CN112761626B - Method for determining steam-liquid interface position between SAGD injection and production wells - Google Patents
Method for determining steam-liquid interface position between SAGD injection and production wells Download PDFInfo
- Publication number
- CN112761626B CN112761626B CN202011607639.8A CN202011607639A CN112761626B CN 112761626 B CN112761626 B CN 112761626B CN 202011607639 A CN202011607639 A CN 202011607639A CN 112761626 B CN112761626 B CN 112761626B
- Authority
- CN
- China
- Prior art keywords
- liquid interface
- injection
- vapor
- temperature
- steam
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Active
Links
Images
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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 DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
- E21B43/2406—Steam assisted gravity drainage [SAGD]
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
- E21B43/30—Specific pattern of wells, e.g. optimizing the spacing of wells
-
- 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
- Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
- Y02E10/00—Energy generation through renewable energy sources
- Y02E10/10—Geothermal energy
Abstract
Aiming at the steam-assisted gravity drainage process, the invention utilizes the monitoring data of the injection well to the nearby temperature monitoring well, analyzes the temperature change characteristics of the steam-liquid interface between the injection well and the production well by means of an energy conservation equation, and establishes a novel method for determining the steam-liquid interface position between the SAGD injection well and production well by utilizing the temperature monitoring well through calculating and judging the temperature gradient changes of the vertical different depth positions at the monitoring well.
Description
Technical Field
The invention belongs to the field of oil and gas field development, and particularly relates to a method for determining the position of a gas-liquid interface between SAGD injection and production wells.
Background
In the production process of steam assisted gravity drainage (steam assisted gravity drainage, SAGD), judging and controlling the position of a steam-liquid interface between injection and production wells is important for SAGD development effect. If the gas-liquid interface is positioned below the horizontal production well, the steam injected by 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 affected. If the vapor-liquid interface is located above the horizontal vapor injection well, the injected vapor will first contact the liquid above, which will reduce the temperature of the injected vapor, reduce the thermal efficiency of the vapor, and adversely affect the effective expansion of the vapor chamber. The optimal vapor-liquid interface position is positioned between the horizontal vapor injection well and the horizontal production well, so that the injected vapor can be ensured to effectively promote the development of a vapor cavity, and meanwhile, the vapor can not directly enter the production well to cause vapor channeling, thereby avoiding the vapor waste and the reduction of the vapor heat utilization rate. At present, the judgment of the position of a gas-liquid interface mainly depends on monitoring data of the temperature and the pressure in a horizontal injection well. And integrating a plurality of data such as injection temperature of the steam injection well, actual measurement values of different pressure and temperature measuring points of the production well along the shaft direction, 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 pressure and the saturated steam pressure of the measuring point of a production well; secondly, comparing the measured temperature with the measured temperature at the point, and if the measured temperature is lower than the calculated saturated steam temperature, obtaining liquid at the position, namely a liquid phase region below a vapor-liquid interface; if the measured temperature is equal to or greater than the calculated saturated steam temperature, the steam is the steam, namely the vapor phase area above the vapor-liquid interface. However, the method can only judge the gas-liquid state conditions of different points of the horizontal production well along the shaft direction, and cannot truly judge the gas-liquid interface positions between the injection and production wells.
Disclosure of Invention
For practical SAGD development of injection and production well pairs, temperature monitoring wells are typically placed in close proximity to the well pairs, by periodically collecting temperature data, as an effective way to characterize and describe the temperature changes over time in the longitudinal direction of the reservoir. Based on the conventional method, the problem that the gas-liquid interface at the production well can only be reflected by using the relevant monitoring data of the injection well, the invention provides a novel method for determining the gas-liquid interface position between SAGD injection and production wells by using the injection well to monitor the nearby temperature.
The invention provides a method for determining the position of a steam-liquid interface between SAGD injection and production wells, which is characterized in that the steam-liquid interface position between the injection and production wells is obtained by calculating the temperature gradient changes of different depths at monitoring wells near the injection and production wells based on the characteristic analysis of the steam-liquid interface temperature changes between the injection and production wells.
The method for determining the steam-liquid interface position between SAGD injection and production wells comprises the following steps:
1) The method comprises the steps of collecting monitoring data of a nearby temperature monitoring well by an injection and production well,
2) Respectively calculating temperature gradient change values of 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 well and the production well according to the temperature gradient change values of different depths.
Wherein, the monitoring data in the step 1) comprises time-varying data of temperatures at different depths.
The calculation method of the temperature gradient change values with different depths in the step 2) is based on the analysis of the characteristic of the temperature change of the gas-liquid interface between the injection and production wells.
The characteristic analysis of the temperature change of the gas-liquid interface between the injection and production wells comprises the following steps:
21 A gas-liquid interface between the injection well and the production well is divided into an upper area and a lower area, wherein a vapor phase area is arranged above the gas-liquid interface, namely, the injected steam of the injection well is in a vapor phase state; a liquid phase zone is arranged below the vapor-liquid interface and consists of vapor condensate 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 the injection and production wells is a horizontal interface, and only the migration of the fluid on the vertical section is considered, and the energy conservation formula at the gas-liquid interface is as follows:
Q c ＝Q d +N (1)
in which Q c Is energy transferred by heat conduction; q (Q) d Is energy transferred by convection; n is the change of internal energy with time;
23 The formula in the step 2) is transformed to obtain:
wherein, c r Is oil deposit hot melting, J/kg. ℃; ρ is the reservoir density, kg/m 3 The method comprises the steps of carrying out a first treatment on the surface of the C is the thermal conductivity of the liquid phase zone reservoir and the fluid at the vapor-liquid interface, W/m DEG C. T is the temperature of a liquid phase region at a vapor-liquid interface and is at the temperature of DEG C; v x 、v y Fluid flow velocity in x, y directions, m/s, respectively;
24 For SAGD development, condensed steam and heated crude oil form a liquid phase zone, compared with the distribution range of the liquid phase zone between injection and production wells, the condensed water and heated crude oil flowing into the liquid phase zone under the action of gravity in unit time have negligible influence on the temperature of porous medium in the liquid phase zone at a vapor-liquid interface, namely
Since the fluid flow in the steam cavity is mainly affected by gravity in the vertical direction, its component in the horizontal direction is almost zero, combined with a large liquid phase separation range and a low flow velocity of condensate and heated crude oil at the steam-liquid interface, the horizontal and vertical directions are due to fluid movement (v x 、v y ) The resulting convective heat transfer is negligible, namely: />
25 Bringing the analysis result in step 24) into formula (2) in step 23), resulting in:
the formula (5) is the gradient of the temperature in the y direction, namely the temperature gradient change values of different depths, and is used for judging the vapor-liquid state at the depth y and indirectly judging whether the y is in a liquid phase region or not. As described below, when the gradient is 0, and no temperature difference is confirmed, the y is in a vapor state, or a vapor phase region; the gradient is not 0, which means that there is a difference in temperature at y, which is then in the liquid state, or liquid phase region.
Wherein, the liquid crystal display device comprises a liquid crystal display device,the judging method in the step 3) is that if the depth y=y 1 At the position of the first part,
then y 1 Is a vapor phase zone; if the depth y=y 2 At (I) a part of>
Then y 2 The position is a liquid phase region; there is a depth y=y between the depths y1 and y2 3 At (I) a part of>
For a first value from zero to a non-zero constant, then y 3 The position of the gas-liquid interface is shown.
The invention has the beneficial effects that: according to the conventional method, only the vapor-liquid state of the production well can be judged according to the temperature and pressure measurement result of the production well, and the vapor-liquid position between the injection well and the production well cannot be determined; the invention provides a method for calculating and judging the position of a gas-liquid interface between injection and production wells by calculating the temperature gradient changes of different depths at a monitoring well near the injection and production wells based on the characteristic analysis of the temperature change of the gas-liquid interface between the injection and production wells.
Drawings
FIG. 1 is a schematic diagram of a vapor-liquid two-phase zone separation in an ideal state of SAGD development process;
FIG. 2 is a monitoring well L 1 (a) And L 2 (b) Different depth temperature gradient calculations (results after partial depth calculations).
Detailed Description
The principles and features of the present invention are described below with reference to the drawings, the examples are illustrated for the purpose of illustrating the invention and are not to be construed as limiting the scope of the invention.
Aiming at the steam-assisted gravity drainage process, the invention utilizes the monitoring data (the detection data specifically comprises the data of the change of different depths and the temperature along with time) of the temperature monitoring wells nearby the injection and production well pair (the injection and production well pair is used as a whole, and the expression utilizes the temperature monitoring wells nearby the injection and production well pair), analyzes the temperature change characteristics of the steam-liquid interface between the injection and production wells by means of an energy conservation equation, and establishes a novel method for determining the steam-liquid interface position between the SAGD injection and production wells by utilizing the temperature monitoring wells by calculating and judging the temperature gradient change of the vertical different depths of the monitoring wells.
For SAGD development, the ideal state vapor-liquid interface location is as shown in section FIG. 1 (a), i.e., the vapor-liquid interface is between the steam injection well and the production well. In the figure, D I 、D P The depth m of the corresponding position of the steam injection well and the production well at the monitoring well is m; li is the planar distance between the monitoring well and the injection well and m. The vapor-liquid interface is provided with a vapor phase region, namely, the vapor injected by 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 crude oil flowing down under the force of gravity after heating. Assuming a homogeneous reservoir, the gas-liquid interface between the injection and production wells is a horizontal interface, considering only the migration of fluids in the vertical section.
The energy conservation formula at the gas-liquid interface:
Q c ＝Q d +N (1)
in which Q c Is energy transferred by heat conduction; q (Q) d Is energy transferred by convection; n is the change of internal energy with time.
Wherein, c r Is oil deposit hot melting, J/kg. ℃; ρ is the reservoir density, kg/m 3 The method comprises the steps of carrying out a first treatment on the surface of the C is the thermal conductivity of the liquid phase zone reservoir and the fluid at the vapor-liquid interface, W/m DEG C. T is the temperature of a liquid phase region at a vapor-liquid interface and is at the temperature of DEG C; v x 、v y The fluid flow velocity in the x, y directions, m/s, respectively. Equation (2) is a variation of the energy conservation equation. The energy conservation formula is: internal energy change = the energy absorbed by the system from the environment-the work the system performs on the environment. For the course of the present study, no work was done by the system on the environment. Thus, it is simplified as: internal energy change = energy absorbed by the system from the environment. The energy absorbed from the environment is further divided into three types, heat conduction, heat transfer and heat radiation. In the present inventionThe formula (2) is obtained for both heat conduction and heat transfer, irrespective of the heat radiation effect.
For SAGD development, condensed steam and heated crude oil constitute the liquid phase zone. The horizontal injection well pair has a well length of 300-1500 m, the distance between adjacent injection well pairs is 40-150 m, and the liquid phase area is wide. Compared with the distribution range of the liquid phase region between the injection and production wells, the condensed water and heated crude oil flowing into the liquid phase region under the action of gravity in unit time have negligible influence on the temperature of the porous medium in the liquid phase region at the vapor-liquid interface. Namely:
furthermore, since the fluid flow in the steam chamber is mainly affected by gravity in the vertical direction, its component force in the horizontal direction is almost zero. Together with the larger liquid-phase separation range and the lower flow velocity of condensed water and heated crude oil at the vapor-liquid interface, the liquid phase is separated horizontally and vertically by fluid movement (v x 、v y ) The resulting convective heat transfer is negligible. Namely:
in addition, due to the SAGD process, injected steam moves upward, condensed water and heated crude oil move downward, and temperature changes are mainly reflected in changes in the vertical direction. In summary, formula (2) can be changed to:
using equation (5), the liquid phase interface level at the monitoring well can be calculated.
If y=y 1 At the position of the first part,
then y 1 Is a vapor phase zone;
if y=y 2 At the position of the first part,
then y 2 The position is a liquid phase region;
if y=y 3 At the position of the first part,
for a first value from zero to a non-zero constant, then y 3 The position of the gas-liquid interface is shown.
As shown in fig. 1b, in both the vapor phase region and the liquid phase region, the temperature gradient is constant, but different constants can be used to distinguish whether the vapor phase region or the liquid phase region is: d1 and D2 are located in the vapor phase region. For the vapor phase zone, D1 and D2 are the same temperature, although different in depth, due to the same pressure in the entire vapor phase zone (as belonging to one vapor chamber), i.e., T D1 ＝T D2 The vapor temperature (which is a fixed correspondence between saturated vapor pressure and temperature) is the vapor temperature corresponding to vapor phase zone pressure. Therefore, the temperature gradient is constant and 0, and it can be determined that this is the vapor phase region. D3 and D4 are located in the liquid phase region. For the liquid phase region, the positions of different depths, the pressure and the temperature are different, and the property of the fluid (condensed water and crude oil) in the pore-throat framework and the pores is considered to be unchanged in the longitudinal direction, and the change of the temperature in the longitudinal direction is consistent (the temperature gradually decreases, T D4 <T D3 ) I.e. the temperature gradient is constant but non-zero. By utilizing the rule, the point that the temperature gradient changes from 0 to a non-zero constant is found, and the vapor-liquid interface can be judged.
Example 1
The method of the invention is described by taking two adjacent temperature monitoring wells for developing different injection and production wells by SAGD of a certain oil field as an example. Specifically, the following is described.
According to the method of the invention, temperature gradients of corresponding depth positions of two monitoring wells are calculated respectively, as shown in figure 2 (the result of partial depth calculation in figure 2 is that the longitudinal temperature of the monitoring wells is not provided with a measuring point at each depth, one measuring point can be arranged at every 1m or one measuring point can be arranged at every 2m, and the measuring points are arranged above and below the opposite injection and production wells at the monitoring wells. For the monitoring well L1, the corresponding injection well depth is-195 m, and the production well depth is-200 m; for the 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 of 2013, the temperature gradient at 196m is 0, and the other depths are nonzero constants, and it can be determined that the gas-liquid interface is 196m, and the gas-liquid interface is located between the injection well (depth 195 m) and the production well (depth 200 m). The temperature gradient from-196 m to-199 m in the depth from 1 month 2013 to 6 months 2013 becomes 0 in sequence, which means that the vapor phase zone gradually moves downwards in the time, i.e. the vapor-liquid interface is positioned between the injection and production wells and gradually moves towards the production wells. As can be seen from fig. 2 (b), the temperature gradients at the corresponding depth positions between the injection wells are all non-zero constants during the monitoring time, and the vapor-liquid interface is located above the injection well during the monitoring time. After 1 month of 2015, the temperature gradient at each depth position gradually tends to a non-zero constant. Since the depth-202 m corresponds to the depth of the injection well, it is indicated that the depth of the injection well is always a liquid phase region and the vapor-liquid interface is located above the injection well during the monitoring time. The determination of the vapor-liquid interface is to determine the position of the vapor-liquid interface with respect to one time point, that is, at a certain time point. In the embodiment, if the change of the temperature gradient along with time can be plotted, the change of the gas-liquid interface position along with time can be used for distinguishing.
Two monitoring wells in this implementation correspond to different pairs of injection and production wells. Each injection well pair is actually used for one monitoring well. In this embodiment, two pairs of injection wells are taken as examples, and different cases are described respectively. The condition that the gas-liquid interface is positioned between the injection well and the production well is explained by using the monitoring well 1; the detection well 2 is used to illustrate the case where it is determined that the vapor-liquid interface is always located above the injection well.
The foregoing description of the preferred embodiments of the invention is not intended to limit the invention to the precise form disclosed, and any such modifications, equivalents, and alternatives falling within the spirit and scope of the invention are intended to be included within the scope of the invention.
Claims (3)
1. The method for determining the steam-liquid interface position between SAGD injection and production wells is characterized in that the method is based on the characteristic analysis of the steam-liquid interface temperature variation between the injection and production wells, and the steam-liquid interface position between the injection and production wells is obtained by calculating the temperature gradient variation of different depths at the monitoring well near the injection and production wells; the method specifically comprises the following steps:
1) The method comprises the steps of collecting monitoring data of a nearby temperature monitoring well by an injection and production well,
2) Respectively calculating temperature gradient change values with different depths according to the monitoring data acquired in the step 1), wherein the calculation method of the temperature gradient change values with different depths in the step 2) is based on the calculation made by the analysis of the temperature change characteristics of the gas-liquid interface between the injection and production wells;
3) Judging the position of a gas-liquid interface between the injection and production wells according to the temperature gradient change values with different depths obtained in the step 2);
the characteristic analysis of the temperature change of the steam-liquid interface between the injection and production wells comprises the following steps:
21 The inside of the injection well is divided into an upper area and a lower area by a vapor-liquid interface, and a vapor phase area is arranged above the vapor-liquid interface, namely, the injected vapor of the injection well is in a vapor phase state; a liquid phase zone is arranged below the vapor-liquid interface and consists of vapor condensate 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 the injection and production wells is a horizontal interface, and only the migration of the fluid on the vertical section is considered, and the energy conservation formula at the gas-liquid interface is as follows:
Q c ＝Q d +N (1)
in which Q c Is energy transferred by heat conduction; q (Q) d Is energy transferred by convection; n is the change of internal energy with time;
23 The formula in the step 2) is transformed to obtain:
wherein, c r Is oil deposit hot melting, J/kg. ℃; ρ is the reservoir density, kg/m 3 The method comprises the steps of carrying out a first treatment on the surface of the C is the thermal conductivity of a liquid phase region reservoir and fluid at a vapor-liquid interface, and W/m DEG C; t is the temperature of a liquid phase region at a vapor-liquid interface and is at the temperature of DEG C; v x 、v y Fluid flow velocity in x and y directions, m/s, respectively;
24 For SAGD development, condensed steam and heated crude oil form a liquid phase zone, compared with the distribution range of the liquid phase zone between injection and production wells, the condensed water and heated crude oil flowing into the liquid phase zone under the action of gravity in unit time have negligible influence on the temperature of porous medium in the liquid phase zone at a vapor-liquid interface, namely
Since the fluid flow in the steam cavity is mainly affected by gravity in the vertical direction, its component in the horizontal direction is almost zero, combined with a large liquid phase separation range and a low flow velocity of condensate and heated crude oil at the steam-liquid interface, the horizontal and vertical directions are due to fluid movement (v x 、v y ) The resulting convective heat transfer is negligible, namely: />
25 Bringing the analysis result in step 24) into formula (2) in step 23), resulting in:
equation (5) is the temperature gradient in the y-direction, i.e., the temperature gradient change value at different depths.
2. A method for determining the position of a steam-liquid interface between SAGD injection and production wells according to claim 1, wherein the monitoring data in step 1) comprises time-dependent temperature data at different depths.
3. According to claim 2A method for determining the position of a gas-liquid interface between SAGD injection and production wells is characterized in that the judging method in the step 3) is that if the depth y=y 1 At the position of the first part,
then y 1 Is a vapor phase zone; if the depth y=y 2 At the position of the first part,
then y 2 The position is a liquid phase region; there is a depth y=y between the depths y1 and y2 3 At (I) a part of>
For a first value from zero to a non-zero constant, then y 3 The position of the gas-liquid interface is shown.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202011607639.8A CN112761626B (en) | 2020-12-30 | 2020-12-30 | Method for determining steam-liquid interface position between SAGD injection and production wells |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202011607639.8A CN112761626B (en) | 2020-12-30 | 2020-12-30 | Method for determining steam-liquid interface position between SAGD injection and production wells |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN112761626A CN112761626A (en) | 2021-05-07 |
| CN112761626B true CN112761626B (en) | 2023-06-20 |
Family
ID=75697567
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN202011607639.8A Active CN112761626B (en) | 2020-12-30 | 2020-12-30 | Method for determining steam-liquid interface position between SAGD injection and production wells |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN112761626B (en) |
Citations (4)
| 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 | Method and system for determining liquid-vapor interface between double horizontal SAGD (Steam Assisted Gravity Drainage) reservoir wells |
| 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 |
Family Cites Families (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN102272418B (en) * | 2008-11-28 | 2014-09-17 | 普拉德研究及开发股份有限公司 | Method for estimation of sagd process characteristics |
-
2020
- 2020-12-30 CN CN202011607639.8A patent/CN112761626B/en active Active
Patent Citations (4)
| 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 | Method and system for determining liquid-vapor interface between double horizontal SAGD (Steam Assisted Gravity Drainage) reservoir wells |
| 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 |
Also Published As
| Publication number | Publication date |
|---|---|
| CN112761626A (en) | 2021-05-07 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| Song et al. | Numerical analysis of the heat production performance of a closed loop geothermal system | |
| Butler | Rise of interfering steam chambers | |
| Liu et al. | Evolution characteristics of SAGD steam chamber and its impacts on heavy oil production and heat consumption | |
| US8756019B2 (en) | Method for estimation of SAGD process characteristics | |
| Kim et al. | Turbulent film condensation of high pressure steam in a vertical tube | |
| Newell Jr et al. | Analysis of combined free and forced convection for fully developed laminar flow in horizontal tubes | |
| RU2530930C1 (en) | Oil-filled formation preheating method | |
| Ren et al. | Development of force balance model for prediction of bubble departure diameter and lift-off diameter in subcooled flow boiling | |
| You et al. | Models of steam-assisted gravity drainage (SAGD) steam chamber expanding velocity in double horizontal wells and its application | |
| US20150198546A1 (en) | Steam quality meter | |
| Ma et al. | A thermal-dissipation correction method for in-situ soil thermal response test: Experiment and simulation under multi-operation conditions | |
| CN105160161A (en) | Shaft internal thermal parameter calculation method and apparatus | |
| Yuan et al. | Subcool, fluid productivity, and liquid level above a SAGD producer | |
| JP6230025B2 (en) | Thermal response test analysis method and analysis program | |
| CN106951649A (en) | A kind of method for determining horizontal well SAGD vapor chamber expansion rates | |
| CN103175658B (en) | The test method of nuclear power station pipeline leakage rate and system | |
| CN112761626B (en) | Method for determining steam-liquid interface position between SAGD injection and production wells | |
| Jiao et al. | Stratum temperature recovery considering groundwater advection in periodic operations of deep borehole heat exchangers | |
| Wang et al. | Comparative study on effects of macroscopic and microscopic fracture structures on the performance of enhanced geothermal systems | |
| Su et al. | Study on the multi-factors interaction of annular pulsating heat pipe based on response surface method and temperature curve analysis | |
| WO2007094705A1 (en) | Method for determining filtration properties of rocks | |
| Siddiqui et al. | Experimental study of boiling incipience in a closed loop vertical annular thermosiphon | |
| Tournier et al. | The onset of natural convection in vertical fault planes: consequences for the thermal regime in crystalline basementsand for heat recovery experiments | |
| CN103792255B (en) | Rock soil cold and hot response testing system | |
| CA3146692A1 (en) | Infill well methods for hydrocarbon recovery |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| GR01 | Patent grant | ||
| GR01 | Patent grant |