CN108304959A - The method for improving formation fluid pressure precision of prediction - Google Patents
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Abstract
The present invention provides a kind of method improving formation fluid pressure precision of prediction, including：Step 1, pass through hydrogeology and fluid geologic feature, analysis strata pressure geophysics, geology and the corresponding feature of geochemistry, and then clear typical pressure system features；Step 2, sand shale density, physical property, the fitting of these data points of sound wave and the correlation analysis obtained according to log data, seeks model key parameter；Step 3, prediction model is established using key parameter, strata pressure P is calculated；Step 4, according to Effective Stress Equation, porosity Fluid pressure is calculated.The method of the raising formation fluid pressure precision of prediction by ground press the stage of development and superpressure distribution research it will be seen that oil-gas bearing basin in hydrocarbon generation, migration, aggregation at dynamic (dynamical) stage and process, effectively determine overpressure system and the relationship with petroleum distribution.
Description
Technical field
The present invention relates to oil field development technical field, a kind of formation fluid pressure precision of prediction that improves is especially related to
Method.
Background technology
The Hinterland of The Junggar Basin strong overpressure system of the apparent deep layer of generally existing now, has more than 20 mouth wells in abdomen so far
Area, which is bored, meets apparent superpressure, and for pressure coefficient between 1.24~2.07, the superpressure layer position of announcement is mainly Jurassic system, is partly Cretaceous System
And the Triassic system, the depth of superpressure development can be from 3800m to 7000m.With going deep into for oil-gas exploration work, more and more evidences
Show that the formation, evolution and distribution of hydrocarbon migration and accumulation and superpressure are closely related, influence of the superpressure to Hydrocarbon Formation Reservoirs receives extensively
General concern.During Area of Junggar Basin abdomen superpressure and petroleum distribution relationship, superpressure adjacent top surface is surrounded, is found
A series of noticeable geological phenomenons：1. when the distribution relation of the superpressure top surface and oil-gas Layer disclosed according to more than 20 mouth drilling wells
It was found that Hinterland Area majority oil-gas reservoir integrated distribution is in superpressure adjacent top surface；2. basin modelling and fluid inclusion pressure simulation
Data all shows that formation and the release of hydrocarbon charge and superpressure have very close relationship.Specify Structural unit abnormal pressure point
Cloth feature and abnormal pressure develop, and improve Structural unit Regularity of Hydrocarbon Accumulation understanding, and it is to grind to provide foundation for oil-gas exploration deployment
The purpose studied carefully needs the evolution research for carrying out overpressure mechanism, superpressure energy field.
Current Predicting Technique, depth method whens equal based on sound wave, the pressure for caused by abnormal compaction have preferable knowledge
Other effect, but the overlapping development of western part of China basin stratum, it is old that target zone buries deep stratum, and it is frequently mutual that rock is densified serious sand mud
Layer, can not be effectively predicted this type formation fluid pressure.Existing prediction technique includes：
(1) normal compaction tendency method has equivalent depth method, normal compaction tendency method under this method principle.
Equivalent depth method：
Rock averag density * g* depth-(rock averag density-equivalent depth under equivalent depth under pressure=depth
Under average fluid density) * g* depth
Normal compaction tendency method (depth at setting h1 and h2 two)：
Pressure=hydrostatic pressure+﹛ [(rock averag density-water flooding averag density) * g* depth differences]/[(h2's log logs well
Value/h1 log values) low temperature gradients * differences in height on+0.435* logs between the temperature coefficient * both heights of any point] ﹜ * log
(specific geophysical parameters/estimation of the estimation with normal compaction trend area is regional specifically with abnormal pore pressure
Ball physical parameter)
Think after analysis, which is directed to thick-layer pure shale section, and the differential compaction under needing normal compaction curve to correct is different
Normal pressure power, and it is suitable only for Meso-Cenozoic basin.
(2) direct pressure estimation algorithm has Fillippone methods and Holbrock methods under this method principle.
Fillippone methods：
Pressure=0.18677*e0.00047* instantaneous velocitys* [lithostatic pressure * (basement rock speed-instantaneous velocity)/(basement rock speed-rigidity
Speed when being zero)]
Holbrock methods：
The maximum effective stress * (1- porositys) of pressure=be compacted to Within Monominerals rock when porosity is zeroRock strain coefficient
(3) seismic velocity inversion method has AVO prediction superpressures and Impedance Inversion prediction superpressure under this method principle.
AVO：
Velocity of longitudinal wave variable quantity/velocity of longitudinal wave=(effective pressure when pressure/starting)1/6-1
Impedance Inversion：
Wave impedance=coefficient A* interval velocities1+ coefficient Bs
Think after analysis, direct pressure estimation algorithm and seismic velocity inversion method are required to earthquake constant speed degrees of data, pressure
Precision of prediction is inadequate, has area's adaptability strongly.We have invented a kind of new raising formation fluid pressures to predict essence thus
The method of degree solves the above technical problem.
Invention content
Considering a variety of geologic(al) factors the object of the present invention is to provide a kind of, disclosure satisfy that the accurate of strata pressure precision evaluation
It is required that the raising formation fluid pressure precision of prediction in petroleum resources geological prospecting and development evaluation field can be widely used in
Method.
The purpose of the present invention can be achieved by the following technical measures：The method for improving formation fluid pressure precision of prediction,
The method of the raising formation fluid pressure precision of prediction includes：Step 1, by hydrogeology and fluid geologic feature, analytically
Stressor layer geophysics, geology and the corresponding feature of geochemistry, and then clear typical pressure system features；Step 2, according to well logging
Sand shale density, physical property, the fitting of these data points of sound wave and the correlation analysis that data obtain, seek model key parameter；Step
Rapid 3, prediction model is established using key parameter, strata pressure P is calculated；Step 4, according to Effective Stress Equation, hole is calculated
Gap Fluid pressure.
The purpose of the present invention can be also achieved by the following technical measures：
In step 1, comprehensive analysis is carried out to research area's hydrology and fluid geologic feature, determines the basic class of pressure system
Type marks off overpressure system, has characteristic response：Mud stone is earlier than sandstone superpressure, and, silt particle big with depth segment superpressure amplitude
It is consistent to respond form.
In step 2, the model key parameter sought includes lithology, depth h, formation porosity φ, earth's surface porosity
φ0, porosity correction empirical constants K, stratum interval transit time △ t, rock matrix interval transit time △ tm, pore-fluid interval transit time
△ tf, interval transit time empirical calibration factor CP, effective stress б, effective stress factor alpha.
In step 2, lithology and depth h, lithology dimensionless, the unit m of depth h are directly read.
In step 2, formation porosity φ, unit μ s/m are obtained according to well logging porosity；Earth's surface hole is obtained according to actual measurement
Porosity φ0, unit μ s/m；
In step 2, porosity correction empirical constants K is obtained according to well logging porosity and actual measurement correction；According to well logging number
According to the stratum interval transit time △ t for obtaining being full of fluid, unit μ s/m.
In step 2, rock matrix interval transit time △ tm and pore-fluid interval transit time △ tf are obtained according to core test,
Unit is μ s/m.
In step 2, it is corrected to obtain interval transit time empirical calibration factor C according to log data and core testP。
In step 2, when calculating effective stress б, amendment and improved Athy models, porosity and effective stress are utilized
There are following relationships：
ψ (h)=ψ 0*e-k* б (3)
Wherein, ψ 0 is earth's surface porosity；б is effective stress；K is regional experience constant, according to well logging porosity and actual measurement
Correction obtains；
The formula can be rewritten as effective stress expression formula：
б=(1/k) * [㏑ ψ 0- ㏑ ψ (h)] (4)
Formation porosity calculation formula is obtained using time-average equation：
ψ=(1/Cp) * (Δ t- Δ tm)/(Δ tf- Δ tm) (5)
Wherein, ψ is formation porosity, and Δ t, Δ tf, Δ tm are respectively stratum, gap fluid and the rock bone for being full of fluid
The interval transit time of frame, unit μ s/m；In view of rock is cementing or compaction, need that empirical school is added to time-average equation
Positive divisor Cp corrects to obtain according to log data and core test；
It can be obtained according to the calculating of the principle of effective stress：
б=(1/k) * ﹛ ㏑ [﹙ Δ tf- Δ tm ﹚/(Δ t- Δ tm)+﹙ ㏑ ψ 0+ ㏑ Cp ﹚] ﹜
(6)。
In step 3, strata pressure P is expressed as integral of the density function to depth, and calculation formula is：
P=∫0 h(ρ gdh)=∫0 h(2.10*е0.00003h)gdh (2)
Wherein, h is buried depth of strata, m；G is acceleration of gravity, n/kg；ρ is density of earth formations, and the fitting with depth of stratum is closed
System is ρ=2.10*e0.00003h。
In step 4, according to Effective Stress Equation, when rock is in force balance state, porosity fluid pressure meter
It is shown as：
Pf=P- б (1)
Wherein, P is side pressure point overlying formation pressure, and б is effective stress, PfFor pore fluid pressure, the above unit is
MPa。
In step 4, according to stratum lithology prediction strata pressure, then according to effective stress, formula (1) is brought into, then
Obtain formation fluid pressure：
Sandstone is weak compression skeleton, P=б+Pf(α=1) (7)
Mud stone is to suppress contracting skeleton, P=α б+Pf(α<1) (8)
Wherein, α is effective stress coefficient, and according to principle of effective stress, sand shale differential response obtains, α=1-0.02*
Vsh, wherein VshFor shale content.
The method of raising formation fluid pressure precision of prediction in the present invention, it is special by hydrogeology and fluid geology first
Sign, analysis strata pressure geophysics, geology and the corresponding feature of geochemistry, and then clear typical pressure system features；Meanwhile
Pressure prediction method network analysis, clears method applicability, introduces the pressure prediction method of effective stress.This method passes through ground pressure
Educate the stage and superpressure distribution research it will be seen that oil-gas bearing basin in hydrocarbon generation, migration, aggregation at dynamic (dynamical) stage
And process, effectively determine overpressure system and the relationship with petroleum distribution.
Description of the drawings
Fig. 1 is the flow chart of a specific embodiment of the method for the raising formation fluid pressure precision of prediction of the present invention；
The schematic diagram that Fig. 2 chooses for each well key parameter in research area in the specific embodiment of the present invention；
Fig. 3 be the present invention a specific embodiment in actual measurement cross figure with effective stress is calculated；
Fig. 4 be the present invention a specific embodiment in actual measurement cross figure with strata pressure is calculated.
Specific implementation mode
For enable the present invention above and other objects, features and advantages be clearer and more comprehensible, it is cited below particularly go out preferable implementation
Example, and coordinate shown in attached drawing, it is described in detail below.
As shown in FIG. 1, FIG. 1 is the flow charts of the method for the raising formation fluid pressure precision of prediction of the present invention.Including such as
Lower step：
In step 101, pass through hydrogeology and fluid geologic feature, analysis strata pressure geophysics, geology and the earth
Chemical individual features, and then clear typical pressure system features.Comprehensive analysis is carried out to research area's hydrology and fluid geologic feature,
Determine that the fundamental type of pressure system, relatively pervious single pressure system divide, mark off overpressure system, have characteristic
Response：Mud stone is and big with depth segment superpressure amplitude earlier than sandstone superpressure, and it is consistent that silt particle responds form.Flow enters step
102。
In step 102, the fitting of the data points such as sand shale density, physical property, the sound wave obtained according to log data and correlation
Analysis, seeks 13 key parameters of model (lithology, depth h, pore fluid pressure Pf, porosity φ, earth's surface porosity φ0, hole
Porosity correction empirical constants K (ooze according to hole and obtained with sound wave), interval transit time △ t, rock matrix interval transit time △ tm, fluid sound
Wave time difference △ tf, interval transit time empirical calibration factor CP, effective stress б, effective stress factor alpha, as shown in Figure 2).
In step 21, lithology can be directly read, dimensionless；
In step 22, depth h can be directly read, unit m；
In step 23, formation porosity φ can be obtained according to well logging porosity, unit μ s/m；
In step 24, earth's surface porosity φ0It can be obtained according to actual measurement, unit μ s/m；
In step 25, porosity correction empirical constants K can be according to well logging porosity (value that log is read) and reality
(theoretical value that experiment obtains) correction is surveyed to obtain,；
In step 26, the stratum interval transit time △ t for being full of fluid can be obtained according to log data, unit μ s/m；
In step 27, rock matrix interval transit time △ tm can be obtained according to core test, unit μ s/m；
In step 28, pore-fluid interval transit time △ tf can be obtained according to core test, unit μ s/m；
In step 29, interval transit time empirical calibration factor CPIt can be according to log data (value that log is read) and rock
Heart test (theoretical value that experiment obtains) correction obtains；
In step 210, seeking for б (effective stress) is the key that establish standing balance formation pressure calculation model, is needed
Find the computation model between effective stress and geophysical parameters.Using correct and improved Athy models (Smith,
1971), there are following relationships for porosity and effective stress：
ψ (h)=ψ 0*e-k* б (3)
Note：ψ 0 is earth's surface porosity；б is effective stress；K is regional experience constant, according to well logging porosity (log
The value of reading) it is obtained with actual measurement (theoretical value that experiment obtains) correction.
The formula can be rewritten as effective stress expression formula：
б=(1/k) * [㏑ ψ 0- ㏑ ψ (h)] (4)
Formation porosity calculation formula is obtained using time-average equation：
ψ=(1/Cp) * (Δ t- Δ tm)/(Δ tf- Δ tm) (5)
Note：ψ is formation porosity, and Δ t, Δ tf, Δ tm are respectively stratum, gap fluid and the rock matrix for being full of fluid
Interval transit time, unit μ s/m.In actual application, it is contemplated that rock is cementing or compaction, needs average to the time
Empirical correction factor CP is added in equation, and according to log data (value that log is read) and core test, (experiment obtains
Theoretical value) correction obtain.
It can be obtained according to the calculating of the principle of effective stress：
б=(1/k) * ﹛ ㏑ [﹙ Δ tf- Δ tm ﹚/(Δ t- Δ tm)+﹙ ㏑ ψ 0+ ㏑ Cp ﹚] ﹜ (6)
Effective stress б and porosity φ has relational expression (4), (5) to obtain；Flow enters step 103.
In step 103, prediction model is established using key parameter, strata pressure P is calculated.
P (stratum overlying load) can be expressed as integral of the density function to depth, can be expressed as in western basin：
P=∫0 h(ρ gdh)=∫0 h(2.10*е0.00003h)gdh (2)
(note：H is buried depth of strata, m；G is acceleration of gravity, n/kg；ρ is density of earth formations, the fit correlation with depth of stratum
For ρ=2.10*e0.00003h。)
In step 104, according to Effective Stress Equation (principle), when rock is in force balance state, porosity fluid
Pressure can be expressed as：
Pf=P- б (1)
(note：P is side pressure point overlying formation pressure, and б is effective stress, PfFor pore fluid pressure, the above unit is
MPa。)
According to formation lithology (weak, suppress contracting skeleton) prediction strata pressure formula is brought into then with the effective stress acquired
(1), formation fluid pressure is then obtained：
Sandstone is weak compression skeleton, P=б+Pf(α=1) (7)
Mud stone is to suppress contracting skeleton, P=α б+Pf(α<1) (8)
Wherein, α is effective stress coefficient, and according to principle of effective stress, sand shale differential response obtains, α=1-0.02*
Vsh, wherein VshFor shale content.
Effective stress calculates prognosis modelling value and carries out the comparison (Fig. 3,4) that crosses with measured value, it can be seen that has preferable
Regularity, the pressure prediction model precision based on effective stress is high, and error rate controls within 12%.
Claims (12)
1. the method for improving formation fluid pressure precision of prediction, which is characterized in that the raising formation fluid pressure precision of prediction
Method includes：
Step 1, by hydrogeology and fluid geologic feature, analysis strata pressure geophysics, geology and geochemistry are corresponding
Feature, and then clear typical pressure system features；
Step 2, sand shale density, physical property, the fitting of these data points of sound wave and the correlation analysis obtained according to log data, is asked
Modulus type key parameter；
Step 3, prediction model is established using key parameter, strata pressure P is calculated；
Step 4, according to Effective Stress Equation, porosity Fluid pressure is calculated.
2. the method according to claim 1 for improving formation fluid pressure precision of prediction, which is characterized in that in step 1,
Comprehensive analysis is carried out to research area's hydrology and fluid geologic feature, the fundamental type of pressure system is determined, marks off overpressure system,
With characteristic response：Mud stone is and big with depth segment superpressure amplitude earlier than sandstone superpressure, and it is consistent that silt particle responds form.
3. the method according to claim 1 for improving formation fluid pressure precision of prediction, which is characterized in that in step 2,
The model key parameter sought includes lithology, depth h, formation porosity φ, earth's surface porosity φ0, porosity correction experience it is normal
Number K, stratum interval transit time △ t, rock matrix interval transit time △ tm, pore-fluid interval transit time △ tf, interval transit time experience school
Positive divisor CP, effective stressб, effective stress factor alpha.
4. the method according to claim 3 for improving formation fluid pressure precision of prediction, which is characterized in that in step 2,
Directly read lithology and depth h, lithology dimensionless, the unit m of depth h.
5. the method according to claim 3 for improving formation fluid pressure precision of prediction, which is characterized in that in step 2,
Formation porosity φ, unit μ s/m are obtained according to well logging porosity；Earth's surface porosity φ is obtained according to actual measurement0, unit μ s/m.
6. the method according to claim 3 for improving formation fluid pressure precision of prediction, which is characterized in that in step 2,
Porosity correction empirical constants K is obtained according to well logging porosity and actual measurement correction；The ground for obtaining being full of fluid according to log data
Layer interval transit time △ t, unit μ s/m.
7. the method according to claim 3 for improving formation fluid pressure precision of prediction, which is characterized in that in step 2,
Rock matrix interval transit time △ tm and pore-fluid interval transit time △ tf are obtained according to core test, unit is μ s/m.
8. the method according to claim 3 for improving formation fluid pressure precision of prediction, which is characterized in that in step 2,
It is corrected to obtain interval transit time empirical calibration factor C according to log data and core testP。
9. the method according to claim 3 for improving formation fluid pressure precision of prediction, which is characterized in that in step 2,
When calculating effective stress б, using amendment and improved Athy models, there are following relationships for porosity and effective stress：
ψ（h）=ψ0*e-k*б （3）
Wherein, ψ 0 is earth's surface porosity；б is effective stress；K is regional experience constant, is corrected according to well logging porosity and actual measurement
It obtains；
The formula can be rewritten as effective stress expression formula：
б=（1/k）* [㏑ψ0-㏑ψ（h）] （4）
Formation porosity calculation formula is obtained using time-average equation：
ψ=（1/Cp）*（Δt-Δtm）/（Δtf-Δtm）（5）
Wherein, ψ is formation porosity, and Δ t, Δ tf, Δ tm are respectively the stratum for being full of fluid, gap fluid and rock matrix
Interval transit time, unit μ s/m；In view of rock is cementing or compaction, need to time-average equation be added empirical correction because
Sub- Cp corrects to obtain according to log data and core test；
It can be obtained according to the calculating of the principle of effective stress：
б=（1/k）* ﹛ ㏑ [﹙ Δs tf- Δ tm ﹚/（Δt-Δtm）+ ﹙ ㏑ ψ 0+ ㏑ Cp ﹚] ﹜（6）.
10. the method according to claim 1 for improving formation fluid pressure precision of prediction, which is characterized in that in step 3
In, side pressure point overlying formation pressure P is expressed as integral of the density function to depth, and calculation formula is：
P=∫0 h（ρgdh）=∫0 h（2.10*е0.00003h）gdh（2）
Wherein, h is buried depth of strata, m；G is acceleration of gravity, n/kg；ρ is density of earth formations, and the fit correlation with depth of stratum is ρ
=2.10*е0.00003h。
11. the method according to claim 1 for improving formation fluid pressure precision of prediction, which is characterized in that in step 4
In, according to Effective Stress Equation, when rock is in force balance state, porosity Fluid pressure is expressed as：
Pf =P-б（1）
Wherein, P is side pressure point overlying formation pressure,бFor effective stress, PfFor pore fluid pressure, the above unit is MPa.
12. the method according to claim 11 for improving formation fluid pressure precision of prediction, which is characterized in that in step 4
In, according to stratum lithology prediction strata pressure, then according to effective stress, brings porosity Fluid pressure into and calculate formula, then
Obtain formation fluid pressure：
Sandstone is weak compression skeleton, P=б+Pf （α=1）（7）
Mud stone is to suppress contracting skeleton, P=α б+Pf（α<1 ）（8）
Wherein, α is that effective stress coefficient is obtained, α=1-0.02*V according to principle of effective stress by sand shale differential responsesh,
In, VshFor shale content.
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| Publication number | Priority date | Publication date | Assignee | Title |
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| CN109283597A (en) * | 2018-11-15 | 2019-01-29 | 中国地质大学（武汉） | A kind of carbonate formation overpressure prediction method |
| CN109447365A (en) * | 2018-11-09 | 2019-03-08 | 昆明理工大学 | A kind of prediction technique for the Seed harvest ultrasonic velocity that the loose crushed stone soil layer of floral tube grouting and reinforcing is formed |
| CN113550740A (en) * | 2020-04-24 | 2021-10-26 | 中国石油化工股份有限公司 | Method for realizing continuous calculation of longitudinal pressure gradient of single well |
| CN113687412A (en) * | 2020-05-18 | 2021-11-23 | 中国石油化工股份有限公司 | Method and device for predicting pressure of stratum between salts, electronic equipment and medium |
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| CN113687412B (en) * | 2020-05-18 | 2024-03-26 | 中国石油化工股份有限公司 | Method and device for predicting formation pressure between salts, electronic equipment and medium |
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