CA2980368C - Cyclical steam injection process and equipment with water seal for thermal protection casing and pneumatic artificial lift for produced oil - Google Patents
Cyclical steam injection process and equipment with water seal for thermal protection casing and pneumatic artificial lift for produced oil Download PDFInfo
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- CA2980368C CA2980368C CA2980368A CA2980368A CA2980368C CA 2980368 C CA2980368 C CA 2980368C CA 2980368 A CA2980368 A CA 2980368A CA 2980368 A CA2980368 A CA 2980368A CA 2980368 C CA2980368 C CA 2980368C
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- 238000000034 method Methods 0.000 title claims abstract description 54
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 title claims abstract description 44
- 238000010793 Steam injection (oil industry) Methods 0.000 title claims description 26
- 230000014759 maintenance of location Effects 0.000 claims abstract description 31
- 239000011435 rock Substances 0.000 claims abstract description 19
- 238000002347 injection Methods 0.000 claims abstract description 17
- 239000007924 injection Substances 0.000 claims abstract description 17
- 238000000605 extraction Methods 0.000 claims abstract description 11
- 238000004519 manufacturing process Methods 0.000 claims description 18
- 230000006837 decompression Effects 0.000 claims description 3
- 238000002791 soaking Methods 0.000 claims description 3
- 230000000977 initiatory effect Effects 0.000 claims 2
- 230000003213 activating effect Effects 0.000 claims 1
- 238000004401 flow injection analysis Methods 0.000 claims 1
- 238000009434 installation Methods 0.000 abstract 1
- 239000003129 oil well Substances 0.000 description 5
- 239000011248 coating agent Substances 0.000 description 3
- 238000000576 coating method Methods 0.000 description 3
- 239000012530 fluid Substances 0.000 description 3
- 241000191291 Abies alba Species 0.000 description 2
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 description 2
- 238000006243 chemical reaction Methods 0.000 description 2
- 238000005553 drilling Methods 0.000 description 2
- 238000011084 recovery Methods 0.000 description 2
- 230000015572 biosynthetic process Effects 0.000 description 1
- 238000004140 cleaning Methods 0.000 description 1
- 125000004122 cyclic group Chemical group 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 230000002708 enhancing effect Effects 0.000 description 1
- 238000011156 evaluation Methods 0.000 description 1
- 238000005457 optimization Methods 0.000 description 1
- 230000002093 peripheral effect Effects 0.000 description 1
- 238000005086 pumping Methods 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 239000000377 silicon dioxide Substances 0.000 description 1
- 239000000243 solution Substances 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
-
- 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
- E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
- E21B43/121—Lifting well fluids
- E21B43/122—Gas lift
- E21B43/123—Gas lift valves
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- 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)
- Earth Drilling (AREA)
Abstract
This patent describes a thermal oil extraction process that allows steam in a reservoir or group of reservoirs to convey oil. This invention also allows the oil extraction with compressed gas in order to obtain oil using an alternate method that does not require a rig intervention to replace the injection equipment for the extraction equipment and vice versa. In order to promote the produced oil lifting, this process uses energy stored in the compressed gas. The process of the current patent is controlled by a set of valves on the surface controlled by solenoids valves, which are commanded by a programmable logic controller (PLC), being that the process begins with the aperture of the Valves (1), (10), (11), and (12) and the Automatic Valve (13), being that the Valve (1) is destined to control the water flow from the Annulus (2) formed by the Casing (3) and the External Column (4); and still by the comeback water to be done by the Annulus (14) formed by the Intermediate Column (15) and Internal Column (16), which passes through the Retention Valves (18) and (19), accessing the Interior of the Internal Column (7) until it reaches the surface. A constructive variation to be applied in wells where the casing is unable to withstand steam and water injection high pressures, in a way of preserving the well's Casing (3) from the pressures that will occur during the injection process, where the installation of the Packer (32) above the Perforation (6) of the Reservoir Rock (5), being the temperature control made by water circulation, being the Valves (1) and (9) are opened and the water is injected in the Annulus (2) and returns by the Annulus (20), passing through the Valve (9), being directed to its final destination.
Description
CYCLICAL STEAM INJECTION PROCESS AND EQUIPMENT WITH WATER
SEAL FOR THERMAL PROTECTION CASING AND PNEUMATIC ARTIFICIAL
LIFT FOR PRODUCED OIL
FIELD OF THE INVENTION
The current patent describes a thermal oil extraction process that allows steam in a reservoir or group of reservoirs to extract oil. This invention also allows the oil extraction with compressed gas to obtain oil using an alternate method that does not require a rig intervention to replace the injection equipment for the extraction equipment. To promote the produced oil lifting, this process uses energy stored in the compressed gas.
BACKGROUND OF THE INVENTION
Usually, wells which will participate of steam injection projects are special wells submitted to pre tensioning effort, silica cementing, production casing cementing (all extension), and profiles' careful cementing evaluation to detect issues such as bi fixation, amongst others. The possibility of an existing casing temperature control during steam injection allows wells which were not submitted to the criteria above to be employed as cyclical steam injectors.
Among the high viscosity oil recovery thermal methods, the steam injection, cyclical or continuous, is the most common. Many different optimization proposals for the process are expensive and the results are not always as good as expected, being the ones passing through horizontal well drilling to become continuous injection producers or even overlapped horizontal wells drilling to act both as, alternatively, producers and injectors. This patent process offers a higher performance when compared to conventional cyclical processes, enhancing its results.
Steam usage in oil wells is known and described by the technique's state in countless documents, mainly in horizontal wells and, according to some researches made within preeminent world-wide database, one of the most relevant documents is the U53543850, which describes high viscosity oil Date Recue/Date Received 2020-05-01 recovery, where the steam is destined to reduce its viscosity level, allowing its extraction.
Otherwise, steam and compressed gas utilization either combined or used alternated is also known and described in some documents, being the most important ones the BR PI 1105806-4, the US7993110, and the RU2164289;
which utilize elements as such for high viscosity oil extraction, differently from the object of this current patent, which seeks to overcome the performance of those described technologies.
SUMMARY OF THE INVENTION
With the purpose of improving the technical possibilities beyond the ordinary, this invention offers the capacity of using the well as steam injector and oil producer alternately, with no further necessities of rig intervention in order to make this conversion. This process presents many advantages, such as:
= Alternately inject steam and produce oil, without rig intervention to make the conversion;
= As the rig utilization is not required to convert the producing oil well in injector, reservoir engineers can, with no further expenses, choose short, medium or long cycles, depending which well presents the best performance;
= Also allows steam to be circulated at low rates with the purpose of retaining heat in the rock reservoir in the vicinity of the well during the production;
= The process also allows the well production to be interrupted from time to time to clean the well by circulating steam at high flow rates;
= Both the cycle process (injection/production) and the pneumatic pumping cycle can be manually or automatically controlled.
= The process allows, during steam injection, the casing temperature to be controlled by a water flow. Casing temperature control increases the number of wells that can be used with this process for cyclic steam injection.
SEAL FOR THERMAL PROTECTION CASING AND PNEUMATIC ARTIFICIAL
LIFT FOR PRODUCED OIL
FIELD OF THE INVENTION
The current patent describes a thermal oil extraction process that allows steam in a reservoir or group of reservoirs to extract oil. This invention also allows the oil extraction with compressed gas to obtain oil using an alternate method that does not require a rig intervention to replace the injection equipment for the extraction equipment. To promote the produced oil lifting, this process uses energy stored in the compressed gas.
BACKGROUND OF THE INVENTION
Usually, wells which will participate of steam injection projects are special wells submitted to pre tensioning effort, silica cementing, production casing cementing (all extension), and profiles' careful cementing evaluation to detect issues such as bi fixation, amongst others. The possibility of an existing casing temperature control during steam injection allows wells which were not submitted to the criteria above to be employed as cyclical steam injectors.
Among the high viscosity oil recovery thermal methods, the steam injection, cyclical or continuous, is the most common. Many different optimization proposals for the process are expensive and the results are not always as good as expected, being the ones passing through horizontal well drilling to become continuous injection producers or even overlapped horizontal wells drilling to act both as, alternatively, producers and injectors. This patent process offers a higher performance when compared to conventional cyclical processes, enhancing its results.
Steam usage in oil wells is known and described by the technique's state in countless documents, mainly in horizontal wells and, according to some researches made within preeminent world-wide database, one of the most relevant documents is the U53543850, which describes high viscosity oil Date Recue/Date Received 2020-05-01 recovery, where the steam is destined to reduce its viscosity level, allowing its extraction.
Otherwise, steam and compressed gas utilization either combined or used alternated is also known and described in some documents, being the most important ones the BR PI 1105806-4, the US7993110, and the RU2164289;
which utilize elements as such for high viscosity oil extraction, differently from the object of this current patent, which seeks to overcome the performance of those described technologies.
SUMMARY OF THE INVENTION
With the purpose of improving the technical possibilities beyond the ordinary, this invention offers the capacity of using the well as steam injector and oil producer alternately, with no further necessities of rig intervention in order to make this conversion. This process presents many advantages, such as:
= Alternately inject steam and produce oil, without rig intervention to make the conversion;
= As the rig utilization is not required to convert the producing oil well in injector, reservoir engineers can, with no further expenses, choose short, medium or long cycles, depending which well presents the best performance;
= Also allows steam to be circulated at low rates with the purpose of retaining heat in the rock reservoir in the vicinity of the well during the production;
= The process also allows the well production to be interrupted from time to time to clean the well by circulating steam at high flow rates;
= Both the cycle process (injection/production) and the pneumatic pumping cycle can be manually or automatically controlled.
= The process allows, during steam injection, the casing temperature to be controlled by a water flow. Casing temperature control increases the number of wells that can be used with this process for cyclic steam injection.
2 Date Recue/Date Received 2020-05-01 BRIEF DESCRIPTION OF THE DRAWINGS
Figure 1 represents the direct water and steam injection process, without the presence of a packer. The water injected by the annular coating and external column is mixed with injected steam, filling the interior of the coating, passing through the check valves and accessing the interior of the internal column and internal annular column / intermediate column until it reaches the surface. When the flow arrives at the surface, as the valves that allow the circulation are closed, directing the flow of water and steam to the perforation / oil reservoir rock.
Figure 2 represents the process with a packer to be applied in wells where the coating cannot be subjected to the steam and water injection pressures that occur in the process. The packer is installed above the perforation in order to preserve the lining of the well from the pressures that will develop during the injection process where the steam is injected directly through the internal column or through the annular of the internal column and intermediate column. In this scheme, water is injected through the annular lining and external column and circulates to cool without exerting pressure on the lining. The steam injection pressure is contained in the oil reservoir rock below the packer.
A schematic represented picture Figure 1 presents a technical solution to attend this process' proposals.
This process, as shown in Figure 1, allows steam injection followed by the oil production, keeping steam circulation at low rates, simultaneously or in cycles, to maintain the heat during the lifting on the formation's peripheral oil well zone.
This process, as shown in Figure 1, also allows the steam to circulate at high rates, which promotes cleaning with debris removal that can accumulate in the well, mostly at slope (directional) or horizontal wells.
The current patent can be better understood through the detailed process description along with Figure 1 that represents the preferred configuration for vertical, slope (directional), and horizontal wells.
Figure 1 represents the direct water and steam injection process, without the presence of a packer. The water injected by the annular coating and external column is mixed with injected steam, filling the interior of the coating, passing through the check valves and accessing the interior of the internal column and internal annular column / intermediate column until it reaches the surface. When the flow arrives at the surface, as the valves that allow the circulation are closed, directing the flow of water and steam to the perforation / oil reservoir rock.
Figure 2 represents the process with a packer to be applied in wells where the coating cannot be subjected to the steam and water injection pressures that occur in the process. The packer is installed above the perforation in order to preserve the lining of the well from the pressures that will develop during the injection process where the steam is injected directly through the internal column or through the annular of the internal column and intermediate column. In this scheme, water is injected through the annular lining and external column and circulates to cool without exerting pressure on the lining. The steam injection pressure is contained in the oil reservoir rock below the packer.
A schematic represented picture Figure 1 presents a technical solution to attend this process' proposals.
This process, as shown in Figure 1, allows steam injection followed by the oil production, keeping steam circulation at low rates, simultaneously or in cycles, to maintain the heat during the lifting on the formation's peripheral oil well zone.
This process, as shown in Figure 1, also allows the steam to circulate at high rates, which promotes cleaning with debris removal that can accumulate in the well, mostly at slope (directional) or horizontal wells.
The current patent can be better understood through the detailed process description along with Figure 1 that represents the preferred configuration for vertical, slope (directional), and horizontal wells.
3 Date Recue/Date Received 2020-05-01 DETAILED DESCRIPTION OF THE INVENTION
The process of the current patent is controlled by a set of valves on the surface controlled by solenoids, which are commanded by a programmable logic controller (PLC). The process goes:
.. The process, as represented at Figure 1, begins with the opening of a first Valve (1), a second Valve (10), a third Valve (11), and a fourth Valve (12) and a first Automatic Valve (13). The opening of the first Valve (1) allows water access to a first Annulus (2), formed by a Casing (3) and an Outer Tubing (4). Initially, the water will fill an Interior of the Casing (25) and it will return through a second Annulus (14) formed by an Intermediate Tubing (15) and an Inner Tubing (16). The water will pass through a first Retention Valve (18) and a second Retention Valve (19), passing through an Interior of the Inner Tubing (17) until it reaches the surface.
When the water circulation is stabilized, the steam circulation process begins with the opening of a fifth Valve (7), a sixth Valve (8), and a seventh Valve (9). The opening of these valves allows the steam to reach a third Annulus (20), formed by the Outer Tubing (4) and the Intermediate Tubing (15). Initially, steam and water, together, will fill the Interior of the Casing (25) and they will return through the second Annulus (14) formed by the Intermediate Tubing (15) and the Inner Tubing (16), passing through the first Retention Valve (18) and the second Retention Valve (19), accessing the Interior of the Inner Tubing (17), until they reach the surface.
When the steam returns to the surface with water, the third Valve (11) and the fourth Valve (12), and the first Automatic Valve (13) are closed, forcing the flow of Steam and Water, through a Perforation (6) to be injected in a Reservoir Rock (5).
With steam and water flows stabilized at the expected values, the fluid injection will occur until the end of the forecasted goal.
Ending the steam injection cycle, and being the Soaking period fulfilled, the oil production process will be initiated. For this to occur, the first Valve (1), the fifth Valve (7), the sixth Valve (8), and the seventh Valve (9) should be closed, and the third Valve (11), the fourth Valve (12), and an eighth Valve (22) should be closed.
The process of the current patent is controlled by a set of valves on the surface controlled by solenoids, which are commanded by a programmable logic controller (PLC). The process goes:
.. The process, as represented at Figure 1, begins with the opening of a first Valve (1), a second Valve (10), a third Valve (11), and a fourth Valve (12) and a first Automatic Valve (13). The opening of the first Valve (1) allows water access to a first Annulus (2), formed by a Casing (3) and an Outer Tubing (4). Initially, the water will fill an Interior of the Casing (25) and it will return through a second Annulus (14) formed by an Intermediate Tubing (15) and an Inner Tubing (16). The water will pass through a first Retention Valve (18) and a second Retention Valve (19), passing through an Interior of the Inner Tubing (17) until it reaches the surface.
When the water circulation is stabilized, the steam circulation process begins with the opening of a fifth Valve (7), a sixth Valve (8), and a seventh Valve (9). The opening of these valves allows the steam to reach a third Annulus (20), formed by the Outer Tubing (4) and the Intermediate Tubing (15). Initially, steam and water, together, will fill the Interior of the Casing (25) and they will return through the second Annulus (14) formed by the Intermediate Tubing (15) and the Inner Tubing (16), passing through the first Retention Valve (18) and the second Retention Valve (19), accessing the Interior of the Inner Tubing (17), until they reach the surface.
When the steam returns to the surface with water, the third Valve (11) and the fourth Valve (12), and the first Automatic Valve (13) are closed, forcing the flow of Steam and Water, through a Perforation (6) to be injected in a Reservoir Rock (5).
With steam and water flows stabilized at the expected values, the fluid injection will occur until the end of the forecasted goal.
Ending the steam injection cycle, and being the Soaking period fulfilled, the oil production process will be initiated. For this to occur, the first Valve (1), the fifth Valve (7), the sixth Valve (8), and the seventh Valve (9) should be closed, and the third Valve (11), the fourth Valve (12), and an eighth Valve (22) should be closed.
4 Date Recue/Date Received 2020-05-01 The lifting process will begin with the opening of a second Automatic Valve (23), allowing access of the compressed gas through the second Annulus (14) and the Chamber (31) ¨ where the oil to be lifted will be stored. The gas flow will push the oil from the Chamber (31), forcing the closure of the first Retention Valve (18) and the opening of the second Retention Valve (19), directing the flow to the Interior of the Inner Tubing (17) up the surface.
Next, a third Automatic Valve (24) is opened, allowing the second Annulus (14) and the Chamber (31) to decompress. The first Automatic Valve (13) is initially used to this function, whilst the fluids are at high temperatures right after the steam injection.
With this decompression, the oil ¨ prevenient from the Reservoir Rock (5) ¨
gathered at the Interior of the Casing (25), refills the Chamber (31). The production process repeats until it is required to repeat the steam cycle.
A Set (26), composed by one Flange, one Cross Tee and Valves is the conventional Christmas Tree for preexistent steam in the well. The crosshatch set is a Special Adapter (27). Special Adapter (27) is the equipment that holds the Outer Tubing (4), the Intermediate Tubing (15), and the Inner Tubing (16), and has the function of adapter, hanger and also injector.
The Special Adapter (27) has internally three overlapped hangers, an Inferior Hanger (30) anchors the Outer Tubing (4), an Intermediate Hanger (29) anchors the Intermediate Tubing (15), and a Superior Hanger (28) anchors the Inner Tubing (16).
At this configuration, access is allowed to the second Annulus (14), through the eighth Valve (22) and the forth Valve (12), and to the third Annulus (20) through the seventh Valve (9) and a ninth Valve (21).
Amongst the different multiple casings composing an oil well, the Figure 1 and Figure 2 are only representing the Production Casing (3) for being the main casing in the described process.
If the configuration, depicted at Figure 1, is not applicable at wells where the casing cannot be submitted to the steam and water injection pressure that will occur at the described process, the use of the configuration depicted at Figure 2 is recommended.
Next, a third Automatic Valve (24) is opened, allowing the second Annulus (14) and the Chamber (31) to decompress. The first Automatic Valve (13) is initially used to this function, whilst the fluids are at high temperatures right after the steam injection.
With this decompression, the oil ¨ prevenient from the Reservoir Rock (5) ¨
gathered at the Interior of the Casing (25), refills the Chamber (31). The production process repeats until it is required to repeat the steam cycle.
A Set (26), composed by one Flange, one Cross Tee and Valves is the conventional Christmas Tree for preexistent steam in the well. The crosshatch set is a Special Adapter (27). Special Adapter (27) is the equipment that holds the Outer Tubing (4), the Intermediate Tubing (15), and the Inner Tubing (16), and has the function of adapter, hanger and also injector.
The Special Adapter (27) has internally three overlapped hangers, an Inferior Hanger (30) anchors the Outer Tubing (4), an Intermediate Hanger (29) anchors the Intermediate Tubing (15), and a Superior Hanger (28) anchors the Inner Tubing (16).
At this configuration, access is allowed to the second Annulus (14), through the eighth Valve (22) and the forth Valve (12), and to the third Annulus (20) through the seventh Valve (9) and a ninth Valve (21).
Amongst the different multiple casings composing an oil well, the Figure 1 and Figure 2 are only representing the Production Casing (3) for being the main casing in the described process.
If the configuration, depicted at Figure 1, is not applicable at wells where the casing cannot be submitted to the steam and water injection pressure that will occur at the described process, the use of the configuration depicted at Figure 2 is recommended.
5 Date Recue/Date Received 2020-05-01 At the depicted configuration Figure 2, a Packer (32) is installed above the Perforation (6) of the Reservoir Rock (5) in a way that the Casing (3) is preserved from pressures that will come during the injection process. In this case, the temperature control is made by water circulation, where the first Valve (1) and the seventh Valve (9) are opened and the water is injected in the first Annulus (2) and returned through the third Annulus (20), passing through the seventh Valve (9) and being directed to its final destination.
In order to begin the steam injection process, a Cap (33) is withdrawn, a tenth Valve (34) and the second Valve (10) are opened and the second Retention Valve (19) and the first Retention Valve (18) are retreated, using, for this, a Slickline Unit, which is very common in the oil industry. After that, the tenth Valve (34) is closed.
Then, the eighth Valve (22), a eleventh Valve (35), and a twelfth Valve (36) are opened and the steam is injected through the second Annulus (14), passing through where the first Retention Valve (18) lies, through the Interior of the Casing (25) and through the Perforation (6), into the Reservoir Rock (5).
In case of the necessity of an operational facility, the steam can be injected through a line connected to the tenth Valve (34), directly through the Interior of the Inner Tubing (17). In this case, the line containing the eleventh Valve (35) and the twelfth Valve (36) would cease to exist and the eighth Valve (22) would be closed. This step is concluded when the foreseen project's entire quota of steam is injected.
With the end of the steam injection cycle and after the Soaking period, the oil production process will be initiated. For this, the first Valve (1), the eleventh Valve (35), and the twelfth Valve (36) must be closed, the tenth Valve (34) must be opened, and the second Retention Valve (19) and the third Retention Valve (18) must be reinstalled using, for this, a Slickline Unit. After that, the tenth Valve (34) is closed.
In order to initiate the oil lift process, the third Valve (11) and the fourth Valve (12) are opened. The lifting process will begin with the opening of the second Automatic Valve (23) which will allow the compressed gas to access the second Annulus (14) and the Chamber (31) where the oil to be lifted will be stored.
The gas flow will push the oil from the Chamber (31), forcing the closure of the first
In order to begin the steam injection process, a Cap (33) is withdrawn, a tenth Valve (34) and the second Valve (10) are opened and the second Retention Valve (19) and the first Retention Valve (18) are retreated, using, for this, a Slickline Unit, which is very common in the oil industry. After that, the tenth Valve (34) is closed.
Then, the eighth Valve (22), a eleventh Valve (35), and a twelfth Valve (36) are opened and the steam is injected through the second Annulus (14), passing through where the first Retention Valve (18) lies, through the Interior of the Casing (25) and through the Perforation (6), into the Reservoir Rock (5).
In case of the necessity of an operational facility, the steam can be injected through a line connected to the tenth Valve (34), directly through the Interior of the Inner Tubing (17). In this case, the line containing the eleventh Valve (35) and the twelfth Valve (36) would cease to exist and the eighth Valve (22) would be closed. This step is concluded when the foreseen project's entire quota of steam is injected.
With the end of the steam injection cycle and after the Soaking period, the oil production process will be initiated. For this, the first Valve (1), the eleventh Valve (35), and the twelfth Valve (36) must be closed, the tenth Valve (34) must be opened, and the second Retention Valve (19) and the third Retention Valve (18) must be reinstalled using, for this, a Slickline Unit. After that, the tenth Valve (34) is closed.
In order to initiate the oil lift process, the third Valve (11) and the fourth Valve (12) are opened. The lifting process will begin with the opening of the second Automatic Valve (23) which will allow the compressed gas to access the second Annulus (14) and the Chamber (31) where the oil to be lifted will be stored.
The gas flow will push the oil from the Chamber (31), forcing the closure of the first
6 Date Recue/Date Received 2020-05-01 Retention Valve (18) and the opening of the second Retention Valve (19), directing the flow from the Interior of the Inner Tubing (17) up to the surface.
Following, the third Automatic Valve (24) is opened for the second Annulus (14) and the Chamber (31) to decompress. The first Automatic Valve (13) is initially used to this function, while the fluids are on high temperatures right after the steam injection. With this decompression, the oil ¨ prevenient from the Reservoir Rock (5) ¨ accumulated at the Interior of the Casing (25), refills the Chamber (31).
The lifting process repeats until a new steam cycle is required.
The Set (26) composed by Flange, one Cross Tee and Valves is the conventional Christmas tree for preexistent steam in the well. The crosshatch set is a Special Adapter (27). Special Adapter (27) is the equipment that holds the Outer Tubing (4), the Intermediate Tubing (15) and the Inner Tubing (16).
The Special Adapter (27) possesses three internally overlapped hangers, the Inferior Hanger (30) anchors the Outer Tubing (4), the Intermediate Hanger (29) anchors the Intermediate Tubing (15), and the Superior Hanger (28) anchors the Inner Tubing (16). At this configuration, the access to the second Annulus (14) is allowed through the eighth Valve (22) and the forth Valve (12), and to the third Annulus (20) through the seventh Valve (9) and the ninth Valve (21).
Amongst the different multiple casings composing an oil well, the Figure 1 and Figure 2 depict only the Production Casing (3) for being the main casing to the described process.
Following, the third Automatic Valve (24) is opened for the second Annulus (14) and the Chamber (31) to decompress. The first Automatic Valve (13) is initially used to this function, while the fluids are on high temperatures right after the steam injection. With this decompression, the oil ¨ prevenient from the Reservoir Rock (5) ¨ accumulated at the Interior of the Casing (25), refills the Chamber (31).
The lifting process repeats until a new steam cycle is required.
The Set (26) composed by Flange, one Cross Tee and Valves is the conventional Christmas tree for preexistent steam in the well. The crosshatch set is a Special Adapter (27). Special Adapter (27) is the equipment that holds the Outer Tubing (4), the Intermediate Tubing (15) and the Inner Tubing (16).
The Special Adapter (27) possesses three internally overlapped hangers, the Inferior Hanger (30) anchors the Outer Tubing (4), the Intermediate Hanger (29) anchors the Intermediate Tubing (15), and the Superior Hanger (28) anchors the Inner Tubing (16). At this configuration, the access to the second Annulus (14) is allowed through the eighth Valve (22) and the forth Valve (12), and to the third Annulus (20) through the seventh Valve (9) and the ninth Valve (21).
Amongst the different multiple casings composing an oil well, the Figure 1 and Figure 2 depict only the Production Casing (3) for being the main casing to the described process.
7 Date Recue/Date Received 2020-05-01
Claims (7)
1) A CYCLICAL STEAM INJECTION APPARATUS WITH WATER SEAL
FOR THERMAL PROTECTION CASING AND PNEUMATIC
ARTIFICIAL LIFT FOR PRODUCED OIL, for a thermal oil extraction process that allows, alternately and without the need for intervention of a rig to replace a set of steam injection equipment with a set of production equipment, injection of steam in a Reservoir Rock (5) and production from the Reservoir Rock (5), the apparatus comprising:
a Special Adapter (27) that holds an Outer Tubing (4), an Intermediate Tubing (15) and an Inner Tubing (16), the Special Adapter (27) comprising internally three overlapped hangers, the three overlapped hangers including an Inferior Hanger (30) which anchors the Outer Tubing (4), an Intermediate Hanger (29) which anchors the Intermediate Tubing (15) and a Superior Hanger (28) which anchors the Inner Tubing (16), wherein the Special Adapter (27) allows access to a second Annulus (14) through an eighth Valve (22) and a forth Valve (12), and to a third Annulus (20) through a seventh Valve (9) and a ninth Valve (21), and wherein the apparatus is configured for a steam and water injection process which begins with opening of a first Valve (1), a second Valve (10), a third Valve (11), and the forth Valve (12) and a first Automatic Valve (13), where the first Valve (1) controls, at a surface, a water flow to a first Annulus (2) formed by a Casing (3) and the Outer Tubing (4);
and the process also includes the return of the water flow to the surface through the second Annulus (14) formed by the Intermediate Tubing (15) and the Inner Tubing (16), the water flow on its return passing through a first Retention Valve (18) and a second Retention Valve (19) and passing through an Interior of the Inner Tubing (17) until it reaches the surface.
FOR THERMAL PROTECTION CASING AND PNEUMATIC
ARTIFICIAL LIFT FOR PRODUCED OIL, for a thermal oil extraction process that allows, alternately and without the need for intervention of a rig to replace a set of steam injection equipment with a set of production equipment, injection of steam in a Reservoir Rock (5) and production from the Reservoir Rock (5), the apparatus comprising:
a Special Adapter (27) that holds an Outer Tubing (4), an Intermediate Tubing (15) and an Inner Tubing (16), the Special Adapter (27) comprising internally three overlapped hangers, the three overlapped hangers including an Inferior Hanger (30) which anchors the Outer Tubing (4), an Intermediate Hanger (29) which anchors the Intermediate Tubing (15) and a Superior Hanger (28) which anchors the Inner Tubing (16), wherein the Special Adapter (27) allows access to a second Annulus (14) through an eighth Valve (22) and a forth Valve (12), and to a third Annulus (20) through a seventh Valve (9) and a ninth Valve (21), and wherein the apparatus is configured for a steam and water injection process which begins with opening of a first Valve (1), a second Valve (10), a third Valve (11), and the forth Valve (12) and a first Automatic Valve (13), where the first Valve (1) controls, at a surface, a water flow to a first Annulus (2) formed by a Casing (3) and the Outer Tubing (4);
and the process also includes the return of the water flow to the surface through the second Annulus (14) formed by the Intermediate Tubing (15) and the Inner Tubing (16), the water flow on its return passing through a first Retention Valve (18) and a second Retention Valve (19) and passing through an Interior of the Inner Tubing (17) until it reaches the surface.
2) A CYCLICAL STEAM INJECTION PROCESS WITH WATER SEAL
FOR THERMAL PROTECTION CASING AND PNEUMATIC
ARTIFICIAL LIFT FOR PRODUCED OIL, being a thermal oil extraction process that allows, alternately and without the need for intervention of a rig to replace a set of steam injection equipment with a set of production equipment, injection of steam in a Reservoir Rock (5) and production from the Reservoir Rock (5), the process comprising:
opening of a first Valve (1), a second Valve (10), a third Valve (11), and a forth Valve (12) and a first Automatic Valve (13), where the first Valve (1) controls a water flow to a first Annulus (2) formed by a Casing (3) and an Outer Tubing (4) at a surface;
returning the water flow to the surface through a second Annulus (14) formed by an Intermediate Tubing (15) and an Inner Tubing (16), the water flow on its return passing through a first Retention Valve (18) and a second Retention Valve (19) and passing through an Interior of the Inner Tubing (17) until it reaches the surface;
opening a fifth Valve (7), a sixth Valve (8) and a seventh Valve (9), where the fifth Valve (7), the sixth Valve (8) and the seventh Valve (9) control a steam flow to a third Annulus (20) formed by the Outer Tubing (4) and the Intermediate Tubing (15); and returning the steam flow to the surface through the second Annulus (14) formed by the Intermediate Tubing (15) and the Inner Tubing (16), the steam flow on its return passing through the first Retention Valve (18) and the second Retention Valve (19) and passing through the Interior of the Inner Tubing (17) until it reaches the surface.
FOR THERMAL PROTECTION CASING AND PNEUMATIC
ARTIFICIAL LIFT FOR PRODUCED OIL, being a thermal oil extraction process that allows, alternately and without the need for intervention of a rig to replace a set of steam injection equipment with a set of production equipment, injection of steam in a Reservoir Rock (5) and production from the Reservoir Rock (5), the process comprising:
opening of a first Valve (1), a second Valve (10), a third Valve (11), and a forth Valve (12) and a first Automatic Valve (13), where the first Valve (1) controls a water flow to a first Annulus (2) formed by a Casing (3) and an Outer Tubing (4) at a surface;
returning the water flow to the surface through a second Annulus (14) formed by an Intermediate Tubing (15) and an Inner Tubing (16), the water flow on its return passing through a first Retention Valve (18) and a second Retention Valve (19) and passing through an Interior of the Inner Tubing (17) until it reaches the surface;
opening a fifth Valve (7), a sixth Valve (8) and a seventh Valve (9), where the fifth Valve (7), the sixth Valve (8) and the seventh Valve (9) control a steam flow to a third Annulus (20) formed by the Outer Tubing (4) and the Intermediate Tubing (15); and returning the steam flow to the surface through the second Annulus (14) formed by the Intermediate Tubing (15) and the Inner Tubing (16), the steam flow on its return passing through the first Retention Valve (18) and the second Retention Valve (19) and passing through the Interior of the Inner Tubing (17) until it reaches the surface.
3) The CYCLICAL STEAM INJECTION PROCESS WITH WATER SEAL FOR
THERMAL PROTECTION CASING AND PNEUMATIC ARTIFICIAL LIFT
FOR PRODUCED OIL according to claim 2, further comprising closing the third Valve (11) and the forth Valve (12) and the first Automatic Valve (13) after the steam flow returns along with the water flow at the surface, pushing the steam flow and the water flow through a Perforation (6), to be injected into the Reservoir Rock (5).
THERMAL PROTECTION CASING AND PNEUMATIC ARTIFICIAL LIFT
FOR PRODUCED OIL according to claim 2, further comprising closing the third Valve (11) and the forth Valve (12) and the first Automatic Valve (13) after the steam flow returns along with the water flow at the surface, pushing the steam flow and the water flow through a Perforation (6), to be injected into the Reservoir Rock (5).
4) The CYCLICAL STEAM INJECTION PROCESS WITH WATER SEAL FOR
THERMAL PROTECTION CASING AND PNEUMATIC ARTIFICIAL LIFT
FOR PRODUCED OIL according to claim 3, further comprising, following closing the third Valve (11) and the forth Valve (12) and the first Automatic Valve (13), closing the first Valve (1), the fifth Valve (7), the sixth Valve (8) and the seventh Valve (9) and opening the third Valve (11), the forth Valve (12), and the eighth Valve (22) to begin an oil production process.
THERMAL PROTECTION CASING AND PNEUMATIC ARTIFICIAL LIFT
FOR PRODUCED OIL according to claim 3, further comprising, following closing the third Valve (11) and the forth Valve (12) and the first Automatic Valve (13), closing the first Valve (1), the fifth Valve (7), the sixth Valve (8) and the seventh Valve (9) and opening the third Valve (11), the forth Valve (12), and the eighth Valve (22) to begin an oil production process.
5) The CYCLICAL STEAM INJECTION PROCESS WITH WATER SEAL
FOR THERMAL PROTECTION CASING AND PNEUMATIC
ARTIFICIAL LIFT FOR PRODUCED OIL according to claim 4, further comprising, following closing the first Valve (1), the fifth Valve (7), the sixth Valve (8) and the seventh Valve (9) and opening the third Valve (11), the forth Valve (12), and the eighth Valve (22):
opening a second Automatic Valve (23) that allows a compressed gas flow access to the second Annulus (14) and a Chamber (31), wherein the compressed gas flow will carry a flow of oil from the Chamber (31) to the Interior of the Inner Tubing (17), forcing the closure of the first Retention Valve (18) and the opening of the second Retention Valve (19), thereafter directing the flow of oil from the Interior of the Inner Tubing (17) to the surface; and next, opening of a third Automatic Valve (24) allowing a decompression of the second Annulus (14) and the Chamber (31), allowing a quantity of oil from the Reservoir Rock (5), stored in an Interior of the Casing (25), to refill the Chamber (31).
FOR THERMAL PROTECTION CASING AND PNEUMATIC
ARTIFICIAL LIFT FOR PRODUCED OIL according to claim 4, further comprising, following closing the first Valve (1), the fifth Valve (7), the sixth Valve (8) and the seventh Valve (9) and opening the third Valve (11), the forth Valve (12), and the eighth Valve (22):
opening a second Automatic Valve (23) that allows a compressed gas flow access to the second Annulus (14) and a Chamber (31), wherein the compressed gas flow will carry a flow of oil from the Chamber (31) to the Interior of the Inner Tubing (17), forcing the closure of the first Retention Valve (18) and the opening of the second Retention Valve (19), thereafter directing the flow of oil from the Interior of the Inner Tubing (17) to the surface; and next, opening of a third Automatic Valve (24) allowing a decompression of the second Annulus (14) and the Chamber (31), allowing a quantity of oil from the Reservoir Rock (5), stored in an Interior of the Casing (25), to refill the Chamber (31).
6) A CYCLICAL STEAM INJECTION PROCESS WITH WATER SEAL
FOR THERMAL PROTECTION CASING AND PNEUMATIC
ARTIFICIAL LIFT FOR PRODUCED OIL, being a thermal oil extraction process that allows, alternately and without the need for intervention of a rig to replace a set of steam injection equipment with a set of production equipment, injection of steam in a Reservoir Rock (5) and production from the Reservoir Rock (5), the process to be applied in a well where a Casing (3) cannot be subjected to high pressure injections of a flow of steam and a flow of water in order to preserve the Casing (3) from the pressures that will occur during high pressure injections, the process comprising:
opening of a first Valve (1), where the first Valve (1) controls a water flow to a first Annulus (2) formed by the Casing (3) and an Outer Tubing (4) at a surface;
installing a Packer (32) above a Perforation (6) of the Reservoir Rock (5), a temperature being controlled by the water flow, where the first Valve (1) and a seventh Valve (9) are opened and the water flow is injected in the first Annulus (2) and returned by a third Annulus (20), passing through the seventh Valve (9) and being directed to its final destination through the seventh Valve (9).
FOR THERMAL PROTECTION CASING AND PNEUMATIC
ARTIFICIAL LIFT FOR PRODUCED OIL, being a thermal oil extraction process that allows, alternately and without the need for intervention of a rig to replace a set of steam injection equipment with a set of production equipment, injection of steam in a Reservoir Rock (5) and production from the Reservoir Rock (5), the process to be applied in a well where a Casing (3) cannot be subjected to high pressure injections of a flow of steam and a flow of water in order to preserve the Casing (3) from the pressures that will occur during high pressure injections, the process comprising:
opening of a first Valve (1), where the first Valve (1) controls a water flow to a first Annulus (2) formed by the Casing (3) and an Outer Tubing (4) at a surface;
installing a Packer (32) above a Perforation (6) of the Reservoir Rock (5), a temperature being controlled by the water flow, where the first Valve (1) and a seventh Valve (9) are opened and the water flow is injected in the first Annulus (2) and returned by a third Annulus (20), passing through the seventh Valve (9) and being directed to its final destination through the seventh Valve (9).
7) The CYCLICAL STEAM INJECTION PROCESS WITH WATER SEAL FOR
THERMAL PROTECTION CASING AND PNEUMATIC ARTIFICIAL LIFT
FOR PRODUCED OIL according to claim 6, further comprising:
beginning a process of steam injection by withdrawing a Cap (33), opening a tenth Valve (34) and a second Valve (10) and retreating a second Retention Valve (19) and a first Retention Valve (18), and closing the tenth Valve (34) right away after retreating the second Retention Valve (19) and the first Retention Valve (18);
after that, an eighth Valve (22), an eleventh Valve (35) and a twelfth Valve (36) are opened and the steam flow is injected through the second Annulus (14), passing through the first Retention Valve (18), though the Interior of the Casing (25) and through the Perforation (6) into the Reservoir Rock (5);
initiating an oil production process, after an end of the steam flow injection and after a Soaking period, by closing the first Valve (1), the eleventh Valve (35), and the twelfth Valve (36), opening the tenth Valve (34) and reinstalling the second Retention Valve (19) and the first Retention Valve (18), followed by closing the tenth Valve (34);
then, activating an oil lifting process by opening the third Valve (11) and the forth Valve (12), and initiating the oil lifting process by opening a second Automatic Valve (23), which will allow a compressed gas flow access to the second Annulus (14) and the Chamber (31) where a flow of oil to be lifted is stored;
pushing, using the compressed gas flow, the flow of oil out of the Chamber (31) forcing the first Retention Valve (18) closed and opening the second Retention Valve (19), directing the flow of oil to the Interior of the inner Tubing (17) and up to the surface; and next, opening a third Automatic Valve (24), allowing the second Annulus (14) and the Chamber (31) to decompress.
THERMAL PROTECTION CASING AND PNEUMATIC ARTIFICIAL LIFT
FOR PRODUCED OIL according to claim 6, further comprising:
beginning a process of steam injection by withdrawing a Cap (33), opening a tenth Valve (34) and a second Valve (10) and retreating a second Retention Valve (19) and a first Retention Valve (18), and closing the tenth Valve (34) right away after retreating the second Retention Valve (19) and the first Retention Valve (18);
after that, an eighth Valve (22), an eleventh Valve (35) and a twelfth Valve (36) are opened and the steam flow is injected through the second Annulus (14), passing through the first Retention Valve (18), though the Interior of the Casing (25) and through the Perforation (6) into the Reservoir Rock (5);
initiating an oil production process, after an end of the steam flow injection and after a Soaking period, by closing the first Valve (1), the eleventh Valve (35), and the twelfth Valve (36), opening the tenth Valve (34) and reinstalling the second Retention Valve (19) and the first Retention Valve (18), followed by closing the tenth Valve (34);
then, activating an oil lifting process by opening the third Valve (11) and the forth Valve (12), and initiating the oil lifting process by opening a second Automatic Valve (23), which will allow a compressed gas flow access to the second Annulus (14) and the Chamber (31) where a flow of oil to be lifted is stored;
pushing, using the compressed gas flow, the flow of oil out of the Chamber (31) forcing the first Retention Valve (18) closed and opening the second Retention Valve (19), directing the flow of oil to the Interior of the inner Tubing (17) and up to the surface; and next, opening a third Automatic Valve (24), allowing the second Annulus (14) and the Chamber (31) to decompress.
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| PCT/BR2016/050005 WO2017124159A1 (en) | 2016-01-22 | 2016-01-22 | Cyclical steam injection process and equipment with water seal for thermal protection casing and pneumatic artificial lift for produced oil |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CA2980368A1 CA2980368A1 (en) | 2017-07-27 |
| CA2980368C true CA2980368C (en) | 2021-01-12 |
Family
ID=59361173
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA2980368A Active CA2980368C (en) | 2016-01-22 | 2016-01-22 | Cyclical steam injection process and equipment with water seal for thermal protection casing and pneumatic artificial lift for produced oil |
Country Status (3)
| Country | Link |
|---|---|
| US (1) | US20180051544A1 (en) |
| CA (1) | CA2980368C (en) |
| WO (1) | WO2017124159A1 (en) |
Families Citing this family (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN107893650A (en) * | 2017-11-21 | 2018-04-10 | 中国石油天然气股份有限公司 | Oil production method and device for oil field vacation oolitic limestone oil reservoir |
| CN111502623A (en) * | 2020-05-08 | 2020-08-07 | 克拉玛依红山油田有限责任公司 | Tubular sand washing and steam injection device and process |
| CN112031712B (en) * | 2020-09-08 | 2023-01-17 | 长江大学 | Underground gas drive drainage and production pump and gas drive drainage and production method |
| CN112922846B (en) * | 2021-02-01 | 2022-07-05 | 北京化工大学 | Hydraulic submersible pump for lifting oil at bottom of well in thermal recovery of oil field |
| US11913296B1 (en) * | 2022-10-10 | 2024-02-27 | Saudi Arabian Oil Company | Auto recycle system to maintain fluid level on ESP operation |
Family Cites Families (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| BR0208894A (en) * | 2002-11-25 | 2004-09-28 | Engepet Empresa De Engenharia | Concentric Column Multiple Suspension System |
| BRPI0600287A (en) * | 2006-01-17 | 2008-03-04 | Engepet Empresa De Engenharia | multiple suspension system of concentric columns |
| BRPI1105806A2 (en) * | 2011-10-26 | 2015-12-29 | Engepet Empresa De Engenharia De Petróleo Ltda | oil lifting system in wells subjected to cyclic steam injection without the need for a rig to change equipment |
-
2016
- 2016-01-22 WO PCT/BR2016/050005 patent/WO2017124159A1/en active Application Filing
- 2016-01-22 CA CA2980368A patent/CA2980368C/en active Active
- 2016-01-22 US US15/557,852 patent/US20180051544A1/en not_active Abandoned
Also Published As
| Publication number | Publication date |
|---|---|
| CA2980368A1 (en) | 2017-07-27 |
| WO2017124159A1 (en) | 2017-07-27 |
| US20180051544A1 (en) | 2018-02-22 |
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