US20140083706A1 - Methods and Systems for Providing Steam - Google Patents
Methods and Systems for Providing Steam Download PDFInfo
- Publication number
- US20140083706A1 US20140083706A1 US14/115,052 US201214115052A US2014083706A1 US 20140083706 A1 US20140083706 A1 US 20140083706A1 US 201214115052 A US201214115052 A US 201214115052A US 2014083706 A1 US2014083706 A1 US 2014083706A1
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- United States
- Prior art keywords
- steam
- boiler tubes
- water
- condensate
- wet
- Prior art date
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- Abandoned
Links
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Images
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F22—STEAM GENERATION
- F22B—METHODS OF STEAM GENERATION; STEAM BOILERS
- F22B37/00—Component parts or details of steam boilers
- F22B37/02—Component parts or details of steam boilers applicable to more than one kind or type of steam boiler
- F22B37/26—Steam-separating arrangements
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F22—STEAM GENERATION
- F22B—METHODS OF STEAM GENERATION; STEAM BOILERS
- F22B35/00—Control systems for steam boilers
- F22B35/06—Control systems for steam boilers for steam boilers of forced-flow type
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
- Y02E10/00—Energy generation through renewable energy sources
- Y02E10/40—Solar thermal energy, e.g. solar towers
- Y02E10/46—Conversion of thermal power into mechanical power, e.g. Rankine, Stirling or solar thermal engines
Definitions
- One common practice is to recycle a portion of the condensate, with or without processing in a water treatment plant, and reusing it as boiler feed water.
- the quantity of condensate that can be recycled is limited by the build-up of dissolved solids in the boiler feed water, which can precipitate in the boiler tubes if a portion of the condensate is not continuously purged from the system.
- a “reservoir” is a subsurface rock or sand formation from which a production fluid can be harvested.
- the rock formation may include sand, granite, silica, carbonates, clays, and organic matter, such as oil, gas, or coal, among others.
- Reservoirs can vary in thickness from less than one foot (0.3048 m) to hundreds of feet (hundreds of m).
- the thermal recovery processes chosen for a particular stage of a development sets the steam quality to be utilized. For example, in the early cycles of a recovery process such as cyclic steam stimulation (CSS) wet steam is sufficient, since the majority of recovery mechanisms are not related to gravity drainage, but may include dilation/compaction, solution gas drive, water flashing, and the like. As the CSS recovery process matures, the significance of these additional recovery mechanisms declines and the recovery role of gravity drainage increases. Similarly, conventional steam flood processes for hydrocarbon recovery may use a combination of heating and the imposition of a significant pressure gradient to displace the oil to the offset production wells, allowing the use of wet steam.
- CCS cyclic steam stimulation
- FIG. 5 is a drawing of a steam generation system 500 in a series design in which the condensate 406 from a first steam generator 206 is separated from the dry steam 402 in a separator 404 and used as a feed water stream for a smaller steam generator 502 .
- the wet steam 504 generated by the smaller steam generator 502 can be passed through a second separator 506 .
- the dry steam 508 from the second separator 506 can be combined with the dry steam 402 from the first separator 404 to form a combined dry steam 510 , which may be transported to injection wells by a pipeline.
- a bypass line 710 can be included to allow wet steam 208 from the first steam system 702 to bypass the separator 404 and add to the amount available for the wet steam stream 302 . For example, this may be useful if a new portion of the development is opened, increasing the wet steam demand after the conversion. As described below, further increases in dry steam may be achieved by adding or directing wet steam 208 from the second steam system 706 to the inlet 712 of the third steam system 708 , as described with respect to FIG. 8 .
- FIG. 9 is a drawing of a steam generation system that may provide similar production of wet and dry steam as described for FIGS. 7 and 8 .
- the steam generators 206 each feed a wet steam 208 into a common wet steam header 902 .
- a first portion 904 of the wet steam 208 may be sent to a field as the wet steam stream 302 .
- the remaining portion 906 of the wet steam 208 from the wet steam header 902 is sent to a separator 404 , from which the dry steam 402 may be sent to a field.
- the condensate 406 can be recycled to the feed water header 908 , displacing a comparable quantity of boiler feed water 205 from the water treatment facility 204 .
- the process of cascading the condensate 406 between the parallel steam systems 702 , 706 , and 708 will result in lower steam systems 706 and 708 operating at a lower pressure than the steam system 702 and 706 from which the condensate 406 was sourced.
- This will result in the wet steam 208 , for example, to be used in the CSS recovery process, being provided at the lowest pressure of the steam systems 702 , 706 , and 708 . While this outcome may be satisfactory if a CSS process is utilizing sub-fracture pressures for steam injection, it may be problematic if higher pressures are useful.
- the wet steam 1528 from section C 1506 and section C′ 1508 is sent to a final separator 1530 , which separates the dry steam 1532 from the condensate 1534 .
- the condensate 1534 may be sent to disposal or to a water treatment facility for recycling. If the contaminants are sufficiently low in the condensate 1534 , it may be in returned to the inlet of the same steam generator 1500 , or to the inlet of a successive steam generator. At least a portion of the condensate 1534 may be treated or disposed to control the build-up of contaminants. Further, a takeoff from the wet steam 1528 may be used to provide a wet steam stream 1538 to a development. In this case, the condensate stream 1534 may be blended with the wet steam stream 1538 for disposal, since the extra contaminants will not harm the wet steam stream 1538 .
- the contaminant loading at the exit of the last steam system in the cascade is predicted to be less than the solubility limit, the opportunity exists to reduce the level of the boiler water treatment, saving operating costs, and potentially capital.
- the contaminant loading at the exit of the last parallel steam generator is predicted to be above the solubility limit, then the steam quality generated in the last parallel steam generators can be reduced to maintain solubility.
- the steam systems can be formed from parallel groups of two or more steam generators, with the condensate cascaded between these steam systems. The number of generators per steam system can be chosen to ensure that solubility is maintained in the last group of generators.
- the last steam generator in the cascading arrangement can be returned to wet steam service by bypassing the separation step at the exit of the steam system. If the demand for wet steam increases further, additional steam generators near the end of the cascading arrangement can be converted to wet steam service. Conversely, if the short or long term demand for dry steam were to increase, starting with the most recently converted wet steam generator, the steam generators can be easily converted back to dry steam service by completing the separation step at the exit of the generator.
- FIG. 17 is a drawing of a development 1700 for which dry steam is separated from the wet steam and the different steam lines are directed to regions of the field where recovery processes efficiently use the wet or dry steam.
- the steam system shown in FIGS. 17-19 is essentially the system 1000 discussed with respect to FIG. 10 , it can be understood that any of the systems discussed with respect to FIGS. 7-15 may be used.
- the dry steam 402 is supplied to the injection well 1702 of a SAGD pair. Hydrocarbons may then be harvested from the collection or production well 1704 .
- the wet steam 302 from the steam generators 206 may be directly supplied to a series of steamflood wells 1706 .
- the condensate 406 from the separator (or any comparable condensate stream in FIGS. 7-15 ) can be added to the wet steam 302 to reduce contaminates.
- An exemplary embodiment provides a steam system.
- the steam system includes a steam generator that includes boiler tubes that are modified to form a number of intermediate take-offs for removing water and steam from the boiler tubes.
- a number of intermediate separators are used to separate the water and steam at each of the number of intermediate take-offs.
- a number of intermediate couplings are used to inject the water back into the boiler tubes downstream of each of the plurality of intermediate take-offs.
- a section of boiler tubes beyond the last of the plurality of intermediate take-offs is duplicated to provide a spare section of boiler tubes.
- the duplicated section of boiler tubes is shared by adjacent steam generators.
- the method includes performing a plurality of thermal recovery processes on regions within the hydrocarbon reservoir. Different recovery processes are used for different regions or at different times.
- the method includes performing a thermal recovery process comprising steam assisted gravity drainage (SAGD), cyclic steam stimulation (CSS), a steam flood process, a warm water extraction process, a Clark hot water extraction process, or any combinations thereof.
- SAGD steam assisted gravity drainage
- CSS cyclic steam stimulation
- a steam flood process a warm water extraction process
- Clark hot water extraction process or any combinations thereof.
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- Engineering & Computer Science (AREA)
- Physics & Mathematics (AREA)
- Thermal Sciences (AREA)
- Mechanical Engineering (AREA)
- General Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Life Sciences & Earth Sciences (AREA)
- Combustion & Propulsion (AREA)
- Fluid Mechanics (AREA)
- Environmental & Geological Engineering (AREA)
- Chemical & Material Sciences (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
Applications Claiming Priority (3)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA2742565 | 2011-06-10 | ||
| CA2742565A CA2742565C (fr) | 2011-06-10 | 2011-06-10 | Methodes et systemes de generation de vapeur |
| PCT/US2012/032906 WO2012170114A1 (fr) | 2011-06-10 | 2012-04-10 | Procédés et systèmes d'amenée de vapeur |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| US20140083706A1 true US20140083706A1 (en) | 2014-03-27 |
Family
ID=47296356
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| US14/115,052 Abandoned US20140083706A1 (en) | 2011-06-10 | 2012-04-10 | Methods and Systems for Providing Steam |
Country Status (3)
| Country | Link |
|---|---|
| US (1) | US20140083706A1 (fr) |
| CA (1) | CA2742565C (fr) |
| WO (1) | WO2012170114A1 (fr) |
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Also Published As
| Publication number | Publication date |
|---|---|
| CA2742565C (fr) | 2019-04-02 |
| CA2742565A1 (fr) | 2012-12-10 |
| WO2012170114A1 (fr) | 2012-12-13 |
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