Method, apparatus and chemical products for treating petroleum equipment

• US 9,328,300 B2
• Filed: 03/15/2013
• Issued: 05/03/2016
• Est. Priority Date: 04/16/2012
• Status: Active Grant

• Current Assignee: Marcello Ferrara
• Original Assignee: Marcello Ferrara
• Inventors: Ferrara, Marcello
• Primary Examiner(s): MCCAIG, BRIAN A
• Application Number:
  US13/836,857
• Publication Number:
  US 20130270157A1
• Time in Patent Office: 1,145 Days
• US Class Current: 1/1
• CPC Class Codes: C10G 2300/4075 Limiting deterioration of equipment
• CPC Class Codes: C10G 45/02 to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbons; Hydrofinishing
• CPC Class Codes: C10G 7/00 Distillation of hydrocarbon oils
• CPC Class Codes: C10G 75/04 by addition of antifouling agents
• CPC Class Codes: C10G 9/005 Coking (in order to produce liquid products mainly)
• CPC Class Codes: C10G 9/007 Visbreaking
• CPC Class Codes: C10G 9/16 Preventing or removing incrustation
• CPC Class Codes: F24D 17/0021 with accumulation of the heated water
• CPC Class Codes: F24D 17/0031 with accumulation of the heated water
• CPC Class Codes: F24D 17/02 using heat pumps
• CPC Class Codes: Y10T 29/49 Method of mechanical manufacture

Abstract

The present invention provides a method, an apparatus and chemical products for treating petroleum equipment wherein a fluid is flowing, preferably of the hydrocarbon type, and wherein treating is performed by establishing a closed or semi-closed flow circulation loop, during the normal production operations of the equipment. The treatment can refer to the cleaning of equipment, to yield improvement as compared to normal run conditions and/or to a reduction of coke formation and/or to coke removal on catalysts.

Claims

1. A method for treating a petroleum plant or equipment of the petroleum plant during a running of the petroleum plant, comprising:

maintaining, during a treatment period, the petroleum plant under a production operating condition, typical of the plant itself, which includes providing fresh feed to the petroleum plant;

while maintaining the petroleum plant under the production operating condition, there is carried out one or both of a) and b);

a) introducing in the petroleum plant, during the treatment period, a hydrocarbon-based treatment fluid;

b) varying an established feed rate, present at initiation of the treatment of the petroleum plant or equipment of the petroleum plant, which established feed rate ranges from a maximum operation rate for the petroleum plant, which is inclusive of a design rate for the petroleum plant, to a minimum operation rate which is set at a level for satisfying a minimum production operating state in the petroleum plant;

wherein said introduction of a hydrocarbon-based treatment fluid and/or said variation to the established feed rate generates an additional source or sources for distillation with respect to the amount provided by the established rate present at initiation of treatment; and

distilling said additional source or sources for distillation in conjunction with the distillation of a plant process stream as to form a combination distillate, and diverting a portion of said combination distillate from a flow stream of said combination distillate as to form both a flowing continuation stream of the combination distillate and a diverted stream of the combination distillate, and re-introducing the diverted stream containing combination distillate to the or another plant process stream such that the combination distillate passes within a plant treatment zone for the purpose of plant treatment.

2. The method of claim 1 wherein b) is carried out for purposes of plant treatment, and the additional source or sources of distillate generated by the variation to the established feed rate is fed into the current fresh feed of the plant as the introduction source “

a)”

or as a supplement to an alternate introduction source “

a)”

to the plant.

3. The method of claim 1 wherein b) is carried out for purposes of plant treatment, and varying the established feed rate includes an adjustment of the established feed rate in association with an introduction of the hydrocarbon-based treatment fluid at least partly derived from an external source and wherein said first externally derived hydrocarbon-based treatment fluid is introduced into a closed or semi-closed loop at least partly formed by said plant.

4. The method of claim 3 wherein said hydrocarbon-based fluid is a fluid that cleans a heavy deposit in said plant by removal from a source location in the plant and passing the removed heavy deposit with the cleaning hydrocarbon-based fluid to an outlet of said plant.

5. The method of claim 1 wherein b) is carried out, and the varying of the established feed rate includes varying the fresh feed rate to the plant by an increase adjustment in the plant fresh feed rate from said established feed rate to a level above the established feed rate as to generate an additional quantity of distillates relative to a quantity generated at the established feed rate, and the diverting of at least a portion of a flow of said combination distillate includes the drawing off at least some of an overall quantity of distillate generated from the increased plant feed rate and the re-introducing of the diverted portion for the purpose of plant treatment includes introducing the drawn off distillate into a treatment region of said plant.

6. The method of claim 5 further comprising passing the diverted flow of said combination distillate, which includes said drawn off distillate, through a closed or semi-closed loop forming at least a portion of said plant and extending through the treatment region.

7. The method of claim 6 wherein said closed or semi-closed loop of said plant is configured such that drawn off distillate is re-introduced into a distillation device of the plant which is a source of the initially drawn off distillate and drawing off a recirculation output of distillate from said distillation device following receipt of the re-introduced drawn off distillate and passing the recirculation output of distillate to the treatment region.

8. The method of claim 6 further comprising adjusting a plant configuration to include the closed or semi-closed loop.

9. The method of claim 5 further comprising introducing the drawn off distillate to one or more fresh feed rate passageways of the plant such that, upon introduction to the fresh feed rate passageways of the plant, the introduced drawn off distillate provides a source for said introduction of said hydrocarbon-based treatment fluid or a supplement thereto, and varying the fresh feed rate includes a lowering of a current fresh feed rate to the plant such that the lowered fresh feed rate plus the additional drawn off distillate passing through one or more common passages in the plant sum to conform with plus or minus 60% of the established rate.

10. The method of claim 9 wherein the sum to conform is plus or minus 30% of the established rate.

11. The method of claim 5 further comprising introducing an increasing amount of the drawn off distillate to one or more fresh feed passageways of the plant and varying the fresh feed rate to the plant includes a coordinated lowering of a current fresh feed rate to the plant such that the lowered fresh feed rate plus the additional drawn off distillate is summed together to a desired treatment feed rate and wherein a controller is configured as to monitor and adjust the fresh feed rate to the plant, based on an input level of the drawn off distillate being received in said one or more fresh feed passageways, a current fresh feed to the plant, and a set desired treatment feed rate in the plant.

12. The method of claim 5 wherein the drawn off distillate is introduced into a fresh feed passageway of the plant and wherein there is an introduction of hydrocarbon-based fluid that includes introduction of a first and/or second hydrocarbon-based fluid, and varying the established feed rate comprises an introduction of the first and/or second hydrocarbon treatment fluids, with the introduction of first and/or second hydrocarbon treatment fluids including both the drawn off distillate plus an external source of said first and/or second hydrocarbons placed into combination with the drawn off distillate so as to establish a desired treatment feed rate.

13. The method of claim 1 further comprising introducing into a closed or semi-closed loop of the petroleum plant, during the treatment period, the hydrocarbon-based fluid, with the hydrocarbon-based fluid being derived from either an external source of the hydrocarbon-based fluid, an internal plant source of the hydrocarbon-based fluid or both.

14. The method of claim 13 wherein the introduction of the hydrocarbon-based fluid comprises the introduction of a hydrocarbon based fluid A and/or a hydrocarbon based fluid B, with hydrocarbon based fluid A being introduced in a ratio comprised between 0% and 100% with respect to a current fresh feed in the plant.

15. The method of claim 14 further comprising introducing in said plant hydrocarbon-based fluid B in a ratio comprised between 0.01% and 50% with respect to a current fresh feed in the plant.

16. The method of claim 1 wherein the diverting of at least a portion of the flow of said combination distillate comprises passing at least a portion of the combination distillate from a non-treatment, normal, plant operation mode passage route to a treatment mode passage route by feeding combination distillate into a closed or semi-closed circulation loop at least partially passing inside the plant and which closed or semi-closed circulation loop passes the combination distillate received therein to a different location in the plant than when directed in the non-treatment mode.

17. The method of claim 16 wherein said different location in the plant is at a location positioned upstream of plant equipment to be treated.

18. The method of claim 16 wherein there is circulated in the closed or semi-closed loop one or both of a first hydrocarbon-based fluid and a second hydrocarbon-based fluid inside the equipment to be treated as part of the introduction of hydrocarbon-based fluids in the plant, such that a portion of the products distilling during said circulation are re-introduced in said closed or semi-closed loop, whereas another portion of the distillates makes up the petroleum plant production and/or the normal distillate flow stream.

19. The method of claim 16 wherein there is circulated in the closed or semi-closed loop one or both of a first hydrocarbon-based fluid and a second hydrocarbon-based fluid inside the equipment to be treated, for a time of at least 20 minutes, at a temperature comprised between 100°

C. and 900°

C. and at a pressure comprised between 1 bar and 400 bar.

20. The method of claim 1 wherein a treatment zone cleaning status monitoring criteria associated with a running of said plant is monitored, and wherein the introduction of the hydrocarbon based fluid includes the circulation within a closed or semi-closed loop of a first hydrocarbon-based fluid or a first and a second hydrocarbon based fluids, and which circulation is carried out in repeated fashion until the treatment zone cleaning status monitoring criteria is deemed satisfactory.

21. The method of claim 1 wherein the plant operating running conditions during treatment are such that there is continued distillation of fresh feed source material.

22. The method of claim 1 wherein varying the established feed rate includes, a reduction in the established feed rate by varying the fresh feed rate of the plant to a value comprised between 40% and below 100% with respect to the design feed rate, followed by the introduction of the hydrocarbon-based fluid which comprises an introduction of first and/or the second hydrocarbon-based fluid(s) in an amount as to compensate up to the difference among the rate at which the plant is running and its design feed rate, and so as to manage up to the maximum allowable plant distillate flow rate or in any case the distillate flow rate applicable prior to the introduction of the first and/or the second hydrocarbon-based fluid(s), such as to run the plant at the flow rate resulting from the sum:

[flow rate of reduced fresh feed]+[flow rate of the first and/or the second hydrocarbon-based fluid(s)], and wherein said flow rate is equal to or higher to the one prior to the reduction in fresh feed rate.

23. The method of claim 1 wherein the introduction of the hydrocarbon based fluid comprises introduction in the plant of a first and a second hydrocarbon-based fluid from separate sources, and which second hydrocarbon-based fluid joins and passes together with the first hydrocarbon-based fluid to a common treatment introduction point of the petroleum plant.

24. The method of claim 1 wherein the treatment is carried out in a plant with a furnace and wherein the treatment increases a value setting for a furnace inlet temperature of the furnace, and/or for reducing or avoiding the increase of a value setting for the tube metal temperature of the furnace, existing at the point of initiation of the treatment.

25. The method of claim 1 wherein the treatment increases the plant distillation yield in a manner beyond the quantity derivable from an equal overall feed amount to the plant distillation source(s) at a point of treatment initiation.

26. The method of claim 1 wherein the treatment reduces plant catalysts agglomeration and/or reduces coke formation on plant catalysts and/or reduces heavy compounds deposits, including coke, on plant catalysts and/or reduces differential pressure in a plant reactor containing a catalyst.

27. The method of claim 1 wherein the hydrocarbon-based fluid used for the treatment is recovered or reused in a way selected from the group consisting of:

i) routing as a blend component of a fuel/heavy oil;

ii) routing to a crude tank;

iii) routing to slop;

iv) routing inside the petroleum plant containing the equipment which has (have) been treated;

v) routing to another petroleum plant; and

(vi) any combination or subcombination of (i) to (v).

28. The method of claim 1 wherein the hydrocarbon based fluid includes the introduction of one or both of a first hydrocarbon-based fluid and a second hydrocarbon fluid that is or are capable of solubilizing the deposits in said equipment to be treated essentially under near critical or supercritical conditions at the operating conditions of the plant.

29. The method of claim 28 wherein the first hydrocarbon-based fluid contains one or more chemical products and said first hydrocarbon-based fluid and said chemical products are mixed in a proportion designed in order to be utilized in a solution form, and wherein said first hydrocarbon-based fluid forms the solvent of said chemical products.

30. The method of claim 29 wherein in the ratio solvent/chemical products varies in the range:

solvent 70%-99.99%, chemical products 0.01%-30%.

31. The method of claim 29 wherein the solvent coincides with the first hydrocarbon fluid and is internally generated in said plant and circulated inside the petroleum plant.

32. The method of claim 1 wherein the treatment is carried out according to one of:

i) injection of a first hydrocarbon fluid introduced from outside of the plant and further introduced in any part of the plant, upstream a distillation column, which is thereafter distilled and introduced in any part of the plant;

ii) internal plant generation of a first hydrocarbon fluid produced by distillation at a certain feed rate, followed by the variation of fresh feed rate, the withdrawal of said hydrocarbon fluid from any part of the plant and the introduction of said internal plant produced distillate in any part of the plant;

iii) introduction of the first hydrocarbon fluid according to one or more of the above points i) and ii) and iv) the introduction according to iii) together with a second hydrocarbon fluid which is introduced simultaneously with or subsequently to said first hydrocarbon fluid.

33. The method according to claim 1 wherein the introduction of the hydrocarbon based fluid comprises the introduction of a first hydrocarbon fluid or the first and a second hydrocarbon fluid, and which first and/or second hydrocarbon fluid is or are selected from a group consisting of distillation products from crude oil originating from the petroleum plant and/or being anyway present in the petroleum plant, by being finished products, blending components of finished products, intermediate products or feed to the petroleum plant and are selected from the group consisting of:

gasoline, diesel, gas oil, virgin naphtha, kerosene, reformed gasoline, pyrolysis gasoline, pyrolysis gas oil, light cycle oil from FCCU, decant oil from FCCU, methyl-tert-butyl-ether (MTBE), benzene, toluene, xylenes, cumene, methanol, cyclohexane, cyclohexanone, ethylbenzene, linear alkylbenzene (LAB), dimethylterephthalate, phtalic anhydride, styrene, tert-amyl-methyl-ether (TAME), ethanol, dimethylformamide (DMF), dioctylphthalate, isopropyl alcohol, butyl alcohol, allyl alcohol, butylglycol, methylglycol, ethyl-tert-butyl-ether (ETBE), ethanolamines, acetone, octyl alcohol, methyl-ethyl-ketone (MEK), methyl-isobutyl-ketone (MIBK), crude oil, fuel oil, quench oil from Ethylene Unit, aromatic gasoline from Reforming Unit, benzene/toluene/xylenes (BTX) as produced by an Aromatic Extraction Unit (inclusive of the Sulfolane, Furfural, Glycols or Formylmorpholine type), the gasoline and/or the gas oil produced in an Ethylene Unit (pyrolysis gasoline/gas oil).

34. The method according to claim 33 wherein the first and/or the second hydrocarbon fluid is or are used in combination with one or more compounds, as a standalone or mixture thereof, selected from the group consisting of:

polymethacrylates, polyisobutylene succinimmides, polyisobutylene succinates;

laurylacrylate/hydroxyethylmethacrylate copolymer;

alkylarylsulfonates, alkanolamine-alkylarylsulfonates and alkylarylsulfonic acids;

substituted amines, where the substituent is an hydrocarbon containing at least 8 carbon atoms;

acylated compounds containing nitrogen and having a substituent with at least 10 aliphatic carbon atoms, such substituent being obtained by reaction of an acylant carboxylic acid with at least an aminic compound containing at least a group-NH—

, said acylant agent being joined to said aminic compound by way of a imido, amido, amidine or acyloxyammonium bridge;

nitrogen containing condensated compounds of a phenol, an aldehyde or an aminic compound, having at least a group —

NH—

;

esters of a substituted carboxylic acid;

hydrocarbyl substituted phenols;

alkoxylated derivatives of an alcohol, a phenol or an amine;

phthalates;

organic phosphates;

oleic acids esters;

diethylhydroxylamine;

glycols and/or their derivatives, said glycols and/or their derivatives being not in a polymeric form, in the sense that they are molecules of single compounds, also in an adduct form, and not molecules constituted by a chain where a single monomer is repeated, e.g.;

tetraethyleneglycol;

mono- and di-ethers, mono- and di-esters, ether-esters and thioethers of single glycols;

glycol of general formula CH₂OH—

(CH)_nOH_n—

CH₂OH where n=0-10;

glycol ethers of general formula R₁—

O—

CH₂—

CH₂—

O—

R₂ where R₁ is an hydrocarbyl substituent C₁-C₂₀ and R₂ is H atom or an hydrocarbyl substituent C₁-C₂₀;

glycol esters of general formula R₁—

O—

O—

CH₂—

CH₂—

O—

O—

R₂ where R₁ is an hydrocarbyl substituent C₁-C₂₀ and R₂ is H atom or an hydrocarbyl substituent C₁-C₂₀;

thioglycols of general formula HO—

R₁—

S—

R₂—

OH where R₁ is an hydrocarbyl substituent C₁-C₁₀ and R₂ is H atom or an hydrocarbyl substituent C₁-C₁₀;

glycol ethers-esters of general formula R₁—

O—

CH₂—

CH₂—

O—

O—

R₂ where R₁ and R₂ are an hydrocarbyl substituent C₁-C₂₀;

ethers of general formula R₁—

O—

R₂ where R₁ or R₂ is an hydrocarbyl substituent C₁-C₂₀;

substituted benzenes of general formula

35. The method of claim 1 wherein the introduction of the hydrocarbon based treatment fluid includes the introduction in the petroleum plant of a first hydrocarbon-based fluid in a ratio comprised between 0.1% and 100% with respect to current plant fresh feed and a second hydrocarbon-based fluid in a ratio comprised between 0.01% and 50% with respect to a current plant fresh feed;

and

wherein the second hydrocarbon fluid is selected from the group consisting of;

methanol, ethanol, propanol, isopropanol, butanol, isobutanol, methylglycol monomethylether, butylglycol monobutylether, toluene, aliphatic amines C₈⁺ ethoxylated with at least 6 moles ethylene oxide, arylsulfonates, benzene, diphenyl, phenanthrene, nonylphenol, 1-methyl-2-pyrrolidinone, diethyl ether, dimethylformamide (DMF), tetrahydrofuran (THF), ethylenediamine, diethylamine, triethylamine, trimethylamine, propylamine, 1-(3-aminopropyl)-2-pyrrolidone, 1-(3-aminopropyl) imidazole, N-hydroxyethyl-imidazolidinone, N-aminoethyl-imidazolidinone, 2-(2-aminoethylamino) ethanol, isopropylamine, cumene, 1, 3, 5 trimethylbenzene, 1, 2, 4 trimethylbenzene, maleic anhydride, p-toluidine, o-toluidine, dipropylamine, diphenyl ether, hexamethylbenzene, propylbenzene, cyclohexylamine, 1-isopropyl-4-methyl-benzene, 1, 2, 3, 5 tetramethylbenzene, hexanol, morpholine, o-xylene, m-xylene, p-xylene, butylamine, methylamine, mesitylene, examine, succinic anhydride, decahydronaphthalene, ethylbenzene, 1, 2 dimethylnaphthalene, 1, 6 dimethylnaphthalene, p-cymene, ethyl ether, isopropyl ether, etoxybenzene, phenyl ether, acetophenone, monoethanolamine (MEA), diethanolamine (DEA), triethanolamine (TEA), diethyleneglycol, triethyleneglycol, tetraethyleneglycol, hexyl glycol, dodecylbenzene, lauryl alcohol, myristyl alcohol, thiodiglycol, dioctylphthalate, diisooctylphthalate, didecylphthalate, diisodecylphthalate, dibutylphthalate, dinonylphthalate, methylethylketone (MEK), methylisobutylketone (MIBK), methyl-tert-butyl-ether (MTBE), cyclohexane, cyclohexanone, methyl- or ethyl-esters of fatty acids achieved by esterification of vegetal and/or animal oils (biodiesel);

dimethylamine, ethylamine, ethyl formate, methyl acetate, dimethylformamide (DMF), propanol, propylamine, isopropylamine, trimethylamine, tetrahydrofuran (THF), ethyl vinyl ether, ethyl acetate, propyl formate, butanol, methyl propanol, diethyl ether, methyl propyl ether, isopropyl methyl ether, diethyl sulfide, butylamine, isobutylamine, diethylamine, diethylhydroxylamine, cyclopentanol, 2-methyltetrahydrofuran, tetrahydropyran, pentanal, isobutyl formate, propyl acetate, pentanoic acid, butyl methyl ether, tert-butyl methyl ether, ethyl propyl ether, methylpyridines, methylcyclopentane, cyclohexanol, hexanal, pentyl formate, isobutyl acetate, 2-ethoxyethyl acetate, methyl pentyl ether, dipropyl ether, diisopropyl ether, hexanol, methyl pentanols, triethylamine, dipropylamine, diisopropylamine, benzaldehyde, toluene, cresols, benzyl alcohol, methylanilines, dimethylpyridines, furfural, pyridine, methylcyclohexane, heptanol, acetophenone, ethylbenzene, xylenes, ethylphenols, xylenols, anilines, dimethylaniline, ethylaniline, octanenitrile, ethyl propanoate, methyl butanoate, methyl isobutanoate, propyl propanoate, ethyl 2-methyl propanoate, methyl pentanoate, heptanoic acid, octanoic acid, 2-ethylhexanoic acid, propyl 3-methylbutanoate, octanoles, 4-methyl-3-heptanol, 5-methyl-3-heptanol, 2-ehtyl-1-hexanol, dibutyl ether, di-tert-butyl ether, dibutylamine, diisobutylamine, quinoline, isoquinoline, indane, cumene, propylbenzene, 1,2,3-trimethylbenzene, 1, 2, 4, -trimethylbenzene, mesitylene, o-toluidine, N,N-dimethyl-o-toluidine, nonanoic acid, nonanols, naphthalene, butylbenzene, isobutylbenzene, cymenes, p-diethylbenzene, 1,2,4,5-tetramethylbenzene, decahydronaphthalene, decanoic acid, decanol, 1-methylnaphthalene, carbazole, diphenyl, hexamethylbenzene, dodecanols, diphenylmethane, tridecanols, tetradecanols, hexadecanols, heptadecanols, terphenyls, octadecanols, eicosanols;

fatty amines and their mixtures, p-toluidine, toluene, dipropylamine, diisobutyl acetate, propyl acetate, propyl-ethyl-ether, triethylamine, ethylbenzene, propylbenzene, butylbenzene, cumene, para-xylene, hexamethylbenzene, triethanolamine, diphenylmethane, MTBE, dioctylphthalate, diisodecylphthalate, diisoctylphthalate, nonylether, methyloleate, dioctylether;

the compounds named in plural refer to all possible isomers of said compound;

e.g. the term “

xylenes”

indicated o-xylene, m-xylene, p-xylene;

said compounds can also be used under supercritical conditions.

36. The method according to claim 35 wherein the second hydrocarbon fluid comprises one or more compound(s) working as swelling agent selected from those forming hydrogen bonds and those not forming hydrogen bonds, wherein the swelling agents not forming hydrogen bonds are selected from the group consisting of:

benzene, toluene, cyclohexane, naphthalene, diphenyl, xylene, tetralin, methylcyclohexane; and

wherein the swelling agents forming hydrogen bonds are selected from the group consisting of;

pyridine, methanol, ethanol, ethylenediamine, propanol, 1,4-dioxane, acetone, formamide, aniline, tetrahydrofuran, N,N-dimethylaniline, diethylether, dimethylsulphoxide, acetophenone, dimethylformamide, ethyl acetate, methyl acetate, methylethylketone, 1-methyl-2-pyrrolidone, quinoline.

37. The method of claim 1 wherein the introduction of the hydrocarbon based treatment fluid includes the introduction in the petroleum plant of a first hydrocarbon-based fluid in a ratio comprised between 0.1% and 100% with respect to current plant fresh feed and a second hydrocarbon-based fluid in a ratio comprised between 0.01% and 50% with respect to a current plant fresh feed;

and wherein the second hydrocarbon fluid comprises one or more compound(s) having a boiling temperature >

150°

C. selected from the group selected of;

anthraquinone, eicosanol, benzalacetophenone, benzanthracene, hydroquinone, dodecylbenzene, hexaethylbenzene, hexamethylbenzene, nonylbenzene, 1,2,3-triaminobenzene, 1,2,3-trihydroxybenzene, 1,3,5-triphenylbenzene, diphenylmethanol, p-benzidine, benzil, 2-benzoylbenzofurane, benzoic anhydride, 2-benzoyl-methyl benzoate, benzyl benzoate, 4-tolyl benzoate, benzophenone, 4,4′

-bis(dimethylamino) benzophenone, 2,2′

-dihydroxybenzophenone, 2,2′

-dimethylbenzophenone, 4,4′

-dimethylbenzophenone, methylbenzophenone, 2-amino benzyl alcohol, 3-hydroxy benzyl alcohol, α

-1-naphthyl benzyl alcohol, benzyl-ethyl-phenyl-amine, benzylaniline, benzyl ether, phenylacetophenone, 2-acetamide diphenyl, 2-amino diphenyl, 4,4′

-bis(dimethylamino) diphenyl, biphenol, butyl-bis(2-hydroxyethyl)amine, butylphenylamine, butylphenylketone, carbazole, diphenylcarbonate, cetyl alcohol, cetylamine, benzylcinnamate, coumarin, lindane, dibenzofuran, dibenzylamine, diethylene glycol dibenzyl ether, diethylene glycol monolaurate, diethylene glycol (2-hydroxypropyl) ether, diethylenetriamine, di-α

-naphthylamine, di-β

-naphthylamine, dioctylamine, diphenylamine, diphenylmethane, 4,4′

-diamino diphenyl, 4,4′

-dimethylamino diphenyl, 4-hydroxy diphenyl, diphenylmethanol, diphenylethylamine, di-(α

-phenylethyl) amine, di-iso-propanolamine, di-2-tolylamine, eicosanol, 1,1,2 triphenylethane, ethylene glycol 1,2 diphenyl, ethyl-di-benzylamine, ethylene glycol monobenzyl ether, ethylene glycol monophenyl ether, N,N-diphenylformamide, phenylformamide, tolylformamide, 2-benzoylfurane, 2,5 diphenylfurane, and related esters, heptadecylamine, heptadecanol, cetyl alcohol, hexadecanamine, cethylic alcohol, hydroxyethyl-2-tolylamine, triethanolamine, cyclohexanone, imidazole, methylimidazole, phenylimidazole, 5-amino-indane, 5-hexyl-indane, 1-phenyl-1,3,3-trimethyl-indane, 2,3 diphenyl-indene, indole, 2,3 dimethyl-indole, tryptamine, 2-phenyl-indo le, isocoumarin, diethyl-isophthalate, isoquinoline, benzyl laurate, phenyl laurate, lauryl alcohol, lauryl amine, lauryl sulphate, diethyl-benzyl-malonate, melamine, diphenylmethane, triphenylmethane, 4 benzyl-morpholine, 4-phenyl-morpholine, 4-(4 tolyl)-morpholine, myristic alcohol, 9,10-dihydro-naphthacene, acetyl-naphthalene, benzyl-naphthalene, butyl-naphthalene, dihydro-naphthalene, dihydroxy-naphthalene, methyl-naphthalene, phenyl-naphthalene, naphthol, naphthylamine, methylnaphthylamine, naphthylphenalamine, α

-naphthyl-2-tolyl-Ketone, nonacosanol, octadecanol, octyl-phenyl-ether, pentadecylamine, pentadecanol, 3-hydroxyacetophenone, tyramine, 4-hydroxyphenylacetonitrile, o-phenylenediamine, N-phenyl-phenylenediamine, 4-methyl-phenylenediamine, diphenylether, bis-(2-phenylethyl)amine, phosphine derivatives as phenyl, triphenyl and oxide, triphenylphosphite, dibutyl phthalate, dibenzyl phthalate, diethyl phthalate, dioctyl phthalate, diisoctyl phthalate, didecyl phthalate, diphenyl phthalate, phthalic anhydride, N-benzoylpiperidine, 1,3-diphenoxypropane, N-(2-tolyl)propionamide, 1-methyl-3-phenyl-pyrazoline, pyridine derivatives as 3-acetamido, 3-benzyl, 4-hydroxy, 2-phenyl, phenylsuccinic anhydride, succinimide, N-benzylsuccinimide, N-phenylsuccinimide, o-terphenyl, m-terphenyl, 1,14 tetradecanediol, tetradecanol, tetraethyleneglycol, tetraethylenepentamine, 2,5-diaminotoluene, 3,5-dihydroxytoluene, 4-phenyltoluene, p-toluenesulfonic acid and related methyl and propyl esters, o-toluic acid and related anhydride, N-benzyl-toluidine (o-, m- e p-), tribenzylamine, tributylamine, triethanolamine, triethyleneglycol and related monobutylether, trihepylamine, trioctylamine, triphenylamine, tritane, tritanol, 2-pyrrolidone, xanthene, xanthone, xylidine.

38. Method according to claim 1 further comprising monitoring treatment level and wherein the monitoring is performed with one or more analysis method selected from the group consisting of:

viscosity (e.g. ASTM D

     445);

density (e.g. ASTM D1298);

atmospheric or vacuum distillation (e.g. ASTM D86, D1160);

carbon residue (e.g. ASTM D4530, D

     189);

sediments by hot filtration (e.g. IP 375,

     390);

sediments by extraction (e.g. ASTM D473);

sediments by filtration (e.g. ASTM

     4807);

ash (e.g. ASTM D482, EN6245);

asphaltene (e.g. IP143), color (e.g. ASTM D1500), water and sediments (e.g. ASTM D2709, D1796);

or an analysis method of the physical type, selected from the group consisting of;

i) evaluation of the fouling factor, defined as the ratio among the heat transfer coefficient of clean equipment and the heat transfer coefficient of the equipment at the time when the value is recorded;

ii) evaluation of pressure in various points of the plant;

iii) evaluation of temperature in various points of the plant.

39. Method according to claim 1 further comprising the following steps to achieve gas free/safe entry conditions:

a) suspension of feed introduction;

b) optional circulation in a closed or semi-closed loop of the first and/or second hydrocarbon fluid inside the equipment to be treated, for a time of at least 20 minutes, at a temperature comprised between 100°

C. and 900°

C. and at a pressure comprised between 1 bar and 400 bar;

c) cooling of the equipment/plant;

d) emptying of the equipment/plant from all of the hydrocarbons;

e) introduction of water inside the equipment/plant;

f) implementing a closed circulation loop encompassing the equipment/plant;

g) introduction in the closed circulation loop of one or more chemical washing/cleaning products and their mixtures;

h) setting up the temperature and the pressure inside the closed circulation loop at values comprised between 60°

C. and 350°

C. and between 1 bar and 50 bar;

i) circulation of the water solution of the chemical product(s) inside the closed circulation loop under conditions of temperature and pressure comprised between 60°

C. and 350°

C. and between 1 and 50 bar, for a time comprised between 20 minutes and 60 days;

j) cooling (including the eventual introduction of fresh water in the loop) and emptying of the loop from the water solution;

k) optional routing of the water solution to the oily water treatment plant;

l) optional repeating of the steps from e) to k).

40. Method according to claim 39 wherein the steps from e) to k) are replaced by the steps:

m) introduction inside of the apparatus/plant of steam at a pressure comprised between 1.5 bar and 100 bar;

n) introduction in said steam of one or more washing/cleaning chemical product(s) including their mixtures;

o) introduction inside of the equipment/plant of the mixture steam/chemical product(s) according to present invention, for a time of at least 20 minutes,

p) optional circulation of condensed steam, containing a chemical product;

q) emptying of condenses from the equipment/plant;

r) optional routing of condenses to the oily water treatment plant.

41. The method according to claim 40 wherein the chemical product used for washing/cleaning is selected from the group consisting of:

non-ionic surfactants, anionic surfactants, terpenes derivatives, emulsifiers, hydrogen sulphide scavengers, mercury scavengers and their mixtures in any proportion, including their aqueous solutions.

42. Method according to claim 41 wherein the anionic and non-ionic surfactants are selected from the group consisting of:

alkyl-, aryl-, or alkylaryl-benzensulphonates of general formula RC₆H₄SO₃M wherein R is an hydrocarbyl substituent C₈-C₂₀ and M is the ion H, Na, Ca, ammonium, triethanolammonium, isopropylammonium;

dialkylsulfosuccinates of general formula RO₂CCH₂CH(SO₃Na)CO₂R wherein R is an hydrocarbyl substituent C₂-C₂₀;

alkylsulfates of general formula ROSO₃M wherein R is an hydrocarbyl substituent C₅-C₂₀ and M is the ion sodium, ammonium, triethanolammonium;

ethoxylated and sulphated alcohols of general formula R—

(—

OCH₂CH2-)_n-OSO₃M wherein R is an hydrocarbyl substituent C₅-C₂₀, n=1-5 and M is the ion sodium, ammonium, triethanolammonium;

ethoxylated and sulphated alkylphenols of general formula RC₆H₆—

(—

OCH₂CH₂—

)_n—

OSO₃M wherein R is an hydrocarbyl substituent C₅-C₂₀, n=1-5 and M is the ion sodium, ammonium, triethanolammonium;

ethoxylated alcohols of general formula R—

(—

O—

CH₂CH₂—

)_n—

OH wherein R is an hydrocarbyl substituent C₅-C₃₀, n=1-30;

ethoxylated alkyl phenols of general formula RC₆H₄—

(—

OCH₂CH₂—

)_n—

OH wherein R is an hydrocarbyl substituent C₅-C₃₀, n=1-40;

mono- and di-fatty acids glyceric esters wherein acid contains an hydrocarbyl substituent C₁₀-C₄₀;

mono- and di-polyoxyethylene esters of oils and fatty acids of general formula RCO—

(—

OC₂H₄—

)_n—

OH and RCO—

(—

OC₂H₄—

)_n—

OOCR wherein the oil is of the “

tall oil”

or “

rosin oil”

type, n=1-40 and the acid contains and hydrocarbyl substituent C₁₀-C₄₀;

ethoxylated “

castor oils”

(castor oil is a triglyceride abundant in ricinoleic esters) containing a number of polyethoxylated ethylene oxide groups variable between 5 and 200;

mono- and di-ethanolamides of fatty acids of general formula RCONHC₂H₄OOCR and RCON(C₂H₄OH)C₂H₄OOCR wherein R is an hydrocarbyl substituent C₁₀-C₄₀;

surfactants of poly(oxyethylene-co-oxypropylene), also known as block polymer, having molecular weight of 50-10000;

mono-, di- and poly-aliphatic amines derived from fatty acids, such as RNHCH₂CH₂CH₂NH₂ wherein R is an hydrocarbyl substituent C₁₀-C₄₀;

N-alkyltrimethylendiamines of general formula

43. The method according to claim 39 wherein the chemical product used for washing/cleaning is selected from the group consisting of:

non-ionic surfactants, anionic surfactants, terpenes derivatives, emulsifiers, hydrogen sulphide scavengers, mercury scavengers and their mixtures in any proportion, including their aqueous solutions.

44. Method according to claim 43 wherein the anionic and non-ionic surfactants are selected from the group consisting of:

alkyl-, aryl-, or alkylaryl-benzensulphonates of general formula RC₆H₄SO₃M wherein R is an hydrocarbyl substituent C₈-C₂₀ and M is the ion H, Na, Ca, ammonium, triethanolammonium, isopropylammonium;

dialkylsulfosuccinates of general formula RO₂CCH₂CH(SO₃Na)CO₂R wherein R is an hydrocarbyl substituent C₂-C₂₀;

alkylsulfates of general formula ROSO₃M wherein R is an hydrocarbyl substituent C₅-C₂₀ and M is the ion sodium, ammonium, triethanolammonium;

ethoxylated and sulphated alcohols of general formula R—

(—

OCH₂CH2-)_n—

OSO₃M wherein R is an hydrocarbyl substituent C₅-C₂₀, n=1-5 and M is the ion sodium, ammonium, triethanolammonium;

ethoxylated and sulphated alkylphenols of general formula RC₆H₆—

(—

OCH₂CH₂—

)_n—

OSO₃M wherein R is an hydrocarbyl substituent C₅-C₂₀, n=1-5 and M is the ion sodium, ammonium, triethanolammonium;

ethoxylated alcohols of general formula R—

(—

O—

CH₂CH₂—

)_n—

OH wherein R is an hydrocarbyl substituent C₅-C₃₀, n=1-30;

ethoxylated alkyl phenols of general formula RC₆H₄—

(—

OCH₂CH₂—

)_n—

OH wherein R is an hydrocarbyl substituent C₅-C₃₀, n=1-40;

mono- and di-fatty acids glyceric esters wherein acid contains an hydrocarbyl substituent C₁₀-C₄₀;

mono- and di-polyoxyethylene esters of oils and fatty acids of general formula RCO—

(—

OC₂H₄—

)_n—

OH and RCO—

(—

OC₂H₄—

)_n—

OOCR wherein the oil is of the “

tall oil”

or “

rosin oil”

type, n=1-40 and the acid contains and hydrocarbyl substituent C₁₀-C₄₀;

ethoxylated “

castor oils”

(castor oil is a triglyceride abundant in ricinoleic esters) containing a number of polyethoxylated ethylene oxide groups variable between 5 and 200;

mono- and di-ethanolamides of fatty acids of general formula RCONHC₂H₄OOCR and RCON(C₂H₄OH)C₂H₄OOCR wherein R is an hydrocarbyl substituent C₁₀-C₄₀;

surfactants of poly(oxyethylene-co-oxypropylene), also known as block polymer, having molecular weight of 50-10000;

mono-, di- and poly-aliphatic amines derived from fatty acids, such as RNHCH₂CH₂CH₂NH₂ wherein R is an hydrocarbyl substituent C₁₀-C₄₀;

N-alkyltrimethylendiamines of general formula

45. A petroleum plant apparatus to perform the method according to claim 1 comprising:

i) withdrawal means from one or more point(s) in the petroleum plant of one or more hydrocarbon fluid(s);

ii) introduction means of said one or more hydrocarbon fluid(s) as above withdrawn into one or more point(s) of the petroleum plant;

iii) distillation means of said one or more hydrocarbon fluid(s) as above introduced into one or more point(s) of the petroleum plant;

iv) re-withdrawal and re-introduction means of said one or more hydrocarbon fluid(s) as above distilled to re-withdraw said distilled fluid(s) and re-introduce it (them) into one or more point(s) of the petroleum plant, wherein said re-withdrawal and re-introduction means can be the same withdrawal and introduction means as above;

v) connection means in order to form a closed or semi-closed loop, encompassing the equipment to be treated, wherein said one or more hydrocarbon fluid(s) will be continuously distilled, withdrawn and introduced;

vi) a discharge system of the hydrocarbon fluid(s), to allow their removal from the closed or semi-closed loop;

vii) control means, to control or regulate temperature and/or pressure and/or flowrate;

viii) optional filtration means.

46. The apparatus of claim 45 wherein said withdrawal means has the one or more withdrawal points positioned as to withdraw one or more hydrocarbon fluid(s) having the following intervals of boiling points:

a) up to 75°

C.;

b) from 75°

C. to 175°

C.;

c) from 175°

C. to 350°

C.;

d) above 350°

C.; and

wherein introduction means introduce the one or more withdrawn hydrocarbon fluid(s) in any one or more point(s) of the plant.

47. A petroleum plant apparatus to perform the method according to claim 1 comprising a distillate source wherein a distillate from said distillate source is withdrawn from a point within a closed or semi-closed loop forming at least a portion of said plant, and an entry point wherein there is introduced upstream of equipment to be treated the drawn off distillate and then redistilled to be thereafter re-withdrawn from the same point and re-introduced in the same equipment to be treated for a time necessary to treat said equipment.

48. The apparatus of claim 47 wherein withdrawal means are located in one or more point(s) of the plant that is (are) selected from the group consisting of:

suction/discharge of a produced gasoline pump;

suction/discharge of an overhead reflux pump;

suction/discharge of one or more bottom/middle/top pumparound pump(s);

suction/discharge of a produced kerosene pump;

suction/discharge of a produced gas oil pump;

suction/discharge of any distilled hydrocarbon pump;

hydrocarbon line exiting any petroleum apparatus;

suction/discharge of a crude oil booster pump at desalter outlet;

any combination or sub-combinations for the items listed above;

wherein introduction means are located in one or more point(s) of the plant selected from the group consisting of;

suction/discharge of a plant feed pump;

suction/discharge of a crude oil booster pump at desalter outlet;

suction/discharge of a column bottom pump;

suction/discharge of a heavy gas oil pump;

inlet of an preheat train;

inlet of an equipment to be treated;

distillation residue line, upstream/downstream of any heat exchanger;

column bottom;

in a pump external of the plant, being part of another plant or installed on purpose, in temporary or permanent execution;

any combination or sub-combinations for the items listed above;

wherein distillation means are located in one or more point(s) of the petroleum plant selected from the group consisting of;

atmospheric distillation column;

vacuum distillation column;

extractive distillation column;

any combination or sub-combinations for the items listed above;

and wherein the withdrawal point(s) and the introduction point(s) of said one or more hydrocarbon fluid(s) are connected to form a closed or semi-closed loop.

49. A method of designing a plant for carrying out the method of claim 1 wherein the equipment subject to treatment is designed such that there is avoided inputting into the equipment an equal to or greater than 20% fouling factor as well as presentment of fouling back up equipment in the plant design.

50. A method of manufacturing of a plant for carrying out the method of claim 1 comprising rendering into a physical plant based on a plant design wherein the equipment subject to treatment is designed such that there is avoided inputting into the equipment an equal to or greater than 20% fouling factor as well as presentment of fouling back up equipment in the plant design.

51. The method of claim 50 wherein the treated equipment has a surface from 0.1% to 100% lower with respect to a non-treated equipment.

52. The method of claim 1 wherein the hydrocarbon-based treatment fluid is utilized and is limited to an internal-to-plant originated distillation product that is circulated and recirculated within the plant to a treatment zone upstream or downstream from the distillation source location of the plant.

53. The method of claim 1, further comprising

varying the fresh feed rate to the plant in association with a) and/or b).

54. The method of claim 1 wherein, following distilling said additional source or sources for distillation for the purpose of plant treatment, distillate source or sources used for plant treatment are circulated and recirculated continuously and without interruption within the plant until output from the plant with output plant product.

55. The method of claim 1 wherein said introduction of a hydrocarbon-based treatment fluid includes that which is sourced from a distillation device of the plant;

and distilling said additional source or sources for distillation for the purpose of plant treatment is carried out within the distillation device.

56. The method of claim 1 wherein the additional source or sources of distillate is associated with a variation to the fresh feed rate being fed into the plant, and wherein there is a re-introduction of distillate to another point in the plant through a closed or semi-closed loop associated with the plant, and wherein the plant runs continuously and without interruption both during and between production of the additional source or sources and the reintroduction of distillate.

57. The method of claim 1 wherein the process stream involved in the formation of the combination distillate comprises fresh feed of the plant.

58. The method of claim 1 wherein, in the step of passing the diverted stream containing combination distillate to the process stream, the diverted stream containing combination distillate is fed through a closed or semi-closed loop, at least partly formed by said plant, to the process stream of the plant.

59. The method of claim 1 wherein the relative concentration of the distillates forming the combination distillate is the same in each of the continuation stream and the diverted stream after diversion.

60. The method of claim 1 wherein the diverted stream is placed in contact with equipment of the plant positioned in the plant treatment zone and upstream of a distillation unit that forms the combination distillate.

61. The method of claim 1 wherein the combination distillate is formed by a first distillation unit and the combination distillate stream formed by the first distillation unit is directed to a separation unit as to recover some or all of the hydrocarbon-based treatment fluid for the purpose of plant treatment.

62. The method of claim 1 wherein the diverted stream is subjected to a second distillation and then hydrocarbon-based treatment fluid is separated out from the second distilled diverted stream for the purpose of plant treatment.

63. A method for treating a petroleum plant or equipment of the petroleum plant during a running of the petroleum plant, comprising:

maintaining, during a treatment period, the petroleum plant under a production operating condition, typical of the plant itself, which includes providing fresh feed to the petroleum plant;

while maintaining the petroleum plant under the production operating condition, there is carried out one or both of a) and b);

a) introducing in the petroleum plant, during the treatment period, a hydrocarbon-based treatment fluid;

b) varying an established feed rate, present at initiation of the treatment of the petroleum plant or equipment of the petroleum plant, which established feed rate ranges from a maximum operation rate for the petroleum plant, which is inclusive of a design rate for the petroleum plant, to a minimum operation rate which is set at a level for satisfying a minimum production operating state in the petroleum plant;

wherein said introduction of a hydrocarbon-based treatment fluid and/or said variation to the established feed rate generates an additional source or sources for distillation with respect to the amount provided by the established rate present at initiation of treatment; and

distilling said additional source or sources for distillation for the purpose of plant treatment, and

wherein the petroleum plant runs, relative to a pre-existing fresh feed rate, at an increased fresh feed rate that is below a design fresh feed rate of the plant, or at the design fresh feed rate, or higher than the design fresh feed rate, so as to produce an increased amount of distillates, and, thereafter, varying the fresh feed rate to the plant by progressively reducing the fresh feed rate, such that the increased amount of produced distillates, with respect to the amount of distillates produced with the pre-existing fresh feed rate, is circulated in parts of the plant to be treated.

64. A method for treating a petroleum plant or equipment of the petroleum plant during a running of the petroleum plant, comprising:

maintaining, during a treatment period, the petroleum plant under a production operating condition, typical of the plant itself, while providing fresh feed to the petroleum plant;

while maintaining the petroleum plant under the production operating condition, introducing, during the treatment period, a hydrocarbon-based treatment fluid into a closed or semi-closed loop forming at least part of the petroleum plant with the hydrocarbon-based fluid being derived from either an external source of the hydrocarbon-based fluid, an internal plant source of the hydrocarbon-based fluid or both; and

varying a fresh feed rate to the petroleum plant in conjunction with the introduction of the hydrocarbon-based treatment fluid.

65. The method of claim 64 wherein varying a fresh feed rate to the petroleum plant in conjunction with the introduction of the hydrocarbon-based treatment fluid includes an initial reduction in an established feed rate of the plant to a value comprised between 40% and below 100% with respect to the design feed rate, followed by the introduction of the hydrocarbon-based fluid which comprises an introduction of first and/or the second hydrocarbon-based fluid(s) in an amount as to compensate up to the difference among the rate at which the plant is running and its design feed rate, and so as to manage up to the maximum allowable plant distillate flow rate or in any case the distillate flow rate applicable prior to the introduction of the first and/or the second hydrocarbon-based fluid(s), such as to run the plant at the flow rate resulting from the sum:

[flow rate of reduced fresh feed]+[flow rate of the first and/or the second hydrocarbon-based fluid(s)], and wherein said flow rate is equal to or higher to the one prior to the reduction in feed rate.

66. The method of claim 64 wherein the internal plant source of the hydrocarbon-based fluid is a distillation column and distillate from the column is sent to a treatment region of the plant upstream or downstream from said distillation column.

67. A method for treating a petroleum plant or equipment of the petroleum plant during a running of the petroleum plant, comprising:

maintaining, during a treatment period, the petroleum plant under a production operating condition, typical of the plant itself, while providing fresh feed to the petroleum plant;

while maintaining the petroleum plant under the production operating condition, introducing in the petroleum plant, during the treatment period, a hydrocarbon-based treatment fluid; and

adjusting of the fresh feed by increasing the plant fresh feed rate from an established feed rate to a level above the established feed rate as to generate an additional quantity of distillates relative to a quantity generated at the established feed rate, and drawing off at least some of an overall quantity of distillate generated from the increased plant feed rate and introducing the drawn off distillate into a treatment region of said plant for the purpose of cleaning deposits from one or more pieces of equipment in the treatment region.

68. A petroleum plant apparatus to perform the method according to claim 67, comprising:

one or more withdrawal point(s) of a distillate or mixtures of distillates;

one or more introduction point(s) of a distillate or mixtures of distillates, as previously withdrawn;

one or more introduction point(s) of a first and/or second hydrocarbon fluid;

one or more pump(s) connected to said withdrawal point(s) of distillate(s) and/or of the product(s) exiting the plant, having sufficient characteristics to introduce said distillate(s) and/or said product(s) exiting the plant in the closed or semi-closed circulation loop and/or in one or more selected point(s) of the plant, said pump(s) being already part of said petroleum plant, or installed on purpose, or in mobile and/or temporary execution;

an inlet system of an hydrocarbon fluid or mixtures of hydrocarbon fluids, to allow the introduction of said hydrocarbon fluid(s) in the closed or semi-closed loop;

one or more lines and/or connection systems to close the closed or semi-closed loop comprising the withdrawal point(s) and/or introduction point(s) of the distillate(s), the pump(s) and the equipment, having sufficient characteristics to circulate said distillate(s) and/or said product exiting the plant inside the closed or semi-closed loop and/or in one or more selected point(s) in the plant, said lines and/or connections being already part of said petroleum plant, or installed on purpose, or in mobile and/or temporary execution;

a discharge system of the fluids, to allow their removal from the closed or semi-closed loop;

gauges and/or controllers of temperature, pressure, flow rate; and

valves and/or sectioning and/or non-return systems.

69. The method of claim 67 further comprising passing said drawn off distillate through a closed or semi-closed loop forming at least a portion of said plant and extending through the treatment region, and wherein said closed or semi-closed loop of said plant is configured such that drawn off distillate is re-introduced into a distillation device of the plant which is a source of the initially drawn off distillate and drawing off a recirculation output of distillate from said distillation device following receipt of the re-introduced drawn off distillate and passing the recirculation output of distillate to the treatment region.

70. The method of claim 67 wherein the petroleum plant runs, relative to a pre-existing fresh feed rate, at an increased fresh feed rate that is below a design fresh feed rate of the plant, or at the design fresh feed rate, or higher than the design fresh feed rate, so as to produce an increased amount of distillates, thereafter progressively reducing the fresh feed rate, such that the increased amount of produced distillates, with respect to the amount of distillates produced with the pre-existing fresh feed rate, is circulated in parts of the plant to be treated.

71. The method of claim 67 wherein the treatment region is upstream or downstream from a distillation device from which distillate is sourced, and wherein introducing the drawn off distillate into a treatment region of said plant is carried out in a continuously re-circulating manner and removes heavy deposits from one or more pieces of equipment in the treatment region.