# US 12,760,641 B2 · Encoding data across different downlink channels > Agents: this data is available as JSON from the patentgrep API and MCP server — see https://patentgrep.com/llms.txt - Number: US 12,760,641 B2 - Document ID: US12760641B2 - Status: Granted - Kind: B2 - Application number: 18/189,803 - Filed: 2023-03-24 - Published: 2024-09-26 - Granted: 2026-10-13 - Earliest claimed: 2023-03-24 - Assignees: Halliburton Energy Services, Inc. - Applicants: Halliburton Energy Services, Inc. - Inventors: Paravastu Badrinarayanan - Web page: https://patentgrep.com/patent/US12760641B2 ## CPC - E21B 47/18: through the well fluid {, e.g. mud pressure pulse telemetry} - E21B 44/00: Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions - H04B 13/02: Transmission systems in which the medium consists of the earth or a large mass of water thereon, e.g. earth telegraphy - E21B: EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS - H04B: TRANSMISSION ## Abstract Some implementations include a method for transmitting encoded information via operations of drilling equipment in a drilling system comprises. The method may include emitting, via a first device, a first signal indicating first encoded information. The method may include determining a relationship between a first aspect of the first signal and a second aspect of a second signal, the relationship indicating second encoded information. The method may include emitting, via a second device, the second signal in relation to the first signal so the first and second aspects exhibit the relationship. ## Claims ### Claim 1 A method for transmitting encoded information via operations of drilling equipment in a drilling system, the method comprising: emitting, via a first device, a first signal indicating first encoded information; determining a relationship between a first aspect of the first signal and a second aspect of a second signal, the relationship indicating second encoded information comprising a portion of a data stream having information values independent of information values encoded in the first and second signals; and emitting, via a second device, the second signal in relation to the first signal so the first and second aspects exhibit the relationship, wherein the first aspect of the first signal is a first leading edge of the first signal and the second aspect of the second signal is a second leading edge of the second signal, and wherein the relationship is a time duration between the first and second leading edges. ### Claim 2 (depends on 1) The method of claim 1, the second signal including a third aspect indicating third encoded information. ### Claim 3 (depends on 1) The method of claim 1, wherein the first device includes a mud pump at a surface and the second device includes a rotary tool powered by a rotary table at the surface. ### Claim 4 (depends on 1) The method of claim 1, wherein the first signal is a negative pressure pulse from a drilling fluid pump and the second signal is a downhole measurement indicative of a revolutions per minute (RPM) of a rotary motor at a surface. ### Claim 5 (depends on 1) The method of claim 1, wherein the first signal is an electromagnetic signal and wherein the second signal is pulses selected from a group consisting of a negative pressure pulse from a drilling fluid system, RPM pulses generated by a rotating force at a surface, and RPM pulses generated by a downhole generator turbine. ### Claim 6 A method for transmitting encoded information via operations of drilling equipment in a drilling system, the method comprising: emitting, via a first device, a first signal including a first pulse that includes a first leading edge, wherein the first pulse indicates first encoded information and; determining a first time duration between the first leading edge and a second leading edge of a second pulse of a second signal, wherein the first time duration indicates second encoded information comprising a portion of a data stream having information values independent of information values encoded in the first and second signals; and emitting, via a second device, the second pulse of the second signal so the second leading edge is separated from the first leading edge by the first time duration, wherein the second pulse indicates third encoded information. ### Claim 7 (depends on 6) The method of claim 6 further comprising: determining a second time duration between the first leading edge of the first signal and a third leading edge of a third pulse of a third signal, wherein the second time duration indicates fourth encoded information; and emitting, via a third device, the third signal so the third leading edge is separated from the first leading edge, wherein the third pulse indicates fifth encoded information. ### Claim 8 (depends on 7) The method of claim 7, wherein the third signal includes a fourth pulse indicating a fourth encoded information without relation to the first signal. ### Claim 9 (depends on 6) The method of claim 6, wherein each of the first device and the second device include at least one component selected from a group consisting of: a valve, a mud pump, an electromagnetic antenna, and a rotary table. ### Claim 10 (depends on 6) The method of claim 6, wherein the first pulse indicates a negative pressure of mud flow in a borehole and the second pulse is a change in revolutions per minute of a downhole rotary tool. ### Claim 11 (depends on 6) The method of claim 6 further comprising: performing a drilling operation in a borehole based on the third encoded information. ### Claim 12 (depends on 6) The method of claim 6 further comprising: decoding, via a third downhole device, the second encoded information based on the first time duration between the first leading edge and the second leading edge. ### Claim 13 (depends on 6) The method of claim 6, where the first encoded information is encoded via differential pulse position modulation (DPPM) of flowing mud and the second encoded information is encoded via pulse width modulation of revolutions per minute of a rotating tool. ### Claim 14 (depends on 6) The method of claim 6, wherein the first device and the second device are mechanical devices. ### Claim 15 A method for transmitting encoded information via operations of drilling equipment in a drilling system, the method comprising: emitting, via a first device of the drilling system, a first signal with a first aspect indicative of a first encoded information; and emitting, via a second device of the drilling system, a second signal with a second aspect indicative of a second encoded information, wherein the emission of the second signal is performed in a relationship to the first signal, and wherein the relationship between the first signal and the second signal indicates a third encoded information comprising a portion of a data stream having information values independent of information values encoded in the first and second signals, wherein the first aspect of the first signal is a first leading edge of the first signal and the second aspect of the second signal is a second leading edge of the second signal, and wherein the relationship between the first and second signals is a time duration between the first and second leading edges. ### Claim 16 (depends on 15) The method of claim 15, wherein the first device and the second device are mechanical devices. ### Claim 17 (depends on 15) The method of claim 15 further comprising: decoding, via a third device, the first encoded information based on the first aspect of the first signal; decoding, via the third device, the second encoded information based on the second aspect of the second signal; and decoding, via the third device, the third encoded information based on the relationship between the first signal and the second signal.