CN106761647B - Method for estimating planar reconstruction area after shale reservoir lamination - Google Patents
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Abstract
The invention discloses a method for estimating the plane transformation area after shale reservoir lamination, which comprises the following steps: reading the fracture pressure P of each section of well head of single well0(ii) a Predicting bottom hole fracture pressure P of each section of single well1(ii) a Calculating the actual bottom hole fracture pressure P of each section of the single well of the reservoir2(ii) a Obtaining a continuous crack model; generating an equivalent fracture model; selective extension pressure P3Average extension pressure P4And construction effective time T; defining a construction effective pressure P; defining the range of tension and extrusion stress areas in a fracturing modification strain prediction graph; if P1‑P2>p, only considering a near wellbore extrusion stress area in a fracture transformation strain prediction graph; if P1‑P2<p, the fracture transformation strain prediction graph is the transformation area of the plane after the fracturing; drawing the transformation area of the pressed plane, and further evaluating the fracturing effect. The invention utilizes the geomechanical simulation technology to predict and evaluate the fracturing modification range, and achieves the purposes of optimizing the drilling and completion and fracturing design, evaluating the fracturing modification effect and realizing the continuous and efficient exploitation of the shale gas field.
Description
Technical Field
The invention relates to the field of shale gas exploitation, in particular to a method for estimating a plane transformation area after shale reservoir lamination.
Background
The hydraulic fracturing method is the core technology of shale gas exploitation. Due to the existence state of shale gas dispersion, shale layers must be fractured into a fracture network in the exploitation process of shale gas so as to achieve the purposes of exploitation and yield increase. The large-scale hydraulic fracturing of horizontal wells is mostly adopted in domestic and overseas development, for regional development, a 'well factory cluster well' development mode is adopted, the reasonable development well spacing adopted in the Fuling shale gas field is 500-600m, and along with the continuous exploitation of shale gas wells, the shale gas wells inevitably face lower and lower pressure and yield until the gas wells finish the natural production period. How to further effectively exploit in the later stage is to carry out repeated fracturing on an old well or to continue development by adopting an encrypted well, and is a great problem in front of shale gas decision makers.
Through investigation, the main methods for evaluating the post-compression transformation area at present are found to be Mayer software post-compression simulation and fracture micro-seismic monitoring technology. The Meyer software is a simulation tool which is widely applied to the aspect of hydraulic measure design. The MFrac is a comprehensive simulation design and evaluation module and has a plurality of functions such as three-dimensional fracture geometric shape simulation and the like. The software can simulate real-time and replay data in combination with process analysis of fracturing propping agent transmission and heat transfer, so that a fracture network (including fracture geometric dimension and SRV) formed after fracturing can be described and evaluated, but the Mayer software simulation after fracturing has the defects that the software simulates the whole reservoir space by 'one-hole observation' according to the basic data of well completion and the construction parameters of fracturing after being introduced into the software based on the electric measurement original data of the well completion in the simulation process, the influence of geological properties such as natural fracture and plane unevenness on fracturing is not considered, the model is approximate to a uniform model, the simulated fracture network has different shapes, the real fracture network system after fracturing cannot be reflected, and the continuous exploitation of shale gas has no guiding significance.
Microseisms are the primary technique used for induced fracture monitoring during hydraulic fracturing. The borehole microseism monitoring technology has a good effect in fracturing evaluation, and can monitor the parameter characteristics of the position, the azimuth, the length, the height and the like of a crack generated in the fracturing process in real time. The device has the advantages of quick measurement and convenient field application; determining the location of the microseismic event in real time; determining the height, length, inclination angle and orientation of the crack; the fracture network resulting from the fracture spacing exceeding the fracture length is measured directly. The main disadvantage of microseismic monitoring techniques in fractured wells is that effective fracture evaluation cannot be performed for all wells in a block. First, due to technical and production limitations, a block often cannot find a suitable monitoring well, and many fracturing wells cannot reach monitoring conditions. Second, shale gas development is not possible to implement microseismic monitoring techniques for most or all wells, subject to production cost. This brings inconvenience to the exploitation of shale gas.
Disclosure of Invention
The invention aims to provide a method for estimating the plane transformation area of a shale reservoir after lamination, so as to solve the problems in the background technology.
In order to achieve the purpose, the invention provides the following technical scheme:
a method for estimating a plane transformation area after shale reservoir lamination comprises the following specific steps:
step one, collecting each wellThe section pressure construction parameters and the fracturing construction curve are read, and the fracture pressure P of each section of the well mouth of the single well is read according to the characteristics of the fracturing curve0；
Collecting shale reservoir well completion electric logging original data, and predicting bottom hole fracture pressure P of each section of a single well by adopting SAOR reservoir ground stress analysis software1；
Thirdly, calculating the actual bottom hole fracture pressure P of each section of the single well of the reservoir by adopting a classic clear water friction calculation formula and a chart2Bottom hole burst pressure P2Well head cracking pressure P0+ liquid column pressure PH-total friction resistance PF-a net pressure p;
inputting the seismic attribute of a depth domain and an imaging logging fracture indication curve into FracPredifactor software to perform multi-attribute fusion by using a neural network algorithm to obtain a continuous fracture model;
inputting the continuous crack model generated in the fourth step into FracPredifctor software to generate an equivalent crack model;
step six, optimizing the extension pressure P by adopting a median method according to actual fracturing curves and parameters of each section of the single well and the extension pressure second point data group during optimized stable displacement fracturing3Mean extension pressure P4The effective construction time T;
step seven, if | P3-P4|<P, then P is discarded4If P3-P4|>P, then P is discarded3Defining the extension pressure value which is not discarded and remained as construction effective pressure P;
step eight, according to shale gas development experience, assuming that the height H of a fracture is 30m, assuming that the flow velocity v of fracturing fluid under stable discharge is a constant value, simulating an original stress field of a reservoir by adopting an OSplacticials module in FracPredifctor software, inputting construction effective pressure P and construction effective time T of each section of a single well into the FracPredifctor software according to a fracturing sequence, simulating the stress distribution condition of a hydraulic fracture in the reservoir after liquid injection, and determining the range of a tension stress area and an extrusion stress area in a fracturing modification strain prediction diagram according to the simulated stress type and size;
step nine, if P1-P2>p, only considering a near wellbore extrusion stress area in a fracture transformation strain prediction graph; if P1-P2<p, the fracture transformation strain prediction graph is the transformation area of the plane after the fracturing;
step ten, manually drawing a fracturing range formed by hydraulic fracturing, namely the area of the plane after fracturing, and further evaluating the fracturing effect according to the step nine.
As a further scheme of the invention: the clear water friction calculation formula comprises a clear water on-way friction formula and a clear water hole friction formula.
As a further scheme of the invention: the formula of the friction resistance of the clear water along the way is (delta P)f)0＝1.385×106×D-4.8·Q1.8H, D is the internal diameter of the fracturing tubing string in mm, Q is the injection displacement of the pump in the construction process in m3H is the length of the oil pipe and the unit is m; the formula of the friction resistance of the clear water hole is
Compared with the prior art, the invention has the beneficial effects that: the method is simple and convenient, combines the interaction of the fracturing engineering and the geological property, utilizes the geomechanics simulation technology to predict and evaluate the fracturing modification range, achieves the aims of optimizing the drilling and completion and fracturing design, evaluating the fracturing modification effect and realizing the continuous and efficient exploitation of the shale gas field, has low development cost, reduces the exploitation cost of the shale gas and has wide application prospect.
Drawings
FIG. 1 is a graph comparing SRA estimated from a focal page AA well and a fracture network estimated from a microseismic in a method for estimating a planar reformation area after shale reservoir lamination.
FIG. 2 is a graph comparing the SRA estimated by the focal page BB well and the fracture network estimated by the micro-seismic in the method for estimating the planar reconstruction area after shale reservoir lamination.
FIG. 3 is a diagram of the calculated geostress results of stages 1-5 of CC wells in the method for estimating the planar reformation area after shale reservoir formation.
FIG. 4 is a graph of SRA effect of the focal page CC well estimation in the method for estimating the planar reformation area after shale reservoir lamination.
Detailed Description
The technical solution of the present patent will be described in further detail with reference to the following embodiments.
The fracturing effect is the interaction result of the hydraulic fracture and the natural fracture, the hydraulic fracture of the former section changes the surrounding stress field, the construction of the latter fracturing section and the behavior of the natural fracture are influenced, and the natural fracture is likely to open in advance before the hydraulic fracture arrives, namely the stress shadow effect. As shown in the following figures. This is a good explanation of the microseismic event signals far from the hydraulic fracture, and the smaller the reservoir anisotropy, the smaller the hydraulic fracture-natural fracture angle, and the more susceptible the natural fracture to opening. Barnett shale has performed an SRV (reservoir modification volume) correlation analysis. The data show that with high displacement, pumping is completed in a shorter time, an optimal SRV value can be established, with the maximum SRV value usually being achieved with the highest displacement and maximum fluid volume.
The shale gas is developed by adopting large-scale hydraulic fracturing, and when fracturing liquid flows through the perforation holes, the fracturing liquid is subjected to friction resistance of the perforation holes and instantaneous friction resistance in sequence, so that impact force is generated on the front end face. Fracture pressure models of shale anisotropy influence mainly include the following:
breaking along the rock body:
in the first place, the first,
in the second place, the first place is,
shear failure along natural fracture:
in the third place, the first place is,
tensile failure along natural fractures:
the final fracture stress criterion is
The momentum-impulse theorem reflects the cumulative effect of force over time (impulse), with the increment being the accumulation of force over time. When the speed of the high-speed fluid acts on the front end section and is instantaneously changed into 0 or reverse speed, great impact force can be generated, and the destructive property of the liquid on the rock can be analyzed according to the impact force.
The liquid is changed into zero from a quick instant, the action process is a short integral process, and an impact force formula is derived by combining a mass and sectional area formula as follows:
impact fracturing of rock occurs only when the impact force is greater than the rock fracture stress.
A material is dispersed into a group of particles by adopting a physical point method of dual description of Lagrange and Euler, the particles only carry mass and position information so as to be convenient for tracking a material interface, corresponding physical quantities are calculated on an Euler grid, and information interaction between the particles and the Euler grid is completed through an interpolation function. The mass points carry all material information, and constitutive equation calculation is carried out on the mass points so as to process materials related to history conveniently; (2) establishing a discrete format of a momentum equation by adopting particle dispersion through an equivalent integral weak form; (3) explicit temporal integration is employed.
Conservation of mass ρ (X, t) J (X, t) ═ ρ0(X) (1)
Equation of momentum σij，j+ρbi＝ρüi(2)
Initial conditions
Subscripts i and j represent space coordinate components and obey Einstein summation convention, and subscript 0 represents a value at an initial time; rho is the density at the current moment, J is an Jacobian determinant, bi is physical strength, ui is displacement, wint is internal energy of unit mass, sigma ij is a Cauchy stress tensor, and Dij is a deformation rate tensor; t and v represent the designated face force boundary and velocity boundary in the current configuration, ti and vi are the designated face force and velocity, respectively; nj is the unit outer normal direction of the material boundary. The material particle method is to disperse a material area into a group of particles (material particles) moving relative to a background grid, wherein each particle represents a material area and carries all material information such as mass, velocity, stress, strain and the like, and therefore the set of all particles represents the whole material area; the background grid is used to compute the spatial derivatives and solve the momentum equations. Taking the imaginary displacement ui e 0, 0 { [ ui | ui ∈ C0, ui | u ═ 0} as the weight function, the weak form of the equivalent integral (imaginary function equation) of the momentum equation (2) and the given surface force boundary condition (6) can be obtained as
For the convenience of formula derivation, specific stress σ sij ═ σ ij/ρ and specific boundary surface force-tsi ═ ti/ρ are introduced into formula (8), with
The virtual equation can be converted into a summation form by substituting the equation (9) into the virtual work equation (10)
Wherein: uip ui (xp), uip j ui, j (xp), σ sijp σ sij (xp), bip bi (xp), tsip-tsi (xp), and h is the thickness of the hypothetical boundary layer introduced to convert the last boundary integral at the left end of equation (10) into a volume fraction. As can be seen from equation (11), the material point method converts each integral in equation (10) into the sum of the product of the value of the integrand function at each material point and the volume represented by the material point, i.e., the material point integration is used.
When solving the momentum equation, the particles and the background grid are completely fixed and move together with the background grid, so that the mapping of information between the particles and the background grid nodes can be realized by the finite element shape function NI (xi) established on the nodes of the background grid. In the following, the variables of the background grid nodes are represented by quantities with subscript I and the variables carried by the particles are represented by quantities with subscript p, the displacement uip of the particles p can be interpolated from the displacement uiI of the background grid nodes, i.e.
Where Np is ni (xp) is the value of the node I's shape function at the dot p, and ng is the total number of nodes of the computational grid. If a regular hexahedron background grid is adopted, the shape function of the node I is the shape function of an eight-node hexahedron unit
ξ I, η I and ζ I are natural coordinates of nodes corresponding to the parent unit of the node I, and values of the natural coordinates are +/-1 respectively
Where uiI represents the virtual displacement of the background mesh node I. Substituting equations (12) and (14) into the weak form (11), and considering that the virtual displacement uiI is 0 on the essential boundary v, at any point of the rest, the equation of motion of the background mesh node can be obtained
A method for estimating a plane transformation area after shale reservoir lamination comprises the following specific steps:
collecting pressure construction parameters and fracturing construction curves of each section of a single well, and reading fracturing pressure P of each section of the single well according to the characteristics of the fracturing curves0；
Collecting shale reservoir well completion electric logging original data, and predicting bottom hole fracture pressure P of each section of a single well by adopting SAOR reservoir ground stress analysis software1；
Thirdly, calculating the actual bottom hole fracture pressure P of each section of the single well of the reservoir by adopting a classic clear water friction calculation formula and a chart2The clear water friction calculation formula comprises a clear water on-way friction formula and a clear water hole friction formula, wherein the clear water on-way friction formula is (delta P)f)0＝1.385×106×D-4.8·Q1.8H, D is the internal diameter of the fracturing tubing string in mm, Q is the injection displacement of the pump in the construction process in m3H is the length of the oil pipe and the unit is m; the formula of the friction resistance of the clear water hole is
Bottom hole burst pressure P2Well head cracking pressure P0+ liquid column pressure PH-total friction resistance PF-a net pressure p;
inputting the seismic attribute of a depth domain and an imaging logging fracture indication curve into FracPredifactor software to perform multi-attribute fusion by using a neural network algorithm to obtain a continuous fracture model;
inputting the continuous crack model generated in the fourth step into FracPredifctor software to generate an equivalent crack model;
step six, optimizing the extension pressure P by adopting a median method according to actual fracturing curves and parameters of each section of the single well and the extension pressure second point data group during optimized stable displacement fracturing3Mean extension pressure P4The effective construction time T;
step seven, if | P3-P4|<P, then P is discarded4If P3-P4|>P, then P is discarded3Defining the extension pressure value which is not discarded and remained as construction effective pressure P;
step eight, according to shale gas development experience, assuming that the height H of a fracture is 30m, assuming that the flow velocity v of fracturing fluid under stable discharge is a constant value, simulating an original stress field of a reservoir by adopting an OSplacticials module in FracPredifctor software, inputting construction effective pressure P and construction effective time T of each section of a single well into the FracPredifctor software according to a fracturing sequence, simulating the stress distribution condition of a hydraulic fracture in the reservoir after liquid injection, and determining the range of a tension stress area and an extrusion stress area in a fracturing modification strain prediction diagram according to the simulated stress type and size;
step nine, if P1-P2>p, only considering a near wellbore extrusion stress area in a fracture transformation strain prediction graph; if P1-P2<p, the fracture transformation strain prediction graph is the transformation area of the plane after the fracturing;
step ten, according to the step nine, manually drawing a fracturing range formed by hydraulic fracturing, namely the area of the plane after fracturing, and further evaluating the fracturing effect
The effect demonstrates that:
first, when the application effect is (P)1-P2<p) is as follows: the coke shale AA well penetrates through a high-quality shale reservoir for 40 days, the fracturing construction is completed for 28 sections, the average well opening pressure is 21.60MPa, the average fracture pressure is 76.83MPa, the average pump stopping pressure is 35.30MPa, and the construction displacement is 12-15m3Min, total construction liquid amount 59010m3Total sand amount for construction 1420.2m3Average single stage liquid amount 1967.0m3Average single-segment sand amount of 47.34m3. The comparison effect of the post-compression plane transformation area SRA estimated by the technical method and the fracture network estimated by the micro earthquake is shown in figure 1. The coke shale BB well penetrates through the high-quality shale reservoir for 36 days, the fracturing construction is completed for 22 sections, the average well opening pressure is 27.33MPa, the average fracture pressure is 82.61MPa, the average pump stopping pressure is 40.81MPa, and the construction displacement is 12-16m3Min, total construction liquid amount 45230.15m3Total sand amount for construction 1029.75m3Average single stage liquid amount 1739.62m3Average single-stage sand amount 39.61m3. The comparison effect of the post-compression plane transformation area SRA estimated by the technical method and the fracture network estimated by the micro earthquake is shown in figure 2.
Second, when the application effect is (P)1-P2>p) is as follows: and (3) the coke shale CC well passes through the high-quality shale reservoir for 5 days, the fracturing construction is completed for 4 sections totally, and the average well opening pressure is 41.2MPa, no obvious fracture pressure, average highest construction pressure of 93.67MPa, average pump-stopping pressure of 74.35MPa, construction discharge capacity of 6-12m3Min, total construction liquid amount 8384.39m3Total sand amount for construction 132.33m3Average single stage liquid amount 1676.88m3Average single-segment sand amount of 26.47m3. The step 2 of the method adopting the technology, namely the bottom hole fracture pressure (the bottom hole fracture pressure of the 1 st to 5 th sections is calculated by 110-130MPa) is calculated by adopting SAOR reservoir ground stress analysis software, and is shown in figure 3, and the plane transformation area effect after the pressure estimated by the method adopting the technology is shown in figure 4.
It will be evident to those skilled in the art that the invention is not limited to the details of the foregoing illustrative embodiments, and that the present invention may be embodied in other specific forms without departing from the spirit or essential attributes thereof. The present embodiments are therefore to be considered in all respects as illustrative and not restrictive, the scope of the invention being indicated by the appended claims rather than by the foregoing description, and all changes which come within the meaning and range of equivalency of the claims are therefore intended to be embraced therein. Any reference sign in a claim should not be construed as limiting the claim concerned.
Furthermore, it should be understood that although the present description refers to embodiments, not every embodiment may contain only a single embodiment, and such description is for clarity only, and those skilled in the art should integrate the description, and the embodiments may be combined as appropriate to form other embodiments understood by those skilled in the art.
Claims (3)
1. A method for estimating a plane transformation area after shale reservoir lamination is characterized by comprising the following specific steps:
collecting pressure construction parameters and fracturing construction curves of each section of a single well, and reading fracturing pressure P of each section of the single well according to the characteristics of the fracturing construction curves0；
Collecting shale reservoir well completion electric logging original data, and adopting SAOR reservoir ground stress analysis software to predict listBottom hole burst pressure P of each section of well1；
Thirdly, calculating the actual bottom hole fracture pressure P of each section of the single well of the reservoir by adopting a classic clear water friction calculation formula and a chart2Bottom hole burst pressure P2Well head cracking pressure P0+ liquid column pressure PH-total friction resistance PF-a net pressure p;
inputting the seismic attribute of a depth domain and an imaging logging fracture indication curve into FracPredifactor software to perform multi-attribute fusion by using a neural network algorithm to obtain a continuous fracture model;
inputting the continuous crack model generated in the fourth step into FracPredifctor software to generate an equivalent crack model;
step six, selecting an extension pressure second point data group during the stable displacement fracturing period by adopting a median method according to actual fracturing curves and parameters of each section of the single well to obtain extension pressure P3Mean extension pressure P4The effective construction time T;
step seven, if | P3-P4|<P, then P is discarded4If P3-P4|>P, then P is discarded3Defining the extension pressure value which is not discarded and remained as construction effective pressure P;
step eight, according to shale gas development experience, assuming that the height H of a fracture is 30m, assuming that the flow velocity v of fracturing fluid under stable discharge is a constant value, simulating an original stress field of a reservoir by adopting an OSplacticials module in FracPredifctor software, inputting construction effective pressure P and construction effective time T of each section of a single well into the FracPredifctor software according to a fracturing sequence, simulating the stress distribution condition of a hydraulic fracture in the reservoir after liquid injection, and determining the range of a tension stress area and an extrusion stress area in a fracturing modification strain prediction diagram according to the simulated stress type and size;
step nine, if P1-P2>p, only considering a near wellbore extrusion stress area in a fracture transformation strain prediction graph; if P1-P2<p, the fracture transformation strain prediction graph is the transformation area of the plane after the fracturing;
step ten, manually drawing a fracturing range formed by hydraulic fracturing, namely the area of the plane after fracturing, and further evaluating the fracturing effect according to the step nine.
2. The method for estimating the plane reformation area of a shale reservoir stratum after lamination as claimed in claim 1, wherein the fresh water friction calculation formula comprises a fresh water path friction formula and a fresh water hole friction formula.
3. The method for estimating the planar reformation area of a shale reservoir as claimed in claim 2, wherein the formula of the friction drag of the clean water along the way is (Δ P)f)0＝1.385×106×D-4.8·Q1.8H, D is the internal diameter of the fracturing tubing string in mm, Q is the injection displacement of the pump in the construction process in m3H is the length of the oil pipe and the unit is m; the formula of the friction resistance of the clear water hole is
PmEyelet friction resistance, in units of MPa, Q: construction displacement in m3/min。
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| CN108490487B (en) * | 2018-02-24 | 2019-10-18 | 中国石油化工股份有限公司 | The new method of nearly well fracture parameters is determined using well test data |
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