) continuity equation when a seam is vertical to a horizontal well are simultaneously solved to predict the yield of the low-permeability oilfield fractured horizontal well; for the interlaced portion, by increasing the scale of construction, the liquid amount is 500m3Above, the discharge capacity is 6m3And more than min, obtaining the optimized seam net superposition effect.
11. The method for optimizing tight oil horizontal well seam network parameters using rebuild volume of claim 4, wherein step 4) field fracture testing; and optimizing the seam network parameters through a transformation volume target formed in a compact oil layer in a research area to form the shortest distance seepage of the matrix to the cracks.
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