# US 8,788,210 B2 · Job monitoring methods and apparatus for logging-while-drilling equipment > Agents: this data is available as JSON from the patentgrep API and MCP server — see https://patentgrep.com/llms.txt - Number: US 8,788,210 B2 - Document ID: US8788210B2 - Status: Granted - Kind: B2 - Application number: 13/799,361 - Filed: 2013-03-13 - Published: 2013-08-01 - Granted: 2014-07-22 - Earliest claimed: 2008-06-23 - Assignees: Schlumberger Technology Corporation - Applicants: Schlumberger Technology Corporation - Inventors: Sylvain Ramshaw; Julian J. Pop; Peter Swinburne; Kai Hsu; Steven Villareal - Web page: https://patentgrep.com/patent/US8788210B2 ## CPC - E21B 49/08: Obtaining fluid samples or testing fluids, in boreholes or wells - 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 - 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: EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS ## Abstract Job monitoring methods and apparatus for logging-while-drilling equipment are disclosed. A disclosed example method includes identifying a downhole scenario based on a property of an underground geological formation, selecting a first telemetry frame type based on the identified downhole scenario, conveying an identifier representative of the selected first telemetry frame type to a downhole fluid sampling tool, and receiving a first telemetry data frame from the downhole fluid sampling tool, the telemetry data frame containing fluid analysis parameters for a fluid, and being constructed in accordance with the selected first telemetry frame type. ## Claims ### Claim 1 A method comprising: identifying a downhole scenario based on a property of an underground geological formation; selecting a first telemetry frame type based on the identified downhole scenario; conveying an identifier representative of the selected first telemetry frame type to a downhole fluid sampling tool; and receiving a first telemetry data frame from the downhole fluid sampling tool, the first telemetry data frame containing first fluid analysis parameters for a fluid, and being constructed in accordance with the selected first telemetry frame type. ### Claim 2 (depends on 1) The method as defined in claim 1, further comprising receiving a second telemetry data frame from a second downhole fluid sampling tool, the second telemetry data frame conveying information associated with the property of the formation. ### Claim 3 (depends on 2) The method as defined in claim 2, comprising conveying an identifier representative of the second telemetry frame type to the downhole fluid sampling tool in response to determining that an incorrect downhole scenario was identified. ### Claim 4 (depends on 2) The method as defined in claim 2, wherein the second telemetry data frame is constructed in accordance with a second telemetry frame type different from the first telemetry frame type. ### Claim 5 (depends on 2) The method as defined in claim 2, wherein the second downhole fluid sampling tool comprises the first downhole fluid sampling tool. ### Claim 6 (depends on 2) The method as defined in claim 2, wherein the second telemetry data frame conveys second fluid analysis parameters for a second fluid, and wherein at least one of the second fluid analysis parameters differs from one of the first fluid analysis parameters. ### Claim 7 (depends on 6) The method as defined in claim 6, wherein the one of the second fluid analysis parameters differs from the one of the first fluid analysis parameters in at least one of a parameter type, a parameter resolution or a frequency of conveyance. ### Claim 8 (depends on 1) The method as defined in claim 1, wherein the property of the formation is measured at a first location of the formation, and the first telemetry data frame contains fluid analysis parameters for a fluid sample associated with a second location of the formation. ### Claim 9 (depends on 8) The method as defined in claim 8, wherein the first location of the formation comprises a first wellbore in the formation, and the second location of the formation comprises a second wellbore in the formation. ### Claim 10 (depends on 1) The method as defined in claim 1, wherein the property of the formation is at least one of a formation resistivity, a formation porosity, a formation bulk density, an identified formation fluid type, or a pressure gradient. ### Claim 11 (depends on 1) The method as defined in claim 1, wherein the identifier is conveyed to the downhole sampling tool before the downhole sampling tool is placed into a wellbore. ### Claim 12 (depends on 1) The method as defined in claim 1, further comprising: presenting the property of the formation to an operator; and receiving the identified fluid type from the operator. ### Claim 13 (depends on 1) The method as defined in claim 1, wherein the downhole scenario is identified using a basin or reservoir model representing fluid flow in the underground geological formation. ### Claim 14 (depends on 1) The method as defined in claim 1 wherein: the downhole scenario comprises at least one of a formation fluid type, an operating condition, a formation dynamic property, a tool status, a tool condition, a drilling fluid type, a sampling regime, a formation property, a wellbore property, a downhole tool property, or a formation fluid property; and the formation fluid type comprises at least one of water, heavy oil, black oil, volatile oil, wet gas, dry gas, or gas condensate. ### Claim 15 (depends on 1) The method of claim 1 wherein identifying a downhole scenario comprises determining whether a fault condition exists, and wherein selecting the first telemetry frame type is based on whether the fault condition exists. ### Claim 16 (depends on 1) The method of claim 1, wherein the first telemetry frame type defines a subset of sensor outputs to be conveyed within the first telemetry data frame. ### Claim 17 (depends on 1) The method of claim 1, wherein the first telemetry frame type defines a precision level for a sensor output to be conveyed within the first telemetry data frame. ### Claim 18 (depends on 1) The method of claim 1, wherein selecting a first telemetry frame type comprises selecting the first telemetry frame type from a library of frame types.