CN118133480A - Method, system, medium and equipment for calculating fluid composition in reservoir reconstruction well bore - Google Patents
Method, system, medium and equipment for calculating fluid composition in reservoir reconstruction well bore Download PDFInfo
- Publication number
- CN118133480A CN118133480A CN202211538848.0A CN202211538848A CN118133480A CN 118133480 A CN118133480 A CN 118133480A CN 202211538848 A CN202211538848 A CN 202211538848A CN 118133480 A CN118133480 A CN 118133480A
- Authority
- CN
- China
- Prior art keywords
- liquid
- volume
- shaft
- total volume
- equal
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Pending
Links
- 239000012530 fluid Substances 0.000 title claims abstract description 114
- 239000000203 mixture Substances 0.000 title claims abstract description 66
- 238000000034 method Methods 0.000 title claims abstract description 50
- 239000007788 liquid Substances 0.000 claims abstract description 358
- 238000005086 pumping Methods 0.000 claims abstract description 61
- 238000004364 calculation method Methods 0.000 claims abstract description 17
- 230000000007 visual effect Effects 0.000 claims abstract description 14
- 238000012545 processing Methods 0.000 claims description 30
- 238000003860 storage Methods 0.000 claims description 19
- 238000006073 displacement reaction Methods 0.000 claims description 6
- 238000010276 construction Methods 0.000 abstract description 43
- 238000004458 analytical method Methods 0.000 abstract description 9
- 238000005457 optimization Methods 0.000 abstract description 6
- 238000004590 computer program Methods 0.000 description 22
- 230000008569 process Effects 0.000 description 13
- 238000010586 diagram Methods 0.000 description 11
- 230000006870 function Effects 0.000 description 8
- 230000008859 change Effects 0.000 description 7
- 230000000694 effects Effects 0.000 description 7
- 238000005516 engineering process Methods 0.000 description 6
- 238000004519 manufacturing process Methods 0.000 description 5
- 230000008901 benefit Effects 0.000 description 4
- 238000011161 development Methods 0.000 description 4
- 230000004044 response Effects 0.000 description 4
- 230000008878 coupling Effects 0.000 description 3
- 238000010168 coupling process Methods 0.000 description 3
- 238000005859 coupling reaction Methods 0.000 description 3
- 238000011156 evaluation Methods 0.000 description 3
- 239000000700 radioactive tracer Substances 0.000 description 3
- 239000009096 changqing Substances 0.000 description 2
- 238000004891 communication Methods 0.000 description 2
- 230000001186 cumulative effect Effects 0.000 description 2
- 238000013211 curve analysis Methods 0.000 description 2
- 238000013461 design Methods 0.000 description 2
- 238000001514 detection method Methods 0.000 description 2
- 230000000670 limiting effect Effects 0.000 description 2
- 239000003129 oil well Substances 0.000 description 2
- 238000003672 processing method Methods 0.000 description 2
- 230000009286 beneficial effect Effects 0.000 description 1
- 230000005540 biological transmission Effects 0.000 description 1
- 238000004422 calculation algorithm Methods 0.000 description 1
- 238000009960 carding Methods 0.000 description 1
- 238000005266 casting Methods 0.000 description 1
- 238000006243 chemical reaction Methods 0.000 description 1
- 238000004140 cleaning Methods 0.000 description 1
- 238000013079 data visualisation Methods 0.000 description 1
- 230000007423 decrease Effects 0.000 description 1
- 230000003247 decreasing effect Effects 0.000 description 1
- 230000007547 defect Effects 0.000 description 1
- 238000009826 distribution Methods 0.000 description 1
- 230000002452 interceptive effect Effects 0.000 description 1
- 230000007774 longterm Effects 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 230000003287 optical effect Effects 0.000 description 1
- 230000036961 partial effect Effects 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 238000003825 pressing Methods 0.000 description 1
- 230000002829 reductive effect Effects 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 239000004576 sand Substances 0.000 description 1
- 239000009671 shengli Substances 0.000 description 1
- 238000012360 testing method Methods 0.000 description 1
Classifications
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02A—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE
- Y02A10/00—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE at coastal zones; at river basins
- Y02A10/40—Controlling or monitoring, e.g. of flood or hurricane; Forecasting, e.g. risk assessment or mapping
Landscapes
- Management, Administration, Business Operations System, And Electronic Commerce (AREA)
Abstract
The invention discloses a calculation method, a system, a medium and equipment for fluid composition in a reservoir reconstruction shaft, which are used for judging which type of fluid is pumped on the ground at each moment according to the accumulated liquid amount in the stage, and calculating the pumping stage of the fluid on the ground; when the ground fluid pumping stages are different values, respectively calculating the composition conditions of the fluid in the shaft at all moments of the different pumping stages; and obtaining the fluid composition in the well bore at all times. The method can be used for carrying out programmed treatment on the reservoir reconstruction construction data, carrying out visual analysis on the construction curve and the fluid composition in the shaft, and playing an important role in construction optimization according to the important index of the fluid composition in the shaft.
Description
Technical Field
The invention belongs to the technical field of data processing and visual display in oil and gas field development, and particularly relates to a method, a system, a medium and equipment for calculating fluid composition in a reservoir reconstruction shaft.
Background
Most of the gas reservoirs in China are low-permeability gas reservoirs, the gas reservoirs generally have the characteristics of low holes and low permeability, the natural productivity is low, the stable production condition is poor, and most of the wells are subjected to sand fracturing before casting. However, under the influence of various factors such as geology, engineering and the like, partial wells are low in yield after primary fracturing, even industrial airflow cannot be achieved, even if economic exploitation value is achieved, after long-term production activities, the fracture conductivity gradually decreases until failure, the normal development of a gas field is seriously influenced, and repeated fracturing is needed for recovering the productivity of the wells to obtain economic exploitation benefits.
With the development of hydraulic fracturing technology, repeated fracturing technology research is started in 1960 abroad, a series of mature core technologies are formed at present, and remarkable economic benefits are achieved. The method is characterized in that the repeated fracturing technology is started later in China until 1990, but the method is rapid in development, a large number of repeated fracturing operations are carried out on oil fields such as Daqing, shengli, changqing, dagang and Jilin, a certain exploration is made from theory and practice, a repeated fracturing technology series including restarting old cracks, extending the old cracks, cleaning crack wall surfaces, diverting in the cracks and the like is formed, but related work mainly aims at low-permeability oil wells, and the repeated fracturing technological method for the low-permeability gas wells is still to be perfected. Several repeated fracturing practices developed in the Changqing low-permeability gas field prove that compared with the low-permeability oil well, the repeated fracturing technology of the low-permeability gas well has higher difficulty, and each link of well selection and evaluation, fracturing materials, fracturing process, flowback process and the like has the specificity and needs to be overcome.
At present, the main measures for correcting the flowback rate of the fracturing fluid for the reservoir reformation of the gas well are as follows: and (3) pressing a certain amount of tracer into the reservoir together with the fracturing fluid, periodically detecting the concentration change of the tracer in the flowback fluid, and comprehensively judging the flowback condition of the fracturing fluid according to the cumulative tracer flowback volume and the flowback fluid volume. The method has longer implementation period and higher operation cost, and is not suitable for popularization and application of large-scale and large-scale gas well reservoir reconstruction fracturing construction.
Reservoir reconstruction is an important means for improving the production capacity of an oil and gas well, and the reservoir reconstruction construction effect needs to be analyzed and evaluated according to construction data recorded in the construction process; the existing construction curve analysis method does not calculate and analyze the fluid composition condition in the shaft in the construction process, so that an analysis result lacks important parameters, and the analysis result is one-sided and cannot effectively guide construction optimization.
Disclosure of Invention
The invention aims to solve the technical problems that aiming at the defects in the prior art, a method, a system, a medium and equipment for calculating the fluid composition in a reservoir reconstruction shaft are provided, so that the technical problems that the existing construction curve analysis method does not calculate and analyze the fluid composition condition in the shaft in the construction process, so that an analysis result lacks important parameters, the analysis result is one-sided, and the construction optimization cannot be effectively guided are solved.
The invention adopts the following technical scheme:
the method for calculating the fluid composition in the reservoir reconstruction well bore comprises the steps of judging the ground fluid pumping stage at each moment according to the accumulated liquid amount of the stage; and carrying out data processing on the ground fluid pumping stages corresponding to all the moments to obtain the fluid pumping stages corresponding to each moment and the fluid composition in the well bore.
Specifically, when the calculated time period accumulated liquid amount is smaller than the last time period accumulated liquid amount, the fluid pumping enters the next period, and the ground fluid pumping period at all time periods is judged.
Specifically, when in the first pumping stage:
If the phase accumulated liquid amount is smaller than the shaft volume, the first liquid and the original shaft liquid are simultaneously present in the shaft, the volume of the first liquid is the phase accumulated liquid amount, and the volume of the original shaft liquid is the shaft volume minus the phase accumulated liquid amount; if the accumulated liquid amount in the stage is larger than the volume of the shaft, the first liquid is in the shaft, and the volume is the volume of the shaft.
Specifically, when in the second pumping stage:
If the total volume of the phase accumulated liquid and the first liquid is smaller than the volume of the shaft, the second liquid is simultaneously present in the shaft, the first liquid and the original shaft liquid, and the volume of the second liquid is equal to the phase accumulated liquid; the volume of the first liquid is equal to the total volume of the first liquid; the original shaft liquid volume is equal to the shaft volume minus the first liquid total volume, and then minus the stage accumulated liquid volume;
If the total volume of the phase accumulated liquid and the first liquid is larger than the volume of the shaft and the phase accumulated liquid is smaller than the volume of the shaft, the second liquid and the first liquid are simultaneously present in the shaft, the volume of the second liquid is equal to the phase accumulated liquid, and the volume of the first liquid is equal to the volume of the shaft minus the phase accumulated liquid;
if the accumulated liquid amount in the stage is larger than the volume of the shaft, the second liquid is in the shaft, and the volume is the volume of the shaft.
Specifically, when in the third to fifteenth pumping stages:
if the total volume of the phase accumulated liquid is added with the total volume of the second liquid and then added with the total volume of the first liquid, and the total volume of the first liquid is smaller than the volume of the shaft, then third liquid, second liquid, first liquid and original shaft liquid simultaneously exist in the shaft, the volume of the third liquid is equal to the total volume of the phase accumulated liquid, the volume of the second liquid is equal to the total volume of the second liquid, the volume of the first liquid is equal to the total volume of the first liquid, the volume of the original shaft liquid is equal to the volume of the shaft minus the total volume of the phase accumulated liquid, and then the total volume of the second liquid is subtracted, and finally the total volume of the first liquid is subtracted;
If the phase accumulated liquid volume plus the second liquid total volume and the first liquid total volume are larger than the well bore volume and the phase accumulated liquid volume plus the second liquid total volume is smaller than the well bore volume, third liquid is simultaneously present in the well bore, the second liquid and the first liquid, the volume of the third liquid is equal to the phase accumulated liquid volume, the volume of the second liquid is equal to the second liquid total volume, the volume of the first liquid is equal to the well bore volume minus the phase accumulated liquid volume, and the second liquid total volume is subtracted.
If the total volume of the phase accumulated liquid plus the second liquid is greater than the volume of the well bore and the phase accumulated liquid is less than the volume of the well bore, a third liquid and a second liquid are simultaneously present in the well bore, the volume of the third liquid is equal to the phase accumulated liquid, and the volume of the second liquid is equal to the volume of the well bore minus the phase accumulated liquid.
If the stage accumulated liquid amount is greater than the well bore volume, only a third liquid is in the well bore, the third liquid volume being equal to the well bore volume.
Specifically, the result of data processing is converted into a data format of echart visual display files, all moments are stored into a moment list, oil pressures corresponding to all moments are stored into an oil pressure list, jacket pressures corresponding to all moments are stored into a pressure list, the stage accumulated liquid amounts corresponding to all moments are stored into a stage accumulated liquid amount list, the displacement corresponding to all moments is stored into a displacement list, and wellbore liquids corresponding to all moments are respectively stored into a liquid list, so that visual display of data is realized.
Further, when the data is more than 2 ten thousand, the data in the liquid list is subjected to thinning treatment, and according to the thinning step length, the data in the liquid list is subjected to thinning treatment, wherein the thinning step length is 10, so that all the data at all the moments are visually displayed in echart files.
In a second aspect, embodiments of the present invention provide a fluid composition calculation system in a reservoir retrofit wellbore, comprising:
the calculation module is used for judging the ground fluid pumping stage at each moment according to the stage accumulated liquid amount;
And the output module is used for carrying out data processing on the ground fluid pumping stages corresponding to all the moments to obtain the fluid pumping stages corresponding to each moment and the fluid composition in the shaft.
In a third aspect, a computer device comprises a memory, a processor and a computer program stored in the memory and executable on the processor, the processor implementing the steps of the method for calculating the composition of a fluid in a reservoir-altering wellbore described above when the computer program is executed.
In a fourth aspect, embodiments of the present invention provide a computer readable storage medium comprising a computer program which when executed by a processor performs the steps of the method of calculating a composition of a fluid in a reservoir inversion wellbore described above.
Compared with the prior art, the invention has at least the following beneficial effects:
According to the calculation method for the fluid composition in the reservoir reconstruction well bore, data of a ground fluid pumping stage does not exist in an original construction curve of reservoir reconstruction, and the ground fluid pumping stage at each moment is calculated according to the accumulated liquid amount of the stage. The stage accumulated liquid amount is the only data which can calculate the pumping stage of the surface fluid through data processing in all the original construction curve data. The invention provides a judging method; when the ground fluid pumping stages are different values, the fluid composition in the well bore can be calculated according to conditions; the invention provides a general rule and a calculation method for carding different conditions. According to the method, the fluid composition in the well bore can be calculated for any surface pumping stage.
Further, the stage accumulated liquid amount is the original data in the original construction curve of reservoir reformation. The value of the phase accumulated liquid quantity gradually increases from 0 when the ground pumps a certain fluid, and the phase accumulated liquid quantity is restarted to be accumulated from 0 when the ground starts pumping a next fluid. The ground pumping is described as entering the next stage by judging the value of the accumulated liquid quantity at each time and the stage at the previous time, and when the accumulated liquid quantity at the stage at the present time is smaller than the accumulated liquid quantity at the stage at the previous time.
Further, when in the first pumping stage: if the phase accumulated liquid amount is smaller than the shaft volume, the first liquid and the original shaft liquid are simultaneously present in the shaft, the volume of the first liquid is the phase accumulated liquid amount, and the volume of the original shaft liquid is the shaft volume minus the phase accumulated liquid amount; if the accumulated liquid amount in the stage is larger than the volume of the shaft, the first liquid is in the shaft, and the volume is the volume of the shaft.
Further, when in the second pumping stage: if the total volume of the phase accumulated liquid and the first liquid is smaller than the volume of the shaft, the second liquid is simultaneously present in the shaft, the first liquid and the original shaft liquid, and the volume of the second liquid is equal to the phase accumulated liquid; the volume of the first liquid is equal to the total volume of the first liquid; the original shaft liquid volume is equal to the shaft volume minus the first liquid total volume, and then minus the stage accumulated liquid volume; if the total volume of the phase accumulated liquid and the first liquid is larger than the volume of the shaft and the phase accumulated liquid is smaller than the volume of the shaft, the second liquid and the first liquid are simultaneously present in the shaft, the volume of the second liquid is equal to the phase accumulated liquid, and the volume of the first liquid is equal to the volume of the shaft minus the phase accumulated liquid; if the accumulated liquid amount in the stage is larger than the volume of the shaft, the second liquid is in the shaft, and the volume is the volume of the shaft.
Further, when in the third to fifteenth pumping stages: if the total volume of the phase accumulated liquid is added with the total volume of the second liquid and then added with the total volume of the first liquid, and the total volume of the first liquid is smaller than the volume of the shaft, then third liquid, second liquid, first liquid and original shaft liquid simultaneously exist in the shaft, the volume of the third liquid is equal to the total volume of the phase accumulated liquid, the volume of the second liquid is equal to the total volume of the second liquid, the volume of the first liquid is equal to the total volume of the first liquid, the volume of the original shaft liquid is equal to the volume of the shaft minus the total volume of the phase accumulated liquid, and then the total volume of the second liquid is subtracted, and finally the total volume of the first liquid is subtracted; if the phase accumulated liquid volume plus the second liquid total volume and the first liquid total volume are larger than the well bore volume and the phase accumulated liquid volume plus the second liquid total volume is smaller than the well bore volume, third liquid is simultaneously present in the well bore, the second liquid and the first liquid, the volume of the third liquid is equal to the phase accumulated liquid volume, the volume of the second liquid is equal to the second liquid total volume, the volume of the first liquid is equal to the well bore volume minus the phase accumulated liquid volume, and the second liquid total volume is subtracted. If the total volume of the phase accumulated liquid plus the second liquid is greater than the volume of the well bore and the phase accumulated liquid is less than the volume of the well bore, a third liquid and a second liquid are simultaneously present in the well bore, the volume of the third liquid is equal to the phase accumulated liquid, and the volume of the second liquid is equal to the volume of the well bore minus the phase accumulated liquid. If the stage accumulated liquid amount is greater than the well bore volume, only a third liquid is in the well bore, the third liquid volume being equal to the well bore volume.
Furthermore, in order to enable the processing results to be visually displayed, interactive display can be performed during display. The data processing results are processed into a echart data structure.
Furthermore, according to the actual test result, when carrying out data visualization display by echart, if the data volume is too large, the display is stuck, the data volume needs to be subjected to thinning treatment, and the data volume is reduced while the data curve is kept without large deformation.
It will be appreciated that the advantages of the second to fourth aspects may be found in the relevant description of the first aspect and are not repeated here.
In summary, the method calculates the fluid composition condition in the shaft in the construction process according to the reservoir reconstruction construction curve, realizes the visual display of the calculation result, provides important parameters for reservoir reconstruction construction effect evaluation, can perform programmed processing on reservoir reconstruction construction data, quickly performs visual analysis on the construction curve and the fluid composition in the shaft, and plays an important role in construction optimization according to the important index of the fluid composition in the shaft.
The technical scheme of the invention is further described in detail through the drawings and the embodiments.
Drawings
FIG. 1 is a schematic illustration of the composition of fluids in a wellbore at various stages of surface fluid pumping;
FIG. 2 is a reservoir retrofit construction graph;
FIG. 3 is a diagram of reservoir reconstruction construction curves and wellbore fluid composition;
fig. 4 is a schematic diagram of a computer device according to an embodiment of the present invention.
Detailed Description
The following description of the embodiments of the present invention will be made clearly and fully with reference to the accompanying drawings, in which it is evident that the embodiments described are some, but not all embodiments of the invention. All other embodiments, which can be made by those skilled in the art based on the embodiments of the invention without making any inventive effort, are intended to be within the scope of the invention.
In the description of the present invention, it will be understood that the terms "comprises" and "comprising," when used in this specification, specify the presence of stated features, integers, steps, operations, elements, and/or components, but do not preclude the presence or addition of one or more other features, integers, steps, operations, elements, components, and/or groups thereof.
It is also to be understood that the terminology used in the description of the invention is for the purpose of describing particular embodiments only and is not intended to be limiting of the invention. As used in this specification and the appended claims, the singular forms "a," "an," and "the" are intended to include the plural forms as well, unless the context clearly indicates otherwise.
It should be further understood that the term "and/or" as used in the present specification and the appended claims refers to any and all possible combinations of one or more of the associated listed items, and includes such combinations, e.g., a and/or B, may represent: a exists alone, A and B exist together, and B exists alone. In addition, the character "/" herein generally indicates that the front and rear associated objects are an "or" relationship.
It should be understood that although the terms first, second, third, etc. may be used to describe the preset ranges, etc. in the embodiments of the present invention, these preset ranges should not be limited to these terms. These terms are only used to distinguish one preset range from another. For example, a first preset range may also be referred to as a second preset range, and similarly, a second preset range may also be referred to as a first preset range without departing from the scope of embodiments of the present invention.
Depending on the context, the word "if" as used herein may be interpreted as "at … …" or "at … …" or "in response to a determination" or "in response to a detection". Similarly, the phrase "if determined" or "if detected (stated condition or event)" may be interpreted as "when determined" or "in response to determination" or "when detected (stated condition or event)" or "in response to detection (stated condition or event), depending on the context.
Various structural schematic diagrams according to the disclosed embodiments of the present invention are shown in the accompanying drawings. The figures are not drawn to scale, wherein certain details are exaggerated for clarity of presentation and may have been omitted. The shapes of the various regions, layers and their relative sizes, positional relationships shown in the drawings are merely exemplary, may in practice deviate due to manufacturing tolerances or technical limitations, and one skilled in the art may additionally design regions/layers having different shapes, sizes, relative positions as actually required.
The invention provides a calculation method for fluid composition in a reservoir reconstruction shaft, which realizes visual display of calculation results and provides important parameters for reservoir reconstruction construction effect evaluation.
The invention discloses a fluid composition calculation method in a reservoir reconstruction shaft, which comprises the following steps of:
S1, calculating ground fluid pumping
Judging the ground fluid pumping stage at each moment according to the stage accumulated liquid amount; when the calculated accumulated liquid quantity at the moment stage is smaller than the accumulated liquid quantity at the previous moment stage, the fluid is pumped into the next stage; and judging the ground fluid pumping stage at all moments according to the principle.
S2, calculating the composition of the fluid in the well bore at all moments in stages;
Referring to fig. 1, when the surface fluid pumping stages are different values (considering the case of fifteen pumping stages in total, specifically, from the first pumping stage to the fifteenth pumping stage), the liquid composition in the wellbore at that time is calculated respectively.
S201, when in the first pumping stage:
If the stage accumulated liquid amount is less than the wellbore volume, then 2 liquids (first liquid, raw wellbore liquid) are present in the wellbore at the same time, wherein the first liquid volume is the stage accumulated liquid amount and the raw wellbore liquid volume is the wellbore volume minus the stage accumulated liquid amount.
If the accumulated liquid amount in the stage is larger than the volume of the shaft, the first liquid is in the shaft at present, and the volume is the volume of the shaft.
S202, when in the second pumping stage:
if the total volume of the stage accumulated liquid plus the first liquid is less than the wellbore volume, then 3 fluids (second liquid, first liquid, raw wellbore liquid) are currently simultaneously present in the wellbore, wherein the second liquid volume is equal to the stage accumulated liquid volume. The first liquid volume is equal to the first liquid total volume. The original wellbore liquid volume is equal to the wellbore volume minus the first liquid total volume, minus the stage cumulative liquid volume.
If the total volume of the phase accumulated liquid plus the first liquid is greater than the wellbore volume and the phase accumulated liquid is less than the wellbore volume, then two liquids (second liquid, first liquid) are currently present in the wellbore at the same time, wherein the second liquid volume is equal to the phase accumulated liquid. The first liquid volume is equal to the wellbore volume minus the stage accumulated liquid volume.
If the accumulated liquid amount is larger than the volume of the shaft, the second liquid is in the shaft, and the volume is the volume of the shaft.
S203, when in the third pumping stage:
If the total volume of the first liquid is smaller than the total volume of the shaft, 4 liquids (third liquid, second liquid, first liquid and original shaft liquid) exist in the shaft at present. Wherein the third liquid volume is equal to the stage accumulated liquid volume. The second liquid volume is equal to the second liquid total volume. The first liquid volume is equal to the first liquid total volume. The original shaft liquid volume is equal to the shaft volume minus the stage accumulated liquid volume, minus the second liquid total volume, and minus the first liquid total volume.
The reservoir reconstruction construction process is to sequentially pump a plurality of liquids from the ground to the underground (through a shaft pipe column) and fracture the stratum into artificial cracks, so that the purpose of increasing the stratum oil and gas transmission capacity is achieved. The first liquid, the second liquid and the third liquid respectively refer to different kinds of liquids from bottom to top in the well pipe column at each moment.
If the total volume of the phase accumulated liquid plus the total volume of the second liquid plus the total volume of the first liquid is greater than the volume of the well bore and the total volume of the phase accumulated liquid plus the total volume of the second liquid is less than the volume of the well bore, then 3 liquids (third liquid, second liquid, first liquid) are present in the well bore at the same time. Wherein the third liquid volume is equal to the stage accumulated liquid volume. The second liquid volume is equal to the second liquid total volume. The first liquid volume is equal to the wellbore volume minus the stage accumulated liquid volume, and minus the second liquid total volume.
If the total volume of the phase accumulated liquid plus the second liquid is greater than the wellbore volume and the phase accumulated liquid is less than the wellbore volume, then 2 liquids (third liquid, second liquid) are present in the wellbore at the same time, wherein the third liquid volume is equal to the phase accumulated liquid volume and the second liquid volume is equal to the wellbore volume minus the phase accumulated liquid volume.
If the staged accumulated liquid volume is greater than the wellbore volume, then there is currently only a third liquid in the wellbore, the third liquid volume being equal to the wellbore volume.
S204, when the pumping stage is from the fourth pumping stage to the fifteenth pumping stage, the processing method is similar to that of stage 3, and the description is omitted.
S205, the above cases consider the case that the wellbore contains 4 fluids at most, and in the actual reservoir reconstruction construction process, the pumped liquid volume of each stage is generally greater than the wellbore volume, so the above considerations can meet the actual construction curve processing requirement.
S3, processing the construction curve and the data of the fluid composition in the shaft;
S301, format conversion
And (3) processing the data at each moment in the step (S2) to obtain a fluid pumping stage corresponding to each moment and a fluid composition in a shaft, converting the data processing result into a data format of a echart visual display file for visual display, storing all moments into a moment list through a openpyxl library of python software, storing oil pressures corresponding to all moments into an oil pressure list, storing jacket pressures corresponding to all moments into a sleeve pressure list, storing stage accumulated liquid amounts corresponding to all moments into a stage accumulated liquid amount list, and storing displacement corresponding to all moments into a displacement list. The corresponding wellbore liquids (raw wellbore liquid, liquid 1 through liquid 15) at all times are respectively stored as liquid lists.
S302, data thinning
If all the data at all the moments are visually displayed in echart files, the time required for curve refreshing is long, and the curve is dynamically displayed and blocked, so that the data in the list are required to be subjected to thinning processing according to the thinning step length, and the data in the list are subjected to thinning processing. For data with more than 2 ten thousand lines, the thinning step length is 10, and a good final dynamic display effect is obtained.
S4, data visual display and analysis
The echart file is opened by a browser, and the visually displayed construction curve and the fluid composition condition of the shaft can be seen. Sliding the mouse over the curve will have a quick presentation of the curve name and data value. The composition of the fluid in the well bore is displayed by adopting a pile-up histogram in the whole construction process, so that the change of the composition of the fluid in the well bore can be visually seen. The method can focus the position with severe oil pressure change through the scaling operation, and analyze the influence rule of the liquid composition in the well bore on the oil pressure change.
In yet another embodiment of the present invention, a system for calculating a composition of a fluid in a modified wellbore is provided, the system being capable of being used to implement the method for calculating a composition of a fluid in a modified wellbore described above, and in particular, the system for calculating a composition of a fluid in a modified wellbore includes a calculation module and an output module.
The calculation module judges the ground fluid pumping stage at each moment according to the stage accumulated liquid amount;
And the output module is used for carrying out data processing on the ground fluid pumping stages corresponding to all the moments to obtain the fluid pumping stages corresponding to each moment and the fluid composition in the shaft.
In yet another embodiment of the present invention, a terminal device is provided, the terminal device including a processor and a memory, the memory for storing a computer program, the computer program including program instructions, the processor for executing the program instructions stored by the computer storage medium. The processor may be a central processing unit (Central Processing Unit, CPU), but may also be other general purpose processor, digital signal processor (DIGITAL SIGNAL Processor, DSP), application Specific Integrated Circuit (ASIC), off-the-shelf Programmable gate array (Field-Programmable GATE ARRAY, FPGA) or other Programmable logic device, discrete gate or transistor logic, discrete hardware components, etc., which are a computational core and a control core of the terminal adapted to implement one or more instructions, in particular adapted to load and execute one or more instructions to implement a corresponding method flow or a corresponding function; the processor according to the embodiment of the invention can be used for the operation of a fluid composition calculation method in a reservoir reconstruction well bore, and comprises the following steps:
Judging the ground fluid pumping stage at each moment according to the stage accumulated liquid amount; and carrying out data processing on the ground fluid pumping stages corresponding to all the moments to obtain the fluid pumping stages corresponding to each moment and the fluid composition in the well bore.
In a further embodiment of the present invention, the present invention also provides a storage medium, in particular, a computer readable storage medium (Memory), which is a Memory device in a terminal device, for storing programs and data. It will be appreciated that the computer readable storage medium herein may include both a built-in storage medium in the terminal device and an extended storage medium supported by the terminal device. The computer-readable storage medium provides a storage space storing an operating system of the terminal. Also stored in the memory space are one or more instructions, which may be one or more computer programs (including program code), adapted to be loaded and executed by the processor. The computer readable storage medium may be a high-speed RAM Memory or a Non-Volatile Memory (Non-Volatile Memory), such as at least one magnetic disk Memory.
One or more instructions stored in a computer-readable storage medium may be loaded and executed by a processor to implement the respective steps of the methods of calculating fluid composition in a wellbore in connection with reservoir reformation in the embodiments described above; one or more instructions in a computer-readable storage medium are loaded by a processor and perform the steps of:
Judging the ground fluid pumping stage at each moment according to the stage accumulated liquid amount; and carrying out data processing on the ground fluid pumping stages corresponding to all the moments to obtain the fluid pumping stages corresponding to each moment and the fluid composition in the well bore.
Fig. 4 is a schematic diagram of a computer device according to an embodiment of the present invention. As shown in fig. 4, the computer device 60 of this embodiment includes: a processor 61, a memory 62, and a computer program 63 stored in the memory 62 and executable on the processor 61, the computer program 63 when executed by the processor 61 implements the reservoir inversion wellbore fluid composition calculation method of the embodiment, and is not described in detail herein to avoid repetition. Or the computer program 63 when executed by the processor 61 performs the functions of the various models/units in the fluid composition calculation system in the reservoir reformation wellbore of the embodiment, and is not described in detail herein to avoid redundancy.
The computer device 60 may be a desktop computer, a notebook computer, a palm top computer, a cloud server, or the like. Computer device 60 may include, but is not limited to, a processor 61, a memory 62. It will be appreciated by those skilled in the art that fig. 4 is merely an example of a computer device 60 and is not intended to limit the computer device 60, and may include more or fewer components than shown, or may combine certain components, or different components, e.g., a computer device may also include an input-output device, a network access device, a bus, etc.
The Processor 61 may be a central processing unit (Central Processing Unit, CPU), but may also be other general purpose processors, digital signal processors (DIGITAL SIGNAL Processor, DSP), application SPECIFIC INTEGRATED Circuit (ASIC), field-Programmable gate array (Field-Programmable GATE ARRAY, FPGA) or other Programmable logic device, discrete gate or transistor logic device, discrete hardware components, or the like. A general purpose processor may be a microprocessor or the processor may be any conventional processor or the like.
The memory 62 may be an internal storage unit of the computer device 60, such as a hard disk or memory of the computer device 60. The memory 62 may also be an external storage device of the computer device 60, such as a plug-in hard disk provided on the computer device 60, a smart memory card (SMART MEDIA CARD, SMC), a Secure Digital (SD) card, a flash memory card (FLASH CARD), or the like.
Further, the memory 62 may also include both internal storage units and external storage devices of the computer device 60. The memory 62 is used to store computer programs and other programs and data required by the computer device. The memory 62 may also be used to temporarily store data that has been output or is to be output.
For the purpose of making the objects, technical solutions and advantages of the embodiments of the present invention more apparent, the technical solutions of the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings in the embodiments of the present invention, and it is apparent that the described embodiments are some embodiments of the present invention, but not all embodiments of the present invention. The components of the embodiments of the present invention generally described and illustrated in the figures herein may be arranged and designed in a wide variety of different configurations. Thus, the following detailed description of the embodiments of the invention, as presented in the figures, is not intended to limit the scope of the invention, as claimed, but is merely representative of selected embodiments of the invention. All other embodiments, which can be made by those skilled in the art based on the embodiments of the invention without making any inventive effort, are intended to be within the scope of the invention.
Examples
Referring to fig. 1, a schematic diagram of the composition of fluid in a well bore is shown for different stages of surface fluid pumping. The composition and amount of fluid in the wellbore are calculated for each of the different phases.
Referring to fig. 2, a construction curve is drawn by using an excel table, and the curve contains time-varying information of fluid composition in a shaft, so that the construction effect cannot be effectively analyzed.
TABLE 1 reservoir reconstruction construction curve data sheet
According to the construction data, the data in table 1 is processed by adopting the processing method of the invention.
The resulting inventive effect is shown in fig. 3. The echart file is opened by a browser, and the visually displayed construction curve and the fluid composition condition of the shaft can be seen. Sliding the mouse over the curve will have a quick presentation of the curve name and data value. The composition of the fluid in the well bore is displayed by adopting a pile-up histogram in the whole construction process, so that the change of the composition of the fluid in the well bore can be visually seen. The method can focus the position with severe oil pressure change through the scaling operation, and analyze the influence rule of the liquid composition in the well bore on the oil pressure change.
By the method, the reservoir reconstruction construction data can be subjected to programmed treatment, the construction curve and the fluid composition in the shaft can be rapidly subjected to visual analysis, and the construction optimization can be played an important role according to the important index of the fluid composition in the shaft.
In summary, the method, the system, the medium and the equipment for calculating the fluid composition in the reservoir reconstruction well bore can perform programmed treatment on the reservoir reconstruction construction data, quickly perform visual analysis on the construction curve and the fluid composition in the well bore, and play an important role in construction optimization according to the important index of the fluid composition in the well bore.
It will be apparent to those skilled in the art that, for convenience and brevity of description, only the above-described division of the functional units and modules is illustrated, and in practical application, the above-described functional distribution may be performed by different functional units and modules according to needs, i.e. the internal structure of the apparatus is divided into different functional units or modules to perform all or part of the above-described functions. The functional units and modules in the embodiment may be integrated in one processing unit, or each unit may exist alone physically, or two or more units may be integrated in one unit, where the integrated units may be implemented in a form of hardware or a form of a software functional unit. In addition, the specific names of the functional units and modules are only for distinguishing from each other, and are not used for limiting the protection scope of the present application. The specific working process of the units and modules in the above system may refer to the corresponding process in the foregoing method embodiment, which is not described herein again.
In the foregoing embodiments, the descriptions of the embodiments are emphasized, and in part, not described or illustrated in any particular embodiment, reference is made to the related descriptions of other embodiments.
Those of ordinary skill in the art will appreciate that the various illustrative elements and algorithm steps described in connection with the embodiments disclosed herein may be implemented as electronic hardware, or combinations of computer software and electronic hardware. Whether such functionality is implemented as hardware or software depends upon the particular application and design constraints imposed on the solution. Skilled artisans may implement the described functionality in varying ways for each particular application, but such implementation decisions should not be interpreted as causing a departure from the scope of the present invention.
In the embodiments provided in the present invention, it should be understood that the disclosed apparatus/terminal and method may be implemented in other manners. For example, the apparatus/terminal embodiments described above are merely illustrative, e.g., the division of the modules or units is merely a logical function division, and there may be additional divisions when actually implemented, e.g., multiple units or components may be combined or integrated into another system, or some features may be omitted or not performed. Alternatively, the coupling or direct coupling or communication connection shown or discussed may be an indirect coupling or communication connection via interfaces, devices or units, which may be in electrical, mechanical or other forms.
The units described as separate units may or may not be physically separate, and units shown as units may or may not be physical units, may be located in one place, or may be distributed on a plurality of network units. Some or all of the units may be selected according to actual needs to achieve the purpose of the solution of this embodiment.
In addition, each functional unit in the embodiments of the present invention may be integrated in one processing unit, or each unit may exist alone physically, or two or more units may be integrated in one unit. The integrated units may be implemented in hardware or in software functional units.
The integrated modules/units, if implemented in the form of software functional units and sold or used as stand-alone products, may be stored in a computer readable storage medium. Based on such understanding, the present invention may implement all or part of the flow of the method of the above embodiment, or may be implemented by a computer program to instruct related hardware, where the computer program may be stored in a computer readable storage medium, and when the computer program is executed by a processor, the computer program may implement the steps of each of the method embodiments described above. Wherein the computer program comprises computer program code which may be in source code form, object code form, executable file or some intermediate form etc. The computer readable medium may include: any entity or device capable of carrying the computer program code, a recording medium, a U disk, a removable hard disk, a magnetic disk, an optical disk, a computer Memory, a Read-Only Memory (ROM), a random access Memory (RandomAccess Memory, RAM), an electrical carrier wave signal, a telecommunications signal, a software distribution medium, etc., it should be noted that the computer readable medium may contain content that is appropriately increased or decreased according to the requirements of jurisdictions and patent practices, such as in certain jurisdictions, according to the jurisdictions and patent practices, the computer readable medium does not include electrical carrier wave signals and telecommunications signals.
The present application is described with reference to flowchart illustrations and/or block diagrams of methods, apparatus (systems) and computer program products according to embodiments of the application. It will be understood that each flow and/or block of the flowchart illustrations and/or block diagrams, and combinations of flows and/or blocks in the flowchart illustrations and/or block diagrams, can be implemented by computer program instructions. These computer program instructions may be provided to a processor of a general purpose computer, special purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, create means for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be stored in a computer-readable memory that can direct a computer or other programmable data processing apparatus to function in a particular manner, such that the instructions stored in the computer-readable memory produce an article of manufacture including instruction means which implement the function specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be loaded onto a computer or other programmable data processing apparatus to cause a series of operational steps to be performed on the computer or other programmable apparatus to produce a computer implemented process such that the instructions which execute on the computer or other programmable apparatus provide steps for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
The above is only for illustrating the technical idea of the present invention, and the protection scope of the present invention is not limited by this, and any modification made on the basis of the technical scheme according to the technical idea of the present invention falls within the protection scope of the claims of the present invention.
Claims (10)
1. The calculation method for the fluid composition in the reservoir reconstruction well bore is characterized in that the ground fluid pumping stage at each moment is judged according to the accumulated liquid amount of the stage; and carrying out data processing on the ground fluid pumping stages corresponding to all the moments to obtain the fluid pumping stages corresponding to each moment and the fluid composition in the well bore.
2. The method of claim 1, wherein when the accumulated fluid volume at the time of calculation is smaller than the accumulated fluid volume at the previous time, the fluid pumping enters the next stage, and the ground fluid pumping stages at all times are determined.
3. The method of calculating fluid composition in a reservoir retrofitted wellbore of claim 1 wherein, when in a first pumping stage:
If the phase accumulated liquid amount is smaller than the shaft volume, the first liquid and the original shaft liquid are simultaneously present in the shaft, the volume of the first liquid is the phase accumulated liquid amount, and the volume of the original shaft liquid is the shaft volume minus the phase accumulated liquid amount; if the accumulated liquid amount in the stage is larger than the volume of the shaft, the first liquid is in the shaft, and the volume is the volume of the shaft.
4. The method of calculating fluid composition in a reservoir retrofitted wellbore of claim 1 wherein, when in a second pumping stage:
If the total volume of the phase accumulated liquid and the first liquid is smaller than the volume of the shaft, the second liquid is simultaneously present in the shaft, the first liquid and the original shaft liquid, and the volume of the second liquid is equal to the phase accumulated liquid; the volume of the first liquid is equal to the total volume of the first liquid; the original shaft liquid volume is equal to the shaft volume minus the first liquid total volume, and then minus the stage accumulated liquid volume;
If the total volume of the phase accumulated liquid and the first liquid is larger than the volume of the shaft and the phase accumulated liquid is smaller than the volume of the shaft, the second liquid and the first liquid are simultaneously present in the shaft, the volume of the second liquid is equal to the phase accumulated liquid, and the volume of the first liquid is equal to the volume of the shaft minus the phase accumulated liquid;
if the accumulated liquid amount in the stage is larger than the volume of the shaft, the second liquid is in the shaft, and the volume is the volume of the shaft.
5. The method of calculating fluid composition in a reservoir retrofitted wellbore of claim 1 wherein, when in a third pumping stage to a fifteenth pumping stage:
if the total volume of the phase accumulated liquid is added with the total volume of the second liquid and then added with the total volume of the first liquid, and the total volume of the first liquid is smaller than the volume of the shaft, then third liquid, second liquid, first liquid and original shaft liquid simultaneously exist in the shaft, the volume of the third liquid is equal to the total volume of the phase accumulated liquid, the volume of the second liquid is equal to the total volume of the second liquid, the volume of the first liquid is equal to the total volume of the first liquid, the volume of the original shaft liquid is equal to the volume of the shaft minus the total volume of the phase accumulated liquid, and then the total volume of the second liquid is subtracted, and finally the total volume of the first liquid is subtracted;
If the total volume of the phase accumulated liquid and the second liquid are added, and the total volume of the first liquid is larger than the volume of the shaft, and the total volume of the phase accumulated liquid and the second liquid is smaller than the volume of the shaft, third liquid is simultaneously present in the shaft, the volume of the second liquid and the first liquid is equal to the total volume of the phase accumulated liquid, the volume of the second liquid is equal to the total volume of the second liquid, and the volume of the first liquid is equal to the volume of the shaft minus the total volume of the phase accumulated liquid, and then the total volume of the second liquid is subtracted;
If the total volume of the phase accumulated liquid and the second liquid is larger than the volume of the shaft and the phase accumulated liquid is smaller than the volume of the shaft, the third liquid and the second liquid are simultaneously present in the shaft, the volume of the third liquid is equal to the phase accumulated liquid, and the volume of the second liquid is equal to the volume of the shaft minus the phase accumulated liquid;
if the stage accumulated liquid amount is greater than the well bore volume, only a third liquid is in the well bore, the third liquid volume being equal to the well bore volume.
6. The method for calculating the fluid composition in the reservoir reconstruction wellbore according to claim 1, wherein the result of data processing is converted into a data format of echart visual presentation files, all moments are stored into a moment list, oil pressures corresponding to all moments are stored into an oil pressure list, jacket pressures corresponding to all moments are stored into a jacket pressure list, the phase accumulated liquid amount corresponding to all moments is stored into a phase accumulated liquid amount list, the displacement corresponding to all moments is stored into a displacement list, wellbore liquids corresponding to all moments are respectively stored into a liquid list, and visual presentation of data is achieved.
7. The method for calculating the fluid composition in the reservoir reconstruction wellbore of claim 6, wherein when the data is greater than 2 ten thousand, the data in the liquid list is subjected to thinning, and the data in the liquid list is subjected to thinning according to a thinning step length, wherein the thinning step length is 10, so that all the data at all moments are visually displayed in echart files.
8. A fluid composition computing system in a reservoir reformation wellbore, comprising:
the calculation module is used for judging the ground fluid pumping stage at each moment according to the stage accumulated liquid amount;
And the output module is used for carrying out data processing on the ground fluid pumping stages corresponding to all the moments to obtain the fluid pumping stages corresponding to each moment and the fluid composition in the shaft.
9. A computer readable storage medium storing one or more programs, the one or more programs comprising instructions, which when executed by a computing device, cause the computing device to perform the method of any of claims 1-7.
10. A computing device, comprising:
One or more processors, memory, and one or more programs, wherein the one or more programs are stored in the memory and configured to be executed by the one or more processors, the one or more programs comprising steps for performing any of the methods of claims 1-7.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202211538848.0A CN118133480A (en) | 2022-12-01 | 2022-12-01 | Method, system, medium and equipment for calculating fluid composition in reservoir reconstruction well bore |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202211538848.0A CN118133480A (en) | 2022-12-01 | 2022-12-01 | Method, system, medium and equipment for calculating fluid composition in reservoir reconstruction well bore |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CN118133480A true CN118133480A (en) | 2024-06-04 |
Family
ID=91238781
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN202211538848.0A Pending CN118133480A (en) | 2022-12-01 | 2022-12-01 | Method, system, medium and equipment for calculating fluid composition in reservoir reconstruction well bore |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN118133480A (en) |
-
2022
- 2022-12-01 CN CN202211538848.0A patent/CN118133480A/en active Pending
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN106204304B (en) | A kind of poly- determination method for driving permeability saturation curve of Conglomerate Reservoir | |
| CN104500016B (en) | Utilize the new method of shale gas reservoir pressing crack construction pressure drop segment data analysis reservoir properties | |
| CN105298483B (en) | The method and device of reservoir synthesis injury in a kind of acquisition the injecting process | |
| CN115510777B (en) | Low-permeability reservoir pressure flooding water injection fluid-solid coupling numerical simulation method, device and medium | |
| CN106761602B (en) | Method and device for determining production conditions of oil well | |
| CN109344534B (en) | Injection-production string critical erosion flow rate determination method and device | |
| CN102562024B (en) | Fracturing design method for optimizing uniform spreading concentration | |
| CN109057763B (en) | Method for judging emulsification position in long rock core | |
| CN108843296B (en) | Single-well repeated fracturing effect prediction method based on multi-factor influence | |
| CN118133480A (en) | Method, system, medium and equipment for calculating fluid composition in reservoir reconstruction well bore | |
| Gao et al. | Novel mathematical model for transient pressure analysis of multifractured horizontal wells in naturally fractured oil reservoirs | |
| CN111582532A (en) | Stress-sensitive oil reservoir horizontal well fluid production capacity prediction method and device | |
| CN115906681A (en) | Full life cycle fracturing fracture volume evaluation treatment method and device | |
| CN113486537B (en) | Well spacing design method, device and equipment based on gas-water alternating oil displacement | |
| Daneshy | Analysis of Front and Tail Stress Shadowing in Horizontal Well Fracturing: Their Consequences With Case History | |
| CN112127877B (en) | Method, device, equipment and storage medium for predicting dynamic reserve of oil well | |
| CN110410044B (en) | Block oil yield calculation method under gas drive CO2 and N2 development mode | |
| CN113833446B (en) | Fracturing effect evaluation method and device | |
| CN111963161A (en) | Method and device for determining hidden abnormal oil well | |
| CN112396265B (en) | Method and device for determining water circulation level of water flooding sandstone reservoir | |
| CN114636808B (en) | Crude oil asphaltene precipitation research method combining experiment with digital-analog | |
| CN117610771A (en) | Method, device and medium for dividing post-pressure drainage and production stages of sandstone reservoir | |
| Wang et al. | Impact Analysis of Different Production History Input Methods on Test Well Interpretation Results for Africa Low Productivity Swabbing Wells | |
| CN110069791B (en) | Indoor experiment simulation method for scale correction | |
| CN112049624B (en) | Method, device, equipment and storage medium for predicting dynamic reserve of oil well |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination |