A METHOD FOR TREATING PETROLEUM OR NATURAL GAS

FIELD OF THE INVENTION

The present invention relates to a method for treating petroleum or natural gas, a petroleum or a natural gas obtainable by such method, a method for preparing an addition agent for petroleum or natural gas and an addition agent for petroleum or natural gas obtainable by such method.

BACKGROUND OF THE INVENTION

Sulfur and sulfur-containing compounds in crude oil result in degradation of oil quality (API gravity, viscosity, salts, bottom sediments, and water).

Such sulfur-containing compounds, particularly sulfides, and especially soluble sulfides (H2S, HS , S ² , or combinations thereof), frequently detected in petroleum and oil field brines as a consequence of the activities of sulfate-reducing bacteria (SRB) pose serious problems due to their toxicity, odor, corrosive nature, and potential for well bore plugging. Current treatment technologies for sulfide removal include physical/chemical methods such as stripping with steam or flue gas, air oxidation, and precipitation. However, microbial treatment may be a more efficient and cost-effective alternative for reducing sulfide levels.

In order to remove sulfur-containing products from crude oil, naphtha and derivatives, attempts have been made long since to find microbiological procedures. E.g., as can be seen in a comprehensive paper published in 1978 by Malik (ref. (1 ) at the end of the present specification), Desulfovibrio desulfuricans, Arthrobacter sp., Pseudomonas sp., Pseudomonas aeruginosa, Acinetobacter sp., Rhizobium sp. were researched.

EP 0 409 314 A1 discloses a stable, single-phased solution of water-in-oil microemulsions that contain microorganisms and/or parts thereof are described. They are obtained by adding to crude oil and/or at least one product of the refining of same an aqueous concentrated solution of microorganisms and/or parts thereof, in such a way that said aqueous solution is solubilized in crude oil or the refined product and that the blend thus obtained has the form of a stable, single-phased solution. GB 2 303 127 A discloses a process for oxidation of sulfide compounds in brines, oil and/or gases by contact with a bacterial culture preferably containing a Campylobacter species. The brine, oil or gas may also contain a nitrate.

OBJECTIVE OF THE INVENTION

It is an objective of the present invention to provide a method for treating petroleum, petroleum fractions or natural gas in order to reduce sulfur, particularly sulfides.

SUMMARY OF THE INVENTION

This objective is solved by a method according to claim 1 for treating petroleum, a petroleum fraction or natural gas. In further aspects, laid down in further independent claims, the invention also provides with a petroleum or a natural gas, obtainable by such method, a method for preparing an addition agent for petroleum, petroleum fractions or natural gas, wherein the addition agent can be used for (treating) petroleum, a petroleum fraction, or natural gas, particularly for reducing sulfur or sulfur compounds, and an addition agent for petroleum or natural gas which is obtainable by such method.

The present invention provides with a method (also called process) for treating, particularly for reducing sulfur and sulfur compounds in petroleum, a petroleum fraction, or natural gas, the process comprising:

Adding

a) a first component which is selected from material, particularly roots, of a plant of the genus Glycyrrhiza, and/or an arbuscular mycorrhizal fungi, and b) a second component which is selected from a plant material or -ingredient of a plant of the family Elaeocarpaceae,

to the petroleum, petroleum fraction, or natural gas.

This invention may be called a chemo-biological process, or a fermentation process, for treating petroleum (also called crude oil), petroleum fractions and natural gas.

In petroleum and petroleum fractions the invention, in general or specific embodiments, leads to one or more of the following results for the petroleum and/or petroleum fractions: - reduces sulfate-reducing bacteria (SRB)

- reduces sulfur and sulfur compounds

- lowers particularly the hhS concentration, preferably to harmless levels (<10 ppm), or even substantially eliminates hhS

- reduces salts

- reduces heavy metals content

- increases API gravity, either in well reservoirs or in processing facilities (upstream or downstream)

- decreases viscosity

- increases energy density of petroleum or petroleum fractions

- generates raffinates with high API gravity, that are, inter alia, environment-friendly

- leads to decrease of corrosion in processing facilities and application apparatus, e.g. gas turbines

- decreases corrosion, e.g. in pipelines and tanks, particularly microbially influenced corrosion (MIC)

- prevents or reduces biofouling

In natural gas, the invention, in general or specific embodiments, leads to one or more of the following results:

- reduces sulfur (sweetens sour gas). Sulfur or sulfur compounds particularly precipitate from the gas

- increases the heat rate

- decreases the specific gravity

- increases volume

- lowers the hhS concentration, preferably to harmless levels (<10 ppm)

- decreases corrosion in pipelines or storage tanks

The invention, in general or specific embodiments, provides with one or more of the following benefits:

- is suitable for oil well intervention and increases production volume

- increases refinery process gain of the petroleum and/or the petroleum fractions and increases the whole efficiency, particularly the production rate and light/medium fraction yields, of the refinery plant

- reduces transportation energy needs and reduces crude oil shipping costs - reduces equipment mechanical failure due to cold and hot corrosion

- facilitates the concept of‘anti-degradation’ and‘anti-depletion’ of crude oil global

reserves

- direct production of petroleum raffinates with high API gravity

- can be used as a clean fuel for combustion engines as a more viable energy source that decreases fuel consumption and reduces emissions

- reduces the environmental impact in terms of emissions and greenhouse gases of petroleum or natural gas production, processing and product consumption through its efficiency increases and purity

Exemplary and non-limiting petroleum fractions the method can be applied to are liquefied petroleum gas (LPG), liquefied natural gas (LNG), gasoline (petrol), naphtha, kerosene, diesel fuel, fuel oils, lubricating oils, paraffin wax, asphalt, heavy fuel oils, tar, bitumen.

The process can be applied upstream in subterranean reservoirs and at surficial recovery plants as well as at downstream in refining and processing facilities.

The process can be applied to the treatment of petroleum or a petroleum fraction, particularly bitumen, that is comprised by/in oil sand. The process of the invention can be used to treat oil sand. Oil sands, also known as tar sands or crude bitumen, or more technically bituminous sands, are a type of petroleum deposit. Oil sands may be either loose sands or partially consolidated sandstone containing a naturally occurring mixture of sand, clay, and water, saturated with a dense and viscous form of petroleum technically referred to as bitumen.

The process can be applied to the treatment of heavy fuel oil or sludge that results from heavy fuel oil. Particularly heavy fuel oil or sludge that is comprised in fuel tanks, for example of ships, in (industrial) furnaces or in (industrial) combustion plants. If applied in this manner, the process can help to liquefy heavy fuel oil residues, particularly sludge. The process can, as alternative, be used to refine heavy fuel oil.

The present invention also provides with a petroleum, a petroleum fraction, or a natural gas, obtainable by or obtained by above-said method or, as a further or additional definition, comprising, as additives above-mentioned first and second components. The invention also provides with a method for preparing an addition agent for petroleum, a petroleum fraction, or natural gas, the method comprising:

Mixing

a first component which is selected from material, particularly roots, of a plant of the genus Glycyrrhiza, and/or an arbuscular mycorrhizal fungi, and a second component which is selected from a plant material or -ingredient of a plant of the family Elaeocarpaceae,

The present invention also provides with an addition agent for petroleum, a petroleum fraction, or natural gas, obtainable by or obtained by above-said method or, as a further or additional definition, comprising said first and second components.

The addition agent may be used in above-mentioned method for treating petroleum, a petroleum fraction, or natural gas.

In a more general aspect, the present invention also provides with a method for treating petroleum, a petroleum fraction, or natural gas, the process comprising:

adding a component which is selected from material, particularly roots, of a plant of the genus Glycyrrhiza, and/or an arbuscular mycorrhizal fungi, to the petroleum, petroleum fraction, or natural gas. Here, only the above-mentioned first component is added.

In a further general aspect, the present invention also provides with a method for treating petroleum, a petroleum fraction, or natural gas, the process comprising:

adding a component which is selected from a plant material or -ingredient of a plant of the family Elaeocarpaceae, to the petroleum, petroleum fraction, or natural gas. Here, only the above-mentioned second component is added.

DETAILED DESCRIPTION OF THE INVENTION

Any numbering of components, such as“first component” and“second component” is intended to distinguish components from each other and name components by kind of abbreviation. Such numbering is not intended to mean a sequence of adding, or using. In embodiments of this invention a hydrocarbon or a hydrocarbon carrying one or more substituents or functional groups may be used or employed. A hydrocarbon is a compound consisting entirely of hydrogen and carbon. A hydrocarbon and a hydrocarbon carrying or comprising one or more substituents or functional groups may in this invention also in summary called a“hydrocarbon” or“a hydrocarbon, which may be substituted”. So, if the term“hydrocarbon” is used in this description for sake of abbreviation, a

hydrocarbon carrying one or more substituents or functional groups is encompassed, even if possible substitution is not explicitly mentioned. A hydrocarbon carrying one or more substituents is also called“substituted hydrocarbon”.

The hydrocarbon can be selected from one or more of an aliphatic hyrocarbon and an aromatic hydrocarbon.

An aliphatic hydrocarbon carrying one or more substituents may be an alcohol. An alcohol is in one more specific embodiment an aliphatic alcohol, preferably a C1 - C10 alcohol, such as methanol, ethanol, propanol, butanol or pentanol, wherein all isomers thereof are encompassed. A mixture of two or more different alcohols may be used. All this may apply to all embodiments of this invention where alcohol is used or mentioned.

An aromatic hydrocarbon in the present invention may comprise, or be selected from, benzene, toluene, xylene, and any mixture of one or more thereof. This may apply to all embodiments of this invention where aromatic hydrocarbon is used or mentioned.

The liquid hydrocarbon is preferably not a triglyceride or not a vegetable oil.

The term or state“liquid” particularly refers to liquid state at usual temperature for performing the methods of the invention, particularly at room temperature, even more particularly at 20°C or at least 20°C.

First component:

The first component is selected from

- material, particularly roots, of a plant of the genus Glycyrrhiza, and/or

- an arbuscular mycorrhizal fungi (AMF). The material, particularly roots, of a plant of the genus Glycyrrhiza, is in a specific embodiment material, particularly roots, from Glycyrrhiza glabra. Glycyrrhiza is known to live in symbiosis with arbuscular mycorrhizal fungi (also abbreviated as AMF, also called Glomeromycota). The material, particularly roots, used in the invention may comprise AMF, preferably in symbiotic relationship.

Specific examples of the plant of the genus Glycyrrhiza are

Glycyrrhiza acanthocarpa

Glycyrrhiza aspera

Glycyrrhiza astragalina

Glycyrrhiza bucharica

Glycyrrhiza echinata

Glycyrrhiza eglandulosa

Glycyrrhiza foetida

Glycyrrhiza foetidissima

Glycyrrhiza glabra L, particularly the varieties Glycyrrhiza glabra var. glabra

Glycyrrhiza glabra glandulifera,

Glycyrrhiza gontscharovii

Glycyrrhiza iconica

Glycyrrhiza inflata

Glycyrrhiza korshinskyi

Glycyrrhiza squamulosa

Glycyrrhiza lepidota

Glycyrrhiza pallidiflora

Glycyrrhiza triphylla (syn. Meristotropsis triphylla)

Glycyrrhiza uralensis

Glycyrrhiza yunnanensis

Any combination of one or more of these plants of the genus Glycyrrhiza, particularly Glycyrrhiza glabra, with one or more AMF, particularly AMF mentioned herein, such as AMF from the genus Glomus, the genus Acaulospora, Glomus mossae or Acaulospora laevis, may be employed.

The material of a plant of the genus Glycyrrhiza may be any material, like whole plants or plant parts, such as stems, leaves, roots, and any mixture of plant parts. In a beneficial embodiment the material is roots. The material may be processed material, for example by drying, milling, grinding, comminuting, or a combination thereof. The material may alternatively or additionally be suspended and/or soaked in a liquid, particularly, and without limitation, a liquid hydrocarbon, which may be substituted, preferably an alcohol, such as ethanol, propanol, ethanol, and/or a liquid aromatic hydrocarbon, which may be substituted. The aromatic hydrocarbon may be toluene or a xylene. A liquid hydrocarbon mixture may be used, such as kerosene.

AMF may be provided by any source. AMF may be provided in isolated form. AMF may be suspended and/or soaked in a liquid, particularly, and without limitation, a liquid

hydrocarbon, which may be substituted, preferably a liquid alcohol and/or a liquid aromatic hydrocarbon, which may be substituted. The aromatic hydrocarbon may be toluene or a xylene. A liquid hydrocarbon mixture may be used, such as kerosene.

In one embodiment, the arbuscular mycorrhizal fungi (AMF) is selected from the genus Glomus and/or the genus Acaulospora, and particularly selected from Glomus mossae or Acaulospora laevis. Such fungi and methods for obtaining them are described in Yadav et. al, Agric Res. (2013), 2(1 ):43-47, which is incorporated by reference in this description.

AMF that could be employed in the invention are AMF from following genera:

Acaulospora, Ambispora, Archaeospora, Diversispora, Entrophospora, Funneliformis, Geosiphon, Gigaspora, Glomus, Claroideoglomus, Otospora, Pacispora, Paraglomus, Racocetra, Redeckera, Rhizophagus, Scutellospora, Sclerocystis.

Further AMF and information about AMF can be found in: Tancredo Souza, Handbook of Arbuscular Mycorrhizal Fungi, Springer International Publishing Switzerland 2015, ISBN 978-3-319-24848-6, ISBN 978-3-319-24850-9 (eBook), DOI 10.1007/978-3-319-24850-9, Library of Congress Control Number: 2015953773, which is incorporated by reference in its entirety.

Second component:

The second component can be selected from a plant material or -ingredient of a plant of the family Elaeocarpaceae. In the second component, the plant may be a plant of the genus Elaeocarpus.

In the second component the plant may be a plant of the species Elaeocarpus

hygrophilus.

The term“plant material or -ingredient” may encompass any part of a plant, such as fruits, leaves, roots, or stems. The plant ingredient may be any ingredient that is present in the plant or gained from a plant, for example, and without limitation, by pressing or extraction. Exemplary plant ingredients are such as oil or juice, without limitation, for example oil or extract from fruits, such as oil or juice.

The plant material may comprise one or more of the following substances:

- pigments

- triglycerides

- fatty acids

- glucosides

- akinetes,

either singly or in any combination or sub-combination thereof.

The plant material or -ingredient may be processed material, for example obtained by drying, milling, grinding, comminuting, extracting a plant or plant part, or a combination thereof. The plant material or -ingredient may alternatively or additionally be suspended, dissolved, emulsified and/or soaked in a liquid, particularly, and without limitation, a liquid hydrocarbon, which may be substituted, preferably a liquid aromatic hydrocarbon, which may be substituted. The aromatic hydrocarbon may be toluene or a xylene. A liquid hydrocarbon mixture may be used such as kerosene.

The plant material or -ingredient in a further embodiment comprises, which particularly may be combined with the previous embodiment, a compound belonging to the class of phenylethanoids particularly a tyrosol ester of elenolic acid, which may be further hydroxylated or and glycosylated. Particularly suitable compounds are selected from 10- hydroxyoleuropein, ligstroside, 10-hydroxyligstroside, Oleocanthal and Oleuropein

((4S,5E,6S)-4-[2-[2-(3,4-dihydroxyphenyl)ethoxy]-2-oxoeth ylj- 5-ethylidene-6- [[(2S,3R,4S,5S,6R)-3,4,5-trihydroxy-6-(hydroxymethyl)- 2-tetrahydropyranyl]oxy]-4H- pyran-3-carboxylic acid, methyl ester). Such compounds are believed to be harmful to SRB. Such compound(s) are preferably contained in the plant material or -ingredient, if it is olive oil.

In one embodiment, the plant material or -ingredient is a plant oil or a plant extract, particularly a leave or fruit extract.

The first and second component may be added sequentially to the petroleum, petroleum fraction, or natural gas, or at the same time. In a beneficial embodiment, the first and second component are mixed with each other and then allowed to stand before they are added to the petroleum, a petroleum fraction, or natural gas. An addition agent may be prepared from the first and second component according to a method of the invention for preparing an addition agent, and this addition agent added to the petroleum, a petroleum fraction, or natural gas.

The term mixing in this invention comprises any kind of mixing, or adding a first matter to a second, matter, or vice versa. The term mixing does not necessarily require, but may encompass, agitation, such as stirring.

Without wishing to be bound by theory and without limitation of the scope of the invention, it is believed that the first component and the second component undergo a reaction and/or association with each other, which can for example be of chemical and/or biological nature. A biological reaction may for example be formation of a composite organism. A reaction or association may change the character of the isolated

components. The present invention encompasses also methods and products wherein such reaction and/or association of the first and second component has or may have occurred. The present invention encompasses also methods and products, particularly a petroleum, petroleum fraction, or a natural gas, or an addition agent, wherein such reaction and/or association of the first and second component has or may have occurred or wherein any kind of product of such reaction and/or association is formed, or contained.

In one embodiment of the method for treating petroleum, petroleum fraction, or natural gas, adding the first and the second component is done in following steps:

adding the second component to the petroleum, petroleum fraction, or natural gas, allowing the petroleum, petroleum fraction, or natural gas to stand, for example for a residence time in a discontinuous or continuous process adding a mixture of the first and the second component the petroleum, petroleum fraction, or natural gas.

In this embodiment, the petroleum, petroleum fraction, or natural gas is in a first or previous step treated with the second component alone, without the first component. Concentrations in the second component in this previous step may differ from

concentrations in the second component in the step when the first component is also added. API gravity may already be increased and sulfur content and/or salt content be reduced in advance, before the treatment with a mixture of first and second component is done. It is believed that the so called previous step of adding the second component is harmful to SRB.

In another embodiment of the method of the invention, the first component and second component that are added to the petroleum, petroleum fraction, or natural gas, which is to be treated, are comprised in a first (also called: previous) petroleum, first (also called: previous) petroleum fraction, or first (also called: previous) natural gas, wherein the first petroleum, first petroleum fraction, or first natural gas is added to the petroleum, petroleum fraction, or natural gas, which is to be treated. In this embodiment, the first or previous petroleum/petroleum fraction/natural gas can be a petroleum/petroleum fraction/natural gas that was treated by a method of the invention earlier.

In one embodiment of the method for treating petroleum, a petroleum fraction, or natural gas, the method comprises adding a further component to the petroleum, petroleum fraction, or natural gas which, wherein the further component is selected from a biocide, at least one amine, at least one or quaternary ammonium compound, or a mixture thereof. This step is preferably done before the first and second component are added, or before a second component is added solely according to the previously mentioned embodiment. After adding said further component, the petroleum, petroleum fraction, or natural gas may be allowed to stand. So, the method for treating petroleum, petroleum fraction, or natural gas may comprise following steps in following order: adding the further component to the petroleum, petroleum fraction, or natural gas, selected from a biocide, at least one amine, at least one or quaternary ammonium compound, or a mixture thereof,

allowing the petroleum, petroleum fraction, or natural gas to stand, optionally adding the second component to the petroleum or petroleum fraction,

optionally allowing the petroleum or petroleum fraction to stand,

adding a mixture of the first and the second component to the petroleum, petroleum fraction, or natural gas.

The expression“allowing to stand” encompasses standing (or waiting) without agitation or with agitation.

The expression“allowing to stand” encompasses continuous, discontinuous and batch processes. In a continuous process, the time over which a matter is allowed to stand is the residence time, particularly an average residence time, for example a residence time in a tank reactor or tube reactor.

The amine or quaternary ammonium compound is in one embodiment water-soluble.

The biocide may be selected from any biocide which is harmful to SRB. A beneficial biocide is glutaraldehyde.

The further component which is selected from a biocide, at least one amine, at least one or quaternary ammonium compound, or a mixture thereof, is preferably used in aqueous media. So, the further component is preferably present in aqueous media, e.g. as solution, emulsion or suspension, and added in this state to the petroleum, petroleum fraction, or natural gas. Using aqueous media leads to at least partial extraction of SRB, particularly inactivated SRB, from the petroleum, petroleum fraction, or natural gas.

A petroleum or petroleum fraction treated according to the method of the invention is a product showing one or more of the following properties:

- high API gravity (API = American Petroleum Institute), particularly higher than 35 API at 59“Fahrenheit

- low sulfur content, particularly less than 0.5 % - low salt content, particularly less than 10 PTB (pounds per thousand barrels).

- product corresponds to a light sweet petroleum quality

- generate raffinates with high API gravity

- the product can be directly used, for example in combustion engines

A natural gas treated according to the method of the invention is a product showing one or more of the following properties:

- reduced specific gravity due to hhS extraction

- increased heating value due to cleaning and sweetening

- reduced corrosiveness of the treated natural gas

A feedstock of petroleum, petroleum fraction, or natural gas, or a portion of said feedstock may be treated in discontinuous or continuous manner. The method for treatment is preferably a continuous method.

In another embodiment, the product of the method for treatment is blended with further petroleum, a further petroleum fraction, which was not treated according to the method. Such blending may reduce API gravity, raise sulfur content and raise salt content, but by choosing a suitable blending ratio, these parameters may be set in a desired and still beneficial range.

So, the method of the invention for treatment of petroleum, a petroleum fraction may further comprise:

adding the petroleum, or the petroleum fraction, that was treated by adding the first component and the second component to a further petroleum, or a further petroleum fraction, that has not yet been treated by the method, particularly in order to reduce sulfur and sulfur compounds in the further petroleum, or the further petroleum fraction,

optionally repeating the previous step once or more, thereby treating a still further petroleum or petroleum fraction, that has not been treated before.

By this method, it is possible to reach also in the further one or more of the benefits that were described for the method earlier, e.g. reducing sulfur and sulfur compounds, increasing API gravity etc., also in the further petroleum (fraction). In this embodiment, the product of the treatment can be used for further treatment of further petroleum(fraction) in order to reach benefits of the treatment. So it is not strictly necessary to prepare addition agent of the invention to perform the method. Using addition agent is one alternative of the method for treatment. The other alternative is using the product of the method for continuing the method for treatment of further petroleum (fraction).

This can be continued as often as desired, by optionally

- repeating above step of addition once or more, thereby treating a still further petroleum or petroleum fraction, that has not been treated before. A scheme of such repeated method, performed in several generations of treatment can be illustrated as follows:

1 ) T reatment of petroleum (fraction) (1 ^st generation) with first and second component.

2) Obtaining treated petroleum (fraction) (product of 1 ^st generation). The product of 1 ^st generation comprises first and second component, and/or a product formed from the first and second component.

3) Treatment of petroleum (fraction) (2 ^nd generation) with product of 1 ^st generation

4) Obtaining treated petroleum (fraction) (product of 2 ^nd generation). The product of 2 ^nd generation comprises first and second component, and/or a product formed from the first and second component.

5) repeating 3) and 4) for as many further generations as desired. Here, treating with the product of a previous generation or with a product of any earlier generation can be done.

In one embodiment of the invention, the method comprises:

adding a hydrocyrabon, which may be substituted, particularly an alcohol or a liquid aromatic hydrocarbon, to the petroleum, or the petroleum fraction, that was treated by adding the first component and the second component (which is called a product of the method).

The product of the method can be stored for further purpose, e.g. for later treatment of further petroleum (fraction) which is still to be treated. It has been shown, that adding a liquid aromatic hydrocarbon, which may be substituted, promotes the effect of the product when it is used for treatment of the further petroleum, or the further petroleum fraction. Without wishing to be bound by theory, it is believed, that liquid aromatic hydrocarbon, which may be substituted, serves as a substrate for maintenance, growth and/or proliferation of a biological complex which is formed by the first and the second

component. Such maintenance, growth and/or proliferation helps in possible further treatment of further petroleum (fractions). The liquid aromatic hydrocarbon, which may be substituted, may be a pure liquid aromatic hydrocarbon or comprised in a petroleum fraction that is not a fraction which is to be treated for any purpose of the method of the invention, e.g. for reducing sulfur and sulfur compounds. Particularly, the liquid aromatic hydrocarbon may be comprised in a diesel fuel. So, diesel fuel may be added to the petroleum, or the petroleum fraction, that was treated by adding the first component and the second component.

In one embodiment, the method comprises:

Adding a liquid aromatic hydrocarbon, which may be substituted, to the petroleum, or the petroleum fraction, that was treated by adding the first component and the second component, and then adding this mixture to a further petroleum, or the further petroleum fraction, that has not been treated. The effect of adding liquid aromatic hdrocarbon was already mentioned before: It has been shown, that adding a liquid aromatic hydrocarbon, which may be substituted, promotes the effect of the product when it is used for treatment of the further petroleum, or the further petroleum fraction. As in the embodiment above, the liquid aromatic hydrocarbon may be a pure liquid aromatic hydrocarbon or comprised in a petroleum fraction that is not a fraction which is to be treated for any purpose of the method of the invention, e.g. for reducing sulfur and sulfur compounds. Particularly, the liquid aromatic hydrocarbon may be comprised in a diesel fuel. So, diesel fuel may be added to the petroleum, or the petroleum fraction, that was already treated by adding the first component and the second component, before it is added to the further petroleum, or the further petroleum fraction, that has not been treated.

In a further embodiment, the method of treatment comprises:

washing the petroleum, or the petroleum fraction, after it was treated by adding the first component and the second component, with an aqueous liquid phase. Such washing is intended for, and has the effect of, removing or at least decreasing sulfur and sulfur compounds from/in the treated petroleum (fraction). For example, FhS in the petroleum may be converted to sulfur or other sulfur compound which may precipitate or remain in some extend in the treated petroleum (fraction). Such sulfur or other sulfur compound can be removed by washing from the petroleum (fraction). The aqueous phase can consist of water, or comprise water, or be based on water (>50 vol% water in the aqueous liquid phase). Washing can be done at room temperature, particularly 20-25°C, or at increased temperature, for example at 30-60°C. The aqueous liquid phase may comprise binding agents to bind sulfur or sulfur compounds, if desired. Suitable binding agents are hydroxides, such as NaOH.

In a further aspect, the invention provides with a production method for an oil product, comprising

I) diverting a portion of a feedstock of petroleum or petroleum fraction,

II) treating said portion of the feedstock according to the method for treating petroleum, or a petroleum fraction, as described above,

III) blending the product obtained in II) with the remaining part of the feedstock which was not treated according to the method for treating petroleum, or a petroleum fraction.

This production method may be a continuous method which can be applied upstream in subterranean reservoirs and at surficial recovery plants as well as at downstream in refining and processing facilities.

The production method may comprise one or more of following steps

diverting the portion of the feedstock to an oil/water separator and separating water heating up of the separated oil stream

Addition agent:

The following description relates to further aspects of an above-mentioned (cf. SUMMARY OF THE INVENTION) method for preparing an addition agent for petroleum, petroleum fraction, or natural gas.

The addition agent comprises above-disclosed first component which is selected from material, particularly roots, of a plant of the genus Glycyrrhiza, and/or an arbuscular mycorrhizal fungi, and above-disclosed second component which is selected from of a plant material or -ingredient of a plant of the family Elaeocarpaceae, according to its general and specific embodiments.

The first and/or second components may already comprise a liquid component.

Alternately or additionally, at least one liquid compound may be added in order to prepare the addition agent. Such liquid compound may in one embodiment be selected from a liquid hydrocarbon, which may be substituted. The liquid, optionally substituted, hydrocarbon may be a liquid alcohol and/or a liquid aromatic hydrocarbon, such as Benzene, Toluene or a Xylene. A liquid hydrocarbon mixture may be used such as kerosene. Such liquid compound can be comprised in the addition agent.

Such liquid compound can be comprised in the addition agent. The addition agent may comprise at least one liquid hydrocarbon, which may be substituted. The liquid, optionally substituted, hydrocarbon may be a liquid alcohol and/or a liquid aromatic hydrocarbon, such as Benzene, Toluene or a Xylene. A liquid hydrocarbon mixture may be used such as kerosene.

In one embodiment, the first and second component are exposed to light during mixing and/or after mixing. The light is preferably visible light, which may be composed from one or more wave-lengths. The light may be light from a white light source or daylight. In one embodiment, the light is daylight. Exposure to light may also be done when mixing further components and/or after mixing of further components.

In one embodiment, the method comprises, during mixing of the first and second component and/or after mixing the first and second component, performing following sequence of steps a) and b), in any order (i.e. a), b), or b), a))

a) exposing the mixture to a first illuminance for a first period of time, b) exposing the mixture to a second illuminance for a second period of time, wherein the first illuminance in step a) is higher than the second illuminance in step b).

The method optionally comprises,

- repeating the sequence of steps a) and b) at least once, wherein the values of first illuminance and second illuminance may vary from initial or previous values, under the condition that the first illuminance is higher than the second illuminance,

and wherein the first period of time and the second period of time may vary from an initial or previous first/second period of time. This is to say that illuminations and periods of time may change in one or more of the repetitions of steps a) and b), as long as the first illuminance in step a) is higher than the second illuminance in step b).

The embodiment with repetition may particularly mean following sequence

a), b), a), b), a), b)...., or

b), a), b) a), b), a) .

The first period of time in step a) and the second period of time in step b) may be the same or different. The first period of time in step a) and/or the second period of time in step b) may be at least 0.5 hours or at least 1 hour, preferably at least 2 hours. Steps a) and b) may preferably be done for up to 48 hours or 72 hours, wherein these upper limits can be combined, in any combination, with any of the lower limits given before.

Illumination may be done with light. The light is preferably visible light, which may be composed from one or more wave-lengths. The light may be light from a white light source or daylight.

The feature that the first illuminance in step a) is higher than the second illuminance in step b) can mean that the difference in illuminance between a) and b) is at least 10 Lux, preferably at least 100 Lux, even more preferably at least 500 Lux, still more preferably at least 1000 Lux. The difference may be at most 450000 Lux.

Illumincance in step a) may be more than 10 Lux, or at least 100 Lux, preferably at least 500 Lux, more preferably at least 1000 Lux, even more preferably at least 5000 Lux. An upper limit that can be combined with any of the lower limits, in any combination, may be 100000 Lux, or 200000 Lux, or 450000 Lux.

In step b), illuminance may be at most 10 Lux, more preferably at most 1 Lux, even more preferably at most 0.1 Lux, still more preferably at most 0.01 Lux. A lower limit that could be combined mit any of the upper limits, in any combination, may be 0.001 Lux, or 0.0001 Lux, or 0.00001 Lux, or O Lux (zero). In one embodiment, the method for producing the addition agent comprises mixing, or adding, a chalconoid compound as a further component. The term chalconoid compound comprises chalcone and derivatives of chalcone (1 ,3-Diphenylprop-2-en-1-one), such as substituted chalcones, preferably substituted at one of the aromatic rings. Typical, but non-limiting substituents are hydroxy, alkoxy, particularly methoxy or ethoxy, halogen or alkenyl. A specific example is 2, 4, 4’ trimethoxy chalcone.

In one embodiment, the method for producing the addition agent comprises mixing, or adding plant material from the family Asteraceae or Costaceae, particularly from genus Saussurea, particularly Saussurea costus, or from the genus Costus as a further component. Reference is made is this regard to https://en.wikipedia.org/wiki/Costus and https://en.wikipedia.org/wiki/Saussurea_costus, which are incorporated by reference in its entirety. This plant material may be treated, particularly soaked, in liquid hydrocarbon, which may be substituted, preferably a liquid alcohol and/or a liquid aromatic hydrocarbon.

Mixing of the components may be done sequentially, in step-wise manner. In still a further embodiment an intermediate mixture is allowed to stand after each mixing step, i.e. after addition of any component. Standing time may be at least 1 hour, preferably, at least 2 hours, or at least 4 hours, or at least 6 hours, or at least 8 hours, or 8 to 16 hours, or 10 to 12 hours.

In a more specific embodiment of the method for preparing an addition agent, mixing of the first and second component is done by performing the following steps

i) mixing the first component and at least one first liquid compound to prepare a first liquid composition,

ii) mixing the second component and at least one second liquid compound, to prepare a second liquid composition,

iii) mixing the first liquid composition and the second liquid composition, to obtain a mixture of the first liquid composition and the second liquid composition.

The first and the second liquid compound may be the same or different. The first and the second liquid compound may be a liquid hydrocarbon, which may be substituted, preferably a liquid alcohol and/or a liquid aromatic hydrocarbon. The alcohol is in one specific embodiment an aliphatic alcohol, preferably a C1 - C10 alcohol, such as methanol, ethanol, propanol, butanol or pentanol, wherein all isomers thereof are encompassed. The liquid aromatic hydrocarbon may be selected from toluene, xylene, kerosene.

Step i) may further comprise adding one or more alcohols, if mentioned first liquid compound is not an alcohol.

Step i) may be done by sequentially adding portions of material, particularly roots, of a plant of the genus Glycyrrhiza to a volume of the first liquid compound in sequential steps and allowing to stand for 1 hour, preferably, at least 2 hours, or at least 4 hours, or at least 6 hours, or at least 8 hours, or 8 to 16 hours, or 10 to 12 hours, between each step.

The first liquid composition and/or the second liquid composition may be allowed to stand for at least 1 hour, preferably, at least 2 hours, or at least 4 hours, or at least 6 hours, or at least 8 hours, or 8 to 16 hours, or 10 to 12 hours, before mixing of the first liquid composition and the second liquid composition.

The material, particularly roots, of a plant of the genus Glycyrrhiza may be suspended and/or soaked in the first liquid compound.

In one embodiment, the method comprises

performing following sequence of steps a) and b), in any order

a) exposing the first liquid composition to a first illuminance for a first period of time,

b) exposing the first liquid composition to a second illuminance for a second

period of time,

wherein the first illuminance in step a) is higher than the second illuminance in step b),

and optionally repeating the sequence of steps a) and b) at least once,

and/or

performing following sequence of steps a’) and b’), in any order

a’) exposing the second liquid composition to a first illuminance for a first period of time,

b’) exposing the second liquid composition to a second illuminance for a second period of time, wherein the first illuminance in step a’) is higher than the second illuminance in step b’),

and optionally repeating the sequence of steps a’) and b’) at least once, and/or

performing following sequence of steps a”) and b”), in any order

a”) exposing the mixture of the first liquid composition and the second liquid

composition to a first illuminance for a first period of time,

b”) exposing the mixture of the first liquid composition and the second liquid

composition to a second illuminance for a second period of time, wherein the first illuminance in step a”) is higher than the second illuminance in step b”),

and optionally repeating the sequence of steps a”) and b”) at least once.

For this process it is referred to the lllumincance and time values and ranges indicated above which could applied here in similar manner.

First and second illuminance are intended to designate a difference in illuminance when first and second illuminance are compared.

However, it is possible that first illumincances in a), a’), and a”) are (partially or wholly) the same or (partially or wholly) different. It is possible that second illumincances in b), b’), and b”) are (partially or wholly) the same or (partially or wholly) different.

Illumination may be done with light. The light is preferably visible light, which may be composed from one or more wave-lengths. The light may be light from a white light source or daylight.

The feature that the first illuminance in step a), a’) or a”) is higher than the second illuminance in step b), b’) or b”) can mean that the difference in illuminance between any of a)/b), a’)/b’), or a”)/b”), is at least 10 Lux, preferably at least 100 Lux, even more preferably at least 500 Lux, still more preferably at least 1000 Lux. The difference may be at most 450000 Lux. The differences in a)/b), a’)/b’), or a”)/b”), may be partially or wholly different. lllumincance in step a), a’) or a”) may be more than 10 Lux, or at least 100 Lux, preferably at least 500 Lux, more preferably at least 1000 Lux, even more preferably at least 5000 Lux. An upper limit that can be combined with any of the lower limits, in any combination, may be 100000 Lux, or 200000 Lux, or 450000 Lux.

Illumincance in step b), b’) or b”) may be at most 10 Lux, more preferably at most 1 Lux, even more preferably at most 0.1 Lux, still more preferably at most 0.01 Lux. A lower limit that could be combined mit any of the upper limits, in any combination, may be 0.001 Lux, or 0.0001 Lux, or 0.00001 Lux, or 0 Lux (zero).

The periods of time in steps a) and/or b) may be (partially or wholly) the same or (partially or wholly) different. The periods of time in steps a’) and/or b’) may be (partially or wholly) the same or (partially or wholly) different. The periods of time in steps a”) and/or b”) may be (partially or wholly) the same or (partially or wholly) different.

First periods of time in a), a’), and a”) may be (partially or wholly) the same or (partially or wholly) different.

Second periods of time in b), b’), and b”) may be (partially or wholly) the same or (partially or wholly) different.

In other words, with respect to the period of time,“first” and“second” only indicate other periods of time, but do not say anything about their length.

Any first period of time in step a), a’) or a”) may be at least 0.5 hours or 1 hour, preferably at least 2 hours. Upper limits are up to 48 hours or 72 hours, wherein these upper limits can be combined, in any combination, with any of the lower limits given before.

Any second period of time in step b), b’) or b”) may be at least 0.5 hours or 1 hour, preferably at least 2 hours. Upper limits are up to 48 hours or 72 hours, wherein these upper limits can be combined, in any combination, with any of the lower limits given before.

When repeating the sequence of steps a) and b), and/or a’) and b’), and/or a”) and b”) at least once, the values of first illuminance and second illuminance may vary from initial or previous values, under the condition that the first illuminance is higher than the second illuminance. When repeating the sequence of steps a) and b), and/or a’) and b’), and/or a”) and b”), the first period of time and the second period of time may vary from an initial or previous first/second period of time.

When repeating the sequence of steps a) and b), and/or a’) and b’), and/or a”) and b”), first Illuminance and second illuminance may vary from initial or previous values, under the condition that the first illuminance is higher than the second illuminance.

This is to say that illuminations and periods of time may change in one or more of the repetitions of steps a) and b), and/or a’) and b’), and/or a”) and b”), as long as the first illuminance in step a), a’) or a”) is higher than the second illuminance in step b), b’) or b”).

The present invention is also directed to an independent (i.e. independent from

aforedescribed method) method for preparing an addition agent for petroleum, petroleum fraction, or natural gas, the method comprising

mixing

a first component which is selected from material, particularly roots, of a plant of the genus Glycyrrhiza, and/or arbuscular mycorrhizal fungi, and a second component which is selected from a plant material or -ingredient of a plant of the family Elaeocarpaceae and

wherein mixing is done by performing the following steps

i) mixing the first component and at least one first liquid compound to prepare a first liquid composition,

ii) mixing the second component and at least one second liquid compound, to prepare a second liquid composition,

iii) mixing the first liquid composition and the second liquid composition, to obtain a mixture of the first liquid composition and the second liquid composition.

In this method, same specific embodiments may apply as in a method for preparing an addition agent which was described before.

In one embodiment, the methods for producing the addition agent comprises mixing, or adding, a hydrocarbon, which may be substituted, preferably an aromatic hydrocarbon, such as Toluene or a Xylene, or an alcohol, as a further component. In one embodiment, the methods of the invention for producing the addition agent comprises mixing, or adding, one or more alcohols as a further component. The alcohol is in one more specific embodiment an aliphatic alcohol, preferably a C1 - C10 alcohol, such as methanol, ethanol, propanol, butanol or pentanol, wherein all isomers thereof are encompassed.

In one embodiment, the methods for producing the addition agent comprises mixing, or adding, a reverse demulsifier and/or a flocculant, as a further component.

In one embodiment, the mixture of the first component and the second component, or of the first liquid composition and the second liquid composition, or generally the product of any of the methods, is allowed to stand after mixing the components, or after mixing the first liquid composition and the second liquid composition. The first and the second component are in a beneficial embodiment brought into contact before adding them to a petroleum, petroleum fraction or natural gas, in order to form the so-called addition agent. Even more beneficially, the mixture of first and second component, and further components, if present, is allowed to stand before it is added to the petroleum, petroleum fraction or natural gas.

In a specific embodiment, the mixture of the first component and the second component, or of the first liquid composition and the second liquid composition, or generally the product of any of the methods is allowed to stand for at least 1 hour, preferably, at least 2 hours, or at least 4 hours, or at least 6 hours, or at least 8 hours, or 8 to 16 hours, or 10 to 12 hours, after mixing the components or liquid compositions comprising the components.

The present invention relates, in a further aspect also to the use of a mixture of

a) a first component which is selected from material, particularly roots, of a plant of the genus Glycyrrhiza, and/or an arbuscular mycorrhizal fungi, and b) a second component which is selected from of a plant material or -ingredient of a plant of the family Elaeocarpaceae,

for treatment of petroleum, petroleum fraction or natural gas.

The present invention relates, in a further aspect also to the use of a component which is selected from material, particularly roots, of a plant of the genus Glycyrrhiza, and/or an arbuscular mycorrhizal fungi, for treatment of petroleum, petroleum fraction or natural gas. This aspect relates to the use of the first component only.

The present invention relates, in a further aspect also to the use of a component which is selected from of a plant material or -ingredient of a plant of the family Elaeocarpaceae, for treatment of petroleum, petroleum fraction or natural gas. This aspect relates to the use of the second component only.

BRIEF DESCRIPTION OF THE FIGURES

Fig. 1 shows a schematic flow diagram of a process of the invention for the treatment of a subterranean petroleum reservoir; Fig. 2 shows a schematic flow diagram of a process of the invention for the treatment of petroleum and its fractions in surficial recovery plants and downstream refining and processing facilities;

Fig. 3 shows a schematic flow diagram of a process of the invention for the treatment of a subterranean natural gas reservoir;

Fig. 4 shows a schematic flow diagram of a process of the invention for the treatment of natural gas in downstream refining and processing facilities;

EXAMPLES

Example 1 : Preparation of an addition agent of the invention

First component:

Any part of Licorice is mixed with an alcohol, such as ethanol, or an aromatic, preferably toluene or xylene, for example in a ratio of 25/75 (vol/vol) or specifically by following procedure.

Preparation of maceration of“Glycyrrhiza glabral licorice”

A. Soak 2000 g of licorice in 435 g of suitable aromatic solvent such as Xylenes CsH-io (about 500 ml).

B. Soaking is encountered in ten steps at every step soak 200 g of licorice with the same volume amount of Xylenes.

C. The reaction time is 10-14 hours between every step.

Total reaction time = 10-14 hours x 10 = 100 - 140 h.

The mixture is placed into light and dark (preferably, but not a must, natural light) as follows.

Day 1 : Dark 8h/Light 16h

Day 2: Dark 10h/Light 14h

Day 3: Dark 12h/Light 12h

Second component:

Any part of the plant, preferably the fluid (oil) pressed from the fruits, of Elaeocarpus hygrophilus is mixed with an alcohol, preferably ethanol, or an aromatic, preferably toluene or xylene, in a ratio of 25/75 (vol/vol). The mixture is placed into light and dark (preferably, but not a must, natural light) as follows.

Day 1 : Dark 8h/Light 16h

Day 2: Dark 10h/Light 14h

Day 3: Dark 12h/Light 12h

Then the first and the second component are mixed 1 :1. The mixture is placed into light and dark (preferably, but not a must, natural light) as follows.

Day 1 : Dark 6h/Light 18h

Day 2: Dark 8h/Light 16h

Day 3: Dark 10h/Light 14h

Day 4: Dark 12h/Light 12h

Day 5: Dark 14h/Light 10h

Day 6: Dark 16h/Light 8h

Day 7: Dark 18h/Light 6h

Day 8: Dark 20h/Light 4h

Day 9: Dark 22h/Light 2h

Day 10: Dark 24h/Light Oh

For following examples see also the list of reference symbols as enclosed.

Example 2: Treatment of a subterranean petroleum reservoir

A specific embodiment of the process is the treatment of a subterranean petroleum reservoir RV (Fig. 1 ) via downhole injection. The treatment solutions are prepared in the vessels PV110, PV120 and PV130. PV110 mixes an ingredient of a plant of the species Elaeocarpus hygrophilus (such as extracted oil from fruits) (CF1 10) with kerosene (SF1 10), PV120 mixes biocide (glutaraldehyde, NovaCide 1 125™ by Nova Star LP), and amine/quaternary ammonium compound (one or more of corrosion inhibitors Nova Star NS-1435™, NS-1442™, NS-1471™, NS-2129™, NS-1445™ by Nova Star LP) (CF120) with water (SF120) and PV130 mixes the additive produced in example 1 , supra (CF130)— with kerosene (SF130). PV130 then feeds the fermentor PV140. The actual treatment is done in two stages:

1. Batch sequential injection with shut-in wellhead.

• First, the extractor treatment solution from PV120 in concentrations of around 2 % and 5 % respectively, is pumped into the downhole DH with high pressure pumps where it is injected into the reservoir RV sequentially via injection tubing IT.

• The reaction interval time is about 12 hours after each injection; this initial cycle consists of four steps and can be repeated as required based on sample laboratory analysis results.

• Second, the reactor treatment solution from PV110 in concentration of around 20 % is pumped into the downhole DH with high pressure pumps where it is injected into the reservoir RV via injection tubing IT.

• This stage inhibits SRB growth and reduces their bioactivity. H ₂ S and sulfur are reduced by about 50 % at this stage as the sulfur content in crude oil is proportional to the SRB colony population within crude oil.

2. Continuous partial injection with flowing well.

• A portion of the production crude oil stream (5 % to 15 %) is forwarded to fermentor vessel PV140 for treatment by adding around 10 % of a chemo-biological fermentation solution with ca. 16 % concentration.

• The typical fermentation time in PV140 is about 72 hours.

• The fermented product from PV140 is pumped into the downhole DH with high pressure pumps where it is injected into the reservoir RV via injection tubing IT continuously to improve the crude oil stream flow through the production tubing PT as required.

• This stage develops the energetic biological anti-degradation reactions in the reservoir RV formation that enhance the hydrocarbon chains, increase API gravity, decrease viscosity, and reduce sulfur contents and H ₂ S concentration by about 90

%.

The quantity of treatment solutions to be injected and number of cycles is determined specifically for each well as it depends on various factors, e.g. the composition of the crude oil, the production volume and treatments targets. The initial bio-reaction retention time in the reservoir RV is minimum 24 hours. The embodiment of the invention according to Fig. 1 particularly reduces sulfur, salts and heavy metals content, lowers the FhS concentration to harmless levels (<10 ppm), increases API gravity and decreases viscosity in the product PR.

Example 3: Treatment of petroleum or petroleum fractions in surficial recovery plants and downstream refining and processing facilities

Another specific embodiment of the process is the treatment of petroleum and petroleum fractions (Fig. 2) in surficial recovery plants and downstream refining and processing facilities. The treatment solutions are prepared in the vessels PV240, P250 and PV290. PV240 mixes an ingredient of a plant of the species Elaeocarpus hygrophilus (such as extracted oil from fruits) (CF210) with kerosene (SF210), PV250 mixes biocide and amine (products as in example 2 supra) (CF220) with water (SF220) and PV290 mixes the addition agent produced in example 1 , supra (CF230)— with kerosene (SF230). PV290 then feeds the fermentor PV260. The actual treatment is done as follows:

• A feed stock FS portion (ca. 20 %) from the production manifold or storage facility is routed into PV210 for separation of gas and water (water is extracted via drain DR) from the crude oil by gravity segregation.

• The separated crude oil stream is heated in HE210 to ca. 80 Celsius before being forwarded to extractor PV220.

• The heated crude oil stream in PV220 is injected sequentially with extractor treatment solution (around 20 % of the heated crude oil quantity) from PV250 in concentrations of around 2 % and 5 %, respectively.

• The reaction interval time is about 12 hours after each injection; this initial cycle consists of four steps and can be repeated as required based on sample laboratory analysis results.

• The extracted SRB in the bottom water (sludge) of PV220 are removed via the blowdown BD at the end of each reaction cycle.

• When the reaction is complete, the downstream product is forwarded to reactor PV230.

• Here it is injected with reactor treatment solution from PV240 (around 5 - 10 % of the intermediate product volume) in concentration of around 20 %.

• The bio-reaction time in reactor PV230 is about 12 hours (without water draining). • When the reaction is complete, the downstream product is forwarded to fermentor PV260.

• Here it is injected with a chemo-biological fermentation solution from PV290 (around 15 % of the intermediate product volume) in concentration of around 16 %.

• The typical fermentation time in PV260 is about 72 hours.

• The fermentation process gain in PV260 in terms of volume of downstream product is in the range of 30 % to 50 %.

• When the reaction is complete, the fermented product is forwarded to product mixer PV270 or it may be used directly, e.g., as a high energy, clean fuel for combustion engines or turbines in conjunction with fuel injection system modification accommodating for the higher calorific value of these raffinates RA.

• In PV270, the fermented product is mixed with the remaining 80 % of feedstock FS.

• The bio-reactivity of the fermented oil in PV270 is highly efficient and dynamic. The energy flow to increase the Gibbs energy of the hydrocarbons (their calorific value) happens on the account of the complete inhibition of SRB, utilizing its stored energy (even from its decomposed dead cells) in the anabolism of the new hydrocarbon chains.

• The typical reaction time in PV270 is about 72 hours.

• When the reaction is complete, the finished product is forwarded to PV280, ready for shipment.

• A portion of the finished product PR from product tank PV280 may serve as makeup for the fermentor PV260 as required.

• The fermentor PV260 can be composed of one or more physical vessels to shorten cycle times, e.g. one in reaction complete state, one in makeup state and one in fermented product delivery state.

Feedstock and treatment parameters are listed in the table below.

So called raffinates RA corresponds to a light sweet petroleum quality. Product PR corresponds to an ultralight sweet petroleum quality.

The benefits of the embodiment of Fig. 2 are comparable to Fig. 1 , i.e. one or more of above- mentioned benefits can be reached. Moreover, it generates high energy, clean raffinates RA.

The quantity of treatment solutions to be injected and number of cycles is determined specifically for each application as it depends on various factors, e.g. the composition of the crude oil, the production volume and treatments targets. Example 4: T reatment of sour natural in a subterranean natural reservoir

Fig. 3 shows a natural gas reservoir RV. Fermentor Solution mixer PV310 mixes the addition agent produced in example 1 , supra (CF310)— with methanol (SF310). The mix is fed into the natural gas reservoir RV via injection tubing IT. Treated (i.e. sweetened) natural gas is obtained as a product PR from the production tubing PT.

Example 5: Treatment of natural in downstream facilities

In Fig. 4, fermentor solution mixer PV410 mixes the product produced in example 1 , supra (CF410)— with methanol (SF410). The mix is fed into the pipeline between feedstock FS and separator PV420 with the liquids (black water and condensate) extracted via drain DR. So, the natural gas from the feedstock FS is treated during flowing through the pipeline. Moreover, the mix from PV410 is also fed into the separator PV420 itself to treat natural gas in the separator. Solutions of biocide and amine treatment can be applied in addition to the above-described procedure.

The embodiments in Fig. 3 and 4 reduce sulfur (sweeten sour gas), increase the heat rate, decreases the specific gravity and lowers the FhS concentration to harmless levels (< 10 ppm).

It has to be emphasized that above examples illustrate the essence of the invention. The details, such as amounts and concentrations may vary from application to application (e.g. kind of feedstock, treatment target, man-made plant or natural reservoir) without leaving the scope and idea of the invention.

Example 6: Treatment of oil sand

Oil sand, as mined, was placed into a vessel.

In the next step, addition agent of the invention, as prepared in example 1 , was added to the vessel. The process was accelerated by stirring or tumbling. After a retention time of 1 h, for which the above mixture is allowed to stand, easy accessible hydrocarbons (>50%) were separated from the non-organic solids and transformed into crude oil-like product.

The obtained crude oil-like product was siphoned off. Hot water (>80°C) was added in order to accelerate the transformation of the remaining solidified hydrocarbons into crude oil-like product. This transformation needed about 24 h. The process was accelerated by stirring or tumbling.

Remaining non-organic solids were completely stripped of hydrocarbons. After the clean crude oil-like product has been siphoned off, the wash water could be recirculated, possibly after some treatment, if required (e.g. sulfates extraction).

LIST OF REFERENCE SYMBOLS

Fig. 1 :

IT: Injection Tubing

PT: Production Tubing

PR: Product

DH: Downhole

RV: Reservoir

PV1 10: Reactor Solution Mixer

PV120: Extractor Solution Mixer

PV130: Fermentor Solution Mixer

PV140: Fermentor

CF1 10: Reactor Chemicals Feed

CF120: Extractor Chemicals Feed

CF130: Fermentor Chemicals Feed

SF1 10: Reactor Solvent Feed

SF120: Extractor Solvent Feed

SF130: Fermentor Solvent Feed Fig. 2:

FS: Feedstock

PR: Product

DR: Drain

BD: Blowdown

RA: Raffinates

PV210: Separator

HE210: Heater

PV220: Extractor

PV230: Reactor

PV240: Reactor Solution Mixer

PV250: Extractor Solution Mixer

PV260: Fermentor

PV270: Product Mixer

PV280: Product Tank

PV290: Fermentor Solution Mixer

CF210: Reactor Chemicals Feed

CF220: Extractor Chemicals Feed

CF230: Fermentor Chemicals Feed

SF210: Reactor Solvent Feed

SF220: Extractor Solvent Feed

SF230: Fermentor Solvent Feed

Fig. 3:

IT: Injection Tubing

PT: Production Tubing

PR: Product

DH: Downhole

RV: Reservoir

PV310: Fermentor Solution Mixer

CF310: Fermentor Chemicals Feed

SF310: Fermentor Solvent Feed

Fig. 4:

FS: Feedstock

PR: Product

DR: Drain

PV410: Fermentor Solution Mixer PV420: Separator

CF410: Fermentor Chemicals Feed SF410: Fermentor Solvent Feed