CA2899348C - Processing oil sand streams - Google Patents
Processing oil sand streams Download PDFInfo
- Publication number
- CA2899348C CA2899348C CA2899348A CA2899348A CA2899348C CA 2899348 C CA2899348 C CA 2899348C CA 2899348 A CA2899348 A CA 2899348A CA 2899348 A CA2899348 A CA 2899348A CA 2899348 C CA2899348 C CA 2899348C
- Authority
- CA
- Canada
- Prior art keywords
- oil sand
- tailings
- stream
- ratio
- bitumen
- 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.)
- Expired - Fee Related
Links
Classifications
-
- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G1/00—Production of liquid hydrocarbon mixtures from oil-shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal
- C10G1/04—Production of liquid hydrocarbon mixtures from oil-shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by extraction
- C10G1/045—Separation of insoluble materials
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N21/00—Investigating or analysing materials by the use of optical means, i.e. using sub-millimetre waves, infrared, visible or ultraviolet light
- G01N21/62—Systems in which the material investigated is excited whereby it emits light or causes a change in wavelength of the incident light
- G01N21/66—Systems in which the material investigated is excited whereby it emits light or causes a change in wavelength of the incident light electrically excited, e.g. electroluminescence
- G01N21/68—Systems in which the material investigated is excited whereby it emits light or causes a change in wavelength of the incident light electrically excited, e.g. electroluminescence using high frequency electric fields
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N21/00—Investigating or analysing materials by the use of optical means, i.e. using sub-millimetre waves, infrared, visible or ultraviolet light
- G01N21/62—Systems in which the material investigated is excited whereby it emits light or causes a change in wavelength of the incident light
- G01N21/71—Systems in which the material investigated is excited whereby it emits light or causes a change in wavelength of the incident light thermally excited
- G01N21/718—Laser microanalysis, i.e. with formation of sample plasma
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N23/00—Investigating or analysing materials by the use of wave or particle radiation, e.g. X-rays or neutrons, not covered by groups G01N3/00 – G01N17/00, G01N21/00 or G01N22/00
- G01N23/22—Investigating or analysing materials by the use of wave or particle radiation, e.g. X-rays or neutrons, not covered by groups G01N3/00 – G01N17/00, G01N21/00 or G01N22/00 by measuring secondary emission from the material
- G01N23/221—Investigating or analysing materials by the use of wave or particle radiation, e.g. X-rays or neutrons, not covered by groups G01N3/00 – G01N17/00, G01N21/00 or G01N22/00 by measuring secondary emission from the material by activation analysis
- G01N23/222—Investigating or analysing materials by the use of wave or particle radiation, e.g. X-rays or neutrons, not covered by groups G01N3/00 – G01N17/00, G01N21/00 or G01N22/00 by measuring secondary emission from the material by activation analysis using neutron activation analysis [NAA]
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N23/00—Investigating or analysing materials by the use of wave or particle radiation, e.g. X-rays or neutrons, not covered by groups G01N3/00 – G01N17/00, G01N21/00 or G01N22/00
- G01N23/22—Investigating or analysing materials by the use of wave or particle radiation, e.g. X-rays or neutrons, not covered by groups G01N3/00 – G01N17/00, G01N21/00 or G01N22/00 by measuring secondary emission from the material
- G01N23/223—Investigating or analysing materials by the use of wave or particle radiation, e.g. X-rays or neutrons, not covered by groups G01N3/00 – G01N17/00, G01N21/00 or G01N22/00 by measuring secondary emission from the material by irradiating the sample with X-rays or gamma-rays and by measuring X-ray fluorescence
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N33/00—Investigating or analysing materials by specific methods not covered by groups G01N1/00 - G01N31/00
- G01N33/24—Earth materials
- G01N33/241—Earth materials for hydrocarbon content
Abstract
Disclosed is a method of controlling an oil sand treatment process. The method includes analyzing an oil sand stream of the oil sand treatment process to obtain a ratio of aluminum to silicon in the oil sand stream, and adjusting a parameter of the oil sand treatment process based on the ratio.
Description
PROCESSING OIL SAND STREAMS
BACKGROUND
Field of Disclosure [0001] The disclosure relates generally to the field of oil sand processing.
Description of Related Art
BACKGROUND
Field of Disclosure [0001] The disclosure relates generally to the field of oil sand processing.
Description of Related Art
[0002] This section is intended to introduce various aspects of the art, which may be associated with the present disclosure. This discussion is believed to assist in providing a framework to facilitate a better understanding of particular aspects of the present disclosure.
Accordingly, it should be understood that this section should be read in this light, and not necessarily as admissions of prior art.
Accordingly, it should be understood that this section should be read in this light, and not necessarily as admissions of prior art.
[0003] Modern society is greatly dependent on the use of hydrocarbon resources for fuels and chemical feedstocks. Hydrocarbons are generally found in subsurface formations that can be termed "reservoirs". Removing hydrocarbons from the reservoirs depends on numerous physical properties of the subsurface formations, such as the permeability of the rock containing the hydrocarbons, the ability of the hydrocarbons to flow through the subsurface formations, and the proportion of hydrocarbons present, among other things.
Easily harvested sources of hydrocarbons are dwindling, leaving less accessible sources to satisfy future energy needs. As the costs of hydrocarbons increase, the less accessible sources become more economically attractive.
Easily harvested sources of hydrocarbons are dwindling, leaving less accessible sources to satisfy future energy needs. As the costs of hydrocarbons increase, the less accessible sources become more economically attractive.
[0004] Recently, the harvesting of oil sand to remove heavy oil has become more economical. Hydrocarbon removal from oil sand may be performed by several techniques.
For example, a well can be drilled to an oil sand reservoir and steam, hot air, solvents, or a combination thereof, can be injected to release the hydrocarbons. The released hydrocarbons may be collected by wells and brought to the surface. In another technique, strip or surface mining may be performed to access the oil sand, which can be treated with water, steam or solvents to extract the heavy oil.
For example, a well can be drilled to an oil sand reservoir and steam, hot air, solvents, or a combination thereof, can be injected to release the hydrocarbons. The released hydrocarbons may be collected by wells and brought to the surface. In another technique, strip or surface mining may be performed to access the oil sand, which can be treated with water, steam or solvents to extract the heavy oil.
[0005] Oil sand extraction processes are used to liberate and separate bitumen from oil sand so that the bitumen can be further processed to produce synthetic crude oil or mixed with diluent to form "dilbit" and be transported to a refinery plant. Numerous oil sand extraction processes have been developed and commercialized, many of which involve the use of water as a processing medium. Where the oil sand is treated with water, the technique may be referred to as water-based extraction (WBE). WBE is a commonly used process to extract bitumen from mined oil sand. Other processes are non-aqueous solvent-based processes. An example of a solvent-based process is described in Canadian Patent Application No.
2,724,806 (Adeyinka et al, published June 30, 2011 and entitled "Process and Systems for Solvent Extraction of Bitumen from Oil Sands"). Solvent may be used in both aqueous and non-aqueous processes.
2,724,806 (Adeyinka et al, published June 30, 2011 and entitled "Process and Systems for Solvent Extraction of Bitumen from Oil Sands"). Solvent may be used in both aqueous and non-aqueous processes.
[0006] One WBE process is the Clark hot water extraction process (the "Clark Process"). This process typically requires that mined oil sand be conditioned for extraction by being crushed to a desired lump size and then combined with hot water and perhaps other agents to form a conditioned slurry of water and crushed oil sand. In the Clark Process, an amount of sodium hydroxide (caustic) may be added to the slurry to increase the slurry pH, which enhances the liberation and separation of bitumen from the oil sand.
Other WBE
processes may use other temperatures and may include other conditioning agents, which are added to the oil sand slurry, or may operate without conditioning agents. This slurry is first processed in a Primary Separation Cell (PSC), also known as a Primary Separation Vessel (PSV), to extract the bitumen from the slurry.
Other WBE
processes may use other temperatures and may include other conditioning agents, which are added to the oil sand slurry, or may operate without conditioning agents. This slurry is first processed in a Primary Separation Cell (PSC), also known as a Primary Separation Vessel (PSV), to extract the bitumen from the slurry.
[0007] In one bitumen extraction process, a water and oil sand slurry is separated into three major streams in the PSC: bitumen froth, middlings, and a PSC underflow.
[0008] Regardless of the type of WBE process employed, the process will typically result in the production of a bitumen froth that requires treatment with a solvent. For example, in the Clark Process, a bitumen froth stream comprises bitumen, solids, and water. Certain processes use naphtha to dilute bitumen froth before separating the product bitumen by centrifugation. These processes are called naphtha froth treatment (NFT) processes. Other 411b processes use a paraffinic solvent, and are called paraffinic froth treatment (PFT) processes, to produce pipelineable bitumen with low levels of solids and water. In the PFT
process, a paraffinic solvent (for example, a mixture of iso-pentane and n-pentane) is used to dilute the froth before separating the product, diluted bitumen, by gravity. A portion of the asphaltenes in the bitumen is also rejected by design in the PFT process and this rejection is used to achieve reduced solids and water levels. In both the NFT and the PFT
processes, the diluted tailings (comprising water, solids and some hydrocarbon) are separated from the diluted product bitumen.
100091 Solvent is typically recovered from the diluted product bitumen component before the bitumen is delivered to a refining facility for further processing.
[0010] The PFT process may comprise at least three units: Froth Separation Unit (FSU), Solvent Recovery Unit (SRU) and Tailings Solvent Recovery Unit (TSRU).
Mixing of the solvent with the feed bitumen froth may be carried out counter-currently in two stages in separate froth separation units. The bitumen froth comprises bitumen, water, and solids. A
typical composition of bitumen froth is about 60 wt. % bitumen, 30 wt. %
water, and 10 wt. %
solids. The paraffinic solvent is used to dilute the froth before separating the product bitumen by gravity. The foregoing is only an example of a PFT process and the values are provided by way of example only. An example of a PFT process is described in Canadian Patent No.
2,587,166 to Sury.
[0011] From the PSC, the middlings, comprising bitumen and about 10-30 wt. %
solids, or about 20-25 wt. % solids, based on the total wt. % of the middlings, is withdrawn and sent to the flotation cells to further recover bitumen. The middlings are processed by bubbling air through the slurry and creating a bitumen froth, which is recycled back to the PSC. Flotation tailings (FT) from the flotation cells, comprising mostly solids and water, are sent for further treatment or disposed in an external tailings area (ETA).
[00121 In ETA tailings ponds, a liquid suspension of oil sand fines in water with a solids content greater than 2 wt. %, but less than the solids content corresponding to the Liquid Limit are called Fluid Fine Tailings (FFT). FFT settle over time to produce Mature Fine Tailings (MFT), having above about 30 wt. % solids.
[0013] It would be desirable to have an alternative or improved method of controlling an oil sand treatment process.
SUMMARY
[0014] It is an object of the present disclosure to provide a method of controlling an oil sand treatment process.
[0015] Disclosed is a method of controlling an oil sand treatment process. The method comprises analyzing an oil sand stream of the oil sand treatment process to obtain a ratio of aluminum to silicon in the oil sand stream, and adjusting a parameter of the oil sand treatment process based on the ratio.
[0016] The foregoing has broadly outlined the features of the present disclosure so that the detailed description that follows may be better understood.
Additional features will also be described herein.
BRIEF DESCRIPTION OF THE DRAWINGS
[0017] These and other features, aspects and advantages of the disclosure will become apparent from the following description, appending claims and the accompanying drawings, which are briefly described below.
[0018] Fig. 1 is a flow chart of a method of controlling an oil sand treatment process.
[0019] Fig. 2 is a graph of clay fraction of mineral solids as a function of Al:Si wt. %, from an oil sand ore sample.
[0020] Fig. 3 is a graph of clay fraction of mineral solids as a function of K wt. %, from an oil sand ore sample.
[0021] Fig. 4 is a graph of clay fraction of mineral solids as a function of Al:Si wt. %, from an oil sand tailings sample.
[0022] Fig. 5 is a graph of clay fraction of mineral solids as a function of K wt. %, from an oil sand tailings sample.
[0023] It should be noted that the figures are merely examples and no limitations on the scope of the present disclosure are intended thereby. Further, the figures are generally not drawn to scale, but are drafted for purposes of convenience and clarity in illustrating various aspects of the disclosure.
DETAILED DESCRIPTION
[0024] For the purpose of promoting an understanding of the principles of the disclosure, reference will now be made to the features illustrated in the drawings and specific language will be used to describe the same. It will nevertheless be understood that no limitation of the scope of the disclosure is thereby intended. Any alterations and further modifications, and any further applications of the principles of the disclosure as described herein are contemplated as would normally occur to one skilled in the art to which the disclosure relates. It will be apparent to those skilled in the relevant art that some features that are not relevant to the present disclosure may not be shown in the drawings for the sake of clarity.
[0025] At the outset, for ease of reference, certain terms used in this application and their meaning as used in this context are set forth below. To the extent a term used herein is not defined below, it should be given the broadest definition persons in the pertinent art have given that term as reflected in at least one printed publication or issued patent. Further, the present processes are not limited by the usage of the terms shown below, as all equivalents, synonyms, new developments and terms or processes that serve the same or a similar purpose are considered to be within the scope of the present disclosure.
[0026] Throughout this disclosure, where a range is used, any number between or inclusive of the range is implied.
[0027] A "hydrocarbon" is an organic compound that primarily includes the elements of hydrogen and carbon, although nitrogen, sulfur, oxygen, metals, or any number of other elements may be present in small amounts. Hydrocarbons generally refer to components found in heavy oil or in oil sand. However, the techniques described are not limited to heavy oils but may also be used with any number of other reservoirs to improve gravity drainage of liquids. Hydrocarbon compounds may be aliphatic or aromatic, and may be straight chained, branched, or partially or fully cyclic.
[0028] "Bitumen" is a naturally occurring heavy oil material. Generally, it is the hydrocarbon component found in oil sand. Bitumen can vary in composition depending upon the degree of loss of more volatile components. It can vary from a very viscous, tar-like, semi-solid material to solid forms. The hydrocarbon types found in bitumen can include aliphatics, aromatics, resins, and asphaltenes. A typical bitumen might be composed of:
19 weight (wt.) % aliphatics (which can range from 5 wt. % - 30 wt. %, or higher);
19 wt. % asphaltenes (which can range from 5 wt. % - 30 wt. %, or higher);
30 wt. % aromatics (which can range from 15 wt. % - 50 wt. %, or higher);
32 wt. % resins (which can range from 15 wt. % - 50 wt. %, or higher); and some amount of sulfur (which can range in excess of 7 wt. %), the weight %
based upon total weight of the bitumen.
In addition, bitumen can contain some water and nitrogen compounds ranging from less than 0.4 wt. % to in excess of 0.7 wt. %. The percentage of the hydrocarbon found in bitumen can vary. The term "heavy oil" includes bitumen as well as lighter materials that may be found in a sand or carbonate reservoir.
[0029] "Heavy oil" includes oils which are classified by the American Petroleum Institute ("API"), as heavy oils, extra heavy oils, or bitumens. The term "heavy oil" includes bitumen. Heavy oil may have a viscosity of about 1,000 centipoise (cP) or more, 10,000 cP or more, 100,000 cP or more, or 1,000,000 cP or more. In general, a heavy oil has an API gravity between 22.3 API (density of 920 kilograms per meter cubed (kg/m3) or 0.920 grams per centimeter cubed (g/cm3)) and 10.0 API (density of 1,000 kg/m3 or 1 g/cm3).
An extra heavy oil, in general, has an API gravity of less than 10.00 API (density greater than 1,000 kg/m3 or 1 g/cm3). For example, a source of heavy oil includes oil sand or bituminous sand, which is a combination of clay, sand, water and bitumen. The recovery of heavy oils is based on the viscosity decrease of fluids with increasing temperature or solvent concentration. Once the viscosity is reduced, the mobilization of fluid by steam, hot water flooding, or gravity is possible. The reduced viscosity makes the drainage or dissolution quicker and therefore directly contributes to the recovery rate.
[0030] The term "bituminous feed" refers to a stream derived from oil sand that requires downstream processing in order to realize valuable bitumen products or fractions.
The bituminous feed is one that comprises bitumen along with undesirable components.
Undesirable components may include but are not limited to clay, minerals, coal, debris and water. The bituminous feed may be derived directly from oil sand, and may be, for example, raw oil sand ore. Further, the bituminous feed may be a feed that has already realized some initial processing but nevertheless requires further processing. Also, recycled streams that comprise bitumen in combination with other components for removal as described herein can be included in the bituminous feed. A bituminous feed need not be derived directly from oil sand, but may arise from other processes. For example, a waste product from other extraction processes which comprises bitumen that would otherwise not have been recovered may be used as a bituminous feed.
[0031] "Fine particles" or "fines" are generally defined as those solids having a size of less than 44 microns (um), as determined by laser diffraction particle size measurement.
[0032] "Coarse particles" are generally defined as those solids having a size of greater than 44 microns (um).
[0033] The term "solvent" as used in the present disclosure should be understood to mean either a single solvent, or a combination of solvents.
[0034] The terms "approximately," "about," "substantially," and similar terms are intended to have a broad meaning in harmony with the common and accepted usage by those of ordinary skill in the art to which the subject matter of this disclosure pertains. It should be understood by those of skill in the art who review this disclosure that these terms are intended to allow a description of certain features described and claimed without restricting the scope of these features to the precise numeral ranges provided. Accordingly, these terms should be interpreted as indicating that insubstantial or inconsequential modifications or alterations of the subject matter described and are considered to be within the scope of the disclosure.
[0035] The articles "the", "a" and "an" are not necessarily limited to mean only one, but rather are inclusive and open ended so as to include, optionally, multiple such elements.
[0036] The term "paraffinic solvent" (also known as aliphatic) as used herein means solvents comprising normal paraffins, isoparaffins or blends thereof in amounts greater than 50 wt. %. Presence of other components such as olefins, aromatics or naphthenes may counteract the function of the paraffinic solvent and hence may be present in an amount of only 1 to 20 wt. % combined, for instance no more than 3 wt. %. The paraffinic solvent may be a C4 to C20 or C4 to C6 paraffinic hydrocarbon solvent or a combination of iso and normal components thereof. The paraffinic solvent may comprise pentane, iso-pentane, or a combination thereof. The paraffinic solvent may comprise about 60 wt. %
pentane and about 40 wt. % iso-pentane, with none or less than 20 wt. % of the counteracting components referred above.
[0037] The inventors have shown that a ratio of aluminum (Al) to silicon (Si) in an oil sand stream can be valuable information and can be used to adjust oil sand treatment processes.
[0038] The present disclosure provides a method of controlling an oil sand treatment process. With reference to Figure 1, first, an oil sand stream of the oil sand treatment process is analyzed (102) to obtain a ratio of aluminum to silicon in the oil sand stream. Then, a parameter of the oil sand treatment process is adjusted (104) based on the ratio.
[0039] The ratio may be an elemental signal ratio, a molar ratio, or weight ratio.
[0040] The analysis may be achieved by any suitable technique capable of determining or otherwise approximating the ratio.
For instance, the analysis may be of visible light, x-rays, or gamma rays. The analysis may use LIBS (Laser-Induced Breakdown Spectroscopy), XRF (X-Ray Fluorescence), PGNAA (Prompt Gamma Neutron Activation Analysis), Inductively Coupled Plasma Atomic Emission Spectroscopy (ICP-AES), or Atomic Absorption (AA).
[0041] The analysis may be effected online, inline, offline, or atline.
[0042] The "oil sand stream" is any suitable stream stemming from oil sand.
Examples include, but are not limited to, oil sand, a bituminous feed, a bitumen froth, tailings, a stream from an aqueous based extraction, a stream from solvent based extraction, a solvent diluted bitumen froth, a hydrotransport slurry, a solvent-ore slurry, or a combination thereof.
The tailings may be primary separation tailings, middlings, flotation tailings, froth separation tailings, tailings solvent recovery unit (TSRU) tailings, fluid fine tailings (FFT), mature fine tailings (MFT), thickened tailings, centrifuged tailings, hydrocycloned tailings, or a combination thereof.
[0043] More particularly, the oil sand stream may comprise a bituminous feed, a bitumen froth, or a tailings stream. The oil sand stream may stem from aqueous based extraction. The oil sand stream may stem from solvent based extraction. The oil sand stream may comprise solvent diluted bitumen froth. The oil sand stream may comprise primary separation tailings, middlings, flotation tailings, froth separation tailings, tailings solvent recovery unit (TSRU) tailings, fluid fine tailings (FFT), mature fine tailings (MFT), thickened tailings, centrifuged tailings, hydrocycloned tailings, or a combination thereof. The oil sand stream may comprise oil sand ore, a hydrotransport slurry, or a solvent-ore slurry.
[0044] The "oil sand treatment process" simply means a process used to treat an oil sand stream. Examples of treatment are vast. To name only three, we can name reducing a solids content, removing water, and removing solvent. The oil sand treatment process may
process, a paraffinic solvent (for example, a mixture of iso-pentane and n-pentane) is used to dilute the froth before separating the product, diluted bitumen, by gravity. A portion of the asphaltenes in the bitumen is also rejected by design in the PFT process and this rejection is used to achieve reduced solids and water levels. In both the NFT and the PFT
processes, the diluted tailings (comprising water, solids and some hydrocarbon) are separated from the diluted product bitumen.
100091 Solvent is typically recovered from the diluted product bitumen component before the bitumen is delivered to a refining facility for further processing.
[0010] The PFT process may comprise at least three units: Froth Separation Unit (FSU), Solvent Recovery Unit (SRU) and Tailings Solvent Recovery Unit (TSRU).
Mixing of the solvent with the feed bitumen froth may be carried out counter-currently in two stages in separate froth separation units. The bitumen froth comprises bitumen, water, and solids. A
typical composition of bitumen froth is about 60 wt. % bitumen, 30 wt. %
water, and 10 wt. %
solids. The paraffinic solvent is used to dilute the froth before separating the product bitumen by gravity. The foregoing is only an example of a PFT process and the values are provided by way of example only. An example of a PFT process is described in Canadian Patent No.
2,587,166 to Sury.
[0011] From the PSC, the middlings, comprising bitumen and about 10-30 wt. %
solids, or about 20-25 wt. % solids, based on the total wt. % of the middlings, is withdrawn and sent to the flotation cells to further recover bitumen. The middlings are processed by bubbling air through the slurry and creating a bitumen froth, which is recycled back to the PSC. Flotation tailings (FT) from the flotation cells, comprising mostly solids and water, are sent for further treatment or disposed in an external tailings area (ETA).
[00121 In ETA tailings ponds, a liquid suspension of oil sand fines in water with a solids content greater than 2 wt. %, but less than the solids content corresponding to the Liquid Limit are called Fluid Fine Tailings (FFT). FFT settle over time to produce Mature Fine Tailings (MFT), having above about 30 wt. % solids.
[0013] It would be desirable to have an alternative or improved method of controlling an oil sand treatment process.
SUMMARY
[0014] It is an object of the present disclosure to provide a method of controlling an oil sand treatment process.
[0015] Disclosed is a method of controlling an oil sand treatment process. The method comprises analyzing an oil sand stream of the oil sand treatment process to obtain a ratio of aluminum to silicon in the oil sand stream, and adjusting a parameter of the oil sand treatment process based on the ratio.
[0016] The foregoing has broadly outlined the features of the present disclosure so that the detailed description that follows may be better understood.
Additional features will also be described herein.
BRIEF DESCRIPTION OF THE DRAWINGS
[0017] These and other features, aspects and advantages of the disclosure will become apparent from the following description, appending claims and the accompanying drawings, which are briefly described below.
[0018] Fig. 1 is a flow chart of a method of controlling an oil sand treatment process.
[0019] Fig. 2 is a graph of clay fraction of mineral solids as a function of Al:Si wt. %, from an oil sand ore sample.
[0020] Fig. 3 is a graph of clay fraction of mineral solids as a function of K wt. %, from an oil sand ore sample.
[0021] Fig. 4 is a graph of clay fraction of mineral solids as a function of Al:Si wt. %, from an oil sand tailings sample.
[0022] Fig. 5 is a graph of clay fraction of mineral solids as a function of K wt. %, from an oil sand tailings sample.
[0023] It should be noted that the figures are merely examples and no limitations on the scope of the present disclosure are intended thereby. Further, the figures are generally not drawn to scale, but are drafted for purposes of convenience and clarity in illustrating various aspects of the disclosure.
DETAILED DESCRIPTION
[0024] For the purpose of promoting an understanding of the principles of the disclosure, reference will now be made to the features illustrated in the drawings and specific language will be used to describe the same. It will nevertheless be understood that no limitation of the scope of the disclosure is thereby intended. Any alterations and further modifications, and any further applications of the principles of the disclosure as described herein are contemplated as would normally occur to one skilled in the art to which the disclosure relates. It will be apparent to those skilled in the relevant art that some features that are not relevant to the present disclosure may not be shown in the drawings for the sake of clarity.
[0025] At the outset, for ease of reference, certain terms used in this application and their meaning as used in this context are set forth below. To the extent a term used herein is not defined below, it should be given the broadest definition persons in the pertinent art have given that term as reflected in at least one printed publication or issued patent. Further, the present processes are not limited by the usage of the terms shown below, as all equivalents, synonyms, new developments and terms or processes that serve the same or a similar purpose are considered to be within the scope of the present disclosure.
[0026] Throughout this disclosure, where a range is used, any number between or inclusive of the range is implied.
[0027] A "hydrocarbon" is an organic compound that primarily includes the elements of hydrogen and carbon, although nitrogen, sulfur, oxygen, metals, or any number of other elements may be present in small amounts. Hydrocarbons generally refer to components found in heavy oil or in oil sand. However, the techniques described are not limited to heavy oils but may also be used with any number of other reservoirs to improve gravity drainage of liquids. Hydrocarbon compounds may be aliphatic or aromatic, and may be straight chained, branched, or partially or fully cyclic.
[0028] "Bitumen" is a naturally occurring heavy oil material. Generally, it is the hydrocarbon component found in oil sand. Bitumen can vary in composition depending upon the degree of loss of more volatile components. It can vary from a very viscous, tar-like, semi-solid material to solid forms. The hydrocarbon types found in bitumen can include aliphatics, aromatics, resins, and asphaltenes. A typical bitumen might be composed of:
19 weight (wt.) % aliphatics (which can range from 5 wt. % - 30 wt. %, or higher);
19 wt. % asphaltenes (which can range from 5 wt. % - 30 wt. %, or higher);
30 wt. % aromatics (which can range from 15 wt. % - 50 wt. %, or higher);
32 wt. % resins (which can range from 15 wt. % - 50 wt. %, or higher); and some amount of sulfur (which can range in excess of 7 wt. %), the weight %
based upon total weight of the bitumen.
In addition, bitumen can contain some water and nitrogen compounds ranging from less than 0.4 wt. % to in excess of 0.7 wt. %. The percentage of the hydrocarbon found in bitumen can vary. The term "heavy oil" includes bitumen as well as lighter materials that may be found in a sand or carbonate reservoir.
[0029] "Heavy oil" includes oils which are classified by the American Petroleum Institute ("API"), as heavy oils, extra heavy oils, or bitumens. The term "heavy oil" includes bitumen. Heavy oil may have a viscosity of about 1,000 centipoise (cP) or more, 10,000 cP or more, 100,000 cP or more, or 1,000,000 cP or more. In general, a heavy oil has an API gravity between 22.3 API (density of 920 kilograms per meter cubed (kg/m3) or 0.920 grams per centimeter cubed (g/cm3)) and 10.0 API (density of 1,000 kg/m3 or 1 g/cm3).
An extra heavy oil, in general, has an API gravity of less than 10.00 API (density greater than 1,000 kg/m3 or 1 g/cm3). For example, a source of heavy oil includes oil sand or bituminous sand, which is a combination of clay, sand, water and bitumen. The recovery of heavy oils is based on the viscosity decrease of fluids with increasing temperature or solvent concentration. Once the viscosity is reduced, the mobilization of fluid by steam, hot water flooding, or gravity is possible. The reduced viscosity makes the drainage or dissolution quicker and therefore directly contributes to the recovery rate.
[0030] The term "bituminous feed" refers to a stream derived from oil sand that requires downstream processing in order to realize valuable bitumen products or fractions.
The bituminous feed is one that comprises bitumen along with undesirable components.
Undesirable components may include but are not limited to clay, minerals, coal, debris and water. The bituminous feed may be derived directly from oil sand, and may be, for example, raw oil sand ore. Further, the bituminous feed may be a feed that has already realized some initial processing but nevertheless requires further processing. Also, recycled streams that comprise bitumen in combination with other components for removal as described herein can be included in the bituminous feed. A bituminous feed need not be derived directly from oil sand, but may arise from other processes. For example, a waste product from other extraction processes which comprises bitumen that would otherwise not have been recovered may be used as a bituminous feed.
[0031] "Fine particles" or "fines" are generally defined as those solids having a size of less than 44 microns (um), as determined by laser diffraction particle size measurement.
[0032] "Coarse particles" are generally defined as those solids having a size of greater than 44 microns (um).
[0033] The term "solvent" as used in the present disclosure should be understood to mean either a single solvent, or a combination of solvents.
[0034] The terms "approximately," "about," "substantially," and similar terms are intended to have a broad meaning in harmony with the common and accepted usage by those of ordinary skill in the art to which the subject matter of this disclosure pertains. It should be understood by those of skill in the art who review this disclosure that these terms are intended to allow a description of certain features described and claimed without restricting the scope of these features to the precise numeral ranges provided. Accordingly, these terms should be interpreted as indicating that insubstantial or inconsequential modifications or alterations of the subject matter described and are considered to be within the scope of the disclosure.
[0035] The articles "the", "a" and "an" are not necessarily limited to mean only one, but rather are inclusive and open ended so as to include, optionally, multiple such elements.
[0036] The term "paraffinic solvent" (also known as aliphatic) as used herein means solvents comprising normal paraffins, isoparaffins or blends thereof in amounts greater than 50 wt. %. Presence of other components such as olefins, aromatics or naphthenes may counteract the function of the paraffinic solvent and hence may be present in an amount of only 1 to 20 wt. % combined, for instance no more than 3 wt. %. The paraffinic solvent may be a C4 to C20 or C4 to C6 paraffinic hydrocarbon solvent or a combination of iso and normal components thereof. The paraffinic solvent may comprise pentane, iso-pentane, or a combination thereof. The paraffinic solvent may comprise about 60 wt. %
pentane and about 40 wt. % iso-pentane, with none or less than 20 wt. % of the counteracting components referred above.
[0037] The inventors have shown that a ratio of aluminum (Al) to silicon (Si) in an oil sand stream can be valuable information and can be used to adjust oil sand treatment processes.
[0038] The present disclosure provides a method of controlling an oil sand treatment process. With reference to Figure 1, first, an oil sand stream of the oil sand treatment process is analyzed (102) to obtain a ratio of aluminum to silicon in the oil sand stream. Then, a parameter of the oil sand treatment process is adjusted (104) based on the ratio.
[0039] The ratio may be an elemental signal ratio, a molar ratio, or weight ratio.
[0040] The analysis may be achieved by any suitable technique capable of determining or otherwise approximating the ratio.
For instance, the analysis may be of visible light, x-rays, or gamma rays. The analysis may use LIBS (Laser-Induced Breakdown Spectroscopy), XRF (X-Ray Fluorescence), PGNAA (Prompt Gamma Neutron Activation Analysis), Inductively Coupled Plasma Atomic Emission Spectroscopy (ICP-AES), or Atomic Absorption (AA).
[0041] The analysis may be effected online, inline, offline, or atline.
[0042] The "oil sand stream" is any suitable stream stemming from oil sand.
Examples include, but are not limited to, oil sand, a bituminous feed, a bitumen froth, tailings, a stream from an aqueous based extraction, a stream from solvent based extraction, a solvent diluted bitumen froth, a hydrotransport slurry, a solvent-ore slurry, or a combination thereof.
The tailings may be primary separation tailings, middlings, flotation tailings, froth separation tailings, tailings solvent recovery unit (TSRU) tailings, fluid fine tailings (FFT), mature fine tailings (MFT), thickened tailings, centrifuged tailings, hydrocycloned tailings, or a combination thereof.
[0043] More particularly, the oil sand stream may comprise a bituminous feed, a bitumen froth, or a tailings stream. The oil sand stream may stem from aqueous based extraction. The oil sand stream may stem from solvent based extraction. The oil sand stream may comprise solvent diluted bitumen froth. The oil sand stream may comprise primary separation tailings, middlings, flotation tailings, froth separation tailings, tailings solvent recovery unit (TSRU) tailings, fluid fine tailings (FFT), mature fine tailings (MFT), thickened tailings, centrifuged tailings, hydrocycloned tailings, or a combination thereof. The oil sand stream may comprise oil sand ore, a hydrotransport slurry, or a solvent-ore slurry.
[0044] The "oil sand treatment process" simply means a process used to treat an oil sand stream. Examples of treatment are vast. To name only three, we can name reducing a solids content, removing water, and removing solvent. The oil sand treatment process may
- 9 -comprise ore feed blending, primary bitumen conditioning and separation, bitumen froth treatment, or bitumen tailings treatment.
[0045] While the Al:Si ratio may be used to adjust the process, the ratio may also be converted to another measurement, which can provide useful information and which can in turn be used to adjust a process parameter.
[0046] For instance, a clay fraction of mineral solids in the oil sand stream may be approximated using the ratio and reference data. The clay fraction is the clay content as a fraction of total mineral solids, and may be on a weight basis. The clay fraction may be used to adjust a process parameter.
[0047] The method is technology-agnostic with respect to the instrument used to generate the data, provided that a Al:Si ratio can be measured. The measurement need not be accurate in terms of the Al:Si ratio itself, it may merely provide a useful correlation to the clay fraction or other parameter. The selected instrument need not directly report the weight or elemental percentages of Al and Si. If the instrument is known to produce linear signal response with changes in Al and Si weight for instance, then the ratio of Al:Si signal is sufficient without performing an intermediary determination of the weight or elemental fraction of each component. The measurement may then be used to adjust a process parameter.
[0048] In oil sand ore, multiple types of clay are present, such as kaolinite, illite, chlorite, mica, and smectite. The Al and Si content of these clays can vary substantially among clay types. Al can vary between about 10-22 wt. %, based upon the total weight of the clay. Si can vary between about 15-31wt. %, based upon the total weight of the clay.
Additionally, ore may comprise other minerals that comprise Al and/or Si, such as albite and microcline. These facts suggest that Al:Si ratio alone may be an inaccurate indicator of clay content. However, as Fig. 2 illustrates, concentrations of minerals are not random, such that the Al:Si ratio can be used to approximate a clay fraction of mineral solids with a reasonable or useful degree of consistency and/or accuracy. Fig. 2 is a plot of clay fraction of mineral
[0045] While the Al:Si ratio may be used to adjust the process, the ratio may also be converted to another measurement, which can provide useful information and which can in turn be used to adjust a process parameter.
[0046] For instance, a clay fraction of mineral solids in the oil sand stream may be approximated using the ratio and reference data. The clay fraction is the clay content as a fraction of total mineral solids, and may be on a weight basis. The clay fraction may be used to adjust a process parameter.
[0047] The method is technology-agnostic with respect to the instrument used to generate the data, provided that a Al:Si ratio can be measured. The measurement need not be accurate in terms of the Al:Si ratio itself, it may merely provide a useful correlation to the clay fraction or other parameter. The selected instrument need not directly report the weight or elemental percentages of Al and Si. If the instrument is known to produce linear signal response with changes in Al and Si weight for instance, then the ratio of Al:Si signal is sufficient without performing an intermediary determination of the weight or elemental fraction of each component. The measurement may then be used to adjust a process parameter.
[0048] In oil sand ore, multiple types of clay are present, such as kaolinite, illite, chlorite, mica, and smectite. The Al and Si content of these clays can vary substantially among clay types. Al can vary between about 10-22 wt. %, based upon the total weight of the clay. Si can vary between about 15-31wt. %, based upon the total weight of the clay.
Additionally, ore may comprise other minerals that comprise Al and/or Si, such as albite and microcline. These facts suggest that Al:Si ratio alone may be an inaccurate indicator of clay content. However, as Fig. 2 illustrates, concentrations of minerals are not random, such that the Al:Si ratio can be used to approximate a clay fraction of mineral solids with a reasonable or useful degree of consistency and/or accuracy. Fig. 2 is a plot of clay fraction of mineral
- 10-solids as measured by X-Ray Diffraction (XRD) against an estimate of Al:Si wt.
% ratio of mineral solids. The Al:Si wt. % ratio is estimated by assigning elemental compositions to XRD profiles. The samples used were oil sand ore samples. The samples excluded any samples having less than 40 wt. % quartz or more than 50 wt. % clay, as these fall outside the range of ores that are typically processed in significant quantities. Water, bitumen, and hydrocarbon solvent comprise negligible amounts of Si and Al such that this approach may be used with a wide variety of oil sand streams without regard to these non-mineral components.
[0049] A particle size in the oil sand stream may be approximated using the clay fraction and reference data. The particle size parameter may be a fraction of particles falling within a predetermined size range. The predetermined size range may be 0-44 microns, namely fines. The particle size parameter may be used to adjust a process parameter.
[0050] Clay and sand (quartz) are typically the primary mineral components in typical oil sand streams. Si is the primary metal in quartz, while both Si and Al are present in clays. Combined with density measurements, this ratio can provide the absolute clay content of a stream. Therefore, a total clay content in the oil sand stream may be approximated using the ratio and a solids mass measurement of the oil sand stream. The total clay content may be used to adjust a process parameter.
[0051] A methylene blue index (MBI) value in the oil sand stream may be approximated using the clay fraction and reference data. The MBI may be used to adjust a process parameter.
[0052] The reference data discussed herein may be experimental data or otherwise.
[0053] To date, the oil sand industry has struggled with analyzing clay content of oil sand streams. A measurement of total clay may be used for process control.
Analysis work has shown that correlations exist between total clay content, methylene blue index (MBI), and sands to fines ratio (SFR) of flotation tailings samples. For operation of a thickener, blending of feed streams may be performed to achieve a target feed SFR window, and chemical dosage is informed by the MBI of the combined streams. Therefore, measurement of total clay could
% ratio of mineral solids. The Al:Si wt. % ratio is estimated by assigning elemental compositions to XRD profiles. The samples used were oil sand ore samples. The samples excluded any samples having less than 40 wt. % quartz or more than 50 wt. % clay, as these fall outside the range of ores that are typically processed in significant quantities. Water, bitumen, and hydrocarbon solvent comprise negligible amounts of Si and Al such that this approach may be used with a wide variety of oil sand streams without regard to these non-mineral components.
[0049] A particle size in the oil sand stream may be approximated using the clay fraction and reference data. The particle size parameter may be a fraction of particles falling within a predetermined size range. The predetermined size range may be 0-44 microns, namely fines. The particle size parameter may be used to adjust a process parameter.
[0050] Clay and sand (quartz) are typically the primary mineral components in typical oil sand streams. Si is the primary metal in quartz, while both Si and Al are present in clays. Combined with density measurements, this ratio can provide the absolute clay content of a stream. Therefore, a total clay content in the oil sand stream may be approximated using the ratio and a solids mass measurement of the oil sand stream. The total clay content may be used to adjust a process parameter.
[0051] A methylene blue index (MBI) value in the oil sand stream may be approximated using the clay fraction and reference data. The MBI may be used to adjust a process parameter.
[0052] The reference data discussed herein may be experimental data or otherwise.
[0053] To date, the oil sand industry has struggled with analyzing clay content of oil sand streams. A measurement of total clay may be used for process control.
Analysis work has shown that correlations exist between total clay content, methylene blue index (MBI), and sands to fines ratio (SFR) of flotation tailings samples. For operation of a thickener, blending of feed streams may be performed to achieve a target feed SFR window, and chemical dosage is informed by the MBI of the combined streams. Therefore, measurement of total clay could
- 11 -be used for feed-forward control of both of these applications. Similar examples may be found in other oil sand processing, such as polymer dosage control.
[0054] One existing method for online clay measurement is the K40 Analyzer, available from Industrial Sensors Technologies (Edmonton, Canada). The K40 Analyzer measures gamma ray emissions from radioactive decay of potassium (K). However, K is only present in some oil sand clay (such as illite and mica) and is also present in other minerals (such as microcline). Therefore, the use of K as a clay signature may be less robust than the Al:Si ratio, as illustrated by comparing Fig. 3 (using K) to Fig. 2 (using Al:Si). Fig. 3 is a plot of clay fraction of mineral solids as measured by X-Ray Diffraction (XRD) against an estimate of K wt. % of the minerals. The K wt. % is estimated by assigning elemental compositions to XRD profiles. As with Fig. 2, the samples used were oil sand ore samples. As with Fig. 2, the samples excluded any samples having less than 40 wt. % quartz or more than 50 wt. % clay.
[0055] Figures 4 and 5 are similar to Figures 2 and 3 except that the samples were oil sand tailings samples rather than oil sand ore samples. As with Fig. 2, Fig. 4 illustrates that concentrations of minerals are not random, such that the Al:Si ratio can be used to approximate a clay fraction of mineral solids with a reasonable or useful degree of consistency and/or accuracy. The use of K as a clay signature may be less robust than the Al:Si ratio, as illustrated by comparing Fig. 5 (using K) to Fig. 4 (using Al:Si).
[0056] While Figures 2 to 5 are provided to illustrate the existence and strength of the correlation, the particular values of Figures 2 to 5 are specific to a particular ore and oil sand process, and are therefore not included. To use the invention, a data set should be created that is particular to an oil sand stream being processed.
[0057] By way of example only, where the oil sand stream is a bituminous feed, the ratio of aluminum to silicon in the bituminous feed may be between 0 and 0.33 and/or the clay fraction of mineral solids in the bituminous feed may be between 0 and 0.5.
[0054] One existing method for online clay measurement is the K40 Analyzer, available from Industrial Sensors Technologies (Edmonton, Canada). The K40 Analyzer measures gamma ray emissions from radioactive decay of potassium (K). However, K is only present in some oil sand clay (such as illite and mica) and is also present in other minerals (such as microcline). Therefore, the use of K as a clay signature may be less robust than the Al:Si ratio, as illustrated by comparing Fig. 3 (using K) to Fig. 2 (using Al:Si). Fig. 3 is a plot of clay fraction of mineral solids as measured by X-Ray Diffraction (XRD) against an estimate of K wt. % of the minerals. The K wt. % is estimated by assigning elemental compositions to XRD profiles. As with Fig. 2, the samples used were oil sand ore samples. As with Fig. 2, the samples excluded any samples having less than 40 wt. % quartz or more than 50 wt. % clay.
[0055] Figures 4 and 5 are similar to Figures 2 and 3 except that the samples were oil sand tailings samples rather than oil sand ore samples. As with Fig. 2, Fig. 4 illustrates that concentrations of minerals are not random, such that the Al:Si ratio can be used to approximate a clay fraction of mineral solids with a reasonable or useful degree of consistency and/or accuracy. The use of K as a clay signature may be less robust than the Al:Si ratio, as illustrated by comparing Fig. 5 (using K) to Fig. 4 (using Al:Si).
[0056] While Figures 2 to 5 are provided to illustrate the existence and strength of the correlation, the particular values of Figures 2 to 5 are specific to a particular ore and oil sand process, and are therefore not included. To use the invention, a data set should be created that is particular to an oil sand stream being processed.
[0057] By way of example only, where the oil sand stream is a bituminous feed, the ratio of aluminum to silicon in the bituminous feed may be between 0 and 0.33 and/or the clay fraction of mineral solids in the bituminous feed may be between 0 and 0.5.
- 12 -[0058] By way of example only, where the oil sand stream is a tailings stream, the ratio of aluminum to silicon in the tailings stream may be between 0 and 0.65, and/or the clay fraction of mineral solids in the tailings stream may be between 0 and 1.
[0059] The process adjustment may be any suitable process adjustment.
Various non limiting examples are provided below, separated by category.
[0060] In the category of ore and slurry preparation, the following are mentioned:
blending of ores from different parts of a mine, mass of water added to form a hydrotransport slurry, temperature of water to form a hydrotransport slurry, mass of caustic added to a slurry, and mass of another additive added to a slurry.
[0061] In the category of primary separation cell (PSC), the following are mentioned:
slurry dilution water rate and temperature added, PSC underwash flow rate and temperature, middlings withdrawal rate, middlings displacement rate (re-injecting flotation tailings into PSC), and additive injection rate into PSC.
[0062] In the category of tailings treatment, the following are mentioned: blending ratio of multiple tailings streams ahead of subsequent treatment, flocculant addition rate, addition rate of another chemical (e.g. a coagulant), thickener operating parameters (e.g.
feedwell dilution, rake speed, or residence time), in-line flocculant operating parameters (e.g.
dynamic mixer speed), and a decision about whether to by-pass tailings treatment process (if tailings materials are determined to be off-specification).
[0063] In the category of solvent based extraction, the following are mentioned:
blending ratio of ores from different parts of a mine, mass ratio of solvent mixed with ore, and mass of water added to a solvent ore slurry.
[0064] The process adjustment may be adjustment of polymer dosage, caustic dosage, or blending ratio with another oil sand stream. The process adjustment may be adjustment to achieve a sands to fines ratio (SFR) of a resultant tailings stream within a predetermined range. The process adjustment may be adjustment of a flocculant addition rate.
The process
[0059] The process adjustment may be any suitable process adjustment.
Various non limiting examples are provided below, separated by category.
[0060] In the category of ore and slurry preparation, the following are mentioned:
blending of ores from different parts of a mine, mass of water added to form a hydrotransport slurry, temperature of water to form a hydrotransport slurry, mass of caustic added to a slurry, and mass of another additive added to a slurry.
[0061] In the category of primary separation cell (PSC), the following are mentioned:
slurry dilution water rate and temperature added, PSC underwash flow rate and temperature, middlings withdrawal rate, middlings displacement rate (re-injecting flotation tailings into PSC), and additive injection rate into PSC.
[0062] In the category of tailings treatment, the following are mentioned: blending ratio of multiple tailings streams ahead of subsequent treatment, flocculant addition rate, addition rate of another chemical (e.g. a coagulant), thickener operating parameters (e.g.
feedwell dilution, rake speed, or residence time), in-line flocculant operating parameters (e.g.
dynamic mixer speed), and a decision about whether to by-pass tailings treatment process (if tailings materials are determined to be off-specification).
[0063] In the category of solvent based extraction, the following are mentioned:
blending ratio of ores from different parts of a mine, mass ratio of solvent mixed with ore, and mass of water added to a solvent ore slurry.
[0064] The process adjustment may be adjustment of polymer dosage, caustic dosage, or blending ratio with another oil sand stream. The process adjustment may be adjustment to achieve a sands to fines ratio (SFR) of a resultant tailings stream within a predetermined range. The process adjustment may be adjustment of a flocculant addition rate.
The process
- 13 -adjustment may be adjustment to achieve 0-44 um particle content of a hydrotransport slurry within a predetermined range. The process adjustment may be adjustment of a caustic dosage to a hydrotransport slurry based on reference data.
[0065] The ratio of aluminum to silicon may combined with an indication of density and/or flow rate of the oil sand stream to determine a direction and/or quantity of adjustment to be made to the parameter in the oil sand treatment process.
[0066] It should be understood that numerous changes, modifications, and alternatives to the preceding disclosure can be made without departing from the scope of the disclosure.
The preceding description, therefore, is not meant to limit the scope of the disclosure. Rather, the scope of the disclosure is to be determined only by the appended claims and their equivalents. It is also contemplated that structures and features in the present examples can be altered, rearranged, substituted, deleted, duplicated, combined, or added to each other.
[0065] The ratio of aluminum to silicon may combined with an indication of density and/or flow rate of the oil sand stream to determine a direction and/or quantity of adjustment to be made to the parameter in the oil sand treatment process.
[0066] It should be understood that numerous changes, modifications, and alternatives to the preceding disclosure can be made without departing from the scope of the disclosure.
The preceding description, therefore, is not meant to limit the scope of the disclosure. Rather, the scope of the disclosure is to be determined only by the appended claims and their equivalents. It is also contemplated that structures and features in the present examples can be altered, rearranged, substituted, deleted, duplicated, combined, or added to each other.
- 14 -
Claims (33)
1. A method of controlling an oil sand treatment process, the method comprising:
a) analyzing an oil sand stream of the oil sand treatment process to obtain a ratio of aluminum to silicon in the oil sand stream; and b) adjusting a parameter of the oil sand treatment process based on the ratio.
a) analyzing an oil sand stream of the oil sand treatment process to obtain a ratio of aluminum to silicon in the oil sand stream; and b) adjusting a parameter of the oil sand treatment process based on the ratio.
2. The method of claim 1, wherein the ratio is an elemental signal ratio, a molar ratio, or a weight ratio.
3. The method of claim 1, wherein step a) analyzes visible light, X-rays, or gamma rays.
4. The method of claim 1, wherein step a) uses LIBS (Laser-Induced Breakdown Spectroscopy), XRF (X-Ray Fluorescence), PGNAA (Prompt Gamma Neutron Activation Analysis), Inductively Coupled Plasma Atomic Emission Spectroscopy (ICP-AES), or Atomic Absorption (AA) to obtain the ratio.
5. The method of any one of claims 1 to 4, wherein step a) is effected online, inline, offline, or atline.
6. The method of any one of claims 1 to 5, further comprising approximating a clay fraction of mineral solids in the oil sand stream using the ratio and reference data.
7. The method of claim 6, wherein the clay fraction is on a weight basis.
8. The method of claim 6 or 7, wherein step b) is performed based on the clay fraction.
9. The method of claim 6 or 7, further comprising approximating a particle size parameter using the clay fraction and reference data.
10. The method of claim 9, wherein the particle size parameter is a fraction of particles falling within a predetermined size range.
11. The method of claim 10, wherein the predetermined size range is 0-44 microns.
12. The method of any one of claims 9 to 11, wherein step b) is performed based on the particle size parameter.
13. The method of any one of claims 1 to 5, further comprising approximating a total clay content in the oil sand stream using the ratio and a solids mass measurement of the oil sand stream.
14. The method of claim 13, wherein step b) is performed based on the total clay content in the oil sand stream.
15. The method of claim 6 or 7, further comprising approximating a methylene blue index (MBI) value using the clay fraction and reference data.
16. The method of claim 15, wherein step b) is performed based on the MBI.
17. The method of any one of claims 1 to 16, wherein step b) comprises adjustment of polymer dosage, caustic dosage, or blending ratio with another oil sand stream.
18. The method of any one of claims 1 to 16, wherein step b) comprises adjustment to achieve a sands to fines ratio (SFR) of a resultant tailings stream within a predetermined range.
19. The method of claim 14, wherein step b) comprises adjustment of a flocculant addition rate to the oil sand stream.
20. The method of any one of claims 1 to 16, wherein step b) comprises adjustment to achieve 0-44 micron particle content of a resultant hydrotransport slurry within a predetermined range.
21. The method of any one of claims 1 to 16, wherein step b) comprises adjustment of a caustic dosage to the oil sand treatment process based on reference data.
22. The method of any one of claims 1 to 21, wherein the oil sand stream comprises a bituminous feed, a bitumen froth, or a tailings stream.
23. The method of any one of claims 1 to 21, wherein the oil sand stream stems from aqueous based extraction.
24. The method of any one of claims 1 to 21, wherein the oil sand stream stems from solvent based extraction.
25. The method of any one of claims 1 to 21, wherein the oil sand stream comprises solvent diluted bitumen froth.
26. The method of any one of claims 1 to 21, wherein the oil sand stream comprises primary separation tailings, middlings, flotation tailings, froth separation tailings, tailings solvent recovery unit (TSRU) tailings, fluid fine tailings (FFT), mature fine tailings (MFT), thickened tailings, centrifuged tailings, hydrocycloned tailings, or a combination thereof.
27. The method of any one of claims 1 to 21, wherein the oil sand stream comprises oil sand ore, a hydrotransport slurry, or a solvent-ore slurry.
28. The method of any one of claims 1 to 21, wherein the oil sand treatment process comprises ore feed blending, primary bitumen conditioning and separation, bitumen froth treatment, or bitumen tailings treatment.
29. The method of any one of claims 1 to 21 and 28, wherein the oil sand stream is a bituminous feed and wherein the ratio of aluminum to silicon in the bituminous feed is between 0 and 0.33.
30. The method of any one of claims 1 to 21, 28, and 29, wherein the oil sand stream is a bituminous feed and wherein the clay fraction of mineral solids in the bituminous feed is between 0 and 0.5.
31. The method of any one of claims 1 to 21 and 28, wherein the oil sand stream is a tailings stream and wherein the ratio of aluminum to silicon in the tailings stream is between 0 and 0.65.
32. The method of any one of claims I to 21, 28, and 31, wherein the oil sand stream is a tailings stream and wherein the clay fraction of mineral solids in the tailings stream is between 0 and 1.
33. The method of claim 1, wherein the ratio of aluminum to silicon is combined with an indication of density and/or flow rate of the oil sand stream to determine a direction and/or quantity of adjustment to be made to the parameter in the oil sand treatment process.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA2899348A CA2899348C (en) | 2015-08-04 | 2015-08-04 | Processing oil sand streams |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA2899348A CA2899348C (en) | 2015-08-04 | 2015-08-04 | Processing oil sand streams |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CA2899348A1 CA2899348A1 (en) | 2015-10-02 |
| CA2899348C true CA2899348C (en) | 2016-06-14 |
Family
ID=54393207
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA2899348A Expired - Fee Related CA2899348C (en) | 2015-08-04 | 2015-08-04 | Processing oil sand streams |
Country Status (1)
| Country | Link |
|---|---|
| CA (1) | CA2899348C (en) |
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US11186780B1 (en) | 2020-05-05 | 2021-11-30 | Syncrude Canada Ltd. In Trust For The Owners Of The Synerude Project As Such Owners Exist Now And In | Methods for processing oil sands containing swelling clays |
Families Citing this family (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US20210278390A1 (en) * | 2016-10-31 | 2021-09-09 | Dow Global Technologies Llc | Online analysis of oil sands tailings content |
| US10371633B2 (en) | 2017-10-30 | 2019-08-06 | Saudi Arabian Oil Company | Determining a specific gravity of a sample |
| US10712330B2 (en) * | 2018-07-25 | 2020-07-14 | Syncrude Canada Ltd. | Controlling bitumen recovery from an oil sands ore body by using a predictive ore processability model in producing a blended ore feedstock |
| DE102019109051A1 (en) * | 2019-04-05 | 2020-10-08 | Rwe Power Ag | Devices and methods for determining an elemental composition of a material |
| US11662288B2 (en) | 2020-09-24 | 2023-05-30 | Saudi Arabian Oil Company | Method for measuring API gravity of petroleum crude oils using angle-resolved fluorescence spectra |
-
2015
- 2015-08-04 CA CA2899348A patent/CA2899348C/en not_active Expired - Fee Related
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US11186780B1 (en) | 2020-05-05 | 2021-11-30 | Syncrude Canada Ltd. In Trust For The Owners Of The Synerude Project As Such Owners Exist Now And In | Methods for processing oil sands containing swelling clays |
Also Published As
| Publication number | Publication date |
|---|---|
| CA2899348A1 (en) | 2015-10-02 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CA2899348C (en) | Processing oil sand streams | |
| CA2909029C (en) | A method for controlling an oil sand tailings treatment | |
| CA2714842C (en) | Controlling bitumen quality in solvent-assisted bitumen extraction | |
| CA2952035C (en) | Method of controlling a water-based oil sand extraction process | |
| CA2940007A1 (en) | Processing oil sand streams | |
| CA2952398C (en) | Analyzing oil sand streams | |
| CA3022709C (en) | Analyzing bitumen containing streams | |
| CA3055368C (en) | Method of measuring a slurry using a non-representative sample | |
| US20210278390A1 (en) | Online analysis of oil sands tailings content | |
| CA2915562C (en) | Method of analyzing an oil sand stream | |
| CA3047870C (en) | Supplementary chemical additive dosage optimization for bitumen recovery | |
| CA2973311C (en) | Method of measuring a slurry feed for a solid-liquid separation process | |
| CA3131999C (en) | Measurement in a vessel comprising bitumen via ir camera | |
| CA3010076C (en) | Bitumen extraction using a process aid | |
| CA2967868C (en) | Optimized bitumen recovery and process aid dosage via water chemistry feedback control | |
| CA3184361A1 (en) | Separation of warm water from froth tailings | |
| CA2974554C (en) | Use of a polysaccharide to assist fines capture in oil sand tailings | |
| CA2965582C (en) | Water-based oil sand extraction using overwash | |
| CA3067314C (en) | Shearing and sparging of bitumen froth treatment tailings | |
| CA2928380C (en) | Paraffinic froth treatment | |
| CA2942996C (en) | Process for recovering solvent from oil sand tailings streams | |
| CA2916601C (en) | Agglomeration process for solvent-based oil sand slurry | |
| CA3133719A1 (en) | High velocity steam injection in hydrocarbon containing streams | |
| CA2933892A1 (en) | Processing of oil sand streams via chemically-induced micro-agglomeration |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| MKLA | Lapsed |
Effective date: 20210804 |