# US 2019/0376385 A1 · Systems and methods for real-time well surveillance > Agents: this data is available as JSON from the patentgrep API and MCP server — see https://patentgrep.com/llms.txt - Number: US 2019/0376385 A1 - Document ID: US20190376385A1 - Status: Published application - Kind: A1 - Application number: 16/544,335 - Filed: 2019-08-19 - Published: 2019-12-12 - Earliest claimed: 2013-09-04 - Assignees: Petrolink International Ltd. - Applicants: Petrolink International Ltd. - Inventors: Rafael Angel BERMUDEZ MARTINEZ - Web page: https://patentgrep.com/patent/US20190376385A1 ## CPC - E21B 47/06: Measuring temperature or pressure - E21B 49/00: Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells - E21B 44/04: in response to the torque of the drive {; Measuring drilling torque (E21B44/06 takes precedence; measuring stresses in a well bore pipe E21B47/007)} - E21B 49/005: {Testing the nature of borehole walls or the formation by using drilling mud or cutting data} - G01V 11/002: {Details, e.g. power supply systems for logging instruments, transmitting or recording data, specially adapted for well logging, also if the prospecting method is irrelevant (means for transmitting well survey signals E21B47/12; signal transmission systems in general G08C; transmission in general H04B)} - E21B: EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS - G01V: GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS (means for indicating the location of accidentally buried, e.g. snow-buried, persons A63B29/02) ## Abstract In an embodiment, a method is performed by a computer system. The method includes integrating a series of data inputs related to a well. The series of data inputs includes at least one real-time data input and at least one non-real-time data input. The method further includes based, at least in part, on a result of the integrating, facilitating a real-time display of performance data for the well. The real-time display includes information related to at least one of hydraulic surveillance and torque-and-drag surveillance. ## Claims ### Claim at position 1 1-20. (canceled) ### Claim 21 A method comprising, by a computer system: receiving, in real-time, a volumetric flow rate and a mud weight produced by sensors in relation to a well; receiving non-real-time data in relation to the well; identifying at least one of a laminar flow, a transitional flow, and a turbulent flow of a fluid in the well based, at least in part, on the mud weight; responsive to the identifying, determining a fanning friction factor; determining an equivalent circulating density associated with each of a plurality of measured depths in the well based, at least in part, on the fanning friction factor, the volumetric flow rate, the mud weight, and the non-real-time data; and for each of the plurality of measured depths, facilitating a real-time display of the equivalent circulating density, wherein the real-time display of the equivalent circulating density comprises information relating to the equivalent circulating density corresponding to real-time measured depths in the well. ### Claim 22 (depends on 21) The method of claim 21, comprising: determining a Reynolds number based, at least in part, on the mud weight and the non-real-time data; determining a critical velocity based, at least in part, on the Reynolds number and the non-real-time data; and determining a critical flow rate based, at least in part, on the critical velocity. ### Claim 23 (depends on 22) The method of claim 22, wherein the fanning friction factor is based, at least in part, on the Reynolds number. ### Claim 24 (depends on 21) The method of claim 21, comprising determining a pressure loss gradient based, at least in part, on the volumetric flow rate, the mud weight, and the non-real-time data. ### Claim 25 (depends on 24) The method of claim 24, comprising determining a pressure loss for at least one of inside a drill pipe, inside a drill collar, between a drill pipe and casing of the well, between a drill pipe and an open portion of the well, and between a drill collar and an open portion of the well based, at least in part, on the pressure loss gradient. ### Claim 26 (depends on 21) The method of claim 21, comprising determining at least one power law constant based, at least in part, on the non-real-time data. ### Claim 27 (depends on 26) The method of claim 26, comprising determining an effective viscosity base, at least in part, on the at least one power law constant and the volumetric flow rate. ### Claim 28 A system comprising a processor and memory, wherein the processor and memory in combination are operable to implement a method comprising: receiving, in real-time, a volumetric flow rate and a mud weight produced by sensors in relation to a well; receiving non-real-time data in relation to the well; identifying at least one of a laminar flow, a transitional flow, and a turbulent flow of a fluid in the well based, at least in part, on the mud weight; responsive to the identifying, determining a fanning friction factor; determining an equivalent circulating density associated with each of a plurality of measured depths in the well based, at least in part, on the fanning friction factor, the volumetric flow rate, the mud weight, and the non-real-time data; and for each of the plurality of measured depths, facilitating a real-time display of the equivalent circulating density, wherein the real-time display of the equivalent circulating density comprises information relating to the equivalent circulating density corresponding to real-time measured depths in the well. ### Claim 29 (depends on 28) The system of claim 28, wherein the method comprises: determining a Reynolds number based, at least in part, on the mud weight and the non-real-time data; determining a critical velocity based, at least in part, on the Reynolds number and the non-real-time; and determining a critical flow rate based, at least in part, on the critical velocity. ### Claim 30 (depends on 29) The system of claim 29, wherein the fanning friction factor is based, at least in part, on the Reynolds number. ### Claim 31 (depends on 28) The system of claim 28, wherein the method comprises determining a pressure loss gradient based, at least in part, on the volumetric flow rate, the mud weight, and the non-real-time data. ### Claim 32 (depends on 31) The system of claim 31, wherein the method comprises determining a pressure loss for at least one of inside a drill pipe, inside a drill collar, between a drill pipe and casing of the well, between a drill pipe and an open portion of the well, and between a drill collar and an open portion of the well based, at least in part, on the pressure loss gradient. ### Claim 33 (depends on 28) The system of claim 28, wherein the method comprises determining at least one power law constant based, at least in part, on the non-real-time data. ### Claim 34 (depends on 33) The system of claim 33, wherein the method comprises determining an effective viscosity base, at least in part, on the at least one power law constant and the volumetric flow rate. ### Claim 35 A computer-program product comprising a non-transitory computer-usable medium having a computer-readable program code embodied therein, the computer-readable program code adapted to be executed to implement a method comprising: receiving, in real-time, a volumetric flow rate and a mud weight produced by sensors in relation to a well; receiving non-real-time data in relation to the well; identifying at least one of a laminar flow, a transitional flow, and a turbulent flow of a fluid in the well based, at least in part, on the mud weight; responsive to the identifying, determining a fanning friction factor; determining an equivalent circulating density associated with each of a plurality of measured depths in the well based, at least in part, on the fanning friction factor, the volumetric flow rate, the mud weight, and the non-real-time data; and for each of the plurality of measured depths, facilitating a real-time display of the equivalent circulating density, wherein the real-time display of the equivalent circulating density comprises information relating to the equivalent circulating density corresponding to real-time measured depths in the well. ### Claim 36 (depends on 35) The computer-program product of claim 35, wherein the method comprises: determining a Reynolds number based, at least in part, on the mud weight and the non-real-time data; determining a critical velocity based, at least in part, on the Reynolds number and the non-real-time data; and determining a critical flow rate based, at least in part, on the critical velocity. ### Claim 37 (depends on 36) The computer-program product of claim 36, wherein the fanning friction factor is based, at least in part, on the Reynolds number. ### Claim 38 (depends on 35) The computer-program product of claim 35, wherein the method comprises determining a pressure loss gradient based, at least in part, on the volumetric flow rate, the mud weight, and the non-real-time data. ### Claim 39 (depends on 38) The computer-program product of claim 38, wherein the method comprises determining a pressure loss for at least one of inside a drill pipe, inside a drill collar, between a drill pipe and casing of the well, between a drill pipe and an open portion of the well, and between a drill collar and an open portion of the well based, at least in part, on the pressure loss gradient. ### Claim 40 (depends on 35) The computer-program product of claim 35, wherein the method comprises: determining at least one power law constant based, at least in part, on the non-real-time data; and determining an effective viscosity base, at least in part, on the at least one power law constant and the volumetric flow rate.