# US 11,898,430 B2 · Adjusting wellbore operations in target wellbore using trained model from reference wellbore > Agents: this data is available as JSON from the patentgrep API and MCP server — see https://patentgrep.com/llms.txt - Number: US 11,898,430 B2 - Document ID: US11898430B2 - Status: Granted - Kind: B2 - Application number: 17/318,638 - Filed: 2021-05-12 - Published: 2022-11-17 - Granted: 2024-02-13 - Earliest claimed: 2021-05-12 - Assignees: Halliburton Energy Services, Inc. - Applicants: Halliburton Energy Services, Inc. - Inventors: Eric Howard Holley - Web page: https://patentgrep.com/patent/US11898430B2 ## CPC - E21B 43/267: reinforcing fractures by propping - E21B 43/2607: {Surface equipment specially adapted for fracturing operations} - E21B 47/06: Measuring temperature or pressure - E21B 47/113: using electrical indications; using light radiations - 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 - G01V 3/38: Processing data, e.g. for analysis, for interpretation, for correction - G06N 20/00: Machine learning - E21B 2200/20: Computer models or simulations, e.g. for reservoirs under production, drill bits - G01V 1/226: {Optoseismic systems} - 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) - G06N: COMPUTING ARRANGEMENTS BASED ON SPECIFIC COMPUTATIONAL MODELS ## Abstract A system can receive data that can indicate a flow rate with respect to perforations in a reference wellbore. The data can be received from a fiber optic cable in the reference wellbore in a geographic area of interest. The system can determine a uniformity index, which can indicate a uniformity of flow with respect to the perforations, based on the data. The system can generate a pressure-based model by training a model using the uniformity index for applying the pressure-based model to a target wellbore in the geographic area of interest to determine controls to rate and proppant with respect to the target wellbore. ## Claims ### Claim 1 A method comprising: receiving, by a computing device, a pressure-based model trained using a uniformity index based on data received from a fiber optic cable in a reference wellbore in a geographic area of interest, wherein the uniformity index is determined for each perforation cluster of a plurality of perforation clusters of the reference wellbore, wherein the uniformity index indicates a uniformity of flow for each perforation of each perforation cluster of the plurality of perforation clusters with respect to other perforation clusters included in the plurality of perforation clusters; receiving, by the computing device, data indicating pressure with respect to a target wellbore in the geographic area of interest; applying, by the computing device, the pressure-based model to the data to determine an estimated uniformity index of the target wellbore; and outputting, by the computing device, commands to adjust a completion operation with respect to the target wellbore based on the estimated uniformity index. ### Claim 2 (depends on 1) The method of claim 1, wherein the data received from the fiber optic cable includes flow rates per perforation cluster of a plurality of perforation clusters in the reference wellbore, and wherein the pressure-based model correlates the uniformity index of the reference wellbore a pressure of the reference wellbore. ### Claim 3 (depends on 1) The method of claim 1, wherein applying the pressure-based model to the data to determine the estimated uniformity index of the target wellbore includes determining the estimated uniformity index of the target wellbore without any fiber optic cable being present in the target wellbore. ### Claim 4 (depends on 1) The method of claim 1, wherein outputting commands to adjust the completion operation with respect to the target wellbore based on the estimated uniformity index includes determining a pump rate of the completion operation and a proppant of the completion operation. ### Claim 5 (depends on 4) The method of claim 4, wherein the target wellbore includes a second plurality of perforation clusters, and wherein applying the pressure-based model to the data to determine the estimated uniformity index of the target wellbore includes determining the estimated uniformity index for the second plurality of perforation clusters. ### Claim 6 (depends on 5) The method of claim 5, wherein outputting commands to adjust the completion operation with respect to the target wellbore includes generating the commands based on the estimated uniformity index for the second plurality of perforation clusters. ### Claim 7 (depends on 1) The method of claim 1, wherein the pressure-based model includes a pump-rate model, a diverter model, or a proppant model, wherein a pump rate of a completion operation is controllable by the pump-rate model, wherein an amount of diverter to drop with respect to the completion operation is controllable by the diverter model, and wherein a sand mixture used in the completion operation is controllable by the proppant model. ### Claim 8 A non-transitory computer-readable medium comprising instructions that are executable by a processing device for causing the processing device to perform operations comprising: receiving data from a fiber optic cable in a reference wellbore in a geographic area of interest, the data indicating a flow rate with respect to a plurality of perforation clusters in the reference wellbore; determining a uniformity index for each perforation cluster of the plurality of perforation clusters based on the data, the uniformity index indicating a uniformity of flow for each perforation of each perforation cluster of the plurality of perforation clusters with respect to other perforation clusters included in the plurality of perforation clusters; generating a pressure-based model by training a model using the uniformity index for applying the pressure-based model to a target wellbore in the geographic area of interest; receiving data indicating pressure with respect to the target wellbore in the geographic area of interest; applying the pressure-based model to the data indicating pressure with respect to the target wellbore to determine an estimated uniformity index of the target wellbore; and outputting commands to adjust a completion operation with respect to the target wellbore based on the estimated uniformity index. ### Claim 9 (depends on 8) The non-transitory computer-readable medium of claim 8, wherein the data from the fiber optic cable includes a pump rate of the reference wellbore and a pressure of the reference wellbore usable for determining a flow distribution of the reference wellbore, and wherein the operation of determining the uniformity index based on the data from the fiber optic cable includes using a coefficient of variation that is a standard deviation of the flow distribution of the reference wellbore divided by a mean of the flow distribution in the reference wellbore. ### Claim 10 (depends on 9) The non-transitory computer-readable medium of claim 9, wherein the pressure-based model is usable for controlling rate and proppant in the target wellbore without any fiber optic cable being present in the target wellbore. ### Claim 11 (depends on 8) The non-transitory computer-readable medium of claim 8, wherein the operation of generating the pressure-based model includes training the pressure-based model using the uniformity index for each perforation cluster of the plurality of perforation clusters. ### Claim 12 (depends on 11) The non-transitory computer-readable medium of claim 11, wherein the operation of outputting commands to adjust the completion operation with respect to the target wellbore includes generating the commands based on the estimated uniformity index for the plurality of perforation clusters. ### Claim 13 (depends on 8) The non-transitory computer-readable medium of claim 8, wherein the pressure-based model includes a pump-rate model or a proppant model, wherein a pump rate of a completion operation is controllable by the pump-rate model, and wherein a sand mixture used in the completion operation is controllable by the proppant model. ### Claim 14 (depends on 1) The method of claim 1, wherein the uniformity index comprises a plurality of cluster uniformity indexes, and wherein each cluster uniformity index of the plurality of cluster uniformity indexes corresponds to a different perforation cluster of the plurality of perforation clusters.