CN114491900A - Method for determining parameters of unstable water injection of oil field with drainage well pattern - Google Patents
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- 239000007924 injection Substances 0.000 title claims abstract description 185
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Abstract
The invention relates to a method for determining parameters of unstable water injection of a drainage pattern oil field, and belongs to the technical field of oil exploration and development. According to the method, the corresponding water injection mode, the water injection half period and the water injection quantity change range are determined according to the characteristics of the oil field with the drainage pattern and the problems in the water injection process, three factors of the water injection mode, the water injection half period and the water injection quantity change range are subjected to orthogonal experiments, water injection simulation schemes with different water injection parameter combinations are designed, and the water injection parameter corresponding to the water injection simulation scheme with the optimal accumulated yield is selected as the final water injection parameter. The method determines the type and the range of the water injection parameters based on the characteristics of the drainage oil field, selects the parameters by taking the highest accumulated yield as a target through numerical simulation, enables the finally determined parameters to be more suitable for the drainage oil field, and can effectively improve the water injection effect of the drainage oil field.
Description
Technical Field
The invention relates to a method for determining parameters of unstable water injection of a drainage pattern oil field, and belongs to the technical field of oil exploration and development.
Background
The unstable water injection is also called unstable water injection, intermittent water injection or pulse water injection, theoretical research and indoor experiments are carried out in the fifty and sixties at home and abroad, the SulUnion SulCuchev firstly puts forward the concept of the unstable water injection in the 50 s, and the SulCongress considers that the water injection parameters are periodically changed, and the unstable state is established in a reservoir stratum so as to improve the yield of crude oil. After 1964, mine field tests and industrial exploitation in more than 50 oil fields in the former Soviet Union can achieve certain effects, but a complete unstable water injection technical scheme is not formed. The application of the traditional unstable water injection technology is to oil-water well patterns in single small blocks or well groups with definite oil-water relation in local oil fields, and Chinese patent application with application publication number CN1912338A discloses a periodic injection and production method of a water injection sandstone oil field, which only considers the influence in the well groups although researching parameters of unstable water injection of the sandstone oil field, but not only the influence among wells in the well groups for the drainage injection and production well patterns, but also the influence among injection and production well groups adjacent to a target area can mutually influence each other, so the technology has limitation when facing the oil field with complicated injection and production relation, namely the drainage injection and production well pattern oil field.
At present, many oil fields adopting a drainage injection and production well pattern development mode in the world enter the later stage of ultrahigh water content. The drainage well pattern is relatively fixed in injection and production, a relatively fixed injection and production flow line is easily formed in the middle and later development stages, the water-containing rising speed of an oil field is increased, the residual oil exploitation difficulty is increased, unstable water injection has the effect of reducing the water content and improving the crude oil yield, and therefore the drainage well pattern is applied to the development stage in the middle and later development stages of the drainage well pattern, how to control the water-containing rising speed of a drainage well pattern oil reservoir, delay the yield to decrease progressively and dig the residual oil in the submerged wells is the key for improving the oil field development effect in the middle and later development stages and improving the recovery ratio.
Disclosure of Invention
The invention aims to provide a parameter determination method for unstable water injection of a drainage pattern oil field, which aims to solve the problems of low recovery ratio and poor oil field development effect of unstable water injection of the existing drainage pattern oil field.
The invention provides a method for determining parameters of unstable water injection of a drainage pattern oil field to solve the technical problems, which comprises the following steps:
1) determining three water injection modes according to the existing characteristics of the oil field with the drainage pattern;
2) determining a water injection half period according to the reduction process of the water injection of the oil field of the previous drainage pattern;
3) designing the variation range of the water injection quantity according to the stratum energy conservation condition, the on-site water injection well and the equipment condition;
4) taking a water injection mode, a water injection half period and a water injection quantity variation range as three factors of unstable water injection; performing orthogonal experiments on the three unstable water injection factors, formulating water injection simulation schemes with different water injection parameter combinations, predicting the accumulated yield of each water injection simulation scheme by using a numerical model, and selecting the water injection parameter corresponding to the water injection simulation scheme with the optimal accumulated yield, wherein the water injection parameter is the finally determined water injection parameter.
According to the method, the corresponding water injection mode, the water injection half period and the water injection quantity change range are determined according to the characteristics of the oil field with the drainage pattern and the problems in the water injection process, three factors of the water injection mode, the water injection half period and the water injection quantity change range are subjected to orthogonal experiments, water injection simulation schemes with different water injection parameter combinations are designed, and the water injection parameter corresponding to the water injection simulation scheme with the optimal accumulated yield is selected as the final water injection parameter. The method determines the type and the range of the water injection parameters based on the characteristics of the drainage oil field, selects the parameters by taking the highest accumulated yield as a target through numerical simulation, enables the finally determined parameters to be more suitable for the drainage oil field, and can effectively improve the water injection effect of the drainage oil field.
Further, in order to better adapt to the characteristics of the drainage oil field and improve the water injection effect of the drainage oil field, the three water injection modes respectively comprise:
row-by-row substitution type unstable water injection: the water injection quantity of the water wells of the adjacent water well rows is periodically changed alternately, and is increased and decreased;
streamline staggered unstable water injection: the water injection quantity of adjacent wells in the same well row is periodically changed alternately, and the water injection quantity is increased and decreased;
full-stop full-injection type unstable water injection: the water injection amount of all the wells is synchronously and periodically changed alternately, and the water injection amount is increased and decreased.
Further, the half period of water injection is 5 days, 15 days or 30 days.
Furthermore, the variation range of the water injection amount comprises 0.5-1.5 times of the original water injection amount and 0-2 times of the original water injection amount.
Further, the numerical model prediction is realized by adopting numerical simulation Petrel software.
Drawings
FIG. 1 is a schematic representation of the geological structure of a K field in an embodiment of the present invention;
FIG. 2 is a schematic illustration of the sedimentary facies of a K oilfield in an embodiment of the present invention;
FIG. 3 is a schematic diagram of a K-field pattern arrangement in an embodiment of the present invention;
FIG. 4 is a schematic view of a streamline distribution of a K-field well pattern numerical simulation in an embodiment of the present invention;
FIG. 5 is a schematic diagram of the corresponding relationship between the K oil field wells in the embodiment of the present invention;
FIG. 6 is a schematic illustration of a K-field I-zone well pattern profile in an embodiment of the present invention;
FIG. 7 is a schematic layout of a test area selected from a K field in an embodiment of the present invention;
FIG. 8-a is a schematic production curve for well 1 of K oilfield in accordance with an embodiment of the present invention;
FIG. 8-b is a schematic representation of a production curve for a K oilfield 2 well zone in an embodiment of the present invention;
FIG. 9-a is a schematic representation of the oil saturation of the well zone K oilfield 1 in accordance with an embodiment of the present invention;
FIG. 9-b is a schematic representation of the oil saturation of the K oilfield 2 well zone in an embodiment of the present invention;
FIG. 10 is a schematic diagram of the waterflooding pattern determined for a drainage field in accordance with the present invention;
FIG. 11-a is a water cut prediction plot for a different waterflooding scenario for a 718 well in an example of the present invention;
FIG. 11-b is a graph of predicted daily oil production for various waterflooding schemes for a 718-well in an example embodiment of the present invention;
11-c are graphs of predicted cumulative oil production for various waterflooding schemes for 718 wells in an example of the present invention;
FIG. 11-d is a saturation prediction plot for an existing waterflooding scenario for a 718 well in an embodiment of the present invention;
FIG. 11-e is a saturation prediction plot for a 718 well using a waterflooding scheme of the present invention in an example of the present invention;
FIG. 12 is a schematic view of a selected test well region in an embodiment of the present invention;
FIG. 13 is a schematic diagram of the oil-water well distribution and the remaining oil saturation distribution of the layer I of the test well zone selected in the example of the present invention;
FIG. 14-a is a schematic diagram showing the injection and production reaction curve of an oil-water well in a test well zone selected in the example of the present invention;
FIG. 14-b is a simulation of the injection and production flow lines of an oil-water well for a test well zone selected in an embodiment of the present invention;
FIG. 15 is a schematic diagram of a water well flooding scheme for a test well zone selected in an example of the present invention;
FIG. 16 is a graphical illustration of well production from a well zone following an unstable waterflood in an embodiment of the present invention;
FIG. 17 is a flow chart of a method for determining parameters for a displaced pattern oilfield unstable waterflood of the present invention.
Detailed Description
The following further describes embodiments of the present invention with reference to the drawings.
The invention designs three water injection modes aiming at the characteristics of a plurality of corresponding water wells of a single oil well, complex oil-water relation and the like in the drainage pattern oil field, and the problems that the flow lines between oil wells and water wells are relatively fixed and the retention area of residual oil between wells is difficult to be subjected to water flooding; determining a water injection half period according to the reduction process of the water injection of the oil field of the previous drainage pattern; designing the variation range of the water injection quantity according to the stratum energy conservation condition, the on-site water injection well and the equipment condition; taking a water injection mode, a water injection half period and a water injection quantity variation range as three factors of unstable water injection; performing orthogonal experiments on the three unstable water injection factors, designating water injection simulation schemes with different water injection parameter combinations, predicting the accumulated yield of each water injection simulation scheme by using a numerical model, and selecting the water injection parameter corresponding to the water injection simulation scheme with the optimal accumulated yield, wherein the water injection parameter is the finally determined water injection parameter. The implementation flow is shown in fig. 17, and the specific process is as follows.
The specific implementation process of the invention is described in detail by taking the K oil field as an example, the K oil field is located in the middle Asia, has a relatively simple structure, is relatively self-contained in an oil reservoir (as shown in fig. 1), and consists of four fault blocks, wherein the I fault block (main fault block) is developed by adopting a row-shaped well pattern and is currently in an ultra-high water-cut period, namely the middle and later periods of oil field development. The oil field belongs to a mesopore-hypotonic-structure sandstone oil reservoir, and the problems that the water content rises quickly, the yield is reduced greatly, the effect of a water well is poor through multiple times of profile control measures, more residual oil exists and the excavation difficulty is high are faced at present. Before determining the unstable water injection parameters of the oil field, research is carried out on reservoir heterogeneity, well pattern adaptability and residual oil potential, and whether the oil field is suitable for unstable water injection is judged.
Reservoir heterogeneity analysis: as shown in fig. 2, the K oil field is composed of three sedimentary phases, namely a riverway phase, a tidal sand dam phase and a tidal surge phase, through statistical analysis of geological parameters of the K oil field, the overall heterogeneity on a plane is moderately strong, the interlayer heterogeneity is moderately strong, the heterogeneity in the reservoir layers of the riverway phase and the tidal sand dam phase is moderately strong in the in-layer aspect, and the heterogeneity of the tidal surge phase is weak. On the whole, the heterogeneity of the K oil field is moderate and strong, and the stronger the heterogeneity, the more suitable for the development by adopting an unstable water injection mode.
Well pattern adaptability analysis: as shown in FIG. 3, the development of the K oil field adopts a row-shaped cutting well pattern, the current average well spacing is 240-350m, and the water drive control degree of the oil field is 91.6 percent and the water drive utilization degree is 71.2 percent through calculation, which belong to a class of water drive control conditions; as shown in fig. 4 and 5, the flow lines after numerical simulation are distributed uniformly, the reservoir plane communication degree is better, and the corresponding relation between oil wells and water wells is good.
Residual oil potential analysis: as shown in figure 6, the I-layer system well pattern of the K oil field is perfect, the reserve utilization degree is high, and the residual potential is mainly residual oil which is detained among wells, distributed and dispersed and locally enriched. At present, the extraction degree is 30.86 percent, the residual recoverable reserves are 483.5 ten thousand tons, and the residual recoverable reserves are mainly concentrated on the upper small layer and account for 78.3 percent of the residual recoverable reserves.
In summary, the K-field in this embodiment can be injected with water in an unstable injection manner.
And determining an unstable water injection mode according to the development characteristics of the oil field of the drainage pattern.
The drainage well pattern water injection has the characteristics that a single oil well is large in number of corresponding wells, complex in oil-water relationship and the like, flow lines between oil wells and water wells are relatively fixed, and residual oil retention areas between wells are difficult to spread by water flooding. For the embodiment, a well region with representative and generalizable K oil field is selected as an experimental well region, and a typical well region with different deposition types, different water contents and different remaining oil potentials is preferably selected as an experimental region, as shown in fig. 7, in the embodiment, a well region No. 1 and a well region No. 2 are selected as experimental well regions.
The number 1 well zone and the number 2 well zone are typical row-type well patterns, the injection-production well ratio is 1:1, and the average injection-production well spacing is 621m and 623 m. No. 1 well zone has 8 ports of oil well and water well, 8 ports of daily produced liquid 1183t/d, daily produced oil 44t/d, water content 96%, accumulated oil 810923t, production degree 39.4% and residual recoverable reserve 14.8 multiplied by 104t; no. 2 well zone has 6 mouths of oil well and 6 mouths of water well, daily produced fluid 413t/d, daily produced oil 26t/d, water content 93.6%, accumulated oil 381921t, production degree 29.7%, and residual recoverable reserve 21.6X 104t, as shown in table 3:
TABLE 3
The production curves of the two wells are shown in FIGS. 8-a and 8-b, and the residual oil saturation conditions are shown in FIGS. 9-a and 9-b, from which it can be seen that the residual oil types of both wells are mainly interwell retention type residual oil. In the research process, various independent variable (water injection amount, water injection mode and the like) schemes need to be taken into consideration in theoretical experiments, and reference and comparison are carried out to obtain the optimal scheme. On-site production can only select the optimal scheme which can meet the on-site conditions from theoretical schemes due to the restriction of various conditions, such as labor cost, equipment bearing capacity and the like.
Three unstable water injection modes are designed for the retention type residual oil between wells, and as shown in fig. 10, the first mode is row-by-row alternative unstable water injection: the water injection quantity of the water wells of the adjacent water well rows is periodically changed alternately, and is increased and decreased; streamline staggered unstable water injection: the water injection quantity of adjacent wells in the same well row is periodically changed alternately, and the water injection quantity is increased and decreased; full-stop full-injection type unstable water injection: the water injection amount of all the wells is synchronously and periodically changed alternately, and the water injection amount is increased and decreased.
And in the selection of the half period of water injection, analyzing the water injection effect process of the oil well of the I layer system according to the dynamic analysis work result of the previous K oil field, and finally determining the experimental parameters of the half period to be 5 days, 15 days and 30 days in consideration of the risk of sudden flooding.
At present, the injection-production ratio of the layer I is about 1, the stratum energy maintaining condition is good, the conditions of a field water injection well and equipment are considered, and meanwhile, in order to prevent sudden flooding of an oil well, the variation range of the water injection quantity is designed to be 0.5-5 times of the original water injection quantity alternately and 0-2 times of the original water injection quantity alternately.
Within the range of the selected No. 1 well and the No. 2 well, orthogonal experiments are designed according to three factors of different water injection modes, water injection quantity fluctuation ranges and water injection periods, and 36 water injection schemes are formulated and respectively shown in tables 4 and 5. And predicting the cumulative yield corresponding to each simulation scheme by utilizing numerical simulation, and selecting the water injection parameter corresponding to the water injection scheme with the highest cumulative yield as the final water injection parameter of the well region. For example, for the 718 well, the water cut prediction of the water flooding scheme of the present invention is shown in fig. 11-a, the daily oil production prediction is shown in fig. 11-b, and the cumulative oil production prediction is shown in fig. 11-c, from which it can be seen that the water flooding scheme of the present invention can reduce the water cut, increase the oil production, and increase the cumulative oil production, the oil saturation of the existing water flooding scheme is shown in fig. 11-d, and the oil saturation obtained by using the water flooding scheme of the present invention is shown in fig. 11-e. The embodiment adopts Petrel-re software to carry out numerical simulation, and adopts a formulated water injection scheme on the basis of the existing production history fitting of the oil-water well until the current time, so that the water injection rate of the well periodically changes in a specified time period in the future can be automatically calculated and predicted according to indexes such as the accumulated oil production rate, the water content and the like of the corresponding oil well.
TABLE 4
TABLE 5
In order to further explain the effect of the invention, the method is applied to a specific rowed well region of the K oil field, different from theoretical experiments, the field application needs to consider a plurality of factors such as actual equipment conditions of the well field, personnel operation conditions and the like, and the following principle is followed for selecting a test well region: 1) the water well in the well area has certain injection increasing potential, the water injection pipe column is intact, and the ground meets the conditions; 2) the corresponding relation of oil-water wells in the well area is good, and the effect of injection and production in history is achieved; 3) the influence on the overall yield (high production well) of the I-layer system is reduced as much as possible.
Based on the selection principle, the invention selects a test well zone in the K oil field, as shown in FIG. 12. The daily water injection rate of the 2-hole water well distributed in the test area is 450m3And d, 8 oil wells, the daily liquid yield of 900t/d, the daily oil yield of 32.2t/d and the water content of 96.4 percent. The permeability is 14.1-18.6md, and the effective thickness is 9.9-12.4 m; the connectivity on the plane of the reservoir is good, and the development is stable in the longitudinal direction; geological reserve of test well region 91.1 multiplied by 104t, recoverable reserve 39.5X 104t, the calibrated recovery ratio is 43.4 percent;
the remaining oil of the well zone is mainly remained oil between wells, as shown in FIG. 13, daily production fluid of the well zone is 900t/d, daily production oil is 32.2t/d, water content is 96.4%, and cumulative production oil is 50.6X 104t, splitting to the well area for 21.05X 10 cumulative oil recovery4t, the extraction degree is 23.1%, and the residual recoverable reserve is 18.5 × 104t, as shown in table 6; according to the injection and production reaction curve of the oil-water well in the well region, the oil well in the well region has the water injection effect of the water well, and the injection and production are correspondingly obvious, as shown in figures 14-a and 14-b; the pumping pressure of the well is different from the oil pressure, the daily water injection rate of a single well is 200-3/d, the well has certain injection increasing potential, the casing pressure is 1-5MPa, and the water injection is stable, as shown in the table 7.
TABLE 6
TABLE 7
| Number of water well | 167 well | 219 well |
| Pressure of |
15 | 15.4 |
| Oil pressure MPa | 6.0 | 10.5 |
| Pressure of jacket MPa | 5 | 1.0 |
| Daily water injection quantity m3/ |
200 | 250 |
| Accumulated water injection amount m3 | 393959 | 1141108 |
In consideration of reducing the yield risk, according to the water injection condition of a water well in the current well zone and aiming at the conditions of high extraction degree, high water content and high liquid volume of a test well zone, the corresponding water injection parameters are determined by the unstable water injection parameter determination method, and the following suggestions are proposed in the field test well zone:
adopts streamline staggered water injection, the water injection quantity adopts 0.5 to 1.5 times of change, namely 167 wells with 100-3D, 219 well 125-375m3D; the water injection half period is 30 days by combining the working system of field operators; during unstable waterflooding, daily oil production from the well remained unchanged, as shown in fig. 15; after unstable water injection is carried out in 1 month in 2020, the water content of the well area is in a descending trend, and as shown in FIG. 16, after the on-site statistics of the KKM oil field, the oil well of the well area is tested to reach 99 tons of oil increase in total in the bottom test of 3 months. Therefore, the method for determining the parameters of unstable water injection can effectively improve the water injection effect.
Claims (5)
1. A method for determining parameters of unstable waterflood in a drainage pattern oil field is characterized by comprising the following steps:
1) determining three water injection modes according to the existing characteristics of the oil field with the drainage pattern;
2) determining a water injection half period according to the reduction process of the water injection of the oil field of the previous drainage pattern;
3) designing the variation range of the water injection quantity according to the stratum energy conservation condition, the on-site water injection well and the equipment condition;
4) taking a water injection mode, a water injection half period and a water injection quantity variation range as three factors of unstable water injection; performing orthogonal experiments on the three unstable water injection factors, formulating water injection simulation schemes with different water injection parameter combinations, predicting the accumulated yield of each water injection simulation scheme by using a numerical model, and selecting the water injection parameter corresponding to the water injection simulation scheme with the optimal accumulated yield, wherein the water injection parameter is the finally determined water injection parameter.
2. The method for determining the parameters of the unstable waterflooding of the oil field with the drainage pattern as claimed in claim 1, wherein the three waterflooding modes are respectively as follows:
row-by-row substitution type unstable water injection: the water injection quantity of the water wells of the adjacent water well rows is periodically changed alternately, and is increased and decreased;
streamline staggered unstable water injection: the water injection quantity of adjacent wells in the same well row is periodically changed alternately, and the water injection quantity is increased and decreased;
full-stop full-injection type unstable water injection: the water injection amount of all the wells is synchronously and periodically changed alternately, and the water injection amount is increased and decreased.
3. The method for determining parameters of displaced well pattern oilfield instability waterflooding as in claim 1 or 2, wherein the half cycle of waterflooding is 5 days, 15 days, or 30 days.
4. The method for determining the parameters of the unstable waterflood of the oil field with the rowed well pattern as defined in claim 1 or 2, wherein the variation range of the waterflood comprises 0.5-1.5 times of the original waterflood and 0-2 times of the original waterflood.
5. The method for determining the parameters of the unstable waterflood in the oil field with the latticed well pattern as defined in claim 1 or 2, wherein the numerical model prediction is realized by adopting numerical simulation Petrel software.
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