CN116108608A - Supercritical state CO2 semi-quantitative evaluation and complex fluid identification method and related devices - Google Patents
Supercritical state CO2 semi-quantitative evaluation and complex fluid identification method and related devices Download PDFInfo
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- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/12—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
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- E21B49/08—Obtaining fluid samples or testing fluids, in boreholes or wells
- E21B49/087—Well testing, e.g. testing for reservoir productivity or formation parameters
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Abstract
The invention discloses a supercritical state CO based on nuclear magnetic logging while drilling 2 Semi-quantitative evaluation and complex fluid identification methods and related devices. The method comprises the following steps: collecting the logging curve of the target layer, collecting data such as stratum test results, logging curve values and the like corresponding to depth points or depth segments, and selecting the data conforming to CO from the logging curve 2 The curve of response characteristic is used as a sensitive curve, the density porosity and the total porosity of the nuclear magnetism while drilling are determined as basic parameters, and the difference value between the density porosity and the total porosity of the nuclear magnetism while drilling is calculated
Establishing density porosity-porosity difference
Establishing a CO by using the intersection graph 2 Semi-quantitative evaluation plate, and CO is carried out on target intervals of research areas by using the plate 2 Semi-quantitative evaluation. According to CO 2 Semi-quantitative evaluation and target fluid discrimination criteria, and determining the type of complex fluid to be measured. Through multiple verification, the CO of the invention 2 The semi-quantitative evaluation and complex fluid identification method has high accuracy and wide applicability, and can reduce logging cost.
Description
Technical Field
The invention relates to the field of petroleum exploration, in particular to a nuclear magnetic logging while drilling-based supercritical state CO 2 Semi-quantitative evaluation and complex fluid identification methods and related devices.
Background
Logging fluid identification has been a key problem in reservoir logging evaluation and is also the basis for reservoir evaluation. The most common fluids in reservoirs include oil, methane-based hydrocarbon gas and water, and conventional fluid identification is very mature at home and abroad, but for CO in the supercritical state 2 Fluid identification of primarily non-hydrocarbon gas reservoirs, condensate reservoirs, volatile oils, and the like is difficult. With the domestic scholars to CO 2 Gas recognition research is advanced gradually, and CO is treated 2 Fluid identification of gas, condensate gas, hydrocarbon gas has been applied and promoted in domestic basins. But these methods focus onSandstone reservoirs are shallow (less than 2000 m), and the porosity of the reservoirs is high (15-30%), and when the porosity is small and the depth of burial is deep, neutron and density logging response characteristics react weakly and are difficult to identify. Due to supercritical state CO 2 Compared with oil density, the method is difficult to identify through conventional logging, and part of well sections cannot identify complex fluid properties according to conventional logging and logging data, so that great difficulty is brought to subsequent logging evaluation, exploration and development.
Disclosure of Invention
The present invention has been made in view of the above problems, and aims to provide a supercritical state CO based on nuclear magnetic logging while drilling that overcomes or at least partially solves the above problems 2 Semi-quantitative evaluation and complex fluid identification methods and related devices.
In a first aspect, embodiments of the present invention provide a supercritical state CO based on nuclear magnetic logging while drilling 2 A semi-quantitative evaluation method comprising:
collecting a logging curve of a target layer;
collecting a preset number of depth points or depth segments of a target layer as research samples, and establishing a research sample set, wherein the research samples comprise stratum test results, flash separation experiment results, oil test conclusions and logging curve values corresponding to the depth points or depth segments;
according to the logging value of the research sample, carrying out parameter analysis, determining logging response characteristic differences of different fluids in complex fluid according to the result of the parameter analysis, and selecting the CO from the logging curve according to the logging response characteristic differences 2 The curve of the response characteristic is used as a sensitive curve, and the sensitive curve comprises a density logging curve RHOB and a nuclear magnetic total porosity while drilling MPHS-LWD;
determining the density porosity PHIE_D of the depth point or depth section on the sensitivity curve and the total porosity MPHS-LWD of the nuclear magnetic while drilling as basic parameters based on the selected sensitivity curve, and calculating the difference value between the density porosity of the depth point or depth section and the total porosity of the nuclear magnetic while drilling 
CO according to the depth point or depth segment 2 Content, density porosity, porosity differential
Establishing the Density porosity PHIE_D-porosity difference +.>
A cross-over diagram;
by means of density-porosity PHIE_D-porosity difference
Establishing a CO (carbon monoxide) by using an intersection diagram 2 Semi-quantitatively evaluating a plate and using the plate to perform CO on a target interval of a research area 2 Semi-quantitative evaluation. />
In some alternative embodiments, the acquiring the log of the layer of interest includes:
borehole diameter curve CAL, natural gamma log GR, neutron log NPHI, density log RHOB, sonic log AC, nuclear magnetic total porosity MPHS and nuclear magnetic total porosity while drilling MPHS-LWD.
In some alternative embodiments, the acquiring the log of the target layer further includes:
pre-treating a log, the pre-treating comprising: quality analysis and standardization processing, and removing borehole expansion influence, abnormal values and systematic deviations caused by different logging instrument measurements.
In some alternative embodiments, the collecting the target layer with the preset number of depth points or depth segments as the study sample includes:
extracting a logging curve value corresponding to the depth point or the depth section from a formation test result, a flash separation experimental result and an oil test conclusion which are drilled in the loading area;
The formation testing includes DST testing and/or MDT testing.
In some alternative embodiments, the establishing a study sample set includes:
carrying out mass analysis and sample screening on the samples, and establishing a research sample set; the samples in the sample set include depth points or depth segments of CO 2 Content, oil and gas content and logging value.
In some alternative embodiments, the complex fluid comprises:
supercritical CO 2 Condensate gas and oil.
In some alternative embodiments, the density porosity is different from the total nuclear magnetic porosity while drilling
The method comprises the following steps:
wherein PHIE_ D, MPHS-LWD is the density porosity and the total porosity of the nuclear magnetism while drilling respectively.
In some alternative embodiments, the density-porosity PHIE_D-porosity difference is used
Establishing a CO (carbon monoxide) by using an intersection diagram 2 A semi-quantitative evaluation plate comprising:
according to different COs 2 Density porosity PHIE_D-porosity difference at content
Establishing a CO (carbon monoxide) by using an intersection diagram 2 Semi-quantitative evaluation plate, CO 2 Semi-quantitative evaluation plate contains a mixture of the different COs 2 The content is divided into a plurality of evaluation sections.
In a second aspect, an embodiment of the present invention provides a complex fluid identification method based on nuclear magnetic logging while drilling, including:
CO of build target layer 2 Semi-quantitatively evaluating the plate;
by CO 2 Semi-quantitative evaluation of plate for CO 2 Semi-quantitative evaluation according to the orderThe standard layer is based on CO 2 Determining the type of complex fluid in the target layer according to the fluid discrimination standard of the content;
the CO 2 Semi-quantitative evaluation plate is based on supercritical state CO of nuclear magnetic logging while drilling according to the method 2 Semi-quantitative evaluation method.
In a third aspect, embodiments of the present invention provide a supercritical state CO based on nuclear magnetic logging while drilling 2 A semi-quantitative evaluation device comprises:
the sensitive curve acquisition module is used for acquiring a logging curve of a target layer, acquiring depth points or depth sections of a preset number of target layers as research samples, and establishing a research sample set, wherein the research samples comprise stratum test results, flash separation experimental results, oil test conclusions and logging curve values corresponding to the depth points or depth sections, carrying out parameter analysis according to the logging values of the research samples, determining logging response characteristic differences of different fluids in complex fluids according to the results of the parameter analysis, and selecting the materials meeting the CO from the logging curve according to the logging response characteristic differences 2 The curve of the response characteristic is used as a sensitive curve, and the sensitive curve comprises a density logging curve RHOB and a nuclear magnetic total porosity while drilling MPHS-LWD;
First CO 2 A semi-quantitative evaluation plate establishing module for determining density porosity PHIE_D of the depth point or depth section on the sensitivity curve and total porosity MPHS-LWD of the nuclear magnetic while drilling based on the selected sensitivity curve, and calculating the difference value between the density porosity of the depth point or depth section and the total porosity MPHS-LWD of the nuclear magnetic while drilling
CO according to the depth point or depth segment 2 Content, density porosity, porosity Difference +.>
Establishing the Density porosity PHIE_D-porosity difference +.>
A cross-over diagram; benefit (benefit)Density porosity PHIE_D-porosity difference +.>
Establishing a CO (carbon monoxide) by using an intersection diagram 2 Semi-quantitatively evaluating a plate and using the plate to perform CO on a target interval of a research area 2 Semi-quantitative evaluation.
In a fourth aspect, an embodiment of the present invention provides a complex fluid identification device based on nuclear magnetic logging while drilling, including:
second CO 2 Semi-quantitative evaluation plate establishing module for establishing CO of target layer 2 Semi-quantitatively evaluating the plate;
complex fluid identification module for passing CO 2 Semi-quantitative evaluation based on CO according to the target layer 2 Determining the type of complex fluid in the target layer according to the fluid discrimination standard of the content; the CO 2 Semi-quantitative evaluation plate is based on supercritical state CO of nuclear magnetic logging while drilling according to the previous method 2 Semi-quantitative evaluation method.
In a fifth aspect, an embodiment of the present invention provides an electronic device, including: memory, processor and computer program stored in the memory and executable on the processor, the processor implementing the aforementioned supercritical state CO based on nuclear magnetic logging while drilling when executing the program 2 Semi-quantitative evaluation method or a complex fluid identification method based on nuclear magnetic logging while drilling.
In a sixth aspect, embodiments of the present invention provide a computer storage medium having stored therein computer executable instructions that when executed by a processor implement the aforementioned nuclear magnetic logging while drilling based supercritical state CO 2 Semi-quantitative evaluation method or a complex fluid identification method based on nuclear magnetic logging while drilling.
The technical scheme provided by the embodiment of the invention has the beneficial effects that at least:
the invention adopts the nuclear magnetic porosity while drilling of the logging value generated by the nuclear magnetic logging while drilling technology as the supercritical CO 2 Basis for semi-quantitative evaluation of fluidOne of the parameters is that the nuclear magnetic logging while drilling technology can reflect the real fluid property of the stratum, and compared with the cable nuclear magnetic resonance logging, the cable nuclear magnetic resonance logging has the influence of factors such as mud invasion, soaking and the like, the original stratum fluid property is influenced, and the logging value generated by the nuclear magnetic logging while drilling is more accurate, so that the improvement of supercritical CO is facilitated 2 Accuracy of semi-quantitative evaluation of fluid.
Because of the density log value commonly found in common wells, density log costs are lower than nuclear magnetic resonance log and because of CO 2 In the supercritical state, the density is similar to the density of oil, the density porosity is approximately equal to the cable nuclear magnetic porosity, and the density porosity can be calculated by a density logging value, so that the density porosity can be used for replacing the cable nuclear magnetic total porosity and the nuclear magnetic total porosity while drilling for comparison analysis under the condition that the density porosity is approximately equal to the cable nuclear magnetic porosity, the method can be widely applied to a general oil field, only one time of logging while drilling which can reflect the real-time state of a stratum is needed, and the cable nuclear magnetic resonance logging is not needed, so that the logging cost can be obviously reduced, and the influence of the cable nuclear magnetic resonance logging on the property of original stratum fluid can be reduced.
By applying the present invention to the Sulboride reservoir CO of Brazilian Mortolus basin 2 Semi-quantitative evaluation and fluid identification prove that the identification accuracy is higher through repeated stratum testing, flash separation experiments and oil testing conclusion verification, and the identification method provided by the invention has higher identification accuracy and better applicability, and can be applied to other areas.
Thus, the invention provides the supercritical CO based on the nuclear magnetic logging while drilling with higher accuracy 2 Fluid semi-quantitative evaluation and complex fluid identification technology, and through multiple verification, the method solves the problem of supercritical CO 2 Effective technical means of complex fluid identification;
additional features and advantages of the invention will be set forth in the description which follows, and in part will be obvious from the description, or may be learned by practice of the invention. The objectives and other advantages of the invention will be realized and attained by the structure particularly pointed out in the written description and claims thereof as well as the appended drawings.
The technical scheme of the invention is further described in detail through the drawings and the embodiments.
Drawings
The accompanying drawings are included to provide a further understanding of the invention and are incorporated in and constitute a part of this specification, illustrate the invention and together with the embodiments of the invention, serve to explain the invention. In the drawings:
FIG. 1 shows supercritical CO in an embodiment of the present invention 2 A semi-quantitative evaluation method flow chart;
FIG. 2 is a log histogram of Brazilian Santous basin X-1 well 5620-5763m in accordance with one embodiment of the present invention;
FIG. 3 is a graph showing density-porosity differential intersection at different CO2 levels in an embodiment of the present invention;
FIG. 4 is a schematic diagram of CO in an embodiment of the invention 2 Semi-quantitatively evaluating the plate;
FIG. 5 is a flow chart of a complex fluid identification method according to an embodiment of the invention;
FIG. 6 is a column diagram of Brazilian Sanatose basin A well 5420-5550m in one embodiment of the invention;
FIG. 7 shows A well 5420-5550mCO in an embodiment of the invention 2 Semi-quantitatively evaluating the plate;
FIG. 8 is a supercritical CO in an embodiment of the present invention 2 A semi-quantitative evaluation device block diagram;
FIG. 9 is a block diagram of a complex fluid identification device in accordance with one embodiment of the present invention.
Detailed Description
Exemplary embodiments of the present disclosure will be described in more detail below with reference to the accompanying drawings. While exemplary embodiments of the present disclosure are shown in the drawings, it should be understood that the present disclosure may be embodied in various forms and should not be limited to the embodiments set forth herein. Rather, these embodiments are provided so that this disclosure will be thorough and complete, and will fully convey the scope of the disclosure to those skilled in the art.
To solve the problems in the prior artFor CO 2 Identification of condensate gas and oil layers is lack of identification method and means at present, because of CO in supercritical state 2 Compared with oil density, the method is difficult to identify through conventional logging, and part of well sections cannot identify fluid properties according to conventional logging and logging data, so that great difficulty is brought to subsequent logging evaluation, exploration and development, and the embodiment of the invention provides a supercritical state CO based on nuclear magnetic logging while drilling 2 Semi-quantitative evaluation of fluid and complex fluid identification techniques.
Example 1
The embodiment of the invention provides a supercritical state CO based on nuclear magnetic logging while drilling 2 Semi-quantitative evaluation method, refer to supercritical state CO shown in FIG. 1 2 A semi-quantitative evaluation method flowchart comprising the steps of:
step S1: collecting a logging curve of a target layer;
the logs include, for example, a borehole diameter curve CAL, a natural gamma log GR, a neutron log NPHI, a density log RHOB, an acoustic log AC, a nuclear magnetic total porosity MPHS, a while-drilling nuclear magnetic total porosity MPHS-LWD, and the like.
The well logging curve is preprocessed, wherein the preprocessing comprises quality analysis and standardization processing, and borehole expansion influence, abnormal values and systematic deviations caused by different well logging instrument measurements are removed.
Step S2: and collecting a preset number of depth points or depth sections of a target layer as research samples, and establishing a research sample set, wherein the research samples comprise stratum test results, flash separation experiment results, oil test conclusions and logging curve values corresponding to the depth points or depth sections.
In specific implementation, a preset number of depth points or depth sections of a preset number of wells of a target layer are selected, a formation test result, a flash separation experiment result and an oil test conclusion of drilled formations in a loading area are extracted, logging curve values corresponding to the depth points or depth sections are extracted, and a system comprising CO is established 2 Samples of data such as content, hydrocarbon content, etc.
Carrying out mass analysis and sample screening on the samples, and establishing a research sample set; the sample setComprises CO of depth points or depth segments 2 Content, oil and gas content and logging value. The quality analysis and sample screening means selecting samples with good quality and log values more conforming to the change rule.
In the embodiment of the present invention, the change rule includes: first, supercritical CO 2 Has the characteristics of gas phase and liquid phase, the density is equivalent to that of oil, and the density is 0.85-0.9g/cm 3 Left and right, therefore, no matter what CO 2 The content is high and low, and the density is slightly influenced; second, CO 2 Does not contain hydrogen atoms, and has a hydrogen index H CO2 Is 0; the density of the crude oil is 0.85g/cm 3 It is generally considered that the hydrogen index Ho il 1.05; hydrogen index H of methane gas CH4 The nuclear magnetic resonance well logging measures the hydrogen index in the fluid and is only sensitive to hydrogen elements in reservoir pore fluid, while the nuclear magnetic resonance while drilling reflects the real fluid property of the stratum, while the cable nuclear magnetic resonance well logging influences the original stratum fluid property due to the influence of factors such as mud invasion, soaking and the like, if the stratum is high in CO 2 Cable nuclear magnetism T 2 Spectral distribution and nuclear magnetism while drilling T 2 The spectrum distribution forms have obvious difference, and the porosity difference of the two can be along with CO 2 The content increases with increasing value.
Formation testing, including Drill Stem formation testing (DST) testing and/or modular formation dynamic testing (MDT, modular Formation Dynamics Test) testing.
For example, according to DST and MDT test results, flash separation test results, oil test conclusions and the like of 201 depth points or depth sections of a 32-mouth test well in a certain area of a target layer, extracting logging curve values corresponding to the depth points or depth sections, carrying out sample mass analysis, sample screening and selecting research samples.
Step S3: according to the logging value of the research sample, carrying out parameter analysis, determining logging response characteristic differences of different fluids in complex fluid according to the result of the parameter analysis, and selecting the CO from the logging curve according to the logging response characteristic differences 2 The curve of the response characteristic is taken as a sensitive curve, and the sensitive curve comprises a density logging curve RHOB and a nuclear magnetic total pore while drillingThe degree MPHS-LWD.
Such complex fluids include, for example: supercritical CO 2 Condensate gas and oil. Supercritical CO 2 Refers to CO in supercritical state 2 . Condensate gas refers to gas produced by the reverse evaporation of liquid hydrocarbons after the subsurface temperature and pressure are above the critical temperature and pressure. Any substance has three phases of gas phase, liquid phase and solid phase. The point where the liquid and gas phases are in equilibrium is called the critical point. The temperature and pressure at the critical point are referred to as critical temperature and critical pressure. The state above the critical temperature and critical pressure and near the critical point is referred to as the supercritical state. The pressure and temperature required for the critical point varies from substance to substance. When the substance is in a supercritical state, the gas-liquid two-phase property is very close.
For example, the difference of logging response characteristics is determined by means of dual-parameter and three-parameter intersection analysis, and the CO can be known by the analysis 2 The difference from other fluid logging response characteristics is the hydrogen index. CO 2 The content is low and has little influence on the density logging value.
For example, in a chalk-based reservoir under Brazilian Santous basin salt, a burial depth of about 4000-6000m, CO from a sample analysis and pressure system analysis of a well test section of a formed layer 2 Has a density of 0.9g/cm 3 And the left and right sides are equivalent to the oil density. Thus no matter what CO 2 The content is high and low, and the density is slightly influenced. FIG. 2 is a log of the Brazilian Santous basin X-1 well 5620-5763m, wherein the fifth trace is density porosity, cable core magnetic total porosity, while-drilling cable core magnetic total porosity, density porosity substantially overlapping cable core magnetic total porosity, density porosity not significantly different from cable core magnetic total porosity, density porosity significantly different from while-drilling core magnetic total porosity. The sixth and seventh channels are respectively the difference value of the density porosity and the total porosity of the nuclear magnetism while drilling, the difference value of the total porosity of the cable nuclear magnetism and the total porosity of the nuclear magnetism while drilling, and the difference between the two difference values is smaller.
Nuclear magnetic resonance logging is the hydrogen index in the fluid and is only sensitive to the reservoir pore fluid hydrogen element. While drilling nuclear magnetic resonance reflects the true fluid properties of the formation, while cable nuclear magnetic resonance Logging affects the properties of the original formation fluid due to oil-based mud invasion, if the formation fluid is highly CO-containing 2 Two-pass nuclear magnetism T 2 The spectral morphology, total porosity, will vary. As shown in FIG. 2, the interval is tested for CO by the formation 2 The content was 96%. The third and the fourth channels are respectively nuclear magnetic resonance T while drilling 2 Distribution, cable nuclear magnetic resonance T 2 Distribution, obvious morphology difference of the two, nuclear magnetic resonance T while drilling 2 Distributed oil-free gas display, whereas cable nuclear magnetic resonance T 2 The distribution shows oil gas distribution and the pores are better.
Because the common well commonly has a density logging value, the density logging cost is lower than that of nuclear magnetic resonance logging, and the cable nuclear magnetic resonance logging affects the original stratum fluid property due to the influence of factors such as mud invasion, soaking and the like, and due to CO 2 In the supercritical state, the density is similar to the density of oil, the density porosity is approximately equal to the cable nuclear magnetic porosity, the density porosity and the cable nuclear magnetic total porosity are basically overlapped, the difference is not large, and the density porosity can be calculated by a density logging value, so that the density porosity can be used for replacing the cable nuclear magnetic total porosity and the while-drilling nuclear magnetic total porosity for comparison analysis under the condition that the density porosity is approximately equal to the cable nuclear magnetic porosity. For the above reasons, the present invention preferably selects the density log RHOB and the nuclear magnetic total porosity while drilling MPHS-LWD as the sensitive curves.
Step S4: determining the density porosity PHIE_D of the depth point or depth section on the sensitivity curve and the total porosity MPHS-LWD of the nuclear magnetic while drilling as basic parameters based on the selected sensitivity curve, and calculating the difference value between the density porosity of the depth point or depth section and the total porosity of the nuclear magnetic while drilling
The relationship of density porosity is:
PHIE_D＝(DEN-D ma )/(D f -D ma )，
wherein PHIE_D is density porosity in V/V, DEN is density log, D ma Is the density value of the rock skeleton, D f DEN, D is the fluid density value ma And D f In g/cm 3 。
The density porosity and the total porosity difference of nuclear magnetism while drilling
The relation is:
PHIE_ D, MPHS-LWD is the density porosity and the total porosity of the nuclear magnetism while drilling, and the unit is V/V.
Step S5: CO according to the depth point or depth segment 2 Content, density porosity, porosity differential
Establishing the Density porosity PHIE_D-porosity difference +.>
And (5) intersecting the graph.
For example, the following method is used to study CO 2 Content, density porosity, porosity differential
Correlation of the three: finding out CO from a research sample set 2 Samples with a content of 0.02% were obtained by subjecting these samples to a density porosity and a porosity difference +.>
The corresponding density porosity of each of the samples is +. >
Marked as density porosity PHIE_D-porosity difference +.>
On the intersection graph, thus in density porosity PHIE_D-porosity difference +.>
A plurality of sample points are formed on the intersection graph. Then carrying out mathematical analysis on the sample points, fitting a straight line representing the distribution rule of the sample points, and marking the straight line on the density porosity PHIE_D-porosity difference value +.>
On the intersection graph, the slope of this line is taken as CO 2 At a content of 0.02% the density porosity-porosity difference>
Is a slope of (2). Similarly, other COs can be found using the methods described above 2 Density porosity-porosity difference at content +.>
Is a slope of (2). The resulting density-porosity PHIE_D-porosity difference +.>
Examples of the cross-over diagrams refer to different COs shown in FIG. 3 2 Density porosity-porosity difference plot at content.
FIG. 3 shows the formation testing intervals of A blocks X-6, X-17, X-21, P blocks P-1 well, CO 2 Density porosity-porosity difference of 0.02%, 44%, 66%, 96%, respectively
Cross-over diagram, wherein figure a is CO 2 Content 0.02%Is the intersection of (b) CO 2 Intersection graph with 44% content, graph c is CO 2 Intersection graph with 66% content, graph d is CO 2 Intersection graph with 96% content. The slopes of the straight lines drawn by the broken lines in the diagrams a, b, c and d are CO respectively 2 The content is 0.02%, 44%, 66%, 96% of density porosity-porosity difference +.>
Is a slope of (2).
Referring to FIG. 3, CO 2 Content, density porosity and porosity differential
Has positive correlation, i.e. with CO, with the same density porosity 2 Increased content, porosity difference->
Increased density porosity-porosity difference +.>
The greater the slope, the more significant the CO 2 In the same content, as the density porosity increases, the porosity difference +.>
Increasing.
Step S6: by means of density-porosity PHIE_D-porosity difference
Establishing a CO (carbon monoxide) by using an intersection diagram 2 Semi-quantitatively evaluating a plate and using the plate to perform CO on a target interval of a research area 2 Semi-quantitative evaluation.
According to different COs 2 Density porosity PHIE_D-porosity difference at content
Establishing a CO (carbon monoxide) by using an intersection diagram 2 The plate was evaluated semi-quantitatively and,CO 2 semi-quantitative evaluation plate contains a mixture of the different COs 2 The content is divided into a plurality of evaluation sections.
For example, refer to CO shown in FIG. 4 2 Semi-quantitative evaluation plate, first, respectively drawing CO 2 The content is 0.02%, 0.3%, 17%, 18%, 43%, 66%, 77%, 96% and the like
Intersecting the graph and dividing the graph into different COs 2 Fitting the generated straight line under the content, and drawing the straight line at the same density porosity-porosity difference value +.>
On the slope intersection graph. For example, in FIG. 4, by +.>
The solid line of calibration is CO 2 The content of 0.02% represents a straight line with regular distribution of sample points, which is composed of +.>
The solid line of calibration is CO 2 The content of 0.3% represents a straight line with regular distribution of sample points, which is composed of +.>
The solid line of calibration is CO 2 The content of 17% represents a straight line of the sample point distribution rule, which is composed of +.>
The solid line of calibration is CO 2 The content of the straight line representing the distribution rule of the sample points at the time of 18 percent is formed by
The solid line of calibration is CO 2 The content of 43% represents a straight line with regular distribution of sample points, which is composed of +.>
The solid line of calibration is CO 2 The content of 66% represents a straight line with regular distribution of sample points, which is composed of +.>
The solid line of calibration is CO 2 The content of 77% represents a straight line with regular distribution of sample points, which is composed of +.>
The solid line of calibration is CO 2 The content of 96% represents a straight line with regular sample point distribution. Then according to the change trend of the slope of the solid line straight line, fitting to represent different COs 2 A straight line that demarcates the numerical range of the content. In FIG. 4, the CO is fitted separately 2 Straight lines with the sample point distribution rule are drawn in the times of 0, 40%, 60%, 80% and 100% of the content, and are broken line straight lines for distinguishing the straight lines from the straight lines drawn before. By CO 2 The dotted line straight line with the content of 0, 40%, 60%, 80% and 100% representing the sample point distribution rule is used for calibrating a coordinate system, and CO is used for calibrating the coordinate system 2 The content is divided into four sections of 0 to 40 percent, 40 to 60 percent, 60 to 80 percent and 80 to 100 percent so as to establish CO 2 Semi-quantitatively evaluating the plate.
By CO 2 The semi-quantitative evaluation plate can accurately and semi-quantitatively evaluate CO 2 The content is as follows. For example, the density porosity PHIE_D is obtained by collecting the sensitive curve density log RHOB of the target layer, the density porosity PHIE_D is obtained by collecting the sensitive curve MPHS-LWD of the target layer, the MPHS-LWD is obtained, and the difference value between the density porosity and the MPHS-LWD is obtained by calculation
In CO 2 In the semi-quantitative evaluation plate, we find the density porosity PHIE_D as abscissa, and let ∈ ->
Is of the ordinatePoint, according to most points at CO 2 Semi-quantitatively evaluating the position in the plate to determine the CO 2 Numerical range of content to complete CO 2 Semi-quantitative evaluation.
In CO 2 After the semi-quantitative evaluation of the plate is drawn, in the range with smaller abscissa, the dividing lines are relatively dense, and the coordinate system space is inconvenient to distinguish, so that the accuracy of the semi-quantitative evaluation can be realized according to CO 2 And (3) the specific distribution condition of the demarcation straight line after the drawing of the semi-quantitative evaluation drawing plate is finished, and the data of the area with the unclear demarcation coordinate is excluded.
For example, referring to FIG. 4, after the plate is drawn, CO is present at an abscissa density porosity of less than 6% 2 The content distinguishing effect is poor, and data with the density and the porosity lower than 6% in the reservoir can be removed first and then semi-quantitative evaluation can be performed, so that the accuracy of the semi-quantitative evaluation is improved.
Example two
The second embodiment of the invention provides a complex fluid identification method based on nuclear magnetic logging while drilling, which refers to a complex fluid identification method flow chart shown in fig. 5, and comprises the following steps:
step S7: CO of build target layer 2 Semi-quantitatively evaluating the plate. For specific steps in creating a plate reference is made to embodiment one.
Step S8: by CO 2 Semi-quantitative evaluation of plate for CO 2 Semi-quantitative evaluation based on CO according to the target layer 2 And determining the type of the complex fluid in the target layer according to the fluid discriminant criteria of the content. The CO 2 Semi-quantitative evaluation plate is based on supercritical state CO of nuclear magnetic logging while drilling according to the previous method 2 Semi-quantitative evaluation method.
For example, a preset number of depth points or depth segments of a preset number of wells of a target layer are selected, DST, MDT test results, flash separation test results, oil test conclusions and the like are carried out on the selected depth points or depth segments, logging curve values corresponding to the selected depth points or depth segments are obtained, and a method comprising CO is established 2 The quality analysis is carried out on the established samples of the data such as the content, the oil gas content and the like,sample screening, namely establishing a research sample set from the screened samples. According to the actual situation of the local area reflected by the research sample set, using CO 2 The content of the supercritical CO is respectively defined 2 Gas, condensate and oil layers, thereby establishing a research area based on CO 2 Fluid content criteria. For example, define CO 2 The gas layer with the content higher than 80% is supercritical CO 2 Gas layer, CO 2 The hydrocarbon fluid with the content of 60-80% is condensate gas, CO 2 The type of fluid having a content of less than 60% is oil.
For example, referring to the Brazilian Santous basin A well 5420-5550m log histogram shown in FIG. 6, the fourth is the density porosity, the nuclear magnetic total porosity while drilling contrast, and the fifth is the porosity difference
It can be seen that the difference between the two is small, namely the difference of the porosity
The values remain in the lower interval. Refer to the A well 5420-5550mCO shown in FIG. 7 2 Semi-quantitative evaluation plate, when the density porosity of the complex fluid to be measured is more than 6%, referring to FIG. 7, the porosity difference is +.>
The values are kept low, i.e. the ordinate of FIG. 7 is kept low, and it is known that the density-porosity difference +. >
The slope is in the range of 0-40%, so as to judge the CO of the fluid to be tested 2 With a content of 0-40%, and then the investigation region established according to step S8 is based on CO 2 The fluid to be measured belongs to the oil layer by the fluid discrimination standard of the content. Wherein, formation test proves that the fluid to be tested is CO 2 And the oil layer with the content of 0.3 percent, the test result falls in the interval of the semi-quantitative evaluation result, and the semi-quantitative evaluation result is accurate.
Semi-quantitative evaluation of CO by 4 wells and 8 horizon logging in Brazilian Santous basin 2 And comparing the fluid type identification with the actual measurement result, and semi-quantitatively evaluating the CO by applying a complex fluid identification method based on nuclear magnetic logging while drilling 2 The accuracy of the method is 75%, and the accuracy of fluid identification is 100%. The method is shown to be effective in semi-quantitatively evaluating CO 2 The content of the fluid can be used for identifying the property of the fluid.
Example III
The embodiment of the invention provides a supercritical state CO based on nuclear magnetic logging while drilling 2 Semi-quantitative evaluation device, refer to supercritical state CO shown in fig. 8 2 A semi-quantitative evaluation device block diagram comprising:
the sensitive curve acquisition module 101 is configured to acquire a logging curve of a target layer, acquire a preset number of depth points or depth segments of the target layer as research samples, and establish a research sample set, where the research samples include formation test results, flash separation experimental results, oil test conclusions and logging curve values corresponding to the depth points or depth segments, perform parameter analysis according to the logging values of the research samples, determine logging response characteristic differences of different fluids in the complex fluid according to the results of the parameter analysis, and select a sample meeting the above CO from the logging curve according to the logging response characteristic differences 2 The curve of the response characteristic is used as a sensitive curve, and the sensitive curve comprises a density logging curve RHOB and a nuclear magnetic total porosity while drilling MPHS-LWD;
first CO 2 A semi-quantitative evaluation plate creation module 102 for determining density porosity phie_d of the depth point or depth segment on the sensitivity curve and total porosity while drilling MPHS-LWD as basic parameters based on the selected sensitivity curve, and calculating the difference value between the density porosity of the depth point or depth segment and the total porosity while drilling MPHS
CO according to the depth point or depth segment 2 Content, density porosity, porosity Difference +.>
Establishing Density porosity PHIE_D-porosity differential
A cross-over diagram; by means of the density porosity PHIE_D-porosity difference +.>
Establishing a CO (carbon monoxide) by using an intersection diagram 2 Semi-quantitatively evaluating a plate and using the plate to perform CO on a target interval of a research area 2 Semi-quantitative evaluation.
Example IV
The embodiment of the invention provides a complex fluid identification device based on nuclear magnetic logging while drilling, which is shown by referring to a block diagram of the complex fluid identification device in FIG. 9 and comprises:
second CO 2 A semi-quantitative evaluation plate establishing module 111 for establishing CO of the target layer 2 Semi-quantitatively evaluating the plate;
a complex fluid identification module 112 for passing CO 2 Semi-quantitative evaluation based on CO according to the target layer 2 Determining the type of complex fluid in the target layer according to the fluid discrimination standard of the content; the CO 2 Semi-quantitative evaluation plate is based on supercritical state CO of nuclear magnetic logging while drilling according to the previous method 2 Semi-quantitative evaluation method.
The embodiment of the invention provides electronic equipment, which comprises: memory, processor and computer program stored in the memory and executable on the processor, the processor implementing the aforementioned supercritical state CO based on nuclear magnetic logging while drilling when executing the program 2 Semi-quantitative evaluation methods or complex fluid identification methods based on nuclear magnetic logging while drilling.
Embodiments of the present invention provide a computer storage medium having stored therein computer executable instructions that, when executed by a processor, implement the foregoing supercritical state CO based on nuclear magnetic logging while drilling 2 Semi-quantitative evaluation methods or complex fluid identification methods based on nuclear magnetic logging while drilling.
In the method or apparatus provided in the above embodiments, the logging value while drilling nuclear magnetic porosity generated by the while drilling nuclear magnetic logging technique is used as the supercritical CO 2 One of basic parameters of semi-quantitative evaluation of fluid, because the nuclear magnetic logging while drilling technology can reflect the real fluid property of the stratum, compared with cable nuclear magnetic resonance logging, the cable nuclear magnetic resonance logging has the advantages that the original stratum fluid property is influenced due to the influence of factors such as mud invasion, soaking and the like, the logging value generated by the nuclear magnetic logging while drilling is more accurate, and therefore the improvement of supercritical CO is facilitated 2 Accuracy of semi-quantitative evaluation of fluid.
In addition, because the density logging value is commonly measured in the common well, the density logging cost is lower than that of the nuclear magnetic resonance logging, the method or the device provided by the embodiment can be widely applied to the common oil field, and only one time of nuclear magnetic resonance logging while drilling which can reflect the real-time state of the stratum is needed to be measured, and the cable nuclear magnetic resonance logging is not needed to be performed, so that the logging cost can be obviously reduced, and the influence of the cable nuclear magnetic resonance logging on the properties of the original stratum fluid can be reduced.
And by applying the invention to the Sulboride reservoir CO of Brazilian Mortolus basin 2 The identification method provided by the invention has higher identification accuracy and better applicability, and can be applied to other areas and has better technical value.
The method or the device provided in the embodiment provides the supercritical CO based on the nuclear magnetic logging while drilling with higher accuracy 2 Fluid semi-quantitative evaluation and complex fluid identification technology, and through multiple verification, the method solves the problem of supercritical CO 2 Efficient technical means for complex fluid identification.
The specific manner in which the various modules perform the operations in the apparatus of the above embodiments have been described in detail in connection with the embodiments of the method, and will not be described in detail herein.
It should be understood that the specific order or hierarchy of steps in the processes disclosed are examples of exemplary approaches. Based on design preferences, it is understood that the specific order or hierarchy of steps in the processes may be rearranged without departing from the scope of the present disclosure. The accompanying method claims present elements of the various steps in a sample order, and are not meant to be limited to the specific order or hierarchy presented.
In the foregoing detailed description, various features are grouped together in a single embodiment for the purpose of streamlining the disclosure. This method of disclosure is not to be interpreted as reflecting an intention that the claimed embodiments of the subject matter require more features than are expressly recited in each claim. Rather, as the following claims reflect, invention lies in less than all features of a single disclosed embodiment. Thus the following claims are hereby expressly incorporated into this detailed description, with each claim standing on its own as a separate preferred embodiment of this invention.
Those of skill would further appreciate that the various illustrative logical blocks, modules, circuits, and algorithm steps described in connection with the embodiments disclosed herein may be implemented as electronic hardware, computer software, or combinations of both. To clearly illustrate this interchangeability of hardware and software, various illustrative components, blocks, modules, circuits, and steps have been described above generally in terms of their functionality. Whether such functionality is implemented as hardware or software depends upon the particular application and design constraints imposed on the overall system. 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 disclosure.
The steps of a method or algorithm described in connection with the embodiments disclosed herein may be embodied directly in hardware, in a software module executed by a processor, or in a combination of the two. A software module may reside in RAM memory, flash memory, ROM memory, EPROM memory, EEPROM memory, registers, hard disk, a removable disk, a CD-ROM, or any other form of storage medium known in the art. An exemplary storage medium is coupled to the processor such the processor can read information from, and write information to, the storage medium. In the alternative, the storage medium may be integral to the processor. The processor and the storage medium may reside in an ASIC. The ASIC may reside in a user terminal. The processor and the storage medium may reside as discrete components in a user terminal.
For a software implementation, the techniques described herein may be implemented with modules (e.g., procedures, functions, and so on) that perform the functions described herein. These software codes may be stored in memory units and executed by processors. The memory unit may be implemented within the processor or external to the processor, in which case it can be communicatively coupled to the processor via various means as is known in the art.
The foregoing description includes examples of one or more embodiments. It is, of course, not possible to describe every conceivable combination of components or methodologies for purposes of describing the aforementioned embodiments, but one of ordinary skill in the art may recognize that many further combinations and permutations of various embodiments are possible. Accordingly, the embodiments described herein are intended to embrace all such alterations, modifications and variations that fall within the scope of the appended claims. Furthermore, as used in the specification or claims, the term "comprising" is intended to be inclusive in a manner similar to the term "comprising," as interpreted when employed as a transitional word in a claim. Furthermore, any use of the term "or" in the specification of the claims is intended to mean "non-exclusive or".
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