CN109458176A - The prediction technique and its application of carbonate reservoir pressure - Google Patents
The prediction technique and its application of carbonate reservoir pressure Download PDFInfo
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- 101150091879 neo gene Proteins 0.000 claims description 2
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 claims 1
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- DHNCFAWJNPJGHS-UHFFFAOYSA-J [C+4].[O-]C([O-])=O.[O-]C([O-])=O Chemical compound [C+4].[O-]C([O-])=O.[O-]C([O-])=O DHNCFAWJNPJGHS-UHFFFAOYSA-J 0.000 description 1
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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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- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06F—ELECTRIC DIGITAL DATA PROCESSING
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Abstract
The invention discloses a kind of prediction techniques of carbonate reservoir pressure comprising: effective stress computation model is established using neutron porosity, shale content, stratigraphic rock density；The effective stress on stratum is obtained according to effective stress computation model, and according to the first principles computations formation pore pressure of effective stress；Wherein, effective stress computation model are as follows:In formula, A0、A1、A2、A3、A4、A5And A6It is model coefficient, can be obtained by multiple regression analysis；VpFor formation rock velocity of longitudinal wave, unit km/s；ρ is stratigraphic rock density, unit g/cm3；VshFor shale content；CNL is neutron porosity；PeFor effective stress, unit MPa.Thus acoustic speed-the effective stress established is multifactor to seek model, higher to the prediction result precision of carbonate formation pressure, is also able to satisfy the exploration and development needs of carbonate reservoir.
Description
Technical field
The present invention relates to geological exploration fields, a kind of prediction technique in particular to carbonate reservoir pressure and
It is applied.
Background technique
Carbonate formation has since there are the corrosion holes of different scale, crack in structure with clastic rock
A great difference.Studies have shown that carbonate reservoir hole, hole, the formation of seam and distribution are mainly deposited, karstification, diagenesis are made
With and tectonic activity combined influence, can't be embodied in the longitudinal direction according to log response its porosity obvious regular
Variation, the complexity of carbonate rock itself in addition, the cementation and deposition of carbonate sediment be almost the same time into
It goes, fluid expansion mechanism caused by hydro carbon-generation, crude oil pyrolysis, hydro-thermal pressurization etc. brings primary with various diagenesis epigenesises
The destructive or constructive influence of hole, these can all destroy contacting between porosity and normal compaction, effective stress.Thus
For carbonate formation, the origin cause of formation and prediction methods of fracture research of superpressure cannot simply divert clastic rock series of strata, based on compacting
The conventional pressure prediction technique that mechanism causes porosity to change necessarily will cause biggish error.Just because of this, for carbonate
The a great problem of the origin mechanism of rock abnormal high pressure and its prediction or petroleum, geology field is still in spy both at home and abroad at present
The rope stage, so as to cause the accurate pressure prediction method lacked to carbonate reservoir.
Summary of the invention
One of the objects of the present invention is to provide the prediction techniques and its application of a kind of carbonate reservoir pressure, to carbon
Carbonate Reservoir pressure carries out Accurate Prediction.
The present invention solves its technical problem and adopts the following technical solutions to realize.
The present invention provides a kind of prediction techniques of carbonate reservoir pressure comprising:
Effective stress computation model is established using neutron porosity, shale content, stratigraphic rock density；
The effective stress on stratum is obtained according to effective stress computation model, and according to the first principles computations of effective stress
Layer pore pressure；
Wherein, the effective stress computation model is following equation:
In formula, A0、A1、A2、A3、A4、A5And A6It is model coefficient, is fitted to obtain by multiple regression；VpIt is vertical for formation rock
Wave velocity, km/s；ρ is stratigraphic rock density, g/cm3；VshFor shale content；CNL is neutron porosity；PeFor effective stress,
MPa。
The present invention also provides a kind of prediction techniques of above-mentioned carbonate reservoir pressure on fracture hole type Carbonate Reservoir
Application.
Comprehensively consider the influence of porosity, shale content, bulk density, effective stress to carbonate rock acoustic speed, by
Acoustic speed-effective stress of this foundation is multifactor to seek model, higher to the prediction result precision of carbonate formation pressure,
Also the exploration and development needs of carbonate reservoir are able to satisfy.And then Pore Pressure on Carbonate Rock Formation is predicted, effective stress
Method has more extensive application prospect.
Detailed description of the invention
It, below will be to use required in embodiment in order to illustrate more clearly of the technical solution of embodiment of the present invention
Attached drawing be briefly described, it should be understood that the following drawings illustrates only certain embodiments of the present invention, therefore is not to be seen as
It is the restriction to range, it for those of ordinary skill in the art, without creative efforts, can be with root
Other relevant attached drawings are obtained according to these attached drawings.
Fig. 1 is the degree of correlation of the effective stress computation model of the embodiment of the present invention 1.；
Fig. 2 is based on effective stress method No. 2 well prediction of formation pressure section of the embodiment of the present invention；
Fig. 3 is based on effective stress method No. 5 well prediction of formation pressure section of the embodiment of the present invention；
Fig. 4 is No. 1 well normal compaction trend line figure of the embodiment of the present invention；
Fig. 5 is based on equivalent depth method No. 1 well prediction of formation pressure section of the embodiment of the present invention；
Fig. 6 is No. 2 well normal compaction trend line figures of the embodiment of the present invention；
Fig. 7 is based on equivalent depth method No. 2 well prediction of formation pressure section of the embodiment of the present invention.
Specific embodiment
It, below will be to embodiment party of the present invention to keep the purposes, technical schemes and advantages of embodiment of the present invention clearer
Technical solution in formula is clearly and completely described.The person that is not specified actual conditions in embodiment or embodiment, according to routine
The condition that condition or manufacturer suggest carries out.Reagents or instruments used without specified manufacturer, being can be by commercially available purchase
Buy the conventional products of acquisition.
The prediction technique to the carbonate reservoir pressure of embodiment of the present invention being related to and its application have below
Body explanation.
Some embodiments of the present invention provide a kind of prediction technique of carbonate reservoir pressure comprising:
Effective stress computation model is established using neutron porosity, shale content, stratigraphic rock density；
The effective stress on stratum is obtained according to effective stress computation model, and according to the first principles computations of effective stress
Layer pore pressure；
Wherein, effective stress computation model is following equation:
In formula, A0、A1、A2、A3、A4、A5And A6It is model coefficient, is fitted to obtain by multiple regression；VpIt is vertical for formation rock
Wave velocity, km/s；ρ is stratigraphic rock density, g/cm3；VshFor shale content；CNL is neutron porosity；PeFor effective stress,
MPa。
Inventor the study found that carbonate formation due in structure there are the corrosion hole of different scale, crack, because
And there is a great difference with clastic rock.Studies have shown that carbonate reservoir hole, hole, the formation of seam and distribution are mainly deposited, rock
The combined influence of molten effect, diagenesis and tectonic activity, according to log response, its porosity can't embody in the longitudinal direction
Obvious regular variation, the in addition complexity of carbonate rock itself, the cementation and deposition of carbonate sediment
Almost the same time carries out, after fluid expansion mechanism caused by hydro carbon-generation, crude oil pyrolysis, hydro-thermal pressurization etc. and various diagenesis
Raw effect brings the destructive or constructive influence of primary pore, these can all destroy porosity and normal compaction, effective stress
Between connection.Thus for carbonate formation, the origin cause of formation and prediction methods of fracture research of superpressure cannot simply divert clast
Rock stratum system, the conventional pressure prediction technique for causing porosity to change based on compacting mechanism necessarily will cause biggish error.Into one
Step ground, inventor it has been investigated that, for carbonate formation, be mainly characterized in that porous media, complex pore structure and stitch
Hole development, the unstability and heterogeneity on stratum are extremely strong, and the presence of these factors largely all affects cement bond logging
The confidence level of well data, therefore the simple effective stress for relying on acoustic logging response to be established seeks model and is difficult to have persuasion
Power, even if effectively also seeming not reasonable.Inventor creatively proposes after numerous studies and practice for carbonate
Porosity, shale content, rock volume density, effective stress are included in model expression all, comprehensively considered by rock section stratum
Relationship between each log response and effective stress, the carbonate formation effective stress to construct suitable for different origins are sought
Model.For being actually embedded in the rock of underground, effective stress used in model is vertical effective stress now, to also keep away
The load of stratum primary deposit is exempted from and uplift erosion unloads this and is not easy determining problem.
In some embodiments, formation pore pressure is obtained by the basic principle of effective stress, based on the principle
Calculate equation are as follows: Pe=Po-αPp, in formula, P0For overlying formation pressure；PeFor effective stress；PpFor formation pore pressure；α is hole bullet
Property coefficient.
Further, in some embodiments, hole coefficient of elasticity is obtained by following steps:
The coefficient of bulk compressibility and the skeleton particle compressed coefficient for measuring rock respectively, the hole bullet of rock is calculated with following formula
Property coefficient:In formula, Cs is particles compress coefficient；Cb is volume compression system.Further, according to some implementations
Mode obtains Cb and Cs using three-axis tester RTR-1000 in two steps, first in the case where keeping pore pressure constant, increases
Add confining pressure, acquires Cb；Then confining pressure and pore pressure increase at a same speed simultaneously, acquire Cs.
According to some embodiments, for carbonate reservoir, can choose hole coefficient of elasticity is 0.2~0.9.
According to some embodiments, above-mentioned overlying formation pressure P0 is obtained using density log material computation, by with
Lower step obtains:
In formula, H0For starting point depth of logging well；ρ0It (h) is the density that section depth is h point of not logging well；ρ (h) is that depth is h point
Well logging density；G is acceleration of gravity.Further, shale content VshIt is obtained by following steps:
Shaliness index SH is calculated according to the variation of natural gamma relative amplitude first:
In formula, layer natural gamma value for the purpose of GR；GRmaxFor the natural gamma value of pure shale layer；GRminFor clean sandstone or pure
The natural gamma value of carbonate formation, the variation range of SH are 0~1；
Then, then with following formula by SH it is converted into shale content Vsh；
Wherein, G is empirical, takes 2 for old stratum, Paleogene and Neogene stratum takes 3.7, sound wave velocity of longitudinal wave Vsh
It converts to obtain by acoustic logging readings.
According to some embodiments, above-mentioned prediction technique further include: earth bore is drawn out according to the formation pore pressure
Gap barometric gradient section.It can reflect strata pressure situation comprehensively by formation pore pressure gradient profile.
According to some embodiments, above-mentioned prediction technique further include: the actual measurement well section of multiple regression analysis will be had neither part nor lot in
Measured result is compared and analyzed with the model calculation.And then further detect the accuracy of the pressure value predicted.
Feature and performance of the invention are described in further detail below in conjunction with specific embodiment.
Ordovician system buried hill reservoirs are the important kinds of Paleozoic Era oil-gas reservoir.Ordovician strata thickness is more stable, distribution
Extensively.In terms of comprehensive, stratum is divided into room-between lower system Peng Lai Ba Zuheyingshan group, middle unification from bottom to top and spits the wooden shock group (big portion
Region-by-region lacks substantially), the well compactness of Ji Shangtong and Sang Ta wood group (table 1).Its lithological composition mainly includes limestone, white clouds
Transitional type between rock and transitional type between the two and carbonate rock and argillaceous rocks.
1 Ordovician strata of table divides table
The control that the formation of well compactness effective reservoir is acted on by high energy depositional environment, corrosion and tectonic activity,
Especially the corrosion of diagenesis early stage atmospheric water and phase corrosion is buried, is that the area improves reservoir hole and seeps the main constructive of performance
Diagenesis.The metrical water corrosion stage mainly includes molten with raw phase metrical water corrosion and well compactness advanced stage metrical water
Diagenetic stage is lost, so that the primary pores such as reef flat body skeleton hole, intergranular pore are developed.And the natural gas occurred since Early Himalaya
The fracture network that strong filling process is formed, also plays important role for optimizing and improving reservoir property.As it can be seen that in good
The diagenesis of tower lattice group scene-affinity reef flat body is relatively complicated, experienced cementing more phases, corrosion, seam effect etc., be polymorphic type,
The result of transformation superposition of more phases time.But on the whole, Constructive diagenesis is less than the destructive diagenesis such as cementing and diagenetic compaction
Effect.
Show that it is discontinuous that strata pressure system is distributed in the longitudinal direction in area according to reality drilling datas a large amount of in work area.
The undercompaction phenomenon that Permian-carboniferous mudstone stratum is widely present causes this set stratum to have the feature of abnormal high pressure, not only exists
Sealing role is played to the oil gas in underlying strata in physical property, since fluid has abnormal high pressure in stratum, from fluid neuron network
Mechanism on also prevent oil gas upward dissipation, this to superpressure preservation be also it is considerably advantageous.Measured formation pressure data
It is also shown that there is a pressure barrier inside reservoir, the upper and lower Measured formation pressure of the barrier obviously mutates, under oil reservoir
In overpressure system.The formation of the pressure barrier is related with lithology, is one layer of fine and close mud stone section in certain wells, or fine and close
The section of rock containing cream.
According to related logging data are read in well-log information, wherein overlying formation pressure P0 is real by point stratum of acquisition
Border pore pressure data is calculated using density log data by formula α Pp=P0-Pe.It is collected simultaneously in research work area
The pore pressure field data of carbonate formation, and the value formation pressure that bound fraction is converted by drilling fluid density, benefit
Effective stress is calculated with effective stress theorem (the acquired hole coefficient of elasticity of through hole flexibility test test is 0.4149).
Such as table 2 of parametric statistics needed for model.
2 effective stress model parameter statistical form of table
It according to above data, is fitted by Multiple Non Linear Regression, establishes the calculating of two effective stresses in research work area
Model:
In formula: VpFor formation rock velocity of longitudinal wave, km/s；
ρ is stratigraphic rock density, g/cm3；
VshFor shale content, decimal；
CNL is neutron porosity, decimal；
Pe is effective stress, MPa.
The degree of correlation of above-mentioned model, as shown in Figure 1.
Based on well-log information, formation pressure detection has been carried out to No. 2 wells and No. 5 wells using the model, has been established by calculating
Play No. 2 wells and No. 5 well Reservoir Section prediction of formation pressure sections as shown in Figures 2 and 3.It is credible for evaluation and foreca result
Degree, the measured result for the actual measurement well section for having neither part nor lot in Multiple Non Linear Regression is compared and analyzed with the model calculation, as a result
As shown in table 3.
3 prediction of formation pressure Comparative result of table
It can be preferable based on the effective stress model of well-log information building by the result explanation in Fig. 2, Fig. 3 and table 3
Suitable for studying the pressure prediction of work area carbonate formation, the safety and technical requirements of site operation can satisfy.
Comparative example 1
It is predicted using equivalent depth method
It is real to bore stratum abridged table such as table 4 for No. 1 well.
4 No. 1 well drilling strata abridged tables of table
As can be seen from the above table, No. 1 well is after 2590m, stratum is directly entered the Triassic system, has lacked Jurassic system therebetween, and under
Layer throw oneself on the ground as successive sedimentation, therefore the foundation of normal compaction trend line should be using 2590m as separation.
The value principle of carbonate rock section mud stone interval transit time: 1. select well: the necessary drill-through all purposes layer of selected well section,
Known target zone may be substantially close to normal hydrostatic column pressure, and in mud stone well section comparison rule.2. geological epoch: differently
The matter age should be segmented to make；3. selecting lithology: referring to compound logging lithological profile and digital processing result map table, choosing pure mud
Rock or shale, if without pure shale section, it is optional containing ash or grey matter mud stone, cloud matter mud stone；4. select log: high GR, low R,
Enlarging rate is less than in a certain range, and thickness is greater than 2 meters.When readings, avoids reading isolated mistake high point or cross low spot, should read as far as possible
It makes even straight section numerical value；5. removing mentioned above principle, vertical correction should also be carried out to inclined shaft.
According to the value principle of carbonate rock section mud stone interval transit time, in conjunction with each borehole logging tool data, filtering out rationally has
The mud stone section interval transit time data of effect.It is as shown in Figure 4 that No. 1 well normal compaction trend line is established accordingly.
No. 1 well normal compaction trend line equation obtained by Fig. 4: ln (Ac)=- 0.00029H+6.771, in formula when sound wave
Poor unit is us/m.
On the basis of above formula, No. 1 well Ordovician strata pore pressure section, such as Fig. 5 is calculated with equivalent depth method
It is shown, and contrast verification is carried out with observed pressure point, obtain table 5.
5 No. 1 well prediction of formation pressure Comparative results of table
From figure 5 it can be seen that being based on the well normal compaction tendency equation, want high using the result that equivalent depth method is predicted
The mud density used in the process of actual well drilled says that this does not meet site requirement from engineering viewpoint, with observed pressure in table
The comparing result (table 5) of point also permits value far beyond error.Similar analysis is carried out to No. 2 wells according to above-mentioned thinking.
For No. 2 wells in research work area, stratum enters Jurassic system, intercalary delection Cretaceous System after 2108m.Under and
Portion stratum is successive sedimentation, and therefore, the mud stone section normal compaction trend line filtered out is established by starting point of 2108m.No. 2 wells are just
Normal compaction trend line figure is as shown in Figure 6.
No. 2 well normal compaction trend line equations: ln (Ac)=- 0.000227H+6.643, sound wave in formula are obtained by Fig. 6
Time difference unit is us/m.On the basis of above formula, No. 2 well Ordovician strata pore pressure sections are calculated with equivalent depth method
(Fig. 7), and contrast verification is carried out with observed pressure point, obtain table 6.
6 No. 2 well prediction of formation pressure Comparative results of table
It can be seen from figure 7 that utilizing the result and actual well drilled mistake of equivalent depth method prediction in 5470-5700m well section
Mud density used coincide preferably in journey, and the prediction effect of understratum then universal poor, pair with observed pressure point in table
The larger feature of error is also embodied than result.Main cause may be because that 5470-5700m well section is mainly sand, mudstone stratum,
And lower part contains based on marl then with marl.
It is comprehensive by the comparison of embodiments herein and comparative example 1 it is found that being directed to the prediction of carbonate reservoir pressure
Consider that acoustic speed-effective stress that porosity, shale content, bulk density, effective stress are established is multifactor and seeks model, it is right
The prediction result precision of carbonate formation pressure is higher, is also able to satisfy drilling engineering needs.Compared to equivalent depth method, based on having
The strata pressure Logging estimation model of efficacy theory can more efficiently be realized to the pre- of Pore Pressure on Carbonate Rock Formation
Survey analysis.And then for the pore pressure prediction of carbonate formation, effective stress method has more extensive application prospect.
Embodiments described above is a part of the embodiment of the present invention, instead of all the embodiments.Reality of the invention
The detailed description for applying example is not intended to limit the range of claimed invention, but is merely representative of selected implementation of the invention
Example.Based on the embodiments of the present invention, obtained by those of ordinary skill in the art without making creative efforts
Every other embodiment, shall fall within the protection scope of the present invention.
Claims (10)
1. a kind of prediction technique of carbonate reservoir pressure, characterized in that it comprises:
Effective stress computation model is established using neutron porosity, shale content, stratigraphic rock density；
The effective stress on stratum is obtained according to effective stress computation model, and according to the first principles computations earth bore of effective stress
Gap pressure；
Wherein, the effective stress computation model are as follows:
In formula, A0、A1、A2、A3、A4、A5And A6It is model coefficient, is fitted and is obtained by multiple regression；VpFor formation rock longitudinal wave speed
Degree, unit km/s；ρ is stratigraphic rock density, unit g/cm3；VshFor shale content；CNL is neutron porosity；PeTo have
Efficacy, unit MPa.
2. the prediction technique of carbonate reservoir pressure according to claim 1, which is characterized in that the formation pore pressure
Power is obtained by the basic principle of effective theory, and the basic principle of effective stress can be indicated by following equation:
Pe=Po-αPp
In formula, P0For overlying formation pressure；PeFor effective stress；PpFor formation pore pressure；α is hole coefficient of elasticity.
3. the prediction technique of carbonate reservoir pressure according to claim 2, which is characterized in that hole coefficient of elasticity passes through
Following steps obtain:
The coefficient of bulk compressibility and the skeleton particle compressed coefficient for measuring rock respectively, the hole elasticity system of rock is calculated with following formula
Number:In formula, Cs is particles compress coefficient；Cb is volume compression system.
4. the prediction technique of carbonate reservoir pressure according to claim 3, which is characterized in that use three-axis tester
RTR-1000 obtains Cb and Cs in two steps, first in the case where keeping pore pressure constant, increases confining pressure, acquires Cb；Then
Confining pressure and pore pressure increase at a same speed simultaneously, acquire Cs.
5. the prediction technique of carbonate reservoir pressure according to claim 2, which is characterized in that hole coefficient of elasticity is
0.2~0.9.
6. the prediction technique of carbonate reservoir pressure according to claim 2, which is characterized in that overlying formation pressure P0
It is to be obtained using density log material computation, is obtained by following steps:
In formula, H0For starting point depth of logging well；ρ0It (h) is the density that section depth is h point of not logging well；ρ (h) is the survey that depth is h point
Well density；G is acceleration of gravity.
7. the prediction technique of described in any item carbonate reservoir pressure according to claim 1~6, which is characterized in that shale
Content VshIt is obtained by following steps:
Shaliness index SH is calculated according to the variation of natural gamma relative amplitude first:
In formula, layer natural gamma value for the purpose of GR；GRmaxFor the natural gamma value of pure shale layer；GRminFor clean sandstone or pure carbonic acid
The natural gamma value on rock salt stratum, the variation range of SH are 0~1；
Then, then with following formula by SH it is converted into shale content Vsh；
Wherein, G is empirical, takes 2 for old stratum, Paleogene and Neogene stratum takes 3.7, sound wave velocity of longitudinal wave VshPass through
Acoustic logging readings converts to obtain.
8. the prediction technique of carbonate reservoir pressure according to claim 1, which is characterized in that further include: according to institute
It states formation pore pressure and draws out formation pore pressure gradient profile.
9. the prediction technique of carbonate reservoir pressure according to claim 8, which is characterized in that further include: it will not join
It is compared and analyzed with the measured result of the actual measurement well section of multiple regression analysis with the model calculation.
10. the prediction technique of carbonate reservoir pressure as described in any one of claims 1 to 9 is in fracture hole type Carbonate Reservoir
On application.
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| CN114417587A (en) * | 2022-01-12 | 2022-04-29 | 成都理工大学 | Stratum pore pressure prediction method suitable for compact clastic rock stratum in low-pressure state |
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