CN114673494A - Method for predicting storage layer pore permeability after steam huff and puff - Google Patents
Method for predicting storage layer pore permeability after steam huff and puff Download PDFInfo
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- 230000035699 permeability Effects 0.000 title claims abstract description 75
- 239000011148 porous material Substances 0.000 title claims abstract description 39
- 238000000034 method Methods 0.000 title claims abstract description 38
- 238000009991 scouring Methods 0.000 claims abstract description 35
- 230000008859 change Effects 0.000 claims abstract description 29
- 238000005406 washing Methods 0.000 claims abstract description 14
- 238000004364 calculation method Methods 0.000 claims abstract description 13
- 238000011010 flushing procedure Methods 0.000 claims abstract description 10
- 230000015572 biosynthetic process Effects 0.000 claims abstract description 8
- 238000005259 measurement Methods 0.000 claims abstract description 5
- 239000003129 oil well Substances 0.000 claims abstract description 5
- 238000007405 data analysis Methods 0.000 claims abstract description 4
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 84
- 239000004576 sand Substances 0.000 claims description 31
- 229920006395 saturated elastomer Polymers 0.000 claims description 18
- 230000008569 process Effects 0.000 claims description 15
- 238000002474 experimental method Methods 0.000 claims description 14
- 238000010793 Steam injection (oil industry) Methods 0.000 claims description 12
- 238000010438 heat treatment Methods 0.000 claims description 9
- 238000004519 manufacturing process Methods 0.000 claims description 9
- 230000000638 stimulation Effects 0.000 claims description 7
- 238000013401 experimental design Methods 0.000 claims description 6
- 230000032683 aging Effects 0.000 claims description 2
- 230000005465 channeling Effects 0.000 abstract description 8
- 238000010276 construction Methods 0.000 abstract description 4
- 230000002265 prevention Effects 0.000 abstract description 2
- 238000009472 formulation Methods 0.000 abstract 1
- 239000000203 mixture Substances 0.000 abstract 1
- 239000003921 oil Substances 0.000 description 33
- 238000002347 injection Methods 0.000 description 13
- 239000007924 injection Substances 0.000 description 13
- 239000012071 phase Substances 0.000 description 11
- 230000003628 erosive effect Effects 0.000 description 8
- 239000002245 particle Substances 0.000 description 8
- 239000000295 fuel oil Substances 0.000 description 7
- 239000007788 liquid Substances 0.000 description 7
- 239000011435 rock Substances 0.000 description 7
- 239000003795 chemical substances by application Substances 0.000 description 6
- 238000011161 development Methods 0.000 description 5
- 230000018109 developmental process Effects 0.000 description 5
- 239000007789 gas Substances 0.000 description 5
- 239000010779 crude oil Substances 0.000 description 4
- 238000013508 migration Methods 0.000 description 4
- 230000005012 migration Effects 0.000 description 4
- 230000000694 effects Effects 0.000 description 3
- 230000000704 physical effect Effects 0.000 description 3
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 2
- 238000010795 Steam Flooding Methods 0.000 description 2
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- 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
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- 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
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N15/00—Investigating characteristics of particles; Investigating permeability, pore-volume, or surface-area of porous materials
- G01N15/08—Investigating permeability, pore-volume, or surface area of porous materials
- G01N15/082—Investigating permeability by forcing a fluid through a sample
- G01N15/0826—Investigating permeability by forcing a fluid through a sample and measuring fluid flow rate, i.e. permeation rate or pressure change
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N15/00—Investigating characteristics of particles; Investigating permeability, pore-volume, or surface-area of porous materials
- G01N15/08—Investigating permeability, pore-volume, or surface area of porous materials
- G01N15/088—Investigating volume, surface area, size or distribution of pores; Porosimetry
Abstract
The invention discloses a reservoir porosity and permeability prediction method after steam huff and puff, which comprises the following steps of S1, measuring the porosity and permeability of a representative reservoir after different huff and puff rounds; s2, collecting formation physical parameters, and calculating the flushing times of the reservoir oil well handling rounds in the step S1 by combining a steam handling working system; s3, performing data analysis on the measurement and calculation results in the steps S1 and S2, and establishing a relation between reservoir pore permeability change and washing multiple; and S4, predicting the porosity and permeability values of different well positions in the same block after different throughput rounds by using the relationship between the reservoir pore permeability change and the flushing multiple established in the step S3. The reservoir pore permeability variation amplitude is represented by the calculated scouring multiple, so that the pore permeability specific values of different well positions of the same block after multiple rounds of steam huff and puff can be quickly predicted, a relatively accurate data base is provided for the formulation of subsequent operation measures such as prevention and treatment of gas channeling of the reservoir, construction cost is reduced, and construction efficiency is improved.
Description
Technical Field
The invention belongs to the technical field of oil reservoir development, and particularly relates to a reservoir pore permeability prediction method after steam huff and puff.
Background
The heavy oil is an important petroleum resource and is widely distributed worldwide. Along with the continuous increase of the demand of social development on petroleum, the development of the thickened oil in China is gradually increased. The steam huff and puff is used as a simple and effective heavy oil thermal recovery method and is widely applied to the development of the heavy oil in China.
When thick oil is produced by using steam huff-and-puff, multi-cycle huff-and-puff operation (multiple rounds of steam huff-and-puff) is generally required to effectively heat the reservoir so as to improve the development effect. However, several times or even tens of times of huffing and puff operations not only can cause the thick oil in the reservoir to be heated and the viscosity of the thick oil is reduced, but also can cause the porosity and the permeability (hole permeability for short) of the reservoir in the huffing and puff area to be changed in the huffing and puff process, thereby influencing the effect of steam huffing and puff operations.
Therefore, before the next steam huff and puff operation is carried out, if the pore permeation change rule of the reservoir after multiple rounds of steam huff and puff can be researched and the pore permeation of the corresponding reservoir can be predicted, the application effects of subsequent channeling prevention and plugging agent injection can be improved.
Disclosure of Invention
Aiming at the defects of the prior art, the technical problems to be solved by the invention are as follows: for the reservoir stratum after steam huff and puff, no accurate and feasible pore seepage prediction means exists, and the basic parameters of measures for preventing and controlling the gas channeling scheme in the mine field are insufficient.
In order to solve the technical problems, the invention adopts the following technical scheme:
the method for predicting the reservoir pore permeability after steam huff and puff is characterized by comprising the following steps of:
s1, measuring the porosity and permeability of the representative reservoir after different handling rounds;
s2, collecting formation physical parameters, and calculating the scouring times corresponding to the huff and puff rounds of the reservoir oil wells in the step S1 by combining a steam huff and puff working system, wherein the scouring times are the total volume of accumulated passing water phases in unit pore volume;
s3, performing data analysis on the measurement and calculation results in the steps S1 and S2, and establishing a relation between reservoir pore permeability change and washing multiple;
and S4, predicting the porosity and permeability values of different well positions in the same block after different throughput rounds by using the relationship between the reservoir pore permeability change and the flushing multiple established in the step S3.
By adopting the scheme, the porosity and the permeability of the reservoir have important influence on the injection of the plugging agent for preventing and controlling the gas channeling machine in a mine, the change rules of the scouring multiples of different layers in the same area are similar, and the scouring multiples and the change amplitude of the reservoir have better correlation according to analysis, so that the pore permeation change amplitude of the reservoir is represented by taking the scouring multiples as characteristic parameters on the basis of the scouring multiples, the scheme is feasible, the result is relatively more accurate and reliable, and better data reference can be provided for the establishment of subsequent measures for preventing and controlling the gas channeling.
Preferably, the method comprises the following steps: in the step S1, a one-dimensional steam huff and puff experiment is performed through a sand-packed pipe to determine the porosity and permeability, which includes the following steps:
s1.1, selecting an actual sand sample of a representative reservoir to fill a sand pipe, sequentially carrying out vacuumizing and saturated water operation, and calculating the original porosity of the representative reservoir in the sand pipe according to the volume of the saturated water;
s1.2, connecting each experimental instrument according to experimental design, driving a sand filling pipe by water at variable speed, recording the pressure difference at two ends of the sand filling pipe, and calculating the original permeability of a representative reservoir in the sand filling pipe according to a Darcy formula;
s1.3, low-speed saturated oil, and calculating the saturation of the bound water according to the volume of the effluent;
s1.4, after the initialization of the model is completed, entering an experimental operation stage, injecting a certain amount of steam into the sand filling pipe according to the designed flow rate, then stewing, starting a well for production after stewing is completed, measuring the discharged water amount, improving the back pressure of an outlet at the other end of the sand filling pipe, injecting hot water into the sand filling pipe, and recording the pressure difference and flow rate data at the two ends of the sand filling pipe;
s1.5, repeating the handling process until the experimental design requirement is met;
and S1.6, after the experiment is finished, calculating and analyzing the porosity and permeability change amplitude percentage according to the data condition recorded in the experiment.
By adopting the scheme, the measuring efficiency can be improved by means of the one-dimensional steam throughput experimental device, and the accuracy of the result can be improved by adopting relatively real simulation conditions.
Preferably, the method comprises the following steps: and (3) after the saturated oil operation in the step S1.3 is finished, placing the sand filling pipe in a thermostat and aging for more than 24 hours. By adopting the scheme, the saturated oil can be fully contacted with the filling sand, the stratum condition can be fully simulated, and the result reliability can be improved.
Preferably, the method comprises the following steps: in step S2, the water phase includes steam and hot water, and a heating zone formed in the formation during steam injection is divided into a steam zone and a hot water zone, where the washing multiple of the heating zone at a position r from the wellbore is N-Nw+NsWhere N is the flush multiple, m3/m3，Nw、NSRespectively corresponding to the flushing times of the hot water and the steam. By adopting the scheme, the scouring of the steam and the hot water is considered at the same time, the method is more consistent with the actual situation of a mine field, and the accuracy of the calculation result is also favorably ensured.
Preferably, the method comprises the following steps: and the relation between the reservoir pore permeability change and the scouring multiple is a relational expression and/or a chart between the reservoir pore permeability change amplitude percentage and the scouring multiple. By adopting the scheme, various prediction requirements can be met, the result is more accurate by adopting the relational expression, and the chart is more visual and convenient.
The working principle of the invention is as follows:
by adopting the method for predicting the reservoir permeability after steam huff-puff provided by the invention, the correlation between the scouring multiple and the reservoir permeability is deeply analyzed, in the steam huff-puff process, due to the injection of steam, the erosion and migration of rock particles occur in the stratum, and further the obvious change of the physical properties of the reservoir occurs, and no matter the erosion of the rock particles and the migration of the rock particles, the applicant combines a large number of researches to discover and confirm that the erosion of the rock particles and the migration degree of the rock particles form a positive correlation with the steam injection amount (the scouring condition of steam), so that the concept of creatively introducing the scouring multiple describes the scouring condition of steam to the stratum, and the relationship between the scouring multiple and the variation condition of the reservoir permeability is established. And because different well working systems are different in the actual production process, and steam injection conditions are also different, the adaptability of the existing pore seepage prediction method is poor, and because the washing multiple takes the difference of the working systems into account, the prediction method is more universal and is beneficial to popularization and use.
In addition, the reservoir pore permeability variation amplitude is represented by the calculated scouring multiple, the pore permeability specific values of different well positions in the same block after multiple rounds of steam huffing and puff can be predicted more quickly, and then a more accurate data basis is provided for the subsequent operation measures of preventing and treating gas channeling and the like of the reservoir, so that the construction cost is reduced, the construction efficiency is improved, and the like.
Drawings
FIG. 1 is a schematic flow diagram of the present invention;
FIG. 2 is a plot of a representative reservoir porosity growth rate versus steam scour multiple fit;
FIG. 3 is a representative reservoir permeability and steam flush multiple interpolation plot.
Detailed Description
The present invention will be described in further detail with reference to the accompanying drawings.
Referring to fig. 1 to 3, the method for predicting pore permeability of a reservoir after steam stimulation mainly comprises the following steps, namely step S1, measuring the porosity and permeability of a representative reservoir after different stimulation rounds; step S2, collecting formation physical parameters, and calculating the scouring times corresponding to the huff and puff rounds of the reservoir oil wells in the step S1 by combining a steam huff and puff working system, wherein the scouring times are the total volume of accumulated passing water phases in unit pore volume; step S3, performing data analysis on the measurement and calculation results in the step S1 and the step S2, and establishing the relation between the reservoir pore permeability change and the scouring multiple; and step S4, predicting the porosity and permeability values of different well positions in the same block after different throughput rounds by using the relationship between the reservoir pore permeability change and the scouring multiple established in the step S3.
In the implementation of step S1, a sand-packed pipe and a one-dimensional steam huff and puff experimental device are preferably used to perform a one-dimensional steam huff and puff experiment for determination, the experimental device may refer to a patent No. 202011132908, an X-experimental device for simulating heavy oil and injecting nitrogen to assist steam huff and puff, a 202122603755.9-a steam huff and puff visual experimental device, and the like, which are not described herein, but the main measurement parameters and the operation steps are slightly adjusted, specifically, as follows, step S1.1, selects an actual sand sample sand-packed pipe of a representative reservoir, collects and records reservoir physical parameters and a working system, pushes and packs the sand pipe to perform vacuum pumping and saturated water operation in sequence, and the original porosity of the representative reservoir in the sand-packed pipe can be calculated according to the saturated water volume.
And S1.2, connecting each experimental instrument according to experimental design, driving the sand-packed pipe by water at variable speed, recording the pressure difference at two ends of the sand-packed pipe, and calculating the original permeability of a representative reservoir in the sand-packed pipe according to the Darcy formula.
And S1.3, low-speed saturated oil, calculating the saturation of the bound water according to the volume of the effluent, and improving the generation rate of the bound water by adopting a low-speed saturation mode, wherein after the oil saturation is finished, a sand filling pipe is usually placed in a thermostat and aged for more than 24 hours, and the temperature setting of the thermostat can be set by referring to the actual ground bottom temperature of a corresponding reservoir, so that the filled sand can fully absorb the saturated oil, the saturated oil and the saturated oil are fused more thoroughly, and the fusion of the saturated oil and the saturated oil is closer to the actual situation of the stratum.
Step S1.4, after the initialization of the model is completed, entering an experimental operation stage, injecting a certain amount of steam into the sand filling pipe according to a designed flow rate, then carrying out stewing, after the stewing is finished, starting production (the stewing mainly refers to a hot water process that steam heat is absorbed by liquid in pores and is mixed with the liquid, judging is carried out mainly by observing pressure, the pressure is obviously reduced, and the steam can be regarded as being completely changed into hot water), measuring the liquid discharge amount, improving the outlet back pressure at the other end of the sand filling pipe (being beneficial to carrying out the huff and puff again, changing the steam into the hot water, and improving the accuracy of a permeability calculation result), injecting the hot water into the sand filling pipe, recording the pressure difference and the flow rate data at the two ends of the sand filling pipe, mainly referring to the liquid production rate, namely the liquid production amount in unit time or recorded average time, and calculating the change amplitude of the permeability through the pressure difference and the flow rate data.
And S1.5, repeating the handling process until the experimental design requirement is met, wherein the design requirement refers to the same handling times as the reservoir to be predicted.
And S1.6, after the experiment is finished, calculating and analyzing the porosity and permeability change amplitude percentage according to the experiment record data condition, wherein the original porosity and permeability of the representative reservoir in the sand-packed pipe are already calculated according to the step S1.1 and the step S1.2, the porosity change amplitude can be calculated by combining the difference value of the injected liquid amount and the liquid outlet amount, and the permeability change amplitude is calculated according to the pressure difference and the flow data in the same way, and the elasticity of the sand-packed pipe is ignored in the calculation process.
In the embodiment, the experiment is mainly carried out on the basis of the thickened oil sand-filled pipe, and certainly, the experiment can also be carried out by adopting the reservoir core section, so that the experiment result is relatively more real.
In step S2, first, formation physical parameters need to be collected, a steam huff-and-puff working system is combined, and a scouring multiple corresponding to the huff-and-puff turns of the reservoir oil well in step S1 is calculated, wherein the scouring multiple is a total volume of accumulated water phase passing through a unit pore volume, the water phase comprises steam and hot water, a heating region is formed in the formation during steam injection and is divided into a steam region and a hot water region, and then the scouring multiple of the heating region at a position r away from a shaft is N ═ Nw+NsWhere N is the flush multiple, m3/m3，Nw、NSThe specific calculation process of the washing times respectively corresponding to the hot water and the steam is as follows:
assumption of conditions
1) The oil reservoir is a horizontal homogeneous equal-thickness oil reservoir, and the change of the physical property of the oil reservoir along with the temperature is not considered;
2) in the steam injection process, injection parameters (pressure, temperature, steam dryness and the like) are kept stable and unchanged;
3) because the steam injection is fast in the steam huff and puff process, the steam override is not considered;
4) wherein the steam zone temperature is equal to the injected steam temperature and the hot water zone temperature decreases linearly in a radial direction from the steam temperature to the reservoir temperature.
The following is calculated for the hot water zone and the steam zone, respectively:
in the hot water area, at any injection time t, the washing multiple N is at the position r away from the shaft radiuswComprises the following steps:
the cumulative water phase volume passing through this section is, according to the continuity equation:
for the steam injection process of the steam huff-puff well, according to a Buckley-Leveret water flooding theory, an isosaturation surface movement equation is arranged in a hot water area under the condition of plane radial flow:
shifting the equal sign of the formula (3) left and right and integrating respectively, the upper and lower limits of the integration in the formula (2) can be written as follows:
for radius r from the wellbore, due to water saturation SwRegarding the injection time t only, the differential form of writing equation (4) left and right as t can be obtained:
then, equation (2) can be rewritten as:
after integration and simplification, the following results are obtained:
then (1) can be rewritten as:
to determine the calculation of equation (9), the calculation of the water production rate and its derivative needs to be determined.
According to the definition formula of the water yield, the water yield is as follows:
for heavy oil reservoirs, the viscosity-temperature relationship of crude oil can be written as Andrade:
the relative permeability ratio of most rocks has the following relationship:
wherein, for coefficients a and b, the rock hydrophilicity is generally considered to be enhanced due to the temperature rise in the heavy oil thermal recovery process, and the oil-water relative permeability curveThe overall shape is shifted to the right, and the b value is considered to remain unchanged. The assumption is that the coefficient a is obtained by calculation according to the oil-water relative permeability at the original oil reservoir temperatureiThe right shift quantity of the oil-water relative permeability curve is delta S along with the increase of unit temperaturewThen, there are:
the right migration rule of oil-water phase seepage of different oil reservoirs along with the temperature is different, and S can be determined by oil-water phase seepage curves at different temperatureswAs a function of reservoir temperature T. It is assumed here that the variation is a linear relationship, namely:
ΔSw＝m(T-Ti) (14)
then, formula (14) can be substituted by formula (13):
then equation (10) can be rewritten as:
the physical significance of the above formula lies in the relationship between the water saturation and the water production rate at each seepage section, and the water production rate changes along with the change of the water saturation along with the position of the distance from the wellbore. Derivation can be obtained by left-right derivation of the above formula:
the water saturation S at different times can be obtained by substituting the formula (17) into the formula (4)w：
Under the assumption that the temperature of the hot water region varies linearly in the radial direction, the heating radius of the hot water region can be expressed as the following temperature variation:
according to the newly modified Marx-Langenheim model, the hot water zone heating radii are:
wherein:
let the average dryness in the steam cavity be xiAnd then the heating radius of the steam area is as follows:
substituting equations (20) and (21) into equation (19) yields the temperature T at a distance r from the wellbore as a function of injection time T:
then, from the equation (9), the change relationship of the hot water area flushing multiple along with the injection time t is:
the water saturation and the washing multiple of the hot water area at the position r away from the shaft can be obtained.
For the steam zone, it is believed that the hold up to the section r from the wellbore remains constant, i.e., the wash rate at r should be equal to the expansion of the steam chamber to rAt a time tsCorresponding hot water flushing multiple NwPlus the flushing multiple N of the steam brought by the expansion of the steam cavitysAt this time, the density of steam and hot water at r under the dryness is considered as follows:
then directly apply mechanically (1) formula, the washing multiple that steam chamber expands through r department cross-section at this moment is:
then the total washing multiple at the position r away from the shaft is as follows:
N＝Nw+Ns (26)
it should be noted that, because the actual output and the predicted value of the capacity of the steam huff-and-puff well in the process of spitting often cannot correspond to each other, the erosion multiple brought to the process of spitting is greatly influenced, if the erosion multiple is calculated in the hole seepage prediction after the huff and puff, the prediction precision is obviously reduced, so that when the method is implemented, only the erosion multiple in the steam injection process is adopted when the erosion multiple and the hole seepage variation amplitude are established, and meanwhile, because the calculated values of the erosion multiples at different distances from the shaft are different, the calculated value at the position 0.5m away from the shaft is usually selected, and the calculation process can refer to the early patent of the applicant: the patent number is 201911199882.8, and the invention is named as a method for adjusting the optimal steam injection speed in the steam drive exploitation of the heavy oil reservoir.
Description of the symbols: n is the washing multiple, m3/m3In which N isw、NSRespectively corresponding to the washing times of hot water and steam; wpFor the amount of flushing through the cross-section, m3(ii) a r is the radius from the shaft, m; h is the oil layer thickness, m;
is the oil layer porosity, decimal; wiTo steamEquivalent amount of cold water injected by steam, m3；WzIs the hold up between the wellbore and the cross-section at radius r from the wellbore, m3；isInjecting cold water into the steam at an equivalent rate of kg/s; f. ofw(Sw) The corresponding water content and decimal fraction under a certain water saturation; t is toTime, s, for the injection front to reach the section at r; t is the cumulative injection time, s; f'w(Sw) Is the water cut rate of rise; swfThe steam flooding front edge water saturation is decimal; f. ofw(Swf) The water content of the front edge of the steam cavity corresponds to the saturated water content; f. ofw'(Swf) The derivative of the water content corresponding to the water saturation of the front edge of the steam cavity; swThe water saturation and decimal of the section r from the time t to the shaft is shown; mu.swIs the viscosity of water, mPas; mu.soCrude oil viscosity, mPa · s; koEffective permeability of the oil phase, D; k iswEffective permeability of the aqueous phase, D; t is the oil layer temperature, K; t isiIs the original temperature of the oil layer, K; m is the coefficient of variation of the phase permeation curve with temperature, and has no dimension; t issIs the steam injection temperature, K; r issIs the steam cavity radius, m; r iswIs the radius of the hot water zone, m; h issIs composed of
The injection temperature corresponds to the enthalpy of hot water, J/g; h iswThe original temperature of the oil layer corresponds to the enthalpy of hot water, J/kg; mRIs the thermal capacity of the oil layer, J/(m)3·K)；αsIs the top and bottom layer thermal diffusivity, m2/s；λeThe thermal conductivity of the top layer and the bottom layer is W/(m.K); x is the dryness of steam injected into the bottom of the well, and the decimal number; l isvJ/kg as latent heat of vaporization; rho is the density of the water phase in the steam cavity, kg/m3；ρsAs steam density, kg/m3；ρwIs hot water density, kg/m3A, B, a and B are constants and can be obtained by fitting a relation curve of the viscosity and the temperature of the crude oil.
In the application, the relation between the reservoir permeability change and the scouring multiple is a relational expression and/or a chart between the reservoir permeability change amplitude percentage and the scouring multiple.
Referring to fig. 1 to 3, a one-dimensional sand-packed pipe packing and a plurality of steam huff and puff experiments are performed on 6 target wells selected in a target block, the original pore permeability is firstly measured, and relevant physical property parameters and a gas injection working system are collected and recorded as follows:
watch (1)
Carrying out throughput experiment based on the basic data, recording and sorting, and collecting the average heat capacity of 2431 × 10 of the oil layer of the target block3J/(m3K), the thermal conductivity of the top and bottom layers is 1.51W/(m.K), and the thermal diffusivity of the top and bottom layers is 1.33X 10- 6m2And s. Obtaining a viscosity-temperature relationship regression curve of the crude oil of the block, wherein A is 22.3115, B is 268.12, and a correlation coefficient R is 0.9905; regression of the initial reservoir temperature lower permeability curve of the block to obtain ai9801645 and b 27.446, and the correlation coefficient R is 0.9987.
After the corresponding scouring multiple is calculated by using a given formula, summarizing data as shown in FIG. 2, establishing a common logarithmic relation between the porosity growth rate and the scouring multiple in a parameter-to-standard mode through data processing means such as fitting and the like:
e＝1.2917(lgn)2-5.1918lgn+4.4671
in the formula:
e is the porosity growth rate in swept areas,%;
n is the washing multiple and has no dimension.
Since the original permeability has a certain influence on the permeability increase. Therefore, the common logarithm of the scouring multiple is taken as the horizontal axis, the original permeability is taken as the vertical axis, and a common logarithm chart of the permeability increase rate and the scouring multiple is drawn by an interpolation method, as shown in fig. 3. The vertical axis in the plate is the original permeability of the oil layer, the unit is D, the value on the oblique line is the permeability increase rate, the unit is% according to the original permeability of the oil layer and the common logarithm value of the scouring multiple, the corresponding oblique line is searched, and the increase rate of the permeability at the moment can be determined.
Using the above relation and the plate to determineAnd determining the pore permeability change conditions of other wells in the area, and further determining the dosage of the injection plugging agent, such as: taking the same block of Y1917 wells as an example, the thermal property and other parameters of the oil layer are unchanged, the effective thickness of the oil layer is 5.2m, the original porosity is 36 percent, 5 times of steam injection are accumulated during steam channeling, and the total thickness is 483m3The steam scouring multiple is 67081 according to the specific working system, the porosity increase amplitude is 9.5 percent by substituting the formula, namely the porosity is 39.42 percent after 5 times of throughout, and the amount of the plugging agent is 67.21m by calculation by combining the permeability prediction data3Before this, the actual usage amount of the well in the oil field and the mine field for steam channeling plugging is 64m3And the relative error is less than 5%, which proves that the prediction precision of the pore permeability parameter of the reservoir is higher after the huff and puff of multiple times, the particle size selection of the particle plugging agent needs the permeability parameter to calculate the diameter of pore throats in pores of the reservoir, and meanwhile, the interpolation chart shown in figure 3 can quickly determine the current permeability so as to select the particle size of the plugging agent with better quality.
The above are only preferred embodiments of the present invention, and it should be noted that a person skilled in the art may make several variations and modifications without departing from the technical scope of the present invention, and the technical scope of the present invention should be considered as falling within the scope of the present invention.
Claims (5)
1. A reservoir pore permeability prediction method after steam stimulation is characterized by comprising the following steps:
s1, measuring the porosity and permeability of the representative reservoir after different handling rounds;
s2, collecting formation physical parameters, and calculating the scouring times corresponding to the huff and puff rounds of the reservoir oil wells in the step S1 by combining a steam huff and puff working system, wherein the scouring times are the total volume of accumulated passing water phases in unit pore volume;
s3, performing data analysis on the measurement and calculation results in the steps S1 and S2, and establishing a relation between reservoir pore permeability change and washing multiple;
and S4, predicting the porosity and permeability values of different well positions in the same block after different throughput rounds by using the relationship between the reservoir pore permeability change and the flushing multiple established in the step S3.
2. The method of predicting reservoir pore permeability after steam stimulation according to claim 1, wherein: in the step S1, a one-dimensional steam huff and puff experiment is performed through a sand-packed pipe to determine the porosity and permeability, which includes the following steps:
s1.1, selecting an actual sand sample of a representative reservoir to fill a sand pipe, sequentially carrying out vacuumizing and saturated water operation, and calculating the original porosity of the representative reservoir in the sand pipe according to the volume of the saturated water;
s1.2, connecting each experimental instrument according to experimental design, driving a sand filling pipe by water at variable speed, recording the pressure difference at two ends of the sand filling pipe, and calculating the original permeability of a representative reservoir in the sand filling pipe according to a Darcy formula;
s1.3, low-speed saturated oil, and calculating the saturation of the bound water according to the volume of the effluent;
s1.4, after the initialization of the model is completed, entering an experimental operation stage, injecting a certain amount of steam into the sand filling pipe according to the designed flow rate, then stewing, starting a well for production after stewing is completed, measuring the discharged water amount, improving the back pressure of an outlet at the other end of the sand filling pipe, injecting hot water into the sand filling pipe, and recording the pressure difference and flow rate data at the two ends of the sand filling pipe;
s1.5, repeating the handling process until the experimental design requirement is met;
and S1.6, after the experiment is finished, calculating and analyzing the change amplitude percentage of the porosity and the permeability according to the data condition recorded in the experiment.
3. The method of post-steam stimulation reservoir pore-permeability prediction of claim 2, characterized by: and (3) after the saturated oil operation in the step S1.3 is finished, placing the sand filling pipe in a thermostat and aging for more than 24 hours.
4. The method of predicting reservoir pore permeability after steam stimulation according to claim 1, wherein: in step S2, the water phase includes steam and hot water, and a heating zone formed in the formation during steam injection is divided into a steam zone and a hot water zone, where the washing multiple of the heating zone at a position r from the wellbore is N ═ NNw+NsWhere N is the flush multiple, m3/m3，Nw、NSRespectively corresponding to the flushing times of the hot water and the steam.
5. The method of predicting reservoir porosity after steam stimulation according to any one of claims 1 to 4, wherein: and the relation between the reservoir pore permeability change and the scouring multiple is a relational expression and/or a chart between the reservoir pore permeability change amplitude percentage and the scouring multiple.
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