CN110359892B - Steam flooding scheme optimization design method based on oil reservoir conditions - Google Patents
Steam flooding scheme optimization design method based on oil reservoir conditions Download PDFInfo
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Abstract
The invention discloses a steam flooding scheme optimization design method based on oil reservoir conditions, which relates to a steam flooding scheme optimization design theoretical analysis and calculation method, and comprises the following steps: (a) determining the liquid production capacity and the injection capacity of a single well by combining with the analysis of actual production data of the steam flooding oil reservoir, and judging the applicability and the available well pattern form of the oil reservoir; (b) and optimizing and determining the optimal operating condition parameters of the steam flooding through the calculated data, and simultaneously completing the prediction and evaluation of the development effect of the steam flooding. The beneficial effects are as follows: the 4 optimal operation condition parameter influence factors of the steam flooding are mutually related, and the steam flooding effect is comprehensively influenced in a multi-element factor coupling mode, so that the obtained parameters conform to the actual thermal recovery; the influence factors of the 4 optimal operating condition parameters are comprehensively considered, so that the globality of the optimized parameters is facilitated; the method can be applied to steam flooding operation condition parameter optimization and development effect evaluation, and the obtained result has clear physical significance; the operation method is simple, and the time and labor cost of a computer are reduced.
Description
The technical field is as follows:
the invention relates to a steam flooding scheme optimization design method, in particular to a simple and practical steam flooding scheme optimization design theoretical method based on oil reservoir conditions.
Background art:
the research of the theory of thick oil steam flooding and the field production practice prove that under certain technical conditions, the maximum economic recovery rate of a thick oil reservoir suitable for steam flooding is selected and depends on the self condition of the reservoir, and whether the expected development effect can be obtained in the implementation depends on the operation condition designed by the development scheme (see Yueqingshan et al, the technology for developing the steam injection of the thick oil reservoir, Beijing, the oil industry press, 1998, 71-78 pages), and the two are equally important. In order to realize successful steam flooding, namely to realize the recovery ratio of actual recovery ratio close to the due recovery ratio of oil reservoir conditions, the statistical analysis results of domestic and foreign successful steam flooding cases show that 4 optimal operating conditions which must be met simultaneously are as follows: 1) the steam injection strength Qs is 1.5-1.6 m 3/(d.ha.m); 2) production injection ratio RPI1.2-1.3; 3) steam quality f at the bottom of the welldNot less than 40 percent; 4) the reservoir pressure P is less than 5MPa, and preferably is 1-3 MPa.
How to design a steam drive scheme meeting the 4 optimal conditions at the same time is a common design method of people is a numerical simulation calculation method. As pointed out by Zhang et al (Kyoho et al, Kyoho, Beijing, oil industry Press 1999, pages 143 + 178) of thermal recovery experts in China, numerical simulation is not universal, and anyone cannot guarantee that the numerical simulation result can completely reflect the actual condition of the oil reservoir. The reason is that the numerical simulation method is also based on a plurality of simplifying assumptions, such as a plurality of grids to represent the actual oil reservoir is highly similar; secondly, people have limited knowledge of the oil reservoir, the accurate information which can be obtained is often limited to the oil reservoir at the drilled well point, the oil reservoir characteristics among wells are predicted by means of various approximate theoretical methods, the complex oil reservoir is simulated and described based on one point of data, and the simulation result is only approximate. Therefore, it is necessary to establish a steam flooding scheme design theoretical model based on reservoir conditions, and provide a new steam flooding scheme design method and a related parameter calculation method.
At present, only Yue Qingshan, Zhao Hongshan and Made Sheng propose a theoretical formula design method for designing an optimal scheme of steam flooding (see Yue Qingshan et al: "steam injection development technology for heavy oil reservoir:. Beijing: oil industry Press, 1998, pp.71-78.). However, the Yueqingshan et al considers the reservoir pressure as an independent variable, and does not perform systematic fundamental research on the functional relationship between the reservoir pressure and the steam temperature and the latent heat of vaporization in the steam cavity of the reservoir, and the steam injection rate, the steam dryness and the reservoir pressure parameters in the optimal operating conditions of the steam flooding are not strictly determined according to the reservoir parameter coupling, so that the theoretical basis of the design method of the optimal scheme of the steam flooding needs to be strengthened. The invention develops research aiming at the problems and improves defects, and provides a steam flooding scheme optimization design theory and a parameter calculation method based on oil reservoir conditions.
The invention content is as follows:
the invention aims to overcome the defects of the existing steam flooding scheme design technical method, and provides a steam flooding scheme optimization design method based on oil reservoir conditions, and the calculation steps and the specific method are as follows:
(a) firstly, combining an actual heavy oil reservoir test, statistical analysis and determining the single-well liquid production capacity and the injection capacity of a steam flooding reservoir, further judging whether the reservoir is suitable for steam flooding and an available well pattern form of the reservoir, expecting the development effect of the steam flooding and providing a foundation for ensuring the operation of the steam flooding under the optimal condition;
(b) calculating the suitable bottom-hole steam dryness value f by using the actual oil deposit datadSingle well steam injection rate iwSteam injection rate Qs and extraction-injection ratio R of unit oil reservoir volumePIAnd a production well spacing d; and optimizing and determining the optimal well placement mode and the optimal operating condition parameters of the steam flooding through the calculated data, and simultaneously expecting the development effect of the steam flooding.
And c, determining the oil reservoir single-well liquid production capacity and the injection capacity in the step a by a steam flooding field pilot test, a special pilot injection and pilot production test, or empirical data of steam swallowing and spitting and steam flooding which are successfully analyzed and summarized. For example, (1) Liaohe oil field 40 oil well fluid production capacity statistical analysis example: according to the production data collection and statistical analysis of the steam huff-and-puff stage of the relevant well group of 40 aligned Nelumbo Nucifera II oil layers, in the first period and the last period of the steam huff-and-puff, the liquid production amount in the first month is respectively 51t/d and 26t/d, and the corresponding production pressure difference is respectively 1.5MPa and 0.8 MPa. It follows that the liquid production indices of the first and last cycle are about 34t/(MPa.d) and 32.5t/(MPa.d), respectively. This result indicates that the well fluid production index is essentially constant during the steam stimulation phase, with an average value of around 33 t/(mpa.d). Further, it was found by calculation using a numerical simulation method that the liquid production rate of the oil well was calculated under the conditions of a reservoir pressure of 2.5MPa and a differential pressure of 1.8MPa, and the result was 62t/d, and the liquid production index was 34.4 t/(mpa.d). As can be seen from the comprehensive analysis, under the conditions that the reservoir pressure is kept at 2.5MPa and the production pressure difference is 1.8MPa in the steam flooding process, the liquid production index of 40 lotus II oil reservoirs in the steam flooding is about 34t/(MPa.d), the liquid production capacity of an oil well is about 60t/d, and the liquid production capacity q of a single well can be conservatively taken in consideration of the current thermal oil recovery process level of China150-55 t/d. For example, (2) example of statistical analysis of steam injection capability of 40 steam injection wells in Liaohe oilfield: analyzing 40 blocks of related well group steam throughput productionData show that the steam injection rate can reach more than 300t/d below the reservoir fracture pressure; for example, 15-29 well group steam injection data in the same 40 blocks indicate that the steam injection speed is about 120t/d under the pressure of a steam injection well head of 4-5 MPa. Comprehensive analysis of these actual data shows that for any steam flooding scheme, no injection problems occurred in 40 complete nelumbo reservoirs.
According to successful steam flooding experience, the injection and production capacity of an injection and production well is given full play during scheme design: if the difference of the injection and production capacities is small, the production can be carried out by using a five-point well pattern; when the injection capacity is about 2 times of the liquid production capacity, the seven-point well pattern can be used for production; when the injection capacity is 3 times of the liquid production capacity, a nine-point well pattern is adopted for production.
As a further improvement of the invention, the bottom hole steam dryness value f in the step bdThe calculation method of (2) is as follows:
(1) steam quality before steam flooding steam breakthrough
(2) Steam quality after steam flooding steam breakthrough
In the above formula: d, oil layer buried depth ft;
h-reservoir thickness, ft;
theta-oil layer dip angle, °;
μ — crude oil viscosity; mPa.s;
k-oil layer permeability, mD;
phi-reservoir porosity;
Soi-initial oil saturation of the oil layer;
Sors-residual oil saturation in the steam band;
g (t) -correction factor related to steam flood development time.
As a further improvement of the invention, the single-well steam injection rate i in the step bwThe calculation method of (2) is as follows:
in the above formula: i.e. iw-steam injection rate, bbl/day;
A0-steam injection well group area (constant), acre;
t*the steam flooding steam breakthrough time can be 3-4 years according to experience;
Khr、Kho、Do、Drthermal conductivity and thermal diffusivity, Btu/(ft. ° F.day), ft, of the overburden and oil reservoir, respectively2/day；
ρwWater density at steam temperature, taken approximately as 57.5lb/ft3；
fd-dryness of the steam;
ΔT＝Ts-TR-represents the difference, F, between the steam temperature in the reservoir and the original temperature of the formation;
Lv-latent heat of vaporization of water, Btu/lb. ° F, under reservoir pressure, temperature conditions.
As a further improvement of the invention, the steam injection rate per unit reservoir volume Q in the step bsThe calculation method of (2) is as follows:
in the above formula: h iszone-thickness of the pure oil layer; other symbols have the same physical meaning as before.
As a further improvement of the invention, the production-injection ratio R in the step b isPIThe calculation method of (2) is as follows:
in the above formula:
n is the ratio of the production wells to the injection wells of the well group, the five-point method is 1, the reverse seven-point method is 2, and the reverse nine-point method is 3;
q1-single well fluid production rate;
Khr、Kho、Do、Drthermal conductivity and thermal diffusivity, Btu/(ft. ° F.day), ft, of overburden and oil layer, respectively2/day；
fd-dryness of the steam;
ΔT＝Ts-TR-represents the difference, F, between the steam temperature in the reservoir and the original temperature of the formation;
LV-latent heat of vaporization of water, Btu/lb. ° F, under reservoir pressure, temperature conditions;
as a further improvement of the present invention, the well spacing d between adjacent production wells in step b is calculated as follows:
in the above formula: khr、Kho、Do、Dr-thermal conductivity and thermal diffusivity, Btu/ft. ° F.day, ft, of overburden and reservoir respectively2/day；
ρwWater density at steam temperature, taken approximately as 57.5lb/ft3；
fd-dryness of the steam;
ΔT＝Ts-TR-represents the difference, F, between the steam temperature in the reservoir and the original temperature of the formation;
LV-latent heat of vaporization of water, Btu/lb. ° F, under reservoir pressure, temperature conditions;
d, well spacing of adjacent production wells;
FAthe area coefficient of the well group is 1.0 by a five-point method, 2.6 by an inverse seven-point method and 4.0 by an inverse nine-point method;
n is the ratio of the production wells to the injection wells of the well group, the five-point method is 1, the reverse seven-point method is 2, and the reverse nine-point method is 3;
q1-single well fluid production rate;
t*the steam breakthrough time can be 3-4 years according to experience;
RPIand the ratio of the liquid extraction speed to the steam injection speed of the well group, which is called the extraction-injection ratio for short, is calculated from the previous step.
As a further improvement of the invention, the steam dryness value f at the bottom of the well in the step b isdGreater than or equal to 0.4, corresponding to a reservoir pressure of less than 5MPa (preferably close to or slightly less than 3MPa), then fdThe value may be used as a trial value.
As a further improvement of the invention, in the step b, when the calculated value of Qs is greater than or equal to 1.5m3V. (day. ha. m), i.e. within reasonable ranges.
As a further improvement of the invention, the injection-production ratio R in the step b isPIThe calculated value is greater than or equal to 1.2, i.e. within a reasonable range.
As a further improvement of the invention, in the step b, when the relative error between the calculated value of the well spacing d of the adjacent production wells and the data of the well spacing of the actual well pattern is less than or equal to 5%, namely within a reasonable range.
The steam flooding scheme optimization design method comprises the following steps: (1) the past design idea is changed, the oil reservoir pressure item is not independent, but is coupled with factors such as steam temperature in an oil reservoir steam cavity, latent heat of vaporization of corresponding water and the like for consideration, so that 4 optimal steam drive operating condition parameters of steam drive are correlated with each other to jointly influence the steam drive effect, and the thermal recovery is more in line with the thermal recovery practice. (2) The steam flooding optimal operation condition parameters determined by the method are completely calculated according to the steam flooding oil reservoir basic data and the steam data, and the influence factors of the 4 optimal condition parameters are comprehensively considered (but not respectively considered), so that the method is favorable for optimizing the constraint conditions of the parameters, and has stronger global property, consistency and harmony, and the result obtained by simultaneous multivariate optimization of the 4 parameters is more reasonable. (3) The method can be applied to steam flooding operation condition parameter optimization and development effect evaluation; the optimization calculation result is a key technical parameter influencing the steam flooding effect, the obtained result has clear physical meaning, and the optimization method is convenient to operate. (4) The method of the invention is not only simple to operate, but also can complete the key points of the steam drive development scheme which can be obtained by a numerical simulation method within several minutes and requiring tens of hours, greatly reduces the computer time and labor cost, and has economic benefit.
Description of the drawings:
FIG. 1 is a comparison graph of theoretical design results of the invention and actual results of daily oil production in a 40-block steam flooding pilot test area.
The specific implementation mode is as follows:
the following describes a specific calculation method for each data.
1 steam flooding instantaneous oil-to-steam ratio calculation
1.1 transient oil-to-steam ratio calculation before steam flooding steam breakthrough
Before steam flooding steam breakthrough, neglecting the difference between the volume rates of the steam displacement crude oil and the produced crude oil, the oil yield calculation formula at this stage can be obtained as follows:
in formula (1):
Soi-original oil saturation;
Sors-residual oil saturation in the steam band;
M`s-the combined volumetric heat capacity of the steam band,
lv is the latent heat of vaporization of water under the conditions of reservoir pressure and temperature, Btu/lb;
Cw-the heat capacity of the water,
t-steam injection (steam flooding operation) time, day;
Δ T-difference between the steam temperature within the reservoir steam band (cavity) and the original reservoir temperature, F;
α — the ratio of the amount of oil driven from the hot water zone below the steam band to the amount of oil driven from the steam band itself, α having a value of about 0.5.
When the heat utilization efficiency of steam flooding is high, the heat produced with oil production can be considered to be very small, so that the net injection of heat in the form of steam into the oil reservoir at the surface is approximately equal to the bottom injection of heat into the well, and thus, the heat injection rate can be obtained
In formula (2):
iw-steam injection rate, bbl/day;
ρwdensity of water, lb/ft3；
fd-bottom hole steam quality;
Lvb-latent heat of vaporization, Btu/lb, of water at bottom hole pressure and temperature of the steam injection well;
Tbsteam temperature at bottom-hole pressure of the steam-injection well, F.
The combined vertical type (1) and the formula (2) can obtain
By analyzing the technical data of dozens of successful steam flooding test projects at home and abroad, some successful steam flooding experiences can be applied to simplify the formula (3). (ii) for steam flooding reservoirs, L is generally at typical reservoir pressuresV+CwΔ T and Lvb+CwTbValues of 1100 and 1150Btu/lb, respectively, are nearly equal, typically differing by only a few percent; ② for most oil reservoirs, the effective volumetric heat capacity Ms is about 33Btu/ft3DEG F; ③ in the applicable temperature range of the steam flooding, the specific heat capacity of the water is about 1.0Btu/lb DEG F; fourthly, the heat produced along with oil extraction is about 10 percent of the total heat injected on the ground. From the empirical parameter value analysis described above, namely
So that there are
Vp≈3.0φ(Soi-Sors)fdiwt (4)
The physical meanings and units of the symbols in the formula (4) are as defined above.
According to the OSR definition of the oil/steam ratio, it is obtained
So the calculation formula of the instantaneous oil/steam ratio before the steam flooding steam breakthrough can be obtained as follows,
OSR＝3.0φ(Soi-Sors)fd (6)
1.2 instantaneous oil-to-steam ratio calculation after steam flooding steam breakthrough
The crude oil volume calculation formula after steam flooding steam breakthrough is as follows,
therefore, the calculation formula of the predicted oil-steam ratio after the steam flooding steam breakthrough can be obtained as
OSR＝3.0φ(Soi-Sors)fdG(t) (9)
Equation (9) shows that after steam breakthrough, the oil/steam ratio is not only related to steam quality, reservoir parameters, but also as a function of time, which varies with G (t). G (t) the value of the function decreases with increasing time, so that the steam flooding instantaneous oil/steam ratio after steam breakthrough also decreases according to the same law of change as g (t).
The foreign scholars Chu (see Chu, C.: State of the Art Review of Steamflood Field Projects [ J ]. Jour.of Pet.Tech., October 1984, pp.1887-1902.) analyzed the reasonable data of 28 foreign successful steam flooding fields through statistics, he did not count different conditions before and after steam breakthrough respectively, and given the empirical formula of the statistical results of the oil/steam ratio OSR (suitable for both before and after steam breakthrough) suitable for successful steam flooding:
in formula (10):
d-buried depth, ft;
h-thick layer thickness, ft;
theta-oil layer dip angle, °;
μ — crude oil viscosity; mPa.s;
k-oil layer permeability, mD;
Soi-initial oil saturation of the oil layer.
2 steam flooding applicable steam dryness determination method
2.1 steam quality calculation before steam flooding steam breakthrough
According to the steam-drive-to-steam ratio OSR definition, i.e. have
Well bottom steam dryness f obtained by finishingdIs expressed as
Now, by combining the steam dryness equation (11) with the empirical equation (10) of Chu, the calculation equation (12) for determining the steam dryness before the steam flooding steam breakthrough, which is provided by the invention, can be obtained as
2.2 steam dryness calculation after steam flooding steam breakthrough
The applicable steam dryness calculation formula after the steam drive steam breakthrough is as follows,
equation (13) shows that after a steam breakthrough, steam quality is not only related to reservoir parameters, but it is a function of time, with specific values that decrease as time increases.
2.3 verification of steam dryness calculation method applicable to steam flooding
The invention verifies the correctness and the accuracy of the steam dryness formula by applying the actual production data of 40 steam flooding oil reservoirs in the Liaohe oil field.
The actual situation of 40 steam flooding sites is as follows: the same 40 steam flooding is the successful case of the common thickened oil steam flooding in the middle and deep layers worldwide. (1) Before steam breakthrough, the steam quality value actually applied to the on-site construction of 40 steam flooding blocks is 50%. (2) Simultaneous 40 steam flooding experience t*Steam breakthrough occurred after 3.5 years. (3) The average steam quality used for 40 lots 6 years after steam breakthrough was about 45%.
Theoretically calculating input parameters: the parameters input during calculation by the method are taken from Liaohe oil field 40 steam drive pilot test well groups, and the 40 oil reservoir parameters are as follows: the oil layer burial depth is 924m, the effective thickness of the oil layer is 30m, the crude oil viscosity is 3100mPa · s, the porosity is 0.30, the oil layer inclination angle is 6-15 °, 10 ° is taken, the original oil saturation is 0.55 °, the residual oil saturation after steam flooding is generally 0.06-0.15, the average value is 0.11, the permeability is 1490mD, and the steam breakthrough time t is 3.5 years.
The method of the invention has the following calculation results: firstly, substituting the actual data of 40 blocks of steam into formula (12) calculation, and calculating to obtain the steam dryness f before breakthrough of 40 blocks of steam driven steamd0.4963. ② substituting 40 related data into formula (13) to calculate, and obtaining steam after 6 years break (i.e. t)*3.5, t 3.5+6 9.5) may be calculated as 35.83% steam dryness, with an average steam dryness of (0.4963+0.3583)/2 of 42.73% for 6 steam breakthrough years.
And (4) verification result: the calculated values of the formula (12) and the formula (13) are in good accordance with the steam dryness value used in the actual production of 40 blocks, and particularly the numerical simulation design result of the pilot test scheme of 40 blocks of steam drive is consistent with the calculated values of the formula (12) and the formula (13).
3 steam flooding optimal steam injection (heat) rate determination method
3.1 optimal steam injection (Heat) Rate calculation before steam flooding steam breakthrough
The invention determines the optimal steam injection rate at this stage mainly starts from three aspects, firstly, the optimal but most extreme condition is considered, namely according to the view point of foreign thermal recovery experts K.C.hong (see [ U.S. ] K.C. flood, steam flooding reservoir management [ M ]. Yueqingshan et al translation. Beijing: oil industry publishing company, 1996, pp.108-330.), the heat produced along with oil recovery is considered to be zero (namely, the heat utilization rate under the condition is the highest); secondly, the steam injection displacement rate is considered to be consistent with the production capacity; thirdly, the determined heat injection rate can reduce the residual oil quantity in the formation to the minimum.
1) Optimal heat injection rate in relation to heat utilization
The basic purpose of realizing energy balance of the steam flooding reservoir by injecting steam (or heat) into the ground is to heat the oil layer and reduce the viscosity of underground crude oil, thereby obtaining effective steam band growth. That is, from the viewpoint of k.c. hong, the effective amount of heat injected into the ground in the form of steam can be expressed as,
in the Kern-River steam flooding field test project of the United states, the test result is obtained through tests
The value is approximately equal to 12% of the total heat injected (approximately
About 20% of the total heat input, i.e., taking into account the statistics of most steam drive site production practices, the effective heat injected at the surface should be,
it is clear that the U.S. Kern-River steam flood field experience is about 20% less than the theoretical value of equation (14), but these two equations are not without evidence. Thus, the present invention employs the average of both equations (14) and (15) as one of the methods for determining the optimal heat (or steam) injection rate prior to steam flooding steam breakthrough, namely
Note that: steam injection Rate i in equation (16)wHas the units of bbl/day and i in the formula (15)wUnit of (ft)3Different from day, the rest are the same as before.
2) Optimal steam injection rate in relation to steam coverage area
Successful steam flooding development practices at home and abroad show that the steam flooding steam breakthrough generation time is about t*About 3-4 years, and in the period of time, using the applicable steam dryness fdThe number is iwThe steam injection rate of the steam injection device injects heat, and a steam belt just reaches the steam driveTotal coverage of well group area. Only the ideal case is considered, that is, the heat utilization rate of the steam flooding is considered to be high, and the theoretical analysis formula (17) is established.
As can be derived from a theoretical analysis,
so that the method has the advantages that,
get A0Is equal to the actual area of the steam injection well group (network), when area A0Unchanged and exactly equal to the actual well group area (constant), then it is available,
the finishing agent can be obtained by finishing,
namely, the method comprises the following steps:
application formula (19) for steam flooding field actual well group (well pattern) area A0Expected steam flooding steam breakthrough time t*After the parameters are equal, the steam injection rate i can be obtainedw。
In formula (19):
iw-steam injection rate, bbl/day;
A0-steam injection well group area (constant), acre;
t*the steam breakthrough time can be 3-4 years according to experience;
Khr、Kho、Do、Drthermal conductivity and thermal diffusivity of overburden and reservoir, Btu/(ft. DEG F. day), ft2/day；
ρwThe density of water at steam temperature is approximately 57.5lb/ft3；
fd-steam dryness;
ΔT＝Ts-TR-representing the difference, F, between the steam temperature in the formation and the original temperature of the formation;
lv is the latent heat of vaporization of water under the conditions of reservoir pressure and temperature, Btu/lb DEG F;
3.2 optimal Heat injection Rate calculation after steam flooding steam breakthrough
After the steam breakthrough, some adjustments need to be made to the steam flooding scheme in order to improve the utilization efficiency of the ground heat injection and improve the economic benefit of the steam flooding development scheme. The content of the adjustment is mainly the adjustment of the steam (heat) injection mode, namely the adjustment of the heat injection quantity. Such as reducing the heat injection speed, reducing the steam dryness, intermittently injecting steam, alternately injecting steam/water, etc. The optimal steam (heat) injection amount at this stage is not only required to maintain Q theoreticallyprodAnd the steam zone coverage area maintains the well group area not to increase or decrease on the premise of keeping the volume of the steam zone to increase normally. Theoretical research results show that the optimal steam injection (heat) rate calculation formula of the steam flooding at the stage after the steam breakthrough is as follows,
based on the calculated decreasing heat injection rate formula (20), the optimal steam injection rate i applicable after the steam flooding steam breakthrough can be calculatedw。
Studies have shown that the heat injection rate after a steam breakthrough is dependent on the heat injection rate before the steam breakthroughAverage heat injection rate
It can be seen that the optimum heat injection rate before steam flooding steam breakthrough
The determination is very critical.
4 steam flooding optimal scheme design method
A design method of a steam flooding scheme is proposed by Yueqing mountain, Zhao Hongshan and Made Sheng (Yueqing mountain, et al, thick oil reservoir steam injection development technology [ M ]. Beijing: Petroleum industry Press, 1998, pp.71-78), which establish a steam flooding operation condition judgment formula, namely formula (21)
In the formula (21), the compound represented by the formula,
d, well spacing of adjacent production wells;
FAthe area coefficient of the well group is 1.0 by a five-point method, 2.6 by an inverse seven-point method and 4.0 by an inverse nine-point method;
n is the ratio of the production wells to the injection wells of the well group, the five-point method is 1, the reverse seven-point method is 2, and the reverse nine-point method is 3;
hzone-thickness of the pure oil layer;
Qs-steam injection rate per reservoir volume within the well group;
q1-single well fluid production rate;
RPIand the ratio of the liquid extraction speed to the steam injection speed of the well group is called the extraction-injection ratio for short.
A design method of a steam flooding scheme of Yueqing mountain, Zhaohong rock and Madeng Sheng considers reservoir pressure as an independent variable, does not consider the functional relation between the reservoir pressure, the steam temperature in the reservoir and the latent heat of vaporization of water, and does not determine the steam dryness f suitable for steam flooding based on the coupling relation between actual reservoir parametersdStrength of injected steam QsProduction injection ratio RPIAnd tools for reservoir pressure effectsVolume calculation formula and calculation method. The method is different from a design method of a steam flooding scheme of Yue Qingshan, Zhao Hongshan and Madein, and a steam flooding theoretical analysis and calculation formula which is based on oil reservoir reality and considers oil reservoir multi-parameter coupling influence is established according to the physical significance of specific parameters.
For the convenience of distinguishing and analyzing from the predecessor method, the calculation formula of the design parameters of the steam flooding scheme of the present invention, which has been described above, is listed as follows:
(1) steam quality before steam flooding steam breakthrough
(2) Steam quality after steam flooding steam breakthrough
(3) Single well steam injection rate iwIs calculated by
(4) Steam injection rate per unit reservoir volume QsIs calculated by
(5) Production injection ratio RPIIs calculated by
(6) Method for calculating well spacing d between adjacent production wells
Based on the above formulas of the present invention, attention is paid to the latent heat of vaporization L of water in the formulasvRelated to reservoir pressure and steam temperature, therefore, once LvAfter determination, the applicable reservoir pressure value can be determined accordingly. On the basis of the above formula, formula (22), formula (24) and formula (25) can be solved simultaneously to obtain RPID, then with RPI、d、Qs、fdAnd checking and comparing the optimal values (or reasonable value ranges) of the parameters to judge whether the design result of the steam drive scheme is optimal or reasonably usable.
Because, before and after steam flooding steam breakthrough iwIs different, the steam injection speed i before the steam breakthroughwIs constant, i after steam breakthroughwIs a time dependent variable, so it is necessary to pay attention to R after steam breakthrough at design timePIAnd QsChange over time. According to the present invention, the analysis and calculation after steam breakthrough are the same as described above, but it should be noted that equation (22) should be applied to determine i firstwAnd then repeating the steps.
5. Design calculation example and related description by applying method of the invention
The calculation steps and the specific method are as follows:
(1) firstly, analyzing and determining the liquid production capacity and the injection capacity of a single well of an oil reservoir.
(2) Based on the actual data information of the steam flooding oil reservoir, the applicable shaft bottom steam dryness value f is calculated by applying the formula (12) and the formula (13)d. If the theoretical calculated steam dryness is greater than or equal to 0.4, the steam dryness can be used as a trial value.
(3) According to the actual data of the oil deposit, the single-well steam injection rate i is calculated by an application formula (22)w。
(4) According to the actual data of the oil reservoir, calculating the steam injection rate Q of the unit oil reservoir volumesJudgment of QsWhether the calculated value is within a reasonable range.
(5) Using the determined oil deposit single well liquid production capacity and the calculated single well steam injection rate iwCalculating and checking the injection-production ratio RPIWhether within a reasonable range.
(6) And calculating whether the well spacing d of the adjacent production wells is consistent with the actual well pattern or not by using the actual oil deposit data and the calculation result of the invention.
(7) Repeatedly optimizing the applicable water vaporization latent heat data according to the reasonable range of the optimal reservoir pressure P during design calculation, and calculating f on the basisd、Qs、RPIAnd d and the like are all within a reasonable (or optimal) value range, the steam flooding scheme is reasonably designed.
The following is a specific description of a Liaohe oil field 40 steam flooding injection-production scheme as an example and is compared with the numerical simulation design scheme result of the block in the early years.
Before design and calculation, the relevant oil reservoir parameters of 40 steam drive pilot test areas in Liaohe oil field are collected and obtained and are shown in table 1.
TABLE 1 Liaohe oil field 40 steam flooding input reservoir parameters
The main results of the pilot test scheme of the present invention for 40 steam drives, which are designed and calculated by applying the theory and the design method, are listed as follows:
(1) statistical analysis of fluid production capacity of 40 oil wells
According to the production data collection and statistical analysis of 40 steam huff-puff stages, the first period and the last period of the steam huff-puff are respectively 51t/d and 26t/d, and the corresponding production pressure difference is respectively 1.5MPa and 0.8 MPa. From this, the liquid production indexes of the first cycle and the last cycle are 34t/(MPa.d) and 32.5t/(MPa.d), respectively, and this result shows that the liquid production index of the oil well is almost constant in the steam throughput stage, and the average value is about 33 t/(MPa.d). Further, the liquid production rate of the oil well was calculated under the conditions of the reservoir pressure of 2MPa and the differential pressure of 1.8MPa on a history-fitted reservoir model by using the numerical simulation method, and the result was that the liquid production index of 62t/d was 34.4 t/(mpa.d). As can be seen from the above analysis, the liquid production index of 40 lotus II reservoirs in steam flooding is about 34 t/(MPa.d).
(2) Statistical analysis of steam injection capability of 40 steam injection wells
The full 40 pieces of steam throughput production data show that the steam injection rate can reach more than 300t/d below the reservoir fracture pressure; the 15-29 well group steam injection data in the same 40 blocks show that the steam injection speed is about 120t/d under the pressure of a steam injection well head of 4 MPa. A comprehensive analysis of these data shows that for any steam flooding scenario, no injection problems occurred for 40 nelumbo reservoirs.
(3) Well group well spacing design with simultaneous 40 steam flooding injection-production parameter optimization and applicability
A. Individual well fluid production determination
This parameter is carefully determined based on steam stimulation tests of the actual reservoir or pilot injection studies of the injected steam. Whether the parameter value accords with the reality or not directly influences the success or failure of the implementation of the steam drive development scheme. According to the analysis of the liquid production index of 40 aligned steam huff-puff oil wells, under the conditions that the oil reservoir pressure in steam flooding is kept at 2.5MPa and the production pressure difference is 1.8MPa, the liquid production capacity of the oil well is 60t/d, and the liquid production capacity q of a single well is conservatively taken in consideration of the current thermal oil recovery process level of China1＝50～55t/d。
B. Steam injection well injection capability determination
The injection capacity is also carefully determined based on actual reservoir data. According to the analysis of the injection capacity of 40 blocks and the comprehensive analysis of the dynamic data of 40 blocks of related oil reservoirs, the injection problem of 40 blocks of nelumbo nucifera II oil reservoirs can not occur to any steam flooding development scheme.
C. Calculation of steam quality for use based on reservoir parameters
According to the theoretical research result of the invention, the steam dryness before the steam flooding steam breakthrough is known as follows:
if it is desired to design a suitable steam quality value after a steam breakthrough, the calculation formula can be:
the input parameters for calculating the steam dryness suitable for steam breakthrough are basically the same as those before breakthrough, namely, the burial depth of 40 oil layers is 924m, the effective thickness of the oil layer is 31m, the viscosity of crude oil is 3100mPa & s, the porosity is 0.30, the inclination angle of the oil layer is 6-15 degrees, the average is 10 degrees, the original oil saturation is 0.55, the residual oil saturation after steam flooding is generally 0.06-0.15, the average is 0.11, the permeability is 1490mD, and the steam breakthrough time t is*After 3.5 years. Then the calculation results can be obtained: steam breakthrough 6 years later (i.e., t)*3.5, t is 3.5+6 is 9.5), the dry weight of the steam available in 40 blocks is 35.83%, and the average dry weight of the steam in 6 years of steam breakthrough is (0.4963+0.3583)/2 is 42.73%.
D. Steam injection rate determination
Based on the oil deposit parameters, the steam dryness value f obtained by calculation is obtaineddCalculating the steam injection rate iwIs composed of
E. Determination of steam injection rate (or steam injection intensity) of unit volume oil reservoir
Calculating steam injection strength Q by using oil reservoir parameterssThe method has the advantages that (1) the,
according to successful steam flooding experience, when the oil layer is shallow (less than 500m), the net total thickness ratio is large (more than 0.6) and the steam dryness at the bottom of the well is high (more than 60 percent), Q can be takens＝1.6～1.7m3/(day ha · m); when the oil layer is deep, the net total thickness ratio is small and the steam dryness at the bottom of the well is low, Q can be takens＝1.7～1.8m3/(day ha · m); the deep and net total thickness ratio of the oil layer of the pilot test area of the simultaneous 40 steam drives is about more than 0.6, and theoretical calculation shows that the dryness of steam at the bottom of the well is moderate, so that the optimal steam injection strength Q is designed through comprehensive analysiss＝1.6～1.8m3/(day ha m), it can be seen that the calculated values for the design of the present invention are in the optimal value range.
F. Determination of production-injection ratio
Calculating the extraction-injection ratio R according to the calculated resultPIThe method has the advantages that (1) the,
in general, the production-injection ratio RPIThe value is affected by the depth of the reservoir, the net gross thickness ratio and the dryness of the steam at the bottom of the well. When the oil layer is shallow, the net total thickness ratio is large and the steam dryness is high, R can be selectedPI1.3; when the oil layer is deep, the net total thickness ratio is small and the steam dryness is low, R can be selectedPI1.2. Because, the neat 40 oil layers are deep (more than 500m), the net total thickness is large (more than 0.53 and close to 0.6), and the applicable steam dryness is moderate (not more than 60 percent) through calculation; in addition, the original formation pressure of the full 40 reservoirs is 8-11MPa, the middle pressure of an oil layer is 9.5MPa, and the oil layer pressure of the full 40 steam-driven pilot test area is reduced to 2-3MPa by 6 months in 1997, so that the optimal production-injection ratio R is obtained through comprehensive analysisPIThe calculated value of the design of the invention is close to the optimal value 1.2-1.3.
G. Steam flooding well group parameter determination
Designing a steam flooding well group by utilizing the parameters, calculating the well distance d of adjacent production wells, namely,
because the reservoir parameters input during d calculation and f calculationd、iw、Qs、RPIThe reservoir parameters input when the parameters are equal are a group of parameters, so the calculation results of all the parameters are the same, and the obtained conclusion is consistent. The optimal value results of main technical parameters of the 40-block steam drive pilot test designed by the theory and the method are summarized in a table 2.
TABLE 2 summary of theoretical calculation results of main technical parameters of 40 steam drive pilot tests
The comparison between the pilot test scheme result of the 40 steam-driven block calculated by applying the theory and the design method of the invention and the pilot test scheme result of the 40 steam-driven block designed by applying the numerical simulation method in units such as Liaohe oil field and the like is shown in Table 3 (in detail, Yue Qingshan, oil reservoir engineering theory and practice, Beijing, oil industry Press, 2012, pages 127-142), the comparison analysis shows that the design results are quite consistent, and the summary analysis shows that the design results are both in good accordance with the pilot test result of the 40 steam-driven block, thereby fully verifying the correctness of the theory and the design method of the invention. As mentioned above, the design results of the invention clearly show that compared with the numerical simulation design method of the steam flooding scheme, the theory and the design method of the invention are simple, economical and practical, and are particularly convenient for the field operation of the oil field.
TABLE 3 comparison table of actual indexes and scheme design indexes of 40 steam drive pilot tests
The design result based on the theory and the design method of the invention is compared with the actual steam drive development effect of 40 Liaohe oil field, for example, as shown in figure 1, it can be seen that good results in accordance with the reality can be obtained by applying the theory and the design method of the invention to design a steam drive scheme.
Claims (5)
1. A steam flooding scheme optimization design method based on oil reservoir conditions comprises the following calculation steps:
(a) firstly, combining with the analysis of an actual heavy oil reservoir, determining the liquid production capacity and the injection capacity of a single well of the oil reservoir, and further judging whether the oil reservoir is suitable for steam flooding and an available well pattern form of the oil reservoir, wherein the liquid production capacity and the injection capacity of the single well of the oil reservoir are determined by a steam flooding pilot test, a special pilot injection and production test, or analysis and summary of successful steam swallowing and steam flooding empirical data;
(b) calculating the steam dryness value f at the bottom of the well by using the oil reservoir basic datadSingle well steam injection rate iwSteam injection rate Qs and extraction-injection ratio R of unit oil reservoir volumePIAnd a production well spacing d; optimizing and determining the optimal well placement mode and the optimal operating condition parameters of the steam flooding through the calculated data, and simultaneously expecting the development effect of the steam flooding;
the bottom hole steam dryness value f in the step bdThe calculation method of (2) is as follows:
(1) steam quality before steam flooding steam breakthrough
(2) Steam quality after steam flooding steam breakthrough
Each physical parameter contained in the above formula is an actual reservoir parameter, and these parameters are:
d, oil layer buried depth ft;
h-thickness of pure oil layer, ft;
theta-oil layer dip angle, °;
μ — crude oil viscosity; mPa.s;
k-oil layer permeability, mD;
phi-reservoir porosity;
Soi-initial oil saturation of the oil layer;
Sors-residual oil saturation in the steam band;
g (t) -correction coefficients related to steam flood development time;
the single-well steam injection rate i in the step bwThe calculation method of (2) is as follows:
each physical parameter contained in the above formula is an actual reservoir parameter, and these parameters are:
iw-steam injection rate, bbl/day;
A0-steam injection well group area, acre;
t is steam flooding steam breakthrough time, and 3-4 years can be taken according to experience;
Khr、Kho、Do、Drthermal conductivity and thermal diffusivity, Btu/(ft. ° F.day), ft, of the overburden and oil reservoir, respectively2/day；
ρwWater density at steam temperature, taken approximately as 57.5lb/ft3；
fd-steam dryness values, calculated from the previous;
ΔT＝Ts-TR-represents the difference, F, between the steam temperature in the reservoir and the original temperature of the formation;
LVreservoir pressure and reservoir steam temperature TsLatent heat of vaporization of water under conditions, Btu/lb DEG F;
the steam injection rate Q per unit oil reservoir volume in the step bsThe calculation method of (2) is as follows:
each physical parameter contained in the above formula is an actual reservoir parameter. Parameter hzoneRepresents the pure oil layer thickness, ft; the physical meaning of other parameters is the same as before; q obtained by the above formulaSIn units of bbl/(day. Note that multiplying the result by 1.3 changes the unit to m3/(day.ha.m)；
The production-injection ratio R in the step bPIThe calculation method of (2) is as follows:
each physical parameter contained in the above formula is an actual reservoir parameter, and these parameters are:
A0-steam injection well group area, acre;
ρwwater density at steam temperature, taken approximately as 57.5lb/ft3；
n is the ratio of the production wells to the injection wells of the well group, the five-point method is 1, the reverse seven-point method is 2, and the reverse nine-point method is 3;
q1-single well fluid production rate;
Khr、Kho、Do、Drthermal conductivity and thermal diffusivity, Btu/(ft. ° F.day), ft, of overburden and oil layer, respectively2/day；
fd-steam dryness, calculated from the previous;
t is steam flooding steam breakthrough time, and 3-4 years can be taken according to experience;
ΔT＝Ts-TR-represents the difference, F, between the steam temperature in the reservoir and the original temperature of the formation;
LVreservoir pressure and reservoir steam temperature TsLatent heat of vaporization of water under conditions, Btu/lb. ° F;
the method for calculating the well spacing d of the adjacent production wells in the step b is as follows
All physical parameters contained in the formula are actual oil deposit parameters, and the parameter FARepresenting well group area coefficient, for a five-point well pattern FA1.0, 2.6 for a reverse seven-point well pattern and 4.0 for a reverse nine-point well pattern; the physical meaning of the other parameters is the same as before.
2. The method of claim 1, wherein the steam flooding scheme in step b has a downhole steam quality value fdGreater than or equal to 0.4, the corresponding reservoir pressure is less than 5MPa, then fdThe value may be used as a trial value.
3. The method of claim 1, wherein the calculation of Qs in step b is greater than or equal to 1.5m3V. (day. ha. m), i.e. within reasonable ranges.
4. The method of claim 1, wherein the optimal design of the steam flooding scheme based on the reservoir conditions is determined as the production-injection ratio R in the step bPIThe calculated value is greater than or equal to 1.2, i.e. within a reasonable range.
5. The method of claim 1, wherein the relative deviation between the calculated distance d between adjacent production wells and the actual well pattern data in step b is less than or equal to 5%, i.e. within a reasonable range.
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