CN114592840B - Temporary plugging fracturing method and application thereof - Google Patents
Temporary plugging fracturing method and application thereof Download PDFInfo
- Publication number
- CN114592840B CN114592840B CN202011399483.9A CN202011399483A CN114592840B CN 114592840 B CN114592840 B CN 114592840B CN 202011399483 A CN202011399483 A CN 202011399483A CN 114592840 B CN114592840 B CN 114592840B
- Authority
- CN
- China
- Prior art keywords
- temporary plugging
- fracturing
- natural
- unit
- fracture
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Active
Links
- 238000000034 method Methods 0.000 title claims abstract description 189
- 239000000463 material Substances 0.000 claims abstract description 245
- 238000010276 construction Methods 0.000 claims abstract description 64
- 238000004088 simulation Methods 0.000 claims abstract description 10
- 230000006378 damage Effects 0.000 claims description 56
- 238000006073 displacement reaction Methods 0.000 claims description 46
- 239000012530 fluid Substances 0.000 claims description 44
- 238000004364 calculation method Methods 0.000 claims description 43
- 230000035699 permeability Effects 0.000 claims description 37
- 239000011148 porous material Substances 0.000 claims description 35
- 230000000903 blocking effect Effects 0.000 claims description 26
- 239000007788 liquid Substances 0.000 claims description 16
- 239000011435 rock Substances 0.000 claims description 15
- 238000010008 shearing Methods 0.000 claims description 12
- 239000002245 particle Substances 0.000 claims description 10
- 230000000977 initiatory effect Effects 0.000 claims description 8
- 238000003384 imaging method Methods 0.000 claims description 7
- 239000011159 matrix material Substances 0.000 claims description 7
- 230000009471 action Effects 0.000 claims description 5
- 238000013461 design Methods 0.000 claims description 5
- 240000002044 Rhizophora apiculata Species 0.000 claims description 4
- 208000027418 Wounds and injury Diseases 0.000 claims description 4
- 239000000835 fiber Substances 0.000 claims description 4
- 208000014674 injury Diseases 0.000 claims description 4
- 238000013459 approach Methods 0.000 claims description 3
- 239000003129 oil well Substances 0.000 claims description 3
- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 claims description 2
- 238000004458 analytical method Methods 0.000 claims description 2
- 239000004576 sand Substances 0.000 claims description 2
- 230000008569 process Effects 0.000 abstract description 21
- 238000004519 manufacturing process Methods 0.000 abstract description 4
- 230000020477 pH reduction Effects 0.000 abstract description 3
- 230000035515 penetration Effects 0.000 abstract description 2
- 206010017076 Fracture Diseases 0.000 description 184
- 208000010392 Bone Fractures Diseases 0.000 description 164
- 238000002474 experimental method Methods 0.000 description 42
- 238000009826 distribution Methods 0.000 description 25
- 238000002347 injection Methods 0.000 description 21
- 239000007924 injection Substances 0.000 description 21
- 238000012360 testing method Methods 0.000 description 18
- 239000007789 gas Substances 0.000 description 12
- 230000000694 effects Effects 0.000 description 10
- 230000000052 comparative effect Effects 0.000 description 8
- 230000001276 controlling effect Effects 0.000 description 6
- 238000005457 optimization Methods 0.000 description 5
- 230000009466 transformation Effects 0.000 description 5
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 5
- 239000002253 acid Substances 0.000 description 4
- 230000015572 biosynthetic process Effects 0.000 description 3
- 230000006872 improvement Effects 0.000 description 3
- 208000002565 Open Fractures Diseases 0.000 description 2
- 238000010586 diagram Methods 0.000 description 2
- 238000003780 insertion Methods 0.000 description 2
- 230000037431 insertion Effects 0.000 description 2
- 239000004973 liquid crystal related substance Substances 0.000 description 2
- 238000005259 measurement Methods 0.000 description 2
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- 238000013508 migration Methods 0.000 description 2
- 230000005012 migration Effects 0.000 description 2
- 239000000203 mixture Substances 0.000 description 2
- 229910001220 stainless steel Inorganic materials 0.000 description 2
- 239000010935 stainless steel Substances 0.000 description 2
- 230000000007 visual effect Effects 0.000 description 2
- 230000009286 beneficial effect Effects 0.000 description 1
- 230000015556 catabolic process Effects 0.000 description 1
- 238000012512 characterization method Methods 0.000 description 1
- 230000007423 decrease Effects 0.000 description 1
- 230000006735 deficit Effects 0.000 description 1
- 238000006731 degradation reaction Methods 0.000 description 1
- 230000032798 delamination Effects 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 230000018109 developmental process Effects 0.000 description 1
- 238000005553 drilling Methods 0.000 description 1
- 239000012467 final product Substances 0.000 description 1
- 239000011521 glass Substances 0.000 description 1
- 230000005764 inhibitory process Effects 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
- 239000005445 natural material Substances 0.000 description 1
- 238000012856 packing Methods 0.000 description 1
- 230000001105 regulatory effect Effects 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 230000011218 segmentation Effects 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
- 238000012800 visualization Methods 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
- E21B43/261—Separate steps of (1) cementing, plugging or consolidating and (2) fracturing or attacking the formation
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/13—Methods or devices for cementing, for plugging holes, crevices, or the like
-
- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06F—ELECTRIC DIGITAL DATA PROCESSING
- G06F30/00—Computer-aided design [CAD]
- G06F30/20—Design optimisation, verification or simulation
Abstract
The invention provides a temporary plugging fracturing method and application thereof, wherein the method comprises the operation of determining the consumption of temporary plugging steering materials and the operation of determining the adding time of the temporary plugging steering materials; the method for determining the consumption of the temporary plugging diversion material considers the existence of natural cracks with different production shapes, considers the influence of the bearing capacity of different temporary plugging diversion materials, and calculates the consumption of the temporary plugging diversion material through a temporary plugging layer penetration model; according to the method for determining the adding time of the temporary plugging diversion material, expansion simulation of plugging dominant cracks of the temporary plugging diversion material is added in multi-cluster crack expansion, and the adding time of the temporary plugging diversion material is determined according to the fracturing results and fracturing forms of the temporary plugging obtained at different adding time of the temporary plugging diversion material. The temporary plugging fracturing method provided by the invention can accurately guide the fracturing acidification construction of the oil-gas well by determining the dosage of the temporary plugging diverting material which accords with the actual construction and determining the adding time of the temporary plugging diverting material in the construction process, thereby effectively improving the yield of the construction well.
Description
Technical Field
The invention relates to the technical field of oil and gas well fracturing construction, in particular to a temporary plugging fracturing method and application thereof during temporary plugging construction in the oil and gas well fracturing construction process.
Background
In multi-layer reservoirs, thicker reservoirs or oil and gas wells of long horizontal well sections, the general construction of one-time fracturing acid fracturing can only reform a certain part of reservoirs, so layering or sectionally reform is needed to ensure that all reservoir layer sections are effectively reformed. The main method at present is mechanical segmentation, and temporary blocking is carried out by using temporary blocking balls to correlation Kong Kongyan. However, mechanical packing operations are complex and time consuming, with a significant risk of delamination for high temperature deep well tools. The temporary plugging ball temporary plugging process is only suitable for oil and gas wells with perforation completion. And the problem can be solved by temporarily plugging the cracks. Although there are many materials for temporary plugging of cracks, the calculation of the dosage is always a difficult problem. Although there are many materials for temporary plugging of cracks, the determination of the timing of the addition thereof has been a difficult problem.
CN109267985a provides a method for controlling the amount of temporary plugging material used in temporary plugging diversion fracturing. The method needs to use the dynamic data of the production of the adjacent well, and does not consider the influence of the natural fracture on the temporary plugging fracturing acid pressure. More importantly, the calculation formula is V temporary plugging material=V Crack and crack +V Fracture fluid loss +V Near wellbore fluid loss It is impossible to block all the volumes of the hydraulic fracture, and the amount calculated by the formula is large. In addition, temporary plugging pressure bearing capacities of different temporary plugging materials are different, and the same formula cannot be adopted for calculation.
CN106194145a provides a multistage temporary plugging depth network acid fracturing method. The method also does not consider the influence of natural fractures on temporary plugging fracturing acid fracturing. The influence of the sizes of the natural cracks and the hydraulic cracks on the consumption of temporary plugging materials is not considered, but the inner diameter and the sectional area of the construction pipe column are considered, and the temporary plugging materials actually need to enter the cracks to play a role.
CN110685657a provides a method for calculating the amount of temporary plugging particles for diverting fracturing. The method is calculated by using a particle bridging theory, and the horizontal migration speed of bridging particles needs to be determined through an indoor experiment, which is not completely matched with the horizontal migration speed of particles in site construction. And is also not suitable for fibrous temporary plugging materials.
CN101553552a and CN104727800a provide a temporary blocking steering material and a method of use, respectively, but neither involves determination of the timing of addition.
CN107090282a provides a mixed temporary plugging material and temporary plugging material mixture, temporary plugging method and application. The method is only described with respect to the timing of the addition of the gel mixture temporary plugging material provided by the method. The conventional temporary plugging materials for the oil and gas well are temporary plugging particles and fibers, and the determination method of the adding time of the temporary plugging particles and fibers is not reported at present.
Disclosure of Invention
In order to solve the problems, the invention aims to provide a temporary plugging fracturing method and application thereof. According to the temporary plugging fracturing method, the dosage of the temporary plugging steering material which accords with actual construction is determined, and meanwhile, the adding time of the temporary plugging steering material in the construction process is determined, so that the fracturing acidification construction of an oil-gas well can be accurately guided, and the yield of a construction well is effectively improved.
In order to solve the problems, the invention provides a temporary plugging fracturing method, which comprises the operation of determining the using amount of temporary plugging steering materials and the operation of determining the adding time of the temporary plugging steering materials;
the method for determining the using amount of the temporary plugging steering material comprises the following steps:
determining reservoir mechanical parameters, describing the number of natural cracks and the occurrence of the natural cracks, and determining the pressure-bearing capacity and the permeability of the temporary plugging layer of the temporary plugging steering material;
determining the size and construction scale of the hydraulic fracture through a fracturing simulation experiment according to the mechanical parameters of the reservoir;
when the number of natural cracks in a reservoir is more than 0, calculating a net pressure critical value required by opening the natural cracks according to the mechanical parameters of the reservoir and the occurrence of the natural cracks, and determining the number of the natural cracks according to the pressure-bearing capacity of the temporary plugging steering material; when the number of natural cracks in the reservoir is 0, calculating a net pressure critical value required by opening a new branch seam according to the mechanical parameters of the reservoir;
When the number of natural cracks in the reservoir is more than 0, calculating the consumption of temporary plugging steering materials required for temporarily plugging the natural cracks and the hydraulic cracks according to the construction scale, the permeability of the temporary plugging layer, the occurrence of the natural cracks, the net pressure critical value required for opening the natural cracks and the number of the natural cracks; when the number of natural cracks in the reservoir = 0, calculating the consumption of temporary plugging steering materials required by temporary plugging hydraulic cracks according to the construction scale, the permeability of the temporary plugging layer and the net pressure critical value required by opening the new branch cracks;
the method for determining the adding time of the temporary plugging steering material comprises the following steps:
s1, defining the fracturing start time as 0, the fracturing total time as T, and designating one time within 0 to T as T (namely, the fracturing total time T comprises two sections of 0 to T time and T to T time);
s2, injecting fluid into the two-dimensional multi-cluster fracture geological model for temporary plugging and fracturing before temporary plugging in the time of 0 to t;
s3, adding temporary plugging steering materials (namely temporary plugging steering materials) at the time t to plug the opened cracks;
s4, injecting residual fluid in the time from T to T for temporary plugging and then fracturing, and finishing the fracturing after temporary plugging;
s5, deriving and analyzing fracturing results and fracturing forms after temporary plugging;
s6, selecting different moments within 0 to T as T, repeating S2 to S5, comparing fracturing results and fracturing forms obtained at different T moments, and determining the T moment with the maximum total length of the cracks and the most uniform corresponding length of each crack, namely the moment when the temporary plugging steering material is added.
In the temporary plugging fracturing method, the method for determining the consumption of the temporary plugging diversion material considers the influence of the existence of natural cracks with different production states and the temporary plugging pressure-bearing capacity of different temporary plugging diversion materials on the consumption of the temporary plugging diversion material, and has the advantages of simple calculation process, accurate result and accordance with the actual situation of temporary plugging; the method for determining the adding time of the temporary plugging steering material utilizes the cohesive zone model to simulate crack expansion, and temporary plugging units in the geological model simulate the diversion effect of the fracturing fluid after segmented temporary plugging, so that the accuracy is high and the practicability is high. In a specific embodiment of the invention, the process of determining the usage amount of the temporary plugging diversion material and the process of determining the adding time of the temporary plugging diversion material are respectively and independently carried out, and the sequence of the two is not limited.
In a specific embodiment of the invention, the amount of temporary plugging diversion material required for temporary plugging of natural fractures and hydraulic fractures can be calculated according to a temporary plugging layer permeability model in combination with a darcy formula. The temporary plugging layer permeability model is as follows:
ΔP’≥P net ，
wherein Δp' is wellbore holding pressure, which is numerically equal to the net pressure in the slot; p (P) net The net pressure threshold required for fracture opening. The meaning of the model formula is: when the well bore pressure is greater than or equal to the net pressure critical value required by crack opening, the natural cracks are communicated or new branch cracks are generated.
In the temporary plugging layer permeability model, the opening of the natural fracture or the new branch joint generally comprises the following processes: increasing filling quantity, reducing the porosity of a temporary plugging layer, reducing permeability, reducing the fluid quantity flowing into a crack, compressing wellbore fluid, and generating wellbore holding pressure delta P '. Fwdarw.delta P'. Gtoreq.P net (net pressure threshold required for fracture opening) → communicate with natural fractures or create new branch fractures. According to the critical value of net pressure required for opening the natural fracture or the new branch fracture, the single-fracture temporary plugging steering material consumption can be calculated through a Darcy formula, and then the temporary plugging main fracture (hydraulic fracture) and the material consumption of the opened natural fracture are calculated.
In the method for determining the consumption of the temporary plugging steering material, the net pressure required by opening the natural fracture refers to the temporary plugging net pressure required by opening the natural fracture of the reservoir rock body containing the natural fracture; the hydraulic fracture refers to a fracture formed by artificial hydraulic fracturing; the net pressure required for opening the new branch crack is the temporary plugging net pressure required for opening the new branch crack after temporarily plugging the hydraulic crack.
In particular embodiments of the invention, in the method of determining the amount of temporary plugging diverting material, the reservoir mechanical parameters generally include maximum horizontal stress, minimum horizontal stress, tensile strength, poisson's ratio, and cohesion. The reservoir mechanics can be obtained by analysis and calculation of logging data by using ground stress continuous section analysis software.
In a specific embodiment of the present invention, in the method for determining the amount of temporary plugging diversion material, the occurrence of the natural fracture may be determined by imaging logging, and generally includes the length of the natural fracture, the width of the natural fracture, and the angle of approach of the natural fracture to the maximum level principal stress. The number of natural fractures is typically determined from imaging logs.
In the specific embodiment of the invention, in the method for determining the consumption of the temporary plugging steering material, the pressure bearing capacity of the temporary plugging steering material and the permeability of the temporary plugging layer are generally determined according to a temporary plugging pressure bearing capacity test experiment.
In a specific embodiment of the present invention, in the method of determining the amount of temporary plugging material, the type of natural fracture opening generally includes tensile failure and shear failure.
In a specific embodiment of the invention, in the method for determining the amount of temporary plugging material, the calculation of the threshold value of the net temporary plugging pressure required for opening the tensile failure of the natural fracture generally follows the W-T rule, i.e. P.gtoreq.sigma n Wherein P is pore pressure of crack near wall surface, unit is MPa, sigma n The unit is MPa for the normal stress acting on the natural fracture surface.
In the specific embodiment of the present invention, in the method for determining the amount of temporary plugging material, the calculation formula of the net pressure critical value required when the tensile failure of the natural fracture is opened is generally:
wherein P is net The unit is MPa for the net pressure critical value required for crack opening; sigma (sigma) H The unit is MPa, which is the maximum horizontal stress; sigma (sigma) h The unit is MPa, which is the minimum horizontal stress; θ is natural crack and sigma H Is a approximation angle of (a); when the pore pressure P of the crack near wall surface meets P more than or equal to P net When the natural fracture is opened, the fracture is opened by the tensile failure.
In a specific embodiment of the present invention, in the method for determining the amount of temporary plugging material, the calculation formula of the net pressure critical value required when the natural fracture tensile failure is opened may be calculated according to the following process:
in general, the pore pressure P of the crack near-wall surface is defined as: p is greater than or equal to sigma n ，
When the hydraulic fracture is intersected with and communicated with the natural fracture, liquid enters the natural fracture, and the critical condition of the pore pressure P of the fracture near the wall surface is P=sigma n ，
Wherein, the calculation formula of P is: p=σ h +P net ，
σ n The calculation formula of (2) is as follows:
p is pore pressure of a near-wall surface of the natural fracture, and the unit is MPa; p (P) net The unit is MPa for the net pressure critical value required for crack opening; sigma (sigma) n The unit is MPa for the normal stress acting on the natural fracture surface; sigma (sigma) H The unit is MPa, which is the maximum horizontal stress; sigma (sigma) h The unit is MPa, which is the minimum horizontal stress; θ is natural crack and sigma H Is a approximation angle of (a); when P is greater than or equal to P net When the natural fracture is opened, the fracture is opened by the tensile failure.
In a specific embodiment of the invention, in the method of determining the amount of temporary plugging material, the calculation of the net pressure at which the shear failure of the natural fracture opens generally follows the molar coulomb criterion, i.eP is pore pressure of a crack near wall surface, and the unit is MPa; sigma (sigma) 0 The cohesion is expressed in MPa; mu (mu) f The friction factor is the friction factor of the natural fracture surface, and is dimensionless; sigma is a shearing force acting on a natural fracture surface and the unit is MPa; sigma (sigma) n The unit is MPa for the normal stress acting on the natural fracture surface.
In a specific embodiment of the present invention, in the method for determining the amount of temporary plugging material, the calculation process of the net pressure when the natural fracture is opened for shear failure may include:
the critical limiting conditions of pore pressure P of the crack near wall surface are as follows:
when the hydraulic fracture is intersected with and communicated with the natural fracture, liquid enters the natural fracture, and the critical limiting condition of the pore pressure P of the near-wall surface of the natural fracture is as follows:
The calculation formula of P is: p=σ h +P net ，
σ n The calculation formula of (2) is as follows:
p is pore pressure of a near-wall surface of the natural fracture, and the unit is MPa; p (P) net The unit is MPa for the critical value of net pressure required for crack opening; sigma (sigma) n The unit is MPa for the normal stress acting on the natural fracture surface; sigma (sigma) H The unit is MPa, which is the maximum horizontal stress; sigma (sigma) h The unit is MPa, which is the minimum horizontal stress; sigma is a shearing force acting on a natural fracture surface and the unit is MPa; θ is natural crack and sigma H Is a approximation angle of (a); sigma (sigma) 0 The cohesion is expressed in MPa; mu (mu) f The friction factor of the natural fracture surface is dimensionless; when P is greater than or equal to P net When the natural fracture is opened, the natural fracture is sheared and destroyed.
In a specific embodiment of the present invention, in the method for determining the amount of temporary plugging material, the critical value of the net pressure required for opening the new branch seam is generally:
P net ＝(σ H -σ h )+S t ，
wherein P is net The unit is MPa for the net pressure critical value required for crack opening; sigma (sigma) H The unit is MPa, which is the maximum horizontal stress; sigma (sigma) h The unit is MPa, which is the minimum horizontal stress; st is the tensile strength of the rock in MPa; when the pore pressure P of the crack near wall surface meets P more than or equal to P net And opening a new branch seam.
In a specific embodiment of the present invention, in the method for determining the amount of temporary plugging diverting material, the net pressure required for the formation of the new branch slits (i.e., the formation of new branch slits by the non-developing rock mass) may be derived from the following mechanical model:
Elliptical cracks in a planar wireless domain, and a long half axis is l f The short half shaft is w, and the compressive stress sigma in the long axis direction of infinity is H Compressive stress sigma in the short axis direction h With uniform pressure P in the seam net (numerically equal to the net pressure threshold required for the new branch seam to open). The boundary conditions of the model are as follows: when y=0, |x|is less than or equal to l f Where sigma y ＝-P net ,σ xy =0; at the position ofWhere sigma x →σ H ,σ y →σ h ,σ xy →0；
According to the solving method of the elastic mechanical plane problem, the stress distribution on the fracture surface can be obtained as follows:
wherein θ is the included angle between the connecting line of any point of the seam boundary and the origin and the positive half axis of x;
factor l f > w, then m.apprxeq.1, so we can get:
σ θ ＝P net -σ h +σ H ，
and according to the elastic failure criteria:
σ θ ＝-S t ，σ θ is the stress on the hydraulic fracture face;
combining the above formulas, the final product is:
P net ＝(σ H -σ h )+S t ，
the rock body is broken to generate a new seam, and the requirement of P is more than or equal to (sigma) H -σ h )+S t That is to say natural fracture non-developing reservoirsAnd forming new branch joints on the rock mass, wherein the requirement that the pore pressure of the near-wall surface of the joint is more than or equal to the sum of the maximum and minimum horizontal stress differences and the tensile strength of the rock is met.
In a specific embodiment of the present invention, in the method for determining the amount of temporary plugging material, the limit conditions of the number of openings of the natural fracture are generally: ΔP is greater than or equal to P net ΔP is the pressure-bearing capacity of the temporary blocking steering material, P net The net pressure required to open a single natural fracture.
In the method for determining the use amount of the temporary plugging steering material, the size (such as height, width and the like) of the hydraulic fracture can be determined by performing fracture simulation by using the reservoir mechanical parameters (such as maximum horizontal stress, minimum horizontal stress, tensile strength, poisson ratio and the like) and combining with the Mangrove fracture design and simulation software (such as Mangrove 1.21 of Mangrove Schlem).
In a specific embodiment of the present invention, in the method for determining a usage amount of a temporary plugging steering material, a calculation formula of the usage amount of the temporary plugging steering material may include:
M＝2M d0 +M d1 +M d2 +…M di ，
m is the total consumption of temporary plugging steering materials, M d0 The amount of temporary plugging steering material required for temporarily plugging a single hydraulic fracture (main fracture), M di The amount of temporary plugging steering material required for temporarily plugging the i-th opened natural crack;
the calculation formula of the consumption of temporary plugging steering materials required by temporarily plugging a single hydraulic fracture or a natural fracture is as follows:
wherein M is d The unit of the using amount of temporary plugging steering materials required for temporarily plugging a single hydraulic fracture or a natural fracture is kg; ρ d For temporary plugging of the apparent density of the steering material, the unit is kg/m 3 ；H f The height of the hydraulic fracture or the natural fracture is m; w (W) f Is hydraulic powerThe width of the crack or natural crack is m; Δp' is the wellbore holding pressure in Pa, and its value is equal to the net pressure threshold required for fracture opening; k (K) d For the permeability of the temporary plugging layer (generally measured according to the temporary plugging pressure bearing capacity experiment), the unit is m 2 The method comprises the steps of carrying out a first treatment on the surface of the Mu is the viscosity of the carrying liquid and the unit is Pa.s; q is the construction displacement (i.e. construction scale), in m 3 /s；
When the number of the opened natural cracks is more than 0, calculating the delta P' adopted by the consumption of temporary plugging steering materials required by temporarily plugging a single hydraulic crack and the natural crack to be equal to the net pressure critical value required by opening the natural crack;
when the number of the opened natural cracks=0, the delta P' adopted for calculating the using amount of temporary plugging steering materials required for temporarily plugging the single hydraulic cracks is equal to the net pressure critical value required for opening the new branch cracks.
In the specific embodiment of the invention, the calculation formula of the amount of temporary plugging steering material required by a single hydraulic fracture or a natural fracture can also be:
M d ＝ρ d ×H f ×W f ×L d
M d the unit of the dosage of temporary plugging steering materials required for temporary plugging of single hydraulic cracks or natural cracks is kg; ρ d For temporary plugging of the apparent density of the steering material, the unit is kg/m 3 ；L d The length of the temporary plugging section of the crack is m; h f The height of the crack is m; w (W) f The width of the crack is m;
l in the above formula d Can be expressed in Darcy's formulaThe delta P 'is the well bore pressure holding unit Pa, and the value of the delta P' is equal to the net pressure critical value required by crack opening; k (K) d For temporary plugging layer permeability, the unit is m 2 The method comprises the steps of carrying out a first treatment on the surface of the Mu is the viscosity of the carrying liquid and the unit is Pa.s; q is construction displacement, the unit is m 3 /s；
When the number of the opened natural cracks is more than 0, calculating the delta P' adopted by the consumption of temporary plugging steering materials required by temporarily plugging a single hydraulic crack and the natural crack to be equal to the net pressure critical value required by opening the natural crack;
when the number of the opened natural cracks=0, the delta P' adopted for calculating the using amount of temporary plugging steering materials required for temporarily plugging the single hydraulic cracks is equal to the net pressure critical value required for opening the new branch cracks.
In a specific embodiment of the present invention, in the method of determining the timing of addition of the temporary plugging diverting material, in S1, the T may be one of 0T (i.e., at the beginning of fracturing), 10% T, 20% T, 30% T, 40% T, 50% T, 60% T, 70% T, 80% T, 90% T, 100% T (i.e., at the completion of fracturing).
In a specific embodiment of the present invention, the method for determining the adding timing of the temporary plugging diversion material may include performing a temporary plugging fracturing experiment in a flow distribution test experimental apparatus in advance according to the adding timing of the temporary plugging diversion material as the time t after the time t is designated in S1, wherein the flow distribution condition of each cluster of cracks before and after temporary plugging is recorded, and then performing S2-S4 of the method. The number of cracks in S2 is equal to the number of cracks in a flow distribution test experimental device, and the fluid flow distribution conditions of the crack distribution of each cluster in S2 and S4 are the same as the flow distribution conditions of the crack distribution of each cluster before temporary plugging and after temporary plugging in a temporary plugging pressure experiment performed in advance.
In a specific embodiment of the present invention, in the method for determining the timing of adding the temporary plugging diversion material, the fracturing result and the fracturing morphology generally refer to the lengths of the multi-cluster cracks and the expansion morphology of the multi-cluster cracks (including uniformity of the cracks and the like).
In a specific embodiment of the present invention, in the method for determining the adding timing of the temporary plugging steering material, in S2, the method for constructing a two-dimensional multi-cluster fracture geologic model generally includes: obtaining geological parameters of a target area and constructing a geological model; and inserting a cohesive unit between matrix units of the geological model, and describing crack initiation and damage by adopting a separation-displacement curve to obtain the two-dimensional multi-cluster crack geological model.
In a specific embodiment of the present invention, in the above method of constructing a two-dimensional multi-cluster fracture geologic model, the geologic model is generally constructed from ABAQUS software (e.g., ABAQUS 6.1 from Dassault Simulia, inc.) in the form of a finite element model composed of a finite element mesh. The geological parameters adopted for constructing the geological model generally comprise maximum principal stress, minimum principal stress, pore pressure, young modulus, poisson ratio, triaxial compressive strength, single cluster perforation number before temporary plugging, injection viscosity, rock tensile strength, rock shear strength, permeability, porosity, producing layer stratum pressure and temporary plugging ball number.
In a specific embodiment of the present invention, the method for constructing a two-dimensional multi-cluster fracture geologic model generally includes inserting a cohesive unit into a matrix unit of the geologic model (the cohesive unit forms a cohesive region model), and determining a damage form (representing initiation of a fracture), a damage evolution rule and a fluid flow rule (representing damage evolution of the fracture) of the cohesive unit after constructing the geologic model, so as to obtain the two-dimensional multi-cluster fracture geologic model.
In the specific embodiment of the invention, in the method for constructing the two-dimensional multi-cluster fracture geologic model, the maximum nominal stress criterion is generally adopted as the initial judgment criterion of the fracture of the cohesive unit, namely when the maximum nominal stress ratio reaches 1, the damage starts, and the expression of the damage form is as follows:
wherein t is n 、t s 、t t Nominal stress normal to the cohesive unit, nominal stress in the first tangential direction and nominal stress in the second tangential direction, in Pa;is the normal critical nominal stress, the first tangential critical nominal stress and the second tangential critical nominal stress of the cohesive unit, and the unit is Pa;<>is a MacAuley operator, expressed as: />
In the specific embodiment of the invention, in the method for constructing the two-dimensional multi-cluster fracture geological model, the property that the damage variable evolves between the beginning and the final failure of the damage is generally adopted as the damage evolution rule of the cohesive unit, and the damage evolution under the combined action of the stretching and the shearing deformation of the cohesive unit is described. For example, ABAQUS software (ABAQUS 6 14.1, which may be from Dassault Simulia) may be employed as the evolution law, using damage variables, which may be defined according to the following expression:
Wherein D is a damage variable,for an effective displacement maximum in the loading history, < > j->For effective displacement at the beginning of injury, +.>Is the effective displacement at the time of final failure.
In a specific embodiment of the present invention, in the method for constructing a two-dimensional multi-cluster fracture geologic model described above, the effective displacement is determined from a normal nominal strain, a first tangential nominal strain, and a second tangential nominal strain of the cohesive unit. Specifically, the effective displacement may be defined by the following expression:
wherein delta m For effective displacement, delta n Nominal strain, delta, being the normal to the cohesive unit s First cut of cohesive unitNominal strain delta of direction t Is the nominal strain of the second tangential direction of the cohesive unit.
In a specific embodiment of the present invention, in the above method of constructing a two-dimensional multi-cluster fracture geologic model, the lateral flow of fluid in the cohesive unit generally satisfies the following equation:
qd＝-k t ▽p，
wherein q is flow, and the unit is m 3 S; d is the gap opening degree, and the unit is m; k (k) t The tangential permeability is given in m 2 The method comprises the steps of carrying out a first treatment on the surface of the P is Hamiltonian of pore pressure of a cohesive unit, namely spatial divergence of pressure, and the unit is Pa; the tangential permeability k t The expression of (c) may be:
d is the gap opening degree, and the unit is m; mu is the viscosity of the fluid in Pa.s.
In a specific embodiment of the present invention, in the above method of constructing a two-dimensional multi-cluster fracture geologic model, fluid normal flow may be allowed by defining the fluid loss coefficient of the porous medium. The normal flow of fluid in the cohesive unit generally satisfies the normal fluid loss equation, and the expression is:
wherein q t 、q b The upper surface flow velocity and the lower surface flow velocity of the cohesive unit in the vertical direction are respectively expressed in m 3 /s；p i Is the internal pressure of the cohesive unit, and the unit is Pa; p is p t 、p b The upper pore pressure and the lower pore pressure of the bonding unit in the vertical direction are respectively Pa; c t 、c b The upper fluid loss coefficient and the lower fluid loss coefficient in the vertical direction of the unit are respectively.
In a specific embodiment of the present invention, in the method for constructing a two-dimensional multi-cluster fracture geologic model, the number of fracture clusters of the two-dimensional multi-cluster fracture geologic model may be 3-7 clusters, preferably 3-5 clusters.
In a specific embodiment of the present invention, the temporary plugging fracturing method may include the steps of:
1. determining reservoir mechanical parameters such as maximum horizontal stress, minimum horizontal stress, tensile strength, poisson ratio, cohesion and the like, and describing the number and the occurrence of natural cracks; meanwhile, determining the pressure bearing capacity and the permeability of a temporary plugging layer of the temporary plugging steering material through a temporary plugging pressure bearing capacity experiment;
2. Determining the length, width and other dimensions of the hydraulic fracture and the construction scale through a fracturing simulation experiment according to the mechanical parameters of the reservoir;
3. (1) when the number of natural cracks in the reservoir is more than 0, calculating net pressure critical values required for opening the natural crack by the tensor damage and opening the natural crack by the shear damage according to the mechanical parameters of the reservoir:
wherein, the net pressure critical value required when the natural fracture tensor damage is opened is:
the net pressure threshold required when the shear failure of a natural fracture opens is:
and then determining the number of the natural cracks according to the pressure bearing capacity of the temporary plugging steering material, wherein the limit conditions of the number of the natural cracks are as follows: ΔP is greater than or equal to P net ΔP is the pressure-bearing capacity of the temporary blocking steering material, P net A net pressure threshold required for natural fracture initiation;
(2) When the number of natural fractures in the reservoir = 0, the net pressure threshold required for the new branch fracture to open is:
P net ＝(σ H -σ h )+S t ；
in the above formula, P net The net pressure critical value required for crack opening is MPa; sigma (sigma) H The unit is MPa, which is the maximum horizontal stress; sigma (sigma) h The unit is MPa, which is the minimum horizontal stress; θ is natural crack and sigma H Is a approximation angle of (a); sigma (sigma) 0 The cohesion is expressed in MPa; mu (mu) f The friction factor of the natural fracture surface is dimensionless; s is S t The tensile strength of the rock is expressed in MPa;
5. the amount of material required to temporarily plug the natural fracture and the hydraulic fracture is calculated according to the following formula:
M＝2M d0 +M d1 +M d2 +…M di ，
wherein M is the total consumption of temporary plugging steering materials, M d0 The amount of temporary plugging steering material required for temporary plugging of hydraulic cracks (main cracks), M di The amount of temporary plugging steering material required for temporarily plugging the i-th opened natural crack;
(1) When the number of the opened natural cracks is more than 0, calculating the material consumption required by temporarily plugging the natural cracks and the hydraulic cracks in the reservoir containing the natural cracks, wherein the calculation formula of the temporary plugging steering material consumption required by temporarily plugging the single hydraulic crack or the natural cracks is as follows:
wherein ρ is d For temporary plugging of the apparent density of the steering material, the unit is kg/m 3 ；H f The height of the hydraulic fracture or the natural fracture is m; w (W) f The width of the hydraulic fracture or the natural fracture is m; Δp' is the wellbore holding pressure in Pa equal to the net pressure threshold required for natural fracture opening; k (K) d For temporary plugging layer permeability, the unit is m 2 The method comprises the steps of carrying out a first treatment on the surface of the Mu is the viscosity of the carrying liquid and the unit is Pa.s; q is displacement, the unit is m 3 /s；
(2) When the number of open natural fractures=0, the amount of material required to temporarily plug the hydraulic fracture in the reservoir without the natural fracture is calculated,
The calculation formula of the consumption of temporary plugging steering materials required by temporarily plugging a single hydraulic fracture or a natural fracture is as follows:
wherein ρ is d For temporary plugging of the apparent density of the steering material, the unit is kg/m 3 ；H f The height of the hydraulic fracture is m; w (W) f The hydraulic fracture width is m; Δp' is the wellbore holding pressure in Pa equal to the net pressure threshold required for opening the new branch joint; k (K) d For temporary plugging layer permeability, the unit is m 2 The method comprises the steps of carrying out a first treatment on the surface of the Mu is the viscosity of the carrying liquid and the unit is Pa.s; q is displacement, the unit is m 3 /s。
6. Obtaining geological parameters of a target area and constructing a geological model;
7. inserting a cohesive unit into a matrix unit of the geological model (the cohesive unit forms a cohesive area model), and determining the damage form, the damage evolution rule and the flow rule of fluid in the cohesive unit to obtain the two-dimensional multi-cluster crack geological model:
the maximum nominal stress criterion is adopted as a crack initial judgment criterion of the cohesive unit, and the damage form of the cohesive unit has the following expression:
wherein t is n 、t s 、t t Nominal stress normal to the cohesive unit, nominal stress in the first tangential direction and nominal stress in the second tangential direction, in Pa;is the normal critical nominal stress, the first tangential critical nominal stress and the second tangential critical nominal stress of the cohesive unit, and the unit is Pa; <>Is a MacAuley operator, expressed as: />
The property that the damage variable evolves between the beginning and the final failure of the damage is taken as a damage evolution rule of the cohesive unit, the damage evolution under the combined action of the stretching and the shearing deformation of the cohesive unit is described, the ABAQUS software (such as ABAQUS6 14.1 of Dassault Simulia) can be used for taking the damage variable as the evolution rule, and the damage variable can be defined according to the following expression:
wherein D is a damage variable,for an effective displacement maximum in the loading history, < > j->For effective displacement at the beginning of injury, +.>Is the effective displacement at the final failure;
the effective displacement described above can be defined by the following expression:
wherein delta m For effective displacement, delta n Nominal strain, delta, being the normal to the cohesive unit s Nominal strain, delta, being the first tangential of the cohesive unit t A nominal strain that is the second tangential of the cohesive unit;
the lateral flow of fluid in the cohesive unit generally satisfies the following equation:
qd＝-k t ▽p，
wherein q is flow, and the unit is m 3 S; d is the gap opening degree, and the unit is m; k (k) t For cuttingPermeability in m 2 The method comprises the steps of carrying out a first treatment on the surface of the P is Hamiltonian of pore pressure of a cohesive unit, namely spatial divergence of pressure, and the unit is Pa;
Wherein the tangential permeability k t The expression of (c) may be:d is the gap opening degree, and the unit is m; mu is the viscosity of the fluid and the unit is Pa.s;
the normal flow of fluid in the cohesive unit generally satisfies the normal fluid loss equation, and the expression is:
wherein q t 、q b The upper surface flow velocity and the lower surface flow velocity of the cohesive unit in the vertical direction are respectively expressed in m 3 /s；p i Is the internal pressure of the cohesive unit, and the unit is Pa; p is p t 、p b The upper pore pressure and the lower pore pressure of the bonding unit are respectively Pa; c t 、c b The upper fluid loss coefficient and the lower fluid loss coefficient of the unit are respectively;
8. defining the fracturing starting time as 0, the fracturing total time as T, and designating one time within 0 to T as T (namely, the fracturing total time T comprises two sections of 0 to T time and T to T time);
9. injecting fluid into the two-dimensional multi-cluster fracture geological model obtained in the step 7 in the time of 0 to t for temporary plugging pre-fracturing; adding temporary plugging steering materials at the time t to plug the opened cracks; injecting residual fluid in the time T to T for temporary plugging and then fracturing; deriving and analyzing the fracturing result and fracturing morphology (comprising the lengths of the multi-cluster cracks and the expansion morphology of the multi-cluster cracks) after temporary plugging;
10. and (3) selecting different moments within 0 to T as T, repeating the step (9), comparing fracturing results and fracturing forms obtained at different T moments, and determining the T moment with the maximum total length of the cracks and the most uniform corresponding length of each crack, namely the moment when the temporary plugging steering material is added.
In the above method, step 1-5 is a method for determining the amount of temporary plugging steering material, and the flow chart of the method may be shown in fig. 1; step 6-10 is a method for determining the adding time of temporary plugging steering materials, and the flow chart of the method can be shown in fig. 2. In particular embodiments of the present invention, steps 1-5 and steps 6-10 may be performed independently and simultaneously, and steps 6-10 may also be performed prior to or subsequent to steps 1-5.
The invention also provides application of the temporary plugging fracturing method in oil and gas well fracturing and acidizing construction. For example, the optimization method can be applied to fracturing and acidizing construction of a reservoir where one or more than two of carbonate rock, shale, volcanic rock, sandstone and sand are combined; the optimization method is suitable for fracturing and acidizing construction of one of an oil well, a gas well and an oil and gas well; the optimization method is suitable for fracturing and acidizing construction of one of a vertical well, a horizontal well and a highly deviated well; meanwhile, the optimization method is suitable for various temporary plugging steering materials, such as temporary plugging particles and temporary plugging fibers.
The invention has the beneficial effects that:
1. in the temporary plugging fracturing method provided by the invention, the temporary plugging layer penetration model is adopted to calculate the consumption of the temporary plugging steering material in the process of determining the consumption of the temporary plugging steering material; the method provided by the invention considers the existence of natural cracks with different occurrence, considers the influence of the bearing capacity of different temporary plugging steering materials, does not need to participate in calculation of the parameter with large uncertainty of the temporary plugging length, has simple calculation process and better accords with the actual situation of temporary plugging construction.
2. In the temporary plugging fracturing method provided by the invention, the expansion simulation of the dominant plugging cracks of the temporary plugging steering material is added in the multi-cluster crack expansion in the process of determining the adding time of the temporary plugging steering material, so that the expansion form characterization of the hydraulic cracks in a geological model is realized; and the time for adding the temporary plugging steering materials can be determined according to the fracturing results and fracturing forms after temporary plugging, which are obtained at the adding time of different temporary plugging steering materials. The optimization method is high in accuracy and strong in practicability, and can be widely applied to fracturing and acidizing construction of oil and gas wells.
3. The temporary plugging fracturing method provided by the invention can accurately guide the fracturing acidification construction of the oil-gas well by determining the dosage of the temporary plugging diverting material which accords with the actual construction and determining the adding time of the temporary plugging diverting material in the construction process, thereby effectively improving the yield of the construction well.
Drawings
FIG. 1 is a schematic flow chart of a method for determining the amount of temporary blocking diverting material according to some embodiments of the present invention.
Fig. 2 is a flow chart of a method for determining timing of addition of a temporary blocking diverting material in some embodiments of the present invention.
Fig. 3 is a measurement result of the difference between the maximum horizontal stress and the minimum horizontal stress in example 1.
Fig. 4 is a measurement result of cohesion in example 1.
FIG. 5 is a graph showing the results of the insertion hole press-bonding units in the matrix unit in example 1.
FIG. 6 is a schematic representation of a two-dimensional multi-cluster fracture geologic model in example 1.
FIG. 7 is a schematic diagram showing the structure of the flow distribution test experimental apparatus in example 1.
FIG. 8 is a graph showing the experimental results of the control group 1 in example 1.
Fig. 9 is a graph of the experimental results of experimental group 1 in example 1.
Fig. 10 is a graph of the experimental results of experimental group 2 in example 1.
FIG. 11 is a graph showing the results of experiment 3 in example 1.
FIG. 12 is a graph showing the results of experiment set 4 in example 1.
Detailed Description
The technical solution of the present invention will be described in detail below for a clearer understanding of technical features, objects and advantageous effects of the present invention, but should not be construed as limiting the scope of the present invention.
Example 1
The embodiment provides a temporary plugging fracturing method, which comprises the operation of determining the using amount of temporary plugging steering materials and the operation of determining the adding time of the temporary plugging steering materials.
1. Determining the consumption of temporary plugging steering materials:
the method for determining the using amount of the temporary plugging steering material comprises the following steps:
1. determining reservoir mechanical parameters: the stress state test result of the A well reservoir section is the maximum horizontal stress sigma H >Vertical stress sigma v >Minimum horizontal stress sigma h Log interpretation sigma H-h 13.1MPa; cohesive force sigma 0 24.1-92.4MPa, and the average value of cohesion is 69.3MPa; friction factor mu of natural fracture surface f 0.89.
2. And (3) depicting the number and the appearance of natural cracks: the A-well reservoir sections 7337-7370m were severely lost, and imaging logs revealed that the reservoir sections 7337-7370m had a natural fracture density of 0.52 per meter, and that the reservoir sections had a total of 17 natural fractures. The average height of the natural cracks is 3m, the width is 3mm, and each natural crack is equal to the maximum horizontal stress sigma H The approximation angle θ of (2) is 0-90 °.
3. Determining the bearing capacity of the temporary plugging steering material:
the process of the indoor temporary plugging experiment is as follows: an annular filling vessel having an inner diameter of 1 inch and an outer diameter of 1.5 inches and a length of 2 inches was prepared, and one end of the annular vessel was welded with a stainless steel mesh having an aperture of 200 mesh and connected to a cylindrical artificial core having a diameter of 1.2 inches and a length of 3 inches.
Particles of temporary plugging diverting material A (density 1200kg/m 3 ) Filled in an annular filling container, and a high-permeability artificial Core is connected to the rear of the flow, and then the Core is placed in a Core holder, and the Core is tested in a Core flow system (model AFS-870 manufactured by Core Lab). And (3) injecting slick water by starting a pump, gradually increasing the pressure along with the injection process, and recording the stable value of the injection pressure as the pressure-bearing capacity of the temporary plugging steering material. And then, under the pressure bearing capacity of the temporary plugging steering material, recording the quantity of slickwater flowing out in a certain time, and calculating the permeability of the temporary plugging layer of the temporary plugging steering material according to a Darcy formula.
Finally, the blocking capacity of the temporary blocking steering material A is 15MPa, and the permeability of the temporary blocking layer of the temporary blocking steering material A is 8.37 multiplied by 10 -10 m 2 。
4. Determining the size of the hydraulic fracture and the construction scale according to the pressure simulation experiment:
under the condition that the natural cracks exist, the crack width of the hydraulic cracks is 3mm and the crack height is 33m calculated through Mangrove1.21 fracturing design and simulation software of the Schlenmez company, the average height of the natural cracks is 3m and the width is 3mm according to imaging logging, and each natural crack is matched with the maximum horizontal stress sigma H The approximation angle theta of (2) is 0-90 DEG, and the temporary plugging construction displacement (construction scale) is 2m 3 /min (i.e. 0.033m 3 The viscosity of the liquid used in the experiment was 32 mPas (i.e., 0.032 Pa.s).
5. The study reservoir of this example contained natural fractures, and therefore calculated the critical net pressure of temporary plugging required for natural fracture initiation:
(1) The critical value of temporary plugging net pressure when the natural fracture is sheared, destroyed and opened is as follows:
wherein P is net The unit is MPa for the net pressure critical value required for crack opening; sigma (sigma) H The unit is MPa, which is the maximum horizontal stress; sigma (sigma) h The unit is MPa, which is the minimum horizontal stress; θ is natural crack and sigma H Is a approximation angle of (a); sigma (sigma) 0 The cohesion is expressed in MPa; mu (mu) f Is the friction factor of the natural fracture surface, and has no dimension.
FIG. 3 is σ H-h Calculation results of net pressure required for shearing and opening of natural fracture when the=13.1 MPa, cohesion of 24.1MPa (low value), 69.3MPa (mean value), 92.4MPa (mean value) and natural fracture approximation angle θ is 0-90 ° respectively. According to the above formula, the temporary plugging net pressure for shearing damage opening of each natural crack is 22.2-116.9MPa, and the pressure bearing capacity of the temporary plugging steering material measured in the step 3 is smaller than the temporary plugging net pressure range required for shearing damage opening of each natural crack, so that the shearing damage of the natural cracks can not be realized.
(2) The critical value of temporary plugging net pressure when the natural fracture is opened by the tensile fracture is as follows:
wherein P is net The net pressure critical value required for crack opening is MPa; sigma (sigma) H The unit is MPa, which is the maximum horizontal stress; sigma (sigma) h The unit is MPa, which is the minimum horizontal stress; θ is natural crack and sigma H Is a constant angle of approximation.
FIG. 4 is σ H-h As shown in fig. 4, the calculation result of the critical net pressure required for the opening of the natural fracture by the open fracture when the natural fracture approach angle θ is 0-90 ° is calculated according to the above formula, among 17 natural fractures, the temporary plugging net pressure for the opening of each natural fracture by the open fracture is 0-13.1MPa, because the pressure bearing capacity of the temporary plugging steering material measured in the step 3 is 15MPa, the whole temporary plugging steering material is larger than the temporary plugging net pressure required by opening the tensile fracture of each natural fracture, 17 natural fractures can be judged to be opened in the tensile fracture mode, and the critical net pressure for opening the tensile fracture mode is uniformly valued to be 13.1MPa.
6. Calculating the temporary plugging hydraulic fracture and the temporary plugging steering material dosage required by the natural fracture in the reservoir with the natural fracture:
temporary plugging steering material dosage M required by temporary plugging of single hydraulic fracture or single natural fracture d Calculated according to the following formula:
ρ d for temporary plugging of the apparent density of the steering material, the unit is kg/m 3 ；H f The height of the crack is m; w (W) f The width of the crack is m; Δp' is the wellbore holding pressure in Pa equal to the net pressure threshold required for natural fracture opening; k (K) d For temporary plugging layer permeability, the unit is m 2 The method comprises the steps of carrying out a first treatment on the surface of the Mu is the viscosity of the carrying liquid and the unit is Pa.s; q is displacement, the unit is m 3 /s。
Substituting the measured values, and calculating the consumption of temporary plugging steering materials required by a single natural crack as follows:
substituting the measured values, and calculating the consumption of temporary plugging steering materials required by the single-wing hydraulic fracture as follows:
7. determining the consumption of each temporary plugging steering material according to a reservoir material combination formula:
according to the calculation result of the step 6, the total amount of temporary plugging steering materials required by 17 natural cracks is 17×0.999=16.98 kg, the hydraulic cracks are double-wing, and the amount of temporary plugging steering materials required by temporary plugging hydraulic cracks is 2×120.9 kg=241.8 kg.
From the above, the amount of temporary plugging steering material required for temporarily plugging the hydraulic fracture is 241.8kg, the amount of temporary plugging steering material required for temporarily plugging 17 natural fractures is 16.98kg, and the total amount of temporary plugging steering material required is 258.78kg.
2. Determining the adding time of the temporary plugging steering material:
the method for determining the adding time of the temporary plugging steering material specifically comprises the following steps:
1. geologic parameters in Table 1 were used to model the geology of the A well reservoir section at the ABQUS14.1 software from Dassault Simulia:
TABLE 1
| Model parameters | Numerical value | Model parameters | Numerical value |
| Maximum principal stress (MPa) | 52 | Viscosity of injection (mPa. S) | 1 |
| Minimum principal stress (MPa) | 47 | Tensile strength of rock (MPa) | 6 |
| Pore pressure (MPa) | 35.125 | Rock shear strength (MPa) | 20 |
| Young's modulus (GPa) | 21.0 | Permeability (mD) | 1 |
| Poisson's ratio | 0.2 | Porosity of the porous body | 0.1 |
| Triaxial compressive Strength (MPa) | 213.9 | Producing layer formation pressure (MPa) | 35.125 |
| Single cluster perforation number before temporary blocking | 12 | Number of temporary plugging balls (number of balls) injected | 30 |
2. The matrix unit in the geological model is inserted into the cohesive unit to represent the expansion of the crack, a cohesive area model simulating the expansion of the crack is constructed by describing the initiation and damage of the crack by adopting a separation-displacement curve, and the damage form, the damage evolution rule and the flow rule of fluid in the cohesive unit are determined, wherein the specific process is as follows:
the maximum nominal stress criterion is adopted, i.e. it is considered that damage starts when the maximum nominal stress reaches 1. The damage forms are as follows:
wherein t is n 、t s 、t t Nominal stress normal to the cohesive unit, nominal stress in the first tangential direction, and nominal stress in the second tangential direction, in Pa, respectively; Is the normal critical nominal stress, the first tangential critical nominal stress and the second tangential critical nominal stress of the cohesive unit, the unit is Pa;<>is a MacAuley operator, expressed as: />
Introducing an effective displacement delta m It is defined as:
wherein delta m For effective displacement, delta n Nominal strain, delta, being the normal to the cohesive unit s Is stickyNominal strain, delta, of first tangential of a poly unit t Is the nominal strain of the second tangential direction of the cohesive unit.
The property that the effective displacement describes the evolution of the damage variable D between the start and the final failure of the damage is utilized to describe the damage evolution under the combined action of the stretching and the shearing deformation of the cohesive unit. For the linear degradation law, ABAQUS uses the impairment variable D as the evolution law, expressed as:
wherein, the liquid crystal display device comprises a liquid crystal display device,for the effective displacement maximum in the loading history, +.>For effective displacement at the beginning of injury, +.>Is the effective displacement at the time of final failure.
The lateral flow pattern of the fluid in the cohesive unit is then defined. The lateral flow of fluid in the cohesive unit satisfies the viscous fluid flow equation: qd= -k t And p, q is the flow in m 3 The ratio of the gap opening degree is represented by the unit of m, the unit of kt is the tangential permeability, and the unit of m 2 V P is Hamiltonian of pore pressure of a cohesive unit, and the unit is Pa;
Wherein the tangential permeability k t The calculation formula of (2) is as follows:d is the gap opening degree, and the unit is m; mu is the viscosity of the fluid in Pa.s.
Fluid flow in the direction perpendicular to the fracture face is mainly a fluid loss process, and fluid normal flow is allowed by defining the fluid loss coefficient of the porous medium.
The fluid loss equation is:
wherein q t 、q b The upper surface flow velocity and the lower surface flow velocity of the cohesive unit in the vertical direction are respectively expressed in m 3 /s；p i Is the internal pressure of the cohesive unit, and the unit is Pa; p is p t 、p b The upper pore pressure and the lower pore pressure of the bonding unit are respectively Pa; c t 、c b The upper fluid loss coefficient and the lower fluid loss coefficient of the cohesive unit are respectively.
The cohesive units (pore-press cohesive units) constructed as described above were inserted in a finite element mesh of a geologic model, resulting in fig. 5. As shown in fig. 5, the insertion process is to insert a pore press-bonding unit between finite element grids (100 m×200m), and the pore press-bonding unit includes displacement nodes and pore press nodes, so that the expansion form of the hydraulic fracture can be effectively represented.
FIG. 6 is a schematic diagram of a two-dimensional multi-cluster fracture geologic model. The length of the model is 100m, the height is 200m, 5 clusters of cracks are distributed, the cluster spacing is 15m, and the number of cluster perforation is 12.
3. And (3) changing the temporary plugging steering material adding moment, performing temporary plugging construction on the two-dimensional multi-cluster fracture geological model in the step (2), deriving and analyzing the fracturing result and the morphology after temporary plugging, comparing the fracturing result and the fracturing morphology obtained at different temporary plugging moments, and determining the temporary plugging moment with the minimum total length of the fracture and the most uniform and corresponding length of each fracture, namely the temporary plugging steering material adding moment. Defining the fracturing starting time as 0, the fracturing total time as T, and designating one time within the time from 0 to T as T. The fracturing experiments without temporary plugging (control group 1) were performed, and t is 30% T, 50% T, 70% T, and 90% T (experimental groups 1-4).
The flow distribution conditions of the cracks of each cluster in each experimental group and each cluster in the comparison group are determined according to temporary plugging fracturing experiments which are performed in the flow distribution test experimental device in advance. The device for carrying out the flow distribution test experiment generally comprises a water tank, a power device, a temporary plugging steering material delivery device and an experiment pipeline. The power device adopts a 700-type fracturing pump, so that the displacement of carrying liquid can be regulated to be 0.26 square/min to 0.53 square/min, and the on-site working condition can be effectively simulated; the temporary plugging steering material delivery device can control the quantity of the temporary plugging steering materials on line; the visual pipe column is adopted in the experimental pipeline, so that the blocking effect and the temporary blocking position of the temporary blocking steering material can be better observed, and meanwhile, the experimental pipeline is divided into 5 clusters, and can be used for simulating 5 clusters of flow distribution. Specifically, the structure of the flow distribution test experimental device is shown in fig. 7, and the device mainly comprises: the device comprises a water tank 1, a high-pressure power device 2, a temporary plugging steering material ball throwing device 3-6 and an experimental pipeline 7-15. When a flow distribution experiment is carried out, the carrying liquid in the water tank 1 is pumped out through the high-pressure power device 2, and then temporary plugging steering materials are delivered into the experiment pipeline 7 by controlling the opening and closing of the four valves of the ball throwing device 3-6. Temporary plugging steering materials in the experimental pipeline 7 enter the visualization tubular column 10 through the pressure gauge 8 and the pressure relief protection valve 9 (can effectively ensure personnel safety and test pressure). The visualized tubular column 10 adopts an organic glass tubular column, perforations 11 are arranged on the wall of the tubular column and are divided into 5 clusters, the perforations 11 are spiral holes for simulating the real perforation azimuth of the site, a pneumatic valve 12 is used for connecting the perforations with a PC tube, and flow meters 13-1 to 13-5 are arranged on the PC tube. The outflow pipe column 14 is an outflow pipe column of each cluster, and the valve 15 is used for pressure relief protection. The temporary plugging diverting material in the visual string 10 enters the PC pipe via the pneumatic valve 12, flows out of the outflow string 14, and the flow distribution of the multi-cluster fracture is recorded by the flowmeters 13-1 to 13-5. The total time of flow distribution experiments was 1200s, and the flow ratio before and after temporary blocking of each cluster recorded by the flow meters on the pipelines of 5 clusters (1, 2, 3, 4 and 5 clusters) was shown in Table 2 for no temporary blocking steering material input and temporary blocking steering material input at 360s,600s,840s and 1080s, respectively, when the experiments were performed by using the displacement of 0.53 square/min.
TABLE 2
The specific procedure for the fracturing simulation for each control/experimental group was as follows:
control group 1: the total injection displacement of the injection fluid in the geologic model of a two-dimensional multi-cluster fracture constructed using the method of example 1 (FIG. 6) was 12m 3 And/min, the total fracturing time is 1200s, each cluster of cracks distributes the amount of injection fluid according to each cluster of cracks before temporary plugging in table 2, and the experimental results obtained by expanding the lengths of the cracks are shown in fig. 8.
As can be seen from fig. 8, the lengths of 5 cracks after the experiment were 98.6m, 76.5m, 23.5m, 76.5m, 98.6m, respectively. The middle crack is severely disturbed by stress and distributed by flow, and is extruded by the side seam, and fluid cannot be uniformly obtained by the middle crack, so that the uneven expansion form of the crack is caused.
Experiment group 1: controlling the total injection displacement to be 12m 3 And/min, wherein the total fracturing time is 1200s. Experiments were performed with 30% of the total fracturing time as the time to add temporary plugging diverting material. The method comprises the following steps: in a two-dimensional multi-cluster fracture geologic model (fig. 6) constructed by the method of example 1, the length of each cluster of fractures distributed and injected with fluid before temporary plugging is expanded within 0-360s according to the results of the flow distribution test experiment of table 2; then adding temporary plugging steering materials at the moment of 360s to realize plugging; the amount of injected fluid distributed by each cluster of cracks after temporary plugging was expanded for a residual length according to the results of the flow distribution test experiments of table 2 within 360s-1200s (840 s total). The experimental results are shown in FIG. 9.
As can be seen from fig. 9, the 5 clusters of cracks have an expanded morphology of 95.6 meters, 78.5 meters, 30.5 meters, 78.5 meters, 95.6 meters, respectively, although the crack morphology is shown as under-developed for the middle (HF 3) and secondary side (HF 2 and HF 4) seams (HF 1 and HF 5) seams; however, compared with the result of comparative example 1, the HF3 inferior crack in this experiment was 30.5 meters, and the HF3 inferior crack in comparative example 1 was expanded to 23.5 meters, which is improved; the crack lengths of HF1 and HF5 were reduced from 98.6 m (comparative example 1) to 95.6 m (this experiment), with some inhibition. The method shows that even reconstruction of the crack can be improved to a certain extent when the temporary plugging time is 360s, the expansion (HF 3) of the middle minor crack is promoted, and the excessive expansion of the side seams (HF 1 and HF 5) and the secondary side seams (HF 2 and HF 4) is restrained.
Experiment group 2: controlling the total injection displacement to be 12m 3 And/min, wherein the total fracturing time is 1200s, and experiments are carried out by selecting 50% of the total fracturing time as the time for adding temporary plugging steering materials. The method comprises the following steps: in a two-dimensional multi-cluster fracture geologic model (fig. 6) constructed by the method of example 1, the length of each cluster of fractures distributed and injected with fluid before temporary plugging is expanded within 0-600s according to the results of the flow distribution test experiment of table 2; then adding temporary plugging steering materials at the moment of 600s to realize plugging; the amount of injected fluid distributed and injected by each cluster of cracks after temporary plugging in the results of the flow distribution test experiment of table 2 was expanded in length within 600s-1200s (total 600 s). The experimental results are shown in FIG. 10.
As can be seen from fig. 10, after the experiment, the 5 cracks are respectively expanded in the form of 93.6 m, 82.5 m, 53.5 m, 82.5 m and 93.6 m, and the improvement degree of the cracks is improved compared with the crack length of comparative example 1, so that the crack length is more uniform.
Experiment group 3: controlling the total injection displacement to be 12m 3 And/min, wherein the total fracturing time is 1200s, and experiments are carried out by selecting 70% of the total fracturing time as the time for adding temporary plugging steering materials. The method comprises the following steps: in a two-dimensional multi-cluster fracture geologic model (fig. 6) constructed by the method of example 1, the length of each cluster of fractures distributed and injected with fluid before temporary plugging is expanded within 0-840s according to the results of the flow distribution test experiment of table 2; then adding temporary plugging steering materials at 840s to realize plugging; the amount of injected fluid distributed and injected by each cluster of cracks after temporary plugging in the results of the flow distribution test experiment of table 2 was extended in length within 840s-1200s (360 s total). The experimental results are shown in FIG. 11.
As can be seen from fig. 11, after the experiment, the 5 cracks were expanded in the form of 97.6 m, 80.5 m, 25.5 m, 80.3 m, and 98 m, respectively, and the improvement degree of the cracks was improved compared with the crack length of comparative example 1, and the crack length was more uniform.
Experiment group 4: controlling the total injection displacement to be 12m 3 Per min, total fracturing time of 1200s, 90% of total fracturing time being selected as adding temporary plugging rotationExperiments were conducted on the timing of the materials. The method comprises the following steps: in a two-dimensional multi-cluster fracture geologic model (fig. 3) constructed by the method of example 1, the length of each cluster of fractures distributed and injected with fluid before temporary plugging is expanded within 0-1080s according to the results of the flow distribution test experiment of table 2; then adding temporary plugging steering materials at 1080s to realize plugging; the amount of injected fluid distributed and injected by each cluster of cracks after temporary plugging in the time of 1080s-1200s (total 120 s) is expanded according to the results of the flow distribution test experiment of table 2. The experimental results are shown in FIG. 12.
As can be seen from fig. 12, the expansion forms of the crack in experiment 5 are 98.0 m, 80.3 m, 24.5 m, 80.3 m and 98 m respectively, and the improvement degree of the crack is improved compared with the crack length in comparative example 1, and the crack length is more uniform.
The length of the longitudinal crack and the uniformity of the expansion of the crack obtained by experiments of the control group 1 and the experimental groups 1-4 are used as indexes of the transformation effect, and the fracture uniformity of the control group 1 can be seen to be worst, and the total transformation length is 373.7m and is lower than that of the experimental groups 1-4 in the embodiment. The experimental results of the experimental groups 1-4 show that as the percentage of time for injecting the temporary plugging diversion material at the total fracturing time increases, the temporary plugging fracturing transformation effect gradually rises and peaks, wherein the temporary plugging fracturing effect is best when the temporary plugging injection time is 50% of the fracturing time (namely, the temporary plugging time is 600s after fracturing), the total fracture transformation length is 405.7 meters, and then the temporary plugging transformation effect begins to decline along with the percentage of the temporary plugging time accounting for the total fracturing time. Therefore, the optimal timing for injecting the temporary plugging diversion material is determined when the temporary plugging diversion material injection time t is 50% T.
3. And (3) carrying out temporary plugging steering at different adding moments according to the calculated temporary plugging steering material consumption, and verifying the construction effect of the fracturing temporary plugging fracturing method in the production well in the well A area:
the horizontal section of the A202H2-1 well is divided into 30 sections for fracturing, 250.9kg of temporary plugging steering material is added when the fracturing time of each section is 50%, temporary plugging steering is carried out, and the yield of the well after construction is 55.5 square/day;
the horizontal section of the A202H2-2 well is divided into 30 sections for fracturing, 250.9kg of temporary plugging steering material is added when the fracturing time of each section is 30%, temporary plugging steering is carried out, and the yield of the well after construction is 38.9 square/day;
the horizontal section of the A202H2-3 well is divided into 30 sections for fracturing, 250.9kg of temporary plugging steering material is added when 70% of the fracturing time of each section is needed for temporary plugging steering, and the yield of the well after construction is 40.5 square/day;
the horizontal section of the A202H2-4 well is divided into 30 sections for fracturing, 250.9kg of temporary plugging steering material is added when 90% of the fracturing time of each section is needed for temporary plugging steering, and the yield of the well after construction is 20.6 square/day;
from the above construction results, it can be seen that the temporary plugging fracturing effect is best when the temporary plugging injection timing is 50% of the fracturing time, which is consistent with the results provided by the timing of temporary plugging diverting material injection determined above.
Example 2
The embodiment provides a temporary plugging fracturing method, which comprises the operations of determining the consumption of temporary plugging steering materials and determining the adding time of the temporary plugging steering materials, and specifically comprises the following steps:
1. determining reservoir mechanical parameters: the stress state test result of the B well reservoir section is the maximum horizontal stress sigma H >Vertical stress sigma v >Minimum horizontal stress sigma h Log interpretation sigma H-h 11.1MPa and 4MPa.
2. And (3) depicting the number and the appearance of natural cracks: no drilling fluid leakage occurs in the reservoir section 6584-6631m of the B well, and the imaging logging reveals that the reservoir section 6584-6631m has no natural fracture development.
3. Determining the bearing capacity of the temporary plugging steering material:
the process of the indoor temporary plugging experiment is as follows: an annular filling vessel having an inner diameter of 1 inch and an outer diameter of 1.5 inches and a length of 2 inches was prepared, and one end of the annular vessel was welded with a stainless steel mesh having an aperture of 200 mesh and connected to a cylindrical artificial core having a diameter of 1.2 inches and a length of 3 inches.
Particles of temporary plugging diverting material B (density 1250kg/m 3 ) Filled in an annular filling container, and connected with the rear part of the flowThe high permeability artificial Core was then placed in a Core holder and tested in a Core flow system (model AFS-870, manufactured by Core Lab). And (3) injecting slick water by starting a pump, gradually increasing the pressure along with the injection process, and recording the stable value of the injection pressure as the pressure-bearing capacity of the temporary plugging steering material. And then, under the pressure bearing capacity of the temporary plugging steering material, recording the quantity of slickwater flowing out in a certain time, and calculating the permeability of the temporary plugging layer of the temporary plugging steering material according to a Darcy formula.
The final blocking capacity of the temporary blocking steering material B is 16.5MPa, and the permeability of the temporary blocking layer of the temporary blocking steering material B is 6.92 multiplied by 10 -10 m 2 。
4. Determining the size of the hydraulic fracture according to a pressure simulation experiment:
the hydraulic fracture is calculated to have a seam width of 5mm, a seam height of 47m and a temporary plugging construction displacement of 6m through Mangrove1.21 fracturing design and simulation software of Schlenmek company 3 /min (i.e. 0.01m 3 The viscosity of the liquid used in the experiment was 65 mPas (i.e., 0.065 Pa.s).
5. The research reservoir of this embodiment does not contain natural cracks, so a new branch joint is calculated to open the temporary plugging net pressure threshold value:
P net ＝(σ H -σ h )+S t ，
in the above formula, P net The unit is MPa for the net pressure critical value required for crack opening; sigma (sigma) H The unit is MPa, which is the maximum horizontal stress; sigma (sigma) h The unit is MPa, which is the minimum horizontal stress; s is S t The tensile strength of the rock is expressed in MPa.
And calculating according to the formula to obtain a net pressure critical value required by opening the new branch joint, wherein the net pressure critical value is 15.1MPa. Under the condition that the pressure bearing capacity of the temporary plugging steering material B is 16.5MPa, the artificial hydraulic fracture can be completely plugged temporarily, and a new branch joint body can be opened.
6. Calculating the consumption of temporary plugging steering materials required for temporary plugging of hydraulic fractures in a reservoir without natural fractures:
Temporary plugging steering material dosage M required by temporary plugging of single hydraulic fracture d Calculated according to the following formula：
ρ d For temporary plugging of the apparent density of the steering material, the unit is kg/m 3 ；L d The length of the temporary plugging section of the crack is m; h f The height of the hydraulic fracture is m; w (W) f The hydraulic fracture width is m; Δp' is the wellbore holding pressure in Pa equal to the net pressure threshold required for opening the new branch joint; k (K) d For temporary plugging layer permeability, the unit is m 2 The method comprises the steps of carrying out a first treatment on the surface of the Mu is the viscosity of the carrying liquid and the unit is Pa.s; q is displacement, the unit is m 3 /s。
Substituting the measured value to calculate the temporary plugging steering material amount M required by the single-wing hydraulic fracture d The method comprises the following steps:
the amount of temporary plugging diverting material required for a two-winged hydraulic fracture is 2 x 111kg = 222kg.
From the above, the amount of temporary plugging steering material required for temporarily plugging the hydraulic fracture is 222kg.
2. The timing of the injection of the temporary plugging diverting material was determined as in the method of determining the timing of the addition of the temporary plugging diverting material in example 1, when the injection timing t of the temporary plugging diverting material was 50% t.
3. 222kg of temporary plugging steering material is added when 50% of the fracturing time of the stratum is reached, temporary plugging steering is carried out, fracturing and acidizing construction is carried out on the well stratum 6584-6631m, and the natural gas yield of the well stratum 6584-6631m after construction is 25.6 square/day.
Comparative example 1
The comparative example provides a temporary plugging fracturing method, which adopts temporary plugging steering materials and construction reservoir sections which are the same as those of the embodiment 1, wherein the method comprises the following steps of determining the consumption of the temporary plugging steering materials:
class 1 of exampleSimilarly, a temporary blocking diverting material A (true density of 1200kg/m 3 Bulk density of 900kg/m 3 ) But its blocking ability and temporary blocking layer permeability were not measured. Well A reservoir section does not interpret stress state, σ using logging H-h 、σ 0 、μ f Is of a size of (a) and (b).
Well A reservoir section 7137-7175m is severely lost, imaging well logging reveals that reservoir section 7137-7175m has a natural fracture density of 0.50 per meter, develops 19 natural fractures, has an average height of 3m, a width of 3mm, and a theta of 0-90 degrees.
Construction displacement is 2m during temporary plugging 3 The viscosity of the liquid used was 32 mPas, the hydraulic fracture width calculated by the Mangrove1.21 fracturing design and simulation software of the Srenbescher company was 3mm and the fracture height was 38m. The plugging effect can be achieved by assuming that the natural fracture and the hydraulic fracture are plugged with a depth s=0.08m.
The volume V of the plugging crack is calculated as follows:
V＝V hydraulic power +V Natural material ＝2×38×0.003×0.08+19×3×0.003×0.08＝0.03192m 3
According to the bulk density of the temporary plugging diverting material of 900kg/m 3 The calculation of the temporary plugging steering material consumption M is as follows: m=900 v=28.73 kg,
Comparing the calculated results with those of example 1, it can be seen that the calculated amount of temporary plugging material is significantly smaller in the case where both the hydraulic fracture and the natural fracture are larger in scale than in example 1.
2. The timing of the injection of the temporary plugging diverting material was determined as in the method of determining the timing of the addition of the temporary plugging diverting material in example 1, when the injection timing t of the temporary plugging diverting material was 50% t.
3. 28.73kg of temporary plugging diversion material was added at 50% of the fracturing time of the above interval to perform temporary plugging diversion, and the well yield after construction was 3.21 square per day, which was significantly lower than the construction yield results of example 1.
The results show that the using amount of the temporary plugging diverting material determined by the temporary plugging fracturing method provided by the invention is more in line with the actual situation of temporary plugging, and can be effectively matched with the adding machine of the determined temporary plugging diverting material, so that the construction effect is better, the fracturing and acidizing construction of an oil-gas well can be accurately guided, and the construction yield is obviously improved.
Claims (39)
1. A temporary plugging fracturing method comprises the operation of determining the consumption of temporary plugging steering materials and the operation of determining the adding time of the temporary plugging steering materials;
the method for determining the using amount of the temporary plugging steering material comprises the following steps:
Determining reservoir mechanical parameters, describing the number of natural cracks and the occurrence of the natural cracks, and determining the pressure-bearing capacity and the permeability of the temporary plugging layer of the temporary plugging steering material;
determining the size and construction scale of the hydraulic fracture through a fracturing simulation experiment according to the mechanical parameters of the reservoir;
when the number of natural cracks in a reservoir is more than 0, calculating a net pressure critical value required by opening the natural cracks according to the mechanical parameters of the reservoir and the occurrence of the natural cracks, and determining the number of the natural cracks according to the pressure-bearing capacity of the temporary plugging steering material; when the number of natural cracks in a reservoir = 0, calculating a net pressure critical value required for opening a new branch crack according to the mechanical parameters of the reservoir;
when the number of natural cracks in the reservoir is more than 0, calculating the consumption of temporary plugging steering materials required for temporarily plugging the natural cracks and the hydraulic cracks according to the construction scale, the permeability of the temporary plugging layer, the occurrence of the natural cracks, the net pressure critical value required for opening the natural cracks and the number of the natural cracks; when the number of natural cracks in the reservoir = 0, calculating the consumption of temporary plugging steering materials required by temporary plugging hydraulic cracks according to the construction scale, the permeability of the temporary plugging layer and the net pressure critical value required by opening the new branch cracks;
The method for determining the adding time of the temporary plugging steering material comprises the following steps:
s1, defining the fracturing start time as 0, the fracturing total time as T, and designating one time within the time from 0 to T as T;
s2, injecting fluid into the two-dimensional multi-cluster fracture geological model for temporary plugging and fracturing before temporary plugging in the time of 0 to t;
s3, adding temporary plugging steering materials at the time t to plug the opened cracks;
s4, injecting residual fluid in the time from T to T for temporary plugging and then fracturing, and finishing the fracturing after temporary plugging;
s5, deriving and analyzing fracturing results and fracturing forms after temporary plugging;
s6, selecting different moments in time from 0 to T as T, repeating S2 to S5, comparing fracturing results and fracturing forms obtained at different moments, and determining the moment T with the maximum total length of the cracks and the most uniform correspondence of the lengths of the cracks, namely the moment of adding temporary plugging steering materials.
2. The method of temporary plugging fracturing of claim 1, wherein in the method of determining the amount of temporary plugging diverting material:
the reservoir mechanical parameters include maximum horizontal stress, minimum horizontal stress, tensile strength, poisson's ratio, and cohesion;
the natural fracture shape includes the length of the natural fracture, the width of the natural fracture, and the angle of approach of the natural fracture to the maximum horizontal principal stress.
3. The method of temporary plugging fracturing of claim 2, wherein the reservoir mechanical parameters are obtained by analysis and calculation of logging data by a geostress continuous profile analysis software.
4. The temporary plugging fracturing method of claim 2, wherein the number of natural fractures is determined from imaging log results.
5. The method of temporary plugging fracturing of claim 1, wherein in the method of determining the amount of temporary plugging diverting material: the types of natural fracture opening include tensile failure and shear failure.
6. The method of temporary plugging fracturing of claim 5, wherein in the method of determining the amount of temporary plugging diverting material:
the calculation of the temporary plugging net pressure required by the natural fracture when the tensile fracture is opened follows the W-T rule.
7. The temporary plugging fracturing method of claim 6, wherein the calculation formula of the critical value of the net pressure required for opening the natural fracture tensile failure is:
wherein P is net The unit is MPa for the net pressure critical value required for crack opening; sigma (sigma) H The unit is MPa, which is the maximum horizontal stress; sigma (sigma) h The unit is MPa, which is the minimum horizontal stress; θ is natural crack and sigma H Is a approximation angle of (a); when the pore pressure P of the crack near wall surface meets P more than or equal to P net When the natural fracture is opened, the fracture is opened by the tensile failure.
8. The temporary plugging fracturing method of claim 7, wherein the calculation of the threshold value of net pressure at which the natural fracture tensile failure opens comprises:
the critical limiting conditions of pore pressure P of the crack near wall surface are as follows: p=σ n
Wherein, the calculation formula of P is: p=σ h +P net ，
σ n The calculation formula of (2) is as follows:
p is pore pressure of a crack near wall surface, and the unit is MPa; p (P) net The unit is MPa for the net pressure critical value required for crack opening; sigma (sigma) n The unit is MPa for the normal stress acting on the natural fracture surface; sigma (sigma) H The unit is MPa, which is the maximum horizontal stress; sigma (sigma) h The unit is MPa, which is the minimum horizontal stress; θ is natural crack and sigma H Is a approximation angle of (a); when P is greater than or equal to P net When the natural fracture is opened, the fracture is opened by the tensile failure.
9. The method of temporary plugging fracturing of claim 5, wherein in the method of determining the amount of temporary plugging diverting material:
the calculation of the net pressure at which the natural fracture opens for shear failure follows the molar coulomb criterion.
10. The temporary plugging fracturing method of claim 9, wherein the calculation formula of the critical value of the net pressure at which the shear damage of the natural fracture is opened is:
Wherein P is net A critical value of net pressure required for crack initiation, MPa; sigma (sigma) H The unit is MPa, which is the maximum horizontal stress; sigma (sigma) h The unit is MPa, which is the minimum horizontal stress; θ is natural crack and sigma H Is a approximation angle of (a); sigma (sigma) 0 The cohesion is expressed in MPa; mu (mu) f The friction factor of the natural fracture surface is dimensionless; when the pore pressure P of the crack near wall surface meets P more than or equal to P net When the natural fracture is opened, the natural fracture is sheared and destroyed.
11. The temporary plugging fracturing method of claim 10, wherein the calculation of the net pressure at which the natural fracture shear failure opens comprises:
the critical limiting conditions of pore pressure P of the crack near wall surface are as follows:
wherein, the calculation formula of P is: p=σ h +P net ，
σ n The calculation formula of (2) is as follows:
p is pore pressure of a crack near wall surface, and the unit is MPa; p (P) net The unit is MPa for the critical value of net pressure required for crack opening; sigma (sigma) n The unit is MPa for the normal stress acting on the natural fracture surface; sigma is a shearing force acting on a natural fracture surface and the unit is MPa; sigma (sigma) H The unit is MPa, which is the maximum horizontal stress; sigma (sigma) h The unit is MPa, which is the minimum horizontal stress; θ is natural crack and sigma H Is a approximation angle of (a); sigma (sigma) 0 The cohesion is expressed in MPa; mu (mu) f The friction factor of the natural fracture surface is dimensionless; when P is greater than or equal to P net When the natural fracture is opened, the natural fracture is sheared and destroyed.
12. The method of temporary plugging fracturing of claim 1, wherein in the method of determining the amount of temporary plugging diverting material:
the critical value of the net pressure required for opening the new branch seam is:
P net ＝(σ H -σ h )+S t ，
wherein P is net The net pressure required for crack opening is in MPa; sigma (sigma) H The unit is MPa, which is the maximum horizontal stress; sigma (sigma) h The unit is MPa, which is the minimum horizontal stress; s is S t The tensile strength of the rock is expressed in MPa;
when the pore pressure P of the crack near wall surface meets P more than or equal to P net And opening a new branch seam.
13. The method of temporary plugging fracturing of any one of claims 1, 5-12, wherein in the method of determining the amount of temporary plugging diverting material:
the limit conditions of the number of the natural cracks are as follows:
ΔP≥P net ，
ΔP is the pressure-bearing capacity of the temporary blocking steering material, P net The net pressure threshold required for a single natural fracture to open.
14. The method of temporary plugging fracturing of claim 1, wherein in the method of determining the amount of temporary plugging diverting material:
and carrying out fracturing simulation by using reservoir mechanical parameters and combining Mangrove fracturing design and simulation software so as to determine the size of the hydraulic fracture.
15. The temporary plugging fracturing method of claim 14, wherein the size of the hydraulic fracture comprises a height and a width of the hydraulic fracture.
16. The method of temporary plugging fracturing of claim 1, 14 or 15, wherein in the method of determining the amount of temporary plugging diverting material:
the calculation formula of the using amount of the temporary plugging steering material comprises the following steps:
M＝2M d0 +M d1 +M d2 +…M di ，
wherein M is the total consumption of temporary plugging steering materials, M d0 The amount of temporary plugging steering material required for temporarily plugging a single hydraulic fracture is M di The amount of temporary plugging steering material required for temporarily plugging the i-th opened natural crack;
the calculation formula of the amount of temporary plugging steering material required for temporarily plugging a single hydraulic fracture or a single natural fracture is as follows:
wherein M is d The dosage of temporary plugging steering materials required for temporarily plugging a single hydraulic fracture or a single natural fracture is kg; ρ d For temporary plugging of the apparent density of the steering material, the unit is kg/m 3 ；H f The height of the hydraulic fracture or the natural fracture is m; w (W) f The width of the hydraulic fracture or the natural fracture is m; Δp' is the wellbore holding pressure in Pa, and its value is equal to the net pressure threshold required for fracture opening; k (K) d For temporary plugging layer permeability, the unit is m 2 The method comprises the steps of carrying out a first treatment on the surface of the Mu is the viscosity of the carrying liquid and the unit is Pa.s; q is construction displacement, the unit is m 3 /s；
When the number of the natural cracks is more than 0, calculating the delta P' adopted by the consumption of temporary plugging steering materials required by temporarily plugging a single hydraulic crack and the natural crack to be equal to the net pressure critical value required by opening the natural crack;
When the number of natural cracks=0, Δp' used for calculating the amount of temporary plugging steering material required for temporarily plugging a single hydraulic crack is equal to the net pressure critical value required for opening a new branch crack.
17. The method of temporary plugging fracturing of claim 1, 14 or 15, wherein in the method of determining the amount of temporary plugging diverting material:
the calculation formula of the consumption of temporary plugging steering materials required by temporarily plugging a single hydraulic fracture or a natural fracture is as follows:
M d ＝ρ d ×H f ×W f ×L d
M d the unit of the dosage of temporary plugging steering materials required for temporary plugging of single hydraulic cracks or natural cracks is kg; ρ d For temporary plugging of the apparent density of the steering material, the unit is kg/m 3 ；L d The length of the temporary plugging section of the crack is m; h f The height of the crack is m; w (W) f The width of the crack is m;
in the above formula, L d The calculation formula of (2) is as follows:
Δp' is the wellbore holding pressure in Pa, and its value is equal to the net pressure threshold required for fracture opening; k (K) d For temporary plugging layer permeability, the unit is m 2 The method comprises the steps of carrying out a first treatment on the surface of the Mu is the viscosity of the carrying liquid and the unit is Pa.s; q is construction displacement, the unit is m 3 /s；
When the number of the opened natural cracks is more than 0, calculating the delta P' adopted by the consumption of temporary plugging steering materials required by temporarily plugging a single hydraulic crack and the natural crack to be equal to the net pressure critical value required by opening the natural crack;
When the number of the opened natural cracks=0, the delta P' adopted for calculating the using amount of temporary plugging steering materials required for temporarily plugging the single hydraulic cracks is equal to the net pressure critical value required for opening the new branch cracks.
18. The method of temporary plugging fracturing of claim 16, wherein in the method of determining the amount of temporary plugging diverting material:
the calculation formula of the consumption of temporary plugging steering materials required by temporarily plugging a single hydraulic fracture or a natural fracture is as follows:
M d ＝ρ d ×H f ×W f ×L d
M d the unit of the dosage of temporary plugging steering materials required for temporary plugging of single hydraulic cracks or natural cracks is kg; ρ d For temporary plugging of the apparent density of the steering material, the unit is kg/m 3 ；L d The length of the temporary plugging section of the crack is m; h f The height of the crack is m; w (W) f The width of the crack is m;
in the above formula, L d The calculation formula of (2) is as follows:
Δp' is the wellbore holding pressure in Pa, and its value is equal to the net pressure threshold required for fracture opening; k (K) d For temporary plugging layer permeability, the unit is m 2 The method comprises the steps of carrying out a first treatment on the surface of the Mu is the viscosity of the carrying liquid and the unit is Pa.s; q is construction displacement, the unit is m 3 /s；
When the number of the opened natural cracks is more than 0, calculating the delta P' adopted by the consumption of temporary plugging steering materials required by temporarily plugging a single hydraulic crack and the natural crack to be equal to the net pressure critical value required by opening the natural crack;
When the number of the opened natural cracks=0, the delta P' adopted for calculating the using amount of temporary plugging steering materials required for temporarily plugging the single hydraulic cracks is equal to the net pressure critical value required for opening the new branch cracks.
19. The temporary plugging fracturing method of claim 1, wherein in the method of determining the timing of addition of temporary plugging diverting material:
in S1, T is one of 0T, 10% T, 20% T, 30% T, 40% T, 50% T, 60% T, 70% T, 80% T, 90% T and 100% T.
20. The temporary plugging fracturing method of claim 1, wherein in the method of determining the timing of addition of temporary plugging diverting material:
s2, the construction method of the two-dimensional multi-cluster fracture geological model comprises the following steps: obtaining geological parameters of a target area and constructing a geological model; and inserting a cohesive unit between matrix units of the geological model, and describing crack initiation and damage by adopting a separation-displacement curve to obtain the two-dimensional multi-cluster crack geological model.
21. The temporary plugging fracturing method of claim 20, wherein the method for constructing the two-dimensional multi-cluster fracture geologic model comprises inserting a cohesive unit into a matrix unit of the geologic model after constructing the geologic model, and determining the damage form, the damage evolution rule and the fluid flow rule of the cohesive unit to obtain the two-dimensional multi-cluster fracture geologic model.
22. The temporary plugging fracturing method of claim 20 or 21, wherein in the construction method of the two-dimensional multi-cluster fracture geologic model, a maximum nominal stress criterion is adopted as a fracture initiation judgment criterion of a cohesive unit, namely when the maximum nominal stress ratio reaches 1, damage starts, and the expression of the damage form is as follows:
wherein t is n 、t s 、t t Nominal stress normal to the cohesive unit, nominal stress in the first tangential direction, and nominal stress in the second tangential direction, in Pa, respectively;is the normal critical nominal stress, the first tangential critical nominal stress and the second tangential critical nominal stress of the cohesive unit, the unit is Pa;<>is a MacAuley operator, expressed as: />
23. The temporary plugging fracturing method of claim 20 or 21, wherein the property of evolution of a damage variable between the start of damage and the final failure is adopted as a damage evolution rule of the cohesive unit, and the damage evolution under the combined action of stretching and shearing deformation of the cohesive unit is described.
24. The temporary plugging fracturing method of claim 22, wherein the property of the evolution of the damage variable between the start of damage and the final failure is adopted as a damage evolution rule of the cohesive unit, and the damage evolution under the combined action of the stretching and the shearing deformation of the cohesive unit is described.
25. The temporary plugging fracturing method of claim 23, wherein the damage variable is expressed as:
wherein D is a damage variable,for an effective displacement maximum in the loading history, < > j->For effective displacement at the beginning of injury, +.>Is the effective displacement at the time of final failure.
26. The temporary plugging fracturing method of claim 25, wherein the effective displacement is determined from a nominal strain normal to the cohesive unit, a nominal strain of the first tangential direction, a nominal strain of the second tangential direction.
27. The temporary plugging fracturing method of claim 26, wherein the expression of the effective displacement is:
wherein delta m For effective displacement, delta n Nominal strain, delta, being the normal to the cohesive unit s Nominal strain, delta, being the first tangential of the cohesive unit t Is the nominal strain of the second tangential direction of the cohesive unit.
28. The temporary plugging fracturing method of claim 23, wherein in the method for constructing a two-dimensional multi-cluster fracture geologic model, the flow rule of the fluid at the cohesive unit comprises a transverse flow rule and a normal flow rule of the fluid at the cohesive unit.
29. The temporary plugging fracturing method of claim 28, wherein the lateral flow of fluid in the cohesive unit satisfies the following equation:
qd＝-k t ▽p，
Wherein q is flow, and the unit is m 3 And/s, d is the gap opening degree, and the unit is m and k t The tangential permeability is given in m 2 And P is Hamiltonian of pore pressure of the cohesive unit, and the unit is Pa.
30. The temporary plugging fracturing method of claim 29, wherein the tangential permeability is calculated as:
wherein k is t The tangential permeability is given in m 2 The method comprises the steps of carrying out a first treatment on the surface of the d is the gap opening degree, and the unit is m; mu is the viscosity of the fluid in Pa.s.
31. The temporary plugging fracturing method of claim 20 or 21, wherein in the method of determining timing of addition of temporary plugging diverting material: the normal flow of the fluid in the cohesive unit meets the normal fluid loss equation, and the expression is as follows:
wherein q t 、q b The upper surface flow speed and the lower surface flow speed of the cohesive unit in the vertical direction are respectively m3/s; p is p i Is the internal pressure of the cohesive unit, and the unit is Pa; p is p t 、p b The upper pore pressure and the lower pore pressure of the bonding unit are respectively Pa; c t 、c b The upper fluid loss coefficient and the lower fluid loss coefficient of the cohesive unit are respectively.
32. The method of temporary plugging fracturing of claim 20, wherein in the method of determining timing of addition of temporary plugging diverting material: and the number of crack clusters of the geological model of the two-dimensional multi-cluster crack is 3-7 clusters.
33. The temporary plugging fracturing method of claim 32, wherein the geological model of two-dimensional multi-cluster fractures has a fracture cluster number of 3-5 clusters.
34. The method of temporary plugging fracturing of claim 20, wherein in the method of determining timing of addition of temporary plugging diverting material:
in S5, the fracturing result and the fracturing form refer to the lengths of the multi-cluster cracks and the expansion form of the multi-cluster cracks.
35. Use of the temporary plugging fracturing method of any one of claims 1-34 in fracturing acidizing construction of oil and gas wells.
36. The use of the temporary plugging fracturing method of claim 35 in oil and gas well fracturing acidizing construction, wherein the lithofacies of the reservoir where the fracturing acidizing construction is located comprise one or a combination of more than two of carbonate, shale, volcanic, sandstone and sand.
37. The use of the temporary plugging fracturing method of claim 35 in oil and gas well fracturing acidizing operations wherein the well of the fracturing acidizing operations comprises one of an oil well, a gas well and a gas and oil well.
38. The use of the temporary plugging fracturing method of claim 35 in oil and gas well fracturing acidizing operations wherein the well of the fracturing acidizing operations comprises one of a vertical well, a horizontal well and a highly deviated well.
39. The use of the temporary plugging fracturing method of claim 35 in oil and gas well fracturing and acidizing construction, wherein temporary plugging diversion materials adopted in the fracturing and acidizing construction comprise temporary plugging particles and/or temporary plugging fibers.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202011399483.9A CN114592840B (en) | 2020-12-04 | 2020-12-04 | Temporary plugging fracturing method and application thereof |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202011399483.9A CN114592840B (en) | 2020-12-04 | 2020-12-04 | Temporary plugging fracturing method and application thereof |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN114592840A CN114592840A (en) | 2022-06-07 |
| CN114592840B true CN114592840B (en) | 2023-10-27 |
Family
ID=81803230
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN202011399483.9A Active CN114592840B (en) | 2020-12-04 | 2020-12-04 | Temporary plugging fracturing method and application thereof |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN114592840B (en) |
Families Citing this family (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN115792189A (en) * | 2022-11-11 | 2023-03-14 | 常州大学 | Method for evaluating leakage stopping effect of drilling fluid in fracture extension type leakage reservoir |
| CN117633409B (en) * | 2024-01-25 | 2024-04-09 | 中国科学院地质与地球物理研究所 | Method, system and equipment for calculating shale oil and gas reservoir fracture network seepage parameters |
Citations (9)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN105041287A (en) * | 2015-07-23 | 2015-11-11 | 中国石油天然气股份有限公司 | Fiber temporary plugging turnaround fracture method capable of improving low permeability tight sandstone oil and gas well production capacity |
| CN106869896A (en) * | 2017-04-26 | 2017-06-20 | 西南石油大学 | A kind of Low permeable oil and gas reservoirs straight well volume fracturing reservoir reconstruction method for predicting volume |
| CN108587587A (en) * | 2018-04-24 | 2018-09-28 | 东方宝麟科技发展(北京)有限公司 | A kind of oil/gas well temporary plugging ball of high-strength degradable and the preparation method and application thereof |
| CN109372466A (en) * | 2018-10-10 | 2019-02-22 | 中国石油天然气股份有限公司华北油田分公司 | The temporary stifled forward method of liquid-solid-liquid phase state conversion is realized using natural Temperature Field |
| CN110685657A (en) * | 2019-10-21 | 2020-01-14 | 中国石油化工股份有限公司 | Method for calculating temporary plugging particle dosage for steering fracturing |
| CN110905472A (en) * | 2019-10-29 | 2020-03-24 | 中国石油集团川庆钻探工程有限公司 | Method for determining real-time steering fracturing parameters based on composite temporary plugging system |
| US10689972B1 (en) * | 2019-05-31 | 2020-06-23 | Southwest Petroleum University | Automatic diagnosis method for wellhead pressure curve of hydraulic fracturing in shale gas horizontal well |
| CN111322050A (en) * | 2020-04-24 | 2020-06-23 | 西南石油大学 | Shale horizontal well section internal osculating temporary plugging fracturing construction optimization method |
| CN111502593A (en) * | 2020-06-17 | 2020-08-07 | 西南石油大学 | Method for determining dosage of temporary plugging diversion fracturing phase change temporary plugging agent in crack |
Family Cites Families (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN110185427B (en) * | 2019-05-10 | 2020-06-30 | 西南石油大学 | Method for acquiring natural crack opening time under condition of temporary plugging in crack |
| CN110334868B (en) * | 2019-07-08 | 2020-12-08 | 西南石油大学 | Method for predicting optimal soaking time by coupling fluid flow and geological stress |
| CN110929413B (en) * | 2019-12-04 | 2020-11-10 | 西南石油大学 | Method for simulating hydraulic fracture wall discontinuity behavior in fractured reservoir |
-
2020
- 2020-12-04 CN CN202011399483.9A patent/CN114592840B/en active Active
Patent Citations (9)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN105041287A (en) * | 2015-07-23 | 2015-11-11 | 中国石油天然气股份有限公司 | Fiber temporary plugging turnaround fracture method capable of improving low permeability tight sandstone oil and gas well production capacity |
| CN106869896A (en) * | 2017-04-26 | 2017-06-20 | 西南石油大学 | A kind of Low permeable oil and gas reservoirs straight well volume fracturing reservoir reconstruction method for predicting volume |
| CN108587587A (en) * | 2018-04-24 | 2018-09-28 | 东方宝麟科技发展(北京)有限公司 | A kind of oil/gas well temporary plugging ball of high-strength degradable and the preparation method and application thereof |
| CN109372466A (en) * | 2018-10-10 | 2019-02-22 | 中国石油天然气股份有限公司华北油田分公司 | The temporary stifled forward method of liquid-solid-liquid phase state conversion is realized using natural Temperature Field |
| US10689972B1 (en) * | 2019-05-31 | 2020-06-23 | Southwest Petroleum University | Automatic diagnosis method for wellhead pressure curve of hydraulic fracturing in shale gas horizontal well |
| CN110685657A (en) * | 2019-10-21 | 2020-01-14 | 中国石油化工股份有限公司 | Method for calculating temporary plugging particle dosage for steering fracturing |
| CN110905472A (en) * | 2019-10-29 | 2020-03-24 | 中国石油集团川庆钻探工程有限公司 | Method for determining real-time steering fracturing parameters based on composite temporary plugging system |
| CN111322050A (en) * | 2020-04-24 | 2020-06-23 | 西南石油大学 | Shale horizontal well section internal osculating temporary plugging fracturing construction optimization method |
| CN111502593A (en) * | 2020-06-17 | 2020-08-07 | 西南石油大学 | Method for determining dosage of temporary plugging diversion fracturing phase change temporary plugging agent in crack |
Also Published As
| Publication number | Publication date |
|---|---|
| CN114592840A (en) | 2022-06-07 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN110608024B (en) | Volume fracturing method for improving filling efficiency of micro-support system by deep shale gas | |
| Jiang et al. | Experimental and numerical study on hydraulic fracture propagation in coalbed methane reservoir | |
| Lian et al. | A study on casing deformation failure during multi-stage hydraulic fracturing for the stimulated reservoir volume of horizontal shale wells | |
| CN110905472B (en) | Method for determining real-time steering fracturing parameters based on composite temporary plugging system | |
| CN111236908A (en) | Multi-stage fractured horizontal well productivity prediction model and productivity sensitivity analysis method suitable for low-permeability tight gas reservoir | |
| Furui et al. | A Comprehensive Model of High-Rate Matrix-Acid Stimulation for Long Horizontal Wells in Carbonate Reservoirs: Part II—Wellbore/Reservoir Coupled-Flow Modeling and Field Application | |
| US11560776B2 (en) | Methods and systems of modeling fluid diversion treatment operations | |
| CN114592840B (en) | Temporary plugging fracturing method and application thereof | |
| Yamamoto et al. | Multiple fracture propagation model for a three-dimensional hydraulic fracturing simulator | |
| US11499406B2 (en) | Method for predicting of hydraulic fracturing and associated risks | |
| Michael | Hydraulic fracturing optimization: experimental investigation of multiple fracture growth homogeneity via perforation cluster distribution | |
| CN112541287A (en) | Loose sandstone fracturing filling sand control production increase and profile control integrated design method | |
| CN117052347B (en) | Plugging simulation experiment device and method | |
| Zhu et al. | Hydraulic fracture propagation in sand-mudstone interbedded reservoir integrated with different fluid flow of multi-perforated fractures | |
| Zhai et al. | Experimental study of hydraulic fracturing initiation and propagation from perforated wellbore in oil shale formation | |
| CN114592823A (en) | Method for determining dosage of temporary blocking steering material and application | |
| Mack et al. | Hydraulic fracture orientation and pressure response during fracturing of producing wells | |
| CN104712299B (en) | It is adapted to gas well control water and increases the design method that air pressure splits | |
| Molina et al. | A computational fluid dynamics approach to predict pressure drop and flow behavior in the near wellbore region of a frac-packed gas well | |
| Brinkmann | Status report on fracturing of deep and low permeable formations in West Germany | |
| CN114607332A (en) | Two-dimensional multi-cluster crack geological model, construction method thereof, determination method of temporary blocking steering material adding time and application | |
| Mishra | A model for matrix acidizing of long horizontal well in carbonate reservoirs | |
| Mavko et al. | Hydraulic fracture model for application to coal seams | |
| Martyushev et al. | Researching features of development of fractured porous reservoirs reserves using well-test data (Russian) | |
| Akash | Numerical Simulations Of Hydraulic Fracturing Through Perforated Wellbores |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| GR01 | Patent grant | ||
| GR01 | Patent grant |