CA1250225A - Burner for igniting an injection well - Google Patents
Burner for igniting an injection wellInfo
- Publication number
- CA1250225A CA1250225A CA000497164A CA497164A CA1250225A CA 1250225 A CA1250225 A CA 1250225A CA 000497164 A CA000497164 A CA 000497164A CA 497164 A CA497164 A CA 497164A CA 1250225 A CA1250225 A CA 1250225A
- Authority
- CA
- Canada
- Prior art keywords
- combustion chamber
- burner
- combustion
- oxidizing gas
- formation
- 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.)
- Expired
Links
- 238000002347 injection Methods 0.000 title claims abstract description 19
- 239000007924 injection Substances 0.000 title claims abstract description 19
- 230000015572 biosynthetic process Effects 0.000 claims abstract description 33
- 238000000034 method Methods 0.000 claims abstract description 20
- 238000010438 heat treatment Methods 0.000 claims abstract description 12
- 238000002485 combustion reaction Methods 0.000 claims description 55
- 239000007789 gas Substances 0.000 claims description 38
- 230000001590 oxidative effect Effects 0.000 claims description 26
- 239000000446 fuel Substances 0.000 claims description 25
- 239000000567 combustion gas Substances 0.000 claims description 17
- 239000000463 material Substances 0.000 claims description 17
- 239000000203 mixture Substances 0.000 claims description 16
- 238000001816 cooling Methods 0.000 claims description 11
- 238000004519 manufacturing process Methods 0.000 claims description 9
- 239000012530 fluid Substances 0.000 claims description 8
- ATUOYWHBWRKTHZ-UHFFFAOYSA-N Propane Chemical compound CCC ATUOYWHBWRKTHZ-UHFFFAOYSA-N 0.000 claims description 4
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims description 4
- 238000004891 communication Methods 0.000 claims description 3
- 239000000112 cooling gas Substances 0.000 claims description 3
- UGFAIRIUMAVXCW-UHFFFAOYSA-N Carbon monoxide Chemical compound [O+]#[C-] UGFAIRIUMAVXCW-UHFFFAOYSA-N 0.000 claims description 2
- RWSOTUBLDIXVET-UHFFFAOYSA-N Dihydrogen sulfide Chemical compound S RWSOTUBLDIXVET-UHFFFAOYSA-N 0.000 claims description 2
- OTMSDBZUPAUEDD-UHFFFAOYSA-N Ethane Chemical compound CC OTMSDBZUPAUEDD-UHFFFAOYSA-N 0.000 claims description 2
- 239000001273 butane Substances 0.000 claims description 2
- 229910002091 carbon monoxide Inorganic materials 0.000 claims description 2
- 239000001257 hydrogen Substances 0.000 claims description 2
- 229910052739 hydrogen Inorganic materials 0.000 claims description 2
- 229910000037 hydrogen sulfide Inorganic materials 0.000 claims description 2
- IJDNQMDRQITEOD-UHFFFAOYSA-N n-butane Chemical compound CCCC IJDNQMDRQITEOD-UHFFFAOYSA-N 0.000 claims description 2
- OFBQJSOFQDEBGM-UHFFFAOYSA-N n-pentane Natural products CCCCC OFBQJSOFQDEBGM-UHFFFAOYSA-N 0.000 claims description 2
- 239000001294 propane Substances 0.000 claims description 2
- 125000004435 hydrogen atom Chemical class [H]* 0.000 claims 1
- QVGXLLKOCUKJST-UHFFFAOYSA-N atomic oxygen Chemical compound [O] QVGXLLKOCUKJST-UHFFFAOYSA-N 0.000 abstract description 12
- 239000001301 oxygen Substances 0.000 abstract description 12
- 229910052760 oxygen Inorganic materials 0.000 abstract description 12
- 238000005755 formation reaction Methods 0.000 description 26
- 229940090044 injection Drugs 0.000 description 13
- 238000011065 in-situ storage Methods 0.000 description 6
- 229910052751 metal Inorganic materials 0.000 description 6
- 239000002184 metal Substances 0.000 description 6
- 238000011084 recovery Methods 0.000 description 6
- 239000004058 oil shale Substances 0.000 description 3
- 238000010793 Steam injection (oil industry) Methods 0.000 description 2
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 2
- 239000004215 Carbon black (E152) Substances 0.000 description 1
- MYMOFIZGZYHOMD-UHFFFAOYSA-N Dioxygen Chemical compound O=O MYMOFIZGZYHOMD-UHFFFAOYSA-N 0.000 description 1
- UFHFLCQGNIYNRP-UHFFFAOYSA-N Hydrogen Chemical compound [H][H] UFHFLCQGNIYNRP-UHFFFAOYSA-N 0.000 description 1
- 239000003570 air Substances 0.000 description 1
- 239000004568 cement Substances 0.000 description 1
- 238000009841 combustion method Methods 0.000 description 1
- 238000005553 drilling Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 229930195733 hydrocarbon Natural products 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 239000011261 inert gas Substances 0.000 description 1
- 150000002739 metals Chemical class 0.000 description 1
- 230000000153 supplemental effect Effects 0.000 description 1
Classifications
-
- 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
- E21B43/243—Combustion in situ
-
- 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
- E21B36/00—Heating, cooling or insulating arrangements for boreholes or wells, e.g. for use in permafrost zones
- E21B36/02—Heating, cooling or insulating arrangements for boreholes or wells, e.g. for use in permafrost zones using burners
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
Abstract
BURNER FOR IGNITING AN INJECTION WELL
ABSTRACT
A method and apparatus for downhole heating of a well which provides for the ignition of an oxygen or fire flood in a hydrocarbonaceous formation or reservoir while generating a flame of a sufficient temperature to avoid damaging a cased well or plugging said formation or reservoir.
ABSTRACT
A method and apparatus for downhole heating of a well which provides for the ignition of an oxygen or fire flood in a hydrocarbonaceous formation or reservoir while generating a flame of a sufficient temperature to avoid damaging a cased well or plugging said formation or reservoir.
Description
~J~ ~ 5 BURNER FOR IGNITING AN INJECTION WELL
This invention relates to the in-situ combustion of a subterranean, viscous oil-containing formation for the recovery of oil. More particularly, the present invention is directed to an apparatus and process for controlling the combustion temperature of a hydrocarbonaceous formation or reservoir.
A variety of supplemental recovery techniques have been employed in order to increase the recovery of viscous oil from subterranean viscous oil-containing formations. These techniques include thermal recovery methods, water flooding and miscible flooding.
Of the aforementioned recovery methods, in-situ combustion appears to be the most promising for econornically recovering large amounts of viscous hydrocarbonaceous deposits with currently available technology. The attractiveness of the in-situ combustion method arises because it requires relatively little energy necessary for sustaining combustion of the hydrocarbon deposits. In contradistinction, other in-situ techniques, such as elec-trical resistance heating and steam injection require considerable amounts of energy, e.g., to heat the steam on the surface before it is injected into the viscous oil-containing formation.
Conventional in-situ combustion involves drilling at least two substantially vertical wells into the formation, the wells being separated by a horizontal distance within the formation. One of the wells is designated an injection well, and the other a production well. The recovery of oil is accomplished by raising the temperature of the in-place oil adjacent the injection well to combustion temperatures by some simple rrleans, e.g., with some type of a conventional downhole heater/burner apparatus, or by steam injec-tion and then supporting combustion by injecting an oxygen-containing gas such as air, oxygen enriched air, oxygen mixed F-3152 --2~~
with an inert gas, or substantially pure oxygen. Thereafter, the injection of the oxygen-containing gas is continued so as to maintain the high temperature combustion front which is formed, and to drive the front through the formation toward the production well. As the combustion front moves through the formation, it displaces ahead of it the in-place oil reduced in viscosity as well as other formation fluids such as water and also combustion gas produced during the combustion process and these fluids are recovered from the formation by the production well.
When using a conventional downhole heater/burner apparatus, in cased wells, it is often necessary to avoid temperatures hot enough to damage the metal contained in the formation and also the burner. It is also desirable to have a method for controlled heating of a cased or uncased well to avoid respectively either damaging the metal casing or plugging the Formation by hydrocarbonaceous materials.
U.S. Patent No. 3~952~801 issued to Burton on April 27~
1976 discusses a technique for igniting the oil shale rubble pile in an in-situ oil shale retort. Here a gas/air burner is lowered through a hole to a plenum over the oil shale to be ignited. An excess of air is passed through the hole and around the burner so that it is kept cool as a flame from it impinges on the rubble pile. The air also transfers heat downwardly into the rubble pile and provides oxygen for combustion of hydrocarbonaceous material in the shale. Preferably the burner is in a cylindrical housing having a flame exit that is lowered in so that a hot flame is ejected downwardly.
Here some of the air from the air supply was forced into the upper portion of the burner for cooling the interior while a hole or holes near the bottom of the burner discharge provided additional cooling air. Additional cooling air was forced into the region surrounding the burner. This air mixed with the air forced down the borehole. This internal cooling of the burner with air that was mixed with the air surrounding the burner significantly s reduced the internal temperature of the burner. As is apparent, the purpose of this method was to cool the burner and provide oxygen for combustion of hydrocarbonaceous material in the shale. The hotter the flame, the better. Indeed, a hot flame was deemed necessary.
Controlling the temperature of the flame was not necessary or required in Burton's technique.
Therefore, what is needed is a method and apparatus for controlling the temperature of the hot gases emitted from the burner in a more direct and simple manner to avoid damaging the metal in cased wells and to avoid plugging hydrocarbonaceous formations or reservoirs.
This invention is directed to a method and apparatus for recovering viscous hydrocarbonaceous material from a sùbterranean viscous hydrocarbonaceous material containing formation penetrated by at least one injection well and one spaced apart production well, the injection well and the production well being in fluid communication with the formation. This method includes placing a burner downhole in the injection well which burner is capable of combusting fuel and an oxidizing gas suitable for heating the formation surrounding the injection well. The ratio oF air to Fuel is controlled so as to avoid developing a flame which becomes too hot and which could possibly damage the metal in a cased well or plug a hydrocarbonaceous formation or reservoir. Heat resultant from the flame is controlled by diverting a suitable or substantial portion of the oxidizing gas into the hot exhaust combustion gases.
The burner utilized for heating this hydrocarbonaceous formation contains a means for injecting fuel and an oxidizing gas into a cylindrical combustion chamber circumferentially located within an outer burner shield. Fuel entering the combustion chamber is ignited causing the hot gases resultant from the combustion to be emitted from the combustion chamber. A means for diverting an appropriate amount of the oxidizing gas away from the combustion chamber is provided. This diverting means causes the diverted oxidizing gas to cool the combustion chamber and be subsequently ~s~
mixed with the hot combustion gases. By so diverting desired proportions of the oxidizing gas and mixing the diverted gas with the hot combustion gases emitted from the combustion chamber, the burner is maintained at a desirable temperature which minimizes the damage to metals contained in a cased well and also avoids the formation of hydrocarbonaceous materials which could plug the formation or reservoir.
Accordingly, this invention provides an apparatus for heating a hydrocarbonaceous formation or reservoir penetrated by at least one injection well to recover hydrocarbonaceous materials therefrom comprising:
(a) a combustion chamber having an open lower end;
(b) an outer shield surrounding the combustion chamber;
(c) means for introducing in separate streams a fuel and an oxidizing gas into the combustion chamber;
(d) means for diverting a portion of the oxidizing fluid into the annular space between the combustion chamber and the outer shield to cool the combustion chamber; and (e) means for exhausting the combustion and cooling gases out of the combustion chamber and outer shield without substantial back flow of the gases into the combustion chamber and outer shield.
This invention also provides a method for recovering viscous hydrocarbonaceous material from a subterranean viscous hydrocarbonaceoUs material containing formation or reservoir penetrated by at least one injection well and one spaced apart production well, the injection well and the production well being in fluid communication with tne formation comprising:
(a) lowering a burner downhole in the injection well, the burner being capable of combusting a substantially unstable combustible mixture of desired ratios of fuel and an oxidizing gas, and of heating the formation or reservoir to a desired level;
(b) igniting and combusting the mixture in the combustion chamber of the burner;
B
F-315~ --5--(c) diverting a portion of the oxidizing gas from the combustion chamber to cool the combustion chamber and the hot combustion gases emitted therefrom; and (d) heating the hydrocarbonaceous reservoir or formation with the hot combustion gases for a time sufficient to cause hydrocarbonaceous materials to be removed therefrom.
In t~e drawings a~pended to this speciflcation:
Figure 1 illustrates a longitudinal cross section of the burner in a casing; and Figure 2 is an enlarged view of the burner as shown in Figure 1.
A burner which can be used in the practice of this invention is depicted in Figure 1. This figure shows that burner 10 is lowered into well casing 18. Perforations 16 are also shown in the casing. This casing is often comprised of metal to prevent the well from subsiding. The burner 10 is placed into and held within the injection well casing 1~ by a winch (not shown). The burner is lowered to the desired level within the casing from which it is desired to remove the hydrocarbonaceous materials. ~hen viewed from a cross sectional perspective, the burner is composed of outer tube 14 connected to outer shield 10. A packer 22 is used to position the burner and attached tubes in the desired location. Disposed within outer tube 14 is fuel tube 30. These two tubes proceed downwardly and terminate in the inner burner 12. Inner burner 12 is made of a high temperature cement. Inner burner 12 is affixed to the outer circumference of outer tube 14 by a circumferential plate 8. Outer tube 14 contains ports or openings 24 through which a part of an oxidizing gas such as oxygen or air flows. A portion of the oxidizing gas passes through ports 24 and around the exterior of inner burner 12. After passing around the inner burner 12 the oxidizing gas enters cooling area 34 below inner burner 12.
The other portion of the oxidizing gas flows down outer tube 14 and enters combustion chamber 26 of inner burner 12.
~ql`Z2~
F-3152 - --6~-An igniter (not shown) is placed near the burner and serves to ignite the oxidizing gas/fuel mixture from tubes 14 and 30. An igniter which can be used for this purpose is described in U.S.
Patent No. 3,880,235 issued to Berry et al. Upon ignition, the fuel/oxidizing gas mixture becomes combustible and generates a temperature of about 1093C (2000F). This temperature is much too high for contact with casing 18 and other tubular materials therein.
In order to cool the combustion gases emitted from combustion chamber 26, oxidizing gas from outer tube 14 which has flowed through openings 24 above circumferential plate 8 flows around inner burner 12 and mixes with the combustion gases from combustion chamber 26. This gas is substantially cooler than the combustion gases exiting from combustion chamber 26 which results in cooling the combustion gases to a temperature of from 427C (800F) to 538C (1000F). A thermocouple 20 is used to measure the temperature on the outer surface of burner 10.
After being cooled to the desired temperature, the cooled gases exit the cooling area 34 via exit jet 28 onto the well casing 18 near perforations 16. To permit cooling of the burner, ports 24 are sized so that sufficient oxidizing gas Flows therethrough into the annular space between inner burner 12 and enter shield 10. The temperature in the well and casing area is maintained at about 427C
(800F) to about 538C (1,000F) for a time su-FFicient to combust the hydrocarbonaceous ma-terial therein. As shown in the drawings, cooling area 34 is open downwardly so that there is no back flow of the combustion and cooling gases into combustion chamber 26. Upon combustion of the hydrocarbonaceous material9 the fire flood front progresses through the formation to generate sufficient combustion gases and hydrocarbonaceous materials which can thereafter be removed.
Fuels which may be used in -the practice of this invention include methane, ethane, propane, butane and mixtures thereof.
Carbon monoxide, hydrogen and hydrogen sulFide may also be used for the desired fuel :~2~ 225 Oxidizing gases or fluids which can be used for combustion purposes include air and oxygen.
In order to obtain the desired heating and cooling effect, the ratio of air to fuel can be varied from about 1 to about 50 to about 1 to about ~5 parts of air per part of fuel during combustion. Preferably, it is desired to maintain the fuel/air mixture at about 1 part of fuel to about 57 parts of air during combustion. Utilizing these fuel to air ratios results in a stable combustion of fuel where the separate streams of injected fluids or gases are not stable. An unstable mixture as defined herein means a mixture of fuel and air or oxygen which will not continually support combustion. As a result, substantially low fuel mixtures can be utilized and combusted wherein generally, said mixtures would not be combustible. As is understood by those skilled in the art, the fuels which are desired to be used can be used either with oxygen alone or with mixtures of oxygen and other gases or with air.
This invention relates to the in-situ combustion of a subterranean, viscous oil-containing formation for the recovery of oil. More particularly, the present invention is directed to an apparatus and process for controlling the combustion temperature of a hydrocarbonaceous formation or reservoir.
A variety of supplemental recovery techniques have been employed in order to increase the recovery of viscous oil from subterranean viscous oil-containing formations. These techniques include thermal recovery methods, water flooding and miscible flooding.
Of the aforementioned recovery methods, in-situ combustion appears to be the most promising for econornically recovering large amounts of viscous hydrocarbonaceous deposits with currently available technology. The attractiveness of the in-situ combustion method arises because it requires relatively little energy necessary for sustaining combustion of the hydrocarbon deposits. In contradistinction, other in-situ techniques, such as elec-trical resistance heating and steam injection require considerable amounts of energy, e.g., to heat the steam on the surface before it is injected into the viscous oil-containing formation.
Conventional in-situ combustion involves drilling at least two substantially vertical wells into the formation, the wells being separated by a horizontal distance within the formation. One of the wells is designated an injection well, and the other a production well. The recovery of oil is accomplished by raising the temperature of the in-place oil adjacent the injection well to combustion temperatures by some simple rrleans, e.g., with some type of a conventional downhole heater/burner apparatus, or by steam injec-tion and then supporting combustion by injecting an oxygen-containing gas such as air, oxygen enriched air, oxygen mixed F-3152 --2~~
with an inert gas, or substantially pure oxygen. Thereafter, the injection of the oxygen-containing gas is continued so as to maintain the high temperature combustion front which is formed, and to drive the front through the formation toward the production well. As the combustion front moves through the formation, it displaces ahead of it the in-place oil reduced in viscosity as well as other formation fluids such as water and also combustion gas produced during the combustion process and these fluids are recovered from the formation by the production well.
When using a conventional downhole heater/burner apparatus, in cased wells, it is often necessary to avoid temperatures hot enough to damage the metal contained in the formation and also the burner. It is also desirable to have a method for controlled heating of a cased or uncased well to avoid respectively either damaging the metal casing or plugging the Formation by hydrocarbonaceous materials.
U.S. Patent No. 3~952~801 issued to Burton on April 27~
1976 discusses a technique for igniting the oil shale rubble pile in an in-situ oil shale retort. Here a gas/air burner is lowered through a hole to a plenum over the oil shale to be ignited. An excess of air is passed through the hole and around the burner so that it is kept cool as a flame from it impinges on the rubble pile. The air also transfers heat downwardly into the rubble pile and provides oxygen for combustion of hydrocarbonaceous material in the shale. Preferably the burner is in a cylindrical housing having a flame exit that is lowered in so that a hot flame is ejected downwardly.
Here some of the air from the air supply was forced into the upper portion of the burner for cooling the interior while a hole or holes near the bottom of the burner discharge provided additional cooling air. Additional cooling air was forced into the region surrounding the burner. This air mixed with the air forced down the borehole. This internal cooling of the burner with air that was mixed with the air surrounding the burner significantly s reduced the internal temperature of the burner. As is apparent, the purpose of this method was to cool the burner and provide oxygen for combustion of hydrocarbonaceous material in the shale. The hotter the flame, the better. Indeed, a hot flame was deemed necessary.
Controlling the temperature of the flame was not necessary or required in Burton's technique.
Therefore, what is needed is a method and apparatus for controlling the temperature of the hot gases emitted from the burner in a more direct and simple manner to avoid damaging the metal in cased wells and to avoid plugging hydrocarbonaceous formations or reservoirs.
This invention is directed to a method and apparatus for recovering viscous hydrocarbonaceous material from a sùbterranean viscous hydrocarbonaceous material containing formation penetrated by at least one injection well and one spaced apart production well, the injection well and the production well being in fluid communication with the formation. This method includes placing a burner downhole in the injection well which burner is capable of combusting fuel and an oxidizing gas suitable for heating the formation surrounding the injection well. The ratio oF air to Fuel is controlled so as to avoid developing a flame which becomes too hot and which could possibly damage the metal in a cased well or plug a hydrocarbonaceous formation or reservoir. Heat resultant from the flame is controlled by diverting a suitable or substantial portion of the oxidizing gas into the hot exhaust combustion gases.
The burner utilized for heating this hydrocarbonaceous formation contains a means for injecting fuel and an oxidizing gas into a cylindrical combustion chamber circumferentially located within an outer burner shield. Fuel entering the combustion chamber is ignited causing the hot gases resultant from the combustion to be emitted from the combustion chamber. A means for diverting an appropriate amount of the oxidizing gas away from the combustion chamber is provided. This diverting means causes the diverted oxidizing gas to cool the combustion chamber and be subsequently ~s~
mixed with the hot combustion gases. By so diverting desired proportions of the oxidizing gas and mixing the diverted gas with the hot combustion gases emitted from the combustion chamber, the burner is maintained at a desirable temperature which minimizes the damage to metals contained in a cased well and also avoids the formation of hydrocarbonaceous materials which could plug the formation or reservoir.
Accordingly, this invention provides an apparatus for heating a hydrocarbonaceous formation or reservoir penetrated by at least one injection well to recover hydrocarbonaceous materials therefrom comprising:
(a) a combustion chamber having an open lower end;
(b) an outer shield surrounding the combustion chamber;
(c) means for introducing in separate streams a fuel and an oxidizing gas into the combustion chamber;
(d) means for diverting a portion of the oxidizing fluid into the annular space between the combustion chamber and the outer shield to cool the combustion chamber; and (e) means for exhausting the combustion and cooling gases out of the combustion chamber and outer shield without substantial back flow of the gases into the combustion chamber and outer shield.
This invention also provides a method for recovering viscous hydrocarbonaceous material from a subterranean viscous hydrocarbonaceoUs material containing formation or reservoir penetrated by at least one injection well and one spaced apart production well, the injection well and the production well being in fluid communication with tne formation comprising:
(a) lowering a burner downhole in the injection well, the burner being capable of combusting a substantially unstable combustible mixture of desired ratios of fuel and an oxidizing gas, and of heating the formation or reservoir to a desired level;
(b) igniting and combusting the mixture in the combustion chamber of the burner;
B
F-315~ --5--(c) diverting a portion of the oxidizing gas from the combustion chamber to cool the combustion chamber and the hot combustion gases emitted therefrom; and (d) heating the hydrocarbonaceous reservoir or formation with the hot combustion gases for a time sufficient to cause hydrocarbonaceous materials to be removed therefrom.
In t~e drawings a~pended to this speciflcation:
Figure 1 illustrates a longitudinal cross section of the burner in a casing; and Figure 2 is an enlarged view of the burner as shown in Figure 1.
A burner which can be used in the practice of this invention is depicted in Figure 1. This figure shows that burner 10 is lowered into well casing 18. Perforations 16 are also shown in the casing. This casing is often comprised of metal to prevent the well from subsiding. The burner 10 is placed into and held within the injection well casing 1~ by a winch (not shown). The burner is lowered to the desired level within the casing from which it is desired to remove the hydrocarbonaceous materials. ~hen viewed from a cross sectional perspective, the burner is composed of outer tube 14 connected to outer shield 10. A packer 22 is used to position the burner and attached tubes in the desired location. Disposed within outer tube 14 is fuel tube 30. These two tubes proceed downwardly and terminate in the inner burner 12. Inner burner 12 is made of a high temperature cement. Inner burner 12 is affixed to the outer circumference of outer tube 14 by a circumferential plate 8. Outer tube 14 contains ports or openings 24 through which a part of an oxidizing gas such as oxygen or air flows. A portion of the oxidizing gas passes through ports 24 and around the exterior of inner burner 12. After passing around the inner burner 12 the oxidizing gas enters cooling area 34 below inner burner 12.
The other portion of the oxidizing gas flows down outer tube 14 and enters combustion chamber 26 of inner burner 12.
~ql`Z2~
F-3152 - --6~-An igniter (not shown) is placed near the burner and serves to ignite the oxidizing gas/fuel mixture from tubes 14 and 30. An igniter which can be used for this purpose is described in U.S.
Patent No. 3,880,235 issued to Berry et al. Upon ignition, the fuel/oxidizing gas mixture becomes combustible and generates a temperature of about 1093C (2000F). This temperature is much too high for contact with casing 18 and other tubular materials therein.
In order to cool the combustion gases emitted from combustion chamber 26, oxidizing gas from outer tube 14 which has flowed through openings 24 above circumferential plate 8 flows around inner burner 12 and mixes with the combustion gases from combustion chamber 26. This gas is substantially cooler than the combustion gases exiting from combustion chamber 26 which results in cooling the combustion gases to a temperature of from 427C (800F) to 538C (1000F). A thermocouple 20 is used to measure the temperature on the outer surface of burner 10.
After being cooled to the desired temperature, the cooled gases exit the cooling area 34 via exit jet 28 onto the well casing 18 near perforations 16. To permit cooling of the burner, ports 24 are sized so that sufficient oxidizing gas Flows therethrough into the annular space between inner burner 12 and enter shield 10. The temperature in the well and casing area is maintained at about 427C
(800F) to about 538C (1,000F) for a time su-FFicient to combust the hydrocarbonaceous ma-terial therein. As shown in the drawings, cooling area 34 is open downwardly so that there is no back flow of the combustion and cooling gases into combustion chamber 26. Upon combustion of the hydrocarbonaceous material9 the fire flood front progresses through the formation to generate sufficient combustion gases and hydrocarbonaceous materials which can thereafter be removed.
Fuels which may be used in -the practice of this invention include methane, ethane, propane, butane and mixtures thereof.
Carbon monoxide, hydrogen and hydrogen sulFide may also be used for the desired fuel :~2~ 225 Oxidizing gases or fluids which can be used for combustion purposes include air and oxygen.
In order to obtain the desired heating and cooling effect, the ratio of air to fuel can be varied from about 1 to about 50 to about 1 to about ~5 parts of air per part of fuel during combustion. Preferably, it is desired to maintain the fuel/air mixture at about 1 part of fuel to about 57 parts of air during combustion. Utilizing these fuel to air ratios results in a stable combustion of fuel where the separate streams of injected fluids or gases are not stable. An unstable mixture as defined herein means a mixture of fuel and air or oxygen which will not continually support combustion. As a result, substantially low fuel mixtures can be utilized and combusted wherein generally, said mixtures would not be combustible. As is understood by those skilled in the art, the fuels which are desired to be used can be used either with oxygen alone or with mixtures of oxygen and other gases or with air.
Claims (7)
1. An apparatus for heating a hydrocarbonaceous formation or reservoir penetrated by at least one injection well to recover hydrocarbonaceous materials therefrom comprising:
(a) a combustion chamber having an open lower end;
(b) an outer shield surrounding the combustion chamber;
(c) means for introducing in separate streams a fuel and an oxidizing gas into the combustion chamber;
(d) means for diverting a portion of the oxidizing gas into the annular space between the combustion chamber and the outer shield to cool the combustion chamber; and (e) means for exhausting the combustion and cooling gases out of the combustion chamber and outer shield without substantial back flow of the gases into the combustion chamber and outer shield.
(a) a combustion chamber having an open lower end;
(b) an outer shield surrounding the combustion chamber;
(c) means for introducing in separate streams a fuel and an oxidizing gas into the combustion chamber;
(d) means for diverting a portion of the oxidizing gas into the annular space between the combustion chamber and the outer shield to cool the combustion chamber; and (e) means for exhausting the combustion and cooling gases out of the combustion chamber and outer shield without substantial back flow of the gases into the combustion chamber and outer shield.
2. The apparatus as recited in Claim 1 wherein diversion means (d) comprises a circumferential deflector having holes therein, the holes being sized to divert appropriate amounts of the oxidizing gas away from the combustion chamber to serve as a cooling means for the combustion chamber and hot exhausted gases.
3. A method for recovering viscous hydrocarbonaceous material from a subterranean viscous hydrocarbonaceous material containing formation or reservoir penetrated by at least one injection well and one spaced apart production well, the injection well and the production well being in fluid communication with the formation comprising:
(a) lowering a burner downhole in the injection well, the burner being capable of combusting a substantially unstable combustible mixture of desired ratios of fuel and an oxidizing gas, and of heating the formation or reservoir to a desired level;
(b) igniting and combusting the mixture in the combustion chamber of the burner;
(c) diverting a portion of the oxidizing gas from the combustion chamber to cool the combustion chamber and the hot combustion gases emitted therefrom; and (d) heating the hydrocarbonaceous reservoir or formation with the hot combustion gases for a time sufficient to cause hydrocarbonaceous materials to be removed therefrom.
(a) lowering a burner downhole in the injection well, the burner being capable of combusting a substantially unstable combustible mixture of desired ratios of fuel and an oxidizing gas, and of heating the formation or reservoir to a desired level;
(b) igniting and combusting the mixture in the combustion chamber of the burner;
(c) diverting a portion of the oxidizing gas from the combustion chamber to cool the combustion chamber and the hot combustion gases emitted therefrom; and (d) heating the hydrocarbonaceous reservoir or formation with the hot combustion gases for a time sufficient to cause hydrocarbonaceous materials to be removed therefrom.
4. The method as recited in Claim 3 wherein in step (a) the fuel is selected from methane, ethane, propane, butane, carbon monoxide, hydrogen, hydrogen sulfide, and mixtures thereof.
5. The method as recited in Claim 3 wherein in step (a) the mixture of fuel and oxidizing gas is in ratio from 1 to 50 to 1 to 65.
6. The method as recited in Claim 5 wherein in step (a) the mixture of fuel and oxidizing gas is in a ratio of about 1 to 57.
7. The method as recited in Claim 3 where the hot combustion gases are cooled to a temperature of from 427°C to 538°C.
Applications Claiming Priority (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US68004084A | 1984-12-10 | 1984-12-10 | |
| US680,040 | 1984-12-10 |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CA1250225A true CA1250225A (en) | 1989-02-21 |
Family
ID=24729411
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA000497164A Expired CA1250225A (en) | 1984-12-10 | 1985-12-09 | Burner for igniting an injection well |
Country Status (3)
| Country | Link |
|---|---|
| AT (1) | AT388414B (en) |
| CA (1) | CA1250225A (en) |
| DE (1) | DE3543259A1 (en) |
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US5488990A (en) * | 1994-09-16 | 1996-02-06 | Marathon Oil Company | Apparatus and method for generating inert gas and heating injected gas |
Families Citing this family (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CA2736894C (en) * | 2008-10-15 | 2016-06-07 | Tctm Limited | A method for performing thermochemical treatment of an oil reservoir |
| CN107575199A (en) * | 2015-03-07 | 2018-01-12 | 刘玉友 | A kind of implementation of underground continuous oil pipe implement |
| CN109237513B (en) * | 2018-08-29 | 2024-01-26 | 西安石油大学 | Multistage solid fuel igniter for deep well |
Family Cites Families (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| SU322084A1 (en) * | 1970-03-23 | 1973-10-26 | DEVICE FOR EXTRACTION OF GEOTHERMAL ENERGY | |
| US4079784A (en) * | 1976-03-22 | 1978-03-21 | Texaco Inc. | Method for in situ combustion for enhanced thermal recovery of hydrocarbons from a well and ignition system therefor |
| US4205725A (en) * | 1976-03-22 | 1980-06-03 | Texaco Inc. | Method for forming an automatic burner for in situ combustion for enhanced thermal recovery of hydrocarbons from a well |
| BR7801180A (en) * | 1977-09-28 | 1979-05-15 | Texaco Development Corp | PROCESS TO START HEAT IN ONE OF TWO POCO, PROCESS TO ASSEMBLE A POCO BURNER AND POCO BURNER |
| FR2504187A1 (en) * | 1981-04-16 | 1982-10-22 | Inst Francais Du Petrole | DEVICE FOR RAISING THE TEMPERATURE OF A GEOLOGICAL FORMATION CROSSED BY A WELL |
-
1985
- 1985-12-06 DE DE19853543259 patent/DE3543259A1/en not_active Withdrawn
- 1985-12-09 CA CA000497164A patent/CA1250225A/en not_active Expired
- 1985-12-10 AT AT357985A patent/AT388414B/en not_active IP Right Cessation
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US5488990A (en) * | 1994-09-16 | 1996-02-06 | Marathon Oil Company | Apparatus and method for generating inert gas and heating injected gas |
Also Published As
| Publication number | Publication date |
|---|---|
| AT388414B (en) | 1989-06-26 |
| DE3543259A1 (en) | 1986-06-12 |
| ATA357985A (en) | 1988-11-15 |
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Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| MKEX | Expiry |