# US 9,038,451 B2 · Optical method for determining fouling of crude and heavy fuels > Agents: this data is available as JSON from the patentgrep API and MCP server — see https://patentgrep.com/llms.txt - Number: US 9,038,451 B2 - Document ID: US9038451B2 - Status: Granted - Kind: B2 - Application number: 13/151,951 - Filed: 2011-06-02 - Published: 2012-05-24 - Granted: 2015-05-26 - Earliest claimed: 2010-07-08 - Assignees: Baker Hughes Incorporated - Applicants: Corina L. Sandu; Sebatian Csutak; Marco Respini; Huzeifa Ismail; Michael O. Brauchle - Inventors: Corina L. Sandu; Sebatian Csutak; Marco Respini; Huzeifa Ismail; Michael O. Brauchle - Web page: https://patentgrep.com/patent/US9038451B2 ## CPC - G01N 21/8507: {Probe photometers, i.e. with optical measuring part dipped into fluid sample} - G01N 33/2823: {Raw oil, drilling fluid or polyphasic mixtures} - G01N 2021/8405: {Application to two-phase or mixed materials, e.g. gas dissolved in liquids} - G01N: INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES (measuring or testing apparatus or processes other than immunoassay, involving enzymes or microorganisms C12M, C12Q) ## Abstract A method for detecting the formation of at least one phase in a mixture, particularly a hydrocarbon mixture. The method may include using a probe to expose a portion of the mixture to electromagnetic radiation to determine the value of a parameter of interest indicative of the formation of a phase. The method may also include using the value of the parameter of interest with a correlation between a known property of the mixture and the value of a parameter of interest to detect the formation of a phase. ## Claims ### Claim 1 A method for detecting phase formation in a hydrocarbon mixture using a probe comprising a housing, comprising: installing the probe for operation in a flowing fluid comprising the hydrocarbon mixture such that an exterior of the housing is immersed in the flowing fluid, the probe configured to be retracted while not in operation; and detecting in operation, in situ, formation of a second phase in the hydrocarbon mixture with a first phase using data from the probe and a known property of the hydrocarbon mixture, wherein the probe is responsive to an electromagnetic signal that has passed through a portion of the mixture across a gap in the probe; and wherein the portion of the mixture enters the probe through the gap. ### Claim 2 (depends on 1) The method of claim 1 where the hydrocarbon mixture, is selected from at least one of the group consisting of: (i) a crude oil, (ii) a heavy crude oil, (iii) a heavy fuel oil, (iv) a #6 oil, (v) a diesel oil, and (vi) a bunker fuel oil. ### Claim 3 (depends on 1) The method of claim 1 where the second phase is selected from at least one of the group consisting of: (i) an aggregation of asphaltenes, (ii) scale, and (iii) a hydrocarbon hydrate. ### Claim 4 (depends on 1) The method of claim 1 where the data from the probe is a signal indicating a relative permittivity of the hydrocarbon mixture. ### Claim 5 (depends on 1) The method of claim 1 where the probe comprises: a housing configured to at least partly transmit an electromagnetic beam and configured to be placed in contact with the hydrocarbon mixture; an electromagnetic source configured to transmit an electromagnetic beam through the housing and toward the hydrocarbon mixture; and a sensor positioned to receive a reflected electromagnetic beam from the housing. ### Claim 6 (depends on 1) The method of claim 1, further comprising: changing at least one condition selected from the group consisting of: (i) the temperature of the hydrocarbon mixture, (ii) the pressure of the hydrocarbon mixture, and combinations thereof. ### Claim 7 (depends on 1) The method of claim 1, where the detection is performed continuously. ### Claim 8 (depends on 1) The method of claim 1, wherein the hydrocarbon mixture is flowing. ### Claim 9 (depends on 1) The method of claim 1, wherein the gap is less than 20 micrometers. ### Claim 10 (depends on 1) The method of claim 1, wherein the gap is configured to draw the portion of the mixture into the gap through capillary action. ### Claim 11 (depends on 1) The method of claim 1, wherein the gap is submerged in the flowing fluid and configured for free passage of the mixture into the gap from an exterior of the probe. ### Claim 12 (depends on 1) The method of claim 1, wherein positioning the probe in a flowing fluid comprises inserting the probe into a flow inside at least one of i) a wellbore; and ii) a pipeline. ### Claim 13 (depends on 1) The method of claim 1 where the known property is a correlation between formation of the second phase and a relative permittivity of the hydrocarbon mixture. ### Claim 14 (depends on 13) The method of claim 13, wherein the correlation is estimated using a parameter selected from the group consisting of: (i) p-testing, (ii) titration, and (iii) optical detection and combinations thereof. ### Claim 15 (depends on 1) The method of claim 1 where the probe comprises: a housing; an electromagnetic source disposed on the housing; and a sensor disposed on the housing such that the hydrocarbon mixture is between the electromagnetic source and the sensor along a beam path; wherein the gap comprises a slit in the housing. ### Claim 16 (depends on 15) The method of claim 15 where the electromagnetic source, is selected from at least one of the group consisting of: (i) visible light source, (ii) an infrared light source, and (iii) an ultraviolet light source. ### Claim 17 (depends on 15) The method of claim 15 where the electromagnetic source is a coherent light source. ### Claim 18 (depends on 1) The method of claim 1, further comprising: adding an additive to the hydrocarbon mixture. ### Claim 19 (depends on 18) The method of claim 18, further comprising: detecting an elimination of the second phase in the hydrocarbon mixture using data from the probe and the known property of the hydrocarbon mixture. ### Claim 20 (depends on 18) The method of claim 18, further comprising: controlling an amount of the additive to be added to the hydrocarbon mixture based on data from the probe and the known property of the hydrocarbon mixture. ### Claim 21 A non-transitory computer-readable medium product having stored thereon instructions that, when executed by at least one processor, perform a method, the method comprising: extending a probe from a retracted position to an extended position within a flowing fluid; detecting formation of a second phase in a hydrocarbon mixture with a first phase using data from a probe positioned in a flowing fluid comprising the hydrocarbon mixture and a known property of the hydrocarbon mixture, wherein the probe is responsive to an electromagnetic signal that has passed through a portion of the mixture across a gap in the probe, the portion of the mixture having entered the probe through the gap. ### Claim 22 (depends on 21) The non-transitory computer-readable medium product of claim 21, further comprising at least one of: (i) a ROM, (ii) an EPROM, (iii) an EEPROM, (iv) a removable RAM, (v) a flash memory, and (vi) an optical disk. ### Claim 23 A method for detecting phase formation in a hydrocarbon mixture using a probe comprising a housing, comprising: installing the probe for operation in a flowing fluid comprising the hydrocarbon mixture such that an exterior of the housing is immersed in the flowing fluid, the probe configured to be retracted while not in operation; and detecting, in situ, formation of a second phase in the hydrocarbon mixture with a first phase by comparing a change in a parameter of interest of the hydrocarbon mixture, wherein the parameter of interest is estimated by the probe and the change exceeds a selected threshold. ### Claim 24 (depends on 23) The method of claim 23 where the hydrocarbon mixture, is selected from at least one of the group consisting of: (i) a crude oil, (ii) heavy crude oil, (iii) a heavy fuel oil, (iv) a diesel oil, and (v) a #6 oil, and (vi) a bunker oil. ### Claim 25 (depends on 23) The method of claim 23 where the second phase is selected from at least one of the group consisting of: (i) aggregated asphaltenes, (ii) scale, and (iii) a hydrocarbon hydrate. ### Claim 26 (depends on 23) The method of claim 23 where the parameter of interest is relative permittivity. ### Claim 27 (depends on 23) The method of claim 23, further comprising: controlling an amount of an additive to be added to the substance based on data from the probe and the known property of the hydrocarbon mixture; detecting an elimination of the second phase in the substance using data from the probe and the known property of the hydrocarbon mixture. ### Claim 28 (depends on 23) The method of claim 23, using, for the selected threshold, from about 0.001 to about 0.05 RI units. ### Claim 29 A method for detecting phase formation in a hydrocarbon mixture using a probe comprising a housing, comprising: installing the probe for operation in a flowing fluid comprising the hydrocarbon mixture such that an exterior of the housing is immersed in the flowing fluid, the probe configured to be retracted while not in operation; and detecting, in situ, formation of a second phase in the hydrocarbon mixture with a first phase using data from the probe and a known property of the hydrocarbon mixture; and adding an additive inhibiting the second phase to the hydrocarbon mixture responsive to detecting the second phase. ### Claim 30 (depends on 29) The method of claim 29, further comprising controlling an amount of the additive added to the hydrocarbon mixture based on the data from the probe and the known property of the hydrocarbon mixture. ### Claim 31 A method for detecting phase formation in a hydrocarbon mixture using a probe comprising a housing, comprising: detecting, in situ, formation of a second phase in the hydrocarbon mixture with a first phase using data from the probe and a known property of the hydrocarbon mixture, wherein the probe is responsive to an electromagnetic signal that has passed through a portion of the mixture across a gap in the probe, wherein the gap is configured to draw the portion of the mixture into the gap through capillary action. ### Claim 32 A method for detecting phase formation in a hydrocarbon mixture using a probe comprising a housing, comprising: positioning the probe in a flowing fluid comprising the hydrocarbon mixture such that an exterior of the housing is immersed in the flowing fluid; and detecting, in situ, formation of a second phase in the hydrocarbon mixture with a first phase using data from the probe and a known property of the hydrocarbon mixture, wherein the probe is responsive to an electromagnetic signal that has passed through a portion of the mixture across a gap in the probe; and wherein the portion of the mixture enters the probe through the gap, and wherein the gap is less than 20 micrometers.