FIELD 0001 This disclosure relates to kerosene boiling compositions having high naphthenic content and low aromatic content, fuel compositions or Ike! blending compositions made from kerosene boiling range compositions, and methods for forming such fuel compositions,

(0002) Regulations such as the Renewable Fuels Standard in the United States and Renewable Energy Directive in Europe atm to reduce the carbon intensity (Cl) of transportation fuels, based on a Life Cycle Analysis. Among the transportation sectors is aviation, where sustainable aviation fuels (SAP) are one of the options for reducing Cl. However, SAP produced from biological sources tend to have low availability attributed to the logistical challenges of biomass production and the high costs of upgrading biomass feedstocks to finished fuels or fuel biendstocks. As an alternative, a low carbon aviation fuel (LCAF) derived from petroleum sources may also provide the aviation sector with a viable option for reducing greenhouse gas emissions. Advantages for a LCAF fuel are high availability and low processing costs. There is clearly a need for a readily available, low cost, and low carbon intensity aviation fuel. 0003 In addition to reducing greenhouse gas emissions, possible reductions in ground-level emissions from the aviation sector are also being evaluated, primarily criteria emissions associated with particulate matter and SOx. An aviation fuel that could deliver lower total greenhouse gas emissions while also lowering particulate matter and SOx criteria emissions would be attractive to the aviation sector, 0004 Ait article titled "Impact of Light Tight Oils on Distillate Hydrotreater Operation” in the May 2016 issue of Petroleum Technology Quarterly describes hydroprocessing of kerosene and diesel boiling range fractions derived Horn tight oils. fMiPSj U.S, Patent Application Publication 2017/0183575 describes fuel compositions formed during hydroprocessing of deasphalted oils for lubricant production.

SUMMARY

0005 In various aspects, a kerosene boiling range composition is provided. The kerosene boiling range composition includes a TI0 distillation point of20S*C or less, a final boiling point of 30i> ^:: € or less, a naphthenes to aromatics weight ratio of 3.2 or mote, an aromatics content of 4,0 wt% to 18 wt%, and a sulfur content of i 5ft wppm or less, 0006 Also provided Is a kerosene boiling range product comprising: ! .0 wt¾ to 49 wt% of sustainable aviation fuel in accordance with ASTM D7566; and 51 wt% to 99 wi.% of a kerosene boiling range composition, the kerosene boiling range composition comprising a TIP distillation pomt af205°C or less, a final boiling point ofSfXTC or less, a naphthenes to Momaties weight ratio of 3.2 or more, an aromatics content of 4.0 wt% to IS wt%, and a suitor content of 100 wppin or less.

0008 Also provided is a method for forming a kerosene boiling range composition, comprising: fractionating a erode oil comprising a final boiling point of 550*C or more to form at least a kerosene boiling range fraction, the erode oil comprising a naphthenes to aromatics volume ratio of 2.0 or more and a soliur content, of 0.2 wt% or less, the kerosene boiling range composition comprising a T10 distillation point of 205 °C or less, a final boiling point ofSOQX or less, a naphthenes to aromatics weight ratio of 3.2 or more, an aromatics contented ^' 4.0 wt% to 18 wt%, and a soliur content of 100 wppm or less.

0009 Use of compositions including the kerosene boiling range composition are also provided.

BRIEF DESCRIPTION OF THE DRA WINGS

0010 FIG, l shows compositional information for various crude oils.

0011 FIG, 2 shows compositional information for various crude oils.

0012 FIG, 3 shows compositional values and properties for various kerosene boiling range .tractions.

DllAILiO _. DESCRIPTION

0013 In various aspects, kerosene boding range or jet fuel boiling range compositions are provided that are formed from crude oils with unexpected combinations of high naphthenes to aromatics weight and/or volume ratio and a low sulfur content. This unexpected combination of properties is characteristic of crude oils that can be fractionated to form jet fuel boiling range and/or kerosene boiling range compositions that can be used as fuels / fuel blending products with minimal processing. The resulting kerosene boiling range fractions can have an unexpected combination of a high naphthenes to aromatics weight ratio, a low but substantial aromatics content, and a low sulfur content. In some aspects, the fractions can be used as fuels and/or fuel, blending products after fractionation, optionally with additional processing such as clay treating. In such aspects, the fractions can be used as fuels and/or fuel blending products without exposing the fractions to hydroprocessing and/or other energy intensive refinery processes. By reducing, minimising, or avoiding the amount of hydrpprocessing and/or other refinery processing needed to meet fuel and/or fuel blending product specifications, the fractions derived from the high naphthenes to aromatics ratio and low sulfur erodes can provide fuels and/or fuel blending products having a reduced or minimized carbon intensity . In other words, due to this reduced or minimized processing, the net amount of CO ₂ generation that is required to produce a fuel or fuel blending component and then ase the resulting fuel can he reduced. The reduction in carbon intensity can he on the order of 1% - 10% of the total carbon intensity for the fuel. This is an unexpected benefit, given the difficulty in achieving even small improvements in carbon intensity for conventional fuels and/or fuel blending products,

|0014| Generally, the naphthenes to aromatics weight ratio of the kerosene boiling range fractions described herein can be 1 ,9 or more, or 2.5 or more, or 3,0 or more, or 3,2 or more, or 3,5 or more, or 4,0 or more, such as up to 10 or possibly still higher. However, it is noted that, in various aspects, the high naphthenes to aromatics ratio is not due to an excessively low content of aromatics. For example, the kerosene boiling range (or jet fuel boiling range) compositions can include 4.0 wt% to 27 wt% of aromatics, or 4,0 wt% to 18 wt%, or 4.0 wt% to .16 wt%, or 4.0 wt% to 12 wt%, or 4.0 wt% to HI wt%. Instead, the kerosene boiling range compositions have unexpected combinations of high naphthenes to aromatics ratio while still including a minimum aromatics content. For example, in some aspects the compositions can include a naphthenes to aromatics weight ratio of 3.0 or more (or 3.5 or more) while having an aromatics content of 4.0 wt% to 12 wt%, or 4.0 wt% to 10 wt%. Additionally, the sulfur content of the kerosene boiling range composition can be 250 wppm or less, or 100wppm or less, or 75 wppni or less, such as down to 1.0 wppm or possibly still lower. In terms of vol%, the kerosene boiling range (or jet fuel boiling range) compositions can include 4,0 vol% to 25 vol% aromatics, or 4,0 voi% to 17 vol%, or 4.0 vol% to 15 voi%, or 4,0 vol% to 12 vol%, or 4,0 vol% to 10 vol%. The corresponding naphthenes to aromatics volume ratio can he 1.9 or more, or 2,6 or more, or 3.0 or more, or 3,2 or more, or 3,5 or snore, or 4,0 or more, such as up to 10 or possibly still higher 0015 Having a high naphthenes to aromatics ratio while still having a low but substantial aromatics content is unexpected due to the ring structures present in both, naphthenes and aromatics. Conventionally, it would be expected that a crude fraction Including a high ratio of naphthenes to aromatics would correspond to a) a hydrotreated composition, so that the high ratio of naphthenes was achieved by converting aromatic rings to saturated rings, b) a composition with a de minimis content of aromatics, or c) a combination of a) and b). Unfortunately, using hydroprocessing to arrive at a high ratio of naphthenes to aromatics results in increased carbon intensity for a fuel fraction.

00016 With regard to aromatics content, lower aromatics content is generally beneficial for a kerosene fraction for a variety of reasons, A lower aromatics content, such as an aromatics content of 10 wt% or less, can reduce soot and/or smoke production during combustion. It is generally desirable to have at least a few weight percent of aromatics in a jet fuel composition. When a kerosene is used as a jet fuel, s low aromatics content, such as an aromatics content of 10 wt% or less, can also reduce or minimize flame irradiation effects in turbine engine combustors. However, an aromatics content that is too close to 0 wt% can present difficulties. For example, the presence of aromatics assists with elastomer swell in jet fuel systems, and is also beneficial for providing a desirable density for a jet fuel. Thus, the unexpected combination of a high naphthenes to aromatics ratio white having a low but substantial aromatics content is beneficial for forming at least some types of fuels from a kerosene boiling range fraction. In combination with a low sulfur content, the unexpected combination of a high naphthenes to aromatics ratio and a low but substantial aromatics content can allow for formation of fuels or fuel blending components while reducing or minimizing refinery processing, resulting in a reduced or minimized carbon intensity for the fuel or fuel blending product,

[0017] A kerosene boiling range fuel with a high ratio of naphthenes to aromatics and a low but substantial aromatics content can also provide other advantages. For example, typical kerosene boiling range fuels (such as jet fuels} can typically have a cetane index of less than 30, such as between 20 and 30, In various aspects, a kerosene boiling range fraction with a high ratio of naphthenes to aromatics and a low but substantial content of aromatics can have a cetane index of greater than 30. For example, a kerosene boiling range fraction can have a cetane index of 31 55, or 35 ~ 55, or 40 ~ 55, or 45 ~ 55, It is noted that a cetane index of 45 or more can be beneficial for light aircraft that operate using compression ignition engines. 0018 In aspects where a kerosene fraction is not hydrotreated, a kerosene fraction with a sulfur content of iOO wppm or less can have an unexpectedly high ratio of aliphatic sulfur to total sulfur. Aliphatic sulfur is typically removed easily under hydrotreatmeni conditions, so a kerosene fraction that achie ved a sulfur content of 100 wppm or less due to hydrotreatment can typically have a weight ratio of aliphatic sulfur to total sulfur of less than 0.02. In other words, aliphatic sulfur corresponds to l ess than 2 wt% of the total sui tor. By contrast, a kerosene fraction with a sulfur content of 150 wppm or less (or 100 wppm or less) that has not been exposed to hydrotreating conditions can have a weight ratio of aliphatic st.fl.tor to total sulfur of 0.05 or more, or 0.1 or more, such as up to 0.7 or possibly still higher. It is noted that the limit for aliphatic suitor to some jet fuel products is 30 wppm or less. In some aspects, another indicator of a fraction that has not been hydroprocessed is that a kerosene fraction has a volume ratio of n- parafftns to total paraffins («-paraffins plus isoparaffins) of 0.4 or more. 0019 Still other properties of a kerosene boiling range fraction having a high ratio of naphthenes to aromatics and a low but substantia! aromatics content can include a Saybolt color rating of 25 or more; an interlacial tension rating of 35 dynes or higher; a cloud point: of -4<FC or lower, such as down to ~60°€; a pour point of *40°C or lower, such as down to -tSOX; freeze point of~40X or lower, or -47X or lower (such as down to -frtfC or possibly still lower); and a smoke point of 22 mm or more. 0020 In addition to having a reduced or minimized carbon intensity as a separate Sue! fraction, a kerosene fraction having a high naphthenes to aromatics ratio and a low but substantial aromatics content can also be combined with one or more sustainable aviation fuel fractions, as defined in ASTM D7566, to form a fuel with a reduced carbon intensity. Such a blend has synergistic advantages, as blending a kerosene fraction as described herein with a bio-derived sustainable aviation fuel can allow for correction of the freeze point of the bio-derived sustainable aviation fuel while avoiding the need to add a higher carbon intensity fr action to the sustainable aviation fuel. 0021 The lower carbon intensity of a fuel containing at least a portion of a kerosene fraction as described herein can he realized by using a fuel containing at least a portion of such a kerosene fraction in any convenient type of combustion device. In some aspects, a fuel containing at least a portion of a kerosene fraction as described herein can he nsed as fitei for a combustion engine in an airplane, a ground transportation vehicle, a marine vessel, or another convenient type of vehicle. Still other types of combustion devices can include generators, .furnaces, and other combustion devices that are used to provide heat or power, 0022 Based on the unexpected combinations of compositional properties, the kerosene boiling range compositions can be used to produce fuels and/or fuel blending products that also generate reduced or minimized amounts of other undesired combustion products. The other undeslred combustion products that can be reduced or minimized can include sulfur oxide compounds (SOx), nitrogen oxide compounds (NOx), and soot The low sulfur oxide production is due to the unexpectedly low sulfur content of the compositions. The high naphthenes to aromatics ratio can allow for a cleaner burning fuel, resulting In less incomplete combustion that produces soot. The lower nitrogen oxide production can be due to a corresponding low nitrogen content that is also observed in these low carbon intensity compositions,

{0023] It has been discovered that selected shale crude oils are examples of crude oils having an unexpected combination of high naphthenes to aromatics ratio, a low but substantial content of aromatics, and a low sulfur content. In various aspects, a shale oil fraction can be included as ^• part of a fuel or fuel blending product. Examples of shale oils that provide this unexpected combination of properties include selected shale oils extracted from the Permian basin. For convenience, unless otherwise specified, it is understood that references to incorporation of a shale oil fraction into a fuel also include incorporation of such a fraction into a fuel blending product. {0024} Cutteni commercial standards for jet fuels typically specify a variety of property. Examples of property specifications and/or typical properties for commercial jet feels include a total acidity of 0.1. mg KOH/g or less, or 0.015 rag KOH/g or less, a sulfur content of 3000 wppm or less, a freezing point maximum of -40°C or -47°C, a viscosity at ~20°C of 8.0 cSt or less, a flash point of at least 38°€, an initial boiling point of 140°€ or more, a T10 distillation point of 205°C or less, and/or a final boiling point of 3(KfrC or less. Another example of a property specification is a specification for a maximum deposit thickness on the surface of a healer tube and/or a maximum pressure increase during a thermal stability test at 26CFC (according to ASTM D3241 }, such as a maximum deposit thickness of 85 nm and/or a maximum pressure increase of 25 ram Hg. Still another example of a property specification can be a water separation rating, such as a water separation rating of 85 or more, as measured according to ASTM D3948. A water separation rating provides an indication of the amount of surfactant present in a jet fuel boiling range sample. Petroleum fractions that have an appropriate boiling range and that also satisfy the various requirements for a commercial standard, can be tested (such as according to ASTM D3241) and certified tor use as jet fuels, in some aspects, the kerosene boiling range fraction can correspond to a jet fuel fraction that satisfies the specification for a jet fuel trader ASTM PI 655, This can include a thermal stability breakpoint of 260°C or more, or 275°C or more, as defined by ASTM D3241.

Definitions

{0025} All numerical values within the detailed description and the claims herein are modified by “about” or “approximately” the indicated value, and take into account experimental error and variations that would be expected by a person having ordinary skill in the art.

{0025} In this discussion, a shale crude oil is defined as a petroleum product with a final boiling point greater than 55CFC that is extracted from a shale petroleum source, A shale oil fraction is defined as a boiling range fraction derived from a shale crude oil.

{0027} Unless otherwise specified, distillation points and boiling points can. be determined according to ASTM D2887. For samples that are not susceptible to characterization using ASTM D2887, D7I69 can be used. It is noted that still other methods of boiling point characterization may be provided in the examples. The values generated by such other methods are believed to be Indicative of the values that would be obtained under ASTM D2887 and/or 07169,

0028 In this discussion, the jet fuel boiling range or kerosene boiling range is defined as 14CFC to 30CFC. A jet fuel boiling range fraction or a kerosene boiling range fraction is defined m a fraction with a T10 distillation point o1 ^' 203T or loss, and a final boiling point of 30tT€ or less.

{0029} In this discussion, the distillate boiling range is defined as 170°C to 566°C A distillate boding range fraction is defined as a fraction having a T 10 distillation point of 170°C or more and a T90 distillation point of 566°C or less. The diesel boding range is defined as 176*C to 370X. A diesel boiling range fraction is defined as a fraction having a Tt 0 distillation point of 170*C or more, a final boiling point of 30CFC or more, and a T90 distillation point of 370 ^® C or less. An atmospheric resid is defined as a bottoms fraction having a T 10 distillation point of 149*C or higher, or 350*0 or higher. A vacuum gas oil boiling range fraction (also referred to as a heavy distillate) can have a TIG distillation point of 350*0 or higher and a T90 distillation point of 535"C or less. A vacuum resid is defined as a bottoms fraction having a T! 0 distillation point of 500°C or higher, or 565 ^f; °C or higher. It is noted that the definitions for distillate boiling range fraction, kerosene (or jet fuel) boding range fraction, diesel boiling range fraction, atmospheric resid, and vacuum resid are based on boiling point only. Thus, a distillate boiling range traction, kerosene fraction, or diesel fraction can include components that did not pass through a distillation tower or other separation stage based on boiling point. A shale oil distillate boiling range fraction is defined as a shale oil fraction corresponding to the distillate boiling range. A shale od kerosene (or jet fuel) boiling range fraction is defined as a shale oil fraction corresponding to the kerosene boiling range, A shale oil diesel boiling range fraction is defined as a shale oil fraction corresponding to the diesel boiling range,

(0030} In some aspects, a shale oil fraction that is incorporated into a fuel or fuel blending product can correspond to a shale oil fraction that has not been hydroprocessed and/or that has not been cracked. Cn this discussion, a non-hydroprocessed fraction is defined as a fraction that has not: been exposed to more than 10 psi nf hydrogen in the presence of a catal yst composing a Group VI metal, a Group VOl ml etal, a catalyst comprising a zeolitic framework, or a combination thereof In this discussion, a «on-cracked fraction is defined as a fraction that has not been exposed to a temperature of 4CKPC or mom.

(0031 } In this discussion, a hydroprocessed fraction refers to a hydrocarbon fraction and/or hydrocarbonaceous fraction that has been exposed to a catalyst ha ving hydroprocessing activity in the presence of 300 kPa~a or more of hydrogen at a temperature of 20ifrC or more. Examples of hydroprocessed. fractions include hydroprocessed distillate fractions (te„ a hydroprocessed fraction having the distillate boiling range), hydroprocessed kerosene fractions (i,e„ a hydroprocessed (motion having the kerosene boiling range) and hydroprocessed diesel fractions (re., a hydroprocessed fraction having the diesel boiling range), it is noted that a hydroprocessed fracben derived from a biological source, such as hydrotreated vegetable oil, can correspond to a hydroproeessed distil late fraction, a hydroproeessed kerosene fraction, and/or a hydroproeessed diesel fraction, depending on the boiling range of the hydroproeessed fraction.

0032 With regard to characterizing properties of kerosene boiling range fractions and/or blends of such fractions with other componen ts to form kerosene boiling range fuels, a variety of methods can be used. Density of a blend at 13 ^C C (kg / nr ⁵ ) can be determined according ASTM SD4052. Sulfur (in wppra or wt%) can be determined according to ASTM D2622, while nitrogen (in wppm or wt%) can be determined according to D4629. Kinematic viscosity at either -20°C or ~4(FC (in cSt) can be determined according to ASTM D44S. Pour point can be determined according to ASTM D5949. Cloud point can be determined according to D5773. Freeze point can be determined according to D5972,

0033 With regard to determining paraffin, naphthene,, and aromatics contents, supercritical fluid chromatography (SFC) was used. The characterization was performed using a commercial supercritical fluid chromatograph system, aud the methodology represents an expansion on the methodology described in ASTM DS 186 to allow for separate characterization of paraffins and naphthenes. The expansion on the ASTM D5I86 methodology was enabled by using additional separation columns, to allow for resolution of naphthenes and paraffins. The system was equipped with the following components: a high pressure pump for delivery of supercritical carbon dioxide mobile phase; temperature controlled column oven; auto-sampler with high pressure liquid injection valve for delivery of sample materia! into mobile phase; flame ionization detector; mobile phase splitter (low dead volume tee); hack pressure regulator to keep the CO ₂ in supercritical state; and a computer and data system for control of components and recording of data signal. For analysis, approximately 75 milligrams of sample was diluted in 2 milliliters o f toluene and loaded in standard septum cap autosamp!er vials . The sample was introduced based via the high pressure sampling valve. The SFC separation was performed using multiple commercial silica packed columns (5 micron with either 60 or 30 angstrom pores) connected in series (250 mm in length either 2 mm or 4 ram ID). Column temperature was held typically at 35 or 40°C . For analysis, the head pressure of columns was typically 250 bar. Liquid CCh flow rates were typically 0.3 ml/minute for 2 ram ID columns or 2.0 ml/minute lor 4 mra ID columns. The SFC FID signal was integrated into paraffin and naphthenic regions, in addition to characterizing aromatics according to ASTM D5186, a supercritical fluid chromatograph was used to analyze samples for split of total paraffins and total naphthenes. A variety of standards employing typical molecular types can be used to calibrate the paraffin/naphthene split for quantification. 0034 In this discussion, the term “paraffin” refers to a saturated hydrocarbon chain. Thus, a paraffin is an alkane that does not include a ring structure. The paraffin may he straight-chain or branched-chain and is considered to be a non-ring compound. “Paraffin” is intended to embrace all structural isomeric forms of paraffins, 0035 In this discussion, the term “naphthene” refers to a cycloalkane (also known as a cycloparaffin). Therefore, naphthenes correspond Co saturated ring structures. The term naphthene encompasses single-ring naphthenes and multi-ring naphthenes. The multi-ring naphthenes may have two or more rings, e.g., two-rings, three-rings, four-rings, five-rings, six- rings, seven-rings, eight-rings, nine-rings, and ten-rings. The rings may be fused and/or bridged. The naphthene can also include various side chains, such as one or more alkyl side chains of 1-.I0 carbons. 0036 In this discussion, the term “saturates” refers to all. straight chain, branched, and cyclic paraffins. Thus, saturates correspond to a combination of paraffins and naphthenes. 0037 in this discussion, the term “aromatic ring” means five or six atoms joined in a ring structure wherein (I) at least tour of the atoms joined in the ring structure are carbon atoms and (ti) all of the carbon atoms joined in the ring structure are aromatic carbon atoms. Therefore, aromatic rings correspond to unsattimed ring structures. Aromatic carbons can be identified «sing, for example, ^!“ C Nuclear Magnetic Resonance. Aromatic rings having atoms attached to the ring (e.g,, one or more heteroatoms, one or more carbon atoms, etc.) but which are not part of the ring structure are within the scope of the term “aromatic ring,” Additionally, it is noted that ring structures that include one or more heteroatoms (such as sulfur, nitrogen, or oxygen) can correspond to an “aromatic ring” if the ring structure otherwise falls within the definition of an “aromatic ring”. 0038 In this discussion, the term “non-aromatic ring” means four or more carbon atoms joined in at least one ring structure wherein at least one of the four or more carbon atoms in the ring structure is not an aromatic carbon atom. Non-aromatic rings having atoms attached to the ring (e.g,, one or more heteroatoms, one or more carbon atoms, etc.), but. which are not part of the ring structure, are within the scope of the term “non-aromatic ring.” 0039 In this discussion, the term “aromatics” refers to all compounds that include at least one aromatic ring. Such compounds that include at least one aromatic ring include compounds that have one or more hydrocarbon substituents. It is noted that a compound including at least one aromatic ring and at least one non-aromatic ring fails within the definition of the term “aromatics”. - ϊ 0 -

0040 It. is noted that that some hydrocarbons present within a feed or product may Ml outside of the defections for paraffins, naphthenes, and aromatics. For example, any alkenes that are not pari of an aromatic compound would fall outside of the above definitions. Similarly, non- aromatic compounds that include a heteroatom, such as sulfur, oxygen, or nitrogen, are not included In the definition of paraffins or naphthenes. life Cycle Assessment and Carbon Intensity

0041 Lite cycle assessment (LCA) is a method of quantifying the "comprehensive” environmental impacts of manufactured products, including fuel products, front "cradle to grave". Environmental .impacts may include greenhouse gas (GHG) emissions, freshwater impacts, or other impacts on the environment associated with the .finished product. The general guidelines for LCA are specified in ISO 14040.

0042 The "carbon intensity" of a fuel product (e.g. kerosene fuel or jet fuel) is defined as the Hie cycle GHG emissions associated with that product (kg CO ₂ eq) relative to the energy content of that fuel product (M3, LHV basis). Life cycle GHG emissions associated with fuel products must include GHG emissions associated with crude oil production; crude oil transportation to a refinery; refining of the crude oil; transportation of the refined product to point and combustion of the feel product.

|tMM3| GHG emissions associated with the stages of refined product life cycles are assessed as follows.

(0044] ( I ) GHG emissions associated with drilling and well completion * including hydraulic fracturing, shall be normalised with respect to the expected ultimate recovery of sales-quality crude oil from the well,

(0045) (2) All GHG emissions associated with the production of oil and associated gas, including those associated with (a) operation of artificial lift devices, (h) separation of oik gas, and water, (c) crude oil stabilization and/or upgrading, among other GHG emissions sources shall be normalized wife respect to the volume of oil transferred to sales (e.g, to crude oil pipelines or rail). The tractions of GHG emissions associated with production equipment to be allocated to crude oil, natural gas, and other hydrocarbon products (e.g. natural gas liquids) shall he specified accordance with ISO 14040.

(0040} (3) GHG emissions associated wife rail, pipeline or other forms of transportation between the production sitefs) to the refinery shall he normalized, with respect to the volume of crude oil transferred to the refinery,

0047 (4) GHG emissions associated with the refining of crude oil. to make liquefied petroleum gas, gasoline, distillate fuels and other products shall he assessed, explicitly accounting for foe material Hows within ilia refinery, These emissions shall he normalized with respect to the volume of erode oil refined. 0048 (5) All of the preceding GHG emissions shall be summed to obtain the "Well to refinery" (WTR) GHG intensity of crude oil (e.g, kg CCbeq/bhl crude), 0049 (6) For each refined product, the WTR GHG emissions shah be divided by the product yield (barrels of refined prodisctfoarrels of crude), and then multiplied by the share of refinery GHG specific to that refined product, Tire allocation procedure shall be conducted in accordance wit h ISO i 4040, This procedure yields the WTR GHG intensity of each refined product (e. g, kg CCbeq/bbi kerosene), 0050 (7) GHG emissions associated with mil, pipeline or other forms of transportationbetween foe refinery and point of fueling shall be normalized with respect to the volume of each refined product sold. The sum of foe GHG emissions associa ted with this step and the previous step of this procedure is denoted the "Well to tank" (WTT) GHG intensity of the refined product, 005 1 (8) GHG emissions associated with the combustion of refined products shall be assessed and .normalized with respect to the volume of each refined product sold,

[0052] (9 ) The "carbon intensity” o f each mimed prod uct is the sum of the combustion emissions (kg COjeqfobl) and the "WTT" emissions (kg CCbeq/bbl) relative to the energy value of the refined product during combustion. Following the convention of the EPA Renewable Fuel Standard 2, these emissions are expressed in terras of the low heating value (LHV) of the fuel, i.e, g CCbeq/Mj refined product (LHV basis). 0053 in the above methodology, the dominant contribution for the amount of CDs produced per MI of refilled product rs the CO ₂ formed during combustion of the product. Because the CO ₂ generated during combustion is such a h igh percentage of the total carbon intensity, achieving even small or incremental reductions in carbon intensity has traditionally been challenging. In various aspects, it has been discovered that kerosene fractions derived from selected crude oils can be used to form fuels with reduced carbon intensifies. The selected crude oils correspond to crude oils with high naphthenes to aromatics ratios, low sulfur content, and a low but substantial aromatics content. This combination of features can allow for formation of a kerosene fraction from the crude oil that requires a reduced or minimized amount of refinery processing in order to make a fuel product and/or fuel blending product, 0054 In this discussion, a low carbon Intensity fuel or fuel blending product corresponds to a Fuel or fuel blending product that has reduced GHG emissions per unit of lower of heating value relative to a foe! or fuel blending product derived from a conventional petroleum source.

In some aspects, the reduced GHG emissions can be due in past to reduced refinery processing. For example, fractions that are not hydroprocessecl for sulfur retnovai have reduced well-to- tefinery emissions relative to fractions that require hydroprocessing prior to incorporation into a fuel. In various aspects, an unexpectedly high weight ratio of naphthenes to aromatics in a shale oil fraction can indicate a fraction with reduced GHG emissions, and therefore a lower carbon intensity.

(0055] For a conventionally produced jet fuel, a carbon intensity of §9 g COseq/MI refined product or more would be expected based on life cycle analysis. By reducing or minimizing refinery processing, such as by avoiding hydroprocessing, the carbon intensity for a fuel can be reduced by 1% to 10% relati ve to a conventional fuel. This can result in, .for example, a jet fuel with a carbon intensity of 87.5 g COieq/MJ refined product or less, or 87.0 g CCheq/MJ refined product or less, or 85.0 g CCfreq/MJ refined product or less, such as down to 80 g COseq/MJ refitted product or possibly still lower. 0056 Another indicator of a low carbon intensity fuel can be an elevated ratio of aliphatic sulfur to total sulfur in a fuel or fuel blending product. Aliphatic sulfur is generally easier to remove than other types of sulfur present in a hydrocarbon fraction. In a hydrotreated fraction, the aliphatic sulfur will typically be remove almost entirely, while other types of sulfur species will remain. The presence of increased aliphatic sulfur in a product can indicate a lack of hydroprocess tag for the product, 0057 Still another indicator of a low carbon intensity fuel can be an elevated ratio of basic nitrogen to total nitrogen in a fuel or fuel blending product. Basic nitrogen is typically easier to remove by hydrotreatment. The presence of an increased amount of basic ni trogen in a product can therefore indicate a lack of hydroprocessing for the product, 0058 Yet other ways of reducing carbon intensity .for a hydrocarbon fraction can be related to methods used for extraction of a crude oil For example, carbon intensity for a fraction can be reduced by using solar power, hydroelectric power, or another renewable energy source as the power source for equipment Involved in the extraction process, either during drilling and well completion and/or during production of crude oil. As another example, extracting crude oil from an extraction site without using artificial lift can reduce the carbon Intensity associated with a fuel, 0059 As an example of the benefits of using lower carbon intensity methods for extraction, if crude oil is produced with an upstream GHG intensity of 10 kg CO ₂ eq/bhl, has 3.0 wt% sulfur or less, and an API gravity of 40 or more, then a s ubstantial majori ty of the time, a kerosene fraction (or jet fraction) refined from such a crude oil can haste a “well to wheel” or “well to wake" (lb.? use In aviation) OHO intensity that is 10% lower than the conventional value of 89 g OCheq/MJ refined product or more.

0060 As another example, if erode oil is produced with an upstream GHG intensity of 10 kg COseq/bbk has 3.0 wt% sulfur or less, and an API gravity of 30 or more, then a majority of the time, a kerosene fraction (or jet fraction) refined from such a crude oil can have a “well to wheel” or "well io wake" (lor itse in aviation) GHG intensity (otherwise known as "carbon intensity”) that is 10% lower than the conventional value of 89 g CO?eq/MJ refined product or more.

0061 As still another example _* if crude oil is produced with an upstream GHG intensity of

30 kg CGseq/bbl, has 3.0 wt% sulfur or less, and an API gravity of 40 or more, then in some instances, a kerosene fraction (or jet fraction) refined from such a etude oil can have a "well to wheel” or “well to wake” (for use in aviation) GHG intensity (otherwise known as “carbon intensity”) that is 10% lower than the conventional value of 89 g COaeq/MJ refined product or more.

0062 As yet another example, if erode oil is produced with an upstream GHG intensity of 20 kg CCbeq/bbl, has 3.0 wi% sulfur or less, and an API gravity of 40 or more, then a substantial majority of the time, a kerosene fraction (or jet traction) refined from such a crude oil can have a "well to wheel" or “well to wake" (for use in aviation) GHG intensity (otherwise known as "carbon intensity”) that is 10% lower than the conventional value of 89 g COaeg/MJ refined product or more,

Optional Treatment of Kerosene and/or Jet Fractions

(0063} In various aspects, a kerosene fraction at least in part by distilling a kerosene boiling range fraction from a selected whole crude or parti a! crude that has an unexpected combination of a high naphthenes to aromatics ratio, a low hut substantial aromatics content, and a low sulfur content. In some aspects, the kerosene .fraction can he used as a fuel or fuel blending component with reduced, mimmi*ed _* or substantially no additional processing. In other aspects, it may he desirable to further treat the kerosene fraction. Examples of further treatment methods can include, but are not limited to, wet treating, clay treatment, acid and/or caustic treatment, mercaptan oxidation, salt drying _* and hydroprocessing.

(0064) Clay treatment, or more generally exposure of a jet fuel sample to an adsorbent, is an example of a method that can be used to remove a variety of types of impurities .from a sample. Suitable adsorben ts can include, but are not limited to, natural and/or synthetic clays, Fuller ^* *» earth, aitapy!gite, and silica gels. Such adsorbents are commercially available in various particle sixes and surface areas, it is noted that the effectiveness of an adsorbent: for reducing the content of an impurity (such as nitrogen or nitrogen compounds) in a sample can be dependent on the affinity of the adsorbent for a given compound and/or the prior usage history of the adsorbent For example, exposing a kerosene boiling range fraction to a clay adsorbent that is loaded with basic nitrogen compounds (such as due to prior adsorption from other kerosene boiling range samples) may result in exchange of nitrogen compounds from the current kerosene boiling range sample for previously adsorbed nitrogen compounds. Similar adsorption / desorption type processes may also occur for other polar compounds that, have previously been absorbed by the absorbent.

0065 The conditions employed during clay treatment (or other adsorbent treatment) can vary over a broad range. Treatment with adsorbent can generally be carried out in a temperature range of 0M00 ^® C. and preferably near ambient conditions, such as 20 ^® -40 ^® C, for a period of time generally ranging from about 1 second to I hour. The jet fuel sample can be exposed to the adsorbent in a packed column at any convenient pressure.

(6666] Another alternative for removal of basic compounds from a kerosene or jet fuel fraction is add washing. During acid washing, a feed corresponding to a kerosene or jet fuel sample can be mixed with an aqueous acid solution. Acid can be injected into the feed, for example, at a rate of 6-10 barrels of acid to every thousand barrels of jet fuel. The acid/feed mixture can then pass through a mixing valve, which maintains a mixing differential pressure on the feed of 5-25 psig (35 ···· 175 kPag) to sufficiently contact the acid with the sulfur aud nitrogeu compounds within the jet fuel. The acid/feed mixture can then be routed into the acid coalescer drum. In the coalescer, the acid can be separated from the jet fuel feed «sing an electrical field that accelerates the rate of separation. The acid settles to the bottom of the drum and can be drawn off on level control, After leaving the coalescer, the acid can fie disposed of in any convenient manner, such as sending the acid to offsite storage for resale. It is noted that the sulfuric acid and many types of typical jet fuel feeds are essentially immiscible, so (hat only minimal amounts of emulsion are typically formed in the acid coalescer. An example of a suitable acid can be a sulfuric add mixture at a concentration of 80-95 wf%, The remainder of the acid mixture that is not. sulfuric acid can be mostly water. Optionally, other components can also be present in the mixture, such as acid soluble oils that may he present if the saJfuric acid corresponds to spent sulfuric acid from another refinery process,

(0067] Still another option for upgrading a jet fuel fraction is to imlroproeess the jet fuel fraction, A wide range of hydroprocessing condi tions are potentially sui table for use, as even mild hydroprocessing conditions may produce a benefit in the properties of the jet fuel fraction, Hydroproeessiug of a kerosene fraction can he used to remove sulfur, remove nitrogen, saturate olefins, saturate aromatics, and/or for other purposes. During hydroprocessing, a feedstock that is partially or entirely composed of a jet fuel boiling range fraction is treated in a hydrotreatment (or other hydmproceass.bg) reactor that includes one or more hydrotreatment stages or beds. Optionally, the reaction conditions in the hydrotreatment stage(s) can be conditions suitable for reducing the sulfur content of the leedstrenra, such as conditions suitable for reducing the sulfur content of the feedstrearn to about 3000 wpprn or less, or about 1000 wppm or less, or about 500 wppro or less. The reaction conditions can include an LHSV of 0,1 to 20.0 hr ^' *, a hydrogen partial pressure If ora about 50 psig (0,34 MPag) to about 3000 psig (20,7 MPag), a treat, gas containing at least about S0% hydrogen, and a temperature of from about 450 ^! T (232°C) to about 800F (42T ^' ‘C), Preferably, the reaction conditions include an LHSV of from about 0.3 to about 5 hr ^" *, a hydrogen partial pressure from about 100 psig (0.69 MPag) to about 1000 psig; (6.9 MPag), and a temperature of from about 700°F (3?1°C) to about 750 ^; - ^' F (399 ^S C), pM8| Optionally,, a hydrotreatment reactor can be used that operates at a relatively low total pressure values, such as total pressures of about 200 psig (1.4 MPag) to about 800 psig (5,5 MPag), For example, the pressure in a stage in the hydrotreatment reactor can be at least about 200 psig (1.4 MPag), or at least about 300 psig (2.1 MPag), or at least about 400 psig (2.8 MPag), or at least about 450 psig (3.1 MPag). The pressure in a stage in the hydrotreatment reactor can be about 800 psig (5.5 MPag) or less, or about 700 psig (4,8 MPag) or less, or about 600 psig (4, 1 MPa) or less.

IQ9691 The catalyst in a hydrotreatment stage can be a conventional hydrotreating catalyst, such as a catalyst composed of a Group VIE metal and/or a Group ViH metal on a support. Suitable metals include cobalt, nickel, molybdenum, tungsten, or combinations thereof Preferred combinations of metals include nickel and molybdenum or nickel, cobalt, and molybdenum. Suitable supports include silica, silica-alumina, alumina, and titaoia.

10Q70I in an embodiment, the amount of treat gas delivered to the hydrotreatment stage can be based on the consumption of hydrogen in the stage. The treat gas rate for a hydrotreatment stage can be from about two to about five times the amount of hydrogen consumed per barrel of fresh feed in the stage. A typical hydrotreatment stage can consume from about 50 SCF/B (8,4 m¾fi) to about 1000 SCF/B (168.5 ofi/nr ) of hydrogen, depending on various (actors including the nature of the feed being hydrotreated. Thus, the treat gas rate can be from about 100 SCF/B (16.9 m ³ /m ³ ) to about 5000 SCF/B (842 raVm ³ ), Preferably, the treat gas rate can be (ram about four to about five time the amount of hydrogen consumed. Note tha t the above treat gas rates refer to the rate of hydrogen flow. If hydrogen is delivered as part of a gas stream having less than 100% hydrogen, the treat gas rate for the overall gas stream can be proportionally higher. {0671} Yet another option can be to use a mercaptan oxidation treatment Mercaptan oxidation involves exposing a sulfur-containing hydrocarbon fraction to an aqueous alkaline solution. In the alkaline environment, mercaptans in the hydrocarbon fraction can he converted into mercaptan salts, which are water soluble. The water soluble mercaptan salts stay with the water phase when the hydrocarbon fraction is separated from the alkaline aqueous solution. The mercaptan salts can then be converted to disulfides to facilitate separation of the sulfur compounds item the alkaline aqueous solution.

Characterization of Shale Crude Oils and Shale Oil Fractions - General (0072} Shale crude oils were obtained .from a plurality of different shale oil extraction sources. Assays were performed on the shale crude oils to determine various compositional characteristics and properties for the shale crude oils. The shale crude oils were also fractionated to form various types of tractions, including fractionation into atmospheric resid tractions, vacuum resid fractions, distillate fractions (including kerosene, diesel, and vacuum gas oil boiling range fractions), and naphtha fractions. Various types of characterisation and/or assays were also performed ou these additional fractions.

(0073] The characterization of the shale crude oils and/or crude oil fractions Included a variety of procedures that were used to generate data. For example, data for boiling ranges and fractional distillation points was generated using methods similar to compositional or pseudo compositional analysis such as ASTM 02887, For compositional features, such as the amounts of paraffins, isoparaffins, olefins, naphthenes, and/or aromatics in a crude oil and/or crude oil fraction, data was generated using methods similar to compositional analysis such as ASTM D5186 and/or other gas chromatography techniques. Data related to pour point was generated using methods similar to ASTM D97 and/or ASTM D5949. Data related to cloud point was generated using methods similar to ASTM D2.500 and/or ASTM 05773. Data related to sulfur content of a crude oil and/or crude oil fraction was generated using methods similar to ASTM D2622, ASTM 04294, aud/or ASTM D5443. Data related to density (such as density at !5*C) was generated using methods similar to ASTM D1298 aud/or ASTM D4052. Data related to kinematic viscosity (such as kinematic viscosity at 40*0 was generated using methods similar to ASTM D445 and/or ASTM D7042.

(0074} The data and other measured values for the shale crude oils and shale oil fractions were then incorporated into an existing data library of other representative conventional and non- conventional crude oils for use in an empirical model. The empirical model was used to provide predictions for compositional characteristics and properties for some additional shale oil fractions that were not directly characterized experimentally. In this discussion, data values provided by ibis empirical model will be described as modeled dais. In this discussion, data values that are no t otherwise labeled as modeled data correspond to measured values and/or values that can be directly derived from measured values. An example of such an empirical model Is AVEVA Spiral Suite 2019.3 Assay by AVEVA Solutions Limited. 0075 FIGS. 1 and 2 show examples of the unexpected combinations of properties for shale crude oils that have a high weight ratio and/or volume ratio of naphthenes to aromatics. In FIG,

1, both the weight ratio and the volume ratio of naphthenes to aromatics is shown for five shale crude oils relative to the weight / volume percentage of paraffins in the shale crude oil. The topplot in FIG, I shows the weight ratio of naphthenes to aromatics, while the bottom plot shows the volume ratio. A plurality of other representative conventional crudes are also shown in FIG. .1 for comparison. As shown in FIG, I, the selected shale crude oils described herein have a paraffin content of greater titan 40 wt% while also having a weight ratio of naphthenes to aromatics of 1,8 or more. Similarly, as shown in FIG. I „ the selected shale crude oils described herein have a paraffin content of greater than 40 vol% while also having a weight ratio of naphthenes to aromatics of 2.0 or more. By contrast, none of the conventional crude oils shown in FIG. I have a similar combination of a paraffin conten t of greater than 40 wt% and a weight ratio of naphthenes to aromatics of 1.8 or more, or a combination of paraffin content of greater than 40 voi% and a. weight ratio of naphthenes to aromatics of 2,0 or more. It has been discovered that this unexpected combination of naphthenes to aromatics ratio and paraffin content is present throughout: various fractions that can he derived from such selected crude oils.

{0076} In FIG. 2, both the volume ratio and weight ratio of naphthenes to aromatics is shown for the live shale crude oils in FIG. 1 relative to the weight of sulfur in the crude. The sulfur content of the crude in FIG, 2 is plotted on a logarithmic scale. The top plot in FIG. 2 shows the weight ratio of naphthenes to aromatics, while the bottom plot shows the volume ratio. The plurality of other representative conventional crude oils are also shown for comparison. As shown in FIG, 2, the selected shale erode oils have naphthene to aromatic volume ratios of 2.0 or more, while all of the conventional erode oils ha ve naphthene to aromatic volume ratios below 1 ,8. Similarly, as shown in FIG. 2, the selected shale crude oils have naphthene to aromatic weight ratios of i .8 or more, while all of the conventional crude oils have naphthene to aromatic weight ratios below 1.6. Additionally, the selected shale crude oils have a sulfur content of roughly 0.1 wt% or less, while all of the conventional erode oils shown in FIG, 2 have a sulfur content of greater than 0.2 wt%. It has been discovered that this unexpected combination of high naphthene to aromatics ratio and low sulfur is present within various fractions that can be derived from such selected crude oils. This unexpected combination of properties contributes to the - I 8 - ability to produce low carton intensity fuels from shale oil fractions and/or blends of shale oil fractions derived from the shale crude oils.

Characterization of Shale Oil Fractions ~ Kerosene Boiling Range Fraction 0077 In various aspects, a kerosene boiling range fraction as described herein can be used as a fuel fraction, such as a jet fuel fraction. The combination of low sulfur, hi gh naphthenes to aromatics ratio, and low but substantial aromatics content can allow a kerosene fraction to he used as a fuel fraction with a reduced or minimized amount of refinery processing.

0078 FIG. 3 shows measured values for kerosene fractions derived from nine different shale crude oils and/or crude oil blends, it is noted that the T90 distillation points for the fractions shown in FIG. 3 is between 280°C and 290°C. In aspects where a kerosene fraction is used to form a Jet fuel fraction, a final boiling point between 289X and 300 ^L €, or between 280C and 29(frC, can be beneficial, ft is believed that the compositional properties shown in FIG. 3 are representative of a fraction with a final boi ling point between 280°C and 300*C As shown in FIG. 3, the kerosene fractions had a naphthenes content between 38 wt% to 52 wt%, or 39 wt% to 5.1 wt%. The kerosene fractions also had an aromatics content between 4.0 wt% to 27 wt%, or 4,0 wt% to 18 wi%, or 4.0 wt% to I 6 wt%, or 4.0 wt% to 12 wt%. or 4.0 wt% to 10 wt%. The weight ratio of naphthenes to aromatics ranged from 1,5 to 10. Some of the kerosene fractions had an unexpected combination of high naphthenes to aromatics weight ratio and a low but substantial content of aromatics. For such fractions, the aromatics content was 4.0 wt% to 18 wt%, or 4.0 wt% to lf> wt%, or 4,0 wt% to 12 wt%, or 4.0 wt% to 10 wt%, For such fractions, the naphthenes to aromatics ratio was 3,2 to 10, or 4,0 to 10, or 5.0 to 10, or 6.0 to 10.

0079 In addition to the naphthenes and aromatics contents,, the kerosene fractions shown in FIG. 3 had a density at 15 ^C C between 0.775 and 0,84 g/ml, or between 0,78 and 0.83 g/ml, or between 0.79 g/ml and 0,82 g/ml; a. pour point between ~40 ^® € and ~50 ^'! €, or -40°€ to ~48 ^¾ €; a cloud point between -32 ^* C and ~42"C, or -32 ^f '€ to -40*0, and a freeze point between *3<FC and - 45*C, or between ~35*€ to -45*0. The fractions had a T10 distillation point of 205*0- or less, or 201°C or less. With regard to properties, it is believed that fractionating a selected crude oil to achieve a final boiling point between 280 ^¾ C and 300°C (instead of having a T90 distillation point between 2$0°C and 29CPC) would result la lower temperature values for cold flow properties such as pour point, cloud point, and freeze point. Thus, it is believed that for a fraction with a final boiling point between 280*0 and 300*C, the cloud point would be -40*0 or lower, and the freeze point would be -40 ^® C or lower.

0080 As a comparison for the data in FIG. 3, an article titled "Impact of Light Tight: Oils on Distillate Hydrotreater Operation ⁵ ' in the May 2016 issue of Petroleum Technology Quarterly included a listing of paraffin and aromatics contents for shale oik from a variety of shale oil formations. Comparative Table 1 shows the data provided from that article. Comparative Table 1 also includes a column for a representative kerosene traction derived from West Texas Intermediate _» a conventional light sweet crude oil. it is noted that the representative sulfur content reported in the article for WT1 was greater than 1000 wppm.

(0081) In Comparative Table 1 „ the kerosene fractions correspond to fractions having a boiling range of 350T ···· 500 ^a F ( 177"€ to 260 ^¾ €>. The values for paraffins and aromatics correspond to wt% as reported in the article. The naphthenes value is a maximum potential value calculated based on the reported paraffins and aromatics values. (The actual naphthenes value could be lower due to the presence of polar compounds.) This naphthenes weight percent was then used to calculate the naphthenes to aromatics ratio shown in the final row of the table.

0082 As shown in Comparative Table L the highest naphthenes to aromatics ratio is 3.2. All but one of the fractions in Comparative Table .1 had an aromatics content of 13 wt% or more, while the remaining fraction had an aromatics content of 12 wt% but a naphthenes to aromatics weight ratio of less than 3.0.

Additional Emhodimen is

{0083] Embodiment 1. A kerosene boiling range composition comprising a ^" HO distillation point of 205% ^' or less, a final boiling point of 300%’ or less, a naphthenes to aromatics weight ratio of 3.2 or more _» an aromatics content of 4.0 wi% to IS wi.%. and a sulfur content of 150 wppm or less. (0084) Embodiment 2. A kerosene boiling range product comprising: L0 wt% to 49 wt% of sustainable aviation fuel in accordance with ASTM D7566; and 51. wi% to 99 wt% of a kerosene boiling range composition, the kerosene boiling range composition comprising a T10 distillation point of 2(l$ ⁱ⁵ € or less, a final boiling point of 300*0 or less, a naphthenes to aromatics weight ratio of 3,2 or more, an aromatics content of 4.9 wt% to 18 wt%, and a sulfur content of 100 wppro or less,

(0085) Embodiment 3, The kerosene boding range composition or kerosene boiling range product of any of the above embodiments, wherein the kerosene boding range composition comprises an aromatics content of 4.0 wi% to 12 wt%, or 4,0 wt% to 10 wt%.

|0086| Embodiment 4. The kerosene boiling range composition or kerosene boding range product of any of the abo ve embodiments _* wherein the kerosene boiling range composition comprises a naphthenes to aromatics weight ratio of 4,0 or more, or wherein the kerosene boding range composition comprises a cetane index of 31 to 55, or a combination thereof (0087) Embodiment 5. The kerosene boiling range composition or kerosene boiling range product of any of the above embodiments, wherein the kerosene boding range composition comprises a fuel that satisfies the specifications for a Jet fuel in accordance with ASTM D1655, 0088 Embodiment 6, The kerosene boiling range composition or kerosene boiling range product of any of the above embodiments _* wherein the kerosene boiling range composition comprises a pour point of ~40 ^e C or lower, or wherein the kerosene boiling range composition comprises a cloud point of -40*0 or lower , wherein the kerosene boiling range composi tion comprises a freeze point of -40 ^® C or lower, or a combination thereof.

(0089) Embodiment ?, The kerosene boiling range composition or kerosene boiling range product of any of the above embodiments, wherein the kerosene boiling range composition comprises a weight ratio of aliphatic sulfur to total sulfur of 0.05 or more, or wherein the kerosene boiling range composition comprises a weight ratio of «-paraffins to total paraffins of 0.4 or more, or a combination thereof.

(0090] Embodiment 8, Use of a composition comprising the kerosene boiling range composition according to any of the above embodiments as a fuel in an engine, a furnace, a burner, a combustion de vice _* or a combination thereof.

(0091) Embodiment 9. Use of the composition of Embodiment 8, wherein the kerosene boiling range composition has not been exposed to hydroprocessing conditions, or wherein the distillate boiling range composition comprises a carbon intensity of 87 g CCEeq / M3 of lower heating value or less, or a combination thereof. 0092 Embodiment Ml .4 method for forming a kerosene boiling range composition, comprising: fractionating a crude oil comprising a final boiling point of 550°C or more to form at least a kerosene boiling range fraction, the crude oil comprising a naphthenes to aromatics volume ratio of 2.0 or more and a sulfur content of 0.2 wt% or less, the kerosene boiling range composition comprising a T.10 distillation point of205°€ or less, a final boiling point of 3O0°€ or less, a naphthenes to aromatics weight ratio of 3.2 or more, an aromatics content of 4.0 wt.% to 18 wt¾, and a sulfur content of 100 wppra or less,

{0093} Embodiment ϊ Ϊ. The method of Embodiment 10, wherein the crude oil comprises a paraffins content of 40 voi% or more.

{0094} Embodiment 12, The method of Embodiment 10 or 11 , wherein the kerosene boiling range fraction comprises an aromatics content of 4.0 wt% to 12 wt%, or wherein the kerosene boiling range fraction comprises a naphthenes to aromatics weight ratio of 4.0 or more, or a combination thereof

{0095} Embodiment 13. The method of any of Embodiments 10 to 12, further compri sing blending at least a portion of the kerosene boiling range fraction with a sustainable aviation fuel in accordance with A STM W566.

0096 Embodiment 14, The method of any of Embodiments 10 to 13, wherein the kerosene boiling range composition comprises a non-hydrotreated composition that has uot been exposed to more than 10 psia of hydrogen in the presence of a catalyst comprising a Group VI metal, a Group VT.H metal, a catalyst comprising a zeolitic framework, ora combination thereof {0097} Embodiment 15. The method of any of Embodiments 10 to 14, further comprising exposing the kerosene boiling range fraction to clay treatment, acid treatment, mercaptan oxidation, or a combination thereof.

0098 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. For this reason, then, reference should be made so lely to the appended c laims for purposes of determining t he rate scope of the presen t invention.