US10774635B2
Active / In Force
US
⏱️ 9.6 years remaining
Restimulation process using coiled tubing and fiber optics
Assignee: Halliburton Energy Services Inc
•
Filing: 2016-06-10
•
Granted: 2020-09-15
•
Expires: 2036-06-10
Abstract
Abstract In accordance with presently disclosed embodiments, a method and system for performing real-time evaluation of a restimulation operation using coiled tubing with fiber optics is provided. The method involves performing a restimulation treatment by pumping a slurry with diverter materials through an annulus in the wellbore surrounding the coiled tubing, and using fiber optics in the coiled tubing to identify the order and magnitude of fractures being created during the restimulation treatment. The fiber optics in the coiled tubing may include one or more fiber optic cables designed to collect distributed acoustic sensing (DAS) or distributed temperature sensing (DTS) data. The evaluation of the restimulation operation may be used to validate and/or adjust the restimulation treatment as needed to improve the lateral distribution of transverse fractures through a subterranean formation. The coiled tubing may also be used to remove sand bridges from the wellbore throughout the restimulation treatment.
Inventors
- 👤 William Owen Alexander Ruhle
- 👤 Geoffrey Gullickson
- 👤 Neha Sahdev
Bibliographic Details
Application Number
—
Jurisdiction
US
Data Source
google_patents
Last Synchronized
2026-10-31 02:49
CPC Classifications
E; E21; E21B; E21B49/00; E21B47/00; E21B47/06; E21B47/07; E21B47/10; E21B47/107; E21B47/11; E21B47/12; E21B47/13; E21B47/135; G; G01; G01N; G01N29/00; G01N29/04; G01N29/043; G01N29/22; G01N29/24; G01N29/2418; G01P; G01P5/00; G01P5/24; G01P5/241; E21B43/00; E21B43/25; E21B43/26
Claims Analysis
Total Claims: 23
Claim 1
Independent Claim
123 words
A method, comprising: positioning coiled tubing in a wellbore proximate a plurality of entry points formed between the wellbore and a subterranean formation; pumping a slurry comprising diverter material into an annulus of the wellbore surrounding the coiled tubing; collecting distributed acoustic sensing (DAS) data along a fiber optic cable disposed in the coiled tubing while pumping the slurry; analyzing the DAS data to evaluate changes in fracture planes in the subterranean formation due to interaction of the diverter material with the plurality of entry points; and wherein analyzing the DAS data comprises determining a velocity of fluid moving through the annulus based on the DAS data and determining a quantity and direction of fluid moving through the annulus based on the velocity.
Claim 2
Independent Claim
123 words
A method, comprising: positioning coiled tubing in a wellbore proximate a plurality of entry points formed between the wellbore and a subterranean formation; pumping a slurry comprising diverter material into an annulus of the wellbore surrounding the coiled tubing; collecting distributed acoustic sensing (DAS) data along a fiber optic cable disposed in the coiled tubing while pumping the slurry; analyzing the DAS data to evaluate changes in fracture planes in the subterranean formation due to interaction of the diverter material with the plurality of entry points; and wherein analyzing the DAS data comprises determining a velocity of fluid moving through the annulus based on the DAS data and determining a quantity and direction of fluid moving through the annulus based on the velocity.
Claim 3
Dependent Claim
24 words
The method of claim 1 , further comprising removing residual particulates from the wellbore proximate the plurality of entry points via the coiled tubing.
Claim 4
Dependent Claim
30 words
The method of claim 1 , further comprising raising the coiled tubing to a location above the plurality of entry points prior to pumping a treatment fluid into the wellbore.
Claim 5
Dependent Claim
43 words
The method of claim 3 , further comprising lowering the coiled tubing from the location above the plurality of entry points to a position proximate the plurality of entry points to collect DAS data multiple times during breaks in pumping the treatment fluid.
Claim 6
Dependent Claim
27 words
The method of claim 3 , further comprising pumping the treatment fluid into the wellbore when the coiled tubing is disposed at least partially in the wellbore.
Claim 7
Dependent Claim
28 words
The method of claim 3 , further comprising pumping the treatment fluid into the wellbore when the coiled tubing is entirely removed to a surface of the wellbore.
Claim 8
Dependent Claim
38 words
The method of claim 1 , further comprising shutting in the wellbore and performing a baseline DAS data survey of the wellbore proximate the plurality of entry points via the fiber optic cable prior to pumping the slurry.
Claim 9
Dependent Claim
37 words
The method of claim 1 , further comprising blocking one or more entry points of the plurality of entry points via the diverter material in the slurry, and redirecting fluids from the wellbore into different entry points.
Claim 10
Dependent Claim
26 words
The method of claim 1 , further comprising collecting the DAS data along a length of the wellbore spanning all of the plurality of entry points.
Claim 11
Dependent Claim
28 words
The method of claim 1 , further comprising pumping a tracer fluid with the slurry and collecting the DAS data to detect a flow of the tracer fluid.
Claim 12
Dependent Claim
23 words
The method of claim 1 , further comprising displaying an injectivity profile indicative of the changes in fracture planes in the subterranean formation.
Claim 13
Dependent Claim
28 words
The method of claim 1 , further comprising adjusting an amount of diverter material in the slurry based on the changes in fracture planes in the subterranean formation.
Claim 14
Independent Claim
180 words
A system, comprising: a coiled tubing member comprising a distributed acoustic sensing (DAS) fiber optic cable for collecting DAS data along a length of the coiled tubing member; a processing component communicatively coupled to the DAS fiber optic cable; and a memory component containing a set of instructions that, when executed by the processing component, cause the processing component to: receive DAS data collected by the DAS fiber optic cable when the coiled tubing member is disposed in a wellbore and a slurry containing diverter material is being pumped through the wellbore and into a subterranean formation via entry points; analyze the DAS data to evaluate changes in fracture planes in the subterranean formation due to interaction of the diverter material with the plurality of entry points; and determine a change in fracture planes in the subterranean formation based on the collected DAS data, wherein analyzing the DAS data comprises determining a velocity of fluid moving through the annulus based on the DAS data and determining a quantity and direction of fluid moving through the annulus based on the velocity.
Claim 15
Independent Claim
180 words
A system, comprising: a coiled tubing member comprising a distributed acoustic sensing (DAS) fiber optic cable for collecting DAS data along a length of the coiled tubing member; a processing component communicatively coupled to the DAS fiber optic cable; and a memory component containing a set of instructions that, when executed by the processing component, cause the processing component to: receive DAS data collected by the DAS fiber optic cable when the coiled tubing member is disposed in a wellbore and a slurry containing diverter material is being pumped through the wellbore and into a subterranean formation via entry points; analyze the DAS data to evaluate changes in fracture planes in the subterranean formation due to interaction of the diverter material with the plurality of entry points; and determine a change in fracture planes in the subterranean formation based on the collected DAS data, wherein analyzing the DAS data comprises determining a velocity of fluid moving through the annulus based on the DAS data and determining a quantity and direction of fluid moving through the annulus based on the velocity.
Claim 16
Dependent Claim
27 words
The system of claim 13 , further comprising a slurry pump coupled to the wellbore to pump the slurry through the wellbore and into the subterranean formation.
Claim 17
Dependent Claim
19 words
The system of claim 13 , wherein a section of the wellbore having the entry points is horizontally oriented.
Claim 18
Dependent Claim
45 words
The system of claim 13 , wherein the coiled tubing member further comprises a distributed temperature sensing (DTS) fiber optic cable for collecting DTS data along the length of the coiled tubing member, wherein the DTS fiber optic cable is coupled to the processing component.
Claim 19
Dependent Claim
27 words
The system of claim 13 , further comprising a display coupled to the processing component to display an injectivity profile indicative of the change in fracture planes.
Claim 20
Independent Claim
150 words
A method, comprising: positioning coiled tubing in a wellbore proximate a plurality of entry points formed between the wellbore and a subterranean formation; pumping a slurry comprising diverter material into an annulus of the wellbore surrounding the coiled tubing; collecting distributed acoustic sensing (DAS) data along a first fiber optic cable disposed in the coiled tubing while pumping the slurry; analyzing the DAS data to evaluate changes in fracture planes in the subterranean formation due to interaction of the diverter material with the plurality of entry points; collecting distributed temperature sensing (DTS) data along a second fiber optic cable disposed in the coiled tubing while pumping the slurry; analyzing the DTS data with the DAS data to evaluate changes in fracture planes in the subterranean formation; and pumping a thermal tracer into the wellbore with the slurry and collecting the DTS data to detect a flow of the thermal tracer.
Claim 21
Independent Claim
150 words
A method, comprising: positioning coiled tubing in a wellbore proximate a plurality of entry points formed between the wellbore and a subterranean formation; pumping a slurry comprising diverter material into an annulus of the wellbore surrounding the coiled tubing; collecting distributed acoustic sensing (DAS) data along a first fiber optic cable disposed in the coiled tubing while pumping the slurry; analyzing the DAS data to evaluate changes in fracture planes in the subterranean formation due to interaction of the diverter material with the plurality of entry points; collecting distributed temperature sensing (DTS) data along a second fiber optic cable disposed in the coiled tubing while pumping the slurry; analyzing the DTS data with the DAS data to evaluate changes in fracture planes in the subterranean formation; and pumping a thermal tracer into the wellbore with the slurry and collecting the DTS data to detect a flow of the thermal tracer.
Claim 22
Dependent Claim
70 words
The method of claim 18 , further comprising one or more of: raising the coiled tubing to a location above the plurality of entry points prior to pumping a treatment fluid into the wellbore; and lowering the coiled tubing from a location above the plurality of entry points to a position proximate the plurality of entry points to collect DAS data multiple times during breaks in pumping the treatment fluid.
Claim 23
Dependent Claim
146 words
The method of claim 19 , further comprising one or more of: shutting in the wellbore and performing a baseline DAS data survey of the wellbore proximate the plurality of entry points via the first fiber optic cable prior to pumping the slurry; blocking one or more entry points of the plurality of entry points via the diverter material in the slurry, and redirecting fluids from the wellbore into different entry points; collecting the DAS data along a length of the wellbore spanning all of the plurality of entry points; pumping a tracer fluid with the slurry and collecting the DAS data to detect a flow of the tracer fluid; displaying an injectivity profile indicative of the changes in fracture planes in the subterranean formation; and adjusting an amount of diverter material in the slurry based on the changes in fracture planes in the subterranean formation.
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USPTO Annuity & Maintenance Windows
| Annuity Stage | Window Opens | Payment Deadline | Surcharge Period Until | Estimated Fee | Status |
|---|---|---|---|---|---|
| 3.5 Years (Year 4) | 2023-09-15 | 2024-03-16 | 2024-09-15 | $2000.00 | Window Closed / Lapsed |
| 7.5 Years (Year 8) | 2027-09-15 | 2028-03-16 | 2028-09-15 | $3760.00 | Pending Window |
| 11.5 Years (Year 12) | 2031-09-15 | 2032-03-16 | 2032-09-15 | $7700.00 | Pending Window |