Patent Grant
8481796
This invention relates to compositions useful as fuels, such as jet fuel and diesel fuel, and hydrocarbon fluids, such as solvents or lubricants, and an olefin oligomerization process for producing such compositions.
Improved hydrocarbon compositions are needed to help meet the growing demand for middle distillate products, such as aviation turbine fuels, for example, JP-8 and diesel fuel. Diesel fuel generally provides a higher energy efficiency in compression ignition engines than automotive gasoline provides in spark combustion engines, and has a higher rate of demand growth than automotive gasoline, especially outside the U.S. Further, improved fuel compositions are needed to meet the stringent quality specifications for aviation fuel and the ever tightening quality specifications for diesel fuel as established by industry requirements and governmental regulations.
One known route for producing hydrocarbon compositions useful as fuels is the oligomerization of olefins over various molecular sieve catalysts. Exemplary patents relating to olefin oligomerization include U.S. Pat. Nos. 4,444,988; 4,456,781; 4,504,693; 4,547,612 and 4,879,428. In these disclosures, feedstock olefins are mixed with an olefinic recycle material and contacted with a zeolite, particularly in a series of fixed bed reactors. The oligomerized reaction product is then separated to provide a distillate stream, and typically a gasoline stream, and any number of olefinic recycle streams.
However, in these known oligomerization processes, the focus is on producing relatively heavy distillate products, and even lube base stocks. To enable the production of relatively heavy materials, the processes employ, either directly or indirectly, a relatively large amount of olefinic recycle containing significant quantities of C10+ material. The relatively large recycle rate provides control over the exotherm of the oligomerization reaction in the preferred fixed bed, adiabatic reactor system, while the relatively heavy recycle composition enables the growth of heavier oligomers and thus higher molecular weight and denser distillate product. A high rate of recycle requires much larger equipment to handle the increased volumetric flow rate, and uses more separation/fractionation energy, and hence more and larger associated energy conservation elements. Further, a high molecular weight oligomer product requires very high temperatures for the fractionation tower bottoms streams that may eliminate the use of simple steam reboilers and require more expensive and complicated fired heaters.
The recycle streams in conventional olefin oligomerization processes are produced in a variety of fashions typically including some sort of single stage flash drum providing a very crude separation of reactor product as a means of providing some of the relatively heavy components, followed by various fractionation schemes which may or may not provide sharper separations, and again often provide heavy components as recycle. The dense distillate product is generally characterized by a relatively high specific gravity (in excess of 0.775) and a high viscosity, in part due to the composition comprising relatively high levels of aromatics and naphthenes.
Very few references discuss both the merits and methods of producing lighter distillate products, typified by such as jet fuel, kerosene and No. 1 Diesel, via the oligomerization of C3 to C8 olefins. Jet/kero is generally overlooked as a particularly useful middle distillate product, inasmuch as the volume consumed in the marketplace is considerably smaller than its heavier cousins, No. 2 Diesel and No. 4 Diesel (fuel oil). However, jet/kero is a high volume commercial product in its own right, and is also typically suitable as a particular light grade of diesel, called No. 1 Diesel, that is especially useful in colder climates given its tendency to remain liquid and sustain volatility at much lower temperatures. In addition, jet/kero type streams are often blended in with other stocks to produce No. 2 Diesel, both to modify the diesel fuel characteristics, and to allow introduction of otherwise less valuable blendstocks into the final higher value product.
U.S. Pat. No. 4,720,600 discloses an oligomerization process for converting lower olefins to distillate hydrocarbons, especially useful as high quality jet or diesel fuels, wherein an olefinic feedstock is reacted over a shape selective acid zeolite, such as ZSM-5, to oligomerize feedstock olefins and further convert recycled hydrocarbons. The reactor effluent is fractionated to recover a light-middle distillate range product stream and to obtain light and heavy hydrocarbon streams for recycle. The middle distillate product has a boiling range of about 165° C. to 290° C. and contains substantially linear C9 to C16 mono-olefinic hydrocarbons, whereas the major portion of the C6 to C8 hydrocarbon components are contained in the lower boiling recycle stream, and the major portion (e.g., 50 wt % to more than 90 wt %) of the C16+ hydrocarbon components are contained in the heavy recycle fraction.
Isoparaffinic hydrocarbon fluid compositions in various boiling ranges and having a number of other characteristic properties are also of interest, and are subject to the same increasing quality requirements as fuels noted above, particularly in terms of environmental and hygienic performance. A typical isoparaffinic fluid manufacturing method includes oligomerization of propylene or butene feeds to form higher olefins, followed by hydrogenation, and, optionally fractionation before or after hydrogenation. The chemical properties (f. ex. carbon number, branching level, biodegradability) and physical properties and volumes of isoparaffinic fluids obtained by this method are determined by types of feedstocks available for oligomerization. Hence it is desirable to find other manufacturing methods that allow to increase production volumes and can lead to different types of isoparaffinic hydrocarbons.
The present invention provides a novel process well suited to the production of new isoparaffinic hydrocarbon fluid compositions. While this process is primarily aimed at the production of high quality jet fuel, the process has many advantageous attributes relative to the historical processes from which hydrocarbon fluids were derived. For example, in making a wide boiling range fuel, vis-a-vis the solid phosphoric acid process for light carbon number motor gasoline production, or the butene dimerization process over zeolites for eventual oxo-alcohol production, which are focused on a narrow product series, the process of the present invention has a greater flexibility to handle a wide array of olefin feedstocks, and greater flexibility to vary the product carbon number distribution through control of the olefinic recycle rate and composition. Further, the process of the present invention can make a unique isoparaffinic hydrocarbon fluid composition having a very low content of naphthenes and aromatics, particularly in combination with relatively high boiling points, which has been a significant challenge to the industry.
One embodiment of the present invention is a hydrocarbon fluid composition that has species of at least 3 different carbon numbers; at least 95 wt % non-normal hydrocarbons; no greater than 1000 wppm aromatics; and no greater than 10 wt % naphthenes, wherein said hydrocarbon fluid composition has a minimum initial boiling point to maximum final boiling point range at or within 185° C. to 350° C.
Another embodiment of the present invention is a hydrocarbon fluid composition comprising species of at least 3 different carbon numbers; at least 95 wt % non-normal hydrocarbons; no greater than 1000 wppm aromatics; and no greater than 10 wt % naphthenes, wherein said hydrocarbon fluid composition has an initial boiling point in the range of from about 185° C. to about 265° C. and a final boiling point in the range of from about 210° C. to about 350° C.
Another embodiment of the present invention is a hydrocarbon fluid composition comprising species of at least 3 different carbon numbers; at least 95 wt % non-normal hydrocarbons; no greater than 1000 wppm aromatics; and less than 4 wt % naphthenes, wherein said hydrocarbon fluid composition has a minimum initial boiling point to maximum final boiling point at or within the range of 170° C. to 350° C.
Another embodiment of the present invention is a hydrocarbon fluid composition comprising species of at least 3 different carbon numbers; at least 95 wt % non-normal hydrocarbons; no greater than 1000 wppm aromatics; and less than 4 wt % naphthenes, wherein said hydrocarbon fluid composition has an initial boiling point in the range of from about 170° C. to about 265° C. and a final boiling point in the range of from about 190° C. to about 350° C.
In further embodiments, in addition to the limitations of any one of the above embodiments, the hydrocarbon fluid composition further comprises substantially no sulfur.
In further embodiments, in addition to the limitations of any one of the above embodiments, the hydrocarbon fluid composition has a Bromine Index of less than 100 mg Br/100 g sample.
In further embodiments, in addition to the limitations of any one of the above embodiments, the hydrocarbon fluid composition exhibits a passing result on either the Hot Acid Test and the ASTM Test Method D565, preferably both.
Another aspect of the present invention is a process to produce the above hydrocarbon fluid composition of the present invention, as well as middle distillate fuel products. The process comprises: (a) contacting a feed stream comprising at least one C3 to C8 olefin and an olefinic recycle stream with a molecular sieve catalyst in at least one reaction zone under olefin oligomerization conditions such that the recycle to feed weight ratio is about 0.1 to about 3.0, the WHSV is at least 1.0 based on the olefin in the feed stream, and the difference between the highest and lowest temperatures within the at least one reaction zone is 40° F. (22° C.) or less, the contacting producing an oligomerization effluent stream; (b) separating the oligomerization effluent stream into at least a hydrocarbon product stream having a first difference in initial boiling point and final boiling point and the olefinic recycle stream of (a), wherein the olefinic recycle stream contains no more than 10 wt % of C10+ non-normal olefins, and the hydrocarbon product stream contains at least 1 wt % and no more than 30 wt % of C9 non-normal olefins; (c) forming the hydrocarbon fluid composition by either (i) separating the hydrocarbon product stream to form at least a first and a remainder separated hydrocarbon product stream, then hydrogenating the first separated hydrocarbon product stream to form the hydrocarbon fluid composition or (ii) hydrogenating the hydrocarbon product stream to form a hydrogenated hydrocarbon product stream, then separating the hydrogenated hydrocarbon product stream to form the hydrocarbon fluid composition, or. The resulting hydrocarbon fluid composition has a second difference in initial boiling point and final boiling point that is less than the first difference.
Any two of the above embodiments can be combined to describe additional embodiments of the invention of this patent application.
Terms and Measurements
As used herein, the term “Cx hydrocarbon” indicates hydrocarbon molecules having the number of carbon atoms represented by the subscript “x”. The term “Cx+ hydrocarbons” indicates those molecules noted above having the number of carbon atoms represented by the subscript “x” or greater. For example, “C10+ hydrocarbons” would include C10, C11 and higher carbon number hydrocarbons. Similarly “Cx− hydrocarbons” indicates those molecules noted above having the number of carbon atoms represented by the subscript “x” or fewer.
Unless otherwise specifically noted, Weight Hourly Space Velocity (WHSV) values cited herein are based on the amount of the molecular sieve contained in the olefin oligomerization catalysts without allowing for any binder or matrix that may also be present in the catalyst.
The initial boiling point and final boiling point of the hydrocarbon fluid composition is determined by ASTM D86-05, the entire contents of which are incorporated herein by reference. The final boiling point according to this method is also known as the dry point. Herein, the listing of a “minimum initial boiling point to maximum final boiling point range at or within” a prescribed pair of temperature figures means that the initial boiling point will have a value no less than the first FIGURE listed in the pair, and the final boiling point will have a value no greater than the second number listed in the pair. Further, the final boiling point will always be a greater temperature than the initial boiling point. Thus, for example, the hydrocarbon fluid could have an initial boiling point of 190° C. and a final boiling point of 340° C., and would fulfill the stipulation of a minimum initial boiling point to maximum final boiling point range at or within 185 to 350° C. 100241 The term “difference in initial boiling point and final boiling point” used herein is the numerical difference of the initial boiling point subtracted from the final boiling point, i.e., the absolute value of the difference of the figures in the boiling point range of a given material (e.g., a boiling point range 170 to 350° C. would have a difference in initial boiling point and final boiling point of 180° C.).
The determination of the identity and content of hydrocarbon species can be accomplished by a number of suitable methods well known to those skilled in the art, such as combined gas chromatograph/mass spectroscopy (GC/MS), Nuclear Magnetic Resonance (NMR) and Infrared Spectroscopy (IR) techniques, potentially in combination. A straightforward method that can be used for a determination of the hydrocarbon fluid properties noted herein is the normal paraffin (or linear paraffin) gas chromatograph method. That is, for an appropriate gas chromatograph with a separation column of adequate resolution, a normal paraffin of a given carbon number is assumed to delineate a peak, above which, species may be assumed to comprise the carbon number of the next higher carbon number normal paraffin peak. For example, all peaks for material eluting in between the peaks for n-decane and n-undecane are assumed to be C11 species. Similarly for this method, the quantity of non-normal hydrocarbons is determined as the total peak area of the chromatogram less the sum of the normal paraffins. NMR and IR techniques on narrow boiling range aliquots derived from a broader boiling range sample are also useful to determine non-normal hydrocarbon concentration and type. Any method of reasonable resolution will provide similar results to distinguish a hydrocarbon fluid of the present invention, although perhaps at slightly different absolute values depending on its sophistication and calibration standards.
The term “carbon number” as used herein refers to the number of carbon atoms in a species. For example, a composition having a species with 3 different carbon numbers may mean a complex mixture of C5 species, C9 species, and C12 species.
The analytical determination of naphthene content has historically been quite difficult due to the relatively close nature of that specie to isoparaffins. Naphthene content may be determined via methods such as GC/MS, such as ASTM Test Method D2475 and ASTM Test Method D2786, the MS being necessary to differentiate the naphthenes from the olefins and saturates via their atomic fracture patterns, or NMR or IR spectroscopy measurements. Preferably, the content of naphthenes may also be determined (or validated) via knowledge of the properties of various specific components, there typically being a very limited number of different species in such compositions. Each species (e.g., normal paraffins, iso-paraffins and naphthenes) have distinct density and refractive index properties that may be correlated to determine the blend quantities. It may be desirable to understand other properties of the composition first by other methods, for example, the amount of aromatics and isoparaffins, to ensure the reliability of such a technique. Another excellent method to employ in the method of the present invention for the determination of naphthene content is a hybrid GC method such as 2-D GC (some details of which may be found at http://www.srigc.com/2003catalog/cat-21.htm), which provides greater resolution of naphthenic species relative to normal and iso-paraffinic species than conventional GC.
The content of aromatics is to be determined by a suitable ultraviolet spectraphotometric method. Any method of reasonable resolution, well known to those skilled in the art, will provide the same results within about +/−20%, with the difference attributable to the type of aromatics and substrate used for calibration of a given method. One straightforward method that can be used for a determination of the content of aromatics of a hydrocarbon fluid noted herein is France NF M 07-073, “Determination of Total Aromatics Content in Heating Fuels and Other Mainly Saturated Hydrocarbons,” the entire contents of which are incorporated herein by reference.
Bromine Index is determined by ASTM Test Method D2710 with units of mg Br/100 g sample, the entire contents of which are incorporated herein by reference.
The determination of refractive index is by ASTM Test Method D1218, in reference to water with a refractive index of 1.33299 at 20° C.
The term “normal olefin” or “normal paraffin” (both being examples of “normal hydrocarbons”) refers to any olefin or paraffin that contains a single, unbranched chain of carbon atoms as defined in Hawley's Condensed Chemical Dictionary, 14th Edition. Therefore a “non-normal olefin” or “non-normal paraffin” as used herein, is hydrocarbon that is not “normal” and would, therefore, contain at least one branched chain of carbon atoms. Naphthenes are cyclo-paraffins or cyclo-olefins that may contain an additional alkyl group or groups, and are considered non-normal hydrocarbons. Similarly, an aromatic is as defined in Hawley's Condensed Chemical Dictionary, 14th Edition. In general, an aromatic comprises at least one 6 carbon number ring moiety with three double bonds in the ring, which may have additional alkyl group substituents.
Oligomerization Feed
The fresh feed to the oligomerization process can include any single C3 to C8 olefin or any mixture thereof in any proportion. Particularly suitable feeds include mixtures of propylene and butylenes having at least 5 wt %, such as at least 10 wt %, for example, at least 20 wt %, such as at least 30 wt % or at least 40 wt % C4 olefin. Also useful are mixtures of C3 to C5 olefins having at least 40 wt % C4 olefin and at least 10 wt % C5 olefin, or at least 30 wt % C4 olefin and at least 20 wt % C5 olefin, or at or at least 40 wt % C4 olefin and at least 10 wt % C5 olefin.
Conveniently, the feed should contain no more than about 1.0 wt %, or even no more than 0.1 wt % of C2− hydrocarbons, because ethylene is less reactive in the present process than other light olefin, and thus requires substantially more processing to obtain a good ultimate conversion. Further, ethylene and light saturates, such as ethane and methane, are highly volatile, and it will require much more work to recover them in the separation system, likely necessitating the use of expensive and complicated refrigeration systems. It is also of benefit to limit the amount of C9+ hydrocarbons, of any kind, in the feed, to no more than about 10 wt %, or no more than 5 wt %, or even no more than 1 wt %, because C9+ hydrocarbons are useful components of the hydrocarbon product stream and so it is counter-productive to subject them to the oligomerization process of the invention.
It is also desirable to limit the amount of saturates in the feed stream, because saturates are not converted in the oligomerization step and tend to accumulate in the olefinic recycle stream, thereby reducing the light olefin content of the olefinic recycle stream. The amount of non-olefins, especially saturates, in the feed stream should be less than 45 wt %, such as less than 35 wt %, for example less than 25 wt %, typically less than 15 wt %, or less than 10 wt % or even less than 5 wt %. More particularly, the amount of non-olefins, especially saturates in the feed stream should be from about 5 wt % to about 45 wt %, from about 10 wt % to about 35 wt %, from about 15 wt % to about 25 wt %. More particularly, the amount of propane can be no greater than about 10 wt %, such as no more than 5 wt %, for example, no more than 1 wt %, or no more than 0.5 wt %. Even more particularly, the amount of propane can be no greater than about 0.5 wt % to about 10 wt % or about 1 wt % to about 5 wt %.
In one embodiment, the olefinic feed is obtained by the conversion of an oxygenate, such as methanol, to olefins over a silicoaluminophosphate (SAPO) catalyst, according to the method of, for example, U.S. Pat. No. 4,677,243 and 6,673,978; or an aluminosilicate catalyst, according to the method of, for example, W004/18089; W004/16572; EP 0 882 692; and U.S. Pat. No. 4,025,575. Alternatively, the olefinic feed can be obtained by the catalytic cracking of relatively heavy petroleum fractions, or by the pyrolysis of various hydrocarbon streams, ranging from ethane to naphtha to heavy fuel oils, in admixture with steam, in a well understood process known as “steam cracking”.
As stated above, the overall feed to the oligomerization process also contains an olefinic recycle stream containing no more than 10 wt % of C10+ non-normal olefins. Generally, the olefinic recycle stream should contain no greater than 7.0 wt %, for example no greater than 5.0 wt %, such as no greater than 2.0 wt %, or no greater than 1.0 wt %, or even no greater than 0.1 wt % of C10+ non-normal olefins. The olefinic recycle stream may contain from about 0.1 wt % to about 10.0 wt %, or about 0.5 wt % to about 10.0 wt %, or about 1.0 wt % to about 7.0 wt % of C10+ non-normal olefins. Alternatively, the final boiling point temperature of the olefinic recycle stream should be no greater than 360° F. (182° C.), no greater than 340° F. (171° C.), such as no greater than 320° F. (160° C.), for example no greater than 310° F. (154° C.), or even no greater than 305° F. (152° C.). The final boiling point temperature of the olefinic recycle stream should be in the range of from 300° F. (149° C.) to 360° F. (182° C.), from 305° F. (152° C.) to 340° F. (171° C.), or from 310° F. (154° C.) to 320° F. (160° C.).
In one embodiment, the olefinic recycle stream contains no greater than 30.0 wt %, such as, no greater than 25.0 wt %, for example no greater than 20.0 wt %, or no greater than 15.0 wt %, or no greater than 10.0 wt % of C9+ non-normal olefins. The olefinic recycle stream may contain from about 5.0 wt % to about 30.0 wt %, or from about 10 wt % to about 25 wt %, or from about 15 wt % to about 20 wt % of C9+ non-normal olefins. Alternatively, the final boiling point temperature of the olefinic recycle stream can be no greater than 290° F. (143° C.), such as no greater than 275° F. (135° C.), for example, no greater than 260° F. (127° C.). The final boiling point temperature of the olefinic recycle stream can be in the range of from 260° F. (127° C.) to 310° F. (154° C.) or from 275° F. (135° C.) to 290° F. (143° C.).
In one embodiment, the olefinic recycle stream can contain at least 1 wt %, at least 5 wt %, at least 10 wt %, at least 15 wt %, or at least 20 wt % C4 hydrocarbons of any species. In one embodiment, the olefinic recycle stream contains no greater than 50 wt %, no greater than 40 wt %, no greater than 30 wt %, or no greater than 25 wt %, or no greater than 20 wt %, or no greater than 10 wt %, or no greater than 5 wt % C4 hydrocarbons of any species. The olefinic recycle stream can contain from about 1 wt % to about 50 wt %, or from about 5 wt % to about 40 wt %, or from about 10 wt % to about 30 wt %, or from about 20 wt % to about 25 wt % C4 hydrocarbons of any species. Additionally, the olefinic recycle stream may contain no greater than 20 wt %, no greater than 10 wt %, no greater than 5 wt %, or no greater than 2 wt % C3− hydrocarbons, such as propylene or propane. The olefinic recycle stream may contain from about 0.1 wt % to about 20 wt %, or from about 0.5 wt % to about 10 wt %, or from about 1.0 wt % to about 5 wt %, or from about 1.5 wt % to about 2 wt % C3− hydrocarbons, such as propylene or propane. This can be achieved by, for example, employing an additional separation of all or a portion of the olefinic recycle stream generated by a separation device into one stream comprising C4− with only a small amount of C5+ hydrocarbons, and a second debutanized stream as all or a portion of the olefinic recycle stream provided to the oligomerization reactor.
In one embodiment, the olefinic recycle stream contains no more than about 7.0 wt % of C10+ non-normal olefins, for example, no greater than about 5.0 wt %, such as no greater than about 2.0 wt %, or no greater than about 1.0 wt %, or even no greater than about 0.1 wt % of C9+ non-normal olefins. The olefinic recycle stream should contain from about 0.1 wt % to about 10.0 wt %, or about 0.5 wt % to about 10.0 wt %, or about 1.0 wt % to about 7.0 wt % of C9+ non-normal olefins.
Alternatively, the final boiling point temperature of the olefinic recycle stream should be no greater than about 295° F. (146° C.), no greater than about 275° F. (135° C.), such as no greater than about 265° F. (129° C.), or for example no greater than about 260° F. (127° C.). The final boiling point temperature of the olefinic recycle stream should be in the range of from about 260° F. (127° C.) to about 295° F. (146° C.), or from about 265° F. (129° C.) to about 275° F. (135° C.). Additionally, the inital boiling point temperature of the olefinic recycle stream should be at least about 215° F. (102° C.), such as at least about 235° F. (113° C.), for example, at least about 255° F. (124° C.), for example, at least about 275° F. (135° C.), or for example, at least about 295° F. (146° C.). The initial boiling point temperature of the olefinic recycle stream should be in the range of from about 215° F. (102° C.) to about 295° F. (146° C.), from about 235° F. (113° C.) to about 275° F. (135° C.), or from about 240° F. (116° C.) to about 255° F. (124° C.).
In one embodiment, the olefinic recycle stream contains no greater than about 60 wt %, or no greater than about 50 wt %, including no greater than about 40 wt %, or no greater than about 30.0 wt %, such as no greater than about 25.0 wt %, for example, no greater than about 20.0 wt %, or no greater than about 15.0 wt %, or no greater than about 10.0 wt % of C8+ non-normal olefins. The olefinic recycle stream may contain from about 5.0 wt % to about 30.0 wt %, or from about 10 wt % to about 25 wt %, or from about 15 wt % to about 20 wt % of C8+ non-normal olefins.
Alternatively, the final boiling point temperature of the olefinic recycle stream should be no greater than about 245° F. (118° C.), such as no greater than about 230° F. (110° C.), or for example, no greater than about 215° F. (102° C.). The initial boiling point temperature of the olefinic recycle stream should be in the range of from about 215° F. (102° C.) to about 245° F. (118° C.), or from about 220° F. (104° C.) to about 230° F. (110° C.).
The amount of olefinic recycle stream fed to the oligomerization process is such that said olefinic recycle stream to fresh feed stream weight ratio is from about 0.1 to about 3.0, alternatively from about 0.5 to about 2.0, alternatively from about 0.5 to about 1.3. More particularly, the weight ratio of olefinic recycle stream to fresh olefinic feedstock can be at least 0.1, or at least 0.3, or at least 0.5, or at least 0.7 or at least 0.9, but generally is no greater than 3.0, or no greater than 2.5, or no greater than 2.0, or no greater than 1.8, or no greater than 1.5 or no greater than 1.3. The weight ratio of olefinic recycle stream to fresh olefinic feedstock can be from about 0.1 to about 3.0, or from about 0.3 to about 2.5, or from about 0.5 to about 2.0, or from about 0.7 to about 1.8, or from about 0.9 to about 1.5, or from about 1.0 to about 1.3.
The feed stream containing at least one C3 to C8 olefin derived from the conversion of an oxygenate has a particular advantage in the present invention in that it can provide an olefinic feed with substantially no sulfur as can be detected by any reasonable analysis. This lack of sulfur improves the efficacy of the subsequent hydrogenation step, particularly on noble metal catalysts, such as, but not limited to, palladium and platinum, to provide a fluid product with substantially no aromatics.
Oligomerization Process
The oligomerization process of the invention comprises contacting the C3 to C8 olefin feed and the olefinic recycle stream with a molecular sieve catalyst under conditions such that the olefins are oligomerized to produce a hydrocarbon composition conveniently comprising at least 90 wt % of C9 to C20 non-normal olefin, non-normal saturates or combinations thereof. Typically the hydrocarbon composition comprises less than 15 wt % of C17+ non-normal olefins, and generally less than 15 wt % of C17+ hydrocarbons.
The catalyst used in the oligomerization process can include any crystalline molecular sieve which is active in olefin oligomerization reactions. In one embodiment, the catalyst includes a medium pore size molecular sieve having a Constraint Index of about 1 to about 12. Constraint Index and a method of its determination are described in U.S. Pat. No. 4,016,218, which is incorporated herein by reference. Examples of suitable medium pore size molecular sieves are those having 10-membered ring pore openings and include those of the TON framework type (for example, ZSM-22, ISI-1, Theta-1, Nu-10, and KZ-2), those of the MTT framework type (for example, ZSM-23 and KZ-1), of the MFI structure type (for example, ZSM-5), of the MFS framework type (for example, ZSM-57), of the MEL framework type (for example, ZSM-11), of the MTW framework type (for example, ZSM-12), of the EUO framework type (for example, EU-1) and members of the ferrierite family (for example, ZSM-35).
Other examples of suitable molecular sieves include those having 12-membered pore openings, such as ZSM-18, zeolite beta, faujasites, zeolite L, mordenites, as well as members of the MCM-22 family of molecular sieves (including, for example, MCM-22, PSH-3, SSZ-25, ERB-1, ITQ-1, ITQ-2, MCM-36, MCM-49 and MCM-56). Other 10- and 12-member pore ring structure aluminosilicates and their SAPO analogs will also function.
In one embodiment, the molecular sieve catalyst comprises ZSM-5 having a homogeneous crystal size of <0.05 micron and a relatively high activity (alumina content) characterized by a SiO2/Al2O3 molar ratio of around 50:1.
The crystalline molecular sieve catalyst has an average crystal size no greater than 0.15, or 0.12, or 0.10, or 0.07 or 0.05 micron and an alpha value between about 100 and about 600, or between about 200 and about 400, or between about 250 and about 350.
The molecular sieve may be supported or unsupported, for example, in powder form, or used as an extrudate with an appropriate binder. Where a binder is employed, the binder is conveniently a metal oxide, such as alumina, and is present in an amount such that the oligomerization catalyst contains between about 2 and about 80 wt % of the molecular sieve.
The oligomerization reaction should be conducted at sufficiently high WHSV of fresh feed to the reactor to ensure the desired low level of C17+ oligomers in the reaction product. In general, the reaction should occur at a WHSV of no less than 1.0, or no less than 1.5, or no less than 1.7, or no less than 2.0, or no less than 2.2, or no less than 2.5, or no less than 2.8, or no less than 3.0, or no less than 3.5, or no less than 4.0, or no less than 4.5, or no less than 5.0, or no less than 5.5, or no less than 6.0 based on olefin in the fresh feed to the reactor and the amount of molecular sieve in the oligomerization catalyst. With regard to the combined fresh olefin feed and recycle to the reactor, the WHSV should be no less than about 1.2, or no less than about 1.5, or no less than about 1.7, or no less than about 2.0, or no less than about 2.2, or no less than about 2.5, or no less than about 3.0, or no less than 4.0, or no less than about 5.0, or no less than 6.0, or no less than about 7.0, or no less than 8.0 again based on the amount of molecular sieve in the oligomerization catalyst.
The upper level of WHSV is not narrowly defined but is generally no more than about 9.0, or no more than about 8.0 or no more than about 7.0 based on olefin in the fresh feed to the reactor and the amount of molecular sieve in the oligomerization catalyst. Increasing the WHSV beyond these levels may significantly decrease the catalyst/reactor cycle length between regenerations, especially at higher levels of C4 conversion. For the same reason, the WHSV for the combined fresh olefin feed and recycle to the reactor should be no more than about 14, or no more than about 12 or no more than about 11 based on the amount of molecular sieve in the oligomerization catalyst.
In other embodiments of the process of the present invention, the contacting (a) is conducted at a WHSV of about 1.0 to about 9.0, or from about 1.5 to about 9.0, or about 1.7 to about 9.0, or about 2.0 to about 9.0, or about 1.0 to about 8.0, or from about 1.5 to about 8.0, or about 2.0 to about 8.0, or from about 1.0 to about 7.0, or from about 1.0 to about 6.0, or from about 1.5 to about 6.0, or from about 1.0 to about 5.0, or from about 1.5 to about 5.0 based on the olefin in the feed, and/or a WHSV of about 1.2 to about 14, or about 1.5 to about 14, or about 1.7 to about 14, or about 2.0 to about 14, or about 2.2 to about 14, or from about 1.2 to about 12, or from about 2.0 to about 12, or from about 2.5 to about 12, or from about 2.0 to about 9.0 based on the olefin in the combined feed and olefinic recycle streams.
The oligomerization process can be conducted over a wide range of temperatures, although generally the highest and lowest temperatures within the oligomerization reaction zone should be between about 150° C. and about 350° C., such as between about 180° C. and about 330° C., or for example between about
It is, however, important to ensure that the temperature across the reaction zone is maintained relatively constant so as to produce the desired level of C4 olefin conversion at a given WHSV and point in the reaction cycle, and to minimize the production (yield) of undesirable butane and lighter saturates from the oligomerization reaction (contacting). Thus, as discussed above, the difference between the highest and lowest temperatures within the reactor should be maintained at about 40° F. (22° C.) or less, such as about 30° F. (17° C.) or less, for example, about 20° F. (11° C.) or less, conveniently about 10° F. (6° C.) or less, or even about 5° F. (3° C.) or less. The difference between the highest and lowest temperatures within the reactor should be maintained from about 1° F. (0.6° C.) to about 40° F. (22° C.), or from about 5° F. (3° C.) to about 30° F. (17° C.), or from about 10° F. (6° C.) to about 20° F. (11° C.).
The oligomerization process can be conducted over a wide range of olefin partial pressures, although higher olefin partial pressures are preferred since low pressures tend to promote cyclization and cracking reactions, and are thermodynamically less favorable to the preferred oligomerization reaction. Typical olefin partial pressures of olefins in the combined feed stream and olefinic recycle stream as total charge to the reactor comprise at least about 400 psig (2860 kPa), such as at least about 500 psig (3550 kPa), for example, at least about 600 psig (4240 kPa), or at least about 700 psig (4930 kPa), or at least about 800 psig (5620 kPa), or even about 900 psig (6310 kPa). Typical olefin partial pressures of olefins in the combined feed stream and olefinic recycle stream as total charge to the reactor are in the range of from about 400 psig (2860 kPa) to about 2000 psig (13,782 kPa), or from about 500 psig (3550 kPa) to about 1500 psig (10,337 kPa), or from about 600 psig (4240 kPa) to about 1200 psig (8269 kPa). It will, of course, be appreciated that the olefin partial pressure will be lower at the exit to the reactor as fewer moles of olefins exist due to the oligomerization reaction.
Typically, the conditions of the oligomerization process are controlled so as ensure that the conversion of C4 olefins in the feed stream is at least about 80 wt %, or at least about 85 wt %, or at least about 90 wt %, or at least about 92 wt %, but no greater than about 99%, or no greater than about 98 wt %, or no greater than about 96 wt %, or no greater than about 94 wt %. The conditions of the oligomerization process are controlled so as to ensure that the conversion of C4 olefins in the feed stream is in the range of from about 80 wt % to about 99 wt %, or from about 85 wt % to about 98 wt %, or from about 90 wt % to about 96 wt %, or from about 92 wt % to about 94 wt %. During the course of the oligomerization process, the catalyst will lose activity due to the accumulation of carbonaceous deposits and hence the C4 olefin conversion will tend to decline with time. Thus to sustain a given level of C4 olefin conversion, the temperature at which the oligomerization reaction is conducted is continually raised until some limit, discussed above, is reached. At that point, the catalyst is generally regenerated, either in situ or ex situ, by combustion of the coke deposits with oxygen/air using methods and conditions that are well known in the art. The regenerated catalyst may then be used again in the oligomerization reaction at some initial temperature, with the continually increasing temperature cycle being repeated.
The catalyst and the reactor conditions may be selected to achieve a low yield of butane and lighter saturates from the oligomerization reaction, such as no greater than about 2.0 wt %, or no greater than about 1.5 wt %, or no greater than about 1.0 wt % butanes and lighter saturates. The catalyst and the reactor conditions may be selected to achieve a low yield of butane and lighter saturates from the oligomerization reaction in the range of from about 0.1 wt % to about 2.0 wt %, or from about 0.2 wt % to about 1.5 wt % butanes and lighter saturates.
Conveniently, the oligomerization process is conducted in a plurality of serial adiabatic reactors with interstage cooling, such as is disclosed in U.S. Pat. No. 4,560,536, the entire contents of which is incorporated herein by reference. In order to achieve the desired low ΔT within each reactor, more than three reactors, for example, about 4 to 10 reactors, may be required. Conveniently, the reactors employed are boiling water reactors, sometimes called heat exchanger reactors, e.g., such as is discussed in U.S. Pat. Nos. 4,263,141 and 4,369,255 (for methanol production), and “Petroleum Processing, Principles and Applications,” R. J. Hengstebeck, McGraw-Hill, 1959, pages 208-218 (specifically for olefin oligomerization, using solid phosphoric acid). Typically, the oligomerization is conducted to achieve a desired level of feed olefin conversion (such as C4 olefin, noted above) in a single boiling water reactor, although a plurality of boiling water reactors may be used in parallel to provide additional capacity, and using boiling water reactors in series to achieve incremental olefin conversion of the effluent of one boiling water reactor by feeding it to another may also be employed.
Hydrocarbon Product Streams
The hydrocarbon composition recovered as the hydrocarbon product stream in the process of the invention comprises at least about 1.0 wt %, such as at least about 2.0 wt %, such as at least about 3.0 wt %, for example at least about 4.0 wt %, conveniently at least about 5.0 wt %, or even at least about 10.0 wt % of C9 non-normal olefin. Further, the hydrocarbon product stream comprises no greater than about 30 wt %, for example no greater than about 25 wt %, conveniently no greater than about 20 wt %, or no greater than about 15 wt % of C9 non-normal olefin. The hydrocarbon composition recovered as the hydrocarbon product stream in the process of the invention comprises in the range of from about 1.0 wt % to about 30 wt %, or from about 2.0 wt % to about 25 wt %, or from about 3.0 wt % to about 20 wt % of C9 non-normal olefin.
In general, the hydrocarbon product stream contains at least about 90 wt %, for example, at least about 92 wt %, such as at least about 95 wt %, or even at least about 97 wt %, including at least about 99 wt % or at least about 99.5 wt % non-normal olefins, non-normal saturates or combinations thereof. The hydrocarbon product stream contains in the range of from about 90 wt % to about 97 wt %, or from about 92 wt % to about 95 wt % of C9 to C20 non-normal olefins, non-normal saturates or combinations thereof. Moreover, the hydrocarbon product stream generally contains at least about 0.5 wt %, or at least about 1.0 wt %, or at least about 2.0 wt %, or even at least about 3.0 wt %, or at least about 5.0 wt % of C17 to C20 non-normal olefins, but typically no greater than about 20 greater than about 10.0 wt %, or no greater than about 8.0 wt %, or no greater than about 6.0 wt %, or even no greater than about 4.0 wt %, or even no greater than about 2.0 wt % of C17 to C20 non-normal olefins. The hydrocarbon product stream generally contains in the range of from about 0.5 wt % to about 20 wt %, or from about 0.5 wt % to about 15 wt %, from about 0.5 wt % to about 12 wt %, or from about 1.0 wt % to about 10 wt %, or from about 2.0 wt % to about 8.0 wt %, or from about 3.0 wt % to about 6.0 wt %, or from about 4.0 wt % to about 5.0 wt % of C17 to C20 non-normal olefins. C21+ hydrocarbons, such as non-normal olefins, may also be present, though typically the content is low.
The initial boiling point of the hydrocarbon product stream is typically at least about 260° F. (127° C.), such as at least about 280° F. (138° C.), including at least about 300° F. (149° C.), for example at least about 320° F. (160° C.), or even at least about 340° F. (171° C.), or even at least about 360° F. (182° C.). The initial boiling point of the hydrocarbon product stream is typically in the range of from about 260° F. (127° C.) to about 360° F. (182° C.), or from about 280° F. (138° C.) to about 340° F. (171° C.), or from about 300° F. (149° C.) to about 320° F. (160° C.). The final boiling point of the hydrocarbon product stream is typically no greater than about 350° C., such as no greater than about 330° C., for example no greater than about 310° C. or even no greater than about 300° C. The final boiling point of the hydrocarbon product stream is typically in the range of from about 260° C. to about 350° C., or from about 280° C. to about 330° C.
In one embodiment, the hydrocarbon composition recovered as the hydrocarbon product stream in the process of the invention comprises at least about 3.0 wt %, for example at least about 4.0 wt %, alternatively at least about 5.0 wt %, or alternatively at least about 10.0 wt % of C8 non-normal olefin. The hydrocarbon composition recovered as the hydrocarbon product stream in the process of the invention comprises in the range of from about 3.0 wt % to about 10.0 wt %, or from about 4.0 wt % to about 5.0 wt % of C8 non-normal olefin. Further, the hydrocarbon product stream comprises no greater than about 25 wt %, conveniently no greater than about 20 wt %, or no greater than about 15 wt % of C 8 non-normal olefin. The hydrocarbon composition recovered as the hydrocarbon product stream in the process of the invention comprises in the range of from about 3.0 wt % to about 25 wt %, or from about 4.0 wt % to about 20.0 wt %, or from about 5.0 wt % to about 15.0 wt % of C8 non-normal olefin.
In general, the hydrocarbon product stream contains at least about 60 wt % to no greater than about 90 wt % of C11 to C18 non-normal olefins, non-normal saturates or combinations thereof. Moreover, the hydrocarbon product stream generally contains at least about 50 wt % to no greater than about 75 wt % of C12 to C16 non-normal olefins, non-normal saturates or combinations thereof.
Additionally, the initial boiling point of the hydrocarbon product stream can be at least about 215° F. (102° C.), such as at least about 235° F. (113° C.), including at least about 255° F. (124° C.), for example, at least about 275° F. (135° C.), or even at least about 295° F. (146° C.). The initial boiling point of the hydrocarbon product stream is typically in the range of from about 215° F. (102° C.) to about 295° F. (146° C.), or from about 235° F. (113° C.) to about 275° F. (135° C.), or from about 240° F. (116° C.) to about 255° F. (124° C.). The hydrocarbon product stream can contain at least about 40 wt %, for example at least about 50 wt %, such as at least about 60 wt %, or even at least about 70 wt % of material having a boiling range of from about 365° F. (185° C.) to about 495° F. (257° C.).
Hydrogenation of the Hydrocarbon Product Stream or the First Separated Hydrocarbon Product Stream
The hydrocarbon product stream or the separated hydrocarbon product stream(s) produced by the process of the invention can be used directly as a blending stock to produce jet or diesel fuel. Alternatively, the stream(s) can be hydrogenated, e.g., according to the method of U.S. Pat. Nos. 4,211,640 and 6,548,721, the entire contents of which are incorporated herein by reference, to saturate at least part of the olefins therein and produce a saturated product. The first separated hydrocarbon product stream is hydrogenated to form the hydrocarbon fluid composition. The hydrogenated hydrocarbon product stream or the hydrocarbon fluid composition can contain at least about 80 wt %, or at least about 85 wt %, or at least about 90 wt %, or at least about 95 wt % or at least about 99 wt % aliphatic hydrocarbons. The hydrogenated hydrocarbon product stream or the hydrocarbon fluid composition can contain in the range of from about 80 wt % to about 99 wt %, or from about 85 wt % to about 95 wt %, or from about 87 wt % to about 90 wt % aliphatic hydrocarbons. All other characteristics of the hydrogenated hydrocarbon product stream or the hydrocarbon fluid composition in terms of carbon number distribution, non-normal proportions and boiling point ranges will remain largely unchanged from the hydrocarbon product stream or the separated hydrocarbon product stream(s).
Methods employing a “massive nickel” catalyst, or a noble metal (typically platinum and/or palladium) catalyst, that do not require or employ pre-or continuous sulfiding, are also effective in hydrogenating the hydrocarbon product stream or the first separated hydrocarbon product stream produced by the process of the invention. Typically, molecular hydrogen is co-fed along with the olefinic stream across the hydrogenation catalyst, at temperatures, pressures and WHSV adequate to provide the desired level of saturation of all olefinic and aromatic species. These methods and conditions are well within the knowledge of those skilled in the art.
Thus, by appropriate hydrogenation, the hydrogenated hydrocarbon product stream or the hydrocarbon fluid composition produced by the process of the invention may have no greater than 500 wppm, or no greater than 100 wppm, or no greater than 50 wppm, or no greater than 10 wppm, or no greater than 5 wppm, or no greater than 2 wppm, or no greater than 1 wppm aromatics.
Alternatively or in addition, by appropriate hydrogenation, the hydrogenated hydrocarbon product stream or the hydrocarbon fluid composition produced by the process of the invention may have a Bromine Index of no greater than about 1000 mg Br/100 g sample, or no greater than about 700 mg Br/100 g sample, or no greater than about 500 mg Br/100 g sample, or no greater than about 200 mg Br/100 g sample, or no greater than about 100 mg Br/100 g sample, or no greater than about 50 mg Br/100 g sample, or no greater than about 10 mg Br/100 g sample, or no greater than about 5 mg Br/100 g sample or no greater than about 2 mg Br/100 g sample.
Further alternatively or in addition, by appropriate hydrogenation, the hydrogenated hydrocarbon product stream or the hydrocarbon fluid composition produced by the process of the invention may have a passing result on one or more of the Hot Acid Test and the ASTM Test Method D565.
The hydrocarbon product stream or the separated hydrocarbon product stream(s) produced by the process of the invention may contain at least about 40 wt %, or at least about 50 wt %, or at least about 60 wt %, or even at least about 70 wt % of material having a boiling range of from about 365° F. to about 495° F. (185° C. to 257° C.).
Separation of the Hydrocarbon Product Stream or the Hydrogenated Hydrocarbon Product Stream
The hydrocarbon product stream can be separated into at least two or three separated hydrocarbon product streams, for example, a first separated hydrocarbon product stream and a remainder separated hydrocarbon product stream. A separated hydrocarbon product stream may then be hydrogenated (as described above) to form a hydrocarbon fluid composition. Alternatively a hydrogenated hydrocarbon product stream (formed as described above) can be separated to produce at least one hydrocarbon fluid composition (and optionally more than one). Each of these separated streams and fluid compositions will have different boiling ranges, and they will each have a difference in initial boiling point and final boiling point that is lower than the difference possessed by the hydrocarbon product stream.
In certain embodiments, a separated hydrocarbon product stream or a hydrocarbon fluid composition will have a minimum initial boiling point of from 110° C. to 265° C., preferably from 150° C. to 265° C., more preferably from 185° C. to 265° C., and a maximum final boiling point of from 140° C. to 350° C., preferably from 175° C. to 350° C., more preferably from 215° C. to 350° C. In certain embodiments of the process of the present invention, at least one separated hydrocarbon product stream or hydrocarbon fluid composition has a minimum initial boiling point to maximum final boiling point at or within a range of 170° C. to 350° C., or 185° C. to 350° C.
In various other embodiments, at least one separated hydrocarbon product stream or hydrocarbon fluid composition has a minimum initial boiling point to a maximum final boiling point at or within a range of about 235 to about 289° F. (113 to 143° C.), or about 311 to about 354° F. (155 to 179° C.), or about 340 to about 376° F. (171 to 191° C.), or about 349 to about 394° F. (176 to 201° C.), or about 352 to about 408° F. (178 to 209° C.), or about 365 to about 412° F. (185 to 211° C.), or about 410 to about 504° F. (210 to 262° C.), or about 420 to about 495° F. (216 to 257° C.), or about 455 to about 534° F. (235 to 279° C.) or about 505 to about 624° F. (263 to 329° C.). Alternatively, at least one separated hydrocarbon product stream or hydrocarbon fluid composition has a minimum initial boiling point to a maximum final boiling point at or within a range of about 239° F. to about 282° F. (115° C. to 139° C.), or about 325° F. to about 349° F. (163° C. to 176° C.), or about 354° F. to about 369° F. (179° C. to 187° C.), or 358° F. to about 385° F. (181° C. to 196° C.), or 361° F. to about 399° F. (183° C. to 204° C.), or 372° F. to about 405° F. (189° C. to 207° C.), or 432° F. to about 496° F. (222° C. to 258° C.), or 433° F. to about 489° F. (223° C. to 254° C.), or 460° F. to about 525° F. (238° C. to 274° C.), or 523° F. to about 592° F. (273° C. to 311° C.).
Potentially, at least two streams or compositions (i.e., a minimum of two of one, or a combination of one each, of a separated hydrocarbon product stream or a hydrocarbon fluid composition) have a minimum initial boiling point to a maximum final boiling point at or within a range of about 235 to about 289° F. (113 to 143° C.), or about 311 to about 354° F. (155 to 179° C.), or about 340 to about 376° F. (171 to 191° C.), or about 349 to about 394° F. (176 to 201° C.), or about 352 to about 408° F. (178 to 209° C.), or about 365 to about 412° F. (185 to 211° C.), or about 410 to about 504° F. (210 to 262° C.), or about 420 to about 495° F. (216 to 257° C.), or about 455 to about 534° F. (235 to 279° C.) or about 505 to about 624° F. (263 to 329° C.).
The preferred method of separation, regardless of the order of separation, is fractional distillation using fractionation columns. The fractionation columns may be ordered in any number of ways to produce any number of the desired boiling ranges, e.g., making lighter cuts first from each of the overheads of fractionation columns in series. Additionally, some cuts not within the prescribed boiling ranges may be made on some columns to allow making the desired cuts on another column using the material not within the prescribed boiling ranges for some other purpose, such as fuel gas, motor gasoline, jet or diesel fuel.
Referring now to
The second heated combined reactor feed in line 24 is provided to heat exchanger reactor 27, where it flows through tubes 28, coming into contact with catalyst contained within tubes 28. The rate of the second heated combined reactor feed in line 24 and amount of catalyst within the tubes 28 of heat exchanger reactor 27 are such that a WHSV of at least 1.2 is achieved, based on the content of olefin in the second heated combined reactor feed in line 24.
The oligomerization reaction thus occurs within tubes 28, generating heat, and the heat passes through tubes 28 to be absorbed by boiling water flowing around the outside of the tubes in shell side 30. The boiling water in shell side 30 is a mixture of steam and liquid water that passes through line 38 to disengaging vessel 34. Make-up liquid boiler feed water is provided in line 32 to disengaging vessel 34, and the combined liquid make-up boiler feed water and liquid water formed in the disengaging vessel 34 from the mixture of steam and liquid water that came through line 38 exit the bottom of disengaging vessel 34 through line 36. The steam generated in the heat exchanger reactor 27 emanates from the top of disengaging vessel 34 through line 40, and may be used, for example, to provide heat in fractionation tower reboilers or to make electricity in turbogenerators. The liquid water in line 36 is then provided to the shell side of heat exchanger reactor 27 to become the boiling water in shell side 30.
The presence of a quite pure component, such as water, in a boiling state on the shell side 30 provides an almost constant temperature within shell side 30 and can, given other appropriate design considerations of heat exchanger reactor 27, provide for a very close approach to isothermal conditions for the reaction occuring within the tubes 28. The difference between the highest and lowest temperature within any and between all tubes 28 in heat exchanger reactor 27 is no greater than 40° F. Further, this configuration of heat exchanger reactor system 26 allows for good control of the reaction temperature within tubes 28 through controlling the pressure within the disengaging vessel 34 (sometimes called a “steam drum”). The pressure in the steam drum 34 controls the temperature at which the water will boil in shell side 30, one of the key factors governing the rate of absorbtion of the heat of reaction within tubes 28. As the catalyst in tubes 28 deactivates with time on stream, a given level of conversion of olefins can be obtained by increasing the pressure in steam drum 34, thus increasing the boiling temperature of the fluid in shell side 30, and increasing the temperature of the oligomerization reaction within tubes 28. Of course, the temperature of the boiling fluid in shell side 30 must be kept lower than the desired oligomerization reaction temperature within tubes 28, conveniently at least 5° C. lower, such as at least 10° C. lower, including at least 15° C. lower and even at least 20° C. lower, but typically not exceeding 40° C. lower to reduce the risk of introducing too great a radial temperature gradient within tubes 28 and decreasing the isothermality of the oligomerization reaction within tubes 28.
One design consideration for approaching isothermal conditions in heat exchanger reactor 27 is a relatively small diameter of the tubes 28, for example, an outside diameter of less than about 3 inches, conveniently less than about 2 inches, such as less than about 1.5 inches, and an inside diameter commensurate with the desired pressure rating for the inside of the tubes 28. This provides a relatively small resistance to heat transfer relative to the heat generated per unit volume of reaction space within tubes 28. Another such design consideration is a relatively long length for tubes 28, such as greater than about 5 meters, including greater than about 7 meters, conveniently greater than about 9 meters, which reduces the heat release per unit volume of reaction within tubes 28 and also promotes isothermality.
The oligomerization reaction product exits heat exchanger reactor 27 through line 42, and is provided to feed/effluent exchanger 18. The cooled reaction product exits feed/effluent exchanger 18 through line 44, and is provided to oligomerized product separation device 46. Separation device 46 may include one or more well known elements, such as fractionation columns, membranes, and flash drums, among other elements, and serves to separate the various components in the cooled reaction product in line 44 into various streams having differing concentrations of components than the cooled reaction product in line 44, including an olefinic recycle stream containing no greater than 10 wt % C10+ olefins in line 14. Also produced in separation device 46 is a hydrocarbon product stream in line 48 that contains at least 1 wt % and no greater than 30 wt % C9 non-normal olefins, and that has a first difference in initial and final boiling points. Additionally, one or more purge streams may be produced by separation device 46 and exit via line 50. Such purge streams in line 50 conveniently include streams richer in saturated hydrocarbons than the feedstock stream in line 12, such as a C4− rich stream containing unreacted butylenes and relatively concentrated C4− aliphatics, or a portion of material of identical or similar composition to that of the olefinic recycle stream in line 14 and relatively concentrated in C5+ aliphatics. Providing such purge streams is convenient to controlling the partial pressure of olefins provided for reaction in heat exchanger reactor 27.
The hydrocarbon product stream in line 48 is provided to hydrogenation unit 52, along with a hydrogen containing stream in line 54. Hydrogenation unit 52 may include a hydrogenation reactor, one or more flash drums, a hydrogenated product recirculation pump to maintain a relatively low temperature increase across the hydrogenation reactor, and a light byproduct stabilizer column, among other elements. The olefins in the hydrocarbon product stream are thoroughly hydrogenated, for example, using a catalyst comprising platinum and/or palladium on an alumina support in a hydrogenation reactor, to provide a hydrogenated hydrocarbon product stream in line 56 having a Bromine Index no greater than 1000 mg Br/100 g sample. A purge stream in line 58 may exit hydrogenation unit 52, for example comprising unreacted hydrogen and minor amounts of undesirable low molecular weight cracking byproducts generated by a light byproduct stabilizer column within hydrogenation unit 52.
The hydrogenated hydrocarbon product stream in line 56 is provided to hydrogenated hydrocarbon product separation system 60. In this example, hydrogenated hydrocarbon product separation system 60 comprises two fractionation columns, notably first fractionation column 62 and second fractionation column 68, and the hydrogenated hydrocarbon product stream in line 56 is provided to first fractionation column 62. In first fractionation column 62, the hydrogenated hydrocarbon product stream in line 56 is separated into a first hydrocarbon fluid composition as an overhead product in line 64 having a minimum initial boiling point to maximum final boiling point range (boiling range) according to ASTM Test Method D86-05 at or within a range of, for example, 235 to 289° F. (113 to 143° C.), or 311 to 354° F. (155 to 179° C.), or 340 to 376° F. (171 to 191° C.), or 349 to 394° F. (176 to 201° C.), or 352 to 408° F. (178 to 209° C.), or 365 to 412° F. (185 to 211° C.), and which has a (second) difference in initial and final boiling points that is lower than the first difference for the hydrocarbon product stream in line 48. (Optionally, the material in line 64 may have been a hydrogenated remainder separated stream).
First fractionation column 62 also generates a first remaining separated hydrogenated stream as a bottoms product in line 66. The first remaining separated hydrogenated stream in line 66 has corresponding initial boiling point and final boiling point temperatures that are higher than those of the first hydrocarbon fluid composition in line 64, and is provided to second fractionation column 68. In second fractionation column 68, the first remaining separated hydrogenated stream in line 66 is separated into a second hydrocarbon fluid composition as an overhead product in line 70 having a boiling range different from, and in this case greater than, that of the first hydrocarbon fluid composition in line 64. For example, the second hydrocarbon fluid composition in line 70 may have a boiling range at or within a range of 340 to 376° F. (171 to 191° C.), or 349 to 394° F. (176 to 201° C.), or 352 to 408° F. (178 to 209° C.), or 365 to 412° F. (185 to 211° C.), or 420 to 495° F. (216 to 257° C.) or 505 to 624° F. (263 to 329° C.), and which has a (third) difference in initial and final boiling points that is lower than the first difference for the hydrocarbon product stream in line 48. Also generated by second fractionation column 68 is a second remaining separated hydrogenated stream as a bottoms product in line 72. The second remaining separated hydrogenated stream in line 72 has an initial boiling point and final boiling point temperature that is higher than that of the second hydrocarbon fluid composition in line 70, and may be, for example, a third hydrocarbon fluid composition within one of the prescribed boiling ranges with a (fourth) difference in initial and final boiling points that is lower than the first difference for the hydrocarbon product stream in line 48. (Optionally, the material in line 72 may have been another remainder separated hydrogenated stream, such as a high molecular weight byproduct to be used as a diesel fuel).
Hydrocarbon Fluid Compositions
A hydrocarbon fluid composition of the present invention, which can be prepared by the process of the present invention described herein, has a minimum initial boiling point to maximum final boiling point range according to ASTM Test Method D86-05 (boiling range) at or within about 170° C. to about 350° C., or about 185° C. to about 350° C., or about 190° C. to about 350° C., or about 200° C. to about 350° C., or about 210° C. to about 350° C. Alternatively, a hydrocarbon fluid composition can have a minimum initial boiling point to maximum final boiling point ranges at or within about 170° C. to about 340° C., or about 185° C. to about 340° C., or about 190° C. to about 340° C., or about 200° C. to about 340° C., or about 210° C. to about 340° C.
In other embodiments, a hydrocarbon fluid composition of the present invention may have a minimum initial boiling point to maximum final boiling point range according to ASTM Test Method D86-05 (boiling range) at or within a range of about 340 to 376° F. (171 to 191° C.), or 349 to 394° F. (176 to 201° C.), or 352 to 408° F. (178 to 209° C.), or 365 to 412° F. (185 to 211° C.), or 410 to 504° F. (210 to 262° C.), or 420 to 495° F. (216 to 257° C.), or 455 to 534° F. (235 to 279° C.) or 505 to 624° F. (263 to 329° C.).
The hydrocarbon fluid composition of the present invention may also be characterized by having at least 3 carbon numbers, for example at least 4 carbon numbers, for example at least five carbon numbers, for example at least six or more carbon numbers within any given boiling range. The hydrocarbon fluid composition may also be characterized by having from 3 to 10 carbon numbers, for example from 4 to 8 carbon numbers, or for example from five to six carbon numbers. In general, the heavier the cut, the more different carbon number molecules there are in the cut. This is typically measured with the Linear Paraffin GC method, discussed below.
The hydrocarbon fluid composition of the present invention may also be characterized by having at least about 95 wt %, or at least about 97 wt %, or at least about 98 wt %, or at least about 99 wt %, or at least about 99.5 wt %, or even at least about 99.9 wt % non-normal hydrocarbons. The hydrocarbon fluid composition may also be characterized by having from about 95 wt % to about 99.9 wt % non-normal hydrocarbons, or from about 97 wt % to about 99.5 wt % non-normal hydrocarbons, or from about 98 wt % to about 99 wt % non-normal olefins. Analysis can be done by a number of methods, conveniently some form of GC/MS or GC and NMR analysis at the highest levels of non-normal hydrocarbon content.
The hydrocarbon fluid composition of the present invention may also be characterized by having no greater than about 1000 wppm, no greater than about 500, no greater than about 100, no greater than about 50, no greater than about 10, no greater than about 1, no greater than about 0.5 wppm, or even no greater than about 0.1 wppm aromatics. The hydrocarbon fluid composition may also be characterized by having from about 0.1 to about 1000 wppm, or about 0.5 to about 500, or about 1 to about 100, or about 10 to about 50 aromatics. The best way to determine this is with some form of UV measurement. The hydrocarbon fluid composition may also be characterized by having a Bromine Index by ASTM Test Method D2710 of no greater than about 1000 mg Br/100 g sample, or no greater than about 100 mg Br/100 g sample, or no greater than about 50 mg Br/100 g sample, or no greater than about 10 mg Br/100 g sample, or no greater than about 7 mg Br/100 g sample, or no greater than about 5 mg Br/100 g sample or no greater than about 2 mg Br/100 g sample. The hydrocarbon fluid composition may also be characterized by having a Bromine Index from about 2 mg Br/100 g sample to about 1000 mg Br/100 g sample, or about 2 mg Br/100 g sample to about 100 mg Br/100 g sample, or about 2 mg Br/100 g sample to about 50 mg Br/100 g sample. Below a Bromine Index of about 2 mg Br/100 g sample, the ASTM D565 or Hot Acid Wash test may be more useful to evaluate the presence of unsaturates, including aromatics, without requiring very sensitive analysis on very expensive and complicated instruments.
Thus the hydrocarbon fluid composition of the present invention may be further characterized by having a passing result according to ASTM Test Method D565 (Standard Test Method for Carbonizable Substances in White Mineral Oil), and/or a passing result for the Hot Acid Test according to BGVV-XXXVI (now BFR: German Federal Institute for Risk Assessment, for liquid paraffins used in the production of polymers, papers and defoamers that may come into contact with food).
The hydrocarbon fluid composition of the present invention may also be characterized by having no greater than about 10 wt % napththenes, or no greater than about 7 wt % naphthenes, or no greater than about 5 wt % naphthenes, or no greater than about 4 wt % naphthenes, or no greater than about 3 wt %, or no greater than about 2 wt %, or no greater than about 1 wt %. The hydrocarbon fluid composition may also be characterized by having from about 1 wt % to about 10 wt % naphthenes, such as from about 1 wt % to about 7 wt % naphthenes, for example from about 2 wt % to about 7 wt % naphthenes, or may have from about 1 wt % to about 4 wt % naphthenes, such as about 1 wt % to about 3 wt % naphthenes.
The hydrocarbon fluid composition, if made with olefins derived from some form of oxygenate conversion, will have substantially no sulfur, meaning the amount of sulfur in the hydrocarbon fluid composition is below the detectable level by any reasonable type of test no matter how sophisticated. The low sulfur content of the hydrocarbon product stream results in improved efficiency of the hydrogenation step, particularly on noble metal catalysts (Pd, Pt), resulting in a hydrocarbon fluid composition with substantially no aromatics (as discussed above), and indirectly contributes in turn to providing a product with very low naphthenes (as discussed above).
End Uses
The fluids of the present invention have a variety of uses in for example drilling fluids, industrial solvents, in printing inks, as metal working fluids, in coatings, in household product formulations, as extenders in silicone sealant compositions. Therefore, in a further embodiment, the fluids of the present invention are used as new and improved solvents.
The fluids of this invention are particularly useful as drilling fluids. In one embodiment, the invention relates to a drilling fluid having the fluid of this invention as a continuous oil phase. In another embodiment, this invention relates to a rate of penetration enhancer comprising a continuous aqueous phase having the fluid of this invention dispersed therein.
Drilling fluids used for offshore or on-shore applications need to exhibit acceptable biodegradability, human, eco-toxicity, eco-accumulation and lack of visual sheen credentials for them to be considered as candidate fluids for the manufacturer of drilling fluids. In addition, fluids used in drilling need to possess acceptable physical attributes. These generally include viscosity's of less than 4.0 cSt at 40° C. and, for cold weather applications, pour points of −40° C. or lower. These properties have typically been only attainable through the use of expensive synthetic fluids such as hydrogenated polyalpha olefins, as well as unsaturated internal olefins and linear alpha-olefins and esters. These properties are provided by some fluids of the present invention, the products having a boiling range in the range 235° C. to 300° C. (ASTM D-86) being preferred.
Drilling fluids may be classified as either water-based or oil-based, depending upon whether the continuous phase of the fluid is mainly oil or mainly water. At the same time water-based fluids may contain oil and oil-based fluids may contain water.
Water-based fluids conventionally include a hydratable clay, suspended in water with the aid of suitable surfactants, emulsifiers and other additives including salts, pH control agents and weighing agents such as barite. Water constitutes the continuous phase of the formulated fluid and is usually present in an amount of at least 50% of the entire composition; minor amounts of oil are sometimes added to enhance lubricity.
We have found that the fluids of the present invention are particularly useful in oil-based fluids having a hydrocarbon fluid as the continuous phase. These fluids typically include other components such as clays to alter the viscosity, and emulsifiers, gallants, weighting agents and other additives. Water may be present in greater or lesser amounts but will usually not be greater than 50% of the entire composition; if more than about 10% water is present, the fluid is often referred to as an invert emulsion, i.e. a water-in-oil emulsion. In invert emulsion fluids, the amount of water is typically up to about 40 wt % based on the drilling fluid, with the oil and the additives making up the remainder of the fluid.
One advantage of the use of the fluids of the present invention is that they possess low levels of normal paraffins and exhibit good biodegradability and low toxicity. Further they have low pour points compared to other products made from vacuum gas oil feeds. Their viscosity does not increase rapidly with decreasing temperature and therefore they disperse more rapidly in the cold water conditions found in deep sea environments and northern climates. Therefore drilling fluids based on the present invention typically do not need to be stored in heated areas, even in cold weather climates.
The fluids of the present invention may also be used as metal working fluids together with traditional additives, such as extreme pressure agents, antioxidants, biocides and emulsifiers if the lubricants are to be used as aqueous emulsions. The use of the fluids of the present invention results in a reduction of undesirable odours, less solvent loss due to undesirable evaporation. The fluids may also be used in lubricants that are operational at lower temperatures. The products of this invention may be used for aluminium rolling.
The fluids of the present invention are also useful to dissolve or suspend resins. In accordance with one aspect of the present invention, there is provided a solvent-resin composition comprising a resin component dissolved or suspended in the fluid of the present invention. The fluid component is typically 5-95% by total volume of the composition.
In accordance with a more limited aspect of the invention, the fluid is present in the amount 40-95% by total volume of the composition. In accordance with a still more limited aspect of the invention, the fluid is present in the amount 30%-80% by total volume of the composition.
The fluids of the present invention may be used in place of solvents currently used for inks, coatings and the like.
The fluids of the present invention may be used to dissolve resins such as:
The type of specific applications for which the solvents and solvent-resin blends of the present invention may be used are coatings, cleaning compositions and inks.
For coatings the mixture preferably has a high resin content, i.e., a resin content of 20%-60% by volume. For inks, the mixture preferably contains a lower concentration of the resin, i.e., 5%-30% by volume. In yet another embodiment, various pigments or additives may be added.
The formulations can be used as cleaning compositions for the removal of hydrocarbons, for dry cleaning, for industrial cleaning or for ink removal, in particular in removing ink from printing machines. In the offset industry it is very important that ink can be removed quickly and thoroughly from the printing surface without harming the metal or rubber components of the apparatus. Further there is a tendency to require that the cleaning compositions are environmentally friendly in that they contain no or hardly any aromatic volatile organic compounds and/or halogen containing compounds.
The hydrocarbon fluid compositions of the present invention are also useful as solvents for household consumer formulations, in particular for insecticide formulations such as those used in electrical wick insecticide devices, or as combustion fuels for portable stoves, in cosmetic products or in agricultural compositions.
The hydrocarbon fluid composition may also be compounded with an erstwhile crystalline polyolefin, conveniently polypropylene, to impart flexibility characteristics to the polyolefin, with the compound then used in an article of manufacture, such as a disposable medical gown.
The hydrocarbon fluid composition may also be used as a fuel, such as a diesel fuel or jet fuel.
The invention will now be more particularly described with reference to the following examples.
Olefinic feedstock and recycle materials were prepared as shown in Table 1 and were oligomerized over a catalyst comprising 65 wt % of 0.02 to 0.05 micron crystals of ZSM-5 having a SiO2/Al2O3 molar ratio of 50:1, and 35 wt % of an alumina binder. The catalyst was in the form of 1/16 inch extrudates and about 90 cc of catalyst was blended with about 202 cc of inert, silicon carbide beads to reduce the heat generation per unit volume of reaction and placed in the reaction bed of a tubular reactor equipped with a heat management system that allowed the oligomerization reaction to proceed under near isothermal conditions.
Over the course of this first experimental run, various charges were provided to the reactor to test performance under various conditions over an extended period of time. As the experimental run progressed, the catalyst activity declined, requiring an increase in reactor temperature later in the run to achieve a given conversion of feedstock olefins. In two particular experiments, the feedstock and recycle materials were blended in the proportions shown in Table 1, and the single blended stream (“Charge”) was provided to the reactor at 1000 psig (6891 kPa) and other conditions shown in Table 2; wherein the WHSV was based on the olefin in the total charge (combined feed and recycle) and, in this example, the total catalyst composition (ZSM-5 and binder). Four thermocouples were available, positioned evenly through the reaction bed in the reactor, with one very near the first point where the charge and catalyst come into contact, and one very near the outlet of the reaction bed. The difference between the highest and lowest temperatures within the reactor was from 2 to 7° C. The reaction product was analyzed with a gas chromatograph, and the composition of the products is provided in Table 2. No products having a carbon number greater than 21 were detected.
The same apparatus and procedure as Example 1 was utilized for a second, extended experimental run with a fresh batch of catalyst and another set of charge compositions as shown in Table 3. The olefinic feedstocks shown in Table 3 were produced by reacting methanol over a SAPO-34 catalyst generally according to the method of U.S. Pat. No. 6,673,978, with separation of the methanol reaction products to provide a C4+ olefin composition. Over 90 wt % of the olefins in each feed composition were normal in atomic configuration, and the feed composition further contained about 1000 wppm oxygenates, such as methanol and acetone (not shown in Table 3), and 1000 ppm dienes. Some minor adjustments of some components in the feed compositions were made by additions of reagent grade materials to test certain aspects of the operation.
The olefinic recycle compositions shown in Table 3 were produced by taking accumulated batches of the reaction products from the first and this second experimental run and periodically providing those batches to a fractionation tower to separate a distillate product from a light olefinic recycle material, collecting those fractionated materials, and using the fractionated light olefinic recycle material for subsequent experiments. Over 90 wt % of the olefins in each recycle composition were non-normal in atomic configuration. Some minor adjustments of some components in the recycle compositions were made via addition of reagent grade materials to account for unavoidable losses in the fractionation step and test certain other aspects of the operation.
For a number of particular experiments using the charge material and proportions shown in Table 3, the butylene conversion and yield of C10+ material in the reactor product for each of the charge compositions under a variety of temperatures and aproximate days on stream are provided in Table 4. In all of the experiments shown in Table 4, the total reactor pressure was about 1000 psig (7000 kPa), the WHSV was between 3.5 and 4.0 based on the olefin in the total charge (combined feed and recycle) and, in this example, the total catalyst composition (ZSM-5 and binder), and the difference between the highest and lowest temperatures within the reactor was 10° C. or less.
Several batches of distillate materials were produced from the fractionation of various batches of reactor product obtained in the first and second esperimental runs. The carbon number distribution of those distillate material batches, via the Linear Paraffin GC method, are provided in Table 5. Distillates 1 and 2 in Table 5 were obtained from fractionation operations using the aggregate reactor product from the first experimental run, while Distillate 3 was obtained from fractionation operations of the aggregate reactor product from Charges C, D, and E of the second experimental run. All of the distillate materials contain all of the C11+ and almost all of the C11 material present from the reaction products, i.e., no separation of any components heavier than C11 was conducted on the reactor product in obtaining the distillate materials. As obtained directly from the reactor product via the fractionation tower, all the distillate materials are over 90 wt % non-normal olefin, and further contain very low amounts of aromatics (<100 wppm).
The batches of distillate materials obtained in Example 3 were hydrogenated in discrete batches by reacting them with hydrogen over a hydrogenation catalyst. Distillates 1 and 2 were hydrogenated over a nickel-containing catalyst while Distillate 3 was hydrogenated over a palladium-containing catalyst, each according to operations and conditions well known to those skilled in the art. The carbon number distribution of the distillates are provided in Table 5 and in Table 5A. Hydrogenation did not significantly change the non-normal character of the distillate compositions although, following hydrogenation, the distillate materials were almost completely aliphatic. No products having a carbon number greater than 21 were detected. Table 5 provides the carbon number distribution according to the Linear Paraffin GC method, which defines carbon number as all peaks eluting between two adjacent linear paraffins.
A the carbon distribution of the non-hydrogenated distillate samples is given using more detailed references for various carbon number isomers. Retention times of known normal and mono-methyl isomers were determined. The normal (or linear) paraffin is known to have the longest retention time. Every peak between the shortest retention time mono-methyl of Cn and normal Cn is assumed to be a branched species of Cn+1. Every peak between the normal Cn and shortest retention time mono-methyl Cn+1 is assumed to be a relatively low branched Cn+1.
With the linear paraffin method what is defined as Cn can contain, e.g., a Cn−1 or Cn+1 isomer due to overlapping GC peaks. As a result, there are differences between the carbon distribution in Table 5 and 5A for the same distillate samples.
The GC analysis data for both Table 5 and 5A were collected on a PONA (Paraffin, Olefin, Naphthene, Aromatic) Gas Chromatograph. On this GC, the distillate sample, prior to entering the GC separation column, is coinjected with hydrogen across a small reactor bed containing saturation catalyst. All the olefinic material in the distillate sample to the GC separation column is thus saturated (if not yet saturated before by hydrogenation). However, it is believed that the carbon number distribution (CND) measured herein are accurate.
Table 6 provides composition and other physical and fuel performance properties of the hydrogenated distillate materials.
Naphthenes Measurement
Table 7 below provides detailed information regarding the low naphthene content and other pertinent properties of the hydrocarbon fluid compositions of the present invention. Also provided is similar information for conventional hydrocarbon fluids. Some of these conventional hydrocarbon fluids are formed via commercial and laboratory processes other than that disclosed herein, including oligomerization of propylene and butylenes over solid phosphoric acid (sPa), and molecular sieve catalysts ZSM-22 and ZSM-57, conducted without any recycle of olefinic material derived from the oligomerization effluent. All materials in Table 7 have been fully hydrogenated to contain similar, very low concentrations of anything but aliphatics.
In Table 7, reference materials with known properties were obtained from various sources, notably samples A, B, C, D, K, P and Q. Sample A is a very highly branched iso-dodecane product available from providers of reagent grade chemicals, for example, Bayer. Similarly, Sample C is a completely linear dodecane from, for example, Aldrich. Sample B is a 2/1 w/w mixture of those two materials (2/3 Sample A and 1/3 Sample C materials by weight), to approximate the very mixed branching nature of both the inventive and commercial materials while accounting for the relatively large impact of normal paraffins on refractive index. These aforementioned reference materials are known to contain almost no naphthenes. Sample Q is a commercial Nappar™brand naphthene 10 product obtained from ExxonMobil Chemical Company, in this case produced by a facility in the U.S, known to be almost 100% naphthenes. Note the significant increase in both refractive index and density of the near 100% naphthenic material; the density is particularly significant given its considerably lower carbon number. Samples D, J and P are prepared mixtures of portions of Sample B and Sample Q in known concentrations, thus filling out the reference and calibration figures for subsequent determination of the remaining samples.
Regarding Table 7, Samples E, G, H and J are inventive compositions derived from distillations of the distillates of Example 2 above. Samples F, I, L, M, N and O are compositions obtained from conventional sources, as noted, prepared by other oligomerization processes including distillation of the oligomerization effluent. All distillations were conducted to achieve roughly similar carbon number distributions in an instructive range around C12; the composition is detailed in Table 7. The initial boiling point of these non-reference compositions is about 335° F. (168° C.), and their final boiling point is about 410° F. (210° C.).
In table Table 7, the content of naphthenes in the far right column is determined via a GC/MS method typically used in industry for these types of materials. It should be noted that this method is known to be increasingly less accurate with lower naphthene content, particularly at levels below about 5 wt %. This idiosyncrasy is shown most prominently in the results for Samples A and B, which by this GC/MS method show 5 wt % and 2 wt % naphthenes, respectively. However, it is known that these materials, by virtue of their method of manufacture as reagent grade chemicals and other analytical techniques, comprise virtually no naphthenes.
Table 7 also contains other properties of the various materials including refractive index and specific gravity. It is desirable to quantify the level of napthenes in materials of this type via knowledge of and correlation with the properties of the various components because each species has distinct density and refractive index properties that may be interpolated to determine the blend quantities. The extremely low concentration of naphthenes of the inventive hydrocarbon fluid compositions correlate well with their corresponding very low refractive indices and specific gravities.
In addition to the testing for naphthenes discussed above, a sample of the broad boiling range Distillate 3 (hydrogenated) material, as described in Example 4, was run on a 2-D GC instrument. This was done, given the historical difficulty of measuring naphthenes, as another means to determine and validate the presence of naphthenes at any boiling range of hydrocarbon fluids of the present invention that may be derived from the process of the present invention. Using well understood naphthenes from a conventional diesel fuel as a marker to fingerprint the region where such naphthenes would be located, there was no indication that Distillate 3 contained any naphthenes at all.
While the present invention has been described and illustrated by reference to particular embodiments, those of ordinary skill in the art will appreciate that the invention lends itself to variations not necessarily illustrated herein. The unique compositions may be anticipated to generated in other fashions than the olefin oligomerization process described, and the novel olefin oligomerization process may employ numerous permutations, combinations and optimizations from the information provided. For this reason, then, reference should be made solely to the appended claims for purposes of determining the true scope of the present invention.
This application claims the benefit of U.S. Provisional Application 60/648,947, filed Jan. 31, 2005; U.S. Provisional Application No. 60/648,938, filed Jan., 31, 2005; and U.S. Provisional Application No. 60/762,164, filed Jan. 25, 2006, all of which are fully incorporated herein by reference. The present application is related by subject matter to co-pending U.S. patent application Ser. No. 11/342,374, filed Jan. 27, 2006; U.S. patent application Ser. No. 11/342,385, filed Jan. 27, 2006; U.S. patent application Ser. No. 11/342,000, filed Jan. 27, 2006; and U.S. patent application Ser. No. 11/342,365, filed Jan. 27, 2006.
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