CN115273997A - Temporary plugging acidification design method utilizing temperature response type temporary plugging agent - Google Patents
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Abstract
The invention discloses a temporary plugging acidification design method by using a temperature response type temporary plugging agent, which comprises the following specific steps: acquiring basic data and determining the number of segmented acidification segments; (2) preferably selecting an acid liquor system and a construction process; (3) Calculating the acid liquor consumption and a shaft-stratum temperature field, and selecting a temperature response type liquid gel temporary plugging agent; (4) Calculating the dosage of the temporary plugging agent, and determining a gelling reaction kinetic equation; (5) Calculating a shaft-stratum temperature field and optimizing design construction parameters; (6) And (5) repeating the step (S3) to the step (S5) and designing construction parameters of each section of acidification. The design method provided by the invention is comprehensive in system and strong in operability; the influence of multiple factors is considered, so that the calculation result is more accurate; the injected liquid is all liquid, and the construction difficulty is small.
Description
Technical Field
The invention relates to an acidification yield-increasing technology in the development process of an oil and gas field, in particular to a temporary plugging acidification design method by using a temperature response type temporary plugging agent, and belongs to the field of yield-increasing transformation of the oil and gas field.
Background
In order to improve economic benefit, many oil and gas wells adopt multilayer commingled production or single-layer long well section development, and the production reduction phenomenon is increasingly highlighted due to the problem of reservoir heterogeneity. In addition, screen completion is widely used in offshore and partially onshore oil and gas fields to address problems such as reservoir sand production and borehole wall instability. Compared with hydraulic fracturing and acid fracturing, matrix acidification (acidification for short) yield increase technology has the advantages of small risk, small occupied space, low construction cost and the like, and is widely applied. In order to solve the problem caused by reservoir heterogeneity, temporary plugging agents (also called diverting agents and diverting agents) are applied to acidification production increase so as to realize uniform acidification reconstruction of the whole well section. However, because the sieve tube has high sand blocking precision, solid temporary plugging agents such as chemical particles, fibers and the like are difficult to enter a reservoir through the sieve tube, and the use of the solid temporary plugging agents is limited. Therefore, liquid-based temporary plugging agents that become sticky and liquid-based gels are preferred. Most of the liquid viscosity-changing temporary plugging agents are viscoelastic surfactants, viscosity changing is realized by forming micelles, but the effect of the viscosity-changing temporary plugging agents is extremely undesirable for reservoirs with strong heterogeneity (meaning great permeability difference). Therefore, a liquid gel-forming temporary plugging agent is used. In recent years, various temperature-responsive liquid gel-forming temporary plugging agents have been developed, such as a temperature-responsive microgel disclosed in CN110283579B, a temperature-responsive self-degrading temporary plugging agent disclosed in CN113185960B and CN113185656B, a temperature-responsive hydrogel disclosed in CN111187607A, an intelligent diverter disclosed in CN111269703A, a thermotropic supramolecular gel disclosed in CN106190087B, and the like. However, due to the lack of a temperature response type temporary plugging and acidizing design method of the liquid gel temporary plugging agent, the construction success rate is not ideal, and the large-scale popularization and application of the temporary plugging and acidizing agent are also limited.
Disclosure of Invention
The invention aims to provide a design method for temporary plugging acidification by using a temperature response type temporary plugging agent, and the specific technical scheme is as follows.
Step S1: acquiring well body structure and well track data, thermophysical property parameters and temperature gradient data of each stratum, porosity, permeability and skin coefficient distribution data along a well bore in a production layer, and determining the number n of segmented acidizing sections by specifically calculating the following (Schroebalance. Complex carbonate reservoir horizontal well high-efficiency acidizing numerical simulation research [ D ]. Southwest oil university, 2017. Leying Yingchuan. Second edition of oil production engineering [ M ]. Beijing: oil industry Press, 2008.):
in the formula: j-production index, m3V (d.Pa); n is the number of segmented acidification sections and is dimensionless; ki-section i acidified permeability, D; h isiThe acid treatment is single-stage long, m; mu-reservoir fluid viscosity, pa · s; r ise-the bleed radius, m; r isw-wellbore radius, m; kd,i-permeability of the zone of contamination, section i, D; r isi-radius of acidification, m. And optimizing the number n of the segmented acidification sections by taking the J optimal as a target.
Step S2: selecting a main acid solution type according to the lithology of the reservoir, determining an acid solution injection process according to the selected main acid solution type, and selecting a main acid solution system according to a construction purpose, wherein the method specifically comprises the following steps: if the reservoir is sandstone, selecting a fluorine-containing acid liquid system as the main acid liquid acid type; if the carbonate rock is adopted, a non-fluorine-containing acid solution system is selected as the main acid solution acid type; if the main acid liquid acid type is a fluorine-containing acid liquid system, a hydrochloric acid liquid injection process is added before and after the main acid is injected to create an acidic environment and avoid secondary precipitation damage to a reservoir; if the construction purpose requires that the acid liquid can penetrate deeply, a main acid liquid system should be a retarding acid liquid system, and a common retarding acid liquid system comprises self-generated acid, fluoboric acid, polyhydroic acid and the like; if the construction purpose requires high corrosion, the main acid system should be earth acid or hydrochloric acid.
And step S3: calculating the acid liquor consumption, considering the pit shaft-stratum temperature field of acid rock reaction heat, selecting temperature response type liquid gel forming temporary plugging agent, and requiring bottom hole temperature TbottomIs less than but close to the gelling temperature T of the temperature response type liquid gelling temporary plugging agentgelAnd the treatment zone virgin formation temperature ToriginIs higher than the gel breaking temperature T of the temperature response type liquid gel temporary plugging agentbreak。
The acid liquor consumption is specifically calculated as follows (Zhang Feng super. Offshore oil well acidification self-acid generation system research [ D)]Southwest university of petroleum, 2019.), and the amount of the main acid solution QmThe calculation formula is as follows:
in the formula: qmAmount of main acid solution, m3(ii) a Phi-porosity, decimal; n is a radical ofDa-DamKahler number, dimensionless; n is a radical ofACAcid capacity, dimensionless.
If the main acid isThe liquid is a fluorine-containing acid liquid system, and the dosage Q of the preposed hydrochloric acid liquid is also required to be designedpreAnd the amount of the hydrochloric acid solution Q is added at the rear partlaterDosage Q of hydrochloric acid solution is presetpreThe calculation formula is as follows:
in the formula: qprePre hydrochloric acid solution dosage, m3；CHCl-hydrochloric acid solubles fraction, decimal; xHClThe solvency of hydrochloric acid, dimensionless; zeta1Empirical coefficients, typically greater than 1.
The dosage Q of the post hydrochloric acid solutionlaterThe calculation formula is as follows:
in the formula: qlaterThe amount of hydrochloric acid solution used, m3；rmDisplacement radius (recommended greater than 0.5 m), m; zeta2Empirical coefficients, typically greater than 1.
The wellbore-formation temperature field considering the acid rock reaction heat is specifically calculated as follows, and the calculation formula of the wellbore temperature field is (xian chao authigenic solid-phase chemical fracturing temperature field simulation research [ D ]. Southwest university of petroleum, 2018 ]):
in the formula: q. q.sj-flow at unit j in the wellbore, m3/s；Tj,flu-the temperature of the fluid at cell j in the wellbore, K; x-borehole trajectory direction, m; r is a radical of hydrogenj-the pipe inside radius at unit j in the wellbore, m; alpha is alphaj-convective heat transfer coefficient of fluid at unit j in wellbore and pipe wall, W/(m)2·K)；Tj,c/s-wall temperature, K, at unit j in the wellbore; rhoj-density of fluid at unit j in wellbore, kg/m3；Cj-the specific heat capacity of the fluid at unit J in the wellbore, J/(kg · K); f. ofj-friction coefficient at unit j in the wellbore; u. ofj-flow velocity, m/s, at cell j in the wellbore; t is time, s.
The formation temperature field calculation formula is (cheiran. Complex carbonate reservoir horizontal well high-efficiency acidizing numerical simulation research [ D ]. Southwest oil university, 2017.):
in the formula: rhosRock density, kg/m3；CPs-specific heat capacity of rock, J/(kg K); t iss-rock temperature, K; rhofFluid density, kg/m3；CPf-fluid specific heat capacity, J/(kg K); t is a unit off-the fluid temperature, K; u-flow velocity, m/s; k is a radical ofef-fluid thermal conductivity, W (/ m · K); k is a radical of formulaes-rock thermal conductivity, W/(m · K); delta Hr-enthalpy of acid rock reaction, J/mol; a isv-specific pore surface area, m2/m3；kc-mass transfer velocity, m/s; cfAcid liquid mass concentration in pores, mol/m3；CsThe mass concentration of the acid solution at the pore wall surface, mol/m3。
Determining the solution conditions: initially, keeping the temperature distribution in the shaft consistent with the formation temperature, wherein the formation temperature is the original formation temperature; the wellhead temperature is the actual temperature of the injected fluid, and the formation adopts a constant temperature boundary condition.
And step S4: and calculating the dosage of the temperature response type liquid gel forming temporary plugging agent, and determining a gel forming reaction kinetic equation. Dosage Q of temperature response type liquid gel forming temporary plugging agentdivThe calculation formula is as follows:
in the formula: qdivTemperature responsive liquid gel-forming type temporaryAmount of blocking agent, m3；ζ3-empirical coefficients, generally greater than 1; pn-temporary blocking strength, MPa; pbThe breakthrough pressure gradient is MPa/m.
Gel forming reaction kinetics equation determination methods (Zhang Nanlin. Phase transition self-supporting fracturing Key theory research [ D ]. Southwest Petroleum university, 2022; wang Yan Lian. Synthesis of modified fatty amine and its curing reaction research on epoxy [ D ]. Henan university, 2015; wang Lin Hao, rongming, et al. Curing reaction kinetics research of liquid polycarbosilanes [ J ]. Macromolecule Notification, 2016, (09): 149-155: non-isothermal Differential Scanning Calorimetry (DSC) tests are carried out on the temperature response type liquid gel forming temporary plugging agent at different heating rates, the preferable heating rate is 2.5, 5.0, 7.5, 10.0, 12.5, 15.0, 17.5, 20.0, 22.5, 25.0, 27.5 or 30.0K/min, at least 3 heating rates are selected, and the DSC test result is simply processed to obtain heat delta H and gel forming rate d alpha/dt; calculating an index factor A and an activation energy E by using an integral method Flynn-Wall-Ozawa method and a differential method Kissinger-Akahira-Sunose method, respectively averaging the results obtained by the two methods, and calculating a kinetic index n by using a crank equation; taking the DSC test result into a formula (8), and drawing y (alpha) -alpha experiment graphs; a common kinetic mechanism function f (alpha) (corresponding to function numbers from 1 to 45) is taken into formula (9), and a standard curve chart from y (alpha) to alpha is drawn; and drawing the standard curve graph and the experimental curve graph together, comparing the experimental curve with which standard curve has the highest contact ratio, and selecting the kinetic mechanism function f (alpha) with the highest contact ratio to carry into the formula (10) to obtain the gelling reaction kinetic equation.
y(α)＝Af(α) (9)
In the formula: y (α) -defining a function; e-activation energy, J/mol; r is the molar gas constant, J/(mol.K); t-temperature, K; alpha-gel formation rate, decimal; a-pre-exponential factor, s-1(ii) a f (α) -a kinetic mechanism function; d α/dt-gel formation rate, s-1。
Step S5: and calculating a shaft-stratum temperature field considering the gelling reaction heat and the acid rock reaction heat of the temperature response type liquid gelling temporary plugging agent, and optimizing and designing construction parameters.
The wellbore-stratum temperature field considering the gelling reaction heat and the acid rock reaction heat of the temperature response type liquid gelling temporary plugging agent is specifically calculated as follows, and the calculation formula of the wellbore temperature field is as follows:
in the formula: Δ H-Heat (positive for exotherm and negative for endotherm), J/kg; vj-volume at unit j in the wellbore, m3。
The calculation formula of the formation temperature field is as follows:
by varying the injection displacement qjThe injection time t can regulate and control the distribution of the temperature field, so that the temperature response type liquid gel temporary plugging agent cannot gel in a shaft, and can gel in the stratum as soon as possible to realize temporary plugging, and finally the aim of optimizing design construction parameters is fulfilled; the preferred injection rate should correspond to a bottom hole pressure that is not greater than the formation fracture pressure.
Step S6: repeating the step S3 to the step S5, and designing construction parameters of each section of acidification; when designing the last segment, only step 3 needs to be repeated.
In the calculation method, the same symbols related in all formulas have the same meaning, and the symbols are all universal after being labeled once.
The flow of the design method for temporary plugging and acidizing by using the temperature response type temporary plugging agent is shown in figure 1.
The invention has the advantages that: the design method for realizing uniform acidification of the heterogeneous reservoir based on the temperature response type liquid gel forming temporary plugging agent is provided, and the method is comprehensive in system and strong in operability; all injected liquid is liquid during construction, and the liquid can smoothly pass through sand control completion tools such as a sieve tube and the like and enter a reservoir; the reaction heat, the friction heat, the heat conduction and the heat convection are considered, and the temperature field is calculated more accurately.
Additional advantages, objects, and features of the invention will be set forth in part in the description which follows and in part will become apparent to those having ordinary skill in the art upon examination of the following or may be learned from practice of the invention.
Drawings
FIG. 1 is a flow chart of a design method for temporary plugging acidification by using a temperature responsive temporary plugging agent.
FIG. 2 is a profile of a property parameter of a producing zone along a horizontal wellbore.
FIG. 3 is a plot of number of staged acidification stages versus production index.
FIG. 4 is a wellbore temperature profile.
FIG. 5 is a profile of a formation temperature distribution.
Figure 6 is DSC test data.
Detailed Description
The preferred embodiments of the present invention will be described in conjunction with the accompanying drawings, and it will be understood that they are described herein for the purpose of illustration and explanation and not limitation.
Examples
Taking an offshore BZ oilfield Y-5H well as an example, the lithology of a producing zone of the Y-5H well is sandstone, the middle part of the producing zone is vertical to 3650m in depth, the horizontal section is 1250m in length, and in the open hole sand control screen pipe well completion, the producing zone has a larger positive skin coefficient due to the damage of drilling fluid, and temporary plugging acidification modification is needed.
Step S1: the porosity, permeability and skin coefficient distribution data along the shaft in the producing zone are shown in fig. 2, the drainage radius is 600m, the shaft radius is 0.07m, the average pollution zone radius of the horizontal well section is 0.15m, the average pollution zone radius of the horizontal well section is 470-1250 m is 0.36m, and the successful acidification plug removal needs to break through the pollution zone (namely, the acidification radius is not less than the pollution zone radius, and the acidification radius can be set to be equal to the pollution zone radius). Setting 5 segmentation schemes, scheme 1: the whole well is generally acidized, i.e. not segmented; scheme 2: the whole well is acidified in 2 sections, and the acidification is 0-470 m and 470-1250 m; scheme 3: the whole well is divided into 3 sections for acidification, which are divided into 0-470 m, 470-910 m and 910-1250 m; scheme 4: the whole well is divided into 4 sections for acidification, and the sections are divided into 0-470 m, 470-780 m, 780-950 m and 950-1250 m; scheme 5: the whole well is divided into 5 sections for acidification, and the sections are 0-470 m, 470-610 m, 610-770 m, 770-950 m and 950-1250 m. J under different schemes is calculated by formula (1), as shown in fig. 3, the more segments are, the larger J is, but the more complicated the corresponding construction operation is, so that scheme 3 is optimal in 3 segments, i.e. n =3.
Step S2: the lithology is sandstone, the main acid liquid acid type is a fluorine-containing acid liquid system, and a hydrochloric acid liquid injection process is added before and after the main acid is injected; as the physical property of the reservoir is relatively good, the construction purpose requires high corrosion to remove pollution, and the main acid system is selected from earth acid.
Section 1 (0-470 m)
And step 3: the DamKahler number is 0.06, the acid capacity is 0.09, the average porosity is 0.16, the acid treatment single section length is 470m, the acidification radius is 0.15m, the well bore radius is 0.07m, the soluble matter content ratio of hydrochloric acid is 0.12, the dissolving capacity of hydrochloric acid is 0.08, zeta1Empirical coefficient 1.2, displacement radius 0.6m, ζ2The empirical factor is 1.2. Calculating the main acid solution consumption by the formula (2) to be 65.3m3Calculating the consumption of the pre-hydrochloric acid solution by the formula (3) to be 39.3m3The consumption of the post hydrochloric acid solution is calculated by the formula (4) to be 100.6m3. Well trajectory: the vertical well section is 0-2100 m, the deflecting section is 2100-4534 m, and the horizontal section is 4534-5784 m. The oil pipe injects, the injection displacement is 0.8m3And/min. Oil pipe: inner diameter of 0.38m, outer diameter of 0.045m, density of 7420kg/m3The specific heat capacity is 470J/(kg. DEG C.), and the thermal conductivity is 49J/(m. DEG C. S). Injecting a fluid: viscosity of 0.02 pas and density of 1100kg/m3The specific heat capacity is 3500J/(kg. DEG C.), and the thermal conductivity is 0.6J/(m. DEG C. S). Rock: density 2340kg/m3Specific heat capacity 285J/(kg. DEG C.), thermal conductivity 2.7J/(m. DEG C. S). Ground temperature 18 deg.CThe temperature gradient is 3.4 ℃/100m, the HCl concentration is 15 percent, the HF concentration is 3 percent, the acid-rock reaction enthalpy is 13692J/mol, and the pore specific surface area is 3000m2/m3. The wellbore temperature profile calculated from equation (5) is shown in fig. 4, and the formation temperature profile calculated from equation (6) is shown in fig. 5. The bottom hole temperature is about 77 ℃, the temperature of the original formation of the treated layer is about 142 ℃, and the temporary plugging agent PSA-2 disclosed in CN201610532563.4 is selected according to the conditions that the initial gel forming temperature is 90 ℃, the final gel forming temperature is 95 ℃, the initial gel breaking temperature is 120 ℃ and the final gel breaking temperature is 125 ℃.
And step S4: temporary plugging strength is 2.5MPa, and breakthrough pressure gradient is 29.3MPa/m, zeta3The empirical coefficient is 1.3, the acid treatment single section length is 470m, the well bore radius is 0.07m, and the dosage of the temperature response type liquid gel temporary plugging agent is 36.9m calculated by the formula (7)3. DSC test data are shown in FIG. 6, and Δ H is calculated to be 1.9kJ/g, pre-exponential factor 2.7X 1012The activation energy is 90.2kJ/mol and the kinetic index is 2.2, a kinetic mechanism function obtained by formulas (8) and (9) is a function number 2, and a gelling reaction kinetic equation is obtained by substituting the kinetic mechanism function into a formula (10) as follows:
step S5: the wellbore temperature distribution is calculated from equation (11) and the formation temperature distribution is calculated from equation (12). By changing the injection displacement, the temperature distribution of the shaft and the stratum under different displacements can be obtained; the greater the injection displacement, the lower the wellbore-formation temperature will be. Because the gelling is an endothermic process, the temperature of the shaft-stratum obtained under the conditions of the same discharge capacity and the same injection time is lower than that of the shaft-stratum obtained in the figures 4 and 5, so that the temporary plugging agent cannot gel in the shaft and can rapidly gel in the stratum, and the injection discharge capacity is optimized to be 0.4m3Min, and the bottom hole pressure corresponding to the discharge is lower than the fracture pressure of the producing zone, and the bottom hole temperature is 83 ℃.
Step S6: repeating the step S3 to the step S5, and designing the construction parameters of the section 2 acidification in the same way; only step 3 is repeated, and the acidification construction parameters of the last section (namely the 3 rd section) can be designed similarly.
Although the present invention has been described with reference to a preferred embodiment, it should be understood that various changes, substitutions and alterations can be made herein without departing from the spirit and scope of the invention as defined by the appended claims.
Claims (4)
1. A design method for temporary plugging acidification by using a temperature response type temporary plugging agent is characterized by comprising the following steps:
s1: acquiring well structure and well track data, thermophysical parameters and temperature gradient data of each stratum layer, porosity, permeability and skin coefficient distribution data along a well shaft in a production layer, and determining the number of segmented acidification sections;
s2: selecting a main acid solution type according to reservoir lithology, determining an acid solution injection process according to the selected main acid solution type, and selecting a main acid solution system according to a construction purpose;
s3: calculating the acid liquor consumption, considering the pit shaft-stratum temperature field of acid rock reaction heat, selecting temperature response type liquid gel forming temporary plugging agent, and requiring bottom hole temperature TbottomIs less than but close to the gelling temperature T of the temperature response type liquid gelling temporary plugging agentgelAnd the treatment zone virgin formation temperature ToriginIs higher than the gel breaking temperature T of the temperature response type liquid gel temporary plugging agentbreak；
S4: calculating the dosage of the temperature response type liquid gel forming temporary plugging agent, and determining a gel forming reaction kinetic equation;
s5: calculating a shaft-stratum temperature field considering the gelling reaction heat and the acid rock reaction heat of the temperature response type liquid gelling temporary plugging agent, and optimizing and designing construction parameters;
s6: repeating the step S3 to the step S5, and designing construction parameters of each section of acidification; when the last segment is designed, only step 3 needs to be repeated.
2. The design method for temporary plugging acidification by using the temperature response type temporary plugging agent according to claim 1, wherein in step S2, if the reservoir is sandstone, a fluoric acid solution system is selected as the main acid solution; if the carbonate rock is adopted, a non-fluorine-containing acid solution system is selected as the main acid solution acid type; if the main acid liquid is in an acid type containing fluorine acid liquid, a hydrochloric acid liquid injection process is added before and after the main acid is injected; if the construction purpose requires that the acid liquid can penetrate deeply, a main acid liquid system should select a retarding acid liquid system; if the construction purpose requires high corrosion, the main acid system should be earth acid or hydrochloric acid.
3. The design method for temporary plugging and acidizing by using the temperature response type temporary plugging agent as claimed in claim 1, wherein in the step S4, the dosage Q of the temperature response type liquid gel type temporary plugging agent is useddivThe calculation formula is as follows:
in the formula: qdivThe dosage of the temperature response type liquid gel temporary plugging agent m3；hiThe acid treatment is single-stage long, m; zeta3-empirical coefficients, generally greater than 1; p isn-temporary blocking strength, MPa; pb-breakthrough pressure gradient, MPa/m; r iswThe wellbore radius, m.
4. The design method for temporary plugging and acidizing by using the temperature-responsive temporary plugging agent as claimed in claim 1, wherein in step S5, the wellbore-formation temperature field considering the gelling reaction heat and the acid rock reaction heat of the temperature-responsive liquid gelling temporary plugging agent is specifically calculated as follows, and the calculation formula of the wellbore temperature field is as follows:
in the formula: q. q.sj-flow at unit j in the wellbore, m3/s；Tj,flu-the temperature of the fluid at cell j in the wellbore, K; x-borehole trajectory direction, m; r isj-the inside radius of the tube at unit j in the wellbore, m; alpha is alphaj-convective heat transfer coefficient of fluid at unit j in wellbore and pipe wall, W/(m)2·K)；Tj,c/s-wall temperature, K, at unit j in the wellbore; ρ is a unit of a gradientj-density of fluid at unit j in wellbore, kg/m3；Cj-the specific heat capacity of the fluid at unit J in the wellbore, J/(kg · K); f. ofj-friction coefficient at unit j in the wellbore; u. ofj-flow velocity, m/s, at cell j in the wellbore; t is time, s; Δ H-Heat (positive for exotherm and negative for endotherm), J/kg; vj-volume at unit j in the wellbore, m3；
The calculation formula of the formation temperature field is as follows:
in the formula: rhosRock density, kg/m3；CPs-specific heat capacity of rock, J/(kg K); t is a unit ofs-rock temperature, K; rhofFluid density, kg/m3；CPf-fluid specific heat capacity, J/(kg K); t isf-the fluid temperature, K; u-flow velocity, m/s; phi-porosity, decimal; k is a radical ofef-fluid thermal conductivity, W (/ m · K); k is a radical ofes-the thermal conductivity of the rock, W/(m · K); delta Hr-enthalpy of acid rock reaction, J/mol; a is avPore specific surface area, m2/m3；kc-mass transfer velocity, m/s; cfAcid liquid mass concentration in pores, mol/m3；CsAcid solution mass concentration at pore wall surface, mol/m3(ii) a By varying the injection displacement qjAnd the injection time t regulates and controls the distribution of the temperature field, so that the temperature response type liquid gel temporary plugging agent cannot gel in a shaft and cannot gel in the stratumCan be gelatinized as soon as possible to realize temporary plugging; the preferred injection rate should correspond to a bottom hole pressure that is not greater than the formation fracture pressure.
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| CN117266844A (en) * | 2023-10-12 | 2023-12-22 | 中国石油大学(华东) | Repeated temporary plugging acid pressure well and layer selecting method for fracture-cavity carbonate rock |
| CN117266844B (en) * | 2023-10-12 | 2024-04-09 | 中国石油大学(华东) | Repeated temporary plugging acid pressure well and layer selecting method for fracture-cavity carbonate rock |
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