CN109630078B - In-layer generation of CO2Method for designing profile control process parameters - Google Patents
In-layer generation of CO2Method for designing profile control process parameters Download PDFInfo
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- E—FIXED CONSTRUCTIONS
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- 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
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/164—Injecting CO2 or carbonated water
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Abstract
The application discloses in-layer generation of CO2The method for designing the profile control process parameters comprises the following steps: simplifying an actual oil layer into a multi-oil-layer geological model containing a profile control layer and a de-plugging layer; dynamically splitting the using amounts of the gas generating agent and the gas releasing agent, and establishing a gas generating agent injection amount, a gas releasing agent injection amount, gas generating agent injection time, gas releasing agent injection time and injection section plug number calculation model when the water absorption index variation coefficient is minimized by analyzing the difference degree of the water absorption indexes of all small layers after profile control and flooding; establishing an injection pressure calculation model of the gas generating agent and the gas releasing agent; the above model is solved by a genetic algorithm. In-layer CO generation for the present application2The design method of profile control process parameters comprises the following steps: the injection amount and the injection slug number of the profile control and flooding agent (the gas generating agent and the gas releasing agent) can be calculated; the real-time prediction calculation of the injection pressure in the construction process can be realized; and the measure effect is visually represented.
Description
Technical Field
The application relates to the field of petroleum, in particular to in-situ CO generation in oil reservoir water injection development2A design method for profile control and flooding process parameters.
Background
In-layer CO generation2The parameters of the profile control and flooding process mainly comprise the consumption of gas generating agent and gas releasing agent, the design of parameters of a slug, the construction injection pressure and the injection displacement. The scientific and reasonable design of the profile control and flooding process parameters can avoid the pollution of the low-permeability layer by the plugging agent, improve the water absorption profile to the maximum extent and enlarge the swept volume, thereby improving the effectiveness of profile control and flooding measures. The dosage design of the current profile control and flooding agent mainly comprises the following components: the method for determining the profile control agent dosage of the decision technology of the pressure drop index PI (pressure index) and the oil reservoir engineering RE (reservoir engineering) needs a field test injection experiment to determine the dosage coefficient, and is high in cost; secondly, the numerical simulation method needs the processes of history fitting, multi-section plug combination prediction and the like, and the time consumption is long; thirdly, a ratio method of front and rear injection capacities needs to determine the ratio of water absorption capacities before and after the profile control and flooding interval treatment in advance, and the flexibility is poor. The design method of the injection pressure of the profile control agent mainly comprises a selective injection pressure method, a displacement setting method, a numerical simulation method and the like. The selective injection pressure method and the displacement setting method need mine field experiments to determine injection pressure gradient and the like, and have high cost; the numerical simulation method needs geological modeling, historical fitting and the like, and the research period is long.
Disclosure of Invention
In order to solve the above technical problems, the present application provides a method for generating CO in a layer2The design method of profile control and flooding process parameters comprises establishing in-layer CO generation2Designing a model of the injection amount and the injection slug of the medicament in the profile control and flooding process; and starting from the pressure balance of the injection and production system, and establishing a real-time calculation model of the injection pressure in the construction process by combining the calculated real-time displacement. Therefore, the design of construction process parameters is realized, and the optimal medicament dosage and the optimal profile control and flooding effect are achieved.
To achieve the objects of the present application, the present application provides an in-layer CO generation2The method for designing the profile control process parameters comprises the following steps:
(1) simplifying an actual oil layer into a multi-oil-layer geological model containing a profile control layer and a de-plugging layer;
(2) dynamically splitting the using amounts of the gas generating agent and the gas releasing agent, and establishing a gas generating agent injection amount, a gas releasing agent injection amount, gas generating agent injection time, gas releasing agent injection time and injection section plug number calculation model when the water absorption index variation coefficient is minimized by analyzing the difference degree of the water absorption indexes of all small layers after profile control and flooding;
(3) establishing an injection pressure calculation model of the gas generating agent and the gas releasing agent;
(4) the above model is solved by a genetic algorithm.
In this application, the reaction to CO is injected into the formation through the injection well2Herein, the term "within a layer" refers to within a reservoir formation. Due to the ubiquitous difference in reservoir water uptake index, gas generants and gas release agents selectively penetrate the formation. According to the inflow dynamic of the profile control agent in the stratum, CO is generated in the combined layer2The results of the profile control and drive selection layer can simplify the actual oil layer into a multi-oil-layer ideal geological model containing a profile control and drive layer and a blockage removal layer, a small layer in the stratum which needs to be obviously blocked is defined as the profile control and drive layer, a gas release agent is needed for acidification to improve the physical properties of the stratum, and CO is used for improving the physical properties of the stratum2The small layer where the foam blocking effect is insignificant is defined as the deblocking layer.
After the profile control and flooding measures are taken, due to the natural selection effect of the profile control and flooding agent on the stratum, the water absorption index of each profile control and flooding layer is reduced in different degrees, the non-uniform degree of the relative water absorption of the high-permeability and low-permeability layers is also reduced continuously, and the water absorption profile is effectively improved. With the continuous injection of the profile control agent, the difference of the water absorption indexes of the high-permeability and low-permeability layers is smaller and smaller. When the total injection amount of the profile control agent reaches a certain degree, the difference of the water absorption indexes of the high and low permeable layers is reduced to the minimum value, the profile control agent is continuously injected, and the difference of the water absorption indexes is increased. Therefore, an optimal amount of the profile control agent exists, and the heterogeneity of the water absorption profile can be improved to the maximum extent.
And (3) assuming that the wellhead injection pressure and injection displacement of the profile control and flooding well are reasonably controlled, all small layers are started, and the performance parameters (including concentration, viscosity, density and the like) of the gas generating agent and the gas releasing agent are fixed. The formation is homogeneous and uniform horizontally, and the elastic effect of the liquid and the rock stratum is neglected. The first digit of the subscript of the appointed letter code is that i represents a driver layer and j represents a deblocking layer. The first digit of the convention letter code is 1 for an air generating agent and 2 for an air releasing agent.
Single injection of gas generating agent process
The profile control and flooding process can firstly carry out a single gas generating agent injection process, and under a certain instant time step, the total split amount of the gas generating agent is equal to the discharge volume v of the gas generating agent at the instant1(z) the total amount of cleavage of the outgasing agent is equal to the displacement v of the outgasing agent at that moment2(z)。
The seepage of the gas-generating agent in the stratum conforms to the linear seepage rule. Therefore, on a longitudinal section, the total injection amount of the gas generating agent in unit time step can be split into small layers according to the water absorption index distribution before the displacement control measure by utilizing Darcy's law.
In the formula: j. the design is a squareiAdjusting the water absorption index of the flooding layer i before the flooding measure, m3/(h·MPa)；JjWater absorption index, m, of the unblocking layer j before the profile control measures3/(h·MPa)；v1(z) is the displacement of the z-th slug gas generating agent, m3/h； n1The number of the small layers is the number of the profile control layer; n is2The number of the blocking removing layers is small; q1iTo adjust the gas-generating agent injection quantity, m, of the flooding layer i3； kiPermeability of profile control layer i, mD; h isiIs the effective thickness of the profile control layer i, m; k is a radical ofjPermeability of the unblocking layer i, mD; h isjIs the effective thickness of the deblocking layer i, m; mu.swViscosity of water, mPa · s; r iswFor the well bore radius of a water injection well，m；reIs the drainage radius, m; a is a unit conversion coefficient, and a is 0.0036.
Then, the plugging radius of the gas generating agent on each small layer at the time step can be calculated according to a volume method:
in the formula, rfiThe plugging radius of the gas generating agent of the profile control layer i is m; phi is aiTo adjust the porosity of the flooding layer i.
In the profile control layer, because the gas generating agent is a solution of certain carbonate, a large amount of aggregation can also generate a weak plugging effect, and therefore, the reduction of the permeability caused by the single injection of the gas generating agent is not negligible. The plugging action of the gas generating agent forms a low-permeability area around the wellbore of the profile control and flooding layer, thereby causing the change of a stratum seepage field. The flow area of formation fluid within the profile control zone may be divided into a flow from the wellbore to the plugging radius and a flow from the plugging radius to the supply edge annulus according to the varying characteristics of the formation seepage resistance. From this, the water absorption index J 'of each modifying layer after the gas generating agent was injected can be calculated'i：
In the formula: j'iIn order to adjust the water absorption index of the flooding layer after the gas generating agent is injected, m3/(h·MPa)；RRF1And generating the residual resistance coefficient of the aerogenic agent.
The effect of the injection of the gas generating agent of the blocking removing layer is neglected, so that the water absorption index of the blocking removing layer is kept unchanged before and after the injection of the gas generating agent:
in the formula: k is a radical ofjPermeability of the deblocking layer, mD; h isjM, the effective thickness of the deblocking layer; j. the design is a squarej、JjWater absorption index m before and after the measures of removing the blocking layer3/(h·MPa)。
Annotating a gasagent Process
After completion of the gas generant injection process, a gas generant solution may be injected into the formation. In the first time step, the air release agent can be split in each layer according to the water absorption index of each layer after the air generation agent is injected.
In the formula: j'iAdjusting the water absorption index of the flooding layer i, m, after the flooding measures3/(h·MPa)；J′jWater absorption index m of unblocking layer j after profile control and flooding measures3/(h·MPa)；v2(z) is the displacement of the z-th slug release agent, m3/h； Q2iIn order to adjust the injection amount of the gas release agent m of the flooding layer i3；Q2j is the injection amount of the outgas agent of the deblocking layer j, m3；
The gas generating agent reacts with the gas releasing agent to generate CO2The foam system, and to deblocking layer, because remaining oil saturation is higher, meets oil defoaming effect, so can calculate the deblocking radius who transfers the foam shutoff radius on the flooding layer and deblocking layer under a time step according to the volume method:
in the formula: r isfiThe plugging radius of the gas generating agent of the profile control layer i is m; r isfiThe foam plugging radius of the profile control layer i is m; r issjThe deblocking radius of the deblocking layer j, m.
Calculating the water absorption index of each layer after the first time step:
in the formula: theta is the acidification degree of the gas release agent; RRF is the foam residual drag coefficient.
And in the next time step, when the dosage of the air release agent is split, splitting is carried out according to the water absorption index of each layer after the change of the last time step.
After a certain time step, the amount of the gas releasing agent in the profile control and flooding layer is more than the total amount of the gas generating agent, namely
At the moment, a water absorption index calculation formula in the profile control and flooding layer is changed, the profile control and flooding layer has the acidification effect of the gas release agent, and the foam plugging radius and the acidification radius of the gas release agent of the profile control and flooding layer can be calculated according to a volume method:
the water absorption index calculation formula of the profile control layer and the unblocking layer is as follows:
after the slug cycle, the final water absorption index of each small layer was used as an evaluation index. The closer the water absorption indexes of the small layers are, the more uniform the water absorption profile in the water injection process is. Therefore, in order to reflect the difference degree of the water absorption indexes of the permeable layers after profile control and flooding, the coefficient of variation is used as an evaluation index. In statistics, the coefficient of variation, also known as the standard deviation rate, is defined as the ratio of the standard deviation of a set of observations to the mathematical expectation, which reflects the degree of dispersion and difference between the observations. The coefficient of variation of the water absorption index can thus be defined as follows:
wherein
In the formula:to adjust the average water absorption index of the formation after flooding, m3/(h·MPa)；VJThe coefficient of variation of the water absorption index.
The larger the water absorption index variation coefficient after profile control is, the larger the difference degree of the water absorption capacity of each layer is, the more uneven the water absorption profile is, and the lower the effect degree of the measures is; otherwise, the more uniform the water absorption profile, the better the profile control effect. Therefore, the construction parameter when the coefficient of variation of the water absorption index reaches the minimum value is the formation of CO in the layer2And adjusting and driving optimal construction parameters. The design process comprises the following steps:
the above formula is respectively substituted into the water absorption index variation coefficient formula, so that the water absorption index is found under the condition that the formation parameters, the performance parameters of the gas generating agent and the gas releasing agent are certainCoefficient of numerical variation VJIs a gas generating agent and a gas releasing agent with a discharge volume v1(z) v2(z) days of inflatant/outgasser injection d1 d2The number of slugs z is a function of VJ[v1(z)，v2(z)，d1，d2，z]. Thus by solving the objective function VJ[v1(z)，v2(z)，d1，d2，z]The minimum value of the above-mentioned two components can be used to obtain the discharge volume v of gas-generating agent and gas-releasing agent1 v2Days d for injecting qi-generating agent and qi-releasing agent1 d2And the number z of the slugs. Because the objective function is a nonlinear optimization problem, in order to quickly and accurately obtain a global optimal solution, a genetic algorithm is adopted for solving.
Model for calculating injection pressure of gas generating agent and gas releasing agent
In the process of injecting the gas generating agent and the gas releasing agent, the pressure of an injection system is balanced at any time, so that a pressure equation in the construction process can be established according to a pressure balance principle and a seepage theory:
Pwht＝Pft+ΔP+Pr-Pht (20)
in the formula: pwhtInjecting pressure of the agent wellhead in MPa; phtThe liquid column pressure of the medicament in a shaft is MPa; pftIs friction resistance of the medicament in a shaft, and is MPa; delta P is displacement differential pressure, MPa; prIs the current formation pressure, MPa.
Liquid column pressure P of medicament in wellborehtComprises the following steps:
in the formula: rhotIs the density of the medicament, g/cm3(ii) a H is the depth of the profile control layer section, m.
Friction resistance P of medicine in wellftComprises the following steps:
in the formula: q is the injection speed of the drug, m3S; v is kinematic viscosity of the medicament, m2S; d is the diameter of the oil pipe, m; beta and m are friction coefficient, and the value is related to the fluid state of the fluid.
Because the Reynolds number is smaller in the injection process of the profile control agent, the flow state mainly presents laminar flow or hydraulic smoothness. In laminar flow, β is 4.15, m is 1; when the hydraulic power is smooth, beta is 0.0246, and m is 0.25.
The displacement pressure difference Δ P is:
in the formula: v-discharge of the agent, m3/h；
Will Pht、ΔPw、ΔP、PftThe formula (20) is substituted, and the calculation formula of the wellhead injection pressure is obtained by arranging:
from equation (24), it can be seen that the wellhead injection pressure P of the agent is determined for the optimum displacementwhtHas also been determined. Therefore, the construction pressure during injection with the optimal displacement can be calculated, and a construction pressure curve can be drawn.
The genetic algorithm is used to solve the equation (24) as shown in fig. 4, and the basic operation steps can be expressed as follows:
(1) initializing operation, and determining genetic operation methods such as selection, intersection and mutation operators and genetic parameters such as intersection probability and mutation probability;
(2) selecting a coding strategy, and converting the feasible solution set into a chromosome structure space to generate an initial population;
(3) defining an adaptive function, which is convenient for calculating the fitness value of an individual;
(4) judging termination conditions, if the group performance meets a certain index or the preset iteration times are finished, terminating the iterative operation, otherwise, turning to the operation of the step (5);
(5) selecting copy operation, and processing the population by using a corresponding selection operator;
(6) performing cross operation, namely processing the population by using a corresponding cross operator;
(7) performing mutation operation, namely processing the population by using a corresponding mutation operator;
(8) and (3) forming a next generation population after the parent population is subjected to selection, intersection and mutation operator operation, and then turning to the step (2).
The design method can also be applied to reservoir water injection development, and CO is generated in the reservoir by using the gas generating agent dosage, the gas releasing agent dosage and the slug number obtained by the design method2After the profile control and the flooding, the water injection amount and the accumulated augmented injection of the water injection well are both obviously increased, and the net oil increasing effect of the well group oil well is obvious.
Compared with the conventional in-layer CO generation2The design method has the following advantages that the profile control process parameter is calculated: (1) the injection amount and the injection slug number of the profile control and flooding agent (the gas generating agent and the gas releasing agent) can be calculated; (2) the real-time prediction calculation of the injection pressure in the construction process can be realized; (3) static and dynamic factors are comprehensively considered, and the calculation method is more matched with the process characteristics and is more scientific.
Additional features and advantages of the application will be set forth in the description which follows, and in part will be obvious from the description, or may be learned by the practice of the application. The objectives and other advantages of the application may be realized and attained by the structure particularly pointed out in the written description and claims hereof as well as the appended drawings.
Drawings
The accompanying drawings are included to provide a further understanding of the claimed subject matter and are incorporated in and constitute a part of this specification, illustrate embodiments of the subject matter and together with the description serve to explain the principles of the subject matter and not to limit the subject matter.
FIG. 1 is a schematic diagram of an ideal geologic model of "multi-reservoir".
FIG. 2 is a diagram of process parameter design concept.
Fig. 3 is a schematic view of a pressure system.
FIG. 4 is a schematic diagram of a genetic algorithm.
Fig. 5 is a graph of construction displacement over time in the embodiment of the present application.
Fig. 6 is a graph showing the change of the construction pressure with time in the embodiment of the present application.
FIG. 7 is a water injection curve of a construction well in the embodiment of the application, and the construction time is 2016 from 5 months and 24 days to 5 months and 27 days.
FIG. 8 is a set oil production curve of a construction well in the embodiment of the application, and the construction time is 2016 from 5 months and 24 days to 5 months and 27 days.
Detailed Description
To make the objects, technical solutions and advantages of the present application more apparent, embodiments of the present application will be described in detail below with reference to the accompanying drawings. It should be noted that the embodiments and features of the embodiments in the present application may be arbitrarily combined with each other without conflict.
Examples
The general principles of the invention are explained below with respect to water injection wells by way of example, but it should be noted that the present application is in no way limited to the following water injection wells. The following water injection well data were used for calculation, the basic data of the water injection well are shown in table 5-1:
TABLE 1 basic data of water injection well
| Small layer | Thickness/m | Porosity of | permeability/mD | Daily water absorption/m/d | Corrected permeability/mD | Flooding/unblocking layer |
| L30 | 1.3 | 0.247 | 62 | 0 | 50 | Unblocking layer |
| L40 | 14.5 | 0.287 | 1572.15 | 423.8 | 175.94 | Unblocking layer |
| L50 | 15.1 | 0.285 | 2206.60 | 3284.45 | 1309.35 | Layer of driving and regulating |
| L60 | 13.5 | 0.273 | 954 | 1907.1 | 850.37 | Layer of driving and regulating |
| L70 | 8.5 | 0.246 | 678.01 | 529.75 | 375.16 | Unblocking layer |
| L80+L90 | 34.6 | 0.256 | 849.14 | 3496.35 | 608.29 | Layer of driving and regulating |
| L100 | 23.5 | 0.252 | 719.38 | 741.65 | 189.98 | Layer of driving and regulating |
| L110 | 4.3 | 0.225 | 438 | 211.9 | 296.64 | Unblocking layer |
According to the calculation formula in the text, a genetic algorithm is applied to solve, and the final calculation results are as follows:
TABLE 2 Water injection well dosage
TABLE 3 gas generating agent and gas releasing agent discharge volume of each slug of water injection well
| Number of slugs | Gas generating agent injection speed/m3/h | Injection velocity of gas releasing agent/m3/h |
| 1 | 16.14 | 19.49 |
| 2 | 16.35 | 21.13 |
| 3 | 16.37 | 21.25 |
| 4 | 16.49 | 18.77 |
| 5 | 16.66 | 21.56 |
Water injection well carries out in-situ CO generation according to design results in text2The water injection quantity after the drive regulation measures is 982m3D rises to 1732m3107 days of increased injection and 39254m of cumulative increased injection3(ii) a 6 production wells in the well group, wherein 5 production wells have effect, and 8000m cumulative net oil increase3The effective period is 5 months.
Although the embodiments disclosed in the present application are described above, the descriptions are only for the convenience of understanding the present application, and are not intended to limit the present application. It will be understood by those skilled in the art that various changes in form and details may be made therein without departing from the spirit and scope of the disclosure as defined by the appended claims.
Claims (5)
1. In-layer generation of CO2The method for designing the profile control process parameters comprises the following steps:
(1) simplifying the actual oil layer into a multi-oil-layer geological model comprising a profile control layer, a flooding layer and a de-plugging layer, defining a small layer in the stratum needing obvious plugging as the profile control layer, needing a gas release agent for acidification to improve the physical properties of the stratum, and simultaneously using CO for improving the physical properties of the stratum2The small layer with unobvious foam plugging function is defined as a deblocking layer;
(2) firstly, performing a single gas generating agent injection process, and then performing a gas agent injection process; dynamically splitting the using amounts of the gas generating agent and the gas releasing agent, and establishing a gas generating agent injection amount, a gas releasing agent injection amount, gas generating agent injection time, gas releasing agent injection time and injection section plug number calculation model when the water absorption index variation coefficient is minimized by analyzing the difference degree of the water absorption indexes of all small layers after profile control and flooding;
(3) establishing an injection pressure calculation model of the gas generating agent and the gas releasing agent;
(4) the above model is solved by a genetic algorithm.
2. The method according to claim 1, wherein in step (2), at a certain moment in time step, the total amount of split of the gas generant is equal to that at that moment in timeDischarge volume v of gas generating agent1(z) the total amount of cleavage of the outgasing agent is equal to the displacement volume v of the outgasing agent at that moment2(z)，
And splitting the total injection amount of the gas generating agent in unit time step into small layers according to the water absorption index distribution before the profile control and flooding measures:
in the formula: j. the design is a squareiAdjusting the water absorption index of the flooding layer i before the flooding measure, m3/(h·MPa)；JjWater absorption index, m, of the unblocking layer j before the profile control measures3/(h·MPa)；v1(z) is the displacement of the z-th slug gas generating agent, m3/h；n1The number of the small layers is the number of the profile control layer; n is2The number of the blocking removing layers is small; q1iTo adjust the gas-generating agent injection quantity, m, of the flooding layer i3；kiPermeability of profile control layer i, mD; h isiIs the effective thickness of the profile control layer i, m; k is a radical ofjPermeability, mD, of the unblocking layer j; h isjIs the effective thickness of the unblocking layer j, m; mu.swViscosity of water, mPa · s; r iswIs the radius of the well bore of the water injection well, m; r iseIs the drainage radius, m; and a is a unit conversion coefficient a equal to 0.0036.
3. The method according to claim 1, wherein in step (3), a pressure calculation model in the construction process is established according to a pressure balance principle and a seepage theory:
Pwht＝Pft+ΔP+Pr-Pht (20)
wherein the content of the first and second substances,Pwhtinjecting pressure of the agent wellhead in MPa; phtThe liquid column pressure of the medicament in a shaft is MPa; pftIs friction resistance of the medicament in a shaft, and is MPa; delta P is displacement differential pressure, MPa; prIs the current formation pressure, MPa.
4. The method of claim 1, wherein in step (4), the solving includes chromosome coding, individual fitness evaluation, selection replication operations, crossover operations, and mutation operations.
5. Use of the method of any one of claims 1 to 3 in reservoir waterflooding.
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| CN106761618A (en) * | 2016-12-26 | 2017-05-31 | 中国石油天然气股份有限公司 | For the profile control method for determination of amount and its device of water injection well |
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