# US 10,871,068 B2 · Piping assembly with probes utilizing addressed datagrams > Agents: this data is available as JSON from the patentgrep API and MCP server — see https://patentgrep.com/llms.txt - Number: US 10,871,068 B2 - Document ID: US10871068B2 - Status: Granted - Kind: B2 - Application number: 15/661,311 - Filed: 2017-07-27 - Published: 2019-01-31 - Granted: 2020-12-22 - Earliest claimed: 2017-07-27 - Assignees: AOL Inc. - Applicants: AOI (Advanced Oilfield Innovations, Inc.) - Inventors: Daniel Maurice Lerner; Andre Orban - Web page: https://patentgrep.com/patent/US10871068B2 ## CPC - E21B 47/12: Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling - E21B 34/10: operated by control fluid supplied from outside the borehole - E21B 47/00: Survey of boreholes or wells (monitoring pressure or flow of drilling fluid E21B21/08) - E21B 47/138: {Devices entrained in the flow of well-bore fluid for transmitting data, control or actuation signals} - G06K 19/06009: {with optically detectable marking (G06K19/063, G06K19/08 take precedence)} - H04L 67/12: specially adapted for proprietary or special-purpose networking environments, e.g. medical networks, sensor networks, networks in vehicles or remote metering networks - E21B 34/06: in wells - E21B: EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS - G06K: GRAPHICAL DATA READING (image or video recognition or understanding G06V); PRESENTATION OF DATA; RECORD CARRIERS; HANDLING RECORD CARRIERS - H04L: TRANSMISSION OF DIGITAL INFORMATION, e.g. TELEGRAPHIC COMMUNICATION (arrangements common to telegraphic and telephonic communication H04M) ## Abstract A control system with probes for generating and utilizing at least one or more addressed datagrams that communicate information to and from devices along piping assemblies comprising; one or more transmitters, one or more receivers, and one or more controllers, wherein the transmitters transmit information via one or more addressed datagrams encoded within a working medium to one or more receivers among the piping assemblies, is described. Transmitters convert datagrams into signals that are transmitted within the working medium and the receivers receive signals from the transmitters and also convert signals from the working medium which is converted back into datagrams. The controllers receive and decode the datagrams so that the controllers selectively communicate and perform logical operations on piping assembly devices according to directions received from the addressed datagrams. The entire control system can function as a network of controllers, receivers, transmitters, and/or transponders as required by one or more users. ## Claims ### Claim 1 One or more probes that generate and/or utilize at least one or more addressed datagrams allowing communication from information contained within said datagrams, said probes comprising; one or more addressable transponders having one or more controllers, wherein said transponders transmit and receive information via said one or more addressed datagrams encoded within said probes or within said piping assemblies wherein said probes are used for installing, inventorying, accessing, actuating, and/or controlling one or more down-hole device(s) in a wellbore assembly comprising; marked sections along a length of an assembly, wherein components and/or portions of an original section of said assembly together function as unique readable active or passive markers, wherein said probes further comprise; (i) a first ability to read said markers, (ii) a second ability to act upon reading said markers using at least one reader by locating specific addresses within said wellbore assembly corresponding with commands having at least one signature obtained from energy sources that transmit data which is compiled into a datagram, wherein said energy sources are initiated either at the surface, bottom, or along the length of said wellbore assembly. ### Claim 2 (depends on 1) The method for using the probes of claim 1, wherein inserting said markers in strategically placed locations along an axial and/or radial portion of said piping assemblies is creating one or more patterns or sequence of patterns and wherein said markers are comprised of components each possessing, identical or different selected material compositions with cross sectional areas corresponding to each of said components. ### Claim 3 (depends on 2) The method of claim 2, wherein at least two or more of said components are rings made from different materials with distinct measurable property differences along said length of said piping assemblies, wherein said rings collectively function by providing a readable identification (ID) code producing coded piping assemblies created when said one or more patterns or sequence of patterns are read. ### Claim 4 (depends on 2) The method of claim 2, wherein said components are materials with properties selected from one or more, in any combination, from a group consisting of electrically conductive, electrically resistive, electrically insulative, electrically capacitive, electrically inductive, magnetically permeable, magnetically non-permeable, magnetically polarized, sonically transmissive, sonically absorptive, optically reflective, optically absorptive, radiation absorptive, radiation emissive that exhibit one or more features of said materials and wherein said components can be rings comprising said materials. ### Claim 5 (depends on 2) The method of claim 2, wherein said readable ID code is read in precise locations along a length of said piping assembly. ### Claim 6 (depends on 5) The method of claim 5, wherein said locations are a specific address corresponding to a feature either at the surface of, or embedded in, said piping assemblies. ### Claim 7 (depends on 2) The method of claim 2, wherein said markers appear as multiple readable bars to a reader that is reading said permanent components of said piping assemblies. ### Claim 8 (depends on 7) The method of claim 7, wherein said multiple readable bars comprise a spatial, binary, and/or bar code. ### Claim 9 (depends on 8) The method of claim 8, wherein reading by scanning said code with a reader provides an ability for finding a specific address along said piping assembly and allows for carrying out an action at said address. ### Claim 10 (depends on 2) The method of claim 2, wherein said piping assemblies are a casing which can also function as a production collar within a borehole. ### Claim 11 (depends on 2) The method of claim 2, wherein said at least one reader is at least one probe and wherein said probe is an autonomous tool. ### Claim 12 (depends on 11) The method of claim 11, wherein said reader is one or more tethered probes. ### Claim 13 (depends on 2) The method of claim 2, wherein said probes function alone or in any combination as a plug, sensor, computer, recorder, detector, scanner, and/or barcode scanner. ### Claim 14 (depends on 10) The method of claim 10, wherein said probes detect material property differences within said permanent components within said sections along said length of said casing. ### Claim 15 (depends on 2) The method of claim 2, wherein said probes direct magnetic fields in a radial direction thereby measuring eddy currents and/or changes in eddy current intensity, and wherein said probes are shielded. ### Claim 16 (depends on 15) The method of claim 15, wherein said probes are unshielded. ### Claim 17 (depends on 15) The method of claim 15, wherein said probes are singularly, collectively, or in any combination, reading, transmitting, computing, recording, receiving, distinguishing, networking, and/or measuring, at least a portion of one or more datagrams from signals generated, emitted, and/or transmitted from said probes. ### Claim 18 (depends on 17) The method of claim 17, wherein said signals are being actively generated, emitted, and/or transmitted from said piping assemblies and can be converted into datagrams. ### Claim 19 (depends on 18) The method of claim 18, wherein said signals are passively generated, emitted, and/or transmitted from said piping assemblies. ### Claim 20 (depends on 2) The method of claim 2, wherein utilizing said probes and coded piping assemblies results in uninterrupted, unimpaired, detected material property changes in said markers by using detectable changes in eddy current values received from said coded piping assemblies. ### Claim 21 (depends on 20) The method of claim 20, wherein said probes are moving or stationary and wherein said signals are read while said probes are moving or stationary. ### Claim 22 (depends on 10) The method of claim 10, wherein said collar is moving or stationary. ### Claim 23 (depends on 2) The method of claim 2, wherein said one or more probes function as sensors that they sense changes in permanent components of selected material compositions along said length of said piping assemblies. ### Claim 24 (depends on 2) The method of claim 2, wherein said permanent components are placed as radial sections in and along said length of said piping assemblies. ### Claim 25 (depends on 2) The method of claim 2, wherein marking said markers is accomplished while said piping assemblies are one or more production collars being installed in one or more wellbores. ### Claim 26 (depends on 2) The method of claim 2, wherein providing said readable ID code to a reader assists in identifying specific borehole features. ### Claim 27 (depends on 26) The method of claim 26, wherein providing said readable ID code to a reader assists in identifying specific features within a wellbore casing. ### Claim 28 (depends on 26) The method of claim 26, wherein providing said readable ID code assists in identifying branching of a borehole casing. ### Claim 29 (depends on 26) The method of claim 26, wherein said readable ID code is being read by said reader when said reader is moving in either a forward or backward direction. ### Claim 30 (depends on 26) The method of claim 26, wherein said readable ID code is read by a reader on a wireline so that said code is translated into data, wherein said data is sent to an uphole surface of a wellbore. ### Claim 31 (depends on 26) The method of claim 26, wherein said readable ID code is read by a reader on a wireline which is conveyed by jointed piping, or continuous tubing, to said uphole surface. ### Claim 32 (depends on 26) The method of claim 26, wherein said readable ID code is read by a reader on a wireline which is conveyed by a tractor or pipe crawler. ### Claim 33 (depends on 26) The method of claim 26, wherein said readable ID code is read by a reader connected to equipment not limited to measuring, computing, recording, and/or actuating. ### Claim 34 (depends on 26) The method of claim 26, wherein said readable ID code is read by a reader moved by fluids in said wellbore and not limited to pumping and production of said fluids. ### Claim 35 (depends on 26) The method of claim 26, wherein said readable ID code is read by a reader moved by gravity. ### Claim 36 (depends on 26) The method of claim 26, wherein said readable ID code is read by a reader moved by buoyancy in said fluid. ### Claim 37 (depends on 26) The method of claim 26, wherein said readable ID code is read by a reader moved by self-propulsion. ### Claim 38 (depends on 26) The method of claim 26, wherein said reader takes action upon reading said readable ID code. ### Claim 39 (depends on 38) The method of claim 38, wherein said action releases mechanical keys. ### Claim 40 (depends on 38) The method of claim 38, wherein said action upon reading said readable ID code is actuating a mechanical, electrical, electromagnetic, magnetic, pneumatic, hydraulic, radioactive, or fiber optic circuit. ### Claim 41 (depends on 38) The method of claim 38, wherein said action upon reading readable ID code initiates measurements. ### Claim 42 (depends on 38) The method of claim 38, wherein said action upon reading readable ID code is communicating with a unique identifier to specifically identified equipment along a length of and including an uphole surface of said borehole. ### Claim 43 (depends on 42) The method of claim 42, wherein actuating communications is accomplished directly or remotely using wired or wireless communication signals.