# US 12,180,795 B2 · Debris resistant keyed running tool and method > Agents: this data is available as JSON from the patentgrep API and MCP server — see https://patentgrep.com/llms.txt - Number: US 12,180,795 B2 - Document ID: US12180795B2 - Status: Granted - Kind: B2 - Application number: 17/523,533 - Filed: 2021-11-10 - Published: 2023-05-11 - Granted: 2024-12-31 - Earliest claimed: 2021-11-10 - Assignees: Halliburton Energy Services, Inc. - Applicants: Halliburton Energy Services, Inc. - Inventors: Wesley P. Dietz; David Joe Steele - Web page: https://patentgrep.com/patent/US12180795B2 ## CPC - E21B 23/03: for setting the tools into, or removing the tools from, laterally offset landing nipples or pockets - E21B 7/061: {the tool shaft advancing relative to a guide, e.g. a curved tube or a whipstock} - E21B 23/00: Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells (setting of casings, screens or liners E21B43/10) - E21B: EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS ## Abstract Provided is a keyed running tool for use with a slotted orientation apparatus. The keyed running tool, in one aspect, includes a housing, and two or more keys extending from the housing, the two or more keys movable between a radially retracted state and a radially extended state, wherein adjacent ones of the two or more keys are laterally offset from each other and radially offset from each other by Y degrees, wherein Y is 180 degrees or less. ## Claims ### Claim 1 A keyed running tool for use with a slotted orientation apparatus, comprising: a housing, the housing having a first lateral location and a second different lateral location; a first key extending from the housing at the first lateral location, the first key movable between a first radially retracted state and a first radially extended state; a second key adjacent to the first key and extending from the housing at the second different lateral location, the second key movable between a second radially retracted state and a second radially extended state, wherein the first key and the second key are radially offset from each other by Y degrees, wherein Y is less than or equal to 180 degrees and greater than zero degrees, and further wherein the first lateral location has no key that radially aligns with another key in the second different lateral location; and a third key extending from the housing at a third different lateral location, the third key movable between a third radially retracted state and a third radially extended state, wherein no more than two of the first, second and third keys are configured to engage with the slot. ### Claim 2 (depends on 1) The keyed running tool as recited in claim 1, wherein Y is less than 180 degrees. ### Claim 3 (depends on 1) The keyed running tool as recited in claim 1, wherein Y is 120 degrees or less. ### Claim 4 (depends on 1) The keyed running tool as recited in claim 1, wherein Y is 90 degrees or less. ### Claim 5 (depends on 1) The keyed running tool as recited in claim 1, wherein the first and second keys are laterally offset from each other by a maximum distance (dm) ranging from 2.5 cm to 900 cm. ### Claim 6 (depends on 1) The keyed running tool as recited in claim 1, wherein adjacent ones of the first, second and third keys are radially offset from each other by the Y degrees, wherein Y is equal to 120 degrees. ### Claim 7 (depends on 1) The keyed running tool as recited in claim 1, wherein an odd number of keys extend from the housing. ### Claim 8 (depends on 1) The keyed running tool as recited in claim 1, wherein the first and second keys are first and second spring loaded keys. ### Claim 9 (depends on 1) The keyed running tool as recited in claim 1, further including a swivel coupled to an uphole end of the housing, the swivel configured to allow the housing and the first and second keys to rotate when following a slot in a slotted orientation apparatus. ### Claim 10 (depends on 1) The keyed running tool as recited in claim 1, further including an engagement member coupled to a downhole end of the housing, the engagement member configured to engage with a downhole tool and rotationally position the downhole tool within a wellbore it is located within. ### Claim 11 (depends on 10) The keyed running tool as recited in claim 10, wherein the downhole tool is a whipstock. ### Claim 12 A well system, comprising: a slotted orientation apparatus positioned within a wellbore located in a subterranean formation, the slotted orientation apparatus including: a tubular having a wall thickness (t); and a slot extending at least partially through the tubular, the slot having first and second axial portions laterally offset from one another by a distance (ds), and an angled portion connecting the first and second axial portions; and a keyed running tool having a downhole tool coupled to a downhole end therein positioned within the slotted orientation apparatus, the keyed running tool including: a housing, the housing having a first lateral location and a second different lateral location; a first key extending from the housing at the first lateral location, the first key movable between a first radially retracted state and a first radially extended state; a second key adjacent to the first key and extending from the housing at the second different lateral location, the second key movable between a second radially retracted state and a second radially extended state, wherein the first key and the second key are radially offset from each other by Y degrees, wherein Y is less than or equal to 180 degrees and greater than zero degrees, and further wherein the first lateral location has no key that radially aligns with another key in the second different lateral location; and a third key extending from the housing at a third different lateral location, the third key movable between a third radially retracted state and a third radially extended state, wherein no more than two of the first, second and third keys are configured to engage with the slot. ### Claim 13 (depends on 12) The well system as recited in claim 12, wherein at least one of the first and second keys is engaged with the slot. ### Claim 14 (depends on 12) The well system as recited in claim 12, wherein two of the first and second keys are engaged with the slot. ### Claim 15 (depends on 12) The well system as recited in claim 12, wherein the slot radially extends around the tubular X degrees, wherein Y is substantially equal to X. ### Claim 16 (depends on 12) The well system as recited in claim 12, wherein Y is less than 180 degrees. ### Claim 17 (depends on 12) The well system as recited in claim 12, wherein Y is 120 degrees or less. ### Claim 18 (depends on 12) The well system as recited in claim 12, wherein the slot has a length (ls) and adjacent ones of the first and second keys are laterally offset by a maximum distance (dm), and further wherein the maximum distance (dm) is less than the length (ls). ### Claim 19 (depends on 12) The well system as recited in claim 12, wherein adjacent ones of the first, second and third keys radially offset from each other by the Y degrees, wherein Y is 120 degrees. ### Claim 20 (depends on 12) The well system as recited in claim 12, further including a swivel coupled to an uphole end of the housing, the swivel configured to allow the housing and the first and second keys to rotate when following the slot. ### Claim 21 (depends on 12) The well system as recited in claim 12, further including an engagement member coupled to a downhole end of the housing, the engagement member configured to engage with the downhole tool and rotationally position the downhole tool within the wellbore. ### Claim 22 (depends on 21) The well system as recited in claim 21, wherein the downhole tool is a whipstock. ### Claim 23 A method for aligning a downhole tool, comprising: positioning a slotted orientation apparatus within a wellbore located in a subterranean formation, the slotted orientation apparatus including: a tubular having a wall thickness (t); and a slot extending at least partially through the tubular, the slot having first and second axial portions laterally offset from one another by a distance (ds), and an angled portion connecting the first and second axial portions; and positioning a keyed running tool having a downhole tool coupled to a downhole end thereof at least partially within the slotted orientation apparatus, the keyed running tool including: a housing, the housing having a first lateral location and a second different lateral location; a first key extending from the housing at the first lateral location, the first key movable between a first radially retracted state and a first radially extended state; a second key adjacent to the second key and extending from the housing at the second different lateral location, the second key movable between a second radially retracted state and a second radially extended state, wherein the first key and the second key are radially offset from each other by Y degrees, wherein Y is less than or equal to 180 degrees and greater than zero degrees, and further wherein the first lateral location has no key that radially aligns with another key in the second different lateral location; and a third key extending from the housing at a third different lateral location, the third key movable between a third radially retracted state and a third radially extended state, wherein no more than two of the first, second and third keys are configured to engage with the slot. ### Claim 24 (depends on 23) The method as recited in claim 23, wherein adjacent ones of the first, second and third keys radially offset from each other by the Y degrees, wherein Y is 120 degrees, and further wherein positioning the keyed running tool includes: pushing the keyed running tool downhole causing a downhole one of the first, second and third keys to initially engage with and rotate within the slot until the downhole one of the first, second and third keys is positioned within the second axial portion of the slot and a middle one of the first, second and third keys is positioned within the first axial portion of the slot; then continuing to push the keyed running tool downhole causing the middle one of the first, second and third keys to rotate within the slot until the middle one of the first, second and third keys is positioned within the second axial portion of the slot and an uphole one of the first, second and third keys is positioned within the first axial portion of the slot; and then continuing to push the keyed running tool downhole causing the uphole one of the first, second and third keys to rotate within the slot until the uphole one of the first, second and third keys is positioned within the second axial portion, at which time the downhole tool is rotationally positioned within the wellbore. ### Claim 25 (depends on 23) The method as recited in claim 23, wherein adjacent ones of the first, second and third keys radially offset from each other by the Y degrees, wherein Y is 120 degrees, and further wherein positioning the keyed running tool includes: pushing the keyed running tool downhole causing a downhole one of the of the first, second and third keys to miss the slot and a middle one of the first, second and third keys to initially engage with and rotate within the slot until the middle one of the first, second and third keys is positioned within the second axial portion of the slot and an uphole one of the first, second and third keys is positioned within the first axial portion of the slot; and then continuing to push the keyed running tool downhole causing the uphole one of the first, second and third keys to rotate within the slot until the uphole one of the first, second and third keys is positioned within the second axial portion, at which time the downhole tool is rotationally positioned within the wellbore. ### Claim 26 (depends on 23) The method as recited in claim 23, wherein adjacent ones of the first, second and third keys radially offset from each other by the Y degrees, wherein Y is 120 degrees, and further wherein positioning the keyed running tool includes: pushing the keyed running tool downhole causing a downhole one and a middle one of the first, second and third keys to miss the slot and an uphole one of the first, second and third keys to initially engage with and rotate within the slot until the uphole one of the first, second and third keys is positioned within the second axial portion of the slot, at which time the downhole tool is rotationally positioned within the wellbore.