CN112145164B - Method for determining formation water volume compression coefficient and natural gas volume compression coefficient - Google Patents
Method for determining formation water volume compression coefficient and natural gas volume compression coefficient Download PDFInfo
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- CN112145164B CN112145164B CN201910577213.3A CN201910577213A CN112145164B CN 112145164 B CN112145164 B CN 112145164B CN 201910577213 A CN201910577213 A CN 201910577213A CN 112145164 B CN112145164 B CN 112145164B
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- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 title claims abstract description 94
- 239000008398 formation water Substances 0.000 title claims abstract description 82
- 239000003345 natural gas Substances 0.000 title claims abstract description 47
- 230000006835 compression Effects 0.000 title claims abstract description 46
- 238000007906 compression Methods 0.000 title claims abstract description 46
- 238000000034 method Methods 0.000 title claims abstract description 34
- 230000033558 biomineral tissue development Effects 0.000 claims abstract description 41
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 30
- 238000009933 burial Methods 0.000 claims abstract description 13
- 238000012360 testing method Methods 0.000 claims abstract description 9
- 238000005056 compaction Methods 0.000 claims description 4
- 230000001089 mineralizing effect Effects 0.000 claims 1
- 239000012530 fluid Substances 0.000 abstract description 12
- 238000004364 calculation method Methods 0.000 abstract description 8
- 238000011158 quantitative evaluation Methods 0.000 abstract description 4
- 230000015572 biosynthetic process Effects 0.000 description 15
- 239000007789 gas Substances 0.000 description 5
- 230000000694 effects Effects 0.000 description 2
- 238000011156 evaluation Methods 0.000 description 2
- 239000011435 rock Substances 0.000 description 2
- 238000005070 sampling Methods 0.000 description 2
- 238000013459 approach Methods 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 230000018109 developmental process Effects 0.000 description 1
- 229930195733 hydrocarbon Natural products 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 238000011545 laboratory measurement Methods 0.000 description 1
- 239000011159 matrix material Substances 0.000 description 1
- 238000005259 measurement Methods 0.000 description 1
- 238000000691 measurement method Methods 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 239000003921 oil Substances 0.000 description 1
- 239000011148 porous material Substances 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
-
- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06F—ELECTRIC DIGITAL DATA PROCESSING
- G06F17/00—Digital computing or data processing equipment or methods, specially adapted for specific functions
- G06F17/10—Complex mathematical operations
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02A—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE
- Y02A90/00—Technologies having an indirect contribution to adaptation to climate change
- Y02A90/30—Assessment of water resources
Abstract
A method of determining a formation water volume compressibility and a natural gas volume compressibility is disclosed. The method for determining the formation water volume compression coefficient comprises the following steps: according to the formation water experimental test data, obtaining the mineralization degree of the formation water; and calculating the water volume modulus of the stratum according to the mineralization degree of the stratum water, and further calculating the water volume compression coefficient of the stratum. According to the method, the formation water bulk modulus and the compression coefficient are determined through the mineralization degree, the natural gas bulk modulus and the compression coefficient calculation data are determined through the burial depth, the method is convenient to obtain, the practicability is high, and a foundation and a basis are provided for fluid prediction and quantitative evaluation based on acoustic logging and seismic data.
Description
Technical Field
The invention relates to the field of oil and gas reservoir fluid property identification and evaluation, in particular to a method for determining a stratum water volume compression coefficient and a natural gas volume compression coefficient.
Background
In the process of identifying and quantitatively evaluating the properties of oil and gas reservoir fluids by using acoustic logging and seismic data, elastic parameters such as the volume modulus of underground stratum water and hydrocarbons are often required. The acquisition of these elastic parameters includes two approaches: firstly, laboratory measurement is carried out through core sampling; and secondly, obtaining the method by checking documents and related calculation methods. The experimental measurement method needs on-site sampling, and the experimental flow is complex and low-efficiency, so that the method cannot be adopted on a large scale; parameters such as fluid components, formation temperature and pressure data are often required by using literature or related calculation methods, on the one hand, the parameters are often difficult to obtain, and on the other hand, the calculation method is too cumbersome and inconvenient to use.
Batzel and Wang (1992) propose a method for determining the bulk modulus of formation water and oil gas under formation conditions, however, the process of obtaining the volume coefficients of formation water and natural gas is complicated, and the critical parameters fluid components, temperature and pressure parameters are often difficult to obtain, which limits the application of the method. Therefore, there is a need to develop a method of determining the formation water volume compressibility and the natural gas volume compressibility.
The information disclosed in the background section of the invention is only for enhancement of understanding of the general background of the invention and should not be taken as an acknowledgement or any form of suggestion that this information forms the prior art already known to a person skilled in the art.
Disclosure of Invention
The invention provides a method for determining the formation water volume compression coefficient and the natural gas volume compression coefficient, which can determine the formation water volume modulus and the natural gas volume compression coefficient through mineralization, and determine the natural gas volume modulus and the compression coefficient through burial depth, so that the method is convenient to obtain, has strong practicability, and provides a basis for fluid prediction and quantitative evaluation based on acoustic logging and seismic data.
According to one aspect of the invention, a method of determining a formation water volume compaction factor is presented. The method may include: according to the formation water experimental test data, obtaining the mineralization degree of the formation water; and calculating the water volume modulus of the stratum according to the mineralization degree of the stratum water, and further calculating the volume compression coefficient of the stratum water.
Preferably, the formation water volume modulus is calculated by equation (1):
K w ＝3.3×10 -6 P wn +1.7254 (1)
wherein K is w For the formation water volume modulus, P wn Is the mineralization degree of stratum water.
Preferably, the formation water volume compaction factor is calculated by equation (2):
wherein C is w Is the water compression coefficient of the stratum.
Preferably, the method further comprises: and when the formation water experimental test data are absent, calculating the formation water mineralization degree through logging data.
Preferably, calculating the formation water mineralization by logging data comprises: determining the porosity and the resistivity of a target interval according to the logging information; calculating the formation water resistivity under the underground condition according to the porosity and the resistivity of the target interval; calculating the resistivity under the ground condition according to the formation temperature and the formation water resistivity under the formation condition; and calculating the mineralization degree of the stratum water according to the resistivity under the ground condition.
Preferably, the formation water resistivity under the subsurface conditions is calculated by equation (3):
R w ＝R t φ m (3)
wherein R is w For the formation water resistivity under subsurface conditions, phi is the porosity of the interval of interest, R t The resistivity of the target interval is represented by m, which is the stratum cementation index; calculating the resistivity under the surface condition by the formula (4):
wherein R is wn For the resistivity at surface conditions, x is the temperature of the desired interval.
Preferably, the formation water mineralization is calculated by equation (5):
wherein R is wn Is of resistivity, P wn Mineralization degree.
According to another aspect of the present invention, there is provided a method of determining the compressibility of natural gas comprising: calculating the natural gas bulk modulus according to the burial depth; and calculating the natural gas volume compression coefficient according to the natural gas volume modulus.
Preferably, the natural gas bulk modulus is calculated by equation (6):
K g ＝6×10 -7 DEP 1.4192 (6)
wherein K is g DEP is the burial depth, which is the natural gas bulk modulus.
Preferably, the natural gas volumetric compression coefficient is calculated by equation (7):
wherein C is g Is the natural gas compression coefficient.
The method and apparatus of the present invention have other features and advantages which will be apparent from or are set forth in detail in the accompanying drawings and the following detailed description, which are incorporated herein, and which together serve to explain certain principles of the present invention.
Drawings
The foregoing and other objects, features and advantages of the invention will be apparent from the following more particular descriptions of exemplary embodiments of the invention as illustrated in the accompanying drawings wherein like reference numbers generally represent like parts throughout the exemplary embodiments of the invention.
Fig. 1 shows a flow chart of the steps of a method of determining a formation water volumetric compression factor according to the present invention.
FIG. 2 illustrates an intersection of formation water bulk modulus and formation water mineralization according to one embodiment of the invention.
FIG. 3 shows a plot of natural gas bulk modulus versus burial depth in accordance with one embodiment of the invention.
Detailed Description
The invention will be described in more detail below with reference to the accompanying drawings. While the preferred embodiments of the present invention are illustrated in the drawings, it should be understood that the present invention 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 invention to those skilled in the art.
Fig. 1 shows a flow chart of the steps of a method of determining a formation water volumetric compression factor according to the present invention.
In this embodiment, a method of determining a formation water volumetric compression factor according to the present invention may include: step 101, obtaining the mineralization degree of the formation water according to the experimental test data of the formation water; and 102, calculating the water volume modulus of the stratum according to the mineralization degree of the stratum water, and further calculating the volume compression coefficient of the stratum water.
In one example, the formation water bulk modulus is calculated by equation (1):
K w ＝3.3×10 -6 P wn +1.7254 (1)
wherein K is w For the formation water volume modulus, P wn Is the mineralization degree of stratum water.
In one example, the formation water volumetric compression factor is calculated by equation (2):
wherein C is w Is the water compression coefficient of the stratum.
In one example, further comprising: and when the formation water experimental test data are absent, calculating the formation water mineralization degree through the logging data.
In one example, calculating formation water mineralization from well logging data includes: determining the porosity and the resistivity of the target interval according to logging data; calculating the formation water resistivity under the underground condition according to the porosity and the resistivity of the target interval; calculating the resistivity under the ground condition according to the formation temperature and the formation water resistivity under the formation condition; and calculating the mineralization degree of the stratum water according to the resistivity under the ground condition.
In one example, formation water resistivity under subsurface conditions is calculated by equation (3):
R w ＝R t φ m (3)
wherein R is w For the formation water resistivity under subsurface conditions, phi is the porosity of the interval of interest, R t The resistivity of the target interval is represented by m, which is the stratum cementation index; calculating the resistivity under the surface condition by the formula (4):
wherein R is wn For the resistivity at surface conditions, x is the temperature of the desired interval.
In one example, formation water mineralization is calculated by equation (5):
wherein R is wn Is of resistivity, P wn Mineralization degree.
In particular, in the field of oil and gas exploration and development, it is often necessary to utilize seismic, well logging data for reservoir and fluid prediction, and petrophysical analysis (such as Gassman evaluation analysis, etc.) is the basis of this work. Determination of the bulk modulus and compressibility of the rock matrix, fluids in the pores (including formation water, oil and gas) is critical. These key parameters can be obtained from experimental measurements, but experimental samples are difficult and expensive to obtain, and are therefore often obtained through empirical estimation and literature in practical work. The rock skeleton and the oil bulk modulus parameters are easily obtained through literature, and the formation water and natural gas bulk modulus parameters are greatly influenced by formation conditions, and no literature data is obtained yet.
The method of determining bulk moduli of formation water and natural gas according to the present invention may include:
according to the formation water experimental test data, directly obtaining the mineralization degree of the formation water; when the formation water experimental test data are absent, the formation water mineralization degree is calculated through logging data: determining the porosity and the resistivity of the target interval according to logging data; according to the porosity and the resistivity of the target interval, calculating the formation water resistivity under the underground condition through a formula (3); calculating the resistivity under the ground condition according to the formation temperature and the formation water resistivity under the formation condition by a formula (4); and (5) calculating the mineralization degree of the stratum water according to the resistivity under the ground condition by using the formula (5).
FIG. 2 illustrates an intersection of formation water bulk modulus and formation water mineralization according to one embodiment of the invention.
The formation water bulk modulus is a complex function of temperature, pressure and mineralization, under formation conditions, both formation pressure and temperature increase with increasing depth, and their effects on the formation water bulk modulus cancel each other out, so that the formation water bulk modulus under formation conditions can be approximated as being primarily affected by mineralization. It is found that the formation water volume modulus and the mineralization degree form an approximately linear relationship as shown in fig. 2, and the formation water volume modulus is calculated according to the formation water mineralization degree by the formula (1), and then the formation water volume compression coefficient is calculated by the formula (2).
In this embodiment, the method of determining the volumetric compression coefficient of natural gas according to the present invention may comprise: step 201, calculating the natural gas bulk modulus according to the burial depth; and 202, calculating the natural gas volume compression coefficient according to the natural gas volume modulus.
In one example, the natural gas bulk modulus is calculated by equation (3):
K g ＝6×10 -7 DEP 1.4192 (3)
wherein K is g DEP is the burial depth, which is the natural gas bulk modulus.
In one example, the natural gas volumetric compression coefficient is calculated by equation (4):
wherein C is g Is the natural gas compression coefficient.
FIG. 3 shows a plot of natural gas bulk modulus versus burial depth in accordance with one embodiment of the invention.
In particular, natural gas bulk modulus influencing factors include fluid composition, temperature, formation pressure influence. It is found that the natural gas bulk modulus is mainly related to the burial depth under the stratum condition, and the intersection chart is shown in fig. 3, then the natural gas bulk modulus is calculated by a formula (6), and the natural gas bulk compression coefficient is calculated by a formula (7).
After the formation water volume compression coefficient and the natural gas volume compression coefficient are obtained through calculation according to the method, subsequent petrophysical analysis can be performed.
The method determines the formation water bulk modulus and the compression coefficient through the mineralization degree, and determines the natural gas bulk modulus and the compression coefficient calculation data through the burial depth, so that the method is convenient to obtain, has strong practicability, and provides a basis and a foundation for fluid prediction and quantitative evaluation based on acoustic logging and seismic data.
Application example
In order to facilitate understanding of the solution and the effects of the embodiments of the present invention, a specific application example is given below. It will be understood by those of ordinary skill in the art that the examples are for ease of understanding only and that any particular details thereof are not intended to limit the present invention in any way.
Calculating the mineralization degree of the stratum water by logging data: determining the porosity and resistivity of the interval of interest based on the logging data as shown in table 1; according to the porosity and the resistivity of the target interval, calculating the formation water resistivity under the underground condition through a formula (3); calculating the resistivity under the ground condition according to the formation temperature and the formation water resistivity under the formation condition by a formula (4); and (5) calculating the mineralization degree of the stratum water according to the resistivity under the ground condition by using the formula (5).
TABLE 1
According to the mineralization degree of the stratum water, calculating the water volume modulus of the stratum through a formula (1), and further calculating the volume compression coefficient of the stratum water through a formula (2). The natural gas bulk modulus is calculated by equation (6) and the natural gas bulk compression coefficient is calculated by equation (7). The calculation results are shown in Table 2.
TABLE 2
The parameters in table 2 are key parameters for petrophysical studies (based on gasman equation analysis, etc.). By petrophysical analysis, a foundation for predicting reservoir and fluid properties by utilizing seismic data and logging data is laid.
In conclusion, the formation water bulk modulus and the compression coefficient are determined through the mineralization degree, the natural gas bulk modulus and the compression coefficient calculation data are determined through the burial depth, the method is convenient to obtain, the practicability is high, and a foundation and a basis are provided for fluid prediction and quantitative evaluation based on acoustic logging and seismic data.
It will be appreciated by persons skilled in the art that the above description of embodiments of the invention has been given for the purpose of illustrating the benefits of embodiments of the invention only and is not intended to limit embodiments of the invention to any examples given.
The foregoing description of embodiments of the invention has been presented for purposes of illustration and description, and is not intended to be exhaustive or limited to the embodiments disclosed. Many modifications and variations will be apparent to those of ordinary skill in the art without departing from the scope and spirit of the various embodiments described.
Claims (4)
1. A method of determining a formation water volume compaction factor comprising:
according to the formation water experimental test data, obtaining the mineralization degree of the formation water;
calculating the water volume modulus of the stratum according to the mineralization degree of the stratum water, and further calculating the volume compression coefficient of the stratum water;
wherein the formation water volume modulus is calculated by formula (1):
K w ＝3.3×10 -6 P wn +1.7254(1)
wherein K is w For the formation water volume modulus, P wn Mineralizing the stratum water;
wherein the formation water volume compaction factor is calculated by equation (2):
wherein C is w Is the water compression coefficient of the stratum.
2. The method of determining a formation water volumetric compression factor of claim 1, further comprising:
and when the formation water experimental test data are absent, calculating the formation water mineralization degree through logging data.
3. The method of determining a formation water volume compressibility of claim 2, wherein calculating the formation water mineralization by logging data comprises:
determining the porosity and the resistivity of a target interval according to the logging information;
calculating the formation water resistivity under the underground condition according to the porosity and the resistivity of the target interval;
calculating the resistivity under the ground condition according to the stratum temperature and the stratum water resistivity under the underground condition;
calculating the mineralization degree of the stratum water according to the resistivity under the ground condition;
wherein the formation water resistivity under the subsurface conditions is calculated by equation (3):
R w ＝R t φ m (3)
wherein R is w For the formation water resistivity under subsurface conditions, phi is the porosity of the interval of interest, R t The resistivity of the target interval is represented by m, which is the stratum cementation index;
calculating the resistivity under the surface condition by the formula (4):
wherein R is wn The resistivity under the ground condition is given, and x is the temperature of the target interval;
wherein, calculate the formation water mineralization degree through formula (5):
wherein R is wn Is of resistivity, P wn Mineralization degree.
4. A method of determining a volumetric compression factor of natural gas comprising:
calculating the natural gas bulk modulus according to the burial depth;
calculating the natural gas volume compression coefficient according to the natural gas volume modulus;
wherein the natural gas bulk modulus is calculated by equation (6):
K g ＝6×10 -7 DEP 1.4192 (6)
wherein K is g Is the natural gas bulk modulus, DEP is the burial depth;
wherein the natural gas volumetric compression coefficient is calculated by equation (7):
wherein C is g Is the natural gas compression coefficient.
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