US20180223635A9 - Chemical injection with subsea production flow boost pump - Google Patents
Chemical injection with subsea production flow boost pump Download PDFInfo
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- US20180223635A9 US20180223635A9 US15/719,100 US201715719100A US2018223635A9 US 20180223635 A9 US20180223635 A9 US 20180223635A9 US 201715719100 A US201715719100 A US 201715719100A US 2018223635 A9 US2018223635 A9 US 2018223635A9
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- subsea tree
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- fluid conditioner
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- 239000000126 substance Substances 0.000 title claims abstract description 115
- 238000004519 manufacturing process Methods 0.000 title claims abstract description 38
- 238000002347 injection Methods 0.000 title claims abstract description 35
- 239000007924 injection Substances 0.000 title claims abstract description 35
- 239000012530 fluid Substances 0.000 claims abstract description 212
- 239000007788 liquid Substances 0.000 claims description 63
- 238000000034 method Methods 0.000 claims description 6
- 239000000203 mixture Substances 0.000 claims description 6
- 238000005086 pumping Methods 0.000 claims description 5
- 238000004891 communication Methods 0.000 claims description 4
- 230000000903 blocking effect Effects 0.000 claims 1
- 239000000314 lubricant Substances 0.000 description 3
- 238000012986 modification Methods 0.000 description 3
- 230000004048 modification Effects 0.000 description 3
- 241000237858 Gastropoda Species 0.000 description 2
- 230000002706 hydrostatic effect Effects 0.000 description 2
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 2
- 239000002253 acid Substances 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 229930195733 hydrocarbon Natural products 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 239000013535 sea water Substances 0.000 description 1
Images
Classifications
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/01—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/02—Surface sealing or packing
- E21B33/03—Well heads; Setting-up thereof
- E21B33/068—Well heads; Setting-up thereof having provision for introducing objects or fluids into, or removing objects from, wells
- E21B33/076—Well heads; Setting-up thereof having provision for introducing objects or fluids into, or removing objects from, wells specially adapted for underwater installations
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B34/00—Valve arrangements for boreholes or wells
- E21B34/02—Valve arrangements for boreholes or wells in well heads
- E21B34/025—Chokes or valves in wellheads and sub-sea wellheads for variably regulating fluid flow
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B34/00—Valve arrangements for boreholes or wells
- E21B34/02—Valve arrangements for boreholes or wells in well heads
- E21B34/04—Valve arrangements for boreholes or wells in well heads in underwater well heads
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/11—Perforators; Permeators
- E21B43/116—Gun or shaped-charge perforators
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
- E21B43/121—Lifting well fluids
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/34—Arrangements for separating materials produced by the well
- E21B43/36—Underwater separating arrangements
Definitions
- the present disclosure relates to boosting the flow of well fluids from a subsea well using a sea floor boost pump, and in particular to using the sea floor boost pump to also selectively inject chemicals into the well.
- Subsea boost pumps have been proposed to boost production from subsea wells.
- the subsea boost pump increases the drawdown on the well, boosting the pressure of the produced fluids to overcome pipeline and hydrostatic losses.
- One type of subsea boost pump proposed comprises an electrical submersible pump mounted in a canister or flow line jumper.
- a chemical injection pump injects the chemicals.
- the chemical injection pump is separate from the well fluid pump employed to pump well fluid from the well.
- the well fluid being produced contains both liquid and gas hydrocarbons.
- the performance of certain types of well pumps, particularly centrifugal pumps, is detrimentally affected by a high gas content in the well fluids.
- Various types of separators may be employed to separate the oil from the gas prior to reaching the intake of the well pump. After the discharge of the pump, the liquid enriched phase may be recirculated to the pump intake to reduce the relative gas content at the pump intake.
- a subsea well production system comprises a subsea boost pump having an intake operatively coupled to a subsea tree conduit of a subsea tree.
- a valve in the subsea tree conduit in the subsea tree conduit selectively opens and closes the subsea tree conduit.
- a boost pump outlet conduit operatively couples between a discharge of the boost pump and an outlet flow line.
- a recirculation line extends from the boost pump outlet conduit to the subsea tree conduit.
- a chemical injection source line extends from a chemical injection source and is connected to the subsea tree conduit at a point between the valve in the subsea tree conduit and the intake of the boost pump.
- a chemical source valve selectively opens and closes the chemical injection source line.
- the valve in the subsea tree conduit is open and the chemical source valve is closed, causing the boost pump to pump well fluid flowing from the subsea tree to the outlet flow line, and in many cases diverting a portion of the well fluid back through the recirculation line to the subsea tree conduit.
- the valve in the subsea tree conduit is closed and the chemical source valve is open, causing the boost pump to pump the chemical from the chemical source through the recirculation line into the subsea tree conduit and from the subsea tree conduit into the subsea tree.
- An intake fluid conditioner may be mounted in the subsea tree conduit.
- the intake fluid conditioner has means for separating heavier and lighter components in the well fluid flowing from the subsea tree and forming a storage reservoir of liquid while the system is in the production flow boosting mode.
- the recirculation line extends from the boost pump outlet fluid conditioner to the intake fluid conditioner. While the system is in the production flow boosting mode, the recirculation line delivers a liquid-rich portion of the well fluid discharged by the boost pump to the intake fluid conditioner to mix with the well fluid flowing from the subsea tree. While the system is in the chemical injection mode, the recirculation line delivers the chemical discharged by the boost pump to the intake fluid conditioner and from there to the subsea tree.
- An outlet fluid conditioner may be mounted in the boost pump outlet conduit.
- the outlet fluid conditioner has means for separating gas and liquid components of well fluid discharged from the boost pump and delivering the heavier components to the outlet recirculation line while the system is in the production flow boosting mode.
- the recirculation line extends from the outlet fluid conditioner to the subsea tree conduit or intake fluid conditioner. While the system is in the production flow boosting mode, the recirculation line delivers a liquid-rich portion of the well fluid within the outlet fluid conditioner to the subsea tree conduit or intake fluid conditioner to mixx with the well fluid flowing from the subsea tree. While the system is in the chemical injection mode, the recirculation line delivers the chemical in the outlet fluid conditioner to the subsea tree conduit and from there into the subsea tree.
- the intake fluid conditioner in the embodiment shown separates a higher liquid content portion of the well fluid flowing from the subsea tree from a lower liquid content portion to create a liquid level in the intake fluid conditioner.
- the recirculation line extends to the intake fluid conditioner at a point selected to be above the liquid level in the intake fluid conditioner.
- the intake fluid conditioner has an outlet in the subsea tree conduit that is selected to be below the liquid level in the intake fluid conditioner.
- the valve in the subsea tree conduit is between the outlet of the intake fluid conditioner and the intake of the boost pump.
- the outlet fluid conditioner separates a higher liquid content portion of the well fluid from a lower liquid content portion to create a liquid level in the outlet fluid conditioner.
- the recirculation line is connected to the outlet fluid conditioner at a point selected to be below the liquid level in the outlet fluid conditioner.
- the outlet flow line is adapted to be connected to the outlet fluid conditioner below the liquid level in the outlet fluid conditioner.
- the chemical source may comprise a chemical tank adapted to be located subsea adjacent the boost pump, or a conduit to a remotely located chemical tank, either subsea or on the surface.
- the boost pump may comprise a canister containing an electrical submersible pump.
- FIG. 1 is a schematic view of subsea boost pump system in a production mode with arrows indicating well fluid production flow.
- FIG. 2 is a schematic view of the subsea boost pump system of FIG. 1 in a chemical injection mode with arrows indicating chemical injection into the well.
- FIG. 1 shows a sea floor pressure boosting system operatively connected to subsea well production equipment such as a subsea tree 11 .
- Subsea tree 11 is a conventional pressure control tubular member that is mounted above a well 13 .
- Subsea tree 11 is located on or near a sea floor 15 .
- Subsea tree 11 typically has a number of valves, including a production flow or wing valve 17 .
- a subsea tree flow line 19 extends from wing valve 17 to convey well fluid flowing from well 13 .
- subsea tree flow line 19 connects to an intake fluid conditioner 21 , which is a vessel configured to create a level of liquid therein.
- Intake conditioner 21 has internal components to separate lighter or gaseous components from the heavier or liquid components, such as oil and water.
- intake conditioner 21 has an internal, vertically oriented perforated tube 23 extending upward from its outlet, which is on a lower end.
- Well fluid flows into the upper end of intake conditioner 21 and swirls as it moves downward. The swirling tends to cause the heavier components to move into an annulus outside of perforated tube 23 and the lighter components to remain within perforated tube 23 .
- the holes in perforated tube 23 meter the liquid outside of perforated tube 23 into perforated tube 23 at a selected flow rate.
- the heavier components within perforated tube 23 flow out of intake fluid conditioner 21 into a pump intake line 25 that extends from a lower end of intake conditioner 21 .
- Heavier component well fluid accumulates in the annulus outside of perforated tube 23 to a liquid level that varies depending on the quantity of gas within the well fluid. If gas slugs flow from well 13 , the liquid level may drop, but the perforations in perforated tube 23 continue to supply some liquid to pump intake line 25 .
- the lighter components are not vented to the exterior of intake fluid conditioner 21 , rather will mix with the heavier components in perforated tube 23 and flow to pump intake line 25 .
- Pump intake line 25 , intake conditioner 21 , and subsea tree flow line 19 may be considered to comprise a subsea tree conduit leading from subsea tree 11 .
- Pump intake line 25 leads to a sea floor boost pump assembly that may be a variety of types, such as a centrifugal pump, a multi-phase pump or a twin-screw pump, for example.
- the pump assembly includes a flow line jumper, conduit or canister 27 .
- Pump intake line 25 has a pump intake valve 29 , which may be considered to be a subsea tree conduit valve that selectively opens and closes the outlet of intake fluid conditioner 21 .
- Pump canister 27 is a conduit or canister, normally oriented horizontal, that has an electrical submersible pump (ESP) 31 mounted inside.
- ESP 31 includes a centrifugal pump 33 that has a large number of stages, each stage comprising an impeller and a diffuser.
- Pump 33 has an intake 35 for receiving fluid flowing within pump canister 27 .
- a pressure equalizer or seal section 37 secures to intake 35 of pump 33 .
- a motor 39 connects to seal section 37 .
- Motor 39 is normally a three-phase electrical motor filled with a dielectric lubricant to lubricant internal bearings.
- Seal section 37 has a movable element, such as a bladder or bellows, that equalizes a pressure of the lubricant in motor 39 with well fluid on the exterior of motor 39 in pump canister 27 .
- the well fluid flowing from pump intake line 25 flows around motor 39 into pump intake 35 .
- Outlet flow line 43 extends to an outlet fluid conditioner 45 , which is a vessel similar to intake conditioner 21 .
- Outlet conditioner 45 has features to separate lighter gaseous components from the heavier liquid components, such as oil and water.
- outlet conditioner 45 has an internal, vertically oriented perforated tube 49 extending upward from its outlet, which is on a lower end. Well fluid from pump 33 flows into the upper end of outlet conditioner 45 and swirls as it moves downward.
- the swirling tends to cause the heavier components to move into the annulus on the outside of perforated tube 49 and the lighter components to remain within perforated tube 49 .
- the holes in perforated tube 49 restrict but allow a selected flow rate of the liquid outside of perforated tube 49 to flow into perforated tube 49 .
- the heavier components mix with lighter components within perforated tube 49 and flow out an outlet flow line 51 extending from a lower end of outlet conditioner 45 .
- Lighter components are not vented from outlet fluid conditioner 45 , rather mix and flow with the heavier components out outlet flow line 51 .
- Outlet flow line 51 may lead to a production platform on the surface or other equipment on sea floor 15 , such as a manifold 53 .
- An outlet valve 55 in outlet flow line 51 selectively opens and closes outlet flow line 51 .
- the holes in perforated tube 49 create a liquid level in the annulus surrounding perforated tube 49 . The level of the liquid varies depending on the quantity of gas in the well fluid and the well flow rates.
- a diverter or recirculation line 57 extends from outlet conditioner 45 at a point below the liquid level to deliver some of the heavier components of well fluid back to intake conditioner 21 .
- Recirculation line 57 is in fluid communication with subsea tree conduit 19 and enters intake conditioner 21 near or at its upper end, preferably above the liquid level in intake conditioner 21 .
- Recirculation line 57 optionally could be connected directly into subsea tree conduit 19 between wing valve 17 and intake fluid conditioner 21 .
- the recirculated well fluid mixes with the well fluid flowing into intake conditioner 21 from subsea tree flow line 19 .
- a choke 59 is incorporated into recirculation line 57 to meter the flow rate of fluid flowing from outlet conditioner 45 . Choke 59 may be adjustable in a variety of manners.
- a chemical source selectively supplies chemicals to pump 33 for injection into well 13 while pump 33 is not pumping well fluid.
- the chemical source comprises at least one chemical tank 63 that is lowered from a surface production platform to a location near the subsea well fluid boosting system.
- Chemical tank 63 contains a treating chemical for treating the well fluid within well 13 to improve the flow rate.
- the treating chemical may be a variety of chemicals depending on the well, such as relatively high pH acid chemicals.
- Chemical tank 63 preferably has an accumulator or pressure equalizer that equalizes the pressure of the chemicals it contains with the hydrostatic pressure of the sea water.
- the chemicals in chemical tank 63 may be dispensed into chemical tank 63 while chemical tank 63 is on the production platform and prior to deploying chemical tank 63 subsea.
- a fill up line (not shown) may extend from the production platform to chemical tank 63 to refill chemical tank 63 after it has been depleted.
- chemical tank 63 could be eliminated and replaced with a special purpose line (not shown) that extends down from the production platform and connects to pump canister 27 to deliver chemicals when needed.
- the size of chemical tank 63 may vary, and as an example, it could have a capacity of between about 10 and 100 barrels.
- a chemical line 65 delivers chemicals from chemical tank 63 to pump canister 27 .
- chemical line 65 connects into pump intake line 25 at a point between pump intake valve 29 and pump canister 27 .
- chemical line 65 could connect directly to pump canister 27 .
- a chemical line valve 67 selectively opens and closes chemical line 65 .
- Outlet conditioner 45 also creates a liquid level, and returns a portion of the heavier components of the well fluid through recirculation line 57 to intake conditioner 21 .
- the heavier components within recirculation line 57 mix with the well fluid flowing into intake conditioner 21 from subsea tree flow line 19 .
- the mixture of heavier and lighter components in perforated tube 49 of outlet conditioner 45 flows out outlet flow line 51 .
- Pump 33 pumps the chemicals out outlet flow line 43 , causing the chemicals to flow through outlet conditioner 45 and recirculation line 57 into subsea tree conduit 19 as indicated by the arrows in FIG. 2 . If the end of recirculation line 57 is connected to the upper end of intake conditioner 21 , as schematically shown, the chemicals would enter the upper end of intake conditioner 21 , then flow out of intake conditioner 21 into subsea tree conduit 19 .
Abstract
Description
- This application claims priority to provisional application Ser. No. 62/406,496, filed Oct. 11, 2016.
- The present disclosure relates to boosting the flow of well fluids from a subsea well using a sea floor boost pump, and in particular to using the sea floor boost pump to also selectively inject chemicals into the well.
- Subsea boost pumps have been proposed to boost production from subsea wells. The subsea boost pump increases the drawdown on the well, boosting the pressure of the produced fluids to overcome pipeline and hydrostatic losses. One type of subsea boost pump proposed comprises an electrical submersible pump mounted in a canister or flow line jumper.
- It is also known to inject chemicals into wells to enhance production. Normally, a chemical injection pump injects the chemicals. The chemical injection pump is separate from the well fluid pump employed to pump well fluid from the well.
- In many wells, the well fluid being produced contains both liquid and gas hydrocarbons. The performance of certain types of well pumps, particularly centrifugal pumps, is detrimentally affected by a high gas content in the well fluids. Various types of separators may be employed to separate the oil from the gas prior to reaching the intake of the well pump. After the discharge of the pump, the liquid enriched phase may be recirculated to the pump intake to reduce the relative gas content at the pump intake.
- A subsea well production system comprises a subsea boost pump having an intake operatively coupled to a subsea tree conduit of a subsea tree. A valve in the subsea tree conduit in the subsea tree conduit selectively opens and closes the subsea tree conduit. A boost pump outlet conduit operatively couples between a discharge of the boost pump and an outlet flow line. A recirculation line extends from the boost pump outlet conduit to the subsea tree conduit. A chemical injection source line extends from a chemical injection source and is connected to the subsea tree conduit at a point between the valve in the subsea tree conduit and the intake of the boost pump. A chemical source valve selectively opens and closes the chemical injection source line. While the system is in a production flow boosting mode, the valve in the subsea tree conduit is open and the chemical source valve is closed, causing the boost pump to pump well fluid flowing from the subsea tree to the outlet flow line, and in many cases diverting a portion of the well fluid back through the recirculation line to the subsea tree conduit. While the system is in a chemical injection mode, the valve in the subsea tree conduit is closed and the chemical source valve is open, causing the boost pump to pump the chemical from the chemical source through the recirculation line into the subsea tree conduit and from the subsea tree conduit into the subsea tree.
- An intake fluid conditioner may be mounted in the subsea tree conduit. The intake fluid conditioner has means for separating heavier and lighter components in the well fluid flowing from the subsea tree and forming a storage reservoir of liquid while the system is in the production flow boosting mode. The recirculation line extends from the boost pump outlet fluid conditioner to the intake fluid conditioner. While the system is in the production flow boosting mode, the recirculation line delivers a liquid-rich portion of the well fluid discharged by the boost pump to the intake fluid conditioner to mix with the well fluid flowing from the subsea tree. While the system is in the chemical injection mode, the recirculation line delivers the chemical discharged by the boost pump to the intake fluid conditioner and from there to the subsea tree.
- An outlet fluid conditioner may be mounted in the boost pump outlet conduit. The outlet fluid conditioner has means for separating gas and liquid components of well fluid discharged from the boost pump and delivering the heavier components to the outlet recirculation line while the system is in the production flow boosting mode. The recirculation line extends from the outlet fluid conditioner to the subsea tree conduit or intake fluid conditioner. While the system is in the production flow boosting mode, the recirculation line delivers a liquid-rich portion of the well fluid within the outlet fluid conditioner to the subsea tree conduit or intake fluid conditioner to mixx with the well fluid flowing from the subsea tree. While the system is in the chemical injection mode, the recirculation line delivers the chemical in the outlet fluid conditioner to the subsea tree conduit and from there into the subsea tree.
- The intake fluid conditioner in the embodiment shown separates a higher liquid content portion of the well fluid flowing from the subsea tree from a lower liquid content portion to create a liquid level in the intake fluid conditioner. The recirculation line extends to the intake fluid conditioner at a point selected to be above the liquid level in the intake fluid conditioner. The intake fluid conditioner has an outlet in the subsea tree conduit that is selected to be below the liquid level in the intake fluid conditioner. The valve in the subsea tree conduit is between the outlet of the intake fluid conditioner and the intake of the boost pump.
- In the embodiment shown, the outlet fluid conditioner separates a higher liquid content portion of the well fluid from a lower liquid content portion to create a liquid level in the outlet fluid conditioner. The recirculation line is connected to the outlet fluid conditioner at a point selected to be below the liquid level in the outlet fluid conditioner. The outlet flow line is adapted to be connected to the outlet fluid conditioner below the liquid level in the outlet fluid conditioner.
- The chemical source may comprise a chemical tank adapted to be located subsea adjacent the boost pump, or a conduit to a remotely located chemical tank, either subsea or on the surface. The boost pump may comprise a canister containing an electrical submersible pump.
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FIG. 1 is a schematic view of subsea boost pump system in a production mode with arrows indicating well fluid production flow. -
FIG. 2 is a schematic view of the subsea boost pump system ofFIG. 1 in a chemical injection mode with arrows indicating chemical injection into the well. - While the invention will be described in connection with the preferred embodiments, it will be understood that it is not intended to limit the invention to that embodiment. On the contrary, it is intended to cover all alternatives, modifications, and equivalents, as may be included within the spirit and scope of the invention as defined by the appended claims.
- The method and system of the present disclosure will now be described more fully hereinafter with reference to the accompanying drawings in which embodiments are shown. The method and system of the present disclosure may be in many different forms and should not be construed as limited to the illustrated embodiments set forth herein; rather, these embodiments are provided so that this disclosure will be thorough and complete, and will fully convey its scope to those skilled in the art. Like numbers refer to like elements throughout. In an embodiment, usage of the term “about” includes +/−5% of the cited magnitude. In an embodiment, usage of the term “substantially” includes +/−5% of the cited magnitude.
- It is to be further understood that the scope of the present disclosure is not limited to the exact details of construction, operation, exact materials, or embodiments shown and described, as modifications and equivalents will be apparent to one skilled in the art. In the drawings and specification, there have been disclosed illustrative embodiments and, although specific terms are employed, they are used in a generic and descriptive sense only and not for the purpose of limitation.
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FIG. 1 shows a sea floor pressure boosting system operatively connected to subsea well production equipment such as a subsea tree 11. Subsea tree 11 is a conventional pressure control tubular member that is mounted above awell 13. Subsea tree 11 is located on or near asea floor 15. Subsea tree 11 typically has a number of valves, including a production flow orwing valve 17. A subseatree flow line 19 extends fromwing valve 17 to convey well fluid flowing from well 13. - In this example, subsea
tree flow line 19 connects to anintake fluid conditioner 21, which is a vessel configured to create a level of liquid therein.Intake conditioner 21 has internal components to separate lighter or gaseous components from the heavier or liquid components, such as oil and water. In this example,intake conditioner 21 has an internal, vertically orientedperforated tube 23 extending upward from its outlet, which is on a lower end. Well fluid flows into the upper end ofintake conditioner 21 and swirls as it moves downward. The swirling tends to cause the heavier components to move into an annulus outside ofperforated tube 23 and the lighter components to remain withinperforated tube 23. The holes inperforated tube 23 meter the liquid outside ofperforated tube 23 intoperforated tube 23 at a selected flow rate. - The heavier components within
perforated tube 23 flow out ofintake fluid conditioner 21 into apump intake line 25 that extends from a lower end ofintake conditioner 21. Heavier component well fluid accumulates in the annulus outside ofperforated tube 23 to a liquid level that varies depending on the quantity of gas within the well fluid. If gas slugs flow from well 13, the liquid level may drop, but the perforations inperforated tube 23 continue to supply some liquid to pumpintake line 25. The lighter components are not vented to the exterior ofintake fluid conditioner 21, rather will mix with the heavier components inperforated tube 23 and flow to pumpintake line 25.Pump intake line 25,intake conditioner 21, and subseatree flow line 19 may be considered to comprise a subsea tree conduit leading from subsea tree 11. -
Pump intake line 25 leads to a sea floor boost pump assembly that may be a variety of types, such as a centrifugal pump, a multi-phase pump or a twin-screw pump, for example. In this embodiment, the pump assembly includes a flow line jumper, conduit orcanister 27.Pump intake line 25 has apump intake valve 29, which may be considered to be a subsea tree conduit valve that selectively opens and closes the outlet ofintake fluid conditioner 21.Pump canister 27 is a conduit or canister, normally oriented horizontal, that has an electrical submersible pump (ESP) 31 mounted inside.ESP 31 includes acentrifugal pump 33 that has a large number of stages, each stage comprising an impeller and a diffuser.Pump 33 has anintake 35 for receiving fluid flowing withinpump canister 27. A pressure equalizer orseal section 37 secures tointake 35 ofpump 33. Amotor 39 connects to sealsection 37.Motor 39 is normally a three-phase electrical motor filled with a dielectric lubricant to lubricant internal bearings.Seal section 37 has a movable element, such as a bladder or bellows, that equalizes a pressure of the lubricant inmotor 39 with well fluid on the exterior ofmotor 39 inpump canister 27. The well fluid flowing frompump intake line 25 flows aroundmotor 39 intopump intake 35. -
Pump 33 has adischarge 41 that extends sealingly out ofpump canister 27 and connects to anoutlet flow line 43. Acheck valve 47 inoutlet flow line 43 prevents back flow intopump 33. In this embodiment,outlet flow line 43 extends to anoutlet fluid conditioner 45, which is a vessel similar tointake conditioner 21.Outlet conditioner 45 has features to separate lighter gaseous components from the heavier liquid components, such as oil and water. In this example,outlet conditioner 45 has an internal, vertically orientedperforated tube 49 extending upward from its outlet, which is on a lower end. Well fluid frompump 33 flows into the upper end ofoutlet conditioner 45 and swirls as it moves downward. The swirling tends to cause the heavier components to move into the annulus on the outside ofperforated tube 49 and the lighter components to remain withinperforated tube 49. The holes inperforated tube 49 restrict but allow a selected flow rate of the liquid outside ofperforated tube 49 to flow intoperforated tube 49. - The heavier components mix with lighter components within
perforated tube 49 and flow out anoutlet flow line 51 extending from a lower end ofoutlet conditioner 45. Lighter components are not vented fromoutlet fluid conditioner 45, rather mix and flow with the heavier components outoutlet flow line 51. -
Outlet flow line 51 may lead to a production platform on the surface or other equipment onsea floor 15, such as amanifold 53. Anoutlet valve 55 inoutlet flow line 51 selectively opens and closesoutlet flow line 51. The holes inperforated tube 49 create a liquid level in the annulus surroundingperforated tube 49. The level of the liquid varies depending on the quantity of gas in the well fluid and the well flow rates. - A diverter or
recirculation line 57 extends fromoutlet conditioner 45 at a point below the liquid level to deliver some of the heavier components of well fluid back tointake conditioner 21.Recirculation line 57 is in fluid communication withsubsea tree conduit 19 and entersintake conditioner 21 near or at its upper end, preferably above the liquid level inintake conditioner 21.Recirculation line 57 optionally could be connected directly intosubsea tree conduit 19 betweenwing valve 17 andintake fluid conditioner 21. The recirculated well fluid mixes with the well fluid flowing intointake conditioner 21 from subseatree flow line 19. Achoke 59 is incorporated intorecirculation line 57 to meter the flow rate of fluid flowing fromoutlet conditioner 45.Choke 59 may be adjustable in a variety of manners. - A chemical source selectively supplies chemicals to pump 33 for injection into well 13 while
pump 33 is not pumping well fluid. In this embodiment, the chemical source comprises at least onechemical tank 63 that is lowered from a surface production platform to a location near the subsea well fluid boosting system.Chemical tank 63 contains a treating chemical for treating the well fluid within well 13 to improve the flow rate. The treating chemical may be a variety of chemicals depending on the well, such as relatively high pH acid chemicals.Chemical tank 63 preferably has an accumulator or pressure equalizer that equalizes the pressure of the chemicals it contains with the hydrostatic pressure of the sea water. - The chemicals in
chemical tank 63 may be dispensed intochemical tank 63 whilechemical tank 63 is on the production platform and prior to deployingchemical tank 63 subsea. Alternately, a fill up line (not shown) may extend from the production platform tochemical tank 63 to refillchemical tank 63 after it has been depleted. Alternately,chemical tank 63 could be eliminated and replaced with a special purpose line (not shown) that extends down from the production platform and connects to pumpcanister 27 to deliver chemicals when needed. The size ofchemical tank 63 may vary, and as an example, it could have a capacity of between about 10 and 100 barrels. - A
chemical line 65 delivers chemicals fromchemical tank 63 to pumpcanister 27. In this example,chemical line 65 connects intopump intake line 25 at a point betweenpump intake valve 29 andpump canister 27. Alternately,chemical line 65 could connect directly to pumpcanister 27. Achemical line valve 67 selectively opens and closeschemical line 65. - While in the production flow mode of
FIG. 1 ,chemical line valve 67 is closed and the other valves open. As indicated by the arrows inFIG. 1 , well fluid 13 will normally have enough natural pressure to flow from well 13 out subsea tree 11 intointake conditioner 21. Alternately, a down hole pump (not shown) could be suspended within well 13 to convey the well fluid to subsea tree 11.Intake conditioner 21 separates the gaseous portion from the liquid portion, as explained above, to create a level of liquid withinintake conditioner 21. The liquid level reduces the chances for large volume gas slugs to flow to pumpintake 35, which can cause gas locking ofpump 33. All of the well fluid flowing intointake conditioner 21, including all of the gas and liquid, will eventually flow throughpump intake line 25 to pumpcanister 27 andpump intake 35. -
Pump 33 boosts the pressure of the well fluid and delivers it tooutlet conditioner 45.Outlet conditioner 45 also creates a liquid level, and returns a portion of the heavier components of the well fluid throughrecirculation line 57 tointake conditioner 21. The heavier components withinrecirculation line 57 mix with the well fluid flowing intointake conditioner 21 from subseatree flow line 19. The mixture of heavier and lighter components inperforated tube 49 ofoutlet conditioner 45 flows outoutlet flow line 51. - To inject chemicals, the operator closes
pump intake valve 29 andoutlet line valve 55 and openschemical line valve 67.Wing valve 17 remains open. Power supplied to pumpmotor 39 causes the suction ofpump 33 to draw chemicals fromchemical tank 63 intopump canister 27.Pump 33 pumps the chemicals outoutlet flow line 43, causing the chemicals to flow throughoutlet conditioner 45 andrecirculation line 57 intosubsea tree conduit 19 as indicated by the arrows inFIG. 2 . If the end ofrecirculation line 57 is connected to the upper end ofintake conditioner 21, as schematically shown, the chemicals would enter the upper end ofintake conditioner 21, then flow out ofintake conditioner 21 intosubsea tree conduit 19. Because of the closedpump intake valve 29, the chemicals flow through subseatree flow line 19 into subsea tree 11 and down well 13.Pump 33 will be pumping the chemicals at a greater pressure than the natural pressure of the well fluid at subsea tree 11. The chemicals are thus bullheaded down well 13 from subsea tree 11. - The present invention described herein, therefore, is well adapted to carry out the objects and attain the ends and advantages mentioned, as well as others inherent therein. While a presently preferred embodiment of the invention has been given for purposes of disclosure, numerous changes exist in the details of procedures for accomplishing the desired results. These and other similar modifications will readily suggest themselves to those skilled in the art, and are intended to be encompassed within the spirit of the present invention disclosed herein and the scope of the appended claims.
Claims (20)
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US15/719,100 US10066465B2 (en) | 2016-10-11 | 2017-09-28 | Chemical injection with subsea production flow boost pump |
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US201662406496P | 2016-10-11 | 2016-10-11 | |
US15/719,100 US10066465B2 (en) | 2016-10-11 | 2017-09-28 | Chemical injection with subsea production flow boost pump |
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US20180223635A9 true US20180223635A9 (en) | 2018-08-09 |
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BR (1) | BR112019007067B1 (en) |
CA (1) | CA3039771C (en) |
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CA2999842A1 (en) * | 2015-09-23 | 2017-03-30 | Aker Solutions Inc. | Subsea pump system |
GB2573121B (en) | 2018-04-24 | 2020-09-30 | Subsea 7 Norway As | Injecting fluid into a hydrocarbon production line or processing system |
CN108505984B (en) * | 2018-05-29 | 2024-03-08 | 南京聚源隆能源科技有限公司 | Oil well liquid drives pressure boost system |
CN109339754A (en) * | 2018-12-13 | 2019-02-15 | 美钻深海能源科技研发(上海)有限公司 | Marine oil field closing well robotics injection device |
RU2741296C1 (en) * | 2020-06-02 | 2021-01-25 | Общество с ограниченной ответственностью "ЛУКОЙЛ-ПЕРМЬ" | Unit set for cluster separation |
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US5547021A (en) * | 1995-05-02 | 1996-08-20 | Raden; Dennis P. | Method and apparatus for fluid production from a wellbore |
NO312138B1 (en) * | 2000-05-04 | 2002-03-25 | Kongsberg Offshore As | Process and sea-based installation for handling and processing of multi-fraction hydrocarbons for sea |
WO2002031309A2 (en) * | 2000-10-13 | 2002-04-18 | Schlumberger Technology B.V. | Methods and apparatus for separating fluids |
US7178592B2 (en) * | 2002-07-10 | 2007-02-20 | Weatherford/Lamb, Inc. | Closed loop multiphase underbalanced drilling process |
US7059345B2 (en) * | 2002-12-03 | 2006-06-13 | Baker Hughes Incorporated | Pump bypass system |
AU2004270771B2 (en) * | 2003-09-04 | 2010-07-08 | Optimum Production Technologies Inc. | Positive pressure gas jacket for a natural gas pipeline |
NO319654B1 (en) * | 2003-10-07 | 2005-09-05 | Aker Kværner Tech As | Method and apparatus for limiting fluid accumulation in a multiphase flow pipeline |
US7163063B2 (en) * | 2003-11-26 | 2007-01-16 | Cdx Gas, Llc | Method and system for extraction of resources from a subterranean well bore |
US7243726B2 (en) | 2004-11-09 | 2007-07-17 | Schlumberger Technology Corporation | Enhancing a flow through a well pump |
US7686086B2 (en) * | 2005-12-08 | 2010-03-30 | Vetco Gray Inc. | Subsea well separation and reinjection system |
AU2007234781B2 (en) * | 2006-04-06 | 2011-09-15 | Baker Hughes Incorporated | Subsea flowline jumper containing ESP |
US7569097B2 (en) * | 2006-05-26 | 2009-08-04 | Curtiss-Wright Electro-Mechanical Corporation | Subsea multiphase pumping systems |
US20090008101A1 (en) * | 2007-07-06 | 2009-01-08 | Coady Patrick T | Method of Producing a Low Pressure Well |
US7806186B2 (en) | 2007-12-14 | 2010-10-05 | Baker Hughes Incorporated | Submersible pump with surfactant injection |
US8113288B2 (en) * | 2010-01-13 | 2012-02-14 | David Bachtell | System and method for optimizing production in gas-lift wells |
NO331478B1 (en) * | 2010-12-21 | 2012-01-16 | Seabox As | Technical system, method and applications for dosing at least one liquid treatment agent in injection water to an injection well |
NO333264B1 (en) * | 2011-04-18 | 2013-04-22 | Siemens Ag | Pump system, method and applications for transporting injection water to an underwater injection well |
NO337767B1 (en) * | 2014-06-24 | 2016-06-20 | Aker Subsea As | Underwater pumping or compression system |
US9181786B1 (en) * | 2014-09-19 | 2015-11-10 | Baker Hughes Incorporated | Sea floor boost pump and gas lift system and method for producing a subsea well |
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WO2018071193A1 (en) | 2018-04-19 |
NO20190512A1 (en) | 2019-04-15 |
BR112019007067B1 (en) | 2023-04-18 |
CA3039771A1 (en) | 2018-04-19 |
GB2570078A (en) | 2019-07-10 |
US10066465B2 (en) | 2018-09-04 |
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