WO2016192077A1 - Procédé pour établir et résoudre un modèle numérique d'essais de puits horizontal pour fracturation hydraulique de réservoir gazier compact - Google Patents

Procédé pour établir et résoudre un modèle numérique d'essais de puits horizontal pour fracturation hydraulique de réservoir gazier compact Download PDF

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WO2016192077A1
WO2016192077A1 PCT/CN2015/080767 CN2015080767W WO2016192077A1 WO 2016192077 A1 WO2016192077 A1 WO 2016192077A1 CN 2015080767 W CN2015080767 W CN 2015080767W WO 2016192077 A1 WO2016192077 A1 WO 2016192077A1
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wellbore
pressure
dimensionless
crack
curve
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Chinese (zh)
Inventor
欧阳伟平
张冕
袁冬蕊
李杉杉
杨燕
孙贺东
池小明
高红平
刘欢
徐俊芳
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CNPC Chuanqing Drilling Engineering Co Ltd
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CNPC Chuanqing Drilling Engineering Co Ltd
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    • G—PHYSICS
    • G06—COMPUTING OR CALCULATING; COUNTING
    • G06F—ELECTRIC DIGITAL DATA PROCESSING
    • G06F30/00—Computer-aided design [CAD]
    • G06F30/20—Design optimisation, verification or simulation
    • G06F30/23—Design optimisation, verification or simulation using finite element methods [FEM] or finite difference methods [FDM]

Definitions

  • the invention relates to a method for establishing a numerical well test model for a tight gas pressure crack horizontal well, and belongs to the field of oil and gas well test in the petroleum industry.
  • tight gas is rich in resources and has great development potential.
  • Tight gas reservoirs have the characteristics of low permeability, low pressure, low abundance, etc.
  • the natural productivity of gas wells is low, and it is necessary to have industrial exploitation value after the reservoir reform measures.
  • Hydraulic fracturing technology and horizontal well technology are effective ways to increase the productivity of tight gas reservoirs.
  • the exploitation of tight gas reservoirs generally uses multi-stage fracturing horizontal well technology.
  • Well test interpretation of tight gas fracturing horizontal wells is an important means to obtain post-press fracture parameters and reservoir parameters, and is also an effective method for direct verification of seepage mechanism. Due to the seepage mechanism and well-type complexity of multi-stage fracturing horizontal wells in tight gas reservoirs, there is no well test interpretation model for fractured horizontal wells in tight gas reservoirs in China, mainly using the multi-section provided by conventional commercial software Saphir and EPS software. The fractured horizontal well analytical model is used for interpretation analysis, which seriously affects the correct interpretation of the well test data of the tight gas fracture horizontal well.
  • the currently used well test interpretation model does not consider nonlinear seepage mechanisms such as stress sensitivity and starting pressure gradient of tight gas reservoirs.
  • Conventional well testing models based on the Darcy linear seepage mechanism are not suitable for tight gas reservoirs. If the conventional fracturing horizontal well test model is used to interpret and analyze the well test data of the tight gas fracturing horizontal well, it will bring difficulties to the fitting interpretation, and the results obtained by the fitting may also be very large. error.
  • the conventional well test analytical model assumes that the reservoir is a homogeneous medium and cannot consider the heterogeneity of the reservoir.
  • the actual reservoir has obvious heterogeneity, and the reservoir heterogeneity is bound to be It has an important influence on the tight gas seepage and the bottomhole pressure response. Therefore, the reservoir heterogeneity is not considered at present, which will also have an impact on the well test curve fitting and interpretation results.
  • the pressure measured by the pressure gauge is usually regarded as the pressure of the horizontal wellbore section, which will inevitably cause errors in the well test interpretation.
  • the best way to solve this problem is to build a fractured horizontal well test model that considers the wellbore multiphase flow and the actual wellbore trajectory.
  • the object of the present invention is to provide a method for solving a numerical well test model of a compact gas pressure crack horizontal well with a fast calculation speed, a good curve fitting and an accurate interpretation result.
  • the technical solution adopted by the present invention is: a method for establishing a numerical well test model for a dense gas pressure crack horizontal well, comprising the following steps:
  • Step 1 Formation of two-dimensional geological bodies and three-dimensional geological bodies in horizontal wells in tight gas reservoirs;
  • Step 2 Perform grid separation on the generated two-dimensional geological body and three-dimensional geological body of the horizontal well in the tight gas reservoir;
  • Step 3 Calculation of seepage model without pressure difference in the wellbore
  • Step 4 Establish a coupling model, and solve the established coupling model, and generate a well test theoretical curve by the obtained solution;
  • Step 5 The theoretical curve obtained in step 4 is fitted to the measured curve to obtain the parameters of the well test interpretation.
  • the two-dimensional geological body and the three-dimensional geological body of the horizontal well in the tight gas reservoir are generated, and the specific steps are as follows:
  • the geometrical Boolean operation is used to generate the three-dimensional geological body.
  • the internal and external boundary genus in the 2D geological body and the 3D geological body are respectively formed into a 2D mesh file and a 3D mesh file according to the requirements of the Netgen mesh file format, and then the mesh discrete step is performed according to the mesh discrete step set by Netgen. .
  • the mixed finite element method is used to solve the transformed formation and fracture seepage equations.
  • the finite element equations of the stratum and fracture system are decomposed into the finite element equation of the formation region (the first term on the right side of Equation 9) and the finite element representing the fracture system. Equation (the second term on the right side of Equation 9).
  • the finite element equations (10) ⁇ (15) are combined to form the system stiffness matrix.
  • the parallelized SuperLU numerical solver is used to solve the large linear equations, and the pressure field distribution and the inner boundary normal pressure gradient of the whole reservoir can be obtained. Then calculate the production flow of each crack:
  • the coupling model is established in the fourth step, and the established coupling model is solved according to the following steps:
  • the multi-phase flow calculation formula of the wellbore is used to calculate, and the dimensionless differential pressure MP iD of each point of the wellbore is obtained.
  • the specific formula is as follows:
  • the liquid holdup rate H L and the frictional resistance coefficient ⁇ are calculated by the Beggs-Brill method.
  • the wellbore pressure gradient is obtained according to formula (17), and then the pressure difference between each point and the bottom hole standard point is obtained according to the relative distance of the inner boundary of the wellbore:
  • the dimensionless differential pressure MP iD at each point can be obtained.
  • step B The pressure difference MP iD of the inner boundary obtained in step A is brought into the seepage model to calculate the wellbore pressure p' WD and the crack flow Q' fi .
  • the coupling conditions of the wellbore multiphase flow model and the seepage model are as follows :
  • step D the p' WD determined in step C and the corresponding Q' fi are recorded. If the time step k ⁇ total time step n, then the calculation of the next time step is continued, according to the current wellbore pressure p WD , the crack flow rate Q fi , starting from step A, a new round of p' WD and Q' fi is calculated;
  • the fifth step is mainly to compare and compare the theoretical curve and the measured curve in the double logarithmic curve, the semi-logarithmic curve and the full historical pressure curve. According to the fitting degree of the curve, the fitting parameters can be adjusted, and finally The theoretical curve and the measured curve can be well matched in the double logarithmic curve, the semi-logarithmic curve and the full historical pressure curve, and the curve fitting is completed; after the curve fitting is completed, the well test can be obtained. Interpreted parameters, including crack parameters and reservoir parameters.
  • the invention adopts the above technical solutions and has the following advantages, and has the advantages of fast calculation speed, good curve fitting and accurate interpretation result.
  • Figure 1 Three-dimensional geological body and grid dispersion of fractured horizontal wells considering well trajectory and reservoir heterogeneity
  • Figure 2 is a flow chart for the establishment and solution of the coupled model.
  • a method for solving a numerical well test model of a dense gas-fractured horizontal well includes the following steps:
  • Step 1 Formation of two-dimensional geological bodies and three-dimensional geological bodies in horizontal wells in tight gas reservoirs;
  • the geometrical Boolean operation is used to generate the three-dimensional geological body.
  • Step 2 As shown in Figure 1, the generated tight gas reservoir fracturing horizontal well two-dimensional geological body and three-dimensional geological body grid discrete; first, the Netgen open source software package is successfully compiled to build the operating environment;
  • the internal and external boundary genus in the 2D geological body and the 3D geological body are respectively formed into a 2D mesh file and a 3D mesh file according to the requirements of the Netgen mesh file format, and then the mesh discrete step is performed according to the mesh discrete step set by Netgen. .
  • Step 3 Calculation of seepage model without horizontal pressure difference in horizontal wellbore
  • the mixed finite element method is used to solve the transformed formation and fracture seepage equations.
  • the finite element equations of the stratum and fracture system are decomposed into the finite element equation of the formation region (the first term on the right side of Equation 9) and the finite element representing the fracture system. Equation (the second term on the right side of Equation 9).
  • the finite element equations (10) ⁇ (15) are combined to form the system stiffness matrix.
  • the parallelized SuperLU numerical solver is used to solve the large linear equations, and the pressure field distribution and the inner boundary normal pressure gradient of the whole reservoir can be obtained. Then calculate the production flow of each crack:
  • Step 4 Establish a coupling model, solve the established coupling model, and generate the test well theory curve by solving the obtained solution; and solve the established coupling model according to the following steps:
  • the multi-phase flow calculation formula of the wellbore is used to calculate, and the dimensionless differential pressure MP iD of each point of the wellbore is obtained.
  • the specific formula is as follows:
  • the liquid holdup rate H L and the frictional resistance coefficient ⁇ are calculated by the Beggs-Brill method.
  • the wellbore pressure gradient is obtained according to formula (17), and then the pressure difference between each point and the bottom hole standard point is obtained according to the relative distance of the inner boundary of the wellbore:
  • the dimensionless differential pressure MP iD at each point can be obtained.
  • step B The pressure difference MP iD at the inner boundary obtained in step A is brought into the seepage model to calculate the wellbore pressure p' WD and the crack flow Q' fi .
  • the coupling conditions of the wellbore multiphase flow model and the seepage model are as follows :
  • step D the p' WD determined in step C and the corresponding Q' fi are recorded. If the time step k ⁇ total time step n, then the calculation of the next time step is continued, according to the current wellbore pressure p WD , the crack flow rate Q fi , starting from step A, a new round of p' WD and Q' fi is calculated;
  • Step 5 Fitting the theoretical curve obtained in step 4 with the measured curve to obtain the parameters of the well test interpretation;
  • the fifth step is mainly to compare and compare the theoretical curve and the measured curve in the double logarithmic curve, the semi-logarithmic curve and the full historical pressure curve. According to the fitting degree of the curve, the fitting parameters can be adjusted, and finally The theoretical curve and the measured curve can be well matched in the double logarithmic curve, the semi-logarithmic curve and the full historical pressure curve, and the curve fitting is completed; after the curve fitting is completed, the well test can be obtained. Interpreted parameters, including crack parameters and reservoir parameters.
  • a two-dimensional geological body is built, and then a two-dimensional geological body is converted into a three-dimensional geological body.
  • the outer boundary of the geological body where the fracturing horizontal well is located the inner boundary of the wellbore, the crack and the composite zone are realized, and then the inner and outer boundaries and the crack properties are determined.
  • the specific size and shape of the geological body can quickly establish a two-dimensional geological body. From the two-dimensional geological body, combined with the well trajectory and the position of the upper and lower boundaries of the reservoir, the geometric Boolean operation can be used to directly generate the three-dimensional geological body, and the OpenCasCade tool is used to display the three-dimensional view, as shown in Figure 1.
  • the Netgen open source software package is successfully compiled, the running environment is set up, and then the internal and external boundary attributes in the 2D geological body are formed into a 2D mesh file according to the requirements of the Netgen grid file format, and then the mesh discrete steps set by Netgen are performed.
  • Grid discrete The discrete process of a 3D geological body is similar to the discrete process of a 2D geological body. The difference is that the 3D mesh discretization first needs to output the 3D geological body into a common format (such as STEP format), and then use Netgen to network the output format file.
  • Discrete The discrete time of the two-dimensional geological body is relatively short, and the time required is generally between 10s and 30s.
  • the discrete time of the three-dimensional geological body is long, and it needs to be determined according to the density of the discrete mesh. Usually, the discrete time is less than 5 minutes. Discrete grid nodes and grid lines are automatically displayed after the grid is discrete, as shown in Figure 1.
  • a well test interpretation model considering multi-factor coupling is established.
  • the parameters involved in the model are divided into known parameters and unknown parameters (parameters to be interpreted).
  • the known parameters and unknown parameters should be set different input interfaces to avoid confusion.
  • the known parameters are entered according to the actual situation, and the unknown parameters can be determined after the curve fitting is completed.
  • the numerical solution algorithm of the design model is designed, and the computer code of the model numerical solution is compiled, as shown in the model solution flow chart shown in FIG. 2 .
  • the basic data is input, the geological body model is established, and the geological body model is meshed.
  • the initial step is to calculate the seepage model according to the method of no pressure difference in the wellbore, and calculate the initial bottomhole flow pressure and the distribution of each crack flow.
  • the wellbore multiphase flow calculation model is used to calculate the differential pressure distribution of the wellbore, and then the differential pressure is used.
  • the seepage model is calculated to obtain a new bottom hole pressure and crack flow distribution, and compared with the previous calculation results to determine whether the iteration of the time step is over. If the difference between the two is less than the small amount ⁇ , the next time step is calculated, otherwise the iteration is continued until the next time is stabilized. The calculation of the step. Using this method, the calculation of all the set time steps is finally completed, that is, the solution of the coupled model is completed.
  • the well test theory curve is automatically generated, and the theoretical curve and the measured curve are compared and fitted in a double logarithmic curve, a semi-logarithmic curve and a full historical pressure curve.
  • the double logarithmic graph is in the main view, while the semi-log graph and the full historical pressure graph are in the auxiliary view region, and the fitting parameters can be adjusted according to the degree of fitting of the curve.
  • the theoretical curve and the measured curve can be well matched in the double logarithmic curve, the semi-logarithmic curve and the full historical pressure curve, and the curve fitting is completed. After the curve fitting is completed, the test can be obtained.
  • Well explained parameters including crack parameters and reservoir parameters.
  • a two-dimensional geological body is built, and then a two-dimensional geological body is converted into a three-dimensional geological body.
  • the heterogeneous characteristics of the reservoir including porosity, gas saturation and initial permeability distribution, are divided into different regions in the geological body, each region representing a homogeneous body, each The homogeneous bodies have different porosity, water saturation and initial permeability, and the heterogeneity of the entire geological system is composed of many different homogeneous bodies.
  • the two-dimensional geological body combined with the well trajectory and the position of the upper and lower boundaries of the reservoir, can directly generate three-dimensional geological bodies;
  • Better display of 3D geological bodies based on OpenCasCade tools for 3D view display, including 3D geological bodies, grid discrete maps, and computational cloud maps.
  • the generated geological body is converted into a STEP format file, an IGES format file or a BREP format file, and then the Netgen open source tool is used to realize the automatic mesh discrete function of the two-dimensional geological body and the three-dimensional geological body, and the two-dimensional mesh is a triangular mesh, three-dimensional The mesh is a tetrahedral mesh.
  • the grid around the wellbore and the crack is automatically encrypted by setting the number of cracks and discrete nodes of the wellbore, and the discrete quality of the grid is controlled by setting the discrete parameters of the grid.
  • the denser the mesh the more the mesh volume, the longer the mesh discrete time, the longer the calculation time, and the smaller the mesh size will affect the calculation accuracy. Therefore, the actual mesh density should be selected.
  • the amount of two-dimensional grid is between 10,000 and 30,000, and the amount of three-dimensional grid is between 100,000 and 500,000.
  • the tight gas fracturing horizontal well is divided into three flow areas: the wellbore, the fracture and the formation.
  • the flow mechanism is different in different regions.
  • the wellbore is a gas-liquid two-phase flow
  • the fracture is a high-speed non-Darcy flow
  • the formation is a stress-sensitive nonlinear seepage.
  • the fracture zone is regarded as the high-permeability high-speed non-Darcy flow zone. Since the crack width is small, the fluid flow in the fracture zone is regarded as two-dimensional flow, and a fracturing horizontal well is established.
  • Two-dimensional model is mainly used for completion of horizontal wellbore in casing form, and three-dimensional model is used for horizontal wellbore completion in open hole; in the basis of the seepage model Considering the gas-liquid two-phase flow in the wellbore, the Beggs-Brill method is used to establish the flow resistance calculation method of the gas-liquid two-phase flow in the wellbore.
  • the seepage model and the wellbore multiphase flow model are coupled according to the continuous pressure of the formation and the wellbore contact surface.
  • the model is numerically solved by the hybrid finite element method, and the seepage model and the wellbore gas-liquid two-phase flow calculation model are coupled and iteratively calculated.
  • the calculation time node is set to logarithmic distribution, and 10 to 20 calculation points are set in each logarithmic period.
  • the calculated start time and end time can be adjusted according to actual conditions.
  • the condition for the end of each time step is that the calculation results satisfy both the seepage model and the wellbore multiphase flow calculation model.
  • the SuperLU solver The linear equations of the two-dimensional model are solved, and the linear equations of the three-dimensional model are solved by the parallelized SuperLU solver.
  • the number of threads used for parallel computing is determined according to the calculated grid amount. Under normal circumstances, the number of parallel threads is set. 6 to 10 can meet the computing needs.
  • the well test theory curve is automatically generated, and the theoretical curve and the measured curve are compared and fitted in a double logarithmic curve, a semi-logarithmic curve and a full historical pressure curve.
  • the double logarithmic graph is in the main view, while the semi-log graph and the full historical pressure graph are in the auxiliary view region, and the fitting parameters can be adjusted according to the degree of fitting of the curve.
  • the theoretical curve and the measured curve can be well matched in the double logarithmic curve, the semi-logarithmic curve and the full historical pressure curve, and the curve fitting is completed. After the curve fitting is completed, the test can be obtained.
  • Well explained parameters including crack parameters and reservoir parameters.

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Abstract

La présente invention concerne un procédé pour établir et résoudre un modèle numérique d'essais de puits horizontal pour fracturation hydraulique de réservoir gazier compact. Le procédé comprend les étapes suivantes : (1) la génération de modèles de corps géologiques bidimensionnel et tridimensionnel d'un puits horizontal pour fracturation hydraulique de réservoir gazier compact ; (2) la réalisation d'une discrétisation en grille sur les modèles de corps géologiques bidimensionnel et tridimensionnel du puits horizontal pour fracturation hydraulique de réservoir gazier compact ; (3) le calcul d'un modèle de percolation d'un puits de forage horizontal qui ne présente aucune différence de pression ; (4) l'établissement d'un modèle d'accouplement, la résolution du modèle d'accouplement établi, et la génération d'une courbe théorique d'essais de puits à partir de la solution acquise ; et (5) l'ajustement de la courbe théorique acquise dans l'étape (4) et d'une courbe mesurée pour acquérir des paramètres d'interprétation d'essais de puits. La présente invention présente les avantages de calcul rapide, de bon ajustement de courbe, et de résultats d'interprétation précis.
PCT/CN2015/080767 2015-06-04 2015-06-04 Procédé pour établir et résoudre un modèle numérique d'essais de puits horizontal pour fracturation hydraulique de réservoir gazier compact Ceased WO2016192077A1 (fr)

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