# US 10,246,992 B2 · Multiphase fluid analysis > Agents: this data is available as JSON from the patentgrep API and MCP server — see https://patentgrep.com/llms.txt - Number: US 10,246,992 B2 - Document ID: US10246992B2 - Status: Granted - Kind: B2 - Application number: 15/025,841 - Filed: 2014-09-24 - Published: 2016-08-25 - Granted: 2019-04-02 - Earliest claimed: 2013-09-30 - Assignees: Total E&P Danmark A/S - Applicants: Total E&P Danmark A/S - Inventors: Jens Henrik Hansen; Kristian Mogensen - Web page: https://patentgrep.com/patent/US10246992B2 ## CPC - E21B 47/10: Locating fluid leaks, intrusions or movements - E21B 43/00: Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells (applicable only to water E03B) - E21B 43/12: Methods or apparatus for controlling the flow of the obtained fluid to or in wells (E21B43/25 takes precedence; valve arrangements E21B34/00) - E21B 47/06: Measuring temperature or pressure - E21B 2200/09: Detecting, eliminating, preventing liquid slugs in production pipes - E21B: EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS ## Abstract A method and a system of analyzing multiphase fluid flow in at least one well or pipeline is provided, the method comprises characterizing slug flow in the multiphase fluid flow by receiving a plurality of well pressure data from the at least one well, processing the plurality of well pressure data to obtain a time-varying slug amplitude and/or a time-varying slug period for slugs in the slug flow, analyzing the slug amplitudes and/or the slug periods over a period of time to thereby determine a measure of well performance. Also an oil field monitoring system for an oil field comprising a plurality of wells is provided. Each well has a pressure gauge installed to measure a well pressure and is connected to a multiphase fluid flow analyzing system. An oil field unit receives the measure of well performance from the multiphase fluid flow analyzing system, and output the measures of well performance for each of the plurality of wells. ## Claims ### Claim 1 A method of analysing multiphase fluid flow in at least one well, the method comprises: receiving in a storage a plurality of well pressure data from at least one pressure gauge installed on the at least one well; processing using a processor the plurality of well pressure data to obtain a time-varying slug amplitude and a time-varying slug period for slugs in the slug flow; analyzing, using the processor, the slug amplitudes and/or the slug periods over a period of time to thereby determine a measure of well performance to thereby characterise slug flow in the multiphase fluid flow, wherein the measure comprises a slug amplitude distribution and/or a slug period distribution over the period of time and/or wherein the measure comprises a slug amplitude average and/or a slug period average, determining average slug amplitudes and/or average slug periods over a predetermined period of time; and correlating the determined average slug amplitudes and/or average slug periods to well operating parameters, wherein the well operating parameters comprise lift gas rate, choke settings, fluid injection rates, gas-liquid ratio, wellhead pressure, downhole pressure, water-cut, water-oil ratio, temperature at wellhead and downhole; controlling an oil field unit to schedule the at least one well for testing via a test manifold based on the determined measure of well performance, wherein scheduling based on the determined measure reduces an amount of time required to identify poorly performing wells; routing, via the test manifold and according to the schedule, the at least one well to a test separator for testing. ### Claim 2 (depends on 1) The method according to claim 1, wherein the determined measure of well performance is compared with a previous measure of well performance, and if the difference between the determined measure and the previous measure fulfils a threshold criterion, perform at least one action to investigate the cause of the difference. ### Claim 3 (depends on 2) The method according to claim 2, wherein the action comprises prioritising the well in a well test schedule, receiving additional measurements from a well system, and taking a correcting action. ### Claim 4 (depends on 1) The method according to claim 1, wherein the method further comprises: determining a difference between the determined slug amplitude distribution and/or slug period distribution and a previous slug amplitude distribution and/or slug period distribution; and if the difference fulfils a threshold criterion, prioritizing the at least one well to be tested before a second well in the well test scheduling. ### Claim 5 (depends on 1) The method according to claim 1, wherein the processing of the plurality of well pressure data comprises the steps of identifying in the plurality of well pressure data a plurality of well pressure maxima and a plurality of well pressure minima, deriving a pressure difference between subsequent well pressure maxima and well pressure minima to determine time-varying slug amplitudes, and/or—deriving a time lag between two subsequent well pressure maxima and/or well pressure minima to determine time-varying slug periods. ### Claim 6 (depends on 1) The method according to claim 1, wherein the processing of the plurality of well pressure data comprises the steps of analysing the plurality of well pressure data using a Wavelet transform to determine a representation of the well pressure data, and deriving time-varying slug amplitude and/or time-varying slug period from the representation of the well pressure data. ### Claim 7 (depends on 1) The method according to claim 1, wherein the method further comprises comparing the measure of well performance for the at least one well with a reference measure of well performance for the at least one well and/or wherein the determined measure of well performance is stored in a database comprising previously determined measures of well performance for the at least one well. ### Claim 8 (depends on 1) The method according to claim 1, wherein the multiphase fluid comprises oil, gas, water and solids. ### Claim 9 (depends on 1) The method according to claim 1, wherein the method further comprises determining a number of slugs over a predetermined period of time and wherein the measure of well performance is further dependent on the number of slugs. ### Claim 10 (depends on 1) A non-transitory computer readable medium having stored thereon at least one code section for causing a processor to perform the steps of claim 1. ### Claim 11 (depends on 2) The method according to claim 2, wherein the method further comprises: comparing the determined slug amplitude distribution and/or slug period distribution with a previous slug amplitude distribution and/or slug period distribution and if the difference fulfils the threshold criterion, prioritising the at least one well in the well test scheduling; and/or determining average slug amplitudes and/or average slug periods over a predetermined period of time and correlating the determined average slug amplitudes and/or average slug periods to well operating parameters. ### Claim 12 (depends on 2) The method according to claim 2, wherein the processing of the plurality of well pressure data comprises the steps of identifying in the plurality of well pressure data a plurality of well pressure maxima and a plurality of well pressure minima, deriving a pressure difference between subsequent well pressure maxima and well pressure minima to determine time-varying slug amplitudes, and/or—deriving a time lag between two subsequent well pressure maxima and/or well pressure minima to determine time-varying slug periods. ### Claim 13 (depends on 2) The method according to claim 2, wherein the processing of the plurality of well pressure data comprises the steps of analysing the plurality of well pressure data using a Wavelet transform to determine a representation of the well pressure data, and deriving time-varying slug amplitude and/or time-varying slug period from the representation of the well pressure data. ### Claim 14 (depends on 2) The method according to claim 2, wherein the method further comprises comparing the measure of well performance for the at least one well with a reference measure of well performance for the at least one well and/or wherein the determined measure of well performance is stored in a database comprising previously determined measures of well performance for the at least one well. ### Claim 15 A system for analysing a multiphase fluid flow in at least one well transporting multiphase fluids, each well having at least one pressure gauge configured to measure well pressure, the system comprises: a processor configured to: receive well pressure data; process the well pressure data to obtain a time-varying slug amplitude and a time-varying slug period for slugs in the multiphase fluid flow; analyse the time-varying slug amplitudes and/or the time-varying slug periods over a period of time to thereby determine a measure of well performance, wherein the measure comprises a slug amplitude distribution and/or a slug period distribution over the period of time and/or wherein the measure comprises a slug amplitude average and/or a slug period average; determine average slug amplitudes and/or average slug periods over a predetermined period of time; correlate the determined average slug amplitudes and/or average slug periods to well operating parameters, wherein the well operating parameters comprise lift gas rate, choke settings, fluid injection rates, gas-liquid ratio, wellhead pressure, downhole pressure, water-cut, water-oil ratio, temperature at wellhead and downhole; control an oil field unit to schedule the at least one well for testing via a test manifold based on the determined measure of well performance, wherein scheduling based on the determined measure reduces an amount of time required to identify poorly performing wells; and routing, via the test manifold and according to the schedule, the at least one well to a test separator for testing. ### Claim 16 (depends on 15) The system according to claim 15, the system further comprising a database for receiving well pressure data from the at least one pressure gauge for the at least one well, the processor configured to receive the well pressure data from the database. ### Claim 17 (depends on 16) The system according to claim 16, further comprising a control unit configured to compare the determined measure of well performance with a previous measure of well performance, and, if the difference between the determined measure and the previous measure fulfils a threshold criterion, to provide a control signal indicating that an action should be performed. ### Claim 18 (depends on 15) A well system comprising one or more wells, each well having at least one pressure gauge installed to measure a well pressure; a common production manifold configured to receive well production output from the one or more wells; a test manifold configured to receive well production output from one of the one or more wells; and a multiphase fluid flow analysing system according to claim 15; and an oil field unit being configured to receive the control signal from the multiphase fluid flow analysing system, wherein the oil field unit is configured to schedule a well for testing in response to a received control signal from the multiphase fluid flow analysing system. ### Claim 19 (depends on 15) An oil field monitoring system for an oil field comprising a plurality of wells, each well having at least one pressure gauge installed to measure a well pressure and being connected to a multiphase fluid flow analysing system according to claim 15, the oil field monitoring system comprising: an oil field unit being configured to receive the measure of well performance from the multiphase fluid flow analysing system for each of the plurality of wells; and an interface for outputting the measures of well performance for each of the plurality of wells.