US2024229641A1PendingUtilityA1
Annulus pressure prediction and control system for hydrocarbon wells
Est. expiryJan 11, 2043(~16.5 yrs left)· nominal 20-yr term from priority
E21B 47/117E21B 44/00E21B 47/06E21B 2200/20
31
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Claims
Abstract
A method and system for predicting a well pressure for a hydrocarbon well are configured to perform actions including receiving well attributes data describing a physical configuration of a well; generating, based on values of the well attributes data, a relationship for predicting an annulus pressure by equating a change in volume of fluid in the well to a change in volume of a tubing casing annulus; updating the relationship based on fluid properties of the fluid; and predicting a TCA pressure for the well based on the updated relationship.
Claims
exact text as granted — not AI-modifiedWhat is claimed is:
1 . A method for predicting a well pressure for a hydrocarbon well for controlling operation of the hydrocarbon well, the method comprising:
receiving well attributes data describing a physical configuration of a well; generating, based on values of the well attributes data, a relationship for predicting an annulus pressure by equating a change in volume of fluid in the well to a change in volume of a tubing casing annulus; updating the relationship based on fluid properties of the fluid; and predicting a TCA pressure for the well based on the updated relationship.
2 . The method of claim 1 , wherein the well attributes data comprising a casing material type, a fluid type and quantity, temperature, and diameter.
3 . The method of claim 1 , wherein the fluid properties comprise at least one of a compressibility and a volumetric coefficient for the fluid.
4 . The method of claim 1 , wherein the relationship is defined as:
P
=
(
∝
f
-
∝
V
)
Δ
T
(
β
+
D
t
*
E
)
where: ∝ f is a volumetric coefficient of thermal expansion of the fluid, ∝ V is a volumetric coefficient of thermal expansion of the annulus, ΔT is a change in temperature; β is a compressibility factor of the fluid, −ΔP is a change in pressure of the fluid, D is a diameter of the annulus, t is a thickness of the annulus, and E is an elastic modulus of the annulus.
5 . The method of claim 1 , further comprising:
based on the prediction of the TCA pressure for the well, causing one or more remedial actions for the well.
6 . The method of claim 5 , wherein the remedial action comprises at least one of a as TCA refill, a TCA lubrication, and a pressure bleed-off for the well.
7 . The method of claim 1 , further comprising:
controlling a pressure in the well, based on the predicting, wherein controlling comprises causing one or more of a pressure bleed off event and generation of a notification instructing an operator to inspect the well for leakage or blockage, the notification being transmitted to the operator.
8 . A system configured for monitoring pressure in hydrocarbon wells for controlling operation of the hydrocarbon well, the system comprising:
at least one processor; and a memory storing instructions that, when executed by the at least one processor, cause the at least one processor to perform operations comprising:
receiving well attributes data describing a physical configuration of a well;
generating, based on values of the well attributes data, a relationship for predicting an annulus pressure by equating a change in volume of fluid in the well to a change in volume of a tubing casing annulus;
updating the relationship based on fluid properties of the fluid; and
predicting a TCA pressure for the well based on the updated relationship.
9 . The system of claim 8 , wherein the well attributes data comprising a casing material type, a fluid type and quantity, temperature, and diameter.
10 . The system of claim 8 , wherein the fluid properties comprise at least one of a compressibility and a volumetric coefficient for the fluid.
11 . The system of claim 8 , wherein the relationship is defined as:
P
=
(
∝
f
-
∝
V
)
Δ
T
(
β
+
D
t
*
E
)
where: ∝ f is a volumetric coefficient of thermal expansion of the fluid, ∝ V is a volumetric coefficient of thermal expansion of the annulus, ΔT is a change in temperature; β is a compressibility factor of the fluid, −ΔP is a change in pressure of the fluid, D is a diameter of the annulus, t is a thickness of the annulus, and E is an elastic modulus of the annulus.
12 . The system of claim 8 , the operations further comprising:
based on the prediction of the TCA pressure for the well, causing one or more remedial actions for the well.
13 . The system of claim 12 , wherein the remedial action comprises at least one of a as TCA refill, a TCA lubrication, and a pressure bleed-off for the well.
14 . The system of claim 8 , the operations further comprising:
controlling a pressure in the well, based on the predicting, wherein controlling comprises causing one or more of a pressure bleed off event and generation of a notification instructing an operator to inspect the well for leakage or blockage, the notification being transmitted to the operator.
15 . One or more non-transitory computer readable media storing instructions for monitoring pressure in hydrocarbon wells for controlling operation of the hydrocarbon well, the instructions when executed by at least one processor, configured to cause the at least one processor to perform operations comprising:
receiving well attributes data describing a physical configuration of a well; generating, based on values of the well attributes data, a relationship for predicting an annulus pressure by equating a change in volume of fluid in the well to a change in volume of a tubing casing annulus; updating the relationship based on fluid properties of the fluid; and predicting a TCA pressure for the well based on the updated relationship.
16 . The one or more non-transitory computer readable media of claim 15 , wherein the well attributes data comprising a casing material type, a fluid type and quantity, temperature, and diameter.
17 . The one or more non-transitory computer readable media of claim 15 , wherein the fluid properties comprise at least one of a compressibility and a volumetric coefficient for the fluid.
18 . The one or more non-transitory computer readable media of claim 15 , wherein the relationship is defined as:
P
=
(
∝
f
-
∝
V
)
Δ
T
(
β
+
D
t
*
E
)
where: ∝ f is a volumetric coefficient of thermal expansion of the fluid, ∝ V is a volumetric coefficient of thermal expansion of the annulus, ΔT is a change in temperature; β is a compressibility factor of the fluid, −ΔP is a change in pressure of the fluid, D is a diameter of the annulus, t is a thickness of the annulus, and E is an elastic modulus of the annulus.
19 . The one or more non-transitory computer readable media of claim 15 , the operations further comprising:
based on the prediction of the TCA pressure for the well, causing one or more remedial actions for the well.
20 . The one or more non-transitory computer readable media of claim 19 , wherein the remedial action comprises at least one of a as TCA refill, a TCA lubrication, and a pressure bleed-off for the well.Join the waitlist — get patent alerts
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