# US 10,246,994 B2 · System for communicating data via fluid lines > Agents: this data is available as JSON from the patentgrep API and MCP server — see https://patentgrep.com/llms.txt - Number: US 10,246,994 B2 - Document ID: US10246994B2 - Status: Granted - Kind: B2 - Application number: 14/850,341 - Filed: 2015-09-10 - Published: 2017-03-16 - Granted: 2019-04-02 - Earliest claimed: 2015-09-10 - Assignees: Cameron International Corporation - Applicants: Cameron International Corporation - Inventors: Andrew Jaffrey - Web page: https://patentgrep.com/patent/US10246994B2 ## CPC - E21B 47/18: through the well fluid {, e.g. mud pressure pulse telemetry} - E21B 33/064: specially adapted for underwater well heads - E21B 41/0007: {for underwater installations (E21B41/005, E21B41/04, E21B41/06, E21B41/08, E21B41/10 take precedence)} - E21B 47/06: Measuring temperature or pressure - E21B 47/07: Temperature - E21B 47/09: Locating or determining the position of objects in boreholes or wells {, e.g. the position of an extending arm}; Identifying the free or blocked portions of pipes - F16K 37/005: {for measuring fluid parameters (F16K37/0033 takes precedence)} - G01R 33/07: Hall effect devices - E21B: EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS - F16K: VALVES; TAPS; COCKS; ACTUATING-FLOATS; DEVICES FOR VENTING OR AERATING {(devices for emptying and evacuating the excess liquid in valves or conduits F16L55/07)} - G01R: MEASURING ELECTRIC VARIABLES; MEASURING MAGNETIC VARIABLES (indicating correct tuning of resonant circuits H03J3/12) ## Abstract The present disclosure relates generally to data communication in subsea oil and gas drilling and production operations. In particular, data communication from sensors located on a piece of subsea oil and gas drilling and/or production equipment to a remote location, such as to a demodulation system, is disclosed. The data communication system can include sensors for measuring various characteristics of the subsea equipment, for coding the measured data into a signal, for transmitting the signal, and for ultimately decoding the signal. The signal is transmitted along the structures which provide the containment for existing hydraulic fluid lines associated with the subsea equipment by a variety of methods, such as by pulse position modulation and/or reverse time pulse position modulation. The communication system can further include a local power generator assembly to power associated sensors and transmitters. ## Claims ### Claim 1 A system comprising: a plurality of pieces of subsea equipment capable of fluid communication with a plurality of fluid pressurized lines; a plurality of sensors, each sensor coupled to a respective piece of subsea equipment of the plurality of pieces of subsea equipment and configured to measure a respective characteristic of the respective piece of subsea equipment; a plurality of transmitters each coupled to a first portion of a respective structure that provides containment for a respective pressurized fluid line of the plurality of pressurized fluid lines and are each configured to transmit the respective measured characteristic from the respective sensor via a respective signal along the respective structure that provides containment for the respective pressurized fluid line of the plurality of pressurized fluid lines; and a plurality of receivers each coupled to a second portion of the respective structure that provides containment for the respective pressurized fluid line of the plurality of pressurized fluid lines and are each configured to receive the respective signal transmitted along the respective structure that provides containment for the respective pressurized fluid line of the plurality of pressurized fluid lines. ### Claim 2 (depends on 1) The system of claim 1, further comprising a demodulator configured to receive the signal from the receiver and decode the signal. ### Claim 3 (depends on 1) The system of claim 1, further comprising a communal demodulator configured to receive the signals from the plurality of receivers and decode the signals. ### Claim 4 (depends on 1) The system of claim 1, further comprising a plurality of demodulators configured to receive the signals from the plurality of receivers and decode the signals. ### Claim 5 (depends on 1) The system of claim 1, wherein the signal comprises a time reversed pulse position modulated signal. ### Claim 6 (depends on 1) The system of claim 1, wherein the signal comprises a pulse position modulated signal. ### Claim 7 (depends on 1) The system of claim 1, wherein the plurality of pieces of subsea equipment comprises a blowout preventer and an associated control system. ### Claim 8 (depends on 1) The system of claim 1, wherein the measured characteristic is at least one of temperature, pressure, and position of a movable element located within the piece of subsea equipment. ### Claim 9 (depends on 7) The system of claim 7, wherein a sensor from the plurality of sensors is coupled to the blowout preventer and configured to measure a characteristic of the blowout preventer; and wherein a transmitter from the plurality of transmitters is configured to vibrate the structure that provides the containment for the fluid line located on and capable of fluid communication with the blowout preventer to transmit the measured characteristic of the blowout preventer via a signal along the structure that provides the containment for the fluid line to a respective receiver. ### Claim 10 (depends on 9) The system of claim 9, further comprising a demodulator configured to receive and decode the signal. ### Claim 11 (depends on 9) The system of claim 9, wherein the signal comprises a time reversed pulse position modulated signal. ### Claim 12 (depends on 9) The system of claim 9, wherein the signal comprises a pulse position modulated signal. ### Claim 13 (depends on 9) The system of claim 9, wherein the characteristic is at least one of temperature, pressure, and position of a movable element located within the blowout preventer. ### Claim 14 (depends on 9) The system of claim 9, wherein the sensor is coupled to a valve on the blowout preventer and the measured characteristic comprises a position of the valve. ### Claim 15 (depends on 9) The system of claim 9, further comprising a subsea power generator coupled to the system and configured to power the sensor and the transmitter. ### Claim 16 (depends on 15) The system of claim 15, wherein the subsea power generator comprises a piezoelectric material configured to be in contact with a fluid contained in the fluid line and to generate an electrical charge when deformed by the fluid. ### Claim 17 (depends on 16) The system of claim 16, wherein the subsea power generator further comprises a capacitor bank configured to store electrical charge. ### Claim 18 (depends on 9) The system of claim 9, wherein the receiver is coupled to the structure that provides the containment for the fluid line and is configured to receive the signal.