Mathematical modeling of heat losses for field natural gas gathering systems

About the authors:

Arambiy A. Paranuk, Cand. Sci. (Tech.), Associate Professor, Department of Gas and Oil Transportation Systems and Equipment of the Oil and Gas Industry, Institute of Oil, Gas and Power Engineering, Kuban State Technological University, Krasnodar, Russia; rambi.paranuk@gmail.com, https://orcid.org/0000-0003-2443-683X

Vladislav I. Dunaev, Dr. Sci. (Phys.-Math.), Professor, Department of Gas and Oil Transportation Systems and Equipment of the Oil and Gas Industry, Institute of Oil, Gas and Power Engineering, Kuban State Technological University, Krasnodar, Russia; dunayev1964@bk.ru, https://orcid.org/0000-0002-4166-6808

Abstract:

The paper presents a mathematical model that allows determining the temperature distribution in field natural gas collection systems for various technical purposes. Often, gas collection systems (collectors, plumes) have a length from 10 m to 500 m, and at large fields their length can reach from 5 km to 10 km. Therefore, there is a problem of determining and monitoring the temperature of the gas collection plume up to the installation of complex gas treatment, as well as maintaining the field plume in a hydrate-free operating mode. In this regard, the considered mathematical model takes into account the thermal boundary layer and the turbulent core in the gas flow, which occurs when gas is supplied from the well to the field gas collection collector. This model includes the equations of motion in the Navier–Stokes form, the continuity equation, the equation of state of real gas, and the heat conductivity equation taking into account the convective heat transfer. As a result of solving this system of equations numerically and analytically, an expression is obtained for determining the temperature of the field gas collection plume. The paper compares the developed model with the well-known Shukhov formula, which takes into account only one parameter — the change in temperature inside the gas pipeline cavity from the turbulent core to the inner wall, which occurs when natural gas moves from the well to the complex treatment unit. The developed mathematical model has two coefficients: one is responsible for the presence of a turbulent convective core (α), and the other is for the thermal boundary layer (β).

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