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Special Catalytic Reforming Topics
Published in Soni O. Oyekan, Catalytic Naphtha Reforming Process, 2018
To sustain the operations and reliability of the crude unit and minimize corrosion of crude unit overhead section, opportunity crude oils should be fully inspected for chloride types and blended with other crude oils to reduce organic chloride concentrations. Desalter operations should be improved by maintaining water wash at about 5% and at temperatures greater than 250 F to help minimize the concentrations of residual inorganic salts entering furnaces and crude distillation towers. Atmospheric distillation tower overhead sections should also be subjected to efficient neutralizer and filmer chemical treatment programs and adequate water washes. Neutralizer, filmer, and water washes can be applied to the overhead section of the atmospheric distillation unit, as shown in Figure 8.17.(46)
Pilot Testing and Design of an Activated Sludge System for Refinery Wastewater
Published in John W. Bell, Proceedings of the 45th Industrial Waste Conference May 8, 9, 10, 1990, 1991
Edward C. Copeland, James D. Cole
The refinery process operations generate the following wastestreams. The volatilized material from the preflash, crude tower, quench stack, and stabilizer all contain a mixture of water and product in vapor form. As this vapor is condensed, product separates from the water and is returned to the process. The wastewater is split into two streams, one of which is discharged directly to the wastewater treatment system. The remainder is diverted to the desalter. The desalter mixes oil and water intimately to remove dissolved salts and other inorganics from the oil. Water is removed by phase separation and split, with part of it being recycled to the head of the desalter, while the remainder is discharged to the wastewater treatment system.
Modular Systems in Oil Industry
Published in Yatish T. Shah, Modular Systems for Energy and Fuel Recovery and Conversion, 2019
PPE modular oil refining process includes the following [41]: Atmospheric distillation unit (ADU) that separates the different fractions of the crude oil into naphtha, kerosene, diesel, and residuum products according to boiling range. It operates at less than 15 psig.VDU that performs the same function as an ADU, but operates at a pressure of less than zero psig. It produces products such as marine fuel oil (MDO) and asphalt from the ADU residuum (HFO).Catalytic reformer unit (CRU) that produces high-octane gasoline from naphtha.Hydro-desulfurization unit (HDS) that removes sulfur and other impurities from naphtha and distillate fuels.HCU that produces naphtha, kerosene, and diesel from heavy feedstock like VDU distillates.Desalter that removes salt from crude oil prior to distillation to prevent fouling and corrosion.Splitter/stabilizer that separates a feedstock into two products.Flare that combusts any excess vapor released by process equipment.
Quantifying Implications of Deposit Aging from Crude Refinery Preheat Train Data
Published in Heat Transfer Engineering, 2020
Edward Masato Ishiyama, Erik Falkeman, D. Ian Wilson, Simon John Pugh
Preem is the Sweden’s largest refiner with 80% of Swedish refining capacity. The case study presented here is based on a section of the preheat train of its refinery in Göteborg. In the preheat train section, the crude is pumped from storage tanks through a set of shell-and-tube heat exchangers which raise its temperature from ambient to about 130 °C before entering the desalter. The desalter washes the crude with water to remove inorganic impurities. The desalted crude is then pumped and split into five branches through a set of exchangers which heat it to temperatures ranging from about 250 °C to 280 °C. The branches merge and ultimately enter a furnace to receive additional heat before crude entering the distillation column. Figure 1 shows the layout of the section of the preheat train downstream of the desalter. Pressure drop measurements were made at the entrance and exit of each group of exchangers. Three examples of exchanger groups that are discussed here are indicated on the figure (E45, E5AB, and E50ABC). All these units had crude on the tube side. The shell-side streams were LCR (lower circulating reflux), HLGO (heavy light gasoil) and MCR (middle circulating reflux), which are less prone to fouling during cooling, so it was reasonable to assume that fouling was restricted to the tube side. In addition, there was little product-side deposition observed during cleaning of these units.