US20140054028A1 - Bitumen recovery process - Google Patents
Bitumen recovery process Download PDFInfo
- Publication number
- US20140054028A1 US20140054028A1 US13/971,893 US201313971893A US2014054028A1 US 20140054028 A1 US20140054028 A1 US 20140054028A1 US 201313971893 A US201313971893 A US 201313971893A US 2014054028 A1 US2014054028 A1 US 2014054028A1
- Authority
- US
- United States
- Prior art keywords
- solvent
- bitumen
- well
- heating element
- steam
- 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.)
- Abandoned
Links
- 239000010426 asphalt Substances 0.000 title claims abstract description 63
- 238000011084 recovery Methods 0.000 title claims abstract description 24
- 239000002904 solvent Substances 0.000 claims abstract description 82
- 238000000034 method Methods 0.000 claims abstract description 41
- 238000010438 heat treatment Methods 0.000 claims abstract description 32
- 230000008569 process Effects 0.000 claims abstract description 31
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 18
- 238000002156 mixing Methods 0.000 claims abstract description 5
- 238000005553 drilling Methods 0.000 claims abstract description 3
- 238000001704 evaporation Methods 0.000 claims abstract description 3
- 239000012530 fluid Substances 0.000 claims description 18
- 239000000203 mixture Substances 0.000 claims description 18
- 230000005611 electricity Effects 0.000 claims description 11
- 229930195733 hydrocarbon Natural products 0.000 claims description 11
- 150000002430 hydrocarbons Chemical class 0.000 claims description 11
- VLKZOEOYAKHREP-UHFFFAOYSA-N n-Hexane Chemical compound CCCCCC VLKZOEOYAKHREP-UHFFFAOYSA-N 0.000 claims description 9
- OFBQJSOFQDEBGM-UHFFFAOYSA-N n-pentane Natural products CCCCC OFBQJSOFQDEBGM-UHFFFAOYSA-N 0.000 claims description 9
- 239000004215 Carbon black (E152) Substances 0.000 claims description 7
- 239000012046 mixed solvent Substances 0.000 claims description 5
- ATUOYWHBWRKTHZ-UHFFFAOYSA-N Propane Chemical compound CCC ATUOYWHBWRKTHZ-UHFFFAOYSA-N 0.000 claims description 4
- 239000001273 butane Substances 0.000 claims description 3
- 239000000295 fuel oil Substances 0.000 claims description 3
- IJDNQMDRQITEOD-UHFFFAOYSA-N n-butane Chemical compound CCCC IJDNQMDRQITEOD-UHFFFAOYSA-N 0.000 claims description 3
- 239000001294 propane Substances 0.000 claims description 2
- 230000015572 biosynthetic process Effects 0.000 description 14
- 238000005755 formation reaction Methods 0.000 description 14
- 239000003921 oil Substances 0.000 description 12
- 238000004519 manufacturing process Methods 0.000 description 7
- 238000010796 Steam-assisted gravity drainage Methods 0.000 description 6
- 238000005516 engineering process Methods 0.000 description 5
- KRKNYBCHXYNGOX-UHFFFAOYSA-N citric acid Chemical compound OC(=O)CC(O)(C(O)=O)CC(O)=O KRKNYBCHXYNGOX-UHFFFAOYSA-N 0.000 description 3
- 238000002347 injection Methods 0.000 description 3
- 239000007924 injection Substances 0.000 description 3
- 239000007788 liquid Substances 0.000 description 3
- 230000008016 vaporization Effects 0.000 description 3
- XLYOFNOQVPJJNP-ZSJDYOACSA-N Heavy water Chemical compound [2H]O[2H] XLYOFNOQVPJJNP-ZSJDYOACSA-N 0.000 description 2
- 238000009833 condensation Methods 0.000 description 2
- 230000005494 condensation Effects 0.000 description 2
- 239000003085 diluting agent Substances 0.000 description 2
- 238000005485 electric heating Methods 0.000 description 2
- 230000005484 gravity Effects 0.000 description 2
- NNPPMTNAJDCUHE-UHFFFAOYSA-N isobutane Chemical compound CC(C)C NNPPMTNAJDCUHE-UHFFFAOYSA-N 0.000 description 2
- 238000005086 pumping Methods 0.000 description 2
- 239000004576 sand Substances 0.000 description 2
- 238000009834 vaporization Methods 0.000 description 2
- 239000011800 void material Substances 0.000 description 2
- CTQNGGLPUBDAKN-UHFFFAOYSA-N O-Xylene Chemical compound CC1=CC=CC=C1C CTQNGGLPUBDAKN-UHFFFAOYSA-N 0.000 description 1
- 238000010793 Steam injection (oil industry) Methods 0.000 description 1
- 230000009471 action Effects 0.000 description 1
- 238000007792 addition Methods 0.000 description 1
- 238000009835 boiling Methods 0.000 description 1
- 239000004568 cement Substances 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- 238000006243 chemical reaction Methods 0.000 description 1
- 238000001816 cooling Methods 0.000 description 1
- 230000001351 cycling effect Effects 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 230000018109 developmental process Effects 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 238000005265 energy consumption Methods 0.000 description 1
- 230000007613 environmental effect Effects 0.000 description 1
- 238000002474 experimental method Methods 0.000 description 1
- 238000011049 filling Methods 0.000 description 1
- 238000011065 in-situ storage Methods 0.000 description 1
- 230000004941 influx Effects 0.000 description 1
- 230000001788 irregular Effects 0.000 description 1
- 239000001282 iso-butane Substances 0.000 description 1
- 235000013847 iso-butane Nutrition 0.000 description 1
- 239000007791 liquid phase Substances 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 239000012071 phase Substances 0.000 description 1
- 230000000630 rising effect Effects 0.000 description 1
- 150000003839 salts Chemical class 0.000 description 1
- 229920006395 saturated elastomer Polymers 0.000 description 1
- 239000011877 solvent mixture Substances 0.000 description 1
- -1 steam Substances 0.000 description 1
- 238000003860 storage Methods 0.000 description 1
- 239000002352 surface water Substances 0.000 description 1
- 239000008096 xylene Substances 0.000 description 1
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
- E21B43/2401—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection by means of electricity
-
- 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
Definitions
- SAGD steam assisted gravity drainage
- the heating element can be any type known in the art, including the following: 1) a continuous tube having an electric heating element or 2) a continuous tube permitting circulation of a heated fluid such as steam, gas, superheated liquid, molten salts, or other heated fluids known in the art. These heating elements are typically utilized to preheat the underground formation prior to injection of the steam into the formation.
- the solvent assisted technique includes the following steps: 1) the solvent is injected into the formation; 2) the solvent is mixed with the bitumen; 3) the solvent/bitumen mixture is recovered from the bitumen formation; and 4) the solvent is separated from the bitumen, recycled and then used in the formation again.
- US 2011/0303423 teaches recovering in situ viscous oil from an underground reservoir. Electricity is conducted through the underground reservoir by at least two electrodes in an amount that would, in the absence of solvent injection, cause water in the reservoir to vaporize adjacent to the electrodes. Solvent is injected into the reservoir to mitigate water vaporization adjacent to the electrodes by vaporizing solvent in this region. Oil and solvent are produced through one or more production wells.
- the method disclosed in US 2011/0303423 does not contemplate an energy efficient process that reduces both solvent usage and water treatment procedures.
- the known enhanced oil recovery technologies are heavily investigated, but still require improvements at every stage.
- the required improvements include 1) simplifying oil recovery the process; 2) reducing the need for materials such as steam and solvents thereby reducing energy consumption for steam generation; 3) reducing water treatment procedures; and 4) improving the process solvent recovery from the bitumen mixture.
- Disclosed herein is a process for recovering hydrocarbons such as bitumen from an underground formation which is designed to increase energy efficiency by reducing I) surface water treatment and 2 ) solvent usage.
- bitumen recovery process comprises the following steps:
- the heating element utilizes electricity, steam, or a hot fluid circulating through the well. In a further embodiment, the heating element utilizes electricity, steam, or a hot fluid circulating through the well in a tube. In yet another embodiment, the electricity, steam, or hot fluid is reheated at the surface or in the bore of the well.
- the solvent used in the process comprises propane, butane (normal, iso & mixed), pentane (normal, iso & mixed), or hexane (normal, iso & mixed).
- the solvent is a mixed solvent with a composition from C3 to C8.
- the solvent is a mixed solvent with a composition from C5 to C7. Even further, the solvent composition is a heavier C7 in the initial recovery process and is progressively replaced with lighter hydrocarbons as the process continues
- steam is injected into the well along with the solvent.
- the produced fluids recovered from the well are primarily bitumen or heavy oil with a small amount of miscible contained solvent and some connate water.
- FIG. 1 is a cross-sectional view of single well heating.
- FIG. 2 is a cross-sectional view of the end of pre-heating the single well.
- FIG. 3 is an alternative view of the end of pre-heating the single well.
- FIG. 4 is a cross-sectional view of the single well near abandonment.
- FIG. 5 is a production profile of single well heating.
- FIG. 6 is a graph showing the production profile of single well heating.
- FIG. 7 is a cross-sectional view of solvent recovery in single well heating.
- a well is drilled into the target formation.
- the entire operation may be achieved in a vertical well, slant well, horizontal well or an irregular well having a combination of vertical, horizontal and tilted portions to adapt to the geometry of the formation. Even further, the horizontal well can be extended from the vertical well.
- a single well is used to achieve a gravity driven bitumen or heavy oil production process. However, multiple wells may be heated and produced simultaneously or sequentially, each with their own heat string.
- the well is cased to the bottom of an intermediate casing, where the horizontal section includes a thermal casing and thermal cement. In the horizontal section, the well has a liner with either slotting or screens to control any sand influx.
- a string of tubing 2 is placed into the hole down through the vertical section and out into the horizontal section to a desired length. Then, the tube 2 subsequently curls back to return along the horizontal run and back to the surface 4 .
- the tubing can be fully insulated, partially insulated, or non-insulated.
- the tubing contains a heating medium 6 which could be electricity, steam, or another fluid with high-heat transfer characteristics.
- a heating medium 6 which could be electricity, steam, or another fluid with high-heat transfer characteristics.
- the electricity, steam, or fluid is reheated to the target temperature and then returned to the portion of tubing string 2 in the well.
- the electricity, steam, or fluid is at super-heated or saturated steam condition as it enters the well bore so that it transfers heat to the horizontal section.
- This initial preheating of the formation creates and initiates a depletion chamber. Condensing may take place and, because of the phase change and fixed volume, a thermo-siphon effect will be created.
- a solvent is introduced into the well.
- the solvent is a straight chain hydrocarbon which is easily vaporized at the well temperature and is miscible with the reservoir bitumen/oil.
- the solvent is a light hydrocarbon such as butane, iso-butane, pentane, hexane or a mixed solvent with similar commercial diluents with a composition from C3 to C8, but the bulk of the solvent volume in the C5-C7 range.
- xylene and natural citric acid may also be used as solvents. Varying the solvent composition over time may be helpful from heavier C7 to lighter C3 over the production cycle. It should be kept in mind that the solvent composition must be matched to the specific reservoir operating conditions, ensuring a good vaporization and condensation temperature that matches the down hole temperature.
- an initial fill of solvent in the horizontal well bore should be sufficient to maintain the process.
- the liquid solvent reaches the tube heated by steam, the heat of condensation is released to the solvent.
- the solvent quickly heats to its boiling point and vaporizes. Since vapor is lighter and has a lower density than the liquid phase, solvent vapor will rise in the well bore filling the depletion chamber. The vapor will rise until it reaches a surface that is cool enough to condense it. Generally, the cooling surface will be the bitumen above the cased well. Once the vapor is condensed onto or with the bitumen, a hydrocarbon mixture is created and the viscosity and density of the mixture are much lower than bitumen alone but higher than pure solvent.
- the hydrocarbon mixture will flow by gravity down to the horizontal section of the well, creating a void space above in the reservoir.
- the lighter hydrocarbon mixture falls into the horizontal section of the well bore and meets with the heat of the steam tubing again. This causes the solvent portion of the mixture to evaporate and rise into the void space in a new cycle.
- the bitumen in the well bore is maintained at a warm temperature, which keeps it mobile.
- the mobile bitumen can be recovered from the horizontal well by means known in the art.
- a gas lift or electric submersible pump system 12 can be used to lift the hot bitumen to surface.
- the heat source is positioned at ground level.
- it may be also positioned down hole, as when using a standard ESP (electric submersible pump) which generates a significant amount of heat in the pumping action.
- an electric heating source can be used alone or in combination with other heating sources.
- the solvent will stay in the reservoir throughout the process without the need to top up the solvent. This results in little or no solvent in the production fluid because the solvent remains a working fluid within the reservoir.
- the solvent has a repeating cycle consisting of being warm liquid in the horizontal section to hot vapor rising through the reservoir to a bitumen/solvent mixture flow back to the horizontal section. Because the solvent remains a working fluid in the reservoir, there is no solvent recovery until the end of the process resulting in less solvent used in the overall process.
- the bitumen produced from this process will still contain some water, since there is connate water entrapped around the sand grains in the reservoir along with the bitumen. However, the volume of water in the well will be substantially lower. In fact, the 300% volume of water in the bitumen volume experienced in typical SAGD operation is reduced to 15-30% volume of water in the bitumen volume.
- the solvent remaining inside the formation can be cooled, drained to the bottom of the well, and recovered from the well for future reuse.
Landscapes
- 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)
- Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
- Working-Up Tar And Pitch (AREA)
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US13/971,893 US20140054028A1 (en) | 2012-08-21 | 2013-08-21 | Bitumen recovery process |
Applications Claiming Priority (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US201261691484P | 2012-08-21 | 2012-08-21 | |
| US13/971,893 US20140054028A1 (en) | 2012-08-21 | 2013-08-21 | Bitumen recovery process |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| US20140054028A1 true US20140054028A1 (en) | 2014-02-27 |
Family
ID=50146985
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| US13/971,893 Abandoned US20140054028A1 (en) | 2012-08-21 | 2013-08-21 | Bitumen recovery process |
Country Status (12)
| Country | Link |
|---|---|
| US (1) | US20140054028A1 (fr) |
| EP (1) | EP2888439A1 (fr) |
| CN (1) | CN104520529A (fr) |
| AU (1) | AU2013305433A1 (fr) |
| BR (1) | BR112015003024A2 (fr) |
| CA (1) | CA2880092A1 (fr) |
| CO (1) | CO7180210A2 (fr) |
| MX (1) | MX2015000934A (fr) |
| PL (1) | PL411369A1 (fr) |
| RU (1) | RU2015101920A (fr) |
| SG (1) | SG11201500300QA (fr) |
| WO (1) | WO2014029009A1 (fr) |
Cited By (9)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| WO2016070262A1 (fr) * | 2013-11-06 | 2016-05-12 | Nexen Energy Ulc | Procédés de production d'hydrocarbures à partir d'un réservoir |
| WO2016140664A1 (fr) * | 2015-03-04 | 2016-09-09 | Halliburton Energy Services, Inc. | Dispositif d'injection et de production actionné par vapeur |
| WO2017193195A1 (fr) * | 2016-05-12 | 2017-11-16 | Nexen Energy Ulc | Procédés de production d'hydrocarbures à partir d'un réservoir |
| US10385259B2 (en) * | 2013-08-07 | 2019-08-20 | Schlumberger Technology Corporation | Method for removing bitumen to enhance formation permeability |
| US10487636B2 (en) | 2017-07-27 | 2019-11-26 | Exxonmobil Upstream Research Company | Enhanced methods for recovering viscous hydrocarbons from a subterranean formation as a follow-up to thermal recovery processes |
| US10934822B2 (en) * | 2016-03-23 | 2021-03-02 | Petrospec Engineering Inc. | Low-pressure method and apparatus of producing hydrocarbons from an underground formation using electric resistive heating and solvent injection |
| US11002123B2 (en) | 2017-08-31 | 2021-05-11 | Exxonmobil Upstream Research Company | Thermal recovery methods for recovering viscous hydrocarbons from a subterranean formation |
| US11142681B2 (en) | 2017-06-29 | 2021-10-12 | Exxonmobil Upstream Research Company | Chasing solvent for enhanced recovery processes |
| US11261725B2 (en) | 2017-10-24 | 2022-03-01 | Exxonmobil Upstream Research Company | Systems and methods for estimating and controlling liquid level using periodic shut-ins |
Citations (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US4697642A (en) * | 1986-06-27 | 1987-10-06 | Tenneco Oil Company | Gravity stabilized thermal miscible displacement process |
| CA2304938A1 (fr) * | 1999-08-31 | 2001-02-28 | Suncor Energy Inc. | Procede d'extraction ameliore, dans les puits inclines, pour la recuperation d'huile lourde et de bitume au moyen de chaleur et de solvants |
Family Cites Families (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN1011522B (zh) * | 1985-09-10 | 1991-02-06 | 切夫尔昂研究公司 | 用于开采地下油层石油的二聚磺酸盐表面活性剂循环蒸汽刺激工艺 |
| CA2374115C (fr) * | 2002-03-01 | 2010-05-18 | John Nenniger | Methode et appareil a faible consommation d'energie pour la stimulation de la production d'huile lourde |
| US7493952B2 (en) * | 2004-06-07 | 2009-02-24 | Archon Technologies Ltd. | Oilfield enhanced in situ combustion process |
| CA2718462C (fr) * | 2009-10-23 | 2015-12-22 | Conocophillips Company | Processus de recuperation d'huile |
-
2013
- 2013-08-21 WO PCT/CA2013/000730 patent/WO2014029009A1/fr not_active Ceased
- 2013-08-21 PL PL411369A patent/PL411369A1/pl unknown
- 2013-08-21 MX MX2015000934A patent/MX2015000934A/es unknown
- 2013-08-21 CN CN201380041458.5A patent/CN104520529A/zh active Pending
- 2013-08-21 EP EP13831655.9A patent/EP2888439A1/fr not_active Withdrawn
- 2013-08-21 CA CA2880092A patent/CA2880092A1/fr not_active Abandoned
- 2013-08-21 BR BR112015003024A patent/BR112015003024A2/pt not_active Application Discontinuation
- 2013-08-21 RU RU2015101920A patent/RU2015101920A/ru not_active Application Discontinuation
- 2013-08-21 US US13/971,893 patent/US20140054028A1/en not_active Abandoned
- 2013-08-21 SG SG11201500300QA patent/SG11201500300QA/en unknown
- 2013-08-21 AU AU2013305433A patent/AU2013305433A1/en not_active Abandoned
-
2015
- 2015-01-22 CO CO15012615A patent/CO7180210A2/es unknown
Patent Citations (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US4697642A (en) * | 1986-06-27 | 1987-10-06 | Tenneco Oil Company | Gravity stabilized thermal miscible displacement process |
| CA2304938A1 (fr) * | 1999-08-31 | 2001-02-28 | Suncor Energy Inc. | Procede d'extraction ameliore, dans les puits inclines, pour la recuperation d'huile lourde et de bitume au moyen de chaleur et de solvants |
Cited By (15)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US10385259B2 (en) * | 2013-08-07 | 2019-08-20 | Schlumberger Technology Corporation | Method for removing bitumen to enhance formation permeability |
| US20190257183A1 (en) * | 2013-11-06 | 2019-08-22 | Cnooc Petroleum North America Ulc | Processes for producing hydrocarbons from a reservoir |
| CN107109918A (zh) * | 2013-11-06 | 2017-08-29 | 尼克森能源无限责任公司 | 用于从储层生产烃的方法 |
| WO2016070262A1 (fr) * | 2013-11-06 | 2016-05-12 | Nexen Energy Ulc | Procédés de production d'hydrocarbures à partir d'un réservoir |
| US10041341B2 (en) | 2013-11-06 | 2018-08-07 | Nexen Energy Ulc | Processes for producing hydrocarbons from a reservoir |
| US10344579B2 (en) * | 2013-11-06 | 2019-07-09 | Cnooc Petroleum North America Ulc | Processes for producing hydrocarbons from a reservoir |
| WO2016140664A1 (fr) * | 2015-03-04 | 2016-09-09 | Halliburton Energy Services, Inc. | Dispositif d'injection et de production actionné par vapeur |
| US10018024B2 (en) | 2015-03-04 | 2018-07-10 | Halliburton Energy Services, Inc. | Steam operated injection and production device |
| US10934822B2 (en) * | 2016-03-23 | 2021-03-02 | Petrospec Engineering Inc. | Low-pressure method and apparatus of producing hydrocarbons from an underground formation using electric resistive heating and solvent injection |
| WO2017193195A1 (fr) * | 2016-05-12 | 2017-11-16 | Nexen Energy Ulc | Procédés de production d'hydrocarbures à partir d'un réservoir |
| US20190112907A1 (en) * | 2016-05-12 | 2019-04-18 | Nexen Energy Ulc | Processes for producing hydrocarbons from a reservoir |
| US11142681B2 (en) | 2017-06-29 | 2021-10-12 | Exxonmobil Upstream Research Company | Chasing solvent for enhanced recovery processes |
| US10487636B2 (en) | 2017-07-27 | 2019-11-26 | Exxonmobil Upstream Research Company | Enhanced methods for recovering viscous hydrocarbons from a subterranean formation as a follow-up to thermal recovery processes |
| US11002123B2 (en) | 2017-08-31 | 2021-05-11 | Exxonmobil Upstream Research Company | Thermal recovery methods for recovering viscous hydrocarbons from a subterranean formation |
| US11261725B2 (en) | 2017-10-24 | 2022-03-01 | Exxonmobil Upstream Research Company | Systems and methods for estimating and controlling liquid level using periodic shut-ins |
Also Published As
| Publication number | Publication date |
|---|---|
| MX2015000934A (es) | 2015-04-16 |
| RU2015101920A (ru) | 2016-10-10 |
| EP2888439A1 (fr) | 2015-07-01 |
| CN104520529A (zh) | 2015-04-15 |
| SG11201500300QA (en) | 2015-02-27 |
| CA2880092A1 (fr) | 2014-02-27 |
| PL411369A1 (pl) | 2016-02-29 |
| AU2013305433A1 (en) | 2015-02-05 |
| WO2014029009A1 (fr) | 2014-02-27 |
| CO7180210A2 (es) | 2015-02-09 |
| BR112015003024A2 (pt) | 2018-04-24 |
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Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| AS | Assignment |
Owner name: KEMEX LTD., CANADA Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:LITTLE, LAUREEN;JAMES, KENNETH;NABATA, BOB;SIGNING DATES FROM 20130731 TO 20130808;REEL/FRAME:031048/0890 |
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