Oil and Gas Applications
From Crude to Final Productions
For over 80 years the PECO brand of products has led the way in Oil & Gas filtration solutions. Customers trust the PECO brand for quality and performance to handle complex contaminant management issues. Total cost of filtration is not just about how much a filter costs, but rather how much overall cost of maintenance it can reduce. Adding PECO filtration equipment to your process will diminish contaminant build-up in process equipment, protect critical equipment from damage, help minimize downtime, lower energy consumption, and keep products within spec.
The PECO breadth of products continues to evolve, with safety and innovation in mind. We provide code stamped filter vessels and filter cartridges to service the upstream, midstream and downstream segments of the Oil & Gas market.
Acid Gas Recovery
The objective of the Amine Treating Unit is to remove H2S, CO2 and mercaptan compounds from various gas streams, such as recycled gas in hydrotreating and hydrocracking processes, hydrogen plant feed, and fuel gas systems. The H2S recovered is used as feed for the Sulfur Recovery Unit (SRU).
Gas containing hydrogen sulfide (H2S) is generated as a result of the hydrotreating process. Amine is used for selective removal of H2S often referred to as "Acid Gas."
Acid gas is introduced to the bottom of the absorber (contact tower) while an amine/water combination is introduced at the upper section of the contactor. As the streams circulate and come into contact with one another, the amine removes the acid gas by absorption. The rich amine is then fractionated to separate and remove the hydrogen sulfide. The lean amine, which is stripped of the hydrogen sulfide, is recycled back to the contact tower.
Refinery - Amine Unit
Acid Gas Recovery Brochure
Explore Parker's filtration solutions ideal for the amine units of refineries.
Amine Unit Application Data Sheet
Download this helpful datasheet describing the filtration and separation equipment essential to the anime unit of the refinery.
Hydrotreating
Commonly used as Feed Preparation Units for downstream Catalytic Processes. Hydrotreating Processes remove impurities such as Sulfur and Nitrogen from Distillate Fuels (Naphtha, Kerosene and Diesel) by treating the feed with Hydrogen at an elevated temperature and pressure in the presence of a catalyst. Hydrotreating has been extended in recent years to atmospheric residuals to reduce the sulfur and metal content of residuals for producing low sulfur fuel oils. The principal impurities removed by this unit are Sulfur, Nitrogen, Oxygen, Olefins, Aromatics, Halogens, and Metals.
All Catalytic Processes such as CCR (Catalytic Reforming), HCU (Hydrocracker Unit), FCC (Fluid Catalytic Cracking), ISOM (Isomerization), ALKY (Alkylation) need the feed to be treated in a Hydrotreater.
Hydrotreating Refinery Map
Hydrotreating Brochure
Learn more about Parker's filtration solutions for hydrotreating units of refineries.
Hydrotreating Unit Application Data Sheet
Download this helpful datasheet describing the filtration and separation equipment essential to the hydrotreating unit of the refinery.
Ethylene
Crude Oil and Natural Gas processed in a refinery and a gas processing plant respectively, produces feedstock such as Ethylene for the downstream petrochemical market segment, a critical intermediary in the production of final products like Poly Ethylene, Poly Propylene etc., which constitutes as key ingredients for many commonly used finished goods. Ethylene is produced by several methods in the petrochemical industry. A primary method is steam cracking (SC) where hydrocarbons and steam are heated to 750–950 °C. This process converts large hydrocarbons into smaller ones and introduces unsaturation. When ethane is the feedstock, ethylene is the product.
Ethylene Brochure
Learn more about the ethylene process, including cracking and separation filtration solutions.
Ethylene Process Application Sheet
Take a closer look at Parker's filtration solutions for the ethylene process.
Natural Gas Dehydration
The objective of a Glycol (TEG) Dehydration system is to remove water (H2O) from Natural Gas. Natural Gas typically contains a high concentration of water. Water in the gas stream can cause many issues if not removed shortly after being withdrawn from the well bore. Without dehydration, dissolved water can drop out of the gas phase forming free water causing upsets, fouling, and corrosion in downstream process equipment. Depending on the gas composition, dissolved water mixed with the gas can form hydrates at varying pressures and temperatures plugging off equipment and causing costly failures. To protect against these potential issues, most customers require the water moisture content not to exceed 7 lbs/MMscf.
Glycol Dehydration System
Natural Gas Dehydration Brochure
Learn more about Parker's filtration solutions for Glycol Dehydration.