CN111022012A - Dense oil steam flooding steam temperature design method - Google Patents
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- 238000010795 Steam Flooding Methods 0.000 title claims abstract description 31
- 238000000034 method Methods 0.000 title claims abstract description 25
- 238000013461 design Methods 0.000 title claims abstract description 6
- 239000010779 crude oil Substances 0.000 claims abstract description 81
- 239000003921 oil Substances 0.000 claims abstract description 67
- 230000006835 compression Effects 0.000 claims abstract description 21
- 238000007906 compression Methods 0.000 claims abstract description 21
- 238000004364 calculation method Methods 0.000 claims abstract description 10
- 230000015572 biosynthetic process Effects 0.000 claims description 29
- 238000002347 injection Methods 0.000 claims description 21
- 239000007924 injection Substances 0.000 claims description 21
- 238000012360 testing method Methods 0.000 claims description 14
- 238000010793 Steam injection (oil industry) Methods 0.000 claims description 8
- 238000004519 manufacturing process Methods 0.000 claims description 6
- 230000008569 process Effects 0.000 claims description 5
- 238000002474 experimental method Methods 0.000 claims description 3
- 238000011161 development Methods 0.000 abstract description 11
- 230000008859 change Effects 0.000 abstract description 10
- 230000000694 effects Effects 0.000 abstract description 10
- 238000005457 optimization Methods 0.000 abstract description 2
- 238000006073 displacement reaction Methods 0.000 description 5
- 239000012530 fluid Substances 0.000 description 5
- 238000011084 recovery Methods 0.000 description 5
- 230000035699 permeability Effects 0.000 description 4
- 239000013589 supplement Substances 0.000 description 4
- 238000004458 analytical method Methods 0.000 description 3
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- 230000009471 action Effects 0.000 description 2
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- 230000000704 physical effect Effects 0.000 description 2
- 239000011435 rock Substances 0.000 description 2
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 2
- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- 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
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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
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Abstract
The invention discloses a dense oil-steam flooding steam temperature design method, which is used for determining the optimal steam temperature range in a dense oil reservoir, and calculating the change degree of the layer pressure when the oil reservoir temperature is heated to different degrees according to the thermal expansion coefficient and the compression coefficient of crude oil tested by a high-temperature high-pressure phase state analyzer; meanwhile, under the condition of considering the starting pressure gradient and the fracture pressure, a calculation method of the optimal steam temperature is provided. The method breaks through the limitation that the conventional steam flooding is only suitable for thick oil development, provides a theoretical basis for the optimization of the energy parameter of the stratum supplemented by the compact oil, and provides a new method for improving the development effect of the compact oil.
Description
Technical Field
The invention belongs to the technical field of enhanced recovery of dense oil in oil and gas field development, and particularly relates to a dense oil steam flooding steam temperature design method.
Background
The compact oil refers to petroleum stored in a compact sandstone, a compact carbonate rock and other reservoirs with effective permeability less than or equal to 0.3 mD. By tight oil is meant, in a broad sense, oil produced in low porosity and low permeability shale or other tight rock reservoirs. As an important unconventional oil reservoir type, because of low permeability of a reservoir stratum, water injection in an economic extreme well pattern is difficult to establish an effective displacement pressure system, and quasi-natural energy development is usually carried out in a horizontal well and volume fracturing mode at present. Because the formation energy can not be effectively supplemented, the yield in the dense oil development process is greatly reduced, and the recovery ratio is much lower than that of the conventional water-flooding oil reservoir and is only about 10 percent. How to supplement the formation energy is the key to improve the development effect of the compact oil.
The steam flooding is a process of continuously injecting gas from a gas injection well and continuously producing oil from an adjacent production well by using high-temperature steam as a heat-carrying fluid and a driving medium, and improving the oil displacement efficiency by using the injected heat and quality. The steam flooding improves the recovery efficiency through mechanisms such as viscosity reduction, distillation, thermal expansion and the like. Practice and theory prove that steam flooding is an effective thick oil development mode, wherein the viscosity reduction effect is the most important mechanism for producing thick oil by steam flooding. Because the crude oil of the compact reservoir is generally low-viscosity light crude oil, the viscosity reduction effect of steam flooding is limited; compared with thick oil, light crude oil has better thermal expansion characteristic, and a temperature field formed in an oil reservoir by steam flooding through heat transfer action is larger than a flow field in a steam flooding range, so that crude oil in a high-temperature field formed by steam flooding can flow out of a compact matrix through the thermal expansion action, and possibility is provided for the compact oil to supplement formation energy. Therefore, how to exert the thermal expansion effect of the light crude oil to the maximum extent is the key for the dense oil to supplement the formation energy.
At present, the water injection throughput test of the horizontal well is carried out on the energy of the compact oil replenishing stratum, but the stage extraction degree is increased by less than 0.2 percent, and the effect is not ideal. The research of replenishing the stratum energy of the compact oil reservoir by utilizing steam flooding is blank.
Disclosure of Invention
Aiming at the problems that the late yield is greatly reduced, the recovery ratio is low, and no method for effectively supplementing stratum energy and improving the recovery ratio exists temporarily due to the fact that the existing tight oil reservoir development uses quasi-natural energy development of 'horizontal well + volume fracturing', a method for heating crude oil by a high-temperature field formed by steam flooding and improving the stratum energy by means of the thermal expansion of the crude oil is provided.
In order to achieve the purpose, the method for designing the steam temperature of the dense oil steam flooding comprises the following steps of:
step 1, testing the expansion coefficient of crude oil α under different pressureso(ii) a Testing the compression coefficient C of crude oil at different temperatureso；
Step 2, obtaining the crude oil expansion coefficient α under different pressures according to the step 1oAnd compression coefficient C of crude oil at different temperaturesoCalculating the formation pressure P at different reservoir temperatures;
step 3, carrying out compact oil-steam flooding starting pressure gradient test to obtain a target compact oil reservoir steam injection starting pressure gradient lambda;
step 4, calculating theoretical limit well spacing r of the horizontal well according to the stratum pressure P at different oil reservoir temperatures obtained in the step 2 and the starting pressure gradient lambda obtained in the step 31Theoretical limit well spacing r of vertical well2Calculating the minimum injection well bottom pressure P under the combined well spacing of the vertical well and the horizontal wellmin；
Step 5, obtaining the minimum bottom pressure P of the injection well according to the step 4minThe expansion coefficient of crude oil obtained in step 1 is αoAnd crude oil compressibility factor CoCalculating the minimum reservoir steam temperature TminThe expansion coefficient of the crude oil obtained according to the step 1 is αoAnd crude oil compressibility factor CoCalculating the maximum oil deposit steam temperature T by taking the stratum fracture pressure of the target area as an upper limitmax。
Further, in step 2, the calculation formula of the formation pressure P after the crude oil is expanded at different reservoir temperatures is as follows:
in the above formula, αoThe expansion coefficient of the crude oil is 1/DEG C; coThe compression coefficient of the crude oil is 1/MPa; t is the temperature, DEG C, T of the expanded crude oiliTo the original reservoir temperature, PiIs the formation original pressure, MPa.
Further, in the step 3, a core physical model experiment is utilized to measure the steam injection starting pressure gradient of the target tight oil reservoir, and the starting pressure gradient is lambda.
Further, in step 4, a minimum injector bottom pressure P is calculatedminThe process of (2) is as follows:
r1+r2＝D(3)；
the simultaneous formulas (1), (2) and (3) are shown, and the obtained bottom pressure P of the gas injection well is the minimum bottom pressure P of the injection wellminIn the formulas (1) to (3), L is half length of horizontal section, r1 is theoretical limit well distance of horizontal well, r2 is theoretical limit well distance of vertical well, D is distance between actual vertical well and horizontal well, rwIs the wellbore radius; p is the bottom hole pressure of the gas injection well, PiIs the original formation pressure, PwIs the bottom hole pressure of the production well; λ is the starting pressure gradient.
Further, in step 5, the minimum reservoir steam temperature TminIs calculated byThe formula is as follows:
α0taking the expansion coefficient of crude oil under Pmin pressure, CoAnd taking the compression coefficient of the crude oil at the original oil reservoir temperature Ti.
Further, in step 5, the maximum reservoir steam temperature TmaxThe calculation formula of (2) is as follows:
wherein: pfraFor formation fracture pressure, α0Taking the expansion coefficient of crude oil under Pmin pressure, CoAnd taking the compression coefficient of the crude oil at the original oil reservoir temperature Ti.
Compared with the prior art, the invention has at least the following beneficial technical effects:
the invention utilizes the high-temperature field formed by steam flooding to heat the crude oil, and the energy of the compact oil formation is improved by means of the thermal expansion effect of the crude oil. In order to define the optimal steam temperature range in the compact oil reservoir, the change degree of the pressure of the oil reservoir when the temperature of the oil reservoir is heated to different degrees is calculated on the basis of the thermal expansion coefficient and the compression coefficient of the crude oil tested by a high-temperature high-pressure phase state analyzer; meanwhile, under the condition of considering the starting pressure gradient and the fracture pressure, a calculation method of the optimal steam temperature is provided. The method breaks through the limitation that the conventional steam flooding is only suitable for thick oil development, provides a theoretical basis for the optimization of the energy parameter of the stratum supplemented by the compact oil, and provides a new method for improving the development effect of the compact oil.
The formation pressure gradient must be higher than the starting pressure gradient, the fluid will flow, the starting pressure gradient of the medium-high permeability reservoir is low and can be ignored, but for the tight oil reservoir, the flow belongs to the nonlinear seepage when flowing in the porous medium, just because the starting pressure gradient is large, most of the formation energy is used for overcoming the resistance caused by the starting pressure gradient, so that the effective energy for keeping the fluid flow is greatly reduced, therefore, the starting pressure gradient must be considered, when the formation pressure gradient is equal to the starting pressure gradient, the fluid is at the critical point of transition from static state to flow, and the starting pressure gradient is used for restricting the lower limit (lowest value) of the steam temperature under the formation condition in the patent.
The fracture pressure is the critical pressure when the core is irreversibly deformed, and the formation fracture pressure needs to be considered when measures are selected, otherwise, injected steam is easy to blow along cracks, and the steam flooding effect is influenced. Therefore, the invention is to ensure that the pressure value after the formation pressure is increased due to the expansion of crude oil after steam injection is smaller than the fracture pressure, and the pressure value is used as the upper limit (maximum value) of the small steam temperature under the condition of restricting the formation.
Drawings
FIG. 1 is a schematic representation of the thermal expansion coefficients of crude oils at different pressures;
FIG. 2 is a graph showing the compressibility of crude oils at various temperatures.
Detailed Description
The present invention will be described in detail below with reference to the accompanying drawings and specific embodiments.
In the description of the present invention, it is to be understood that the terms "center", "longitudinal", "lateral", "up", "down", "front", "back", "left", "right", "vertical", "horizontal", "top", "bottom", "inner", "outer", and the like, indicate orientations or positional relationships based on those shown in the drawings, and are used only for convenience in describing the present invention and for simplicity in description, and do not indicate or imply that the referenced devices or elements must have a particular orientation, be constructed and operated in a particular orientation, and thus, are not to be construed as limiting the present invention. Furthermore, the terms "first", "second" and "first" are used for descriptive purposes only and are not to be construed as indicating or implying relative importance or implicitly indicating the number of technical features indicated. Thus, a feature defined as "first" or "second" may explicitly or implicitly include one or more of that feature. In the description of the present invention, "a plurality" means two or more unless otherwise specified. In the description of the present invention, it should be noted that, unless otherwise explicitly specified or limited, the terms "mounted," "connected," and "connected" are to be construed broadly, e.g., as meaning either a fixed connection, a removable connection, or an integral connection; can be mechanically or electrically connected; they may be connected directly or indirectly through intervening media, or they may be interconnected between two elements. The specific meanings of the above terms in the present invention can be understood in specific cases to those skilled in the art.
Referring to fig. 1, a dense oil steam flooding steam temperature design method fully utilizes the thermal expansion characteristic of light low-viscosity crude oil to supplement dense oil stratum energy by steam flooding, utilizes the principle that a temperature field formed by injecting high-temperature steam enables the crude oil to be heated and expanded to improve the dense oil reservoir stratum energy, firstly utilizes a high-temperature high-pressure phase state analysis system to respectively test and obtain the thermal expansion coefficients of the crude oil under different pressures and the compression coefficients of the crude oil under different temperatures, and calculates the stratum pressure after the crude oil is expanded under different oil reservoir temperatures; then, considering the starting pressure gradient of the steam drive of the tight oil reservoir, calculating the minimum injection-production pressure difference of the existing well pattern steam injection and displacement pressure system; and calculating the lowest oil reservoir temperature of the steam flooding established displacement pressure system and the highest oil reservoir temperature considering the fracture pressure, and determining a reasonable oil reservoir steam temperature range. The method specifically comprises the following steps:
step 1) testing the expansion coefficient α of crude oil under different pressureso
The expansion coefficient of crude oil is the volume change of unit volume crude oil when the temperature rises by 1 ℃. The method comprises the steps of measuring the expansion coefficient of crude oil under a set pressure by using a high-temperature high-pressure phase state analyzer according to a 9.3 thermal expansion test flow in a formation crude oil physical property analysis method, and continuously converting the test pressure to obtain crude oil expansion coefficient curves under different pressures, wherein the curves are shown in figure 1.
Step 2) testing the compression coefficient C of crude oil at different temperatureso
The compression coefficient of crude oil is the volume change of unit volume crude oil when the pressure rises by 1MPa, the compression coefficient of the crude oil is measured at a set temperature by using a high-temperature high-pressure phase state analyzer according to a 9.4 constant mass expansion experimental flow in SY/T5542-2000 stratum crude oil physical property analysis method, and a crude oil compression coefficient curve at different temperatures is obtained by continuously changing the test temperature, which is shown in figure 2.
And 3) calculating the formation pressure at different reservoir temperatures.
Calculating the change of the formation pressure caused by the expansion of the crude oil at different temperatures according to the relationship between the formation pressure and the expansion coefficient and the compression coefficient of the crude oil;
equation 1 is crude oil expansion coefficient αoAnd crude oil compressibility factor CoAnd (4) defining a formula.
According to the formula
Obtaining a calculation formula of the pressure change value delta P of the crude oil, and then processing
Get Δ T, and substitute into equation (2) to get equation (3).
In the above formula αoThe expansion coefficient of the crude oil is 1/DEG C;
Cothe sum compression coefficient of crude oil is 1/MPa;
delta V is the volume change value of the crude oil subjected to thermal expansion, and V is the initial volume of the crude oil, mL;
Δ T is a temperature change value, TiThe original reservoir temperature, T is the post-expansion temperature of the crude oil, C
P is the formation pressure after the crude oil expansion, PiThe original pressure of the stratum is shown, and the delta P is the pressure change value of crude oil, namely MPa;
after the high-temperature steam is injected, the crude oil is heated and expanded, the initial volume before the steam is injected and the changed volume after the steam is injected, and the difference value between the initial volume and the changed volume is the volume change value of the crude oil heated and expanded.
Step 4) compact oil steam drive starting pressure gradient test
Measuring a steam injection starting pressure gradient of the target tight oil reservoir by using a core physical model experiment to obtain a starting pressure gradient lambda;
step 5) calculating the bottom pressure of the minimum injection well under the combined well distribution of the vertical well and the horizontal well
When the steam injection well is a vertical well and the oil production well is a horizontal well, the calculation is carried out according to a theoretical formula, and the calculation process of the minimum injection pressure under the existing well network is as follows:
when r is1+r2When D, the bottom pressure P of the gas injection well is calculated as the minimum bottom pressure P of the injection wellmin。
In the above formula: l is half length of horizontal section, r1 is theoretical limit well spacing of horizontal well, r2 is theoretical limit well spacing of vertical well, D is distance between actual vertical well and horizontal well, rwIs the wellbore radius, m;
p is the bottom hole pressure of the gas injection well, PiIs the original formation pressure, PwThe bottom hole pressure of the production well is MPa;
lambda is starting pressure gradient, MPa/m;
the formula (4) and the formula (5) are limit theoretical well spacing calculation companies of the vertical well and the horizontal well under the condition of considering the starting pressure gradient respectively; only if the sum of the two distances is less than the actual well distance, the displacement pressure system can be established and fluid will flow.
Step 6) calculating the minimum oil reservoir steam temperature Tmin
Minimum gas injection bottom pressure P obtained according to step 5minSubstituting into equation (3) yields equation (6):
minimum injection well bottom pressure PminThe lower corresponding steam temperature is the lowest reservoir steam temperature Tmin：
Step 7) calculating the highest oil reservoir steam temperature Tmax
And (3) calculating to obtain the highest oil reservoir steam temperature by taking the stratum fracture pressure of the target area as an upper limit:
in formula (8): pfraFor formation fracture pressure, MPa, &lTtTtransition = 'α' &gTt α &lTt/T &gTt0Taking the expansion coefficient of crude oil under Pmin pressure, CoAnd taking the compression coefficient of the crude oil at the original oil reservoir temperature Ti.
The above-mentioned contents are only for illustrating the technical idea of the present invention, and the protection scope of the present invention is not limited thereby, and any modification made on the basis of the technical idea of the present invention falls within the protection scope of the claims of the present invention.
Claims (6)
1. A dense oil steam flooding steam temperature design method is characterized by comprising the following steps:
step 1, testing the expansion coefficient of crude oil α under different pressureso(ii) a Testing the compression coefficient C of crude oil at different temperatureso；
Step 2, obtaining the crude oil expansion coefficient α under different pressures according to the step 1oAnd compression coefficient C of crude oil at different temperaturesoCalculating the formation pressure P at different reservoir temperatures;
step 3, carrying out compact oil-steam flooding starting pressure gradient test to obtain a target compact oil reservoir steam injection starting pressure gradient lambda;
step 4Calculating theoretical limit well spacing r of the horizontal well according to the stratum pressure P at different reservoir temperatures obtained in the step 2 and the starting pressure gradient lambda obtained in the step 31Theoretical limit well spacing r of vertical well2Calculating the minimum injection well bottom pressure P under the combined well spacing of the vertical well and the horizontal wellmin；
Step 5, obtaining the minimum bottom pressure P of the injection well according to the step 4minThe expansion coefficient of crude oil obtained in step 1 is αoAnd crude oil compressibility factor CoCalculating the minimum reservoir steam temperature TminThe expansion coefficient of the crude oil obtained according to the step 1 is αoAnd crude oil compressibility factor CoCalculating the maximum oil deposit steam temperature T by taking the stratum fracture pressure of the target area as an upper limitmax。
2. The method for designing the steam flooding temperature of tight oil as claimed in claim 1, wherein in step 2, the formation pressure P after the crude oil expands at different reservoir temperatures is calculated according to the following formula:
in the above formula, αoThe expansion coefficient of the crude oil is 1/DEG C; coThe compression coefficient of the crude oil is 1/MPa; t is the temperature, DEG C, T of the expanded crude oiliTo the original reservoir temperature, PiIs the formation original pressure, MPa.
3. The method for designing the steam flooding temperature of the tight oil according to claim 1, wherein in the step 3, a core physical model experiment is utilized to measure a steam injection starting pressure gradient of the target tight oil reservoir, and the starting pressure gradient is lambda.
4. The method for designing dense oil-steam flooding steam temperature according to claim 1, characterized in that in the step 4, the minimum injection well bottom pressure P is calculatedminThe process of (2) is as follows:
r1+r2＝D (3)；
the simultaneous formulas (1), (2) and (3) are shown, and the obtained bottom pressure P of the gas injection well is the minimum bottom pressure P of the injection wellminIn the formulas (1) to (3), L is half length of horizontal section, r1 is theoretical limit well distance of horizontal well, r2 is theoretical limit well distance of vertical well, D is distance between actual vertical well and horizontal well, rwIs the wellbore radius; p is the bottom hole pressure of the gas injection well, PiIs the original formation pressure, PwIs the bottom hole pressure of the production well; λ is the starting pressure gradient.
5. The method for designing the steam temperature for tight oil steam flooding according to claim 1, wherein in the step 5, the lowest reservoir steam temperature T isminThe calculation formula of (2) is as follows:
α0taking the expansion coefficient of crude oil under Pmin pressure, CoAnd taking the compression coefficient of the crude oil at the original oil reservoir temperature Ti.
6. The method as claimed in claim 1, wherein in step 5, the maximum reservoir steam temperature T is set asmaxThe calculation formula of (2) is as follows:
wherein: pfraFor formation fracture pressure, α0Taking the expansion coefficient of crude oil under Pmin pressure, CoAnd taking the compression coefficient of the crude oil at the original oil reservoir temperature Ti.
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Application publication date: 20200417 |