US2024352849A1PendingUtilityA1
A Remote Monitoring and Control System and Method for Improving Hydrocarbon Production Efficiency
Assignee: MOTOMECANICA ARGENTINA S APriority: Apr 24, 2023Filed: Apr 23, 2024Published: Oct 24, 2024
Est. expiryApr 24, 2043(~16.7 yrs left)· nominal 20-yr term from priority
E21B 43/12E21B 47/008E21B 47/138
44
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0
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Claims
Abstract
The present invention relates to a remote control and monitoring system to improve the production efficiency of a hydrocarbon well, including a choke located between a wellhead production tree and the production line of hydrocarbons, an actuator operating the choke, the actuator being in communication with a remote control and monitoring unit, a power supply source supplying power to the control and monitoring unit, and a plurality of data acquisition means including transducers arranged upstream and downstream of the choke, where the data acquisition means sends information related to the wellhead pressure, the production line pressure, and optionally, the wellhead temperature to the control and monitoring unit, where the control and monitoring unit is configured to carry out well shut-in cycles and well opening cycles determined based on compliance with a plurality of well shut-in and opening criteria by which a measured or calculated value of a parameter is compared to a preset value for the parameter, where the measured or calculated parameters are selected from wellhead pressure, production line pressure, wellhead pressure to production line pressure ratio, shut-in or opening time of the well, flow rate and critical flow rate. A method for improving the production efficiency of a hydrocarbon well employing the same is also provided.
Claims
exact text as granted — not AI-modified1 . A remote control and monitoring system to improve the production efficiency of a hydrocarbon well, the system characterized in that it comprises:
a choke ( 1 ) located between a wellhead production tree ( 6 ) and the production line ( 7 ) of hydrocarbons, an actuator ( 1 . 8 ) operating said choke ( 1 ), said actuator ( 1 . 8 ) being in communication with a remote control and monitoring unit ( 3 ), a power supply source ( 4 ) supplying power to said control and monitoring unit ( 3 ), and a plurality of data acquisition means including transducers ( 16 , 17 , 18 ) arranged upstream and downstream of said choke ( 1 ), where said data acquisition means sends information related to the wellhead pressure (WHP), production line pressure (LP), and optionally, wellhead temperature (T) to the control and monitoring unit ( 3 ), where said control and monitoring unit ( 3 ) is configured to carry out well shut-in cycles and well opening cycles determined based on compliance with a plurality of well opening and shut-in criteria by which a measured or calculated value of a parameter is compared to a preset value for said parameter, where said measured or calculated parameters are selected from wellhead pressure (WHP), production line pressure (LP), wellhead pressure to production line pressure ratio (WHP)/LP), shut-in or opening time of the well, flow rate and critical flow rate.
2 . A remote control and monitoring system for improving the production efficiency of a hydrocarbon well according to claim 1 , characterized in that said hydrocarbon well is a natural gas well.
3 . A remote control and monitoring system for improving the production efficiency of a hydrocarbon well according to claim 1 , characterized in that said choke ( 1 ) is connected, on the one hand, to the production side valve ( 11 ) of a wellhead tree ( 6 ) and on the other hand, to the production line ( 7 ).
4 . A remote control and monitoring system for improving the production efficiency of a hydrocarbon well according to claim 1 , characterized in that a safety valve ( 12 , 19 ) is arranged between the production side valve ( 11 ) of a wellhead tree ( 6 ) and choke ( 1 ).
5 . A remote control and monitoring system for improving the production efficiency of a hydrocarbon well according to claim 1 , characterized in that at the upper end of the wellhead production tree ( 6 ), a pressure regulating valve ( 14 ) operated by a gas instrument ( 15 ) is arranged to feed gas to the pneumatic circuit of the actuator ( 1 . 8 ).
6 . A remote control and monitoring system for improving production efficiency of a hydrocarbon well according to claim 1 , characterized in that said plurality of data acquisition means includes transducers ( 16 , 17 , 18 ) configured to measure pressure upstream and downstream of choke ( 1 ).
7 . A remote control and monitoring system for improving production efficiency of a hydrocarbon well according to claim 6 , characterized in that said plurality of data acquisition means includes transducers ( 16 , 17 , 18 ), wherein the transducers ( 16 ) are configured to measure pressure upstream and downstream of choke ( 1 ) and are disposed on respective block and bleed valves, or the transducers ( 17 ) are disposed on a lateral branch of the wellhead production tree ( 6 ) and the transducers ( 18 ) are disposed on the production line ( 7 ).
8 . A remote control and monitoring system for improving the production efficiency of a hydrocarbon well according to claim 1 , characterized in that said actuator ( 1 . 8 ) comprises a hollow actuator body ( 1 . 9 ) configured to house a compression spring ( 1 . 11 ) and allow the displacement in axial direction of an actuating stem ( 1 . 10 ) having an actuating end and an opposite end connected to a seal ( 1 . 12 ), where, in response to a closing signal of choke ( 1 ), said actuating stem ( 1 . 10 ) moves against the spring ( 1 . 11 ) compressing it, while in response to an opening signal of choke ( 1 ), said actuating stem ( 1 . 10 ) moves in the opposite direction decompressing said spring ( 1 . 11 ).
9 . A remote control and monitoring system for improving the production efficiency of a hydrocarbon well according to claim 1 , characterized in that said choke ( 1 ) comprises a main hollow body ( 1 . 1 ) having integrated connection means ( 1 . 2 , 1 . 2 ′), said main hollow body defining a through conduit ( 1 . 3 ) housing a calibrated orifice ( 1 . 4 ) configured to house a hollow insert ( 1 . 5 ).
10 . A remote control and monitoring system for improving the production efficiency of a hydrocarbon well according to claim 9 , characterized in that said calibrated orifice ( 1 . 4 ) has an elongated hollow body ( 1 . 4 a ) defining a through inner conduit ( 1 . 4 b ) inside which said hollow insert ( 1 . 5 ) is housed, said through inner conduit ( 1 . 4 b ) extends along the entire length of the calibrated orifice ( 1 . 4 ), and at one of its ends, it widens defining a support surface ( 1 . 4 c ).
11 . A remote control and monitoring system for improving the production efficiency of a hydrocarbon well according to claim 9 , characterized in that the calibrated orifice ( 1 . 4 ) has a perimeter flange ( 1 . 4 d ) extending radially and on which a gasket ( 1 . 4 e ) is seated to seal the calibrated orifice ( 1 . 4 ) within the through conduit ( 1 . 3 ) of choke ( 1 ).
12 . A remote control and monitoring system for improving the production efficiency of a hydrocarbon well according to claim 9 , characterized in that said insert ( 1 . 5 ) has a through conduit extending longitudinally.
13 . A remote control and monitoring system for improving the production efficiency of a hydrocarbon well according to claim 9 , characterized in that said insert ( 1 . 5 ) is made of a ceramic or tungsten carbide material or other material that withstands the operating conditions of high pressures, flow rates and corrosive fluids.
14 . A remote control and monitoring system for improving the production efficiency of a hydrocarbon well according to claim 9 , characterized in that the calibrated orifice ( 1 . 4 ) is inserted into the seat ( 1 . 13 ) of the stem ( 1 . 10 ) of said choke ( 1 ).
15 . A remote control and monitoring system for improving the production efficiency of a hydrocarbon well according to claim 1 , characterized in that said actuator ( 1 . 8 ) is a pneumatic actuator.
16 . A method for improving the production efficiency of a hydrocarbon well employing the remote monitoring and control system according to claim 1 , characterized in that said method comprises the steps of:
i) acquiring data corresponding to wellhead pressure and production line pressure using data acquisition means comprising pressure transducers ( 16 , 17 , 18 ); ii) sending the acquired data to the control and monitoring unit ( 3 ) iii) determining from the acquired data, the operating mode of the hydrocarbon well, where the operating mode may correspond to an opening cycle or a shut-in cycle of the well, iv) if the well is in a shut-in cycle, the control and monitoring unit ( 3 ) shall actuate the choke open the well when:
a) the elapsed time of well shut-in is longer than or equal to a preset time for well opening, or
b) the measured wellhead pressure is equal to or greater than a preset wellhead pressure for well opening, or
c) the ratio of wellhead pressure to production line pressure (WHP/LP) is greater than or equal to a predetermined ratio (WHP/LP) for the well opening,
v) if the well is in an opening cycle, the control and monitoring unit ( 3 ) shall actuate the choke ( 1 ) to shut in the well when:
d) the elapsed well opening time is greater than or equal to a value of the preset time for well shut-in; or
e) the measured wellhead pressure (WHP) is equal to or greater than the value of the preset wellhead pressure for well shut-in; or
f) the ratio of the measured wellhead pressure to the measured production line pressure (measured WHP/measured LP) is greater than or equal to a preset value of that ratio (WHP/LP) for the well shut-in; or
j) the calculated gas flow rate is greater than or equal a preset value of the preset gas flow rate for well shut-in; or
k) the calculated gas flow rate is greater than or equal to a value of the preset critical gas flow rate for well shut-in.
17 . A method for improving the production efficiency of a hydrocarbon well according to claim 16 , characterized in that the critical flow rate is determined by the Turner's Equation:
Qcritical
(
MMscf
/
D
)
=
.0676
Pd
?
2
(
T
+
460
)
Z
(
45
-
.0031
P
)
1
/
4
(
.0031
P
)
1
/
2
Equation
1
?
indicates text missing or illegible when filed
Wherein
MMscf/D=million standard cubic feet per day
P=wellhead pressure flow (psi)
T=temperature (° F.)
d ti =tubing inside diameter (inches)
Z=compressibility factor
and where the following values are adopted:
Type of liquid: water (worst condition)
Surface tension=60 dyne/cm
Density=67 lbm/(ft 3 )
Z=0.9
T=84.2° F.
18 . A method for improving the production efficiency of a hydrocarbon well according to claim 16 , characterized in that the gas flow rate is calculated considering the following gas flow conditions:
i—single-phase gas flow, wherein no critical or subcritical conditions exist, ii—single-phase gas flow wherein critical or subcritical conditions exist iii—multiphase gas flow wherein critical or subcritical conditions exist.
19 . A method for improving the production efficiency of a hydrocarbon well according to claim 18 , characterized in that when the gas flow is single phase where no critical or subcritical conditions exist, the gas flow rate is calculated according to the following Equation 1:
Qg
(
m
3
/
d
)
=
0.68
*
1
V
(
Grav
.
of
gas
as
regards
air
)
*
520
460
+
?
+
9
5
T
(
°
C
.
)
*
F
?
*
h
W
(
inches
of
water
)
*
(
Pf
(
psi
)
+
14.7
)
?
indicates text missing or illegible when filed
Wherein
Q g : is the gas flow rate in m 3 /day
γ: is the specific gravity of the gas with respect to air.
T: wellhead gas temperature in ° C.
h w : is the differential pressure at the orifice (in inches of water).
Pf: is the line pressure, downstream of the choke,
F b : correction factor depending on the casing dimensions and orifice diameter, or
the gas flow rate is calculated with Equation 2 adjusted on the basis of an instant well control (“history matching”):
Qg
(
m
3
/
d
)
=
Fk
*
h
W
(
inches
of
water
)
*
(
Pf
(
psi
)
+
14.7
)
.
Equation
2
20 . A method for improving the production efficiency of a hydrocarbon well according to claim 18 , characterized in that the gas flow rate in the choke is calculated with Equation 3 when the gas flow is single phase under subcritical conditions:
q
s
c
=
1.248
C
D
A
2
P
u
p
*
k
(
k
-
1
)
γ
g
T
u
p
[
(
P
dn
P
u
p
)
2
k
-
(
P
dn
P
u
p
)
k
+
1
k
]
Equation
3
Wherein
k is the specific heat ratio of the gas at constant pressure and constant volume Cp/Cv
T up is the temperature upstream of the choke
P dn is the pressure downstream of the choke
P up is the pressure upstream of the choke
while the gas flow rate in the choke is calculated with the modified Equation 3 when the gas flow is single phase and critical conditions are present:
Q
s
c
=
8
7
9
C
D
A
P
u
p
*
k
γ
g
T
u
p
(
2
k
+
1
)
k
+
1
k
-
1
Wherein
Q sc : is the gas flow (Mscl/day)
P up : is the pressure upstream of choke (psia)
P dn : is the pressure downstream of the choke (psia)
A 2 : is the choke cross section, in in 2
T up : is the temperature upstream of the choke (° R)
g: is the acceleration of gravity (32.2 ft/sec 2 )
γ g : is the specific gravity of the gas relative to air
k: is the heat capacity ratio Cp/Cv
C D : is the flow coefficient in the choke
where C D depends on the diameter of the tubing upstream of the choke, the diameter of the choke and the Reynolds number.
21 . A method for improving the production efficiency of a hydrocarbon well according to claim 18 , characterized in that the gas flow rate in the choke, when the gas flow is multiphase, is determined by the mixture mass flow equation and the mixture density, wherein the downstream mixture mass flow M2 (lbm/sec) is calculated according to the following formula:
M2:G2.A G2=downstream mass flow rate (lbm/ft 2 /sec) A=area of choke orifice (ft 2 ) Wherein G 2 is the downstream mass flow rate (lbm/ft 2 /sec)
G
2
=
c
d
(
288
g
c
p
1
ρ
m
2
2
(
(
1
-
x
1
)
(
1
-
y
)
ρ
L
+
x
1
k
k
-
1
(
V
G
1
-
yV
G
2
)
)
)
0.5
c d : is the choke discharge index
y: is the downstream pressure/upstream pressure ratio
k: is the ratio of specific heat points (Cp/Cv)
x l : the mass fraction of upstream free gas can be estimated or calculated by a well control
ρ m2 : is the downstream multiphase mixture density (lbm/ft 3 )
ρ L : is the liquid density (lbm/ft 3 )
V G1 : is the specific upstream gas volume (ft 3 /lbm)
V G2 : is the specific downstream gas volume (ft 3 /lbm)
Wherein
if y a <y c , there are critical flow conditions, therefore, y=y c , and
wherein, if ya>yc, there are subcritical flow conditions, therefore y=y a =p 1 /p 2 ,
wherein “y c ” is the ratio of critical pressures according to the Sachteva and Perkins model, and “y a ” is the ratio of the actual pressures upstream and downstream of the choke.
22 . A method for improving the production efficiency of a hydrocarbon well according to claim 18 , characterized in that the preset values for the parameters of time, wellhead pressure (WHP), line pressure (LP), wellhead pressure to production line pressure ratio (WHP/PL) and gas flow rate are established based on a periodic analysis of the actual behavior of the well to which the remote monitoring and control system is applied.
23 . A method for improving the production efficiency of a hydrocarbon well according to claim 18 , characterized in that the remote control and monitoring system is configured to automatically collect well production data, generate well profiles based on the data, and self-adjust to maintain a well production rate at a desirable level.Join the waitlist — get patent alerts
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