Liquified Petroleum Gas, often referred to as LPG, is a type of flammable hydrocarbon gas like propane, butane, or a mixture of these gases. When stored under pressure, LPG becomes a liquid which allows for easy transportation and storage. LPG poses numerous hazards ranging from potential leaks and explosions to the dangers posed by improper handling and storage. Liquified petroleum gas is heavier than air and will flow along floors and tend to settle in low spots, such as basements. This could cause an explosion if the mixture of LPG and air is within its explosive limits and there is an ignition source. Workers can be at risk of suffocating if the gas displaces air and reduces the oxygen concentration in the area. Hazardous exposure to LPG can happen by inhalation, skin, and eye contact. Excess pressure due to overfilling, temperature changes, corrosion, a faulty pressure relief valve, or a malfunctioning regulator can lead to leakage, container rupture, damage to connected equipment, or even explosion. Because of these hazards, adequate training must be provided to all workers who may handle compressed or liquified gas cylinders or who will be working near LPG tanks. Appropriate PPE, especially eye and hand protection, should be worn when connecting and disconnecting LPG to or from hoses. Take care when choosing a storage location for liquified petroleum gas. The containers should not be located in any area that has a risk of experiencing excessive heat, tampering by unauthorized persons, or physical damage by passing or falling objects. It’s best to store LPG cylinders at least 20 feet away from the building in an area that is protected from rain, like an open-air cage with floor and a roof. LPG cylinders should not be stored (even temporarily) near exits, stairways, or any other high-traffic areas. Protect stored LPG cylinders from falling by using a support system, like a chain. Consider securing each container individually for easy and safe removal. LPG cylinders should not be rolled, dropped, dragged along the floor, or allowed to bang against other objects. LPG cylinders should be placed in a such a way that the relief valve is in direct contact with the vapor space in the container. LPG cylinders, like propane, may generally be stored in a vertical position. When propane cylinders used to fuel forklifts are placed horizontally the relief device must be at the top. When not in use, the valve on the LPG container should be closed to avoid a potential leak. Do not use excessive force when opening or closing the valve. Carry and transport liquified petroleum gas cylinders in a vertical position, with the valves closed. It is best if the LPG containers have some amount of ventilation while being transported. The LPG cylinders must not be left inside a closed vehicle during hot weather if there is a chance of excessive heat build-up. When transporting an LPG cylinder in a vehicle, it’s generally okay to lay it down but it’s always best to keep it standing up and secured, if possible. Never ask a passenger to hold onto an LPG container. Always transport LPG cylinders in the trunk or cargo area of the vehicle.

Corrosion typically happens when materials are exposed to an aggressive environment, which results in a degradation of material. Corrosion testing calculates the material's resistance to corrosion under certain environmental conditions, such as humidity and temperature. The process is measured and analysed to determine the likelihood of corrosion. We can test a variety of metal types, including duplex and austenitic stainless steels and wrought nickel-rich chromium-bearing alloys. Our Metallurgical Department offers several different corrosion testing methods, including Intergranular Corrosion Testing (IGC), Pitting Corrosion Testing, and Rate Corrosion Testing. We work to the following testing standards: Pitting and crevice corrosion testing to ASTM G48 (Method A) and ASTM A923 Method C* Intergranular corrosion tests (ICC) to ASTM A262 Practice A, C and E and BS EN ISO 3651-2 Method A and ASTM G28 (Method A).

Well servicing encompasses all the work on an oil well after drilling until capping. Because servicing includes maintenance and repairs on the well's structure or components, a separate team headed by the well services supervisor oversees these tasks. All tasks involved in well servicing ensure that the oil continues to flow and the well components function as expected. Well servicing involves many types of work. Sometimes the well can continue to operate while it undergoes servicing. In some instances, shutting down production can result in better flow following the changes, making the workover effort worth the temporary stoppage. Since each well's situation differs, and various well servicing tasks will be needed at different times. Well servicing encompasses all the work on an oil well after drilling until capping. Because servicing includes maintenance and repairs on the well's structure or components, a separate team headed by the well services supervisor oversees these tasks.Well servicing is an essential part of operating an oil or gas well. Servicing encompasses the tasks done during the rest of the life of the well after drilling. Therefore, it is essential to keep up with these maintenance activities. Regular servicing can prevent problems before major disruptions occur. Understanding the basics of well maintenance and services will give you a better appreciation for these tasks during the well's production life. Well work, also known as well interventions, includes any repairs or changes needed to improve the well's operation. This type of service includes light and heavy interventions. Light interventions typically fall to the well service crew. These types of well work do not require the well to stop pumping. Instead, crews may conduct operations such as using wireline or coiled tubing to prevent future blockages. In some cases, light interventions may include collecting data from the bottom of the well or adjusting pumps and valves downwell. The other type of well work is heavy intervention, which also goes by the term workover.

Gas conditioning Gas conditioning involves a series of treatments like dehydration, sweetening, and fractionation to eliminate impurities and make the gas suitable for its intended applications. These processes help prevent pipeline blockages, equipment corrosion, reduced flow rates, increased energy consumption, and potential system failures, ensuring a reliable and optimized natural gas supply for various industries and consumers. Dehydration involves removing moisture from the gas stream to prevent the formation of hydrates, which can cause pipeline blockages. Sweetening involves removing acid gases that can corrode pipelines and equipment and harm the environment. Fractionation involves separating the heavier hydrocarbons from the natural gas to meet specific product specifications. During the gas conditioning process, removing at least 99.5% of the particles and impurities present in the natural gas stream is necessary for many critical reasons. Safety and Compliance: Impurities in natural gas can pose safety risks and regulatory compliance issues. For example, acid gases like hydrogen sulfide can be toxic and corrosive, posing health hazards to workers and causing damage to equipment and infrastructure. Removing a significant portion of these impurities makes the gas safer to handle, transport and utilize in various applications. Efficiency and Performance: Impurities in natural gas can have detrimental effects on the efficiency and performance of gas processing and utilization systems. Liquid droplets and particulate matter can cause blockages in pipelines, reducing the flow rates, and hindering the system’s overall performance. By removing a substantial portion of these particles, the gas can flow smoothly, maximizing its utilization efficiency and ensuring optimal system performance. Product Quality: Impurities can affect the quality and specifications of natural gas required for specific applications. For instance, heavy hydrocarbons can impact the energy content and combustion characteristics of the gas, affecting its performance in gas turbines or other combustion processes. By achieving a high removal rate of impurities, the resulting gas meets the desired quality standards, ensuring consistent and reliable performance in various industrial and commercial applications. Environmental Considerations: Some impurities in natural gas, such as sulfur compounds, contribute to air pollution and environmental degradation when released into the atmosphere. By removing a significant portion of these impurities, the gas conditioning process helps reduce emissions and minimize the environmental impact associated with natural gas production, transportation, and utilization.

Two Phase Separators Two-phase separator is also called gas-liquid separator. As its name suggests, it is used for separating gas and liquid in wet gas stream, or more generally the gas/liquid stream, when the complex liquid phase components are not required to be separated from each other.

Working Guide to Drilling Equipment and Operations offers a practical guide to drilling technologies and procedures. The book begins by introducing basic concepts such as the functions of drilling muds; types of drilling fluids; testing of drilling systems; and completion and workover fluids. This is followed by discussions of the composition of the drill string; air and gas drilling operations; and directional drilling. The book identifies the factors that should be considered for optimized drilling operations: health, safety, and environment; production capability; and drilling implementation. It explains how to control well pressure. It details the process of fishing, i.e. removal of a fish (part of the drill string that separates from the upper remaining portion of the drill string) or junk (small items of non-drillable metals) from the borehole. The remaining chapters cover the different types of casing and casing string design; well cementing; the proper design of tubing; and the environmental aspects of drilling.

Oil and gas well tubing strings must be designed to withstand the forces and stresses generated by the anticipated service conditions over the operating life of the well. In addition, if the tubing is free to move, tubing length changes must be determined so that adequate seal assembly lengths are selected. This section is designed to help the completion engineer in understanding the reasons and consequences of the stresses and strain caused to the tubing and guide him/her through the tubing stress analysis process. Introduction: The cost of tubulars and completion components is often a large portion of the total well cost and can be as high as 20% of the total. The tubing and the completion form an integral part of the safety of the well. Failure of the completion can result in injuries, fatalities, major expenditure and considerable loss of production. Tubing stress analysis is a major requirement of any completion design. Since the calculations involved in the analysis procedure are complex, a computer program is used in determining the optimum tubing design. Consequently, it is no longer necessary for the designer to perform hand calculations to analyse tubing string stress and strain. However, an understanding of the calculations and procedure is required to properly utilise the tubing analysis computer model. Computer analysis liberates the designer from the drudgery of repetitious calculations due to the all the permutations of prognosed data available and optional completion designs so that he or she can concentrate on achieving a more accurate estimate of the service conditions. The tubing stress analysis computer program in use by BP worldwide is Enertech’s WellCat package. This document is not intended to be a user manual for such computing packages although reference can be made to the WellCat manual. Keywords: tubing stress analysis, oil and gas industry, drilling

In petroleum refining, the Crude Distillation Unit (CDU), also known as as the Atmospheric Distillation Unit, is usually the first processing equipment through which crude oil is fed. Crude oil is composed of a mixture of hydrocarbons, and the distillation process separates this crude oil into broad categories of its component hydrocarbons, or "fractions," which serve as feedstocks for all other processing units at the refinery.  As oil is being fed into the crude distillation unit, the first thing that happens is the crude is heated to a temperature between 215°F and 280°F (100°C - 137°C).  This allows salts, which can be harmful and corrosive to some equipment, to be removed at the desalter.  The now desalted crude is further heated to temperatures up to 750°F (400°C) as it is fed into the atmospheric distillation tower where the vapors and liquids separate based on the different temperatures at which they boil/condense. At temperatures above 750°F (400°C), the oil would thermally crack, or break apart, which would hinder the distillation process.