Carbonate reservoir type identification method and system

Abstract

The invention relates to a carbonate reservoir type identification method and system, and belongs to the field of geological exploration. The method comprises the following steps: preliminarily identifying the type of the carbonate reservoir based on a conventional resistivity curve and a deep resistivity-acoustic logging curve overlapping method; based on a gas logging curve, and / or a nuclear magnetic T2 spectrum, and / or a pore permeability relation, and / or mercury injection and pore throat distribution, and / or an imaging logging interpretation result and / or core analysis, verifying the preliminarily identified carbonate reservoir type; and completing the carbonate reservoir type based on the verification result. According to the carbonate reservoir type identification method, preliminary identification of the carbonate reservoir type can be completed based on the conventional resistivity curve and the deep resistivity-acoustic logging curve overlapping method, then the identification result is verified through other conventional logging information, namely, identification of the carbonate reservoir type is completed, the identification process is simple, and the identification efficiency is greatly improved for the reservoir lacking special logging information. And type identification can be completed.

Description

Technical Field

[0001] This invention belongs to the field of geological exploration, and specifically relates to a method and system for identifying carbonate reservoir types. Background Technology

[0002] Reservoir classification is a crucial aspect of carbonate reservoir evaluation. Different reservoir types exhibit varying physical properties and permeability characteristics, leading to differences in logging responses and identification criteria. Generally, fractured reservoirs possess good permeability but limited storage space; porous reservoirs offer significant storage space but poor permeability, typically requiring acid fracturing for modification; and composite porous-fracture-cavity reservoirs represent a more ideal type, possessing both ample storage space and effective permeability pathways. However, existing methods for identifying carbonate reservoir types involve core analysis and geological interpretation. This process is complex, requiring extensive geological and exploration data. For reservoirs lacking core samples and geological interpretation, relying solely on conventional logging curves is insufficient for accurate carbonate reservoir type identification. Summary of the Invention

[0003] To address the above problems, this invention provides a method and system for identifying carbonate reservoir types.

[0004] The first objective of this invention is to provide a method for identifying carbonate reservoir types, comprising:

[0005] Based on conventional resistivity curves, the deep resistivity-sonic logging curve overlay method was used to preliminarily identify carbonate reservoir types.

[0006] Based on gas logging curves, and / or nuclear magnetic resonance T2 spectra, and / or porosity-permeability relationships, and / or mercury injection and pore throat distribution, and / or imaging logging interpretation results and / or core analysis, the preliminarily identified carbonate reservoir types are verified.

[0007] Based on the verification results, the carbonate reservoir types were determined.

[0008] In a specific embodiment of the present invention, the conventional resistivity curve, the deep resistivity-sonic logging curve overlay method, for preliminary identification of carbonate reservoir types includes:

[0009] Determine the morphological characteristics of a conventional resistivity curve;

[0010] Superimpose deep resistivity and sonic logging curves, and determine the overlap characteristics of the two curves;

[0011] Based on the curve morphology and the size of the overlapping area, the type of carbonate reservoir can be preliminarily identified.

[0012] In a specific embodiment of the present invention, the preliminary identification of carbonate reservoir types based on the curve morphology and overlap characteristics of conventional resistivity curves includes:

[0013] The conventional resistivity curve is characterized by a multi-segment "L" shape, and the overlap feature is that the deep resistivity logging curve is to the left of the sonic transit time logging curve. When the two curves overlap and form an overlapping area, and the area of ​​the overlapping area is greater than or equal to the first threshold, the carbonate reservoir type is initially identified as a pore-fracture-vuggy composite type.

[0014] The conventional resistivity curve is U-shaped, and the overlap feature is that the deep resistivity logging curve is to the left of the sonic transit time logging curve. When the two curves overlap and form an overlapping area, and the area of ​​the overlapping area is less than the first threshold, the carbonate reservoir type is initially identified as a pore-fracture type reservoir.

[0015] The conventional resistivity curve is V-shaped, and the overlap is characterized by the deep resistivity logging curve being to the left of the sonic transit time logging curve. After the two curves overlap, an overlapping area is formed, and / or sharp peaks can be seen in the overlapping area. The carbonate reservoir type is preliminarily identified as a fractured reservoir.

[0016] The conventional resistivity curve is characterized by a straight bracket shape, and the overlap is shown in that the deep resistivity logging curve is to the left of the sonic transit time logging curve. After the two curves are superimposed, a slight overlap area is visible, and the two curves have the same or similar shape. The carbonate reservoir type is preliminarily identified as a porous reservoir.

[0017] In a specific embodiment of the present invention, the preliminary identification of carbonate reservoir types based on the curve morphology and overlap characteristics of conventional resistivity curves further includes:

[0018] The conventional resistivity curve is characterized by a flat shape, and if the deep resistivity logging curve is to the right of the sonic transit time logging curve, it is identified as an invalid fracture segment.

[0019] In a specific embodiment of the present invention, the verification of the preliminarily identified carbonate reservoir type based on gas logging curves, and / or nuclear magnetic resonance T2 spectra, and / or porosity-permeability relationships, and / or mercury injection and pore throat distribution, and / or imaging logging interpretation results and / or core analysis includes:

[0020] Based on the analysis results of the gas logging curves, the initially identified carbonate reservoir type was verified.

[0021] And / or, the analysis results of dynamic resistivity imaging can verify the initially identified carbonate reservoir type;

[0022] And / or, the analysis results of static resistivity imaging can verify the initially identified carbonate reservoir type;

[0023] And / or, the analysis results of the T2 NMR spectrum can verify the initially identified carbonate reservoir type;

[0024] And / or, the analysis results of the porosity-permeability relationship can verify the initially identified carbonate reservoir type;

[0025] And / or, the analysis results of mercury injection and pore throat distribution, verify the preliminarily identified carbonate reservoir type;

[0026] And / or, based on the analysis results of core analysis, to confirm the preliminary identification of carbonate reservoir types.

[0027] In a specific embodiment of the present invention, when the initially identified carbonate reservoir type is a pore-fracture-vuggy complex:

[0028] The analysis results of the gas logging curves correspond to high values ​​in a large section, and the total hydrocarbon and methane content curves show a high degree of overlap, indicating that the gas content is abundant.

[0029] The analysis results of dynamic resistivity imaging correspond to a combination of dark lines and patches;

[0030] The analysis results of static resistivity imaging correspond to a combination pattern of bright and light-colored patches;

[0031] The analysis results of the NMR T2 spectrum show a multi-peak characteristic, distributed on both sides of the T2 cutoff line, with the logarithmic mean of T2 and the T2 cutoff value alternating and approaching each other;

[0032] The analysis results of the porosity-permeability relationship show that matrix flow and fracture flow coexist, and the range of porosity-permeability variation conforms to the first range;

[0033] The analysis results of mercury injection and pore throat distribution correspond to the core mercury injection curves. The displacement pressure is less than the second threshold, the mercury injection curve is a standard seat shape with a long straight section, the maximum mercury injection saturation is higher than the third threshold, and the pore throat has a high value and a wide distribution.

[0034] The core analysis results correspond to the development of high-angle fractures and dissolution cavities;

[0035] When the initially identified carbonate reservoir type is a porous-fractured reservoir:

[0036] The analysis results of the gas logging curves correspond to local medium-high values, and the total hydrocarbon and methane content curves are similar;

[0037] The analysis results of dynamic resistivity imaging show a linear pattern with alternating bright and dark colors.

[0038] The analysis results of static resistivity imaging show a predominantly dark and light-colored blocky pattern.

[0039] The analysis results of the NMR T2 spectrum show that the NMR T2 spectrum has a separated double peak shape, distributed on both sides of the T2 cutoff line;

[0040] The analysis results of the porosity-permeability relationship show that matrix flow and fracture flow coexist, and the range of porosity-permeability variation conforms to the second range.

[0041] The analysis results of mercury injection and pore throat distribution correspond to the following: the mercury injection curve shows that the displacement pressure is higher than the fourth threshold, the straight section of the mercury injection curve is short, and the pore throat distribution range is narrow and consistent with the permeability contribution distribution.

[0042] The core analysis results correspond to the development of high-angle open fractures with incomplete filling, or accompanied by visible dissolution pores.

[0043] In a specific embodiment of the present invention, when the initially identified carbonate reservoir type is a fractured reservoir:

[0044] The analysis results of the gas logging curves correspond to medium to high values ​​in a short segment, and the total hydrocarbon and methane content curves are similar;

[0045] The analysis results of dynamic resistivity imaging show a predominantly dark linear pattern.

[0046] The analysis results of static electrophysiological imaging correspond to a light-colored patchy pattern;

[0047] The NMR T2 spectrum analysis results show a single broad peak shape, which is located to the left of the T2 cutoff value. The logarithmic mean of T2 is separated from the T2 cutoff value.

[0048] The analysis results of the porosity-permeability relationship show that it exhibits the characteristics of fracture flow, the matrix porosity is less than the preset value, and the permeability variation range has a difference of 6 orders of magnitude.

[0049] The analysis results of mercury injection and pore throat distribution correspond to the following: the mercury injection curve shows that the displacement pressure is higher than the fourth threshold, the mercury injection curve lacks a flat segment and shows the characteristics of rapid fracture flow. The fourth threshold is higher than the second threshold, the maximum mercury injection saturation is less than the third threshold, the residual mercury saturation is less than the fifth threshold, the mercury removal efficiency is high, the pore throat distribution range is narrow, and the permeability contribution corresponding to high pore throats is large.

[0050] The core analysis results correspond to the development of high-angle open fractures with incomplete filling;

[0051] When the initially identified carbonate reservoir type is a porous reservoir:

[0052] The analysis results of the gas logging curves show that the values ​​are in the middle and high range in a short segment, and the total hydrocarbon and methane content curves are clearly separated at the top and bottom of the reservoir and show low values.

[0053] The analysis results of dynamic resistivity imaging correspond to visible needle-like dark spots;

[0054] The analysis results of static electrophysiological imaging correspond to a dark, blocky pattern;

[0055] The analysis results of the NMR T2 spectrum show a single narrow peak shape, with the main peak generally located to the right of the T2 cutoff line. The logarithmic mean of T2 is close to the T2 cutoff value.

[0056] The analysis results of the porosity-permeability relationship show that it exhibits the characteristics of matrix flow. The porosity-permeability variation range conforms to the third range, the width of the first range is greater than the width of the third range, and the width of the third range is greater than the width of the second range.

[0057] The analysis results of mercury injection and pore throat distribution correspond to the mercury injection curve showing that the displacement pressure is between the fourth threshold and the second threshold, the flat segment of the mercury injection curve is short, and the mercury removal efficiency is low; the pore throat distribution range is wide, and the permeability contribution corresponding to high pore throats is large.

[0058] The core analysis results correspond to no developed fractures or visible dissolution pores.

[0059] A second objective of this invention is to provide a system for identifying carbonate reservoir types, comprising:

[0060] The preliminary identification module is used to preliminarily identify carbonate reservoir types based on conventional resistivity curves and the deep resistivity-sonic logging curve overlay method.

[0061] The verification module is used to verify the initially identified carbonate reservoir type based on gas logging curves, and / or nuclear magnetic resonance T2 spectra, and / or porosity-permeability relationship, and / or mercury injection and pore throat distribution, and / or imaging logging interpretation results and / or core analysis;

[0062] The completion module is used to complete the carbonate reservoir type based on the verification results.

[0063] A third object of the present invention is to provide an electronic device comprising: a processor coupled to a memory;

[0064] The memory is used to store computer programs;

[0065] The processor is configured to execute the computer program stored in the memory, so that the electronic device performs the method described above.

[0066] A fourth object of the present invention is to provide a computer-readable storage medium storing a program or instructions that, when executed on a computer, cause the computer to perform the method described above.

[0067] The beneficial effects of this invention are:

[0068] This invention provides a method and system for identifying carbonate reservoir types. The initial identification of carbonate reservoir types can be completed based on conventional resistivity curves and the deep resistivity-sonic logging curve overlay method. The identification results can then be verified by other conventional logging data (gas logging curves, or nuclear magnetic resonance T2 spectra, or porosimetry and pore throat distribution). Thus, the identification of carbonate reservoir types is completed. The identification process is simple and can also be completed for reservoirs lacking special logging data.

[0069] Secondly, based on the conventional resistivity curve and the preliminary identification process of the deep resistivity-sonic logging curve overlay method, this invention can also identify invalid fracture segments.

[0070] Other features and advantages of the invention will be set forth in the description which follows, and will be apparent in part from the description, or may be learned by practicing the invention. The objects and other advantages of the invention may be realized and obtained by means of the structures pointed out in the description, claims and drawings. Attached Figure Description

[0071] To more clearly illustrate the technical solutions in the embodiments of the present invention or the prior art, the drawings used in the description of the embodiments or the prior art will be briefly introduced below. Obviously, the drawings described below are some embodiments of the present invention. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0072] Figure 1 A flowchart of a method for identifying carbonate reservoir types according to an embodiment of the present invention is shown;

[0073] Figure 2 One of the overlay curves of a conventional resistivity curve and a deep resistivity-sonic logging curve according to an embodiment of the present invention is shown;

[0074] Figure 3 One of the overlay curves of a conventional resistivity curve and a deep resistivity-sonic logging curve according to an embodiment of the present invention is shown;

[0075] Figure 4 One of the overlay curves of a conventional resistivity curve and a deep resistivity-sonic logging curve according to an embodiment of the present invention is shown;

[0076] Figure 5 One of the overlay curves of a conventional resistivity curve and a deep resistivity-sonic logging curve according to an embodiment of the present invention is shown;

[0077] Figure 6 One of the overlay curves of a conventional resistivity curve and a deep resistivity-sonic logging curve according to an embodiment of the present invention is shown;

[0078] Figure 7 The illustration shows a composite chart of pore-fracture-vuggy structures based on conventional resistivity curves, overlapping curves of deep resistivity-sonic logging curves, gas logging curves, nuclear magnetic resonance T2 spectra, porosity-permeability relationship, mercury injection and pore throat distribution, logging imaging, and core analysis identification, according to embodiments of the present invention.

[0079] Figure 8 The diagram illustrates a fracture-pore type chart based on conventional resistivity curves, overlapping curves of deep resistivity-sonic logging curves, gas logging curves, NMR T2 spectra, porosity-permeability relationship, mercury injection and pore throat distribution, logging imaging, and core analysis identification, according to embodiments of the present invention.

[0080] Figure 9 The illustrations show curves based on conventional resistivity curves, overlapping curves of deep resistivity-sonic logging curves, gas logging curves, nuclear magnetic resonance T2 spectra, porosity-permeability relationship, mercury injection and pore throat distribution, logging imaging, and fracture type charts identified by core analysis according to embodiments of the present invention.

[0081] Figure 10 The illustrations show pore type charts based on conventional resistivity curves, overlapping curves of deep resistivity-sonic logging curves, gas logging curves, NMR T2 spectra, porosity-permeability relationships, mercury injection and pore throat distribution, logging imaging, and core analysis identification according to embodiments of the present invention.

[0082] Figure 11 A plate illustrating the identification of carbonate reservoir types on the right bank of the Amu Darya River in overseas Turkmenistan according to an embodiment of the present invention is shown;

[0083] Figure 12 A framework diagram of a carbonate reservoir type identification system according to an embodiment of the present invention is shown;

[0084] Figure 13 A frame diagram of an electronic device according to an embodiment of the present invention is shown;

[0085] In the diagram: Preliminary identification module 1; Verification module 2; Completion module 3; Electronic device 300; Processor 301; Memory 302. Detailed Implementation

[0086] To make the objectives, technical solutions, and advantages of the embodiments of the present invention clearer, the technical solutions of the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of the present invention, not all embodiments. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of the present invention.

[0087] like Figure 1 As shown, a method for identifying carbonate reservoir types according to an embodiment of the present invention includes:

[0088] The first step is to preliminarily identify the carbonate reservoir type based on the conventional resistivity curve and the deep resistivity-sonic logging curve overlay method.

[0089] The second step is to verify the preliminarily identified carbonate reservoir type based on gas logging curves, and / or nuclear magnetic resonance T2 spectra, and / or porosity-permeability relationship, and / or mercury injection and pore throat distribution, and / or imaging logging interpretation results and / or core analysis.

[0090] The third step is to determine the carbonate reservoir type based on the verification results.

[0091] In the first step of this embodiment of the invention, conventional resistivity curves and deep resistivity-sonic logging curve overlay method are used to preliminarily identify carbonate reservoir types, including:

[0092] A1. Determine the curve shape characteristics of a conventional resistivity curve;

[0093] A2. Superimpose the deep resistivity curve with the sonic logging curve and determine the overlap characteristics of the two curves;

[0094] A3. Based on the curve morphology and the size of the overlapping area, the type of carbonate reservoir can be preliminarily identified.

[0095] In the first step, the theoretical basis for identifying carbonate reservoir types using the deep resistivity-sonic logging curve overlay method is that deep resistivity logging can reflect the hydrocarbon content of the reservoir to a certain extent, while sonic logging can indirectly indicate the reservoir's reservoir space characteristics, especially in terms of fractures and vulcanization. The specific process is as follows: the calibrated sonic logging curve is overlaid on the deep resistivity logging curve. In the low-porosity marl layer, the two curves basically overlap to form the baseline layer. This method minimizes the influence of porosity and the additional conductivity of clay on the spacing of the overlapping curves. The overlap area and separation degree of the two curves within the reservoir section can reflect the degree of fracture and vulcanization development, i.e., proceed to step A2.

[0096] Therefore, in this embodiment of the invention, the deep resistivity-sonic logging curve overlay method was used, supplemented by the hydrocarbon-bearing properties revealed by conventional resistivity curves, to complete the preliminary identification of acid rock reservoir types.

[0097] In step A3, based on the curve morphology and overlap characteristics of conventional resistivity curves, the type of carbonate reservoir is preliminarily identified. The specific types of carbonate reservoirs involved include:

[0098] 1) The typical resistivity curve is characterized by a multi-segment "L" shape, such as... Figure 2 The curve located on the right is shown in the middle;

[0099] The overlap characteristic is manifested as the deep resistivity logging curve lying to the left of the sonic transit time logging curve. When the two curves overlap and form an overlapping area, and the area of ​​this overlapping area is greater than or equal to the first threshold, the carbonate reservoir type is preliminarily identified as a pore-fracture-vuggy composite type. Figure 2 The curve located on the left is shown in the middle;

[0100] 2) The conventional resistivity curve is characterized by a "U" shape, such as... Figure 3 The curve located on the right is shown in the middle;

[0101] Furthermore, the overlap characteristic is manifested as the deep resistivity logging curve being to the left of the sonic transit time logging curve, the two curves overlapping to form an overlapping region, and the area of ​​the overlapping region being less than the first threshold, such as... Figure 3 As shown by the curve on the left, the carbonate reservoir type is preliminarily identified as a pore-fracture type reservoir.

[0102] 3) The conventional resistivity curve is characterized by a "V" shape, such as... Figure 4 The curve located on the right is shown in the middle;

[0103] The overlap characteristic is manifested as the deep resistivity logging curve lying to the left of the sonic transit time logging curve. The two curves overlap to form an overlapping region, and / or a sharp overlapping portion may be visible within this region. Figure 4 As shown by the curve on the left, the carbonate reservoir type is preliminarily identified as a fractured reservoir.

[0104] 4) The conventional resistivity curve is characterized by a flat bracket shape, such as... Figure 5 The curve located on the right is shown in the middle;

[0105] Furthermore, the overlap characteristic is manifested in the deep resistivity logging curve being to the left of the sonic transit time logging curve, with a slight overlap area visible after the two curves are superimposed, and the two curves having similar or identical shapes, such as... Figure 5 As shown by the curve on the left, the carbonate reservoir type is preliminarily identified as a porous reservoir.

[0106] The first threshold mentioned above is flexibly set by the size of the overlapping area enclosed by the deep resistivity and sonic logging curves. There is no specific limit to the value. If the area of ​​the overlapping area is larger, it is considered to be greater than or equal to the first threshold. If the area of ​​the overlapping area is smaller, it is considered to be less than the first threshold.

[0107] In the above steps, the type of carbonate reservoir was identified by combining conventional resistivity curves and deep resistivity-sonic logging curve overlay method. This method not only has high accuracy but also identifies invalid fracture intervals. Specifically:

[0108] The typical resistivity curve is flat, as shown in the image. Figure 6 The curve located on the right is shown in the middle;

[0109] Furthermore, the overlap characteristic is manifested in the deep resistivity logging curve being to the right of the sonic transit time logging curve, such as... Figure 6 The curve on the left indicates an invalid fracture segment.

[0110] To further verify the carbonate reservoir type identified by the conventional resistivity curve and deep resistivity-sonic logging curve overlay method, this invention employs a second step: based on gas logging curves, and / or nuclear magnetic resonance T2 spectra, and / or porosity-permeability relationships, and / or mercury injection and pore throat distribution, and / or imaging logging interpretation results and / or core analysis, the preliminarily identified carbonate reservoir type is verified.

[0111] The second step can be completed based on well logging data from wells that identify carbonate reservoir types. Any one of the following data can be used to verify the initial identification, including gas logging curves, NMR T2 spectra, porosity-permeability relationships, mercury injection and pore throat distribution, imaging logging interpretation results, and core analysis data. This simplifies the entire carbonate reservoir type identification process and allows for the prediction of complex fractured-vuggy carbonate reservoirs based on simple logging data (conventional curves: conventional resistivity curves, sonic logging curves, gas logging curves, or NMR T2 spectra, or porosity-permeability relationships, or mercury injection and pore throat distribution).

[0112] Specifically, the second step includes:

[0113] Based on the analysis results of the gas logging curves, the initially identified carbonate reservoir type was verified.

[0114] And / or, the analysis results of dynamic resistivity imaging can verify the initially identified carbonate reservoir type;

[0115] And / or, the analysis results of static resistivity imaging can verify the initially identified carbonate reservoir type;

[0116] And / or, the analysis results of the T2 NMR spectrum can verify the initially identified carbonate reservoir type;

[0117] And / or, the analysis results of the porosity-permeability relationship can verify the initially identified carbonate reservoir type;

[0118] And / or, the analysis results of mercury injection and pore throat distribution, verify the preliminarily identified carbonate reservoir type;

[0119] And / or, based on the analysis results of core analysis, to confirm the preliminary identification of carbonate reservoir types.

[0120] In the actual identification process, when the carbonate reservoir type initially identified in the first step is a pore-fracture-vuggy complex:

[0121] When verifying with gas logging curves, the analysis results of the gas logging curves corresponded to large sections with high values, and the total hydrocarbon and methane content curves showed a high degree of overlap, indicating abundant gas content. Figure 7 As shown in 'a';

[0122] When verified using dynamic resistivity imaging, the analysis results of dynamic resistivity imaging correspond to a combination of dark linear and patchy patterns, such as... Figure 7 As shown in 'a';

[0123] When verified using static resistivity imaging, the analysis results of static resistivity imaging correspond to a pattern of bright and light-colored patches, such as... Figure 7 As shown in 'a';

[0124] When verified using NMR T2 spectroscopy, the analysis results of the NMR T2 spectrum showed a multi-peak characteristic, distributed on both sides of the T2 cutoff line. The logarithmic mean of T2 and the T2 cutoff value alternated and approached each other, such as... Figure 7 As shown in 'a';

[0125] When verifying using the porosity-permeability relationship, the analysis results show that matrix flow and fracture flow coexist, and the range of porosity-permeability variation conforms to the first range, such as... Figure 7 As shown in b;

[0126] In this embodiment of the invention, the range of pore seepage variation is divided into a first range, a second range, and a third range according to the width of the range, wherein the width of the first range is greater than the width of the third range, and the width of the third range is greater than the width of the second range.

[0127] When verifying the results using mercury intrusion porosimetry (MIP) and pore throat distribution, the analysis results correspond to the core MIP curves. The displacement pressure is less than the second threshold, the mercury intrusion curve is a standard seat shape with a long straight section, the maximum mercury intrusion saturation is higher than the third threshold, and the pore throats show high values ​​and a wide distribution. Figure 7 As shown in b;

[0128] In this embodiment of the invention, the exhaust pressure values ​​are sorted according to their magnitude and divided into a second threshold and a fourth threshold. The fourth threshold is equal to the second threshold. The fourth threshold and the second threshold meet the above conditions and can be flexibly defined. When the exhaust pressure is less than the second threshold, it indicates that the exhaust pressure is small. When the exhaust pressure is greater than the fourth threshold, it indicates that the exhaust pressure is high. When the exhaust pressure is between the second threshold and the fourth threshold, the exhaust pressure is medium.

[0129] In this embodiment of the invention, a third threshold is set based on the value of the maximum mercury saturation. The third threshold is flexibly set according to the overall situation of mercury injection and pore throat distribution. When the maximum mercury saturation is higher than the third threshold, it indicates that the maximum mercury saturation is relatively high.

[0130] When verified by gas core analysis, the core analysis results corresponded to the development of high-angle fractures and dissolution cavities, such as... Figure 7 As shown in 'a'.

[0131] In the actual identification process, when the carbonate reservoir type initially identified in the first step is a porous-fractured reservoir:

[0132] When verifying with gas logging curves, the analysis results of the gas logging curves corresponded to local medium-high values, and the total hydrocarbon and methane content curves were similar, such as... Figure 8 As shown in 'a';

[0133] When verified using dynamic resistivity imaging, the analysis results of dynamic resistivity imaging mainly show a linear pattern with alternating bright and dark colors, such as... Figure 8 As shown in 'a';

[0134] When verified using static resistivity imaging, the analysis results of static resistivity imaging showed a predominantly dark and light-colored patchy pattern, such as... Figure 8 As shown in 'a';

[0135] When verified using NMR T2 spectroscopy, the analysis results of the NMR T2 spectrum correspond to a separated bimodal shape, distributed on both sides of the T2 cutoff line, such as... Figure 8 As shown in 'a';

[0136] When verifying using the porosity-permeability relationship, the analysis results show that matrix flow and fracture flow coexist, and the range of porosity-permeability variation conforms to the second range, such as... Figure 8 As shown in b;

[0137] In this embodiment of the invention, the range of pore seepage variation is divided into a first range, a second range, and a third range according to the width of the range, wherein the width of the first range is greater than the width of the third range, and the width of the third range is greater than the width of the second range.

[0138] When verifying using mercury injection and pore throat distribution, the analytical results of mercury injection and pore throat distribution correspond to the following: the mercury injection curve shows that the displacement pressure is higher than the fourth threshold; the mercury injection curve has a short flat segment; and the pore throat distribution range is narrow and consistent with the permeability contribution distribution. Figure 8 As shown in b;

[0139] When verified by core analysis, the analysis results correspond to the development of high-angle open fractures with incomplete filling, or accompanied by visible solution pores, such as... Figure 8 As shown in 'a'.

[0140] In the actual identification process, when the carbonate reservoir type initially identified in the first step is a fractured reservoir:

[0141] When verifying with gas logging curves, the analysis results of the gas logging curves correspond to medium-high values ​​in a short segment, and the total hydrocarbon and methane content curves are similar, such as... Figure 9 As shown in 'a';

[0142] When verified using dynamic resistivity imaging, the analysis results of dynamic resistivity imaging show a predominantly dark linear pattern, such as... Figure 9 As shown in 'a';

[0143] When verified using static electrical imaging, the analysis results of static electrical imaging correspond to a light-colored patchy pattern, such as... Figure 9 As shown in 'a';

[0144] When verified using NMR T2 spectroscopy, the analysis results of the NMR T2 spectrum show a single broad peak shape, distributed to the left of the T2 cutoff line. The logarithmic mean of T2 is separated from the T2 cutoff value. Figure 9 As shown in 'a';

[0145] When verifying the porosity-permeability relationship, the analysis results showed characteristics of fracture flow, with matrix porosity less than the preset value and permeability variation ranging from six orders of magnitude. Figure 9 As shown in b;

[0146] In this embodiment of the invention, the range of pore seepage variation is divided into a first range, a second range, and a third range according to the width of the range, wherein the width of the first range is greater than the width of the third range, and the width of the third range is greater than the width of the second range.

[0147] When verifying using mercury injection and pore throat distribution, the analysis results of mercury injection and pore throat distribution correspond to the following: the mercury injection curve shows that the displacement pressure is higher than the fourth threshold, the mercury ingress curve lacks a flat segment, exhibiting characteristics of rapidly advancing fracture flow. The fourth threshold is higher than the second threshold, the maximum mercury ingress saturation is lower than the third threshold, the residual mercury saturation is lower than the fifth threshold, the mercury removal efficiency is high, the pore throat distribution range is narrow, and the permeability contribution corresponding to high pore throats is large. Figure 9 As shown in b;

[0148] In this embodiment of the invention, the maximum mercury saturation is less than the third threshold, indicating that the maximum mercury saturation is relatively small.

[0149] In this embodiment of the invention, the fifth threshold is set according to the magnitude of the residual mercury saturation value. The fifth threshold is flexibly set according to the overall situation of mercury intrusion and pore throat distribution. When the residual mercury saturation value is less than the fifth threshold, it indicates that the residual mercury saturation is low.

[0150] When verified by core analysis, the analysis results corresponded to the development of high-angle open fractures with incomplete filling, such as... Figure 9 As shown in 'a'.

[0151] In the actual identification process, when the carbonate reservoir type initially identified in the first step is a porous reservoir:

[0152] When verifying with gas logging curves, the analysis results of the gas logging curves showed high values ​​in a short segment, and the total hydrocarbon and methane content curves were clearly separated at the top and bottom of the reservoir and showed low values. Figure 10 As shown in 'a';

[0153] When verified using dynamic resistivity imaging, the analysis results of dynamic resistivity imaging correspond to visible needle-like dark spots, such as... Figure 10 As shown in 'a';

[0154] When verified using static electrical imaging, the analysis results of static electrical imaging correspond to a dark, blocky pattern, such as... Figure 10 As shown in 'a';

[0155] When verifying with NMR T2 spectroscopy, the analysis results of the NMR T2 spectrum show a single narrow peak shape, with the main peak generally located to the right of the T2 cutoff line. The logarithmic mean of T2 is close to the T2 cutoff value. Figure 10 As shown in 'a';

[0156] When verifying using the porosity-permeability relationship, the analysis results show characteristics of matrix flow. The porosity-permeability variation range conforms to a third range, where the width of the first range is greater than the width of the third range, and the width of the third range is greater than the width of the second range. Figure 10 As shown in b;

[0157] When verifying the results using mercury injection and pore throat distribution, the analysis results showed that the mercury injection curve indicated that the displacement pressure was between the fourth and second thresholds, the flat segment of the mercury injection curve was short, and the mercury removal efficiency was low; the pore throat distribution range was wide, and the permeability contribution corresponding to high pore throats was large, such as... Figure 10 As shown in b;

[0158] In this embodiment of the invention, the exhaust pressure values ​​are sorted according to their magnitude and divided into a second threshold and a fourth threshold. The fourth threshold is equal to the second threshold. The fourth threshold and the second threshold meet the above conditions and can be flexibly defined. When the exhaust pressure is less than the second threshold, it indicates that the exhaust pressure is small. When the exhaust pressure is greater than the fourth threshold, it indicates that the exhaust pressure is high. When the exhaust pressure is between the second threshold and the fourth threshold, the exhaust pressure is medium.

[0159] When verified by core analysis, the analysis results correspond to no developed fractures or visible dissolution pores, such as... Figure 10 As shown in 'a'.

[0160] Figures 7-10 In the figure, the vertical axis of the mercury intrusion curve represents capillary pressure (MPa), and the horizontal axis represents mercury saturation (%). The vertical axis of the pore throat distribution curve represents pore throat radius (μm), and the horizontal axis represents pore throat distribution (%).

[0161] Based on the completion of the second step of verification, the identification of carbonate reservoir types was completed.

[0162] Using the method in the first step of the above embodiments, this invention identifies the type of carbonate reservoir on the right bank of the Amu Darya River in overseas Turkmenistan. The final identification chart of the carbonate reservoir type on the right bank of the Amu Darya River in overseas Turkmenistan is as follows: Figure 11 As shown.

[0163] like Figure 12 As shown, a carbonate reservoir type identification system according to an embodiment of the present invention includes:

[0164] Preliminary identification module 1 is used to preliminarily identify carbonate reservoir types based on conventional resistivity curves and deep resistivity-sonic logging curve overlay method;

[0165] Verification module 2 is used to verify the initially identified carbonate reservoir type based on gas logging curves, and / or nuclear magnetic resonance T2 spectra, and / or porosity-permeability relationship, and / or mercury injection and pore throat distribution, and / or imaging logging interpretation results and / or core analysis;

[0166] Module 3 is used to complete the carbonate reservoir type based on the verification results.

[0167] like Figure 13 As shown, in some embodiments of the present invention, an electronic device is provided, the electronic device 300 including: a processor 301 coupled to a memory 302;

[0168] The memory 302 is used to store computer programs;

[0169] The processor 301 is configured to execute the computer program stored in the memory 302, so that the electronic device performs the method described in the above embodiments.

[0170] In some embodiments of the present invention, a computer-readable storage medium is provided that stores a program or instructions that, when executed on a computer, cause the computer to perform the methods described in the above embodiments.

[0171] According to embodiments of the present invention, the computer-readable storage medium may be a non-volatile computer-readable storage medium, such as including, but not limited to: portable computer disks, hard disks, random access memory (RAM), read-only memory (ROM), erasable programmable read-only memory (EPROM or flash memory), portable compact disk read-only memory (CD-ROM), optical storage devices, magnetic storage devices, or any suitable combination thereof. In the present invention, the computer-readable storage medium may be any tangible medium containing or storing a program that can be used by or in conjunction with an instruction execution system, electronic device, or apparatus.

[0172] Although the present invention has been described in detail with reference to the foregoing embodiments, those skilled in the art should understand that modifications can still be made to the technical solutions described in the foregoing embodiments, or equivalent substitutions can be made to some of the technical features; and these modifications or substitutions do not cause the essence of the corresponding technical solutions to deviate from the spirit and scope of the technical solutions of the embodiments of the present invention.

Claims

1. A method for identifying carbonate reservoir types, characterized in that, include: Based on conventional resistivity curves, the deep resistivity-sonic logging curve overlay method was used to preliminarily identify carbonate reservoir types. Based on gas logging curves, and / or nuclear magnetic resonance T2 spectra, and / or porosity-permeability relationships, and / or mercury injection and pore throat distribution, and / or imaging logging interpretation results and / or core analysis, the preliminarily identified carbonate reservoir types are verified. Based on the verification results, the carbonate reservoir types were determined.

2. The method for identifying carbonate reservoir types according to claim 1, characterized in that, The conventional resistivity curves and the deep resistivity-sonic logging curve overlay method are used to preliminarily identify carbonate reservoir types, including: Determine the morphological characteristics of a conventional resistivity curve; Superimpose deep resistivity and sonic logging curves, and determine the overlap characteristics of the two curves; Based on the curve morphology and the size of the overlapping area, the type of carbonate reservoir can be preliminarily identified.

3. The method for identifying carbonate reservoir types according to claim 2, characterized in that, The preliminary identification of carbonate reservoir types based on the curve morphology and overlap characteristics of conventional resistivity curves includes: The conventional resistivity curve is characterized by a multi-segment "L" shape, and the overlap feature is that the deep resistivity logging curve is to the left of the sonic transit time logging curve. When the two curves overlap and form an overlapping area, and the area of ​​the overlapping area is greater than or equal to the first threshold, the carbonate reservoir type is initially identified as a pore-fracture-vuggy composite type. The conventional resistivity curve is U-shaped, and the overlap feature is that the deep resistivity logging curve is to the left of the sonic transit time logging curve. When the two curves overlap and form an overlapping area, and the area of ​​the overlapping area is less than the first threshold, the carbonate reservoir type is initially identified as a pore-fracture type reservoir. The conventional resistivity curve is V-shaped, and the overlap is shown in that the deep resistivity logging curve is to the left of the sonic transit time logging curve. After the two curves overlap, an overlapping area is formed, and / or sharp peaks can be seen in the overlapping area. The carbonate reservoir type is preliminarily identified as a fractured reservoir. The conventional resistivity curve is characterized by a straight bracket shape, and the overlap is shown in that the deep resistivity logging curve is to the left of the sonic transit time logging curve. After the two curves are superimposed, a slight overlap area is visible, and the two curves have the same or similar shape. The carbonate reservoir type is preliminarily identified as a porous reservoir.

4. The method for identifying carbonate reservoir types according to claim 2, characterized in that, The preliminary identification of carbonate reservoir types based on the curve morphology and overlap characteristics of conventional resistivity curves also includes: The conventional resistivity curve is characterized by a flat shape, and if the deep resistivity logging curve is to the right of the sonic transit time logging curve, it is identified as an invalid fracture segment.

5. A method for identifying carbonate reservoir types according to any one of claims 1-4, characterized in that, The verification of the preliminarily identified carbonate reservoir type based on gas logging curves, and / or nuclear magnetic resonance T2 spectra, and / or porosity-permeability relationships, and / or mercury injection and pore throat distribution, and / or imaging logging interpretation results and / or core analysis includes: Based on the analysis results of the gas logging curves, the initially identified carbonate reservoir type was verified. And / or, the analysis results of dynamic resistivity imaging can verify the initially identified carbonate reservoir type; And / or, the analysis results of static resistivity imaging can verify the initially identified carbonate reservoir type; And / or, the analysis results of the T2 NMR spectrum can verify the initially identified carbonate reservoir type; And / or, the analysis results of the porosity-permeability relationship can verify the initially identified carbonate reservoir type; And / or, the analysis results of mercury injection and pore throat distribution, verify the preliminarily identified carbonate reservoir type; And / or, based on the analysis results of core analysis, to confirm the preliminary identification of carbonate reservoir types.

6. The method for identifying carbonate reservoir types according to claim 5, characterized in that, When the initially identified carbonate reservoir type is a porous-fracture-vuggy complex: The analysis results of the gas logging curves correspond to high values ​​in a large section, and the total hydrocarbon and methane content curves show a high degree of overlap, indicating that the gas content is abundant. The analysis results of dynamic resistivity imaging correspond to a combination of dark lines and patches; The analysis results of static resistivity imaging correspond to a combination pattern of bright and light-colored patches; The analysis results of the NMR T2 spectrum show a multi-peak characteristic, distributed on both sides of the T2 cutoff line, with the logarithmic mean of T2 and the T2 cutoff value alternating and approaching each other; The analysis results of the porosity-permeability relationship show that matrix flow and fracture flow coexist, and the range of porosity-permeability variation conforms to the first range; The analysis results of mercury injection and pore throat distribution correspond to the core mercury injection curves, showing that the displacement pressure is less than the second threshold, the mercury injection curve is a standard seat shape with a long straight section, the maximum mercury injection saturation is higher than the third threshold, and the pore throat has a high value and a wide distribution. The core analysis results correspond to the development of high-angle fractures and dissolution cavities; When the initially identified carbonate reservoir type is a porous-fractured reservoir: The analysis results of the gas logging curves correspond to local medium-high values, and the total hydrocarbon and methane content curves are similar; The analysis results of dynamic resistivity imaging show a linear pattern with alternating bright and dark colors. The analysis results of static resistivity imaging show a predominantly dark and light-colored blocky pattern. The analysis results of the NMR T2 spectrum show that the NMR T2 spectrum has a separated double peak shape, distributed on both sides of the T2 cutoff line; The analysis results of the porosity-permeability relationship show that matrix flow and fracture flow coexist, and the range of porosity-permeability variation conforms to the second range. The analysis results of mercury injection and pore throat distribution correspond to the following: the mercury injection curve shows that the displacement pressure is higher than the fourth threshold, the straight section of the mercury injection curve is short, and the pore throat distribution range is narrow and consistent with the permeability contribution distribution. The core analysis results correspond to the development of high-angle open fractures with incomplete filling, or accompanied by visible dissolution pores.

7. The method for identifying carbonate reservoir types according to claim 6, characterized in that, When the initially identified carbonate reservoir type is a fractured reservoir: The analysis results of the gas logging curves correspond to medium to high values ​​in a short segment, and the total hydrocarbon and methane content curves are similar; The analysis results of dynamic resistivity imaging show a predominantly dark linear pattern. The analysis results of static electrophysiological imaging correspond to a light-colored patchy pattern; The NMR T2 spectrum analysis results show a single broad peak shape, which is located to the left of the T2 cutoff value. The logarithmic mean of T2 is separated from the T2 cutoff value. The analysis results of the porosity-permeability relationship show that it exhibits the characteristics of fracture flow, the matrix porosity is less than the preset value, and the permeability variation range has a difference of 6 orders of magnitude. The analysis results of mercury injection and pore throat distribution correspond to the following: the mercury injection curve shows that the displacement pressure is higher than the fourth threshold, the mercury injection curve lacks a flat segment and shows the characteristics of rapid fracture flow. The fourth threshold is higher than the second threshold, the maximum mercury injection saturation is less than the third threshold, the residual mercury saturation is less than the fifth threshold, the mercury removal efficiency is high, the pore throat distribution range is narrow, and the permeability contribution corresponding to high pore throats is large. The core analysis results correspond to the development of high-angle open fractures with incomplete filling; When the initially identified carbonate reservoir type is a porous reservoir: The analysis results of the gas logging curves show that the values ​​are in the middle and high range in a short segment, and the total hydrocarbon and methane content curves are clearly separated at the top and bottom of the reservoir and show low values. The analysis results of dynamic resistivity imaging correspond to visible needle-like dark spots; The analysis results of static electrophysiological imaging correspond to a dark, blocky pattern; The analysis results of the NMR T2 spectrum show a single narrow peak shape, with the main peak generally located to the right of the T2 cutoff line. The logarithmic mean of T2 is close to the T2 cutoff value. The analysis results of the porosity-permeability relationship show that it exhibits the characteristics of matrix flow. The porosity-permeability variation range conforms to the third range, the width of the first range is greater than the width of the third range, and the width of the third range is greater than the width of the second range. The analysis results of mercury injection and pore throat distribution correspond to the mercury injection curve showing that the displacement pressure is between the fourth threshold and the second threshold, the flat segment of the mercury injection curve is short, and the mercury removal efficiency is low; the pore throat distribution range is wide, and the permeability contribution corresponding to high pore throats is large; The core analysis results correspond to no developed fractures or visible dissolution pores.

8. A system for identifying carbonate reservoir types, characterized in that, include: The preliminary identification module is used to preliminarily identify carbonate reservoir types based on conventional resistivity curves and the deep resistivity-sonic logging curve overlay method. The verification module is used to verify the initially identified carbonate reservoir type based on gas logging curves, and / or nuclear magnetic resonance T2 spectra, and / or porosity-permeability relationship, and / or mercury injection and pore throat distribution, and / or imaging logging interpretation results and / or core analysis; The completion module is used to complete the carbonate reservoir type based on the verification results.

9. An electronic device, characterized in that, include: Processor, the processor being coupled to memory; The memory is used to store computer programs; The processor is configured to execute the computer program stored in the memory to cause the electronic device to perform the method as described in any one of claims 1 to 7.

10. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores a program or instructions that, when executed on a computer, cause the computer to perform the method as described in any one of claims 1 to 7.

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