CN112761626A - Method for determining gas-liquid interface position between SAGD injection and production wells - Google Patents
Method for determining gas-liquid interface position between SAGD injection and production wells Download PDFInfo
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- 238000002347 injection Methods 0.000 title claims abstract description 62
- 239000007924 injection Substances 0.000 title claims abstract description 62
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- 238000010796 Steam-assisted gravity drainage Methods 0.000 title claims abstract description 25
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- 238000004134 energy conservation Methods 0.000 claims abstract description 7
- 239000007791 liquid phase Substances 0.000 claims description 37
- 239000012808 vapor phase Substances 0.000 claims description 19
- 239000012530 fluid Substances 0.000 claims description 16
- 239000010779 crude oil Substances 0.000 claims description 14
- 238000011161 development Methods 0.000 claims description 10
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 10
- 238000004458 analytical method Methods 0.000 claims description 9
- 230000005484 gravity Effects 0.000 claims description 9
- 238000010793 Steam injection (oil industry) Methods 0.000 claims description 7
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- 238000000605 extraction Methods 0.000 claims description 4
- 238000002844 melting Methods 0.000 claims description 3
- 230000008018 melting Effects 0.000 claims description 3
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
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- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
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- 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
- E21B43/2406—Steam assisted gravity drainage [SAGD]
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Abstract
Aiming at the steam-assisted gravity drainage process, the invention utilizes the injection and production wells to monitor the data of nearby temperature monitoring wells, analyzes the temperature change characteristics of the gas-liquid interface between the injection and production wells by means of an energy conservation equation, and establishes a new method for determining the position of the gas-liquid interface between the SAGD injection and production wells by utilizing the temperature monitoring wells through calculating and judging the temperature gradient change of the positions at different vertical depths at the monitoring wells.
Description
Technical Field
The invention belongs to the field of oil and gas field development, and particularly relates to a method for determining a gas-liquid interface position between SAGD injection wells.
Background
In the Steam Assisted Gravity Drainage (SAGD) production process, the position of a steam-liquid interface between injection wells is judged and controlled, and the SAGD development effect is very important. If the steam-liquid interface is positioned below the horizontal production well, steam injected from the horizontal steam injection well directly enters the horizontal production well below, so that steam channeling and steam ineffective circulation are caused, and the development effect is influenced. If the vapor-liquid interface is located above the horizontal vapor injection well, the injected vapor will contact the liquid above first, which will reduce the temperature of the injected vapor, reduce the thermal efficiency of the vapor, and have an adverse effect on the effective expansion of the vapor cavity. The optimal steam-liquid interface position is positioned between the horizontal steam injection well and the horizontal production well, so that injected steam can be ensured to effectively promote the development of a steam cavity, and meanwhile, the injected steam cannot directly enter the production well to cause steam channeling, thereby avoiding the waste of steam and the reduction of the steam heat utilization rate. At present, the judgment of the position of a gas-liquid interface mainly depends on temperature and pressure monitoring data in a horizontal injection-production well. The method comprehensively utilizes a plurality of data such as injection temperature of the steam injection well, actual measurement values of different pressure and temperature measurement points of the production well along the direction of a shaft, a saturated vapor pressure corresponding curve and the like. Firstly, calculating the corresponding saturated steam temperature at a measuring point according to the corresponding relation between the measuring point pressure and the saturated steam pressure of the production well; secondly, comparing the measured temperature with the measured temperature of the point, if the measured temperature is lower than the calculated saturated steam temperature, the point is liquid, namely a liquid phase area below a steam-liquid interface; if the measured temperature is equal to or greater than the calculated saturated vapor temperature, the temperature is the vapor, i.e., the vapor phase region above the vapor-liquid interface. However, the method can only judge the steam-liquid state conditions of different points of the horizontal production well along the direction of the shaft, and cannot really judge the steam-liquid interface position between the injection and production wells.
Disclosure of Invention
For the actual SAGD exploitation injection-production well pair, a temperature monitoring well is generally arranged near the well pair, and the temperature data is periodically collected to serve as an effective way for representing and describing the temperature change along with the time in the longitudinal direction of a reservoir. Based on the problem that the steam-liquid interface at the production well can only be reflected by the related monitoring data of the injection and production well in the conventional method, the invention provides a novel method for determining the position of the steam-liquid interface between SAGD injection and production wells by using the injection and production well to the nearby temperature monitoring well.
The invention provides a method for determining the position of a gas-liquid interface between SAGD injection and production wells, which is characterized in that the position of the gas-liquid interface between the injection and production wells is obtained by calculating the temperature gradient changes of different depths of monitoring wells near the injection and production wells based on the temperature change characteristic analysis of the gas-liquid interface between the injection and production wells.
The method for determining the position of a gas-liquid interface between SAGD injection wells comprises the following steps:
1) collecting the monitoring data of the injection and production well to the nearby temperature monitoring well,
2) respectively calculating temperature gradient change values at different depths according to the monitoring data acquired in the step 1);
3) and judging the position of a gas-liquid interface between injection wells and production wells according to the temperature gradient change values of different depths.
Wherein the monitoring data in step 1) comprises the change data of the temperature at different depths along with the time.
The calculation method of the temperature gradient change values at different depths in the step 2) is calculation based on the analysis of the temperature change characteristics of the gas-liquid interface between the injection and production wells.
Wherein, the analysis of the temperature change characteristics of the gas-liquid interface between the injection and production wells comprises the following steps:
21) the gas-liquid interface between the injection and production wells is divided into an upper area and a lower area, and a vapor phase area is arranged above the gas-liquid interface, namely the steam injected into the injection well is in a vapor phase state; a liquid phase area is arranged below the vapor-liquid interface and consists of vapor condensed water and crude oil which flows down under the action of gravity after being heated;
22) assuming a homogeneous reservoir, the gas-liquid interface between injection wells and production wells is a horizontal interface, and only the migration of fluid on a vertical section is considered, and the energy conservation formula at the gas-liquid interface is as follows:
Qc＝Qd+N (1)
in the formula, QcEnergy transferred by heat conduction; qdEnergy transferred by convection; n is the change of the internal energy along with time;
23) and (3) transforming the formula in the step (2) to obtain:
in the formula, crHot melting for oil deposit, J/kg. ℃; rho is the reservoir density, kg/m3(ii) a C is the thermal conductivity of the liquid phase region reservoir and the fluid at the gas-liquid interface, W/m. T is the temperature of the liquid phase zone at the vapor-liquid interface, DEG C; v. ofx、vyThe fluid flow velocities in the x and y directions, m/s, respectively;
24) for SAGD development, condensed steam and heated crude oil form a liquid phase region, and compared with the distribution range of a liquid phase region between injection wells and production wells, the condensed water flowing into the liquid phase region under the action of gravity and the heated crude oil in unit time have negligible influence on the temperature of a porous medium in the liquid phase region at a steam-liquid interface, namely
Since the fluid flow in the vapor chamber is mainly influenced by gravity in the vertical direction, its component force in the horizontal direction is almost zero, together with the large liquid phase region distribution range and the low flow velocity of the condensed water and the heated crude oil at the vapor-liquid interface, the horizontal and vertical directions are due to the fluid movement (v)x、vy) The resulting convective heat transfer is negligible, i.e.:
25) substituting the analysis result in step 24) into formula (2) in step 23) to obtain:
formula (5) is the gradient of temperature in the y direction, i.e. the gradient change value of temperature at different depths, and is used to determine the vapor-liquid state at the depth y, and indirectly determine whether the y is in the liquid phase region. As follows, when the gradient is 0, no temperature difference is demonstrated, then y is in the vapor state, or vapor phase zone; the gradient is not 0, indicating that there is a difference in temperature at y, and is now in a liquid state, or liquid phase region.
Wherein, the determination method in the step 3) is that if the depth y is equal to y1At the position of the air compressor, the air compressor is started,
then y is1Is positioned in a vapor phase area; if the depth y is equal to y2At the position of the air compressor, the air compressor is started,
then y is2Is a liquid phase region; between the depths y1 and y2 there is a depth y ═ y3At the position of the air compressor, the air compressor is started,
is a first value that changes from zero to a non-zero constant, then y3The position of the gas-liquid interface is.
The invention has the beneficial effects that: the conventional method can only judge the vapor-liquid state of the production well through the temperature and pressure measurement result of the production well, and cannot determine the vapor-liquid position between injection wells and extraction wells; the invention provides a method for calculating and distinguishing the position of a gas-liquid interface between injection and production wells by calculating the temperature gradient change of different depths of monitoring wells near the injection and production wells based on the characteristic analysis of the gas-liquid interface temperature change between the injection and production wells.
Drawings
FIG. 1 is a schematic diagram of the vapor-liquid two-phase region distribution in an ideal state of the SAGD development process;
FIG. 2 shows a monitoring well L1(a) And L2(b) Different depth temperature gradient calculations (results after partial depth calculations).
Detailed Description
The principles and features of this invention are described below in conjunction with the following drawings, which are set forth by way of illustration only and are not intended to limit the scope of the invention.
The method aims at the steam-assisted gravity drainage process, utilizes monitoring data (detection data specifically comprises data of temperature changes at different depths along with time) of temperature monitoring wells near an injection-production well pair (the injection-production well pair is equivalent to a whole and expresses that the temperature monitoring wells beside the injection-production well pair) to analyze the temperature change characteristics of a steam-liquid interface between the injection wells and the production wells by means of an energy conservation equation, and establishes a novel method for determining the position of the steam-liquid interface between the SAGD injection wells and the production wells by utilizing the temperature monitoring wells through calculating and judging the temperature gradient changes at the vertical different depths of the monitoring wells.
For SAGD development, the ideal state vapor-liquid interface location is shown in section 1(a), i.e., the vapor-liquid interface is between the steam injection well and the production well. In the figure, DI、DPThe depth of the steam injection well and the production well at the corresponding positions of the monitoring well is m; li is the planar distance, m, between the monitoring well and the injection and production well. A vapor phase area is arranged above the vapor-liquid interface, namely, the vapor injected into the vapor injection well is in a vapor phase state; below the vapor-liquid interface is a liquid phase zone consisting of vapor condensate and heated crude oil that flows down by gravity. Assuming a homogeneous reservoir, the gas-liquid interface between injection wells and production wells is a horizontal interface, and only migration of fluid on a vertical section is considered.
The formula of energy conservation at a vapor-liquid interface is as follows:
Qc＝Qd+N (1)
in the formula, QcEnergy transferred by heat conduction; qdEnergy transferred by convection; n is the change of the internal energy with time.
In the formula, crHot melting for oil deposit, J/kg. ℃; rho is the reservoir density, kg/m3(ii) a C is the thermal conductivity of the liquid phase region reservoir and the fluid at the gas-liquid interface, W/m. T is the temperature of the liquid phase zone at the vapor-liquid interface, DEG C; v. ofx、vyThe fluid flow velocities in the x and y directions, m/s, respectively. Equation (2) is a variant of the energy conservation equation. The energy conservation formula is: the amount of energy change-the energy absorbed by the system from the environment-the work the system does on the environment. For the process of the present invention, there is no work the system does on the environment. Therefore, the method is simplified as follows: the amount of internal energy change is the amount of energy the system absorbs from the environment. The energy absorbed from the environment is divided into three types, namely heat conduction, heat transfer and heat radiation. In the present invention, the heat radiation effect is not considered, so that the formula (2) is obtained for both heat conduction and heat transfer.
For SAGD development, the condensed steam and heated crude oil constitute the liquid phase zone. The horizontal injection-production well pair has the well length of 300-1500 m, the distance between the adjacent injection-production well pairs of 40-150 m and the liquid phase region distribution range is large. Compared with the distribution range of the liquid phase region between injection wells and production wells, the condensed water flowing into the liquid phase region under the action of gravity and the heated crude oil in unit time have negligible influence on the temperature of the porous medium in the liquid phase region at the gas-liquid interface. Namely:
in addition, since the fluid flow in the steam chamber is mainly influenced by gravity in the vertical direction, the component force in the horizontal direction is almost zero. Coupled with the larger liquid phase region distribution and the lower flow velocities of the condensed water and heated crude oil at the vapor-liquid interface, both horizontally and vertically due to fluid movement (v)x、vy) The resulting convective heat transfer is negligible. Namely:
in addition, due to the SAGD process, injected steam migrates upward, condensed water and heated crude oil migrates downward, and temperature changes are mainly reflected as temperature changes in the vertical direction. In summary, in combination with equations (3) and (4), equation (2) may become:
using equation (5), the liquid-phase interface level at the monitoring well can be calculated.
If y ═ y1At the position of the air compressor, the air compressor is started,
then y is1Is positioned in a vapor phase area;
if y ═ y2At the position of the air compressor, the air compressor is started,
then y is2Is a liquid phase region;
if y ═ y3At the position of the air compressor, the air compressor is started,
is a first value that changes from zero to a non-zero constant, then y3The position of the gas-liquid interface is.
As shown in fig. 1b, the temperature gradient is constant in both the vapor phase region and the liquid phase region, but different constants can be used to distinguish the vapor phase region from the liquid phase region: d1 and D2 were located in the vapor phase zone. For the vapor phase region, since the pressure in the entire vapor phase region is the same value (because of the same vapor chamber), D1 and D2 have the same temperature, i.e., TD1＝TD2The vapor temperature is the vapor temperature corresponding to the vapor phase zone pressure (this is a fixed correspondence of saturated vapor pressure and temperature). Therefore, the temperature gradient is constant and 0, it can be determined that this is a vapor phase region. D3 and D4 were located in the liquid phase region. For the liquid phase region, the positions of different depths, pressureThe properties of the fluids (condensed water and crude oil) in the pore throat skeleton and pores are not changed in the longitudinal direction, and the temperature is changed uniformly in the longitudinal direction (gradually decreased temperature, T)D4<TD3) I.e. a constant, but non-zero, temperature gradient. By utilizing the rule, the point that the temperature gradient changes from 0 to a nonzero constant is found, and the vapor-liquid interface can be judged.
Example 1
The use of the method is illustrated by taking two nearby temperature monitoring wells for the development of different injection and production wells by SAGD of a certain oil field as an example. The details are as follows.
According to the method, the temperature gradients of the corresponding depth positions of two monitoring wells are respectively calculated, as shown in figure 2 (the result after partial depth calculation is shown in figure 2; the longitudinal temperature of the monitoring wells is not provided with a measuring point at each depth, a measuring point may be arranged at every 1m or every 2 m; the measuring points are arranged at the monitoring wells relative to the upper part and the lower part of an injection and production well. For the monitoring well L1, the depth of the corresponding injection well is-195 m, and the depth of the corresponding production well is-200 m; for monitoring well L2, the corresponding injection well depth is-202 m and the production well depth is-206 m.
As can be seen from fig. 2(a), in month 1 in 2013, when the temperature gradient at a depth of 196m is 0 and the other depths are nonzero constants, it can be determined that the vapor-liquid interface is located at 196m and the vapor-liquid interface is located between the injection well (depth 195m) and the production well (depth 200 m). And the temperature gradient from the depth of 196m to the depth of 199m is changed into 0 in sequence from 1 month to 2013 and 6 months, which shows that the vapor phase zone gradually moves downwards in the time, namely the vapor-liquid interface is positioned between injection and production wells and gradually moves towards production wells. As can be seen from fig. 2(b), the temperature gradients at the corresponding depth positions between the injection wells and the production wells are all nonzero constants during the monitoring time, which means that the gas-liquid interface is located above the injection well during the monitoring time. After 1 month 2015, the temperature gradient at each depth position gradually tended to a non-zero constant. Since the depth-202 m corresponds to the injection well depth, it is shown that the injection well depth has been a liquid phase region at all times during the monitoring time, and the vapor-liquid interface is above the injection well. The determination of the vapor-liquid interface is to determine the position of the vapor-liquid interface at one time point, that is, at a certain time point. In the embodiment, if the change of the temperature gradient along with the time can be plotted, the change of the vapor-liquid interface position along with the time can be judged.
The two monitoring wells in the implementation correspond to different injection-production well pairs. And each injection well and production well pair is also provided with a monitoring well. In the present embodiment, two injection-production well pairs are taken as examples, and different situations are respectively described. The monitoring well 1 is used for explaining the condition that the judgment result is that the gas-liquid interface is positioned between injection wells and production wells; the case of determining that the vapor-liquid interface is always located above the injection well is described with the detection well 2.
The above description is only for the purpose of illustrating the preferred embodiments of the present invention and is not to be construed as limiting the invention, and any modifications, equivalents, improvements and the like that fall within the spirit and principle of the present invention are intended to be included therein.
Claims (6)
1. The method is characterized in that the method is based on the analysis of the temperature change characteristics of the gas-liquid interface between injection wells and extraction wells, and the gas-liquid interface between the injection wells and the extraction wells is obtained by calculating the temperature gradient changes at different depths of monitoring wells near the injection wells and the extraction wells.
2. The method for determining the position of a gas-liquid interface between SAGD injection and production wells according to claim 1, characterized by comprising the following steps:
1) collecting the monitoring data of the injection and production well to the nearby temperature monitoring well,
2) respectively calculating temperature gradient change values at different depths according to the monitoring data acquired in the step 1);
3) and judging the position of a gas-liquid interface between the injection and production wells according to the temperature gradient change values of different depths obtained in the step 2).
3. The method for determining the position of a gas-liquid interface between SAGD injection and production wells according to claim 1, wherein the monitoring data in step 1) includes data of temperature change at different depths with time.
4. The method for determining the position of a steam-liquid interface between SAGD injection and production wells according to claim 1, wherein the calculation method of the temperature gradient change values at different depths in step 2) is calculation based on the characteristic analysis of the steam-liquid interface temperature change between the injection and production wells.
5. The method of claim 4, where the analysis of the inter-injection-production well gas-liquid interface temperature variation characteristics comprises:
21) the steam injection and production well is divided into an upper area and a lower area by a steam-liquid interface, and a vapor phase area is arranged above the steam-liquid interface, namely the steam injected into the steam injection well is in a vapor phase state; a liquid phase area is arranged below the vapor-liquid interface and consists of vapor condensed water and crude oil which flows down under the action of gravity after being heated;
22) assuming a homogeneous reservoir, the gas-liquid interface between injection wells and production wells is a horizontal interface, and only the migration of fluid on a vertical section is considered, and the energy conservation formula at the gas-liquid interface is as follows:
Qc＝Qd+N (1)
in the formula, QcEnergy transferred by heat conduction; qdEnergy transferred by convection; n is the change of the internal energy along with time;
23) and (3) transforming the formula in the step (2) to obtain:
in the formula, crHot melting for oil deposit, J/kg. ℃; rho is the reservoir density, kg/m3(ii) a C is the thermal conductivity of the liquid phase region reservoir and the fluid at the gas-liquid interface, W/m. T is the temperature of the liquid phase zone at the vapor-liquid interface, DEG C; v. ofx、vyThe fluid flow velocities in the x and y directions, m/s, respectively;
26) for SAGD development, condensed steam and heated crude oil form a liquid phase region, and compared with the distribution range of a liquid phase region between injection wells and production wells, the condensed water flowing into the liquid phase region under the action of gravity and the heated crude oil in unit time have negligible influence on the temperature of a porous medium in the liquid phase region at a steam-liquid interface, namely
Since the fluid flow in the vapor chamber is mainly influenced by gravity in the vertical direction, its component force in the horizontal direction is almost zero, together with the large liquid phase region distribution range and the low flow velocity of the condensed water and the heated crude oil at the vapor-liquid interface, the horizontal and vertical directions are due to the fluid movement (v)x、vy) The resulting convective heat transfer is negligible, i.e.:
27) substituting the analysis result in step 24) into formula (2) in step 23) to obtain:
Equation (5) is the gradient of temperature in the y-direction, i.e., the temperature gradient change value at different depths.
6. The method for determining the position of a gas-liquid interface between SAGD injection and production wells as claimed in claim 5, wherein said determination in step 3) is that if the depth y is equal to y1At the position of the air compressor, the air compressor is started,
then y is1Is positioned in a vapor phase area; if the depth y is equal to y2At the position of the air compressor, the air compressor is started,
then y is2Is a liquid phase region; between the depths y1 and y2 there is a depth y ═ y3At the position of the air compressor, the air compressor is started,
is a first value that changes from zero to a non-zero constant, then y3The position of the gas-liquid interface is.
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Citations (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN101892826A (en) * | 2010-04-30 | 2010-11-24 | 钟立国 | Gas and electric heating assisted gravity oil drainage technology |
| CN102080537A (en) * | 2011-01-11 | 2011-06-01 | 中国石油天然气股份有限公司 | SAGD oil reservoir double-horizontal-well gas-liquid interface determining method and system |
| US20110288778A1 (en) * | 2008-11-28 | 2011-11-24 | Schlumberger Technology Corporation | Method for estimation of sagd process characteristics |
| CA2958648A1 (en) * | 2016-02-26 | 2017-08-26 | Noetic Technologies Inc. | Method for controlling fluid interface level in gravity drainage oil recovery processes with crossflow |
| CN111577255A (en) * | 2020-05-21 | 2020-08-25 | 盘锦辽油晨宇集团有限公司 | Natural gas storage temperature pressure and vibration monitoring system |
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Patent Citations (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US20110288778A1 (en) * | 2008-11-28 | 2011-11-24 | Schlumberger Technology Corporation | Method for estimation of sagd process characteristics |
| CN101892826A (en) * | 2010-04-30 | 2010-11-24 | 钟立国 | Gas and electric heating assisted gravity oil drainage technology |
| CN102080537A (en) * | 2011-01-11 | 2011-06-01 | 中国石油天然气股份有限公司 | SAGD oil reservoir double-horizontal-well gas-liquid interface determining method and system |
| CA2958648A1 (en) * | 2016-02-26 | 2017-08-26 | Noetic Technologies Inc. | Method for controlling fluid interface level in gravity drainage oil recovery processes with crossflow |
| CN111577255A (en) * | 2020-05-21 | 2020-08-25 | 盘锦辽油晨宇集团有限公司 | Natural gas storage temperature pressure and vibration monitoring system |
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