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Abstract

A partition method mathematical model was established for the shutdown process of an overhead pipe, and the effects of crude oil’s variable physical properties on the heat transfer performance were analyzed. The model and solving method were verified by the existing experimental data. The oil temperature distribution in pipe was simulated by FLUENT software, and the allowance shutdown time, which is the time of the oil temperature in the pipe center that it takes to drop to its freezing point, was discussed. In simulation, oil properties including densities, thermal conductivities, viscosities, and specific heat were modeled with their values as functions of temperature or set to their average values in the temperature range. Results show that compared with the latter (oil properties were average value), the allowance shutdown time using variable physical properties were shortened by 16.3%, 7.9%, 0.2%, and increased 61%, respectively; the influence of thermal conductivity was embodied in the second half of the shutdown process. In numerical simulation of the shutdown process for an oil pipeline, the effect of oil viscosity variation can be ignored and, the other properties must not be regarded as constant, especially heat capacity, whose change reflects the influence of latent heat.

Keywords

Influence factor temperature field heat and mass transfer crude oil property shutdown process

Introduction

If a hot oil pipe is shutdown, heat will escape from the pipe to the environment due to the temperature difference between the interior and exterior of the pipe. When the oil temperature drops to the wax-appearance point, paraffin wax will separate out and the oil will coagulate, making the oil pipe hard to restart. Numerical simulation results of pipeline oil temperature distribution have an important guiding role in determining safe shutdown time, establishing restart schemes, and determining maintenance plans.

Because the components of oil are complex, its phase transformation process is different from that of water. Additionally, the physical properties of crude oil are variable. For numerical simulation of oil temperature drops, there are two main problems to resolve: modeling convective heat transfer and wax-appearance precipitation. Natural convection is caused by changes in oil density and affected by oil viscosity. The release of latent heat through crude oil wax precipitation results in specific heat variation. Therefore, oil physical properties play a major role in modeling its temperature drops and phase changes.

However, in previous research, many numerical studies have been dedicated to convection and wax-appearance latent heat.^1–21 Patience and Mehrotra¹ have taken oil properties as constant. Nagano et al.² has studied flow fields by inducing flow function and vorticity, but in the models, oil physical properties were constant except for oil viscosity. Zhang³ and Liu and Zhang⁴ have taken the oil specific heat as constant and added the wax-appearance latent heat at the freezing point. However, the actual wax precipitation process happens over a range of temperatures. Lu et al.^5,6 established an enthalpy method model with constant oil specific heat, the wax-appearance latent heat being given off in the temperature range of 1.5°C above and below the freezing point. Obviously, these approaches are not consistent with the actual situation of wax precipitation. Xu et al.⁷ and Du et al.⁸ proposed a model that converted latent heat into enthalpy, but in simulation, the specific variable was adopted again, which was contradictory because of the latent heat of repeated calculation. Zhu et al.⁹ have considered the relationship between the physical properties of crude oil with temperature; however, they did not present flow patterns and phase change interface shapes. Other researches^10–16 ignored the convective process caused by density change, modeling the heat transfer as pure conductivity. Zu¹⁷ took latent heat as equivalent to specific heat to calculate the temperature drop during shutdown.

Until now, there has not been a report on the influence of variable oil physical properties on temperature distribution. In this article, a partition method mathematical model was established for the crude oil temperature drop in an overhead pipe following shutdown and verified using existing experimental data.²² The influence of different properties of parameters (e.g. density, viscosity, k-factor, and specific heat) on the temperature field was analyzed, and solidification interfaces at different shutdown times were obtained. The oil properties were modeled with their values as functions of temperature or set to their average values in the temperature range. The resulting temperature changes at the center of the pipe, with the resulting differences in shutdown time, were compared. The shutdown time allowance, which is the time taken by the oil temperature in the pipe center to drop to its freezing point, was discussed.

Models

Physical model

In order to simplify the calculation, some assumptions were set as follows:

Thermal resistance of oxidizing coating and protecting coating is negligible;

Each layer has a close connection, without additional thermal resistance;

Each material layer is uniform, and the physical properties of the pipe and thermal insulation material are constant;

At the beginning of shutdown, the temperature of the oil in pipe is uniform;

The Boussinesq²³ approximation was adopted, neglecting viscous dissipation in the fluid.

The physical model of an overhead pipeline in shutdown is shown in Figure 1. The model can be divided into four parts: the crude oil liquid zone, the crude oil solid zone, pipe, and the insulating layer. R₀ is the diameter of the liquid crude oil zone, R₁ is the inner pipe diameter, R₂ is the external pipe diameter, and R₃ is the external diameter of the insulating layer which has direct contact with the atmosphere.

Figure 1.

Physical model of overhead pipeline.

When the overhead pipeline is shutdown, the oil heat transfer process takes place as follows: first, liquid oil transmits the heat to the condensate reservoir or pipe wall by natural convection. Then, the heat is transferred outward through the condensate reservoir, pipe, and insulating layer by conduction. Finally, the heat is transferred from the outermost layer to the atmosphere and the surrounding objects by convection and radiation.

Mathematical model

Partition allocation method mathematical models are established, and the oil in pipe was divided into a liquid zone and solid zone with an infinitely thin phase interface. Energy conservation equations are established in all zones as follows.

Liquid zone

Momentum equations

The momentum equations of liquid are as follows. For a Newtonian fluid

\begin{matrix} \frac{\partial (ρ u_{θ})}{\partial t} + \frac{1}{r} \frac{\partial}{\partial θ} (ρ u_{θ} u_{θ}) + \frac{1}{r} \frac{\partial}{\partial r} (ρ r u_{r} u_{θ}) \\ = \frac{1}{r} \frac{\partial}{\partial θ} (\frac{μ}{r} \frac{\partial u_{θ}}{\partial θ}) + \frac{1}{r} \frac{\partial}{\partial r} (μ r \frac{\partial u_{θ}}{\partial r}) + S_{θ} \end{matrix}

(1a)

\begin{matrix} \frac{\partial (ρ u_{r})}{\partial t} + \frac{1}{r} \frac{\partial}{\partial θ} (ρ u_{θ} u_{r}) + \frac{1}{r} \frac{\partial}{\partial r} (ρ r u_{r} u_{r}) \\ = \frac{1}{r} \frac{\partial}{\partial θ} (\frac{μ}{r} \frac{\partial u_{r}}{\partial θ}) + \frac{1}{r} \frac{\partial}{\partial r} (μ r \frac{\partial u_{r}}{\partial r}) + S_{r} \end{matrix}

(1b)

where

S_{θ} = - \frac{1}{r} \frac{\partial p}{\partial θ} + (- \frac{ρ u_{r} u_{θ}}{r} + \frac{2 μ}{r^{2}} \frac{\partial u_{r}}{\partial θ} - \frac{μ u_{θ}}{r^{2}}) - g ρ β (T - T_{air}) \sin θ

(1c)

S_{r} = - \frac{\partial p}{\partial r} + (\frac{ρ {u_{θ}}^{2}}{r} - \frac{2 μ}{r^{2}} \frac{\partial u_{θ}}{\partial θ} - \frac{μ u_{r}}{r^{2}}) + g ρ β (T - T_{air}) \cos θ

(1d)

For a non-Newtonian fluid

\begin{matrix} \frac{\partial (ρ u_{θ})}{\partial t} + \frac{1}{r} \frac{\partial}{\partial θ} (ρ u_{θ} u_{θ}) + \frac{1}{r} \frac{\partial}{\partial r} (ρ r u_{r} u_{θ}) \\ = - \frac{\partial p}{r \partial θ} + [\frac{1}{r^{2}} \frac{(r^{2} τ_{r θ})}{\partial r} + \frac{1}{r} \frac{\partial τ_{θ θ}}{\partial θ}] - g ρ β (T - T_{f}) \sin θ \end{matrix}

(2a)

\begin{matrix} \frac{\partial (ρ u_{r})}{\partial t} + u_{r} \frac{\partial (ρ u_{r})}{\partial r} + \frac{u_{θ}}{r} \frac{\partial (ρ u_{r})}{\partial θ} - \frac{ρ u_{θ}^{2}}{r} \\ = - \frac{\partial p}{\partial r} + [\frac{1}{r} \frac{(r τ_{rr})}{\partial r} + \frac{1}{r} \frac{\partial τ_{r θ}}{\partial θ} - \frac{τ_{θ θ}}{r}] \\ - g ρ β (T - T_{f}) \cos θ \end{matrix}

(2b)

where

τ_{θ θ} = 2 μ \frac{1}{r} (\frac{\partial v_{θ}}{\partial θ} + v_{r}) - \frac{2}{3} μ \nabla \cdot \vec{V} = \frac{2}{3} μ (2 \frac{\partial v_{θ}}{r \partial θ} - \frac{\partial r v_{r}}{r \partial r} - \frac{\partial u}{\partial x}) + μ \frac{2 v_{r}}{r}

(2c)

τ_{r θ} = τ_{θ r} = μ (\frac{\partial v_{θ}}{\partial r} + \frac{\partial v_{r}}{r \partial θ} - \frac{v_{θ}}{r}) = μ (\frac{\partial r v_{θ}}{r \partial r} + \frac{\partial v_{r}}{r \partial θ}) - 2 μ \frac{v_{θ}}{r}

(2d)

τ_{r r} = 2 μ \frac{\partial v_{r}}{\partial r} - μ \frac{2}{3} \nabla \cdot \vec{V} = \frac{2}{3} μ (2 \frac{\partial r v_{r}}{r \partial r} - \frac{\partial v_{θ}}{r \partial θ} - \frac{\partial u}{\partial x}) - 2 μ \frac{v_{r}}{r}

(2e)

Continuity equation

The continuity equation of liquid is as follows

\frac{\partial ρ}{\partial t} + \frac{1}{r} \frac{\partial (ρ r u_{r})}{\partial r} + \frac{1}{r} \frac{\partial (ρ u_{θ})}{\partial θ} = 0

(3)

Heat transfer equation

Heat transfer equation in liquid oil is shown as follows

\frac{\partial (ρ T)}{\partial t} + \frac{1}{r} \frac{\partial}{\partial θ} (ρ u_{θ} T) + \frac{1}{r} \frac{\partial}{\partial r} ({ρ u}_{r} T) = \frac{1}{r^{2}} \frac{\partial}{\partial θ} (\frac{λ}{c_{p}} \frac{\partial T}{\partial θ}) + \frac{1}{r} \frac{\partial}{\partial r} (\frac{λ}{c_{p}} r \frac{\partial T}{\partial r})

(4)

In the process of solidification, crude oil releases latent heat which can be demonstrated by $c_{p}$ variation.

Solid zone

Pure heat conduction equation for the solid phase of crude oil is shown as follows

\frac{\partial (ρ T)}{\partial t} = \frac{1}{r^{2}} \frac{\partial}{\partial θ} (\frac{λ}{c_{p}} \frac{\partial T}{\partial θ}) + \frac{1}{r} \frac{\partial}{\partial r} (\frac{λ}{c_{p}} r \frac{\partial T}{\partial r})

(5)

Other zones

The heat transfer equations for pipe wall and insulating layer are given by

ρ_{p} c_{1 p} \frac{\partial T_{1}}{\partial t} = \frac{1}{r} \frac{\partial}{\partial r} (λ_{1} r \frac{\partial T_{1}}{\partial t}) + \frac{1}{r^{2}} \frac{\partial}{\partial θ} (λ_{1} \frac{\partial T_{1}}{\partial θ})

(6)

ρ_{i} c_{i} \frac{\partial T_{2}}{\partial t} = \frac{1}{r} \frac{\partial}{\partial r} (λ_{2} r \frac{\partial T_{2}}{\partial t}) + \frac{1}{r^{2}} \frac{\partial}{\partial θ} (λ_{2} \frac{\partial T_{2}}{\partial θ})

(7)

where $u_{θ}$ and $u_{r}$ are the velocity components of u in polar coordinates (m/s); $v_{θ}$ and $v_{r}$ are the velocity components of v in polar coordinates (m/s); $ρ$ is the density of crude oil (kg/m³); $ρ_{p}$ is the material density of the pipe (kg/m³); $ρ_{i}$ is the material density of the insulating layer (kg/m³); $c_{p}$ is the specific heat capacity of crude oil ( $J / (kg \cdot \circ C)$ ); $c_{i}$ is the specific heat capacity of the insulating layer ( $J / (kg \cdot \circ C)$ ); $c_{1 p}$ is the specific heat capacity of the pipe ( $J / (kg \cdot \circ C)$ ); $λ$ is the thermal conductivity of crude oil ( $w / (m \cdot K)$ ); $λ_{1}$ is the thermal conductivity of the pipe ( $w / (m \cdot K)$ ); $λ_{2}$ is the thermal conductivity of the insulating layer ( $w / (m \cdot K)$ ); $μ$ is the oil dynamic viscosity of crude oil ( $Pa \cdot s$ ); g is the acceleration of gravity ( $m / s^{2}$ ); T is the temperature of crude oil (K); $T_{1}$ is the temperature of the pipe (K); $T_{2}$ is the temperature of the insulating layer (K); and $T_{f}$ is the temperature of air (K).

Boundary conditions

At the point of contact between liquid and pipe wall

{- λ_{1} \frac{\partial T_{1}}{\partial r} |}_{r = R_{0}^{+}} = α (T_{0} - T_{1})

(8)

At the point of contact between liquid and solid (at the interface radius is $R_{0}$ )

λ_{l} \frac{\partial T_{l}}{\partial r} | r = R_{0}^{-} = λ_{s} \frac{\partial T_{s}}{\partial r} |_{r = R_{0}^{+}}

(9)

T_{s} | r = R_{0}^{+} = T_{l} |_{| r = R_{0}^{-}}

(10)

At the point of contact between the solid and the pipe wall

λ_{s} \frac{\partial T_{s}}{\partial r} |_{r = R_{1}^{-}} = λ_{1} \frac{\partial T_{1}}{\partial r} |_{r = R_{1}^{+}}

(11)

T_{s} |_{r = R_{1}^{-}} = T_{1} |_{| r = R_{1}^{+}}

(12)

At the contact surfaces between the pipe wall and the insulating layer

λ_{1} \frac{\partial T_{1}}{\partial r} |_{r = R_{2}^{-}} = λ_{2} \frac{\partial T_{2}}{\partial r} |_{r = R_{2}^{+}}

(13)

At the contact surface between the air and the outmost layer of the pipe

λ_{2} \frac{\partial T_{2}}{\partial r} |_{r = R_{3}^{-}} = α_{air} (T_{2} - T_{f})

(14)

where $T_{l}$ and $T_{s}$ are the temperature of liquid oil and solid oil (K), respectively; and $α_{air}$ is the integrated convection heat transfer coefficient of air ( $W / (m \cdot K)$ ).

Initial conditions

T_{0} = const

(15)

where $T_{0}$ is the crude oil temperature in the pipe at the beginning of shutdown.

Model verification

Many methods for validating temperature fields between numerical simulation and experimental data have been developed. This article uses experimental data as reported in the literature²³ to verify the model. The atmospheric temperature as a function of time is as follows

T_{f} = 273.15 + 5 \cos (\frac{6.283 t}{3600 \times 24} + \frac{1}{6}) - 1

(16)

The experimental parameters are shown in Tables 1 –3. The initial oil temperature is 350 K.

Table 1.

Physical parameters of steel pipe.

Density	Specific heat	Conductivity	Dimension of steel pipe
kg/m³	J/(K·kg)	W/(m·K)	mm
7850	500	48	274 × 7

Table 2.

Physical parameters of insulating material.

Density	Specific heat	Thickness	Conductivity
kg/m³	J/(K·kg)	mm	W/(m·K)
60	700	40	0.04

Table 3.

Parameters of experiment crude oil.

Parameter	Unit	Value
Wax precipitation	K	315
Freezing point	K	305
Density $ρ$	kg/m³	$ρ = 0.902 - 8.177 \times 10^{- 4} (T - 273.15) + 1.54 \times 10^{- 6} {(T - 273.15)}^{2}$ (17)
Thermal conductivity $λ$	W/(m·K)	$λ = {\begin{matrix} 0.152 \exp [- 9.18 \times 10^{- 4} \times (T - 273.15)], T \geq T_{1} \\ 0.60576 - 0.01186 \times (T - 273.15), T_{1} > T \geq T_{2} \\ 0.25, T < T_{2} \end{matrix}$ (18) $T_{1} = 315.15 K$ , $T_{2} = 305.15 K$
Dynamic viscosity $μ$	Pa·s	For Newtonian fluid $μ = 10^{5.06039 - 0.01951 T}, T \geq T_{1}$ (19)
Dynamic viscosity $μ$	Pa·s	For non-Newtonian fluid $μ = {\begin{matrix} 10^{37.30785 - 0.12235 T}, T_{2} \leq T < T_{1} \\ 10^{- 14.44979 + 0.0511 T}, T_{3} \leq T < T_{2} \\ 10^{20.81207 - 0.06799 T}, T_{4} \leq T < T_{3} \end{matrix}$ (20) $T_{1} = 313.15 K$ , $T_{2} = 298.15 K$ , $T_{3} = 296.15 K$ , $T_{4} = 292.15 K$
Specific heat capacity c	J/(K·kg)	$c = {\begin{matrix} 809.717 + 3.607 T, T \geq T_{1} \\ - 76349.22 + 568.75 T - 1.01 T^{2}, T_{1} > T \geq T_{2} \\ - 11987.72 + 82.15 T - 0.10979 T^{2}, T < T_{2} \end{matrix}$ (21) $T_{1} = 325.15 K$ , $T_{2} = 305.15 K$

According to the specific conditions of the experimental pipeline, Gambit 2.4.6 software was used to establish a pipeline geometry model, generating 22,671 meshes using the ancient coin method. The outermost layer of the pipeline was set to the third kind of boundary conditions, the atmosphere temperature was given by formula (16), the heat transfer coefficient was 25 W/(m² K), and the surface emissivity was 0.9. There was a coupling boundary between the inner surface of the pipeline and the crude oil. The crude oil properties were used as shown in Table 3; the values with temperature variation were written using C Language programs and imported into the software. The SIMPLE algorithm and $k - ε$ model were adopted for simulation in FLUENT. Taking the pipeline center as monitoring point, temperature change curves were obtained. Finally, the results were compared to the experimental data to verify the model correctness.

Results and discussions

The simulation and experimental results are shown in Figure 2. It can be seen that there is good agreement with a maximum relative error of 3.14%. Thus, the model can be used to discuss the influence of oil properties (such as density, conductivity coefficient-k, viscosity, and specific heat) on heat and mass transfer processes and the temperature field; the liquid–solid interface position can be obtained by FLUENT software. Next, crude oil, with its variable properties and influence on shutdown time, is used as a simulation test case with an initial oil temperature of 333 K. Its physical properties are listed in Table 3.

Figure 2.

Comparison of simulation results and experimental results.

Influence of oil density on the oil temperature field

In different density conditions, the oil temperature drop curves at the pipe center are shown in Figure 3; the solidification cloud charts for different density crude oil are shown in Figure 4. The oil temperature distribution in pipe is symmetrical on Y axis, so take half of the pipe to compare.

Figure 3.

Temperature drop curve of pipe center oil for different density.

Figure 4.

Solidification cloud charts for different density crude oil.

As Figure 3 indicates, when the fluid density is held constant at an average value ( $ρ = \bar{ρ} = 900 kg / m^{3}$ ), it takes about 43 h for the oil temperature to drop from 333 to 305 K at the pipe center. When density is taken as a function of temperature, $ρ = f (T)$ , which is given by formula (17), the allowance shutdown time (the time needed for the oil temperature in the pipe center drop to 305 K) is about 36 h, which is 7 h or 16.3% shorter than that obtained with a constant density model.

In these figures, when the density is set to a constant average value, the oil temperature drop gradient in the pipe center is nearly steady: as there is no density difference, there is no natural convection, which means there is only heat conduction in the crude oil pipe. Therefore, as shown in Figure 4, the temperature field of liquid oil is symmetrical about the pipe center. When oil density is temperature-dependent, because of heat transfer from the oil to the environment, the oil temperature around the inner wall of the pipe is less than that in the pipe center. As hot oil goes up and cold oil goes down, the solidified layer first appears at the bottom pipe wall. When the influence of heat convection is taken into account, the oil in the pipe experiences a rapid dissipation of heat and the temperature falls faster, and the solidification time of the oil at the pipe center is shortened.

Influence of oil thermal conductivity on temperature field

Taking the experimental crude oil in Table 3, for example, it is a light oil and its thermal average and temperature-dependent thermal conductivity is $λ = \bar{λ}$ = 0.15 W/(m K) and $λ = f (T)$ which is given by formula (18), respectively.

For different thermal conductivities, the simulation results of temperature drop of the oil at the pipe center are presented in Figure 5. The crude oil solidification cloud charts of the pipe are shown in Figure 6.

Figure 5.

Temperature drop curve of pipe center for oil with different conductivity.

Figure 6.

Solidification cloud charts for crude oil in different conductivities: (a) 20 h after shutdown and (b) 30 h after shutdown.

From Figure 5, we know that before the oil temperature drops to about 312 K, the temperature drop curves overlap each other. In this stage, the influence of the thermal conductivity change with temperature is small. When the temperature drops below 312 K, the two temperature curves separate and the curve slope with $λ = f (T)$ is larger; the influence of different thermal conductivities is concentrated on the second half of the temperature drop. As most of the oil is liquid at the pipe center at the beginning of shutdown, heat transfer there is dominated by natural convection. Over the last half of the considered temperature drop, however, convection heat transfer is very minor and can be ignored; the heat transfer in the liquid phase can be modeled as pure conduction. The allowance shutdown time is about 38 h for $\bar{λ}$ and about 35 h for $λ = f (T)$ , which is a reduction of approximately 7.9%.

In Figure 6, for an overhead pipe, when the shutdown time is 20 h, the solidification cloud charts are basically the same; when the shutdown time is 30 h, the positions of the solidification interfaces are obviously different. This is due to natural convection when the oil is in a liquid state. As time goes on, the oil begins to gelatinize and the natural convection fades away, and the influence of the heat conduction plays an increasingly major role in heat transfer.

Influence of oil viscosity on the oil temperature field

Oil viscosity affects the flow state of liquid oil, which can be controlled to affect natural convection. For a shutdown pipe, the range of the oil temperature drop is 333 to 305 K and the average value of oil viscosity ( $\bar{μ}$ ) is 0.09 Pa·s. Different viscosity formulations ( $\bar{μ}$ and $μ = f (T)$ ) are used to generate the pipe center oil temperature drop curves as presented in Figure 7.

Figure 7.

Temperature drop curve of pipe center for oil with different viscosities.

In different conditions, the curves are almost same. The difference in oil solidification time at pipe center is negligible. Thus, for numerical simulation, the change of viscosity with temperature can be ignored.

For Daqing oil field, in different blocks, the oil viscosities ( $\bar{μ}$ ) are between 0.01 and 0.06 Pa·s at 50°C. When $\bar{μ}$ is 0.02, 0.04, and 0.06 Pa·s, respectively, temperature drop curves of pipe center are drawn in Figure 8. All the curves are almost same. Obviously, there is almost no effect of the change of oil viscosity on temperature field in pipe.

Figure 8.

Temperature drop curve of pipe center in different $\bar{μ}$ .

For oil from different blocks of the Daqing oil field in Heilongjiang Province, China, the oil viscosities ( $\bar{μ}$ ) are between 0.01 and 0.06 Pa·s at 323 K. When $\bar{μ}$ is 0.02, 0.04, and 0.06 Pa·s, respectively, pipe center temperature drop curves are shown in Figure 8. All the curves are almost same. Obviously, there is almost no effect of the change of oil viscosity on the temperature field in the pipe.

Influence of oil specific heat capacity on oil temperature field

With the drop of oil temperature, wax-appearance latent heat is released and the specific heat capacity increases significantly: its relationship c = f(T) is given by formula (21). When the wax-appearance latent heat is ignored, oil specific heat c can be set as a constant ( $c = \bar{c}$ ). For the two different specific heat capacity conditions, the pipe center oil temperature drop curves are shown in Figure 9.

Figure 9.

Oil temperature drop curves of pipe center in different specific heat capacity conditions.

As shown in Figure 9, when wax-appearance latent heat is ignored, the temperature drop gradient is larger. When wax-appearance latent heat is taken into account, the process of shutdown can be divided into three stages according to the rate of temperature drop at the pipe center. When the temperature decreased from 333 to 325 K, the temperature difference was large between the crude oil and the pipe inner wall, and convection was significant; the temperature gradient was large in this stage. However, with an increasing condensate reservoir thickness and decreasing temperature difference, the overall trend of temperature drop becomes slow. When the temperature is between 325 and 310 K, the temperature gradient becomes small due to the release of wax-appearance latent heat at 325 K and its delay of the crude oil temperature drop. Especially at about 315 K, the temperature gradient was small; this may be due to the fact that the wax in crude oil has about 20 carbon atoms. Also at this time, the latent heat release reached a peak, which can make the temperature drop to slow down. When the temperature of crude oil was less than 310 K, the latent heat release decreased significantly and the temperature gradient increased again. Compared with the constant value specific heat, the allowance shutdown time of variable specific heat was increased by about 22 h.

Conclusion

In this article, physical and mathematical heat transfer models of crude oil in shutdown overhead pipelines have been established. Temperature and flow fields, as well as the solidification cloud in the pipe, can be obtained. The effects of crude oil’s variable physical properties (density, viscosity, k-factor, and specific heat) on temperature distribution and shutdown time have been investigated. The main conclusions are as follows:

When the oil density is held constant at its mean value, $ρ = \bar{ρ}$ , liquid oil does not flow, so there is no convective heat transfer at the phase interface and the oil temperature field is symmetrical about the center point of pipe. Compared with variable density $ρ = f (T)$ , there is a disagreement of 16.3% for allowance shutdown time; the latter is closer to reality.

The results show that whether the thermal conductivity is held at the mean value $λ = \bar{λ}$ or modeled as a function of temperature $λ = f (T)$ , there is no obvious difference in the initial half of the shutdown process. This is due to convective heat transfer being dominant in this stage. For the second half of the process, the influence of thermal conductivity changing with temperature should be considered.

The effect of viscosity on the temperature distribution in the radial direction of the pipe is very small.

Because of the release of wax, the specific heat capacity of the crude oil has obvious variation. In this stage, the temperature drop changes slowly, and compared with that when specific heat capacity is held constant, the allowance shutdown time is longer.

Footnotes

Academic Editor: Oronzio Manca

Declaration of conflicting interests

The author(s) declared no potential conflicts of interest with respect to the research, authorship, and/or publication of this article.

Funding

The author(s) disclosed receipt of the following financial support for the research, authorship, and/or publication of this article: This work was supported by the National Natural Science Foundation of China (nos 51534004 and 51176024), special funds for scientific research of Hei-Longjiang Education Department within the program (grant no. 2016YSFX-02), and the Natural Science Foundation of Heilongjiang Province (no. ZD2015011).

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Effects of crude oil’s variable physical properties on temperature distribution in a shutdown pipeline

Abstract

Keywords

Introduction

Models

Physical model

Mathematical model

Liquid zone

Momentum equations

Continuity equation

Heat transfer equation

Solid zone

Other zones

Boundary conditions

Initial conditions

Model verification

Results and discussions

Influence of oil density on the oil temperature field

Influence of oil thermal conductivity on temperature field

Influence of oil viscosity on the oil temperature field

Influence of oil specific heat capacity on oil temperature field

Conclusion

Footnotes

Declaration of conflicting interests

Funding

References