CN110792418A - Wellbore working fluid formula optimization method and device - Google Patents
Wellbore working fluid formula optimization method and device Download PDFInfo
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- CN110792418A CN110792418A CN201810880327.0A CN201810880327A CN110792418A CN 110792418 A CN110792418 A CN 110792418A CN 201810880327 A CN201810880327 A CN 201810880327A CN 110792418 A CN110792418 A CN 110792418A
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/13—Methods or devices for cementing, for plugging holes, crevices, or the like
Abstract
The invention provides a method and a device for optimizing a formula of a shaft working fluid. The invention provides a wellbore working fluid formula optimization method, which comprises the following steps: the method comprises the steps of obtaining the cohesion of a rock to be tested in a first shaft working fluid and establishing a first relation graph, obtaining the cohesion of a second rock of the rock to be tested in a second shaft working fluid and establishing a second relation graph, establishing a third relation graph according to the first relation graph, the second relation graph and a preset shaft wall stabilizing model, then determining the cohesion of a first compliance rock according to the preset performance requirement of the first shaft working fluid and the third relation graph, determining the first compliance concentration of an inhibitor corresponding to the cohesion of the first compliance rock according to the second relation graph, and taking the first compliance concentration as the concentration of the inhibitor in a shaft working fluid formula. According to the optimization method of the shaft working fluid formula, the relation between the stability of the well wall and the shaft working fluid formula is established, so that the shaft working fluid formula is optimized and designed by using the determined parameters.
Description
Technical Field
The invention relates to the technical field of petroleum exploration, in particular to a method and a device for optimizing a shaft working fluid formula.
Background
Drilling, fracturing and completion fluids are all important components of oilfield chemistry, collectively referred to as wellbore servicing fluids. The common feature is that a single fluid is usually used as a medium, and chemical additives are added to form a complex fluid with special functions.
In the oil drilling process, the idea of designing and optimizing the traditional shaft working fluid formula is as follows: firstly, control indexes such as high-temperature high-pressure water loss, rolling recovery rate and the like of the shaft working fluid are provided, and then formula optimization is carried out according to the indexes.
Therefore, in the optimization method in the prior art, evaluation is only performed according to the performance of the wellbore working fluid, and the final objective of the wellbore working fluid is to maintain the stability of the well wall, so that a wellbore working fluid formula optimization design method based on the requirement of the stability of the well wall needs to be established.
Disclosure of Invention
The invention provides a method and a device for optimizing a formula of a shaft working fluid, which aim to solve the problem of establishing a relation between the stability of a well wall and the formula of the shaft working fluid, so that the optimization design of the formula of the shaft working fluid is developed by using determined parameters.
In a first aspect, the invention provides a wellbore working fluid formulation optimization method, including:
acquiring the cohesion of a first rock of a rock to be tested after the rock to be tested is soaked in a first shaft working fluid for a first time, wherein the concentration of an inhibitor in the first shaft working fluid is a first concentration, and establishing a first relation graph according to the cohesion of the first rock and the first time, wherein the first relation graph is used for representing the relation between the cohesion of the rock to be tested and the soaking time;
acquiring the cohesion of a second rock of the rock to be detected after the rock to be detected is soaked in a second shaft working fluid for a second time, wherein the concentration of the inhibitor in the second shaft working fluid is a second concentration, and establishing a second relation graph according to the cohesion of the second rock and the second concentration, wherein the second relation graph is used for representing the relation between the cohesion of the rock to be detected and the concentration of the inhibitor;
establishing a third relational graph according to the first relational graph, the second relational graph and a preset borehole wall stability model, wherein the third relational graph is used for representing the relation between the collapse pressure equivalent density and the cohesion of the rock to be detected under different expanding conditions;
determining a first compliant rock cohesion from a preset first wellbore servicing fluid performance requirement and the third relationship map, wherein the first wellbore servicing fluid performance requirement comprises: the first hole diameter expansion rate and the first shaft working fluid density are the minimum rock cohesion value for ensuring that the rock to be detected does not collapse;
and determining a first compliant concentration of the inhibitor corresponding to the cohesion of the first compliant rock according to the second relational graph, and using the first compliant concentration as the concentration of the inhibitor in the wellbore working fluid formula.
In one possible design, after the determining the first compliant concentration of the inhibitor corresponding to the cohesion of the first compliant rock according to the second relationship graph, the method further includes:
measuring the cohesion of a third rock of the rock to be detected after the rock to be detected is soaked in the shaft working fluid for the second time;
determining whether the third rock cohesion is greater than the first compliant rock cohesion;
and if the judgment result is yes, the formula of the shaft working fluid is qualified.
In one possible design, after the determining the first compliant concentration of the inhibitor corresponding to the cohesion of the first compliant rock according to the second relationship graph, the method further includes:
establishing a fourth relational graph according to the borehole wall stable model and the permeability coefficient of the rock to be detected obtained through measurement, wherein the fourth relational graph is used for representing the relation between the collapse pressure equivalent density and the permeability coefficient of the rock to be detected under different expanding conditions;
determining a first compliant rock permeability coefficient according to a preset second wellbore working fluid performance requirement and the fourth relational graph, wherein the second wellbore working fluid performance requirement comprises: the first hole diameter expansion rate and the first shaft working fluid density are the same, and the first compliance rock permeability coefficient is the minimum permeability coefficient which ensures that the rock to be detected does not permeate;
and determining a first compliance addition amount of a first plugging agent and a second compliance addition amount of a second plugging agent according to the first compliance rock permeability coefficient and a preset relation graph of the plugging agent and the permeability coefficient, taking the first compliance addition amount as the addition amount of the first plugging agent in the shaft working fluid formula, and taking the second compliance addition amount as the addition amount of the second plugging agent in the shaft working fluid formula.
In one possible design, the determining a first compliant addition amount of the first plugging agent and a second compliant addition amount of the second plugging agent according to the first compliant rock permeability coefficient and a preset plugging agent-permeability coefficient relation map further comprises:
measuring a first permeability coefficient of the rock to be detected after the rock to be detected is soaked in the shaft working fluid for the second time;
determining whether the first permeability coefficient is less than the first compliant rock permeability coefficient;
and if the judgment result is yes, the formula of the shaft working fluid is qualified.
In one possible design, the first blocking agent is ultrafine calcium carbonate and the second blocking agent is a fibrous blocking agent.
In a second aspect, the present invention further provides a wellbore fluid formulation optimization device, including:
the system comprises an acquisition module, a storage module and a control module, wherein the acquisition module is used for acquiring the cohesion of a first rock after a rock to be detected is soaked in a first shaft working fluid for a first time, the concentration of an inhibitor in the first shaft working fluid is a first concentration, a first relation graph is established according to the cohesion of the first rock and the first time, and the first relation graph is used for representing the relation between the cohesion of the rock to be detected and the soaking time;
the obtaining module is further configured to obtain a second rock cohesion of the rock to be detected after the rock to be detected is soaked in a second wellbore working fluid for a second duration, where a concentration of the inhibitor in the second wellbore working fluid is a second concentration, and a second relational graph is established according to the second rock cohesion and the second concentration, where the second relational graph is used to represent a relationship between the cohesion of the rock to be detected and the concentration of the inhibitor;
the calculation module is used for establishing a third relation graph according to the first relation graph, the second relation graph and a preset borehole wall stability model, and the third relation graph is used for representing the relation between the collapse pressure equivalent density and the cohesion of the rock to be detected under different diameter expansion conditions;
the calculation module is further configured to determine a first compliant rock cohesion according to a preset first wellbore servicing fluid performance requirement and the third relationship graph, where the first wellbore servicing fluid performance requirement includes: the first hole diameter expansion rate and the first shaft working fluid density are the minimum rock cohesion value for ensuring that the rock to be detected does not collapse;
and the determining module is used for determining a first compliance concentration of the inhibitor corresponding to the cohesion of the first compliance rock according to the second relation graph, and using the first compliance concentration as the concentration of the inhibitor in the wellbore working fluid formula.
In one possible design, the wellbore fluid formulation optimization device further includes:
the measuring module is used for measuring the cohesion of the third rock after the rock to be measured is soaked in the shaft working fluid for the second time;
and the judging module is used for judging whether the cohesion of the third rock is greater than the cohesion of the first compliant rock, wherein if the judgment result is yes, the formula of the shaft working fluid is qualified.
In a possible design, the calculation module is further configured to establish a fourth relational graph according to the borehole wall stability model and the permeability coefficient of the rock to be measured, where the fourth relational graph is used to represent a relationship between the collapse pressure equivalent density and the permeability coefficient of the rock to be measured under different diameter expansion conditions;
the calculation module is further configured to determine a first compliant rock permeability coefficient according to a preset second wellbore fluid performance requirement and the fourth relational graph, where the second wellbore fluid performance requirement includes: the first hole diameter expansion rate and the first shaft working fluid density are the same, and the first compliance rock permeability coefficient is the minimum permeability coefficient which ensures that the rock to be detected does not permeate;
the determining module is further configured to determine a first compliance dosage of a first blocking agent and a second compliance dosage of a second blocking agent according to the first compliance rock permeability coefficient and a preset relation diagram of the blocking agent and the permeability coefficient, use the first compliance dosage as the dosage of the first blocking agent in the wellbore working fluid formula, and use the second compliance dosage as the dosage of the second blocking agent in the wellbore working fluid formula.
In a possible design, the measurement module is further configured to measure a first permeability coefficient of the rock to be measured after the rock to be measured is soaked in the wellbore working fluid for the second time period;
the judgment module is further used for judging whether the first permeability coefficient is smaller than the first compliance rock permeability coefficient, wherein if the judgment result is yes, the shaft working fluid formula is qualified.
In one possible design, the first blocking agent is ultrafine calcium carbonate and the second blocking agent is a fibrous blocking agent.
The invention provides a shaft working fluid formula optimization method and a device, a first relation graph is established by obtaining the cohesion of a first rock after a rock to be detected is soaked in a first shaft working fluid for a first time, a second relation graph is established by obtaining the cohesion of a second rock after the rock to be detected is soaked in a second shaft working fluid for a second time, a third relation graph used for representing the relation between collapse pressure equivalent density and the cohesion of the rock to be detected under different expanding conditions is established according to the first relation graph, the second relation graph and a preset shaft wall stability model, then the cohesion of the first compliant rock is determined according to the preset performance requirement of the first shaft working fluid and the third relation graph, a first compliance concentration of an inhibitor corresponding to the cohesion of the first compliant rock is determined according to the second relation graph, and the first compliance concentration is used as the concentration of the inhibitor in the shaft working fluid formula, by establishing the relationship between the stability of the well wall and the formula of the working fluid of the well wall, the determined parameters are utilized to carry out the optimization design of the formula of the working fluid of the well wall, and the stability of the well wall is effectively maintained.
Drawings
In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the drawings used in the description of the embodiments or the prior art will be briefly described below, and it is obvious that the drawings in the following description are only some embodiments of the present invention, and for those skilled in the art, other drawings can be obtained according to these drawings without creative efforts.
FIG. 1 is a flow chart illustrating a method of wellbore servicing fluid formulation optimization according to an exemplary embodiment of the present invention;
FIG. 2a is a schematic diagram of a first relationship diagram in the embodiment shown in FIG. 1;
FIG. 2b is a schematic diagram of a second relationship diagram in the embodiment shown in FIG. 1;
FIG. 2c is a schematic illustration of a third relationship diagram in the embodiment of FIG. 1;
FIG. 3 is a flow chart illustrating a method of wellbore servicing fluid formulation optimization according to another exemplary embodiment of the present invention;
FIG. 4a is a schematic diagram of a fourth relationship diagram for the embodiment shown in FIG. 3;
FIG. 4b is a graph of the plugging agent of FIG. 3 versus permeability coefficient;
FIG. 5 is a flow chart illustrating a wellbore fluid formulation optimization device according to an exemplary embodiment of the present invention;
FIG. 6 is a flow chart illustrating a wellbore fluid formulation optimization device according to another exemplary embodiment of the present invention.
Detailed Description
The technical solutions in the embodiments of the present invention will be clearly and completely described below with reference to the drawings in the embodiments of the present invention, and it is obvious that the described embodiments are only a part of the embodiments of the present invention, and not all of the embodiments. All other embodiments, which can be derived by a person skilled in the art from the embodiments given herein without making any creative effort, shall fall within the protection scope of the present invention.
The terms "first," "second," "third," "fourth," and the like in the description and in the claims, as well as in the drawings, if any, are used for distinguishing between similar elements and not necessarily for describing a particular sequential or chronological order. It is to be understood that the data so used is interchangeable under appropriate circumstances such that the embodiments of the invention described herein are, for example, capable of operation in sequences other than those illustrated or otherwise described herein. Furthermore, the terms "comprises," "comprising," and "having," and any variations thereof, are intended to cover a non-exclusive inclusion, such that a process, method, system, article, or apparatus that comprises a list of steps or elements is not necessarily limited to those steps or elements expressly listed, but may include other steps or elements not expressly listed or inherent to such process, method, article, or apparatus.
The technical solution of the present invention will be described in detail below with specific examples. The following several specific embodiments may be combined with each other, and details of the same or similar concepts or processes may not be repeated in some embodiments.
FIG. 1 is a flow chart illustrating a method for wellbore fluid formulation optimization according to an exemplary embodiment of the present invention. As shown in fig. 1, the method for optimizing a wellbore fluid formulation provided in this embodiment includes:
Specifically, the cohesion of a first rock of the rock to be tested after the rock to be tested is soaked in a first wellbore working fluid for a first time period is obtained, wherein the concentration of an inhibitor in the first wellbore working fluid is a first concentration, a first relation graph is established according to the cohesion of the first rock and the first time period, and the first relation graph is used for representing the relation between the cohesion of the rock to be tested and the soaking time period.
Fig. 2a is a schematic illustration of a first relationship diagram in the embodiment shown in fig. 1. As shown in fig. 2a, a rock mechanical test is performed on the rock to be tested, so as to obtain the corresponding cohesion of the rock to be tested after being soaked for different times. Cohesion, which is an important parameter characterizing the stability of rocks, is the mutual attraction between adjacent parts within the same substance, which is an indication of the molecular forces existing between the molecules of the same substance.
And 102, obtaining the cohesion of the second rock after the rock to be detected is soaked in the second shaft working fluid for a second time, and establishing a second relation graph according to the cohesion of the second rock and the second concentration.
Specifically, the cohesion of the second rock of the rock to be tested after the rock to be tested is soaked in the second shaft working fluid for a second time period is obtained, wherein the concentration of the inhibitor in the second shaft working fluid is a second concentration, a second relation graph is established according to the cohesion of the second rock and the second concentration, and the second relation graph is used for representing the relation between the cohesion of the rock to be tested and the concentration of the inhibitor.
Fig. 2b is a schematic diagram of a second relationship diagram in the embodiment shown in fig. 1. As shown in fig. 2b, a rock mechanical test is performed on the rock to be tested, so that the corresponding cohesion of the rock to be tested after being soaked in wellbore working fluids with different concentrations of KCl is obtained.
And 103, establishing a third relational graph according to the first relational graph, the second relational graph and a preset borehole wall stable model.
Specifically, a third relation graph is established according to the first relation graph, the second relation graph and a preset borehole wall stability model, and the third relation graph is used for representing the relation between the collapse pressure equivalent density and the cohesion of the rock to be detected under different expanding conditions. It should be noted that, in this embodiment, the preset borehole wall stable model is a model in the prior art, and may be any borehole wall stable model in the prior art, which is not specifically limited in this embodiment.
Fig. 2c is a schematic diagram of a third relationship diagram in the embodiment shown in fig. 1. As shown in fig. 2c, the third relation chart includes a relation between the collapse pressure equivalent density under different expanding conditions and the cohesion of the rock to be measured, and specifically includes: and (3) the relation between the collapse pressure equivalent density and the cohesion of the rock to be detected under the conditions of 1.1 times of the well diameter, 1.15 times of the well diameter and 1.2 times of the well diameter. And from fig. 2c, it can be seen that the following wellbore fluid density vs. rock cohesion is shown in table one:
illustratively, the wellbore servicing fluid density in Table one corresponds to the collapse pressure equivalent density in FIG. 2 c. In the practical application process, according to the drilling period and the stratum characteristics of a certain well, the comprehensive cost and practical consideration, the hole diameter expansion rate is required to be controlled to be less than or equal to 15%, and the key performance required by the working fluid of the shaft of the mudstone section is as follows: the wellbore servicing fluid density was 1.28.
And step 104, determining the cohesion of the first compliant rock according to the preset performance requirement of the first wellbore working fluid and the third relational graph.
Specifically, the first compliant rock cohesion is determined according to a preset first wellbore servicing fluid performance requirement and a third relational graph, wherein the first wellbore servicing fluid performance requirement comprises: the first hole diameter expansion rate and the first shaft working fluid density are the minimum rock cohesion value which ensures that the rock to be measured does not collapse.
From the first table and fig. 2c, it can be seen that the rock cohesion is greater than or equal to 7.8MPa, i.e. the first compliant rock cohesion is 7.8 MPa.
And 105, determining a first compliance concentration of the inhibitor corresponding to the cohesion of the first compliance rock according to the second relation diagram, and using the first compliance concentration as the concentration of the inhibitor in the wellbore working fluid formula.
Specifically, a first compliance concentration of the inhibitor corresponding to the cohesion of the first compliant rock is determined according to the second relational graph, and the first compliance concentration is used as the concentration of the inhibitor in the wellbore working fluid formula.
Wherein, the stronger the inhibition of the shaft working fluid, the lower the weakening degree of the shaft working fluid to the rock strength. The inhibition of the shaft working fluid is reflected by selecting different high-efficiency low-cost inhibitors, such as the addition of KCl, the formation collapse pressure under corresponding conditions is calculated by testing the rock strength of each inhibitor under different concentrations and different soaking times, and the collapse pressure equivalent density is obtained from the formation collapse pressure.
In the practical application example described above, the cohesive force of the first compliant rock is 7.8MPa, and referring to fig. 2b, the corresponding first compliant concentration can be known, and the first compliant concentration is used as the concentration of the inhibitor in the wellbore fluid formulation.
After determining the first compliance concentration for the inhibitor in the wellbore servicing fluid formulation, to verify that the wellbore servicing fluid formulation meets actual operating requirements. And measuring the cohesion of the third rock after the rock to be measured is soaked in the shaft working fluid for a second time, judging whether the cohesion of the third rock is greater than the cohesion of the first compliant rock, and if so, determining that the shaft working fluid is qualified.
In the practical example, the KCl-polysulfonate or KCl-polymer can be added into the wellbore working fluid formula, and after the KCl-polysulfonate or KCl-polymer wellbore working fluid acts on the core, the cohesive force of the rock is respectively 8.6MPa and 8.2MPa, and is respectively more than 7.8MPa, so that the requirement of controlling the borehole wall expanding diameter to be less than or equal to 15% is met.
In the embodiment, a first relation graph is established by obtaining the cohesion of a first rock after a rock to be detected is soaked in a first wellbore working fluid for a first time, a second relation graph is established by obtaining the cohesion of a second rock after the rock to be detected is soaked in a second wellbore working fluid for a second time, a third relation graph used for representing the relation between the collapse pressure equivalent density and the cohesion of the rock to be detected under different expanding conditions is established according to the first relation graph, the second relation graph and a preset wellbore stability model, the cohesion of the first compliant rock is determined according to the preset performance requirement of the first wellbore working fluid and the third relation graph, a first compliance concentration of an inhibitor corresponding to the cohesion of the first compliant rock is determined according to the second relation graph, the first compliance concentration is used as the concentration of the inhibitor in a wellbore working fluid formula, and the relationship between the wellbore stability and the wellbore working fluid formula is established, therefore, the determined parameters are utilized to carry out the optimization design of the formula of the shaft working fluid, and the stability of the shaft wall is effectively maintained.
FIG. 3 is a flow chart illustrating a method of wellbore servicing fluid formulation optimization according to another exemplary embodiment of the present invention. As shown in fig. 3, the method for optimizing the formulation of the wellbore fluid provided in this embodiment includes:
Specifically, the cohesion of a first rock of the rock to be tested after the rock to be tested is soaked in a first wellbore working fluid for a first time period is obtained, wherein the concentration of an inhibitor in the first wellbore working fluid is a first concentration, a first relation graph is established according to the cohesion of the first rock and the first time period, and the first relation graph is used for representing the relation between the cohesion of the rock to be tested and the soaking time period.
As shown in fig. 2a, a rock mechanical test is performed on the rock to be tested, so as to obtain the corresponding cohesion of the rock to be tested after being soaked for different times. Cohesion, which is an important parameter characterizing the stability of rocks, is the mutual attraction between adjacent parts within the same substance, which is an indication of the molecular forces existing between the molecules of the same substance.
Specifically, the cohesion of the second rock of the rock to be tested after the rock to be tested is soaked in the second shaft working fluid for a second time period is obtained, wherein the concentration of the inhibitor in the second shaft working fluid is a second concentration, a second relation graph is established according to the cohesion of the second rock and the second concentration, and the second relation graph is used for representing the relation between the cohesion of the rock to be tested and the concentration of the inhibitor.
Fig. 2b is a schematic diagram of a second relationship diagram in the embodiment shown in fig. 1. As shown in fig. 2b, a rock mechanical test is performed on the rock to be tested, so that the corresponding cohesion of the rock to be tested after being soaked in wellbore working fluids with different concentrations of KCl is obtained.
And step 203, establishing a third relational graph according to the first relational graph, the second relational graph and a preset borehole wall stable model.
Specifically, a third relation graph is established according to the first relation graph, the second relation graph and a preset borehole wall stability model, and the third relation graph is used for representing the relation between the collapse pressure equivalent density and the cohesion of the rock to be detected under different expanding conditions. It should be noted that, in this embodiment, the preset borehole wall stable model is a model in the prior art, and may be any borehole wall stable model in the prior art, which is not specifically limited in this embodiment.
Fig. 2c is a schematic diagram of a third relationship diagram in the embodiment shown in fig. 1. As shown in fig. 2c, the third relation chart includes a relation between the collapse pressure equivalent density under different expanding conditions and the cohesion of the rock to be measured, and specifically includes: and (3) the relation between the collapse pressure equivalent density and the cohesion of the rock to be detected under the conditions of 1.1 times of the well diameter, 1.15 times of the well diameter and 1.2 times of the well diameter.
Illustratively, the wellbore servicing fluid density in Table one corresponds to the collapse pressure equivalent density in FIG. 2 c. In the practical application process, according to the drilling period and the stratum characteristics of a certain well, the comprehensive cost and practical consideration, the hole diameter expansion rate is required to be controlled to be less than or equal to 15%, and the key performance required by the working fluid of the shaft of the mudstone section is as follows: the wellbore servicing fluid density was 1.28.
And step 204, determining the cohesion of the first compliant rock according to the preset performance requirement of the first wellbore working fluid and the third relational graph.
Specifically, the first compliant rock cohesion is determined according to a preset first wellbore servicing fluid performance requirement and a third relational graph, wherein the first wellbore servicing fluid performance requirement comprises: the first hole diameter expansion rate and the first shaft working fluid density are the minimum rock cohesion value which ensures that the rock to be measured does not collapse.
From the first table and fig. 2c, it can be seen that the rock cohesion is greater than or equal to 7.8MPa, i.e. the first compliant rock cohesion is 7.8 MPa.
And step 205, determining a first compliance concentration of the inhibitor corresponding to the cohesion of the first compliance rock according to the second relation diagram, and using the first compliance concentration as the concentration of the inhibitor in the wellbore working fluid formula.
Specifically, a first compliance concentration of the inhibitor corresponding to the cohesion of the first compliant rock is determined according to the second relational graph, and the first compliance concentration is used as the concentration of the inhibitor in the wellbore working fluid formula.
Wherein, the stronger the inhibition of the shaft working fluid, the lower the weakening degree of the shaft working fluid to the rock strength. The inhibition of the shaft working fluid is reflected by selecting different high-efficiency low-cost inhibitors, such as the addition of KCl, the formation collapse pressure under corresponding conditions is calculated by testing the rock strength of each inhibitor under different concentrations and different soaking times, and the collapse pressure equivalent density is obtained from the formation collapse pressure.
In the practical application example described above, the cohesive force of the first compliant rock is 7.8MPa, and referring to fig. 2b, the corresponding first compliant concentration can be known, and the first compliant concentration is used as the concentration of the inhibitor in the wellbore fluid formulation.
After determining the first compliance concentration for the inhibitor in the wellbore servicing fluid formulation, to verify that the wellbore servicing fluid formulation meets actual operating requirements. And measuring the cohesion of the third rock after the rock to be measured is soaked in the shaft working fluid for a second time, judging whether the cohesion of the third rock is greater than the cohesion of the first compliant rock, and if so, determining that the shaft working fluid is qualified.
In the practical example, the KCl-polysulfonate or KCl-polymer can be added into the wellbore working fluid formula, and after the KCl-polysulfonate or KCl-polymer wellbore working fluid acts on the core, the cohesive forces of the rock are respectively 8.6MPa and 8.2MPa, and are respectively more than 7.8MPa, so that the requirement of controlling the borehole wall expansion to be less than or equal to 15% is met.
And step 206, establishing a fourth relational graph according to the borehole wall stable model and the permeability coefficient of the rock to be measured obtained through measurement.
Specifically, a fourth relational graph is established according to the borehole wall stability model and the permeability coefficient of the rock to be measured, and the fourth relational graph is used for representing the relation between the collapse pressure equivalent density and the permeability coefficient of the rock to be measured under different expanding conditions.
The permeability coefficient refers to the capability of the plugging body to be penetrated by the filtrate of the working fluid of the shaft under the action of pressure difference, comprehensively reflects the plugging performance index of the working fluid of the shaft and is related to the density, viscosity, fracture form and formula gradation of the working fluid of the shaft. Permeability coefficients were determined primarily by core dynamic flow meters. Fig. 4a is a schematic diagram of a fourth relationship diagram in the embodiment shown in fig. 3. As shown in fig. 4a, permeability coefficients of the rock to be measured corresponding to collapse pressure equivalent densities under different diameter expansion conditions are measured by a core dynamic flow meter. And from fig. 4, it can be known that the following wellbore fluid permeability coefficient versus allowable hole diameter enlargement rate is shown in table two:
illustratively, the wellbore servicing fluid densities in table two correspond to the collapse pressure equivalent densities in fig. 4. In practical application, the preset performance requirements of the second wellbore servicing fluid include: when the hole diameter expansion rate is controlled to be less than or equal to 15%, the key performance required by the shaft working fluid is as follows: the density is 1.3g/cm3, and the permeability coefficient is less than or equal to 0.25.
And step 207, determining a first compliance rock permeability coefficient according to the preset second wellbore working fluid performance requirement and the fourth relational graph.
Specifically, a first compliance rock permeability coefficient is determined according to a preset second wellbore working fluid performance requirement and a fourth relational graph, wherein the second wellbore working fluid performance requirement comprises the following steps: the second hole diameter expansion rate and the second shaft working fluid density, and the first compliance rock permeability coefficient is the minimum permeability coefficient which ensures that the rock to be measured does not permeate.
And step 208, determining a first compliance dosage of the first plugging agent and a second compliance dosage of the second plugging agent according to the first compliance rock permeability coefficient and a preset relation graph of the plugging agent and the permeability coefficient, taking the first compliance dosage as the dosage of the first plugging agent in the shaft working fluid formula, and taking the second compliance dosage as the dosage of the second plugging agent in the shaft working fluid formula.
Specifically, a first compliance addition amount of a first plugging agent and a second compliance addition amount of a second plugging agent are determined according to a first compliance rock permeability coefficient and a preset relation table of the plugging agents and the permeability coefficients, the first compliance addition amount is used as an addition amount of the first plugging agent in a shaft working fluid formula, and the second compliance addition amount is used as an addition amount of the second plugging agent in the shaft working fluid formula.
Fig. 4b is a graph of the permeability coefficient of the plugging agent shown in fig. 3, when the first compliant rock has a permeability coefficient of 0.25, as shown in fig. 5, the permeability coefficients corresponding to the four formulations at the upper right corner are all met, but for economic reasons, the formulation corresponding to 0.22, specifically 2% ultrafine calcium carbonate and 2% fiber plugging agent, may be selected.
After determining the first and second compliant amounts of the first and second plugging agents corresponding to the inhibitor in the wellbore servicing fluid formulation, to verify whether the wellbore servicing fluid formulation meets actual service requirements. And measuring a first permeability coefficient of the rock to be detected after soaking in the shaft working fluid for the second time, judging whether the first permeability coefficient is smaller than a first compliance rock permeability coefficient, and if so, determining that the shaft working fluid is qualified.
In the practical example, KCl-polysulfonate or KCl-polymer, 2% of superfine calcium carbonate and 2% of fiber plugging agent can be added into the formula of the wellbore working fluid, the permeability coefficients of the added KCl-polysulfonate or KCl-polymer are respectively reduced to 0.2Md and 0.21Md which are both less than 0.25Md, and the requirement that the wellbore working fluid has the density of 1.3g/cm3 and the control well diameter expansion rate is less than or equal to 15% can be met.
FIG. 5 is a flow chart illustrating a wellbore fluid formulation optimization device according to an exemplary embodiment of the present invention. As shown in fig. 5, the wellbore fluid formulation optimizing apparatus provided in this embodiment includes:
an obtaining module 301, configured to obtain a first rock cohesion of a rock to be detected after the rock to be detected is soaked in a first wellbore working fluid for a first time period, where a concentration of an inhibitor in the first wellbore working fluid is a first concentration, and establish a first relation graph according to the first rock cohesion and the first time period, where the first relation graph is used to represent a relation between the cohesion of the rock to be detected and the soaking time period;
the obtaining module 301 is further configured to obtain a second rock cohesion of the rock to be detected after the rock to be detected is soaked in a second wellbore working fluid for a second duration, where a concentration of the inhibitor in the second wellbore working fluid is a second concentration, and establish a second relation graph according to the second rock cohesion and the second concentration, where the second relation graph is used to represent a relation between the cohesion of the rock to be detected and the concentration of the inhibitor;
a calculating module 302, configured to establish a third relational graph according to the first relational graph, the second relational graph, and a preset borehole wall stability model, where the third relational graph is used to represent a relationship between collapse pressure equivalent density and cohesion of the rock to be measured under different diameter expansion conditions;
the calculation module 302 is further configured to determine a first compliant rock cohesion according to a preset first wellbore servicing fluid performance requirement and the third relationship map, where the first wellbore servicing fluid performance requirement includes: the first hole diameter expansion rate and the first shaft working fluid density are the minimum rock cohesion value for ensuring that the rock to be detected does not collapse;
a determining module 303, configured to determine a first compliance concentration of the inhibitor corresponding to the cohesion of the first compliant rock according to the second relationship diagram, and use the first compliance concentration as the concentration of the inhibitor in the wellbore fluid formulation.
Based on the embodiment shown in fig. 5, fig. 6 is a flow chart of a wellbore fluid formulation optimization apparatus according to another exemplary embodiment of the present invention. The device for optimizing the formula of the wellbore working fluid provided by the embodiment further comprises:
the measuring module 304 is configured to measure the cohesion of the third rock after the rock to be measured is soaked in the wellbore working fluid for the second time period;
a determining module 305, configured to determine whether the third rock cohesion is greater than the first compliant rock cohesion, where if the determination result is yes, the wellbore operating fluid formulation is qualified.
In a possible design, the calculation module 302 is further configured to establish a fourth relational graph according to the borehole wall stability model and the permeability coefficient of the rock to be measured, where the fourth relational graph is used to represent a relationship between the collapse pressure equivalent density and the permeability coefficient of the rock to be measured under different expanding conditions;
the calculation module 302 is further configured to determine a first compliant rock permeability coefficient according to a preset second wellbore fluid performance requirement and the fourth relational graph, where the second wellbore fluid performance requirement includes: the first hole diameter expansion rate and the first shaft working fluid density are the same, and the first compliance rock permeability coefficient is the minimum permeability coefficient which ensures that the rock to be detected does not permeate;
the determining module 303 is further configured to determine a first compliance dosage of a first blocking agent and a second compliance dosage of a second blocking agent according to the first compliance rock permeability coefficient and a preset relation diagram between the blocking agent and the permeability coefficient, use the first compliance dosage as the dosage of the first blocking agent in the wellbore working fluid formula, and use the second compliance dosage as the dosage of the second blocking agent in the wellbore working fluid formula.
In a possible design, the measurement module 304 is further configured to measure a first permeability coefficient of the rock to be tested after the rock to be tested is soaked in the wellbore working fluid for the second time period;
the determining module 305 is further configured to determine whether the first permeability coefficient is smaller than the first compliant rock permeability coefficient, where if the determination result is yes, the wellbore working fluid formulation is qualified.
In one possible design, the first blocking agent is ultrafine calcium carbonate and the second blocking agent is a fibrous blocking agent.
The wellbore working fluid formula optimizing device provided in the embodiments shown in fig. 5 to 6 can be used for executing the method provided in the embodiments shown in fig. 1 and 3, and the specific implementation manner and technical effects are similar and will not be described again here.
Finally, it should be noted that: the above embodiments are only used to illustrate the technical solution of the present invention, and not to limit the same; while the invention has been described in detail and with reference to the foregoing embodiments, it will be understood by those skilled in the art that: the technical solutions described in the foregoing embodiments may still be modified, or some or all of the technical features may be equivalently replaced; and the modifications or the substitutions do not make the essence of the corresponding technical solutions depart from the scope of the technical solutions of the embodiments of the present invention.
Claims (10)
1. A wellbore working fluid formula optimization method is characterized by comprising the following steps:
acquiring the cohesion of a first rock of a rock to be tested after the rock to be tested is soaked in a first shaft working fluid for a first time, wherein the concentration of an inhibitor in the first shaft working fluid is a first concentration, and establishing a first relation graph according to the cohesion of the first rock and the first time, wherein the first relation graph is used for representing the relation between the cohesion of the rock to be tested and the soaking time;
acquiring the cohesion of a second rock of the rock to be detected after the rock to be detected is soaked in a second shaft working fluid for a second time, wherein the concentration of the inhibitor in the second shaft working fluid is a second concentration, and establishing a second relation graph according to the cohesion of the second rock and the second concentration, wherein the second relation graph is used for representing the relation between the cohesion of the rock to be detected and the concentration of the inhibitor;
establishing a third relational graph according to the first relational graph, the second relational graph and a preset borehole wall stability model, wherein the third relational graph is used for representing the relation between the collapse pressure equivalent density and the cohesion of the rock to be detected under different expanding conditions;
determining a first compliant rock cohesion from a preset first wellbore servicing fluid performance requirement and the third relationship map, wherein the first wellbore servicing fluid performance requirement comprises: the first hole diameter expansion rate and the first shaft working fluid density are the minimum rock cohesion value for ensuring that the rock to be detected does not collapse;
and determining a first compliant concentration of the inhibitor corresponding to the cohesion of the first compliant rock according to the second relational graph, and using the first compliant concentration as the concentration of the inhibitor in the wellbore working fluid formula.
2. The wellbore servicing fluid formulation optimization method of claim 1, further comprising, after said determining a first compliant concentration of the inhibitor corresponding to the first compliant rock cohesion from the second relationship graph:
measuring the cohesion of a third rock of the rock to be detected after the rock to be detected is soaked in the shaft working fluid for the second time;
determining whether the third rock cohesion is greater than the first compliant rock cohesion;
and if the judgment result is yes, the formula of the shaft working fluid is qualified.
3. The wellbore servicing fluid formulation optimization method of claim 1 or 2, further comprising, after the determining a first compliant concentration of the inhibitor corresponding to the first compliant rock cohesion from the second relationship graph:
establishing a fourth relational graph according to the borehole wall stable model and the permeability coefficient of the rock to be detected obtained through measurement, wherein the fourth relational graph is used for representing the relation between the collapse pressure equivalent density and the permeability coefficient of the rock to be detected under different expanding conditions;
determining a first compliant rock permeability coefficient according to a preset second wellbore working fluid performance requirement and the fourth relational graph, wherein the second wellbore working fluid performance requirement comprises: the first hole diameter expansion rate and the first shaft working fluid density are the same, and the first compliance rock permeability coefficient is the minimum permeability coefficient which ensures that the rock to be detected does not permeate;
and determining a first compliance addition amount of a first plugging agent and a second compliance addition amount of a second plugging agent according to the first compliance rock permeability coefficient and a preset relation graph of the plugging agent and the permeability coefficient, taking the first compliance addition amount as the addition amount of the first plugging agent in the shaft working fluid formula, and taking the second compliance addition amount as the addition amount of the second plugging agent in the shaft working fluid formula.
4. The wellbore servicing fluid formulation optimization method of claim 3, wherein said determining a first compliant addition of a first plugging agent and a second compliant addition of a second plugging agent based on said first compliant rock permeability coefficient and a predetermined plugging agent to permeability coefficient map further comprises:
measuring a first permeability coefficient of the rock to be detected after the rock to be detected is soaked in the shaft working fluid for the second time;
determining whether the first permeability coefficient is less than the first compliant rock permeability coefficient;
and if the judgment result is yes, the formula of the shaft working fluid is qualified.
5. The wellbore servicing fluid formulation optimization method of claim 4, wherein the first plugging agent is ultra-fine calcium carbonate and the second plugging agent is a fiber plugging agent.
6. A wellbore fluid formulation optimization device, comprising:
the system comprises an acquisition module, a storage module and a control module, wherein the acquisition module is used for acquiring the cohesion of a first rock after a rock to be detected is soaked in a first shaft working fluid for a first time, the concentration of an inhibitor in the first shaft working fluid is a first concentration, a first relation graph is established according to the cohesion of the first rock and the first time, and the first relation graph is used for representing the relation between the cohesion of the rock to be detected and the soaking time;
the obtaining module is further configured to obtain a second rock cohesion of the rock to be detected after the rock to be detected is soaked in a second wellbore working fluid for a second duration, where a concentration of the inhibitor in the second wellbore working fluid is a second concentration, and a second relational graph is established according to the second rock cohesion and the second concentration, where the second relational graph is used to represent a relationship between the cohesion of the rock to be detected and the concentration of the inhibitor;
the calculation module is used for establishing a third relation graph according to the first relation graph, the second relation graph and a preset borehole wall stability model, and the third relation graph is used for representing the relation between the collapse pressure equivalent density and the cohesion of the rock to be detected under different diameter expansion conditions;
the calculation module is further configured to determine a first compliant rock cohesion according to a preset first wellbore servicing fluid performance requirement and the third relationship graph, where the first wellbore servicing fluid performance requirement includes: the first hole diameter expansion rate and the first shaft working fluid density are the minimum rock cohesion value for ensuring that the rock to be detected does not collapse;
and the determining module is used for determining a first compliance concentration of the inhibitor corresponding to the cohesion of the first compliance rock according to the second relation graph, and using the first compliance concentration as the concentration of the inhibitor in the wellbore working fluid formula.
7. The wellbore servicing fluid formulation optimization device of claim 6, further comprising:
the measuring module is used for measuring the cohesion of the third rock after the rock to be measured is soaked in the shaft working fluid for the second time;
and the judging module is used for judging whether the cohesion of the third rock is greater than the cohesion of the first compliant rock, wherein if the judgment result is yes, the formula of the shaft working fluid is qualified.
8. The wellbore working fluid formula optimizing device according to claim 6 or 7, wherein the calculation module is further configured to establish a fourth relational graph according to the borehole wall stability model and the permeability coefficient of the rock to be tested, and the fourth relational graph is used for representing a relation between the collapse pressure equivalent density and the permeability coefficient of the rock to be tested under different expanding conditions;
the calculation module is further configured to determine a first compliant rock permeability coefficient according to a preset second wellbore fluid performance requirement and the fourth relational graph, where the second wellbore fluid performance requirement includes: the first hole diameter expansion rate and the first shaft working fluid density are the same, and the first compliance rock permeability coefficient is the minimum permeability coefficient which ensures that the rock to be detected does not permeate;
the determining module is further configured to determine a first compliance dosage of a first blocking agent and a second compliance dosage of a second blocking agent according to the first compliance rock permeability coefficient and a preset relation diagram of the blocking agent and the permeability coefficient, use the first compliance dosage as the dosage of the first blocking agent in the wellbore working fluid formula, and use the second compliance dosage as the dosage of the second blocking agent in the wellbore working fluid formula.
9. The wellbore servicing fluid formulation optimizing device of claim 8, wherein the measuring module is further configured to measure a first permeability coefficient of the rock to be tested after soaking in the wellbore servicing fluid for the second period of time;
the judgment module is further used for judging whether the first permeability coefficient is smaller than the first compliance rock permeability coefficient, wherein if the judgment result is yes, the shaft working fluid formula is qualified.
10. The wellbore servicing fluid formulation optimization method of claim 9, wherein the first plugging agent is ultra-fine calcium carbonate and the second plugging agent is a fiber plugging agent.
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