WO2018026352A1 - Séparateur vertical cyclonique à double hélice pour séparation d'hydrocarbures en deux phases - Google Patents
Séparateur vertical cyclonique à double hélice pour séparation d'hydrocarbures en deux phases Download PDFInfo
- Publication number
- WO2018026352A1 WO2018026352A1 PCT/US2016/045020 US2016045020W WO2018026352A1 WO 2018026352 A1 WO2018026352 A1 WO 2018026352A1 US 2016045020 W US2016045020 W US 2016045020W WO 2018026352 A1 WO2018026352 A1 WO 2018026352A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- cyclonic
- double helix
- phase hydrocarbon
- hydrocarbon separation
- separator
- Prior art date
Links
- 238000000926 separation method Methods 0.000 title claims abstract description 27
- 229930195733 hydrocarbon Natural products 0.000 title claims abstract description 22
- 150000002430 hydrocarbons Chemical class 0.000 title claims abstract description 22
- 239000004215 Carbon black (E152) Substances 0.000 title claims abstract description 20
- 230000009977 dual effect Effects 0.000 title description 9
- 239000012530 fluid Substances 0.000 claims abstract description 33
- 239000007788 liquid Substances 0.000 claims abstract description 28
- 238000000034 method Methods 0.000 claims abstract description 28
- 230000008569 process Effects 0.000 claims abstract description 25
- 238000004891 communication Methods 0.000 claims abstract description 6
- 230000000295 complement effect Effects 0.000 claims description 5
- 230000009471 action Effects 0.000 claims description 3
- 238000004519 manufacturing process Methods 0.000 description 37
- 239000007789 gas Substances 0.000 description 26
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 11
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 10
- 150000004677 hydrates Chemical class 0.000 description 8
- 239000003921 oil Substances 0.000 description 8
- 239000000126 substance Substances 0.000 description 7
- 238000013461 design Methods 0.000 description 6
- 238000005086 pumping Methods 0.000 description 6
- 239000003345 natural gas Substances 0.000 description 5
- 230000015572 biosynthetic process Effects 0.000 description 4
- 230000008901 benefit Effects 0.000 description 3
- 238000012423 maintenance Methods 0.000 description 3
- 230000004048 modification Effects 0.000 description 3
- 238000012986 modification Methods 0.000 description 3
- 230000001965 increasing effect Effects 0.000 description 2
- 230000000116 mitigating effect Effects 0.000 description 2
- 230000003068 static effect Effects 0.000 description 2
- 208000011616 HELIX syndrome Diseases 0.000 description 1
- 229910000831 Steel Inorganic materials 0.000 description 1
- 238000007792 addition Methods 0.000 description 1
- 238000006243 chemical reaction Methods 0.000 description 1
- 230000000881 depressing effect Effects 0.000 description 1
- 239000012717 electrostatic precipitator Substances 0.000 description 1
- 230000002708 enhancing effect Effects 0.000 description 1
- 238000007667 floating Methods 0.000 description 1
- 238000005187 foaming Methods 0.000 description 1
- 238000009434 installation Methods 0.000 description 1
- 230000014759 maintenance of location Effects 0.000 description 1
- 239000008239 natural water Substances 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 238000005191 phase separation Methods 0.000 description 1
- 238000001556 precipitation Methods 0.000 description 1
- 238000011084 recovery Methods 0.000 description 1
- 230000009467 reduction Effects 0.000 description 1
- 238000005067 remediation Methods 0.000 description 1
- 239000013535 sea water Substances 0.000 description 1
- 238000009491 slugging Methods 0.000 description 1
- 238000000545 stagnation point adsorption reflectometry Methods 0.000 description 1
- 239000010959 steel 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
- E21B43/34—Arrangements for separating materials produced by the well
- E21B43/38—Arrangements for separating materials produced by the well in the well
Definitions
- the present invention relates generally to methods and means for producing oil and gas wells at lower mud-line pressures when operating a subsea production system from a process/production facility, and in a specific though non-limiting embodiment, to a dual helix cyclonic vertical separator useful in systems carrying out the two-phase liquid/gas separation such as a vertical annulus separator and pumping system (VASPS) employed in various mud-line operations.
- VASPS vertical annulus separator and pumping system
- VASPS Vertical annulus separator and pumping system
- VASPS typically consist of a vertical separator disposed in fluids in communication with an inlet near the top of the structure, and some type of compartment(s) where liquids can fall to the bottom while gas flows to the top.
- ESP electrical submersible pump
- the ESP helped increase production, but was limited by the subsea riser inside diameter and a lack of fluid / gas separation that might help the ESP lift the fluids.
- an ESP in a riser is one form of subsea pumping, but is very limited in applications.
- Known shallow water (for example, 300 feet or less) VASPS designs have typically been impractical for offshore water applications. For example, they generally require a large size and elevated pressure-ratings for deeper water depths, and subsea systems make them difficult to design, construct and install in deeper water applications.
- One such system applies multiple vein-to-supply cyclonic forces to the fluids, and spins the heavier fluids toward the outside of the device so that it falls to the bottom of the structure and can be pumped to the surface using a plurality of different sized pipes.
- a second includes a screw that causes fluids to flow to the outside of the structure while gas flows toward the inside to a pipe or other tubular located in the middle of the structure; this structure is a static device and requires a pump to lift the liquids to a process/production structure.
- a cyclonic vertical separator for two-phase hydrocarbon separation including at least a double helix fmned cyclonic device for separating associated process fluids into gasses, liquids, and combinations thereof.
- the double helix fmned cyclonic device comprises a double helix screw.
- the double helix fmned cyclonic device is disposed in electromechanical communication with an electronic submersible pump.
- the double helix fmned cyclonic device is statically disposed in communication with said electronic submersible pump.
- the double helix finned cyclonic device is installed as a package and is removably disposed with said electronic submersible pump.
- the double helix fmned cyclonic device is installed in series on associated electronic submersible pump tubing.
- the double helix screw further comprises a complementary pair of threaded helical surfaces.
- the complementary pair of threaded helical surfaces surrounds a central pipe shaft that defines a first helix surface for the handling of liquids and a second helix surface for the handling of gas.
- an upper portion of the cyclonic separator primarily handles gas and lesser amounts of liquids, and a lower portion of the cyclonic separator primarily handles liquids and lesser amounts of gas.
- a power cable directed toward the electronic submersible pump is installed in a predominantly gas handling portion of the double helix fmned cyclonic device so as to not impede cyclonic action occurring within a predominantly liquid handling portion of the double helix finned cyclonic device.
- Figure 1 is a plan drawing of an example vertical separator according to the prior art.
- Figure 2 illustrates an example separation of liquids and gasses according to a vertical separation system known in the prior art.
- Figure 3 is a plan view of an example dual helix cyclonic vertical separator for two- phase hydrocarbon separation according to the instant invention.
- Figure 4 illustrates example separation of liquids and gasses according to the dual helix cyclonic vertical separator for two-phase Ivydrocarbon separation of the instant invention.
- Figure 5 illustrates various example liquid / gas separation characteristics of fluids separated using the dual helix cyclonic vertical separator for two-phase hydrocarbon separation according to the instant invention.
- Figure 6 illustrates various example liquid / gas separation characteristics of fluids separated using a dual helix cyclonic vertical separator for two-phase hydrocarbon separation according to the instant invention.
- methods and means are provided to convert a direct vertical access riser on a dry tree, for example, a top tensioned riser supported by a tension leg platform (“TLP”) or a buoyant circular floating structure (“SPAR”) with direct vertical access risers and buoyance cans or other structures that have direct vertical access risers that can function as a mud-line pumping system.
- TLP tension leg platform
- SPAR buoyant circular floating structure
- This system has the advantage of being accessible from the direct vertical access riser surface facility without the need for subsea intervention vessels, and thus there is much less cost, more availability of facilities, and less chance of pollution from the system during operations and maintenance.
- the site is not an active well but rather a controlled vertical flow line to the process/production facility.
- ESPs are available today, a double helix cyclonic assembly is required in which inputs, outputs and connections with orientation matching the flow from the mud-line assembly are provided.
- the double helix cyclonic assembly is approximately ten feet long (though longer or shorter units can of course be used within the scope of this disclosure) and is installed in series on the ESP production tubing.
- a double helix finned cyclonic device such as a double helix screw
- a double helix finned cyclonic device comprising a complementary pair of threaded helical surfaces surrounding a central cylindrical pipe shaft that defines one helix surface for the handling of fluid and a second helix surface to handle gas.
- the dual helix screw is a fixed static device associated with the piping tubing of the ESP.
- This center tubing is the conduit for the fluid to be pumped to the surface of the process/production facility by the ESP in the lower sump.
- the natural gas has less density than the fluid and is directed to the second helix area and is allowed to flow up the area outside the tubing above the double helix assembly.
- the inlet pressure at the mud-line is set by the pressure losses in the helix assembly (which are very low), and the vertical gas column defines the inlet operating pressure of the process equipment of the process/production facility.
- the mud-line operating pressure can be very low when a low process/production facility gas inlet production train pressure is low.
- this helix portion of the device is relatively small in diameter, so that it can be installed together with the ESP on the tubing, and replacement and modification are possible every time the ESP is pulled.
- the system can pull down the mud-line flowing subsea pressures very low. In this manner, an upper portion of the cyclonic separator primarily handles gas with only a small amount of liquids, while the lower portion of the structure primarily handles liquids with only a small amount of natural gas by volume.
- this will be the first process phase from the subsea system to the process/production facility. If the process/production facility has a steel centenary riser ("SCR") or a vertical production riser, operations will be carried out more smoothly as compared to the fluid surges experienced from other systems. In short, this is the first process phase of the production facility and can provide a smoother operation from a non-pumped riser system that requires the wells to lift the fluids and gas up a riser and experience surges from fluid "fall back" within the riser.
- SCR steel centenary riser
- this is the first process phase of the production facility and can provide a smoother operation from a non-pumped riser system that requires the wells to lift the fluids and gas up a riser and experience surges from fluid "fall back" within the riser.
- a power cable to the ESP or other power means is installed in the gas portion of the helix screw assembly so as to not impede the cyclonic action of the fluid packed structure.
- the CFD calculates at 200 psi operating mud-line pressure, a flow rate of 99.375 m 3 /hr (around 15,000 barrels of liquids per day), and the separator efficiency was 98.5% with a gradient vector flow of 91.35%.
- the liquids in the gas were 1.5 m 3 /hr (396 gallons or 1.5%), and the back pressure on the system was calculated at a remarkably low 7.25 psi.
- an inlet vent renders the liquid film more stable, and increases efficiency to 99.4% with .6 m 3 /hr (158 gal/hr) at the 15,000 bl/d rate.
- Figures 5 & 6 depict a three-dimensional graphic image of the fluid rotating in the double helix with fluids flowing downward toward the bottom of the structure and the gas flowing upward toward the top of the structure.
- the system disclosed herein has many practical advantages over the prior art, including (but not limited to) operational considerations, wax mitigation and hydrate management.
- various aspects of the disclosed system allow an operator to: operate part of the subsea facility well below the pressure needed for surface fluid flow to the process/production facility from existing non pumping lift risers; increase well production because the subsea system operates with less pressure at the mud-line; improve process/production facility operations since the structure is the first separator installed in the system, which will increase the throughput on the process/production facility; remove major surges on the process/production with n' ainly fuid and gas coming from the installation in a controlled and efficient fashion; maintain -a more steady operating pressure on the subsea flowing structure with fewer riser pressure surges; subject the cyclonic vertical riser to few surges, thereby avoiding countermeasures typically required to overcome the gravitational flow of fluid in a riser originating from the mud-line to the process/production facility; add additional reserves from existing wells as operating pressure is reduced that may increase ultimate oil recovery; improve facility operation with reduction of slugging from water risers from the
- wax can form in the subsea system where the operating temperatures are low enough for wax precipitation from produced oils.
- This fluid pumped system will allow lower pressure at the mud-line and can increase fluid flow rates to help mitigate wax using the heat from the oil producing formation. Being a pumped system, it is possible to send hot fluid from the surface facility and then lift this fluid back to the surface without effectively increasing the pressure in the subsea flow line system. This would also allow for "hot-oil" of a loop flow line subsea system to remove wax build-up and then pump the increased fluid for normal operation.
- various aspects of the disclosed system achieve: operational pressures at the base of the process/production facility that can be reduced to a very low 200 psi with a low gas suction pressure on the first stage of the process/production facility, and thus hydrate formation during subsea well start up is avoided; a need for fewer chemicals to ensure a well can be started from a production loop or a lateral and not form hydrates; the startup of shut-in of a well when not enough chemicals are available to otherwise prevent hydrate formation; a faster start-up after a shut-in as wells come online without the chemicals typically needed to combat hydrates; reduced chemical costs and storage space needed for chemicals on the process/production facility; and remediation of hydrates by depressing the process/production facility side of a hydrate in the subsea lines.
- Hydrates can otherwise form when natural gas and water are mixed at low temperatures and high pressures.
- One example is in the Gulf of Mexico; the deeper water mud-line water temperature is typically 40 degrees Fahrenheit, which creates the possibility of a hydrate problem from the temperature and the pressure needed to produce up a riser in deep-water applications.
- the gas On start-up of a well that has been shut-in for a period of time and operating below the bubble point pressure, the gas will collect in the top of the well. Starting a well that puts natural gas into the pressurized flow line system will cause hydrates in the subsea system if temperatures are low.
- This gas will form hydrates if water is present in the line and the hydrates will seal off the flow line from production. After a hydrate forms, it is hard to correct the problem in 40 degrees Fahrenheit sea water temperature and pressure from the subsea system on the ocean floor.
- the industry has in the past typically used chemicals to reduce the formation of hydrates or circulation oil into the flow line system so there is very little water present. Both of these operational practices have problems ensuring there are enough chemicals in the correct location, and it is difficult to get all of the water out of a flow line system that is radially connected to a well from a loop production system. Starting at a low pressure subsea system can remove this operational problem.
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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)
- Structures Of Non-Positive Displacement Pumps (AREA)
Abstract
L'invention concerne un séparateur vertical cyclonique pour la séparation d'hydrocarbures en deux phases, le séparateur comprenant au moins un dispositif cyclonique à ailettes à double hélice tel qu'une vis à double hélice pour séparer des fluides de traitement associés en gaz, liquides et combinaisons de ceux-ci. Le dispositif cyclonique à ailettes à double hélice est disposé en communication électromécanique avec une pompe submersible électronique, soit statiquement, à savoir sous forme d'un boîtier amovible, soit en série sur un tube de pompe submersible électronique associé. La vis à double hélice comprend une paire de surfaces hélicoïdales filetées entourant un puits de tuyaux central qui définit une première surface d'hélice pour la manipulation de liquides et une deuxième surface d'hélice pour la manipulation de gaz. En pratique, une partie supérieure du séparateur cyclonique traite principalement du gaz et des quantités moins importantes de liquides, et une partie inférieure du séparateur cyclonique traite principalement des liquides et des quantités moins importantes de gaz.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| PCT/US2016/045020 WO2018026352A1 (fr) | 2016-08-01 | 2016-08-01 | Séparateur vertical cyclonique à double hélice pour séparation d'hydrocarbures en deux phases |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| PCT/US2016/045020 WO2018026352A1 (fr) | 2016-08-01 | 2016-08-01 | Séparateur vertical cyclonique à double hélice pour séparation d'hydrocarbures en deux phases |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| WO2018026352A1 true WO2018026352A1 (fr) | 2018-02-08 |
Family
ID=56610043
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| PCT/US2016/045020 WO2018026352A1 (fr) | 2016-08-01 | 2016-08-01 | Séparateur vertical cyclonique à double hélice pour séparation d'hydrocarbures en deux phases |
Country Status (1)
| Country | Link |
|---|---|
| WO (1) | WO2018026352A1 (fr) |
Cited By (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US11391141B1 (en) | 2021-10-22 | 2022-07-19 | Jordan Binstock | Reverse helix agitator |
| US11946356B2 (en) | 2021-04-01 | 2024-04-02 | Whitetail Energy Services, Llc | Reverse helix agitator |
Citations (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US2941619A (en) * | 1958-12-22 | 1960-06-21 | John J Sochor | Process of and apparatus for separating gas and liquid fractions from petroleum gas oil stream |
| US4900433A (en) * | 1987-03-26 | 1990-02-13 | The British Petroleum Company P.L.C. | Vertical oil separator |
| US6036749A (en) * | 1997-08-26 | 2000-03-14 | Petroleo Brasileiro S.A. - Petrobras | Helical separator |
| US20050217489A1 (en) * | 2004-04-02 | 2005-10-06 | Innovative Engineering Systems Ltd. | Device for the separation of the gas phase from a mixture of fluid/gas for use in hydrocarbons producing and injection wells |
| WO2008009204A1 (fr) * | 2006-07-14 | 2008-01-24 | Hongyan Yu | Élément de régulation de séparation de flux multiphase huile/eau/gaz vertical |
-
2016
- 2016-08-01 WO PCT/US2016/045020 patent/WO2018026352A1/fr active Application Filing
Patent Citations (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US2941619A (en) * | 1958-12-22 | 1960-06-21 | John J Sochor | Process of and apparatus for separating gas and liquid fractions from petroleum gas oil stream |
| US4900433A (en) * | 1987-03-26 | 1990-02-13 | The British Petroleum Company P.L.C. | Vertical oil separator |
| US6036749A (en) * | 1997-08-26 | 2000-03-14 | Petroleo Brasileiro S.A. - Petrobras | Helical separator |
| US20050217489A1 (en) * | 2004-04-02 | 2005-10-06 | Innovative Engineering Systems Ltd. | Device for the separation of the gas phase from a mixture of fluid/gas for use in hydrocarbons producing and injection wells |
| WO2008009204A1 (fr) * | 2006-07-14 | 2008-01-24 | Hongyan Yu | Élément de régulation de séparation de flux multiphase huile/eau/gaz vertical |
Cited By (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US11946356B2 (en) | 2021-04-01 | 2024-04-02 | Whitetail Energy Services, Llc | Reverse helix agitator |
| US11391141B1 (en) | 2021-10-22 | 2022-07-19 | Jordan Binstock | Reverse helix agitator |
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