GB2258167A - Method for separating production fluids - Google Patents
Method for separating production fluids Download PDFInfo
- Publication number
- GB2258167A GB2258167A GB9216143A GB9216143A GB2258167A GB 2258167 A GB2258167 A GB 2258167A GB 9216143 A GB9216143 A GB 9216143A GB 9216143 A GB9216143 A GB 9216143A GB 2258167 A GB2258167 A GB 2258167A
- Authority
- GB
- United Kingdom
- Prior art keywords
- separator
- water
- oil
- production fluid
- added
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Withdrawn
Links
- 239000012530 fluid Substances 0.000 title claims abstract description 35
- 238000004519 manufacturing process Methods 0.000 title claims abstract description 30
- 238000000034 method Methods 0.000 title claims abstract description 23
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 37
- 230000015572 biosynthetic process Effects 0.000 claims abstract description 5
- 239000007762 w/o emulsion Substances 0.000 claims abstract description 4
- 238000011144 upstream manufacturing Methods 0.000 abstract description 5
- 239000003129 oil well Substances 0.000 abstract description 2
- 239000003921 oil Substances 0.000 description 14
- 238000000926 separation method Methods 0.000 description 9
- 239000000839 emulsion Substances 0.000 description 7
- 239000007789 gas Substances 0.000 description 3
- 239000004215 Carbon black (E152) Substances 0.000 description 2
- 239000010779 crude oil Substances 0.000 description 2
- 230000005484 gravity Effects 0.000 description 2
- 229930195733 hydrocarbon Natural products 0.000 description 2
- 230000018044 dehydration Effects 0.000 description 1
- 238000006297 dehydration reaction Methods 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 238000010438 heat treatment Methods 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 125000001183 hydrocarbyl group Chemical group 0.000 description 1
- 238000004064 recycling Methods 0.000 description 1
- 239000004576 sand Substances 0.000 description 1
- 239000000126 substance 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
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D17/00—Separation of liquids, not provided for elsewhere, e.g. by thermal diffusion
- B01D17/02—Separation of non-miscible liquids
- B01D17/0217—Separation of non-miscible liquids by centrifugal force
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D17/00—Separation of liquids, not provided for elsewhere, e.g. by thermal diffusion
- B01D17/02—Separation of non-miscible liquids
- B01D17/04—Breaking emulsions
- B01D17/047—Breaking emulsions with separation aids
Landscapes
- Geology (AREA)
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Physics & Mathematics (AREA)
- Mining & Mineral Resources (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Thermal Sciences (AREA)
- Chemical & Material Sciences (AREA)
- Chemical Kinetics & Catalysis (AREA)
- Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
Abstract
A method for separating a production fluid obtained from an oil well into separate components by means of at least one separator 3 comprises adding water 4 to the production fluid before passage to the separator in an amount sufficient to raise water content of said production fluid to a level where the tendency for the formation of a stable water-in-oil emulsion is reduced. As shown the water which is added is partly obtained from the first separator 3, which is a hydrocyclone, and partly from a supply 7, and may be added to the fluid from well 1 upstream or downstream of pressure control valve 2. Gas is discharged from hydrocyclone 3 at outlet 8 and relatively pure oil 9 is fed to a second stage electrostatic separator 10. A demulsifier may also be added. In an example, increasing the initial water content from 10 to 60% causes a reduction in the final water content of the oil from 8.4 to 1.0%. <IMAGE>
Description
METHOD FOR SEPARATING PRODUCTION FLUIDS
This invention relates to a method of separating production fluids, in particular to a method of separating oil, water and gas from hydrocarbon containing fluids produced from an underground reservoir.
Fluids obtained from a production well in contact with an underground hydrocarbon bearing reservoir must be separated into the components of oil, water and gas in order to be transported from the production facility, recycled or for disposal purposes.
At production facilities located onshore the separation equipment required may easily be accommodated. However when production facilities are required on an offshore platform the process equipment necessary for separation has a more limited space availability.
Further the pressure control valve or choke valve situated at the wellhead may cause intense mixing of the produced fluids which may lead to the formation of stable water-in-oil emulsions. For subsequent separation on the platform such emulsions require a series of both gravity and electrostatic separators.
The temperature at which the produced fluids enter the separator facilities is known to affect separation. GB 2233577-A describes a method for separating oil well production fluids by adjusting the temperature of the fluids before separation by means of recycling with heating a portion of the separated water.
We have now found that by increasing the ratio of water to oil in the produced fluids to a level at which the tendency for stable water-in-oil emulsions to form is reduced, separator residence times and hence separator size can be reduced with resultant space and weight saving.
Thus according to the present invention there is provided a method for separating a production fluid obtained from a production well into separate components by means of at least one separator comprising adding water to the production fluid before passage to the or first separator in an amount sufficient to raise the ratio of water to oil in said production fluid to a level whereby the tendency for the formation of a stable water-in-oil emulsion is reduced.
The water may be added to the production fluid either upstream or downstream of the choke valve.
If required demulsifiers may be added either upstream or downstream of the choke valve. They may also be added upstream of the separators to assist in dehydration.
The water may be a recycled portion of the produced water from the separator or alternatively may additionally contain water from a separate source.
The percentage of water present in the fluids before passage to the first separator is in the range 10-95% preferably in the range 50-90% (wt or vol).
The fluids entering the or first stage separator may suitably be at the natural temperature of the produced fluids.
The method of the present invention is suitable for use in the separation of production fluids containing oil, gas, water and other components, for example, sand.
The method is particularly directed to production fluids which contain viscous, heavy crude oils.
By reducing the formation of stable water-in-oil emulsions in the production fluids passing to the or first stage separator, most of the water present easily separates out and can be removed.
Residence times may therefore be very short and may be in the region of 5-10 secs. Suitable separators for the first stage are hydrocyclone separators.
The oil phase leaving this separator therefore has a lower water level compared to the production fluid leaving the reservoir.
The oil may then be passed to a second stage separator which may be a conventional electrostatic separator which may also permit a shorter residence time.
This has the advantage of not requiring a series of gravity and/or electrostatic separators which are required for separation if the production fluids alone are used as the feed.
The size of the separator(s) may thereby be reduced with an associated weight and cost saving.
The method of the present invention is therefore particularly suitable for use in separating fluids produced from a production well on an offshore platform.
The first stage separator may be located if necessary on the sea bed to further enhance weight saving on the platform.
The preferred number of separators for use with the method of the present invention is two.
In certain circumstances efficient separation may be affected by use of a single separator.
The present invention is further illustrated with reference to the accompanying drawing which represents a flow diagram of a process according to the present invention and the following example.
With reference to the drawing, production fluid from a subsea production well flows via line (1) to a choke valve (2) and then to a hydrocyclone separator (3).
Recycled water (4) is added to the production fluid either upstream of the choke valve at (5) or downstream at (6).
The recycled water may additionally contain water from a separate source (7).
After passage through the separator (3) the production fluid is separated into gas (8), water, a portion of which may be recycled (4) and oil with a low water content (9).
The oil phase (9) is then passed to a secondary electrostatic separator (10) for further separation into oil (11) gas (12) and water (13).
Example
A water-in-oil emulsion containing 10% by volume simulated produced water with a total salinity of 192 grams/litre and 90%
Claire crude oil was prepared at 700C using an air-driven blender operating at 4000 rpm. A chemical demulsifier, RP 6101, was added at 150 ppm and the emulsion pumped to a vertical oil/water separator at 700C through which the fluid passed in plug flow. After 15 minutes, the residual water content in the emulsion had fallen to 8.4%.
When this procedure was repeated with the difference that produced water was recycled and blended into the emulsion stream to bring the initial water content to 60% of the total fluid volume prior to entry into the separator, the corresponding residual water content after 15 minutes residence time in the separator was 1.0%
Claims (9)
- Claims 1. A method for separating a production fluid obtained from a production well into separate components by means of at least one separator comprising adding water to the production fluid before passage to the or first separator in an amount sufficient to raise the ratio of water to oil in said production fluid to a level whereby the tendency for the formation of a stable water-in-oil emulsion is reduced.
- 2. A method according to claim 1 wherein a demulsifier is added.
- 3. A method according to either of the preceding claims wherein the water is a recycled portion of the produced water from the separator.
- 4. A method according to any of the preceding claims wherein the ratio of water to oil in the stream before passage to the separator is in the range 10-95% (wt or vol).
- 5. A method according to claim 4 wherein the ratio of water to oil in the stream before passage to the separator is in the range 50-90%.
- 6. A method according to any of the preceding claims wherein the first stage separator is a hydrocylone separator.
- 7. A method according to any of the preceding claims wherein the oil phase from the first stage separator is passed to a second stage separator.
- 8. A method according to claim 7 wherein the second stage separator is an electrostatic separator.
- 9. A method as hereinbefore described with reference to the accompanying drawing.
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| GB919116500A GB9116500D0 (en) | 1991-07-31 | 1991-07-31 | Method for separating production fluids |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| GB9216143D0 GB9216143D0 (en) | 1992-09-09 |
| GB2258167A true GB2258167A (en) | 1993-02-03 |
Family
ID=10699269
Family Applications (2)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| GB919116500A Pending GB9116500D0 (en) | 1991-07-31 | 1991-07-31 | Method for separating production fluids |
| GB9216143A Withdrawn GB2258167A (en) | 1991-07-31 | 1992-07-29 | Method for separating production fluids |
Family Applications Before (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| GB919116500A Pending GB9116500D0 (en) | 1991-07-31 | 1991-07-31 | Method for separating production fluids |
Country Status (1)
| Country | Link |
|---|---|
| GB (2) | GB9116500D0 (en) |
Cited By (9)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US5507958A (en) * | 1993-08-02 | 1996-04-16 | Atlantic Richfield Company | Dehydration of heavy crude using hydrocyclones |
| US6132494A (en) * | 1995-08-24 | 2000-10-17 | Read Group A/S | Process and means for separation of a well production stream |
| WO2004003341A1 (en) * | 2002-06-28 | 2004-01-08 | Alpha Thames Ltd | A method and system for combating the formation of emulsions |
| GB2394737A (en) * | 2002-10-29 | 2004-05-05 | Abb As | A fluid separation system |
| WO2009092998A1 (en) * | 2008-01-22 | 2009-07-30 | Caltec Limited | Separation system and method for separating a fluid mixture with this separating system |
| US8317904B2 (en) | 2008-01-22 | 2012-11-27 | Caltec Limited | Sand separation system and method |
| CN103742124A (en) * | 2013-12-28 | 2014-04-23 | 中国石油天然气股份有限公司 | Method for re-separating produced liquid of underground oil-water separation same-well injection and production well |
| WO2017112523A1 (en) * | 2015-12-22 | 2017-06-29 | Cameron Solutions, Inc. | Electrostatic technology system and process to dehydrate crude oil in a crude oil storage tank of a floating production storage and offloading installation |
| WO2017112524A1 (en) * | 2015-12-22 | 2017-06-29 | Cameron Solutions, Inc. | Topside oil production equipment system for reduction in space and weight |
Citations (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US3582489A (en) * | 1968-12-10 | 1971-06-01 | Petrolite Corp | Process for crude oil purification |
-
1991
- 1991-07-31 GB GB919116500A patent/GB9116500D0/en active Pending
-
1992
- 1992-07-29 GB GB9216143A patent/GB2258167A/en not_active Withdrawn
Patent Citations (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US3582489A (en) * | 1968-12-10 | 1971-06-01 | Petrolite Corp | Process for crude oil purification |
Cited By (17)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US5507958A (en) * | 1993-08-02 | 1996-04-16 | Atlantic Richfield Company | Dehydration of heavy crude using hydrocyclones |
| US6132494A (en) * | 1995-08-24 | 2000-10-17 | Read Group A/S | Process and means for separation of a well production stream |
| WO2004003341A1 (en) * | 2002-06-28 | 2004-01-08 | Alpha Thames Ltd | A method and system for combating the formation of emulsions |
| GB2394737A (en) * | 2002-10-29 | 2004-05-05 | Abb As | A fluid separation system |
| GB2394737B (en) * | 2002-10-29 | 2006-02-22 | Abb As | A fluid separation method and system |
| US7140441B2 (en) | 2002-10-29 | 2006-11-28 | Vetco Aibel As | Fluid separation method and system |
| EA018549B1 (en) * | 2008-01-22 | 2013-08-30 | Калтек Лимитед | Separation system and method for separating a fluid mixture with this separating system |
| US8317904B2 (en) | 2008-01-22 | 2012-11-27 | Caltec Limited | Sand separation system and method |
| WO2009092998A1 (en) * | 2008-01-22 | 2009-07-30 | Caltec Limited | Separation system and method for separating a fluid mixture with this separating system |
| US8747679B2 (en) | 2008-01-22 | 2014-06-10 | Caltec Limited | Separation system and method for separating a fluid mixture with this separating system |
| CN103742124A (en) * | 2013-12-28 | 2014-04-23 | 中国石油天然气股份有限公司 | Method for re-separating produced liquid of underground oil-water separation same-well injection and production well |
| WO2017112523A1 (en) * | 2015-12-22 | 2017-06-29 | Cameron Solutions, Inc. | Electrostatic technology system and process to dehydrate crude oil in a crude oil storage tank of a floating production storage and offloading installation |
| WO2017112524A1 (en) * | 2015-12-22 | 2017-06-29 | Cameron Solutions, Inc. | Topside oil production equipment system for reduction in space and weight |
| US9957446B2 (en) | 2015-12-22 | 2018-05-01 | Cameron Solutions, Inc. | Topside oil production equipment system for reduction in space and weight |
| US9957447B2 (en) | 2015-12-22 | 2018-05-01 | Cameron Solutions, Inc. | Electrostatic technology system and process to dehydrate crude oil in a crude oil storage tank of a floating production storage and offloading installation |
| US10870801B2 (en) | 2015-12-22 | 2020-12-22 | Cameron Solutions, Inc. | Topside oil production equipment system for reduction in space and weight |
| US10927308B2 (en) | 2015-12-22 | 2021-02-23 | Cameron Solutions, Inc. | Electrostatic technology system and process to dehydrate crude oil in a crude oil storage tank of a floating production storage and offloading installation |
Also Published As
| Publication number | Publication date |
|---|---|
| GB9216143D0 (en) | 1992-09-09 |
| GB9116500D0 (en) | 1991-09-11 |
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Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| WAP | Application withdrawn, taken to be withdrawn or refused ** after publication under section 16(1) |