CN114893166A - Formation pressure coefficient calculation method - Google Patents
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- 230000015572 biosynthetic process Effects 0.000 title claims abstract description 60
- 238000004364 calculation method Methods 0.000 title claims description 15
- 238000000034 method Methods 0.000 claims abstract description 30
- 238000005553 drilling Methods 0.000 claims abstract description 18
- 230000002706 hydrostatic effect Effects 0.000 claims abstract description 6
- 238000005056 compaction Methods 0.000 claims description 19
- 239000012530 fluid Substances 0.000 claims description 12
- 230000002159 abnormal effect Effects 0.000 claims description 7
- 239000011148 porous material Substances 0.000 claims description 5
- 238000004458 analytical method Methods 0.000 claims description 4
- 239000011435 rock Substances 0.000 claims description 4
- 239000002002 slurry Substances 0.000 claims description 4
- 239000004215 Carbon black (E152) Substances 0.000 claims description 3
- 238000005516 engineering process Methods 0.000 claims description 3
- 229930195733 hydrocarbon Natural products 0.000 claims description 3
- 150000002430 hydrocarbons Chemical class 0.000 claims description 3
- 238000005259 measurement Methods 0.000 claims description 3
- 238000012545 processing Methods 0.000 claims description 3
- 238000011156 evaluation Methods 0.000 abstract description 3
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 4
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- 238000011161 development Methods 0.000 description 2
- 239000003345 natural gas Substances 0.000 description 2
- 239000003209 petroleum derivative Substances 0.000 description 2
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- E—FIXED CONSTRUCTIONS
- 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
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- E—FIXED CONSTRUCTIONS
- 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
- 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
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Abstract
The invention discloses a method for calculating a formation pressure coefficient, which combines logging information with logging information, obtains a normal mudstone sound wave time difference trend line by using the actual drilling mud density, calculates the mud density by using a difference value after establishing a statistical relation between the difference value of an actually measured sound wave time difference value and a normal value on the mudstone sound wave time difference trend line and the mud density, and realizes the accurate evaluation of the formation pressure coefficient by using the ratio of the formation pressure and the hydrostatic column pressure.
Description
Technical Field
The invention belongs to the technical field of petroleum and natural gas exploration and development, relates to a stratum pressure coefficient calculation method, and particularly relates to a stratum pressure coefficient calculation method based on a statistical relationship between drilling mud density and mudstone sound wave time difference.
Background
The formation pressure coefficient is a very important parameter in the exploration and development of petroleum and natural gas, and has important guiding significance for the determination of a drilling process technology and a hydrocarbon reservoir protection technology.
At present, the eaton method is a common method in the calculation of the formation pressure coefficient, and mainly applies the acoustic time difference to identify abnormal high pressure or abnormal low pressure and estimate the formation pressure, and the essence is that the method is based on the normal compaction trend line of the mudstone acoustic time difference along with the change of the depth, and the abnormal high pressure or low pressure is assumed to deviate from the trend line, but a method how to determine the acoustic time difference of the normal compaction is not provided. That is to say: the eaton method assumes that the part above abnormally high or low pressure is normally compacted and the formation pressure coefficient is 1, which is inaccurate in practice. In addition, in many cases, no pressure related data is available to help obtain data points of mudstone acoustic moveout under normal pressure conditions to map a normal mudstone compaction trend line. Also, there are times when the magnitude of the anomalous pressure is so small (e.g., the formation pressure coefficient is between 0.8 and 1.2) that it is difficult to accurately identify using conventional methods.
On the basis of respectively establishing resistivity and normal compaction trend lines of acoustic time difference, SunChao et al utilize density logging curve data to calculate overburden pressure, and then utilize the Eton method and the Morkelen failure criterion to predict formation pressure and calculate minimum formation principal stress, but the method does not consider the difference of mudstone lithology, so that a proper compaction trend line cannot be established, and a prediction result has certain errors. Han's et al, based on the definition of young's modulus, combined with wave equations, have developed the relationship between formation pressure, compressional and shear velocities and density, which does not require the establishment of normal compaction trend lines, but it is difficult to determine the amount of compression per unit thickness.
Therefore, it is difficult to accurately predict the formation pressure coefficient of the target well region by using the conventional formation pressure coefficient calculation method, and a method capable of accurately calculating the formation pressure coefficient needs to be constructed.
Disclosure of Invention
In order to solve the defects of the prior art, the invention provides a method for calculating the formation pressure coefficient, which combines logging data with logging data, obtains a normal mudstone sound wave time difference trend line according to the actual drilling mud density, calculates the mud density according to the difference after establishing the statistical relationship between the difference of the measured sound wave time difference value and the normal value on the mudstone sound wave time difference trend line and the mud density, and realizes the accurate evaluation of the formation pressure coefficient by utilizing the ratio of the formation pressure to the hydrostatic column pressure.
In order to achieve the purpose, the invention adopts the following technical scheme:
a formation pressure coefficient calculation method comprises the following steps:
step 2, fitting the relation between the acoustic time difference and the depth under the normal compaction condition according to the using condition of the mud drilling fluid in the logging information to obtain a normal compaction trend line;
step 3, calculating the sound wave time difference value of the pure mudstone without diameter expansion in the whole well section under the normal pressure condition according to the normal compaction trend line obtained in the step 2, and taking the sound wave time difference value as a reference value ACnor;
step 4, calculating the difference value delta AC between the acoustic wave time difference value of the pure mudstone section without diameter expansion under the normal pressure condition and the acoustic wave time difference value of the actually measured pure mudstone section with the corresponding depth;
step 5, establishing a cross plot by using the difference value delta AC obtained in the step 4 and the discrete mud density of the well section without abnormal occurrence to obtain a statistical formula of the mud density;
and 7, processing the actual logging by using the formulas established in the steps 5 and 6 to obtain the formation pressure coefficient of the section of the actual logging without hole enlargement.
Preferably, the specific method of the logging identification standard and the identification result in step 1 is as follows: calibrating pure mudstone and sandy mudstone based on results of rock debris logging and core description, extracting characteristic values, establishing an intersection graph by using the characteristic values of the pure mudstone and the sandy mudstone, and establishing a lithologic trend line at the junction of the pure mudstone and the sandy mudstone to serve as a division standard of the pure mudstone and the sandy mudstone.
Further preferably, the logging identification standard of the pure mudstone is as follows: lgRT < e AC-f; the identification standard of the sandy mudstone is as follows: lgRT is more than or equal to e × AC-f, wherein e is the slope of the lithologic trend line, and f is the intercept of the lithologic trend line.
Preferably, the specific method of fitting in step 2 is: and taking the acoustic time difference and depth longitudinal fitting of the pure mudstone without diameter expansion.
Further preferably, the mud density of the pure mudstone without diameter expansion is 0.96-1.04g/cm 3 。
Preferably, the formula of the normal compaction trend line in step 2 is:
AC＝a*DEPTH+c；
in the formula, AC is the sound wave time difference value us/ft; DEPTH is DEPTH, km; a. c is the coefficient of data fit.
Preferably, the formula of the difference Δ AC in step 4 is:
Δ AC ═ AC measured-ACnor;
wherein, the actual measurement of the delta AC and the ACnor are the sound wave time difference value us/ft.
Preferably, the statistical formula in step 5 is:
ρ＝m*△AC+n；
wherein rho is the slurry density, g/cm 3 (ii) a And m and n are coefficients for data fitting.
Preferably, the formula of the formation pressure coefficient in step 6 is:
P＝ρ/1；
wherein P is a formation pressure coefficient and is a dimensionless number.
The invention also provides the application of the formation pressure coefficient technical method in well drilling and/or hydrocarbon reservoir protection.
The invention has the beneficial effects that:
according to the invention, by considering the influences of factors such as borehole diameter abnormity, lithology complexity and the like, a formation pressure coefficient calculation method based on the statistical relationship between the density of drilling mud and the mudstone time difference is constructed, so that the accurate prediction of the formation pressure coefficient is realized, the processes such as the structure of a drilling well body, the density of drilling fluid, well completion and the like can be reasonably determined on the basis before construction, and the method is an effective basis for drilling design and construction; and the method is favorable for guiding physical property evaluation of the reservoir, and lays a foundation for comprehensive interpretation of logging of the reservoir.
Drawings
FIG. 1 is a flow chart of the present invention.
FIG. 2 is a log graph of well A.
Detailed Description
In order to make the objects, technical solutions and advantages of the embodiments of the present invention clearer, the technical solutions of the present invention are further described in detail below with reference to the accompanying drawings and the specific embodiments.
As shown in fig. 1, the present invention provides a method for calculating a formation pressure coefficient, comprising the steps of:
Step 2, according to the using condition of the mud drilling fluid in the logging information, the density of the mud taken is approximately 1g/cm 3 Longitudinally fitting the acoustic time difference and the depth of the pure mudstone without diameter expansion to obtain the relation between the acoustic time difference and the depth under the normal compaction condition, namely a normal compaction trend line;
AC＝a*DEPTH+c；
in the formula, AC is the sound wave time difference value us/ft; DEPTH is DEPTH, km; a. c is the coefficient of data fitting;
when logging, the hole enlargement caused by well wall collapse has certain influence on the amplitude of the logging curve, so that the numerical value of the acoustic wave time difference curve shows irregular change, a jumping curve is formed, and the real condition of the stratum cannot be reflected. Therefore, the influence of the amplitude of the diameter expansion section is removed in order to ensure the accuracy of the calculation method;
step 3, calculating the acoustic wave time difference value of the normal pressure of the pure mudstone without diameter expansion in the whole well section as a reference value ACnor based on the result of the normal compaction trend line;
step 4, calculating the difference value of the acoustic wave time difference value of the pure mudstone section without diameter expansion under the normal pressure condition and the acoustic wave time difference value of the actually measured pure mudstone section with the corresponding depth;
Δ AC ═ AC measured-ACnor;
in the formula, the actual measurement of delta AC and the ACnor are the sound wave time difference value us/ft;
step 5, establishing a cross plot by using the difference value delta AC and the discrete mud density of the well section without the abnormal condition to obtain a statistical formula of the mud density;
ρ＝m*△AC+n；
wherein rho is the slurry density, g/cm 3 (ii) a m and n are coefficients of data fitting;
P＝ρ/1；
in the formula, P is a formation pressure coefficient and is a dimensionless number;
the formation pressure can be balanced while drilling by adjusting the mud density to prevent and handle blowout and other accidents, so that the mud density is approximately equal to the formation pore fluid density.
And 7, processing the actual logging by using the formulas established in the steps 5 and 6 to obtain the formation pressure coefficient of the section of the actual logging without hole enlargement.
In order to further verify the technical effects of the present invention, the technical features and characteristics of the present invention are described in detail by specific examples, which are not intended to limit the scope of the present invention.
Example 1:
taking a well A of a certain oil field as an example, the method provided by the invention is adopted to calculate the formation pressure coefficient, and the specific method comprises the following steps:
s1, acquiring the existing logging data, logging data and core analysis data;
s2, calibrating pure mudstone and sandy mudstone based on results of rock debris logging and core description, extracting characteristic values, establishing an intersection graph and a lithology trend line by using RT and AC logging values, and further obtaining a logging identification standard of the pure mudstone and an identification standard of the sandy mudstone:
the identification standard of pure mudstone in the mudstone of the well A is as follows: lgRT <0.11 × AC-6.14;
a, identification standard of sandy mudstone in the well mudstone: lgRT is more than or equal to 0.11 × AC-6.14;
s3, taking the slurry with the density of 0.96-1.04g/cm 3 The sound wave time difference and the depth of the pure mudstone without diameter expansion are longitudinally fitted to obtain the relation between the sound wave time difference and the depth under the normal compaction condition:
the relation between the acoustic wave time difference and the depth under the normal compaction condition of the well A is as follows: AC-2.7 × DEPTH + 77.51;
s4, calculating a time difference value ACnor of pure mudstone under the normal pressure condition of the whole well section without diameter expansion;
s5, calculating the difference value of the acoustic wave time difference value of the pure mudstone section without diameter expansion under the normal pressure condition and the acoustic wave time difference value of the actually measured pure mudstone section with the corresponding depth: Δ AC ═ AC measured-ACnor;
s6, obtaining the discrete drilling fluid mud density of the well section without abnormal conditions;
s7, establishing a statistical relationship between the sound wave time difference and the mud density to obtain a calculation formula of the mud density:
a well mud density calculation formula: ρ 0.01 × Δ AC + 1.05;
s8, assigning the mud density to the formation pore fluid density, and calculating by using the ratio of the formation pressure to the hydrostatic column pressure to obtain a formation pressure coefficient: p ═ ρ/1;
s9, predicting the formation pressure coefficients of the target layers 1503m and 1546m by using the obtained calculation formula, comparing the formation pressure coefficients with discrete drilling fluid mud density, and verifying the accuracy of the calculation result of the formation pressure coefficient calculation method based on the statistical relationship between the drilling mud density and the mudstone time difference, wherein the result is shown in figure 2 and table 1.
TABLE 1
| Predicting a target formation | Measured discrete drilling fluid density | Predicted formation pressure coefficient |
| 1503m | 1.08g/cm 3 | 1.07 |
| 1546m | 1.08g/cm 3 | 1.08 |
It should be emphasized that the embodiments described herein are illustrative rather than restrictive, and thus the present invention is not limited to the embodiments described in the detailed description, but also includes other embodiments that can be derived from the technical solutions of the present invention by those skilled in the art.
Claims (10)
1. A formation pressure coefficient calculation method is characterized by comprising the following steps:
step 1, obtaining logging information, logging information and core analysis information to obtain a logging identification standard of pure mudstone and an identification standard of sandy mudstone;
step 2, fitting the relation between the acoustic time difference and the depth under the normal compaction condition according to the using condition of the mud drilling fluid in the logging information to obtain a normal compaction trend line;
step 3, calculating the acoustic wave time difference value of the normal pressure of the pure mudstone without diameter expansion in the whole well section according to the normal compaction trend line obtained in the step 2, and taking the acoustic wave time difference value as a reference value ACnor;
step 4, calculating the difference value delta AC between the acoustic wave time difference value of the pure mudstone section without diameter expansion under the normal pressure condition and the acoustic wave time difference value of the actually measured pure mudstone section with the corresponding depth;
step 5, establishing an intersection graph by using the difference value delta AC obtained in the step 4 and the discrete mud density of the well section without the abnormal condition to obtain a statistical formula of the mud density;
step 6, assigning the mud density obtained in the step 5 to the formation pore fluid density, and calculating a formation pressure coefficient by using the ratio of the formation pressure to the hydrostatic column pressure;
and 7, processing the actual logging by using the formulas established in the steps 5 and 6 to obtain the formation pressure coefficient of the section of the actual logging without hole enlargement.
2. The method for calculating the formation pressure coefficient according to claim 1, wherein the specific method of the logging identification standard of pure mudstone and the identification standard of sandy mudstone in the step 1 is as follows: calibrating pure mudstone and sandy mudstone based on results of rock debris logging and core description, extracting characteristic values, establishing an intersection graph by using the characteristic values of the pure mudstone and the sandy mudstone, and establishing a lithologic trend line at the junction of the pure mudstone and the sandy mudstone to serve as a division standard of the pure mudstone and the sandy mudstone.
3. The method of calculating a formation pressure coefficient of claim 2, wherein the log identification criteria for pure mudstone is: lgRT < e AC-f; the identification standard of the sandy mudstone is as follows: lgRT is more than or equal to e × AC-f; wherein e is the slope of the lithologic trend line, and f is the intercept of the lithologic trend line.
4. The method for calculating the formation pressure coefficient according to claim 1, wherein the fitting in the step 2 is performed by: and taking the acoustic time difference and depth longitudinal fitting of the pure mudstone without diameter expansion.
5. The method of claim 4, wherein the unamplified pure mudstone has a mud density of 0.96-1.04g/cm 3 。
6. A method of calculating a formation pressure coefficient as defined in claim 4, wherein the normal compaction trend line is formulated as:
AC＝a*DEPTH+c；
in the formula, AC is the sound wave time difference value us/ft; DEPTH is DEPTH, km; a. c is the coefficient of data fit.
7. The method of calculating a formation pressure coefficient of claim 1, wherein the formula of the difference Δ AC in step 4 is:
Δ AC ═ AC measured-ACnor;
wherein, the actual measurement of the delta AC and the ACnor are the sound wave time difference value us/ft.
8. The method of calculating a formation pressure coefficient of claim 7, wherein the statistical formula in step 5 is:
ρ＝m*△AC+n；
wherein rho is the slurry density in g/cm 3 (ii) a And m and n are coefficients for data fitting.
9. The method of claim 8, wherein the formation pressure coefficient is calculated in step 6 by the formula;
P＝ρ/1；
wherein P is a formation pressure coefficient and is a dimensionless number.
10. Use of the formation pressure coefficient technology method according to any one of claims 1-9 in drilling and/or hydrocarbon reservoir protection.
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