Pump system with neural network to manage buckling of a rod string
A method can include operating a pump system; determining a condition associated with the pump system; and controlling the pump system based at least in part on the condition.
1. A method comprising: operating a pump system, the pump system comprising a rod; utilizing a wave propagation model to estimate a first present downhole condition of the pump system based on a present surface condition of the pump system, wherein the wave propagation model is implemented in the form
vx ( xi,t )= vx ( xi,ti− 1)+( dt/dm )* Ftot _ x ( xi,t− 1)/ fc;
vz ( xi,t )= vz ( xi,t− 1)+( dt/dm )* Ftot _ z ( xi,t− 1)/ fc
omega( xi,t )=omega( xi,t− 1)+( dt/dI )* Mtot _ y ( xi,t− 1)
vx: velocity in horizontal direction in global coordinate system
vz: velocity in vertical direction in global coordinate system
omega: angle velocity describing the bending in each defined segment
t: discretized time
xi: discretized position
dt: time increment
dm: mass per segment
dI: bending moment
Ftot_x: sum of internal and external forces in horizontal direction (spring force, bending force, solid friction)
Ftot_z: sum of internal and external forces in horizontal direction (spring force, bending force, solid friction, gravity)
Mtot_y: bending moment
wherein the solution returns a two-dimensional displacement of a rod of the pump system and time, the two-dimensional displacement comprising vertical and horizontal displacement; and or, wherein the wave propagation model is further implemented in the form
vy ( yi,t )= vy ( xi,ti− 1)+( dt/dm )* Ftot _ x ( yi,t− 1)/ fc;
omega_ x ( yi,t )=omega( yi,t− 1)+( dt/dI )* Mtot _ x ( yi,t− 1)
omega_phi( xi,t )=omega_phi(Phi_ i,t− 1)←( dt/dJ )* Mtorsiona _ z (Phi_ i,t− 1)
Fc: damping adjustment factor
Mtorsiona_z: torsion term
wherein the solution returns a three-dimensional displacement of a rod of the pump system, the three-dimensional displacement comprising vertical displacement, horizontal displacement, and helical buckling; utilizing a machine model to estimate a second present downhole condition of the pump system based on the present surface condition of the pump system; generating training data, wherein the training data is based on a comparison of the first present downhole condition and the second present downhole condition; training the machine model utilizing the training data to generate a trained machine model, wherein the trained machine model predicts a future downhole condition associated with the present surface condition of the pump system, wherein the future downhole condition relates to one or more of rod wear, rod guide wear, and tubing wear; and controlling the pump system based at least in part on the future downhole condition predicted by the trained machine model, such that one or more of rod wear, rod guide wear and tubing wear is reduced.
2. The method of claim 1 , wherein the wave propagation model includes two spatial dimensions.
3. The method of claim 1 , wherein the wave propagation model includes three spatial dimensions.
4. The method of claim 1 , wherein the wave propagation model comprises a first pump load model and the machine model comprises a second pump load model, wherein the first downhole condition comprises acceleration of the rod estimated by the first pump load model and the second downhole condition comprise acceleration of the rod estimated by the second pump load model.
5. The method of claim 4 , wherein the first downhole condition further comprises one or more gas characteristics estimated by the first pump load model and/or a stroke length of the rod estimated by the first pump load model, wherein the second downhole condition further comprises one or more gas characteristics estimated by the first pump load model and/or a stroke length of the rod estimated by the second pump load model.
6. The method of claim 1 , wherein the pump system is disposed at least in part in a deviated well.
7. The method of claim 6 , wherein the wave propagation model is based on an axial dimension and a radial dimension as a dimension normal to the axial dimension.
8. The method of claim 1 , wherein the present surface condition comprises a force measurement and a position of the rod.
9. The method of claim 1 , wherein the pump system comprises a sucker rod pump.
10. The method of claim 1 , wherein the first and second present downhole conditions each comprise a well angle defined with respect to a vertical direction.
11. The method of claim 1 , wherein the first and second present downhole conditions each comprise a fluid condition.
12. The method of claim 1 , wherein controlling the pump system based at least in part on the future downhole condition predicted by the trained machine model reduces the impact of noise.
13. The method of claim 1 , wherein the wave propagation model is implemented in the form
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2
u
(
s
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t
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∂
t
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=
v
2
∂
2
u
(
s
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∂
s
2
-
c
∂
u
(
s
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t
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∂
t
wherein the solution returns a one-dimensional vertical displacement of a rod of the pump system and time.