This disclosure relates to wellbore operations, for example, producing hydrocarbons through wellbores.
Hydrocarbons entrapped in subsurface reservoirs are raised to the surface, i.e., produced, through wellbores formed from the surface to the subsurface reservoirs through a subterranean zone (e.g., a formation, a portion of a formation, multiple formations). The hydrocarbons (e.g., petroleum, natural gas, water, combinations of them) are multiphase fluids including a liquid phase and a gaseous phase. In a first stage of hydrocarbon recovery, the multiphase fluid flows through the wellbore under reservoir pressure. Over time, reservoir pressure decreases. Then, secondary (and sometimes tertiary) stages of hydrocarbon recovery are implemented in which the multiphase fluids are produced using artificial lift techniques. In one such technique, a pump is disposed at a downhole location. The pump draws the multiphase hydrocarbons that is downhole of the pump and flows the hydrocarbons towards the surface. The presence of gaseous phase in the flowing hydrocarbons can result in inefficiency in pump operations.
This disclosure describes technologies relating to downhole gas ventilation systems for artificial lift applications.
Certain aspects of the subject matter described here can be implemented as a downhole gas ventilation system. The system includes a perforated tubing configured to be positioned within a production tubing installed in a wellbore formed in a subterranean zone to a subsurface reservoir in which multiphase hydrocarbons including a liquid phase and a gaseous phase are entrapped. The perforated tubing can fluidically couple to wellbore equipment configured to be positioned uphole of the perforated tubing within the wellbore and to permit flow of the multiphase hydrocarbons received within the perforated tubing into the wellbore equipment. The perforated tubing includes an upper end, a lower end and a sidewall connecting the upper end and the lower end. The perforated tubing includes multiple perforations formed in the sidewall and configured to receive the multiphase hydrocarbons within the perforated tubing. An outer diameter of the perforated tubing is smaller than an inner diameter of the production tubing. The perforated tubing can facilitate separation of the liquid phase from the gaseous phase of the received multiphase hydrocarbons. The system includes a one-way check valve fluidically coupled to the upper end of the perforated tubing. The check valve is configured to vent the gaseous phase that rises towards the upper end of the perforated tubing out of the perforated tubing, out of the production tubing and into an annulus defined between the production tubing and an inner wall of the wellbore.
An aspect combinable with any other aspect includes the following features. The wellbore equipment includes a mandrel configured to receive the multiphase hydrocarbons from which a portion of the gaseous phase has been separated through the upper end of the perforated tubing.
An aspect combinable with any other aspect includes the following features. The system includes a seating nipple that can connect to the perforated tubing. The seating nipple, on one end, can attach to the upper end of the perforated tubing, and on the opposite end, can attach to the mandrel. The seating nipple can flow the liquid phase that is separated from gaseous phase within the perforated tubing into the mandrel.
An aspect combinable with any other aspect includes the following features. The upper end of the perforated tubing is directly connected to the mandrel.
An aspect combinable with any other aspect includes the following features. The mandrel is a gas lift mandrel that includes a gas lift valve fluidically coupled to the production tubing. The one-way check valve is installed within the gas lift mandrel.
An aspect combinable with any other aspect includes the following features. At least a portion of the perforated tubing including the upper end passes through the gas lift mandrel.
An aspect combinable with any other aspect includes the following features. An outer diameter of the gas lift mandrel is greater than an outer diameter of the production tubing and smaller than an inner diameter of the wellbore.
An aspect combinable with any other aspect includes the following features. The one-way check valve is installed in a portion of the gas lift mandrel that extends into the annulus.
An aspect combinable with any other aspect includes the following features. The perforated tubing is substantially concentric with respect to the production tubing.
An aspect combinable with any other aspect includes the following features. The perforated tubing is installed adjacent an inner surface of the production tubing.
An aspect combinable with any other aspect includes the following features. The perforated tubing is an elongate, cylindrical tubing.
An aspect combinable with any other aspect includes the following features. The perforated tubing is an elongate, helical tubing.
An aspect combinable with any other aspect includes the following features. The perforated tubing includes alternating portions of larger and smaller volumes arranged along an axis of the perforated tubing.
An aspect combinable with any other aspect includes the following features. The perforated tubing is a gas anchor or a dip tube.
Certain aspects of the subject matter described here can be implemented as a method performed in a wellbore formed in a subterranean zone to a subsurface reservoir in which multiphase hydrocarbons including a liquid phase and a gaseous phase are entrapped. The multiphase hydrocarbons flow from the subsurface reservoir through the wellbore. A separator is positioned at a downhole location in the wellbore. A portion of the gaseous phase is separated from the liquid phase before flowing into the separator through the intake resulting in multiphase hydrocarbons with reduced gaseous phase. A production tubing is fluidically coupled to the separator. The production tubing extends to the surface and can flow the multiphase hydrocarbons with reduced gaseous phase received via the intake to the surface. A gas ventilation system including a one-way check valve is fluidically coupled to the production tubing. The gas ventilation system can receive the multiphase hydrocarbons with reduced gaseous phase, further separate gaseous phase in the multiphase hydrocarbons with the reduced gaseous phase, and flow gaseous phase in the multiphase hydrocarbons with reduced gaseous phase received through the intake into an annulus defined between the production tubing and an inner wall of the wellbore.
An aspect combinable with any other aspect includes the following features. The wellbore includes a substantially vertical portion and a deviated portion extending from a downhole end of the substantially vertical portion through the subterranean zone. The wellbore includes a bend connecting the substantially vertical portion to the deviated portion. When positioning the separator at the downhole location, the separator is positioned in the bend.
Certain aspects of the subject matter described here can be implemented as a method performed in a wellbore formed in a subterranean zone to a subsurface reservoir in which multiphase hydrocarbons including a liquid phase and a gaseous phase are entrapped. The multiphase hydrocarbons flow from the subsurface reservoir through the wellbore. The multiphase hydrocarbons are flowed into a gas separator positioned at a downhole location in the wellbore. The gas separator separates a portion of the gaseous phase from the liquid phase in multiphase hydrocarbons with reduced gaseous phase. The multiphase hydrocarbons with the reduced gaseous phase are flowed through a production tubing fluidically coupled to the gas separator and extending to the surface. The production tubing defines an annulus with an inner wall of the wellbore. In a perforated tubing installed downstream of the gas separator and fluidically coupled to the production tubing, the portion of the multiphase hydrocarbons with the reduced gaseous phase are received. The perforated tubing further separates gaseous phase from the portion of the multiphase hydrocarbons with the reduced gaseous phase. The one-way check valve flows the gaseous phase separated by the perforated tubing.
An aspect combinable with any other aspect includes the following features. The wellbore includes a substantially vertical portion and a deviated portion extending from a downhole end of the substantially vertical portion through the subterranean zone. The wellbore includes a bend connecting the substantially vertical portion to the deviated portion. When positioning the separator at the downhole location, the separator is positioned in the bend.
The details of one or more implementations of the subject matter described in this specification are set forth in the accompanying drawings and the description below. Other features, aspects, and advantages of the subject matter will become apparent from the description, the drawings, and the claims.
Like reference numbers and designations in the various drawings indicate like elements.
This disclosure describes a downhole gas ventilation system (DGVS) that includes a mandrel (or piping or tubing) coupled with a dip tube, gas anchor or smaller tubing with openings for liquids to enter and a one-way check valve. When the DGVS is positioned in the flow path of a multiphase hydrocarbon stream, the DGVS creates fluid isolation between upstream and downstream fluid, which enables separation between the liquid and gaseous phases. As described below, the gaseous phase is removed via the check valve allowing higher liquid phase to flow towards the surface or towards an inlet of a downhole pump installed in a wellbore to flow the hydrocarbons through the wellbore towards the surface.
In some implementations, the DGVS 100 includes a perforated tubing 110 that is positioned within the production tubing 102. For example, the perforated tubing 110 can be a dip tube or a gas anchor. An outer diameter of the perforated tubing 110 is smaller than that of the production tubing 102 so that the perforated tubing 110 can fit entirely within the production tubing 102. The perforated tubing 110 has an upper end 112, a lower end 114 and a sidewall 116 connecting the upper end 112 and the lower end 114. Multiple perforations (e.g., the perforation 118) are formed on the sidewall 116 of the perforated tubing 110. Each perforation is a hole, a slit, a radial slot, a radial port (or any combination of them or similar perforations) that extends through the sidewall 116. Each perforation is large enough to permit the multiphase hydrocarbons to enter into an inner volume of the perforated tubing 110 through the multiple perforations.
An outer diameter of the upper end 112 is at least equal to an inner diameter of the production tubing 102. Consequently, when the perforated tubing 110 is installed within the production tubing 102, the upper end 112 seals against the inner diameter of the production tubing 102. Any fluid that flows into an annular space between the production tubing 102 and the perforated tubing 110 cannot flow around or flow past the upper end 112, and is forced to enter the inner volume of the perforated tubing 110 through the multiple perforations. The uphole end 112 is fluidically coupled to wellbore equipment uphole of (i.e., downstream of) the upper end 112 such that fluid that flows into the inner volume of the perforated tubing 110 flows downstream into the wellbore equipment.
A one-way check valve 120 is fluidically coupled to the upper end 112 of the perforated tubing 110. Alternatives or additions to the one-way check valve 120 include a relief valve, a back pressure valve, or any orifice or opening that permits gas to pass from within the perforated tubing 110 to outside the perforated tubing 110. In some implementations, the check valve 112 is attached directly to the upper end 112 or to the sidewall 116 near the upper end 112 of the perforated tubing 110.
In some implementations, the perforated tubing 110 and the check valve 112 are each mounted to wellbore equipment 122, which is then connected to the production tubing 102. For example, as shown in the schematic in
In some implementations, the DGVS 100 includes a seating nipple 124 to which the perforated tubing 110 can be connected, for example, by direct welding, using threads or otherwise. Alternatively, the seating nipple 124 can be screwed on top of the mandrel 122, e.g., the gas lift mandrel with the check valve 120. The seating nipple 124 can be any wellbore coupling equipment (e.g., a piece of tubing) that can facilitate a coupling between the perforated tubing 110 and equipment uphole of the perforated tubing 110, for example, additional tubing that extends to the surface or connects to an intake of a pump (not shown). On one end, the seating nipple 124 attaches to the upper end 112 of the perforated tubing 110. On the opposite end, the seating nipple 124 can attach to the wellbore equipment 122, for example, the mandrel. The seating nipple 124 resides uphole of the perforated tubing 110.
In an example operation, the DGVS 100 is mounted to the production tubing 102, which is installed within the wellbore 104. A downhole end of the production tubing 102 extends to the subsurface reservoir in which the multiphase hydrocarbons are entrapped. The liquid phase (schematically shown in
The positioning of the perforated tubing 110 in the flow pathway of the multiphase hydrocarbons causes an isolation between upstream and downstream fluid. The isolation improves separation of the liquid phase from the gaseous phase, for example, due to gravimetric separation. The separated gaseous phase (schematically shown in
Due to the separation of the gaseous phase from the liquid phase, the hydrocarbons that flow through the production tubing 102 (or other flow tubing) downstream of the perforated tubing 110 has a higher liquid fraction compared to the hydrocarbons upstream of the perforated tubing 110. In implementations in which a pump is installed downstream of the perforated tubing 110, the hydrocarbons with the higher liquid fraction will enter a pump intake and be pumped to the surface. By reducing a quantity of gaseous phase that enters the pump intake, pump efficiency can be improved.
In such implementations, baffle plates are installed within the production tubing 102 adjacent the perforated tubing 310. For example, a horizontal plate 322 is installed uphole of the lower end 314 of the perforated tubing 314. An end of the horizontal plate 322 extends to the inner wall of the production tubing 102. The other end of the horizontal plate 322 extends away from the inner wall of the production tubing 102 past the lower end 314 of the perforated tubing 314. A vertical plate 324 is attached to the horizontal plate 324, specifically to the other end of the horizontal plate 322, with the other end of the vertical plate 324 being a free end. The baffle plates are sized such that the multiple perforations (or at least a portion of the perforations) are downhole of the free end of the vertical plate 324. Such an arrangement creates a flow path for the multiphase fluids in a downhole direction as shown by the arrow 324. The multiphase hydrocarbons flow past the baffle plates and into the multiple perforations 318 in the sidewall 316 of the perforated tubing 310. The check valve 320 is downhole of (i.e., upstream of) the upper end 312. The upper end 312 seals against the inner diameter of the production tubing 102, thereby forcing the multiphase hydrocarbons to enter the inner volume of the perforated tubing 310 through the multiple perforations 318 formed on the sidewall 316. In some implementations, the DGVS 300 can be implemented with the seated nipple 124 (
The multiphase hydrocarbons, which includes liquid phase (schematically shown in solid black in
In some implementations, a downhole end of the production tubing 706, which is positioned at a downhole location (e.g., in the vertical portion 702, in the horizontal portion 704 or in the bend 708) can serve as an intake into which the multiphase hydrocarbons flows to enter the production tubing 706. That is, the production tubing 706 can receive the multiphase hydrocarbons directly and without any intermediate well component.
In some implementations, a gas separator 712 can be fluidically coupled to the downhole end of the production tubing 706. The gas separator 712 includes an intake 714 to receive the multiphase hydrocarbons. The gas separator 712 can facilitate separation of the liquid phase and the gaseous phase, for example, by gravimetric separation. For example, the flow direction of the multiphase hydrocarbons can be reversed (e.g., from uphole direction to downhole direction) within the gas separator 712 causing the gaseous phase to rise in the uphole direction and the liquid phase to fall in the downhole direction, resulting in a separation of the two phases.
The gas separator 712 can be installed at a downhole location within the wellbore 702. For example, the gas separator 712 can be installed in the vertical portion 702. In some implementations, the gas separator 712 can be installed in the bend 708. As the multiphase hydrocarbons flow into the bend 708, at least a portion of the liquid and gaseous phases are gravimetrically separated resulting in multiphase hydrocarbons with reduced gaseous phase (i.e., higher liquid fraction) to enter the intake 714 of the gas separator 712. Gaseous phase continues to rise towards the surface through an annulus 716 defined by the production tubing 706 and the wellbore 700.
The DGVS 100 (or any of the other DGVS' described in this disclosure with any of the perforated tubings described in this disclosure) can be installed in the vertical portion 702 downstream of (i.e., uphole of) the gas separator 712. In implementations without a gas separator 712, the DGVS 100 can be installed downstream of the intake into the production tubing 706. In any implementation, multiphase hydrocarbons flow towards the DGVS 100, which separates at least a portion of the gaseous phase from the liquid phase, and releases the separated gaseous phase into the annulus 716 through the check valve included in the DGVS 100.
The phase separation within the DGVS 100 and release of the gaseous phase through the check valve is aided by several flow conditions. For example, a specific gravity of the multiphase hydrocarbons in the production tubing 706 is different from the specific gravity of the fluids (e.g., the gaseous phase) in the annulus 716. The difference in specific gravities creates a pressure differential within the DGVS 100. In another example, in implementations that include the gas separator 712, the removal of a portion of the gaseous phase from the multiphase hydrocarbons by the gas separator 712 creates a pressure differential within the DGVS 100. In a further example, in implementations in which the DGVS 100 has a greater diameter than the production tubing 706 such that the DGVS 100 extends radially into the annulus 716, the distance between the outer surface of the DGVS 100 and the inner wall of the wellbore 700 is less than the distance between the outer surface of the production tubing 706 and the inner wall of the wellbore 700. The reduced distance creates a venturi effect as the free gas that rises through the annulus 716 flows past the DGVS 100. Each of the pressure differentials or the venturi effect or any combination of them aid in the gas separation within the DGVS 100 and release of the separated gas by the check valve into the annulus 716.
At 904, a production tubing is fluidically coupled to the separator. For example, the operator can couple the production tubing to the separator and lower both into the wellbore. The production tubing is configured to flow the multiphase hydrocarbons to the surface. In some implementations, the gas separator need not be used, and the production tubing alone can be lowered into the wellbore. In such implementations, a downhole end of the production tubing serves as the intake for the multiphase hydrocarbons.
At 906, a gas ventilation system (e.g., a DGVS) is fluidically coupled to the production tubing. For example, the DGVS can be coupled to the production tubing at the surface of the wellbore, and the production tubing and the DGVS can be lowered into the wellbore. As described earlier, the DGVS receives the multiphase hydrocarbons, separates the gaseous phase from the multiphase and flows the gaseous phase into an annulus defined between the production tubing and an inner wall of the wellbore. The fluid that is flowed into the annulus after the separation can include liquid phase, but the liquid fraction in such multiphase fluid is smaller than the liquid fraction upstream of the DGVS. At 908, hydrocarbons are produced through the production tubing and the DGVS.
At 1004, the gas separator separates a portion of the gaseous phase from the liquid phase. In implementations in which the gas separator is positioned in the bend connecting the vertical portion and the horizontal portion, the gas separator separates a portion of the gaseous phase from the liquid phase that already has a reduced gaseous phase.
At 1006, a production tubing fluidically coupled to the gas separator and extending to the surface flows the multiphase hydrocarbons with the reduced gaseous phase. The production tubing defines an annulus with an inner wall of the wellbore.
At 1008, a perforated tubing of the DGVS, which is installed downstream of the gas separator and is fluidically coupled to the production tubing, receives the portion of the multiphase hydrocarbons with the reduced gaseous phase. At 1010, the perforated tubing further separates gaseous phase from the multiphase hydrocarbons received by the perforated tubing. At 1012, the check valve in the DGVS flows the separated gaseous phase into the annulus. The liquid phase flows through the production tubing towards the surface, e.g., towards a pump installed downstream of the DGVS. The multiphase fluid that flows through the perforated tubing of the DGVS into the annulus has a higher gaseous fraction compared to the multiphase fluid upstream of the DGVS. Conversely, the liquid phase that flows through the production tubing downstream of the DGVS has a higher liquid fraction compared to the multiphase fluid upstream of the DGVS.
Thus, particular implementations of the subject matter have been described. Other implementations are within the scope of the following claims.