CN116856922A - Experimental device and method for distribution form of dominant channels among steam flooding wells of heavy oil reservoirs - Google Patents
Experimental device and method for distribution form of dominant channels among steam flooding wells of heavy oil reservoirs Download PDFInfo
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- 238000010795 Steam Flooding Methods 0.000 title claims abstract description 64
- 238000000034 method Methods 0.000 title claims abstract description 63
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- 239000003921 oil Substances 0.000 claims abstract description 74
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- 238000002347 injection Methods 0.000 claims abstract description 31
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- 238000003860 storage Methods 0.000 claims abstract description 31
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- 238000011161 development Methods 0.000 claims description 20
- 238000010793 Steam injection (oil industry) Methods 0.000 claims description 19
- 239000003822 epoxy resin Substances 0.000 claims description 11
- 229920000647 polyepoxide Polymers 0.000 claims description 11
- 239000012153 distilled water Substances 0.000 claims description 10
- 239000012530 fluid Substances 0.000 claims description 10
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- 229920005989 resin Polymers 0.000 claims description 6
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- AKHNMLFCWUSKQB-UHFFFAOYSA-L sodium thiosulfate Chemical compound [Na+].[Na+].[O-]S([O-])(=O)=S AKHNMLFCWUSKQB-UHFFFAOYSA-L 0.000 claims description 6
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Classifications
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- 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
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02A—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE
- Y02A10/00—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE at coastal zones; at river basins
- Y02A10/40—Controlling or monitoring, e.g. of flood or hurricane; Forecasting, e.g. risk assessment or mapping
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Abstract
The invention relates to an experimental device and a method for a distribution form of a dominant channel between steam flooding wells of a heavy oil reservoir, wherein the method comprises the following steps: setting a steam flooding dominant channel, selecting particles to fill the oil reservoir model, installing a plurality of wells in the oil reservoir model by a multipoint method, and arranging temperature measuring points and pressure measuring points according to a proper distance; calculating the pore volume and the porosity of the oil reservoir model, and establishing an initial condition temperature field and a crude oil saturation field; starting the injection system and the measurement and control system, setting flow, starting the steam generator, setting temperature and adjusting steam dryness; according to the experimental scheme, designing relevant parameters of a three-dimensional similarity criterion, performing a simulated steam flooding process, continuously injecting steam into an injection well, collecting produced liquid and performing experimental records; ending the displacement when the steam is driven until the instantaneous oil-gas ratio is lower than 0.1, generating stable dominant channels among wells, injecting glue, opening the oil storage model after solidification, taking out the dominant channel skeleton, and quantifying morphological characteristics and scale sizes.
Description
Technical Field
The invention relates to an experimental device and method for a distribution form of a dominant channel between steam flooding wells of a heavy oil reservoir, and belongs to the technical field of oil and gas exploitation.
Background
Steam flooding is an important technology for thermal recovery of thick oil, but because of the phenomenon of overburden steam, the phenomenon of low recovery degree and high saturation of formation residual oil exists in the steam flooding process. In addition, the geological differences of different oil reservoirs lead to different exploitation characteristics of the steam flooding, although three-dimensional experiments for researching development parameters of the steam flooding are more, experiments for quantitatively describing heat transfer rules of a three-dimensional model are fewer, expansion characteristics of temperatures of a steam cavity in the steam flooding process, seepage mechanisms and oil displacement rules in different development stages are unknown, and research on a follow-up mode of the steam flooding in the later period based on three-dimensional experimental results is not found.
At present, in the existing researches on steam throughput and steam flooding, only some possible hypotheses are proposed in the research on the steam channeling mechanism, and the research reports on the steam channeling are mainly focused on the technical level of the process, so that less experimental researches on the steam channeling mechanism are required. In a great deal of research describing a steam channeling channel based on methods such as potential detection, a tracer method, a physical simulation experiment and the like, a reliable research result which can be deduced by combining an experimental result and a theoretical formula and can be widely applied to oil fields is not formed yet. Most of the recognition descriptions aiming at the steam channeling channels adopt a numerical simulation method, but the numerical simulation method is focused on macroscopic index prediction, cannot deeply study mechanisms and effects, and needs to carry out indoor experimental evaluation research on the development rule of the steam channeling channels in the huff-puff and displacement development process from the perspective of a physical simulation experiment.
At present, the water drive dominant channel identification method is more, but the qualitative identification system is incomplete, and the water drive dominant channel identification technology mainly based on static state cannot get rid of the constraint of geological parameter precision and accuracy, and is limited by dynamic monitoring data; the dynamic monitoring method has the technical dead zone, needs combined test, has stronger technical property, is uneven in oilfield production data, sometimes is difficult to meet the requirement, and screens the association between the dynamic data and the channel by using the dynamic-based identification technology, but does not establish a dynamic-static association method with constraint force. Meanwhile, a complete system is not established for dominant channel identification and quantification from near wells and between wells to the whole block, the classification and grading description difficulty is high, and the quantitative characterization method is not yet available.
Disclosure of Invention
Aiming at the technical problems, the invention provides the experimental device and the method for the distribution form of the dominant channels among the steam flooding wells of the heavy oil reservoir, which are simple, convenient, feasible, quick and effective, can intuitively observe the form of the dominant channels of the steam flooding, quantify the scale, analyze and research the development characteristics of the dominant channels of the steam flooding, and the experimental result can form a quantitative characterization method of the dominant channels of the steam flooding, so that the dominant channels of the steam flooding are identified based on the on-site development condition, the types of the dominant channels of the steam flooding are divided, and the comprehensive evaluation standard is established.
In order to achieve the above purpose, the present invention adopts the following technical scheme:
an experimental device for dominant channel distribution form among heavy oil reservoir steam flooding wells, comprising:
the oil reservoir model comprises a shell and an incubator arranged in the shell, wherein sand grains are filled in the incubator;
the injection system comprises a steam generator, a crude oil storage tank, a stratum water storage tank, two booster pumps and two distilled water storage tanks, wherein the input end of one booster pump is connected with one distilled water storage tank, the output end of the booster pump is connected with the inlet of the steam generator, and the outlet of the steam generator is connected with the inlet of the constant temperature box through a multi-way valve; the input end of the other booster pump is connected with the other distilled water storage tank, the output end of the other booster pump is respectively connected with the crude oil storage tank and the stratum water storage tank, and the outlets of the crude oil storage tank and the stratum water storage tank are connected with the inlet of the constant temperature box through a multi-way valve;
the measurement and control system comprises a data collector and an operation terminal, wherein the data collector is connected with a sensor on the oil reservoir model, and is electrically connected with the operation terminal;
a production system includes a reservoir for collecting fluid from the reservoir model.
In the experimental device, preferably, the incubator is a square structure of a constant-temperature detachable filling box, and is internally provided with a heat insulation layer, and the heat insulation layer wraps the sand grains.
In the experimental device, preferably, a plurality of vertical wells are arranged in the incubator, and hypertonic strips are preset among the vertical wells.
The experimental device, preferably, the grain size and the grain weight of the sand are determined by the following formula:
wherein τ is tortuosity; k is permeability; phi is the porosity; s is a specific surface;
wherein c is a constant of 1.2-1.4; di is the particle size; gi is the content of the particle size Di.
The invention provides an experimental method for the distribution form of a dominant channel between steam flooding wells of a heavy oil reservoir, which is based on the experimental device and comprises the following steps:
the steam flooding dominant channels are equivalently arranged in advance, and particles are selected to fill the oil reservoir model according to different pore-penetration conditions required by experiments; installing an injection well and a plurality of production wells in the oil reservoir model by a multipoint method, and arranging temperature measuring points and pressure measuring points according to proper distances;
calculating the pore volume and the porosity of the oil reservoir model according to the operation flow of a steam flooding experiment, and establishing an initial condition temperature field and a crude oil saturation field;
starting the injection system and the measurement and control system, setting flow, starting the steam generator, setting temperature and adjusting steam dryness;
according to the experimental scheme, designing relevant parameters of a three-dimensional similarity criterion, performing a simulated steam flooding process, continuously injecting steam into an injection well, collecting produced liquid and performing experimental records;
and (3) ending the displacement when the steam is driven until the instantaneous oil-gas ratio is lower than 0.1, generating a stable dominant channel between wells, injecting epoxy resin AB glue, opening the oil storage model after the epoxy resin AB glue is solidified, taking out a dominant channel framework, quantifying morphological characteristics and scale sizes, and observing the development rule of the dominant channel.
The experimental method, preferably, the relevant parameters of the three-dimensional similarity criteria include reservoir thickness, production time, model permeability, injected steam dryness, steam flooding outlet pressure, steam injection rate and simulated oil viscosity.
In the experimental method, preferably, in the process of selecting the matrix sand-filled particles, the following points are noted: the permeability of the matrix is determined according to the physical properties of the actual reservoir, and the temperature-resistant resin glue is utilized to contact and bond the particles; the dominant channel is filled with large-particle-size particles, and the particles are bonded by using temperature-resistant resin glue points; initially, in order to prevent the large particles from collapsing, sodium thiosulfate is filled between the large particles of the dominant channels; the sand-filled core is heated to 100-120 ℃ for a certain time to solidify the particles and sublimate the sodium thiosulfate.
Due to the adoption of the technical scheme, the invention has the following advantages:
1. the experimental method is based on a three-dimensional physical simulation experimental device, is established according to a similarity criterion aiming at the displacement dominant channels generated among wells in the steam flooding process of the heavy oil reservoir, and is used for researching the morphological characteristics and development rules of the steam flooding dominant channels by simulating the expansion and distribution of the dominant channels among injection and production wells, carrying out the quantitative characterization on the dominant channels in an imaging manner and analyzing the channeling characteristics and the fluid distribution state among the injection wells and the peripheral communicating wells in the steam flooding process. According to the method, an original stratum condition is simulated by using a three-dimensional physical simulation model, an initial temperature field and an oil saturation field are established, a steam-driven dominant channel is equivalently set in advance, a particle filling model is selected according to different pore-permeation conditions required by an experiment, the dominant channel is cured after a steam displacement experiment is carried out, an experimental device is started to take out a colloid framework, and the distribution morphology of the steam-driven dominant channel is obtained.
2. According to the experimental method, the epoxy resin AB glue is injected after the stable steam-driven dominant channel is generated, after the stable steam-driven dominant channel is formed, an experimental device can be opened to take out the dominant channel skeleton, the form and the quantitative scale of the dominant channel skeleton can be intuitively observed, various physical property data of the dominant channel are obtained, the experimental result can further develop steam-driven dominant channel type division, a multi-parameter evaluation system is established, important basic data can be provided for predicting and evaluating the steam-driven dominant channel of the heavy oil block, and further the establishment of steam-driven dominant channel treatment and channeling prevention measures is served.
3. The invention characterizes the steam flooding dominant channel by imaging, analyzes the development morphology and the expansion characteristics of the dominant channel, is beneficial to solving the contradiction between layers and planes, guides the optimization of steam flooding regulation measures and improves the development effect of steam flooding. According to the technology, according to the steam flooding simulation similarity criterion and by combining the operation conditions of experimental equipment, the actual operation and geometric conditions of a mine field are converted into physical model values in proportion, a three-dimensional physical simulation experiment is carried out, a quantitative description method of a steam flooding dominant channel is researched, and the obtained experimental result can be converted into a mine field prototype in the same proportion.
4. The experimental method is simple, easy, quick and effective, can intuitively observe the form of the steam-driven dominant channel and quantify the dimension, analyze and research the development characteristics of the steam-driven dominant channel, and the experimental result can form a quantitative characterization method of the steam-driven dominant channel, so that the steam-driven dominant channel can be identified based on the on-site development condition, the steam-driven dominant channel types can be divided, and the comprehensive evaluation standard can be established. The method predicts the experimental results and evaluation indexes to have wide applicability, can be applied to field work of oil fields, provides a targeted solution basis for plugging and controlling the gas flooding dominant channels, and has important practical guiding significance for improving the recovery ratio of the thickened oil.
Drawings
FIG. 1 is a schematic diagram of a three-dimensional physical simulation device for steam flooding according to an embodiment of the present invention;
FIG. 2 is a graph of permeability versus mesh provided by this embodiment of the present invention;
FIG. 3 is a cross-sectional view of a reservoir model provided in this embodiment of the invention;
FIG. 4 is a top view of a reservoir model and well layout according to the embodiment of the present invention.
Detailed Description
For the purpose of making the objects, technical solutions and advantages of the present invention more apparent, the technical solutions in the present invention will be clearly and completely described below, and it is apparent that the described embodiments are some embodiments of the present invention, but not all embodiments. All other embodiments, which can be made by one of ordinary skill in the art without undue burden from the present disclosure, are intended to be within the scope of the present disclosure.
Abbreviation and key term definitions
(1) Heavy oil reservoir: and (3) an oil reservoir with a crude oil viscosity of more than 50 mPa.s under the oil reservoir condition. Crude oils having a viscosity of more than 50 mPas under oil layer conditions or a viscosity of more than 100 mPas after degassing are known as thick oils. According to the classification standard of thick oil in China, crude oil with the viscosity of 100-10000 mPa.s and the relative density (20 ℃) of more than 0.92 is called common thick oil; crude oil with viscosity of 10000-50000 mPa.s and relative density of more than 0.95 is called extra thick oil; crude oils having a viscosity of greater than 50000 mPa-s and a relative density of greater than 0.98 are referred to as super heavy oils (or natural asphalt).
(2) Steam flooding: and (3) through a proper well pattern, a certain number of wells are selected to inject high-temperature steam under high pressure, so that a saturated steam zone is formed around the injection wells, and the oil extraction method for heating and displacing crude oil into the production wells is performed. The viscosity of crude oil is reduced by means of the heat of high-pressure steam, and the flow resistance is reduced; the steam cooled and condensed hot water is propelled by the steam injected thereafter to drive the oil toward the production well. The crude oil expands after being heated, which is beneficial to extraction. The light components in the crude oil form a mixed phase zone at the front edge after being evaporated, which is beneficial to improving the oil displacement efficiency.
(3) The advantage channel is as follows: in the long-term water injection/steam injection development process of an oil field, heterogeneous flow of injected water/injected gas is caused due to geological factors such as oil layer heterogeneity and development factors such as unreasonable working system, and the heterogeneous degree of a pore structure of a reservoir is further increased, so that a hypertonic zone and an ultra-high permeability zone, namely an dominant channel, are formed in the reservoir.
(4) A steam cavity: the hot water belt, the vapor-liquid mixed phase belt and the steam belt are formed between the vapor injection well and the production well, crude oil and hot water in an oil layer are extracted in a flowing way towards the production well, and the steam is pulled by the hot water belt to expand towards the production well. In the early stage of steam injection development, the steam cavity is only formed nearby the steam injection well, the range is small, and the expansion degree of steam in the longitudinal direction is good.
(5) Experimental study: experimental research is a controlled method of studying, by which the effect of one or more variables is assessed. The main purpose of the experiment is to establish causal relationships between variables, and it is common practice for researchers to make a causal relationship trial hypothesis in advance and then verify it through experimental operations.
Currently, the existing dominant channel related research is that most research objects are water flooding dominant channels generated by water flooding development of sandstone reservoirs, and there are few references to dominant channels generated by steam flooding of heavy oil reservoirs; the known research method of the steam-driven dominant channel mainly uses the research thought of the water-driven dominant channel, utilizes on-site production data, development dynamic data and the like, and classifies the steam-driven dominant channel by using a fuzzy cluster analysis method. Therefore, the existing research lacks an indoor three-dimensional physical simulation experiment method, does not form a universal standard, and is difficult to ensure the convenience, operability and wide applicability of the method applied to oil fields. The experimental method provided by the invention can simulate actual production and form standard classification evaluation indexes, and can be suitable for large-scale production of oil fields, so that the actual production problem is solved.
The invention is described in further detail below with reference to the drawings and the detailed description.
As shown in FIG. 1, the experimental device for the distribution form of the dominant channels among the steam flooding wells of the heavy oil reservoir comprises a reservoir model, an injection system, a measurement and control system and a production system; the oil reservoir model comprises a shell and an incubator arranged in the shell, wherein sand grains are filled in the incubator; the injection system comprises a steam generator, a crude oil storage tank, a stratum water storage tank, two booster pumps and two distilled water storage tanks, wherein the input end of one booster pump is connected with one distilled water storage tank, the output end of the booster pump is connected with the inlet of the steam generator, and the outlet of the steam generator is connected with the inlet of the constant temperature box through a multi-way valve; the input end of the other booster pump is connected with the other distilled water storage tank, the output end of the other booster pump is respectively connected with the crude oil storage tank and the stratum water storage tank, and the outlets of the crude oil storage tank and the stratum water storage tank are connected with the inlet of the constant temperature box through a multi-way valve; the measurement and control system comprises a data collector and an operation terminal, wherein the data collector is connected with a sensor on the oil reservoir model, and is electrically connected with the operation terminal; a production system includes a reservoir for collecting fluid from the reservoir model.
Specifically, the booster pump is an ISCO pump: the high-pressure high-precision plunger pump is used for injecting crude oil, stratum water and steam generated by the steam generator into the oil reservoir model at a speed required by an experiment; steam generator: mechanical equipment for heating distilled water into hot water or steam by using fuel or other energy heat energy is used for simulating the injection process of steam flooding; crude oil/formation water container: crude oil and stratum water held in the container are used for being injected into an oil reservoir model, so that the model body simulates the original oil-containing and water-containing conditions of the oil reservoir; high pressure nitrogen gas cylinder: the oil reservoir model is pressurized by injecting gas so as to further compact the model, and meanwhile, the gas pipeline joint and the model seal can be checked to prevent gas leakage; six-way valve: the relative positions of the sealing components in the valve body are changed to connect or disconnect all channels of the valve body, so that injection of different fluid devices in the injection system is controlled; back pressure valve: adjusting the pressure of the experimental device in the fluid flowing process through a piston in the valve so as to maintain the pressure in the device to be balanced with a set pressure value; data acquisition unit: acquiring temperature and pressure data of each point position of a physical model in different time periods in the experimental process, and monitoring temperature and pressure distribution conditions; measuring cylinder: the device is used for collecting crude oil, hot water and other fluids produced by a steam displacement experiment, and is convenient for subsequent treatment; reservoir model body: the size of the constant-temperature detachable sand filling box is 50cm multiplied by 50cm, oil sand can be directly filled, and a ceramic/tetrafluoro coat is selected, so that nuclear magnetism/CT scanning is facilitated.
As shown in fig. 3, the constant temperature box is a square structure with a detachable constant temperature filling box, and is internally provided with a heat insulation layer, the heat insulation layer wraps the sand grains, and an oil layer is formed after the sand grains are filled with oil water.
As shown in fig. 2, the particle size and loading of the filled sand are determined as follows:
(1) Sand-filled particle size selection
Correction Kozeny-Carman
Wherein τ is a tortuosity, taking 1.2 based on experimental results; after the steam flooding dominant channel is formed, the permeability K, the porosity phi and the specific surface S are changed.
The specific surface of the porous medium composed of the particles used in the test is required:
c＝1.2-1.4，G i is of particle diameter D i Generally 2 sand grains are used for the experiment.
After the dominant channel is generated, knowing the permeability value K and the porosity value phi, the specific surface of the experimental sand-filled porous medium can be obtained:
and calculating to obtain the specific surface S required by the sand filling pipe according to the permeability K, the porosity phi and the required specific surface S of the sand filling pipe.
Two particle sizes D are selected based on the relationship between permeability and particle size (particle size) shown in FIG. 2 1 And D 2 . Calculating the content G of the selected particles by using the above face formula 1 And G 2 As quartz sand filling the dominant channels.
(2) Physical simulation construction method
Fig. 4 is a schematic cross-sectional view of a matrix of a sand-filled core in a three-dimensional physical simulation experiment, and fig. 4 is a plan view of the three-dimensional model and a well-distribution mode. The three-dimensional physical simulation experiment is provided with three vertical wells, namely a well A (steam injection well), a well B and a well C (production well), and the distance between the model injection and production wells is preset to be 40cm. In order to generate a steam flooding dominant channel faster, a hypertonic strip is preset between injection and production wells, and a steam flooding experiment is carried out by taking well A as the center.
In selecting a matrix sand-pack particle packing process, the following should be noted: (1) the matrix permeability is determined according to the physical properties of the actual reservoir, and the particles are bonded by point contact with the temperature-resistant resin glue. (2) The dominant channel is filled with large-particle-size particles, and the particles are bonded by using temperature-resistant resin glue points. (3) Initially, to prevent the macroparticles from collapsing, the dominant channel macroparticles are internally filled with sodium thiosulfate. (4) The sand-filled core is heated to 100-120 ℃ for about 24 hours, solidifying the particles and sublimating the sodium thiosulfate.
After the steam displacement experiment is finished, the dominant channel is cured by injecting epoxy resin AB glue, so that direct observation and measurement are facilitated. The epoxy resin AB glue is a double-component high polymer material composed of epoxy resin and curing agent, and has the advantages of no toxicity, no environmental pollution, high transparency, high hardness, low viscosity, low cost and the like. The experiment utilizes the epoxy resin AB glue to manufacture the dominant channel skeleton in the physical model, and provides reference for researching the steam-driven dominant channel method.
The invention provides an experimental method for the distribution form of a dominant channel between steam flooding wells of heavy oil reservoirs, which comprises the following steps:
the steam flooding dominant channels are equivalently arranged in advance, and particles are selected to fill the oil reservoir model according to different pore-penetration conditions required by experiments; installing an injection well and a plurality of production wells in the oil reservoir model by a multipoint method, and arranging temperature measuring points and pressure measuring points according to proper distances;
calculating the pore volume and the porosity of the oil reservoir model according to the operation flow of a steam flooding experiment, and establishing an initial condition temperature field and a crude oil saturation field;
starting the injection system and the measurement and control system, setting flow, starting the steam generator, setting temperature and adjusting steam dryness;
according to the experimental scheme, designing relevant parameters of a three-dimensional similarity criterion, performing a simulated steam flooding process, continuously injecting steam into an injection well, collecting produced liquid and performing experimental records;
and (3) ending the displacement when the steam is driven until the instantaneous oil-gas ratio is lower than 0.1, generating a stable dominant channel between wells, injecting epoxy resin AB glue, opening the oil storage model after the epoxy resin AB glue is solidified, taking out a dominant channel framework, quantifying morphological characteristics and scale sizes, and observing the development rule of the dominant channel.
The steam flooding dominant channel similarity criteria are established below, and the relevant parameters of the experiment are calculated by using the steam flooding dominant channel similarity criteria:
in the process of establishing the similarity criteria, subscripts m and p respectively represent parameters in the model and parameters of an actual oil layer.
After the similarity criterion number group is provided, the prototype parameters can be converted into model parameters by utilizing the corresponding equal relation of the similarity criterion number, and the model is designed and built. For convenience, the scale is marked with r (X) as a parameter, i.e
1. Establishing a similarity criterion:
(1) thickness of oil layer: the relation between the thickness of the experimental model oil layer and the thickness of the actual stratum is as follows:
wherein x is p -actual well spacing, m; x is x m -experimental model well spacing, m; h is a p -actual oil layer thickness, m; h is a m Experimental model oil layer thickness, m.
The deformation is available, and the thickness of the simulated oil layer is as follows:
(2) production time: the model production time and the actual production time are related by the three-dimensional experimental similarity criterion:
the finishing method can obtain:
wherein t is m Model production time, min; t is t p -actual production time, min; k-permeability; phi-porosity; k (K) r -relative permeability, i.e. the ratio of the effective permeability of the fluid to the absolute permeability of the fluid; g-gravity acceleration, m/s 2 The method comprises the steps of carrying out a first treatment on the surface of the ρ -Density, kg/m 3 ；μ g -gas viscosity, mpa·s; l-length, m.
(3) Model permeability: the relation between the experimental model and the actual permeability is obtained by a three-dimensional experimental similarity criterion:
in the formula, ρo-crude oil density, kg/m 3 The method comprises the steps of carrying out a first treatment on the surface of the Mu o-viscosity of crude oil, mPa.s; Δs—the amount of change in oil saturation.
The finishing method can obtain:
wherein K is m -experimental model permeability; k (K) p -actual production permeability.
(4) Dryness of injected steam: according to a three-dimensional experimental similarity criterion, the relation between the injected steam dryness and the actual steam dryness of the experimental model is obtained as follows:
in the formula, x is steam dryness; delta t—the difference between the steam injection temperature and the initial temperature; c (C) w Saturated hot water specific heat capacity，J/kg·℃；L v Saturated steam latent heat of vaporization, kJ/kg; .
Determining the specific heat capacity C of saturated hot water by checking related physical parameters of saturated steam according to the saturation temperature of injected steam w And the latent heat of vaporization L of saturated steam v . The finishing method can obtain:
wherein x is m Steam dryness is selected as the model; x is x p -actual production of steam dryness; t (T) s Steam temperature, DEG C; t (T) i -the original formation temperature, c.
(5) Steam flooding outlet end pressure: the three-dimensional experimental similarity criterion is utilized to obtain the relation between the experimental model production pressure difference and the actual production pressure difference as follows:
wherein, deltap-displacement differential pressure, MPa; ρo-crude oil Density, kg/m 3 。
The injection pressure is the saturated vapor pressure of the vapor, Δp=p s (T s )-p out The method comprises the following steps of:
p outm ＝p sm -r(ρ o )r(g)r(L)(p sp -p outp )
wherein p is outm Model outlet end pressure, MPa; p is p outp Actual production outlet pressure, MPa; p is p sm Model steam injection pressure, MPa; p is p sp Actual steam injection pressure, MPa.
(6) Steam injection rate: and obtaining the relation between the steam injection rate of the experimental model and the steam injection rate of actual production by using a three-dimensional experimental similarity criterion, wherein the relation is as follows:
wherein i is s Injection rate, m 3 /d; s-original oil saturation; t-production time, d; phi-porosity; ρ w Density of water, kg/m 3 。
The finishing method can obtain:
wherein i is sm Model injection rate, m 3 /d；i sp Actual injection rate, m 3 /d。
(7) Simulated oil viscosity: according to the three-dimensional experimental similarity criterion, obtaining the relation between the experimental simulated oil and the actual formation crude oil viscosity as
Wherein mu is g Steam viscosity, mpa·s; ρ g Steam density, kg/m 3 。
The finishing method can obtain:
wherein mu is om -model crude oil viscosity, mpa·s; mu (mu) op Model crude oil viscosity, mpa.s.
The similarity criteria and design method used for this experiment are referred to table 1.
Table 1 physical simulation experiment similarity criterion basis and design method
During the physical simulation experiment, reasonable similarity criteria can be selected for different research purposes. The research of the steam flooding dominant channel is based on the premise of injecting steam, so that the similarity criterion of steam is greatly influenced, and the similarity criterion with strong sensitivity is selected, so that the seepage and heat transfer rules of the fluid can be reflected more truly to a certain extent, and the experimental result is more accurate and practical.
2. Utilizing the proposed similarity criteria to develop the related parameters of the three-dimensional similarity criteria calculation experiment
(1) Calculating simulated reservoir thickness
The well distance between two wells on site is x p The thickness of the oil layer is h p Then:
knowing that the injection and production well distance is 100m and the model well distance is 40cm, the experimental model and the actual oil reservoir scale are:
(2) Calculating the experimental production time
According toDeducing:
from (1), the result r (L) =0.004, r (Δρ) =1, r (K r )＝1，r(μ g )＝1，r(φ)＝1，r(g)＝1，r(L)＝1，r(K)＝1，The time scale can be calculated:
if the prototype time value is 21600min (15 d); model value 21600×0.004=86.4 min; i.e. 15 days of on-site steam injection corresponds to 86.4min in a laboratory; the field for 1 day corresponds to 5.76min in laboratory.
(3) Calculating dryness of steam
From the following componentsThe following steps are obtained:
the reservoir model used in the experiment adopts stratum water, and the steam injection temperature is consistent with the site, and the known condition r (C w )＝1，r(ΔT)＝1，r(L v ) =1, calculate the steam dryness fraction:
the experiment may employ injection steam quality consistent with the field.
(4) Calculating the viscosity of model oil
According toCalculating the simulated oil viscosity of the model to obtain:
known, r (ρ o )＝1，r(μ g )＝1，r(ρ g ) =1, r (x) =1, the viscosity ratio can be calculated:
crude oil was used in the experimental procedure consistent with live, degassed crude oil.
(5) Calculating model permeability
According toThe following steps are obtained:
knowing r (Φ) =1, r (Δs) =1, r (μ) o )＝1，r(L)＝0.004，r(ρ o ) =1, r (g) =1, r (t) =0.004, then the permeability scale can be calculated:
the calculated permeability is corrected by Reynolds number criterion:
(6) Calculating the steam injection speed of the model
According toThe steam injection rate can be calculated to yield:
known, r (ρ w ) =1, r (Φ) =1, r (t) =r (L), r (Δs) =1, r (L) =0.004, then the steam flow ratio can be calculated:
if the daily steam injection amount of the prototype is 225t/d, the corresponding laboratory unit is 225 multiplied by 10 6 /(24×60) = 156250mL/min; model number 156250 ×0.004 2 =2.5 mL/min; i.e., the in-situ steam injection rate 225t/d corresponds to 2.5mL/min for the laboratory.
(7) Calculating model differential pressure
According toThe experimental operating pressure gives:
r(Δp)＝r(ρ o )r(g)r(L)
known, r (ρ o ) =1, r (g) =1, r (L) =0.004, the differential pressure scale can be calculated:
r(Δp)＝r(ρ o )r(g)r(L)＝r(L)＝0.004
if the model value Δp=5 MPa, the model value is 5×0.004=0.02 MPa.
According to the actual parameters of the single 56 heavy oil reservoirs and the parameters of the three-dimensional experimental device, a three-dimensional physical simulation parameter table of steam flooding of the single 56 heavy oil reservoirs is obtained by utilizing a three-dimensional similarity criterion, and the table is shown in Table 2.
TABLE 2 conversion table of reservoir prototype and proportional model parameters
The invention establishes a similarity rule of a steam flooding dominant channel, develops a three-dimensional physical simulation experiment, and mainly has the following purposes: (1) Predicting the actual steam injection oil displacement dynamic of the oilfield site by means of a physical simulation experiment; (2) The geometric and physical characteristics and the operation conditions of the actual oil layer are greatly different from those of the experimental model, and the field conditions of the oil field are converted into physical model values according to a certain proportion by combining the operation conditions of experimental equipment and according to a similar theory; (3) The experimental results of the physical model can be converted into field prototypes according to the same proportion, and corresponding results under the actual conditions of the oilfield field can be obtained.
The three-dimensional physical simulation experiment is established on the basis of a similarity theory, and is guided by the similarity theory in the steps of model design, experimental operation process, data processing and description of each stage of an oil reservoir prototype by using experimental results.
After the oil well is subjected to long-time steam flushing, the pore structure of the reservoir layer is changed, injected steam flows along the hypertonic and macroporous channels, and the original pore throat radius and permeability are continuously increased, so that a steam flooding dominant channel is formed. The occurrence of the steam flooding dominant channel can aggravate interlayer contradiction, and the injected steam is circulated in a low-efficiency way, so that great difficulty is caused to stable yield and increase yield. The three-dimensional physical simulation experiment device provided by the invention can establish a physical simulation process of generating an advantageous channel by steam flooding of the thick oil layer under laboratory conditions.
According to the experimental method, according to the steam flooding simulation similarity criteria, steam displacement experiments are carried out under laboratory conditions by selecting particle filling models required by different pore permeation conditions, and solidification treatment is carried out on the stably generated dominant channels, so that the distribution morphology of the steam flooding dominant channels is intuitively researched. According to the three-dimensional physical simulation experiment result, the identification and classification of the gas flooding dominant channel can be completed, and further detailed analysis and expansion research can be carried out.
The implementation method of the technical scheme can be used for guiding indoor researchers to realize physical simulation of the evolution process of the steam-driven dominant channel and developing three-dimensional physical simulation experimental research. The method is based on the known actual geometric and operation conditions of the mine, the actual condition of the mine can be converted into a physical model value only by calculating according to a certain proportion and mathematics, and the development rule of the steam-driven dominant channel is revealed through experiments. The method has simple equipment and easy operation, can reasonably and effectively simulate the distribution and expansion of the dominant channels among the wells in the steam flooding process, ensures that experimental research is smoothly carried out, realizes direct observation, ensures that experimental results are true and reliable, and provides guidance for the establishment of measures for controlling and preventing channeling of the dominant channels among the steam flooding wells of the heavy oil reservoir.
Finally, it should be noted that: the above embodiments are only for illustrating the technical solution of the present invention, and are not limiting; although the invention has been described in detail with reference to the foregoing embodiments, it will be understood by those of ordinary skill in the art that: the technical scheme described in the foregoing embodiments can be modified or some technical features thereof can be replaced by equivalents; such modifications and substitutions do not depart from the spirit and scope of the technical solutions of the embodiments of the present invention.
Claims (7)
1. Experimental device for dominant channel distribution form between viscous crude oil reservoir steam drives well, characterized by comprising:
the oil reservoir model comprises a shell and an incubator arranged in the shell, wherein sand grains are filled in the incubator;
the injection system comprises a steam generator, a crude oil storage tank, a stratum water storage tank, two booster pumps and two distilled water storage tanks, wherein the input end of one booster pump is connected with one distilled water storage tank, the output end of the booster pump is connected with the inlet of the steam generator, and the outlet of the steam generator is connected with the inlet of the constant temperature box through a multi-way valve; the input end of the other booster pump is connected with the other distilled water storage tank, the output end of the other booster pump is respectively connected with the crude oil storage tank and the stratum water storage tank, and the outlets of the crude oil storage tank and the stratum water storage tank are connected with the inlet of the constant temperature box through the multi-way valve;
the measurement and control system comprises a data collector and an operation terminal, wherein the data collector is connected with a sensor on the oil reservoir model, and is electrically connected with the operation terminal;
a production system includes a reservoir for collecting fluid from the reservoir model.
2. The experimental apparatus according to claim 1, wherein the incubator is a constant temperature detachable filling box, and a heat insulation layer is arranged in the incubator, and the heat insulation layer wraps the sand grains.
3. The experimental device according to claim 2, wherein a plurality of vertical wells are arranged in the incubator, and a hypertonic strip is preset between a plurality of vertical wells.
4. The apparatus of claim 3 wherein the grit size and grit weight are determined by the formula:
wherein τ is tortuosity; k is permeability; phi is the porosity; s is a specific surface;
wherein c is a constant of 1.2-1.4; d (D) i Is of particle size; g i Is of particle diameter D i Is contained in the composition.
5. An experimental method of a dominant channel distribution form among steam flooding wells of a heavy oil reservoir, which is characterized by comprising the following steps based on the experimental device of claim 4:
the method comprises the steps of equivalently arranging steam flooding dominant channels in advance, selecting particles to fill an oil reservoir model according to different pore-penetration conditions required by experiments, installing an injection well and a plurality of production wells in the oil reservoir model by a multi-point method, and arranging temperature measuring points and pressure measuring points according to proper distances;
calculating the pore volume and the porosity of the oil reservoir model according to the operation flow of a steam flooding experiment, and establishing an initial condition temperature field and a crude oil saturation field;
starting the injection system and the measurement and control system, setting flow, starting the steam generator, setting temperature and adjusting steam dryness;
according to the experimental scheme, designing relevant parameters of a three-dimensional similarity criterion, performing a simulated steam flooding process, continuously injecting steam into an injection well, collecting produced liquid and performing experimental records;
and (3) ending the displacement when the steam is driven until the instantaneous oil-gas ratio is lower than 0.1, generating a stable dominant channel between wells, injecting epoxy resin AB glue, opening the oil storage model after the epoxy resin AB glue is solidified, taking out a dominant channel framework, quantifying morphological characteristics and scale sizes, and observing the development rule of the dominant channel.
6. The method of claim 5, wherein the three-dimensional similarity criteria related parameters include reservoir thickness, production time, model permeability, injected steam dryness, steam flooding outlet pressure, steam injection rate, and simulated oil viscosity.
7. The method according to claim 5, wherein during the selection of the matrix sand-filled particle packing, the following is noted: the permeability of the matrix is determined according to the physical properties of the actual reservoir, and the temperature-resistant resin glue is utilized to contact and bond the particles; the dominant channel is filled with large-particle-size particles, and the particles are bonded by using temperature-resistant resin glue points; initially, in order to prevent the large particles from collapsing, sodium thiosulfate is filled between the large particles of the dominant channels; the sand-filled core is heated to 100-120 ℃ for a certain time to solidify the particles and sublimate the sodium thiosulfate.
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| CN117489296B (en) * | 2023-12-29 | 2024-03-22 | 克拉玛依市白碱滩区(克拉玛依高新区)石油工程现场(中试)实验室 | Inter-well channeling prevention method and simulation experiment device |
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