WO2019126003A1 - Lubricant compositions having improved oxidation performance - Google Patents

Lubricant compositions having improved oxidation performance Download PDF

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Publication number
WO2019126003A1
WO2019126003A1 PCT/US2018/065942 US2018065942W WO2019126003A1 WO 2019126003 A1 WO2019126003 A1 WO 2019126003A1 US 2018065942 W US2018065942 W US 2018065942W WO 2019126003 A1 WO2019126003 A1 WO 2019126003A1
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WIPO (PCT)
Prior art keywords
cst
less
group iii
base stock
composition
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PCT/US2018/065942
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English (en)
French (fr)
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WO2019126003A8 (en
Inventor
Daniel J. EICHELDOERFER
Richard C. Dougherty
jR. Charles L. BAKER
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Exxonmobil Research And Engineering Company
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Application filed by Exxonmobil Research And Engineering Company filed Critical Exxonmobil Research And Engineering Company
Priority to JP2020534343A priority Critical patent/JP2021507062A/ja
Priority to SG11202003669PA priority patent/SG11202003669PA/en
Priority to CN201880079521.7A priority patent/CN111448297A/zh
Priority to CA3082928A priority patent/CA3082928A1/en
Publication of WO2019126003A1 publication Critical patent/WO2019126003A1/en
Publication of WO2019126003A8 publication Critical patent/WO2019126003A8/en

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    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10M—LUBRICATING COMPOSITIONS; USE OF CHEMICAL SUBSTANCES EITHER ALONE OR AS LUBRICATING INGREDIENTS IN A LUBRICATING COMPOSITION
    • C10M169/00—Lubricating compositions characterised by containing as components a mixture of at least two types of ingredient selected from base-materials, thickeners or additives, covered by the preceding groups, each of these compounds being essential
    • C10M169/04—Mixtures of base-materials and additives
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G45/00—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G45/00—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds
    • C10G45/02—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbons; Hydrofinishing
    • C10G45/04—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbons; Hydrofinishing characterised by the catalyst used
    • C10G45/06—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbons; Hydrofinishing characterised by the catalyst used containing nickel or cobalt metal, or compounds thereof
    • C10G45/08—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbons; Hydrofinishing characterised by the catalyst used containing nickel or cobalt metal, or compounds thereof in combination with chromium, molybdenum, or tungsten metals, or compounds thereof
    • C—CHEMISTRY; METALLURGY
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    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G45/00—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds
    • C10G45/58—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to change the structural skeleton of some of the hydrocarbon content without cracking the other hydrocarbons present, e.g. lowering pour point; Selective hydrocracking of normal paraffins
    • C10G45/60—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to change the structural skeleton of some of the hydrocarbon content without cracking the other hydrocarbons present, e.g. lowering pour point; Selective hydrocracking of normal paraffins characterised by the catalyst used
    • C10G45/62—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to change the structural skeleton of some of the hydrocarbon content without cracking the other hydrocarbons present, e.g. lowering pour point; Selective hydrocracking of normal paraffins characterised by the catalyst used containing platinum group metals or compounds thereof
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    • C10G45/00—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds
    • C10G45/58—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to change the structural skeleton of some of the hydrocarbon content without cracking the other hydrocarbons present, e.g. lowering pour point; Selective hydrocracking of normal paraffins
    • C10G45/60—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to change the structural skeleton of some of the hydrocarbon content without cracking the other hydrocarbons present, e.g. lowering pour point; Selective hydrocracking of normal paraffins characterised by the catalyst used
    • C10G45/64—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to change the structural skeleton of some of the hydrocarbon content without cracking the other hydrocarbons present, e.g. lowering pour point; Selective hydrocracking of normal paraffins characterised by the catalyst used containing crystalline alumino-silicates, e.g. molecular sieves
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    • C10G47/00—Cracking of hydrocarbon oils, in the presence of hydrogen or hydrogen- generating compounds, to obtain lower boiling fractions
    • C10G47/02—Cracking of hydrocarbon oils, in the presence of hydrogen or hydrogen- generating compounds, to obtain lower boiling fractions characterised by the catalyst used
    • C10G47/10—Cracking of hydrocarbon oils, in the presence of hydrogen or hydrogen- generating compounds, to obtain lower boiling fractions characterised by the catalyst used with catalysts deposited on a carrier
    • C10G47/12—Inorganic carriers
    • C—CHEMISTRY; METALLURGY
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    • C10G47/00—Cracking of hydrocarbon oils, in the presence of hydrogen or hydrogen- generating compounds, to obtain lower boiling fractions
    • C10G47/02—Cracking of hydrocarbon oils, in the presence of hydrogen or hydrogen- generating compounds, to obtain lower boiling fractions characterised by the catalyst used
    • C10G47/10—Cracking of hydrocarbon oils, in the presence of hydrogen or hydrogen- generating compounds, to obtain lower boiling fractions characterised by the catalyst used with catalysts deposited on a carrier
    • C10G47/12—Inorganic carriers
    • C10G47/16—Crystalline alumino-silicate carriers
    • C10G47/18—Crystalline alumino-silicate carriers the catalyst containing platinum group metals or compounds thereof
    • C—CHEMISTRY; METALLURGY
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    • C10G65/00—Treatment of hydrocarbon oils by two or more hydrotreatment processes only
    • C10G65/02—Treatment of hydrocarbon oils by two or more hydrotreatment processes only plural serial stages only
    • C10G65/12—Treatment of hydrocarbon oils by two or more hydrotreatment processes only plural serial stages only including cracking steps and other hydrotreatment steps
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10M—LUBRICATING COMPOSITIONS; USE OF CHEMICAL SUBSTANCES EITHER ALONE OR AS LUBRICATING INGREDIENTS IN A LUBRICATING COMPOSITION
    • C10M101/00—Lubricating compositions characterised by the base-material being a mineral or fatty oil
    • C10M101/02—Petroleum fractions
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10M—LUBRICATING COMPOSITIONS; USE OF CHEMICAL SUBSTANCES EITHER ALONE OR AS LUBRICATING INGREDIENTS IN A LUBRICATING COMPOSITION
    • C10M105/00—Lubricating compositions characterised by the base-material being a non-macromolecular organic compound
    • C10M105/02—Well-defined hydrocarbons
    • C10M105/04—Well-defined hydrocarbons aliphatic
    • C—CHEMISTRY; METALLURGY
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    • C10M—LUBRICATING COMPOSITIONS; USE OF CHEMICAL SUBSTANCES EITHER ALONE OR AS LUBRICATING INGREDIENTS IN A LUBRICATING COMPOSITION
    • C10M171/00—Lubricating compositions characterised by purely physical criteria, e.g. containing as base-material, thickener or additive, ingredients which are characterised exclusively by their numerically specified physical properties, i.e. containing ingredients which are physically well-defined but for which the chemical nature is either unspecified or only very vaguely indicated
    • C10M171/02—Specified values of viscosity or viscosity index
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G2400/00—Products obtained by processes covered by groups C10G9/00 - C10G69/14
    • C10G2400/02—Gasoline
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    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G2400/00—Products obtained by processes covered by groups C10G9/00 - C10G69/14
    • C10G2400/04—Diesel oil
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    • C10G2400/06—Gasoil
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    • C10G2400/00—Products obtained by processes covered by groups C10G9/00 - C10G69/14
    • C10G2400/08—Jet fuel
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    • C10G2400/00—Products obtained by processes covered by groups C10G9/00 - C10G69/14
    • C10G2400/10—Lubricating oil
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    • C10M2203/00—Organic non-macromolecular hydrocarbon compounds and hydrocarbon fractions as ingredients in lubricant compositions
    • C10M2203/003—Organic non-macromolecular hydrocarbon compounds and hydrocarbon fractions as ingredients in lubricant compositions used as base material
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    • C10M2203/00—Organic non-macromolecular hydrocarbon compounds and hydrocarbon fractions as ingredients in lubricant compositions
    • C10M2203/06—Well-defined aromatic compounds
    • C10M2203/065—Well-defined aromatic compounds used as base material
    • C—CHEMISTRY; METALLURGY
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    • C10M2203/00—Organic non-macromolecular hydrocarbon compounds and hydrocarbon fractions as ingredients in lubricant compositions
    • C10M2203/10—Petroleum or coal fractions, e.g. tars, solvents, bitumen
    • C10M2203/102—Aliphatic fractions
    • C10M2203/1025—Aliphatic fractions used as base material
    • C—CHEMISTRY; METALLURGY
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    • C10M2205/00—Organic macromolecular hydrocarbon compounds or fractions, whether or not modified by oxidation as ingredients in lubricant compositions
    • C10M2205/02—Organic macromolecular hydrocarbon compounds or fractions, whether or not modified by oxidation as ingredients in lubricant compositions containing acyclic monomers
    • C10M2205/022—Ethene
    • C—CHEMISTRY; METALLURGY
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    • C10M2205/00—Organic macromolecular hydrocarbon compounds or fractions, whether or not modified by oxidation as ingredients in lubricant compositions
    • C10M2205/02—Organic macromolecular hydrocarbon compounds or fractions, whether or not modified by oxidation as ingredients in lubricant compositions containing acyclic monomers
    • C10M2205/024—Propene
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    • C10N2020/00—Specified physical or chemical properties or characteristics, i.e. function, of component of lubricating compositions
    • C10N2020/01—Physico-chemical properties
    • C10N2020/011—Cloud point
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    • C10N2020/02—Viscosity; Viscosity index
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    • C10N2020/00—Specified physical or chemical properties or characteristics, i.e. function, of component of lubricating compositions
    • C10N2020/01—Physico-chemical properties
    • C10N2020/065—Saturated Compounds
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    • C10N—INDEXING SCHEME ASSOCIATED WITH SUBCLASS C10M RELATING TO LUBRICATING COMPOSITIONS
    • C10N2030/00—Specified physical or chemical properties which is improved by the additive characterising the lubricating composition, e.g. multifunctional additives
    • C10N2030/02—Pour-point; Viscosity index
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    • C10N2030/00—Specified physical or chemical properties which is improved by the additive characterising the lubricating composition, e.g. multifunctional additives
    • C10N2030/08—Resistance to extreme temperature
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    • C10N2030/00—Specified physical or chemical properties which is improved by the additive characterising the lubricating composition, e.g. multifunctional additives
    • C10N2030/10—Inhibition of oxidation, e.g. anti-oxidants
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    • C10N2030/00—Specified physical or chemical properties which is improved by the additive characterising the lubricating composition, e.g. multifunctional additives
    • C10N2030/74—Noack Volatility
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    • C10N2040/00—Specified use or application for which the lubricating composition is intended
    • C10N2040/25—Internal-combustion engines
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    • C10N2040/00—Specified use or application for which the lubricating composition is intended
    • C10N2040/25—Internal-combustion engines
    • C10N2040/252—Diesel engines

Definitions

  • This disclosure relates to lubricant compositions formulated with unique Group III base stocks and blends of such base stocks.
  • Base oil is the major constituent in finished lubricants and contributes significantly to the properties of the lubricant.
  • Engine oils for example, are finished crankcase lubricants intended for use in automobile engines and diesel engines and contain two general components, namely, a base stock or base oil (one base stock or a blend of base stocks) and additives.
  • base stock or base oil one base stock or a blend of base stocks
  • additives In general, a few lubricating base oils are used to manufacture a variety of engine oils by varying the mixtures of individual lubricating base oils and individual additives.
  • base stocks are categorized in five groups based on their saturated hydrocarbon content, sulfur level, and viscosity index (Table 1).
  • Lube base stocks are typically produced in large scale from non-renewable petroleum sources.
  • Group I, II, and III base stocks are all derived from crude oil via extensive processing, such as solvent extraction, solvent or catalytic dewaxing, and hydroisomerization.
  • Group III base stocks can also be produced from synthetic hydrocarbon liquids obtained from natural gas, coal or other fossil resources
  • Group IV base stocks are polyalphaolefms (PAOs), and are produced by oligomerization of alpha olefins, such as l-decene.
  • Group V base stocks include all base stocks that do not belong to Groups I-IV, such as naphthenics, polyalkylene glycols (PAG), and esters.
  • Base oils are generally produced from the higher boiling fractions recovered from a vacuum distillation operation. They may be prepared from either petroleum-derived or from syncrude-derived feed stocks or from synthesis of lower molecular weight molecules.
  • Additives are chemicals which are added to base oil to improve certain properties in the finished lubricant so that it meets the minimum performance standards for the grade of the finished lubricant. For example, additives added to the engine oils may be used to improve oxidation stability of the lubricant, increase its viscosity, raise the viscosity index, and control deposits. Additives are expensive and may cause miscibility problems the finished lubricant. For these reasons, it is generally desirable to optimize the additive content of the engine oils to the minimum amount necessary to meet the appropriate requirements.
  • Formulations are undergoing changes driven by a need for increased quality.
  • governing organizations e.g., the American Petroleum Institute
  • the specifications for engine oils are calling for products with excellent low temperature properties and high oxidation stability.
  • Currently, only a small fraction of the base oils blended into engine oils are able to meet the most stringent of the demanding engine oil specifications.
  • formulators are using a range of base stocks including Group I, II, III, IV, and V base stocks to formulate their products.
  • This disclosure relates to formulated lubricant compositions containing unique Group III base stocks and blends.
  • This disclosure relates in part to lubricating compositions prepared with Group III base stocks having a kinematic viscosity at l00°C greater than 2 cSt, such as from 2 cSt to above 14 cSt, for example from 2 cSt to 12 cSt and from 4 cSt to 7 cSt.
  • These base stocks are also referred to as lubricating oil base stocks or products in the present disclosure.
  • the present disclosure provides a lubricating composition
  • a lubricating composition comprising a Group III base stock having: at least 90 wt.% saturated hydrocarbons; kinematic viscosity at l00°C (KV100) of 4.0 cSt to 12.0 cSt; a viscosity index of from 120 to 133; a ratio of multi-ring naphthenes to single ring naphthenes (2R+N/1RN) of less than 0.43; and an effective amount of one or more lubricant additives; wherein the lubricating composition has an oxidation induction time greater than 120 minutes.
  • KV100 kinematic viscosity at l00°C
  • the present disclosure provides a passenger car motor oil composition
  • a passenger car motor oil composition comprising a Group III base stock having: at least 90 wt.% saturated hydrocarbons; kinematic viscosity at l00°C of from 4.0 cSt up to 5.0 cSt; a viscosity index of from 120 to less than 140; a ratio of multi-ring naphthenes to single ring naphthenes (2R+N/1RN) of less than 0.45; and an effective amount of one or more lubricant additives; wherein the oil composition has an oxidation induction time greater than 120 minutes.
  • the present disclosure provides a heavy duty diesel engine lubricating oil composition
  • a heavy duty diesel engine lubricating oil composition comprising a Group III base stock having: at least 90 wt.% saturated hydrocarbons; kinematic viscosity at l00°C of from 5.5 cSt up to 7.0 cSt;
  • a viscosity index of from 120 to less than 144 a ratio of multi-ring naphthenes to single ring naphthenes (2R+N/1RN) of less than 0.56; and an effective amount of one or more lubricant additives wherein the lubricating oil composition has an oxidation induction time greater than 120 minutes.
  • the present disclosure provides a lubricating composition
  • a lubricating composition comprising a Group III base stock having: at least 90 wt.% saturated hydrocarbons; kinematic viscosity at l00°C of 4.0 cSt to 5.0 cSt; a viscosity index of 120 to 140; a ratio of multi-ring naphthenes to single ring naphthenes (2R+N/1RN) of less than 0.52; and a ratio of branched carbons to straight chain carbons (BC/SC) less than or equal to 0.21; and an effective amount of one or more lubricant additives; wherein the lubricating composition has an oxidation induction time greater than 120 minutes.
  • the present disclosure provides a lubricating composition
  • a lubricating composition comprising a Group III base stock having: at least 90 wt.% saturated hydrocarbons; kinematic viscosity at l00°C of 5.0 cSt to 12.0 cSt; a viscosity index of 120 to 140; a ratio of multi-ring naphthenes to single ring naphthenes (2R+N/1RN) of less than 0.59; and a ratio of branched carbons to straight chain carbons (BC/SC) less than or equal to 0.26; and
  • the lubricating oil composition has an oxidation induction time greater than 120 minutes.
  • the present disclosure provides a lubricating composition
  • a lubricating composition comprising a Group III base stock having: at least 90 wt.% saturated hydrocarbons; kinematic viscosity at l00°C (KV100) of 5.0 cSt to 12.0 cSt; a viscosity index of from 120 to 144; a ratio of multi-ring naphthenes to single ring naphthenes (2R+N/1RN) of less than 0.56; and an effective amount of one or more lubricant additives; wherein the lubricating oil composition has an oxidation induction time greater than 120 minutes.
  • KV100 kinematic viscosity at l00°C
  • the Group III base stocks useful in preparing the lubricant compositions of the present disclosure can be obtained utilizing a process for producing a diesel fuel and a Group III base stock.
  • a feed stock e.g., a heavy vacuum gas oil feed stock having a solvent dewaxed oil feed viscosity index of from about 45 to about 150
  • a mixed feed stock having a solvent dewaxed oil feed viscosity index of from about 45 to about 150 is processed through a first stage which is primarily a hydrotreating unit which boosts viscosity index (VI) and removes sulfur and nitrogen. This is followed by a stripping section where light ends and diesel are removed.
  • V viscosity index
  • the heavier lube fraction then enters a second stage where hydrocracking, dewaxing, and hydrofmishing are performed.
  • This combination of feed stock and process approaches produces a base stock with unique compositional characteristics. These unique compositional characteristics are observed in both the low, medium and high viscosity base stocks produced.
  • Fig. l is a multi-stage reaction system according to an embodiment of the disclosure.
  • Fig. 2 shows an example of a processing configuration suitable for producing Group III base stocks of the present disclosure.
  • Fig. 3 is a graph illustrating the relationship between the ratio of molecules with multi- ring naphthenes to molecules with single ring naphthenes (2R+N/1RN) and the viscosity index of light neutral Group III base stocks of the present disclosure as compared to other Group III base stocks.
  • Fig. 4 is a graph illustrating the relationship between the ratio of molecules with multi- ring naphthenes to molecules with single ring naphthenes (2R+N/1RN) and the viscosity index of medium neutral Group III base stocks of the present disclosure as compared to other Group III base stocks.
  • Fig. 5 is a graph illustrating the relationship between the ratio of molecules with multi- ring naphthenes to molecules with single ring naphthenes (2R+N/1RN) and the degree of branching (branched carbons/straight chain carbons) of light neutral Group III base stocks of the present disclosure as compared to other Group III base stocks.
  • Fig. 6 is a graph illustrating the relationship between the ratio of molecules with multi- ring naphthenes to molecules with single ring naphthenes (2R+N/1RN) and the nature of the branching (branched carbon/terminal carbons) of light neutral Group III base stocks of the present disclosure as compared to other Group III base stocks.
  • Fig. 7 is a graph illustrating the relationship between the ratio of molecules with multi- ring naphthenes to molecules with single ring naphthenes (2R+N/1RN) and the degree of branching (branched carbons/straight chain carbons) of medium and high neutral Group III base stocks of the present disclosure as compared to other Group III base stocks.
  • Fig. 8 is a graph illustrating the relationship between the ratio of molecules with multi- ring naphthenes to molecules with single ring naphthenes (2R+N/1RN) and the nature of the branching (branched carbon/terminal carbons) of medium and heavy neutral Group III base stocks of the present disclosure as compared to other Group III base stocks.
  • Fig. 9 is a graph illustrating the relationship between the pour point and mini-rotary viscosity (MRV) behavior of formulated light neutral Group III base stocks prepared according to the present disclosure as compared to other Group III base stocks.
  • MMV mini-rotary viscosity
  • Fig. 10 is a graph illustrating the relationship between the ratio of molecules with multi- ring naphthenes to molecules with single ring naphthenes (2R+N/1RN) and the mini-rotary viscosity (MRV) behavior of formulated light neutral Group III base stocks prepared according to the present disclosure as compared to other Group III base stocks.
  • Fig. 11 is a graph illustrating the relationship between the pour point and mini-rotary viscosity (MRV) behavior of formulated medium neutral Group III base stocks prepared according to the present disclosure as compared to other Group III base stocks.
  • MMV mini-rotary viscosity
  • Fig. 12 is a graph illustrating the relationship between the ratio of molecules with multi ring naphthenes to molecules with single ring naphthenes (2R+N/1RN) and the mini-rotary viscosity (MRV) behavior of formulated medium neutral Group III base stocks prepared according to the present disclosure as compared to other Group III base stocks.
  • Fig.13 is a plot of oxidation induction time vs. viscosity index) of base stocks according to one embodiment.
  • Fig. 14 is a plot of oxidation induction time vs. viscosity index of base stocks according to one embodiment.
  • Fig. 15 is a plot of oxidation induction time vs. 2R+N/1RN (as measured by SFC- corrected GCMS) of base stocks according to one embodiment.
  • Fig. 16 is a plot of oxidation induction time vs. 2R+N/1RN (as measured by SFC- corrected GCMS) of base stocks according to one embodiment.
  • the term“major component” means a component (e.g., base stock) present in a lubricating oil of this disclosure in an amount greater than about 50 weight percent (wt. %).
  • the term“minor component” means a component (e.g., one or more lubricating oil additives) present in a lubricating oil of this disclosure in an amount less than 50 weight percent.
  • the term“single ring naphthenes” means a saturated hydrocarbon group having the general formula C «H 2 « arranged in the form of a single closed ring, where n is the number of carbon atoms. It is also denoted herein as 1RN.
  • multi-ring naphthenes means a saturated hydrocarbon group having the general formula C «H 2 ( «+i-r) arranged in the form of multiple closed rings, where n is the number of carbon atoms and r is the number of rings (here, r > 1). It is also denoted herein as 2+RN.
  • kinematic viscosity at l00°C will be used interchangeably with “KV100” and“kinematic viscosity at 40°C” will be used interchangeably with“KV40.” The two terms should be considered equivalent.
  • the term“straight-chain carbons” means the sum of the alpha, beta, gamma, delta, and epsilon peaks as measured by 13 C nuclear magnetic resonance (NMR) spectroscopy.
  • branched carbons means the sum of the pendant methyl, pendant ethyl, and pendant propyl groups as measured by 13 C NMR.
  • terminal carbons means the sum of the terminal methyl, terminal ethyl, and terminal propyl groups as measured by 13 C NMR.
  • lubricating compositions such as engine lubricating oil compositions, are provided having certain species of paraffin molecules.
  • the present inventors have surprisingly discovered lubricant compositions prepared with base stocks having a low ratio of 2R+N/1RN and/or fewer branched chain carbons, such as those produced, for example, by the method described herein, demonstrate improved oxidation performance as compared to existing commercial base stocks.
  • Lower levels of 2R+N molecules and branched carbon species are desirable in lubricant compositions because high levels of 2R+N molecules and branched carbon species can hinder the oxidation performance of formulated oils.
  • lubricant compositions prepared with base stocks having a ratio of branched carbons to terminal carbons that is lower than existing commercial base stocks also demonstrate improved oxidation performance.
  • oxidative performance of the formulated base stocks of the present disclosure using CEC-L-85 or ASTM D6186, demonstrate an improvement over lubricants prepared with currently commercial conventional base stocks of 10-100 times, for example 20-50 times such as 30-40 times.
  • Oxidation performance can be determined by oxidation induction time (OIT) as measured by pressure differential scanning calorimetry (CEC-L-85). Oxidation induction time is measured by holding the sample temperature constant at l75°C for a period of time, such as 2 hours.
  • a lubricant composition of the present disclosure has an oxidation induction time of 90 minutes or greater, such as 100 minutes or greater, such as 110 minutes or greater, such as 120 minutes or greater.
  • a lubricant composition has an oxidation induction time of from 60 minutes to 120 minutes, such as from 70 minutes to 120 minutes, such as from 80 minutes to 120 minutes.
  • the base stocks utilized in the lubricating compositions of the present disclosure are API Group III base stocks.
  • Group III base stocks of the present disclosure can be produced by an advanced hydrocracking process using a feed stock, for example, a vacuum gas oil feed stock having a solvent dewaxed oil feed viscosity index of at least 45, such as at least 55, for example at least 60 up to 150, or 60 to 90, or a heavy vacuum gas oil and heavy atmospheric gas oil mixed feed stock having a solvent dewaxed oil feed viscosity index of at least 45, such as at least 55, for example, at least 60 to about 150, or 60 to 90.
  • Group III at least 45 such as at least 55, for example at least 60 to 150, or 60 to 90.
  • Group III base stocks of the present disclosure can have a kinematic viscosity at l00°C greater than 2 cSt, such as from 2 cSt to 14 cSt, for example from 2 cSt to 12 cSt and from 4 cSt to 12 cSt.
  • Group III base stocks of the present disclosure can have a ratio of multi-ring naphthenes to single ring naphthenes (2R+N/1RN) less than about 0.59 and a ratio of branched chain carbons to straight-chain carbons of less than or equal to 0.21.
  • Group III base stocks of the present disclosure can also have a ratio of branched chain carbons to terminal carbons less than 2.1.
  • the API Group III base stocks used in the lubricant compositions of the present disclosure can have a ratio of multi-ring naphthenes to single ring naphthenes of less than 0.59, such as less than 0.52, such as less than 0.46, such as less than 0.45 or less than 0.43 for base stocks having a kinematic viscosity at l00°C of 4-12 cSt.
  • the base stocks can have a ratio of (branched chain carbons to terminal carbons (BC/TC)) wherein BC/TC ⁇ 2.3.
  • the light neutral base stocks can have a viscosity index from 102 to 133 and less than or equal to l42*(l - 0.0025 exp(8*(2R+N/lRN))).
  • the medium and heavy neutral base stocks can have a viscosity index 120 to 133 less than or equal to 150.07*(l-0.0l06*exp(4.5*(2R+N/lRN))). Additionally, the levels of naphthenes can be lower in the base stocks of the present disclosure as compared to commercially known base stocks across the range of viscosities.
  • the naphthene content can be 30 wt.% to 70 wt.%.
  • the Group III base stocks of the present disclosure can have less than 0.03 wt.% sulfur, a pour point of -l0°C to -30°C, a Noack volatility of 0.5 wt.% to 20 wt.%, a CCS (cold crank simulator) value at -35°C of 100 cP up to 70,000cP,and naphthene content of 30 wt.% to 70 wt.%.
  • the light neutral Group III base stocks i.e., those with a KV100 of 2 cSt to 5 cSt, can have a Noack volatility of from 8 wt.% to 20 wt.
  • the medium neutral Group III base stocks of the present disclosure i.e., those with KV100 of 5 cSt to 7 cSt, can have a Noack volatility of 2 wt. % to 10 wt.%, a CCS value at -35 °C of 3,500 cP to 20,000 cP, a pour point of -10 °C to -30 °C and naphthene content of 30 wt.% to 60 wt.%.
  • the heavy neutral Group III base stocks of the present disclosure i.e. those with KV100 of 7 cSt to 12 cSt, can have a Noack volatility of 0.5 wt. % to 4 wt.%, a CCS value at -35 °C of 10,000 cP to 70,000 cP, a pour point of -10 °C to -30°C and naphthene content of 30 wt.% to 70 wt.%.
  • the Group III base stocks comprise 30 wt.% to 70% paraffins, or 31 wt.% to 69 wt.% paraffins or 32 wt.% to 68 wt.% paraffins.
  • a light neutral Group III base stock can contain 40 wt.% to 70 wt.%, or 45 wt.% to 70 wt.%, or 45 wt% to 65 wt.% of paraffins.
  • a medium neutral Group III base stock can contain 35 wt.% to 65 wt.%, or 40 wt.% to 65 wt.%, or 40 wt% to 60 wt.% of paraffins.
  • a heavy neutral Group III base stock can contain 30 wt.% to 60 wt.%, or 30 wt.% to 55 wt.%, or 30 wt% to 50 wt.%, or 30 wt.% to 45 wt.%, or 30 wt.% to 40 wt.% of paraffins.
  • a feed stock for example, a heavy vacuum gas oil feed stock having a solvent dewaxed oil feed viscosity index of from at least 45, preferably at least 55, and more preferably at least 60 up to about 150, or a mixed feed stock having a solvent dewaxed oil feed viscosity index of from at least 45, preferably at least 55, and more preferably at least 60 up to about 150 is processed through a first stage which is primarily a hydrotreating unit which boosts viscosity index (VI) and removes sulfur and nitrogen. This is followed by a stripping section where light ends and diesel are removed.
  • a first stage which is primarily a hydrotreating unit which boosts viscosity index (VI) and removes sulfur and nitrogen.
  • the heavier lube fraction then enters a second stage where hydrocracking, dewaxing, and hydrofmishing are performed.
  • This combination of feed stock and process approaches produces a base stock with unique compositional characteristics. These unique compositional characteristics are observed in both the low, medium and high viscosity base stocks produced.
  • the process configurations of the present disclosure produce high quality Group III base stocks that have unique compositional characteristics with respect to conventional Group III base stocks.
  • the compositional advantage may be derived from the muti-ring naphthenes to single ring naphthenes ratio of the composition.
  • the processes of the present disclosure can produce base stocks having a kinematic viscosity at l00°C (KV100) of greater than or equal to 2 cSt, or greater than or equal to 4 cSt, such as from 4 cSt to 7 cSt, or greater than or equal to 6 cSt, or greater than or equal to 8 cSt, or greater than or equal to 10 cSt, or greater than or equal to 12 cSt, or greater than or equal to 14 cSt.
  • the base stocks produced using the processes of the present disclosure can yield base stocks having a VI of at least 120 up to about 145, such as 120 to 140 or 120 to 133.
  • a stage can correspond to a single reactor or a plurality of reactors.
  • multiple parallel reactors can be used to perform one or more of the processes, or multiple parallel reactors can be used for all processes in a stage.
  • Each stage and/or reactor can include one or more catalyst beds containing hydroprocessing catalyst or dewaxing catalyst.
  • a "bed" of catalyst can refer to a partial physical catalyst bed.
  • a catalyst bed within a reactor could be filled partially with a hydrocracking catalyst and partially with a dewaxing catalyst.
  • the hydrocracking catalyst and dewaxing catalyst can each be referred to conceptually as separate catalyst beds.
  • Figure 1 shows an example of a processing configuration suitable for manufacturing the base stocks in this disclosure.
  • Figure 2 shows an example of a general processing configuration suitable for processing a feedstock to produce base stocks.
  • Rl corresponds to 110 in Figure 2; furthermore, R2, R3, R4, and R5 correspond to 120, 130, 140, and 150 from Figure 2, respectively. Details on the processing configuration can be found in ETS Application 2015/715,555.
  • a feedstock 105 can be introduced into a first reactor 110.
  • a reactor such as first reactor 110 can include a feed inlet and an effluent outlet.
  • First reactor 110 can correspond to a hydrotreating reactor, a hydrocracking reactor, or a combination thereof.
  • a plurality of reactors can be used to allow for selection of different conditions.
  • first reactor 110 can correspond to a hydrotreatment reactor while second reactor 120 can correspond to a hydrocracking reactor.
  • second reactor 120 can correspond to a hydrocracking reactor.
  • reactor(s) and/or catalysts within the reactor(s) can also be used.
  • a gas-liquid separation can be performed between reactors to allow for removal of light ends and contaminant gases.
  • the hydrocracking reactor in the initial stage can be referred to as an additional hydrocracking reactor.
  • the hydroprocessed effluent 125 from the final reactor (such as reactor 120) of the initial stage can then be passed into a fractionator 130, or another type of separation stage.
  • Fractionator 130 or other separation stage
  • Fractionator 130 can separate the hydroprocessed effluent to form one or more fuel boiling range fractions 137, a light ends fraction 132, and a lubricant boiling range fraction 135.
  • the lubricant boiling range fraction 135 can often correspond to a bottoms fraction from the fractionator 130.
  • the lubricant boiling range fraction 135 can undergo further hydrocracking in second stage hydrocracking reactor 140.
  • the effluent 145 from second stage hydrocracking reactor 140 can then be passed into a dewaxing / hydrofmishing reactor 150 to further improve the properties of the eventually produced lubricant boiling range products.
  • the effluent 155 from second stage dewaxing / hydrofmishing reactor 150 can be fractionated 160 to separate out light ends 152 and/or fuel boiling range fraction(s) 157 from one or more desired lubricant boiling range fractions 155.
  • the configuration in Figure 2 can allow the second stage hydrocracking reactor 140 and the dewaxing / hydrofmishing reactor 150 to be operated under sweet processing conditions, corresponding to the equivalent of a feed (to the second stage) sulfur content of 100 wppm or less. Under such“sweet” processing conditions, the configuration in Figure 2, in combination with use of a high surface area, low acidity catalyst, can allow for production of a hydrocracked effluent having a reduced or minimized content of aromatics.
  • the final reactor (such as reactor 120) in the initial stage can be referred to as being in direct fluid communication with an inlet to the fractionator 130 (or an inlet to another type of separation stage).
  • the other reactors in the initial stage can be referred to as being in indirect fluid communication with the inlet to the separation stage, based on the indirect fluid communication provided by the final reactor in the initial stage.
  • the reactors in the initial stage can generally be referred to as being in fluid communication with the separation stage, based on either direct fluid communication or indirect fluid communication.
  • one or more recycle loops can be included as part of a reaction system configuration. Recycle loops can allow for quenching of effluents between reactors / stages as well as quenching within a reactor / stage.
  • a feedstock is introduced into a reactor under hydrotreating conditions.
  • the hydrotreated effluent is then passed to a fractionator where the effluent is separated into fuel boiling range fractions and lubricant boiling range fractions.
  • the lubricant boiling range fractions are then passed to a second stage where hydrocracking, dewaxing and hydrofmishing steps are perfomed.
  • the effluent from the second stage is then passed to a fractionator where the Group III base stocks of the present disclosure are recovered.
  • Feedstocks A wide range of petroleum and chemical feedstocks can be hydroprocessed in accordance with the invention. Suitable feedstocks include whole and reduced petroleum crudes, such as Arab Light, extra Light, Midland Sweet, Delaware Basin, West Texas Intermediate, Eagle Ford, Murban and Mars crudes, atmospheric oils, cycle oils, gas oils, including vacuum gas oils and coker gas oils, light to heavy distillates including raw virgin distillates, hydrocrackates, hydrotreated oils, petroleum-derived waxes (including slack waxes), Fischer-Tropsch waxes, raffinates, deasphalted oils, and mixtures of these materials.
  • whole and reduced petroleum crudes such as Arab Light, extra Light, Midland Sweet, Delaware Basin, West Texas Intermediate, Eagle Ford, Murban and Mars crudes, atmospheric oils, cycle oils, gas oils, including vacuum gas oils and coker gas oils, light to heavy distillates including raw virgin distillates, hydrocrackates, hydrotreated oils, petroleum-derived waxes (including slack waxes), Fischer-Tropsch waxes,
  • One way of defining a feedstock is based on the boiling range of the feed.
  • One option for defining a boiling range is to use an initial boiling point for a feed and/or a final boiling point for a feed.
  • Another option is to characterize a feed based on the amount of the feed that boils at one or more temperatures. For example, a“T5” boiling point/ distillation point for a feed is defined as the temperature at which 5 wt% of the feed will boil off.
  • a“T95” boiling point / distillation point is a temperature at which 95 wt% of the feed will boil.
  • Boiling points, including fractional weight boiling points can be determined using an appropriate ASTM test method, such as the procedures described in ASTM D2887, D2892, D6352, D7129, and/or D86.
  • Typical feeds include, for example, feeds with an initial boiling point of at least 600°F ( ⁇ 3 l6°C); similarly, the T5 and/or T10 boiling point of the feed can be at least 600°F ( ⁇ 3 l6°C). Additionally or alternately, the final boiling point of the feed can be H00°F ( ⁇ 593°C) or less; similarly, the T95 boiling point and/or T90 boiling point of the feed can also be 1 l00°F ( ⁇ 593°C) or less. As one non-limiting example, a typical feed can have a T5 boiling point of at least 600°F ( ⁇ 3 l6°C) and a T95 boiling point of H00°F ( ⁇ 593°C) or less.
  • the feed may include a lower boiling range portion.
  • a feed can have an initial boiling point of at least 350°F ( ⁇ l77°C) and a final boiling point of 1 l00°F ( ⁇ 593°C) or less.
  • the aromatics content of the feed can be at least 20 wt%, or at least 25 wt%, or at least 30 wt%, or at least 40 wt%, or at least 50 wt%, or at least 60 wt%, such as up 15 to 75 wt% or up to 90 wt%.
  • the aromatics content can be 25 wt% to 75 wt%, or 25 wt% to 90 wt%, or 35 wt% to 75 wt%, or 35 wt% to 90 wt%.
  • the feed can have a lower aromatics content, such as an aromatics content of 35 wt% or less, or 25 wt% or less, such as down to 0 wt%.
  • the aromatics content can be 0 wt% to 35 wt%, or 0 wt% to 25 wt%, or 5.0 wt% to 35 wt%, or 5.0 wt% to 25 wt%.
  • Particular feed stock components useful in processes of the present disclosure include vacuum gas oil feed stocks (e.g., medium vacuum gas oil feeds (MVGO)) having a solvent dewaxed oil feed viscosity index of from at least 45, at least 50, at least 55, or at least 60 to 150, such as from 65 to 125, at least 65 to 110 from 65 to 100 or 65 to 90.
  • vacuum gas oil feed stocks e.g., medium vacuum gas oil feeds (MVGO)
  • MVGO medium vacuum gas oil feeds
  • feed stock components useful in processes of the present disclosure include feed stocks having a mixed vacuum gas oil feed (e.g., medium vacuum gas oil feed (MVGO)) and a heavy atmospheric gas oil feed, in which the mixed feed stock has a solvent dewaxed oil feed viscosity index of from at least 45, at least 55, at least 60 to 150, such as from 65 to 145, from 65 to 125, from 65 to 100 or 65 to 90.
  • MVGO medium vacuum gas oil feed
  • the feed can have a sulfur content of 500 wppm to 20000 wppm or more, or 500 wppm to 10000 wppm, or 500 wppm to 5000 wppm.
  • the nitrogen content of such a feed can be 20 wppm to 4000 wppm, or 50 wppm to 2000 wppm.
  • the feed can correspond to a“sweet” feed, so that the sulfur content of the feed is 25 wppm to 500 wppm and/or the nitrogen content is 1 wppm to 100 wppm.
  • a first hydroprocessing stage can be used to improve one or more qualities of a feedstock for lubricant base oil production.
  • improvements of a feedstock can include, but are not limited to, reducing the heteroatom content of a feed, performing conversion on a feed to provide viscosity index uplift, and/or performing aromatic saturation on a feed.
  • the conditions in the initial hydroprocessing stage can be sufficient to reduce the sulfur content of the hydroprocessed effluent to 250 wppm or less, or 200 wppm or less, or 150 wppm or less, or 100 wppm or less, or 50 wppm or less, or 25 wppm or less, or 10 wppm or less.
  • the sulfur content of the hydroprocessed effluent can be 1 wppm to 250 wppm, or 1 wppm to 50 wppm, or 1 wppm to 10 wppm.
  • the conditions in the initial hydroprocessing stage can be sufficient to reduce the nitrogen content to 100 wppm or less, or 50 wppm or less, or 25 wppm or less, or 10 wppm or less.
  • the nitrogen content can be 1 wppm to 100 wppm, or 1 wppm to 25 wppm, or 1 wppm to 10 wppm.
  • the hydrotreating catalyst can comprise any suitable hydrotreating catalyst, e.g., a catalyst comprising at least one Group 8 - 10 non-noble metal (for example selected from Ni, Co, and a combination thereof) and at least one Group 6 metal (for example selected from Mo, W, and a combination thereof), optionally including a suitable support and/or filler material (e.g, comprising alumina, silica, titania, zirconia, or a combination thereof).
  • the hydrotreating catalyst according to aspects of this invention can be a bulk catalyst or a supported catalyst. Techniques for producing supported catalysts are well known in the art.
  • Bulk metal catalyst particles can be made via methods where all of the metal catalyst precursors are in solution, or via methods where at least one of the precursors is in at least partly in solid form, optionally but preferably while at least another one of the precursors is provided only in a solution form.
  • Providing a metal precursor at least partly in solid form can be achieved, for example, by providing a solution of the metal precursor that also includes solid and/or precipitated metal in the solution, such as in the form of suspended particles.
  • suitable hydrotreating catalysts are described in one or more of U.S. Patent Nos.
  • Preferred metal catalysts include cobalt/molybdenum (1-10% Co as oxide, 10-40% Mo as oxide), nickel/molybdenum (1-10% Ni as oxide, 10-40% Co as oxide), or nickel/tungsten (1-10% Ni as oxide, 10-40% W as oxide) on alumina.
  • hydrotreating conditions can include temperatures of 200°C to 450°C, or 3 l5°C to 425°C; pressures of 250 psig (-1.8 MPag) to 5000 psig (-34.6 MPag) or 500 psig (-3.4 MPag) to 3000 psig (-20.8 MPag), or 800 psig (-5.5 MPag) to 2500 psig (-17.2 MPag); Liquid Hourly Space Velocities (LHSV) of 0.2-10 hr 1 ; and hydrogen treat rates of 200 scf/B (35.6 m3/m3) to 10,000 scf/B (1781 m3/m3), or 500 (89 m3/m3) to 10,000 scf/B (1781 m3/m3).
  • LHSV Liquid Hourly Space Velocities
  • Hydrotreating catalysts are typically those containing Group 6 metals, and non-noble Group 8 - 10 metals, i.e., iron, cobalt and nickel and mixtures thereof. These metals or mixtures of metals are typically present as oxides or sulfides on refractory metal oxide supports. Suitable metal oxide supports include low acidic oxides such as silica, alumina or titania, preferably alumina.
  • preferred aluminas can correspond to porous aluminas such as gamma or eta having average pore sizes from 50 to 200 A, or 75 to 150 A; a surface area from 100 to 300 m2/g, or 150 to 250 m2/g; and/or a pore volume of from 0.25 to 1.0 cm3/g, or 0.35 to 0.8 cm3/g.
  • the supports are preferably not promoted with a halogen such as fluorine as this generally increases the acidity of the support.
  • the external surface area and the micropore surface area refer to one way of characterizing the total surface area of a catalyst. These surface areas are calculated based on analysis of nitrogen porosimetry data using the BET method for surface area measurement. See, for example, Johnson, M. F. L., Jour. Catal., 52, 425 (1978).
  • the micropore surface area refers to surface area due to the unidimensional pores of the zeolite in the catalyst. Only the zeolite in a catalyst will contribute to this portion of the surface area.
  • the external surface area can be due to either zeolite or binder within a catalyst.
  • the hydrotreating catalyst can be a bulk metal catalyst, or a combination of stacked beds of supported and bulk metal catalyst.
  • bulk metal it is meant that the catalysts are unsupported wherein the bulk catalyst particles comprise 30-100 wt. % of at least one Group 8 - 10 non-noble metal and at least one Group 6 metal, based on the total weight of the bulk catalyst particles, calculated as metal oxides and wherein the bulk catalyst particles have a surface area of at least 10 m2/g.
  • the bulk metal hydrotreating catalysts used herein comprise 50 to 100 wt %, and even more preferably 70 to 100 wt %, of at least one Group 8 - 10 non-noble metal and at least one Group 6 metal, based on the total weight of the particles, calculated as metal oxides.
  • the amount of Group 6 and Group 8 - 10 non-noble metals can be determined via TEM-EDX.
  • Bulk catalyst compositions comprising one Group 8 - 10 non-noble metal and two Group 6 metals are preferred. It has been found that in this case, the bulk catalyst particles are sintering-resistant. Thus the active surface area of the bulk catalyst particles is maintained during use.
  • the molar ratio of Group 6 to Group 8 - 10 non-noble metals ranges generally from 10: 1- 1 : 10 and preferably from 3 : 1-1 :3, In the case of a core-shell structured particle, these ratios of course apply to the metals contained in the shell. If more than one Group 6 metal is contained in the bulk catalyst particles, the ratio of the different Group 6 metals is generally not critical. The same holds when more than one Group 8 - 10 non-noble metal is applied.
  • the molybenum Tungsten ratio preferably lies in the range of 9: 1-1 :9.
  • the Group 8 - 10 non-noble metal comprises nickel and/or cobalt.
  • the Group 6 metal comprises a combination of molybdenum and tungsten.
  • combinations of nickel/molybdenum/tungsten and cobalt/molybdenum/tungsten and nickel/cobalt/molybdenum/tungsten are used. These types of precipitates appear to be sinter-resistant. Thus, the active surface area of the precipitate is maintained during use.
  • the metals are preferably present as oxidic compounds of the corresponding metals, or if the catalyst composition has been sulfided, sulfidic compounds of the corresponding metals.
  • the bulk metal hydrotreating catalysts used herein have a surface area of at least 50 m 2 /g and more preferably of at least 100 m 2 /g. In such aspects, it is also desired that the pore size distribution of the bulk metal hydrotreating catalysts be approximately the same as the one of conventional hydrotreating catalysts.
  • Bulk metal hydrotreating catalysts can have a pore volume of 0.05-5 ml/g, or of 0.1-4 ml/g, or of 0.1-3 ml/g, or of 0.1-2 tag determined by nitrogen adsorption. Preferably, pores smaller than 1 nm are not present.
  • the bulk metal hydrotreating catalysts can have a median diameter of at least 50 nm, or at least 100 nm.
  • the bulk metal hydrotreating catalysts can have a median diameter of not more than 5000 pm, or not more than 3000 pm. In an embodiment, the median particle diameter lies in the range of 0.1-50 pm and most preferably in the range of 0.5-50 pm.
  • hydrotreating catalysts include, but are not limited to, Albemarle KF 848, KF 860, KF 868, KF 870, KF 880, KF 861, KF 905, KF 907, and Nebula; Criterion LH- 21, LH-22, and DN-3552; Haldor-Topsoe TK-560 BRIM, TK-562 HyBRIM, TK-565 HyBRIM, TK-569 HyBRIM, TK-907, TK-911, and TK-951; Axens HR 504, HR 508, HR 526, and HR 544. Hydrotreating may be carried out by one catalyst or combinations of the previously listed catalysts. Second-Stage Processing - Hydrocracking or Conversion Conditions
  • a reaction system can include a high surface area, low acidity conversion catalyst as described herein.
  • a lubricant boiling range feed has a sufficiently low content of heteroatoms, such as a feed that corresponds to a“sweet” feed
  • the feed can be exposed to a high surface area, low acidity conversion catalyst as described herein without prior hydroprocessing to remove heteroatoms.
  • the conditions selected for conversion for lubricant base stock production can depend on the desired level of conversion, the level of contaminants in the input feed to the conversion stage, and potentially other factors.
  • hydrocracking and/or conversion conditions in a single stage, or in the first stage and/or the second stage of a multi-stage system can be selected to achieve a desired level of conversion in the reaction system.
  • Hydrocracking and/or conversion conditions can be referred to as sour conditions or sweet conditions, depending on the level of sulfur and/or nitrogen present within a feed and/or present in the gas phase of the reaction environment.
  • a feed with 100 wppm or less of sulfur and 50 wppm or less of nitrogen, preferably less than 25 wppm sulfur and/or less than 10 wppm of nitrogen represent a feed for hydrocracking and/or conversion under sweet conditions.
  • Feeds with sulfur contents of 250 wppm or more can be processed under sour conditions.
  • Feeds with intermediate levels of sulfur can be processed either under sweet conditions or sour conditions.
  • the initial stage hydrocracking catalyst can comprise any suitable or standard hydrocracking catalyst, for example, a zeolitic base selected from zeolite Beta, zeolite X, zeolite Y, faujasite, ultrastable Y (USY), dealuminized Y (Deal Y), Mordenite, ZSM-3, ZSM-4, ZSM-18, ZSM-20, ZSM-48, and combinations thereof, which zeolitic base can advantageously be loaded 20 with one or more active metals (e.g ., either (i) a Group 8 - 10 noble metal such as platinum and/or palladium or (ii) a Group 8 - 10 non-noble metal such nickel, cobalt, iron, and combinations thereof, and a Group 6 metal such as molybdenum and/or tungsten).
  • a zeolitic base selected from zeolite Beta, zeolite X, zeolite Y, faujasite, ultrastable Y (USY), dealumin
  • zeolitic materials are defined to include materials having a recognized zeolite framework structure, such as framework structures recognized by the International Zeolite Association. Such zeolitic materials can correspond to silicoaluminates, silicoaluminophosphates, aluminophosphates, and/or other combinations of atoms that can be used to form a zeolitic framework structure. In addition to zeolitic materials, other types of crystalline acidic support materials may also be suitable. Optionally, a zeolitic material and/or other crystalline acidic material may be mixed or bound with other metal oxides such as alumina, titania, and/or silica. Details on suitable hydrocracking catalysts can be found in US2015/715555.
  • a high surface area, low acidity conversion catalyst as described herein can optionally be used as part of the catalyst in an initial stage.
  • a hydrocracking process in a first stage can be carried out at temperatures of 200°C to 450°C, hydrogen partial pressures of from 250 psig to 5000 psig (-1.8 MPag to -34.6 MPag), liquid hourly space velocities of from 0.2 hr 1 to 10 hr 1 , and hydrogen treat gas rates of from 35.6 m3/m3 to 1781 m3/m3 (-200 SCF/B to -10,000 SCF/B),
  • the conditions can include temperatures in the range of 300°C to 450°C, hydrogen partial pressures of from 500 psig to 2000 psig (-3.5 MPag to -13.9 MPag), liquid hourly space velocities of from 0.3 hr 'to 5 hr 'and hydrogen treat gas rates of from 213 m3/m3 to 1068 m3/m3 (-1200 SCF/B to -6000 SCF/B).
  • a first reaction stage of the hydroprocessing reaction system can include one or more hydrotreating and/or hydrocracking catalysts.
  • a separator can then be used in between the first and second stages of the reaction system to remove gas phase sulfur and nitrogen contaminants.
  • One option for the separator is to simply perform a gas-liquid separation to remove contaminants.
  • Another option is to use a separator such as a flash separator that can perform a separation at a higher temperature.
  • a high temperature separator can be used, for example, to separate the feed into a portion boiling below a temperature cut point, such as about 350°F (l77°C) or about 400°F (204°C), and a portion boiling above the temperature cut point.
  • the naphtha boiling range portion of the effluent from the first reaction stage can also be removed, thus reducing the volume of effluent that is processed in the second or other subsequent stages.
  • any low boiling contaminants in the effluent from the first stage would also be separated into the portion boiling below the temperature cut point. If sufficient contaminant removal is performed in the first stage, the second stage can be operated as a“sweet” or low contaminant stage.
  • Still another option can be to use a separator between the first and second stages of the hydroprocessing reaction system that can also perform at least a partial fractionation of the effluent from the first stage.
  • the effluent from the first hydroprocessing stage can be separated into at least a portion boiling below the distillate (such as diesel) fuel range, a portion boiling in the distillate fuel range, and a portion boiling above the distillate fuel range.
  • the distillate fuel range can be defined based on a conventional diesel boiling range, such as having a lower end cut point temperature of at least about 350°F (l77°C) or at least about 400°F (204°C) to having an upper end cut point temperature of about 700°F (37l°C) or less or 650°F (343°C) or less.
  • the distillate fuel range can be extended to include additional kerosene, such as by selecting a lower end cut point temperature of at least about 300°F (l49°C).
  • the portion boiling below the distillate fuel fraction includes, naphtha boiling range molecules, light ends, and contaminants such as FhS. These different products can be separated from each other in any convenient manner. Similarly, one or more distillate fuel fractions can be formed, if desired, from the distillate boiling range fraction.
  • the portion boiling above the distillate fuel range represents the potential lubricant base stocks. In such aspects, the portion boiling above the distillate fuel boiling range is subjected to further hydroprocessing in a second hydroprocessing stage.
  • the portion boiling above the distillate fuel boiling range can correspond to a lubricant boiling range fraction, such as a fraction having a T5 or T10 boiling point of at least about 343°C.
  • a lubricant boiling range fraction such as a fraction having a T5 or T10 boiling point of at least about 343°C.
  • the lighter lube fractions can be distilled and operated in the catalyst dewaxing sections in a blocked operation where the conditions are adjusted to maximize the yield and properties of each lube cut.
  • a conversion process under sweet conditions can be performed under conditions similar to those used for a sour hydrocracking process, or the conditions can be different.
  • the conditions in a sweet conversion stage can have less severe conditions than a hydrocracking process in a sour stage.
  • Suitable conversion conditions for a non-sour stage can include, but are not limited to, conditions similar to a first or sour stage.
  • Suitable conversion conditions can include temperatures of about 550°F (288°C) to about 840°F (449°C), hydrogen partial pressures of from about 1000 psia to about 5000 psia ( ⁇ 6.9 MPa-a to 34.6 MPa-a), liquid hourly space velocities of from 0.05 hr 'to 10 hr 1 , and hydrogen treat gas rates of from 35.6 m3/m3 to 1781 m3/m3 (200 SCF/B to 10,000 SCF/B).
  • the conditions can include temperatures in the range of about 600°F (343°C) to about 8l5°F (435°C), hydrogen partial pressures of from about 1000 psia to about 3000 psia ( ⁇ 6.9 MPa-a to 20.9 MPa-a), and hydrogen treat gas rates of from about 213 m3/m3 to about 1068 m3/m3 (1200 SCF/B to 6000 SCF/B).
  • the LHSV can be from about 0.25 hr 'to about 50 hr 1 , or from about 0.5 hr 'to about 20 hr 1 , and preferably from about 1.0 hr 1 to about 4.0 hr 1 .
  • the same conditions can be used for hydrotreating, hydrocracking, and/or conversion beds or stages, such as using hydrotreating conditions for all beds or stages, using hydrocracking conditions for all beds or stages, and/or using conversion conditions for all beds or stages.
  • the pressure for the hydrotreating, hydrocracking, and/or conversion beds or stages can be the same.
  • a hydroprocessing reaction system may include more than one hydrocracking and/or conversion stage. If multiple hydrocracking and/or conversion stages are present, at least one hydrocracking stage can have effective hydrocracking conditions as described above, including a hydrogen partial pressure of at least about 1000 psia ( ⁇ 6.9 MPa-a). In such an aspect, other (subsequent) conversion processes can be performed under conditions that may include lower hydrogen partial pressures.
  • Suitable conversion conditions for an additional conversion stage can include, but are not limited to, temperatures of about 550°F (288°C) to about 840°F (449°C), hydrogen partial pressures of from about 250 psia to about 5000 psia (1.8 MPa-a to 34.6 MPa-a), liquid hourly space velocities of from 0.05 hr 'to 10 hr 1 , and hydrogen treat gas rates of from 35.6 m3/m3 to 1781 m3/m3 (200 SCF/5 B to 10,000 SCF/B).
  • the conditions for an additional conversion stage can include temperatures in the range of about 600°F (343°C) to about 8l5°F (435°C), hydrogen partial pressures of from about 500 psia to about 3000 psia (3.5 MPa-a to 20.9 MPa-a), and hydrogen treat gas rates of from about 213 m3/m3 to about 1068 m3/m3 (1200 SCF/B to 6000 SCF/B).
  • the LHSV can be from about 0.25 hr Ho about hr 1 , or from about 0.5 hr 1 to about 20 hr 1 , and preferably from about 1.0 hr 'to about 4.0 hr 1 .
  • catalytic dewaxing can be included as part of a second and/or sweet and/or subsequent processing stage, such as a processing stage that also includes conversion in the presence of a high surface area, low acidity catalyst.
  • the dewaxing catalysts are zeolites (and/or zeolitic crystals) that perform dewaxing primarily by isomerizing a hydrocarbon feedstock. More preferably, the catalysts are zeolites with a unidimensional pore structure.
  • Suitable catalysts include lO-member ring pore zeolites, such as EU-l, ZSM-35 (or ferrierite), ZSM-l l, ZSM-57, NU-87, SAPO-l 1, and ZSM-22.
  • Preferred materials are EU-2, EU-l 1, ZBM-30, ZSM-48, or ZSM- 23.
  • ZSM-48 is most preferred.
  • a zeolite having the ZSM-23 structure with a silica to alumina ratio of from 20: 1 to 40: 1 can sometimes be referred to as SSZ-32.
  • Other zeolitic crystals that are isostructural with the above materials include Theta-l, NU-10, EU-13, KZ-l, and NU-23.
  • U.S. Patent Nos. 7,625,478, 7,482,300, 5,075,269 and 4,585,747 further disclose dewaxing catalysts useful in the process of the present disclosure, all of which are incorporated herein by reference.
  • the dewaxing catalysts can further include a metal hydrogenation component.
  • the metal hydrogenation component is typically a Group 6 and/or a Group 8 - 10 metal.
  • the metal hydrogenation component is a Group 8 - 10 noble metal.
  • the metal hydrogenation component is Pt, Pd, or a mixture thereof.
  • the metal hydrogenation component can be a combination of a non-noble Group 8 - 10 metal with a Group 6 metal. Suitable combinations can include Ni, Co, or Fe with Mo or W, preferably Ni with Mo or W.
  • the metal hydrogenation component may be added to the dewaxing catalyst in any convenient manner.
  • One technique for adding the metal hydrogenation component is by incipient wetness. For example, after combining a zeolite and a binder, the combined zeolite and binder can be extruded into catalyst particles. These catalyst particles can then be exposed to a solution containing a suitable metal precursor.
  • metal can be added to the catalyst by ion exchange, where a metal precursor is added to a mixture of zeolite (or zeolite and binder) prior to extrusion.
  • the amount of metal in the dewaxing catalyst can be at least 0.1 wt % based on catalyst, or at least 0.15 wt %, or at least 0.2 wt %, or at least 0.25 wt %, or at least 0.3 wt %, or at least 0.5 wt % based on catalyst.
  • the amount of metal in the catalyst can be 20 wt % or less based on catalyst, or 10 wt % or less, or 5 wt % or less, or 2.5 wt % or less, or 1 wt % or less.
  • the amount of metal can be from 0.1 to 5 wt %, preferably from 0.1 to 2 wt %, or 0.25 to 1.8 wt %, or 0.4 to 1.5 wt %.
  • the metal is a combination of a non-noble Group 8 - 10 metal with a Group 6 metal
  • the combined amount of metal can be from 0.5 wt % to 20 wt %, or 1 wt % to 15 wt %, or 2.5 wt % to 10 wt %.
  • a dewaxing catalyst can be a catalyst with a low ratio of silica, to alumina.
  • the ratio of silica to alumina in the zeolite can be less than 200: 1, or less than 110: 1, or less than 100: 1, or less than 90: 1, or less than 80: 1.
  • the ratio of silica to alumina can be from 30: 1 to 200: 1, or 60: 1 to 110: 1, or 70: 1 to 100: 1.
  • a dewaxing catalyst can also include a binder.
  • the dewaxing catalysts used in process according to the invention are formulated using a low surface area binder, a low surface area binder represents a binder with a surface area of 100 m2/g or less, or 80 m2/g or less, or 70 m2/g or less, such as down to 40 m2/g or still lower.
  • the binder and the zeolite particle size can be selected to provide a catalyst with a desired ratio of micropore surface area to total surface area.
  • the micropore surface area corresponds to surface area from the unidimensional pores of zeolites in the dewaxing catalyst.
  • the total surface corresponds to the micropore surface area plus the external surface area. Any binder used in the catalyst will not contribute to the micropore surface area and will not significantly increase the total surface area of the catalyst.
  • the external surface area represents the balance of the surface area of the total catalyst minus the micropore surface area. Both the binder and zeolite can contribute to the value of the external surface area.
  • the ratio of micropore surface area to total surface area for a dewaxing catalyst will be equal to or greater than 25%.
  • a zeolite (or other zeolitic material) can be combined with binder in any convenient manner.
  • a bound catalyst can be produced by starting with powders of both the zeolite and binder, combining and mulling the powders with added water to form a mixture, and then extruding the mixture to produce a bound catalyst of a desired size. Extrusion aids can also be used to modify the extrusion flow properties of the zeolite and binder mixture.
  • a binder can be composed of two or more metal oxides can also be used.
  • Process conditions in a catalytic dewaxing zone can include a temperature of from 200 to 450°C, preferably 270 to 400°C, a hydrogen partial pressure of from 1.8 to 34.6 MPag (-250 to -5000 psi), preferably 4.8 to 20.8 MPag, a liquid hourly 5 space velocity of from 0.2 to 10 hr-l, preferably 0.5 to 3.0 hr-l, and a hydrogen circulation rate of from 35.6 to 1781 m3/m3 (-200 to -10,000 SCF/B), preferably 178 to 890.6 m3/m3 (-1000 to -5000 scf/B).
  • the conditions can include temperatures in the range of 600°F ( ⁇ 343°C) to 8l5°F ( ⁇ 435°C), hydrogen partial pressures of from 500 psig to 3000 psig (-3.5 MPag to -20.9 MPag), and hydrogen treat gas rates of from 213 m3/m3 to 1068 m3/m3 (-1200 SCF/B to -6000 SCF/B).
  • a hydrofmishing and/or aromatic saturation process can also be provided.
  • the hydrofmishing and/or aromatic saturation can occur prior to dewaxing and/or after dewaxing.
  • the hydrofmishing and/or aromatic saturation can occur either before or after fractionation. If hydrofmishing and/or aromatic saturation occurs after fractionation, the hydrofmishing can be performed on one or more portions of the fractionated product, such as being performed on one or more lubricant base stock portions. Alternatively, the entire effluent from the last conversion or dewaxing process can be hydrofmished and/or undergo aromatic saturation.
  • a hydrofinishing process and an aromatic saturation process can refer to a single process performed using the same catalyst.
  • one type of catalyst or catalyst system can be provided to perform aromatic saturation, while a second catalyst or catalyst system can be used for hydrofmishing.
  • a hydrofmishing and/or aromatic saturation process will be performed in a separate reactor from dewaxing or hydrocracking processes for practical reasons, such as facilitating use of a lower temperature for the hydrofmishing or aromatic saturation process.
  • an additional hydrofmishing reactor following a hydrocracking or dewaxing process but prior to fractionation could still be considered part of a second stage of a reaction system conceptually.
  • Hydrofmishing and/or aromatic saturation catalysts can include catalysts containing Group 6 metals, Group 8 - 10 metals, and mixtures thereof.
  • preferred metals include at least one metal sulfide having a strong hydrogenation function.
  • the hydrofmishing catalyst can include a Group 8 - 10 noble metal, such as Pt, Pd, or a combination thereof.
  • the mixture of metals may also be present as bulk metal catalysts wherein the amount of metal is 30 wt. % or greater based on catalyst.
  • Suitable metal oxide supports include low acidic oxides such as silica, alumina, silica-aluminas or titania, preferably alumina.
  • the preferred hydrofmishing catalysts for aromatic saturation will comprise at least one metal having relatively strong hydrogenation function on a porous support.
  • Typical support materials include amorphous or crystalline oxide materials such as alumina, silica, and silica-alumina.
  • the support materials may also be modified, such as by halogenation, or in particular fluorination.
  • the metal content of the catalyst is often as high as 20 weight percent for non-noble metals.
  • a preferred hydrofmishing catalyst can include a crystalline material belonging to the M41 S class or family of catalysts.
  • the M41 S family of catalysts are mesoporous materials having high silica content. Examples include MCM-41, MCM-48 and MCM-50.
  • a preferred member of this class is MCM-41. If separate catalysts are used for aromatic saturation and hydrofmishing, an aromatic saturation catalyst can be selected based on activity and/or selectivity for aromatic saturation, while a hydrofmishing catalyst can be selected based on activity for improving product specifications, such as product color and polynuclear aromatic reduction.
  • an aromatic saturation catalyst can be selected based on activity and/or selectivity for aromatic saturation
  • a hydrofmishing catalyst can be selected based on activity for improving product specifications, such as product color and polynuclear aromatic reduction.
  • U.S. Patent Nos. 7,686,949, 7,682,502 and 8,425,762 further disclose catalysts useful in the process of the present disclosure, all of which are incorporated herein by reference.
  • Hydrofmishing conditions can include temperatures from l25°C to 425°C, preferably l80°C to 280°C, total pressures from 500 psig ( ⁇ 3.4 MPag) to 3000 psig (-20.7 MPag), preferably 1500 psig (-10.3 MPag) to 2500 psig (-17.2 MPag), and liquid hourly space velocity (LHSV) from 0.1 hr-l to 5 hr-l, preferably 0.5 hr-l to 1.5 hr-l .
  • a second fractionation or separation can be performed at one or more locations after a second or subsequent stage.
  • a fractionation can be performed after hydrocracking in the second stage in the presence of the USY catalyst under sweet conditions. At least a lubricant boiling range portion of the second stage hydrocracking effluent can then be sent to a dewaxing and/or hydrofmishing reactor for further processing.
  • hydrocracking and dewaxing can be performed prior to a second fractionation.
  • hydrocracking, dewaxing, and aromatic saturation can be performed prior to a second fractionation.
  • aromatic saturation and/or hydrofmishing can be performed before a second fractionation, after a second fractionation, or both before and after.
  • a lubricant base stock product can be further fractionated to form a plurality of products.
  • lubricant base stock products can be made corresponding to a 2 cSt cut, a 4 cSt cut, a 6 cSt cut, and/or a cut having a viscosity higher than 6 cSt.
  • a lubricant base oil product fraction having a viscosity of at least 2 cSt can be a fraction suitable for use in low pour point application such as transformer oils, low temperature hydraulic oils, or automatic transmission fluid.
  • a lubricant base oil product fraction having a viscosity of at least 4 cSt can be a fraction having a controlled volatility and low pour point, such that the fraction is suitable for engine oils made according to SAE J300 in 0W- or 5W- or lOW-grades.
  • This fractionation can be performed at the time the diesel (or other fuel) product from the second stage is separated from the lubricant base stock product, or the fractionation can occur at a later time. Any hydrofmishing and/or aromatic saturation can occur either before or after fractionation.
  • a lubricant base oil product fraction can be combined with appropriate additives for use as an engine oil or in another lubrication service. Illustrative process flow schemes useful in this disclosure are disclosed in U.S.
  • a base oil constitutes the major component of the engine or other mechanical component oil lubricant composition of the present disclosure and typically is present in an amount from about 50 to about 99 weight percent, preferably from about 70 to about 95 weight percent, and more preferably from about 85 to about 95 weight percent, based on the total weight of the composition.
  • additives constitute the minor component of the engine or other mechanical component oil lubricant composition of the present disclosure and typically are present in an amount ranging from about less than 50 weight percent, preferably less than about 30 weight percent, and more preferably less than about 15 weight percent, based on the total weight of the composition.
  • base oils may be used if desired, for example, a base stock component and a co-base stock component.
  • the co-base stock component is present in the lubricating oils of this disclosure in an amount from about 1 to about 99 weight percent, preferably from about 5 to about 95 weight percent, and more preferably from about 10 to about 90 weight percent, based on the total weight of the composition.
  • the low-viscosity and the high-viscosity base stocks are used in the form of a base stock blend that comprises from 5 to 95 wt. % of the low-viscosity base stock and from 5 to 95 wt. % of the high-viscosity base stock. Preferred ranges include from 10 to 90 wt.
  • the base stock blend can be present in the engine or other mechanical component oil lubricant composition from 15 to 85 wt. % of the low- viscosity base stock and from 15 to 85 wt. % of the high-viscosity base stock, preferably from 20 to 80 wt. % of the low-viscosity base stock and from 20 to 80 wt. % of the high-viscosity base stock, and more preferably from 25 to 75 wt. % of the low-viscosity base stock and from 25 to 75 wt. % of the high-viscosity base stock, based on the total weight of the oil lubricant composition.
  • a low-viscosity, medium viscosity and/or high viscosity base stock is present in the engine or other mechanical component oil lubricant composition in an amount of from about 50 to about 99 weight percent, preferably from about 70 to about 95 weight percent, and more preferably from about 85 to about 95 weight percent, based on the total weight of the composition.
  • the formulated lubricating oil useful in the present disclosure may contain one or more of the other commonly used lubricating oil performance additives including but not limited to antiwear additives, detergents, dispersants, viscosity modifiers, corrosion inhibitors, rust inhibitors, metal deactivators, extreme pressure additives, anti-seizure agents, wax modifiers, other viscosity modifiers, fluid-loss additives, seal compatibility agents, lubricity agents, anti-staining agents, chromophoric agents, defoamants, demulsifiers, emulsifiers, densifiers, wetting agents, gelling agents, tackiness agents, colorants, and others.
  • antiwear additives detergents, dispersants, viscosity modifiers, corrosion inhibitors, rust inhibitors, metal deactivators, extreme pressure additives, anti-seizure agents, wax modifiers, other viscosity modifiers, fluid-loss additives, seal compatibility agents, lubricity agents, anti-stain
  • additives When lubricating oil compositions contain one or more additives, the additive(s) are blended into the composition in an amount sufficient for it to perform its intended function.
  • additives are typically present in lubricating oil compositions as a minor component, typically in an amount of less than 50 weight percent, preferably less than about 30 weight percent, and more preferably less than about 15 weight percent, based on the total weight of the composition.
  • Additives are most often added to lubricating oil compositions in an amount of at least 0.1 weight percent, preferably at least 1 weight percent, more preferably at least 5 weight percent. Typical amounts of such additives useful in the present disclosure are shown in Table 1 below.
  • additives are all commercially available materials. These additives may be added independently but are usually precombined in packages which can be obtained from suppliers of lubricant oil additives. Additive packages with a variety of ingredients, proportions and characteristics are available and selection of the appropriate package will take the requisite use of the ultimate composition into account.
  • Lubricant compositions including the base stocks of the instant disclosure have improved oxidative stability relative to conventional lubricant compositions including Group III base stocks.
  • the low temperature and oxidation performance of lubricating oil base stocks in formulated lubricants are determined from MRV (mini-rotary viscometer) for low temperature performance measured by ASTM D4684, or for oxidation performance measured by oxidation stability time measured by pressure differential scanning calorimetry (CEC-L-85, which is the equivalent of ASTM D6186).
  • the lubricating oils of this disclosure are particularly advantageous as passenger vehicle engine oil (PVEO) products.
  • the lubricating oil base stocks of this disclosure provide several advantages over typical conventional lubricating oil base stocks including, but not limited to, improved oxidation performance such as oxidation induction time measured by pressure differential scanning calorimetry (CEC-L-85, which is the equivalent of ASTM D6186) in engine oils.
  • improved oxidation performance such as oxidation induction time measured by pressure differential scanning calorimetry (CEC-L-85, which is the equivalent of ASTM D6186) in engine oils.
  • the lubricant compositions can be employed in the present disclosure in a variety of lubricant-related end uses, such as a lubricant oil or grease for a device or apparatus requiring lubrication of moving and/or interacting mechanical parts, components, or surfaces.
  • Useful apparatuses include engines and machines.
  • the lube base stocks of the present disclosure are suitable for use in the formulation of automotive crank case lubricants, automotive gear oils, transmission oils, many industrial lubricants including circulation lubricant, industrial gear lubricants, grease, compressor oil, pump oils, refrigeration lubricants, hydraulic lubricants and metal working fluids.
  • the lube base stocks of this disclosure may be derived from renewable sources; such base stocks may qualify as sustainable product and can meet "sustainability" standards set by industry groups or government regulations.
  • Feeds A and B were processed according to the process described in the present disclosure and depicted in Figure 1.
  • the feeds having the properties described in Table 3 were processed to produce the Group III base stocks of the present disclosure.
  • the intermediate feeds having the properties described in Table 4 were subjected to Stage 2 hydroprocessing to produce the Group III base stocks of the present disclosure.
  • Feed A represented a raffinate feed with ⁇ 67 VI
  • Feed B represented a high- quality VGO feed with ⁇ 92 VI.
  • Catalyst A Commercially available hydrotreating catalyst that consists of NiMo supported on AI2O3, for example, Criterion KF-868
  • Catalyst B Commercially available hydrotreating catalyst that consists of a bulk NiMoW oxide, for example, ExxonMobil Nebula-20.
  • Catalyst C 0.6 wt% Pt on USY, bounded with Versal-300 alumina.
  • the USY had a ratio of silica to alumina (S1O2 : AI2O3) of roughly 75 : 1.
  • USY is a zeolite with l2-member ring pore channels.
  • Catalyst D Commercially available dewaxing catalyst that consists of Pt supported on ZSM-48, such as ExxonMobil MSDW.
  • Catalyst E Commercially available hydrofinishing catalyst that consists of Pt/Pd supported on MCM-41, such as such as ExxonMobil MaxSat.
  • Feed A properties are shown in Table 3.
  • the feed was hydrotreated at two conversion levels, namely 17% and 33%, and then blended (44.6/55.4) to give the product with properties shown in Table 3.
  • the amount of dry wax was corrected to the expected value at a pour point of -l8°C based on a correction of -0.33 wt% / °C of pour point.
  • the viscosity index was corrected to the expected value at a pour point of -l8°C based on a correction of 0.33 VI / °C of pour point.
  • Feed A having a solvent dewaxed oil feed viscosity index of about 67 was processed through the first stage which is primarily a hydrotreating unit which boosts viscosity index (VI) and removes sulfur and nitrogen. Both catalysts A and B were loaded in the same reactor, with the feed contacting catalyst A first. The hydrotreated feed was followed by a stripping section where light ends and diesel were removed. During Stage 1 hydrotreating, Feed A was split and underwent conversion at two different levels (labeled“low” and“high” conversion). The properties of the intermediate feeds (Al and A2) are shown in Table 4. The heavier lube fractions from Al and A2 then entered the second stage where hydrocracking, dewaxing, and hydrofmishing were performed.
  • V viscosity index
  • Processing conditions for each of the steps described above - hydrotreating, hydrocracking, catalytic dewaxing, and hydrofmishing - were tuned based on the desired conversion and VI of the final base stock products.
  • the conditions used to manufacture the Group III base stocks that are the subject of this disclosure can be found in Table 5.
  • the extent of 700°F+ conversion in the first hydrotreating stage ranged from 20 to 40%, and processing conditions in the first stage included a temperature from 635°F to 725°F; hydrogen partial pressure from 500 psig to 3000 psig; liquid hourly space velocity from 0.5 hr 1 to 1.5 hr 1 ; and a hydrogen circulation rate from 3500 scf/bbl to 6000 scf/bbl.
  • the second stage which consisted of hydrocracking, catalytic dewaxing, and hydrofmishing, was carried out in a single reactor with a hydrogen partial pressure of 300 psig to 5000 psig; a hydrogen circulation rate from 1000 scf/bbl to 6000 scf/bblCatalysts C, D, and E were loaded into the same reactor in the second stage and the feed contacted them in the order C, D, E. Process parameters were tuned to achieve a desired 700°F+ conversion of 15-70%.
  • Processing conditions in the hydrocracking step included a temperature from 250°F to 700°F; a liquid hourly space velocity from 0.5 hr 1 to 1.5 hr 1 .
  • Processing conditions in the catalytic dewaxing step included a temperature from 250°F to 660°F; and liquid hourly space velocity from 1.0 hr 1 to 3.0 hr 1 .
  • Processing conditions in the hydrotreating step included a temperature from 250°F to 480°F; and liquid hourly space velocity from 0.5 hr 1 to 1.5 hr 1 .
  • Feed B The properties of Feed B are also shown in Table 3.
  • Feed B was processed through the first stage hydrotreating unit, which boosts viscosity index (VI) and removes sulfur and nitrogen.
  • the hydrotreated feed was followed by a stripping section where light ends and diesel were removed. Both catalysts A and B were loaded in the same reactor, with the feed contacting catalyst A first.
  • Stage 1 hydrotreating Feed B was subjected to one conversion level and displayed the properties shown in Table 4.
  • the heavier lube fraction from this intermediate then entered the second stage where hydrocracking, dewaxing, and hydrofmishing were performed.
  • Table 4 Various processing conditions for each of these steps, shown in Table 4, were used to produce six Group III base stocks, B1-B6, which are shown in Tables 6-8. This combination of feed and process has been found to produce a base stock with unique compositional characteristics.
  • the extent of 700°F+ conversion in the first hydrotreating stage ranged from 20 to 40%, and processing conditions in the first stage included a temperature from 635°F to 725°F; hydrogen partial pressure from 500 psig to 3000 psig; liquid hourly space velocity from 0.5 hr 1 to 1.5 hr 1 , preferably from 0.5 hr 1 to 1.0 hr l, most preferably from 0.7 hr 1 to 0.9 hr ; and a hydrogen circulation rate from 3500 scf/bbl to 6000 scf/bbl.
  • the second stage which consisted of hydrocracking, catalytic dewaxing, and hydrofmishing, was carried out in a single reactor with a hydrogen partial pressure of 300 psig to 5000 psig; a hydrogen circulation rate from 1000 scf/bbl to 6000 scf/bblCatalysts C, D, and E were loaded into the same reactor in the second stage and the feed contacted them in the order C, D, E. Process parameters were tuned to achieve a desired 700°F+ conversion of 15-70%, preferably 15- 55%.
  • Processing conditions in the hydrocracking step included a temperature from 250°F to 700°F; and a liquid hourly space velocity from 0.5 hr 1 to 1.5 hr 1 .
  • Processing conditions in the catalytic dewaxing step included a temperature from 250°F to 660°F; and liquid hourly space velocity from 1.0 hr 1 to 3.0 hr 1 .
  • Processing conditions in the hydrotreating step included a temperature from 250°F to 480°F; and liquid hourly space velocity from 0.5 hr 1 to 1.5 hr 1 .
  • a high quality vacuum gas oil feedstock was processed according to the conventional base stock hydroprocessing scheme shown by Figure 1.
  • This conventional hydroprocessing scheme used widely commercially available catalysts, and is meant to be representative of conventionally hydroprocessed Group III base stocks.
  • Base stocks produced by this method are noted in the tables and figures as Kl and K2. Additionally, the properties of several commercially available base stocks can be found in the tables and figures below and are labeled as Commercial Comparative examples.
  • the Commercial Comparative base stocks are all widely commercially available and are representative of the range of Group III products offered on the market today. Taken together, these commercial base stocks and base stocks Kl and K2 are used to illustrate the uniqueness of the inventive base stocks that are the subject of this disclosure.
  • lubricating oil base stock compositions were determined using a combination of advanced analytical techniques including gas chromatography mass spectrometry (GCMS), supercritical fluid chromatography (SFC), and carbon- 13 nuclear magnetic resonance ( 13 C NMR).
  • GCMS gas chromatography mass spectrometry
  • SFC supercritical fluid chromatography
  • 13 C NMR carbon- 13 nuclear magnetic resonance
  • Viscosity index was determined according to ASTM method D2270. VI is related to kinematic viscosities measured at 40°C and l00°C using ASTM Method D445. Note that these will be abbreviated as KV100 and KV40. Pour point was measured by ASTM D5950.
  • the unique compositional character of the lube base stocks of the present disclosure may be determined by the amount and distribution of naphthenes, branched carbons, straight-chain carbons and terminal carbons as determined by GCMS, as shown in Figures 5-8.
  • the GCMS results are corrected by SFC; however, it was found that the 2R+N/1RN ratios are identical regardless of whether or not the GCMS results were corrected by SFC.
  • SFC was conducted on a commercial supercritical fluid chromatograph system.
  • the system was equipped with the following components: a high pressure pump for delivery of the supercritical carbon dioxide mobile phase; temperature controlled column oven; auto-sampler with high pressure liquid injection valve for delivery of sample material into mobile phase; flame ionization detector; mobile phase splitter (low dead volume tee); back pressure regulator to keep the CO2 in a supercritical phase; and a computer and data system for control of components and recording of data signal.
  • ⁇ 75 mg of sample was diluted in 2 mL of toluene and loaded into standard septum cap autosampler vials. The sample was introduced via a high pressure sampling valve. SFC separation was performed using multiple commercial silica packed columns (5 pm with either 60 or 30 A pores) connected in series (250 mm in length and either 2 mm or 4 mm inner diameter). Column temperature was typically held at 35 or 40°C. For analysis, the column head pressure was typically 250 bar. Liquid CO2 flow rates were typically 0.3 mL/minute for 2 mm inner diameter (i.d.) columns or 2.0 mL/minute for 4 mm i.d. columns.
  • the samples run were mostly all saturate compounds that eluted before the solvent (here, toluene).
  • the SFC FID signal was integrated into paraffin and naphthenic regions.
  • a chromatograph was used to analyze lube base stocks for splits of total paraffins and total naphthenes. The paraffin/naphthene ratio was calibrated using a variety of standard materials.
  • SFC was conducted on a commercial supercritical fluid chromatograph system.
  • the system was equipped with the following components: a high pressure pump for delivery of the supercritical carbon dioxide mobile phase; temperature controlled column oven; auto-sampler with high pressure liquid injection valve for delivery of sample material into mobile phase; flame ionization detector; mobile phase splitter (low dead volume tee); back pressure regulator to keep the CO2 in a supercritical phase; and a computer and data system for control of components and recording of data signal.
  • ⁇ 75 mg of sample was diluted in 2 mL of toluene and loaded into standard septum cap autosampler vials. The sample was introduced via a high pressure sampling valve.
  • SFC separation was performed using multiple commercial silica packed columns (5 pm with either 60 or 30 A pores) connected in series (250 mm in length and either 2 mm or 4 mm inner diameter). Column temperature was typically held at 35 or 40°C. For analysis, the column head pressure was typically 250 bar. Liquid CO2 flow rates were typically 0.3 mL/minute for 2 mm inner diameter (i.d.) columns or 2.0 mL/minute for 4 mm i.d. columns. The samples run were mostly all saturate compounds that eluted before the solvent (here, toluene). The SFC FID signal was integrated into paraffin and naphthenic regions. A chromatograph was used to analyze lube base stocks for splits of total paraffins and total naphthenes. The paraffin/naphthene ratio was calibrated using a variety of standard materials.
  • GCMS GCMS used herein, approximately 50 milligram of a base stock sample was added to a standard 2 milliliter auto-sampler vial and diluted with methylene chloride solvent to fill the vial. Vials were sealed with septum caps. Samples were run using an Agilent 5975C GCMS (Gas Chromatography Mass Spectrometer) equipped with an auto-sampler. A non-polar GC column was used to simulate distillation or carbon number elution characteristics off the GC. The GC column used was a Restek Rxi -lms. The column dimensions were 30 meters in length x 0.32 mm internal diameter with a 0.25 micron film thickness for the stationary phase coating.
  • the GC column was connected to the split / split-less injection port (held at 360°C and operated in split-less mode) of the GC.
  • Helium in constant pressure mode ( ⁇ 7 PSI) was used for GC carrier phase.
  • the outlet of the GC column was run into mass spectrometer via a transfer line held at a 350°C.
  • the temperature program for the GC column is a follows: 2 minute hold at l00°C, program at 5°C per minute, 30 minute hold at 350°C.
  • the mass spectrometer was operated using an electron impact ionization source (held at 250°C) and operated using standard conditions (70 eV ionization). Instrumental control and mass spectral data acquisition were obtained using the Agilent Chemstation software. Mass calibration and instrument tuning performance validated using vendor supplied standard based on instrument auto tune feature.
  • GCMS retention times for samples were determined relative to a normal paraffin retention based on analysis of standard sample containing known normal paraffins. Then the mass spectrum was averaged.
  • Samples were prepared for 13 C NMR by dissolving 25-30 wt% sample in CDCb with 7% Cr(III)-acetylacetonate added as a relaxation agent. NMR experiments were performed on a JEOL ECS NMR spectrometer for which the proton resonance frequency was 400 MHz. Quantitative 13 C NMR experiments were performed at 27°C using an inverse gated decoupling experiment with a 45° flip angle, 6.6 seconds between pulses, 64k data points and 2400 scans. All spectra were referenced to trimethylsiloxane (TMS) at 0 ppm. Spectra were processed with 0.2-1 Hz of line broadening and a baseline correction was applied prior to manual integration.
  • TMS trimethylsiloxane
  • straight-chain carbons are defined as the sum of the alpha, beta, gamma, delta, and epsilon peaks.
  • Branched carbons are defined as the sum of pendant methyl, pendant ethyl, and pendant propyl groups.
  • Terminal carbons are defined as the sum of the terminal methyl, terminal ethyl, and terminal propyl groups.
  • Examples of Group III low viscosity lubricating oil base stocks of this disclosure and having a KV100 in the range of 4-5 cSt are shown in Table 6.
  • the low viscosity lubricating oil base stocks of this disclosure are compared with typical Group III low viscosity base stocks having the same viscosity range.
  • the Group III base stocks with unique compositions produced by the advanced hydrocracking process exhibit a range of base stock KV100 from 4 cSt to 12 cSt.
  • the differences in composition include a difference in the ratio of multi-ring naphthenes to single ring naphthenes (2R+N/1RN), the ratio of branched chain carbons to straight chain carbons (BC/SC) and the ratio of branched chain carbons to terminal carbons (BC/TC), as shown in Tables 6-8, as well as Figures 3-8.
  • Table 6
  • Figures 5 and 6 and Tables 6-8 demonstrate the unique area of compositional space demarcated by light neutral (LN) base stocks of the present disclosure.
  • Figure 5 depicts the naphthene ratio (measured by GCMS) versus degree of branching (measured by NMR), and demonstrates that the base stocks of the present disclosure occupy a unique region of the plot. This region, marked by dashed lines, occurs at values of ⁇ 0.52 for naphthene ratio and ⁇ 0.21 for degree of branching.
  • Figure 6 depicts the naphthene ratio (measured by GCMS) vs. nature of branching (measured by NMR).
  • the phrase“nature of branching” indicates the ratio of branched carbons to terminal carbons, where higher ratios indicate more internal branching. Lower ratios here indicate more branching near the ends of the molecules (terminal C).
  • the base stocks of the present disclosure in Figure 6 occupy a unique region of the plot denoted by dashed lines.
  • Figures 7 and 8 demonstrate the unique area of compositional space demarcated by the MN base stocks.
  • Figure 7 demonstrates the naphthene ratio (measured by GCMS) versus degree of branching (measured by NMR), and demonstrates that the inventive base stocks occupy a unique region of the plot. This region, marked by dashed lines, occurs at values of ⁇ 0.59 for naphthene ratio and ⁇ 0.216 for degree of branching.
  • Figure 8 illustrates the naphthene ratio (measured by GCMS) vs. nature of branching (measured by NMR).
  • the phrase“nature of branching” indicates the ratio of branched carbons to terminal carbons, where higher ratios indicate more internal branching. Lower ratios indicate more branching near the ends of the molecules (terminal carbons).
  • the region marked with dashed lines occur at values of ⁇ 0.59 naphthene ratio and ⁇ 0.23 for degree of branching.
  • the base stocks of the present disclosure now occupy a region of the plot denoted by a line (rather than a box).
  • a 10W-40 heavy-duty engine oil (HDEO) formulation was used as the“parent” formulation.
  • the formulation chosen uses an additive package formulated for ACEA E6, a 9 SSI styrene-isoprene VM, and a light neutral co-base stock. Yubase 4 was selected for that purpose.
  • the formulation is provided in Table 9, and low- temperature results are provided in Table 5.
  • the HDEOs were tested for low- temperature performance using a mini-rotary viscometer (MRV) at -30°C, according to ASTM D4684.
  • Table 9 illustrates a formulation used to test Group III MN base stocks in HDEOs. Low- temperature performance data (MRV) are shown in Table 5.
  • PCMO passenger car motor oil
  • a“parent” 0W-20 formulation was chosen that uses a market-general GF-5 additive package, 50 SSI high ethylene olefin copolymer (HE OCP) VM, and a polymethacrylate (PMA) PPD.
  • the formulation is provided below in Table 10. The formulation strategy entailed keeping all non-base-stock components constant between blends; only the Group III base stock was varied.
  • the PCMOs were tested for low temperature performance in the MRV at -40°C (ASTM D4684).
  • Figure 9 demonstrates that the MRV behavior of lubrication compositions prepared with light neutral (LN) base stocks blended into 0W-20 PCMOs is roughly uncorrelated to pour point.
  • LN light neutral
  • One notable exception is the sample with a relatively high pour point (-8°C), which showed an MRV result that was essentially solid (>400,000 mPa.s) at the tested temperature. This point was omitted from Figure 9 for clarity.
  • Figure 10 shows the MRV behavior of lubrication compositions prepared with light neutral (LN) base stocks blended into 0W-20 PCMOs as a function of the naphthene ratio. ETnlike the plots of MRV viscosity vs. pour point, the naphthene ratio demonstrates clear differences for lubrication compositions prepared with base stocks of the present disclosure vs. lubrication compositions prepared with conventionally hydroprocessed base stocks.
  • the equations for the lines in Figure 10 are:
  • Figure 11 shows that the MRV behavior of lubrication compositions prepared with medium neutral (MN) base stocks blended into 10W-40 HDEOs is roughly uncorrelated to pour point. This is a similar conclusion to that reached for the LN base stocks.
  • Figure 12 shows the MRV behavior of lubrication compositions prepared with medium neutral (MN) base stocks blended into 10W-40 HDEOs as a function of the naphthene ratio. Unlike the plots of MRV viscosity vs. pour point, the naphthene ratio demonstrates clear differences for lubrication compositions prepared with base stocks of the present disclosure vs. conventionally hydroprocessed base stocks.
  • compositions line: VI 39054 - 44l25*(2R+N/lRN)
  • HDEO lubricant compositions prepared above in Example 4 were tested for oxidation performance using oxidation induction time (OIT) measured by pressure differential scanning calorimetry (CEC-L-85).
  • OIT oxidation induction time
  • CEC-L-85 The ASTM equivalent of CEC-L-85 is D6186.
  • OIT was measured by holding the sample temperature constant at l75°C for 2 hours, at which point the test was terminated. Samples that did not oxidize in the two hour testing period are indicated with “>120” in the“OIT” column of Table 11.
  • Figures 13 and 14 are graphs illustrating oxidation induction time (OIT) vs. viscosity index (VI).
  • OIT oxidation induction time
  • VI viscosity index
  • Figures 15 and 16 are plots illustrating OIT vs. 2R+N/1RN (as measured by SFC- corrected GCMS).
  • Figure 16 shows the same data as Figure 15, but with a smaller y-axis range. Both plots indicate that lubricating compositions of the present disclosure perform much better in OIT than lubricating compositions prepared with other base stocks.
  • a lubricating composition comprising: a Group III base stock, the Group III base stock having at least 90 wt.% saturated hydrocarbons, a kinematic viscosity at l00°C (KV100) of 4.0 cSt to 12.0 cSt, a viscosity index of from 120 to 133; and a ratio of multi-ring naphthenes to single ring naphthenes (2R+N/1RN) of less than 0.43; and an effective amount of one or more lubricant additives; wherein the lubricating composition has an oxidation induction time greater than 120 minutes.
  • KV100 kinematic viscosity at l00°C
  • a passenger car motor oil composition comprising: a Group III base stock, the Group
  • III base stock having at least 90 wt.% saturated hydrocarbons, a kinematic viscosity at l00°C of from 4.0 cSt up to 5.0 cSt, a viscosity index of from 120 to less than 140; and a ratio of multi-ring naphthenes to single ring naphthenes (2R+N/1RN) of less than 0.45; and an effective amount of one or more lubricant additives; wherein the oil composition has an oxidation induction time greater than 120 minutes.
  • a heavy duty diesel engine lubricating oil composition comprising: a Group III base stock, the Group III base stock having at least 90 wt.% saturated hydrocarbons, a kinematic viscosity at l00°C of from 5.5 cSt up to 7.0 cSt, a viscosity index of from 120 to less than 144; and a ratio of multi-ring naphthenes to single ring naphthenes (2R+N/1RN) of less than 0.56; and an effective amount of one or more lubricant additives; wherein the lubricating oil composition has an oxidation induction time greater than 120 minutes.
  • a lubricating composition comprising: a Group III base stock, the Group III base stock having at least 90 wt.% saturated hydrocarbons, a kinematic viscosity at l00°C of 4.0 cSt to 5.0 cSt, a viscosity index of 120 to 140, a ratio of multi-ring naphthenes to single ring naphthenes (2R+N/1RN) of less than 0.52, and a ratio of branched carbons to straight chain carbons (BC/SC) less than or equal to 0.21; and an effective amount of one or more lubricant additives; wherein the lubricating composition has an oxidation induction time greater than 120 minutes.
  • the base stock has a ratio of branched chain carbons to terminal carbons (BC/TC) less than or equal to 2.1.
  • a lubricating composition comprising: a Group III base stock, the Group III base stock having at least 90 wt.% saturated hydrocarbons, a kinematic viscosity at l00°C of 5.0 cSt to 12.0 cSt, a viscosity index of 120 to 140, a ratio of multi-ring naphthenes to single ring naphthenes (2R+N/1RN) of less than 0.59; and a ratio of branched carbons to straight chain carbons (BC/SC) less than or equal to 0.26; and an effective amount of one or more lubricant additives; wherein the lubricating composition has an oxidation induction time greater than 120 minutes.
  • a lubricating composition comprising: a Group III base stock having: at least 90 wt.% saturated hydrocarbons; kinematic viscosity at l00°C (KV100) of 4.0 cSt to 5.0 cSt; a viscosity index of from 120 to 140; a ratio of multi-ring naphthenes to single ring naphthenes (2R+N/1RN) of less than 0.45; and an effective amount of one or more lubricant additives; wherein the lubricating composition has an oxidation induction time greater than 120 minutes.
  • KV100 kinematic viscosity at l00°C
  • a lubricating composition comprising a Group III base stock having: at least 90 wt.% saturated hydrocarbons; kinematic viscosity at l00°C (KV100) of 5.0 cSt to 12.0 cSt; a viscosity index of from 120 to 144; a ratio of multi-ring naphthenes to single ring naphthenes (2R+N/1RN) of less than 0.56; and an effective amount of one or more lubricant additives; wherein the lubricating composition has an oxidation induction time greater than 120 minutes.
  • KV100 kinematic viscosity at l00°C

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